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218-046
DATA SUBMITTAL COMPLIANCE REPORT 10/26/2018 Permit to Drill 2180460 Well Name/No. GMTU MT6-051-1 Operator CONOCOPHILLIPS ALASKA, INC. API No. 50-103.20771-60.00 MD 15195 TVD 7888 Completion Date 7/14/2018 Completion Status 1-0I1 Current Status 1 -OIL UIC No REQUIRED INFORMATION / Mud Log Noy/ Samples � / No Directional Survey Yes` DATA INFORMATION List of Logs Obtained: GR/ RES NEU/ DEN, CBL (from Master Well Data/Logs) Well Log Information: Log/ Electr Data Digital Dataset Log Log Run Interval OH/ Type Med/Frmt Number Name Scale Media No Start Stop CH Received Comments ED C 29688 Digital Data 62 15196 9/19/2018 Electronic Data Set, Filename: MT6-051-1 Drilling Mechanics Depth Data.las ED C 29688 Digital Data 0 15195 9/19/2018 Electronic Data Set, Filename: MT6-051-1 LTK Memory Drilling Data.las ED C 29688 Digital Data 9/19/2018 Electronic File: MT6-051-1 LTK 21VID Memory Log.cgm ED C 29688 Digital Data 9/19/2018 Electronic File: MT6-051-1 LTK 5MD Memory' Log.cgm ED C 29688 Digital Data 9/19/2018 Electronic File: MT6-051-1 LTK 5TVD Memory . Log.cgm ED C 29688 Digital Data 9/19/2018 Electronic File: MT6-051-1 LTK Memory Drilling Data.dls ED C 29688 Digital Data 9/19/2018 Electronic File: MT6-051-1 Drilling Mechanics ' Depth Log.pdf ED C 29688 Digital Data 9/19/2018 Electronic File: MT6-051-1 LTK 2MD Memory Log.pdf ED C 29688 Digital Data 9/19/2018 Electronic File: MT6-0511 LTK 5MD Memory ' Log.pdf ED C 29688 Digital Data 9/19/2018 Electronic File: MT6-0511 LTK 5TVD Memory Log.pdf ED C 29688 Digital Data 9/19/2018 Electronic File: MT6-051-1 Drilling Mechanics . Time Log Run10.pdf ED C 29688 Digital Data 9/19/2018 Electronic File: MT6-051-1 Drilling Mechanics - Time Log Runt 1.pdf ED C 29688 Digital Data 9/19/2018 Electronic File: MT6-051-1 Drilling Mechanics, Time Log Run12.pdf AOGCC Page I of 3 Friday. October 26, 2018 DATA SUBMITTAL COMPLIANCE REPORT 10/26/2018 Permit to Drill 2180460 Well Name/No. GMTU MT6-051-1 MD 15195 TVD 7888 Completion Date 7/14/2018 ED C 29688 Digital Data ED C 29688 Digital Data ED C 29688 Digital Data ED C 29688 Digital Data Log C 29688 Log Header Scans ED C 29794 Digital Data ED C 29794 Digital Data ED C 29794 Digital Data ED C 29794 Digital Data ED C 29794 Digital Data ED C 29794 Digital Data ED C 29794 Digital Data ED C 29794 Digital Data Log C 29794 Log Header Scans Well Cores/Samples Information: Name INFORMATION RECEIVED Completion Report Production Test Informatior� Geologic Markers/Tops 0 COMPLIANCE HISTORY Completion Date: 7/14/2018 Release Date: 4/20/2018 Description Operator CONOCOPHILLIPS ALASKA, INC. API No. 50-103.20771.60-00 Completion Status 1-0I1 Current Status 1 -OIL UIC No 9/19/2018 Electronic File: MT6-051-1 EOW - NAD27.pdf 9/19/2018 Electronic File: MT6-051-1 EOW - NAD27.txt 9/19/2018 Electronic File: MT6-051-1 EOW - NAD83.pdf 9/19/2018 Electronic File: MT6-051-1 EOW - NAD83.txt 0 0 2180460 GMTV MT6-051-1 LOG HEADERS 10/12/2018 Electronic File: MT6-051-1 EOW - NAD27.pdf 10/12/2018 Electronic File: MT6-051-1 EOW - NAD27.b(t 10/12/2018 Electronic File: MT6-05L1 EOW - NAD83.pdf 10/12/2018 Electronic File: MT6-051-1 EOW - NAD83.txt 10/12/2018 Electronic File: MT6-051-1 EOW - NAD27.pdf 10/12/2018 Electronic File: MT6-051-1 EOW - NAD27.bd 10/12/2018 Electronic File: MT6-051-1 EOW - NAD83.pdf 10/12/2018 Electronic File: MT6-051-1 EOW - NAD83.txt 0 0 2180460 GMTV MT6-051-1 LOG HEADERS Sample Interval Set Start Stop Sent Received Number Comments Directional / Inclination Data G Mud Logs, Image Files, Digital Data Y / J) Core Chips Y /® Mechanical Integrity Test Information pY I NA Composite Logs, Image, Data Files V Core Photographs Y / Daily Operations Summary fY ) Cuttings Samples Y /6A Laboratory Analyses Y /� Date Comments AOGCC Page 2 of Friday, October 26, 2018 DATA SUBMITTAL COMPLIANCE REPORT 10/26/2018 Permit to Drill 2180460 Well Name/No. GMTU MT6-051-1 Operator CONOCOPHILLIPS ALASKA, INC. MD 15195 TVD 7888 Completion Date 7/14/2018 Completion Status 1-0I1- Current Status 1-0I1 Comments: C Compliance Reviewed By: API No. 50-103-20771-60-00 UIC No Date: AOGCC Page 3 of 3 Friday, October 26, 2018 BAER Date: FUGHES a GE company To: Aihy Bell AOGCC 333 West 71h Ave, Suite 100 Anchorage, Alaska 99501 November 28, 2018 From: 21 8046 qq Letter of Transmittal pev b-eA Michael Soper / Yosha Ragbirsingh Baker Hughes, a GE Company 795 East 9411 Avenue Anchorage, Alaska 99515 Please find enclosed the directional survey data for the following well(s): MT6-05PB1 MT6-05PB2 MT6-05 RECEIVED MT6-05L1 NOV 2 9 2018 AOGCC (4) Total prints Enclosed for each well(s): 1 hardcopy print of directional survey reports (NAD27) 1 compact disk containing electronic survey files Note: Please feel free to send an email in place of return mail. Michael Soper, Baker Hughes, Applications Engineer Michael.5oper@BHGE.com P{ 218046 29794 Letter of Transmittal EIIJ Date: — - .. ---— U&ES October 11, 2018 a GE company To: Meredith Guhl AOGCC 333 West 7th Ave, Suite 100 Anchorage, Alaska 99501 From: Michael Soper / Yosha Ragbirsingh Baker Hughes, a GE Company 795 East 941h Avenue Anchorage, Alaska 99515 Please find enclosed the directional survey data for the following well(s): KUPARUK RIVER UNIT GREATER MOOSES TOOTH UNIT 3H -31A MT6-03PH 3H-31AL1 MT6-03 R ec, 1H -21A MT6-05PB1 � " e 1H-21AL1 1H-21AL2 MT6-05PB2VieD OCT 12 MT6-05 2018 1H-21AL2-01 MT6-05L1 AOGcC �71•l• MT6-08PB1 MT6-08 (14) Total prints Enclosed for each well(s): 1 hardcopy print of directional survey reports (NAD27) 1 compact disk containing electronic survey files Note: Please feel free to send us an email in place of return mail. Michael Soper, Baker Hughes, Project Engineer Michael.Soper@BHGE.com Yosha Ragbirsingh, Baker Hughes, Survey Manager ConocoPhillips ConocoPhill ips(Alaska) Inc. -WNS Western North Slope GMT1 Lookout Pad MT6-051-1 50-103-20771-60 Baker Hughes INTEQ Definitive Survey Report 15 August, 2018 218046 BAT(ER UGHES a GE company Phase: ACTUAL Depth From (TVD) (usft) 0.00 5/20/2018 V) 16.50 Tie On Depth: 10,933.50 +NIS (usft) 0.00 +E/ -W (usft) 0.00 Direction V) 320.46 SA ER UGNES 70° 15 22.964 N 151* 28'42.930 W 37.20 usft Field Strength mn 57,422 811512018 5'00:49PM Page 2 COMPASS 5000.14 Build 85 BGGM2017 ConocoPhiilips MT6-05L1 ConocoPhillips Definitive Survey Report Version: Company: Conoco Phillips(Alaska) Inc. -WNS Local Coordinate Reference: Well MT6-05 Project: Western North Slope TVD Reference: MTB -05 Actual @ 88.70usft (Actual D19) Site: GMT1 Lookout Pad MD Reference: MT6-05 Actual @ 88.70usft (Actual D19) Well: MT6-OS North Reference: True Wellbore: MT6-05 Survey Calculation Method: Minimum Curvature Design: MT6-05 Database: EDT 14 Alaska Production Project Western North Slope, North Slope Alaska, United States Map System: US State Plane 1927 (Exact solution) System Datum: Mean Sea Level Geo Datum: NAD 1927 (NADCON CONUS) Map Zone: Alaska Zone 04 Using geodetic scale factor Well MTS -05....._r.._. -,-- Well Position -NI-S 0.00 usft Northing: 5,945, 543.79 usft Latitude: +E/ -W 0.00 usft Easting: 317,059.98 usft Longitude: Position Uncertainty 0.00 usft Wellhead Elevation: 0.00usft Ground Level: Wellbore MT6-0511 Magnetics Model Name Sample Date Declination Dip Angle Phase: ACTUAL Depth From (TVD) (usft) 0.00 5/20/2018 V) 16.50 Tie On Depth: 10,933.50 +NIS (usft) 0.00 +E/ -W (usft) 0.00 Direction V) 320.46 SA ER UGNES 70° 15 22.964 N 151* 28'42.930 W 37.20 usft Field Strength mn 57,422 811512018 5'00:49PM Page 2 COMPASS 5000.14 Build 85 BGGM2017 Design MT6-05L1 Audit Notes: Version: 1.0 Vertical Section: Phase: ACTUAL Depth From (TVD) (usft) 0.00 5/20/2018 V) 16.50 Tie On Depth: 10,933.50 +NIS (usft) 0.00 +E/ -W (usft) 0.00 Direction V) 320.46 SA ER UGNES 70° 15 22.964 N 151* 28'42.930 W 37.20 usft Field Strength mn 57,422 811512018 5'00:49PM Page 2 COMPASS 5000.14 Build 85 ConocoPhillips 6A(ER q ConocoPhilli S UGHES p Definitive Survey Report�� Company: ConomPhillips(Alaska) Inc. -WNS Local Coordinate Reference: Well MTS -05 i Project: Western North Slope TVD Reference: MT6-05 Actual @ 88.70usft (Actual D19) , Site: GMT1 Lookout Pad MD Reference: MT6-05 Actual @1 88.70usft (Actual D19) Well: MT6-05 North Reference: True ; Wellbore: MTS -05 Survey Calculation Method: Minimum Curvature Design: MT6-05 Database: EDT 14 Alaska Production Survey Program Date 8/15/2018 From To Survey Survey (usft) (usft) Survey (Wellbore) Tool Name Description Start Date End Date 60.26 263.26 GYD Gyro DMS 16" (MT6-05PB1) GYD-CT-DMS Gyrodata cont.drillpipe m/s 5/13/2018 5/13/2018 296.26 1,957.96 BHGE MWD -IFR -MSA 16" (MT6-05PB1 MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 5/15/2018 2,050.54 8,894.81 BHGE MWD+IFR+MSA 12-1/4"(MT6-05 MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 5/21/2018 8,968.80 10,933.50 BHGE MWD+IFR+MSA 6x8-3/4"(MT6-0 MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 6/4/2018 i10,939.00 11,114.28 BHGE MWD INC 6" (MT6-051-1) MWD-INC_ONLY (INC>10') MWD-INC_ONLY_FILLER ( INC>10") 7/10/2018 11,165.98 15,165.21 BHGE MWD+CA+MSA 6"(MT6-051-1) MWD+IFR-AK-CAZ-SC MWD+IFRAKCAZSCC 7/10/2018 Survey ----- ...... 1 Map Map Vertical MD Inc Azi ND NDSS -NI-S +E/ -W Northing Easting OLS ti Section (usft) (usft) (usft) (usft) (9100') Survey Tool Name ADDOt8ti0n (ft) Iftl 36.50 0.00 0.00 36.50 52.20 0.00 0.00 5,945,543.79 317,059.98 0.00 0.00 UNDEFINED 60.25 0.33 231.64 60.26 -28.44 -0.04 -0.05 5,945,543.75 317,059.93 1.39 0.00 GYD-CT-DMS(1) 161.76 0.36 194.38 161.76 73.06 -0.53 -0.36 5,945,543.27 317,059.61 0.22 -0.18 GYD-CT-DMS(1) 263.26 0.56 211.72 263.25 174.55 .1.26 -0.70 5,945,542.54 317,059.25 0.24 -0.53 GYD-CT-DM8(1) E 296.26 0.96 224.50 2%.25 207.55 -1.60 -0.98 5,945,542.22 317,058.96. 1.31 -0.61 MWD-IFR-AK-CAZ-SC (2) 390.15 1.24 252.95 390.13 301.43 -2.46 -2.50 5,945,541.40 317,057.42 0.64 -0.30 MWD+IFR-AK-CAZ-SC(2) 483.51 2.22 291.97 483.44 394.74 -2.08 5.15 5,945,541.84 317,054.79 1.58 1.67 MWD+IFR-AK-CAZ-SC(2) 577.56 3.84 299.00 577.36 488.66 0.13 A.59 5,945,544.16 317,050.40 7.76 6.21 MWD+IFR-AK-CAZ-SC (2) 672.51 5.48 303.35 671.99 583.29 4.17 -16.16 5,945,548.35 317,043.93 1.77 13.50 MWD+IFR-AK-CAZ-SC (2) 766.06 7.00 W,1.80 764.99 676.29 9.88 .24.57 5,945,554.26 317,035.66 1.63 23.26 MWD+IFR.AK-CAZ-SC (2) j 860.61 8.03 306.69 858.72 770.02 17.11 -34.60 5,945,561.73 317,025.81 1.12 35.22 MWD+IFR.AK-CAZ-SC (2) ; 955.24 8.96 307.34 952.31 863.61 25.53 45.76 5,945,570.42 317,014.86 0.99 48.82 MWD+IFR-AK-CAZ-SC (2) 1,048.71 10.08 308.87 1,044.50 955.80 35.08 57.91 5,945,580.26 317,002.94 1.23 63.92 MWD+IFR-AK-CAZ-SC (2) 1,143.88 11.57 309.42 1,137.97 1,049.27 46.36 -71.77 5,945,591.88 316,989.36 1.57 81.45 MWD+IFR-AK-CAZSC(2) 1,238.25 12.95 310.96 1,230.19 1,141.49 59.31 437.07 5,945,605.19 316,974.39 1.50 101.16 MWD+IFR-AK-CAZSC (2) 1,332.92 14.13 310.53 1,322.22 1,233.52 73.77 -103.86 5,945,620.06 316,957.95 1.25 123.01 MWD+IFR-AK-CAZSC(2) 1427.45 14.70 308.04 1,413.78 1,325.08 8866 -122.08 5,945,635.38 316,990.10 0.89 146.09 MNN+IFR-AK-CAZ-13C (2) i 1,521.38 15.39 305.44 1,504.49 1,415.79 103.23 -141.62 5,945,650.42 316,920.92 1.03 16977 MWD+IFR-AK-CAZSC(2) 8/15@018 5:00:49PM Page 3 COMPASS 5000.14 Build 85 ConoCoPhillips ConocoPhillips Definitive Survey Report Company: ConocoPhillips(Alaska) Inc. -WNS Local Coordinate Reference: Well MT&05 Project: Western North Slope TVD Reference: MT6-05 Actual @ 88.70usft (Actual D19) Site: GMT1 Lookout Pad MD Reference: MT6-05 Actual @ 88.70usft (Actual D19) Well: MT6-05 North Reference: True Wellbore: MT6-05 Survey Calculation Method: Minimum Curvature Design: MTS -05 Database: EDT 14 Alaska Production Survey (usR) V) B%R 811542018 5:00:49PM Page 4 COMPASS 5000.14 Build 85 Map Map Vertical MD Inc Azl TVD TVDSS +NI -S +EI -W Northing Easting DLS Section Section (usR) V) (°) (usft) (usft) (usR) (usft) (°/100') Survey Tool Name Annotation (ft) (@) 1,616.89 14.91 304.96 1,596.68 1,507.98 117.62 -162.02 5,945,665.30 316.900.88 0.52 193.85 MWD+IFR-AK-CA7-SC(2) 1,710.53 15.15 305.97 1,687.11 1,598.41 131.71 -181.79 5,945,679.87 316,881.46 0.38 217.30 MWD+IFR-AK-CAZ-SC (2) 1.8()U7 16.55 306.15 1.778.73 1,690.03 147.03 -202.82 5,945,695.69 316,860.80 1.48 242.51 MWD+IFR-AK-CAZ-SC (2) 1.899.91 18.01 307.58 1,868.62 1,779.92 163.82 -225.19 5,945,713.02 316,838.85 1.60 269.69 MWD+IFR-AK-CAZ-SC (2) 1,957.96 18.83 308.11 1,923.69 1,834.99 175.07 -239.68 5,945,724.62 316824.64 1.44 287.59 MWD+IFR-AK-CAZ-SC(2) 2,014.00 19.29 307.93 1,976.66 1,887.96 186.34 -254.09 5,945,736.24 316,810.51 0.83 305.46 MWD+IFR-AK-CAZ-SC (3) 13-3/8" X 16" 2,050.54 19.59 307.82 2,011.12 1,922.42 193.81 -263.69 5,945,743.94 316,801.09 0.83 317.33 MWD+IFR-AK-CAZSC(3) 2,089.52 20.21 307.93 2,047.77 1,959.07 201.96 -274.16 5,945,752.33 316790.82 1.59 330.28 MWD+IFR-AK-CAZSC(3) 2,183.73 22.60 308.62 2,135.47 2,046.77 223.26 -301.15 5,945,774.29 316,764.37 2.55 363.89 MWD+IFR-AK-CAZSC(3) 2,278.30 25.23 308.60 2,221.92 2,133.22 247.18 -331.10 5,945,798.93 316,735.00 278 401.41 MWD+1FR-AK-CAZSC(3) 2,372.40 26.72 308.06 2,306.51 2,217.81 272.74 4163.43 5,945,825.26 316,703.30 1.60 44170 MWD+IFR-AK-CAZSC(3) 2,467.33 27.46 308.78 2,391.02 2,362.32 299.60 4197.30 5,945,852.94 316,670.10 0,a5 483.98 MWD+IFR-AK-CAZSC(3) 2,559.45 29.82 306.63 2,471.87 2,383.17 326.58 132.25 5,945,880.75 316,635.82 2.80 527.02 MWD+IFR-AK-CAZSC(3) 2,651.10 30.86 306.4] 2,550.97 2,462.27 354.15 469.44 5,945,909.21 316,599.32 1.14 571.96 MWD+IFR-AK-CAZSC(3) 2,744.71 31.74 307.31 2,630.95 2,542.25 383.34 -508.33 5,945,939.34 316,561.15 1.05 619.24 MWD+IFR-AK-CAZ-SC(3) 2,839.16 32.22 307.74 2,711.07 2,622.37 413.81 548.00 5,945,970.76 316,522.23 0.56 667.99 MWD+IFR-AK-CAZ-SC(3) 2,933.95 32.30 307.89 2,791.22 2,702.52 444.83 587.97 5,946,002.74 316,483.03 0.12 717.36 MWD+IFR-AK-CAZSC(3) 3,028.87 32.99 308.00 2,871.15 2,782.45 476.32 628.35 5,946,035.20 316443.43 0.73 767.34 MWD+IFR-AK-CAZ-SC(3) 3,123.33 33.57 307.67 2,950.12 2,861.42 508.11 569.28 5,946867.97 316,403.28 0.64 817.92 MWD+IFR-AK-CAZ-SC (3) 3,217.41 34.79 307.16 3,027.95 2,939.25 540.22 -711.27 5,946101.09 316,362.09 1.33 869.41 MWD+IFR-AK-CAZ-SC (3) 3,311.94 35.52 307.03 3,105.23 3,016.53 573.05 -754.68 5,946,134.96 316,319.49 0.78 922.36 MWD+IFR-AK-CAZ-SC (3) 3,406.49 36.25 307.26 3,181.84 3,093.14 606.51 -798.86 5,946,169.49 316,276.14 079 976.30 MWD+IFR-AK-CAZ-SC (3) 3,500.89 36.47 306.40 3,257.86 3,169.16 640.06 -643.65 5,946204.11 316,232.18 0.59 1,DW.68 MWD+IFR-AK-CAZSC(3) 3,594.37 37.06 306.99 3,332.75 3,244.05 673.49 688.51 5,946,238.62 316,188.14 0.74 1,085.03 MWD+IFR-AK-CAZSC(3) 3,688.55 37.67 306.99 3,407.60 3,318.90 707.88 -934.17 5,946,274.11 316,143.34 0.65 1,140.61 MWD+IFR-AK-CAZ-SC(3) 3,783.05 39.95 304.39 3,481.23 3,392.53 742.40 -982.28 5,946,309.78 316,096.09 2.97 1,197.86 MWD+IFR-AK-CAZ-SC(3) 3,B77.30 40.94 303.28 3,552.96 3,464.26 776.44 -1,033.06 5,946,345.04 316,046.14 1.30 1,255.44 MWD+IFR-AK-CAZSC(3) 3,971.83 40.95 303.40 3,624.36 3,535.66 810.49 -1,084.82 5,946,380.33 315,995.24 0.08 1,315.64 MWD+IFR-AK-CAZSC(3) 4,065.45 40.97 303.86 3,695.06 3,606.36 844.47 -1,135.92 5,946,415.55 315,944.9B 0.32 1,374.39 MWD+IFR-AK-CAZ-SC(3) 4,159.82 42.09 304.09 3,765.71 3,677.01 879.44 -1,187.80 5,946,45176 315,893.96 1.20 1,434.38 MWD+IFR-AK-CAZ-SC(3) 4,25403 4341 3D540 3,834.89 3,746.19 915.89 -1,240.34 5,946,489.48 315,842.33 169 149594 MWD+IFR-AK-CAZ-SC(3) 811542018 5:00:49PM Page 4 COMPASS 5000.14 Build 85 survey BAii1HEs MD ConocoPhillips Azi ConocoPhillips Definitive Survey Report +Nl-$ Company: ConocoPhillips(Alaska) Inc. -WNS Local Coordinate Reference: Well MT6-05 Project. Western North Slope TVD Reference: MT6-05 Actual @ 88.70usft (Actual 131! Site: GMT1 Lookout Pad MD Reference: MT6-05 Actual @ 88.70usft (Actual D7! Well: MT6-05 North Reference: True Wellborn; MT6-05 Survey Calculation Method: Minimum Curvature Design: MTS -05 Database: EDT 14 Alaska Production survey BAii1HEs MD Inc Azi TVD TVDSS +Nl-$ +El -W Map Map. DLS Vertical (usft) (°) 11 (ueft) (usft (ueft) (usR) Northing Easting (=)1880 Section Survey Tool Name Annotation (ft) (ft) (ft) 4,345.97 44.99 306.85 3,900.80 3,812.10 953.69 -1,292.10 5,946,528.52 315,791.50 2.04 1,558.04 MWD+IFR-AK-CAZSC(3) 4,444,53 45.64 305.62 3,970.11 3,881.41 995.60 -1,348.26 5,946,571.78 315,736.38 0.68 1,626.11 MWD+IFR-AK-CAZSC(3) 4,544.01 45.62 306.31 4,039.67 3,950.97 1,037.86 -1,405.45 5,946,615.42 315,680.24 0.22 1,695.11 MWD+IFR-AKCAZSC(3) 4,639.51 45.64 306.01 4,106.46 4,017.76 1,078.14 -1,460.57 5,946,657.02 315,626.12 0.23 1,761.26 MWD+IFR-AK-CAZSC(3) 4,732.20 45.63 305.04 4,171.27 4,082.57 1,116.65 -1,514.50 5,946,696.82 315,573.15 0.75 1,825.29 MWD+IFR-AK-CAZSC(3) 4,824.17 45.60 304.58 4,235.60 4,146.90 1,154.17 -1,568.46 5,946,735.64 315,520.11 0.36 1,888.58 MWD+IFR-AK-CAZSC(3) 4,918.72 45.65 303.65 4,301.72 4,213.02 1,192.07 -1,624.42 5,946,774.89 315,465.10 0.71 1,953.43 MWD+IFR-AK-CAZ-SC (3) 5,012.80 45.66 304.08 4,367.47 4,278.77 1,229.57 -1,680.29 5,946,813.73 315,410.16 0.33 2,017.92 MWD+IFR-AK-CAZ-SC (3) 5,106.80 45.61 304.63 4,433.20 4,34450 1,267.49 -1,735.77 5,946,852.98 315,355.62 0.42 2,082.48 MWD+IFR-AK-CAZ-SC 13) 5,201.23 45.65 304.35 4,499.23 4,410.53 1,305.71 -1,791.40 5,946,892.64 315,300.93 0.22 2,147.38 MWD+IFR-AK-CAZ-SC (3) 5,295.79 45.60 304.6 4,565.36 4,476.66 1,343.71 -1,847.30 5,946,931.88 315,245.97 0.23 2,212.26 MWD+IFR-AK-CAZ-SC(3) 5,390.61 45.38 303.84 4,631.84 4,543.14 1,381.47 -1,903.39 5,946,971.00 315,190.82 0.28 2,277.10 MWD+IFR-AK-CA7-SC(3) 5,483.33 45.32 304.10 4,697.00 4,608.30 1,418.33 -1,958.10 5,947,009.17 315,137.03 0.21 2,340.34 MWD+IFR-AK-CAZSC(3) 5,578.13 45.23 304.42 4,763.71 4,675.01 1,456.25 -2,013.77 5,947,048.42 315,082.30 0.26 2,405.02 MWD+IFR-AK-CAZSC(3) 5,672.39 45.10 304.91 4,830.17 4,741.47 1,494.26 -2,068.74 5,947,087.76 315,028.27 0.39 2,469.34 MWD+IFR-AKCAZSC(3) 5,766.67 45.12 306.17 4,895.71 4,808.01 1,533.09 -2,123.09 5,947,127.89 314,974.88 0.95 2,533.88 MWD+IFR-AKCAZSC(3) 5,861.26 45.8 307.02 4,963.48 4,874.78 1,573.03 -2,176.88 5,947,169.13 314,922.08 0.64 2,598.93 MWD+IFR-AK-CAZ-SC(3) 5,953.99 45.13 307.58 5,028.93 4,940.23 1,612.84 -2,229.14 5,947,210.19 314,870.81 0.43 2,662.90 MWD+IFR-AK-CAZ-SC (3) 6,048.44 45.04 307.59 5,095.61 5,006.91 1,653.63 -2,282.14 5,947,252.26 314,818.82 0.10 2,728.10 MWD+IFR-AK-CAZ-SC (3) 6,142.51 45.05 30290 5,162.08 5,073.38 1,694.38 -2,334.78 5,947,294.27 314,767.19 0.23 2,793.04 MWD+IFR-AK-CAZ-SC(3) 6,235.05 45.06 307.01 5,227.45 5,138.75 1,734.21 -2,386.78 5,947335.35 314,716.18 0.68 2,856.85 MWD+IFR-AK-CAZ-SC(3) 6,329.17 45.06 306.63 5,293.94 5,205,24 1,774.14 -2,440.11 5,947376.56 314,663.83 0.29 2,921.60 MWD+IFR-AK-CAZSC(3) 6,423.63 45.08 306.42 5,360.65 5,271.95 1813.94 -2,493.85 5,947,417.65 314,611.08 0.16 2,986.50 MWD+IFR-AK-CAZ-SC(3) 6,517.70 45.12 306.32 5,427.05 5,338.35 1,853.46 -2,547.50 5,947458.46 314,558.40 0.09 3,051.13 MWD+IFR-AKCAZSC(3) 6,612.19 4505 306.15 5,493.76 5,405.06 1,893.01 -2,601.47 5,947,499.31 314,505.41 0.15 3,115.99 MM+IFR-AKCAZSC(3) 6,706.20 45.08 306.10 5,560.16 5,471.46 1,932.24 -2,655.23 5,947,539.83 314,452.63 0.05 3,180.47 MWD+IFR-AK-CAZSC(3) 6,801.05 45.11 305.89 5,627.12 5,538.42 1,971.73 -2,709.58 5,947580.62 314,399.25 0.16 3,245.52 MWD+IFR-AKCAZSC(3) 6,896.14 45.10 305.70 5,694.24 5,605.54 2,011.13 -2,764.22 5,947,621.33 314,345.59 0.14 3,310.69 MWD+IFR-AKCAZSC(3) 6,991.21 45.07 305.68 5,761.36 5,672.66 2,050.40 -2,818.90 5,947,661.92 314,291.89 0.03 3,375.79 MWD+IFR-AK-CAZSC(3) 7,085.78 45.08 305.19 5,828.15 5,739.45 2,089.22 -2,873.46 5,947,702.06 314,238.29 0.37 3,440.46 MWD+IFR.AK-CAZSC(3) 7,179.83 45.10 30501 5,894.55 5,80585 2,127.52 -2,927.95 5,947,741.66 314,18075 0.14 3,50469 MWD+IFR-AK-CAZ-SC(3) 871512018 5:00.49PM Page 5 COMPASS 5000.14 Build 85 ConocoPhillips u�REs 0 ConocoPhillips Definitive Survey Report Company: ConocoPhillips(Alaska) Inc. -WNS . Project: Western North Slope Site: GMT1 Lookout Pad Well: MT6-05 Wellbore: MT6-05 Design: MTS -05 Survey Local Coordinate Reference: Well MT6-05 TVD Reference: MT6-05 Actual @ 88.70usft (Actual D19) MD Reference: MT6-05 Actual @ 88.70usft (Actual D19) North Reference: True Survey Calculation Method: Minimum Curvature Database: EDT 14 Alaska Production $1152018 600.49PM Page 6 COMPASS 5000.14 Build 85 Map Map Vertical MD Inc Azi TVD TVDSS *NI -S +E/ -W Northing Easting DLS Section (usft) (1) (1) (usft) (usft) (usft) (usft) (°1100') Survey Tool Name Annotation (ft) (ft) (ft) 7,273.52 45.05 304.86 5,960.71 5,872.01 2,165.51 -2,982.33 5,947,780.96 314,131.31 0.13 3,568.60 MWD+IFR-AK-CAZSC(3) 7,368.38 45.09 305.02 6,027.70 5,939.00 2,203.97 -3,037.39 5,947,820.74 314,077.21 0.13 3,633.31 MWD+IFR-AK-CAZSC(3) 7,462.04 45.09 305.22 6,093.82 6,005.12 2,242.13 -3,091.64 5,947,860.21 314,023.90 0.15 3,697.28 MWD+FR-AK-CAZSC(3) 7,555.32 45.01 304.78 6,159.73 6,071.03 2,280.00 -3,145.72 5,947,899.37 313,970.76 0.34 3,760.91 MWD+IFR-AK-CAZ-SC(3) 7,649.62 45.05 304.53 6,226.37 6,137.67 2,317.94 -3,200.60 5,947,938.63 313,916.82 0.19 3,825.10 MWD+IFR-AK-CAZSC(3) 7,742.03 45.23 305.35 1 6,202.85 2,355.45 -3,254.29 5,947,977.43 313,86406 0.66 3,888.21 MWD+IFR-AK-CAZSC(3) 7,836.64 45.26 305.81 6,358.17 6,269.47 2,394.54 -3,308.93 5,948,017.84 313,810.38 0.35 3,953.15 MWD+IFR-AK-CAZSe(3) 7,930.75 45.27 305.88 6,424.41 6,335.71 2,433.69 5,363.13 5,948,058.29 313,757.16 0.05 4,017.84 MWD+IFR-AK-CAZSC(3) 8,024.98 45.26 306.66 6,490.73 6,402.03 2,473.29 -3,417.09 5,948,099.19 313,704.18 0.59 4,082.73 MWD+IFR-AK-CAZSC(3) 8,118.93 45.30 307.04 6,556.84 6,468.14 2,513.32 -3,470.51 5,948,140.50 313,651.75 0.29 4,147.61 MWD+IFR-AK-CAZSC(3) 8,212.40 45.10 306.82 6,622.70 6,534.00 2,553.17 -3,523.53 5,948,181.63 313,599.72 0.27 4,212.10 14WD+IFR-AKCAZSC(3) 8,306.99 45.06 306.73 6,689.49 6,600.79 2,593.27 -3,577.18 5,948,223.01 313,547.06 0,08 4,277.17 MWDAFR-AKCAZSC(3) 8,401.40 45.07 306.06 6,756.17 6,667.47 2,632.93 -3,630.98 5,948,263.96 313,494.25 0.50 4,342.00 MWD+IFR-AKCAZSC(3) 8,495.22 45.06 305.99 6,822.44 6,733.74 2,671.99 -3,684.69 5,948,304.31 313,441.50 0.05 4,406.32 MWD+IFR-AKCAZSC(3) 8,589.86 45.02 305.60 6,889.31 6,800.61 2,711.16 -3,739.01 5,948,344.79 313,388.15 0.29 4,471.11 MWD+IFR-AKCAZSC(3) 8685.37 45.05 305.58 6,956.81 6,868.11 2,750.49 -3,793.96 5,948,385.44 313,334.18 003 4,536.42 MWD+IFR-AKCAZ-SC(3) 8,779.66 45.06 306.70 7,023.42 6,934]2 2,78904 43,847,86 5,948,426.09 313,281.26 0.84 4,601.08 MWD+IFR-AKCAZSC(3) 8,874.41 45.05 307.12 7,090.35 7,001.65 2,830.12 -3,901.48 5,94$467.65 313,228.63 0.31 4,665.28 MWD+11FR-AKCAZ-SC(3) 8,894.81 45.04 30255 7,104.76 7,016.06 2,838.87 -3,912.96 5,941 313,217.37 1.49 4,680.34 MWD+IFR-AKCAZSC(3) 8,913.12 45.07 307.75 7,117.70 7,029.00 2,846.79 -3,923.22 5,948,484.85 313,207.30 0.78 4,692.98 MWD+IFR-AKCAZSC(4) 9-5/8"X12-1/4" 8,968.80 45.18 308.34 7,156.98 7,068.28 2,871.11 -3,954.29 5,948,509.91 313,176.83 0.78 4,731.51 MWD+IFR-AKCAZSC(4) 9,049.52 44.64 308.19 7,214.15 7,125.45 2,906.40 5,999.04 5,948,546.27 313,132.96 0.68 4,787.21 MWD+IFR-AKCAZ-SC(4) 9,143.80 45.26 308.27 7,280.87 7,192.17 2,947.62 4,051.% 5,948,588.75 313,081.66 0.66 4,852.31 MWD+IFR-AK-CAZ-SC(4) 9,238.18 45.65 309.51 7,347.08 7,258.38 2,989.85 -4,10371 5,948,632.24 313,030.35 1.02 4,918.20 MWD+IFR-AK-CAZ-SC (4) 9,332.26 48.4 311.66 7,411.19 7,322.49 3,034.66 4,155.97 5,998,6]8.30 312,979.20 3.40 4,986.03 MWD+IFR-AK-CAZ-SC (4) 9,426.43 51.49 311.06 7,471.75 7,383.05 3,082.29 4,210.09 5,998,727.23 312,926.26 3.28 5,057.21 MWD+IFR-AK-CAZ-SC (4) 9,519.61 54.02 311.03 7,528.14 7,439.44 3,130.99 4,265.03 5,948,777.27 312,871.52 2.72 5,130.38 MWD+IFR-AK-CAZSC(4) 9,614.22 55.94 310.88 7,582.44 7,493.74 3,181.78 4324.54 5,948,829.46 312,814.26 2.03 5,206.80 MWD+IFR-AK-CAZSC(4) 9,706.62 59.30 312.69 7,63191 7,543.21 3,233.78 4,382.70 5,948,882.85 312,757.39 3.99 5,283.93 MWD+IFR-AKCAZSC(4) 9,80105 61.09 315.59 7,678.86 7,590.16 3,290.84 4,441.48 5,948,941.33 .312700.01 3.27 5,36535 MWD+IFR-AK-CAZSC(4) 9,895.24 63.67 318.04 7,722.52 7633.82 3,351.70 4498.56 5,94900355 312,644.43 3.58 5,44862 MW +IFR-AK-CAZ-SC(4) $1152018 600.49PM Page 6 COMPASS 5000.14 Build 85 ConocoPhillips Ere ConocoPhillips Definitive Survey Report kUGHES Company: Project: Site: Well: Wellborn: Design: Survey MD (usft) 9,969.62 10,083.55 10,178.42 10,271.93 10,366.04 10,460.54 10,555.35 10,650.00 10,745.13 10,839.12 10,933.50 10,939.00 11,017.93 11.114.28 11,165.98 11,261.04 11,355.57 11,450.97 11,546.74 11,641.91 11,722.27 11,736.95 11,832.03 11,927.45 12,023.13 12,118.47 12,213.86 12,309.33 12,403.76 12,499.21 12,594.99 ConomPhillips(Alaska) Inc. -WNS Western North Slope GMT1 Lookout Pad MT6-05 MT6-05 MT6-05 Inc 65.86 68.49 71.79 73.35 75.73 77.60 79.69 81.37 82.41 82.85 82.85 82.85 88.35 %.19 96.45 93.41 90.99 90.97 90,44 90.04 90.05 90.05 89.98 89.98 91.65 92.01 93.12 92.96 93.00 92.96 93.03 Local Coordmate Reference: Well MT6-05 TVD Reference: MT6-05 Actual @ 88.70usft (Actual D19) MD Reference: MTB05 Actual @ 88.70usft (Actual D19) North Reference: True Survey Calculation Method: Minimum Curvature Database: EDT 14 Alaska Production Annotation TIP to MT6-05PB7 KOPTOWS Interpolated Azimuth Interpolated Azimuth MT6-0511 T7.9 (copy) 8/152018 5: 00:49PM Page 7 COMPASS 5000.14 Build 85 Map Map Vertical Azl TVD TVDSS +N/S +EI -W NorthingEastin 9 DLS Section Survey Tool Name (°) (usft) (usft) (usft) (usft) (ft) (ft) (°/100') (ft) 320.87 7,762.77 7,674.07 3,416.57 4,554.04 5,949,069.74 312,590.55 3.57 5,533.97 MM+IFR-AK-CAZ-SC(4) 323.03 7,799.20 7,710.50 3,484.75 4,607.37 5,949,139.19 312,538.89 3.51 5,620.50 MWD+1FR-AK-CAZ-SC (4) 324.53 7,831.43 7,742.73 3,556.72 4,660.08 5,949,212.42 312,487.95 3.78 5,709.56 MWD+IFR-AK-CAZ-SC(4) 325.90 7,859.44 7,770.74 3,630.00 -0,710.97 5,949,286.90 312,438.85 2.18 5,798.46 MWD+1FR-AK-CAZ-SC(4) 327.31 7,884.53 7,795.83 3,705.72 4,760.88 5,949,363.81 312,390.80 2.91 5,888.64 MWD+1FR-AK-CAZSC(4) 329.31 7,906.32 7,817.62 3,783.96 4,809.18 5,949,443.20 312,344.42 2.86 5,979.72 MWD+IFR-AK-CAZSC(4) 330.90 7,924.99 7,836.29 3,864.54 4,855.50 5,949,524.87 312,300.07 2.75 6,071.35 MWD+IFR-AK-CAZSC(4) 331.55 7,940.56 7,851.86 3,946.37 4,900.44 5,949,60776 312,257.14 1.90 6,163.06 MWD+IFR-AK-0AZ-6C(4) 333.18 7,953.98 7,865.28 4,029.80 4,944.12 5,949,692.23 312,215.50 2.02 6,255.21 MWD+IFR-AK-CAZSC(4) 332.20 7,965.04 7,877.34 4,112.62 4,986.86 5,949,776.06 312,174.76 1.14 6,346.31 MWD+IFR-AK-CAZSC(4) 332.88 7,977.79 7,889.09 4,195.72 -5,030.07 5,949,860.17 312,133.61 0.71 6,437.88 MWD+IFR-AK-CAZSC(4) 332.88 7,978.47 7,889.77 4,200.57 -5,032.55 5,949,855.09 312,131.24 O.0 6,443.21 MWD4NC ONLY (INC>10°) (5) 332.89 7,984.53 7,895.83 4,270.60 -5,068.41 5,949,935.96 312,097.10 6.97 6,520.03 MM4NC_ONLY (INC>10') (5) 332.91 7,98071 7,892.01 4,356.23 5,112.23 5,950,022.63 312,055.37 8.14 6,613.97 MWD-INC_ONLY (INC>10°)(5) 332.92 7,975.02 7,886.32 4,401.98 -5,135.63 5,950,068.93 312,033.10 0.50 6,664.15 MWD+IFR-AK-CAZ-SC (6) 330.40 7,966.85 7,878.15 4,485.32 5,180.58 5,950,15333 311,990.18 4.15 6,757.04 MWD+IFR-AK-CAZ-SC (6) 326.47 7,963.22 7,874.52 4,565.78 5,230.02 5,950,234.96 311,942.72 4.88 6,850.56 MWD+IFR-AK-CAZ-SC (6) 327.33 7,961.59 7,872.89 4,645.69 5,282.11 5,950,316.11 311,892.59 0.90 6,945.34 MWD+IFR-AK-CA7-SC (6) 326.32 7,960.41 7,871.71 4,726.74 5,333A0 5,950,398.37 311,843.58 1.17 7,040.31 MWD+IFR-AK-CAZ-SC (6) 331.42 7,960.01 7,871.31 4,809.04 5,380.87 5,950,481.80 311,797.83 3.28 7,134.19 MWD+IFR-AK-CAZ-SC (6) 332.93 7,959.95 7,871.25 4,880.11 5,418.37 5,950,553.75 311,762.07 1.88 7,212.87 MWD+IFR-AK-CA7-SC (6) 333.21 7,959.94 7,871.24 4,893.20 5,425.02 5,950,567.00 311,755.74 1,88 7,227.20 MWD+IFR-AK-CAZ-SC (6) 331.26 7,959.91 7,871.21 4,977.33 -5,469.31 5,950,652.17 311,713.50 2.05 7,320.27 MWD+IFR-AK-CAZ-SC(6) 330.12 7,959.95 7,871.25 5,060.53 -5,516.02 5,950,735.48 311,658.83 1.19 7,414.18 MWD+IFR-AK-CAZSC(6) 331.09 7,958.59 7,869.89 5,143.88 -5,562.98 5,950,820.94 311,623.92 2.02 7,508.35 MW0+IFR-AK-CAZSC(6) 333.54 7,955.54 7,865.84 5,228.26 -5,607.25 5,950,9D6.36 311,581.71 2,60 7,601.60 MWD+IFR-AK-CAZSC (6) 334.95 7,951.27 7,862.57 5,314.8 -5,648.66 5,950,993.16 311,542.40 1.88 7,694.14 MWD+IFR-AK-CAZSC(6) 334.30 7,946.21 7,857.51 5,400.22 -5,689.51 5,951,080.26 311503.66 0.70 7,786.58 MWD+IFR-AK-CAZSC(6) 334.29 7,941.30 7,852.60 5,485.19 -5,730.41 5,951,166.19 311464.83 0.04 7,878.15 MWD+IFR-AK-CAZ-SC(6) 333.07 7,936.34 7,847,64 5,57063 -5,772.68 5,951,252.63 311,424.66 1.28 7,97094 MW4)+IFR-AK-CAZ-SC(6) 333.05 7,931.33 7,84263 5,655.90 -5,816.01 5951,33892 31138341 0.08 8,06429 MWD+IFR-AK-CAZ-SC(6) Annotation TIP to MT6-05PB7 KOPTOWS Interpolated Azimuth Interpolated Azimuth MT6-0511 T7.9 (copy) 8/152018 5: 00:49PM Page 7 COMPASS 5000.14 Build 85 ConocoPhillips 8�cER 11GHES ConocoPhillips Definitive Survey Report Company: ConomPhillips(Alaska) Inc. -WNS Local Co-ordinate Reference: Well MT6-05 N� Project: Western North Slope TVD Reference: MT6-05 Actual @ 88.70usft (Actual D19) Site: GMT1 Lookout Pad MD Reference: MT6-05 Actual @ 88.70usft (Actual D19) Well: MT"5 North Reference: True Wellbore: MT6-05 Survey Calculation Method: Minimum Curvature Design: MT6-05 Database: EDT 14 Alaska Production Survey Annotation 4-1/2" x 6" 87152018 5:00:49PM Page 8 COMPASS 5000.14 Build 85 Map Map Vertical MD Inc Azi TVD TVDSS +N/ -S +E/ -W Northing Easting DLS Section (usft) (°) (°) (usft) (usft) (waft) (usft) (°/100') Survey Tool Name (ft) (ft) (ft) 12,690.05 92.53 334.19 7,926.72 7,838.02 5,740.96 -5,858.20 5,95142497 311,343.30 1.31 8,15674 MWD+IFR-AK-CAZSC(6) 12.785.29 92.50 336.36 7,922.54 7,833.84 5,827.38 -5,897.99 5,951,512.33 311,305.62 2.28 8,248.72 MWD+IFR-AK-CAZSC (6) 12,880.47 92.50 33259 7,918.39 7,829.69 5,914.89 5,935.18 5,951,600.71 311,270.57 1.29 8,339.88 MWD+IFR-AK-CAZSC(6) 12,975.80 91.54 337.73 7,915.03 7,826.33 6,003.01 -5,971.40 5,951,689.68 311,236.51 1.02 8,430.89 MWD+IFR-AK-CAZSC(6) 13,071.06 89.98 338.31 7,913.77 7,825.07 6,091.33 5,007.05 5,951 778.84 311,203.02 1.75 8,521.70 MWD+IFR-AK-CAZ-SC (6) 13,166.38 89.06 338.79 7,914.57 7,825.87 6,180.D5 -6,041.90 5,951,668.37 311,170.33 1.09 8,612.31 MWD+IFR-AK-CA7-SC (6) 13,261.35 88.81 338.95 7,916.33 7,827.63 6,268.62 5,076.13 5,951,957.74 311,138.26 0.31 8,702.40 MWD+IFR-AK-CAZ-SC (6) 13,357.10 88.44 337.83 7,918.63 7,829.93 6,357.61 8,111.38 5,952,047.55 311,105.19 1.23 8,793.47 MWD+IFR-AK-CAZ-$C (6) 13,451.89 88.61 337.02 7,921.07 7,832.37 6,445.11 8,147.76 5,952,135.90 311,070.95 0.87 8,884.11 MWD+IFR-AK-CAZSC(6) 13,547.41 88.48 334.06 7,923.49 7,834.79 6,532.01 8,187.29 5,952,223.74 311,033.54 3.10 8,976.30 MWD+IFR-AK-CAZSC(6) 13,642.74 89.99 333.10 7,924.77 7,836.07 6,617.38 8,229.70 5,952,31D.10 310,993.21 1.88 9,069.13 MWD+IFR-AK-CAZSC(6) 13,737.96 89.98 332.11 7,924.79 7,835.09 6,701.92 5,273.52 5,952,395.68 310,951.47 1.04 9,162.21 MWD+IFR-AK-CAZSC(6) 13,833.14 89.98 331.46 7,924.83 7,836.13 6,785.79 8,318.52 5,952,480.61 310,908.52 0.68 9,255.54 MWD+IFR-AK-CAZSC(6) 13,928.34 89.98 330.15 7,924.86 7,836.16 6,868.89 8,364.95 5,952,564.81 310,864.12 1.38 9,349.19 MWD+IFR-AK-CAZSC(6) 14,023.35 90.05 331.50 7,924.83 7,836.13 6,951.85 8,411.27 5,952,648.86 310,819.84 1.42 9,442.65 MWD+IFR-AK-CAZSC(6) 14,118.55 92.67 331.23 7,922.57 7,833.87 7,035.37 8,456.87 5,952,733.47 310,776.28 2.77 9,536.09 MWD+IFR-AK-CAZSC(6) 14,213.17 93.00 332.19 7,917.89 7,829.19 7,118.59 8,501.66 5,952,817.74 310,733.53 1.07 9,628.78 MWD+IFR-AK-CAZ-SC(6) 14,308.11 94.04 332.59 7,912.07 7,823.37 7,202.56 8,545.58 5,952,902.74 310,691.67 1.17 9,721.49 MWD+IFR-AK-CAZ-SC (6) 14,403.68 93.98 334.20 7,905.38 7,816.68 7,287.79 8,588.27 5,952.988.99 310,651.06 1.68 9,814.41 MWD+IFR-AK-CAZ-SC (6) 14,499.04 94.04 334.70 7,898.71 7,810.01 7,373.62 8,629.31) 5,953,075.78 310,612.13 0.53 9,906.71 MWD+IFR-AK-CAZ-SC (6) 14,594.34 92.96 339.94 7,892.89 7,804.19 7,461.35 8,665.96 5,953,164.37 310,577.61 5.60 9,997.71 MWD+IFR-AK-CAZ-SC(6) 14,689.67 91.82 334.33 7,688.91 7,800.21 7,549.08 8,702.96 5,953,252.97 310,542.76 6.00 10,086.92 MWD+IFR-AK-CAZSC(6) 14,78476 90.99 333.89 7,885.58 7,797.88 7,634.60 8,744.46 5,953,339.46 310,503.34 0.99 10,181.29 MWD+IFR-AK-CAZSC(6) 14,880.40 91.03 333.42 7,884.90 7,796.20 7,720.29 8,786.90 5,953,426.16 310,463.00 0.49 10,274.39 MWD+IFR-AK-CAZSC(6) 14,975.55 89.98 334.37 7,884.06 7,795.36 7,805.73 8,828.76 5,953,512.58 310,423.23 1.49 10,366.93 MWD+IFR-AK-CAZ-$C(6) 15,071.10 88.99 333.68 7,884.92 7,796.22 7,891.62 8,870.61 5,953,599.46 310,383.48 1.26 10,459.81 MWD+IFR-AK-CAZ-SC(6) 15,165.21 88.01 332.09 7,887.38 7,798.68 7,975.36 8,913.49 5,953,684.21 310,342.66 1.96 10,551.68 MWD+IFR-AK-CAZ-SC (6) 15,195.0) 88.01 332.09 7,888.41 7,799.71 8,001.67 5,927.42 5,953,710.84 310,329.36 0.00 10,580.84 PROJECTED to TD Annotation 4-1/2" x 6" 87152018 5:00:49PM Page 8 COMPASS 5000.14 Build 85 BA &%,=a UPRINT DISTRIBUTION LIST 1 a GE company COMPANY ConocoPhillips Alaska, Inc. WELL NAME MT6-05, MT6-05L1, MT6-05PB1, MT6-05PB2 FIELD Greater Mosses Tooth Unit COUNTY BHI DISTRICT ALPINE Alaska AUTHORIZED BY Paul Canizares EMAIL Paul.Canizares@bhge"Com I 6J STATUS Final Replacement: RECEIVED SEP 19 2018 >e sign and return one copy of this trans 1llGIJIC DcoPhillips Alaska, Inc. V Elgarico. ATO 3-380. 'G' Street. forage, Alaska 99501 LOG TYPE GR-RES-DEN-NEU LOG DATE June 23, 2018 TODAYS DATE September 18, 2018 Revision No Details: Rev. Requested by: --- 218046 29688 COMPANY FIELD( FINALas. CD/DVD PRELIM LOGS (CGM,is,PDF,META, FINAL SURVEY REPORT ADDRESS FEDEXMLLNOTDELNERTOP.O.BOX ( ) LOGS CGM, Final Surveys) PERSON ATTENTION # OF PRINTS # OF COPIES # OF COPIES # OF COPIES M 3 ASRC, Attn: Teresa 1mm 3900'C' Street, Suite 801 Anchorage, Alaska 99503-5963 41Wayne Svejnoha 0 0 0 0 Q IBLM State Office 1222 W. 7th Ave., Suite#13 (Anchorage, Alaska 99513-7504 5 iAOGCC ATTN: Natural Resources Tech Q (333 W. 7th Ave., Suite 100 Anchorage, Alaska 99501-3539 Q 1'6-051 is located in a federal oil and gas unit. Only with respect to the [MT6-051 Well Data, CPAI hereby waives its right to indefinite confidentiality, under 5 U.S.C. 552(b)(4) and (9). Nothing in this communication should be construed as a waiver of indefinite confidentiality on any other wells. Please note that for wells not on State land, a state agency should seek consent from the landowner prior to the release of well data by the state agency. See, e.g., AS 43.55.025(f)(2)(C)(i). Here, the landowner is the Bureau of Land Management (BLM) and/or Arctic Slope Regional Corporation (ASRC). TOTALS FOR THIS PAGE: 0 0 1 1 0 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSIONREWIM SEP C ti 20 WELL COMPLETION OR RECOMPLETION REPORT AMMIUAi ta. Well Status: Oil ❑D - Gas❑ SPLUG ❑ Other ❑ Abandoned ❑ Suspended ❑ 20MG 25.105 20AAC 25.110 GINJ ❑ WINJ ❑ WAG❑ WDSPL ❑ No. of Completions: 1b. Well Class: Development Exploratory ❑ Service ❑ Stratigraphic Test ❑ 2. Operator Name: ConocoPhillips Alaska, Inc. 6. Date Comp., Susp., or Abend.: �bt218-046 14. Permit to Drill Number/ Sundry: - 3. Address: P.O. Box 100360 Anchorage, AK 99510-0360 7. Date Spudded: 712/2016 15. API Number: 50-103-20771-60-00 ' 4a. Location of Well (Governmental Section): Surface: 261' FNL, 3171' FEL, Sec 6, T1 ON, R3E, UM ' Top of Productive Interval: 1342' FNL, 3188' FEL, Sec 36, T11 N, R2E, UM Total Depth: 2822' FNL, 5084' FEL, Sec 25, T11 N, R2E, UM 8. Date TD Reached: 7/6/2018 16. Well Name and Number: MT6-05L1 - 9. Ref Elevations: KB:88.7 • GL: 37.2 . BF: 17. Field / Pool(s): Greater Mooses Tooth Un' ne ' 10. Plug Back Depth MD/TVD: N/A 18. Property Designation: - AA081798, AA081818, AA092346 4b. Location of Well (State Base Plane Coordinates, NAD 27): Surface: x- 317060 ' y- 5945544 Zone- 4 . TPI: x- 312131 y- 5949865 Zone- 4 Total Depth: x- 310329 y- 5953711 Zone- 4 11. Total Depth MDfFVD: . 15195/7888 - 19, DNR Approval Number: 932, 533, 000, 932, 553,000, 000,000,000, 12. SSSV Depth MDfrVD: N/A 20. Thickness of Permafrost MD/TVD: ' 1260/1253 ' 5. Directional or Inclination Survey:. Yes RI (attached) No ❑ Submit electronic and printed information per 20 AAC 25.050 13. Water Depth, if Offshore: N/A (ft MSL) 21. Re-drill/Lateral Top Window MD/TVD: . 10939/7978 • 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/Neu/Den/CBL 23. CASING, LINER AND CEMENTING RECORD CASING WT. PER FT GRADE SETTING DEPTH MD SETTING DEPTH TVD HOLE SIZE CEMENTING RECORD AMOUNT PULLED TOP BOTTOM TOP BOTTOM 20 94 H-40 Surface 115 Surface 115 42 Existing, cement to surface 133/8 45.5 L-80 Surface 2014 Surface 1977 13.5 1044 sx 11.Oppg LiteCrete, 350sx 15.8ppg class G 9 518 29.7 L-80 Surface 8921 Surface 7123 9.875 104 sx 12.2ppg Class G 241 sx 15.8ppg Class G 7 26 L-80 Surface 8654 Surface 6934 8.75 Tieback 7 32 L-80 8641 11174 8006 8006 8.75 78 sx 12.2 ppg Class G 12 1Cl 4.5 12.6 L-80 10814 17192 7990 7892 6 Slotted Liner 24. Open to production or injection? - Yes 0 Ll If Yes, list each interval open (MDfTVD of Top and Bottom; Perforation Size and Number; Date Perfd): Slotted Liner @: 10814-15040 MD and 7965-7884 TVD COMPLETION DAT4 __q]N111r (L VERIFIED 25. TUBING RECORD SIZE DEPTH SET (MD) PACKER SET (MD/TVD) 41/2 10819 10814/7963 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. Was hydraulic fracturing used during completion? Yes ❑ No ❑� Per 20 AAC 25.283 (i)(2) attach electronic and printed information DEPTH INTERVAL (MD) JAMOUNT AND KIND OF MATERIAL USED 27. PRODUCTION TEST Date First Production: Method of Operation (Flowing, gas lift, etc.): WAITING FOR HOOK-UP Date of Test: Hours Tested: Production for Test Period Oil -Bbl: Gas -MCF: Water -Bbl: Choke Size: Gas -Oil Ratio: Flow Tubing P Casinq Press: I Calculated 24 -Hour Rate Oil -Bbl: Gas -MCF: Water -Bbl: Oil Gravity- API (corr): Form 10-407 Revised 512017 RBDMS SEP O 5 tBQ1NTINUED ON PAGE 2 yw (.- Zf���� b it ORIGINIIAL o 28. CORE DATA Conventional Core(s): Yes ❑ No ❑� Sidewall Cores: Yes ❑ No ❑� . If Yes, list formations and intervals cored (MD/TVD, From/To), and summarize lithology and presence of oil, gas or water (submit separate pages with this form, if needed). Submit detailed descriptions, core chips, photographs, and all subsequent laboratory analytical results per 20 AAC 25.071. 29. GEOLOGIC MARKERS (List all formations and markers encountered): 30. FORMATION TESTS NAME MD TVD Well tested? Yes ❑ No ❑Q ' Surface If yes, list intervals and formations tested, briefly summarizing test results. Permafrost - Top Surface Permafrost - Base 1260 1253 Attach separate pages to this form, if needed, and submit detailed test Top of Productive Interval information, including reports, per 20 AAC 25.071. Formation Q TPI -Alpine C 10939 7978 TD 15195 7888 Formation at total depth: Alpine C 31. List of Attachments: Daily Operations Summary, Definitive Survey, Cement Report, Schematic Information to be attached includes, but is not limited to: summary of daily operations, wellbore schematic, directional or inclination survey, core analysis, l report. production or well test results. 32. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. WrHj Authorized Name: G.L. Alvord Contact Name: Weifena Dai Authorized Title: Alaska Drilling Manager Contact Email: Weifen .Dai co.com Authorized n / ¢, Zn (v Contact Phone: 265-1077 a Signature: Date: l 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 forth 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 WNS PROD ConocoPhllllpS A1-1Name NaaRa, 111c. LOCKOUT NIPPLE MTS -05 MTpRG Hum or loxias AM Last Tag Vx6.Iseasonal ma 11 AnnoMtlon Eno DamDour MB) last Moa LAST TAG: lennall ey RANSS r as Last Rev Reason Annotation End Data Unrelated ay ................ ................. REV REASON. Install OLD 81912018 boehmbh REV Casing Strings Caamg Descnpnon OD On) op DIKEN sN Depth inns) rel Depth I'LL WULen(I._Grade Tcp Th..a CONDUCTOR 20 36.5 1150 115.0 94.00 H40 Welded Casing Deacrabon OO lin) Top lflKo set Depth(flK9) and DegM1 r,V.) WYLen I1... Gmae Tap Thread CONDUCTOR, .11 too SURFACE 133/8 36.5 2.014.5 1,9]].1 68.00 L-80 TXP Caaln0 Dewrlptlan OO (in) ToplflKa) Set 0epl11 (XKB) SN Dagr(NO)... YNLn(L..GMa TapTbeaaINTERMEDIATEKt 95/8 34.6 8.9208 ).123.1 4000 LA0 J TXPCmming Dewoi OO lin) Top KING) set Depth(NKB) SN Dapdr TPOf.. Wllnn(I Wase TopTllreaa TIEBACK STRING ] 32.6 8,6538 6,931.5 2600 L80 BTCM NIPPLE ZMZ7 Cazing OewrmandOD tin) "IXNa) Set Depth bar) SN DngM1 INC)... Wduop(IGmaaThreadSOL LINER 7 8,640.] 11,1737 8.0051 3200.LA0 Tenans Blue GAS LIFT, 3.M4 rDetails omerelD Nog- Top(SMS) Top(ND)hts.) Topind(') Imm Dee Com Top Im) 8,6407 69252 4504 PACKER SLD( Liner Hanger Packer ]376 Gas um: sago] 8,673.3 6.9483 4505 SEALASSY Lurching bullet seals NO-GO(Seals 578) 6.100 8,676.1 6.950.2 45.05 Setting Sleeve HRDE Liner Sleeve ].735 8,685.0 6,956.5 4505 O CK HE Liner Quirk onnecl,w/Bullet Seats 7 32a, 6.150 CONNECT Tenons Blue TER KPRIW:sz .sv.e 11,167.4 8.005.1 8469 STABILIZER Reamer Shoe Stabilizer w/ Spline Prole, 7' 32# 6070 MYS110 Tenans Blue Casino Oescagbn OD pito ID lino Top(N(el Bel Depth Set OesM IND)... Wtlten P... Castle Top Thw PROD 1 LINER 412 3.96 11 0340 1],191.8 ),891.6 12.60 LA0 TXP Liner Details INIERMEOma Y1:Yb rypminal ID set Top ING TopINO (aKD) iapincl Des tour (In) 11,034.0 ),9912 8291 PACKER HRDE ZXP w/sceDDed Ext. 'upper 3.8]5 Inger (10.35) PUT pin GAs um'.1o,0¢0 11,065.5 ).9941 8290 HANGER 4-1/2x7'Flex Lock V TXPBXP 3.940 GRCGE:Io.Mas Tubing Strings I- Tal Dawnpoon Stmg Ma...mhn Top mNu set Dapm Maas Dear (ND)(... WI(RMI Grade TopcI aechII 1"Up INGRODU 4112 3.96 293 10818.7 79fi3.5 1280 L-80 Hyd563 NIPPLE: 10.1aIg PRODUCTION Completion Details Top INM Taperer Nominal NOGG LOCATOR', taap.a MEALAssY', tama.a Topoll (dna) 1°) It....a Com to (m) 29.3 29.3 0.00 HANGER FM 4-112" Tubing Hanger Hydol 563 .958 PAcitERl idols. 2,012.7 1,9755 1928.NIPPLE NIPPLE,(ANDING, 112',X,3.813', HYD563 -Till-3 1 D,084.9 7,799.7 68.54 GAUGE Schhumber,er Solid Gauge Mandrel (S M)w/encapsulated l -wire, .865 No: gross 4-112" 12.6r Al PIP wlcoupling sEREORE 10=4 HOONASSYI tosses PROD iuNER10 Ba16 ', 10,147.9 7,021.6 7073 NIPPLE NIPPLE. , 15 DB, HYD563 with RHC lug Body 72° 10,191 "DOGE Lock raced m 6,000 psi Installed I ( .75 1$hot LEM: nomas MAL BORE, legal.I -1-0-W73 J, 18 82.68 RUM— Locator No -Go 5.7&' OD LOCATOR 0 10,804.4 7,9617 82.69 SEAT ASSY Seal Assembly Top of Seals 3.44' up from Mule shoe 3.950 TuoM1p Descrlglon Shing Ma.,. ID lin) Top (flNa) aetDrotll m.. set Depm (Tvb)L.. mpbm) Oraae Top Cenneetlon PROD LEM ASSY d.6 395 10,814.0 11049.fi 7,992.2 1260 LAD Hytl5fi3 MPPLE, 11.1.i Completion Defalls Top (ND) Topina Top(RKB) (EKB) (°l than Des Com Nominal In (.a, MEAL A36V: 11,Mt.r 10,814.0 7,962.9 8273 PACKER HRDE ZXP wl 16'sealbore eat 5,00' ID 3.800 10,932.2 7,9776 82.85 XO Top of LEM 3.700 wnlPaTocK u.lmt 10,9354 ],9]80 82.85 SEAL BORE Upper Helix w13.688"Seal Brom (10,932,81) 3.688 10,936.3 ],9]8.1 82.85 HOOK ABBY Latch 25' be. Hl Hanger lot e..I Heli. 3.680 10,938.3 7,9784 82.85 LEM Lateral Entry Module 'W position 1 3.680 sDL uxER', sem.]-u.tn7 10,951.3 7,980.0 82.86 SEAL BORE Beal Sore 3.600' 3.680 11,002.0 7,986.4 82.89 NIPPLE Landing NipDce 3.313"'X'profile, HYD521 4.]20' 3300 11,042.6 7,9913 82.91 SEALASSY Bullet Seal Assembly w/4875"OD Seals 3950 ole (Wireline retrievable plugs, val _ Tep(TV01 is incl Tap mKe) pane) I9 Deo turn Run wa lO pq 11106.2 ),9982 82.91 WHIPSTOCK Whipstock TOW 11,tOfi.21 BOW 1T, 119.5 611&2018 Mandrel Inserts Salt H Top(NO) Top Khoo (dKe) Make Mpsel Carlo) Sery YaNe INoth Po,ISke TRORun Typo Type fnl (p.4 Run Dam Cam 1 3,6594 3384.5 Camco KBG-2 1 GAS LIFT GLV BK 0.188 1]36.0 8NI2018 BK 2 6,490.) 5,408D Camco KBG-2 1 GAS LIFT GLV BK 0.188 111).0 8/9/2018 BK 3 100178 11141 Camco 1BG-2 1 GAS LIFT OV 311-3 0.250 8/8/2018 I 1 1 1.17- 3 General d Safety Entl Dam NOTE PROD, LINER N (cal 1"... i STATE OF ALASKA ALASr,A OIL AND GAS CONSERVATION COMMISSION titULIVED AUG 14 2018 WELL COMPLETION OR RECOMPLETION REPORT 1a. Well Status: OiI ❑� Gas❑ SPLUG ❑ Other ❑ Abandoned ❑ Suspended ❑ 20AAC 25 105 20AAC 25.110 GINJ ❑ WINJ ❑ WAGE] WDSPL ❑ No. of Completions: AN 1b. Well Class: Development 2] Exploratory El Service ❑ Stratigraphic Test ❑ 2. Operator Name: ConocoPhillips Alaska, Inc. 6. Date Comp., Susp or Q�� Abend.: 1A A 14. Permit to Drill Number/ Sundry: 218-046 3. Address: P.O. Box 100360 Anchorage, AK 99510-0360 7. Date Spudded: 7/212018 15. API Number: 50-103-20771-60-00 4a. Location of Well (Governmental Section): Surface: 261' FNL, 3171' FEL, Sec 6, T1014, RX, UM Top of Productive Interval: 1342' FNL, 3188' FEL, Sec 36, T11 N, R2E, UM Total Depth: 2822' FNL, 5084' FEL, Sec 25, T11 N, R2E, UM 8. Date TO Reached: 716/2018 16. Well Name and Number: MT6-05L1 9. Ref Elevations: KB:88.7 GL: 37.2 BF: 17. Field / Pool(s): Greater Mooses Tooth Unit/Alpine Undefined Oil 10. Plug Back Depth MD/TVD: N/A 18. Property Designation: AA081798, AA081818, AA092346 4b. Location of Well (State Base Plane Coordinates, NAD 27): Surface: x- 317060 y- 5945544 Zone- 4 TPI: x- 312131 y- 5949865 Zone- 4 Total Depth: x- 310329 y- 5953711 Zone- 4 11. Total Depth MD/TVD: 15195/7888 19. DNR Approval Number: 932, 533, 000, 932, 553,000, 000,000,000, 12. SSSV Depth MD/TVD: N/A 20. Thickness of Permafrost MD/TVD: 1260/1253 5. Directional or Inclination Survey: Yes 0 (attached) No ❑ Submit electronic and printed information per 20 AAC 25.050 13. Water Depth, if Offshore: N/A (ft MSL) 21. Re-drill/Lateral Top Window MD/TVD: 10939/7978 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/Neu/Den SUPERCEDED 23. p CASING, LINER AND CEMENTING RECORD CASING WT. PER FT SETTING DEPTH MD SETTING DEPTH TVD GRADE HOLE SIZE CEMENTING RECORD AMOUNT PULLED TOP BOTTOM TOP BOTTOM 20 94 1 H-40 Su ce 80 Surface 80 42 Existing, cement to surface L-80 S 1794 Surface 1700 13.5 1044 sx 11.0ppg LiteCrete, 350sx 15.8ppg class G L-80 Su 83 Surface 4004 9.875 104 sx 12.2ppg Class G 241sx 15.8ppg Class G 4.5 11.6 L-80 10935 15040 7978 7884 6 Slotted Liner 24. Open to production or injection? Yes E] No ❑ If Yes, list each interval open (MD/TVD of Top and Bottom; Perforation Size and Number; Date Perfd): Slotted Liner @: 11286-15040 MD and 7965-7884 TVD COMPLETION i VERIFIED 25. TUBING RECORD SIZE DEPTH SET (MD) PACKER SET (MD/TVD) 41/2 10819 10814/7963 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: Method of Operation (Flowing, gas lift, etc.): WAITING FOR HOOK-UP Date of Test: Hours Tested: Production for Test Period Oil -Bbl: Gas -MCF: Water -Bbl: Choke Size: Gas -Oil Ratio: Flow Tubing Press. Casino Press: Calculated 24 -Hour Rate Oil -Bbl: Gas -MCF: Water -Bbl: Oil Gravity - API (torr): RBDMS91-tuG 15 2018 N 1 INUtU UN YAIA 2 y 30 /G Submit URKANIAL Only 28. CORE DATA Conventional Core(s): Yes ❑ No ❑� Sidewall Cores: Yes ❑ No ❑� If Yes, list formations and intervals cored (MD/- VD, From/To), and summarize lithology and presence of oil, gas or water (submit separate pages with this form, if needed). Submit detailed descriptions, core chips, photographs, and all subsequent laboratory analytical results per 20 AAC 25.071. 29. GEOLOGIC MARKERS (List all formations and markers encountered): 30. FORMATION TESTS NAME MD TVD Well tested? Yes ❑ No 0 If yes, list intervals and formations tested, briefly summarizing test results. Permafrost - Top Surface Surface Permafrost - Base 1260 1253 Attach separate pages to this form, if needed, and submit detailed test Top of Productive Interval information, including reports, per 20 AAC 25.071. Formation @ TPI -Alpine C 10939 7978 TD 15196 7887 suer:O/qEJ) � ft Formation at total depth: Alpine C 31. List of Attachments: Daily Operations Summary, Definitive Survey, Cement Report, Schematic Information to be attached includes, but is not limited to: summary of daily operations, wellbore schematic, directional or inclination survey, core analysis, naleontolooical report. production or well test results, per 20 AA _ 32. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. lilt, Authorized Name: G.L. Alvord Contact Name: Weifen L Dai Authorized Title: Alaska DrillingManager Contact Email: Weifen .Dai co .co ' AuthorizedOf Contact Phone: 265-1077 Signature: Date: l 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 10407 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 la: 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 10-007 Revised 5/2017 Submit ORIGINAL Only MT6-05 Multi -lateral Producer, Pre -Completion Schematic 20" 79 ppf H-40 Insulated Conductor 80 feet, cemented to surface ❑0 13-3/8" 68 ppf L-80 TXP to TD Surface Casing @ 2041' MD / 1,980' TVD Ocemented to surface z 4-112" 12.6 ppf L-80 Hydril 563 to 10,818.65' MD Tubino / Liner Comoletion: 1) 4'/2' Landing Nipple (3.813" X) @ 2,012.68' MD 2) 4-1W' x 1" GLM @ 3659.39' MD 3) 4-%" x 1" GLM @ 6490.64' MD 4) 4-%" x 1" GLM wl SOV @ 10,07.78' MD 5) 4-%d' SLG DHG @ 10,084.84' MD 6) 41/" Landing Nipple (3.75" DB) @ 10,147.89' MD 7) Liner Top Packer I Hanger @ 10,813.94'MD w/ Tie Back sleeve 8) LEM and Hook Hanger 9) 4" Landing Nipple (3.313" X profile) @ 11,003' MD 10) Liner Top Packer / Hanger w/ Tie Back Sleeve 9 5/8" 40 ppf L-80 H563 (to 1,335' MD) 9 5/8" 40 ppf L-80 BTC (to 3,981') 9 518" 40 ppf L-80 TXP (to 6,790') 9 5/8" 40 ppf TN -80 HC TXP (to TD) @ 8,921' MD / 7,125' TVD TOC of 9 5/8 -7,921' MD iI 4 l ► O .� 0 Top Alpine C 10,828' MD / 7937' TVD L1 Window - Baker Hook Hanger Junction 10,864' MD/ 7941' TVD O 4'/:" 12.6# L-80 TXP Liner 6" Hole, TD at With Perf Pups at 15,195' MD' 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 Fg io 4-%" 12.6# L-80 TXP Liner 6" Hole, TD at 7" 26 ppf L-80 Tenaris Blue/H563 Liner With Perf Pups at 17,391' MD to 11,163' MD / -7,975' TVD @ 83 deg AlMall, WNS PROD MT6-05 ri„! C Ypell Attribute Merz Angle TD ''Ili WName WeIIWre APVUW WeIIWre 6Ulus l°) MO IX. ACI BIm Ithih N9aka.Ir1C LOOKOUT 5010320]] 100 PROD 5.94 15,93132 17,391.0 Comment rosd m1 OeB AnnoMgon I Ertl no. 3647 7/14/2018 RN RI -110111 SSSV: NIPPLE LAST WO'. 364) ]/34/2018 MT6a. ellvmle3:41:42 we Last Tag .1 VMmOc hi Annotation IF 11 Dole Depth(MB) lealmctl ar LAST TAG: lennalt ............... .....................'-FuioFki3....._ Last Rev Reason ....... ............................ .......... _...... AnnaMlon Ene Da@ IaalmW ev REV REASON New well 181712018 jennall Casing Strings can lrg Dllrnpbon OD(II to and Top IXNe1 etc Depth fri sm Depin (NDL_wuLm IL.. Gra4e Top threes CONDUCTOR 20 1912. 36.5 1150 1150 94.00 H40 Welded coare Deacrytion OD6n) ID (IN Top(XNB) eel ..,I (.at Sed Depth IND)... wVLen(I Gra4e Top TIo SURFACE 13318 1242 36.5 2,014.5 1,977.1 moo L-80 TXP CONDUCTOR;355-1150 Casing 9suppro n ODB"I ID lin) Top(flRed Is. Drug, feek, Sed DeWr IND)... Rev 11 'i Top Thread INTERMEDIATE NI 95A 8.84 34.6 8,920.8 7,1231 40.00 L-80 TXP I Top(XKB) SN CeI4h IhKa) D)... "Me'"II... Grade Top inroad Casing Deacdplbn OD (in) 10(MSal Degn IN TIEBACK STRING ) 6.28 326 8,653.8 6,934.5 2800 L80 BTCM NIPPLE; 20127 Culp Desed, OD BnI ID llnl Tap MR.) .DepthIXKB) Sed DeFN (ND1._ w1ILen 11... GraEe Top thread BOLL ] 6.28 8,640) 11,1733 8,0057 32.00 L-80 Tenaris Blue 6VRFACE: 36. S2,0145 Liner Details GAS LIFT: 3.858.4 xominal ID Top(NRB) Top (NID)had1 Top Incl I') I tem Des Cam (in) 8,6407 89252 45.04 PACHER SLZX Liner Hanger Packer 73]6 Gall -al 410] 8,673.3 6,9483 4505 SEAL ABBY Latching bullet seals NO-GO Bccils 578) 6.1 8,676.1 6,950.2 45.05 Seeing Sleeve HRD-E Liner Sleeve 7=7 8,685.0 6,956.5 45.05 UI K HP Liner Quick onneeUs ulel eals]"3g .150 CONNECT Tenons Blue -r DEaAdeler Gs28a.Ae0.9 M--7,775 11,16].4 8,005.1 84.69 STABILIZER Reamer Shoo Shoilizerw Spline P A, MYS110Tenaris Blue Casing derwislon ODlin) ID(in) Tap in 6e10epm IXKB) Se[DepthGentle Top Thread PROD/LINER 4112 3.96 11,034.0 1],191.8 J, 8916 1260 L-80 TXP Liner Details Nominal lD INTERMEOl9TE41; 94.P e.9me Top lhKa) Top(rvD)XIKa) Topincl l°) Xem Oes corn [n) 11,034.0 7,9902 8291 PACKER HRDE ZXP WERIPPED Etc D ow" Upper 110')4.8)5" 36]5 war (10.35') H521 pin G98lIFT: 10.01)a 11,065.5 7,994.1 82.90 HANGER 4-112" x ]" Flex Lock V TXP BxP J 940 .E;ID.05.9 Tubing Strings Tubing Oescriplion elUng Ma... TUBING 41/2 lO pet) 3.96 top IXKR 29.3 eel Oepin lh 10,8187 se Depll IND) I... 796'3.5 WIUNN) 12.60 Graae L-80 Top Conn two Hyd563 NIPPLE; 10, 129 PRODUCTION Completion Details NOGOLOCATOR;10.=3 TopnVD) Topincl xominal Top Nl ("Ka) 1') Kern Des Com AD (IN SE4ASSYI10,W4.4 29S HANGER FMC 4VZ Tubing Hanger High? 563 39" ..N.. loess 2,612.7 1,975.5 19.28 NIPPLE NIPPLE,t NDING,41/2",X,3.813", HYD563 3813 1 9 J,]99J 68.56 U Chlumbetger DI Gauge Mandrel wl encapsulated J-wire, 3855 KO: lo.ax2 4-1Z 12.68 HYD563, PIP wlcoupling SEAL MORE: I0 AG.4 o,14J.9 ],621.6 ]0.]3 NIPPLE NIPPL , 4112',3,15- Of. w Plug Body 3.750 HOOK ASSY. TOX, PRODS LIN ER; 10934.1 Installed @ 72° (10.101 g1BB-6E LOG rated W 6,000 psi 0 ] LEE: 1..11 BEPL eoRE: 10951.3 10,80.3 ],961.5 8268 LOatcrNo-GoS) "OD 3.950 LOCATOR 10,804.4 ],961] 82.69 SEAL A S SY Seal Assembly Top of Seals3M'up koro Mule shoe 3.95 NIIPPLE.tl OYT Tubing Dwor per, eWna M. l01in) Top IRKB) Sa[Dep1h IR.. 311 Depth IND)/... WIIIdYt) Gude top Connection PROD LEM ASSY 46 3.95 10,614.0 11049.6 ],992.2 126'0 L-80 HyLIZ Completion Details Top IND) Topincl Routine Top Does)IhKe) p) Ikm Des Com ID (iet) 6EALPS6Y: 11.026 10,814.0 79629 8233 PACKER HRDE UP wl 16'sealtare ext. 5.00" ID .800 10,932.2 7,977.6 .5 XO Top of LEM 3700 wHlPel 1+.106.2 10,935.4 ),9]80 SEAL BORE Upper Helix wl3688"Beal Bare (10,932.81') 3.680 10,936.3 ),9]81 .5 700K -ASSY Latch 2.25' team Hook Hanger lndemal Helix 3.680 10,938.3 ),9]873 .85 LEM Lateral Er" Module "B" position 1 3.688 ROIUNERUcerpnl>,tTaT 10,951.3 7.9800 82.86 SEALBORE Seal Bore 3.688' 3,688 1 TOW ], 8.4 82.89 NIPPLE Landing Nipple 3.313"'X"profile, HYD521 433 3.300 11,042.6 79913 82.91 SEALASSY Bulled Seal Assembly w/48)5"OO Seals 3.950 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top f1VD1 rev ln[I Top RIXa) IXKBI 1'1 Doa cam Run wm LD pet) 11106.2 Y, 2 82.92 WHIPSTOCK Whipstock TOW 11,106.21 BOW 11,119.5 611&2010 Mandrel Inserts at HTOpl"t, va" Leleh Por181ae TRO Run Toshiba) I (me) Make Model Ordli IN, Type rypx (in) IW) Run Ooh Cam 3,364.5 Camco KBG-2 1 GAS LIFT GLV DV 1000 71122018 2 673 0.] 5,408.0 Camco FB 11/4 GAS LIFT GLV OMK 0186 1]]]0 8192018 3 10,0".8 7]]4.1 Camco KBG-2 11/4 GAS LIFT OV OMK 0.250 8/812018 Notes: General & Safety Ere Dore Annohlbr NOTE' PROD I LINER;14Wr.6 rr 1],181 S'x WNS PROD MT6-06L1 ConocoPhllllps Well AttribuV Max Ang.I TD FIeM Name WeIIWre APYUWI WellWle SbWa (nncl l—I IMG (R loci RIm 1X3891 Naska.1m LOOKOUT 50103207]160 PROD 605 11,16598 151950 M)86L1. BM1IfA1BJ121]PM' Last Tag Vueal ¢Ivrmcpzup A—WHIRi (AST TAG: Ell Data DepM (IIRaI batMM Ry lenreit Last Rev Reason 6R 293 ...................... .................. Annolainn REV REASON. Newwell JE ne Dare B;d12 teat Moa 9r lennall ................................................................ ......._.._.... Casing Strings caaine Da%ripnon DD (In) PROD, LINER 4112 lO Unl 3.96 Top (XKaI set CIOTTI BN Deptn(1V01...ENLen 1.`934.8 15,0397 ),880.5 p._Glaae Top Tnleao 12.60 L$0 T%P Liner Details Nam—'lD TOP(MEN Ta,(1VO) IXXBI Topinal(°) Item Des Com (In) 10,934.8 ],916.0 82.85 HANGER 4.5"x "e-3 Hook Ha.,el 4-12" 2.6A BTC Din 5.050 Gown - above wintlow CONDUCTOR; 30sltso Notes: General S Safety End Dabannomun NOTE: NIPPLE; 3.0127 SURFACE: M. Y2.01a5 . LIFT; 3.860 a GOB OFT: E'RD7 TIEBACK STRING, 32.Ba. av a INEERMED. 91; M.B 8m0 GAS DR; loo7a GWGE: 1aMa.B NIPPLE: lol.9 NOGG LOCATOR: IOUIRIJ SEALASBr:10.8044 vACItER: ID.aue 0:1C.a SEALBCNE C.4 HOONASar;10938.3 BDL UNER; 86407-11,lM 7 PROD 2 LINER: 109313- 11.,7 -)erations Summary (with Timelog pths) MT6-05 Rig: DOYON 19 Job: DRILLING ORIGINAL Time Log StartDepth Stan Time End Tme Dur (hr) Phase Op Code Ad,Wy Code Time PJA Operabon (ftKB) 0.0 End DepN(ftKB) 0.0 5/11/2018 5/11/2018 3.00 MIRU MOVE RURD P B/D steam & H2) lines. RID service 00:00 03:00 lines & electrical lines. Work on rig move check list. Prep rig floor for skidding. 5/11/2018 5/11/2018 2.00 MIRU MOVE MOB P Back away pipe shed, pits & motors 0.0 0.0 03:00 05:00 complex from sub.Drain lines & secure beaver slide. Skid dg floor. Raise stompers & windwalls & prep sub for move. 5/11/2018 5/11/2018 5.50 MIRU MOVE MOB P Move sub off of MT6-03 & crab over to 0.0 0.0 05:00 10:30 MT6-05. Center sub over well. Lower stompers & windwalls & skid floor. SIMOPS - Spot MPD equipment in cellar. Move pipe shed, pits & motors complex into position. 5/11/2018 5/11/2018 6.00 MIRU MOVE RURD P Hook up steam lines. Work on rig 0.0 0.0 10:30 16:30 acceptance check list. Connect Koomy lines to knife valve. Spot site control & SAFE house shacks. Hook up drain lines & cellar pump. SIMOPS- spot ball ill & work on electric brake. Rig accepted 16:30 Firs. 5/11/2018 5/12/2018 7.50 MIRU MOVE TURD P Cont. to work on dg acceptance check 0.0 0.0 16:30 00:00 list. Test gas alarms. Extend diverter line. NIU surface riser. Take on spud mud. Prime mud pumps. Install black H2O manifold on conductor. SIMOPS - Spot crane to shim auxiliary brake on draw works. 5/12/2018 5/12/2018 4.00 MIRU MOVE RURD 77- Cont. to work on dg acceptance check 0.0 0.0. 00:00 04:00 list. Rig up valves & black water line in cellar. Secure & barricade diverter line. Mobilize BHA tools & equipment to rig floor. Test gas alarms. SIMOPS - Crane assist to shim auxiliary brake on draw works. 5/12/2018 5/12/2018 2.00 MIRU MOVE RGRP T Finish repair on electric brake on draw 0.0 0.0 04:00 06:00 works. 5/12/2018 5/12/2018 2.25 MIRU MOVE KURD P Install 90' mouse hole. M/U 5" 0.0 0.0 06:00 08:15 - elevators. Perform diverter function = Annular close 27 sec / knife valve _ open 1.5 sec (AOGCC & BLM waive wittiness). Pre -spud meeting. Rig evacuation drill. Perform Koomy draw down. 5/12/2018 5/12/2018 3.75 MIRU MOVE SHAH P PJSM. M/U BHA#1 as per Baker. Tag 0.0 115.0 08:15 12:00 bottom of conductor @ 115'. 5/12/2018 5/12/2018 1.25 MIRU MOVE SEQP P Fill hole w/35 bbls mud. Check for 115.0 115.0 12:00 13:15 leaks. Test surface equipment to 3500 psi (good). C/O air boot on flow line 5/12/2018 5/13/2018 10.75 SURFAC DRILL DDRL P Drill ahead f/115'to 1,137' MD 11,131- 115.0 1,137.0 13:15 00:00 TVD, ADT 7.2 Hrs, 725 gpm 11460 psi, Pu wt 94 k, SO wt 94 k, ROT wt 94 k, 60 rpm, 3.5/1.5 k ft lbs lrq 5/13/2018 5/13/2018 9.00 SURFAC DRILL -ETD RL ,P Drill ahead f/1,137'to TO 2,024' MD/ 1,137.0 2,024.0 00:00 09:00 1,986' TVD, ADT 6.8 Hrs, 850 gpm / 2300 psi, Pu wt 115 k, SO wt 112 k, ROT wt 115 k, 75 rpm, 4.5/1.7 k ft lbs trq 5/13/2018 5/13/2018 0.75 SURFAC CASING CIRC P Pump 30 bbl nut plug med sweep 3X 2,024.0 1,871.0 09:00 09:45 and circ hole clean. Rack back 1 stand per B/U f/2,024'to 1,871' 5/13/2018 5/13/2018 0.25 SURFAC CASING OWFF P F/C w/5 rpm (static) B/D top drive. 1,871.0 1,871.0 09:45 10:00 Page 1147 Report Printed: 711812018 MT6-05 � Rig: DOYON 19 Job: DRILLING ORIGINAL Time Log - - - ` Start Depth - . Start rime Entl Tune -Our (hr) Phase Op Code Ac4viry Code Time P -T-% - Operation (flK8) End Depth (MKS) 5/13/2018 5/13/2018 2.50 SURFAC CASING PMPO P Attempt to POOH on elevators. No 1,871.0 1,021.0 10:00 12:30 success (hole swabbing). Pump OOH w/530 gpm f/1,871'to 1,021' 5/13/2018 5/13/2018 0.50 SURFAC CASING CIRC P Cie B/U w/530 gpm 1900 psi. Rack 1,021.0 921.0 12:30 13:00 back 1 stand to 921' 5/13/2018 5/13/2018 3.50 SURFAC CASING PMPO P Attempt to POOH on elevators. No 921.0 180.0 13:00 16:30 success (hole swabbing). Pump OOH w/530-300gpm f/921'to 180'. (Dropped Gyro tool @ 700') 5/13/2018 5/13/2018 3.50 SURFAC CASING BHAH P Pump BHA out of hole w/300 gpm 180.0 0.0 16:30 20:00 1/180'to 86'. Rack back HWDP, Jars, & NMFC's. F/86' UD BHA as per Baker. Bit Grade: 1 -1 -WT -A -E -0 -BU - TD 5/13/2018 5/13/2018 1.50 SURFAC CASING SHAH P Clean & clear floor of BHA tools & 0.0 0.0 20:00 21:30 equipment. 5/13/2018 5/14/2018 2.50 SURFAC CASING RURD P R/U to run casing. R/U Volant & 0.0 0.0 21:30 00:00 - double stack power tongs, casing bales & elevators. 5/14/2018 5/1412018 0.75 SURFAC CASING RURD P R/U strap tongs & finish R/U for 0.0 0.0 00:00 00:45 casing. 5/14/2018 5/14/2018 11.50 SURFAC CASING PUTB P PJSM on casing. RIH 13-3/8" 68# L- 0.0 1,306.0 00:45 12:15 80 TXP casing to 1306'. M/U shoe track & check floats (good). (Having an issue with alignment & galling threads on casing had to swap out several jts casing). 5/14/2018 5/14/2018 1.25 SURFAC CASING CIRC P Circ & cond mud. Stage pumps up to 1,306.0 1,306.0 12:15 13:30 5 bpm / 90 psi. PU wt 128 k / SO wt 124 k 5/14/2018 5/14/2018 3.50 SURFAC CASING PUTB P Cont. to RIH 13-3/8" 68# L-80 TXP 1,306.0 1,937.0 13:30 17:00 casing f/1306 to 1937'. 5/14/2018 5/14/2018 1.00 SURFAC CASING HOSO P M/U hanger & landing jt. Land casing 1,937.0 2,014.0 17:00 18:00 on hanger @ 2,014.5' 5/14/2018 5/14/2018 3.00 SURFAC CEMENT CIRC P Circ & cond mud for cement job. 2,014.0 2,014.0 18:00 21:00 Stage pumps up to 8 bpm 1120 psi. Reciprocate pipe. PU wt 175 k / SO wt 155 k 5/14/2018 5/14/2018 0.75 SURFAC CEMENT RURD P RID casing bales. BID top drive. R/U 2,014.0 2,014.0 21:00 21:45 1 1 1 cement lines to Volant. 5/14/2018 5/14/2018 1.25 SURFAC CEMENT CIRC P Cont. to Dire & cond mud for cement 2,014.0 2,014.0 21:45 2300 jobithru cement linesw/8 bpm 1350 psi. Reciprocate pipe. PU wt 180 k / SO wl 174 k. SIMOPS - work on 142S sensor in pits. 5/14/2018 5/15/2018 1.00 SURFAC CEMENT CMNT P PJSM on cementing. Rig load 50 bbls 2,014.0 2,014.0 23:00 00:00 nut plug marker in pipe. Dowell pump 1.2 bbls H2O & PT to 2500 psi (good). Dowell pump 100 bbls 10.3 ppg mud push w/4 bpm 1100 psi. Shut down & drop bottom plug. 5/15/2018 5/15/2018 2.75 SURFAC CEMENT CMNT P Dowell pump 357 bbis 11.0 ppg 1.92 2,014.0 2,014.0 00:00 02:45 ft3/sx yield LiteCRETE lead cement, • 72.3 15.8 ppg 1.16 ft3/sx yield tail ' cement @ 5 bpm. Drop top plug. Dowell pump 20.1 bbls H2O. Rig displace w/268.7 bbls / 2692 stks 10.0 ppg DrillPlex w/8 bpm 1650 psi. At 250 bbls slow pumps to 3 bpm 1420 psi. Bump plug, pressure 500 psi over to 920 psi for 5 min. Check floats / FIC good. CIP @ 2:38 Hrs. Page 2147 Report Printed: 711812018 MT6-05 DOYON 19 Job: DRILLING ORIGINAL Time Log Stan Depth Slav Time End Time our (hr) Phase Op Code Acfivity Code Tme PJA Operation (MB) End Depth(WK 5/15/2018 5/15/2018 0.75 SURFAC CEMENT W W WH P Disconnect lines to knife valve. Flush 0.0 0.0 02:45 03:30 riser, function diverter annular and flush again 3X w/black H2O. 5/15/2018 5/15/2018 1.50 SURFAC CEMENT RURD P RID cement lines. B/D same. RID 0.0 0.0 03:30 05:00 volant & UD same. B/O landing jt & UD same. UD 90' mouse hole. 5/15/2018 5/15/2018 7.00 SURFAC CEMENT NUND P Remove hole fill & bleeder lines. Drain 0.0 0.0 05:00 12:00 lines. Disconnect Koomy lines. N/D riser. N/D diverter annular & knife valve. N/D diverter line. Remove barricade. 5/15/2018 5/15/2018 1.75 SURFAC WHDBOP NUND P N/U well head & test void 1/1000 psi 0.0 0.0 12:00 13:45 1/10 min good. SIMOPS cont, to remove diverter line sections from back of pad. 5/15/2018 5/15/2018 6.00 SURFAC WHDBOP NUND P N/U BOPE. Tighten speed head. N/U 0.0 0.0 13:45 19:45 choke & kill lines under rig floor. Tighten BOPE rams doors. SIMOPS - Test gas alarms. M/U rocket launcher. 5/15/2018 5/16/2018 4.25 SURFAC WHDBOP MPDA P M/U MPD equipment. N/U MPD 0.0 0.0 19:45 00:00 clamp, orbit valve, flow box, trip nipple, Katch Kan, & 1502 lines. SIMOPS - grease choke, clean pits, install 90' mouse hole. P/U test jt & M/U test plug. 5/16/2018 5/16/2018 3.00 SURFAC WHDBOP MPDA P Cont. to N/U MPD valves. Install lest 0.0 0.0 00:00 03:00 plug. Fill stack w/H20. Energize accumulator unit. Test MPD system to 250 psi for 5 min & 1200 psi for 10 min on chart (good). 5/16/2018 5/16/2018 1.50 SURFAC WHDBOP MPDA P Remove MPD test plug & install trip 0.0 0.0 03:00 04:30 nipple.Align trip nipple for air boots. 5/16/2018 5/16/2018 0.50 SURFAC WHDBOP RURD P Install 5" test joint. R/U BOPE test 0.0 0.0 04:30 05:00 equipment. Fill trip nipple & lines w/H2O 5/16/2018 5/16/2018 - 7.00 SURFAC WHDBOP BOPE P Test BOPE 250/3500 for 5/10 min's 0.0 0.0 05:00 12:00 w/5 test joints. Annular, 4" Demco, Choke valves 1 - 14; IBOP's, Choke - needle valve, Upper/lower 3-1/2" X 6" • VBR's & blind rams, 5" DarVFOSV, HCR / Man choke/kill, Accumulator test, Initial 3020 psi, final 1500 psi, 1st 200 psi recharge = 25 sec's, full recharge = 142 second. Gas alarms, PVT alarms and flow indicated tested. Draw down on chokes V1100 psi. AOGCC Brian Bixby witness, BLM Mutasim Elganzoory waived witness via email. (Auto IBOP Fail/Pass) 5/16/2018 5/16/2018 0.75 SURFAC WHDBOP RURD P RID testing equipment & B/D same. 0.0 0.0 12:00 12:45 Install 12.375" ID wear ring. 5/16/2018 5/16/2018 4.75 SURFAC WHDBOP BOPE T Bring IBOP tools to rig floor. C/O 0.0 0.0 12:45 17:30 upper/lower IBOP assembly. Test same 250 psi for 5 min & 3500 psi for 10 min (good). M/U fedder bolts & wire tie bolts. SIMOPS - install rubber seal underneath flow box. 5/16/2018 5/16/2018 1.25 SURFAC CEMENT BHAH P Bring BHA tools & equipment to rig 0.0 0.0 17:30 18:45 1 1 1 1 floor. SIMOPS - M/U Baker BPA 5/16/2018 5/16/2018 3.75 SURFAC CEMENT BHAH P M/U 12-1/4" BHA#2 as per Baker rep 0.0 622.0 18:45 22:30 to 60'. Plug in and down -load MWD. Cont. to M/U BHA to 622' 5/16/2018 5/16/2018 0.50 SURFAC CEMENT TRIP P RIH w/BHA#2 f/622'to 1750' 622.0 1,750.0 22:30 23:00 Page 3/47 ReportPrinted: 7118/2018 ;•< MT6-05 Rig: DOYON 19 Job: DRILLING ORIGINAL Time Log - - - '-- - - sten Depth StanTime End Time Dur(hr) Phase Op Code Activity Code Time PT -X Operation (ttKB) End Depth(ftKB) 5/16/2018 5/16/2018 0.50 SURFAC CEMENT DHEQ P Shallow hole test MWD tools w/gpm / 1,750.0 1,750.0 23:00 23:30 psi. Circ BIU & cond for casing test. SIMOPS - RA) testing equipment. 5/16/2018 5/17/2018 0.50 SURFAC CEMENT PRTS P Pressure test casing to 2500 psi & 1,750.0 1,750.0 23:30 00:00 chart for 30 min (good). 5/17/2018 5/17/2018 0.50 SURFAC CEMENT PRTS P Finish csg test. & RID testing 1,750.0 1,750.0 00:00 00:30 equipment. 5/17/2018 5/17/2018 4.25 SURFAC CEMENT DRLG P Wash down & tag TOC @ 1,925'. Drill 1,750.0 2,024.0 00:30 04:45 out shoe track & rat hole from 1,925' to 2,024' w/750 gpm 11850 psi, 80 rpm 11.2 k trq. (Float collar & shoe on depth. 5/17/2018 5/17/2018 0.75 SURFAC CEMENT DDRL P Drill 20'new formation f/2,024'to 2,024.0 2,044.0 04:45 05:30 2,044', ADT .2 Hrs w/750 gpm / 1440 psi, 150 rpm / 6.5/2 k trq. SIMOPS - Displace to new 9.4 ppg LSND on the fly 5/17/2018 5/17/2018 0.75 SURFAC CEMENT CIRC P Circ B/U & cond mud for FIT, pump 2,024.0 1,939.0 05:30 06:15 out of hole f/2,044'to 1,939'w/750 gpm / 1250 psi. (No rotation while pulling BHA across shoe) 5/17/2018 5/17/2018 0.25 SURFAC CEMENT RURD P B/D top drive & R/U testing equipment 1,939.0 1,939.0 06:15 06:30 1 for FIT 5/17/2018 5/17/2018 0.50 SURFAC CEMENT FIT P FIT to 18.0 ppg w/9.4 ppg mud. Pump 1,939.0 1,939.0 06:30 07:00 1.5 bbls @ 890 psi 5/17/2018 5/17/2018 0.50 INTRMI DRILL REAM P W&Rf/1,939' to 2,044'w/750 gpm/ 1,939.0 2,044.0 07:00 07:30 1 1320 psi, 50 rpm / 3 k trq 5/17/2018 5/17/2018 4.50 INTRM1 DRILL DDRL P Drill ahead f/2,044' to 2,598' MD / 2,044.0 2,598.0. 07:30 12:00 2,507' TVD, ADT 3.3 Hrs, ECD 9.95 ppg, 750 gpm, 1440 psi, PU wt 135 k, SO wt 125 k, ROT wt 132 k, 150 rpm, 6.5/2ktrq 5/17/2018 5/17/2018 11.75 INTRMI DRILL DDRL P Drill ahead f/2,598" to 4,388' MD / 2,598.0 4,388.0 12:00 23:45 3,930' TVD, ADT 8.7 Hrs, ECD 10.3 ppg, 900 gpm, 2560 psi, PU wt 163 k, SO wt 140 k, ROT wt 158 k, 175 rpm, 9.5/4 ktrq. 5/17/2018 5/18/2018 0.25 INTRM1 DRILL PMPO P Pump OOH w/425 gpm 1680 psi 4,388.0 4,328.0 23:45 00:00 f/4,388'to 4,328'. Paced Ghost Reamer @ 4328.5' between jts #1 & #2 on stand #40 5/18/2018 5/18/2018 0.25 INTRMI DRILL WASH P Wash back in hole f/4,328'to 4,388' 4,328.0 4,78-8-0- 00:00 00:15 w/385 gpm / 590 psi 5/18/2018 5/18/2018 8.50 INTRMI DRILL DDRL P Drill ahead f/4,388'to 5,523' MD / 4,388.0 5,523.0 00:15 08:45 4,725' TVD, ADT 6.0 Hrs, ECD 10.57 ppg, 900 gpm, 2660 psi, PU wt 175 k, SO wt 145 k, ROT wt 162 k, 180 rpm, 11.5/5 ktrq. 5/18/2018 5/18/2018 2.25 INTRMI DRILL RGRP T C/O pulsation dampener on mud 5,523.0 5,523.0 08:45 11:00 pump #2. Reciprocate pipe w/330 gpm /530 psi, 80 rpm / 6.5 k trq 5/18/2018 5/18/2018 0.50 INTRMI DRILL SVRG P Sevice rig & draw works 5,523.0 5,523.0 11:00 11:30 5/18/2018 5/18/2018 0.50 INTRM1 DRILL DDRL P Drill ahead f/5,523'to 5,551' MD / 5,523.0 5,551.0 11:30 12:00 4,745' TVD, ADT 0.2 Hrs, ECD 10.57 ppg, 900 gpm, 2660 psi, PU wt 175 k, SO wt 145 k, ROT wt 162 k, 180 rpm, 11.5/5 ktrq. 5/18/2018 5/19/2018 12.00 INTRMI DRILL DDRL P Drill ahead (/5,551' to 6,935' MD / 5,551.0 6,935.0 12:00 00:00 5,721' TVD, ADT 8.9 Hrs, ECD 10.6 ppg, 900 gpm, 2750 psi, PU wt 202 k, SO wt 154 k, ROT wt 172 k, 170 rpm, 14.515.5 k trq. Page 4147 Report Printed: 7/18/2018 EFY MT6-05 Rig: DOYON 19 Job: DRILLING ORIGINAL Time Log Start Depth StartTime End Time our (hr) Phase Op Code AcOvity Code Time P -T -X Operation (flKB) End Depth (flKB) 5/19/2018 5/19/2018 5.50 INTRMI DRILL DDRL P Drill ahead f/6,935'to 7,595'M51 6,935.0 7,595.0 00:00 05:30 6,187'TVD,ADT 4.1 Hrs, ECD 10.75 ppg, 900 gpm, 2980 psi, PU wt 215 k, SO wt 158 k, ROT wt 182 k, 150 rpm, 16/7 ktrq. 5/19/2018 5/19/2018 0.75 INTRMI DRILL CIRC P Circ & cond w/900 gpm 12980 psi, 7,595.0 7,595.0 05:30 06:15 120 rpm / 8 k trq 5/19/2018 5/19/2018 0.25 INTRMI DRILL OWFF P F/C (static) 7,595.0 7,595.0 06:15 06:30 5/19/2018 5/19/2018 1.00 INTRMI DRILL MPDA P Pull trip nipple & install RCD bearing. 7,595.0 7,595.0 06:30 07:30 Break in bearing as per MPD hand w/900 gpm / 2990 psi, 50 - 150 rpm 17 -8 k trq. 5/19/2018 5/19/2018 4.50 INTRMI DRILL DDRL P Drill ahead V7,595'to 8,042' MD/ 7,595.0 8,042.0 07:30 12:00 6,504' TVD, ADT 3.3 Hrs, ECD 10.88 ppg, 900 gpm, 3150 psi, PU wt 230 k, SO wt 165 k, ROT wt 190 k, 150 rpm, 1719 k trq. 5/19/2018 5/19/2018 8.00 INTRMI DRILL DDRL P Drill ahead f/8,042'to 8,933' MD / 8,042.0 8,933.0 12:00 20:00 7,132'TVD,ADTXHm, ECD11.0 ppg, 900 gpm, 3500 psi, PU wt 230 k, SO wt 165 k, ROT wt 190 k, 150 rpm, 17/9 ktrq. 5/19/2018 5/19/2018 3.75 INTRMI CASING CIRC P Pump 30 bbls high wt nut plug sweep 8,933.0 i 8,819.0 20:00 23:45 & circ hole clean for 3 B/U w/900 gpm / 3500 psi, 170 rpm / 9 - 10 k trq. 10.5 ppg In/Out. UD single it & racked back 1 stand to 8,819' 5/19/2018 5/20/2018 0.25 INTRMI CASING OWFF P F/C to determine if 10.5 ppg is final 8,819.0 8,819.6- 23:45 00:00 1mud wt (static) 5/20/2018 5/20/2018 2.75 INTRMI CASING CIRC P Cont to circ hole clean for 6+ B/U total 8,819.0 8,629.0 00:00 02:45 w/900 gpm / 3500 -3320 psi, 170 - 150 rpm / 10 k trq. Pumped nut plug sweep after 5th B/U. Racked back 2 stands to 8,629' 5/20/2018 5/20/2018 0.25 INTRMI CASING OWFF P F/C (static). SIMOPS -line up MPD 8,629.0 8,629.0 02:45 03:00 equipment to strip OOH 5/20/2018 5/20/2018 3.25 INTRM1 CASING SMPD P Strip OOH as per MPD schedule 8,629.0 4,863.0 03:00 06:15 f/8,629'to 4,863'. Few tight spots, worked thru once and clear. 5/20/2018 5/20/2018 0.25 INTRMI CASING OWFF P F/C (static). SIMOPS - PJSM on 4,863.0 4,863.0 06:15 06:30 removing RCD bearing 5/20/2018 5/20/2018 0.50 INTRMI CASING MPDA P Pull RCD bearing & install trip nipple. 4,863.0 4,863.0 06:30 07:00 5/20/2018 5/20/2018 0.50 INTRMI CASING CIRC P Circ B/U w/900 gpm / 2760 psi, 180 4,863.0 4,771.0 07:00 07:30 rpm /7 k trq. Rack back 1 stand (/4,863' to 4,771' 5/20/2018 5/20/2018 3.00 INTRMI CASING TRIP P POOH f/4,771'to 1,939'. Few tight 4,771.0 1,939.6- 07:30 10:30 spots, worked thru once and clear. 5/20/2018 5120/2018 0.50 INTRMI CASING CIRC P Pump 30 bbl sweep & circ clean 1,939.0 1,845.0 10:30 11:00 w/900 gpm / 2100 psi, 120 rpm / 3 k trq. Rack back 1 stand f/1,939'to 1,845' 5/20/2018 5/20/2018 0.50 INTRM1 CASING OWFF P F/C (static) 1,845.0 1,845.0 11:00 11:30 5/20/2018 5/20/2018 0.75 INTRM1 CASING TRIP P POOH f/1,845'to 622' 1,845.0 622.0 11:30 12:15 5/20/2018 5/20/2018 0.25 INTRMI CASING OWFF P F/C (static) 622.0 622.0 12:15 12:30 5/20/2018 5/20/2018 2.25 INTRMI CASING BHAH P Rack back HWDP &jars & UD BHA 622.0 0.0 12:30 14:45 as per Baker reps f/622'to surface. Bit Grade: 2 -1 -CT -G -X -I -LT -TD Page 5147 ReportPrinted: 7/18/2018 MT6-05 Rig: DOYON 19 Job: DRILLING ORIGINAL Time Log start Depth Start Time End lime Dur (m) Phase Op Code -. Acpvity Code Time P -T -X Operation (WB) End DepN(ftK6) 5/20/2018 5/20/2018 1.00 INTRMI CASING BHAH P Clean& clear floor of BHA tools& 0.0 0.0 14:45 15:45 equipment. 5/20/2018 5/20/2018 0.75 INTRMI CASING WWWH P M/U stack washer to single jt&flush 0.0 0.0 15:45 16:30 stack. Functioned rams & flush again. 5/20/2018 5/20/2018 2.00 INTRMI CASING BOPE P Pull wear ring & set test plug. C/O 0.0 0.0 16:30 18:30 upper rams to 9-5/8" solid body. R/U testing equipment. SIMOPS - R/U Volant 5/20/2018 5/20/2018 1.50 INTRM1 CASING BOPE P Test w/9-5/8" test it. Annular 250 psi 0.0 0.0 18:30 20:00 for 5 min, 2500 psi for 10 min. Upper rams 250 psi for 5 min, 3500 psi for 10 min. 5/20/2018 5/20/1018 0.50 INTRMI CASING BOPE P RID testing equipment. Pull test plug & 0.0 0.0 20:00 20:30 set thin wall casing 13-3/16" casing wear bushing. 5/20/2018 5/20/2018 1.50 INTRMI CASING RURD P RID casing tools & equipment. Install 0.0 0.0 20:30 22:00 mud saver on Volant 5/20/2018 5/21/2018 2.00 INTRMI CASING PUTS P PJSM on running casing. WU shoe 0.0 485.0 22:00 00:00 track & check floats (good). RIH w/9- 5/8" TN -80 40# TXP-HS casing to 485' 5/21/2018 5/21/2018 6.00 INTRMI CASING PUTB P RIH w/9-5/8"f/485'to 4.017'. PU wt 485.0 4,017.0 00:00 06:00 180 k / SO wt 155 k 5/21/2018 5/21/2018 0.50 INTRMI CASING RURD P C/O cup on Volant tool 4,017.0 4,017.0 06:00 06:30 5/21/2018 5/21/2018 1.50 INTRMI CASING CIRC P Circ & cond un -even mud wts w/6 4,017.0 4,017.0 06:30 08:00 bpm / 200 psi. Max mud wt observed 11.0 ppg. 5/21/2018 5/21/2018 2.25 INTRMI CASING PUTB P RIH w/9-518" f/4.017'to 5,476'. PU wt 4,017.0 5,476.0 08:00 10:15 175 k / SO wt 145 k 5/21/2018 5/21/2018 1.00 INTRMI CASING CIRC P Cim & cond un -even mud wts w/8 5,476.0 5,476.0 10:15 11:15 bpm / 320 psi. Max mud wt observed 11.2 ppg 5/21/2018 5/21/2018 2.00 INTRMI CASING PUTB P RIH w/9-5/8" f/5,476' to 6,361'. PU wt 5,476.0 6,361.0 11:15 13:15 240 1<1 SO wt 195k 5/21/2018 5/21/2018 1.00 INTRMI CASING CIRC P Break circ w/5 bpm / 480 psi 6,361.0 6,361.0 13:15 14:15 5/21/2018 5/21/2018 2.75 INTRMI CASING PUTB P RIH w/9-5/8"f/6,361'to 7,669'. PU wt 6,361.0 7,669.0 14:15 17:00 310 k / SO wt 195 k. (Cross threaded 2 its of casing. C/O bad its.) 5/21/2018 5/21/2018 3.00 INTRMI CASING CIRC P Circ & cond un -even mud wts w/8 7,669.0 7,669.0 17:00 20:00 bpm / 520 psi. Max mud wt observed 12+ ppg. Added water & ran centrifuge to condition to 10.5 ppg In / 10.7 ppg Out 5/21/2018 5/21/2018 2.50 INTRM1 CASING PUTB P RIH w/9-5/8" f/7,669- to 8,883". PU wt 7,669.0 8,883.0 20:00 22:30 370 k / SO wt 220 k 5/21/2018 5/21/2018 0.50 INTRMI CASING HOSO P M/U hanger & landing jt. Wash down 8,883.0 8,920.0 22:30 23:00 w/1 bpm & land casing on hanger Qa 8,920.86- 5/21/2018 5/22/2018 1.00 INTRMI CEMENT CIRC P Circ& cond mud for cement job. 8,920.0 8,920.0 23:00 00:00 Stage pumps to 5.5 bpm / 530 psi. Reciprocate pipe 7' due to hanger making contact with lower pipe rams. Max mud wt out observed 11.1 ppg 5/22/2018 5/22/2018 3.50 INTRM1 CEMENT CIRC P Circ & cond mud for cement job. 8,920.0 8,9-2-0.0- 00:00 03:30 Stage pumps F/5.5 to 8 bpm / ICP 530 psi / FCP 400 psi. Reciprocate pipe 7' due to hanger making contact with lower pipe rams. 5/22/2018 5/22/2018 0.50 INTRMI CEMENT KURD P RID mud saver. B/D top drive. RID 8,920.0 8,920.0 03:30 04:00 cement lines. Page 6/47 Report Printed: 7/18/2018 MTG-05 t I Rig: DOYON 19 Job: DRILLING ORIGINAL Time Log Start Depth StartTme End Time our (hr) Phase Op Cade AcOvity Code Time PJTX Operation (fIKB) End Depth(ftKB) 5/22/2018 1512212018 0.50 INTRMI CEMENT CIRC P Break circ lhru cementing lines w/8 8,920.0 8,920.0 04:00 04:30 bpm 1590 psi. PJSM on cementing. 5/22/2018 5/22/2018 3.00 INTRMI CEMENT CMNT P Dowell pump 1.5 bbls H2O & PT lines 8,920.0 8,920.0 04:30 07:30 to 4000 psi (good). Dowell pump 60 bbls 12.0 ppg mud push, drop bottom plug, 42.7 bbls 12.2 ppg 2.31 ft3/sx yield G class lead cement, 49.8 bbls 15.8 ppg 1.16 ft3/sx yield G class tail cement @ 5 bpm. Drop lop plug. Dowell pump 20 Dials H2O. Rig displace w/653 bbls / 6543 stks 10.5 ppg _SND w/8 bpm / 820 psi. At 640 bbis slow pumps to 3 bpm 1530 psi. Did not bump plug, Check floats & slight weeping. CHP @ 7:21 Hrs. 5/22/2018 5/22/2018 0.50 INTRM1 CEMENT OWFF P Install gauge on Volant & slab into 0.0 0.0 07:30 08:00 landing jt. F/C for 30 min. Floats holding. Well static. SIMOPS - RID cementing lines 5/22/2018 5/22/2018 1.75 INTRMI CEMENT RURD P RID Volant & back out landing It LID 0.0 0.0 08:00 09:45 90' mouse hole. Open IBOP's on top drive & BID. SIMOPS - Prep to N/D ROPE. N/D MPD equipment. RID Kalch Kan & hole fill lines. 5/22/2018 5/22/2018 1.25 INTRMI CEMENT WWSP P FMC pull wear Ong. Install pack off& 0.0 0.0 09:45 11:00 1 1 test 5000 psi (good). 5/22/2018 5/22/2018 2.75 INTRMI CEMENT NUND P Pull trip nipple & RID flow line. Loosen 0.0 0.0 11:00 13:45 - studs on well head. LID flow box. P/U & move BOPE away from well head. 5/22/2018 5/22/2018 1.50 INTRMI CEMENT NUND P FMC NIU 7" casing spool. Set BOPE 0.0 0.0 13:45 15:15 back on well head. Torque lower flange & test void to 5000 psi 115 min (good). Torque upper spool to BOPE. 5/22/2018 5/22/2018 1.00 INTRM1 CEMENT NUND P C/O upper rams to 4-1/2" X 7" VBR's 0.0 0.0 15:15 16:15 5/22/2018 5/22/2018 2.50 INTRM1 CEMENT MPDA P Install flow box. NIU MPD equipment. 0.0 0.0 16:15 18:45 Install trip nipple. 5/22/2018 5/22/2018 4.50 INTRMI WHDBOP RURD P Install mouse hole. RID to test BOPE. 0.0 0.0 18:45 23:15 Fill stack w/H20 & flood lines. Check for leaks. H2O leaking out of MPD trip nipple clamp. Truoble shoot. Decision made to BOPE test without trip nipple. r Perform BOPE shell test (good). RID ball mill to AD LOT. Attempt to PT ball mill lines and having trouble with pumnps. Trouble shoot pumnps. PTY to 2500 psi good. 5/22/2018 5/23/2018 0.75 INTRM1 WHDBOP BOPE P Begin BOPE test w/5" test jt. Tested 0.0 0.0 2315 00:00 gas alarms. SIMOPS -AD LOT on 13- 3/8" X 9-5/8" annulus. 5/23/2018 5/23/2018 5.50 INTRM1 - WHDBOP BOPE P Test BOPE 250/3500 for 5/10 min's 0.0 0.0 00:00 05:30 w/4", 5" & 7" testjoints. Annular, 4" Demco, Choke valves 1 - 14; IBOP's, Choke needle valve, Upper 4-1/2" X 7" VBR's, lower 3-1/2" X 6" VBR's & blind rams, 5" Dad/FOSV, HCR / Man choke/kill, Accumulator test, Initial 3050 psi, final 1400 psi, 1st 200 psi recharge = 32 sec's, full recharge = 172 second. Gas alarms, PVT alarms and flow indicated tested. Draw down on chokes U1100 psi. AOGCC Jeff Jones & BLM Mutasim Elganzoory waived witness via email. Page 7147 Report Printed: 711 812 01 8 MT6-05 i Rig: DOYON 19 Job: DRILLING ORIGINAL Time Log Stag Depth Start Time End Tone, Dur(hr) Phase Op Code Activity Code Time PT -X Operaff n (ftKB) End Depth(flKe) 5/23/2018 5/23/2018 0.50 INTRMI WHDBOP BOPE P RID testing equipment & BID lines 0.0 0.0 0530 06:00 5/23/2018 5/23/2018 1.00 INTRMI CEMENT MPDA P Install MPD test plug & test 250/1200 0.0 0.0 06:00 07:00 psi for 5 min. Pull MPD test plug & install trip nipple. 5/23/2018 5/23/2018 0.50 INTRMI CEMENT RURD P FMC set 8.75" ID wear ring. SIMOPS 0.0 0.0 07:00 07:30 5/23/2018 5/23/2018 0.50 INTRM1 CEMENT RURD P FMC set 8.75" ID wear ring. SIMOPS- 0.0 0.0 07:30 . 08:00 Bring BHAtools & equipment to rig floor. 5/23/2018 5/23/2018 1.00 INTRMI CEMENT SHAH P M/U clean out BHA #3 as per Baker to 0.0 399.0 08:00 09:00 399' 5/23/2018 5/23/2018 4.25 INTRM1 CEMENT TRIP P RIH f/399'to 8,746' 399.0 8,746.0 09:00 13:15 5/23/2018 5/23/2018 1.50 INTRMI CEMENT PRTS P B/D top drive. R/U testing equipment. 8,746.0 8,746.0 13:15 14:45 Pressure test casing to 3000 psi & chart for 30 min (good). RID testing equipment. 5/23/2018 5/232018 1.00 INTRMI CEMENT SLPC P Slip & cut 68' drill line. 8,746.0 8,746.0 14:45 15:45 5/23/2018 5/23/2018 0.50 INTRMI CEMENT SVRG P Service rig, top drive & draw works. 8,746.0 8,746.0 15:45 16:15 1Calibrate block height. 5/23/2018 5/23/2018 0.50 INTRMI CEMENT COCF P Wash down f/8,746'to 8,829'w/525 8,746.0 8,829.0 16:15 16:45 gpm / 1960 psi. 5/23/2018 5/23/2018 1.00 INTRMI CEMENT DRLG P Drill shoe track & rat hole f/8,829'to 8,829.0 8,933.0 16:45 17:45 8,933'w/550 gpm / 2000 psi, 65 - 70 rpm 112 k trq 5/23/2018 523/2018 0.75 INTRMI CEMENT DDRL P Drill 20' new hole f/8,933'to 8,953' 8,933.0 8,953.0 17:45 18:30 MD / 7,146' TVD, ADT .7 Hrs 5/23/2018 5/23/2018 0.75 INTRMI CEMENT CIRC P Circ & cond for FIT w/550 gpm / 1900 8,953.0 8,903.0 18:30 19:15 psi, 70 rpm 112 k trq. Rack back 1 stand (/8,953' to 8,903' 5/23/2018 5/23/2018 0.25 INTRMI CEMENT OWFF P F/C (static) 8,903.0 8,9030 19:15 19:30 5/23/2018 5/23/2018 1.00 INTRM1 CEMENT FIT P R/U testing equipment. FIT to 14.0 8,903.0 8,903.0 19:30 20:30 ppg (1320 psi w/10.45 ppg MW). R/D testing equipment 5/23/2018 5/23/2018 0.25 INTRM2 DRILL REAM P W&R f/8,903'to 8,953'w/350 gpm/ 8,903.0 8,953.0 20:30 20:45 1000 psi, 70 rpm / 13 k trq. Pump 30 bbls spacer & displace to 10.8 ppg LSND on the fly. 5/23/2018 5/23/2018 2.25 INTRM2 DRILL DDRL P Drill ahead SDL rat hole f/8,953' to 8,953.0 9,000.0 20:45 23:00 9,000' MD / 7,179' TVD. ADT 1.2 Hrs, 550 gpm, 1900 psi, PU wt 220 k, SO wt 170 k, ROT wt 190 k, 70 rpm, 1219.5 k trq. 5/23/2018 5/23/2018 0,75 INTRM2 CSGDRL BKRM P BROOH f/9,000'to 8,872'w/550 gpm 1 9,000.0 8,872.0 23:00 23:45 1900 psi, 70 rpm / 9 k trq. SPR's 5/23/2018 5/24/2018 0.25 INTRM2 CSGDRL CIRC P FIC (static) Pump 30 bbl 12.5 ppg dry 8,872.0 8,872.0 23:45 00:00 job. 5/24/2018 5/24/2018 5.75 INTRM2 CSGDRL TRIP P POOH f/8,872'to 399' 8,872.0 3WO 00:00 05:45 5/24/2018 5/24/2018 0.25 INTRM2 CSGDRL OWFF P F/C (static) 399.0 399.0 05:45 06:00 5/24/2018 5/24/2018 0.75 INTRM2 CSGDRL SHAH P UD BHA#3 as per Baker f/399'to 399.0 0.0 06:00 06:45 surface. 5/24/2018 5/24/2018 1.50 INTRM2 CSGDRL SHAH P Clean & clear floor of BHA tools & 0.0 0.0 06:45 08:15 equipment. Mobilize SDL components to rig floor. Page 8/47 Report Printed: 7118/2018 MT6-05 Rig: DOYON 19 Job: DRILLING ORIGINAL Time Log Start Depth Slav Time En Time our (hr) Phase Op Gotle ACUWty CMe Time P -T-% Ope26un (ftKe) EM Depth(ftKe) 5/24/2018 5/24/2018 3.00 INTRM2 CSGDRL BHAH P PJSM. M/U 6" SDL BHA as per Baker 0.0 0.0 08:15 11:15 reps. Plug into MWD. M/U bit. Rack back BHA in derrick. SIMOPS - Cont. to bdng SDL & 7" liner running components to rig floor. 5/24/2018 5/24/2018 1.75 INTRM2 CSGDRL RURD P R/U to run 7" SDL liner. (power tongs, 0.0 0.0 11:15 13:00 slips, elevators, elc0. SIMOPS - Mobilize inner string working platform Ito rig floor. 5/24/2018 5/24/2018 6.25 INTRM2 CSGDRL PUTB P PJSM. M/U Baker reamer shoe assy. 0.0 2,485.0 13:00 19:15 RIH w/7" 26# L-80 Tenaris Blue SDL liner to 2,485'. PU wt 112 k / SO wt 110k 5/24/2018 5/24/2018 1.25 INTRM2 CSGDRL RURD P WU lower quick connect. Clean & 0.0 0.0 19:15 20:30 clear floor. Set up inner string working platform., C -plate, & false table. 5/24/2018 5/24/2018 1.50 INTRM2 CSGDRL BHAH P M/U6" inner string BHA &RIH to 0.0 159.0 20:30 22:00 159'. (MWD plug into tools & double check connections & communication.) 5/24/2018 5/24/2018 1.00 INTRM2 CSGDRL TRIP P RIH inner string w/4" DP out of derrick 159.0 650.0 22:00 23:00 f/159' to 650' (Drift each stand w/2.0" OD drift) 5/24/2018 5/24/2018 0.25 INTRM2 CSGDRL SFTY P Perform kick while tripping drill with 650.0 650.0 23:00 23:15 kick stand & SDL. 6.5 min response time. Hold AAR on drill. UD kick stand. 5/24/2018 5/25/2018 0.75 INTRM2 CSGDRL TRIP P RIH inner string w/4" DP out of derrivk 650.0 1,565.0 23:15 00:00 f/650' to 1,565'. (Drift each stand w/2.0" OD drift) 5/25/2018 5/25/2018 1.00 INTRM2 CSGDRL TRIP P RIH inner string w/4" DP out of derrivk 1,565.0 2,531.0 00:00 01:00 f11,565' to 2,531'. (Drift each stand w/2.0" OD drift) 5/25/2018 5/25/2018 0.75 INTRM2 CSGDRL HOSO P No Go out, M/U space out pups & 2,531.0 2,560.0 01:00 01:45 space out inner string. M/U HRDE running tool & tie in innerstring to liner. 5/25/2018 5/25/2018 0.50 INTRM2 CSGDRL RURD P RID false table, false bowl & slips. 2,560.0 2,560.0 01:45 02:15 Clean & clear floor. SIMOPS - Baker reps install blocks & locks on quick connect. 5/25/2018 5/25/2018 0.75 INTRM2 CSGDRL BHAH P M/U flow diverter, stabilizer, & float 2,560.0 2,582.0 02:15 03:00 sub. 5/25/2018 5/25/2018 0.50 INTRM2 CSGDRL TRIP P RIH w/SDL f/2,582'to 3,050' 2,582.0 3,050.0 03:00 03:30 5/25/2018 5/2512018 0.25 INTRM2 CSGDRL DHEQ P Shallow hole test MWD 3,050.0 3,050.0 03:30 03:45 5/25/2018 5125/2018 6.00 INTRM2 CSGDRL TRIP P RIH w/SDL f/3,050'to 8,730' 3,050.0 8,730.0 03:45 09:45 5/25/2018 5/25/2018 0.25 INTRM2 CSGDRL MPDA P Pull trip nipple & install RCD bearing. 8,730.0 8,730.0 09:45 10:00 5/25/2018 5/25/2018 0.50 INTRM2 CSGDRL TRIP P RIH w/SDL f/8,730'to 8,995' 8,730.0 8,995.0 10:00 10:30 5/25/2018 5/25/2018 0.25 INTRM2 CSGDRL CIRC P Shoot MWD survey. SPR's 8,995.0 8,995.0 10:30 10:45 j 5/25/2018 5/25/2018 0.25 INTRM2 CSGDRL REAM P W&R (/8,995 to 9,000'w/250 gpm / 8,995.0 9,000.0 10:45 11:00 1830 psi, 30 rpm / 9 k trk 5/25/2018 5/25/2018 1.00 INTRM2 CSGDRL DCSG P Drill ahead w/SDL f/9,000'to 9,047' 9,000.0 9,047.0 11:00 12:00 MD 17,212' TVD, ADT 1.0 Hrs, ECD 11.62 ppg, 250 gpm, 1880 psi, PU wt 260 k, SO wt 200 k, ROT wt 220 k, 35 rpm, 10.5/9 k trq, WOB 217 k, MPD on connections. (Reduced mud wt from 10.8 ppg to 10.3 ppg) Page 9147 Report Printed: 711812018 - MT6-05 Rig: DOYON 19 Job: DRILLING ORIGINAL Time Log - - - - Start Depth-' SlartTime. EndTime. our (hr) Phase Op Code AcVivity Code Time P -T -X Operation _ (MB), End Depth (111(p) 5/25/2018 5/26/2018 12.00 INTRM2 CSGDRL DCSG P Drill ahead w/SDL f/9,047'to 9,453' 9,047.0 9,453.0 12:00 00:00 MD 17,487' TVD, ADT 11.4 Hrs, ECD 11.4 ppg, 650 gpm, 2700 psi, ROT wt 220 k, 35 rpm, 13/10 k trq, WOB 2113 k, MPD on connections. 5/26/2018 5/26/2018 12.00 INTRM2 CSGDRL DCSG P Drill ahead w/SDL f/9,453'to 9,968' 9,453.0 9,968.0 00:00 12:00 MD / 7,754' TVD, ADT 10.7 Hrs, ECD 11.6 ppg, 650 gpm, 2760 psi, ROT wt 220 k, 50 rpm, 13.5/8.5 k trq, WOB 4/8k, MPD on connections. 5/26/2018 5/27/2018 12.00 INTRM2 CSGDRL DCSG P Drill ahead w/SDL f/9,968'to 10,488' 9,968.0 10,488.0 12:00 00:00 MD / 7,911' TVD, ADT 10.7 Hrs, ECD 11.46 ppg, 650 gpm, 2790 psi, ROT wt 223 k, 50 rpm, 12.5/9 k trq, WOB 5/16 k, MPD on connections. 5/27/2018 5/27/2018 12.00 INTRM2 CSGDRL DCSG P Drill ahead w/SDL f/10,488' to 10,961' 10,488.0 10,961.0 00:00 12:00 MD / 7,980' TVD, ADT 11.1 Hrs, ECD 11.42 ppg, 650 gpm, 2760 psi, ROT wt _ 225 k, 50 rpm, 15/11.5 k trq, WOB 5/10 k, MPD on connections. 5/27/2018 5/27/2018 10.00 INTRM2 CSGDRL DCSG P Drill ahead w/SDLf/10,961'to TO 10,961.0 11,225.0 12:00 22:00 11,225' MD /8,014' TVD, ADT 9.3 Hes, ECD 11.41 ppg, 650 gpm, 2760 psi, ROT wt 230 k, 50 rpm, 22/10 k trq, WOB 2/14 k, MPD on connections. (Drilled to 11,211', Closed reamer & cont. to drill to TO of 11,225', 8-3/4" hole @ 11,164) 5/27/2018 5/28/2018 2.00 INTRM2 CEMENT CIRC P Close ribs on Autotrack, Pump up final 11,225.0 11,225.0 22:00 00:00 survey. Start weighting up from 10.3 ppg to 10.6 ppg w/700 gpm / 3000 psi. 5/28/2018 5/28/2018 2.00 INTRM2 CEMENT CIRC P Cont. to wt up to 10.8 ppg. w/700- 11,225.0 11,225.0 00:00 02:00 525 gpm / 2960 -1920 psi. Maintaining ECD's 11.5 -11.6 ppg. 5/28/2018 5/28/2018 0.75 INTRM2 CEMENT CIRC P Pump w/2 bpm/ 550 psi. Attempt to 11,225.0 11,225.0 02:00 02:45 work liner. PU to 415 k with no movement. Slack off to 230 k. Drop 1.75" OD ball. Slack off to 200 k. Pump ball down w/2 bpm / 550 psi. Ball on seat @ 408 stks. Slack off to 190 k. Pressure up to 3510 psi & shear ball off seat. Pick up & confirm liner released. PU wt 225 k. (7" shoe 11,164' / TOL 8,666) 5/28/2018 5/28/2018 0.25 INTRM2 CEMENT PMPO P Pump BHA out of open hole w/2 bpm/ 11,225.0 11,150.0 02:45 03:00 500 psi. PU wt 225 k 5/28/2018 5/28/2018 0.50 INTRM2 CEMENT CIRC P Circ & cond liner annulus w/330 gpm / 11,150.0 11,150.0 03:00 03:30 2600 psi. 5/28/2018 5/28/2018 0.50 INTRM2 CEMENT OWFF P F/C(static) 11,150.0 11,150.0 03:30 04:00 5/28/2018 5/28/2018 1.00 INTRM2 CEMENT CIRC P Obtain SPR's. Apply back pressure & 11,150.0 11,055.0 04:00 05:00 check to see if floats holding. Floats not holding. Pump 35 bbl 12.8 ppg dry job. Rack back 1 stand f/11,150' to 11,055' 5/28/2018 5/28/2016 4.75 INTRM2 CEMENT SMPD P Strip OOH f/11,055'to 2,766'. Floats 11,055.0 2,766.0 05:00 09:45 not holding. Dry job allowed us to not have to screw into each stand, but half of the stand was still wet pipe. 5/28/2018 5/28/2018 0.25 INTRM2 CEMENT OWFF P F/C (static) 2,766.0 2,766.0 09:45 10:00 5/28/2018 5/28/2018 0.25 INTRM2 CEMENT MPDA P Pull RCD bearing & install trip nipple. 2,766.0 2,766.0 10:00 10:15 Page 10/47 Report Printed:7/18/2018 -_ a MT6-05 Rig: DOYON 19 Job: DRILLING ORIGINAL Time Log start Depth StartTime End❑me Dur(hr) Phase Op Code Activity Code Time P -T -X Operation (fiKB) End Depth(ffB' 5/28/2018 5/28/2018 0.25 INTRM2 CEMENT TRIP P POOH f/2,766'to 2,582' 2,766.0 2,582.0 10:15 10:30 5/28/2018 5/28/2018 0.75 INTRM2 CEMENT BHAH P UD float sub, stabilizer, flow diverter& 2,582.0 2,538.0 10:30 11:15 liner running tool. C/O handling equipment to 4" 5/28/2018 5/28/2018 1.75 INTRM2 CEMENT TRIP P POOH & rack back 4" DP (/2;538' to 2,538.0 159.0 11:15 13:00 159' 5/28/2018 5/28/2018 0.50 INTRM2 CEMENT BHAH P Clean & clear floor of excess BHA 159.0 159.0 13:00 13:30 tools & equipment. 5/28/2018 5/28/2018 1.50 INTRM2 CEMENT BHAH P UD BHA #4 as per Baker reps. 159.0 0.0 13:30 15:00 5/28/2018 5/28/2018 0.50 INTRM2 CEMENT BHAH P Clean & clear floor of excess BHA 0.0 0.0 15:00 15:30 tools & equipment. 5/28/2018 5/28/2018 0.50 INTRM2 CEMENT RURD P Mobilize casing tools & equipment to 0.0 0.0 15:30 16:00 rig floor. R/U power tongs. 5/28/2018 5/28/2018 0.25 INTRM2 CEMENT BHAH P M/U K-1 cement retainer as per Baker 0.0 0.0 16:00 16:15 reps. 5/28/2018 5/28/2018 1.75 INTRM2 CEMENT TRIP P RIH with retainer to 2,532' 0.0 2,532.0 16:15 18:00 5/28/2018 5/28/2018 0.50 INTRM2 CEMENT PUTB P WU 10.59' pup, SLZXP & anchor assy 2,532.0 2,571.0 18:00 18:30 as per Baker reps to 2,571' (utilized casing tongs & torque turn for packer & anchor assy connection) 5/28/2018 5/28/2018 1.00 INTRM2 CEMENT CIRC P Break circ & stage flow rate up to 4 2,571.0 2,571.0 18:30 19:30 bpm / 260 psi.. SIMOPS UD casing tools & equipment. 5/28/2018 5/29/2018 4.50 INTRM2 CEMENT TRIP P RIH cement retainer/ liner top packer 2,571.0 7,563.0 19:30 00:00 assy with 5" DIP f/2,571'to 7,563'. SO wt 155 k. Disp Calc 50 bbls /Act 50 bbls 5/29/2018 5/29/2018 0.75 INTRM2 CEMENT TRIP P Trip in hole with SOL run #2 7,563.0 8,597.0 00:00 00:45 cementing BHA from 7,563' MD to 8,597' MD. P/U=195k S/0=168k. 5/29/2018 5/29/2018 0.50 INTRM2 CEMENT WASH P Wash down through liner top from 8,597.0 8,692.0 00:45 01:15 8,597' MD to 8.692' MD @ 1 bpm, 210 psi. Blow down top drive. 5/29/2018 5/29/2018 2.75 INTRM2 CEMENT TRIP P Continue RIH from 8,692' MD to 8,692.0 11,083.0 01:15 04:00 - 11,083' MD. P/U=230k, S/0=188k. 5/29/2018 5/29/2018 0.50 INTRM2 CEMENT RURD P M/U BOT cement swivel, cement hose 11,083.0 11,083.0 04:00 04:30 1 land 1502 equipment. 5/29/2018 5/29/2018 0.25 INTRM2 CEMENT CIRC P Establish circulation @ 3 bpm, 500 psi 11,083.0 11,083.0 04:30 04:45 5/29/2018 5/29/2018 0.50 INTRM2 CEMENT WASH P Wash down from 11,083'to 11,109' 11,083.0 11,110.0 04:45 05:15 MD @.5 bpm, 250 psi. Observe pressure increase to 270 psi w/ 3k WOB (Locate seals). P/U and break over, SIO to 11,110' and confirm. Good circulation on,8-3/4" x 7" annulus @ .5 bpm, 270 psi. 5/29/2018 5/29/2018 0.25 INTRM2 CEMENT RURD P Make up 5'spaoe out pup, slack off 11,110.0 11,113.0 05:15 05:30 and no-go out @ 11,113' MD with bleeders open. SIO and set down 10k, P/U and observe 1 O overpull. SIO 30k, P/U 20k over to confirm anchor latched. Slack off to 5k down. 5/29/2018 5/29/2018 5.50 INTRM2 CEMENT CIRC P Circulate and condition, stage up 11,113.0 11,113.0 05:30 11:00 from .5 bpm 280 psi to 4 bpm 830 psi. Partial packoff @ 4650 stks into bottoms up from 830 to 1070 psi, did not lose returns. Reduce rate to 1 bpm to stabilize. 5/29/2018 5/29/2018 1.00 INTRM2 CEMENT CIRC P Circulate and condition @ 1 bpm, 380 11,113.0 11,113.0 11:00 12:00 psi. Page 11147 ReportPrinted: 7/1812018 MT6-05 Rig: DOYON 19 Job: DRILLING ORIGINAL Time Log'_ - _ Start Depth Stan Time End Time Dur(hr) Phase Do Code Activity Code Time P -T -X Operation (ftKB). EM Depth (111<8) 5/29/2018 5/29/2018 2.50 INTRM2 CEMENT CIRC P Continue staging up circulating rale 11,113.0 11,113.0 12:00 14:30 from 1 bpm 380 psi to 2 bpm, 450 psi FCR. . 5/29/2018 5/29/2018 1.50 INTRM2 CEMENT HOSO P Drop/Pump down 1.75" release ball, 11,113.0 11,113.0 14:30 16:00 pump down @ 2 bpm 420 psi. Ball on seat @ 36 bbl away. Set down 10k. Pressure up to 4000 psi hold 1 min. Bleed off slowly to 400 psi. Pressure up and shear out ball seat @ 890 psi, observe pressure bleed off. Break circulation @ 1 bpm, 300 psi. P/U 10' @ 225k, liner released. 5/29/2018 5/29/2018 0.50 INTRM2 CEMENT MPSP P Set KI cement retainer per Baker rep. 11,113.0 11,113.0 16:00 16:30 14 turns to right @ 5 rpm 4k Tq. Set down 30k. P/U and observe slips set. Pull 10k over, set down 30k. P/U to neutral 210k and un -sting. P/U 10'@ 225k, free from retainer. Set down and sting back in with 51k. Break circulation @ 1 bpm, 330 psi. 5/29/2018 5/29/2018 1.50 INTRM2 CEMENT PUCM P PJSM and pump 7" liner cement per 11,113.0 11,113.0 16:30 18:00 program, Flood lines, test to 4000 psi. Pump 20 bbl 11.4 ppg Mud Push @ 2 bpm, 400 psi. Pump 32.4 bbl 12.4 ppg Lead cement @ 1.8 bpm, 193 psi followed by 26 bbl 15.8 ppg tail cement @ 1.9 bpm, 46 psi. Chase with 20 bbl water @ 1.9 bpm, 11 psi. 5/29/2018 5/29/2018 1.50 INTRM2 CEMENT CMNT P Displace cement with rig pump, 10.7 11,113.0 11,113.0 18:00 19:30 ppg LSND @ 2 bpm, 630 psi for 128.3 bbl, reduce to 1 bpm 490-590 psi for final 20 bbl. Total displacement 148.8 bbl. CIP @ 19:30 hrs. 5/29/2018 5/29/2018 0.50 INTRM2 CEMENT PACK P Un -Sting from cement retainer, P/U 22' 11,113.0 11,113.0 19:30 20:00 to expose packer setting dog sub. Slack off and set 50k down, observe packer shear / set. P/U, establish rotary @ 15 rpm, 2k Tq. Set down 50k while rotating, repeat. SLZX Packer set, TOL 8,630' MD. 5/29/2018 5/29/2018 1.00 INTRM2 CEMENT CIRC P P/U to 11,076' MD with running tool, 11,113.0 11,076.0 20:00 21:00 circulatestdng, liner and hole clean of cement @ 8 bpm, 1300 psi. Observe increase in pH of mud returns and cement contamination from 450 bbl away. (Liner top). Pumped total 580 bbl. 5/29/2o18 5/29/2018 0.50 INTRM2 CEMENT OWFF P Monitor well static 30 minutes. 11,076.0 11,046.0 21:00 21:30 SIMOPS- Lay down 2 singles and cement swivel assembly. 5/29/2018 5/30/2018 2.50 INTRM2 CEMENT TRIP P POOH on elevators, racking back 5" 11,046.0 8,971.0 21:30 00:00 DP from 11,046' MD to 8,971' MD. PIU=220k, correct hole fill. 5/30/2018 5/30/2018 0.25 INTRM2 CEMENT TRIP P Pull out on elevators from 8,971' MD 8,971.0 8,690.0 00:00 00:15 to 8,690' MD racking back stands. 5/30/2018 5/30/2018 0.50 INTRM2 CEMENT PMPO P Pump out from 8,690' MD to 8,595' 8,690.0 8,595.0 00:15 00:45 MD @ 350 gpm, 840 psi to flush across the liner top tie back extension. Page 12147 ReportPrinted: 7/1812018 T MT6-05 Rig: DOYON 19 Job: DRILLING ORIGINAL Time Log Start Depth StartTime End Time our (hr) Phase Op Code Activity Code Time P -T -X Operation (ftKB) End Depth(ftKB) 5/30/2018 5/30/2018 0.75 INTRM2 CEMENT CIRC P Pump 20 bbl water pill, circulate S -S 8,595.0 8,595.0 00:45 01:30 @ 650 gpm, 2190 psi. Treating cement contamination in active system. Obtain SPR's, complete circulation with 20 bbl 12.2 ppg slug in pipe. Blow down top drive, P/U=215k, S/0=165k. 5/30/2018 5/30/2018 0.25 INTRM2 CEMENT OWFF P Monitor well for flow, static. 8,595.0 8,595.0 01:30 01:45 5/30/2018 5/30/2018 1.00 INTRM2 CEMENT PULD P POOH laying down 5" DP from 8,595' 8,595.0 7,635.0 01:45 02:45 MD to 7,635' MD, hole fill becoming erratic. Stop to observe. 5/30/2018 5/30/2018 0.25 INTRM2 CEMENT OWFF T Monitor for flow, observe extremely 7,635.0 7,635.0 02:45 03:00 aired up mud flowing. Treat trip tank with De-foamer. Pull 1 joint without hole fill pump on, observe fluid level falling properly. 5/30/2018 5/30/2018 5.00 INTRM2 CEMENT PULD P Continue POOH from 7,635' MD to 7,635.0 2,480.0 03:00 08:00 2,480' MD, laying down 5" DP and cleaning cement rings. Proper hole fill. 5/30/2018 5/30/2018 0.50 INTRM2 CEMENT BHAH P Flow check static, Function annular, 4- 2,480.0 2,480.0 08:00 08:30 1/2" x 7" UPR and 3-1/2" x 6" LI Lay down Baker liner running to to 2,439' MD. Swap to 4" elevators. 5/30/2018 5/30/2018 1.25 INTRM2 CEMENT TRIP P POOH, racking back 4" DP in derrick. 2,480.0 0.0 08:30 09:45 Lay down Baker cement retainer running tools. Trip Calc Fill=85.42 bbl, Actual Fill=86 bbl. 5/30/2018 5/30/2018 0.50 INTRM2 CEMENT PRTS P Function blind rams. R/U and pressure 0.0 0.0 09:45 10:15 test 7" Liner top packer to 1000 psi for 10 minutes on chart. 5/30/2018 5/30/2018 1.00 INTRM2 CEMENT SLPC P PJSM, RIH to 95' and hang blocks. 0.0 95.0 10:15 11:15 Cul and slip 60' drilling line. (SIMOS- C/O top drive stabilizer) 5/30/2018 5/30/2018 0.50 INTRM2 CEMENT SVRG P Service top drive and draworks. C/O 95.0 95.0 11:15 11:45 i oil filter on draworks. 5/30/2018 5/30/2018 0.25 INTRM2 CEMENT BHAH P POOH from 95'. Lay down Baker tools 95.0 0.0 11:45 12:00 and equipment via Beaverslide. 5/30/2018 5/30/2018 0.50 INTRM2 CEMENT RURD P Clean and clear rig floor, Mobilize 0.0 0.0 12:00 12:30 casing equipment to rig floor. 5/30/2018 5130/2018 0.50 INTRM2 CEMENT RURD P FMC pull wear bushing. 0.0 0.0 12:30 13:00 5/30/2018 5/30/2018 0.50 INTRM2 CEMENT RURD P Rig up casing equipment. 0.0 0.0 13:00 13:30 5/30/2018 5/30/2018 10.25 INTRM2 CEMENT PUTB P P/U 7" Baker Bullet seal assy, PIU and 0.0 8,615.0 13:30 23:45 run 7" 26# BTCM tie -back casing string per detail to 8,615' MD. (203 jts) P/U= 240k, S10=1 75k. Pumped 40 bbl 12.8 ppg slugs @ 1,509'., 5,104' and 7,519' due mud running over pipe while RIH. Calc and actual displacement=80 bbl. 5/30/2018 5/31/2018 0.25 INTRM2 CEMENT HOSO P Rig up circ head on jt #204, continue 8,615.0 8,655.0 23:45 00:00 RIH to 8,655' MD to locate TOL. 5/31/2018 5/31/2018 0.25 INTRM2 CEMENT HOSO P Continue RIH with Jt #205 and No -Go 8,655.0 8,660.0 00:00 00:15 with 10k @ 8,659.88' MD. Calculate space out. 5/31/2018 5/31/2018 0.25 INTRM2 CEMENT PRTS P Close annular preventer, pump down 8,660.0 8,660.0 00:15 00:30 kill line and pressure test 9-5/8" x 7" annulus (with casing side open) 1000 psi to confine seals engaged. Page 13147 Report Printed: 7/18120.18 MT6-05 Rig: DOYON 19 Job: DRILLING ORIGINAL Time Log: - - Shoo Depth." Startlime Entl Time Dur (m) Phase Op cad. AcWity Code Time PT -X Operation MIKE) End Depth(ftKa) 5/31/2018 5/31/2018 0.25 INTRM2 CEMENT HOSO P Pick up 22' and pull seals out, pump 2 8,660.0 8,642.0 00:30 00:45 bpm 50 psi, slack off to locate TOL with seals. Observe pressure up 8,640' and returns stopped @ 8,642' MD, holding 350 psi not bleeding down. Verify space out. 5/31/2018 5/31/2018 0.75 INTRM2 CEMENT HOSO P Lay down 3 joints, swap#203 for#205 8,642.0 8,573.0 00:45 01:30 for space out to 8,573' MD. 5/31/2018 5/31/2018 0.50 INTRM2 CEMENT HOSO P Make up BTCM-H563 XO joint, 8,573.0 8,573.0 01:30 02:00 hanger and pup, landing joint. Rig up 1 circulating swedge and cement line. PIU=240k, S/0=175k 5/31/2018 5/31/2018 0.25 INTRM2 CEMENT HOSO P Pump 1.5 bpm 50 psi, slack off to 8,573.0 8,639.0 02:00 02:15 observe seals engaging @ 8,640' to verify space out. Pick up and break over, slack off to 8,639' puffing hanger just below annular preventer. Rig up to reverse in Cl brine and diesel FP. 5/31/2018 5/31/2018 1.25 INTRM2 CEMENT CIRC P Reverse circulate @ 3 bpm, circulating 8,639.0 8,639.0 02:15 03:30 out 3 slugs in pipe. SIMOPS- Rig up Ball Mill to pump diesel, pressure test. _ Rig down casing power tongs. PJSM on brine/diesel displacement. 5/31/2018 5/31/2018 2.00 INTRM2 CEMENT FRZP P Reverse in'30.5 bbl 9.7 ppg HV fresh 8,639.0 8,639.0 03:30 05:30 water spacer, 203 bbl 8.6 ppg Corrosion inhibited seawater. Swap to Ball Mill pump for 42 bbl 6.8 ppg diesel (LEPD) freeze protect @ 2 bpm. Final SIP 1128 psi. 5/31/2018 5/31/2018 0.25 INTRM2 CEMENT HOSO P Slack off stripping through annular, 8,639.0 8,653.8 05:30 05:45 sting in seals for 6'. Bleed off pressure from kill line. Continue slacking off and land 7" hanger @ 8,653.79' Bullet Seal depth. (6.09' off of fully located). 5/31/2018 5/31/2018 0.50 INTRM2 CEMENT RURD P Verify pressure bled off, open annular 8,653.8 0.0 05:45 06:15 preventer. Rig down circulating swedge, blow down lines. Back out and lay down 7" landing joint.. Rig down casing elevators. 5/31/2018 5/3112018 1.25 INTRM2 CEMENT WWSP P FMC set 7" pack -off. R/U and test 0.0 0.0 06:15 07:30 pack -off to 250/5000 psi for 5/15 minutes good. SIMOPS- Lay down 5" subs, equipmentr. P/U 4" handling equipment and subs. Prep tools for ram change. 5/31/2018 5/31/2018 1.75 INTRM2 CEMENT PRTS P Rig up and test 9-5/8" x 7" annulus to 0.0 0.0 07:30 09:15 2500 psi for 30 minutes charted, good. Blow down and rig down. 5/31/2018 5/31/2018 1.75 INTRM2 CEMENT BOPE P Change out upper VBR's from 4-1/2" x 0.0 0.0 09:15 11:00 7" to 3-1/2" x 6". SIMOPS- Change out saver sub from 5" NC50 to 4" XT39. 5/31/2018 5/31/2018 1.00 INTRM2 WHDBOP RURD P Rig up to test BOPE. Fill stack, choke 0.0 0.0 11:00 12:00 manifold, choke and kill lines with water. Purge air from system. Page 14147 Report Printed: 7118/2018 MT6-05 i Rig: DOYON 19 Job: DRILLING ORIGINAL Time Log Stan Depth StartTime Emil Time our (hr) Phase Op Code AcOviy Code Time P -T -X Operation (WB) End! Depth (111<11) 5/31/2018 5/31/2018 4.25 INTRM2 WHDBOP BOPE P Perform AOGCC BOPE test, 250/3500 0.0 0.0 12:00 16:15 psi 5 min ea. AOGCC Lou Laubenstien (5/29 12:43) and BLM Mutasim Elganzoory (5/29 14:00) waived witness via email. 4" Test joint, tested Annular preventer, 4" Demco kill, Choke valves #11, 12,13,14, Upper IBOP, Upper 3'/=" x 6" VBR, HCR Kill. CV #9,11, Manual IBOP, CV# 5, 8, 10, XT39 Dart valve. CV# 4, 6, 7, XT39 FOSV, CV# 2, HCR choke, manual choke and kill, lower 3W x 6" VBR. Swap to 4'S" Test joint, test annular preventer, Upper and lower VBR's, 5/31/2018 5/31/2018 0.25 INTRM2 WHDBOP BOPE P Perform accumulator function lest. 0.0 0.0 16:15 16:30 System pressure=3050 psi. Pressure after functioning all rams, annular and HCR's=1400 psi. 200 psi attained= 29 seconds with electric pump. Full system recovery=178 seconds with electric and air pumps.4 bottle N2 average=2200 psi. 5/31/2018 5/31/2018 0.50 INTRM2 WHDBOP BOPE P Pull testjoint, test Blind rams to 0.0 0.0 16:30 17:00 250/3500 psi 5 min each charted, tested manual and super auto choke to 1100 psi. 5/31/2018 5/31/2018 1.00 INTRM2 WHDBOP RURD P Rig down test equipment, pull test 0.0 0.0 17:00 18:00 1 plug. Set 6.125" ID wear bushing. 5/31/2018 5/31/2018 0.50 INTRM2 CEMENT SVRG P Inspect and service top drive, blocks 0.0 0.0 18:00 18:30 and hook. 5/31/2018 5/31/2018 0.50 INTRM2 CEMENT BHAH P PJSM, Mobilize BHA tools and 0.0 0.0 18:30 19:00 components to rig floor. 5/31/2018 5/31/2018 1.00 INTRM2 CEMENT BHAH P M/U 6" Rock bit/ Zero bend motor 0.0 227.0 19:00 20:00 cleanout BHA#5 to 227' MD per Baker rep. 5/31/2018 6/1/2018 4.00 INTRM2 CEMENT PULD P Single in hole from 227' MD to 4,000' 227.0 4,000.0 20:00 00:00 MD with 14# WearKnot drill pipe from pipe shed. P/U=112k, S/0=100k. Annulus C= 70 psi, Annulus B= 120 psi @ 22:00 hrs. 6/1/2018 6/1/2018 1.00 INTRM2 CEMENT PULD P Continue picking up 4" 14# WearKnot 4,000.0 4,509.0 00:00 01:00 pipe from pipe shed, running in 4,000' MD to 4,509' MD filling pipe every 20 stands. 6/1/2018 6/1/2018 1.00 INTRM2 CEMENT TRIP P Trip in hole from 4,509' MD to 7,092' 4,509.0 7,092.0 01:00 02:00 1 1 MD with 4" 14# DP out of derrick. 6/1/2018 6/1/2018 4.00 INTRM2 CEMENT PULD P Continue singling in hole, picking up 4" 7,092.0 10,903.0 02:00 06:00 15.7# DP from pipe shed 7,092' MD to 10,903' MD filling every 20 stands. Observed string lake —8k briefly while RIH @ 8,663' MD. 6/1/2018 6/1/2018 0.75 INTRM2 - CEMENT CIRC P Circulate 1 string volume @ 10,903' 10,903.0 10,903.0 06:00 06:45 MD 210 gpm, 1660 psi. 6/1/2018 6/1/2018 1.50 INTRM2 CEMENT PRTS P Rig up and test casing to 3500 psi for 10,903.0 10,903.0 06:45 08:15 30 minutes charted, testing tie back string and SDL liner. 6/1/2018 6/1/2018 1.25 INTRM2 CEMENT COCF P Wash and ream down to cement 10,903.0 11,103.0 08:15 09:30 retainer @ 200 gpm, 1560-1180 psi, 8- 98 Tq. Tag firm cement @ 11,102.5' MD. P/U=215k, S/0=143k, R0T=162k. Page 16147 ReportPrinted: 711 812 01 8 MT6-05 Rig: DOYON 19 Job: DRILLING ORIGINAL Time Log . Start Depth - . Start Time End Time our (hQ -Phase_ Op Code ACGvity Code Tme PTX Opers}mn (fiKal. End 0sp1h(W) 6/1/2018 6/1/2018 2.50 INTRM2 CEMENT DRLG P Drill out cement, cement retainer and 11,103.0 11,130.0 09:30 12:00 shoe track from 11,103' MD to 11,130' MD @ 200 gpm, 1330 psi, 50 rpm, 9.5k Tq. SIMOPS- UD 4 stands 5' DP with tugger and mousehole. 6/1/2018 6/1/2018 1.00 INTRM2 CEMENT DRLG P Continue drilling shoe track and 11,130.0 11,225.0 12:00 13:00 rathole from 11,130' MD to 11,225' MD. 6/1/2018 6/1/2018 1.00 INTRM2 CEMENT DDRL P Drill new formation from 11,225' MD to 11,225.0 11,236.0 13:00 14:00 11,236' MD, 8,015' TVD. ADT=.6. P/U=225k, S/0=140k, ROT=164k, Tq on/of f=l1 k/10k. Note: Stopped drilling due low ROP and differential pressure to avoid bit destruction and potentail fishing trip. 6/1/2018 6/1/2018 0.50 INTRM2 CEMENT TRIP P POOH from 11,236' MD to 11,093' 11,236.0 11,093.0 14:00 14:30 MD. 6/1/2018 6/1/2018 1.50 INTRM2 CEMENT " CIRC P Circulate and condition @ 210 gpm, 11,093.0 11,093.0 14:30 16:00 1250 psi, 50 rpm, 8k Tq. Recipricate from 11,093' MD to 10,998' MD. CBU x 1.5. Obtain SPR's. 6/1/2018 6/1/2018 0.50 INTRM2 CEMENT OWFF P Monitor well for flow, static 30 minutes. 11,093.0 11,093.0 16:00 16:30 6/1/2018 6/1/2018 6.50 INTRM2 CEMENT TRIP P POOH on elevators from 11,093' MD 11,093.0 318.0 16:30 23:00 to 318' MD. P/U=75k. Calc 811 for trip=70 bbl, Actual fill=74 bbl. Observed brief 5-10k overpull @ 8,865' -8,862' MD 6/1/2018 6/1/2018 0.25 INTRM2 CEMENT OWFF P Monitor well for flow, static. 318.0 318.0 23:00 23:15 6/1/2018 6/212018 0.75 INTRM2 CEMENT BHAH P Rack back last stand, rack back 318.0 0.0 23:15 00:00 HWDP/Jars, UD BHA#5 from 318' MD. Annulus C= 70 psi, Annulus B= 340 psi @ 22:00 hrs. 6/2/2018 6/2/2018 0.25 INTRM2 CEMENT BHAH P Clean and clear rig floor of BHA#5 0.0 0.0 00:00 00:15 fools. Mobilize BHA#6 tools to rig floor. 6/2/2018 6/2/2018 2.75 INTRM2 CEMENT BHAH P PJSM, M/U BHA#6 to 336' MD per 0.0 336.0 00:15 03:00 Baker DD/ MWD. (Upload sources.) 6/2/2018 6/2/2018 0.75 INTRM2 CEMENT TRIP P Trip in hole from 336' MD to 2,238' MD 336.0 2,238.0 03:00 03:45 out of derrick. 6/2/2018 6/2/2018 1.00 INTRM2 CEMENT DHEQ P Fill pipe, establish circulation and 2,238.0 2,238.0 03:45 04:45 shallow pulse test BHA6 @ 200-250 gpm, 970-1400 psi, 25 rpm, 1.2k Tq. P/U=98k, S10=95k, ROT=93k. 6/2/2018 6/2/2018 5.25 INTRM2 CEMENT TRIP P Trip in hole from 2,238' MD to 11,108' 2,238.0 11,108.0 04:45 10:00 MD out of derrick, filling pipe every 20 stands. 0/1.1=2151k, S/0=135k, ROT=158k, 50 rpm @ 10k Tq. 6/2/2018 6/2/2018 0.25 INTRM2 CEMENT OWFF P OWFF static, slightly aired up. 11,108.0 11,108.0 10:00 10:15 SIMOPS- PJSM on installing RCD. 6/2/2018 6/2/2018 0.50 INTRM2 CEMENT MPDA P Remove trip nipple, install RCD 11,108.0 11,108.0 10:15 10:45 bearing with 1 Natural and 1 Poly element. 6/2/2018 6/2/2018 1.25 INTRM2 CEMENT DLOG P Establish circulation @ 180 gpm, 1270 11,108.0 11,220.0 10:45 12:00 psi. Break in bearing @ 50 rpm, 9.8k for 2 minutes. Perform MAD pass, logging from 11,112' MD to 11,220' MD @ 200 gpm, 1900 psi, 75 rpm, 10k Tq. Log @ 150 fph. 6/2/2018 6/2/2018 1.00 INTRM2 CEMENT REAM P Wash and ream down from 11,220' 11,220.0 11,236.0 1200 13:00 MD to 11,236' MD Page 16147 Report Printed: 7/18/2018 MT6-05 Rig: DOYON 19 Job: DRILLING ORIGINAL Time Log StartTime End Time Dur(ho Phase Op Code Activity Cotle Time P -T -X Operation Start Depth (ttKe) End Depth htKa) 6/2/2018 6/2/2018 0.25 INTRM2 CEMENT DDRL P Drill new formation from 11,236' MD to 11,236.0 11,245.0 13:00 13:15 11,245' MD 6/2/2018 6/2/2018 0.25 INTRM2 CEMENT TRIP P POOH from 11,245' MD to 11,108' 11,245.0 11,108.0 13:15 13:30 MD. P/U=230k, S/0=125k. 6/2/2018 6/2/2018 1.00 INTRM2 CEMENT CIRC P Circulate and condition for FIT @ 200 11,108.0 11,108.0 13:30 14:30 gpm, 1700 psi, 100 rpm, 9k Tq. Circulate 10.6 ppg in and out. 6/2/2018 6/2/2018 1.00 INTRM2 CEMENT FIT P Rig up and perform FIT to 12.5 ppg 11,108.0 11,108.0 14:30 15:30 EMW. Pumped 1.4 bbl @.5 bpm to 770 psi. Rig down test equipment. 6/2/2018 6/2/2018 1.00 PRODI DRILL DLOG P Wash down, logging from 11,108' MD 11,108.0 11,245.0 15:30 16:30 1 to 11,245' MD @ 200 gpm, 150 fph. 6/2/2018 6/2/2018 1.50 PRODI DRILL DISP P PJSM, Displace well from 10.6 LSND 11,245.0 11,245.0 16:30 18:00 to 8.5 ppg MOBM per plan. Pumped 40 bbl DeepClean spacer, 75 bbl HV OBM followed by 376 bbl 8.5 ppg MOBM @ 5 bpm. Rotate 100 rpm, 10k Tq, reciprocate from 11,245' MD to 11,203' MD. Maintain 10.5 ppg EMW with MPD as 8.5 ppg mud comes around annulus. 6/212018 6/2/2018 0.50 PRODI DRILL PMPO P Pump out of hole from 11,245' MD to 11,245.0 11,108.0 18:00 18:30 11,108' MD @ 200 gpm, 1900 psi. PIU=200k. 6/2/2018 6/2/2018 0.50 PRODI DRILL OWFF P Rig up and fingerprint formation. Shut 11,108.0 11,108.0 18:30 19:00 down pump, trapping 422 psi. Open choke for 20 seconds, shut in 5 min build to 65 psi. Open choke for 20 seconds, shut in 5 min build to 43 psi. Open choke for 2 min, shut in 5 build to 38 psi. Gained 1 bbl in trip tank. Formation pressure between 8.5 and 8.6 ppg. (Note: 400-500 units gas on bottoms up) 6/2/2018 6/2/2018 0.50 PRODI DRILL REAM P Wash and ream down from 11,108' 11,108.0 11,245.0 19:00 19:30 MD to 11,245' MD @ 200 gpm, 1930 psi, 100rpm, 9k Tq. Obtain SPR's. 6/2/2018 6/3/2018 4.50 PROD1 DRILL DDRL P Directional Drill from 11,245' MD to 11,245.0 11,679.0 19:30 00:00 11,679' MD, 8,067' TVD. ADT=3.4 him, P/U=200k, S/0=125k, ROT=165k, 140 rpm, Tq on/off=10k/9k. 200 gpm, 2000 psi, 9.8 ppg ECD. Holding 230 psi annular pressure during connections (9.0 ppg) dynamically. - Annulus C= 70 psi, Annulus BE 620 psi @ 22:00 hrs. 6/3/2018 6/3/2018 3.50 PROD1 DRILL DDRL P Directional Drill from 11,679' MD to 11,679.0 12,037.0 00:00 03:30 12,037' MD, 8,044' TVD in Kingak shale. ADT=2.6 hrs, P/U=240k, S/0=110k, ROT=170k, 140 rpm, Tq on/off=8.5k/6k. 200 gpm, 2000 psi, 9.8 ppg ECD. Holding 300 psi annular pressure during connections (9.3 ppg) dynamically. Observe steadily rising and erratic ECD along with pump pressure. Page 17147 ReportPrinted: 7/1 812 01 8 MT6-05 i f Rig: DOYON 19 Job: DRILLING ORIGINAL Time Log Shit Depth _. Stad Time EM Time our_ (hr) Phase Op Code . Activity Code Time P -T -X . - Operation (nKe) End Oepih (fIKB) 6/3/2018 6/3/2018 1.00 PROD1 DRILL BKRM T Attempt to backream stand from 12,037.0 11,965.0 03:30 04:30 12,037', packing off @ 200 gpm, 2700 psi. Stall out string @ 11,966' MD 100 rom,m 15k Tq. Drop back down to 12,021' re -attempt to backream, observe packing off 3 times @ 4 bpm, 1200 psi. Bleed off pressure, continue attempts to pump @ 1-2 bpm. Rack back stand @ 11,965' MD. 6/3/2018 6/3/2018 1.00 PROD1 DRILL SMPD T Strip out stand due packing off while 11,695.0 11,870.0 04:30 05:30 attempting to pump. Apply 300 psi annular pressure, pull stand from 11,965' MD to 11,870' MD, P/U=255- 270k.. Work stand up @ 275k max, drop down and re-pull @ 255k, stand back stand #122. 6/3/2018 6/3/2018 6.50 PROD1 DRILL CIRC T Make up single on top of stand #122, 11,870.0 11,870.0 05:30 12:00 attempt to establish circulation .5-1.5 bpm, 600-1050 psi, 20 rpm, 6.5-7.5k Tq. ROT=170k. Observe packing off and torque with any pipe movement, or any attempt to increase in flow rate. "Discuss with engineering, establish plugback plan for Kingak shale section. 6/3/2018 6/3/2018 2.50 PROD1 DRILL CIRC T Continue attemping to establish 11,870.0 11,870.0 12:00 14:30 circulation @ <1 bpm, rotating 20-50 rpm 7-11 k Tq, @ 11,870' MD, intermittently stalling out. Attempting to work string up hole. Increase back pressure to 500 psi, holding 500-700 psi string pressure. 6/3/2018 6/3/2018 0.50 PROD1 DRILL OTHER T While rotating 20 rpm 14k Tq @ 11,870.0 11,870.0 14:30 15:00 11,870' MD, observe torque increase to 18k and stall. Release trapped torque, attempt to slack off down to 75k, no-go, P/U 325k, no-go. Torque to 14k and slump, no movement, no . rotation, no circulation. Holding 300 psi on annulus. 6/3/2018 6/4/2018 9.00 PRODt DRILL JAR T Attempting to free string, alternating 11,870.0 11,870.0 15:00 00:00 jarring up @ 300k, straight pull 430k max. Bumper sub down to 100k, then S/0 to 75k. Reduce back pressure to 300psi. Periodically apply 500-800 psi on drillstring on the up stroke. No movement, circulation or rotary. Stuck @ 11,870' MD. Annulus C= 70 psi, Annulus B= 200 psi @ 22:00 hrs. 6/4/2018 6/4/2018 0.50 PRODt DRILL SFTY T Service blocks, top drive and crown. 11,870.0 11,870.0 00:00 00:30 Perform post jarring derrick inspection. 6/4/2018 6/4/2018 6.00 PROD1 DRILL JAR, T Continue attempting to free string, 11,870.0 11,870.0 00:30 06:30 alternating jarring up @ 300k, straight pull 430k max. Bumper sub down to 100k, then S10 to 75k. Maintain 300psi annular pressure. Periodically apply 500-800 psi on drillstring on the up stroke. No movement, circulation or rotary. 6/4/2018 6/4/2018 0.50 PROD1 DRILL SFTY T Service blocks, top drive and crown. 11,870.0 11,870.0 06:30 07:00 1 1 Perform post jarring derrick inspection. Page 18147 Report Printed: 7/18/2018 MT6-05 �- Rig: DOYON 19 Job: DRILLING ORIGINAL Time Log Start Depth slad Time End Time Dur(hr) Phase Op Code AchvRy Code Time P-iX Operation (ftKB) End Depth(ftKB) 6/4/2018 6/4/2018 2.50 PROD1 DRILL JAR T Continue attempting to free string, 11,870.0 11,870.0 07:00 09:30 alternating jarring up @ 300k, straight pull 440k max. Bumper sub down to 100k, then S/O to 75k. Maintain 300psi annular pressure. Periodically apply 500-800 psi on drillstring on the up stroke. No movement, circulation or rotary. 6/4/2018 6/4/2018 1.50 PROD1 DRILL SFTY T Service draworks, blocks, top drive 11,870.0 11,870.0 09:30 11:00 and crown. Perform postjarring derrick inspection. 6/4/2018 6/4/2018 1.00 PROD1 DRILL JAR T Continue attempting to free string, 11,870.0 11,870.0 11:00 12:00 alternating jarring up @ 300k, straight pull 440k max. Bumper sub down to 100k, then S/O to 75k. Maintain 300psi annular pressure. Periodically apply 500-800 psi on drillstring on the up stroke. Put 15k torque in string and work down, release torque. No movement, circulation or rotary. Install TI W valve on top of stand #121. 6/4/2018 6/4/2018 3.00 PROD1 DRILL JAR T Continue attempting to free string, 11,870.0 11,870.0 12:00 15:00 alternating jamng up @ 250-275k, straight pull 375k. Bumper sub down to 100k. Maintain 300psi annular pressure. 6/4/2018 6/4/2018 0.50 PROD1 DRILL CIRC T Rig up and perform injectivity test 11,870.0 11,870.0 15:00 15:30 down drill string with 8.5 ppg MOBM. Pump at .5 bpm, observe injection at 2860 psi. Stage rate up to 1 bpm, 2500 psi. SIMOPS- Weight up surface mud to 9.2 ppg kill weight. 6/4/2018 6/4/2018 3.50 PRODII DRILL CIRC T Bullhead 9.2 ppg mud to bit @ .5-7 11,870.0 11,870.0 15:30 19:00 bpm, 2720 psi. Total pumped 130 bbl. 6/4/2018 6/4/2018 1.50 PROD1 DRILL CPBO T PJSM with CPA[, Baker fishing and 11,870.0 11,870.0 19:00 20:30 DDI crew, begin blind back -off. Work string from 250k up to 130k down, 20' travel. Begin with 5k left hand torque and work down, stroke string 13x, add I LH Tq, stroke pipe 11x, add tk, stroke 11x, add tk stroke 15x, add 1k stroke 18x, add Ilk for 10k total LH torque, 15 wraps. 6/4/2018 6/4/2018 0.50 PROD1 DRILL CPBO T Work string 7x, on downstroke 11,870.0 4,880.0 20:30 21:00 observe string break out, free LH spin. Shut down, open TIW valve. P/U 3'@ 120k. Drill pipe pressure 160 psi with 9.2 ppg, Annular pressure 300 psi (applied) with 8.6 ppg. P/U 20' to circulate. 6/4/2018 6/4/2018 2.50 PROD1 DRILL CIRC T Pump 9.2 ppg mud up annulus, 4,880.0 11,870.0 21:00 23:30 maintaining constant DPP via MPD choke. Observe 9.2 ppg mud at surface @ 110 bbl pumped, indicating string backed off @ 4,900' MD (as well as 120k string wt). Continue pumping, weighting up to 9.8 ppg from surface to 4,900' MD (9.2 ppg equivalent @ shoe). FCP=770 psi. MPD chokes fully open after final weight up. Page 19/47 ReportPrinted: 7/18/2018 MT6-05 i� Rig: DOYON 19 Job: DRILLING ORIGINAL Time Log" Start Depth Sfaa Time End Tme Our ha) Phase Op Code Activity Code Time P -T -X Operation tftKB) End Depth(ftKB) 6/4/2018 6/5/2018 0.50 PRODI DRILL FISH T Wash and ream down, screw back into 11,870.0 11,870.0 23:30 00:00 drill string. S/0 rotating 5 rpm, 1.5k Tq, .5 bpm 240 psi. P/U=120k, S/0=110k. Locate lop of fish, observe pressure build and 1-2k weight. Kill pump, S/O and screw into string, stall i @ 5k Tq. Work torque down from 120k to 110-k. Stage up string torque to 20k ft/lbs. Stroke string and work torque down. Pull test 175k. Bleed off DP pressure, begin flow check annulus - static. Annulus C= 70 psi, Annulus B= 190 psi @ 22:00 hrs. 6/5/2018 6/5/2018 0.75 PRODI DRILL SFTY T F/C (static) Service blocks, top drive 11,870.0 11,870.0 00:00 00:45 and crown. Perform postjarring derrick inspection. MPD holding 50 psi on backside. 6/5/2018 6/5/2018 .0.25 PROD1 DRILL RURD T Remove TIW valve. UD 2Its DP in 11,870.0 11,870.0 00:45 01:00 mouse hole., 615/2018 6/5/2018 14.50 PRODI DRILL JAR T Continue attempting to free string, 11,870.0 11,870.0 01:00 15:30 alternating jarring up w/275 - 300k, straight pull 440k max. Bumper sub down to 100k, then S/O to 75k. SIMOPS - House keeping, work orders, & prep for E -Line. 6/5/2018 6/5/2018 6.00 PRODI DRILL ELNE T Mobilize E -line tools & equipment to 11,870.0 11,870.0 15:30 21:30 rig floor. M/U FOSV & otis connection to stump. Spot E -line truck WU & test E -Line tools on ground. 6/5/2018 6/6/2018 2.50 PROD1 DRILL ELNE T PJSM. Hang E -Line sheave. R/U 11,870.0 11,870.0 21:30 00:00 logging head. M/U E -line BODE to stump. Set lubricator in mouse hole. Test E -Line tools & tractor for compatibility. 6/6/2018 6/6/2018 3.00 PROD1 DRILL ELNE T Cont to test E -line & tractor easy. PIU 11,870.0 11,870.0 00:00 03:00 E -Line assy & M/U lubricator. Test to 3200 psi (good). M/U pari guns to tractor assy. 6/6/2018 6/6/2018 3.50 PRODI DRILL ELNE T RIH w/2" perf gun tractor assy. Not 11,870.0 11,870.0 03:00 06:30 able to work past 31'. POOH & inspect tolls. Nothing viably wrong with tools. Double check all OD's & ID's (good). M/U 2" weight bar drift assy & RIH. Had trouble running in hole for the first 800', then no issues. Cont. to RIH drift assy to 5,500'. Decision to POOH & R/D E -line. E -Lin a hour'd out. 6/6/2018 6/6/2018 0.50 PROD1 DRILL ELNE T R/D part gunitractor assy. RID E -line. 11,870.0 11,870.0 06:30 07:00 6/6/2018 6/6/2018 2.25 PROD1. DRILL JAR T M/U single jt of drill pipe &cont. to jar 11,870.0 11,870.0 07:00 09:15 on pipe 6/6/2018 6/6/2018 1.00 PROD1 DRILL SLPC T Slip & cut 72' drill line 11,870.0 11,870.0 09:15 10:15 6/6/2018 6/6/2018 0.75 PRODI DRILL SVRG T Sevice rig, top drive & draw works 11,870.0 11,870.0 10:15 11:00 6/6/2018 6/6/2018 3.00 PRODI DRILL JAR T Cont. to jar & straight pull on pipe 11,870.0 11,870.0 11:00 14:00 6/6/2018 6/6/2018 1.50 PRODI DRILL OTHR T R/U & bull head 9.2 ppg OBM down 11,870.0 11,870.0 14:00 15:30 drill string w/.5 bpm @ 3000 psi. Pumped 4 bbls, then formation packed off. Attempt to pump again with no success. Bleed of psi & RID circulating equipment. Page 20147. ReportPrinted: '711812018 MT6-05 Rig: DOYON 19 Job: DRILLING ORIGINAL Time Log Start Depth Start Time End Time our (hr) Phase Op Code Activity Code Time P -T -x OpereUon (ftKe) End Depth(ftKe) 6/6/2018 6/6/2018 0.50 PRODt DRILL ELNE T M/U FOSV & E -Line valves. Hang 11,870.0 11,870.0 15:30 16:00 sheave on top drive. 6/6/2018 6/6/2018 1.50 PROD1 DRILL WAIT T Wait on E -line crew to mobilize to rig. 11,870.0 11,870.0 16:00 17:30 Work on MP -2's & general house keeping. 6/6/2018 6/6/2018 2.00 PROD1 DRILL ELNE T Test E -line & tractor assy. P/U E -Line 11,870.0 11,870.0 17:30 19:30 assy & M/U lubricator. Test to 3200 psi (good). M/U pert guns to tractor assy. (12.5" from bottom of guns to CCL) 6/6/2018 6/6/2018 3.50 PRODi DRILL ELNE T RIHw/2"perfguntractorassyto& 11,870.0 11,870.0 19:30 23:00 correlate to 10' pup jt & HWDP. Space out top of perfs 11,524.5'/ bottom of perfs 11,527.5'. Fire shot. Monitor pressure on back side with no change. POOH w/E-line 100'to 11,427'. Break circ with .5 bpm / 2000 psi. Pump 4 bbls w/good returns. Bleed off pressure on DP to 360 psi. Pressure stabilize on DP @ 780 psi. & 60 psi on back side. 6/6/2018 6/7/2018 1.00 PROD1 DRILL ELNE T POOH w/E-line f/11,427'to 5,700'. DP 11,870.0 11,870.0 23:00 00:00 pressure decrease to 40 psi & 90 psi on back side. 6/7/2018 6/7/2018 2.75 PROD1 DRILL ELNE T POOH w/E-line 85,700'. LID guns (all 11,870.0 11,870.0 00:00 02:45 shots fired(, UD tractor assy. R/D E - Line. 6/7/2018 6/7/2018 0.50 PRODi DRILL RURD T M/U bale extensions. Lower drill string 11,870.0 11,870.0 02:45 03:15 to floor level & M/U circ sub & cement lines. 6/7/2018 6/7/2018 1.25 PROD1 DRILL CIRC T Attempt to circ w/.5 bpm @ 2500 psi. 11,870.0 11,870.0 03:15 04:30 w/300 psi on chokes. Increase to 1 bpm @ 2700 psi. Hole trying to pack off and chokes closing. Drop flow rate back to .5 bpm @ 2500 psi & remove back pressure & fully open chokes. Pumped total of 37.8 bbls w/23 bbls lost to formation. Hale packed off & started injecting into formation. 6/7/2018 6/7/2018 1.25 PROD1 DRILL OWFF T Shut down pumps& monitor well for 11,870.0 11,870.0 04:30 05:45 flow. Pressure build to 800 psi on OR Bleed off to 200 psi & shut back in & monitor for psi build up. Pressure build up to 600 psi. Repeated process until well was static. Only gained <1 bbl of fluid while letting formation relax. 6/7/2018 6/7/2018 2.50 PROW DRILL JAR T R/D circ lines & M/U single jt. 11,870.0 11,870.0 05:45 08:15 Comence working pipe to determine if there is still movement at Jars. No success. LID single It. 6/7/2018 6/7/2018 2.50 PROD1 DRILL ELNE T R/U E -Line. Test E -line & tractor assy. 11,870.0 11,870.0 08:15 10:45 P/U E -Line assy & M/U lubricator. Test to 3200 psi (good). M/U 2" perf guns to tractor assy. (12.5" from bottom of - guns to CCL) 6/7/2018 6/7/2018 3.75 PROD? DRILL ELNE T RIH w/2" perf gun tractor assy to & 11,870.0 11,870.0 10:45 14:30 correlate to OR Space out top of perfs 11,346.74'1 bottom of perfs 11,349.74'. Fire shot. Monitor pressure on back side with no change. POOH w/E-line 100' to 11,249'. Break circ with .9 bpm 1250 psi. Good returns & good communication with back side. 6/7/2018 6/712018 2.00 PROD1 DRILL ELNE T POOH & RID E -Line. 11,870.0 11,870.0 14:30 16:30 Page 21147 Report Printed: 7/1 812 01 8 MT6-05 i Rig: DOYON 19 Job: DRILLING ORIGINAL Time Log _ Stan Depth '. Stan Time - End Time Mr (hr) Phase Op Code Activity Code Time P -T -X Operation (ftKB) End Depth (WS) 6/7/2018 6/712018 3.50 PROM DRILL CIRC T R/U circ sub & cement lines. Break 11,870.0 11,870.0 16:30 20:00 circ & stage flow rate up to 6 bpm @ 2120 psi, Circ & cond mud to 9.2+ pp In/Out. No losses to formation. 1730 units max gas on B/U. 6/7/2018 5/7/2018 1.00 PROD1 DRILL ELNE T Pull string in tension w/250 K. R/U E- 11,870.0 11,870.0 20:00 21:00 Line. M/U RCT assy. 6/7/2018 6/7/2018 2.00 PROM DRILL ELNE T RIH w/RCT assy 11,400'. Started 11,870.0 11,870.0 21:00 23:00 pumping down @ 7,000' w/1 - 2.5 bpm / 400 - 650 psi. 6/7/2018 6/8/2018 1.00 PROM DRILL ELNE T Correlating RCT assy w/perf gun run 11,870.0 11,870.0 23:00 00:00 #2. 6/8/2018 6/8/2018 0.25 PROD1 DRILL ELNE T Correlating RCT assy w/perf gun run 11,870.0 11,870.0 00:00 00:15 #2. RCT cut @ 11,351'. No indication of cut @ surface. 6/8/2018 6/8/2018 3.00 PROD1 DRILL ELNE T POOH & R/D E -Line. Inspected RCT 11,870.0 11,870.0 00:15 03:15 & all indicators showed RCT functioned properly. 6/8/2018 6/8/2018 2.50 PROD1 DRILL JAR T Attempt to work pipe free. Straight 11,870.0 11,870.0 03:15 05:45 pulling to 400K. Applying 22 k max trq & working string to 250K Alternate between the two. No success. Decision made to run severing tool. 6/8/2018 6/8/2018 1.25 PROM DRILL ELNE T R/U E -line & 1.75" OD severing tool. 11,870.0 11,870.0 05:45 07:00 (Radio Silence) 6/8/2018 6/8/2018 2.75 PROD1 DRILL ELNE T RIH w/severing tool & correlate to tool 11,870.0 11,342.0 07:00 09:45 jt @ 11,342'. No indication of sever on surface. 6/8/2018 6/8/2018 2.25 PRODt DRILL ELNE T POOH & R/D E -line. Inspected 11,870.0 11,342.0 09:45 12:00 severing tool & all indicators showed tool functioned properly. 6/8/2018 6/8/2018 2.50 FROM DRILL JAR T Attempt to work pipe free. Straight 11,342.0 11,342.0 12:00 14:30 pulling to 400K. Applying 22 k max trq & working string to 250K Alternate between the two. Break circ w/2.5 bpm @ 520 psi. Pipe broke free w/straight pull of 410 K. (Officially lett BHA #6 in hole @ 14:30 Hrs. Bottom of BHA 11,870'. top of fish @ 11,342) 6/8/2018 6/8/2018 1.25 PROD1 DRILL. JAR T Attempt to work pipe out of hole w/2.5 11,342.0 11,298.0 1430 15:45 bpm @ 520 psi f/11,342'to 11,298'. Hole packed off & not able to circulate & pipe stuck. Attempt to work pipe free with no success. Pipe stuck @ 11,298' 6/8/2018 6/8/2018 1.00 PROD1 DRILL WAIT T Wait on orders & new plan forward 11,298.0 11,298.0 15:45 16:45 from town. Service rig, house keeping, & MP -2's 6/8/2018 6/8/2018 2.00 PROD1 DRILL ELNE T P/U 15' DP pup & pull drill sting in 11,298.0 11,298.0 16:45 18:45 tension & set slips. Clean & clear floor on non-essential E -Line tools & equipment. R/U E -Line. 6/8/2018 6/8/2018 3.75 PROD1 DRILL ELNE T Wait on E -Line & Well Tech to mobilize 11,298.0 11,298.0 18:45 22:30 tools to rig. Configure & test tool string on ground. SIMOPS - Service rig, house keeping, & MP -2's 6/8/2018 6/8/2018 1.00 PROD1 DRILL ELNE T Finish RID E -Line. WU E -Line tractor 11,298.0 11,298.0 22:30 23:30 assy to 9' T' 52 shot perf gun assy. 6/8/2018 6/9/2018 0.50 PROM DRILL ELNE T RIH w/2" perf gun assy to 3600' 11,298.0 11,298.0 23:30 00:00 6/9/2018 6/9/2018 2.75 PROM DRILL ELNE T RIH w/2" perf gun assy to 11,285'. 11,298.0 11,298.0 00:00 02:45 Correlate & shoot perfs. Top of perfs 11,M'/ bottom of perfs 11,285'. Pull guns up hole 100'& break circ w1.5 bpm @ 230 psi. Page 22147 Report Printed: 7/18/2018 MT6-05 f Rig: DOYON 19 Job: DRILLING ORIGINAL Time Log Start Depth Start Time End Time Our (hr) Phase Op Cod. Atnaty Code Time P -T -X Operation (ftKB) End Depth (WS) 6/9/2018 6/9/2018 2.50 PROD1 DRILL ELNE T POOH w/E-Line while pumping .5 bpm 11,298.0 11,298.0 02:45 05:15 @ 230 psi. No losses. RID E -Line & set to side. 6/9/2018 6/9/2018 5.50 PROM DRILL CIRC T M/U single jt. Break circ & stage Saw 11,298.0 11,298.0 05:15 10:45 rate up to 8 bpm / 2900 psi. 9.2+ ppg In/Out. 6/9/2018 6/9/2018 5.25 PROD1 DRILL JAR T Attempt to frre stuck pipe with no 11,298.0 11,298.0 10:45 16:00 success. Straight pull to 445 K max. Work torque down w/22 k fUlbs max trq. Alternating betwen the two. Pumping 2 - bpm with full returns. 6/9/2018 6/10/2018 8.00 PROD1 DRILL ELNE T Decision made to string shot back off. 11,298.0 11,298.0 16:00 00:00 M/U XO & TIW valve. RID E -Line & top drive wire line entry guide. R/U sheaves & align E -Line cable. M/U E - Line & string shot assy & configure & test tools. SIMOPS - Work on MP2's & general housekeeping. 6/10/2018 6/10/2018 2.00 PROD1 DRILL ELNE T M/U E -Line & string shot assy & 11,298.0 11,298.0 00:00 02:00 configure & test tools. Bring string shot assy to rig floor & M/U to slump third single jt DP. RIH to 300'& confirm tools working correctly. 6/10/2018 6/10/2018 1.25 PROD1 DRILL ELNE T RIH w/E-Line f/300'to 3000'. Lost 11,298.0 11,298.0 02:00 03:15 communication w/CCL. Trouble shoot w/no success. 6/10/2018 6/10/2018 2.25 PROD1 DRILL ELNE T POOH w/E-line. Inspect tools & re- 11,298.0 11,298.0 03:15 05:30 configure & test tools (good). (Replaced PLC & repair TTG) 6/10/2018 6/10/2018 4.50 PROM DRILL ELNE T RIH w/E-Line assy to 11,234' (Started 11,298.0 11,298.0 05:30 10:00 pumping down tool w/.5 - 3bpm f/7000') 6/10/2018 6/10/2018 2.75 PROM DRILL ELNE T Correlate string shot to box of jt #8 @ 11,298.0 11,234.0 1000 12:45 11,234'. Coordinate tugger operators & E -line for working torque down to back off point. Apply 11 k ft/lbs left hand torque (13 wraps total) & work string w/205 K up wt & 75 K dwn wt. Apply 13 k fUlbs left hand torque (18.5 wraps total) & work string w/205 K up wt & 75 K dwn wt. Correlate string shot @ 11,234' while pumping 3 bpm/730 psi. Fire 460 grain string shot & observe 1/4 left hand turn when shot fired. Initial string wt 162 K @ 12.6 ft/lbs trapped torque. String wt after shot 154 K @ 8.7 ft/lbs trapped torque. 6/10/2018 6/10/2018 1.00 PROD1 DRILL JAR T POOH w/E-Line to 8,000'Apply 13 k 11,234.0 11,234.0 12:45 13:45 ft/Ibs trq left hand torque, work string 200 k up & 75 k down & observe torque decrease. Bring drill string back to neutral wt & apply 5 k ft/lbs lrq left hand torque & observe drill string back off & free. 6/10/2018 6/10/2018 1.50 PROD1 PLUG ELNE T Cont. to POOH ME -Line 11,234.0 11,234.0 13:45 15:15 6/10/2018 6/10/2018 2.00 PROD1 PLUG ELNE T R/D E -Line. Remove sheaves, grease 11,234.0 11,234.0 15:15 17:15 1 1 1 head, & wire line entry guide. 6/10/2018 6/10/2018 0.75 PROD1 PLUG PMPO T Pump OOH w/4 bpm / 830 psi 11,234.0 10,997.0 17:15 18:00 f/11,234' to 10,997'. PU wt 190 K / SO wt 155 K 6/10/2018 6/10/2018 1.25 PROM PLUG CIRC T Circ & cond mud w/8 bpm / 2950 psi. 10,997.0 10,997.0 18:00 19:15 SIMOPS - Clean & clear floor. UD single It & pup It from mouse hole. Page 23147 Report Printed: 7111812 01 8 MT6-05 i Rig: DOYON 19 Job: DRILLING ORIGINAL Time Log - Start Depth - StartTme End Tine Dur(hr) Phase Op Code A t ity Code Time P -T -X - Operation (RKB) Ertl, Depth(ftKB) 6/10/2018 6/10/2018 1.00 PRODi PLUG CIRC T Mud out of balance. R/U head pin & 10,997.0 10,997-0 19:15 20:15 cement hose. Circ & cond mud w/5 bpm / 1400 psi. Mud wt 9.2 In/Out. SIMOPS - Shuffle 5 stands 15.7 # DP f/DS to ODS. Check torque on every connection & SLM 6/10/2018 6/10/2018 0.75 PROD1 PLUG OWFF T OWFF. Slight oose&slowing down, 10,997.0 10,997.0 20:15 21:00 then static. SIMOPS - B/D cement line- RID head pin & cement hose. 6/10/2018 6/10/2018 0.50 PROD1 PLUG MPDA T PJSM. Remove RCD bearing & install 10,997.0 10,997.0 21:00 21:30 trip niupple. 6/10/2018 6/10/2018 0.50 PROD1 PLUG CIRC T Pump 30 bbls 10.5 ppg dry. Line up on 10,997.0 10,997.0 21:30 22:00 trip tank to POOH 6/10/2018 6/11/2018 2.00 PROD1 PLUG TRIP T POOH on elevators on TT (/10,997' to 10,997.0 9,385.0 22:00 00:00 9,385'. Check torque on every connection & SLM 6/112018 6/11/2018 10.25 PROD1 PLUG TRIP T POOH on elevators on TT f/9,385'to 9,395.0 0.0 00:00 10:15 surface. Check torque on every connection & SLM. Last stand #4+ 1 single it. 6/11/2018 6/11/2018 0.50 PROD1 PLUG OWFF T F/C (static). SIMOPS - Clean & clear 0.0 0.0 10:15 10:45 floor. 6/11/2018 6/11/2018 0.75 PROD1 WHDBOP RURD T M/U wear ring puller & pull same. 0.0 0.0 10:45 11:30 Install 3-112" test it as per FMC. Fill BOP stack, flood lines & purge system. 6/11/2018 6/11/2018 1.50 PROD1 WHDBOP ROPE T Test annular with 3-1/2" test it 250 psi 0.0 0.0 11:30 13:00 5 min /2500 psi 10 min & not able to get a good high test. pressure bleeding off. Test upper & lower 3-1/2" X 6" VBR's 250 psi for 5 min 13500 psi for 10 min & good test. Make another un -successful attempt to test annular. 6/11/2018 6/11/2018 5.00 PROD1 WHDBOP BOPE T Function annular & still not able to 0.0 0.0 13:00 18:00 test. Observe large piece of annular rubber lodged in annular cavity. Dislodge rubber & attempt to re -test w/no success. 6/11/2018 6/11/2018 2.00 PROD1 WHDBOP RGRP T Pull test It& drain stack. Observe 0.0 0.0 18:00 20:00 debris in blind ram cavity (annular 'I element rubber). Install test plug & 3- 1/2" test it. & close lower rams. Open blind lam door & remove debris. Tighten back ram door. Open lower rams. Remove test plug & LID test it. 6/11/2018 6/11/2018 1.50 PRODi WHDBOP RGRP T B/D hole fill lines. N/D MPD 0.0 0.0 20:00 21:30 equipment. Remove trip nipple, flow line & flow box. L/D mouse hole. 6/112018 6/11/2018 2.00 PRODi WHDBOP RGRP T R/U & break annular cap. C/O 0.0 0.0 21:30 23:30 hydraulic fluid. Replace annular element. Tighten annular cap & function test (good). 6/11/2018 6/12/2018 0.50 PROD? WHDBOP RGRP T Install MPD clamp 0.0 0.0 23:30 00:00 6/12/2018 6/12/2018 3.00 PROD1 WHDBOP RGRP T NIU MPD equipment, flow box, hole fill 0.0 0.0 00:00 03:00 & bleeder lines, etc. Install trip nipple & mouse hole. 6/12/2018 6/12/2018 0.50 PROD1 WHDBOP RGRP T P/U 4" test It & set test plug. Fill stack 0.0 0.0 03:00 03:30 with H2O, flood lines & purge system. 6/12/2018 6/12/2018 2.00 PROD1 WHDBOP RGRP T Test annular & blind ram doors w/4" 0.0 0.0 03:30 05:30 testjt 250 psi for 5 min / 3500 psi for 10 min. Test annular w/3.5" test it 250 psi for 5 min / 2500 psi for 10 min. Page 24147 Report Printed: 7118/2018 MT6-05 i Rig: DOYON 19 Job: DRILLING ORIGINAL Time Log Start Depth Stall Tme End Time Dur(hr) Phase DIP Cade Activity Code Tme PJA Operation (MB) End Depth(ftKB) 6/12/2018 6/12/2018 0.50 PROW WHDBOP RURD T RID testing equipment. LID test plug & 0.0 0.0 05:30 06:00 lest jt. Install wear ring as per FMC. 6/12/2018 6/12/2018 1.25 PROM PLUG RURD T R/U to run tubing. RM power tongs, 3- 0.0 0.0 06:00 07:15 1/2" slips & elevators. 6/12/2018 6/12/2018 1.75 PROM PLUG PUTB T RIH 3-1/2" cement stinger assyto 0.0 1,056.0 07:15 09:00 1,056' (18' mule shoe stinger, 33jts tubing, & XO) 6/12/2018 6/12/2018 7.00 PROM PLUG TRIP T C/O over to 4" handle equipment. RIH 1,056.0 11,065.0 09:00 16:00 w/4" DP f11,056 to 11,065' (Culled out 12 jts of 14# DP, found bad box & pin stand #70 in between jts 1 & 2 of original tally) 6/12/2018 6/12/2018 0.50 PRODi PLUG WASH T Wash dowm @ 3 bpm 1670 psi & tag 11,065.0 11,233.0 16:00 16:30 TOF @ 11,233- 6/12/2018 6/12/2018 0.75 PROD? PLUG CIRC T Break circ & stage flow rate up to 6 11,233.0 11,233.0 1630 17:15 bpm 12000 psi 6/12/2018 6/12/2018 1.75 PROD1 PLUG DISP T Pump 3 different spacers (high vis, 11,233.0 11,233.0 17:15 19:00 deep clean, high vis) n& displace well to 9.2 ppg vis brine w/3 - 6 bpm 1670 - 2000 psi 6/12/2018 6/12/2018 0.75 PROM PLUG CIRC T Circ an additional B/U to even out 11,233.0 11,233.0 19:00 19:45 brine. 6 bpm / 670 psi 6/12/2018 6/12/2018 0.50 PROM PLUG RURD T LID top single It. M/U 8' pup jt, TIW, 11,233.0 11,233.0 19:45 20:15 head pin & cement hose. 6/12/2018 6/12/2018 1.50 PROM PLUG CIRC T Break circ through cement line 6 bpm / 11,233.0 11,233.0 20:15 21:45 800 psi. PJSM for cementing. SIMOPS - Build black water pill. 6/12/2018 6/12/2018 0.75 PROM PLUG CMNT T SLB pump 5.2 bbls H2O & PT lines to 11,233.0 11,233.0 21:45 22:30 3500 psi. Pump 24.4 bbls 12.75 ppg mud push @ 2.5 bpm 1250 psi, 22.9 bbls 16.5 ppg 1.06 ft3/sx yield class G cement @ 4 bpm 1760 psi, 10.4 bbisl2.75 ppg mud push @ 2.2 bpm / 160 psi, & 1.4 bbls H2O to clear lines. Rig pump 93 bbls 9.2 ppg brine, Initial 6 bpm 1790 psi & final 3 bpm 1400 psi. 6/12/2018 6/12/2018 0.25 PROD1 PLUG RURD T RID cement hose, head pin & TIW. 11,233.0 11,233.0 22:30 22:45 UD 8' pup It. 6/12/2018 6/13/2018 1.25 PROM PLUG TRIP T POOH 600 ff/hr first 3 stands & 1000 11,233.0 10,589.0 22:45 00:00 ft/hr remaining f/11,233'to 10,589' CIP @ 00:00 Hrs 6/13/18 6/13/2018 6/13/2018 2.00 PROD1 PLUG CIRC T Circ & cond mud with 6 bpm / 860 psi. 10,589.0 10,589.0 00:00 02:00 Saw mud push & trace of cement on B/U. Circ & cond mud for an additional B/U w/8 bpm 1930 psi. Dumped total of 73 bbls contaminated brine. Obtain SPR's. 6/13/2018 6/13/2018 0.25 PROD? PLUG OWFF T FIC (slight moze then static) 10,589.0 10,589.0 02:00 02:15 6/13/2018 6/13/2018 7.75 PROD'I PLUG TRIP T POOH on elevators f/10,589'to 1,056'. 10,589.0 1,056.0 02:15 10:00 SLM & alternate connection breaks 6/13/2018 6/13/2018 0.25 PROD1 PLUG RURD T R/U to UD tubing. M/U TIW & XO 1,056.0 1,056.0 10:00 10:15 6/13/2018 6/13/2018 2.75 PROM PLUG PULD T POOH & UD cement stinger assy 1,056.0 0.0 10:15 13:00 f/1,056'. (XO, 33 jts tubing & stinger) 6/13/2018 6/13/2018 2.25 PROD1 WHDBOP BOPE T Test rig gas alarms with witness of 0.0 0.0 13:00 15:15 AOGCC rep Guy Cook. SIMOPS - R/D tubing equipment. Clean & clear floor. P/U test jt & pull wear ring. Set test plug. R/U to test BOPS. Fill) stack with H2O. Flood & purge lines. Page 25147 ReportPrinted: 711 812 01 8 MT6-05 Rig: DOYON 19 Job: DRILLING ORIGINAL Time Log - Start Depth Slan Time End Time Dur (hr) Phase Op Code Activity Code Time P -T -X Operation (RKa) End Depth mKe) 6/13/2018 6/13/2018 6.75 PROD1 WHDBOP BOPE T Test BOPE 250/3500 for 5/10 min's 0.0 0.0 15:15 22:00 w/4"&4-1/2" test joints. Annular, 4" Demco, Choke valves 1 - 14; IBOP's, Choke needle valve, Upper 4-1/2" X 7" - VBR's, lower 3-112" X 6" VBR's & blind rams, 4" Dart1FOSV, HCR / Man choke/kill, Accumulator test, Initial 3125 psi, final 1400 psi, 1st 200 psi recharge = 28 sec's, full recharge = 160 second. 4 bottles Q 2200 psi. PVT alarms and flow indicated tested. Draw dowm on maunual & super choke. AOGCC Gut Cook witness & BLM Mutasim Elganzocry waived witness via email. 6/13/2018 6/13/2018 0.75 PROD1 WHDBOP RURD T RID testing equipment. Pull test plug. 0.0 0.0 22:00 22:45 Drain stack. B/D choke & lines. Set 6.1875" ID wear ring. 6/13/2018 6/13/2018 0.75 PROD1 PLUG BHAH T Bring to rig floor BHA tools & 0.0 0.0 22:45 23:30 equipment. 6/13/2018 6/14/2018 0.50 PROD1 PLUG BHAH T PJSM. WU 6" clean out BHA as per 0.0 39.0 23:30 00:00 Baker reps to 39' 6/14/2018 6/14/2018 3.25 PROD1 PLUG BHAH T M/U 6" clean out BHA as per Baker 39.0 218.0 00:00 03:15 reps f/39' to 218' 6/14/2018 6/14/2018 1.00 PROD1 PLUG TRIP T RIH f/218'to 2,183' 218.0 2,183.0 03:15 04:15 6/14/2018 6/14/2018 0.25 PROD1 PLUG DHEQ T Shallow hole test MWD w1200 gpm / 2,183.0 2,183.0 04:15 04:30 430 psi (good) 6/14/2018 6/14/2018 4.00 PROD1 PLUG TRIP T RIH 1/2,183' to 8,575' PU wt 185 K/ 2,183.0 8,575.0 04:30 08:30 SO wt 145 K 6/14/2018 6/14/2018 0.75 PRODt PLUG DLOG T Break circ w/ 220 gpm / 940 psi & log 8,575.0 8,670.0 08:30 09:15 RA tag 8584'. Cont. to was down BHA thru quick connect. Observe 6K bobble when mill Q quick connect. 6/14/2018 6/14/2018 1.25 PROD1 PLUG TRIP T RIH f/8,670' to 10,480' PU wt 202 K / 8,570.0 10,480.0 09:15 10:30 1 ISO wt 150 K 6/1412018 6/14/2018 0.75 PROD1 PLUG REAM T W&R fit 0,480'to TOC Qa 10,627' 10,480.0 10,627.0 10:30 11:15 w/220 gpm 11080 psi, 6/1412018 6/14/2018 4.50 PRODt PLUG DRLG T Drill oementf/10,627'10 11,127.5' 10,627.0 11,127.5 11:15 15:45 w/250 gpm, 1170 psi, PU wt 205 K, SO wt 145 K, ROT wt 170 K. 60 rpm, 7-10ktrq 6/14/2018 6/14/2018 0.25 PROD1 PLUG CIRC T Tag TOC @ 11,127.5'W11 5 K WOB 2X 11,127.5 11,127.5 15:45 16:00 w/1.5 bpm / 160 psi with witness of AOGCC rep Guy Cook 6/14/2018 6/14/2018 1.50 PROD? PLUG CIRC T Circ & cond brine. Pump high vis 11,127.5 11,127.5 16:00 17:30 sweep & circ clean w/250 gpm 11100 psi, 60 rpm /7 k trq. 6/14/2018 6/14/2018 0.25 PROW PLUG OWFF T F/C- slight ooze &slowing down. 11,127.5 11,127.5 17:30 17:45 Suspect brine is out of balance. 6/14/2018 6/14/2018 1.25 PROD1 PLUG TRIP T POOH On elevators f/.11,127.5'to 11,127.5 10,480.0 17:45 19:00 10,480'. Appear to be dragging junk out of hole and having improper hole fill. 6/14/2018 6/14/2018 1.75 PROD1 PLUG CIRC T Pump high vis sweep & circ hole clean 10,480.0 10,480.0 19:00 20:45 w/240 gpm 11170 psi, 50 rpm 17 k trq. 6/14/2018 6/14/2018 0.75 PROD1 PLUG TRIP T F/C - (static). POOH on elevators 10,480.0 10,06-3-0- 20:45 21:30 1 1 1(/10,480' to 10,003. Hole fill correct. 6/14/2018 6/14/2018 0.50 PROD1 PLUG CIRC T Pump dry job. B/D top drive 10,003.0 10,003.0 21:30 22:00 6/14/2018 6/14/2018 1.50 PROD1 PLUG TRIP T POOH on elevatom f/10,003'to 83575'. 10,003.0 8,575.0 22:00 23:30 PU wt 188 KI SO wt 145 K Page 26147 Report Printed: 7/1812018 MT6-05 Rig: DOYON 19 Job: DRILLING ORIGINAL Time Log Start Depth StaRTme End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 6/14/2018 6/15/2018 0.50 PROM PLUG SLPC T PJSM. Slip & cut 45' drill line 8,575.0 8,575.0 23:30 00:00 6/15/2018 6/15/2018 0.50 PRODI PLUG SLPC T Slip & cut 45' drill line 8,575.0 8,575.0 00:00 00:30 6/15/2018 6/15/2018 0.50 FROM PLUG SVRG T Service Rig, lop drive, draworks, 8,575.0 8,575.0 00:30 01:00 perform MP-2's 6/15/2018 6/15/2018 5.00 FROM PLUG TRIP T POOH on elevators f/8,575' to 281' 8,575.0 281.0 01:00 06:00 6/15/2018 6/15/2018 0.25 PROD1 PLUG OWFF T FIC (static). SIMOPS - PJSM on BHA 281.0 281.0 06:00 06:15 6/15/2018 6/15/2018 1.50 PRODI PLUG BHAH T UD clean out BHA as per Baker rep. 281.0 0.0 06:15 07:45 6/15/2018 6/15/2018 0.50 FROM PLUG BHAH T Clean & clear BHA tools from rig floor. 0.0 0.0 07:45 08:15 Bring whipstock BHA components to rig floor. 6/15/2018 6/15/2018 3.25 PROD? PLUG BHAH T M/U whipstock BHA as per Baker rep. 0.0 265.0 08:15 11:30 6/15/2018 6/15/2018 5.75 PROM PLUG TRIP T RIH whipstock BHA f/265'to 8,650' 265.0 8,650.0 11:30 17:15 6/15/2018 6/15/2018 0.75 FROM PLUG DLOG T Break circ w/ 250 gpm 11370 psi & log 8,650.0 8,748.0 17:15 18:00 RA tag 8586' no rotation. Cont. to was down BHA thru quick connect. PU wt 175 k/SO wt 140k 6/15/2018 6/15/2018 1.00 FROM PLUG TRIP T RIH whipstock BHAf/8,748'to 10,453'. 8,748.0 10,453.0 18:00 19:00 6/15/2018 6/15/2018 0.25 FROM PLUG TRIP T Take 8 K WOB down @ 10,453'. P/U 10,453.0 10,407.0 19:00 19:15 & observe break over @ 15 K max over pull. Drop back down & take 8 K WOB down @ 10,439'. POOH to 10,407' & observe break over @ 15 K max over pull. Decision made to circ hole clean. Free P/U wt 200 K / Free SO wt 150 k 6/15/2018 6/15/2018 1.25 FROM PLUG CIRC T Circ 2X B/U w/250 gpm 11430 psi. 10,407.0 10,407.0 19:15 20:30 Saw slight amount of cement cuttings after 1 st B/U. 6/15/2018 6/15/2018 0.25 FROM PLUG TRIP T After circulating free P/U wt 200 K 1 10,407.0 10,439.0 20:30 20:45 Free SO wt 157 k. Attempt to RIH f/l0,407' & take 8 K WOB @ 10,439'. Decision to POOH 6/15/2018 6/15/2018 1.00 PROD1 PLUG TRIP T POOH w/whipstock assy f/10,439'to 10,439.0 9,892.0 20:45 21:45 9,892. 6/15/2018 6/15/2018 0.50 FROM PLUG CIRC T F/C (static). Pump 38 bbl dry job & 9,892.0 9,892.0 21:45 22:15 1 B/D top drive. 6/15/2018 6/15/2018 1.00 PRODI PLUG TRIP T POOH w/whipstock assy f/9,892 to 9,892.0 9,416.0 22:15 23:15 9,416'. (15 K overpulls @ 9,816', 9,649', 9,608', 9,570', & 9,443', appears we are dragging debris out of hole & hanging up). PU wt 192 K / SO wt 155K 6/15/2018 6/16/2018 0.75 PRODI PLUG CIRC T Circ & cond w/250 gpm 11430 psi. 9,416.0 9,416.0 23:15 00:00 6/16/2018 6/16/2018 0.50 FROM PLUG CIRC T Cont. circ & cond w/250 gpm 11370 9,416.0 9,416.0 00:00 00:30 psi. 6/16/2018 6/16/2018 1.25 FROM PLUG TRIP T POOH w/whipstock assy f/9,416'to 9,416.0 8,727.0 00:30 01:45 8,727'. (15 - 20 K overpulls, we are dragging debris out of hole & hanging up). PU wt 185 K / SO wt 148 K. 6/16/2018 6/16/2018 0.50 PROD1 PLUG PMPO T Having difficulty pulling whipstock 8,727.0 8,653.0 01:45 02:15 asssy thru quick connect. Not able to work down. Pump assy out of hole w/250 gpm 11330 psi. 20 K max over pull. Page 27147 ReportPrinted: 711812018 _ MT6-05 Rig: DOYON 19 Job: DRILLING ORIGINAL Time Log - - . - Start Depth .. SlartTme End Time Our(hr) Phase Op Code Activity Code TimePT-X - Operation _(ftK8). End Depth(ftKB) 6/16/2018 - 6/16/2018 7.25 PROD1 PLUG TRIP T Cont. to POOH f/8653'to 356'. No 8,653.0 356.0 02:15 09:30 more overpulls once tru quick connect. 6/16/2018 6/16/2018 0.25 PROD1 PLUG OWFF T FIC (static) PJSM on BHA 356.0 356.0 09:30 09:45 6/16/2018 6/16/2018 2.00 PROD1 PLUG BHAH T UD whipstock easy f/356' as per 356.0 0.0 09:45 11:45 Baker rep. Large metal debris on - lower string magnet, window mill bolt. & window hook slot. No signs of stress on whipstock shear bolt or anchor bolts. 6/16/2018 6/16/2018 1.00 PROD1 PLUG BHAH T Clean & clear BHA tools & equip from 0.0 0.0 11:45 12:45 floor. Bring clean out BHA components to floor. 6/16/2018 6/16/2018 0.75 PROD1 PLUG OTHR T Perform trial ran for wireline entry 0.0 0.0 12:45 13:30 guide on top drive. 6/16/2018 6/16/2018 1.00 PRODt PLUG BHAH T M/U clean out BHA as per Baker rep 0.0 67.0 13:30 14:30 to 67'. Waiting on junk basket to be flow over from Deadhorse. 6/16/2018 6/16/2018 0.50 PROD1 PLUG SVRG T Service rig, draw works & iron 67.0 67.0 14:30 15:00 roughneck. 6/16/2018 6/16/2018 1.75 PROD? PLUG WAIT T Clean wind walls, housekeeping, & 67.0 67.0 15:00 16:45 MP-2's. Waiting on junk basket to be flow over from Deadhorse. 6/16/2018 6/16/2018 1.00 PROD1 PLUG BHAH T Finish M/U clean out BHA as per 67.0 102.0 16:45 17:45 Baker rep f/67' to 102' 6/16/2018 6/16/2018 3.75 PROD1 PLUG TRIP T RIH f/102'to 8,606' Fill pipe every 20 102.0 8,606.0 17:45 21:30 stands. 6/16/2018 6/16/2018 0.75 PROD1 PLUG CIRC T Break circ & stage flow rate up to 690 8,606.0 8,606.0 21:30 22:15 gpm / 3900 psi 6/16/2018 6/16/2018 1.00 PROD1 PLUG WASH T Wash thru TOL & quick connect w/690 8,606.0 8,893.0 22:15 23:15 gpm 13950 psi, f/8,606' to 8,893'. No issues or tight spots running thru quick connect. 6/16/2018 6/17/2018 0.75 PROD1 PLUG REAM T W&R w/690 gpm 13950 psi, 30 rpm ! 8,893.0 9,229.0 23:15 00:00 5 k trq f/8,893'to 9,229. PU wt 160 k, SO wt 127 k, ROT wt 144 k 6/17/2018 6/17/2018 6.75 PROD1 PLUG REAM T W&R w/690 - 600 gpm / 4000 psi, 30 9,229.0 11,088.0 00:00 06:45 rpm / 5 - 7 k trq f/9,229' to 11,088'. PU wt 210 k, SO wt 150 k, ROT wt 160 k. Appear to be pushing debris to bottom. Pump sweep Q 10,989' 6/17/2018 6/17/2018 0.25 PRODt PLUG WASH T Wash V11,088'& TOC @ 11,127.5' 11,088.0 11,127.5 06:45 07:00 w/80 gpm 1180 psi. Tag w/8 k WOB. Pick up & mark string 6' off of bottom for compression adjustment and stay off bottom w/ rotating 6/17/2018 6/17/2018 1.50 PROD1 PLUG CIRC T Pump sweeps & circ casing clean 11,127.5 11,127.5 07:00 08:30 w/600 gpm / 4000 psi, 30 rpm / 7 k trq. saw some increase in cement cutflngs when sweep was at surface. 6/17/2018 6/17/2018 0.25 PROD1 PLUG OWFF T FIC -slight ooze, Brine appears to be 11,127.5 11,127.5 08:30 08:45 1 1aired up. 6/17/2018 6/17/2018 0.25 PROD1 PLUG TRIP T POOH f/11,127.5'to 11,084' 11,127.5 11,084.0 08:45 09:00 6/17/2018 6/17/2018 0.25 PROD1 PLUG OWFF T F/C-(static) 11,084.0 11,084.0 09:00 09:15 6/17/2018 6/17/2018 1.75 PROD1 PLUG TRIP T POOH on elevators V11,084'to 8,703' 11,084.0 8,703.0 09:15 11:00 w/no issues. 6/17/2018 6/17/2018 2.00 PROD1 PLUG CIRC T Pump sweep & circ casing clean & 8,703.0 8,703.0 11:00 13:00 quick connect & TOL w/625 - 300 gpm 13200 - 1000 psi. Vary flow rates & reciprocate pipe to flush out any debris. Page 28147 Report Printed: 7118/2018 MT6-05 Rig: DOYON 19 Job: DRILLING ORIGINAL Time Log Start Depth Start Time End Time our (hr) Phase Op Cede Activity Code Time P -T -X Operation (ftK0) End Depth(ftK6) 6/17/2018 6/17/2018 0.25 PRODI PLUG OWFF T FIC -(static) 8,703.0 8,703.0 13:00 13:15 6/17/2018 6/17/2018 0.75 PRODI PLUG TRIP T POOH on elevators f/8,703'to 7,750' 8,703.0 7,750.0 13:15 14:00 Who issues. 6/17/2018 6/17/2018 0.25 PROD1 PLUG CIRC T Pump 37 bbl 10.0 ppg dryjob 7,750.0 7,750.0 14:00 14:15 6/17/2018 6/17/2018 3.00 PRODI PLUG TRIP T POOH on elevators 1/7,750'to 219' 7,750.0 219.0 14:15 17:15 Who issues. 6/17/2018 6/17/2018 0.25 PROD? PLUG OWFF T F/C-(static) 219.0 219.0 1715 17:30 6/17/2018 6/17/2018 0.75 PRODI PLUG BHAH T LID clean out BHA as per Baker reps 219.0 65.0 17:30 18:15 f/219'to 65'. Lots of large metal debris on magnets (cement retainer pieces). Additional debris in junk baskets 6/17/2018 6/17/2018 0.25 PRODI PLUG BHAH T Clean & clear floor. 65.0 65.0 18:15 18:30 6/17/2018 6/17/2018 0.50 PRODI PLUG SHAH T Finish LID clean out BHA. 65.0 0.0 18:30 19:00 6/17/2018 6/17/2018 0.25 PRODI PLUG SHAH T Clean & clear floor. LID clean out BHA 0.0 0.0 19:00 19:15 via beaver slide. 6/17/2018 6/17/2018 2.00 PROD1 PLUG SHAH T M/U Whipstock/milling assy as per 0.0 328.6- 19:15 21:15 Baker reps to 328'. Change out anchor bolts & verify offset @ 337.75 6/17/2018 6/17/2018 1.00 PRODI PLUG TRIP T RIH whipstock/milling assy f/328'to 328.0 2,230.0 21:15 22:15 2,230' 6/17/2018 6/17/2018 0.25 PROD1 PLUG DHEQ T Shallow hole test MWD w/250 gpm / 2,230.0 2,230.0 22:15 22:30 900 psi 6/17/2018 6/18/2018 1.50 PROD1 PLUG TRIP T RIH whipstock/milling assy f/2,23o to 2,230.0 4,816.0 22:30 00:00 4,816'. Fill pipe every 20 sids 6/18/2018 6/18/2018 2.50 PRODI PLUG TRIP T RIH whipstocklmilling assy f/4,816'to 4,816.0 8,526.0 00:00 02:30 8,526'. Fill pipe every 20 stds. No issues. 6/18/2018 6/18/2018 0.75 PROD1 PLUG DLOG T Wash down f,8,526to 8,717'& log RA 8,526.0 8,717.0 02:30 03:15 tag @ 8,587' 6/18/2018 6/18/2018 1.75 PROD1 PLUG TRIP T RIH whipstock/milling assy f/8,717'to 8,717.0 11,003.0 03:15 05:00 11,003'. Fill pipe every 20 stds. No issues. 6/18/2018 6/18/2018 1.00 PRODI PLUG WASH T Wash down fit 1,003'to 11,117'w/230 11,003.0 11,117.0 05:00 06:00 gpm 11350 psi & orient whipstock 30" left. PU wt 212 Is / SO wt 155 k 6/18/2018 6/18/2018 0.25 PRODI PLUG WPST T Set whipstock as per Baker rep. SO 11,117.0 11,106.0 06:00 06:15 f/11,117'to 11,127.5'& set anchor - W17 k WOB. PU to 220 k & confirm anchor set. SO w/33 k WOB & shear mill from slide. PU & observe free travel with milling assy. TOW - 11,106.2' / BOW - 11,119.5' 6/18/2018 6/18/2018 0.25 PROD1 PLUG WPST T PIU to 11,079'. Obtain SPR's & prep to 11,106.0 11,106.0 06:15 06:30 mill window. Wash down f/11,079'to 11,106' w/230 gpm 11350 psi, 80 rpm 19 k trq 6/18/2018 6/18/2018 4.50 PRODI PLUG WPST T Mill window f/11,1 06'10 11,119'w/230 11,106.0 11,119.0 06:30 11:00 gpm 12050 psi, 80 - 100 rpm / 9 - 10 k trq. 6/18/2018 6/18/2018 3.25 PROD1 PLUG WPST T Cont. to polish off window &drill 20' 11,119.0 11,139.0 11:00 14:15 new hole (3' gauge hole) f111,119' to 11,139' w/220 gpm, 2050 psi, 10 - 12 k WOB, 100 rpm, 9 - 10 k trq, PU wt 212 k, SO H4 155 k, ROT wt 175 k. 6/18/2018 6/18/2018 0.50 PRODI PLUG WPST T Dress & polish off window. Work thru 11,139.0 11,139.0 14:15 14:45 with & without pumps. With &without rotation. (good). Page 29/47 Report Printed: 7118/2018 MT6-05 Rig: DOYON 19 Job: DRILLING ORIGINAL Time Log _ - -- ' - Start Depth-' -. Start Time End Time our (hr) Phase Op Code Activity Code Time P-T-X Operation dtK6) End Depth(ftKe) 6/18/2018 6/18/2018 1.50 PROD1 PLUG CIRC T Pump sweep & circ hole clean for FIT 11,139.0 11,075.0 14:45 16:15 w/250 gpm 12230 psi, 50 rpm 18.5 k trq. Pump out of hole to 11,075' 6/18/2018 6/18/2018 0.75 PROD1 PLUG FIT T R/U testing equipment. FIT to 12.5 11,075.0 11,075.0 16:15 17:00 ppg. RID testing equipment. 6/18/2018 6/18/2018 2.75 PROD1 DRILL DISP T PJSM. Displace milling fluid to new 11,075.0 11,075.0 17:00 19:45 9.2 ppg vis Brine w/250 gpm 12300 - 1320 psi, 50 rpm 18.5 k trq. 6/18/2018 6/18/2018 0.25 PROD1 DRILL OWFF T FIG (static) 11,075.0 11,075.0 19:45 20:00 6/18/2018 6/19/2018 4.00 PROD1 DRILL TRIP T POOH on elevators 1/11,075'to 7,037' 11,075.0 7,037.0 20:00 00:00 6/19/2018 6/19/2018 0.75 PROW DRILL TRIP T Pull out of hole from 7.037' MD to 7,037.0 5,836.0 00:00 00:45 5,836' MD on elevators, P/U=145k, S/0=125k. 6/19/2018 6/19/2018 0.25 PROD1 DRILL CIRC T Pump 39 bbl slug @ 10 ppg 5,836.0 5,836.0 00:45 01:00 6/19/2018 6/19/2018 2.50 PROD1 DRILL TRIP T Continue POOH on elevators from 5,836.0 305.0 01:00 03:30 5,836' MD to 305' MD. 6/19/2018 6/19/2018 0.25 PROD1 DRILL OWFF T OWFF- static. 305.0 0.0 03:30 03:45 PJSM on laying down BHA. 6/19/2018 6/19/2018 0.50 PRODII DRILL BHAH T Lay down milling assembly from 305' 0.0 0.0 03:45 04:15 MD to surface, per BOT fishing rep. 6/19/2018 6/19/2018 0.50 PROD1 DRILL BHAH T Clean and clear dg floor, Jay down 0.0 0.0 04:15 04:45 tools and equipment via beaver slide. 6/19/2018 6/19/2018 0.75 PROD1 DRILL W W WH T Make up stack washer and string 0.0 0.0 04:45 05:30 magnets, flush stack @ 700 gpm, 170 psi, 20 rpm 3K. 6/19/2018 6/19/2018 0.25 PROD1 DRILL WWWH T Lay down stack washer and string 0.0 0.0 05:30 05:45magnets (Functioned rams and annular) 6/19/2018 6119/2018 2.25 PROD1 DRILL BHAH T PJSM, M/U kick-off motor (1.5°) BHA 0.0 781.0 05:45 08:00 per BOT to 781' MD. Confirm MWD / Motor TFO=317°. 6/19/2018 6/19/2018 0.50 PROD1 DRILL TRIP T Run in hole with kickoff assembly from 781.0 2,207.0 08:00 08:30 1 1781'MD to 2,207' MD. 6/19/2018 6/19/2018-. 0.25 PROD1 DRILL DHEQ T Shallow test MWD @ 220 gpm, 620 2,207.0 2,207.0 08:30 08:45 psi -good. 6/19/2018 6/19/2018 3.00 PROD? DRILL TRIP T Continue RIH with kickoff BHA from 2,207.0 8,598.0 08:45 11:45 2,207' MD to 8,598' MD, filling pipe every 20 stands. P/U=195k, S10=145k. 6/19/2018 6/19/2018 0.25 PROD1 DRILL RURD - T Rig up Baker BPA to down link (mode 8,598.0 8,598.0 11:45 12:00 switch). Annulus B=50 psi, Annulus C=0 psi @ 12:00 hrs 6/19/2018 6/19/2018 0.50 PROD1 DRILL DLOG T Wash down from 8,598' MD to 8,637' 8,598.0 8,637.0 12:00 12:30 MD logging RA tag @ 230 gpm, 990 psi. Pick up tag @ 8,585' MD (8,627' bit depth). 6/19/2018 6/1912018 1.50 PROD1 DRILL TRIP T Continue RIH from 8,637' MD to 8,637.0 10,790.0 12:30 14:00 10,790' MD. 6/19/2018 6/19/2018 1.00 PROD1 DRILL SLPC T PJSM, Cut and slip 75' drilling line. 10,790.0 10,790.0 14:00 15:00 6/19/2018 6/19/2018 0.50 PROD1 DRILL SVRG T Service top drive, draworks. Calibrate 10,790.0 10,790.0 15:00 15:30 block height. 6/19/2018 6/19/2018 0.75 PROD1 DRILL WASH T Wash down from 10,790' MD to 10,790.0 11,139.0 15:30 16:15 10,980' MD, RIH without pump across whipstock slide to 11,119, continue wash down to bottom 11,139' MD. 6/19/2018 6/19/2018 2.50 PROD1 DRILL DDRL T Directional drill from 11,139' MD to 11,139.0 11,313.0 16:15 18:45 11,313' MD, 8,016' ND, 85' Inc. Page 30/47 i Report Printed: 7118/2018 MT6-05 Rig: DOYON 19 Job: DRILLING ORIGINAL Time Log Start Depth Slad Time End Time our (hr) Phase Op Code Activity Code Time P -T -X Operation (fi(B) End Depth(ftKB) 6/19/2018 6/19/2018 0.75 PROM DRILL CIRC T Circulate @ 170-200 gpm, 670-950 11,313.0 11,313.0 18:45 19:30 psi, CBU X 1 while discussing plan forward. Decide to pull out of hole for Rotary steerable drilling assembly. 6/19/2018 6/19/2018 0.75 PROD1 DRILL PMPO T Pull out of hole with pump @ 200 11.313.0 11,076.0 19:30 20:15 gpm, 950-880 psi from 11,313' MD to 11,171' MD. Shut down pump and pull bit across whipstock ramp to 11,076' MD, good. 6/19/2018 6/19/2018 1.50 PROD1 DRILL CIRC T Pump 35 bbl HV brine sweep, pump 11,076.0 11,076.0 20:15 21:45 around and out @ 250 gpm, 1200- 1280 psi, bottoms up cleaned up good, sweep brought back little returns 6/19/2018 6/19/2018 0.50 PROD? DRILL OWFF T Flow check well, static in 20 minutes, 11,076.0 11,075.0 21:45 22:15 slight drop after 30. 6/19/2018 6/20/2018 1.75 PROD1 DRILL TRIP T Pull out of hole on elevators from 11,076.0 9,170.0 22:15 00:00 11,076' MD to 9,170' MD, proper hole fill. Annulus B=70 psi, Annulus C=0 psi @ 23:00 hrs 6/20/2018 6/20/2018 4.00 PROM DRILL TRIP T Continue POOH on trip tank from 9,170.0 781.0 00:00 04:00 9,170' MD to 781' MD, observe proper hole fill. 6/20/2018 6/20/2018 0.25 PROD1 DRILL OWFF T Flow check well static at HWDP. 781.0 781.0 04:00 04:15 6/20/2018 6/20/2018 1.75 PROD1 DRILL BHAH T Lay down BHA per BOT reps, rack 781.0 0.0 04:15 06:00 back HWDP and Jars, 15.7# DP. String magnets @ 40% capacity. Check TFO on motor /MWD, observe 65° L discrepancy. 6/20/2018 6/20/2018 0.75 PROD1 DRILL BHAH T Clean and clear rig floor, lay down 0.0 0.0 06:00 06:45 tools and equipment. Clean rig floor. 6/20/2018 6/20/2018 0.50 PROD1 DRILL BHAH T PJSM, M/U BHA #13 to 67' per Baker 0.0 67.0 06:45 07:15 reps. 6/20/2018 6/20/2018 0.50 PROD1 DRILL BHAH T Plug in MWD and upload. 67.0 67.0 07:15 07:45 ` SIMOPS- M/U 2 NMFC, Float, Filter, Float, NM stab with tuggers and 90' '. mousehole. Prep source box. 6/20/2018 6/20/2018 0.25 FROM DRILL BHAH T Continue M/U BHA #13 to 144' MD. 67.0 144.0 07:45 08:00 6/20/2018 6/20/2018 0.25 PROD1 DRILL BHAH T Baker MWD load sources in tool. 144.0 144.0 08:00 08:15 6/20/2018 6/20/2018 0.25 PROD1 DRILL BHAH T Continue making up BHA #13 from 144.0 332.0 08:15 08:30 144' MD to 332' MD. P/U=97k, S/0=97k. 6/20/2018 6/20/2018 0.75 FROM DRILL TRIP T RIH from 332' MD to 2,234' MD from 332.0 2,234.0 08:30 09:15 derrick. 6/20/2018 6/20/2018 0.50 PRODt DRILL DHEQ T Shallow pulse test MWD @ 225 gpm, 2,234.0 2,234.0 09:15 09:45 840 psi, 20 rpm, 7k. Good. 6/20/2018 6/20/2018 2.25 PROD1 DRILL TRIP T Continue RIH with BHA#13 from 2,234.0 7,578.0 09:45 12:00 2,234' MD to 7.578' MD, filling pipe every 20 stands. Annulus B=100 psi, Annulus C=0 psi @ 12:00 hrs. 6/20/2018 6/20/2018 2.25 FROM DRILL TRIP T Continue RIH with BHA#13 from 7,578.0 11,007.0 12:00 14:15 7,578' MD to 11,007' MD filling pipe every 20 stands. 6/20/2018 6/20/2018 0.25 PROM DRILL OWFF T Flow check, static. 11,007.0 11,007.0 14:15 14:30 SIMOPS- PJSM on pulling trip nipple. 6/20/2018 6/20/2018 0.50 PROD1 DRILL MPDA T Pull trip nipple and install MPD 11,007.0 11,007.0 14:30 15:00 I element. Page 31147 Report Printed: 7118/2018 MT6-05 I f Rig: DOYON 19 Job: DRILLING ORIGINAL Time Log - - - I - Start Depth SlartTme End Time Dur(hr) Phase Op Code Activity Code Time P -T -X Operation (RKS) End Depth(ftKB) 6/20/2018 6/20/2018 0.25 PROD1 DRILL MPDA T Wash/ ream down from 11,007' MD to 11,007.0 11,102.0 15:00 15:15 11,102' MD, breaking in bearing @ 501100 rpm. Calibrate MPD chokes. P/U=205k, S/0=160k. 6/20/2018 6/20/2018 1.00 PROD1 DRILL TRIP T RIH from 11,107' MD to bottom @ 11,102.0 11,313.0 15:15 16:15 11,313' MD 6/20/2018 6/20/2018 1.75 PROD1 DRILL DISP T PJSM, displace to 9.0 ppg MOBM. 11,313.0 11,313.0 16:15 18:00 Pumped 60 bbl spacer, followed by 9.0 ppg MOBM @ 250 gpm, 1400- . 2740 psi, 60 rpm, 4.5-5.5k Tq. 6/20/2018 6/20/2018 0.50 PROD1 DRILL OWFF T Flow check, shut in MPD chokes 11,313.0 11,313.0 18:00 18:30 observe no pressure build. 6/20/2018 6/20/2018 1.50 PROD1 DRILL DDRL T Directional drill from 11,313' MD to 11,313.0 11,387.0 18:30 20:00 11,387' MD 6/20/2018 6/20/2018 1.25 PROD1 DRILL OTHR T Troubleshoot MWD due not accepting 11,387.0 11,387.0 20:00 21:15 downlink. Tried sending single commands unsuccessful. Adjusted bypass rate on BPA to recommended start point 17 turns out, successful. 6/20/2018 6/21/2018 2.75 PROD1 DRILL DDRL T Directional drill from 11,387' MD to 11,387.0 11,627.0 21:15 00:00 11,627' MD, 8,012' TVD. Tour ADT=3.7 hrs, P/U=193k, S10=152k, ROT=170k, Tq on/oft= 5k/5k, 215 gpm @ 220-0 psi, 100 rpm, 10.5 ECD. Annulus 13=100 psi, Annulus C=0 psi @ 23:00 hrs. 6/21/2018 6/21/2018 5.50 PROD1 DRILL DDRL T Directional drill from 11,627' MD to 11,627.0 12,087.0 00:00 05:30 12,087' MD, 6/21/2018 6/21/2018 4.50 PROD1 DRILL DDRL P Directional drill from 12,087' MD to 12,087.0 12,470.0 05:30 10:00 12,470' MD, 8,012' TVD. Tour . ADT=10.3 hrs, P/U=200k, S/0=140k, ROT=165k, Tq on/off-, 7.5k/6.5k, 218 gpm @ 2350 psi, 160 rpm, 10.75 ECD. Annulus 13=100 psi, Annulus C=50 psi @ 12:00 hrs. 6/21/2018 6/21/2018 2.00 PROD1 DRILL DDRL P Directional drill from 12,470'MD to 12,470.0 13,249.0 10:00 12:00 ', 12,626' MD, 8,01.3' TVD. Tour ADT=10.3 hrs, P/U=200k, S10=140k, ROT=165k, Tq on/off= 7.5k/6.5k, 218 gpm @ 2350 psi, 160 rpm, 10.75 ECD. Annulus 8=100 psi, Annulus C=50 psi @ 12:00 hrs. 6/21/2018 6/22/2018 12.00 PROD1 DRILL DDRL P Directional drill from 12,626' MD to 12,626.0 13,249.0 12:00 00:00 13,249' MD, 8,007' TVD. ADT=10.1 hrs, P/U=196k, S/0=1331k, ROT=162k, Tq on/off= 81</3.5k, 215 gpm @ 2370 psi, 180 rpm, 10.75 ECD. Annulus 13=100 psi, Annulus C=50 psi @ 23:00 hrs. 6/22/2018 6/22/2018 10.00 PROD1 DRILL •, DDRL P Directional drill from 13,249' MD to 13,24$.0 13,785.0 00:00 10:00 13,785' MD, 7,981' TVD. ADT=8.1 hrs, P/U=212k, S/0=1 35k, R0T=165k, Tq on/off= 8k/6k, 215 gpm @ 2340 psi, 160 rpm, 10.87 ECD. Drilled out of zone into Kingak/ boundry from 13,409'-13,585' MD due significant dip change. —140 gAPI, splintered fragile cuttings. Turned up from 88" to 96° to get back in zone. Observed pump pressure and ECD spikes at 13,770', decision to POOH and wipe Kingak section for evaluation. Page 32147 Report Printed: 811 iNT6-05 r I Rig: DOYON 19 Job: DRILLING ORIGINAL Time Log Start oepth Blart Time End Time our (hr) Phase Op Code Activity Code Time P-T-% Operalion (flKB) End Depth (flKB) 6/22/2018 6/22/2018 0.50 PROW DRILL BKRM T Backream out of hole from 13,785' MD 13,785.0 13,769.0 10:00 10:30 to 13,769' MD @ 215 gpm, 2340 psi, 100 rpm, 6.5k Tq. Holding 10.5 ppg CBHP with MPDE. 6/22/2018 6/22/2018 1.50 PROD1 DRILL PMPO T Pump out from 13,769' MD to 13,593' 13,769.0 13,593.0 10:30 12:00 MD @ 2 bpm, 960 psi. Packing off @ 13,636'to 1140 psi. Slack off to 13,648' and break over, continue pump out, packing off @ 13,593' twice. Slack off to 13,674' and break over. P/U=220-245k, S/0=135-118k. Annulus B=100 psi, Annulus C=50 psi @ 12:00 hrs. 6/22/2018 6/22/2018 2.00 PROD1 DRILL PMPO T Continue pumping/stripping out from 13,593.0 13,293.0 12:00 14:00 13,674' MD to 13,293' MD. Pumping @ .5-1 bpm, 700--800 psi. Holding 500 psi annular pressue with MPDE. Packing off and pulling tight @ 13,548', 13,537', 13,413'. 6/22/2018 6/22/2018 2.00 PROD1 DRILL CIRC T Circulate and condition, stage up from 13,293.0 13,293.0 1400 16:00 24 gpm to 215 gpm, 940-2360 psi, stage rotary up to 140 rpm, 8.5k Tq. Shale returns at shakers. 6/22/2018 6/22/2018 1.50 PROD1 DRILL PMPO T Pump out of hole from 13,293' MD to 13,293.0 12,435.0 16:00 17:30 12,435' MD @ 3 bpm, 1000 psi. Maintaining 10.5 ppg EMW with MPDE. P/U=200k, S/0=155k, ROT=165k. 6/22/2018 6/22/2018 4.25 PROD1 DRILL KOST T Trough for open hole side track from 12,435.0 12,470.0 17:30 21:45 12,435' MD to 12,470' MD @ 215 gpm, 2160 psi, 100 rpm 60 fph @ 100% down until sleeve rotation observed, as well as slight drop in incination. Close AutoTrak ribs and make final pass to 12,470' MD. 6/22/2018 6/22/2018 0.50 PROW DRILL KOST T At 12,470' MD bit depth, circulate at 12,470.0 12,470.0 21:45 22:15 base of trough 215 gpm, 2160 psi, 100 rpm, 7k Tq. 6/22/2018 6/23/2018 1.75 PROD1 DRILL KOST T Begin time drilling per plan from 12,470.0 12,471.0 22:15 00:00 12,470' MD to 12,470.5' MD, 8,008' ND. 215 gpm, 2160 psi, 100 rpm, 7k Tq. ADT=2.3, ECD=10.44, P/U=200k, S/0=150k, ROT=165k. Annulus B=100 psi, Annulus C=50 psi @ 22:00 hrs. 6/23/2018 6/23/2018 12.00 PROD1 DRILL KOST T Time drill per Baker recommendation 12,471.0 12,481.0 00:00 12:00 from 12,470.5' MD to 12,481' MD, 8,013' TVD. ADT=12 hrs, ROT=175k, Tq=7.5k, 100 rpm, 215 gpm @ 2200 psi. ECD=10.44 Annulus B=100 psi, Annulus C=100 psi @ 12:00 hrs. 6/23/2018 6/24/2018 12.00 PROD1 DRILL KOST T Continue to time drill per Baker 12,481.0 12,498.0 12:00 00:00 recommendation from 12,481' MD to 12,498' MD, 8,014' TVD. ADT=11.9 hrs, ROT=175k, Tq=7.5k, 100 rpm, 215 gpm @ 2200 psi. ECD=10.49. Observe inclination drop to 88.78°, vs old well bore @ 89.75`. Annulus 6=150 psi,Annulus C=100 psi @ 22:00 hrs. Page 33147 Report Printed: 711812018 a MT6-05 Rig: DOYON 19 Job: DRILLING ORIGINAL Time Log - Start Depth Som Inme End Time our (hr) Phase Op Code Activity Code Tme P-T-X Operation .. (RKB); End Depth (111<8) 6/24/2018 6/24/2018 5.00 PROD1 DRILL KOST T Continue to control drill per Baker 12,498.0 12,530.0 00:00 05:00 recommendation from 12,498' MD to 12,530' MD, 8,014' TVD. ROT=175k, Tq=7.5k, 100 rpm, 215 gpm @ 2260 psi. ECD=10.49. Observe inclination - drop to 88.70°, vs old well bore @ 90.65°. 6/24/2018 6/24/2018 7.00 PROD1 DRILL DDRL T Drill ahead from 12,530' MD with ribs 12,530.0 12,765.0 05:00 12:00 open, holding 89° and slight LH walk to achieve further separation from PB2. Drill from 12,530' MD to 12,756' MD, 8,013' TVD. TourADT=11.2 his. R0T=167k, Tq on/off=7k/6.5k, 160 rpm, 215 gpm @ 2260 psi. ECD=10.63. Annulus B=150 psi, Annulus C=100 psi @ 12:00 hrs. 6/24/2018 6/25/2018 12.00 PROD1 DRILL DDRL T Drill ahead from 12,765' MD to 13,198' 12,765.0 13,198.0 12:00 00:00 MD, 7,989' TVD. Tour ADT=10.5 his. P/U=193k, 8/0=133k, ROT=167k, Tq on/off-7k/6k, 160 rpm, 215 gpm @ 2370 psi. ECD=10.79. Annulus B=110 psi, Annulus C=100 psi @ 22:00 hrs. 6/25/2018 6/25/2018 6.25 PROD1 DRILL DDRL T Drill ahead from 13,198' MD to 13,785' 13,198.0 13,785.0 00:00 06:15 MD, P/U=193k, S/0=133k, ROT=167k, Tq on/off-7k/6k, 160 rpm, 215 gpm @ 2370 psi. ECD=10.79. 6/25/2018 6/25/2018 5.75 PRODi DRILL DDRL P Drill ahead from 13,785' MD to 14,085' 13,785.0 14,085.0 06:15 12:00 MD, 7,954'TVD. Tour ADT=10.0 hrs. P/U=195k, S10=130k, ROT=162k, Tq on/off-7.5k/6.5k, 160 rpm, 215 gpm @ 2430 psi. ECD=10.69. Annulus B=150 psi, Annulus C=100 psi @ 12:00 hrs. 6/25/2018 6/26/2018 12.00 PROD1 DRILL DDRL P Drill ahead from 14,085' MD to 14,849' 14,085.0 14,849.0 12:00 00:00 MD, 7,914' TVD. Tour ADT=9.7 hrs. P/U=190k, S/0=127k, ROT=160k, Tq onloff=8.81<77.5k, 160 rpm, 215 gpm @ 2590 psi. ECD=11.09. Annulus B=175 psi, Annulus C=100 psi @ 22:00 his. 6/26/2018 6/26/2018 1.25 PROD1 DRILL DDRL P Drill ahead from 14,849' MD to 14,912' 14,849.0 14,912.0 00:00 01:15 MD, 7,915' TVD P/U=190k, S/0=125k, ROT=160k, Tq on/off-8.5k/7,5k. 160 rpm, 215 gpm @ 2550 psi. ECD=10.9. 6/26/2018 6/26/2018 0.50 PROD1 DRILL CIRC P Circulate open hole volume, 80 bbl @ 14,912.0 14,912.0 01:15 01:45 215 gpm, 2530 psi, 120 rpm, 7.5k Tq. P/U=188k, S/0=133k, ROT=155k. SIMOPS- PJSM on C/O wash pipe. 6/26/2018 6/26/2018 0.50 PROD1 DRILL SVRG P Service rig, change out wash pipe on 14,912.0 14,912.0 01:45 02:15 top drive. Circulate @ 3 bpm 1300 psi via head pin, while holding 245 annular pressure with MPDE. 6/26/2018 6/26/2018 2.00 PROD1 DRILL DDRL P Drill ahead from 14,912' MD to 15,103' 14,912.0 15,103.0 02:15 04:15 MD, 7,923' TVD. Observe MPD element worn to where bearing not spinning on DP. 6/26/2018 6/26/2018 0.50 PROD1 DRILL CIRC P Circulate open hole volume, 90 bbl @ 15,103.0 15,103.0 04:15 04:45 215 gpm, 2510 psi, 100 rpm, 7k Tq. P/U=188k, S/0=133k, ROT=155k. SIMOPS- PJSM on C/O MPD bearing assy. ' Page 34/47 Report Printed: 7/1812018 MT6-05 I DOYON 19 Job: DRILLING ORIGINAL Time Log Start Depth Stars Time End Time Dur (hr) Phase Op Code Activity Code Time P -T -X Operation (flKB) End Depth (flKB) 6/26/2018 6/26/2018 0.50 PROD1 DRILL MPDA P Change out MPD element. Shutdown 15,103.0 15,103.0 04:45 05:15 mud pump, close chokes trapping 550 psi. Close annular preventer, open MPD chokes. Strip pipe through annular to C/O bearing. Close MPD chokes, equalize presures, open annular, 500 psi still holding in annulus. 6/26/2018 6/26/2018 6.75 PROD1 DRILL DDRL P Drill ahead from 15,103' MD to 15,810' 15,103.0 15,810.0 05:15 12:00 MD, 7,931' TVD. Tour ADT=8.2 hrs. P/U=195k, S/0=120k, ROT=155k, Tq on/off=9.51</8k, 160 rpm, 215 gpm @ 2630 psi. ECD=10.98. Annulus B=150 psi, Annulus C=100 psi @ 12:00 hrs. 6/26/2018 6/27/2018 12.00 PROD1 DRILL DDRL P Drill ahead from 15,810' MD to 16,514' 15,810.0 16,514.0 12:00 00:00 MD, 7,899' TVD. Tour ADT=9.6 hrs. P/U=195k, S/0=120k, ROT=158k, Tq on/off-9k/7k, 160 rpm, 215 gpm @ 2830 psi. ECD=11.27. Annulus B=150 psi, Annulus C=100 psi @ 22:00 hrs. Losses to formation 120 bbl today, currently 6-9 bph seepage loss. Adding fine backgeround LCM. Observing wellbore breathing after 16,159' MD, where seepage loss increased, as well as change in drilling parameters (WOB) and log data.(Res increase). 6/27/2018 6/27/2018 2.50 PROD1 DRILL DDRL P Drill ahead from 16,514' MD to 16,730' 16,514.0 16,730.0 00:00 02:30 MD, 7,899' TVD P/U=195k, S/0=120k, ROT=158k, Tq on/off-8.5k/7.5k, 160 rpm, 215 gpm @ 2900 psi. ECD=11.3. 6/27/2018 6/27/2018 1.75 PROD1 DRILL SEQP T Troubleshoot MWD surface 16,730.0 16,730.0 02:30 04:15 equipment, computer crashed. Re- boot, no go. Tech services remote in and repair corrupted file, re -boot good. SIMOPS- Circulate bottoms up @ 215 gpm, 2730 psi, 100 rpm, 8k Tq. 6/27/2018 6/27/2018 5.25 PROW DRILL DDRL P Drill ahead from 16,730' MD to 17,284' 16,730.0 17,284.0 04:15 09:30 - MD, 7,891' TVD P/U=195k, S/0= (Lost SOW @ 17,199'), ROT=165k, Tq on/off=11 k/8.5k, 160 rpm, 215 gpm @ 2930 psi. ECD=11.48. Tour ADT=6.0 his. 6/27/2018 6/27/2018 2.50 PRODt DRILL CIRC P Circulate and condition hole for 17,284.0 17,284.5- 09:30 12:00 fingerprint, 215-250 gpm, 2880-3550 psi, 100-120 rpm, 8-8.5k Tq. SPR's and on bottom survey. Circulate until 9.0 ppg in/out. Annulus 6=200 psi, Annulus C=100 psi @ 12:00 hrs. 6/27/2018 6/27/2018 0.50 PROD1 DRILL OWFF P Perform MPD drawdown and 17,284.0 17,284.0 12:00 12:30 formation fingerprint, rotating string @ 20 rpm, 8k. OWFF, no pressure build, static with 9.0 ppg. 6/27/2018 6/27/2018 1.50 PROD1 DRILL DDRL P Drill ahead from 17,284' MD to 17,391' 17,284.0 17,391.0 12:30 14:00 MD, 7,884' TVD P/U=195k, S/0= N/A, ROT=165k, Tq on/off=11k/9k, 160 rpm, 215 gpm @ 2900 psi. ECD=11.33. TourADT=1.3 hrs. 6/27/2018 6/27/2018 1.00 PROD1 CASING CIRC P Circulate and condition @ 250 gpm, 17,391.0 17,391.0 14:00 15:00 2570 psi, 120 rpm, 8k Tq. Reciprocate from 17,391' MD to 17,294' MD Page 35147 ReportPrinted: 711812018 MT6-05 Rig: DOYON 19 Jab: 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 (ftKE) 6/27/2018 6/27/2018 5.00 PROD1 CASING CIRC P Rack back stand to 17,294' MD, 17,391.0 17,294.0 15:00 20:00 continue circulating @ 220 gpm 2570 psi, 120 rpm, 8k Tq while weighting up to 9.3 ppg. Rack back second stand to 17,199' MD. Obtain S/O wt @ 125k. 6/27/2018 6/27/2018 0.50 PROD1 CASING CIRC P At 9.3 ppg in/out, obtain SPR's. Test 17,294.0 17,199.0 2000 2030 floats (leaking). Blow down top drive. 6/27/2018 6/27/2018 0.50 PROD1 CASING OWFF P Observe well for flow, static 30 17,199.0 17,199.0 20:30 21:00 minutes @ 9.3 ppg. 6/27/2018 6/27/2018 1.50 PROD1 CASING SMPD P SOOH with 100 psi AP in slips, 260 17,199.0 16,150.0 21:00 22:30 psi pulling @ 1000 fph from 17,199' MD to 16,150' MD. Floats still leaking slowly, able to keep up using rig vac hose -6 fl down DP before pulling. Observe correct hole fill. 6/27/2018 6/27/2018 0.50 PROD1 CASING CIRC P Pump 50 bbl 12.0 ppg dry job @ 215 16,150.0 16,150.0 22:30 23:00 gpm, 2400 psi, 10 rpm 6k, blow down top drive. 6/27/2018 6/28/2018 1.00 PROW CASING SMPD P Continue to SOOH from 16,150' MD to 16,150.0 15,610.0 23:00 00:00 15,610' MD pulling dry pipe. P/U=205k, ROT=175k. Calc F111=9 bbl, Actual fill=12 bbl. Annulus 8=100 psi, Annulus C=100 psi @ 22:00 hrs. Daily seepage loss to formation=130 bbl, Cumulative Interval=574 bbl 6/28/2018 6/28/2018 4.25 PROD1 CASING SMPD P Continue to SOOH from 15,610' MD to 15,610.0 11,007.0 00:00 04:15 11,007' MD holding 290 psi annular back pressure pulling and 100 psi in slips. Checking slack off weight every 10 stands, 125k, 140k, 147k, 150k, 152k. 6/28/2018 6/28/2018 2.00 PROD1 CASING CIRC P Circulate casing clean @ 200 gpm, 11,007.0 11,007.0 04:15 06:15 2350 psi, 120 rpm, 5-6k Tq. Capture slug comin g out of hole, increase rate to 250 gpm, 2770 psi. Pump 80 bbl 10.7+ slug into pipe. Blow down top drive. P/U=192k, S/0=155k, ROT=165k. 6/28/2018 6/28/2018 0.75 PRODt CASING OWFF P OWFF static, drop 2.11" OD hollow 11,007.0 11,007.0 06:15 07:00 drift with tail on stand #112. 6/28/2018 6/28/2018 5.00 PROD1 CASING SMPD P Continue to SOOH from 11,007' MD to 11,007.0 2,043.0 07:00 12:00 2,043' MD holding 290 psi annular back pressure pulling and 100-30 psi in slips. Annulus B=75 psi, Annulus C=0 psi @ 12:00 hrs. 6/28/2018 6/28/2018 0.50 PROD1 CASING CIRC P Circulate bottoms up @ 2,043' MD, 5 2,043.0 2,043.0 12:00 12:30 bpm 1200 psi. Dump slug from hole. 6/28/2018 6/28/2018 0.25 PROD1 CASING OWFF P Monitor well for flow, 15 minutes static 2,043.0 2,043.0 12:30 12:45 prior to pulling RCD. PJSM on pulling RCD. 6/28/2018 6/28/2018 0.75 PROD1 CASING MPDA P Pull RCD bearing, install trip nipple. 2,043.0 2,043.0 12:45 13:30 Change out trip nipple air boot. 6/28/2018 6/28/2018 1.00 PROW CASING TRIP P POOH on elevators from 2,043' MD to 2,043.0 332.0 13:30 14:30 332' MD. P/U=90k. OWFF-Static. 6/28/2018 6/2812018 0.50 PROD1 CASING BHAH P Lay down Jar, PIU HWDPjoint and 332.0 177.0 14:30 15:00 make stand HWDP. Rack back] 2 stands HWDP for liner run. 6/28/2018 2.00 PROD1 CASING P PJSM, Lay down BHA#13 and 177.0 0.0 15:00 17:00 sources from 177' MD. 16/28120111 1BHAH iloss=0. Total losses from SOOH=40 bbl, static Page 36147 Report Printed: 711812018 MT6-05 DOYON 19 Job: DRILLING ORIGINAL Time Log Start Depth Start Time I End Time Dur (hr) Phase Op Code Activity Code Time P -T -X Operation (fixB) End Depth (MB) 6/28/2018 6/28/2018 0.50 PROD1 CASING BHAH P Clean and clear rig floor. 0.0 0.0 17:00 17:30 6/28/2018 6/28/2018 0.50 COMPZ1 WHDBOP RURD P Pull wear bushing, FMC set test plug 0.0 0.0 17:30 18:00 and 4" test joint. 6/28/2018 6/28/2018 1.00 COMPZ1 WHDBOP RURD P Rig up test equipment, flood system 0.0 0.0 18:00 19:00 with water and purge air from system. 6/28/2018 6/28/2018 3.50 COMPZI WHDBOP ROPE P Perform AOGCC BOPE test, 0.0 0.0 19:00 22:30 witnessed by Adam Earl. BLM Mutasim Elganzoory waived 6/22 Q 16:29 him via email. 4" and 4%" Test joints, 250/3500 psi 5 min ea charted. 4" TJ, tested Annular preventer, CV #1,12,13,14.4" Demco Kill, Upper (Auto) IBOP, Upper 3%" x 6" VBR, HCR Kill, CV#9,11. Manual (Lower) IBOP. CV# 5,8,10, XT39 Dart Valve, CV# 4,6,7. XT39 FOSV, CV#2. HCR choke, manual choke, manual kill, Lower 3W x 6" VBR. 41W Test jt, test Annular preventer, Upper and lower 3Y" x 6" VBR's. 6/28/2018 6/28/2018 1.00 COMPZI WHDBOP BOPE P Perform accumulator function test. 0.0 0.0 2230 2330 System pressure=3050 psi, Manifold pressure=1450 psi. System pressure after functioning all rams, annular and HCR valves=1400 psi, manifold=1180 psi. 200 psi attained= 25 seconds with electric pump, full system recovery= 155 seconds with electric and air pumps. 4 bottle Nitrogen average=2150 psi. Test blind rams 250/3500. Test manual and super auto choke to 1100 psi. Tested rig gas alarms, flow paddle and PVT's. 6/28/2018 6/29/2018 0.50 COMPZ1 WHDBOP RURD P Pull test plug, blow down/ rig down 0.0 0.0 23:30 00:00 test equipment. Annulus B=75 psi, Annulus C=0 psi 22:00 hrs. 6/29/2018 6/29/2018 0.25 COMPZI WHDBOP RURD P Set 6.1875" wear ring per FMC. 0.0 0.0 00:00 00:15 SIMOPS- Blow down mud line. 6/29/2018 6/29/2018 1.00 COMPZI CASING RURD P R/U to run 4%;' TXP liner, C/O to 4W 0.0 0.0 00:15 01:15 Tubing elevators, P/U and R/U double slack power tongs. Count pipe and verify running order. 6/29/2018 6/29/2018 6.50 COMPZI CASING PUTB P PJSM, P/U 3'/=" orange peel joint, P/U 0.0 6,118.0 01:15 07:45 and run 4%" TXP liner and pert pups per detail to 6,118' MD. 6/29/2018 6/29/2018 1.50 COMPZI CASING PUTB P Change out elevators to 4", P/U HRDE 6,118.0 6,162.0 07:45 09:15 ZXP liner top packer and Flex Lock liner hanger assy. Make up 2-3/8" slick seal and ball seat assy. Make up SLB SCMT tools to boUtom of liner running tools. Mix and pour Zanplex, RIH to 6,162' MD. P/U=120k, S/0=110k. 6/29/2018 6/29/2018 0.50 COMPZI CASING RUNL P Make up XO to 4" DP, RIH with first 6,162.0 6,271.0 09:15 09:45 stand from 6,162' MD to 6,271' MD from derrick. 6/29/2018 6/29/2018 0.25 COMPZ1 CASING CIRC P Establish circulation @ 1-3 bpm, 60- 6,271.0 6,271.0 09:45 10:00 180 psi to ensure circulation path clear. P/U=120k, S/0=110k. 6/29/2018 6/29/2018 2.00 COMPZ1 CASING RUNL P Run liner on 4" DP from 6,271' MD to 6,271.0 9,508.0 10:00 12:00 9,508' MD. S/0=125k. 6/29/2018 6/29/2018 1.50 COMPZI CASING TRIP P Continue to run liner in hole with 4Y=" 9,508.0 10,949.0 12:00 13:30 liner on drill pipe from 9,508' MD to 10,949' MD. Page 37/47 Report Printed: 7/1812018 CSGFtiT WiO O ,�'.e��y l 7" MT6-05 Rig: DOYON 19 Job: DRILLING ORIGINAL Time Log - Start Tme End Thhe our (hr) -. Phase - op.Code Activity Code Tne P - 6X ..Operation Start Depth (flKBJ End Depth (MB) 6/29/2018 6/29/2018 0.50 COMPZI CASING CIRC P Obtain parameters @ window. Break 10,949.0 10,949.0 13:30 14:00 circulation @ 3 bpm, 580 psi, circulate 9.3 ppg even MW in/out. P/U=175k, S/0=145k, ROT=160k. Check tating torque @ 10 rpm=3.5k, 20 rpm=3.7k. 6/29/2018 6/29/2018 4.50 COMPZI CASING TRIP P Continue running in hole from 10,949' 10,949.0 17,192.0 14:00 18:30 MD to set depth 17,192' MD. Liner top @ 11,034' MD. P/U=225k, S/0=150k. 6/29/2018 6/29/2018 1.00 COMPZI CASING PACK P Drop 1.625" setting ball, pump down 17,192.0 17,192.0 18:30 19:30 @ 3 bpm, 930 psi for 60 bbl, slow rate to 1.5 bpm 520 psi. Ball on seat @ 77 bbl. Increase pressure to 2100 psi. Slack off to 100k observe hanger set. Pressure up to 3650 psi and hold 5 min. Bleed off. PIU and observe free travel @ 215k. S/O and observe shear @ 110k. Repeat. P/U to 190k, seals still located. 6/29/2018 6/29/2018 0.50 COMPZ1 CASING PRTS P Rig up and pressure test liner top 17,192.0 17,192.0 19:30 20:00 packer to 3300 psi for ten minutes charted. 6/29/2018 6/29/2018 0.50 COMPZI WELLPR TRIP P POOH to 11,095' (Running tools 17,192.0 11,095.0 20:00 20:30 length) MD @ 215k to cut and slip. SCMT still in liner. 6/29/2018 6/29/2018 1.00 COMPZI WELLPR SLPC P PJSM, cut and slip 68' of drilling line, 11,095.0 11,095.0 20:30 21:30 calibrate block height. 6/29/2018 6/30/2018 2.50 COMPZ1 WELLPR QEVL P POOH with SCMT logging tools from 11,095.0 9,450.0 21:30 00:00 11,U9b MU to 9,4bd MU, logging out 1500 fph. P/U=200k, Calc Fitl=15 bbl, Actual Fill=20 bbl. Annulus B=75 psi, Annulus C=0 psi @ 22:00 hrs. 6/30/2018 6/30/2018 1.50 COMPZ1 WELLPR QEVL P POOH from 9,450' MD to 8,112' MD, 9,450.0 8,112.0 00:00 01:30 logging with SCMT @ 1500-1800 fph. P/U=175k. 6/30/2018 6/30/2018 0.50 COMPZI WELLPR CIRC P Break circulation, pump 18 bbl 11.1 8,112.0 8,112.0 01:30 02:00 ppg slug @ 3 bpm, 550 psi. Blow down top drive. 6/30/2018 6/30/2018 5.00 COMPZI WELLPR TRIP P POOH from 8,112' MD to 104' MD. 8,112.0 104.0 02:00 07:00 ', Total Calc Fill=81 bbl, Actual F111=90.5 bbl. 6/30/2018 6/30/2018 0.25 COMPZ1 WELLPR OWFF P OWFF- Static, PJSM on laying down 104.0 104.0 07:00 07:15 1 1 liner running tools and SCMT. 6/30/2018 6/30/2018 1.00 COMPZ1 WELLPR BHAH P Lay down Baker liner running tools 104.0 0.0 07:15 08:15 and SLB logging tools from 104' MD 41 6/30/2018 08:15 6/30/2018 08:45 0.50 COMPZI WELLPR BHAH P Clean and clear rig floor, lay down tools off floor. 0.0.0 6/30/2018 6/30/2018 3.25 PROD2 WHPST BHAH P PJSM Make up Whipstock/ Mill 0.0$1.0 08:45 12:00 assembly per Baker reps. `I 6/30/2018 6/30/2018 1.50 PROD2 WHPST BHAH P Continue making up whipstock BHA to 81.0 337.0 12:00 13:30 337' MD 6/30/2018 6/30/2018 0.50 PROD2 WHPST TRIP P Trip in hole from 337' MD to 1,537' 337.0 1,537.0 13:30 14:00 1 MD, S/0=80k. 6/30/2018 6/30/2018 0.50 PROD2 WHPST DHEQ P Shallow pulse test MWD @ 200 gpm, 1,537.0 1,537.0 14:00 14:30 820 psi. Good. 6/30/2018 6/30/2018 5.00 PROD2 WHPST TRIP P Continue tripping in hole from 1,537' 1,537.0 8,726.0 14:30 19:30 MD to 8,726' MD. S/0=150k, P/U=175k. 6/30/2018 6/30/2018 0.50 PROD2 WHPST DLOG P Establish circulation @ 8,726' MD, 8,726.0 8,750.0 19:30 2000 200 gpm 1500 psi. Log RA tag @ 8,586' MD casing depth. Page 38147 Repott Printed: 7/18/2018 } MTG-05 Rig: DOYON 19 Job: DRILLING ORIGINAL Time Log Start Depth Start Time I End Time Dur(hr) Phase Op Code Activity Cotle Time P -T -X Operation 0U(S) End Depth.(rtKS) 6/30/2018 6/30/2018 1.50 PROD2 WHPST TRIP P Continue tripping in hale from 8,750' 8,750.0 10,917.0 20:00 21:30 MD to 10,917' MD. P/U=185k, S/0=150k 6/30/2018 6/30/2018 1.25 PROD2 WHPST WASH P Establish circulation and wash down 10,917.0 11,012.0 21:30 22:45 @ 200 gpm, 1760 psi. Orient whipstock slide @ 13°L, slowly work pipe to work down any rotational movement. 6/30/2018 6/30/2018 0.25 PROD2 WHPST WASH P Made connection @ 11,012' MD, still 11,012.0 10,939.0 22:45 23:00 @ 13°L. Continue washing down and No -Go with 4k down @ 11,035' MD (seal assy @ 11,039'). Slack off 15k and observe Anchor shear set. P/U 10k over to confirm trip anchor set. 1 Slack off 35k, observe whipstock trip bolt shear. Pick up above TOW with u� ,.. 185k. TOW=10,939.14' MD, /1!I " BOW=10,952.44, TOL=11,035' MD drill pipe measurement. 6/30/2018 7/1/2018 1.00 PROD2 WHPST MILL P Begin milling window from 10,939' MD 10,939.0 10,939.0 23:00 00:00 to 10,939.65' MD @ 220 gpm, 2080 psi, 80 rpm, 4-5k Tq. 0-1 k Weight on mill, ROT=167k. Annulus B=O psi, Annulus C=75 psi @ 22:00 hm. 7/1/2018 7/1/2018 4.25 PROD2 WHPST MILL P Continue milling window from 10,939.0 10,952.0 00:00 04:15 10,939.65' MD to 10,952.44' MD @ 220 gpm, 2020 psi, 100 rpm, 5-8k Tq, 15-18k WOB. TOW= 10,939.14' MD, BOW=10,952.44' MD. 7/1/2018 7/1/2018 4.75 PROD2 WHPST DDRL P Continuie drilling formation to 10,973' 10,952.0 10,973.0 04:15 09:00 MD with same parameters, second and third mill pass through window. 7/1/2018 7/1/2018 0.50 PROD2 WHPST REAM P Ream up and down through window 10,973.0 10,916.0 09:00 09:30 @ 220 gpm, 2020 psi, 100 rpm, 5k Tq. P /U=180k, S/0=154k, ROT=165k. Shut down rotary, work mills up and down through window @ 1 bpm, 440 psi. P/U=190k, S/0=156k. Smooth, no obstructions. 7/1/2018 7/1/2018 1.25 PROD2 WHPST CIRC P OWFF static. Pump 30 bbl HV Super 10,916.0 10,916.0 09:30 10:45 Sweep @ 200 gpm, 1900 psi, pump surface to surface sweep out of the hole, minor increase in mill cutting returns. 7/1/2018 711/2018 0.25 PROD2 WHPST OWFF P Obtain SPR's, OWFF- Static 10,916.0 10,916.0 10:45 11:00 7/1/2018 7/1/2018 1.00 PROD2 WHPST TRIP P POOH on elevators from 10,916' MD 10,916.0 10,058.0 11:00 12:00 to 10,058' MD. P/U=190k. 7/1/2018 7/1/2018 6.50 PROD2 WHPST TRIP P Continue POOH on elevators from 10,058.0 241.0 12:00 18:30 10,058' MD to 241' MD. P/U=90k. OWFF- Static. Calc/Actual fill= 73 bbl. 7/1/2018 7/1/2018 1.50 PROD2 WHPST BHAH P PJSM, Lay down milling BHA. 241.0 0.0 18:30 20:00 Magnets fully loaded, Pilot mill 1/2" under gauge, upper mill in gauge. 7/1/2018 7/1/2018 0.50 PROD2 WHPST BHAH P Lay down BHA tools from rig floor, 0.0 0.0 20:00 2030 Clean and clear rig floor. Page 39/47 ReportPrinted: 7/1812018 ' MT6-05 i Rig: DOYON 19 Job: DRILLING ORIGINAL Time Log .. Stan Depth SlanTime I End Time Dur(hr) Phase Op Cotle Actmity Cotle Time P -T -X Operation (ftt(B) End Depth(RKB) 7/1/2018 7/1/2018 1.00 PROD2 WHPST WWWH P Make up stack washer with Baker 0.0 0.0 20:30 21:30 magnets. Function blind rams. RIH with magnets, fuction VBR's. Flush stack @ 10 bpm, 20 rpm for 15 minutes, significant cuttings/shavings over shakers. Flush until shakers clean. Clean magnets, lay down stack washer. 7/1/2018 7/1/2018 0.50 PROD2 WHPST SVRG P Service top drive rollers, block, 0.0 0.0 21:30 22:00 washpipe, crown, draworks, iron roughneck. 7/1/2018 7/1/2018 1.00 PROD2 WHPST BHAH P PJJSM, M/U BHA#15 to 76' MD. 0.0 76.0 22:00 23:00 MWD scribe to motor high side offset 23.9°. Verify offset. Annulus B=0 psi, Annulus C=70 psi @ 22:00 hrs. 7/1/2018 7/2/2018 1.00 PROD2 WHPST BHAH P Continue M/U BHA #15 to 564' MD 76.0 564.0 23:00 00:00 7/2/2018 7/2/2018 0.75 PROD2 WHPST BHAH P Continue MN BHA#15 from 564' MD 564.0 771.0 00:00 00:45 to 771' MD (HWDP and Jars) 7/2/2018 7/2/2018 0.50 PROD2 WHPST TRIP P Trip in hole from 771' MD to 1,720' MD 771.0 1,720.0 00:45 01:15 out of derrick. 7/2/2018 7/2/2018 0.25 PROD2 WHPST DHEQ P Shallow pulse test MWD @ 215 gpm, 1,720.0 1,720.0 01:15 01:30 1000 psi - Good. 7/2/2018 7/2/2018 4.25 PROD2 WHPST TRIP P Continue RIH from 1,720' MD to 1,720.0 8,591.0 01:30 05:45 8,591' MD filling pipe every 20 stands. 7/2/2018 7/2/2018 0.25 PROD2 WHPST DLOG P Break circulation, log from 8,59V0 8,591.0 8,683.0 05:45 06:00 to 8,683' MD @ 220 gpm, 1600 psi, 150 fph to log RA tag. P/U RA tag @ 8,626' MD bit depth (8,584' casing depth) 7/2/2018 7/2/2018 1.50 PROD2 WHPST TRIP P Continue RIH from 8,683' MD to 8,683.0 10,875.0 06:00 07:30 10,875' MD filling pipe every 20 stands. PA)=187k, S/0=150k, Calc/ Actual Disp=72 bbl. 7/2/2018 7/2/2018 0.25 PROD2 WHPST CIRC P Break circulation 220 gpm, 1660 psi. 10,875.0 . 10,875.0 07:30 07:45 Obtain SPR's. Orient motor to 10°L. 7/2/2018 7/2/2018 1.00 PROD2 DRILL TRIP P Shut down pumps, slide through 10,875.010,973.0 07:45 08:45 window with no pump or rotary to 10,973' MD. No obstructions. 7/2/2018 7/2/2018 3.25 PROD2 DRILL DDRL P Directional drill (kick off) from 10,973' 10,973.0 11,113.0 08:45 1200 MD to 11,113' MD, 7,999' MD. ADT=2.4, ART=.5, AST=1.9 hrs. Obtain surveys @ TOW and BOW (10,939'-10,952' MD.) P/U=187k, S10=155k, ROT=160k, Tq on/off=5.5k/5k. 7/2/2018 7/2/2018 0.50 PROD2 DRILL DDRL P Directional drill (kick off) from 11,113' 11,113.0 11,161.0 12:00 12:30 MD to 11,161' MD, 7,974' MD. ADT=0.5, ART=0.5, AST=0.0 hrs. P/U=190k, S/0=150k, ROT=164k, Tq ordoff=6.5k/5k. 7/2/2018 7/2/2018 1.50 PROD2 DRILL CIRC P Circulate bottoms up @ 215 gpm, 11,161.0 11,161.0 12:30 14:00 2260 psi, 80 rpm, 5.5k Tq. Take final survey, obtain SPR's. 7/2/2018 7/2/2018 0.50 PROD2 DRILL BKRM P Backream out of hole @ drilling rates 11,161.0 10,970.0 14:00 14:30 215 gpm, 60 rpm from 11,161' MD to 11,065' MD. Stop rotary and pump out from 11,065'to 10,970' MD orient motor high side to 10"L. P/U=190k. Page 40147 ReportPrinted: 7/1 812 01 8 MT6-05 �- Rig: DOYON 19 Job: DRILLING ORIGINAL Time Log Start Depth Start Time End Time Dur (hr) Phase Op Code Activity Code Time PJX Operation (tKB) End Depth (f1KB) 7/2/2018 7/2/2018 0.50 PROD2 DRILL TRIP P Pull BHA across window from 10,970' 10,970.0 10,847.0 14:30 15:00 MD to 10,847' MD with no pumps or rotary. P/U=190-194k, no overpull. Monitor well - Static. PJSM on installing RCD. 7/2/2018 7/2/2018 0.50 PROD2 DRILL MPDA P Pull trip nipple and install RCD. 10,847.0 10,847.0 15:00 15:30 7/2/2018 7/2/2018 0.50 PROD2 DRILL CIRC P Pump 30 bbl 10.7 ppg slug @ 5 bpm, 10,847.0 10,847.0 15:30 16:00 1 1 11930 psi. 7/2/2018 7/2/2018 6.25 PROD2 DRILL SMPD P Strip outwith MPD from 10,847' MD to 10,847.0 2,006.0 16:00 22:15 2,006' MD holding 290 psi annular back pressure while pulling and 30 psi in slips. 7/2/2018 7/2/2018 0.25 PROD2 DRILL OWFF P OWFF- Static 2,006.0 2,006.0 2215 22:30 SIMOPS- PJSM on pulling RCD, installing trip nipple. Annulus 13=0 psi, Annulus C=75 psi @ 22:00 hrs. 7/2/2018 7/2/2018 0.50 PROD2 DRILL MPDA P Pull RCD, install trip nipple. 2,006.0 2,006.0 22:30 23:00 7/2/2018 7/2/2018 0.75 PROD2 DRILL TRIP P POOH on elevators from 2,006' MD to 2,006.0 771.0 23:00 23:45 771' MD. Calc Fill for trip=65 bbl, Actual Fill=84 bbl. 7/2/2018 7/3/2018 0.25 PROD2 DRILL OWFF P Monitor well @ HWDP for flow, slight 771.0 771.0 23:45 00:00 trickle, diminishing. 7/3/2018 7/3/2018 0.25 PROD2 DRILL OWFF P FIC (statc) - PJSM on UD BHA 771.0 771.0 00:00 00:15 7/3/2018 7/3/2018 2.25 PROD2 DRILL BHAH P UD kick off BHA as per Baker reps. 771.0 0.0 00:15 02:30 7/3/2018 7/3/2018 0.50 PROD2 DRILL BHAH P Clean & clear floor of BHA tools & 0.0 0.0 02:30 03:00 equipment. 7/3/2018 7/3/2018 3.75 PROD2 DRILL BHAH P WU 6" production RSS BHA as per 0.0 329.0 03:00 06:45 Baker eps to 329' 7/3/2018 7/3/2018 0.25 PROD2 DRILL TRIP P RIH 1/32910 420' 329.0 420.0 06:45 07:00 7/3/2018 7/3/2018 0.75 PROD2 DRILL SFTY P Install anti slip safety mats on rig floor. 420.0 420.0 07:00 07:45 713/2018 7/3/2018! 1.00 PROD2 DRILL TRIP P RIH f/420'to 2,231' 420.0 2,231.0 07:45 08:45 7/3/2018 7/3/2018 0.50 PROD2 DRILL DHEQ P Shallow hole test MWD tools w/200- 2,231.0 2,231.0 08:45 09:15 225 gpm 11060 - 1300 psi. 7/3/2018 7/3/2018 6.25 PROD2 DRILL TRIP P RIH f/2,231'to 8,560' (Culling DP as 2,231.0 8,560.0 09:15 15:30 needed) 7/3/2018 7/3/2018 0.50 PROD2 DRILL DLOG P Log RAtag f/8,560'to 8,622'7v/-2-20 8,560.0 8,622.0 15:30 16:00 gpm / 1980 psi. RA tag on depth 7/3/2018 7/3/2018 1.00 PROD2 DRILL TRIP P RIH f/8,622'to 10,813' 8,622.0 10,813.0 16:00 17:00 7/3/2018 7/3/2016 1.00 PROD2 DRILL SLPC P Slip & cut drill line. Calibrate block 10,813.0 10,813.0 17:00 18:00 height. 7/3/2018 7/3/2018 0.50 PROD2 DRILL SVRG P Service rig 10,813.0 10,813.0 18:00 18:30 7/3/2018 7/3/2018 0.50 PROD2 DRILL MPDA P Pull trip nipple & install RCD bearing 10,813.0 10,813.0 18:30 19:00 7/3/2018 7/3/2018 1.50 PROD2 DRILL DISP P Pump 75 bbls high vis sweep & 10,813.0 10,813.0 19:00 20:30 displace well to new 9.0 ppg OBM 7/3/2018 7/3/2018 0.50 PROD2 DRILL OWFF P Close chokes & monitor well for flow. 10,813.0 10,813.0 20:30 21:00 (Static) 7/3/2018 7/3/2018 0.50 PROD2 DRILL TRIP P RIH f/10,813'to 11,050'. No issues 10,813.0 11,050.0 21:00 21:30 across whipstock. 7/3/2018 7/3/2018 0.50 PROD2 DRILL REAM P W&R f/11,050'to 11,161'W/215 gpm / 11,050.0 11,161.0 21:30 22:00 1970 psi, 50 rpm / 5 k trq Page 41147 Report Printed: 7/1812018 Rig: DOYON 19 Job: DRILLING ORIGINAL Time Log - Start Depth Start Time End Time our fir) Phase pp Code Activity Code Time PT -X Operation (ftKB) Ee4 Depth(ftKB) 7/3/2018 7/4/2018 2.00 PROD2 DRILL DDRL P Drill ahead f/11,161'to 11,275' MD / 11,161.0 11,275.0 22:00 00:00 7,960' ND, ADT 1.1 Hrs, ECD 10.12 ppg, 215 gpm, 2060 psi, PU wt 190 k, SO wt 150 k, ROT wt 165 k, 90 rpm, 6/5 k trq, 7/4/2018 7/4/2018 12.00 PROD2 DRILL DDRL P Drill ahead f/11,276to 12,147' MD / 11,275.0 12,147.0 00:00 12:00 7,954' TVD, ADT 10.1 Hrs, ECD 10.38 ppg, 210 gpm, 2160 psi, PU wt 195 k, SO wt 138 k, ROT wt 165 k, 120 rpm, 7/5 k trq, 7/4/2018 7/5/2018 12.00 PROD2 DRILL DDRL P Drill ahead f/12,147' to 13,090' MD / 12,147.0 13,090.0 12:00 00:00 7,913' TVD, ADT 10 Hrs, ECD 10.52 ppg, 210 gpm, 2300 psi, PU wt 200 k, SO wt 140 k, ROT wt 165 k, 120 rpm, 7.5/6 k trq, 7/5/2018 7/5/2018 12.00 PROM DRILL DDRL P Drill ahead f/13,090' to 14,053' MD / 13,090.0 14,053.0 00:00 12:00 7,925' TVD, ADT 9.1 Hrs, ECD 10.88 ppg, 225 gpm, 2630 psi, PU wt 195 k, SO wt 130 k, ROT wt 160 k, 130 rpm, 8.6/7 k trq, 7/5/2018 7/6/2018 12.00 PROD2 DRILL DDRL P Drill ahead f/14,053'to 15,004' MD / 14,053.0 15,004.0 12:00 00:00 7,884' TVD, ADT 10 Hrs, ECD 11.23 ppg, 220 gpm, 2740 psi, PU wt 200 k, SO wt 125 k, ROT wt 162 k, 130 rpm, 9.5/7 k trq, 7/6/2018 7/62018 2.25 PROD2 DRILL DDRL P Drill ahead (/15,004' to TD of 15,195' 15,004.0 15,195.0 00:00 02:15 MD / 7,888' TVD, ADT 1.9 Hrs, ECD 11.14 ppg, 220 gpm, 2770 psi, PU wt 200 k, SO wt 125 k, ROT wt 158 k, 130 rpm, 9/7.5 k trq, 7/6/2018 7/6/2018 0.25 PROM CASING CIRC P Pump up final survey & obtain torque 15,195.0 15,195.0 02:15 02:30 and drag parameters. 7/6/2018 7/6/2018 2.00 PROD2 CASING CIRC P Circ 2 B/U w/220 gpm / 2770 psi, 130 15,195.0 15,004.0 02:30 04:30 rpm 17.5 k trq. Racked back 1 stand per B/U 7/6/2018 7/6/2018 0.25 PROD2 CASING OWFF P Perform formation draw down. Rotate 15,004.0 15,004.0 04:30 04:45 15 rpm. No psi increase (static) 7/6/2018 7/6/2018 3.00 PROD2 CASING CIRC P Wt up to 9.3 ppg w/220 gpm / 2700 - 15,004.0 14,909.0 04:45 07:45 2860 psi, 130 rpm / 7 k trq. Racked back 1 stand. 7/6/2018 7/6/2018 0.25 PROM CASING OWFF P Rotate 15 rpm & F/C (static). Line up 14,909.0 14,909.0 07:45 08:00 to Strip OOH 7/6/2018 7/6/2018 5.00 PROD2 CASING SMPD P Strip OOH as per MPD schedule 14,909.0 10,813.0 08:00 13:00 f/14,909'to 10,813'. No issues pulling BHA thm window. 7/6/2018 7/6/2018 1.00 PROD2 CASING CIRC P Circ 6/U w/220 gpm / 2320 psi, 80 . 10,813.0 10,813.0 13:00 14:00 rpm / 4.5 k trq. 7/6/2018 7/6/2018 0.50 PROD2 CASING OWFF P F/C (static) 10,813.0 10,813.0 14:00 14:30 7/6/2018 7/6/2018 6.50 PROD2 CASING SMPD P Strip OOH as per MPD schedule 10,813.0 1,278.0 14:30 21:00 f/10,813'to 1,278' 7/6/2018 7/6/2018 0.50 PROD2 CASING OWFF P F/C (static) -SIMOPS clean floor 1,278.0 1,278.0 21:00 21:30 7/6/2018 7/6/2018 0.50 PROD2 CASING MPDA P Pull RCD bearing & install trip nipple. 1,278.0 1,278.0 21:30 22:00 7/6/2018 7/6/2018 1.00 PROD2 CASING TRIP P POOH f/ to 1,278'to 329' 1,278.0 329.0 22:00 23:00 7/6/2018 7/6/2018 0.25 PROD2 CASING OWFF P F/C (static) 329.0 329.0 23:00 23:15 716/2018 7/7/2018 0.75 1 PROD2 CASING TRIP P POOH f/329'to 143'. UD jar stand 329.0 143.0 23:15 00:00 I 7/7/2018 7/7/2018 2.00 PROD2 CASING BHAH P PJSM. Remove sources & UD BHA as 143.0 0.0 00:00. 02:00 I per Baker reps. Page 42147 Report Printed: 7/18/2018 MT6-05 r Rig: DOYON 19 Job: DRILLING ORIGINAL Time Log Start Depth Start Time End Time our (hr) Phase Op Code Activity Code Time P -T -X Operation (flKB) End Depth(WEI) 7/7/2018 7/7/2018 1.00 PROD2 CASING SHAH P Clean & Gear floor 0.0 0.0 02:00 03:00 7/7/2018 7/7/2018 1.00 COMPZ2 FISH SHAH P Cont. to clean & clear floor. Mobilize 0.0 0.0 03:00 04:00 BHAIo rig floor. 7/7/2018 7/7/2018 1.50 COMPZ2 FISH BHAH P M/U whipstock retrieval BHA as per 0.0 241.0 04:00 05:30 Baker reps. 7/7/2018 7/7/2018 1.50 COMPZ2 FISH TRIP P RIH f/241'to 2,144' 241.0 2,144.0 05:30 07:00 7/7/2018 7/7/2018 0.50 COMPZ2 FISH DHEQ P Shallow hole test MWD w/180 gpm / 2,144.0 2,144.0 07:00 07:30 680 psi 7/7/2018 7!7/2018 6.00 COMPZ2 FISH TRIP P RIH f/2,144'to 10,726' 2,144.0 10,726.0 07:30 13:30 7/7/2018 7/7/2018 0.25 COMPZ2 FISH OWFF P FIC (static) 10,726.0 10,726.0 13:30 13:45 7/7/2018 7/7/2018 0.50 COMPZ2 FISH MPDA P Pull trip nipple & install RCD bearing 10,726.0 10,726.0 13:45 14:15 7/7/2018 7/7/2018 0.50 COMPZ2 FISH WASH P Wash down f/10,726' to 10,949'w/180 10,726.0 10,949.0 14:15 14:45 gpm / 1400 psi. Orient jet to wash whipstock slot. PU wt 185 k / SO wt 145 k 717/2018 7/7/2018 1.00 COMPZ2 FISH FISH P Orient latch to whipstock slot. Latch up 10,949.0 10,917.0 14:45 15:45 on whipstock. Attempt to straight pull. No success. Set down 10 k WOB & cock jars. P/U to 225 k & fire jars. Ad Attempt to straight pull. No success. p5 Set down 10 k WOB & cock jars. P/U to 250 k & fire jars. Straight pull to 285 n k & release anchor. Pull whipstock i free to 10,917' 7/7/2018 7/7/2018 1.25 COMPZ2 FISH CIRC P Circ B/U w/180 gpm / 1440 psi. 10,917.0 10,917.0 15:45 17:00 7/7/2018 7/7/2018 0.25 COMPZ2 FISH OWFF P F/C (static) 10,917.0 10,917.0 1700 17:15 7/7/2018 7/8/2018 6.75 COMPZ2 FISH SMPD P Strip OOH as per MPD schedule 10,917.0 4,235.0 17:15 00:00 f/10,917' to 4,235' 7/812018 7/8/2018 2.25 COMPZ2 FISH SMPD P Strip OOH as per MPD schedule 4,235.0 1,859.0 00:00 02:15 f/4,235'to 1,859 7/8/2018 7/8/2018 0.25 COMPZ2 FISH OWFF P FIC (static) PJSM on MPD 1,859.0 1,859.0 02:15 02:30 7/8/2018 7/8/2018 0.50 COMPZ2 FISH MPDA P Pull RCD bearing & install trip nipple. 1,859A 1,859.0 02:30 03:00 7/8/2018 7/8/2018 1.00 COMPZ2 FISH TRIP P POOH f/1,859'to 337' 1,859.0 337.0 03:00 04:00 7/8/2018 7/8/2018 3.00 COMPZ2 FISH SHAH P L/D whipstock retrieval BHA & 337.0 0.0 04:00 07:00 whipstock. 7/8/2018 7/8/2018 3.00 COMPZ2 FISH SHAH P Clean & clear rig floor of OBM & BHA 0.0 0.0 07:00 10:00 tools & equipment. UD 1 stand of 15.7# DP & P/U 1 stand of HWDP. 7/8/2018 7/8/2018 2.25 COMPZ2 CASING RURD P R/U to run liner. R/U power tongs, 4- 0.0 0.0 10:00 12:15 1- 1/2" slips & elevators. M/U safety XO. 7/8/2018 7/8/2018 6.75 COMPZ2 CASING PUTS P P/U & RIH 4-1/2" 12.6# L-80 TXP liner 0.0 4,081.0 12:15 19:00 to 4,081'. (98 Its liner & 15 pert pups) 7/8/2018 7/8/2018 1.75 COMPZ2 CASING OTHR P M/U SLB slim hole MWD tools & 4,081.0 4,121.0 19:00 20:45 Baker hook hanger assembly & liner running tools to 4,121'. (MWD offset 266°) PU wt 100 k / SO wt 95 k 7/8/2018 7/8/2018 1.00 COMPZ2 CASING RUNL P RIH w/4-1/2" liner on DPf/4,121'to 4,121.0 5,547.0 20:45 21:45 5.547' 7/8/2018 7/8/2018 0.50 COMPZ2 CASING DHEQ P Shallow hole test MWD tools w/100 5,547.0 5,547.0 21:45 22:15 gpm / 600 psi 7/812018 7/9/2018 1.75 COMPZ2 CASING RUNL P RIH w/4-1/2" liner on DP f/5,547'to 5,547.0 8,879.0 22:15 00:00 1 18,8791 Page 43147 Report Printed: 7/18/2018 MT6-05 i Rig: DOYON 19 Job: DRILLING ORIGINAL Time Log- - - "i - Start Depth _Slat, Time _Entl Time Dur (hr) Phase Op Code Acpvtty Cotle TmePTX Opemfon. (ftK9) End Depth(ftKB) 7/9/2018 7/9/2018 1.50 COMPZ2 CASING RUNL P RIH w/4-1/2" liner on DP f/8,879'to 8,879.0 10,939.0 00:00 01:30 10,939' 7/9/2018 7/9/2018 1.00 COMPZ2 CASING RUNL P Attempt to run liner out window. Stack 10,939.0 11,069.0 01:30 02:30 out on top of lower liner top @ 11,034'. Pick up to above window & apply 3/4, turn & work down. Attempt to run liner out window. Stack out on top of lower i liner top @ 11,034'. PIU & place liner shoe across window. Rotate liner w15 rpm & observe trq spike of 4.3 k when liner shoe bumps window. Release torque & slack off to 11,069'& confirm liner exited window. 7/9/2018 7/9/2018 3.50 COMPZ2 CASING RUNL P RIH w/4-1/2" liner on DP f/11,069'to 11,069.0 15,039.0 02:30 06:00 15,039'. PU wt 225 k / SO wt 150 k 7/9/2018 7/9/2018 3.25 COMPZ2 CASING HOBO P Orient hook hanger to high side& 15,039.0 10,934.0 06:00 0915 slack off past bottom of window. Pick up hook to above window. Orient hook to low side. SIO and hang hook on window with 30 k WOB. Repeat twice IiJ6- & confirm hook on window. Drop V 29/32" ball & pump down w/2.8 bpm / h�y�v S 1290 psi, slow pumps to 1 bpm 1550 f psi. Ball on seat w/95 bbls. Pressure up to 3500 psi & release from hook hanger assy as per Baker rep. Blow ball seat. Top of hook assy @ 10,934.82' 7/9/2018 7/9/2018 1.00 COMPZ2 WELLPR TRIP P POOH f/10,934'to 10,855'. Observe 10,934.0 10,795.0 09:15 10:15 swabbing. Pump OOH f/10,855'to 10,795' Discuss options with town 7/9/2018 7/9/2018 0.25 COMPZ2 WELLPR OWFF P F/C(static) 10,795.0 10,795.0 10:15 10:30 7/9/2018 7/9/2018 1.00 COMM WELLPR SLPC P Slip & cut 58' drill line. SIMOPS - circ 10,795.0 10,795.0 10:30 11:30 & cond mud w/3 bpm 1830 psi 7/9/2018 7/9/2018 1.00 COMPZ2 WELLPR SVRG P Service rig, top drive & draw works. 10,795.0 10,795.0 11:30 12:30 SIMOPS - circ & cond mud w/3 bpm 1 830 psi 7/9/2018 7/9/2018 0.25 COMPZ2 WELLPR SLPC P Calibrate block hight 10,795.0 10,795.0 12:30 12:45 7/9/2018 7/9/2018 0.50 COMPZ2 WELLPR OWFF P FIC (static) 10,795.0 10,795.0 12:45 13:15 7/9/2018 7/9/2018 1.00 COMPZ2 WELLPR TRIP P Attempt to POOH f/10,795'to 10,611'. 10,795.0 10,611.0 13:15 14:15 Observe swabbing. Discuss options with town. Decision made to displace to brine. 7/9/2018 7/9/2018 0.75 COMPZ2 WELLPR TRIP P RIH f/10,61 Vto 10,850' 10,611.0 10,850.0 14:15 15:00 7/9/2018 7/9/2018 1.50 COMPZ2 WELLPR RURD P Clean pits, pipe racks & rig floor in 10,850.0 10,850.0 15:00 16:30 preperation for displacement. Build brine segregation pill. 7/9/2018 7/9/2018 1.00 COMPZ2 WELLPR DISP P Spot 20 bbl OBM / brine segregation 10,850.0 10,750.0 16:30 17:30 pill f/10,850'to 10,750'w/3 bpm / 820 psi. 7/9/2018 7/9/2018 3.50 COMPZ2 WELLPR DISP P Pump 59 bbl 10.45 ppg spacer, 31 bbl 10,750.0 10,750.0 17:30 21:00 deep clean spacer, 38 bbl high vis spacer & displace well to 9.2 ppg brine w/3 - 3.5 bpm 1820 - 400 psi. 7/9/2018 7/9/2018 0.50 COMPZ2 WELLPR OWFF P F/C (static). SIMOPS -Clean under 10,750.0 10,750.0 21:00 21:30 shakers after displacement. 7/9/2018 7/9/2018 0.50 COMPZ2 WELLPR RURD P Cont. to clean under shakers after 10,750.0 10,750.0 21:30 22:00 1 displacement. 7/9/2018 7/10/2018 2.00 COMPZ2 WELLPR TRIP P POOH 1/10,750' to 9,155'. PU wt 180 k 10,750.0 9,155.0 22:00 00:00 1 Page 44147 Report Printed: 7118/2018 MT6-05 Rig: DOYON 19 Job: DRILLING ORIGINAL Time Log start Depth StartTime End Time Dur(hr) Phase Op Code Achvity Code Time P -T -X Operation (MB) End Depth (WB) 7/10/2018 7/10/2018 6.50 COMPZ2 WELLPR TRIP P POOH f/9, 155'to 102' . 9,155.0 102.0 00:00 06:30 7/10/2018 7/10/2018 1.00 COMPZ2 WELLPR SHAH P UD liner running tools & slim pulse 102.0 0.0 06:30 07:30 tools. 7/10/2018 7/10/2018 0.50 COMPZ2 WELLPR SHAH P Clean & clear floor of BHA tools & 0.0 0.0 07:30 08:00 equipment. 7/10/2018 7/10/2018 1.00 COMPZ2 RWRID RURD P R/U to run LEM. R/U power tongs, 4- 0.0 0.0 08:00 09:00 1/2" slips & elevators. M/U safety XO. 7/10/2018 7/10/2018 1.75 COMPZ2 RWRID SHAH P M/U seal assy, LEM, & ZXP w/SLB 0.0 247.0 09:00 10:45 slim pulse to 247' (MWD offset 116°, LEM high side) 7/10/2018 7/10/2018 1.25 COMPZ2 RWRID TRIP P RIH w/LEM assy 1/247'to 2,149' 247.0 2,149.0 10:45 12:00 7/10/2018 7/10/2018 0.50 COMPZ2 RWRID DHEQ P Shallow hole test MWD tools w/100 2,149.0 2,149.0 12:00 12:30 gpm / 250 psi 7/10/2018 7/10/2018 1.00 COMPZ2 RWRID TRIP P RIH w/1 -EM assy f/2,149'to 4,243' 2,149.0 4,243.0 12:30 13:30 7/10/2018 7/10/2018 0.50 COMPZ2 RWRID SVRG P Service rig & iron roughneck 4,243.0 4,243.0 13:30 14:00 7/10/2018 7/10/2018 5.25 COMPZ2 RWRID TRIP P RIH w/LEM assy f/4,243'to 11,004' 4,243.0 11,004.0 14:00 19:15 7/10/2018 7/10/2018 0.75 COMPZ2 RWRID CIRC P Break circ w/100 gpm 1500 psi. Orient 11,004.0 11,004.0 19:15 20:00 LEM 28" left. 7/10/2018 7/10/2018 0.25 COMPZ2 RWRID HOSO P Wash down w/100 gpm / 500 psi 11,004.0 11,049.0 20:00 20:15 f/11004' to 11,049'. Set 30 k WOB & latch up LEM to hook. PIU to 215 k & slack off to 35 k WOB & confirm latch. 7/10/2018 7/10/2018 0.50 COMPZ2 RWRID PACK P Drop 1.625" ball & pump down w/2.6 - 11,049.0 11,049.0 20:15 20:45 2 bpm 1500 - 300 psi. Ball on seat @ 77 bbls. Pressure up to 2500 psi to set packer & hold for 5 min. Increase psi Ito 3560 psi & observe rod shift. 7/10/2018 7/10/2018 2.50 COMPZ2 RWRID PACK T R/U & attempt to pressure test packer. 11,049.0 11,049.0 20:45 23:15 Start pressuring up & at 1000 psi it appears we are injection fluid and not building anymore pressure. Packer appears to not be set. Check all surface equipment & perform 2000 psi -pressure lest on surface (good). Attempt to pressure test packer again with same result. Manually attempt to set packer without rotation. Attempt to pressure test again without success. Discuss options with town. Manually attempt to set packer & saw a second shift & packer appeared to set. 7/10/2018 7/10/2018 0.50 COMPZ2 RWRID PRTS P Pressure test packer to 3000 psi & 11,049.0 10,814.0 23:15 23:45 chart for 10 min (good). 7/10/2018 7/11/2018 0.25 COMPZ2 RWRID TRIP P POOH to above packer sealbore to 10,814.0 10,759.0 23:45 00:00 10,759' (Top of sealbore @ 10,813.94') 7/11/2018 7/11/2018 1.75 COMPZ2 RWRID CIRC P Circ B/U 2.5 - 4 bpm / 250 - 530 psi. 10,759.0 10,759.0 00:00 01:45 7/11/2018 7/11/2018 0.25 COMPZ2 RWRID OWFF P FIC (static) 10,759.0 10,759.0 01:45 02:00 7/11/2018 7/11/2018 11.00 COMPZ2 RWRID P P POOH & UD DP f/10,759'to 86. 10,759.0 86.0 02:00 13:00 (Culled out bad jls of pipe) 7/11/2018 7/11/2018 1.00 COMPZ2 RWRID SHAH P UD Baker running tools & SLB slim 86.0 0.0 13:00 14:00 pulse MWD. Clean & clear floor. 7/11/2018 7/11/2018 0.75 COMPZ2 WHDBOP WWWH P Flush stack w/deep clean. 0.0 0.0 14:00 14:45 Page 46147 ReportPrinted: 7/18/2018 MT6-05 Rig: DOYON 19 Job: DRILLING ORIGINAL Time Log - - - Start Depth Slate Time End Time our(hr)- Phase Op Cotle Adivlty Cotle TimePT-X. -'_ Operation (01<8) End Depth(@KB) 7/11/2018 7/11/2018 1.25 COMPZ2 WHDBOP RURD P Pull wear ring& set test plug as per 0.0 0.0 14:45 16:00 FMC. R/U to lest BOPE. fill stack w/H20 & purge lines. 7/11/2018 7/11/2018 6.25 COMPZ2 WHDBOP BOPE P Test BOPE 250/3500 for 5/10 min's 0.0 0.0 16:00 22:15 w/4" & 4-1/2" test joints. Annular, 4" Demoo, Choke valves 1 - 14; BOP's, Choke needle valve, Upper 4-1/2" X 7" VBR's, lower 3-1/2" X 6" VBR's & blind rams, 4" DarUFOSV, HCR / Man choke/kill, Accumulator test, Initial 3100 psi, final 1450 psi, tat 200 psi recharge = 29 sec's, full recharge = 149 second. 4 bottles @ 2250 psi. Gas alarms, PVF alarms and flow indicated tested. Draw down on (lX H manual & super choke. AOGCC Matt t�Z Herrera & BUM Mutasim Elganzoory 11 waived witness via email. 7/11/2018 7/11/2018 0.50 COMPZ2 WHDBOP RURD P RID testing equipment & B/D lines. 0.0 0.0 2215 22:45 Pull test plug. 7/11/2018 7/12/2018 1.25 COMPZ2 RPCOMP RURD P R/U to run completion. R/U power 0.0 0.0 22:45 00:00 tongs, tubing slips & elevators. RIU Cameo control line. 7/12/2018 7/12/2018 1.25 COMPZ2 RPCOMP RURD P Cont. to R/U to run completion. R/U 1- 0.0 0.0 00:00 01:15 wire sheaves. Bring cannon clamps to floor. 7/12/2018 7/12/2018 16.25 COMP7_2 RPCOMP RCST P RIH 4-1/2" 12.6# L-80 Hyd 563 upper 0.0 10,763.0 01:15 17:30 completion to 10,763' PU wt 157 k / SO wt 131 k 7/12/2018 7/12/2018 1.75 COMPZ2 RPCOMP HOSO P M/U space out its. R/U head pin & 10,763.0 10,763.0 17:30 19:15 break circ w/1 bpm @ 40 psi. Wash in hole & observe psi increase once seals in seal bore. Shut down pumps & cont to RIH & no-go out w/10 k WOB @ 10,822.62'. POOH & L/D space out jts. 7/12/2018 7/12/2018 1.75 COMPZ2 RPCOMP THGR P M/U space out pups & M/U hanger. 10,763.0 10,805.0 19:15 21:00 M/U landing it A. Terminate I wire & pressure test fitting to 5000 psi. RIH w/hanger to 10,805' (seal assy 2' above seal bore) 7/12/2018 7/12/2018 1.50 COMPZ2 RPCOMP- CRIH P Pump 25.5 bbls CI brine & chase 10,805.0 10,805.0 21:00 22:30 w/160 bbls 9.2 brine w/4.5 bpm / 400 psi. (20.5 bbls Cl brine outside pipe & 5 bbls inside). SIMOPS - R/D & UD Camco equipment. 7/12/2018 7/12/2018 0.25 COMPZ2 RPCOMP OWFF P F/C (static) 10,805.0 10,805.0 22:30 22:45 7/12/2018 7/1312018 1.25 COMPZ2 RPCOMP THGR P RIH & land on hanger @ 10,818.65'. 10,805.0 10,818.0 22:45 00:00 (3.97' from fully located). Remove blind flange & verify alignment. RILDS. Test hanger seals 250 psi / 5 min & , 5000 psi / 10 min on chart. 7/13/2018 7/13/2018 0.50 COMPZ2 RPCOMP THGR P Cont. to test hanger seals 5000 psi / 0.0 0.0 00:00 80:30 10 min on chart. 7/13/2018 7/13/2018 3.25 COMPZ2 RPCOMP PRTS P R/D head pin. Drop ball & rod. R/U 0.0 ,( 0.0 00:30 03:45 head pin. Test surface lines to 3800 / 1 psi (good). Test tubing to 3500 psi & A chart for 30 min (good). Bleed down 'T� tubing to 2000 psi. Test IA to 3300 psi / & chart for 30 min (good). Bleed off pressure. Pressure up on IA & shear SOV @ 1800 psi. Break circ w/1 bpm @ 430 psi. Page 46/47 ReportPrinted: 7/18/2018 MTI Rig: DOYON 19 Job: DRILLING ORIGINAL Time Log Start Depth Slad Time End nine Dur(ho Phase Op cede Activity Cede Time P -T -X Operation (MS) End Depth(flKB) 7/13/2018 7/13/2018 0.50 COMPZ2 RPCOMP RURD P RID cement hose. B/D lines & UD 0.0 0.0 03:45 04:15 landing jointA 7/13/2018 7/13/2018 0.50 COMPZ2 RPCOMP OWFF P Fill stack w/1-420 & F/C for 30 min 0.0 0.0 04:15 04:45 (static). SIMOPS - UD power tongs 7/13/2018 7/13/2018 1.00 COMPZ2 RPCOMP MPSP P Install HP-BPV Install landing joint B. 0.0 0.0 04:45 05:45 Test in direction of flow 2500 psi for 15 min (good). UD landing joint B 7/13/2018 7/13/2018 0.50 COMPZ2 RPCOMP OWFF P F/C for 30 min (static). SIMOPS - C/O 0.0 0.0 05:45 06:15 elevators. M/U stack washer. 7/13/2018 7/13/2018 0.50 COMPZ2 RPCOMP WWWH P Flush stack. UD stack washer. 0.0 0.0 06:15 06:45 7/13/2018 7/13/2018 0.75 COMPZ2 RPCOMP RURD P B/D lines. B/D choke. UD excess 0.0 0.0 06:45 07:30 completion tools from rig floor/ UD (- wire spool. 7/13/2018 7/13/2018 6.25 COMPZ2 WHDBOP NUND P Remove trip nipple & floor plates. 0.0 0.0 07:30 13:45 Clean drip pan & flow box. N/D flow line, flow box, Katch Kan & MPD valves. 7/13/2018 7/13/2018 2.75 COMPZ2 WHDBOP NUND P Break ram doors for BWM. Remove 0.0 0.0 13:45 16:30 kill & choke lines. N/D BOPE & rack back on pedestal. SIMOPS - C/O saver sub on top drive. 7/13/2018 7/13/2018 1.75 COMPZ2 WHDBOP NUND P SLB terminale I -wire through tree. 0.0 0.0 16:30 18:15 FMC install smooth bore metal seal. Install test dart in BPV profile. 7/13/2018 7/13/2018 1.25 COMPZ2 WHDBOP NUND P NIU tree adaptor. Unable to seat 0.0 0.0 18:15 19:30 properly. P/U jt HWDP & set down w/14 k WOB to seat. Secure flange. 7/13/2018 7/13/2018 2.00 COMPZ2 WHDBOP PRTS P FMC test flange to 5000 psi (good). 0.0 0.0 19:30 21:30 Fill tree w/diesel & test 250 & chart for 10 min. (Downhole readings f/Camco = 3779 psi @ 174°F) 7/13/2018 7/13/2018 1.00 COMPZ2 WHDBOP PRTS T Attempt to test tree to 5000 psi. Fluid 0.0 0.0 21:30 22:30 leaking from test hose fitting. C/O fitting. Test tree to 5000 psi & chart for 10 min. (good) 7/13/2018 7/13/2018 0.50 COMPZ2 WHDBOP MPSP P FMC pull dart from BPV. Secure well. 0.0 0.0 22:30 23:00 Tubing, IA, IOA, = 0 psi. OA= 75 psi. (Little red will FP off-line once rig is -. moved) 7/13/2018 7/13/2018 0.50 DEMOB MOVE RURD P Clean misc tools & equipment from 0.0 0.0 23:00 23:30 cellar. Set 90' mouse hole. R/U to UD DP 7/13/2018 7/14/2018 0.50 DEMOB MOVE PULD P UD 5 stands 4" DP racked back in 0.0 0.0 23:30 00:00 derrick via 90' mouse hole. 7/14/2018 7/14/2018 7.75 DEMOB MOVE PULD P UD 81 stands 4" DP racked back in 0.0 0.0 00:00 07:45 derrick via 90' mouse hole. 7/14/2018 7/14/2018 0.50 DEMOB MOVE RURD P C/O handle equipment to 5". Pull 0.0 0.6- 07:45 08:15 mouse hole. 7/14/2018 7/14/2018 3.75 DEMOB MOVE RURD P Clean& clear rig floor & cellar. Prep for 0.0 0.0 08:15 12:00 move. Move away ball mill 8:45 Hrs. Move away pits/motors complex 10:30 Hrs. Rig released 12:00 Hrs Page 47147 Report Printed: 7/78/2018 Baker Hughes INTEQ El s Fs O ConocoPhilli p Definitive Survey Report Company; ConacoPhillips Export Company Local Coordinate Reference: Well MT6-05 Protect: Western Nodh Slope TVD Reference: Actual MT6-05@88]Ousfl(AcIual D19) li She: GMT1 Lookout Pad MD Reference: Actual MT645 @ 88.70ush (Actual D19) Well; Ml North Reference: True Wellbore: MT6 501 Upper Lot Survey Calculation Method: Minimum Curvature Design: MT6-05 ml Drah1 Database: OAKEDMP2 Pmlect Westem Noah Slope, Noah Slope Alaska, Unned States Map System: US Slate Plane 1927 (Exact solution) System Datum: Mean Seo level Geo Datum: NAD 1927(NADCON GOMIS) . Map Zone: Alaska Zone 04 Using gaadefc scale factor Well MTeLS Well Position sW45 000 ush Northing: 5,945,543.]9u it Lathude: 70° 15, 22+954 N +&V 000 ush Fasting: 317,D59.911usq Lo"Iftel: 151°20'42.g3oW Position Uncertainty 0.00 usfi Wellhead Elevation: 0.00u58 Gmand Linked; 3].20 usll Wellbore MT6-USLI_Upper Lal ' Magnetics Medal Name Sample Dox DadinMbn OWA"* Field Wine lh M I°I bTl BGGM2017 512W2018 16.50 110]2 57,422 Dea MT"6L1 Audi' Net.: Version. 1.0 Phase: ACTUAL Tie On Depth: 10.933.50 Kr11Gl Sado Depth From IM) ♦Nld eEFM Direction (-am (aloft) (-am M ON 0.00 9.aB 320.46 MR0/B 11:08:31AM Pape 2 COMPASS 5000, N appeal 85 Baker Hughes INTEQ ConocoPhillips Definitive Survey Report Company: ConocDPhlll'Ipe EKpon Company Local Co-ordinate Renitence: OMI MT&05 Prolecn Menem North Slope TVD Reference: Actual MT6-05 C 80.70usR (Actual D19) she. GMTt Lookout Pad MO Retarence: Actual MT645@ 30.70usn(Actual D19) Well: MT6-05 North Reference: Tui WellOort: MTS-051_1_Upper Lat Survey Calculation Method Minimum Curvature Design: MTE-05 wp10 Dra81 Damnna,4 OAKEDMP2 Survey Program Doompdon Data Fre. To MVV0HFRAKCAZSCC (it") (diel Sun'(Wellbort) i 6036 263.26 GYD Gym DMS i6" (MT6-05PB1) 296,26 1,957.96 BHGE MVNNFR+MSA 16"(MT6-05PB1 2,050.54 8094.81 BHGE MWD+IFR+MSA 12-114"(MT645 8963.80 10933.50 BHGE MWD+IFR+MSA 8x84314-(MT6-0 16,939,00 11,114,28 BHGE MWD INC b'(MTB-05L1_UPperL 11,16596 15,165,21 BHGE MVVD+IFR+MSA&"(MT6-05L1_U Survey Tool Na.a Doompdon GYD-CT-0MS Carmine conttled,de Ma MWD+IFR-AK-CAZSC MVV0HFRAKCAZSCC MWD+IFR-AK-0 4IC MWD+IFR AK CAZ SCC MWDHFR-AK-CAZSC MWD+IFR AK CAZ SCC MP INQONLY(INC>10-) MWD-INQONLY_FILLER (INCND°) MWD+IFR-AK-GAZSC MVlD+IFR AK CAZ SGC im Survey Survey San new End read 5/1312018 51132018 5/15(2018 Map Map MD Im kal M TVOSS +W4 +em Noshing Fasting Ol8 (UM (*I 1'1 luau l u I ail Idem Iden) RI) (e) (.11w) 36.50 COO DO] 39.0 _5220 oDo O.Oo _59+_5.543.79 317059.90 0.00 son 033 23164 604 -28.44 -004 -0.05 5,945,50.1.]5 317,059.93 1.39 16178 0.36 194,30 161,76 73.05 4,53 -0.36 5,94554337 317,059.61 am 26326 Om 211.]2 283.25 174.65 -1.26 1.70 5.945542.54 317,058.25 0.24 256.26 0.% 2200 29535 20755 -160 489 5,945,54222 317,05896 131 39015 134 252.95 383.13 301.43 146 -250 5.845.54140 31]05].42 OA4 48351 222 281.97 483.44 394.74 208 4..15 5,945,54184 317,054.79 1.58 577.56 3.84 299.00 SP.36 4118,66 0.13 -9.59 5.945.544.16 317,050.40 1.76 672.51 546 30335 67199 SLU.'b 4.17 A.A. 594554835 317,043.93 177 7%96 TOG 304.80 76499 6TSM 8.60 -N57 5,94555425 317,035m 163 860.61 803 30569 me.C, 770.02 1711 54.60 5,945,561]3 317.025.81 1.12 95524 B95 30734 952,31 863.61 25.53 46.76 5,945,57042 317,014.85 0.99 1,048.71 10.56 ".87 1,044.50 95580 35.08 57.81 5.90.5.itl.S 317,00294 123 1,143.88 11.57 356.2 1,13797 1,049.27 46.36 -71.77 5,945,0tM 316.569.36 157 1,Maim 1285 310.56 11230.19 1,141.0 5.31 47.07 5,945,605.19 316.97439 1.0 1,332.92 14A3 3100 1322.1 1233,52 73.77 -10106 5,945,62006 316,957,95 125 1.42745 14.70 WaM 1,413.78 1,32508 8865 -12200 5945.635.38 31694010 089 1521.38 1539 30.44 1,501.49 1415]8 103.23 -14162 5945.60,42 316,92081 1.03 im Survey Survey San new End read 5/1312018 51132018 5/15(2018 51212018 6142018 7/1012018 7nono18 I Vertical sudden survey Tool came Annotation ml 090 UNDEFINED O.CO GYDCT-0MS(1) -0018 GYDCT-0M6(1) 453 GYDLT-0MS(]) -0.61 MhD+IFR-N4CAZSC(2) 430 MWD+IFR-AKLAZSC(2) 167 MWDHFR-AKLAZSO(21 821 MWDHFR- CAZSC(2) 13.50 MVAD IFR-. CAZAC(2) 23.26 M✓uDHFR-N4CAZSC(2) 35,22 MWD+IFR- CAZSC(2) 48.82 MWDHFRrixCAZSC(2) 6382 MWDHFR✓J(CAZSC(2) 51.45 NNVDHFR-PI(-CAZ41C(2) 101.16 MNpHFR-AKCAZSC 2) 123.01 MW)HFR-AKCAZSC(2) 1460 MWDHFRAK( AZSC(2) 16977 MWDHFR-AKCPL5C(2) BHROfB 11:OB:3fAM P4ipe 3 COMPASS 5000 t4 Solltl BS Co)Iocl3kil (p5 Baker Hughes INTEQ Definitive Survey Report O CompaM/: _CoromPhi9lps Export Company Local Coordinate Reference: Well MT6-D5 Protean Modem NonE Slope TVD Reference: Actual MT"S ® 66.70usfl (Actual 019) See: GMT1 Lookout Pad MD Reference: Actual MTB -05 ® 88.70usR (Actual D19) Well: MT13-05 North Reference: True Wellbore: MT6-05L1 Upper Lot Survey Calculation Method: Minimum Curvatura 3esl9m MT6-05 w,10 Dmf11 Database: OAKEDMP2 Survey MBP Map Vertical MD (.1,11 ledqa (1 V) TVO ("am 711089 (1.D) 4NFd (U-111 4FJ-W ideal Names Eastin9 OLS 111007 Section Survey Tool NBmm Annotation DI IDI DI 1.81809 1491 301,% 1.5101.68 1,50].90 11762 -16202 5945,665.33 316900.80 0.52 193.85 MWOHFRAKLPZSC (21 1.710.53 15.15 3(15.9] 1607 11 1,595.41 131.71 -081.79 5,9456]8.8] 316.08146 0.38 217.30 MWD-IFR--CAZ£C(2) 1.8115]] 18.55 305.15 1.778,73 1.890.03 14TW 4UP82 5,9456195.69 316,�.W 1AS 242.51 MM19NFR- -CAZ C(2) 1,01919.91 16.01 307.55 1068.62 1]]8.92 161,62 -225.19 5945,71&02 316,&14&5 1.60 26968 NWDrIFRA -CA C(2) 185795 1&63 301111 1823.69 1830.199 lMd7 -23966 5,945,]241]2 316,02464 1.44 28759 Mvootl -AK-0A25C(2) 2,014.00 1929 30793 1,918,68 1.87.6 18.34 350.8 5,945.736,21 316610.51 0.83 305.45 MNDgFR A CAZdC (3) 13-316' x 16- 6"2650.54 2 00.5it 18.59 30282 2,011.12 1,922.42 193.81 -263.00 5.915.743.81 311 08 31T.33 MND+IFR-P14U C(3) j 2089.62 2031 30]93 2,04]]1 1859.07 201.08 37416 5,945,752.33 316.790.02 1.59 330.26 MWDNFR-NI-0AZSC(3) 2163.13 M.W 30&82 2135.47 2046," 223.5 501,15 5.945 774.29 316,]61.3] 255 36&69 MWDHFR-AK .SC (3) 2,270.30 25.5 Week) 2,221.92 2133.22 247.18 531.10 5,945,]98,93 316,735.00 2.78 401At L4WDHFR.AKCAZSC(3) 2.3840 2&n 308.00 2300.51 2.21781 2]2.]4 161 5,945,65.5 318.703.30 1.80 44170 MWD+IFRAK-CAZSC(3) 2.457.33 WAS 3011.76 2,391.02 2.302.32 229.60 -391 5945.85291 316.6"10 085 40390 NVV[)+l N(LAZSC(3) 2.559,45 29.82 300,63 2,4]1.0] 2,383,17 35.59 <3225 5,941 316635.02 260 527.02 MAIDNFR-AK-0AZSO(3) j 2651.10 30.8 36.47 2,550,9] 2,46227 35415 -089.44 5,945909.21 316,58932 1.14 57195 MAt).lFR-0KCAZSC(3) 2,]44.]1 31.74 307.31 2.83095 2,542.25 30334 50833 5,945.939.31 316.561.15 1.00 61824 MMD+1FRAK-C L C(3) ! 2.009.18 3222 30]]4 271107 2,521.3] 413.81 34&6 5,845.870,76 316,92.5 0.58 661.99 MNDNFR#K-CAZSC(3) 2,83&95 32.30 Wall 2,79121 2700.52 414.83 S13717 5,946,002]4 315.463.03 0,12 717,36 ~+IFR-N(CAZSC(3) 3p2&07 32.8 300.00 2,871.15 270245 4]8.32 52&35 5046.6530 316,443.43 0Ta 767 34 MNDaIFR✓J(CAZSC(3) 3,12333 33.57 33].67 2,96.12 Zli 608,11 d6938 5,946,6]9] 316,403.5 coo 01702 61WDNFRAK-0AZSC(At 3.217.41 34,79 337.18 3.027.95 293935 54072 -]11.2] 5,048.101.09 316.36.00 1.33 8941 MNDMFR.IX-CA2SC(3) 3.311.91 35,52 307.03 3,105.23 3.0166 5n105 -754.68 5,966.131.% 315,319.49 0.78 9836 akAO-1 -AWCAZSC(3) 3.40&49 3&25 307.5 3.181.61 3.093.14 6651 498.8 5,946,169.49 316,27114 079 97&30 MNONFR-ABCAZSC(3) 3.50089 W47 3640 3.5 AS 3,168.16 6406 4143.65 5.948.54.11 316,23218 0.59 1.03060 MND+WRAK{ C(3) 3,594.37 376 3699 3,332.75 3,244.05 673.49 560.51 5,918.28,62 316,188.14 0.74 1,65.03 MNO+IFR-A CAZSC(3) f 3,60.55 3767 3698 3107.60 3,318.90 ]0].88 43417 5,94&9411 316.143.34 0.85 1,140.61 M +IFR-AI(CALBC(3) ' 3,783,6 38.95 304.38 34615 3,392.6 742.40 402.28 5.846,3fB.]0 316,096.09 2.97 1.1978 MWDHFR-N(CAZSC(3) 3,8]].30 40.94 30320 3552.96 3484.5 778.44 -1,on6 5,846,345.04 316,016.14 1.30 l.MA4 "Di (3) 3197133 49.95 303.40 3,624.36 3,535.00 61049 -1,001.82 5,84538033 315,99eN red 1,31564 MWDHFRAKCAZSC(3) 4,6545 40.87 303.8 3.895.6 3,6636 044.4] -1.13592 5945,41555 315.944,90 032 1,374.39 1AV DNFR-AWCA2SC(3) 4159.02 42019 31M.0B 3.M.71 3.87161 an" -1,10700 5,91 315,093,6 120 1434.30 MMDNFR-AKCAZSC(3) 4.546 43.41 36.40 3,034.89 3.746.19 91589 -1.240.34 5,946,48.40 31504ZW 169 1,49594 M WR-N(CAZSC(3) BnR01811:0&31 M Plata, 4 COMPASS 5000. 14 Build 85 Baker Hughes INTEQ a..�?__ • ConocoPhillips Definitive Survey Report 9: he Company: Conocall illlps EKpon Company Project: VWslem Noah Slope She: GMT1 Lookout Pad Well: FAT -6.05 Wellborn: MT6-OSL1 Upper Lai Design: MT6-05 wp 10 Deal Survey Local Culminate Refinance Wall Willi0 ND Reference: Actual MTB -05 ®85]OusR (Actual 519) MD Reference: Actual MT6-05@ 80]0ucR(Actual 1019) Nunn ReferenceTJ. Survey Calculation Method' Minimum Cumatm, Database'. OAKEDMP2 Section Survey Tool Nat. Annotation IR) 155¢.04 MWD,FRiAKCA2 C(3) 1.020.11 MJVDNFR-MH AZSL(3) 1,145.11 MJvDHFRJJ(-0pZSLIJ) � 1,76126 1AVY13 AKLA 13) 1,825.29 MWD+IFR-AKGPZSC(3) 1,88.9.58 MWD+IFR-AKAAL C(3) 1,95343 MWDdFR-N(-0PZSC(3) 2017.82 MPVV IWf-PK-0AZSO(3) 2081,MJr➢NFR✓J(LAZSC(3) 2147.38 MND+IFR-MK A2! C(3) 2212.5 MN0+1FR-AWLAZSC(3) 22]].10 MNONFR-AKLA (3) 2,340.34 Mani (3) 2,405.02 MWD+IFR-AKL -SC (3) 2,46934 MrVO+IFR-PH-CAZAC(3) 2533.80 Mr4D+IFR-P1(LA2-3C(3) 259693 M0D+IFR-AKLAZSL(3) 2Fb280 M.NDaIFR-AKLPZSL(3) 2,88.10 MWDHFRAKLA (3) 2,793.04 MWD+IFR-AKC C(3) 2.056,85 MWONFRA AZSC(3) 2,921.00 MWDNFR-N(LPZSL(3) 298650 MJVCaFRA A25C(3) 3,01.13 MND+IFR-AK-CAZSC(3) 3,115.99 MNDHFRAK-CAZSC(3) 3.150.47 MWD+IFR-AK-0PZSc(3) 3,24552 Mani (3) 3,310.68 MWD+IFRviXC -SC (3) 3,3]6]9 MPoD+IFR-MR AZSC(3) 3,HD40 MJrDNFRAKLAZSL(3) 3,144.6,9 ~+IFRAK-CAZSL(3) MM IS 11:08:31AM Pape 5 COMPASS 5000.14 Said 85 Map Map MD Ix Ael TVD N055 aWS .121M Na Easting OLS (LO (7 (-am lush) lush) (us") Ift)ion RI IRI I-/lli 4,315.57 44.93 306,05 3,900. 381210 95369 -1292,10 5,946,.52653 315]9150 204 4,444.53 4564 366,62 3,9]11.11 3,88101 WS.0 -1,348.5 5.946.5]1]8 315.735.30 O.fitl 4.544,01 45,62 306.31 4.039.67 3,950,8] 1,03].86 -1,405.45 5,946,615.42 315.680.24 0.22 4,63951 en" 314.01 4,105.46 4,01]]6 107014 -0,460.57 5,948,65702 315,85.12 0.2J 4,]322(1 4563 305.01 4,17127 4,08257 1,11,165 -1,514.50 5,9M',696.82 315,573,15 075 4,8241] 45.60 304.59 4,Z15.W 4,746.90 1154.17 -1,56848 5,945.73564 315,520.8 036 4,910!2 4566 303.65 4,301.8 4,213.02 1,192.07 -1,624.42 5.946.774.89 315,46510 Di 5,01214 4568 304.60 4,36].4] 4,278.77 1,229.57 -1,600.29 S, W,013.]3 315.410.16 0.33 5.106.80 4561 30414 4.433.20 4,344.W 1.57.49 -1,735.77 5.814.652.85 315,355.62 0.43 5.20123 4565 304.35 4,49923 4410.53 1,30.571 -1,791.40 5,946,89254 315,3093 Oil Sallie 45W 30406 4,56530 4476.56 1,34371 -184730 5,946931.88 315.245.97 023 SMOSI 4538 303.84 4,63104 4,543.14 1,381.47 -1,90338 Sam 971 do 315,190.82 0.20 5,48333 4532 301.10 4 6 460630 1418.33 .1 wai10 5,94],008.1] 315,13703 0.21 5,5]8.13 45.26 304.42 4M71 4.61 1455.25 -ZD13]] 5,94704.142 318.08230 D.26 SM.39 45.10 30CP1 4.530.17 4.]414] 14945 -208674 5,94),587.76, 315,01 D.39 5]%.67 45.12 306,17 4M.71 4,808.01 1,533.09 -215.09 5,94],12].60 314,97400 095 510515 45.00 307.02 4,963.40 4,07478 1,57303 -2tM.88 5.947,169.13 314,923.00 0.64 5.953.14 4513 307.58 S.M.93 4,9b5 161284 -2,230.14 5,94721019 314.870.81 043 6.048.44 45,04 307.59 509581 5,014,91 1,66363 4,282.14 5,847,2525 314,018.82 0.10 6,14251 4505 307.90 S1.,M 6,01 1,694.30 -2,334.]8 5,94],294.2] 314,761 OS 6,23505 4614 314.01 SMT 5,130.75 1)34.21 -2386.70 5,947,335.35 314.71618 068 6,32917 45.06 306.0 5.l " 5.20534 1,774.14 -2440,11 5,84).30.58 314,66383 029 Si 45,90 306.42 S3 55 5,271.95 141394 -2,493.85 5,947,417.65 314.611.08 0.16 651]]0 45.12 30532 542705 5,33635 1,053.46 -2,54750 5,947,458.46 314,558,40 009 6,612.19 4514 306.15 5.493.76 5,405.06 1,093.5, -260147 5,947.49131 314505.41 0.15 6,706,.20 45.14 305.10 5,56016, 5,47146 1,93220 -266inn 5,94].53983 314,452Gi 005 6,19105 4511 305.89 5,627.12 5,53842 1,971.73 -2,714.50 5947580.62 314,314.5 016 Steel 4510 30520 5,894.24 5.605.54 2,011.13 -2,76432 5,91 314345.59 014 6,691.21 45.07 305.61 Slaii 5.61 2,0040 -281090 5,947,66192 314291.89 003 7,00.78 45.08 3'066.19 5,02015 5739.45 2MSM ja]346 5.947.702.5 314.23829 037 ]IMM 4510 305.01 5894.55 500585 2127.52 -2,19 5 5.&7741,W 314,18455 0.14 Section Survey Tool Nat. Annotation IR) 155¢.04 MWD,FRiAKCA2 C(3) 1.020.11 MJVDNFR-MH AZSL(3) 1,145.11 MJvDHFRJJ(-0pZSLIJ) � 1,76126 1AVY13 AKLA 13) 1,825.29 MWD+IFR-AKGPZSC(3) 1,88.9.58 MWD+IFR-AKAAL C(3) 1,95343 MWDdFR-N(-0PZSC(3) 2017.82 MPVV IWf-PK-0AZSO(3) 2081,MJr➢NFR✓J(LAZSC(3) 2147.38 MND+IFR-MK A2! C(3) 2212.5 MN0+1FR-AWLAZSC(3) 22]].10 MNONFR-AKLA (3) 2,340.34 Mani (3) 2,405.02 MWD+IFR-AKL -SC (3) 2,46934 MrVO+IFR-PH-CAZAC(3) 2533.80 Mr4D+IFR-P1(LA2-3C(3) 259693 M0D+IFR-AKLAZSL(3) 2Fb280 M.NDaIFR-AKLPZSL(3) 2,88.10 MWDHFRAKLA (3) 2,793.04 MWD+IFR-AKC C(3) 2.056,85 MWONFRA AZSC(3) 2,921.00 MWDNFR-N(LPZSL(3) 298650 MJVCaFRA A25C(3) 3,01.13 MND+IFR-AK-CAZSC(3) 3,115.99 MNDHFRAK-CAZSC(3) 3.150.47 MWD+IFR-AK-0PZSc(3) 3,24552 Mani (3) 3,310.68 MWD+IFRviXC -SC (3) 3,3]6]9 MPoD+IFR-MR AZSC(3) 3,HD40 MJrDNFRAKLAZSL(3) 3,144.6,9 ~+IFRAK-CAZSL(3) MM IS 11:08:31AM Pape 5 COMPASS 5000.14 Said 85 Baker Hughes INTEQ avcY ConocoPhillips Definitive Survey Report l Company: CcnocoPh4bps Export Company Project: Matem Nanh Slope Sate,'. GMT1 Lookout Pae Well: MTB -05 Wellbore: M11`6-051-1_Dpper Let Do."in Ie1`8-05 Wp10 Dra81 Survey Local Co-cralinato Reference: TVD RMerence: MD Reference: North Referance: Survey Calculation Method: Database: Well MT6-05 Actual MT6-05 Op 88.70usD (Actual D19) Amuzl MT6-05 ® 88,70usD (Actual D19) Tlue Minimum Cmv.Wre OAKEDMP2 8/1/10 18 1108:31AM AnnotMlOn &SIB" x 12-1/4" WMNSS 5000.14 said 85 Map Map Vertical MD (Udo I(1 1°1 AM 1'1 NO IUSM NDSB (Ram +643 hunt +Fl -W Juan) Northing Eastln9 DLS section survey Tool Name (n) ID) (•1i9v) (D) ].2]352 45M 304.86 5980,71 58801 2165.51 -2,962.33 5.94])8096 314131,31 Ota n..SAO MWD+IFR AK-CAZSO(3) T.&M 45.09 .5.02 8.02]]0 5,839.00 220387 3,037.39 5,94].020]4 314,077.21 013 3,1aci MWD+IFR- CA25C(3) 7,41 45.09 309.22 8.093.82 6,00.12 2,242.13 -3,83.64 5,947.860.21 314,02350 0,15 3,69720 MNA+IFR-P)(LAZSL(3) 7,555.32 45,01 304.70 6.159,7.7 6,071733 2,280.00 3,145.'/2 5,94],009.3] 313,87076 034 3,]60.81 MW➢HFR- -CAZSC(3) ],649.62 4..05 304.53 6,22637 6,13767 2,31794 51200.60 6947 936,63 313,916.02 0.19 3.825.10 MWD+IFR- -CAZSC(3) ],]4203 4523 30.35 61291,% 6,202.86 2,3MA5 5,25429 5,947,97743 313.84.06 ON 3,88.21 MNDHFRAK-CA C(3) 7,83684 45.26 305.01 6,350.1] 6,28.4] 2384.54 -3,30693 5.940.01784 313.810.38 035 3.953.15 MWD+IFR-AK-0AZSC(3) ],930]5 45.27 305.00 6,4N.41 6,335.71 243369 -3,353.13 5,946M N 313.751.16 005 4017.64 1uND+IFR- CAZSC(3) 8.024.90 45.28 306.8 6.48,73 6,40203 2,47329 3,41709 5,840.093.19 315704.10 059 4408273 MW➢+IFR✓J(L]SSC(3) 8,118.93 4530 30704 6556.84 6.468.14 2,513.32 5,470.51 5,940,140.50 313,651.75 029 4.147.61 MWD+1FRAK-CAZ4IC(3) 6212.40 4510 OWN 6,622.70 6SIP1.00 2,553.17 5,523.53 51040,181.63 313,589.72 0.27 4.212.10 MAD+1FRAK-CA25C(3) 8,301 4506 38.73 6,689.49 66829 2593.27 -3.67..10 5.940.223.01 313,547.06 0.00 4,P].P MWD+11FR-AK-0AZSC 13) 8.401.40 45.07 305.08 6]56.1] 6,66747 2,63293 3.53096 5,94820396 313.49425 0.50 4,342.00 MWD+IFR- -CAZSC(3) 0.495.22 45,06 WON 6,822.44 6]33]4 2671,99 aNIs9 5,948.30431 313,441.50 005 4,40932 MWD+1FRJ AZSC(3) 8,5898 45.02 305.60 5A831 6,800.61 2711,16 5,7.19.01 5,940,344.]9 313,30615 029 473]1]1 MWDNFR-AHLAZSC(3) 8,665.3] 4505 30550 6.956.01 6.888.11 2750A9 5,78396 5,946385.. 313.334.10 003 4,536.42 MAD+1FRAK-CA25C(3) 0,779739 45.06 3M,Z0 7,023.42 6,931 2, Tea" -3,64].86 5,948732609 313.281.28 0.04 4,8108 MND+IFR-AK-CAZSC(3) 8,874,41 45.0 307.12 7093.35 7WIAS 2,830.12 -3,901.40 5,91646765 313220,63 0.31 4,86.28 ~.IFR- CAZSC(3) 8.89461 45.04 307.55 7,104.75 7,01606 2,030.0] 3,912.95 5,940,476.68 313.21].3] 149 4,68034 MWD+IFRAXC]SSL(3) 8,913.12 e5.07 307.75 7,117.]0 7,029.00 2,08.79 5,923.22 5943,484.65 313207.30 0.78 4,69290 MMD+IFRJ CAZSC(4) g8B.8 4510 305.34 7.1898 7,068.28 2,871.11 3959.29 5,94050991 313,178.83 0)9 4,731.51 MJUDNFRJ CA25C(4) 9,04952 4464 38.19 7,214.15 7,125.45 2,905.40 5,99904 5,91 313.132.96 ON 4787,21 MAD+WR-AKCA2SC(4) 9.1438 45.26 308.27 ]28.8] 7,192.1] 2,947.62 4,051.36 5.948.589.]5 313,81.&7 0.8 4.82.31 MMDHFRA CAZ4iC(4) 9,238.10 4565 309.51 7,347.08 7,25630 298985 -0103.71 5,948.632.N 31300135 102 4,918.20 MWD+IFR- CAZSC(4) 9.332z 48.44 311,86 7,411.18 7,322.49 3,NAN -4155.97 5,840,678.30 312,9]920 340 4,98603 MWD -IFR- CAZSC(4) 9,426.43 S1A9 31105 7.471.75 7,383.05 5082.29 -4,21009 5,948,]2]23 312925.25 3.20 5.05721 MMYD+IFR- CAZSC(4) 9,519.61 5492 311.03 7.52614 7,439.. 3,130.99 4,26603 5948.777.27 312071.52 2.72 5,130.38 MAD+1FR-AKCAZSC(4) 9,514.22 55.94 310.8 7,582. 7,493,]4 3,181.78 4,324.54 5,948.829.45 312,01426 2.8 5,206.8 MWD+IFRAKCA2SC(4) 9,706A2 5930 312.69 763191 7,54321 3=78 -4,382]0 5.918,892.8 312}5].39 ani? 5.28.93 MAID01FR-AK-0AZSC(4) 8,80105 6109 315.59 ],6]68 7,59.15 3,20..84 4,441.48 5,946841.33 312,700.01 327 5.635 MWDNFR+WCAL6C(4) 989520 6167 310.04 7.722.52 7,833.82 3,351.70 -4,496,58 5849.8109 3126.A3 358 5.440.62 MWII+IFR-PHCPZSL(4) 8/1/10 18 1108:31AM AnnotMlOn &SIB" x 12-1/4" WMNSS 5000.14 said 85 Baker Hughes INTEQ ConocoPhillips Definitive Survey Report Company'. ConowPhilhps Export Company Local OooNlnate Renitence. Project: Western NOM Slope TVD Reference: She: GMT1 Lookout Pad MD Reference: Well: MTS -()5 Noah Reference: Wellhore: MT&1151-1 Upper Let Survey Calculation Metho& Design: MT6-05 W 10 Drahl Oaiehase: Survey I Well M76-05 Actual MTE415 ® 80.70us0 (Actual DIM) Actual MT8415 @ 88]Ousa (Actual D19) True Minimum Curvature OAKEDMP2 WMIO 11,08.31" Pegs 7 Vertical Semon Survey Tool Name Annotation (NI 55339] MN3+IFR-PI(-CAMC(4) Map Map MD Its AM TVD 1LM1I59 sW8 +0W4 Northing Ea ting DLS IM•111 1% 19 1Ma01 (USM (uaM (..ft) (a) (al (°1100) 9,98982 65.90 3ffie7 7,]82.7 7.07407 3,416.57 Av5 a W 594906914 312,590.55 3.57 100&;55 60.49 323.03 ],]9020 ],]1050 3,484]5 4.69037 5,949.1aa1. 312,Mh 3.51 10,17042 ]t]9 324.53 7,831.43 7,74273 3.556.4 4,woot, 5,949,212.42 31240795 378 10.271.93 7335 325.90 7859.44 ],]]0.]4 3,633,03 <.710.97 5,949.28490 312.43385 210 loasio4 ]4]3 32231 7884.53 ],795.83 3 7051 4,760.88 5,949,363.01 312,39(,80 281 10"60.54 ]]03 32931 7,905.32 ],01].62 3,]03.96 4,818.18 5,94944330 312.3..42 286 1055535 79.90 33090 7,924.99 TOWN 3.864.54 4.110.60 884952407 312.300.07 275 10,650.00 0137 331,55 7,990.55 705185 3,94437 4,960.44 5,94%%7]6 312,257.14 1,90 10.]45.13 02.41 333.16 7.953.90 ],8[538 4,02980 4.9.12 5.949.812.23 312,215M 2.02 10,839.12 8235 332.20 7,966,90 7,87.34 4,11262 4,90480 5.949.7605 312,1]4]6 1,14 10.83390 82.85 Mall 7977.]8 7.809.09 4,195]2 -5,030.07 5,94906017 38,133.61 0.71 X10.839.00 WAS 332.88 ],9]0"] ],809,]7 4,200.57 -5,032.55 584906509 312,81,N 0.00 11,017.33 0335 332.81 7984.53 7,895.1 4,VO.N S,M.41 5,949,93589 312,097,10 697 11.114.0 9619 332.91 7,91.71 ],0@,O1 4,35623 5,112.23 5960,@2.63 312.1155.37 314 11,165.90 WAS 33292 7975.02 7.81.32 4,401.98 5,135.83 5,91,000.93 38,033.10 050 11,251.04 93.41 33040 7,45,05 7,878.15 4,485.32 5,11.1 5,950,153,33 311.91.18 4.15 11,355.57 90.99 326.47 ],96332 7,07/52 4,565]9 5,230.02 5,950,234.96 311,942]2 4.88 11,450,117 9097 MT..33 7.%159 ],8]209 4,645.69 5.28211 5.91,316.11 311,892.1 0.90 11,54074 9044 32332 7,91.41 7.871,71 4)26]4 -5.33310 5.91,398.37 311.843.58 1,R 11.1191 slau 331"2 7,96001 7,871.31 4,81.04 -5,380.07 5.91.481.1 311,797.83 3.28 11,]222] 90.05 332.93 7958.90 7071.25 4,81.11 5,418.37 5,&0553.]5 3114]620] IN 11,73695 90.05 333.21 7959.94 787124 4,093.20 5,425.02 5,950567.1 311,75574 1.1 11.83203 Sam Ml1,M 7,959.91 7 87U 4977,33 541.31 5,91,652.17 311.7131 205 11,97.45 831 M12 7,959,95 7071,25 5,Lf0.53 e,516.02 5,91.736.40 311668,83 1.19 8,023.13 91.1 331.09 7,91.59 7,01,09 5,143.88 6,562.110 5,850,820.94 311,1390 2.02 12,11447 9201 333.54 7,91G.X 7,866.84 5228.26 5,80]85 5,91.906.36 311.581,71 2.60 1221385 9312 334.95 7,951.27 ],0625] 5.314.00 -5,64866 5,9`.4.033.16 311,54240 180 12.30933 92.96 33430 7,946.21 ],85].51 5.40022 -5,689.51 S,A51.01.ID 311,503,1 070 12,403.76 93.1 334.29 7,94130 7,85260 5,485.19 -5.730.41 5951.1119 311,464.03 0.04 12,4BB.21 MSG 333.07 7,9%.34 ],04].64 55701 -57M.1 5,95125283 311"031 1]11 12,14.99 Mon 333,05 7,931,33 7,0421 515.90 5,016.01 5951,338.92 3113141 0.08 WMIO 11,08.31" Pegs 7 Vertical Semon Survey Tool Name Annotation (NI 55339] MN3+IFR-PI(-CAMC(4) 562050 MNO+IFRAWCAZSC(4) 5.709.58 MNDaIFR-A AZSC(4) 5,79x46 ~+IFRAKCkZ6C(4) 5,890.64 M I)+IFRAKCPZSC(4) 5,9]9.8 MWD+IFR.AK / .SC (4) 6,07135 MWD+IFRIJ({.A23C(4) � 416306 MJVDNFR-MCAZSC(4) 6,25521 MJr1lNFgAK-CAZSC(4) 6,346.31 140013N1FRAKLACSC(4) 6.437.86 M I)+IFRAK-CAMC(4) TIP to W6 -05P81 5.443.21 MWD-INCONLY(INCaIWu) KOPTOWS 6.620.0 VNIMNC ONLY (IW,171(5) Inhu,olated&6hro h 6613.97 MW0.I1,10 ONLY(INCNP)(5) Inbryolated Aeimuth 6,66415 MWD+IFRJJ(LALS(,(6) 6.75204 Mr4➢+IFRAi(4:AZS (6) 6.850.1 MJeD+IFR-MI AZ4C 16) 6945.34 BfiND+IFRAKLAZSO(6) 7,04031 MAO+IFRAKLAZSC(6) 7,134.19 MNOHFRA-CAMC(6) 7.212.87 MWD+IFRAK-CAZSC(6) Mill T1.9 7,27.M MWOHFR-AWCAZ4C(6) ],31-1.2] MWD+IFR-Pl(LPZ50(6) 7,414.18 MvlgNFRAKL C(6) 74500.35 MWD+IFRJ A25C(6) 1 7,11.60 MrW+IFR-AN-0.4250(6) ],694.14 eoC+IFR.K AL4C(6) 7,786.58 MJJONFRAK-CA23C(6) 7978.15 MWOHFRAK-CAZ4tC(6) 7.9M.M MWONFRIJ(-0 C(6) 8,90439 MWD -11` CPZS0(6) COMPASS 500414 Su1M M Co.NW.. ConawPhillips Export Oonpany Project: Mstern Noon Slope Baer GMT1 Lookout Pad Well: MT6-05 Wellborn. MT6-05L1_Upper Lar Design: MT6-05 o,100raX1 Survey Baker Hughes INTEQ Definitive Survey Report Local Coordinate Reference: Well MT655 WO Reference: Actual MT655 @ 88.70usN (Actual D19) MD Reference'. Actual MT6-05 Q 88.70usit(Actual D19) North Reference: True Survey Calculation Mi Minimum Curvature Database: OAKEDMPI BH1101811:08:31AM Page 8 COMPASS 5000, I4 suits 85 Map Map DIncWO MD Ic n poi mw ♦-61.414 Northing Eastln9 OLS S.Vertical Survey Tool Nana Annotation (M (9 (ush) Will (ut/1j (rym R) (ft) (•1100'sudden (111) 12.690.05 92.53 334.19 ],936.M 7830.02 5,740.98 5,85820 6961 42497 311,343.30 1.31 0.168.74 MWD+IFR-PI(LAZSC(6) 12,705.29 92.50 338.36 7,921.54 7,83284 5,827.38 S,e97.99 East MM 311306.¢ Z2. &MO.R MWD+IFR✓J(LALSC(6) 12,000.4] 92.50 337.59 7,918.39 7,829.69 5,90488 -5R35.10 5,951,60721 311,2]0.5] 12B 0,2111.80 MW9HFR-AK-CA25C(6) 1ZR7E. x150 33].]3 7.915.03 7,816.33 6,003.01 5,971.40 5,951.688.68 31123SEi 1.02 8,430.89 MMD+IFRJ-CAMC(6) 13,071,07 0890 336.31 ].9137] 7,825.07 6,091,33 46,00.05 5,951,]]8.84 311,203.02 1.75 8,521]0 MWTJ+1FR- aCAMC(6) 13,166.30 0907 338.]9 ],914.5] ],025.8] 6,107.05 46,041.90 5,951,068.37 311.170.33 1.09 0,612.31 MWDHFR-AK-0.4250(6) 13,26135 "Al 330.95 7,916.33 ],82]63 6,269.82 46.0]&13 5.951,95].]4 311,138.26 0.31 0,]02.40 MMD+IFR-AK-0.4250(6) 13.35710 88,44 WAS 7,910.63 7,828.93 635].61 6,111.38 5,9$2047.55 311.105.19 1,23 0,]83.4] MMD+IFR- ,C-0 -SC (6) 13,451.89 O&81 33702 7.921.07 ],032.3] 644511 5,14].]6 EN2.l5.W 3TRMJ5 0.07 0,004.11 M +IFRAKL C(6) 13,54741 6&48 334.66 7,9OS,S, ],834]9 &53201 46,18729 5,94,213.74 311,03254 3.10 8,976.30 MWDAFR-AK-CAZSC(8) 13,64274 0999 33310 ],804.]1 7,036.07 6.617..38 5X19.70 5,952.310.10 310,993.21 104 9.059.13 MWD+IFRN(LRSC(6) 13.737.96 88.98 332.11 7,924.79 7,838.09 6.701.92 5,2]3.52 5,94.395.83 310951.47 1.04 9.16221 MWDNFA-AACAZSC(6) 13,833.14 89.98 331.46 7,924..41 ],836.13 6.]05.]9 5310.4 5,952,48061 310.900.4 deal B,25S54 MWD+1FRJJ(CA,6C(6) 13,4&34 89.98 330.15 7,924.86 7,83616 68fie.eB -6,36485 584.55401 310.W4.12 1.30 8.34%19 MWDHFRAKCALSC(6) 14023.35 90.05 331.50 7.44.83 7,03613 6,951.85 5,41127 5,952,64985 310,819.84 1.42 9,44265 MWO+lFRAK-CAZSC(6) 14,118.55 9267 33123 ],922.5] ],0338] ],0353] 45,tiN 87 5.952.733.47 310.778.28 2.77 9,538.09 MMD+IFP-AK-CAZSC(6) 14.213.17 93.0 332.19 7,87.8. 7,028.1. 7,118.69 5.501.65 5952.81]]4 310.733.53 1.07 9,4.4.70 MMD411'Fa ( SC(6) 14306.11 94.4 TOM 7,912.07 ],823.3] 7,202.56 51545.58 5,94,9474 310,691.67 V] 9,721,49 MJu➢gFRAK-0pL6C(6) 14,403.80 93.98 334.20 7,906M 7,816JN ],24.]9 5,588,27 5,94980.9. 310,651.06 1.68 8,814.41 MND+1FRAKC 4C(6) 14,499.04 8404 33470 7,89091 7,010.01 ],3]262 5,62930 5,&53,07578 310,81213 0.4 9,90621 MND+1FRAK AZSC(6) 14.584.39 PIRG 338.94 7,111 7,004.19 7,461,36 5,075.96 5.953184.37 31057!.51 5.50 9,99].]1 MWD+IFR- CAZSO(6) 14.68987 91.4 334.33 ],11 1 780.21 7,549.00 870298 5,95324.97 31054276 &00 10.08&92 MWD+IFR- -CL SC (6) 10704.76 9099 333.09 ],806.58 7 797A 7,634.60 5,744.46 S,.Sl,33B.46 310,50334 0.69 10,181.28 MWDNFR- CAZSC(6) 1488040 91.03 333.42 ],884.80 ],]9520 7730.29 £,78.90 5952426.16 310,463.03 0.49 10,274.39 MWD+lFR-M-CA ,SC (6) 14,9]5.5 89.89 334.3] 76B4.D6 7795.38 7.80573 5,828]8 5,94,51258 310,423.23 1.49 10.366.93 MWDNFR-N(-0.4250(6) 15.071.10 80.99 33368 7,884.92 7]56.22 7,8914 5.870.61 Sam SEEM 310.363,M 1.20 10,459.81 MND.lFR- -CAZSCpu 15,16521 88.01 321.99 ],88].30 ],]98.68 7975.35 Riaoit 5,853604.21 310,342.07 1.80 10,56165 MAD.1 K-0.4250(6) 15,1&5.07 . 86.01 332.50 7,08.41 a 7,799.71 8,001.37 4,927A2 5,953.71084 310.329.36 0.00 10,58.84 PROJECTED to TD BH1101811:08:31AM Page 8 COMPASS 5000, I4 suits 85 ConocoPhillips ConocoPhillips(Alaska) Inc. -WNS Western North Slope GMT1 Lookout Pad MT6-051-1 50-103-20771-60 Baker Hughes INTEQ Definitive Survey Report 15 August, 2018 BAF�UGHES a GE company 8/15@018 5: 00 49P Page 2 COMPASS 5000.14 Build 85 ConocoPhillipseA"�`uEGRR� a ConocoPhiiiips Definitive Survey Report Company: ConowPhillips(Alaska) Inc. -WNS Local Co-ordinate Reference: Well MT6-05 Project: Western North Slope TVD Reference: MT6-05 Actual C 88.70usft (Actual Dl 9) Site: GMT1 Lookout Pad MD Reference: MT6-05 Actual a 88.70usft (Actual Dig) Well: MT6-05 North Reference: True Wellbore: MT6-05 Survey Calculation Method: Minimum Curvature Design: MT6-05 Database: EDT 14 Alaska Production Project Western North Slope, North Slope Alaska, United States Map System: US State Plane 1927 (Enact solution) System Datum: Mean Sea Level Geo Datum: NAD 1927 (NADCON CONUS) Map Zone: Alaska Zone 04 Using geodetic scale factor Well MTB -0S Well Position +w.3 0.00 usft Northing: 5,945,543.79usft Latitude: 70° 15'22.964 N +El -W 0.00 usft Easting: 317,059.98 usft Longitude: 151°28'42.930W Position Uncertainty 0.00 usft Wellhead Elevation: 0.0ousft Ground Level: 37.20 usft Wellbore MT6-051-7 Magnetics Model Name Sample Dab Declination Dip Angle Field Strength 0 (1) ron BGGM2017 520/2018 16.50 80.72 57,422 Design MT6-0511 Audit Notes: Version: 1.0 Phase: ACTUAL Tie On Depth: 10,933.50 Vertical Section: Depth From (TVD) +NI -S +E/ -W Direction (usft) (usft) (usft) V) 0.00 0.00 0.00 320.46 8/15@018 5: 00 49P Page 2 COMPASS 5000.14 Build 85 ConocoPhillips ER $ ConocoPhillips Definitive Survey Reportu�nFs Company: ConocoPhillips(Alaska) Inc. -WNS Local Coordlnate Reference: Well MT6-05 Project: Western North Slope TVD Reference: MT6-05 Actual @ 88.70ush (Actual D19) Site: GMT1 Lookout Pad MD Reference: MT6-05 Actual @ 88.70ush (Actual D18) Well: MT6-05 North Reference: True Wellbore: MT6-05 Survey Calculation Method: Minimum Curvature Design: MT6-05 Database: EDT 14 Alaska Production Survey Program Date 8/15/2018 From To Survey Survey Nam (uaR) Sumay, (Wellbore) Tool Name Description Start Date End Data 60.26 263.26 GYD Gyro DMS 16" (MT6-05PB1) GYD-CT-DMS Gyrodata wirt.dd8plpe mls 5/13/2018 5/13/2018 296.28 1,957.96 BHGE MWD+IFR+MSA 16"(MT6-0SPB1 MWD+IFR-AK-CAZSC MWD+IFR AK CAZ SCC 5/15/2018 2,050.54 8,894.81 BHGE MWD+IFR+MSA 12-1/4"(MTS-05 MWD+IFR-AK-CAZSC MWD+IFR AK CAZ SCC 5/21/2018 6,968.80 10,933.50 BHGE MWD+IFR+MSA W-3/4"(MT6-0 MWD+IFR-AK•CAZSC MWD+IFR AK CAZ SCC 6/4/2018 10,939.00 11,114.28 BHGE MWD INC 6'(MT6-05L1) MWD-INC_ONLY(INC>10') MWD-INC_ONLY_FILLER(INC>10°) 7/10/2018 11,165.98 15,165.21 BHGE MWD+CA+MSA B"(MT6-05L7) MWD+IFR-AK-CAZSC MWD+IFR AK CAZ SCC 7/10/2018 Survey Map MAP Vertical MD Inc AxI TVD TVDSS +NIS +EI -W Northing Small DLS Sasflon (1)0 (usR) (ustq NOR) Walt) ("n00') Survey Tool Name Annotation(uslt) (R) (N (R) 36.50 0.00 0.00 36.50 52.20 0.00 0.00 5,945,543.79 317,059.98 0.00 0.00 UNDEFINED 60.26 0.33 231.64 60.26 $8.44 -0.04 -0.05 5,945,543.75 317,059.93 1.39 0.00 GYDCT-0MS(1) 161.76 0.36 194.38 161.76 73.06 -0.53 4.36 5,945,543.27 317,059.61 0.22 -0.18 GYD-CTDMS(1) 263.26 0.55 211.72 263.25 174.55 4.26 -0.70 5,945,542.54 317,059.25 0.24 -0.53 GYD-CTDMS(1) 296.26 0.96 224.50 296.25 207.55 -1.60 -0.98 5,945,542.22 317,068.96 1.31 -0.61 MMD+IFR-AK-CAZSC(2) 390.15 1.24 252.95 390.13 301.43 -2.46 -2.50 5,945,541.40 317,057.42 0.64 -0.30 MWD-IFR-AK-CAZ-SC (2) 483.51 2.22 291.97 483.44 394.74 -2.08 5.15 5,945,541.84 317,064.79 1.58 1.67 MWD+IFR-AK-CAZSC(2) 577.56 3.84 299.00 577.36 488.66 0.13 -9.59 5,945,544.16 317,050.40 1.76 6.21 MWD+IFR-AK-CAZSC(2) 672.51 5.48 303.35 671.99 583.29 4.17 -16.16 5,945,646.35 317,093.93 1.77 13.50 MWD+IFR-AK-CAZSC(2) 766.06 7.00 304.80 764.99 676.29 9.88 -24.57 5,945.554.26 317,035.66 1.63 23.26 MWD+IFR-AK-CAZSC(2) 860.61 8.03 306.69 858.72 770.02 17.11 -34.60 5,945,561.73 317,025.81 1.12 35.22 MWD+IFR-AK-CAZSC(2) 955.24 8.96 307.34 952.31 863.61 25.53 45.76 5,945,570.42 317,014.86 0.99 48.82 MWD+IFR-AK-CAZSC(2) 1,048.71 10.08 308.87 1,044.50 955.80 35.08 57.91 5,945,580.26 317,002.94 1.23 63.92 MWD+IFR-AK-CAZSC (2) 1,143.88 11.57 309.42 1.137.97 1,049.27 46.36 -71.77 5,945,591.88 316,989.36 1.57 81.45 MWD+IFR-AK-CAZSC(2) 1,238.25 12.95 310.96 1,230.19 1,141.49 59.31 57.07 5.945.605.19 316,974.39 1.50 101.16 MWD+IFR-AK-CAZSC(2) 1,332.92 14.13 310.53 1,322.22 1,233.52 73.77 -103.86 5,945,620.06 316,957.95 1.25 123.01 MWD+IFR-AK-CAZSC (2) 1,427.45 14.70 308.04 1,413.78 1,325.08 88.68 -122.08 5,945,635.38 316,940.10 0.89 146.09 MWD+IFR-AK-CAZSC(2) 1,521.38 15.39 305.44 1,504.49 1,415.79 103.23 -141.62 5,945,650.42 316,920.92 1.03 169.77 MWD+IFR-AK-W-SC(2) 8/152018 5: 00.49PM Page 3 COMPASS 5000.14 Build 85 ConocoPhillips ConocoPhillips Definitive Survey Report Company: ConocoPhillips(Alaska) Inc. -VVNS Local Coordinate Reference: Well MTMS Project: Western North Slope TVD Reference: MT6-05 Actual @ 88.70usft (Actual D19) Site: GMT1 Lookout Pad MD Reference: MT6-05 Actual @ 88.70usft (Actual D79) Well: MTS -05 North Reference: True Wellbore: MT6.05 Survey Calculation Method: Minimum Curvature Design: MT6-05 Database: EDT 14 Alaska Production Survey BAKER Ji UGHEs Annotation 13-3/8"x 16" 8/152018 5:00:49PM Page 4 COMPASS 5000.14 Build 85 MSP Map VeMeal MD Inc Act TVD TVDSS 4W.8 +El -W DLS Northing Emitting Section Survey Tool Name (USM (1) 0 lusm (weft) Wait) (usm (R) (R) ("MSS') Ift) 1,616.89 14.91 304.96 1,59,15.68 1,507.98 117.62 -162.02 5,945,665.30 316,900.88 0.52 193.65 MWD+IFR-AK-CAZSC(2) 1,710.53 15.15 305.97 1,687.11 1,598.41 131.71 -181.79 5,945,679.87 316,881.46 0.38 217.30 MWD+IFR-AK-CAZSC (2) 1,805.77 16.56 306.15 1,778.73 1,690.03 147.03 -202.82 5,945,695.69 316,860.80 1.48 242.51 MWD+IFR-AK-CAZSC(2) 1,899.91 18.01 307.58 1,868.62 1,779.92 163.82 -225.19 5,945,713.02 316,838.85 1.60 269.69 MWD+IFR-AKCAZSC(2) 1,957.96 18.83 308.11 1,923.69 1,834.99 175.07 -239.68 5,945,724.62 316,824.64 1.44 287.59 MWD+IFR-AKCAZSC (2) 2.014.00 19.29 307.93 1,976.66 1,887.96 186.34 -254.09 5,945,736.24 316,610.51 0.83 305.46 MVYD+IFR-AKCAZSC (3) 2,050.54 19.59 307.82 2,011.12 1,922.42 193.81 -263.69 5,945,743.94 316,801.09 0.83 317.33 MWD+IFR-AKCAZSC(3) 2,089.52 20.21 307.93 2,047.77 1,959.07 201.96 -274.16 5,945,752.33 316,790.82 1.59 330.28 MWD+IFRAKCAZSC(3) 2,183.73 22.60 308.62 2,135.47 2,046.77 223.26 301.15 5,945,774.29 316,764.37 2.55 363.69 MWD+IFR-AKCAZSC (3) 2,278.30 25.23 308.60 2,221.92 2,133.22 247.16 331.10 5,945,798.93 316.735.00 2.78 401.41 MWDNFR-AKCAZSC(3) 2,372.40 26.72 308.06 2,306.51 2,217.81 272.74 383.43 5,945.825.26 316,703.30 1.60 441.70 MND+IFR-AKCAZSC (3) 2,467.33 27.46 308.78 2,391.02 2,302.32 299.60 397.30 5,945,852.94 316,670.10 0.85 483.98 MWD+IFR-AKCAZSC(3) 2,659.45 29.82 306.63 2,471.87 2,383.17 326.58 -432.25 5,94.5,880.75 316,635.82 2.80 527.02 MWD+IFR-AKCAZSC(3) 2,651.10 30.86 306.47 2,550.97 2,462.27 354.15 469.44 5,945,909.21 316,599.32 1.14 571.96 MWD+IFR-AKCAZSC(3) 2,744.71 31.74 307.31 2,630.95 2,542.25 383.34 506.33 5,945,939.34 316,561.15 1.05 619.24 MWD+IFR-AKCAZSC(3) 2,839.16 32.22 307.74 2.711.07 2,622.37 413.81 548.00 5,945,970.76 316,522.23 0.56 667.99 MWD+IFR-AKCAZSC(3) 2,933.95 32.30 307.89 2,791.22 2,702.52 444.83 587.97 5,946,002.74 316,483.03 0.12 717.36 MWD+IFR-AKCAZSC (3) 3,028.87 32.99 308.00 2,871.15 2,782.45 476.32 528.35 5,946,035.20 316,443.43 0.73 767.34 MWD+IFR-AKCAZSC(3) 3,123.33 33.57 307.67 2,950.12 2,861.42 508.11 569.28 5,946,067.97 316,403.28 0.64 817.92 MWD+IFR-AKCAZSC(3) 3,217.41 34.79 307.16 3,027.95 2,939.25 540.22 -711.27 5,946,101.09 316,362.09 1.33 869.41 MWDNFR-AKCAZSC(3) 3,311.94 35.52 307.03 3,105.23 3,016.53 573.05 -754.68 5,946,134.96 316,319.49 0.78 922.36 MWD+IFR-AKCAZSC(3) 3,406.49 36.25 307.26 3,181.84 3,093.14 605.51 -798.86 5,946,169.49 316,276.14 0.79 976.30 MNANFR.AKCAZSC(3) 3,50(1 36.47 306.40 3,257.86 3,169.16 640.06 543.65 5,946,204.11 316,232.18 0.59 1,030.68 MWD+IFR-AKCAZSC(3) 3,694.37 37.06 306.99 3,332.75 3,244.05 673.49 588.51 5,946,238.62 316,188.14 0.74 1.085.03 MWD+IFR-AKCAZSC(3) 3,688.55 37.67 306.99 3,407.60 3,318.90 707.88 534.17 5,946,274.11 316,143.34 0.65 1140.61 MWD+IFR-AKCAZSC (3) 3,783.05 39.95 304.39 3,481.23 3,392.53 742.40 -982.28 5,946,309.78 316,098.09 2.97 1,197.86 MWDNFR-AKCAZSC(3) 3,877.30 40.94 303.28 3,552.96 3,464.26 776.44 -1,033.06 5,946345.04 316,046.14 1.30 1.256.44 MWD+IFR-AKCAZSC(3) 3,971.83 40.95 303.40 3,624.36 3,535.66 810.49 -1,084.82 5,946,380.33 315,995.24 0.08 1,315.64 MWD+IFR-AKCAZSC(3) 4,065.45 40.97 303.86 3,695.06 3,606.36 844.47 -1,135.92 5,946,415.55 315,944.98 0.32 1.374.39 MWD+IFR-AKCAZSC (3) 4.159.82 42.09 304.09 3,765.71 3,677.01 879.44 -1,187.80 5,946,451.76 315,893.96 1.20 1,434.38 MWD+IFR-AKCAZSC (3) 4,254.03 43.41 305.40 3,834.89 3,746.19 915.89 -1,240.34 5,946,489.48 315,842.33 1.69 1,495.94 MWD+IFR-AKCAZSC(3) BAKER Ji UGHEs Annotation 13-3/8"x 16" 8/152018 5:00:49PM Page 4 COMPASS 5000.14 Build 85 ✓ Conoco1Ip5 ConocoPhillips Definitive Survey Report Company: ConocoPhillips(Alaska) Inc. -WNS Local Co-ordinate Reference: Well MT6-05 Protect: Western Norm Sopa TVD Reference: MT6-05 Actual @ 88.70usfl (Actual D19) Site: GMT1 Lookout Pad MD Reference: MTB -05 Actual (8,1 88.70usft (Actual D79) Well: MT6-0S North Reference: True Wellbore: MT6-05 Survey Calculation Method: Minimum Curvature Design: MT6-05 Database: EDT 14 Alaska Production Survey Annotation BATF,R FS WlWO18 5: 00:49PM Page 5 COMPASS 5000 14 Build 85 Map Map al MD Inc Aid TVD TVD88 +NI -3 +EI•W Northing Emitting DLS Sectio Section Survey Tool Name (uaft) (% 0 (uaR) (ualt) (ualp Wait) 116) 1� rnw) 1151 4,345.97 44.99 306.85 3,900.80 3,812.10 953.69 -7,292.10 5,946,528.52 375,791.50 2.04 1,558.04 MWD+IFRAKCAZSC(3) 4,444.53 45.64 306.62 3,970.11 3,881.41 995.60 -1,348.26 5,946,571.78 315,736.38 0.68 1,626.11 MWDNFR-AK-0AZSC(3) 4,544.01 45.62 306.31 4,039.67 3,950.97 1,037.86 -1,405.45 5,946,615.42 315,680.24 0.22 1,695.11 MND+IFR.4KCAZSC (3) 4,639.51 45.64 306.01 4,105.46 4,017.76 1,078.14 -1,460.57 5,946,657.02 315,626.12 0.23 1,761.26 MWD+IFR-AKCAZSC(3) 4,732.20 45.63 305.04 4,171.27 4,082.57 1,116.65 -1,514.50 5,946696.82 315,573.15 0.75 1,825.29 MWD+IFR.AKCAZSC(3) 4,824.17 45.60 304.58 4,235.60 4,146.90 1,154.17 -1,588.46 5,946,735.64 315,520.11 0.36 1,888.58 MWD+IFR-AKCAZSC(3) 4,918.72 45.66 303.65 4,301.72 4,213.02 1,192.07 -1,624.42 5,946,774.89 315,465.10 0.71 1,953.3 MWD+IFR-AKCAZSC(3) 5,012.8D 45.66 309.08 4,357.47 4,278.77 1,229.67 -1,680.29 5,946,813.73 315,410.16 0.33 2,017.92 MWD+IFR-AKCAZSC(3) 5,106.80 45.61 304.63 4,433.20 4,344.50 1,267.49 -1,735.77 5,946852.98 315,355.62 0.42 2,082.48 MND+IFR-AKCAZSC(3) 5,201.23 45.65 304.35 4,499.23 4,410.53 1,305.71 -1,791.40 5,946,892.54 315.300.93 0.22 2,147.38 MWD+IFR-AKCAZSC(3) 5,295.79 45.60 304.06 4,565.36 4,476.66 1,343.71 -0,847.30 5,946,931.88 315,245.97 0.23 2,212.26 MND+IFR-AKCAZSC (3) 5,390.61 45.38 303.84 4,631.84 4,543.14 1,381.47 -1,903.39 5,946,971.00 315,190.82 0.28 2,277.10 MWD+IFR-AKCAZSC(3) 5,483.33 45.32 304.10 4,697.00 4,608.30 1,418.33 -1,958.10 5,947,009.17 315,137.03 0.21 2.340.39 MWD+IFR-AKCAZSC(3) 5,578.13 45.23 304.42 4,763.71 4,675.01 1,456.25 -2,013.77 5,947,048.42 316,OB2.30 0.26 2,405.02 MWD+IFR-AKCA7SC(3) 5,672.39 45.10 304.91 4,830.17 4,741.47 1,494.26 -2,068.74 5,947,087.76 315,028.27 0.39 2,469.34 MWD+IFR-AKCAZSC(3) 5,766.67 45.12 306.17 4.8%.71 4,808.01 1,533.09 -2,123.09 5,947,127.89 314,974.88 0.95 2,533.88 MND+IFR-AKCAZSC(3) 5,861.26 45.0 30L02 4,953.48 4,874.78 1,573.03 -2,176.88 5,947,169.13 314,922.08 0.64 2,598.93 MND+IFRAKCAZ-SC(3) 5,953.99 45.13 307.58 5,028.93 4,940.23 1,612.84 -2,229.14 5,947,210.19 314,870.81 0.43 2,662.90 MWD+IFR-AK-GAZSC(3) 6,048.44 45.04 307.59 5,095.61 5,006.91 1,653.63 -2,282.14 5,947,252.26 314,818.82 0.10 2,728.10 MWD+IFR-AKCAZSC(3) 6142.51 45.05 307.90 5,162.08 5,073.38 1,694.38 -2,334.78 5,947,294.27 314,767.19 0.23 2,793.04 MND+IFR-AKCAZSC (3) 6,235.05 45.06 30L01 5,227.45 5,138.75 1,734.21 -2,386.78 5,947,335.35 314,716.18 0.68 2,856.85 MWO+iFRAK-CAZ-SC(3) 6,329.17 45.06 306.63 5,293.94 5,205.24 1.774.14 -2,440.11 5,947,376.66 314,663.83 0.29 2,921.60 MWD+IFRAKCAZSC(3) 6,423.63 4608 306.42 5,360.65 5.271.96 1,813.94 -2,493.85 5,947,417.65 314,611.08 0.16 2,986.50 MND+IFRAK-CAZSC(3) 6,517.70 45.12 306.32 5,427.05 5,338.35 1,853.46 -2,547.50 5,947,468.46 314,558.40 0.09 3,051.13 MND+IFRAK-CAZSC(3) 6,612.19 45.05 306.15 5,4%]6 5,405.06 1,893.01 -201.47 5,947,499.31 314,505.41 0.15 3,115.99 MWD+IFR-AKCAZSC(3) 6,706.20 45.08 306.10 5,560.16 5,471.46 1,932.24 -2,655.23 5,947.539.83 314,452.63 0.05 3,180.47 MWD+IFRAKCAZSC(3) 6,801.05 45.11 305.89 5,627.12 5,538.42 1,971.73 -2,709.58 5,947,580.62 314,399.25 0.16 3,245.52 MND+IFR-AKCAZSC (3) 6,8%.14 45.10 305.70 5,694.24 5,605.54 2,011.13 -2,764.22 5,947,621.33 314,345.59 0.14 3,310.69 MWD+IFR-AKCAZSC(3) 6,991.21 45.07 305.68 5,761.36 5,672.66 2,05040 -2,818.90 5,947,661.92 314,291.89 0.03 3,375.79 MND+IFR-AKCAZSC (3) 7,085.78 45.08 305.19 5,828.15 5,739.45 2.089.22 -2,873.46 5,947,702.06 314,238.29 0.37 3,440.46 MWD+IFRAKCAZ-SC (3) 7,179.83 45.10 305.01 5,894.55 5,805.85 2,127.52 -2,927.% 5,947.741.88 314,184]5 0.14 3,504.69 MN41)+11FRAK-CA2-SC(3) Annotation BATF,R FS WlWO18 5: 00:49PM Page 5 COMPASS 5000 14 Build 85 Survey ConocoPhillips eyc� ConocoPhillips Definitive Survey Report Company: ConocoPhillips(Alaska) Inc. -WNS Local Co-ordinate Reference: Well MTS -05 Project: Western North Slope TVD Reference: MT6-05 Actual a 88.70usft (Actual D19) Site: GMT1 Lookout Pad MD Reference: MT6-05 Actual Q 88.70usR (Actual D19) Well: MT6-05 North Reference: Two Wellbore: MT6-05 Survey Calculation Method: Minimum Curvature Design: MT6-05 Database: EDT 14 Alaska Production Survey 87152078 5:00:49PM Page 6 COMPASS 500014 Build 85 Map Nap vertical MD Inc Aid TVD TVDSS +W3 +Ef-W Northing Esatirlg DL8 Section Tool Name Annotation Nam 0 P) (uaft) (W1t) loam (Wit) IN) (it)CM001 (111)SurveY 7,273.52 45.05 304.86 5,960.71 5,872.01 2,165.51 -2,982.33 5,947,780.96 314,131.31 0.13 3,568.60 MM+IFR-AK-CAZSC(3) 7,368.38 45.09 305.02 6,027.70 5,939.00 2,203.97 5,037.39 5,947,820.74 314,077.21 0.13 3,633.31 MWD+IFR-AK-CAZSC(3) 7,462.04 45.09 305.22 6,093.82 6,005.12 2,242.13 43,091.89 5,947,860.21 314,023.90 0.15 3,697.28 MWD+IFR-AKCAZSC(3) 7,555.32 45.01 304.78 6,159.73 6,071.03 2,280.00 -3,145.72 5,947,899.37 313,970.76 0.34 3,760.91 MWD+IFR-AK-CAZSC(3) 7,649.62 45.05 304.53 6,226.37 6,137.67 2,317.94 5,200.60 5,947,938.63 313,916.82 0.19 3,825.10 MWD+IFRAK-0AZ-SC(3) 7,742.03 45.23 305.35 6,291.56 6,202.86 2.355.45 -3,254.29 5,947,977.43 313,864.M 0.66 3,888.21 MWD+IFR-AK-CAZSC(3) 7,836.64 45.26 305.81 6,358.17 6,269.47 2,394.54 -3,308.93 5,948,017.64 313,810.38 0.35 3,963.15 MWD+IFR-AK-CA7SC(3) 7,830.75 45.27 305.88 6,424.41 6,33511 2,43369 -3,363.13 5,948,088.29 313,757.16 0.05 4,017.84 MWD+IFR-AK-CAZSC(3) 8,024.98 45.26 306.66 6,490.73 6,402.03 2473.29 -3,417.09 5,948,099.19 313,704.18 0.59 4,002.73 MWD+IFR-AK-CAZ-SC(3) 8,118.93 45.30 307.04 6,556.84 6,468.14 2,513.32 -3,470.51 5,948,140.50 313,651.75 0.29 4,147.61 MWD+IFR-AK-0AZSC(3) 8.212.40 45.10 306.82 6,622.70 6,534.00 2,553.17 -3,523.53 5,948,181.63 313,599.72 0.27 4,212.10 MWD+IFR-AK-CAZSC(3) 8,306.99 45.06 306.73 6.689.49 6,600.79 2,593.27 -3,577.18 5,948,223.01 313,547.06 0.08 4,277.17 MWD+IFR-AK-CAZSC(3) 8.401.40 45.07 305.06 6,755.17 6,667.47 2,632.93 -3,630.98 5,948,263.96 313,494.25 0.50 4,342.00 MWDNFR-AK-CAZSC(3) 8,495.22 45.06 305.99 6,822.44 6,733.74 2,671.99 3,684.69 5,948,304.31 313,441.50 0.05 4,406.32 MWDNFR-AK-WSC(3) 8,589.86 45.02 305.60 6,889.31 6,800.61 2,711.16 -3,739.01 5,948,344.79 313,388.15 0.29 4,471.11 MWD+IFR-AK-CAZSC(3) 8,685.37 45.05 305.58 6.956.81 6,868.11 2,750.49 -3,793.96 5,946385.44 313,334.18 0.03 4,535.42 MWD+IFR-AWC/SSC(3) 8,779.66 45.06 306.70 7,023.42 6,934.72 2,789.84 -3,847.86 5,948,426.09 313,281.26 0.84 4,601.08 MWD+IFR-AK-CAZSC(3) 8,874.41 45.05 307.12 7,090.35 7,001.65 2,830.12 -3,901.48 5,946467.65 313,228.63 0.31 4,666.28 MND+IFRAK-CAZSC (3) 8,894.81 45.04 307.55 7,104.76 7,016.06 2,838.87 3,912.96 5,948,476.68 313,217.37 1.49 4,680.34 MWD+IFR-AK-0AZSC(3) 8,913.12 45.07 307.75 7,117.70 7,029,00 2,846.79 -3,923.22 5,948,484.85 313,207.30 0.78 4,692.98 MWD+IFRAK-0AZSC(4) 9-5/8"x12-1/4" 8,968,80 45.18 308.34 7,156.98 7,068.28 2.871.11 -3,954.29 5,946509.91 313,176.83 0.78 4,731.51 MWD+IFR-AK-CAZSC(4) 9,049.52 44.64 308.19 7,214.15 7,125.45 2,906.40 -3,999.04 5,998,546.27 313,132.96 0.08 4,787.21 MWD+IFRAK-CAZSC(4) 9,143.80 45.26 308.27 7,280.87 7,192.17 2,947.62 -4,051.36 5,948,588.75 313,081.66 0.06 4,852.31 MWD+IFRAK-CAZSC(4) 9,238.18 45.65 309.51 7,347.08 7,258.38 2,989.85 4103.71 5,948,632.24 313,030.35 1.02 4,918.20 MND+IFRAK-CAZSC(4) 9,332.26 48,44 311.66 7,411.19 7,322.49 3,034.66 4,155.97 5,948,678.30 312,979.20 3.40 4,986.03 MWD+IFRAK-CAZSC(4) 9,426.43 51.49 311.06 7,471.75 7,383.05 3,082.29 -4,210.09 5.948,727.23 312.926.26 3.28 5,057.21 MWD+IFRAK-CAZSC(4) 9,519.61 54.02 311.03 7,528.14 7,439.44 3,130.99 4,266.03 5,948,777.27 312,871.52 2.72 5,130.38 MWD+IFRAK-WSC(4) 9,614.22 55.94 310.88 7,582.44 7,493.74 3,181.78 4,324.54 5,948,829.46 312,814.26 2.03 5,206.80 MWD+IFRAK-0AZSC(4) 9,706.62 59.30 31269 7,631.91 7,543.21 3,23378 4,382.70 5,948,882,85 312,757.39 3.99 5,283.93 MWD+IFRAK-CAZSC(4) 9,801.05 61.09 315.59 7,678.86 7,590.16 3,290.84 4,441.48 5,948,941.33 312,700.01 3.27 5,365.35 MND+IFR-AK-CAZSC (4) 9,895.24 63.67 318.04 7722.52 7,633.82 3,35170 4,498.56 5,949,003.55 312,644.43 3.58 5,448.62 MND+IFRAK-0AZSC(4) 87152078 5:00:49PM Page 6 COMPASS 500014 Build 85 10.1 ConocoMillips ConocoPhillips Definitive Survey Report BTER Company: COnocoPhilkps(Alaska) Inc. -WNS Local Coordinate Reference: Well MT6-05 Project: Western North Slope TVD Reference: MT6-05 Actual @ 88.70usft (Actual D19) Site: GMTI Lookout Pad MD Reference: MT6-05 Actual @ 88.70usft (Actual D19) Well: MTS -05 North Reference: Two Wellbore: MT6.05 Survey Calculation Method: Minimum Curvature Design: MT6.05 Database: EDT 14 Alaska Production Survey 87152018 5:00:49PM Page 7 COMPASS 5000.14 Build 85 al MD Inc AZI ND TVDSS +W3 +E/ -W Entire Northing DLS cti Section on Survey Tool Nam Annotation (corm 0 h) (uslt) (uaft) (ustq (usft) (ft) (ft) ('1100') (ft) 9,989.62 65.86 320.87 7,762.77 7,674.07 3,416.57 41,554.04 5,949,069.74 312,590.55 3.57 5,533.97 MWD+IFR-AK-0AZSC(4) 10,083.55 68.49 323.03 7,799.20 7,710.50 3,484.75 4.607.37 5,949,139.19 312,538.89 3.51 5,620.50 MWDNFRAK-CAZSC(4) 10,178.42 71.79 324.53 7,831.43 7,742.73 3,556.72 4,660.08 5,949,212.42 312,487.95 3.78 5,709.56 MND+IFRAK-CAZSC(4) 10,271.93 73.35 325.90 7,859.44 7,770.74 3,630.00 4,710.97 5,949,286.90 312,438.85 2.18 5,798.46 MND+IFR-AK-CAZSC (4) 10,366.04 75.73 327.31 704.53 7,795.83 3,705.72 4,760.88 5,949.363.81 312,390.80 2.91 5,888.64 MWD+IFRAK-CAZSC(4) 10,460.54 77.60 329.31 7,906.32 7,817.62 3,783.96 4,809.18 5,949,443.20 312.344.42 2.86 5,979.72 MWD+IFRAK-CAZSC(4) 10,555.35 79.69 330.90 7,924.99 7,836.29 3,864.64 4,855.50 5,949.524.87 312,300.07 2.75 6,071.35 MWD+IFRAK-CAZSC(4) 10,650.00 81.37 331.55 7,940.56 7,851.86 3,946.37 4,900.44 5,949,607.76 312,257.14 1.90 6,163.06 MWD+IFRAK-CAZSC(4) 10,745.13 KAI 333.18 7,953.98 7,865.28 4,029.80 4,944.12 5,949,692.23 312,215.50 2.02 6,255.21 MWDNFRAK-CAZSC(4) 10,839.12 82.85 332.20 7,966.04 7,877.34 4,112.62 4,996AS 5,949,776.06 312,174.76 1.14 6,346.31 MWD+IFRAWCAZSC(4) 10,933.60 82.85 332.88 7,977.79 7,889.09 4,195.72 -5,030.07 5,949,860.17 312,133.61 0.71 6,437.88 MWD+IFRAK-CAZSC(4) TIP to MT6-05PB1 10,939.00 82.85 332.88 7,978.47 7,889.77 4,200.57 -5,032.55 5,949,665.09 312,131.24 0.00 6,443.21 MWD -INC ONLY(INC>1W)(6) KOPTOWS 11,017.93 88.35 332.89 7,984.53 7895.83 4,270.60 5,068.41 5,949,935.98 312,097.10 6.97 6,520.03 MWD -INC ONLY (INC>10°)(5) Interpolated Azimuth 11,114.28 96.19 332.91 7,980.71 7,892.01 4,356.23 5,112.23 5,950,022.63 312,055.37 8.14 6.613.97 MWD -INC -ONLY (INC>10') (5) Interpolated Azimuth 11,165.98 96.45 332.92 7,975.02 7,886.32 4,401.98 5,135.63 5,950,068.93 312,033.10 0.50 6,664.15 MND+IFRAK-CAZSC(6) 11,261.04 93.41 330.40 7,966.85 7,878.15 4,485.32 5,180.58 5.950.163.33 311,990.18 4.15 6,757.04 MWD+IFRAK-0AZSC(6) 11,355.57 90.99 326.47 7,96322 7,874.52 4.565.78 -5,230.02 5,950,234.96 311,942.72 4.88 6,850.56 MND+IFRAK-CAZSC(6) 11,460.97 90.97 327.33 7,961.59 7,872.89 4,645.69 5,282.11 5,950,316.11 311,892.59 0.90 6,945.34 MWD+IFRAK-CAZSC(6) 11,546.74 90.44 328.32 7,980.41 7,871.71 4,726.74 5,333.10 5,950,398.37 311,843.58 1.17 7,040.31 MWD+IFRAK-CAZSC(6) 11,641.91 90.04 331.42 7,960.01 7,871.31 4,809.04 5,380.87 5,950,481.80 311,797.83 3.28 7,134.19 MWD+IFRAK-CAZSC(6) 11,722.27 90.05 332.93 7,959.95 7,871.25 4,880.11 5,418.37 5,950,553.75 311,762.07 1.88 7,212.87 MWD+IFRAK-CAZ-SC (6) MTB-0SLi T1.9 (copy) 11,736.95 90.05 333.21 7,959.94 7,871.24 4,893.20 5,425.02 5,9WS67.00 311,75574 1.88 7,227.20 MNDNFRAK-CAZSC (6) 11.832.03 89.98 331.26 7,959.91 7,871.21 4,977.33 -5,469.31 5,950,652.17 311,713.50 2.05 7,320.27 MWD+IFRAK4AZ-SC(6) 11,927.45 89.98 330.12 7,959.95 7,871.25 5,060.53 -5,516.02 5,950,736.48 311,668.83 1.19 7,414.18 MWD+IFRAK-CAZSC(6) 12,023.13 91.65 331.09 7,958.59 7,869.89 5,143.88 .5,562.98 5,950.620.94 311,623.92 2.02 7,508.35 MWD+IFRAK-CAZSC(6) 12,118.47 92.01 333.54 7,955.54 7,866.84 6,228.26 5,607.25 5,950,906.36 311,581.71 2.60 7,601.60 MWD+IFRAK-C SSC (6) 12,213.86 93.12 334.95 7,951.27 7,862.57 5,314.08 5,648.66 5,950,993.16 311,542.40 1.88 7,694.14 MND+IFRAK-CAZSC(6) 12,309.33 92.96 334.30 7,946.21 7,857.51 5,400.22 5,689.51 5,951,080.26 311,603.66 0.70 7,786.58 MWD+IFRAK-CA7SC(6) 12,403.76 93.00 334.29 7,941.30 7.852.60 5,485.19 -5,730.41 5,951,166.19 311,464.83 0.04 7,878.15 MWDNFRAK-CAZSC(6) 12,499.21 92.96 333.07 7,936.34 7,847.64 5,670.63 -5,772.68 5.951,252.63 311,424.65 1.28 7,970.94 MWD+IFRAK-CAZSC(6) 12,594.99 93.03 333.05 7,931.33 7,842.63 5,655.90 5.816.01 5,951,338.92 311,383.41 0.08 8,064.29 MWD+IFRAK-0AZSC(6) 87152018 5:00:49PM Page 7 COMPASS 5000.14 Build 85 Survey ConocoPhillips ConocoPhiiiip5 Definitive Survey Report Company: ConocoPhillips(Alaska) Inc. •WNS Local Coordinate Reference: Well MTS -05 Project: Westsm North Slope TVD Reference: MT6-05 Actual @ 88.70usft (Actual D19) Site: GMT1 Lookout Pad MD Reference: MT6-05 Actual @ 88.70usft (Actual 019) Well: MTS -05 North Reference: True Wellbore: MT6-05 Suney Calculation Method: Minimum Curvature Design: MT"5 Database: EDT 14 Alaska Production Survey I a 8/152018 5+00:49PM Page 8 COMPASS 5000.14 Build 85 While Map Vertical MD Inc Azl TVD TVDSS +NAS +Ef-W Northing Euffng DLS Section Survey Tool Name Annotation ("ft) (h M (-ft) Wish) (-it) (=it) (10 it" ('Magi (to 12,690.05 92.53 334.19 7,926.72 7,838.02 5,740.96 5,858.20 5,951,424.97 311,343.30 1.31 8,156.74 MM+IFR-AK-0AZSC (6) 12785.29 92.50 336.36 7,922.54 7,833.84 5,827.38 5,897.99 5,951,512.33 311,305.62 2.28 8,248.72 MWD+IFR-AK-CAZSC(6) 12,880.47 92.50 337.59 7,918.39 7,829.69 5,914.89 5,935.18 5,951,600.71 311,270.57 1.29 8,339.88 MWD+IFRAWCAZSC(6) 12,975.80 91.54 337.73 7,915.03 7,826.33 6,003.01 5,971.40 5,951,689.68 311,236.51 1.02 8,430.89 MWD+IFRAK-CAZSC(6) 13,071.06 89.96 338.31 7,913.77 7,825.07 6,091.33 5,007.05 5,951,778.84 311,203.02 1.75 8,521.70 MNID+IFRAK-CAZSC (6) 13,166.38 89.06 338.79 7,914.57 7,825.87 6,180.05 5,041.90 5,951,868.37 311,170.33 1.09 8,612.31 MWD+IFRAWCAZSC(6) 13,261.35 88.81 338.95 7,916.33 7,827.63 6,268.62 5,076.13 5,951,957.74 311,138.26 0.31 8,702.40 MNANFRAK-CAZSC(6) 13,357.10 88.44 337.83 7,918.63 7829.93 6,357.61 5,111.38 5,952,047.55 311,105.19 1.23 8,79347 MWD+IFRAK-CAZSC(6) 13,451.89 88.61 337.02 7,921.07 7,832.37 6,445.11 5,147.76 5,952,135.90 311,070.95 0.87 8,884.11 MWD+IFRAK-CAZSC(6) 13,547.41 88.48 334.06 7,923.49 7,834.79 6,532.01 5,187.29 5,952,223.74 311,033.54 3.10 8,976.30 MWD+IFRAK-0AZSC(6) 13,642.74 89.99 333.10 7,924.77 7,836.07 6,617.38 5,229.70 5,952,310.10 310,993.21 1.88 9,069.13 MWD+IFRAK-CAZSC(6) 13,737.96 89.98 332.11 7,924.79 7,836.09 6,701.92 5,273.52 5,952,395.68 310,951.47 1.04 9,162.21 MWD+IFRAK-CAZSC(6) 13,833.14 89.98 331.46 7,924.83 7,836.13 6,785.79 5,318.52 5,952,480.61 310,908.52 0.68 9,255.54 MWD+IFRAK-CAZSC(6) 13,928.34 89.98 330.15 7,924.86 7,836.16 6,868.89 5,364.95 5,952.564.81 310,864.12 1.38 9,349.19 MND+IFRAKCAZSC(6) 14,023.35 90.05 331.50 7,924.83 7,836.13 6,951.85 5,411.27 5,952,648.86 310,819.84 1.42 9,442.65 MWD+IFRAK-CAZSC(6) 14,118.55 92.67 331.23 7,922.57 7,833.87 7,035.37 5,456.87 5,952,733.47 310,776.28 2.77 9,536.09 MWD+IFRAK-CAZSC(6) 14,213.17 93.00 332.19 7,917.89 7,829.19 7,118.59 5,501.66 5,952,817.74 310,733.53 1.07 9,628.78 MWD+IFRAK-CAZSC(6) 14,308.11 94.04 332.59 7,912.07 7,823.37 7,202.56 5.545.58 5.952.902.74 310,691.67 1.17 9,721.49 MWD+IFRAK-CAZSC(6) 14,403.68 93.98 334.20 7,905.38 7,816.68 7,287.79 5,588.27 5,952,988.99 310,651.06 1.68 9,814.41 MWD+IFRAK-0AZSC(6) 14,499.04 94.04 334.70 7,898.71 7,810.01 7,373.62 5,629.30 5,953,075.78 310,612.13 0.53 9,906.71 MND+IFR-AK-CAZSC(6) 14,594.34 92.96 339.94 7,892.89 7,804.19 7,461.35 5,665.96 5,953,164.37 310,577.61 5.60 9,997.71 MWDNFRAK-CAZSC(6) 14,689.67 91.62 334.33 7,888.91 7,800.21 7,549.08 5.702.96 5,953,252.97 310,542.76 6.00 10,088.92 MWD+IFRAKCAZSC(6) 14,784.76 90.99 333.89 7,8%.58 7,797.88 7,634.60 5,744.46 5,953,339.46 310,503.34 0.99 10,181.29 MM+IFR-AKCAZSC(6) 14,880.4D 91.03 333.42 7,884.90 7,796.20 7,720.29 4786.90 5,953,426.16 310,463.00 0.49 10,274.39 MND+IFRAKCAZSC (6) 14,975.55 89.98 334.37 7,884.08 7,795.36 7,805.73 5,828.76 5,953,512.68 310,423.23 1.49 1D,366.93 MWD+IFR-AKCAZSC(6) 15,071.10 68.99 333.68 7,884.92 7,796.22 7,891.62 5,870.61 5,953,59946 310,383.48 1.26 10,459.81 MMD+IFRAKCAZSC (6) 15,165.21 88.01 332.09 7,887.38 7,798.68 7,975.36 5.913.49 5,953,684.21 310,342.66 1.98 10,551.68 MWD+IFRAKCAZSC(6) 15,195.00 68.01 332.09 7,888.41 7,799.71 6,001.67 5.927.42 5,953,710.84 310,329.36 0.00 10,580.84 PROJECTEDIOTD 4-1/2"K6" I a 8/152018 5+00:49PM Page 8 COMPASS 5000.14 Build 85 Cement Detail Report �A., 11 "�01'� MT6-05 NwString: Conductor Cement Job: DRILLING ORIGINAL, 5/11/2018 00:00 Cement Details Description Conductor Cement Cementing Start Date 2/6/201614:00 Cementing End Date 2/61201616:00 Wellbore Name MT6-05 Comment Cement Stages Stage # 1 Description Conductor Cement Objective Top Depth (ftKB) Cement Conductor 36.5 Bottom Depth (ftKB) 115.0 Full Return? No Vol Cement... Top Plug? No Btm Plug? No Q Pump Init (bbl/m... Q Pump Final (bbl/... Q Pump Avg (bbl/... P Pump Final (psi) P Plug Bump (psi) Recip? No Stroke (ft) I Rotated? No Pipe RPM (rpm) Tagged Depth (ftKB) Tag Method Depth Plug Drilled Out To (ftKB) Drill Out Diameter (in) Comment Cement Fluids & Additives Fluid Fluid Type Fluid Description Estimated Top (ftKB) Est Stan (ftKB) Amount (sacks) Class Volume Pumped (bbl) Yield (ft'Isack) Mix H2O Ratio (gal/sa... Free Water I%) Density (lb/gal) Plastic Viscosity (CP) Thickening Time (hr) CmprStr 1 (psi) Additives Additive Type Concentration Cone Unit label Page 1/1 Report Printed: 8113/2018 Cement Detail Report MT6-05 String: Surface Casing Cement Job: DRILLING ORIGINAL, 5/11/2018 00:00 Cement Details Description Surface Casing Cement Cementing Start Date 5/14/2018 23:00 Cementing End Date 5/15/2018 02:36 Wellbore Name MT6-05 Comment Cement Stages Stage # 1 Description Surface Casing Cement Objective Top Depth (ftKB) Cement Surface Casing 36.5 Bottom Depth (ftKB) 2,014.5 Full Retum?Vol Yes Cement... 169.0 Top Plug? Yes Btm Plug? Yes Q Pump Init (bbl/m... 8 Q Pump Final (bblif 3 Q Pump Avg (bbl/... 8 P Pump 420.0 Final (psi) P Plug Bump (psi) Recip? 920.0 1 Yes Stroke (ft) 20.00 Rotated? No I Pipe RPM (rpm) Tagged Depth (ftKB) Tag Method Depth Plug Drilled Out To (ftKB) Drill 112114 Out Diameter (In) Comment 169 bbls good cement to surface Cement Fluids & Additives Fluid Fluid Type Lead Cement Fluid Description Estimated Top (ftKB) 36.5 Est Btm (ftKB) 1,514.0 Amount (sacks) 1,044 Class LiteCRETE Volume Pumped (bbl) 357.0 Yield (ft/sack) 1.92 Mix H2O Ratio (gal/sa... 6.88 Free Water (%) 1 Density (lb/gal) 11.00 Plastic Viscosity (cP) 258,000.0 I Thickening Time (hr) 14.52 CmprStr 1 (psi) Additives Additive Type Concentration Cone Unit label Fluid Fluid Type Tail Cement Fluid Description Estimated Top (ftKB) 1,514.0 Est Bum (ftKB) 2,014.5 Amount (sacks) 350 Class Volume G 72.3 Pumped (bbl) Yield (ft/sack) 1.16 Mix H2O Ratio (gal/sa... 5. Free Water (%) 1 Density (Ib/gal) 15.80 Plastic Viscosity (cP) 145,000.0 IThickening Tlme (hr) CmprStr 14.50 1 (psi) Additives Additive Type Concentration Cone Unit label Page 111 Report Printed: 8/13/2018 Cement Detail Report MT6-05 String: Intermediate Casing Cement Job: DRILLING ORIGINAL, 5/11/201800:00 Cement Details Description Intermediate Casing Cement Cementing Start Date. 5/22/2018 04:30 Cementing End Date 5122/2018 07:30 Wellbore Name MT6-05 Comment Cement Stages Stage # 1 Description Intermediate Casing Cement Objective Top Depth (ftKB) Isolate 9-518" Casing 7,921.0 Shoe Bottom Depth (ftKB) 8,920.8 Full Return? Yes Vol Cement... Top Plug? Yes Btm Plug? Yes Q Pump Init (bbl/m... 8 Q Pump Final (bbl/... 3 IQ Pump Avg (bbl/... 8 P Pump Final (psi) 530.0 P Plug Bump (psi) Reclp? Yes Stroke (ft) 7.00 Rotated? No Pipe RPM (rpm) Tagged Depth (ftKB) Tag Method Depth Plug Drilled Out To (ftKB) Drill 8 Out Diameter (in) 314 Comment Did not bump plug, floats held. CIP = 7:21 His Cement Fluids & Additives Fluid Fluid Type Lead Cement Fluid Description Estimated Top (ftKB) 7,921.0 Est Btm (ftKB) 8,421.0 104 Amount (sacks) Class G Volume Pumped (bbl) 42.7 Yield (ft /sack) 2.31 Mix H2O Ratio (gallsa... 13.09 Free Water (%) Density (lb/gal) 12.20 Plastic Viscosity (cP) 47,000.0 IThickening Time (hr) 18.00 CmprStr 1 (psi) Additives Additive Type Concentration Conc Unit label Fluid Fluid Type Tail Cement Fluid Description ESUnli ed Top (ftKB) 8,421.0 Est Btm (ftKB) Amount 8,920.9 241 (sacks) Class G Volume Pumped (bbl) 49.8 Yield (ft /sack) 1.16 Mix H2O Ratio (gal/sa... 5.08 Free Water (%) 1 Density (lb/gal) Plastic 1 15.80 138,000.0 Viscosity (cP) IThIckening Time (hr) 14.45 CmprStr 1 (psi) Additives Additive Type Concentration Conc Unit label Page 111 Report Printed: 8 /1 312 01 8 }, Cement Detail Report MT6-05 String: Liner Cement Job: DRILLING ORIGINAL, 51111201800:00 Cement Details Description Liner Cement Cementing Start Date 5/29/2018 16:30 Cementing End Date 5/29/2018 19:30 Wellbore Name MT6-05 Comment Cement Stages Stage # 1 Description Liner Cement Objective Cement liner Top Depth (ftKB) 9,664.0 Bottom Depth (ftKB) 11,164.0 Full Return? No VolCement... 5.0 Top Plug? NOT BITPlug? No Q Pump Init (bbl/m... 2 1 0 Pump Final (bbl/... 1 Q Pump Avg (bbl/... 2 P Pump 580.0 Final (psi) P Plug Bump (psi) Recip? No I Stroke (ft) Rotated? No I Pipe RPM (rpm) Tagged Depth (ftKB) Tag Method Depth Plug Drilled Out To (ftKB) Drill Out Diameter (in) Comment 32.2 bbl 12.2 Lead, 26 bbl 15.8 ppg Tail. Cement Fluids & Additives Fluid Fluid Type Lead Cement Fluid Description Estimated Top (ftKB) 9,664.0 I Est Btm (ftKB) 10,664.0 Amount (sacks) 78 Class G Volume Pumped (bbl) 32.2 Yield (ft /sack) 2.30 Mix H2O Ratio (gal/sa... 13.16 Free Water (k) Density (Ib/gal) 12.20 Plastic Viscosity (cP) 13.8 Thickening Time (hr) 6.00 CmprStr 1 (psi) Additives Additive Type Concentration Cone Unit label Fluid Fluid TypeFluid Tail Cement Description Estimated Top (ftKB) 10,664.0 Est Bum (ftKB) Amount 11,164.0 126 (sacks) Class G Volume Pumped (bbl) 26.0 Yield (iP/sack) 1.16 Mix H2O Ratio (gal/sa... 5.08 Free Water (%) 1 Density (1b/gal) Plastic 15.80 107.9 Viscosity, (CP) Thickening Time (hr) 4.50 CmprStr 1 (psi) Additives Additive Type Concentration Conc Unit label Page 1/1 ReportPrinted: 8113/2018 l; Cement Detail Report MT6-05 String: Cement Plug Job: DRILLING ORIGINAL, 5/11/2018 00:00 Cement Details Description Cementing Start Date CemeMing End Date Wellbore Name Cement Plug 6/12/201821:30 6/12/201822:30 MT6-05PB1 Comment Cement Stages Stage # 1 Description Objective Top Depth (ftKB) Bottom Depth (ftKB) Full Return? Vol Cement... Top Plug? Btm Plug? Abandonment Plug Isolate BHA#7 & 11,127.5 11,233.0 Yes No No abandon production #1 Q Pump Init (bbl/m... Q Pump Final (bbl/... Q Pump Avg (bbg... P Pump Final (psi) P Plug Bump (psi) lRecipl Stroke (ft) Rotated? Pipe RPM (rpm) 6 3 5 400.0 1 1 Yes 130.00 No Tagged Depth (ftKB) Tag Method Depth Plug Drilled Out To (ftKB) Drili Out Diameter (in) 10,627.0 Drill Bit 11,128.0 6 Comment Abandonment plug 11,233' to TOC 10,627' Polished off plug to 11,127.5' Cement Fluids 8. Additives Fluid Fluid Type Fluid Description Estimated Top (ftKB) I Est Bun (ftKB) Amount (sacks) Class Volume Pumped (bbl) Abandonment 11,127.5 11,233.0 121 G 22.9 Cement Yield (fP/sack) Mix N20 Ratio (gal/sa... JFree Water (%) Density (lb/gal) Plastic Viscosity (CP) Thickening Time (hr) CmprStr 1 (psi) 1.06 4.33 1 16.50 130.0 I 6.50 Additives Additive Type Concentration Conc Unit label Page 1/1 ReportPrinted: 811312018 THE STATE °fALASKA GOVERNOR BILL WALKER Chip Alvord Drilling Manager ConocoPhillips Alaska, Inc. PO Box 100360 Anchorage, AK 99510-0360 Alaska Oil and Gas Conservation Commission 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 www.aogcc.alo5ka.gov Re: Greater Mooses Tooth Unit, Alpine Undefined Pool, MT6-05L1 ConocoPhillips Alaska, Inc. Permit to Drill Number: 218-046 Surface Location: 261' FNL, 3171' FEL, SEC, 6, TI ON, R3E, UM Bottomhole Location: 1358' FNL, 585' FEL, SEC. 26, TI IN, R2E, UM Dear Mr. Alvord: Enclosed is the approved application for permit to drill the above referenced development well. The permit is for a new wellbore segment of existing well Permit No. 218-045, API No. 50-103- 20771-00-00. Production should continue to be reported as a function of the original API number stated above. Per Statute AS 31.05.030(d)(2)(B) and Regulation 20 AAC 25.071, composite curves for well logs run must be submitted to the AOGCC within 90 days after completion, suspension or abandonment of this well. This permit to drill does not exempt you from obtaining additional permits or an approval required by law from other governmental agencies and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the AOGCC reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the AOGCC specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or an AOGCC order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. Sincerely, Hollis S. French Chair k� DATED this z -G day of April, 2018. ' STATE OF ALASKA AL _KA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 AAC 25.005 REUEIVED A 00 ! 7fS1R 1a. Type of Work: . tb. Proposed Well Class: Exploratory -Gas Service - WAG Service - Disp ❑ tc. Specify if well is proposed for: Drill ❑ Lateral ❑� Stratigraphic Test ❑ Development - Oil ❑� ' Service - Winj ❑ Single Zone ❑� ' Coalbed Gas ❑ Gas Hydrates ❑ Redrill ❑ Reentry ❑ Exploratory - Oil ❑ Development - Gas ❑ Service - Supply ❑ Multiple Zone ❑ Geothermal ❑ Shale Gas ❑ 2. Operator Name: 5. Bond: Blanket Single Well 11. Well Name and Number: ConocoPhillips Alaska, Inc. Bond No. 59-52-180 MT6-05L1 ' 3. Address: 8. Proposed p / Depth:6918 12. P.O. Box 100360 Anchorage, AK 99510-0360 DTVD: 7 1017,8'0 Greater Mosses Tooth Unit Alpine Undefined Oil 4a. Location of Well (Governmental Section): 7. Properly Designation: I Surface: 261' FNL, 3171' FEL, Sec. 6, T10N, R3E, UM AA081798,AA081818,AA092346 ?4.1g, .Ig Top of Productive Horizon: 8. DNR Approval Number: 13. Approximate Spud Date: 1354' FNL, 3186' FEL, Sec. 36, T11 N, R2E, UM 932,533,000,932,553 000,000,000,000 5/10/2018 ' 9. Acres in Pro erty: 14. Distance to Nearest Property: Total Depth: 1358' FNL, 585' FEL, Sec. 26, TI IN, R2E, UM 833 S(v y ( .� �� e 1358'to AA081819 4b. Location of Well (State Base Plane Coordinates - NAD 27): 10. KB Elevation above MSL (ft): 70 • 15. Distance to Nearest Well Open Surface: x- 317060 y- 5945544 Zone -4 GL / BF Elevation above MSL (ft): 34 - to Same Pool: 4300' to MT6-03 16. Deviated wells: Kickoff depth: 10850 feet 17. Maximum Potential Pressures in psig (see 20 AAC 25.035) Maximum Hole Angle: 90 degrees Downhole: 3810 Surface: 3100 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" 78.6 H-40 Welded 79 36 36 115 115 10 yds 16" 13-3/8" 68 L-80 H563/rXP 2018 36 36 - 2054 2033 942 sx 11.0 ppg Lead, 12-1/4" 9-5/8" 40 L-80 TXP/TN-80 8946 36 36 - 8982 7099 216 sx 15.8ppg Class G HC 6"x8-3/4" 7" liner 26 L-80 BTC/Blue 2200 8800 6971 - 11000 7959 464 sx Class G 15.8 ppg cemented to 6" 4.5" liner 12.6 L-80 TXP 6098 10820 7952 - 16918 7970 Uncemented open hole 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 Voluma MD TVD Conductor/Structural Surface Intermediate Production Liner Perforation Depth MD (ft): Perforation Depth TVD (ft): Hydraulic Fracture planned? Yes ❑ No ❑ 20. Attachments: Property Plat ❑ Sketch B rillingh Plot DHazard Analysi's Pro B 8✓ DivertOP er Sketch Drilling Fluid AAC 25.050 requirements 4 Report Program 20 21. Verbal Approval: Commission Representative: Date 22. 1 hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Contact Name: Weifeng Dai I/'�' Qo^1 Authorized Name: Chip Alvord Contact Email: WelfeO .Dal CO .COOL Authorized Title: Drilling Manager Contact Phone: 907-265-1077 e� Authorized Signature:. G,. Date: Commission Use Only Permit to DrillAPI Number: 150_16j Permit Approval See cover letter for other Number: F' — 2-077,(-60—OD Date: l requirements. Conditions of approval : If box is checked, well may not be used to explore for, test, or produce coalbed methane, gas hydrates, or gas contained in shales: ,�/ Other: /1 n .T /.— Samples req'd: Yes ❑ No(;O Mud log req'd: Yes[❑✓No U+' j5� o� G94p to / HzS measures: Yes Nom❑-,/ Directional svy req'd: Yes L� No,❑/ Spacing exception req'd: Yes ❑ NoLJ Inclination -only svy req'd: Yes E] No❑✓ Post initial injection MIT req'd: Yes ❑ No❑ APPROVED BY 1 e, Approved by: O THE COMMISSION Date5ubmft Form and onn ews - riot mev •up101e" ConocoPhillips Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907-276-1215 April 5, 2018 Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 Re: Application for Permit to Drill CRU MT6-05L1 Dear Sir or Madam: ConocoPhillips ConocoPhillips Alaska, Inc. hereby applies for a Permit to Drill an onshore production well from the GMT -1 drilling pad with rig Doyon 19. The intended spud date for this well could be as early as 05/05/2018. MT6-05L1 is planned to be an Alpine C Sand upper lateral producer out of the MT6-05 parent well (covered in separate PTD). When the MT6-05L1 is commenced, the parent well will have run and cemented 13-3/8" surface casing to above the C30 Sand. 9-5/8" intermediate 1 casing will have been run and cemented in this HRZ shale. A 7" steerable liner is run and cemented through shale and land horizontally in the target sand. A 6" lateral will have been drilled in the Alpine C Lower Sand and lined with a 4-3/4" liner, with a whipstock set for the MT6-05L1 kickoff in the Alpine Upper C Sand. NI/z " The MT6-05L 1 lateral will then be drilled in the Alpine Upper C Sand and lined with,4,314" liner. A hook hanger and LEM system will be installed at the junction for future lateral accessiblity. The well will be completed with a 4.5" upper completion. A waiver is requested to set the production packer at 72" inc as per 20 AAC 25.412(b).`fi req I ( 0� � ) Please find attached the information required by 20 AAC 25.005 (a) andc for your review../ Pertinent information attached to this application includes the following: 1. Form 10-401 Application For Permit to Drill per 20 AAC 25.005 (a) 2. A proposed drilling program 3. A proposed completion diagram 4. A drilling fluids program summary 5. Pressure information as required by 20 AAC 25.035 (d)(2) 6. Directional drilling / collision avoidance information as required by 20 AAC 25.050 (b) 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 AAC 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 Weifeng Dai at 2634324 (weifeng.dai@ConocoPhillips.com) or Chip Alvord at 265-6120. ��V����� Sincerely, cc: MT5-05L1 Well File / Ann Haggerty -Sherrod ATO 1530 Johnson Njoku ATO 1720 Chip Alvord ATO 1570 Weifeng Dai Viet Nguyen ATO 1788 Staff Drilling Engineer Lanston Chin Kuukpik Corp Apply .on for Permit to Drill, Well MT6-051-1 Saved: 4 -Apr -18 MT6-05L1 Application for Permit to Drill Document H Table of Contents 1. Well Name (Requirements of 20 AAC 25.005 ()9)............................................................ 3 2. Location Summary (Requirements of 20 AAC 25.005(c)(2)) ............................................ 3 Requirements of20 AAC 25.050(b)............................................................................................................. 3 3. Blowout Prevention Equipment Information (Requirements of 20 AAC 25.005(c)(3)) 3 4. Drilling Hazards Information (Requirements of20 AAC 25.005 (c)(4)) ........................ 4 5. Procedure for Conducting Formation Integrity Tests (Requirements of20 AAC 25.005 (c)(5))......................................................................................................................... 5 6. Casing and Cementing Program (Requirements of 20 AAC 25.005(c)(6)) .......... 5 7. Diverter System Information (Requirementsof20AAC25.005(c)(7)).........................5 8. Drilling Fluid Program (Requirements of20 AAC 25.005(c)(8)) ....................................6 9. Abnormally Pressured Formation Information (Requirements of20AAC25.005 (c)(9)) ................................................................................................................................... 7 10. Seismic Analysis (Requirements of20 AAC 25.005 (c)(10)) ......................................... 7 11. Seabed Condition Analysis (Requirements of20 AAC 25.005 (e)(11)) ........................ 7 12. Evidence of Bonding (Requirements of20 AAC 25.005 (c)(12)) ................................... 7 13. Proposed Drilling Program (Requirements of20 AAC 25.005 (c)(13)) .........................7 14. Discussion of Mud and Cuttings Disposal and Annular Disposal ....................... 8 (Requirements of 20 AAC 25.005(c)(14))............................................................................. 8 15. Attachments............................................................................................................... 9 AttachmentI Cement Summary ................................................................................................................. 9 MT6-05L1 APD Page 1 of 14 Printed.: 4 -Apr -18 App._.,ion for Permit to DOII, Well FPI-6-05L1 Saved: 4 -Apr -18 Attachment 1 Drilling Hazards Summary .............................................................................. Attachment 3 Completion Schematic..................................................................................... Attachment 4 Directional Plan............................................................................................. MT6-05L 1 APD Page 2 of 14 Printed. 4 -Apr -18 App .on for Permit to Drill, Well MT6-051-1 Saved: 4 -Apr -18 1. Well Name (Requirements of20AAC25.005 (n) The well for which this application is submitted will be designated as MT6-05L1. 2. Location Summary (Requirements of20 AAC 25.005(c)(2)) Location at Surface 261' FNL 3171' FEL, Sec. 6 T10N, RM, UM NAD 1927 Northings: 5,945,544 Eastings: 317,060 RKB Elevation 70.0' AMSL Pad Elevation 34'AMSL ' Top of Productive Horizon eel 1354' FNL, 3186' FEL Sec. 36, TI IN, R2E, UM NAD 1927 Northings: 5,949,853 Eastings: 312,133 Measured De th, RKB: 11,000' Total Vertical De th, RKB: 7,959' Total Vertical Depth, SS: 1 7,879' Total Depth Upper C Lateral Toe 1358' FNL 585' FEL Sec. 26, TI IN, R2E, UM NAD 1927 Northings: 5,955,194 Eastings: 309,583 Measured Depth, RKB: 16,919' Total Vertical Depth, RKB: 7,970' Total Vertical De t& SS: 7,900' Total Depth Lower C Lateral Toe 1358' FNL, 585' FEL, Sec. 26, T11N R2E, UM NAD 1927 Northings: 5,955,194 Eastings: 309,583 Measured De th, RKB: 16,919' Total Vertical De th, RKB: 7,970' Total Vertical De th, SS: 7,900' Requirements of 20 AAC 25.050(6) Please see Attachment 4: Directional Plan The Applicant is the only affected owner. 3. Blowout Prevention Equipment Information (Requirements of20AAC25.005(c)(3)) Please reference BOP and diverter schematics on file for Doyon 19. MT6-05L1 APD Page 3 of 14 Printed: 4 -Apr -18 App .ion for Permit to Drill, Well MT6-051-1 Saved: 4 -Apr -18 4. Drilling Hazards Information (Requirements of20AAC25.005(c)(4)) The following presents data used for calculation of anticipated surface pressure (ASP) during drilling of this well: Casing Size in Csg Setting Depth MD/TVD ft Fracture Gradient(psi) Pore pressure ASP Drilling (psi) 20 1151115 10.9 52 54 13.375 2054/2033 14.5 910 1,330 9.625 8982/7099 13.5 3,176 3,100 7 11000/7959 12.5 3,810 2,977 4.5 16919/7970 12.5 3,773 N/A PROCEDURE FOR CALCULATING ANTICPATED SURFACE PRESSURE (ASP) ASP is determined as the lesser of 1) surface pressure at breakdown of the formation casing seat with a gas gradient to the surface, or 2) formation pore pressure at the next casing point less a gas gradient to the surface as follows: 1) ASP= [(FG x 0.052) - 0.1]•D Where: ASP = Anticipated Surface pressure in psi FG = Fracture gradient at the casing seat in 16/gal 0.052 = Conversion from Ib./gal to psi/ft 0.1 = Gas gradient in psi/ft D = true Vertical depth of casing seat in ft RKB OR 2) ASP=FPP-(O.1xD) Where: FPP = Formation Pore Pressure at the next casing point FPP = 0.4525 x TVD 1. ASP CALCULATIONS 1. Drilling below 20" conductor ASP = [(FG x 0.052) - 0.1] D =[(10.9x0.052) -0.1]x115=54 psi OR ASP = FPP - (0.1 x D) = 910 - (0.1 x 115') = 899 psi 2. Drilling below surface casing (13-3/8") ASP= [(FG x 0.052) - 0.1] D _ [(14.5 x 0.052) - 0.1] x 2033'= 1,330 psi OR ASP = FPP - (0.1 x D) = 3176 - (0.1 x 2033') = 2,973 psi - 3. Drilling below first intermediate casing (9-5/8") ASP = [(FG x 0.052) - 0.11 D _ [(13.5 x 0.052) - 0.1 ] x 7099 = 4,274 psi OR ASP = FPP - (0.1 x D) = 3810- (0.1 x 7099') = 3,100 psi MT6-05L1 APD Page 4 of 14 Printed: 4 -Apr -18 4. Drilling below production liner (7") OR ASP = [(FG x 0.052) — 0.1 ] D = [(12.5 x 0.052) — 0.11 x 7959 = 4,377 psi ASP= FPP — (0.1 x D) = 3773 — (0.1 x 7959) = 2,977 psi App( on for Permit to Drill, Well MT6-051-1 Saved: 4 -Apr -18 (B) data on potential gas zones; The well bore is not expected to penetrate any gas zones. (C) data concerning potential causes of hole problems such as abnormally geo-pressured strata, lost circulation zones, and zones that have a propensity for differential sticking, Please see Attachment 2 - Drilling Hazards Summary 5. Procedure for Conducting Formation Integrity Tests (Requirements of20AAC25.005 (0)(5)) Drill out surface casing shoe and perform LOT test or FIT in accordance with the Alpine LOT / FIT procedure that ConocoPhillips Alaska has on file with the Commission. 6. Casing and Cementing Program (Requirements of 20 AAC 25.005(c)(6)) Casing and Cementing Program Csg/Tbg Hole sae Weight Grade Conn. Length Top MDITVD Btm MDITVD Cement Program OD (in) (lbl t) (re) (R) (k) 20 42 79 H-40 Welded 80 Surf 115/115 Cemented to surface with 10 yds slurry H563/ Cement to Surface with 13-3/8 16 66 L-60 TXP 2,017 Surf 2,054 / 2,033 942 sx DeepCrete Lead at 11.0 ppg, 328 sx Class G Tail Slurry at 15.8 ppg TXP/ 9-5/8 12-1/4 40 L-80 TN -80 8945 Surf 8,982 / 7,099 216 sx Class G Tail at 15.8 ppg HC 7 6 x 8- 26 L-80 BTC/ 10,963 Surf 11,000 / 7,959 464 sx Class G 15.8 ppg cemented to liner 3/4 Blue top at 8,700' MD 4-1/2 n/a 12.6 L-80 563 9,763 Surf 00 / 7,903 n/a 41/2 6 12.6 L-80 TXP 6,066 10,850 / 7,940 [16,918/ 7,935 Uncemented open hole liner w/ pre - perforated pup joints 41/2 6 12.6 L-80 TXP 6,319 10, / 7,90319 / 7,970 Uncemeneted open hole liner w/ pre - perforated pup joints 7. Diverter System Information (Requirements of20AAC 25.005(c)O) This PTD refers only to the MT6-05L1 production lateral, where the BOPE will be rigged up. The MT6-05 PTD details surface section and request for waiver of the diverter requirement under 20 AAC 25.035 (h) (2). MT6-05L1 APD Page 5 of 14 Printed., 4 -Apr -18 App! an for Permit to Drill, Well MT6-051_1 Saved: 4Apr-18 8. Drilling Fluid Program (Requirements of20AAC25.005(c)(8)) Production Hole: -r 14F:� The horizontal production interval will be drilled with a oil-based mud drill -in fluid VersaPro weighted to 8.8-9.5 ppg with calcium carbonate. MPD will be used to hold back pressure, keeping the well dynamically balanced. Diagram of Doyon 19 Mud System on file. Drilling fluid practices will be in accordance with appropriate regulations stated in 20 AAC 25.033. MT6-05L1 APD Page 6 of 14 Printed: 4 -Apr -18 Production Hole Size in. 6.0 Casing Size in. 4.5 Density PPG 8.8 PV cp 15 YP Ib./100 15-20 ft, Funnel sht. 60-80 Viscosity Initial Gels Ib.1100 10 10 Minute Ib./100 15 Gels ft, API Fluid cc/30 4 0 Loss min. HPHT Fluid 130 10.0 Loss min. pH 9.0-9.5 Production Hole: -r 14F:� The horizontal production interval will be drilled with a oil-based mud drill -in fluid VersaPro weighted to 8.8-9.5 ppg with calcium carbonate. MPD will be used to hold back pressure, keeping the well dynamically balanced. Diagram of Doyon 19 Mud System on file. Drilling fluid practices will be in accordance with appropriate regulations stated in 20 AAC 25.033. MT6-05L1 APD Page 6 of 14 Printed: 4 -Apr -18 App( in for Permit to Drill, Well MT6-05L1 Saved: 4 -Apr -18 9. Abnormally Pressured Formation Information (Requirements of20AAC25.005(0)(9)) N/A - Application is not for an exploratory or stratigraphic test well. 10. Seismic Analysis (Requirements of20 AAC 25.005 (c)(10)) N/A - Application is not for an exploratory or stratigraphic test well. 11. Seabed Condition Analysis (Requirements of20AAC 25.005 (c)(11)) N/A - Application is not for an offshore well. 12. Evidence of Bonding (Requirements of20 AAC 25.005 (c)(12)) Evidence of bonding for ConocoPhillips Alaska, Inc. is on file with the Commission. 13. Proposed Drilling Program (Requirements of10AAC 25.005 (c)(13)) The proposed drilling program is listed below. Please refer to Attachment 3: Completion Schematic. 1. End PTD for C135-25 and begin PTD for CD5-25LL 2. Pick up and RIH with 6" drilling BHA. 3. Drill 6" hole to section TD for the upper C Sand lateral (LVID Program: GR/RES). 4. Pullout of hole with drilling BHA 5. RIH with 4.5" liner hanger, liner top packer and tubing tail. 6. Space out and set liner hanger and packer. 7. RIH with 4.5" upper completion tubing and stab into liner seal assembly. NOTE: A waiver is requested to set the production packer at approximately 72" as per 20 AAC 25.412(b). This is to set the packer above the upper C sand window and maintain sli kline p accessibility to secure the well in the future. et 8. Space out and land hanger. MI -'6-0-5' 9. Install BPV and pressure test seals to 2,500 psi. Nipple down BOP. 10. Install tubing head adapter assembly. Pressure test adapter assembly to 5000 psi. Remove BPV. 11. Test tubing to 3500 psi / 30 minutes and chart test. Test casing annulus separately to 2500 psi / 30 minutes and chart test. 12. Shear circulation valve in GLM. 13. Circulate tubing to diesel and install freeze protection in the annulus. 14. Set BPV and secure well. Rig down and move out. MT6-05L1 APD Page 7 of 14 Printed: 4 -Apr -18 Appf in for Permit to Drill, Well MT6-051.1 Saved: 4 -Apr -18 14. Discussion of Mud and Cuttings Disposal and Annular Disposal (Requirements of20AAC25.005 (c)(14)) Incidental fluids developed from drilling operations on well MT6-05L1 will be injected into dedicated Class 1 disposal well CD1-01A, Once MT6-05 has been drilled and completed, consideration may be given to permit this well for annular injection. An application for Sundry Operations will then be filed. Annular pumping of fluids occurring due to drilling operations, per regu ation 20 AAC 25.080 could then begin once properly permitted. As stated above, any zones containing significant hydrocarbons will be isolated prior to initiating annular pumping. There will be no USDW's open below the shoe or potable/industrial water wells within one mile of the receiving zone. Reference the enclosed directional drilling plan for other formation markers in this well. Surface casing will be set near the base of the Schrader Bluff Formation (C40). These 450-500' thick shales are part of the Colville Group and are known to provide vertical barriers to fluid flow in other areas. The maximum volume of fluids to be pumped down the annulus of this well will not exceed 35,000 bbl without the specific permission of the AOGCC. Fluid densities will range from diesel to a maximum of 12.0 ppg for drilling fluid wastes. Using 12.0 ppg fluid and the rig's specified maximum pumping pressure of 1,500 psi for annular injection, the maximum pressure at the surface casing shoe is estimated by: Max Shoe Pressure = (12.0 ppg) * (0.052) * (Surf. Shoe TVD) + 1,500 psi _ (12.0 ppg) * (0.052) * (2035') + 1,500 psi = 2,770 psi Pore Pressure = 910 psi Therefore Differential = 2770 — 910 = 1860 psi. The internal casing pressure is conservative, since frictional losses while pumping have not been taken into consideration. The surface and intermediate casing strings exposed to the annular pumping operations have sufficient strength by using the 85% collapse and burst ratings listed in the following table: OD Wt (ppf) Grade Range Connection Type Collapse 85% of Collapse Burst 85% of Burst 13-3/8" 68 L-80 3 BTC -M 2260 psi 1921 psi 5020 psi 4267 psi 9-5/8 40 L-80 3 BTC -M 3090 psi 2626 psi 5750 psi 4887 psi MT6-05L1 APD Page 8 of 14 Printed: 4 -Apr -18 15. Attachments Attachment 1 Cement Summary Attachment 2 Drilling Hazards Summary Attachment 3 Completion Schematic Attachment 4 Directional Plan App on for Permit to Drill, Well MT6-051-7 Saved: 4 -Apr -18 MT6-05L1 APD Page 9 of 14 Printed: 4 -Apr -18 Appi, .on for Permit to Drill, Well MT6-051-1 Saved: 4 -Apr -18 Attachment 1 — Cement Summary MT6-05 wp04 Cementing Program: GMTV MT6-05 wp04 •'MA,A; MT6-05L1 APD Page 10 of 14 Printed: 4 -Apr -18 ApplL ..on for Permit to Drill, Well MT6-05Lt Saved: 4 -Apr -18 13-3/8" Surface Casing run to 2,054' MD / 2,032' TVD. Cement from 2,054' MD to 1,554'(500' of tail) with Class G + Adds. @ 15.8 PPG, and from 1,554' to surface with 11.0 ppg DeepCrete. Assume 250% excess annular volume in permafrost and 50% excess below the Permafrost (1,350' MD), zero excess in 20" conductor. Lead slurry from 1,554' MD to surface with DeepCrete @ 11.0 ppg Conductor (115'- 36) X 1.0190 ft3/ft X 1.0 (0% excess) = 81 ft3 Permafrost to Conductor (1,100'- 115) X 0.4206 ft3/ft X 3.5 (250% excess) = 1,450 ft' Top of Tail to Permafrost (1,554'- 1,1001 X 0.4206 ft3/ft X 1.5 (50% excess) =286W Total Volume = 81 + 1,450 + 286 = 1,817 ft3 => 942 sx of 11.0 ppg DeepCrete @ 1.93 1141:3 /sk Tail slurry from 2,054' MD to 1,554' MD with 15.8 ppg Class G + additives Shoe to Top of Tail (2,054'-1,5541 X 0.4206 ft3/ft X 1.50 (50% excess) = 316 ft3 Shoe Joint (801 X 0.8407 ft3/ft X 1.0 (0% excess) = 68 ft' Total Volume = 316 + 68 = 384 ft3 => 328sx of 15.8 ppg Class G + 0.2% D046 antifoamer, 0.3% D065 dispersant and 0.8% 5002 accelerator @ 1.17 ft3/sk 9-5/8" Intermediate casing to 8,982' MD / 7.099' TVD Cement 500' up from 9-5/8" casing shoe from 8982' MD to 8482' MD. Assume 40% excess annular volume. Tail slurry from 8,982' MD to 8,482' MD with 15.8 ppg Class G + additives Shoe to Top of Tail (8,982'-8,4821 X 0.3132 ft3/ft X 1.40 (40% excess) = 220 ft3 Shoe Joint (801 X 0.4257 ft3/ft X 1.0 (0% excess) = 34 ft' Total Volume = 220 + 34 = 254 ft3 => 216 sx of 15.8 ppg Class G + 0.2% D046 antifoamer, 0.3% D065 dispersant and 0.8% 5002 accelerator @ 1.17 ft3/sk 7" Intermediate liner run to 11.000' MD / 7,959' TVD Top of slurry is designed to be at liner top at 8,700' MD. Assume 40% excess annular volume. 6" x 8-3/4" underreamer to be 100ft behind the drill bit. Tail slurry from 11,000' MD to 8,700' MD with 15.8 ppg Class G + additives 8-3/4" Hole to Casing shoe (11,000'-8,700 X 0.1503 ft3/ft X 1.40 (40% excess) = 484 ft3 Liner Lap (8,982'-8,7001 X 0.1503 ft3/ft X 1.0 (0% excess) =42W Shoe Joint (80) X 0.2148 ft3/ft X 1.0 (0% excess) = 17 ft3 Total Volume = 484+ 42 + 17 = 543 ft3 => 464 sx of 15.8 ppg Class G + 0.2% D046 antifoamer, 0.30/a D065 dispersant and 0.8% 5002 accelerator 0 1.17 ft3/sk M76 -05L1 APD Page 11 of 14 Printed: 4 -Apr -18 Apph, in for Permit to Drill, Well MT6-051-1 Saved: 4 -Apr -18 Attachment 2 — Drilling Hazards Summary (To be posted in Rig Floor Doghouse Prior to Spud) 16" Hole / 13-3/8" Casino interval Event Risk Level Mitigation Strategy Conductor Broach Low Monitor cellar continuously during interval. Well Collision Low First well on Pad, traveling cylinder diagrams Gas Hydrates Low If observed — control drill, reduce pump rates and Hole swabbing on trips Medium circulating time reduce mud temperatures Clay Balling Medium Maintain planned mud parameters and flow rates, Lost circulation Low Increase mud weight, use weighted sweeps, Abnormal Pressure in Low reduce fluid viscosity,control ROP Abnormal Pressure in Low Diverter drills, increased mud weight. Shallow Surface Formations Medium hazard study noted minimal risk Lost Circulation Medium Reduce pump rates, mud rheology, add lost circulation material, use of low density cement Abnormal Reservoir Low slurries rt collar, control pipe running seeds 12-1/4" Hole / 9-5/8" Casino Interval Event Risk Level Mitigation Strategy Lost circulation Low Reduce pump rates, reduce trip speeds, real time hole ECD monitoring, mud rheology, add lost circulation material Hole swabbing on trips Medium Reduce trip speeds, condition mud properties, proper hole filling, pump out of hole, real time ECD Lost circulation Low monitoring, MPD stripping ractices Abnormal Pressure in Low Well control drills, check for flow during Overburden Formations connections, increase mud weight. Shallow hazard Hole swabbing on trips Medium study noted minimal risk Hole Cleaning LOW Monitor ECD and torque/drag trends, control drill and use best hole cleaning practices 6" x 8-3/4" Hole / 7" Liner - Casino Interval Event Risk Level Mitigation Strategy Sloughing shale, Tight High MPD for shale stability, Steerable Drilling Liner, hole Increase mud weight, control ROP, connection and trip speeds, sweeps, and real time equivalent circulating density (ECD) monitoring, run casing as liner Lost circulation Low Reduce pump rates, reduce trip speeds, real time ECD monitoring, mud rheology, add lost circulation material Hole swabbing on trips Medium Reduce trip speeds, condition mud properties, proper hole filling, pump out of hole, real time ECD monitoring,Liner will be in place at TD Abnormal Reservoir Low Well control drills, check for flow during Pressure connections increase mud weight Hydrogen Sulfide gas Low H2S drills, detection systems, alarms, standard well control practices, mud scavengers hfT6-05L1 APD Page 12 of 14 Printed: 4 -Apr -18 Applies_ .an for Permit to Drill, Well MT6-051-1 Saved: 4 -Apr -18 6" Hole / 4-1/2" Pre -Perforated Liner - Horizontal Production Hole Event Risk Level Mitigation Strategy Lost circulation Low Reduce pump rates, reduce trip speeds, real time ECD monitoring, mud rheology, add lost circulation material Hole swabbing on trips Medium Reduce trip speeds, condition mud properties, proper hole filling, pump out of hole, real time ECD monitoring Abnormal Reservoir Low Well control drills, check for Flow during Pressure connections increased mud weight Differential Sticking Low Uniform reservoir pressure along lateral, keep pipe moving, control mud weight Hydrogen Sulfide gas Low H2S drills, detection systems, alarms, standard well control practices, mud scavengers Well Proximity Risks: Directional drilling / collision avoidance information as required by 20 ACC 25.050 (b) is provided in the following attachments. Drilling Area Risks: J Reservoir Pressure: normal original pore pressure is prognosed. Nevertheless, LCM material will be on location to deal with losses. Weak sand stringers could be present in the overburden. LCM material will be available to seal in losses in the intermediate section. Lower Shale Stability: HRZ/Kalubik/Miluveach apd instability in the intermediate interval #2 will require higher mud weights and managed pressure drilling in order to stabilize the formations. Standard LCM material and well bore strengthening pills are expected to be effective in dealing with lost circulation if needed. MT6-05L1 APD Page 13 of 14 Printed: 4 -Apr -18 App. .on for Permit to Drill, Well MT6-0511 Saved: 4 -Apr -18 Attachment 3 — Completion Schematic (includes Alpine C Upper lateral, as detailed in MT6-051-1 PTD) MT6-05 Multilateral Producer, wp04 DRAFT Completion Schematic Tap Alpine C 10,828' MD 17937 TVD 20" 79 ppf H -M Insulated Conductor 80 feet cemented to suorfacs 1138"68 ppf L-80 H563 (Surf to 12GOTTXP to TD Surface Casing 1§2054' MD f 2033' TVO Ocemented to surface 4-V2-12.6 ppf L-80 Bove to 10,600' MO 9 58"40 ppf LE0 TXP (to 5847' MD) 9 Vtl- 40 ppf TN -W HC Ito TD} 9 8,982 MD 17099 TVD TOG of 9518.8.400 it MD Tubing; Liner ConVMon: 1) 4'h" Larding Nipple (3.813" 10) 2) 4- 'x 1' GLM 3) 4-'C x 1 -GLM 4) 4-FX1'GLM 5) Liner Top Packer l Hanger w"re Back si eve 6) LEM and Hoak Hanger 7) Liner Top Packerl Hanger vd TP Back Skwa 81 4-"1_' Landing Nipple (3.725' NoGc) 9) 4 if' Elve Blank Pipe 10) 4 Y-' give Liner with Pert Pups L2 Windaw-Baker Hook Hanger Junction 10,864' MDV 7941' TVD 4-%X16#1-80 Efue Liner 6`1fv1e,TDat Mh Perf Joints at 16,917'h€D77935'TVD O O O O O p O O O �\! 7 44-1W1e80 Blue LirerO O PrfJints- N o 7- 26 ppf LEO Tenans B1ue1H563 Liner to 11,000' h1D 1-7,959' TVO @ 93 deg 6"itl le' Mat M 16.915 M01 7970 TVD 2(t12018-11SWRoN MT6-05L1 APD Page 14 of 14 Printed.. 4 -Apr -18 ConocoPhillips ConocoPhill ips(Alaska) Inc. -WNS Western North Slope Plan: GMT1 Lookout Pad Plan: Well #5_GMT1-B2 MT6-05_Upper Lat Plan: MT6-05-wp04 Directional Summary Report 23 January, 2018 ConocoPhillips ConocoPhillips Directional Summary Report Company: ConocoPhillips(Alaska) Inc. -WNS Local Co-ordinate Reference: Well Pian. Well #5 GMT1-B2 Project: Western North Slope TVD Reference: WELL @ 70.00usft (Original Well Elev) - Site: Plan'. GMT1 Lookout Pad MD Reference: WELL @ 70.00usft (Original Well Elev) , Well: Plan 'Well #SGMT1-B2 North Reference: True Wellbore: MT6-05_Upper Let Survey Calculation Method: Minimum Curvature Design: MT6-05-wpD4 Database: EDT Alaska Prod Project Western North Slope, North Slope Alaska, United States Map System: US State Plape 1983System Datum: Mean Sea Level Geo Datum: North American Datum 9983 / ((( /// (Z7 le, Using Well Reference Point Map Zone: Alaska Zone 4 �' Using geodetic scale factor Site Plan: GMT1 Lookout Pad Declination Dip Angle Field Strength Site Position: Northing: 5,945,316.00 Usti Latitude: 70" 15'22.006 N From: Map Easting: 1,457,169.00 usft Longitude: 151' 28'52.049 W Position Uncertainty: 0.00 usft Slot Radius: 0 " Grid Convergence: -1.39 " Vertical Section: Depth From (TVD) -N/-S +El -W Direction - (usft) Well PlanWell #5 GMT1-82 36.00 0.00 0.00 320.84 Well Position 4N/ -S 0.00 usft Northing: 5,945,289.00 usft Latitude: 70° 15'21.723 N +E/.W 0.00 usft Easing: 1,457,094.00 usft Longitude: 151' 28'54.211 W Position Uncertainty 0.00 usft Wellhead Elevation: 0.00 usft Ground Level: 34.00 usft Wellbore MT6-05_Upper Let Magnetics Madel Name Sample Date Declination Dip Angle Field Strength BGGM2017„ 6/4/2018 __.. 16.48 80.71 57,420 Design MT6-05-Wp04 Audit Notes: Version: Phase: PLAN Te On Depth: 10,850.42 Vertical Section: Depth From (TVD) -N/-S +El -W Direction - (usft) (usft) (usft) (°) 36.00 0.00 0.00 320.84 1/23/2018 10: 18 42A Page 2 COMPASS 5000.14 Build 85 ConocoPhillips Company: ConocoPhillips(Alaska) Inc.-WNS DLeg Project: Western North Slope V. Sec Site: Plan'. GMT1 Lookout Pad (usft) Well: Plan'. Well#5_GMT1-B2 (usft) Wellbore: MT6-05 Upper Let (usft) Design: MT6,05-wp04 0.00 0.00 Survey Tool Program Date 1/23/2018 1,452,231.64 From To 0.00 (usft) (usft) Survey (Wellbore) 1,452,225.65 36.00 300.00 MT6-05-wp04 Lower Let ( Wellbore #5) 300.00 2,054.00 MT6-05-wp04_Lower Let (Wellbore #5) 2,054.00 8,982.00 MT6.05-wp04_Lower Let (Wellbore #5) 8,982.00 10,850.42 MT6-05-wp04_1-ower Lal (Wellbore #5) 10,850.42 16,917.76 MT6-05-wp04 (MT6-05_Upper Let) 10,850.40 16,917.76 MT6-05-wpD4 (MT6-05_Upper Let) Planned Survey 6,401.24 5,949,577.22 MD Inc Azi (azimuth) TVD (usft) (') V) (usft) 10,850.42 - 82.81 333.08 7,940.00 KOP 6,522.47 5,949,689.17 10,864.42 84.63 333.08 7,941.53 Start 20.00 hold at 10864.42 MD 5,949,779.40 10,884.42 84.63 333.08 7,943.40 Start DLS 6.00 TFO 0.06 5.949,869.64 10,900.00 65.56 333.08 7,944.73 10,975.94 90.12 333.09 7,947.59 Start 6941.82 hold at 10975.94 MD 7,876.48 11,000.00 90.12 333.09 7,947.54 - 11,100.00 90.12 333.09 7,947.33 11,200.00 90.12 333.09 7,947.12 11,300.00 90.12 333.09 7,946.90 11,400.00 90.12 333.09 7,946.69 11,500.00 90.12 333.09 7,946.48 11,600.00 90.12 333.09 7,946.27 11,700.00 90.12 333.09 7,946.06 11,800.00 90.12 333.09 7,945.85 11,900.00 90.12 333.09 7,945.63 ConocoPhillips Directionaf Summary Report Local Co-ordinate Reference: TVD Reference: MD Reference: Norm Reference: Survey Calculation Method: Database: Well Plan: Well #5_GMTI-B2 WELL @ 70.00usft (Original Well Elev) WELL @ 70.00usft (Original Well Elev) True Minimum Curvature EDT Alaska Prod Tool Name Description - - ,,v-�a�€� Y�,..sY's '.�:iwr��`':`k�+�'$„`Cyte, '�Z':-'•r";s#s,:. BLIND Blind drilling MWD-IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC MWD MWD - Standard MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC TVDSS DLeg TFace V. Sec Northing Easting (usft) ('1100usft) (") (usft) (usft) (usft) 7,870,00 0.00 0.00 6,278.86 5,949,464.23 1,452,231.64 7,871.53 13.00 0.00 6,292.46 5,949,476.78 1,452,225.65 7,873.40 0.00 0.00 6,311.92 5,949,494.75 1,452,217.07 7,874,73 6.00 0.06 6,327.09 5,949,508.76 1,452,210,38 7,877.59 6.00 0.06 6,401.24 5,949,577.22 1,452,177.69 7,877.54 0.00 0.00 6,424.75 5,949,598.93 1,452,167.33 7,877.33 0.00 0.00 6,522.47 5,949,689.17 1,452,124.25 7,877.12 0.00 0.00 6,620.19 5,949,779.40 1,452,081.17 7,876.90 0.00 0.00 6,717.92 5.949,869.64 1,452,038.09 7,876.69 0.00 0.00 6,815.64 5,949,959.88 1,451,995.01 7,876.48 0.00 0.00 6,913.37 5,950,050.12 1,451,951.93 7,676.27 0.00 0.00 7,011.09 5,950,140.36 1,451,908.85 7,876.06 0.00 0.00 7,108.82 5,950,230.59 1,451,865.77 7,875.85 0.00 0.00 7,206.54 5,950,320.83 1,451,822.69 7,875.63 0.00 0.00 7,304.27 5,950,411.07 1,451,779.61 112312018 10:18:42AM Page 3 COMPASS 5000.14 Build 85 ConocoPhillips ConocoPhillips Directional Summary Report Company: ConocoPhillips(Alaska) Inc. -WNS Local Coordinate Reference: Well Plan: Well #5_GMTt-B2 Project: Western North Slope TVD Reference: WELL @ 70,OOusft (Original Well Elev) Site: Plan: GMT1 Lookout Pad MO Reference: WELL Q 70.00usft (Original Well Elev) Well: Plan: Well #5_GMT1-B2 North Reference: True Wellbore: MT"5_Upper Let Survey Calculation Method: Minimum Curvature Design: MT6-05."04 Database: EDT Alaska Prod Planned Survey MD Inc Azi(azimuth) TVD TVDSS DLeg TFace V. Sec Northing Easting (usft) {+j {°) (usft) (usft) (°/100usft) (°I (usft) (usft) (usft) 12,000.00 90.12 333.09 7.945.42 7,875.42 0.00 0.00 7,401.99 5.950,501.31 1,451,736.53 12,100.00 90.12 333.09 7,945.21 7,875.21 0.00 0.00 7.499.71 5,950,591.55 1,451,693.46 12,200.00 90.12 333.09 7,945.00 7,875.00 0.00 0.00 7,597.44 5,950,681.78 1,451,650.38 12,300.00 90.12 333.09 7,944.79 7,874.79 0.00 0.00 7,695.16 5,950,772.02 1,451,607.30 12,400.00 90.12 333.09 7,944.57 7,874.57 0.00 0.00 7,792.89 5,950,862.26 1,451,564.22 12,500.00 90.12 333.09 7,944.36 7,874.36 0.00 0.00 7,890.61 5,950,952.50 1,451,521.14 12,600.00 90.12 333.09 7,944.15 7.874.15 0.00 0.00 7,988.34 5,951,042.74 1,451,478.06 12,700.00 90.12 333.09 7,943.94 7,873.94 0.00 0.00 8,086.06 5,951,132.97 1,451,434.98 12,800.00 90.12 333.09 7,943.73 7,873.73 0.00 0.00 8,183.79 5,951,223.21 1,451,391.90 12,900.00 90.12 333.09 7,943.51 7,873.51 0.00 0.00 8,281.51 5,951,313.45 1,451,348.82 13,000.00 90.12 333.09 7,943.30 7,873.30 0.00 0.00 8,379.23 5,951,403.69 1,451,305.74 13,100.00 90.12 333.09 7,943.09 7,873.09 0.00 0.00 8,476.96 5,951,493.93 1,451,262.66 13,200.00 90.12 333.09 7,942.88 7,872.88 0.00 0.00 8,574.68 5,951,584.16 1,451,219.58 13,300.00 90.12 333.09 7,942.67 7,872.67 0.00 0.00 8,672.41 5,951,674.40 1,451,176.50 13,400.00 90.12 333.09 7,942.45 7,672.45 0.00 0.00 8,770.13 5,951,764.64 1,451,133.43 13,500.00 90.12 333.09 7,942.24 7,872.24 0.00 0.00 8,867-86 5,951,854.88 1,451,090.35 13,600.00 90.12 333.09 7,942,03 7,872.03 0.00 0.00 8,965.58 5,951,945.12 1,451,047.27 13,700.00 90.12 333.09 7,941.82 7,871.82 0.00 0.00 9,063.30 5,952,035.35 1,451,004,19 13,800.00 90.12 333.09 7,941.61 7,871.61 0.00 0.00 9,161.03 5,952,125.59 1,450,961.11 13,900.00 90.12 333.09 7,941.40 7,871.40 0.00 0.00 9,258.75 5,952,215.83 1,450,918.03 14,000.00 90.12 333.09 7,941.18 7,671.18 0.00 0.00 9,356.48 5,952,306.07 1,450,874.95 14,100.00 90.12 333.09 7,940.97 7,670.97 0.00 0.00 9,454.20 5,952,396.31 1,450,631.87 14,200.00 90.12 333.09 7,940.76 7,870.76 0.00 0.00 9,551.93 5,952,486.54 1,450,788.79 14,300.00 90.12 333.09 7,940.55 7,870.55 0.00 0.00 9,649.65 5,952,576.78 1,450,745.71 14,400.00 90.12 333.09 7,940.34 7,870.34 0.00 0.00 9,747.38 5,952,667.02 1,450,702.63 14,500.00 90.12 333.09 7,940.12 7,870.12 0.00 0.00 9,845.10 5,952,757.26 1,450,659.55 14,600.00 90.12 333.09 7,939.91 7,869.91 0.00 0.00 9,942.82 5,952,847.50 1,450,616.47 1232018 10:18:42AM Page 4 COMPASS 5000.14 Build 85 ConocoPhillips ConocoPhillips Directional Summary Report Company: ConocoPhillips(Alaska) Inc. -WNS Local Co-ordinate Reference; Well Pian: Well #5_GMT1-62 Project: Western North Slope TVD Reference: WELL @ 70.00usft (Original Well Elev) Site: Plan: GMT1 Lookout Pad MD Reference: WELL @ 70.00usft (Original Well Elev) Well: Plan: Well #S GMTt-B2 North Reference: True Wellbore: MT6-05_Upper Let Survey Calculation Method; Minimum Curvature Design: MT6-05-wp04 Database: EDT Alaska Prod Planned Survey MD Inc Azi (azimuth) TVD TVDSS DLeg TFace V. Sec Northing Easting (usft) (°) (°) (usft) (usft) (°/100usft) (") (usft) (usft) (usft)„ 14.700.00 90.12 333.D9 7,939.70 7,669.70 0.00 0.00 10,040.55 5.952,937.73 1,450,573.40 74,800.00 90.12 333.09 7,939.49 7,669.49 0.00 0.00 10,138.27 5,953,027.97 1,450,530.32 14,900.00 90.12 333.09 7,939.28 7,869.28 0.00 0.00 10,236.00 5,953,118.21 1,450,487.24 I 15,000.00 90.12 333.09 7,939.06 7,869.06 U0 0.00 10,333.72 5,953,208.45 1,450,444.16 15,100.00 90.12 333.09 7,936.85 7,868.65 0.00 0.00 10,431.45 5,953,298,69 1,450,401.08 15,200.00 90.12 333.09 7,938.64 7,868.64 0.00 0.00 10,529.17 5,953,388.82 1,450,358.00 15,300.00 80.12 333.09 7,938.43 7,868.43 0.00 0.00 10,628.90 5,953,479.16 1,450,314.92 15,400.00 80.12 333.09 7,938.22 7,86822 0.00 0.00 10,724.62 5,853,569.40 1,450,271.84 i 15,500.00 90.12 333.09 7,936.00 7,866.00 0.00 0.00 10,822.34 5,953,659.64 1,450,228.76 ! i 15,600,00 90.12 333.09 7,837.79 7,867.79 0.00 0.00 10,920.07 5,953,749,88 1,450,185.68 15,700.00 90.12 333.09 7,937.58 7,867.58 0.00 0.00 11,017.79 5,853,840.11 1,450,142.60 15,800.00 90.12 333.08 7,937.37 7,867.37 0.00 0.00 11,115.52 5,953,930.35 1,450,099,52 15,900,00 90.12 333.09 7,937.16 7,867.16 0.00 0.00 11,213.24 5,954,020.59 1,450,056.44 j 16,000.00 90.12 333.09 7,936.94 7,666.94 0.00 0.00 11,310.97 5,954,110.83 1,450,013.37 16,100.00 90.12 333.09 7,936,73 7,866.73 0.00 0.00 11,408.69 5,954,201.07 1,449,970.29 16,200.00 90.12 333.09 7,936,52 7,866.52 0.00 0.00 11,506.42 5,954,291.30 1,449,927.21 16,300.00 90.12 333.09 7,936.31 7,866.31 0,00 0.00 11,604.14 5,954,381.54 1,449,884.13 16,400.00 90.12 333.09 7,936.10 7,866,10 0.00 0.00 11,701.86 5,954,471.78 1,449,841.05 16,500.00 90.12 333.09 7,935.89 7,665.89 0.00 0.00 11,799.59 5,954,562.02 1,449,787.97 16,600.00 90.12 333.09 7,935.67 7,865.67 0.00 0.00 11,897.31 5,954,652.26 1,449,754.89 16,700.00 90.12 333.09 7,935.46 7,865.46 0.00 0.00 11,995A4 5,954,74249 1,449,711.81 16,800.00 90.12 333.09 7,935.25 7,865.25 0.00 0.00 12,092.76 5,954,832.73 1,449,668.73 16,900.00 90.12 333.09 7,935.04 7,665.04 0.00 0.00 12,190.49 5,954,922.97 1,449,625.65 i 16,917.76 90.12 333.09 7,935.00 7,665.00 0.00 0.00 12,207.84 5,954,939.00 1,449,618.00 TD at 16917.76.4-1/Y' x 6" j 1/23/2018 10:18'42AM Page 5 COMPASS 5000.14 Build 85 ConocoPhillips ConocoPhillips Directional Summary Report Company: ConowPhillips(Alaska) Inc. -WNS Local Co-oMinata Reference: Well Plan: Well #5_GMT1-82 Project: Western North Slope TVD Reference: WELL @ 70.00usft (Original Well Elev) Site: Plan'. GMT1 Lookout Pad MD Reference: WELL @j 70.00usft (Original Well Elev) Well: Plan: Well #S_GMT1-82 North Reference: True Wellbore: MT6-O5 Upper Let Survey Calculation Method: Minimum Curvature Design: MT6-05-wp04 Database: EDT Alaska Prod 16,917.76 7,935.00 4-1/2" x6" 4-1/2 6 Formations Measured Depth (usft) 2,123.56 8,961.85 5,320.90 10,827.70 7,683.44 9,452.79 4,848.67 3,739.65 4,475.69 8,279.11 2,514.34 7.075.61 Plan Annotations Measured Depth (usft) 10,850.42 10,864.42 10,884.42 10,975.94 16,917.76 Vertical Depth (usft) 2,098.05 7,098.97 4,516.06 7,936.97 6,182.91 7,428.08 4,182.91 3,400.47 3,919.76 6,603.17 2,454.60 5,754.21 Vertical Depth (usft) 7,940.00 7,941.53 7,943.40 7,947.59 7,935.00 Dip Name Lithology (°) C-30 HRZ Slump Albian 95 Alpine C 0.00 Ablian 93 LCU Albian 96 K-3 Alblan 97 Top Fill C-10 Albian 94 Local Coordinates +N/S +E/.W (usft) (usft) 4,055.89 -4,962.85 4,068.30 4,969.15 4,086.06 -4,978.16 4,167.55 -5,019.54 9,465.77 -7,709.14 Comment KOP Start 20.00 hold at 10864.42 MD Start DLS 6.00 TFO 0.06 Start 5941.82 hold at 10975.94 MD TO at 16917.76 Dip Direction 112312018 1Q18:424M Page 6 COMPASS 5000.14 Build 85 9 Project: Western North Slope Site: Plan: GMT1 Lookout Pad Well: Plan: Well #5_GMT1-B2 Wellbore: MT6-05_Upper Lat Design: MT6-05-wp04 8750 4-1/2"x8" c �eUg6 G y 7000 0211 z 0 0 Z 3500 00 ^O t 00 0 0 j --- O O 7750 9-5/8" x 12-1/4" y00 O 00 b O 00 13-3/8"x ifi"________ c -10500 -8750 -7000 -5250 -3500 -1750 0 175D 3500 West( -)/East(+) (3500 usft/in) 0 1000 2000 3000 4000 5000 8D00 7000 8000 9000 10000 11 Vertical Section at 320.84° (2000 usft/in) Remark: AOGCC Permit to Drill No. 218-046 - Coordinate Check 18 April 2018 INPUT OUTPUT Geographic, NAD83 State Plane, NAD27 5004 -Alaska 4, U.S. Feet Accuracies of conversions from NAD 83 to NAD 27 are typically 12 to 18 cm. GREATER MT UNIT M -r -r- (/ v1 Latitude: 70 15 21.72300 Northing1r. 5945544.188 Longitude: 151 28 54.21100 EastinglX: 317059.519 Convergence: -1 23 30.15465 Scale Factor: 0.999938018 Datum Shift (m.): Delta Lat. = 38.573, Delta Lon = -118.045 Corpscon v6.0.1, U.S. Army Corps of Engineers TRANSMITTAL LETTER CHECKLIST WELL NAME: PTD: Development —Service _Exploratory _ Stratigraphic Test _ Non -Conventional FIELD: POOL:�cJ2 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 (If last two digits No. i� API No. 50-�- 2 77��- 15 Production siould continue to be reported as a function of the original in API number are API number stated above. between 60-69) In accordance with 20 AAC 25.005(f), all records, data and logs acquired for the pilot hole must be clearly differentiated in both well Pilot Hole name ( PH) and API number (50- from records, data and logs acquired for well name on ermit). The permit is approved subject to full compliance with 20 AAC 25.055. Approval to produce/inject is contingent upon issuance of a conservation Spacing Exception order approving a spacing exception. (Company Name) Operator assumes the liability of any protest to the spacing exception that may occur. All dry ditch sample sets submitted to the AOGCC must be in no greater Dry Ditch Sample than 30' sample intervals from below the permafrost or from where Sam les are first caught and 10' sample intervals through target zones. Please note the following special condition of this permit: production or production testing of coal bed methane is not allowed for Non -Conventional (name of well) until after (Company Name) has designed and Well implemented a water well testing program to provide baseline data on water quality and quantity. (Company Name) must contact the AOGCC to obtain advance approval of such water well testing program. Regulation 20 AAC 25.071(a) authorizes the AOGCC to specify types of well logs to be run. In addition to the well logging program proposed by (Company Name) in the attached application, the following well logs are also required for this well: Well Logging Requirements Per Statute AS 31.05.030(d)(2)(B) and Regulation 20 AAC 25.071, 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 LL PERMIT CHECKLIST Field &Pool GRTR MOOSES TOOTH, ALPINE UN O -28210 _ _ _Well Name: GREATER MT UNIT M26-051 1 _ Program DEV Well bore seg se PTD#:2180460 Company CONOCOPHIL_LIP�ALASKA INC Initial Classlrype DEV / PEND GeoArea 890 _ Unit 10750 On/Off Shore On Annular Disposal ❑ Administration 17 Nonconven.. gas conforms to AS31,05.0314I-411-2.A-D) . _ ... NA_ - 1 Permitfee attached NA 2 lease number appropriate_ . _ ... _ _ _ _ _ _ _ _ _ _ _ _ _Yes 3 Unique well. name and number _ . _ _ - - Yes 4 WeIII .located ina defined _pool.... No Greater Mooses Tooth, Alpine Undefined_ Oil Pool -282100, governed by statewide spacing 5 Well located proper distance from drilling unit boundary_ _ _ _ - - - Yes regulations. As planned,. this well conforms with statewide spacing requirements... _ 6 Well located proper distance from other wells. ... _ _ _ _ _ _ Yes _ _ _ _ Wellbore will be more than 50V from an exfemal property line where ownership or landownership 7 Sufficient acreage available in drilling unit.. _ _ _ _ _ _ .... _ Yes _ changes.. 8 If deviated, is wellbore plat included _ _ - _ - - - _ Yes ... _ Application for Pool Rules. Lookout Oil Pool received 2/2$/28. As of 4/12/18, application is under review.. _ 9 Operator only affected party.. _ _ _ _ _ _ _ _ _ ... _ Yes 10 Operator has. appropriate bond in force - Yes Appr Date 11 Permit can be issued without conservation order- - _ ... _ _ _ _ _ Yes ________ SFO 4/18/2018 12 Permit. can be issued without administrative approval _ _ _ Yes _ _ _ _ . _ . 13 Can permit be approved before 15 -day wait. _ _ _ _ .. _ _ _ _ Yes 14 Well located within area and. strata authorized by Injection Order# (put 10# incomments)(For. NA_ _ _ _ _ _ ___ _ _ _ 15 A11 wells within 1/4mile area of review identified (For service well only) _ - _ .... _ _ _ NA 16 Pre -produced injector; duration of pre production less than 3 months. (For serv(co well only) _ ..NA - _ . . ........... . . . . . . . . . 18 Conductor stringprovided_ _ _ _ _ . . . .... . . . NA _ set in MT6-95 Engineering 19 ... . . . . . ..... Surface casing. protects all. known USDWs ... _ _ _ NA - _ _ - _ ..Conductor _ _ .... Surface casing will be set in MT6-06 - 20 CMT vol adequate to circulate on conductor & surf. rag _ _ _ .. _ _ _ _ _ _ _ _ _ NA 21 CMT vol adequate to tie-in long string to surf csg_ _ NA 22 CMT will coverall known productive horizons.. _ _ _ _ _ _ _ _ ... _ No. 23 Casing designs adequate for CJ, B &_ permafrost _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes _ _ Slotted liner to be run....... 24 Adequate. tankage or reserve pit _ _ _ _ _ _ _ _ _ _ ___ _ _ _ _ _ Yes Rig has steel pits.. Waste to be trucked to CD1 disposal well. 25 If a re -drill, has a 10-403 for abandonment been approved . . .. . . . . ......... . ... . NA 26 Adequate wellbore separation proposed_ _ _ _ ..... Yes Wellbore is parallel and directly above mainbore 27 If.djverter required, does it meet regulations _ _ .. _ _ _NA Appr Date 28 Drilling fluid program schematic & equip list adequate_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes _ Max formation pressure 3810 psi (9.2 ppg EMW) will use MPD to drill lateral.. GLS 4/19/2018 29 BOPEs, do they meet regulation _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes _ Doyon 19 has ROPE on file.. 30 BOPE.Press rating appropriate; test to (put prig in comments) . . . . ........ . . .. . . . . Yes _ _ _ _ _ .......... 31 Choke manifold complies w/API RP -53 (May 84)- _ _ . . . . . ........ Yes 32 .Work will occur without operation shutdown_ _ _ _ - _ _ Yes .... _ No stimulation planned. 33 Is presence of H2S gas probable - . - _ _ No.. _ _ _ _ _ _ H2$ not expected but rig has sensors and alarms, 34 Mechanical_ condition of wells within AOR verified (For service well only) . - _ _ _ NA _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ 35 Permit. can be issued w(o hydrogen sulfide measures _ _ _ _ .. - No H2S measures required. Geology 36 Datapresentedon potential overpressure zones _ _ _ _ .. _ Yes . . _ .... Pore pressure. within production interval is expected to be 9,1.ppg EMW. Managed Pressure Drilling. Appr Date 37 Seismic analysis of shallow gas zones _ _ _ _ _ _ ..... _ _ _ _ NA ...... _ technique using. 6.6 ppg mud will be -used for control while.drilling productioninterval._ SFD 4/18/2018 38 Seabed condition survey (if off -shore) _ - - - _ - _ - - - _ _ - - .. _ _ _ NA - - - - - - - - - - - - - - -- - - - - - - - - - - - - - - - - - - - - - - 39 Contact namelphone for weekly_ progress reports [exploratory only] _ _ _ _ _ _ _ _ NA _ .. _ _ _ Onshore development well branch_ _ Geologic Commissioner: Date: Commissioner: Date C Public er Date P. -VS Y/eQ J JCP L(IZn1te,
