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Home My WebLink About218-172DATA SUBMITTAL COMPLIANCE REPORT 4/15/2019 Permit to Drill 2181720 Well Name/No. KUPARUK RIV UNIT 113-081-1 Operator CONOCOPHILLIPS ALASKA, INC. API No. 50-029-20266.60-00 MD 8912 TVD REQUIRED INFORMATION 6312 Completion Date 1/10/2019 Completion Status 1 -OIL Current Status 1 -OIL UIC No Mud Log No I/ DATA INFORMATION List of Logs Obtained: GR/Res Well Log Information: Log/ Electr Data Digital Dataset Type Med/Frmt Number Name ED C 30352 Digital Data ED C 30352 Digital Data ED C 30352 Digital Data ED C 30352 Digital Data ED C 30352 Digital Data ED C 30352 Digital Data ED C 30352 Digital Data ED C 30352 Digital Data ED C 30352 Digital Data ED C 30352 Digital Data ED C 30352 Digital Data ED C 30352 Digital Data ED C 30352 Digital Data ED C 30352 Digital Data ED C 30352 Digital Data ED C 30352 Digital Data ED C 30352 Digital Data ED C 30352 Digital Data Samples No V� Directional Survey Ygs Log Log Run Scale Media No (from Master Well Data/Logs) Interval OH I Start Stop CH Received Comments 6104 8912 2/8/2019 Electronic Data Set, Filename: 113-081.1 GAMMA RES.las 2/8/2019 Electronic File: 1D-081_1 2MD Final.cgm 2/8/2019 Electronic File: 1D -08L1 51VID Final.cgm ISI 2/8/2019 Electronic File: 1D -08L1 5TVDSS Final.cgm 2/8/2019 Electronic File: 1 D-081_1 2MD Final.pdf 2/8/2019 Electronic File: 1D-081_1 51VID Final.pdf 2/8/2019 Electronic File: 113-081-1 5TVDSS Final.pdf 2/8/2019 Electronic File: 1D-081_1 - EOW - NAD27.pdf 2/8/2019 Electronic File: 1 D-081.1 - EOW - NAD27.txt 2/8/2019 Electronic File: 1 D -08L1 Final Surveys TD 8912.csv 2/8/2019 Electronic File: 1D-081_1 Final Surveys TO 8912.xlsx 2/8/2019 Electronic File: 1D-081_1 Survey Listing.txt 2/8/2019 Electronic File: 113-081-1 Surveys.txt 2/8/2019 Electronic File: 1D - 08L1 _25_tapescan_BH I_CTK.txt 2/8/2019 Electronic File: 1 D - 08L t_5_tapescan_BHI CTK.txt 2/8/2019 Electronic File: 1D-081_1_output.tap 2/8/2019 Electronic File: 1 D-081_1 21VID Final.tif 2/8/2019 Electronic File: 1D-081.1 SMD Final.tif AOGCC Page 1 of 3 Monday, April 15, 2019 DATA SUBMITTAL COMPLIANCE REPORT 4/15/2019 Permit to Drill 2181720 Well Name/No. KUPARUK RIV UNIT 1113-0811 Operator CONOCOPHILLIPS ALASKA, INC. API No. 50-029-20266-60-00 MD 8912 TVD 6312 Completion Date 1/10/2019 Completion Status 1 -OIL Current Status 1 -OIL UIC No ED C 30352 Digital Data 2/8/2019 Electronic File: 1D -08L1 5TVDSS Final.tif Log C 30352 Log Header Scans 0 0 2181720 KUPARUK RIV UNIT 113-081-1 LOG Release Date: HEADERS ED C 30402 Digital Data 2/26/2019 Electronic File: 1 D-081-1 - EOW - NAD27.pdf ED C 30402 Digital Data 2/26/2019 Electronic File: 1 D-081-1 - EOW - NAD27.txt ED C 30402 Digital Data 2/26/2019 Electronic File: 1 D-081-1 - EOW - NAD83.pdf ED C 30402 Digital Data 2/26/2019 Electronic File: 1 D-081-1 - EOW - NAD83.txt Log C 30402 Log Header Scans 0 0 2181720 KUPARUK RIV UNIT 1D-081-1 LOG HEADERS Well Cores/Samples Information: Sample Interval Set Name Start Stop Sent Received Number Comments INFORMATION RECEIVED Completion Report { Y 1 Directional / Inclination Data Yo Mud Logs, Image Files, Digital Data Y /0 Core Chips Y A Production Test Informatior(�/ NA Mechanical Integrity Test Information Y / NA Composite Logs, Image, Data Files Core Photographs Y N Geologic Markers/Tops �Y Daily Operations Summary O Cuttings Samples Y N� Laboratory Analyses Y NA COMPLIANCE HISTORY Completion Date: 1/10/2019 Release Date: Description Date Comments Comments: AOGCC Page 2 of 3 Monday, April 15, 2019 DATA SUBMITTAL COMPLIANCE REPORT 4/15/2019 Permit to Drill 2181720 Well Name/No. KUPARUK RIV UNIT 1D -08L1 MD 8912 TVD 6�312/�/� letion ate 1/10/2019 Compliance Reviewed By: Y v \ _ - Operator CONOCOPHILLIPS ALASKA, INC. API No. 50.029.20266.60.00 Completion Status 1-0I1- Current Status 1-011- UIC No Date: _ r AOGCC Page 3 of 3 Monday, April 15, 2019 BAF�IGDate: HES BAT GEcompany Abby Bell AOGCC 333 West 7`h Ave, Suite 100 Anchorage, Alaska 99501 February 21, 2019 2 18 172 30 40 2 Letter of Transmittal Michael Soper Baker Hughes, a GE Company 795 East 94`h Avenue Anchorage, Alaska 99515 find enclosed the directional survey data for the following well(s): 1D-OBL1 1D-0821-01 RECEIVED FEB 2 6 2019 OGCC (2) 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, Applications Engineer Michael.Soper(@BakerHughes.com ConocoPhillips ConocoPhillips (Alaska) Inc. -Kup1 Kuparuk River Unit Kuparuk 1D Pad 1D -08L1 50-029-20266-60 Baker Hughes INTEQ Definitive Survey Report 05 February, 2019 2 18 172 30 40 2 BA ER F UGHES a GE company ConocoPhillips ER ConocoPhillips Definitive Survey Report �tS Company: ConocoPhillips (Alaska) Inc. -Kupt Local Co-ordinate Reference: Well 1D-08 Project: Kuparuk River Unit TVD Reference: 1D-08 @ 108.ODusft Site: Kuparuk 1D Pad MD Reference: 1D-08 @ 108.00usft Well: 1D-08 North Reference: Truev Wellbore: 1D-0811 Survey Calculation Method: Minimum Curvature Design: 1D-0811 Database: EDT 14 Alaska Production Project Kuparuk River Unit, North Slope Alaska, United States Map System: US State Plane 1927 (Exact solution) System Datum: Mean Sea Level j leo Datum: NAD 1927 (NADCON CONUS) Using Well Reference Point P ap Zane: Alaska Zone 04 Using geodetic scale factor Well 1D-08 _. _ ,...... .,_ _..-,.._.,.._..-.>-,.. Well Position +N/ -S 0.00 usft Northing: 5,959,064 ODusft Latitude: 70° 17'55,408 N +EI -W 0.00 usft Easting: 560,490.00usft Longitude: 149" 30'36.452 W Position Uncertainty 0.00 usft Wellhead Elevation: usft Ground Level: 0.00 usft Wellbore 1D-0811 Magnetics Model Name Sample Date Declination Dip Angle Field Strength V) V) (nT) BGGM2018 3/1/2019 16.75 80.86 57,424 Design 1D -08L1 Audit Notes: Version: 1.0 Phase: ACTUAL Tie On Depth 6,300.00 Vertical Section: Depth From (TVD) +NI -S +E/ -W Direction (usft) (usft) lush) (') 108.00 0.00 0.00 225.00 Survey Program Date From To Survey Survey (usft) (usft) Survey (Wellbore) Tool Name Description Start Date End Date 200.00 6,300.00 Gyro (1D -OB) GYD-CT-CMS Gyrodata contcasing m/s 3/24/2000 6,396.00 6,466.75 1D-0811 MWD-INC(1D-081-1) MWD-INC—ONLY MWD-INC_ONLY_FILLER 1/1/2019 1/1/2019 6,497.37 8,879.07 1D-0811 MWD(1D-081-1)MWD MWD - Standard 1/5/2019 1/5/2019 2/5/2019 2.03.59PM Page 2 COMPASS 5000 14 Build 85D ConocoPhillips BAd<ER 0 ConocoPhillips UGH j� Definitive Survey Report Company: ConocoPhillips (Alaska) Inc. -Kupl Local Co-ordinate Reference: Well 1D-08 Project: Kuparuk River Unit ND Reference: 1 D-08 Q 108.00usft i Site: Kuparuk 1D Pad MD Reference: 1D-08 @ 108.00usk Well: 1D-08 North Reference: True Wellbore: 1D -08L1 Survey Calculation Method: 'Minimum Curvature Design: 1D-081-1 Database: EDT 14 Alaska Production Survey (°) (°) i Annotation TIP KOP Interpolated Azimuth Interpolated Azimuth 2/52019 2:03:59PM Page 3 COMPASS 5000.14 Build 85D Map Map MD Inc Azi ND NDSS +N/ -S +EI -W Northing Northing Easting OILSVertical Section (usk) (°) (°) (usk) (usft) (usk) Irish) Survey Tool Name (ft) (ft) 6.300 OD 0.78 276.8D 6,298.54 6,190.54 -46.27 15.45 5,959,017.86 560,505.82 0.87 21.79 MWD-INC_ONLY(2) 6,396.00 0.76 299.72 6,394.53 6,286.53 -45.88 14.25 5,959,018.24 560,504.62 0.32 22.36 MWD4NC ONLY (2) 6,431.00 5.97 170.18 6,429.47 6,321.47 -47.56 14.36 5,959,016.56 560,504.74 18.52 23.48 MWD4NC_ONLY (2) 6,466.75 17.08 168.57 8464.45 6,356.45 -54.56 15.72 - 5,959,009.58 560.506.16 31.09 27.46 MWD4NC_ONLY (2) 6,497.37 31.50 168.09 6,492.28 6,384.28 -66.86 18.28 5,958,997.30 560,508.81 47.10 34.35 MWD (3) 6,527.57 44.46 166.62 6,516.04 6,408.04 -84.94 22.37 5,958,979.25 560,513.05 43.02 44.25 MWD(3) 6,557.06 57.03 165.77 6,534.66 6,426.66 -107.07 27.82 5,958,957.17 560,518.68 42.68 56.04 MWD (3) 6,587.85 70.54 164.29 6,548.23 8440.23 -133.69 34.96 5.958.930.61 560,526.03 44.09 69.81 MWD (3) 6,616.74 83.54 162.53 6,554.70 6,446.70 -160.61 42.99 5,958,903.76 560,534.28 45.39 83.17 MWD (3) 6,647.02 96.46 162.86 6,554.70 6,446.70 -189.46 51.98 5,958,874.99 560,543.50 42.68 97.21 MWD (3) 6,677.03 102.07 170.57 6,549.86 6,441.86 -218.24 58.79 5,958,846.26 560,550.54 31.49 112.75 MWD (3) 6,706.71 105.73 181.25 6,542.71 6,434.71 -246.93 60.87 5,958,817.59 560,552.84 37.03 131.57 MWD (3) 6,735.52 105.32 194.51 6,534.97 6,426.97 -274.35 57.07 5,958,790.14 560,549.27 44.36 153.65 MWD (3) 6,766.19 104.11 197.36 6,527.18 6,419.18 -302.87 48.92 5,958,761.56 560,541.35 9.82 179.57 MWD (3) 6,796.44 102.82 197.21 8520.13 6,412.13 -330.96 40.18 5,958,733.40 560,532.84 4.29 205.61 MWD (3) 6,826.04 101.85 196.12 6,513.81 6,405.81 .358+66 31.89 5,958,705.64 560,524.77 4.87 231.07 MWD (3) 6,861.06 99.62 195.94 6,507.29 6,399.29- -391.73 22.39 5,958,672.50 560,515.54 6.39 261.17 MWD (3) 6,891.02 101.68 197.20 6,501.75 6,393.75 419.95 13.99 5,958,644.22 560,507.37 8.02 287.06 MWD (3) 6,921.26 103.80 199.04 6,495.08 6,387.08 447.98 4.82 5,958,616.11 560,498.43 9.19 313.36 MWD (3) 6,951.43 105.44 202.57 6,487.46 6,379.46 475.27 -5.54 5,958,588.75 560,488.28 12.56 339.98 MWD (3) 6,980.85 105.45 203.55 6,479.63 6,371.63 -501.36 -16.65 5,958,562.57 560,477.39 3.21 366.29 MWD f3) 7,011.65 104.87 205.97 6,471.57 6,363.57 -528.35 -29.10 5,958,535.48 560,465.16 7.81 394.18 MWD (3) 7,041.27 103.76 209.06 6,464.25 6,356.25 .553.80 42.36 5,958,509.93 560,452.10 10.78 421.55 MWD (3) 7,071.91 103.51 212.10 6,457.02 6,349.02 -579.43 -57.50 5,958,484.18 560,437.17 9.68 450.38 MWD (3) 7,101.45 103.51 215.50 6,450.12 6,342.12 -603.30 -73.48 5,958,460.19 560,421.38 11.19 478.55 MWD (3) 7,131.36 103.95 217.15 6,443.02 6,335.02 .626.70 -90.69 5,958,436.65 560,404.37 5.56 507.27 MWD (3) 7,161.35 104.62 220.43 6,435.62 6,327.62 .649.35 .108.89 5,958413.85 560,386.35 10.83 536.16 MWD (3) 7,191.71 104.21 223.50 8428.06 6,320.06 -671.21 -128.55 5,958,391.84 560,366.87 9.89 565.52 MWD (3) 7,22063 105.02 226.91 6,420.76 6,312.76 -690.93 -148.41 5,958,371.97 560.347.17 11.75 593.50 MWD (3) 7,250.59 105.28 229.79 6,412.93 6,304.93 .710.15 .170.01 5,958,352.58 560,325.72 9.32 622.37 MWD (3) Annotation TIP KOP Interpolated Azimuth Interpolated Azimuth 2/52019 2:03:59PM Page 3 COMPASS 5000.14 Build 85D ConocoPhillipsHrR �-' GNFS ConocoPhillips Definitive Survey Report Company: Project: Site: Well: Wellbore: Design: ConocoPhillips (Alaska) Inc. -Kupl Kuparuk River Unit Kuparuk 1D Pad 1D-08 1D-08LI 113-0811 Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Database: Well 1D-08 1D-08 @ 108.00usft 1D-08 @ 108.00usft True Minimum Curvature EDT 14 Alaska Production `. 7 Survey .... ___.... I Map Map Vertical MD Inc Azi TVD TVDSS +Nl-S +El -W Northing Easting DLS Section (usft) (1) Pl (usft) (usft) (usft) (usft) (°1100') Survey Tool Name Annotation (ft) (ft) (ftl 7,280.93 103.15 231.60 6,405.48 6,297.48 -728.77 -192.77 5,958,333.77 560,303.12 9.10 651.63 MWD (3) 7,312.29 101.43 234.62 6,398.80 6,290.80 -747.16 -217.27 5,958,315.19 560,278.77 10.89 681.96 MWD (3) I 7,341.33 99.32 237.05 6,393.57 6,285.57 -763.20 -240.91 5,958,298.96 560,255.27 10.98 710.01 MWD (3) 7,372.59 97.54 237.82 6,388.99 6,280.99 -779.84 -266.97 5,958,282.11 560,229.34 6.19 740.21 MWD (3) 7,400.67 95.53 238.52 6,385.79 6,277.79 -794.55 -290.67 5,958,267.21 560,205.76 7.57 767.37 MWD (3) 7,431.13 90.92 237.93 6,384.08 6,276.08 -810.56 -316.51 5,958,250.99 560,180.05 15.26 796.96 MIND (3) 7,461.46 88.93 238.69 6,384.12 6,276.12 -826.50 -342.32 5,958,234.86 560,154.37 7.02 826.48 MWD (3) 7,492.26 91.20 240.88 6,384.09 6,276.09 .841.99 .368.93 5,958,219.15 560,127.89 1024 856.25 MWD (3) 7,521.47 90.37 241.65 6,383.69 6,275.69 .856.03 -394.54 5,958,204.90 560,102.40 388 884.29 MWD (3) 7,552.35 95.50 246.28 6,382.10 6,274.10 -869.57 422.24 5,958,191.15 560,074.82 22.36 913.44 MWD (3) 7,583.07 94.58 248.39 6,379.40 6,271.40 -881.36 450.47 5,958,179.13 560,046.68 7.47 941.74 MWD (3) 7,616.15 94.21 250.31 6,376.87 6,268.87 -892.99 481.33 5,958,167.25 560,015.92 5.89 971.79 MWD (3) 7,648.12 94.11 252.59 6,374.55 6,266.55 -903.13 -511.56 5,958,156.87 559,985.77 7.12 1,000.34 MWD (3) 7,677.11 93.87 254.42 6,372.53 6,264.53 -911.34 -539.29 5,958,148.44 559,958.11 6.35 1,025.75 MWD (3) 7,719.09 93.10 255.70 6,369.98 6,261.98 -922.14 -579.77 5,958,137.31 559,917.72 3.55 1,062.02 MWD (3) 7,747.79 93.60 258.74 6,368.30 6,260.30 -928.48 -607.71 5,958,130.75 559,889.84 10.72 1,086.25 MWD (3) 7,777.76 95.10 262.16 6.366.03 6,258.03 .933.44 .637.18 5,958,125.55 559,860.42 12.43 1,110.59 MWD (3) 7,807.91 94.52 264.07 6,363.50 6,255.50 -937.04 -667.00 5,958,121.71 559,830.63 6.60 1,134.23 MWD(3) 7,838.91 93.10 263.05 6.361.44 6,253.44 .940.51 .697.74 5,958,118.00 559,799.92 5.64 1,158.41 MWD (3) 7,867.71 92.86 260.97 6,359.94 6,251.94 -944.51 .726.22 5,958,113.77 559,771.48 7.26 1,181.38 MWD (3) 7,897.77 91.81 258.59 6,358.72 6,250.72 -949.84 -755.77 5,958,108.20 559,741.97 8.65 1,206.05 MWD (3) 7,927.09 90.46 256.85 6,358.14 6,250.14 -956.07 -784.41 5,958,101.74 559,713.38 7.51 1,230.71 MWD (3) 7,957.27 89.45 254.74 6.358.16 6,250.16 -963,48 -813.67 5.958,094.10 559,684.19 7.75 1,256.63 MWD(3) 7,988.65 89.29 253.13 6,358.51 6,250.51 -972.16 -843.82 5,958,085.18 559,654.11 5.16 1,284.09 MWD (3) 8,017.43 88.31 249.65 6,359.11 6,251.11 -981.34 -871.09 5,958,075.78 559,626.92 12.56 1,309.86 MWD (3) 8,046.81 90.55 248.17 6,359.40 6,251.40 -991.91 -898.49 5,958,064.99 559,599.60 9.14 1,336.72 MWD (3) 8,077.35 94.46 249.04 6,358.07 6,250.07 4,003.04 -926.90 5.958.053.63 559,571.30 13.12 1,364.67 MWD (3) 8,107.24 92.12 243.68 6,356.35 6,248.35 .1,015.00 -954.22 5,958,041.45 559,544.07 19.54 1,392.45 MWD (3) 8,132.34 91.91 240.49 6,355.47 6,247.47 -1,026.74 -976,38 5,958,029.53 559,522.01 12.73 1,416.42 MWD (3) 8,162.39 91.63 236.90 6,354.54 6,246.54 .1,042.35 .1,002.04 5,958,013.72 559,496.48 11.98 1,445.60 MWD (3) 8,192.42 92.21 233.49 6,353.53 6,245.53 -1,059.47 .1,026,68 5,957,996.40 559,471.98 11.51 1,475.14 MWD (3) 21512019 2'03: 59PM Page 4 COMPASS 5000.14 Build 85D ConocoPhillips Company: ConocoPhillips (Alaska) Inc. -Kupl Project: Kuparuk River Unit Site: Kuparuk 1 D Pad Well: 1 D-08 Wellbore: ID -081-1 Design: 1D-0811 Survey ConocoPhillips Definitive Survey Report Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Database: 0 Well 1D-08 1D-08 @ 108.00usft 1D-08 @ 108.00usft True Minimum Curvature EDT 14 Alaska Production 1 Map Vertical Easting DES Section Survey Tool Name Annotation (°1100') (ft) (ft) 559,448.67 11.69 1,504.64 Map MD Inc Azi TVD TVDSS +Nl-S +E/ -W Northing (usft) V) (1) (usft) (usft) (usft) (usft) (k) 8,222.20 94.27 230.68 6,351.85 6,243.85 -1,07774 -1,050.14 5,957,977.95 8,252.20 94.34 228.35 6,349.60 6,241.60 -1,097.16 -1,072.89 5,957,958.34 8282.23 93.35 230.62 6,347.58 6,239.58 -1,116.63 -1,095.66 5,957,938.70 8,312.07 92.67 233.18 6,346.02 6,238.02 -1,135.01 -1,119.11 5,957,920.13 8,345.53 91.57 234.70 6,344.78 6,236.78 -1,154,69 -1,146.14 5,957,900.23 8,377.23 94.34 238.96 6,343.14 6,235.14 -1,172.01 -1,172.63 5,957,882.70 8,407.13 94.92 240.16 6,340.73 6,232.73 -1,187.11 -1,198.32 5,957,867.40 8,437.51 95.07 243.28 6,338.08 6,230.08 -1,20144 -1,224.97 5,957,852.85 8,468.46 94.00 244.99 6,335.64 6,227.64 -1,214.90 -1,252.73 5,957,839.17 8,496.72 91.87 246.73 6,334.19 6,226.19 -1,226,44 -1,278.49 5,957,827.42 8,527.13 92.39 250.88 6,333.06 6,225.06 -1,237.43 -1,306.81 5,957,816.21 8,564.36 92.80 255.17 6,331.37 6,223.37 -1,248.28 -1,342.36 5,957,805.07 8,590.61 92.89 256.51 6,330.07 6,222.07 -1,254.70 -1,367.80 5,957,798.45 8,618.43 94.67 258.16 6,328.24 6,220.24 -1,260.78 -1,394.88 5,957,792.15 8,649.61 92.98 256.27 6,326.16 6,218.16 -1,267.67 -1,425.22 5,957,785.02 8.679.63 93.32 253.71 6,324.51 6,216.51 -1,275.43 -1,454.17 5,957,777.03 8,710.31 94.00 251.67 6,322.55 6,214.55 -1,284.54 -1,483.39 5,957,767.69 8,738.66 92.95 249.85 6,320.63 6,212.83 -1,293.86 -1,510.11 5,957,758.15 8,768.77 91.63 247.28 6,319.63 6,211.63 -1,304.86 -1,538.11 5,957,746.93 8,799.10 91.38 245.05 6,318.83 6,210.63 -1,317.11 -1,565.84 5,957,734.46 8,828.94 91.41 241.10 6,318.10 6,210.10 -1,330.62 -1,592.44 5,957,720.74 8,857.38 93.14 239.80 6,316.97 6,208.97 -1,344.63 -1,617.16 5,957,706.53 8,879.07 95.51 239.89 6,315.34 6,207.34 -1,355.49 -1,635.86 5,957,695.51 8,912.00 95.51 239.89 6,312.18 6,204.18 -1,371.94 -1,664.21 5,957,678.84 0 Well 1D-08 1D-08 @ 108.00usft 1D-08 @ 108.00usft True Minimum Curvature EDT 14 Alaska Production 1 Map Vertical Easting DES Section Survey Tool Name Annotation (°1100') (ft) (ft) 559,448.67 11.69 1,504.64 MWD (3) 559,426.08 7.75 1,534.46 MWD (3) 559,403.46 8.23 1,564.32 MWD (3) 559,380.17 8.87 1,593.91 MWD (3) 559,353.30 5.60 1.626.93 MWD (3) 559,326.95 16.01 1,657.91 MWD (3) 559,301.38 4.45 1,686.75 MWD(3) 559,274.85 10.24 1,715.74 MIND (3) 559,247.20 6.50 1,744.88 MWD (3) 559,221.55 9.73 1,771.25 MWD (3) 559,193.31 13.74 1,799.05 MWO(3) 559,157.84 11.56 1,831.87 MWD (3) 559,132.48 5.11 1,854.38 MWD (3) 559,105.45 8.72 1,877.84 MWD (3) 559,075.17 8.12 1,904.16 MWD (3) 559,046.29 B.59 1,930.12 MWD (3) 559,017.13 7.00 1,957.23 MWD (3) 558,990.50 7.40 1,982.71 MWD (3) 558,962.59 9.59 2,010.28 MWD (3) 558,934.96 7.40 2,038.56 MWD (3) 558,908.48 13.23 2,066.91 MWD (3) 558,883.87 7.61 2,094.30 MWD (3) 558,865.26 10.93 2,115.20 MWD (3) 558.837.04 0.00 2,146.88 PROJECTED to TO 2/5!2019 2:03:59PM Page 5 COMPASS 5000.14 Build 85D STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION :e n• d.,. <.s cv G iJ � isf� FEB 1 1 2O19 WELL COMPLETION OR RECOMPLETION REPORT ANDS 1Fk_' 1a. Well Status: 0110 Gas❑ SPLUG ❑ Other ❑ Abandoned ❑ Suspended❑ 20AAC 25.105 20AAC 25.110 GINJ ❑ WINJ ❑ WAG[-] WDSPL ❑ No. of Completions: 1b. Well Class: Development l] Exploratory❑ Service ❑ Stratigraphic Test ❑ 2. Operator Name: ConocoPhillips Alaska, Inc. 6. Date Comp., Susp., or Aband.: 1/10/2019 14. Permit to Drill Number/ Sundry: 218-172 3. Address: P.O. Box 100360 Anchorage, AK 99510-0360 7. Date Spudded: 1/3/2019 15. API Number: , 50.029.20266-60-00 4a. Location of Well (Governmental Section): Surface: 600' FNL, 602' FEL, Sec 23, T11N, R10E, UM Top of Productive Interval: 647' FNL, 588' FEL, Sec 23, T11N, R10E, UM Total Depth: 1973' FNL, 2268' FEL, Sec 23, T11N, R10E, UM 8. Date TD Reached: 1/5/2019 16. Well Name and Number: KRU 1D -08L1 ' 9. Ref Elevations: KB:108 ' GL: 71 ' BF: 17. Field / Pool(s): Kuparuk River Field/Kuparuk River Oil Pool 10. Plug Back Depth MD/TVD: N/A 18. Property Designation: ADL 25650 4b. Location of Well (State Base Plane Coordinates, NAD 27): Surface: x- 560490 y- 5959064 Zone- 4 TPI: x- 560505 y- 5959018 Zone- 4 Total Depth: x- 558837 y- 5957679 Zone- 4 11. Total Depth MD/TVD: ' 6912/6312 19. DNR Approval Number: LONS 79-016 12. SSSV Depth MD/TVD: N/A 20. Thickness of Permafrost MD/TVD: 1630/1630 5. Directional or Inclination Survey: Yes ❑Q (attached) No ❑ Submit electronic and printed information per 20 AAC 25.050 13. Water Depth, if Offshore: NIA (ft MSL) 21. Re-drill/Lateral Top Window MD/TVD: 6396/6395 22. Logs Obtained: List all logs run and, pursuant to AS 31.05.030 and 20 AAC 25.071, submit all electronic data and printed logs within 90 days of completion, suspension, or abandonment, whichever occurs first. Types of logs to be listed include, but are not limited to: mud log, spontaneous potential, gamma ray, caliper, resistivity, porosity, magnetic resonance, dipmeter, formation tester, temperature, cement evaluation, casing collar locator, jewelry, and perforation record. Acronyms may be used. Attach a separate page if necessary GR/Res 23. CASING, LINER AND CEMENTING RECORD WT. PER GRADE SETTING DEPTH MD SETTING DEPTH NHOLE SIZE CEMENTING RECORD D AMOUNT CASING FT TOP BOTTOM TOP BOTTOM PULLED 16 65 H-40 23 75 23 75 30 475 sx Arcticset 11 cmt 103/4 45.5 K-55 23 2230 23 2230 133/4 2400 sx Permafrost curt 7 26 J-55 22 6869 22 6868 97/8 350 sx Class G 51/2 15.5 L-80 19 6295 19 6294 N/A Tieback Liner 23/8 4.6 L-80 6479 8912 6476 6312 3 Slotted Liner 24. Open to production or injection? Yes 0 No ❑ If Yes, list each interval open (MD/TVD of Top and Bottom; Perforation Size and Number; Date Perfd): SLOTTED LINER @: COMPL.ETION 6492-8849 MD and 6488-6317 TVD ... 1/9I2019 DATE 10111 VERIFIED 25. TUBING RECORD SIZE DEPTH SET (MD) PACKER SET (MDrFVD) 3 112 6338 6294/6292 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. Was hydraulic fracturing used during completion? Yes ❑ No ❑✓ Per 20 AAC 25.283 (1)(2) attach electronic and printed information DEPTH INTERVAL (MD) 1AMOUNT AND KIND OF MATERIAL USED 27. PRODUCTION TEST Date First Production: 1/26/2619 Method of Operation (Flowing, gas lift, etc.): GAS LIFT Date of Test: 1/31/2019 Hours Tested: 14.6 Production for Test Period Oil -Bbl: 1058 Gas -MCF: 3702 Water -Bbl: 2770 Choke Size: 176 Gas -Oil Ratio: 1 3501 Flow Tubing Press. 25OPs! I Casino Press: I 1283osi Calculated 24 -Hour Rate Oil -Bbl: 1715 Gas -MCF: 60 Water -Bbl: 4492 Oil Gravitv - API (corr): 1 24 deg Form 10-407 Revised 5/2017 G 211411-7 ,CQI�JINUED ON PAGE 2 41,120/11/f'//9 RBDMS tM FEB 13 2019 Submit ORIGINIAL only-_ 28. CORE DATA Conventional Core(s): Yes ❑ No ❑+ Sidewall Cores: Yes ❑ No 2 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 ❑� If yes, list intervals and formations tested, briefly summarizing test results. Permafrost - Top Surface Surface Permafrost - Base 1630 1630 Attach separate pages to this form, if needed, and submit detailed test Top of Productive Interval 6418 6416 information, including reports, per 20 AAC 25.071. Formation @ TPI -Kuparuk Al TO 8912 6312 Formation at total depth: Ku aruk A 31. List of Attachments: Daily Operations Summary, Definitive Survey, Schematic Information to be attached includes, but is not limited to: summary of daily operations, wellbore schematic, directional or inclination survey, core analysis, paieontolooical report production or well test results per 20 AAC 25.070. 32. I hereby certify that the foregoing is true and correct to the best of my knowledge. Authorized Name: J i ( Contact Name: William Lon Authorized Title: S waeer-7-P Contact Email: William.R.Lon co .com Authorizedr Contact Phone: 263-4372 Signature: Date: IN TR TIONS General: This form and the required attachments provide a complete and concise record for each well drilled in Alaska. Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed. All laboratory analytical reports regarding samples or tests from a well must be submitted to the AOGCC, no matter when the analyses are conducted. Item 1 a: Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Item 1b: Well Class - Service wells: Gas Injection, Water Injection, Water -Alternating -Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Item 4b: TPI (Top of Producing Interval). Item 9: The Kelly Bushing, Ground Level, and Base Flange elevations in feet above Mean Sea Level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 15: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). Item 19: Report the Division of Oil & Gas / Division of Mining Land and Water: Plan of Operations (LO/Region YY -123), Land Use Permit (LAS 12345), and/or Easement (ADL 123456) number. Item 20: Report measured depth and true vertical thickness of permafrost. Provide MD and TVD for the top and base of permafrost in Box 29. Item 22: Review the reporting requirements of 20 AAC 25.071 and, pursuant to AS 31.05.030, submit all electronic data and printed logs within 90 days of completion, suspension, or abandonment, whichever occurs first. Item 23: Attached supplemental records should show the details of any multiple stage cementing and the location of the cementing tool. Item 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, or Other (explain). Item 28: Provide a listing of intervals cored and the corresponding formations, and a brief description in this box. Pursuant to 20 AAC 25.071, submit detailed descriptions, core chips, photographs, and all subsequent laboratory analytical results, including, but not limited to: porosity, permeability, fluid saturation, fluid composition, fluid fluorescence, vitrinite reflectance, geochemical, or paleontology. Item 30: Provide a listing of intervals tested and the corresponding formation, and a brief summary in this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Item 31: Pursuant to 20 AAC 25.070, attach to this form: well schematic diagram, summary of daily well operations, directional or inclination survey, and other tests as required including, but not limited to: core analysis, paleontological report, production or well test results. Form 10-407 Revised 5/2017 Submit ORIGINAL Only 1D-08 Final CTD Completion 16!'65# H-00 shoe C 75' RKB 70-3/4" 45# K-55 shoe Q 22301 RKB KOP Q 6396' MD C -sand perfs 6384'- 6472- 6479'- 472'6479'- 6484' 7" 26# J-65 shoe 6869' RKB 3 1/2' TuNN L-80 W IBT 312' Landing OS Nipple 0493' like (217Y 10) 3-12' Cam. KBG Mandrels @ 2591', 3786'. 4688', 5336, 5798', 6012' 5' Seel Bore Receptacle wl 4" bore @ 6110 RKB 5' 3�V2"Crossover@6129'RKB Cam. DS Larkliig Nipple @ 6175 RKB (ID 2.813') Cam. GLM @ 6227' RKB Baker GBH -22 Locator @ 6283' RKB Baker 80-00 Seal Assembly Q 6284' RKB Baker FB -1 Packer @ 5294' RKB Baker SBE @ 6296' RKB Cam. D Nipple @ 6326' (Milled Out- 2.811" ID) Baker WLEG @ 633T RKB !bated 1tJ,nMlg(WRL) 1D-0811-01 TD Q 9480' MD Top of Liner @ 6320' MD D -08L1 TO@8912 MD Top of Aluminum Billet ig 6474' MD KUP PROD WELLNAME 1D-08 WELLBORE 1D-08 pa� h,'' Well Attribub Max Angle 1 TD � �,I''ie� Fka Nama w¢Ilborc apwWl wenlwt¢sbwa n¢I .1 mplN 711 Ron IRMe1 Alaska. Inc. KUPARUK RIVER UNIT 500292026600 PROD 89 2.100.00 68800 In. .1. 11 1 Last Tag Vwtial¢ur,uec pcmap pnnWtlon goonjotl(BI End Dale wellbore cast MW By Last Tag'ELMD TIED TO -111 8,510.0122812018 '.. Conaijw SAUDILast CONDUCTOR: XIGCame NIPPLE.Caslnp SURFACE:a AMO Gas LIFT12SU° GAS UFT: 67M.a GRS LIFT. AM I DRS LIFT: a3u,a GASOFeATM3 CAR JFT B.Mt i LOWTOR:41(e3 TRALASSY:6.10 vAGI(ER:d3IX1.T TIE d9CK LINER 512x91(1 ®edeaM: 1Gf.Ma S.E.6.M2 N1vpLE:aLSs WLEG: 6,1313 WHIPSTOCK e.aW.OIIIII IPERF6386.G8AT2.n FRAC', aMeO IPERFI 847- OAIEAl PwG: e.Mo.D IPERF. RENT guitar o- PERFanuaguinuo- PRODUCTON:a1 ,M.O 110,4-111 Rev ReasonAnnoralp End mw w-ueone Lasl Moa By Rev Reason. Add mdled out nipple 1/212019 1D-08 tergusp Casing Strings oeamiuill Oo tin) ID lin) Top LURE) Set Depth(I eel Depth IND).. WULen IIGrave Top Thr. CONDUCTOR 16 1506 230 750 750 6500 H40 WELDED Caere De¢ription .0 pn) ID hnl TopIKKB) Set Degh(RNg) Srt Depth IND)... WOLen I1... Grave Top Th. SURFACE 10 W4 979 22.8 2,23002,229.4 4550 K-55 Deacrlptlon .0 on) II Ta WO) Sedespenter") aper Depth tNOl... when (L.. Grave Top Th. PRODUCTION 7 6.28 22.1 6,869.0 6,867.5 26.00 J-55 BUTT aalnp DescNpdbn ODlln) IDllnl Tap lRRal andurpnbbehe apel Depdh UVO).-j'cen IL.. Gnae Top Threaa TIE BACK LINER 512 x 51/2 4.28 19.1 6,295.5 6294.0 15.50 L-80 BTCM 312 @ 6128.69 Liner Details omlD Top (uts) Toplrvo)Top 4) Item Dee can hid ;l 6,110.1 6,10811011 1 14J SBR BTC PIN PIN CARING SEAL BORE RECEPTACLE 4.000 6,1281 6,127.3 147 XO Reducing 5" BTC Box x 3-12' EUE Pin cross over sub 2.992 6,134.1 6,1M.7 1.46 TUBING 35', 9.3X, LAID EUE-Mod 8rd Tubing joint 2.992 6,175.0 6,173.6 TAPE NIPPLE CAMCO 'DS' LANDING NIPPLE k T111320 2.812 6,186.4 6184.9 1.45 TUBING 3.5". 9,M, L-80 EUE-Mod Bed Tubing joint 2,992 6,227.0 8,225.5 1.7 GAS LIFT CAMCO MMG GLM 419ME07 2920 6246d 6.244.5 114 TUBING 35".9 U. LBO EUE-Mod Bid Tubing joint 2992 6,2829 6,281.0 0.90 LOCATOR BAKER GBH -22 LOCATOR SUB 2990 6284.1 6,2826 0.89 PBR BAKER 8040 SEAL ASSY wl 3-B Space out 2.990 Tubing Strings Tubing Deu,UT-7 54inp Md... ID gn1 iop(XKID set Cepas tR.. set Depth jNOl I... W1(lbRg IG onTopconneur- TUBINGWO2014 3112 2.99 164 6,1232 6,1218 9.30 L80 IBT Completion Details Top Me) TapIMI Nominal T-PMM ME) I.1 Item Des Com head 165 16AJ 005 1 HANGER FMC TUBING HANGER 2.910 492.9 4929076 NIPPLE DS LANDING NIPPLE 2.875 6,104.2 6,1028 147 LOCATOR BAKER LOCATOR SUB 2.992 6.105.1 ..rule 1 1.47 ISILAP11 BAKER 8040 SEALS WI 7' -FT SPACE OUT 2990 Tubing Domineering slang ani 110 pn) TOP 9IKB) Set Depth lR.. s¢I Depth lNol l- - WI d"i Grave Top Con; --tion TUBING 3112 2.99 6,293.7 6,338.0 6,336, 920 N-80 BUTT Completion Details ToptNO) Toprood Nominal Top (RK.) IRKS) M Ittm Des Co. ID lin) 6,2937 6,2922 082 PACKER BAKER'FB-1'PACKER 4.000 62962 6,2941 081 SBE BAKER SEAL BORE EXTENSION 4.0be 6,3255 6,324.0 078 NIPPLE CAMCO '0'NIPPLE (Milled out to 317=17118) 2800 6,337.3 6,3359 078 WLEG BAKER WIRELINE ENTRY GU IDE 2.992 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top"' TOpind TOOIRK. IRKS) I7 pas Com Run Dale IO Un) 6,400.0 6398.5 017 WHIPSTOCK NS HEW whipstock 1/2/2019 0000 655(1.0 65485 OJ7 PLUG Can Iron Bridge Plug 5/14/1978 0.000 Perforations & Slots aunt Dens 1, Here .1. lrvo) bholaM ToptRKB) BM MM ouni 'I Linkev Zone Dab ) Type Com 63840 8,472.06.382.5 64705 CA C- 5/811978 40 (PERF 1D-08 6,479.0 6,484.0 6,477.5 64825 C-2, ID -08 51811978 401PERF 6,636.0 6,841.0 8,834.5 6fi395 A-5, M-08 YSM978 0.0 (PERF 6,644.0 6,652.0 8,842.5I 6,6505 A -S, 1U`a 51511978 40 JIPFRF Frac Summary ...Do. Proppent Designee il6lP,oppanl In Lormahan g6) 72711978 Spi 1 Sreebeb Top1 Kate)a 84t unx to --o syscem VMcleanerna Vol Slu,ylbbp 72711978 T"eve she he Mandrel Inserts Sr an an Tap MD) Vales tNeM1 PMSIu TRO Run N Top"U're 1RKB) Now Model OO (in) Snv Type Type (IN 1WI) Run Dale Com 2,5414 2.5406 CAMCO KBG- 1 GAS LIFT GLV BTM .1 12240 122412018 29 2 3786.3 3)852 CAMCO -KBU-- 1 GASLIFT OV BTM 0.250 00 12/2412018 2.9 3 4,688.3 4,687.1 CAMCO KB - 1 GAS LIFT DMV BTM 0.000 0.0 12/24/2018 2.9 0 5334.5 5,333.3 CAMCO KBG- 1 GAS LIFT DMV BTM 0.000 0.0 12/23/2018 29 5 5,7983 5,797.0 CAMCO KBG- 1 GAS LIFT DMV DK -1A 0. OD 3/24/2014 29 6 fiOil 6010.3 CAMCD KB- 1 GAS LIFT DMY DK -1A 0,000 i 0.0 3124/2014 29 Notes: General & Safety Env OF Arro a nce 12/25'276 NOTE: WAIVERED WELL: IA X OA COMMUNICATION 8184010 IN.,: View Santiod OCw/AsSIUSSChen iC9.0 2/512019 INI View Scbetnauc s Alaska Schematic 10.0 ConocoPhillips Alaska, Im KUP PROD WELLNAME 1D-08 WELLBORE 1D -08L1-01 wo. IDmLI-01.axNla rbAalanm Last Tag V. xlwnam l=)) AnnoUlion oevlb(RKB) End oaM 1 Wed.. fast mM By .._...............______......... 1111.... 1111...... Last Tag: 1D-D8L1-91 lennalt HANGER. 164 i Casing Strings Casing Cascriptnn oo nn) IO in) T. 13) Sx- mKB) Set Dept, ITADl. MNLen 11,., Gmd. rov rnmad SLOTTED LINER Li -01 203/8 1.99 66]95 9,8400 0.60 LA0 Sit LinerDetails Nal Top IRKR) I Top j1Y0)ME) iop 6/1/16 P) Hem Oes Com tin) orvoccrLN. N97a0 6,6795 6,5664 101.11 ALUMINUM Depleymain sleeve 1920. BILLET Frac Summary "Ne"""' paopl++nt-Radad(a) proppoM In FelmaLM (IE) NIPPLE. aPe.9 727/1978 amp SNgNDah Top DepMIkK8) BI.(.8) LlnM to Fluitl $yepm voltlean tpbl) V0151w,ry Lbl) 1 7/27/1978 16,384 0 16,484 0 Notes: General & Safety End Late Annoratron 2162019 NOTES. View Schematic w7ARSNE 60amaliL 100 SUIEWE;..Z..0 Gas LIFT, ;5119 ARSUFT:s.ws GAS UFT:4.Bae.] Gs5UFR5.ases WSLIfT:5.7989 .LIFT8.011 LOCATOR:8.101.2 SEALASS'nel.1 PACKEW.d]BA7 TIE SACK UNEP 51Ry 312 ® 813RR1;1—N5.S SBE', 8.29613 PNODUCTIGN',? 1-6,dd SLOTTED LINER LIL1: B879.5� A,B100 Uperations Summary (with Timelog Depths) 1 D-08 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Sian Depth Start Time End Time Our (hr) Phase Op Code Acdviy Code Time P -T -X Operation (flKB) End Depth(RKB) 12/31/2018 12/31/2018 2.00 MIRU MOVE RURD P Continue to follow RD check list, lift 0.0 0.0 16:00 18:00 landings and stairs, 12/31/2018 12/31/2018 2.00 MIRU MOVE RURD P Crew change, continue to work RD 0.0 0.0 18:00 20:00 checklist, trucks on location @ 18:15 pm, PJSM, hook up to pit module jack up and move to the entrance of the pad, install jeep. 12/31/2018 12/31/2018 1.20 MIRU MOVE RURD P Hook up truck to Sub Module, move 0.0 0.0 20:00 21:12 off well, install jeep, phone security 12/31/2018 12/31/2018 0.47 MIRU MOVE MOB P Pull onto access road 0.0 0.0 21:12 21:40 12/31/2018 1/1/2019 2.33 MIRU MOVE MOB P On spine road, head to 1D -pad 0.0 0.0 21:40 00:00 1/1/2019 1/1/2019 1.75 MIRU MOVE MOB P Continue rig move to next location 1D- 0.0 0.0 00:00 01:45 pad 1/1/2019 1/1/2019 2.00 MIRU MOVE MOB P On location, remove jeeps, hook up 0.0 0.0 01:45 03:45 truck to drilling sub module, spot over well 1/1/2019 1/1/2019 1.75 MIRU MOVE MOB P Spot in rig mats, spot pit module next 0.0 0.0 03:45 05:30 to drilling sub, phone out scaffold crew to rig up in cellar, pusher headed to retrieve shop from 3C -pad. 1/1/2019 1/1/2019 3.50 MIRU MOVE MOB P Work on Rig Move check list, secure 0.0 0.0 05:30 09:00 all landings, walking surfaces, and cellar floor, hook up PUTZ (inter- connect).Rig up steam lines / heaters. Scaffolding crew dg up scaffolding in pits, tool house on location, rig up tiger tank line placing tiger tank off drillers side along well row. 1/1/2019 1/1/2019 4.00 MIRU WHDBOP NUND P Nipple up BOP stack, tighten tree 0.0 0.0 09:00 13:00 bolts, valve crew service tree. Service rig valves in preparation4 for BOPe lest, Rig Accept 12;00 1/1/2019 1/1/2019 1.00 MIRU WHDBOP NUND P Complete prepping for BOPe test. 0.0 0.0 13:00 14:00 Line up and fluid pack rig. Obtaint shell test 1/1/2019 1/1/2019 6.00 MIRU WHDBOP BOPE P Start full initial BOPE lest. Test 0.0 0.0 14:00 20:00 witnessed by Adam Earl, AOGCC. Fail pass on upper blind shears, test # 4, Test PVT's, Gas detectors, and Koomey 1/1/2019 1/1/2019 1.00 MIRU WHDBOP CTOP P BOPe test complete. PT TT line 0.0 0.0 20:00 21:00 1/1/2019 1/1/2019 1.50 MIRU WHDBOP OTHR P PJSM R/U and pull BPV, 350 PSI 0.0 0.0 21:00 22:30 under plug, r/D and load out BPV crew 1/1/2019 1/1/2019 0.50 MIRU WHDBOP CTOP P Pressure test CTC 4000PSI, 0.0 0.0 22:30 23:00 1/1/2019 1/2/2019 1.00 MIRU WHDBOP CTOP P Ademp to bleed off well. All gas. Line 0.0 0.0 23:00 00:00 up to bull head. Pump 70 BBls seawater down well. Well on vac 1/2/2019 1/2/2019 0.50 MIRU WHDBOP PRTS P Pressure test both PDL's 0.0 0.0 00:00 00:30 1/2/2019 1/2/2019 0.40 MIRU WHDBOP CTOP P Fill hove to determine loss rate, Unable 0.0 0.0 00:30 00:54 to fill hole 1/2/2019 1/2/2019 2.00 PROD1 RPEQPT PULD P PJSM, M/U NES HEW whipstock, P/U 0.0 85.9 00:54 02:54 coiltrak with gyro trek tool, M/U to coil and surface test. orient at surface to test gyro 1/2/2019 1/212019 1.40 PROD1 RPEQPT TRIP P RIH BHA#1 with NES HEW 85.9 6,300.0 02:54 04:18 whipstock, EDC open pumping min rate, choke closed, zero WHP Page 1110 Report Printed: 1/21/2019 Operations Summary (with Timelog L)epths) 161 D-08 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Depth Stan Time End The our (hr) Phase Op Code Activity Code Time P -T -x Operation (flKB) End Depth (fiK8) 1/2/2019 1/2/2019 0.20 PRODi RPEQPT DLOG P Log K1. Looks like -11' correction/ Geo 6,300.0 6,400.0 04:18 04:30 not confident with log 1/2/2019 1/2/2019 0.30 PRODt RPEQPT TRIP P PUH to log HRZ 6,400.0 6,050.0 04:30 04:48 1/212019 1/2/2019 0.30 PROD1 RPEQPT DLOG P Log HRZ. for -11' correction 6,050.0 6,191.0 04:48 05:06 1/2/2019 1/2/2019 0.10 PROD? RPEQPT TRIP P PUH to catch GLM in CCL log 6,191.0 6,095.0 05:06 05:12 1/2/2019 1/2/2019 0.30 PROD1 RPEQPT DLOG P Log CCL 6095 to 6475 6,095.0 6,475.0 05:12 05:30 112/2019 1/2/2019 0.50 PROD1 RPEQPT DLOG P Corralate CCL Log, PUH 6,475.0 6,394.0 05:30 06:00 1/212019 1/2/2019 0.20 PRODt RPEQPT TRIP P RBIH to set depth 6,394.0 6,405.0 06:00 06:12 1/2/2019 1/212019 0.50 PROD1 RPEQPT TRIP P Shut down pump, take Gyro Survey 6,405.0 6,405.0 06:12 06:42 1/2/2019 1/212019 0.75 PROD1 RPEQPT TRIP P No correction, move up hole 1.0', 6,405.0 6,404.0 06:42 07:27 shut down pump, take Gyro Survey, close EDC Survey's, 168.1 °, 168.2°, and 167.8" 1/2/2019 1/2/2019 0.30 PROD? RPEQPT WPST P Set NS HEW Whipstock, bring pump 6,404.0 6,404.0 07:27 07:45 up to 0.5 bpm catch fluid, continue pumping 0.5 bpm up to shear pressure 2,100 psi, set down 5.0k, 1/2/2019 1/2/2019 1.10 PRODi RPEQPT TRIP P POOH, PJSM for BHA change 6,404.0 86.0 07:45 08:51 1/212019 1/2/2019 0.30 PRODi RPEQPT PULD P At surface, check well for flow, well on 86.0 86.0 08:51 09:09 a vac. bring c -pump on line 2.4 bpm losses. 1/2/2019 1/2/2019 0.30 PROD1 RPEQPT PULD P Unstab INJH, stand back 86.0 0.0 09:09 09:27 CoilTrak/GyroTrak tools. LD setting tools 1/2/2019 1/2/2019 0.50 PRODt WHPST PULD P PU/MU milling BHA with Weatherford 0.0 F9.3- 09:27 09:57 1.0 fixed bend motor. 1/2/2019 1/2/2019 1.65 PROD1 WHPST TRIP P Tag up zero counters, RIH 89.3 6,140.0 09:57 11:36 1/2/2019 1/2/2019 0.20 PROD1 WHPST CLOG P Log the HRZ, correction of minus 6,140.0 6,206.0 11:36 11:48 12.0', PUW 33 k 1/2/2019 1/212019 1.20 PROD1 WHPST TRIP P Continue IH, circulating 100 bbl High 6,206.0 6,380.0 11:48 13:00 Vis Pill (148 k LSRV) 1/2/2019 1/212019 0.30 PROD1 WHPST CIRC P Continue pumping High Vis Pill 6,380.0 6,380.0 13:00 13:18 1/2/2019 1/212019 0.75 PROD1 WHPST TRIP P Shut down pump, take Gyro -Surveys, 6,380.0 6,380.0 13:18 14:03 171.5°, 171.6°, and 168.9°, satisfied with TF, RIH tag HEW @ 6,400' 1/2/2019 1/2/2019 0.75 PRODi WHPST TRIP P PUH 8.0', Take Gyro -Surveys, 161.4°, 6,380.0 6,399.8 14:03 14:48 173.2°, 171.4°, bring pump online, creep inhale to 6399.8' 1/2/2019 1/2/2019 5.10 PROD1 WHPST WPST P Start milling window 1.81 bpm @ 6,399.8 6,402.5 14:48 19:54 3,600 psi, Diff=915 psi, WHP=O, BHP=2,759. IA=O, OA=144 1/2/2019 1/2/2019 0.90 PROD1 WHPST WPST P Call bottom of window, Continue time 6,402.5 6,403.0 19:54 20:48 1 1 milling 1 foot for string reamer to ecit 1/2/2019 1/2/2019 1.10 PROD1 WHPST MILL P Mill ralhole to 6426, 1.85 BPM @ 6,403.0 6,426.0 20:48 21:54 3300 PSI FS, BHP=2937 1/2/2019 1/2/2019 0.60 PROD1 WHPST REAM P Back ream up through window as 6,426.0 6,388.0 21:54 22:30 drilled. Shut down pump @ 6399'. Tahe gyro survey. Trio in 9 feet to check previous gyro survey - Good 1/2/2019 1/2/2019 0.30 PROD1 WHPST REAM P Ream down as drilled, 1.83 BPM @ 6,388.0 6,408.0 22:30 2248 3237 PSI FS Page 2/10 Report Printed: 112112019 Operations Summary (with Timelog Depths) ID -08 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Stan Depth Start Time End Time our (e) phase Op Code Acdvily Code Time P -T-% Operation (AKB) End Depth (ftKB) 1/2/2019 1/2/2019 0.20 PRODi WHPST REAM P 6408, Backream window 30R of as 6,408.0 6,399.0 22:48 23:00 drilled, PUW=33K 1/2/2019 1/2/2019 0.20 PROD1 WHPST REAM P Roll TF to as drilled, Ream down to 6,410.0 6,399.0 23:00 23:12 6410. Backream up at 30L of as drilled to 6410 1/2/2019 1/2/2019 0.40 PROD1 WHPST REAM P Roll TF to as drilled. ream down. 6,399.0 6,412.0 2312 23:36 Orient to 180 of as drilled. Take gyro survey to confim toolfaoe. Back ream up, PUW=32K 1/2/2019 1/2/2019 0.30 PROD1 WHPST REAM P Back ream up, PUW=32K. 1.83 BPM 6,412.0 6,399.0 23:36 23:54 1/2/2019 1/3/2019 0.10 PRODi WHPST TRIP P Dry drift window clean. Tag TD to 6,399.0 6,426.0 23:54 00:00 confirm whipstock in place, Start POOH 1/3/2019 1/3/2019 0.10 PROD1 WHPST WPST P Stop at 6388, take gyro survey - Good 6,426.0 6,388.0 00:00 00:06 113/2019 1/3/2019 0.90 PROD1 WHPST TRIP P POOH for build section BHA #3 6,388.0 82.0 00:06 01:00 113/2019 1/3/2019 0.60 PROD1 WHPST PULD P PJSM. Flow check well. Lay down 82.0 0.0 01:00 01:36 BHA #2. Mill out @ 2.79 No Go. reamer out @ 2.79 No Go 1/3/2019 1/3/2019 0.70 PROD1 DRILL PULD P P/U BHA#3 with 2.4° AKO motor 0.0 75.0 01:36 02:18 1/3/2019 1/3/2019 1.30 PROD1 DRILL TRIP P Trip in well, EDC closed. Pumping min 75.0 6,130.0 02:18 03:36 rate 1/3/2019 1/3/2019 0.20 PROD? DRILL DLOG P Log HRZ for -11.5' 6,130.0 6,167.0 03:36 03:48 1/3/2019 1/3/2019 0.10 PROD1 DRILL TRIP P Continue in well 6,167.0 1 6,374.0 03:48 03:54 113/2019 1/3/2019 0.50 PROD1 DRILL DLOG P Stop for gyro survey, Get oriented to 6,374.0 6,424.0 03:54 04:24 171 degrees from true north, PUW=34K 1/3/2019 1/3/2019 0.60 PROD1 DRILL TRIP P Continue in well, clean pass through 6,424.0 6,420.0 04:24 05:00 window, take weight @ 6424. PUH. RBIH to 6420'. take gyro TF survey. PUH 10', RBIH to 6420 and resurvey 1/3/2019 1/3/2019 0.70 PROD1 DRILL DRLG P Gyro shows 184° from true north. 6,420.0 6,454.0 05:00 05:42 Bring pumps online 1.82 BPM @ 3070 PSI FS, BHP=2882 1/3/2019 1/3/2019 0.50 PRODi DRILL WPRT P BHA is held up in the window, minus 6,454.0 6,454.0 05:42 06:12 3.0 k, PUW 36 k 1/3/2019 1/312019 0.80 PROD1 DRILL DRLG P OBD, 1.78 bpm at 2,633 psi, Diff --403 6,454.0 6,480.0 06:12 07:00 psi, WHP=O, BHP=2955, IA=O, OA=171 11312019 1/3/2019 0.20 PROD1 DRILL WPRT P TD with Gyro tool 6,480% PUW 36 k, 6,480.0 6,379.0 07:00 07:12 PUH 1/3/2019 1/3/2019 0.20 PROD1 DRILL WPRT P Obtain check shot from GyroTrak to 6,379.0 6,379.0 07:12 07:24 confirm operational 1/3/2019 1/3/2019 1.30 PROD1 DRILL TRIP P POOH, w/no-rerurns 6,379.0 75.0 07:24 08:42 1/3/2019 1/3/2019 0.30 PROD1 DRILL PULD P LD GyroTrak tools on a dead well 75.0 0.0 08:42 09:00 1/3/2019 1/3/2019 0.70 PRODi DRILL PULD P Adjust AKO on motor from 2.40" to 0.0 0.0 09:00 09:42 2.46° 1/3/2019 1/3/2019 0.60 PRODt DRILL PULD P PU/MU standard build section BHA #4 0.0 72.2 09:42 10:18 1/3/2019 1/3/2019 1.20 PROD1 DRILL TRIP P RIH 72.2 6,130.0 10:18 11:30 1/3/2019 1/312019 0.20 PROD1 DRILL DLOG P Log the HRZ correction of minus 11.5' 6,130.0 6,183.6 1130 1142 Page 3110 Report Printed: 1/21/2019 Operations Summary (with Timelog Depths) 1 D-08 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Stan Depm Start Tim End Time our (hr) Phase Op Code Artily Code Tune P -T -X Operation (H<13) End Depth (WS) 1/3/2019 1/3/2019 0.20 PROD1 DRILL TRIP P Close the EDC, PUW 33 k 6,183.6 6,183.0 11:42 11:54 1/3/2019 1/3/2019 0.10 PROD1 DRILL TRIP P Continue IH through window clean 6,183.0 6,480.0 11:54 12:00 1/3/2019 1/3/2019 1.00 PRODt DRILL DRLG P OBD, 1.88 bpm at 3,248 psi, Diff --403 6,480.0 6,580.0 12:00 13:00 psi, WHP=92, BHP=3,157, IA=O, OA=173 1/3/2019 1/3/2019 0.20 PROD1 DRILL WPRT P PUH, lower pump rate to 1.5 bpm to 6,580.0 6,580.0 13:00 13:12 allempt higher build rate. 1/3/2019 1/3/2019 3.00 PROD1 DRILL DRLG P BOBD, 1.51 bpm at 2,586 psi, 6,580.0 6,750.0 13:12 16:12 Diff --406, WHP=125, BHP=3,158, IA=O, OA=174 1/3/2019 1/3/2019 0.20 PROD1 DRILL WPRT P TD Build section, PUH for logging RA, 6,750.0 6,445.0 16:12 16:24 PUW 34 k 1/3/2019 1/3/2019 0.20 PRODt DRILL WPRT P Shut down TF, 220° ROHS, log the 6,445.0 6,379.0 16:24 16:36 RA, marker scued by parent WB perrs, continue PUH 1/3/2019 1/3/2019 1.40 PROD1 DRILL TRIP P Open EDC, Continue POOH 6,379.0 82.0 16:36 18:00 113/2019 1/3/2019 0.70 PROW DRILL PULD P At surface, flow check well, cew 82.0 82.0 18:00 18:42 change out 1/312019 1/3/2019 0.50 PROD1 DRILL PULD P Unstab injector. Lay down motor, FVS, 82.0 0.0 18:42 19:12 and bit 1/3/2019 1/3/2019 1.50 PROD1 DRILL SVRG P Service reel, horse head inc. counter. 0.0 0.0 19:12 20:42 Inspect injector. Pull choke B and Micro motion apart. Change out pack offs 1/3/2019 1/3/2019 1.00 PROD1 DRILL PULD P Dial motor to .5 and scribe. M/U BHA 0.0 78.2 20:42 21:42 #5 with agitator, USR, and Hycalog 3211 M -A2. Make up to coil and surface test 1/3/2019 1/3/2019 1.30 PROD1 DRILL TRIP P RIH BHA#5, Surface test agitator 2 78.2 6,130.0 21:42 23:00 470' 1/3/2019 1/3/2019 0.20 PROD1 DRILL DLOG P 6130'. Log HRZ for -11', PUW=33k, 6,130.0 6,185.0 23:00 23:12 RIW=24K 1/3/2019 1/3/2019 0.70 PROD1 DRILL TRIP P Continue in well, Log RA and 3 nearby 6,185.0 6,750.0 23:12 23:54 spikes, continue in. Set down in build @ 6627, 6637, 6664, 6695, and 6717. Back ream up hole cleared up. Had to work 6746 down to EOB @ 6750 1/3/2019 1/4/2019 0.10 PROD? DRILL DRLG P 6750', Drill, 1.89 BPM @ 3974 PSI 6,750.0 6,754.0 23:54 00:00 FS, BHP=3246, RIW=17.2, DHWOB=2.8K 1/4/2019 1/4/2019 0.30 PROD1 DRILL DRLG P 6754', Drill. 1.9 BPM @ 3974 PSI FS, 6,754.0 6,770.0 00:00 00:18 BHP=3256, Choke closed 1/4/2019 1/4/2019 0.10 PROD1 DRILL WPRT P 6770', BHA wiper to check weights 6,770.0 6,770.0 00:18 00:24 and pressures, PUw=34K 1/4/2019 1/4/2019 0.80 PROD1 DRILL DRLG P 6770', Drill, 1.9 BPM @ 3924 PSI FS, 6,770.0 6,839.0 00:24 01:12 BHP=3290 1/4/2019 1/4/2019 0.10 PROD1 DRILL WPRT P 6839', BHA wiper, PUW=33K 6,839.0 6,839.0 01:12 01:18 1/4/2019 1/4/2019 0.30 PROD? DRILL DRLG P 6839', Drill, 1.9 BPM @ 3924 PSI FS, 6,839.0 6,863.0 01:18 01:36 BHP=3358 1/4/2019 1/4/2019 1.30 PROD1 DRILL TRIP T 6863 tool not responding to inputs. 6,863.0 6,455.0 01:36 02:54 Tool face at 9OR going left. Pressures normal, Check shots within tolerance. DD recommends tripping for inspection 1/4/2019 1/4/2019 0.20 PRODt DRILL PULD T POOH, At surface, Flow check well 6,455.0 84.5 02:54 03:06 Page 4/10 Report Printed: 1/2112019 Operations Summary (with Timelog Depths) 1 D-08 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Star) Depth Start Time End Time our (hr) Phase Op Code Activity Code Time P -T -X Operation (ftKB) End Depth (ftKB) 1/4/2019 1/4/2019 0.60 PROD? DRILL PULD T Unstab injector, Back off quick 84.5 0.0 03:06 03:42 conned. Inspect BHA. Motor OK. Bit out 1-1. Put motor on bench and increase AKO setting. Double check all scribes. Tool out on scribe 1/4/2019 1/412019 0.60 PROD1 DRILL PULD T P/U BHA#6 with .59" motor, Make up 0.0 78.2 03:42 04:18 to coil and surface test 1/4/2019 1/4/2019 1.30 PROD1 DRILL TRIP T RIH BHA #6 78.2 6,130.0 04:18 05:36 1/4/2019 1/4/2019 0.20 PROD1 DRILL DLOG T Log the HRZ correction of minus 12.0' 6,130.0 6,175.0 05:36 05:48 1/4/2019 1/4/2019 1.20 PROD1 DRILL TRIP T Continue IH, setting multiple set 6,175.0 6,863.0 05:48 07:00 downs, work pipe to bottom from 6,765'to 6,863' 1/4/2019 1/412019 1.00 PRODt DRILL DRLG P OBD, 1.88 bpm at 4,163 psi, Diff --890 6,863.0 6,913.0 07:00 08:00 psi, WHP=346, BHP=3,330, IA=O, OA=179 1/4/2019 1/4/2019 0.25 PROD1 DRILL WPRT P Geo/DD Wiper up hole, PUW 33 k, 6,913.0 6,913.0 08:00 08:15 1 1 IRBIH 1/4/2019 1/4/2019 0.75 PROD1 DRILL DRLG P BOBD, 1.87 bpm at 4,025 psi, 6,913.0 6,971.0 08:15 09:00 Diff --890 psi, WHP=306, BHP=3,295, IA=O, OA=179 1/4/2019 1/4/2019 0.20 PROD1 DRILL WPRT P BHA wiper up hole, PUW 35 k 6,971.0 6,971.0 09:00 09:12 1/4/2019 1/412019 3.20 PROD1 DRILL DRLG P BOBD, 1.87 bpm at 4,078 psi, 6,971.0 7,260.0 09:12 12:24 Diff -890 psi, WHP=306, BHP=3,457, IA=O, OA=179 1/4/2019 1/4/2019 0.25 PROD1 DRILL WPRT P Wiper to the EOB 6,750', PUW 35 k 7,260.0 6,750.0 12:24 12:39 1/4/2019 1/4/2019 0.30 PROD1 DRILL WPRT P Wiper back in hole, RIW 18 k 6,750.0 7,260.0 12:39 12:57 1/4/2019 1/4/2019 0.75 PROD1 DRILL DRLG P BOBD, 1.88 bpm at 4,350 psi, 7,260.0 7,342.0 12:57 13:42 Diff -890 psi, WHP=306, BHP=3,717, IA=O, OA=179 1/4/2019 1/4/2019 0.15 PROD1 DRILL WPRT P Geo/DD wiper up hole, PUW 34 k 7,342.0 7,342.0 13:42 13:51 1/4/2019 1/4/2019 2.75 PRODt DRILL DRLG P BOBD, 1.88 bpm at 4,303 psi, 7,342.0 7,650.0 13:51 16:36 Diff=740 psi, WHP=324, BHP=3,318, IA=O, 0A=1 79 1/4/2019 1/412019 0.60 PROD1 DRILL WPRT P Wiper to the window, PUW 35 k 7,650.0 6,410.0 16:36 17:12 1/4/2019 1/4/2019 0.20 PROD1 DRILL DLOG P Log the 3 peaks correction of 6,410.0 6,444.0 17:12 17:24 1/4/2019 1/4/2019 0.60 PROD1 DRILL WPRT P Wiper back to bottom. tight spots 7367 6,444.0 7,650.0 17:24 18:00 through 7400 1/4/2019 1/4/2019 1.40 PROD1 DRILL DRLG P 7650', Drill, 1.9 BPM @ 4103 PSI FS, 7,650.0 7,846.0 18:00 19:24 BHP=3397, RIW=14.9K, DHWOB=3.3K 1/4/2019 1/4/2019 0.20 PRODt DRILL WPRT P 7846, Stall, BHA Wiper, PUW=39K 7,846.0 7,846.0 19:24 19:36 1/4/2019 1/4/2019 2.50 PROD1 DRILL DRLG P 71 Drill, 1.9 BPM @ 4118 PSI FS, 7,846.0 8,025.0 19:36 22:06 BHP=3443 1/4/2019 1/4/2019 0.60 PROD1 DRILL WPRT P 8025', Wiper to EOB with sweeps, 8,025.0 8,025.0 22:06 22:42 PUW=37K, tight area 7365 to 7400 1/4/2019 1/5/2019 1.30 PROD1 DRILL DRLG P 8025', drill, 1.88 BPM @ 4258 PSI FS, 8,025.0 8,076.0 22:42 00:00 BHP=3291 1/5/2019 1/5/2019 0.90 PROD1 DRILL DRLG P 8076', Drill, 1.88 BPM @ 3966 PSI 8,076.0 8,163.0 00:00 00:54 FS, BHP=3966, RIW=I3.OK, DHWOB=I.9K WHP=326 1/5/2019 1/5/2019 0.10 PRODt DRILL WPRT P Pull BHA wiper, PUW=37K 8,163.0 8,163.0 00:54 01:00 I Page 5110 ReportPrinted: 1121/2019 Operations Summary (with Timelog Depths) 1 D-08 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Stan Depth Stan Time Entl Time Dur (hr) Phase Op Code AGvity Code Time PJA Operation (111(B) End Depth (111(8) 1/5/2019 1/5/2019 1.70 PROD1 DRILL DRLG P 8163', Drill 1.87 BPM @4079 PSI FS, 8,163.0 8,323.0 01:00 02:42 BHP=3358 1/512019 1/5/2019 0.10 PROD? DRILL WPRT P BHA Wiper, PUW=37K 8,323.0 8,323.0 02:42 02:48 1/5/2019 1/5/2019 1.10 PROD1 DRILL DRLG P 8323', Drill, 1.88 BPM @ 4061 PSI 8,323.0 8,425.0 02:48 03:54 FS, BHP=3346 PSI 1/5/2019 1/5/2019 0.70 PROD1 DRILL WPRT P 8425', Wiper to 7625 with sweeps, 8,425.0 8,425.0 03:54 04:36 1 1 1 PUW=36K 1/5/2019 1/5/2019 4.00 PROM DRILL DRLG P 8425', Drill, 1.88 BPM @ 4091 PSI 8,425.0 8,825.0 04:36 08:36 FS, BHP=3347 1/5/2019 1/5/2019 1.00 PROD1 DRILL WPRT P Wiper up to the window, 35 k 8,825.0 6,410.0 08:36 09:36 1/5/2019 1/5/2019 0.20 PRODi DRILL DLOG P Log the RA Peaks, correction of plus 6,410.0 6,465.0 09:36 09:48 1.0' 1/5/2019 1/512019 1.00 PROD1 DRILL WPRT P Wiper back in hole, RIW 24 k 6,465.0 8,825.0 09:48 10:48 1/5/2019 1/5/2019 1.60 PROD1 DRILL DRLG P BOBD, 1.85 bpm at 3,492 psi, 8,825.0 8,891.0 10:48 12:24 Diff -878, WHP=180, BHP=3,189, IA=O, 0A=1 80 1/5/2019 1/5/2019 0.50 PROD1 DRILL DRLG P Hard spot, Heavy pickup 65 k, work to 8,891.0 8,891.0 12:24 12:54 drill ahead, phone town engineer 1/512019 1/5/2019 1.80 PROD1 DRILL DRLG P OBD ,1.89 bpm at 3,313 psi, Diff=606 8,891.0 8,913.0 12:54 14:42 psi, WHP=O, BHP=2,793, IA=O, OA=179 1/5/2019 1/5/2019 0.50 PROD1 DRILL WPRT P Town engineer called TD, pump TD 8,913.0 8,913.0 14:42 15:12 sweep 1/5/2019 1/5/2019 1.00 PRODt DRILL WPRT P Wiper up hole to the window 6, 100' 8,913.0 6,130.0 15:12 16:12 1/5/2019 1/5/2019 0.30 PROM DRILL DLOG P Log the HRZ correction of plus 1.5' 6,130.0 6,154.0 16:12 16:30 1/5/2019 1/5/2019 0.20 PROD1 DRILL WPRT P RBIH 6,154.0 6,900.0 16:30 16:42 115/2019 115/2019 0.20 PROD1 DRILL WPRT P PUH for static pressure survey 6,900.0 6,379.8 16:42 16:54 1/5/2019 1/5/2019 0.30 PROD1 DRILL WPRT P Perform static pressure survey, 6,379.8 6,379.8 16:54 17:12 6329.67 TVD Sesor, Annular EMW 1 min 2,786 psi 8.47 ppg 5 min 2,770 psi 8.42 ppg 10 min 2,768 psi 8.41 ppg 15 min 2,768 psi 8.41 ppg 1/5/2019 1/5/2019 1.40 PRODi DRILL WPRT P RIH to confirm TD, Tight spas 6912, 6,379.8 8,912.0 17:12 18:36 7400, 7960, and 7973 115/2019 1/512019 0.40 PROD1 DRILL WPRT P Tag Corrected TD @ 8912'. PUH 8,912.0 8,912.0 18:36 19:00 waiting on beaded liner running pill 1/5/2019 1/5/2019 2.10 PROD1 DRILL TRIP P Trip out pumping beaded liner running 8,912.0 86.0 19:00 21:06 pill 50 BBIs, Paint flags @ 6508 and 3878 1/5/2019 1/5/2019 0.50 PROM DRILL OWFF P At surface, Flow check well, PJSM 86.0 86.0 21:06 21:36 1/512019 115/2019 0.70 PRODt DRILL PULD P Unstab injector, Lay down BHA #6 on 86.0 0.0 21:36 22:18 dead well 1/512019 1/5/2019 0.70 COMPZI CASING RURD P Prep floor to run liner 0.0 0.0 22:18 23:00 175/2019 1/6/2019 1.00 COMPZ1 CASING PUTB P P/U BHA#7 with non pried bullnore, 2 0.0 300.0 23:00 00:00 As blank liner, 78 As slotted 2 3/8" liner, 3.63' pup, and 9' liner top billet. Perform Kick while running liner after 6 joints in hole. 76/2019 1/6/2019 2.90 COMPZI CASING PUTB P Continue picking up L1 completion 300.0 2,432.8 00:00 02:54 Page 6410 Report Printed: 112112019 Operations Summary (with Timelog Depths) 1 D-08 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Depth Staft Tim End Time Dur (hr) phase Op Code A Vity Code Time P-T-X Operatbn (ftKB) End Depth(ftKB) 1/6/2019 1/6/2019 0.80 COMPZ1 CASING PULD P P/U coiltrak M/U to completion. Set 2,432.8 2,477.0 02:54 03:42 pipe slips. M/U to coil and surface test. Change out pack offs and floats in UQC 1/6/2019 1/6/2019 2.00 COMPZ1 CASING TRIP P RIH BHA#7 L1 completion. EDC 2,477.0 8,912.0 03:42 05:42 Closed. Correct -7.7' correction 3800' EOP flag 1/6/2019 1/612019 1.00 COMPZ1 CASING TRIP P Work pipe to bottom from 8,831', TD 8,912.0 6,390.0 05:42 06:42 Flag 5.0' from horse head, Liner on bottom, line up down the coil, bring pump up 1.89 bpm at 3,700 psi, Diff=1,200 psi, PUW 32 K. Stop and remove liner length from counters, PUH above window, 34 k pulling up through window 1/6/2019 1/6/2019 0.25 COMPZ1 CASING TRIP P POOH 6,390.0 6,110.0 06:42 0657 116/2019 1/6/2019 0.20 COMPZ1 CASING DLOG P Log HRZ correction of+2.5' 6,110.0 6,148.0 06:57 0709 1/6/2019 1/6/2019 1.00 COMPZ7 CASING TRIP P Continue POOH 6,148.0 44.2 07:09 08:09 1/6/2019 1/6/2019 a50 COMPZ1 CASING PULD P At surface, Check well for flow (pass), 44.2 44.2 08:09 08:39 6 bbl/hr loss rate ••* Note: Inspect Coil 0.124inch flat spot @ 8.0' up from CTC 1/6/2019 1/6/2019 0.25 COMPZ1 CASING PULD P LD setting tools 44.2 0.0 08:39 08:54 1/6/2019 1/6/2019 1.25 PROM STK PULD P PU/MU L1-01 Build Assembly, Load 0.0 62.6 08:54 10:09 BHI database 1/6/2019 1/6/2019 1.30 PROD2 STK TRIP P RIH, w/Kickoff-Drilling BHA#8, 2.5° 62.6 6,125.0 10:09 11:27 motor and RB bi-center bit 1/6/2019 116/2019 0.20 PROD2 STK DLOG P Log the HRZ correction of-10' 6,125.0 6,138.0 11:27 11:39 1/6/2019 1/612019 0.30 PROD2 STK TRIP P Continue IH, tag TOB @ 6,474' 6,138.0 6,474.0 11:39 11:57 1/6/2019 1/6/2019 1.50 PROD2 STK KOST P PUH, 32 k, 1.89 bpm at 3,247 psi, 6,474.0 6,477.0 11:57 13:27 Diff-478 psi, WHP=228, BHP=3,168, IA=O, OA=172, time milled 1.0' 1fph, 2.0' @ 2 fph, and 3.0' @ 3 fph, 11612019 1/6/2019 0.75 PROD2 DRILL DRLG P Increased controlled drilling to 15-20 6,477.0 6,490.0 13:27 14:12 fph, then 20-30 fph, 1/6/2019 1/6/2019 2.10 PROM DRILL DRLG P Dnll ahead Q 1.89 bpm at 3,152 psi, 6,490.0 6,578.0 14:12 16:18 Diff--428 psi, WHP=190, BHP=3,128, IA=O, OA=176 1/6/2019 1/6/2019 0.15 PROD2 DRILL WPRT P PUH PUW 32 k, Dry drift KOP (clean) 6,578.0 6,450.0 16:18 16:27 1/612019 1/6/2019 0.15 PROD2 DRILL WPRT P RBIH 6,450.0 6,578.0 16:27 16:36 1/6/2019 1/6/2019 4.40 PROD2 DRILL DRLG P BOBD, 1.89 bpm at 3,123 psi, 6,578.0 6,717.0 16:36 21:00 Diff--527 psi, WHP=60, BHP=3,100, IA=O, 0A=1 78, At 6622 lower pump rate for DLS, 1.52 BPM @ 2335 PSI FS, BHP=3150 1/6/2019 1/6/2019 0.10 PROD2 DRILL WPRT P 6717, BHAwiper, PUW=34. Raise 6,717.0 6,717.0 21:00 21:06 pump rate back to 1.88 BPM 1/6/2019 1/6/2019 2.00 PROD2 DRILL DRLG P 6717', Drill, 1.88 BPM @ 3151 PSI 6,717.0 6,855.0 21:06 23:06 1 FS, BHP=3193 1/6/2019 1/7/2019 0.90 PROD2 DRILL TRIP P 6855', Call end of build, Avg DLS= XX, 6,855.0 2,095.0 23:06 00:00 Trip for lateral BHA 1/7/2019 1/7/2019 0.50 PROD2 DRILL TRIP P Continue trip out of well 2,095.0 78.0 00:00 00:30 Page 7110 Report Printed: 1/21/2019 Operations Summary (with Timelog Depths) 1 D-08 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time log Start Depth Stetl Time End Time Dur(hr) Phase Op Code Mvay Code Time P -T -X Operation (M(B) End Depth(MKB) 1/712019 117/2019 0.60 PROD2 DRILL PULD P Flow check well, PJSM Unslab 78.0 0.0 00:30 01:06 injector. UT CT, Min wall thickness .116. PJSM lay down BHA #8 1/7/2019 1/712019 1.00 PROD2 DRILL PULD P PIU BHA #9 with .5°AKO motor, 0.0 80.3 01:06 02:06 Strider and HCC 7X25207 bi center. Make up to coil and surface test. Check packoffs, 1/7/2019 1/7/2019 1.40 PROD2 DRILL TRIP P Trip in hole, Test strider @ 550'. 80.3 6,130.0 02:06 03:30 Continue in well. 1/7/2019 1/7/2019 0.20 PROD2 DRILL DLOG P Log HRZ for -11', PUW=22K 6,130.0 6,185.0 03:30 03:42 1/7/2019 1/7/2019 1.00 PROD2 DRILL TRIP P Continue in well, Clean pass through 6,185.0 6,855.0 03:42 04:42 window and past billet. Stacking @ 6823 Hard to get started @ 6855. Stacking out 1/7/2019 1/7/2019 3.80 PROD2 DRILL DRLG P 6855', Drill, 1.9 BPM @ 3460 PSI FS, 6,855.0 7,015.0 04:42 08:30 BHP=3212, WHP=223, RIW=19.7K, DHWOB=2.4K 117/2019 11712019 0.10 PROD2 DRILL WPRT P Stall motor, PUW 35 k, restart 7,015.0 7,015.0 08:30 08:36 1/7/2019 1!7/2019 1.80 PROD2 DRILL DRLG P BOBD, 1.9 bpm at 3,296 psi, Diff=511, 7,015.0 7,223.0 08:36 10:24 WHP=153, BHP=3,172, IA=O, OA=170 1/7/2019 117/2019 0.10 PROD2 DRILL WPRT P Stall motor, PUW 36 k, restart 7,223.0 7,223.0 10:24 10:30 1/7/2019 1/7/2019 0.20 PROD2 DRILL DRLG P BOBD, 1.89 bpm at 3,296 psi, 7,223.0 7,255.0 10:30 10:42 Diff --508, WHP=136, BHP=3,171, IA=O, OA=170 117/2019 1/7/2019 0.30 PROD2 DRILL WPRT P Wiper up hole, PUW 36 k 7,255.0 6,855.0 10:42 11:00 1/712019 1/7/2019 0.30 PROD2 DRILL WPRT P Wiper back in hole to 6,588', RIW 20 k 6,855.0 7,255.0 11:00 11:18 117/2019 1/7/2019 4.30 PROD2 DRILL DRLG P BOBD, 1.89 bpm at 3,296 psi, 7,255.0 7,655.0 11:18 15:36 Diff --508, WHP=136, BHP=3,171, ]A=O, OA=170 1/7/2019 1/712019 0.50 PROD2 DRILL WPRT P Wiper up hole to the EOB, PUW 33 k 7,655.0 6,855.0 15:36 16:06 1/7/2019 117/2019 0.30 PROD2 DRILL WPRT P Wiper back in hole to 6,588', RIW 20 k 6,855.0 7,655.0 16:06 16:24 1/7/2019 1/7/2019 4.70 PROD2 DRILL DRLG P BOBD, 1.89 bpm at 3,400 psi, 7,655.0 8,050.0 16:24 21:06 Diff --690, WHP=136, BHP=3,171, Ii 0179, stall motor 7,963' and 7,972' 1/7/2019 1/7/2019 0.70 PROD2 DRILL WPRT P Wiper up hole, PUW 33 k 8,050.0 6,130.0 21:06 21:48 1/7/2019 1/7/2019 0.20 PROD2 DRILL DLOG P RBIH, Log the HRZ correction of plus 6,130.0 6,198.0 21:48 22:00 1 10.5' 1/7/2019 1/7/2019 0.80 PROD2 DRILL WPRT P Wiper back in hole, RIW 20 k, 6,198.0 8,050.0 22:00 22:48 "` Note: Bobble @ 7,860' 1/7/2019 1!7/2019 0.70 PROD2 DRILL DRLG P BOBD, 1.88 bpm at 3,400 psi, 8,050.0 8,099.0 22:48 23:30 Diff --672, WHP=95, BHP=3228, IA=O, OA=167 1/72019 17772019 0.10 PROD2 DRILL WPRT P BHA Wiper, PUW=39K 8,099.0 8,099.0 23:30 23:36 1/7/2019 1/8/2019 0.40 PROD2 DRILL DRLG P 8099', Drill, 1.86 BPM @ 3433 PSI 8,099.0 8,125.0 23:36 00:00 FS, BHP=3250. RIW=18K, DHWOB=I.8K 1/8/2019 1/8/2019 2.80 PROD2 DRILL DRLG P 8125', Drill 1.86 BPM @ 3433 PSI FS, 8,125.0 8,450.0 0000 0248 1 I 1 IBHP=3256 Page 8110 ReportPrinted: 112112019 Operations Summary (with Timelog Depths) 1 D-08 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log sten Depth Start Time End Time our (hr) Phase Op Code Ac4vlty Code Time P -T -x Operation (MIS) End Depti(ftKB) 1/8/2019 1/8/2019 0.60 PROD2 DRILL WPRT P Wiper to 7650 with sweeps, 8,450.0 8,450.0 02:48 03:24 PUW=37K, Clean trip up and down 1/8/2019 1/8/2019 2.60 PROD2 DRILL DRLG P 8450', Drill, 1.9 BPM @ 3671 PSI FS, 8,450.0 8,590.0 03:24 06:00 BHP=3327, RIW=12K, DHWOB=2.8K 1/8/2019 1/8/2019 0.10 PROD2 DRILL WPRT P 8590', BHA wiper, PUW=39K 8,590.0 8,590.0 06:00 06:06 1/8/2019 1/8/2019 3.30 PROD2 DRILL DRLG P 8590', Drill, 1.9 BPM @ 3507 PSI FS, 8,590.0 8,850.0 06:06 09:24 BHP=3298, RIW=13.9K, DHWOB=l .9K 1/8/2019 1/8/2019 0.70 PROD2 DRILL WPRT P Wiper to 8000', PUW=38K 8,850.0 8,850.0 09:24 10:06 1/8/2019 1/8/2019 1.70 PROD2 DRILL DRLG P 8850', Drill, 1.89 BPM @ 3540 PSI 8,850.0 9,036.0 10:06 11:48 FS, BHP=3322 1/8/2019 1/8/2019 0.10 PROD2 DRILL WPRT P 9036, Pull BHA wiper, 100', PUW=38K 9,036.0 9,036.0 11:48 11:54 1/8/2019 1/8/2019 1.30 PROD2 DRILL DRLG P 9036', Drill, 1.89 BPM @ 3540 PSI 9,036.0 9,141.0 11:54 13:12 FS, BHP=3327 1/8/2019 1/8/2019 0.10 PROD2 DRILL WPRT P BHA Wiper, PUW=40K 9,141.0 9,141.0 13:12 13:18 1/8/2019 1/8/2019 3.20 PROD2 DRILL DRLG P 9141', Drill, 1.89 BPM @ 3595 PSI 9,141.0 9,250.0 13:18 16:30 FS, BHP=3361 1/8/2019 1/8/2019 1.30 PROD2 DRILL WPRT P 9250', PUW=40K, wiper to TT with tie 9,250.0 6,140.6- 16:30 17:48 into HRZ fro +0.5 correction, 1/8/2019 1/8/2019 1.50 PROD2 DRILL WPRT P RBIH, RIW = 13K 6,140.0 9,250.0 17:48 19:18 1/8/2019 1/8/2019 3.50 PROD2 DRILL DRLG P Drilling, FS = 683 75 psi @ 1.8 bpm, 9,250.0 9,436.0 19:18 22:48 CWT =5.2K, WOB =1.1K, BHP= 3358 psi, WHIP = 192 psi, circ = 3732 psi 1/8/2019 1/9/2019 1.20 PROD2 DRILL DRLG P Drilling, CWT = 1.61K, WOB = 1.4K, 9,436.0 9,469.0 22:48 00:00 BHP = 3386 psi, WHP = 210 psi, circ = 3796 psi, pump 10x10 sweeps, drilled to midnight depth of 1/9/2019 1/9/2019 0.50 PROD2 DRILL DRLG P Drilling, CWT =4.3K, WOB =AK, drill 9,436.0 9,480.0 00:00 00:30 to planned TD of 9480' 1/9/2019 1/9/2019 1.20 PROM DRILL WPRT P Wiper to tubing tail, PUW = 40K, slight 9,480.0 6,130.0 00:30 01:42 negative WOB pull at 6760' 1/9/2019 1/9/2019 0.30 PROD2 DRILL DLOG P Log HRZ for+1' correction, RIH to 6,130.0 6,390.0 01:42 02:00 1 1 1window 1/9/2019 1/9/2019 0.60 PROD2 DRILL DLOG P Confirm 8.6 ppg kills well 6,390.0 6,390.0 02:00 02:36 Pumps off, MID bit = 6390', TVD -sensor 6337.9', Annular = 2803, EMW = 8.5 ppg, increase MW by 1/10 ppg to 8.8 ppg, PUW = 33K 1/9/2019 1/9/2019 1.40 PROD2 DRILL WPRT P RIH, confirm TD at 9480'. PUW = 40K 6,390.0 9,480.0 02:36 04:00 1/9/2019 1/9/2019 2.60 PROD2 DRILL TRIP P Lay in LRP (50 bbl), follow by DuoVis 9,480.0 78.0 04:00 06:36 to surface pumping pipe displacement (8.8 ppg) Paint EDP flags at 6360'& 3180' 1/9/2019 1/9/2019 1.50 PROD2 DRILL PULD P Flow check, LD BHA #9 78.0 0.0 06:36 08:06 1/9/2019 1/9/2019 0.50 PROD2 DRILL BOPE P Perform BOPE function test 0.0 0.0 08:06 0836 1/9/2019 1/912019 0.50 COMM CASING RURD P Prep floor to run liner, UT CT check 0.0 0.0 08:36 0906 flatspots 1/9/2o19 1/9/2019 4.00 COMPZ2 CASING PUTB P PJSM, PIU BHA#10 L1-01 completion 0.0 3,160.5 09:06 13:06 with non ported bullnose, 104 As slotted 2 3/8" liner, 11.89' Pup, and shorty deployment sleeve Page 9110 ReportPrinted: 1/21/2019 Uperations Summary (with Timelog Depths) 1 D-08 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Stan Depth Stan Time End Time Dur (hr) Phase Op Coda Activity Code Time P -T -X Operation 0") End Depth(ftKB) 1/9/2019 1/9/2019 0.30 COMPZ2 CASING RURD P R/D tubing tongs, Rig up little jerks. 3,160.5 3,160.5 13:06 13:24 Make up pup joint onlop of liner 1/9/2019 1/9/2019 1.00 COMPZ2 CASING PULD P Skid injector to floor, change out floats 3,160.5 3,204.7 13:24 14:24 in UQC, Check packoffs. M/U coiltrack to coil and surface test. Tag up to stripper and set depths 1/9/2019 1/912019 0.80 COMPZ2 CASING TRIP P RIH BHA#10 3,204.7 6,317.0 14:24 15:12 1/9/2019 1/9/2019 0.10 COMPZ2 CASING DLOG P Correct to EOP flag fo -12.8, 6,317.0 6,304.0 15:12 15:18 PUW=50K 1/9/2019 1/9/2019 1.00 COMPZ2 CASING TRIP P Continue in well, clean trip to TD @ 6,304.0 9,480.0 15:18 16:18 9480, PUW=50K. Set back down. Pumps on 1.5 BPM Release from liner. PUW=32K 1/9/2019 1/912019 0.10 COMPZ2 CASING TRIP P PUH remove liner length ledt in hole 9,480.0 6,299.0 16:18 16:24 from counter 1/9/2019 1/9/2019 0.50 COMPZ2 CASING SIPB P Stop, Perform static pressure test 6,299.0 6,299.0 16:24 16:54 Sensor TVD=6178', BHP=2784 PSI after 30 min 1/9/2019 1/9/2019 1.10 DEMOB WHDBOP TRIP P Trip out of well 6,299.0 42.0 16:54 18:00 1/9/2019 1/912019 0.90 DEMOB WHDBOP PULD P Flow check, PJSM, LD BHA #10 42.0 0.0 18:00 18:54 1/9/2019 119/2019 0.90 DEMOB WHDBOP DISP P MU nozzle, bullhead seawater to 0.0 0.0 18:54 19:48 window, 2 bpm 1/9/2019 1/9/2019 0.60 DEMOB WHDBOP FRZP P PJSM w/ LRS, bullhead 30 bbl diesel 0.0 0.0 19:48 20:24 freeze -protect, 1 bpm 1/9/2019 1/912019 1.50 DEMOB WHDBOP CIRC P Jet stack, clear floor, PJSM 0.0 0.0 20:24 21:54 1/9/2019 1/9/2019 1.10 DEMOB WHDBOP MPSP P RU lubricator, set BPV, RD lubricator, 0.0 0.0 21:54 23:00 clear floor Note: 215 psi below master valve 1/9/2019 1/10/2019 1.00 DEMOB WHDBOP RURD P Blow down surface lines, boro-scope 0.0 0.0 23:00 00:00 stack, work RD checklist 1/10/2019 1/10/2019 2.00 DEMOB WHDBOP NUND P Suck out slack, lock -out koomey, 0.0 0.0 00:00 02:00 continue RD checklist, ND BOP Rig Released 1/10119 @ 2:00 AM Page 10/10 ReportPrinted: 1/21/2019 ConocoPhillips ConocoPhillips (Alaska) Inc. -Kup1 Kuparuk River Unit Kuparuk 1D Pad 1 D-08 L1 50-029-20266-60 Baker Hughes INTEQ Definitive Survey Report 05 February, 2019 B I UGHES a GE,.m ConocoPhillips 110P CoriocoPhilli In W Definitive Survey Report Compiler. ConocoPhillips(Alaska) Inc.-Kupt Local CoordlnaW Reference: We1110-08 Project: Kupmuk River Unit TVD Reference: 10-08 @ 108.00usM1 SSe: Kupamk 10 Pad MD Reference: 10-08 @ 108.00usM1 Well: 10.08 North Reference: TNG Wellbore: 1D-0811 Survey Calculation Mathod: Minimum Curvature Design: 10.0811 Dalaoase: EDT 14 Alaska Production Project Kuyemk River Un0, North Slope Alaska, United States Map System: US State Plane 1927 (Erect solution) System Datum: Mean Sea Level Geo Datum: NAD 1927 (NADCON CONUS) Using Wall Reference Point Map Zone: Alaska Zone 04 Using gende9c ..Is factor Well 10-08 Well Pseudo. -NVB 0.00 us% Northing: 6959,964.0ausft Whole: 70°17'55.408N .E/4N 0.00 usM1 Fasting: 560,490.00usM1 Longitude: 149° 30' 36.452 W Position Uncenalnty 0.00 usM1 Wellhead Elevation: Usk Ground Level: o.0o usll Walloon, 10.0811 Magnetics Metal Name Samek Data Dechnstion Dip"91. Reld Strength 11 r) Inn BGGM2018 31112019 16.75 80.86 57,424 Design 10-00 L1 Audit Notes: Version'. 1.0 Phase: ACTUAL Te On Depth: 6,300.00 Vertical Section: Depth From (WD) ♦hg4 +EM Direction laenl lose) lush) r) 108,00 0.00 0.00 225.00 Survey Program Data From To Survey Survey (usM1l (U -M Survey (Waltham) Teal Name Description Sort Data End Dffi 200.00 6,300.00 Gyro (10.08) OYD.CT{MS Oymdala unLusing Ms 3124/2000 6,396.00 6466]5 1D -08L1 MWD-INC(i D-081-1) MWD-INC_ONLY MW NC_ONLY_FILLER 11112019 1/112019 6497.37 8,879.07 10-0811 MM(1D-OBL1) MWD MM -Standard 11512019 1/52019 252019 2:03:59PM Page COMPASS 5000.14 BuBd 85D COmcoPhillips ConocoPhilliple Definitive Survey Report Caresser. ConocoPhillips (Alaska) Inc.-Kupl Local Co<rdlnale Reference: Well 10611 Project: Kupamk River Unit WD Reference: 1068@108.0oush She: Kupamk/D Pad MD Reference: 10-08®108.00us0 Well: iD48 North Reference: True Wellbore: 1D-0811 Survey Calculation MetbOe: Minimum Curvature Des"n 1D -08L1 Database: EDT 14 Ahab Produclian Survey 3 0191;03;5SPM Page3 COMPASS 500014 Suild 850 Map Map Venlnl MO Ire llal NO MSS .1,1141.1,1141♦EI-W Northing Eaatln9 OLS Section Survey Tool Name Mnotetion fuse) P) P) (..ft) loan) (usRl (use) (R) (R) Plow) (n) oml).OD 0]8 276.80 6.290.54 6.19054 ?6.23 1545 5959,01786 56050583 O117 2179 MNQINC ONLY (2) TIP 8,398.00 On man 6394.53 6,285.53 J da 1425 5959.018.24 580,504.62 0.32 22.38 MWD -INC ONLY. KOP 6431.00 597 170.18 6a29.47 63214? <Z55 14.36 5958016.% 560,504]4 1852 23.48 M MNL ONLY(2) Intaryolated Azimuth 6,40675 17AB 168.5/ 6,a64AS 63rvA5 54.% 1572 5959.x.58 560,506.16 31.09 27.46 MANNL_ONLY(2) Intaryolated Azimuth 6487.37 31.50 168.09 6,49125 Is"4 0 £6.N 1828 5dat,997.3D 560500.01 47.29 34.35 MWD (3) 6.52752 44.46 19862 6151604 6,40804 484.94 2237 5,958,97935 550513.05 4&02 44.25 MWD(3) 6557.05 57,03 185]2 6,524.06 6426.08 402.07 22.62 5950.95212 SMS1868 4260 56.04 MWD(3) 8.507.85 7054 184.29 6,5a623 6,W ..23 -133.69 34.96 9950.93061 560526.03 44.09 69.01 MAD (3) 6.618.24 03.66 16253 655420 644620 -16061 4229 5950.90176 560534.20 4539 83.12 MWD(3) 6.647.02 9645 162.85 6.55A 70 6445]0 -loom 5198 5,956,824.99 560.543.50 42.68 97.21 MWD (3) 6.61703 102.02 12052 6549.06 644166 -21824 5829 5950.846.28 560.550.54 31,49 11276 MWD(3) 6.706.21 10523 1814 6.54221 6434.71 446'93 60.82 5,958,89.59 560.55284 37.03 131.52 MWD(3) 6.735.52 105.32 191.51 6,534.97 6426.92 -224.35 5]98 5,950.79014 550.5499 44,35 15365 MWo(3) 676.19 104.11 197.36 6,522.10 6.419.18 302.57 40.92 5.951761.55 550.54135 e.. 179.52 Novi 6,296.. 102.82 197.21 6.52013 6.412,13 33096 40.18 5,956233.40 560.532.84 4.29 205.61 MIND (3) 6,826.01 161.65 15612 6.513.01 6,405.81 350,66 3109 595820564 580.SA. 4.07 231.02 MAID (2) 6,851. eav 195.94 650229 6399.29 491.23 22.39 5958.67250 560.51554 839 261.12 MMD(3) 609102 101.60 19720 6.501.75 6,30.75 419.95 13.99 59588.22 660,50737 8'. 20206 AND (3) 8,921.26 10383 19904 6.495.08 6387.08 447.90 402 5,958616.11 56pa9643 8.19 313.36 AND (3) 6,951.43 105.44 2D25T 5,487.4 0.379.46 425.22 454 5.950,512.25 56.48828 1256 339.98 MWD(3) a mo.65 105.45 20..55 6.428.63 6,37163 501% -16.65 5,958.562.57 56K)A7239 3.21 aeom MND(3) 201165 104.07 205.97 6,47152 6..57 52835 -29.10 5,&59.535.40 580.465.16 7,01 394.18 MWD(3) 7,041.27 10376 209.06 6.464.25 6.356.5 553.80 4236 5958.509.93 SW,45210 1020 421.55 MAD (3) 7,07191 103.51 212.10 6,45].02 CM 02 57843 52.50 5,95640418 An 432.12 9.98 450.38 MM (3) 2,101,45 10351 21550 8.498.12 6.34212 -603.30 -73.411 5958.46019 SW42138 11.19 42855 MWD(3) 2,131.30 10395 217.15 6.3.02 6,33502 -6M70 -80.68 5,6511.436.65 560404.32 5.56 5D737 MWD (3) 2,16135 10462 220.43 6,a35.e2 6,32262 619.35 400.89 5,958,413.85 56,380.35 1083 536.16 MD (3) 7,191]1 10421 23398 SAME 6.320.W 671.21 -128.55 5,950,391.84 SW.3M.82 9.89 56552 MD (3) 722063 10502 M6.91 64.76 631276 690.93 -148.41 5,95637197 5634712 11,75 59350 MIND (3) 7.60.59 10528 239.29 6412.93 6,304.93 -71015 -170.01 5,9563525B 5.325.22 9.32 62232 MD (3) 3 0191;03;5SPM Page3 COMPASS 500014 Suild 850 Survey ConocoPhillips ConctAP fillips Definitive Survey Report Map Company: ConocoPM1ilipa(Alaska) Inc.-Kupt Local Co -ordinal¢ Relernme: Well ID -(1B Pmle0t Kup ruk River Unit TVD Reference: 1608 a 108.O1 Site: Kupamk 1D Pad MD Refinance: 1 M @ 100AGnift Well 1D48 Nonh Reference: True Wellbore: ID8BL1 Survey Calculation Method: Minimum Cu.t.. Cosign: 1D-O8L1 Database'. EDT 14 Alaska Production Survey Annotation ammin `�wls 252019 2:03:59PM Page 4 COMPPSS 500014 Build 85D Me, Map ll mo Doo pal TVD TVOSS aMS aEm Northhq Eenny OLS t treaon Survey Tcol Name Juan) (1) 11) lush) (� learn (6019 (111 Ip) (°1109) IRI 7,2Hn93 103.15 231.60 6405.48 6 297A -na.17 -192.27 5,958333]] 560303.12 9.10 65163 MWDO) 7,312211 10143 23462 6398.80 6,28680 -247,16 -21]2) 5,&-8,31519 560,2]6.7] 10.86 601.95 MM(3) 7.341.33 91132 23285 6393.52 6,205.52 -063.21 -24091 5,953,20.95 56025527 10.90 71601 MW➢(3) 7.38.59 97.54 237.82 Gael 6.280.99 -079.0 -256.117 5956292.11 560.22834 6.19 74821 MMa)(3) 740.67 0,53 238.52 6,385.79 6,277]9 -891.5 -290.67 5,950,267.21 56020596 7,57 767.37 MAD (3) 7,431.13 90.92 237.93 6,3174.08 6,276.08 -810.55 316.51 5,99,2099 560.180.0 1526 M.% MND (3) 7,461.40 08.93 238.69 6384.12 8,276.12 -826.50 .02.32 5.958,2".86 50.15437 7.02 826.48 MD (3) 7,492.26 9120 240.86 6384.0 8.278.0 -041.0 388.93 5,958219 15 50.12189 1024 056.25 MAO (3) ]521.47 80.37 24165 630169 6,27569 -050.0 4199.54 5,950,204.90 560.10240 3.88 80429 mu (3) 7,552.35 95.0 246.26 6,382)0 6274.10 -86957 -422.24 5,950.19115 $ ,O74,02 V.. Mass MD (3) 7,583.07 94.58 24839 637940 6.27140 -881.35 450.47 5,956179.13 50.04660 747 04114 MD (3) 7610.15 9421 250.31 6.376.07 6,268.87 492.99 481.33 5.958.16725 560.015.92 5.89 971.79 MID (3) 7M812 84.11 25259 8.374.55 0,X8.55 403.13 -611,56 5.958,1515.87 558985.77 7.12 1,00.34 MD (3) 7,677.11 lov 2 IA2 6.372.53 6,226.53 -911.34 539.29 4959.140.44 559,958.71 835 1025.75 "D (3) 7.7180 93.10 25570 5,360.0 6,X190 822.14 S78P 5,959.13731 558817.@ 3.55 1.06202 MWD(3) 7.74779 9360 25874 636830 6260.30 46846 607.71 S.M.133.75 559,888" Mn 1,086.25 MD (3) 7,77.76 95.10 26216 6,366.03 6,25803 -933.41 637.10 5,958125.55 55986342 843 1,11059 MWD(3) 7.807.91 26.52 226.0 6.363.50 6,25550 S32.04 66100 5,950,12171 559.8300 6 D 1,134.23 MWD(3) 7,830.91 93.10 263.05 6,36140 625344 BW.St -69774 5,958,11800 55979991 5.64 1.158.41 MWD(3) 7,367.71 so. 260.97 6,359.94 6.251.94 -844.51 -7X.22 5,9133 11&77 559.77146 736 1,18139 MWD (3) 7.897,7 9181 258,59 631 625072 449." -75577 5,1150110,211 55974197 0.65 1,206.05 MAD (3) 7,927.0 93.46 255.85 6350.14 6,250.14 l66b7 -0".41 5956 101,74 5511.71330 7.51 1,23071 NAD (3) 7,957.27 89.45 25474 6,358.16 6,2`0.16 86140 61367 5,958,09410 559,6".19 775 1,258.63 MWD (3) 7,98885 09.29 253.13 6,350.51 6,2`0.51 88.16 843.82 5,958,085.18 559,631.11 5.16 1,224.09 MAD(3) 8,01743 Man 249.65 6,359.11 6,X1.11 881.34 -87109 5958.025.78 559.826.92 12.56 13U3.86 MD (3) 6"6.01 90.55 248.17 6.359.40 62!5140 891.91 89IIA9 5,950.0".59 559.599!10 9.14 1,338.72 MND(3) 8,977.35 84.26 249." 6.35807 620.07 1003." A an 5,956053.63 556571.311 13.12 1,354.67 MD (3) 8107.24 92.12 243.68 6.355.35 6,248.35 -1,01500 454Y1 5,958."1.0.5 5595N.07 19.54 1,39245 MWD (3) 813234 9191 240.49 6.355.47 6,247.47 1,026.74 42638 5,958.029.9 559.5mo1 12.73 141642 MWD (3) 0.162311 9163 Man 63m,54 6 24 -1,04235 -100204 5.958,013.8 559,496.48 1190 1445.60 MWD (3) 8.19242 9221 23149 635353 6,245.53 -1.05647 -1,02868 5957.996.40 559,47198 1151 147514 "D (3) Annotation ammin `�wls 252019 2:03:59PM Page 4 COMPPSS 500014 Build 85D Survey ConocoPhillips ConocoPhillips Definitive Survey Report company. Conoco illlps(Alaska) Ina-Kupl Local Coordinate Reference: Well 10-08 Project: Kuperuh River Unit TVD Reference. 1D-08@lolt 00usb site Kuparuk 1D Pad MD Refemnre: 10-00 @ 108.00usX Well'. 1D-00 Numb Reference: True Wellbore: 1D-0811 Survey Calculation Method Minimum Curvature Design: 1D4811 Database: EDT 14 Alaska Produclion Survey Annotation 2 019 2:03:59PM Page 5 COMPASS 5000,14 Sued 850 Map Map 840 Ile Atl TVD TVDSS Mlld +em N."Ing Zenith, OLS glucose Survey Tool Name fault) M 19 team (gall (hen) Naf) In) (ft) Pnov) (,1 82222D 91 mm 635185 6243.85 -107774 -10513,14 595797795 559448.7 11 fig 1,504.64 mAth p) ll.5Z t 94.34 Main 6.34960 6,24160 -1,097.16 -1,0209 5,951.950.34 559426.00 115 1.5]4.46 MAho(3) 0.20223 9335 =62 634150 ant) 58 -111663 y09566 5,957,93820 559,403.46 833 1,564]3 MAD (3) 8312.07 9287 233.18 6,348.02 8,238.3 -1.13501 -111911 5,957,92013 559,30.17 867 1,593.91 MND(3) 8 N5,53 91,57 234.70 6.344]8 6,2W.78 -1,150.89 -1,146.14 5,957,900.23 559.353.30 5.60 1626,93 MAD (3) 6,37723 W,m 238.96 8.343,14 6.235.14 -t,1T101 -1.1?283 5.95188271 559,326.95 16,01 1,65191 MAD(3) 6,401.13 94.95 240.16 6,340]3 6,23273 -1,18711 -1.190,32 5.957,857.40 559,30,36 945 1,68675 MMAD(3) 8,437.51 0.07 24320 6, Mom 6,230.00 -1,20144 -1,224,91 5,957,85206 558,214.85 1024 1,115.14 MAID (3) god"46 94.00 244.98 6,33564 6,22764 -1,21090 -1252.13 5.951839.17 559,24220 6.50 1740.80 "D(3) 84W,II 91.87 246.73 6.334.19 6,226.19 -1,336.40 -1,278.48 5951,021.42 5593315 9.73 1,11135 MWD(3) 8,52713 0.09 20.0 6.333.8 8.225.8 -1,237.43 -132661 5,951,818.21 559,193,31 13.74 179905 MAD (3) a 556436 92.0 255.17 6.331.37 6233,37 -1,248.28 -1,342.38 8,07,005.07 559,157." 11.56 1,831.87 MWD(3) . SW .1 920 256.51 6,330.0 6,Y2,07 -1354.70 -1,367.80 5,957.798.45 559,132.48 5.11 1,654.30 MMAD(3) 6fi1843 94,67 258.16 6.32824 8,220,24 -1.00,78 -1,39480 5,07.792.15 See 1W4 672 1.0184 MND(3) 8"961 92.911 25537 ..3211. 621816 -1,26167 -1,425.22 5,951,7002 559,0517 813 1,O0.tfi MVW(3) 8,09.0 83.2 253]1 8334.51 6,216.51 -0.21543 4,454,17 5,951.7/1.03 559,046.29 8.59 1.930.12 MAD (3) 6,110.31 9400 28161 6322.55 8,214.55 -0,2".54 -1,40.39 5,957]610 559011.13 100 1,07.23 MAtO(3) 813865 92.95 249,65 8.320.0 6212.83 4333.88 -1510.11 5951750.15 55699050 140 1.93271 MIND (3) 8.76071 91.53 24726 6,319.63 621163 -1.304,86 -1,530.11 5,9577460 550,95259 9.59 2,010.20 AAD (3) 8199.10 9138 24505 6,31883 6,210.83 -131111 -156604 5,957)2646 556,9X96 740 2,038.56 MWD(3) 600." 91.41 241.10 6.31810 6.210110 4,33062 -159244 5,957 720.74 50.90848 1333 2,066.91 MAD(3) 8.851.38 93.14 239.80 6,316.97 6,20097 .13".63 -1617.16 5.957 706.53 558.03.07 7.61 2,094.30 MAID (3) 8.8790 0,51 239.89 6,31534 6,20X -1,355.49 -1.035.85 5,957695.51 558.865,26 10.93 2,11&20 MID (3) 8,91214 0,51 239,69 631218 8,20418 -1.37194 -1,8".21 5,957,076." 556037.4 000 2,14660 PROJECTED to TD Annotation 2 019 2:03:59PM Page 5 COMPASS 5000,14 Sued 850 BA ER 0PRINT DISTRIBUTION LIST FIUGHES a GE company COMPANY ConocoPhillips Alaska, Inc. WELL NAME 1D -08L1 FIELD Greater Kuparuk Area COUNTY North Slope Borough BHI DISTRICT Alaska AUTHORIZED BY Patrick Rider EMAIL Patrick. Rider@bakerhugheS.COm STATUS Final Replacement: COMPANY ADDRESS (FEDEK N'nL NOT DELIVER TO P.O. BOX) PERSON ATTENTION V t BP North Slope. EOA. PBOC, PRB-20 (Office 109) '.. D&GWO Wells Admin Brenda Glassmaker & Peggy O'Neill !900 E. Benson Blvd. Anchorage, Alaska 99508 2 ConocoPhillips Alaska Inc. Atm: Ricky Elgarico ATO 708 700 G Street Anchorage, AK 99510 3%XOnMObil, Alaska Atm: Lynda M. Yaskell and/or Leonardo Elias 3201 C Street, Suite 505 Anchorage, AK 99503 4 State of Alaska - AOGCC AM: Natural Resources Technician 11 333 W. 7th Ave, Suite 100 Anchorage, Alaska 99501 5 DNR - Division of011 & Gas *** Attn: Resource Evaluation 550 West 7th Avenue, Suite 1100 Anchorage, Alaska 99501 *** Stamp "confidential" on all r 6 SP Exploration (Alaska) Inc. Petrotechnical Data Center, 900 E. Benson Blvd Anchorage, Alaska 99508 21 81 2 30 35 2 Please sign and return one copy of this transmittal form to: ConocoPhillips Alaska, Inc. Tom Osterkamp (WNS Petroleum Technician) 1700 G Street. 'Anchorage, Alaska 99510 data. LOG TYPE GR - RES LOG DATE January 5, 2019 TODAYS DATE February 7, 2019 Revision No Details: Rev. Requested by: FIELD I FINAL CD/DVD FINAL PRELIM LOGS (las, dlis, PDF, META, SURVEY I REPORT LOGS CGM, Final Sum (Compass) # OF PRINTS # OF COPIES 1# OF COPIES I# OF COPIES RECEIVE® f-r-- 1 DNR TOTALS FOR THIS PAGE: 0 1 2 0 0 i THE STATE °fALASKA GOVERNOR MIKE DUNLEAVY James Ohlinger Staff CTD Engineer ConocoPhillips Alaska, Inc. P.O Box 100360 Anchorage, AK 99510-0360 Alaska Oil and Gas Conservation Commission Re: Kuparuk River Field, Kuparuk River Oil Pool, KRU 1D -08L1 ConocoPhillips Alaska, Inc. Permit to Drill Number: 218-172 Surface Location: 600' FNL, 602' FEL, SEC. 23, TI IN, RI OE, UM Bottomhole Location: 2215' FNL, 2689' FEL, SEC. 23, Tl IN, RI OE, UM Dear Mr. Ohlinger: 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 www.00gcc.alaska.gov Enclosed is the approved application for the permit to drill the above referenced development well. The permit is for a new wellbore segment of existing well Permit No. 177-053, API No. 50-029-20266- 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 4 � Chair DATED this 7-6day of December, 2018. STATE OF ALASKA 1 ALASKA, OIL AND GAS CONSERVATION COMMISSIJN PERMIT TO DRILL 20 AAC 25.005 1a. Type of Work:_ Drill El Lateral ❑Q Redrill ❑ Reentry F-11 1 b. Proposed Well Class: Exploratory - Gas ❑ Service - WAG Service - Disp E]1 Stratigraphic Test ❑ Development - Oil Service - Winj ❑ Single Zone D • Exploratory - Oil ❑ Development - Gas ❑ Service - Supply ❑ Multiple Zone ❑ c. Specify if well is proposed for: Coalbed Gas ❑ Gas Hydrates ❑ Geothermal ❑ Shale Gas ❑ 2. Operator Name: ConocoPhillips Alaska, Inc. 5. Bond: Blanket ❑✓ ' Single Well ❑ Bond No. 5952180 11. Well Name and Number: KRU 1 D-081_1 3. Address: P.O. Box 100360 Anchorage, AK 99510-0360 6. Proposed Depth: MD: 9300' TVD: 6179' • 12. Field/Pool(s): Kuparuk River Pool / Kupamk River Oil Pool 4a. Location of Well (Governmental Section): Surface: 600' FNL, 602' FEL, Sec 23 Tl l N, R10E, UM Top of Productive Horizon: 646' FNL, 588' FEL, Sec 23, T11 N. R1 OE, UM Total Depth: 2215' FNL, 2689' FEL, Sec 23, T11 N, R1 OE, UM 7. Property Designation: ADL 25650 8. DNR Approval Number: LONS 79-016 13. Approximate Spud Date: 1/2/2019 9. Acres in Property: 2560 14. Distance to Nearest Property: 14,550' ' 4b. Location of Well (State Base Plane Coordinates - NAD 27): 10. Surface: x- 560490' y- 5959064 • Zone- 4 KB Elevation above MSL (ft): 108 • GL / BF Elevation above MSL (ft): 71 15. Distance to Nearest Well Open to Same Pool: • 2108' (1 D-130) 16. Deviated wells: Kickoff depth: 6420' • feet 17. Maximum Hole Angle: 104 degrees Maximum Potential Pressures in psig (see 20 AAC 25.035) Downhole: 3664 ` Surface: 3033 18. Casing Program: Specifications Top - Setting Depth - Bottom Cement Quantity, c.f. or sacks Hole Casing Weight Grade Coupling Length MD TVD MD TVD (including stage data) 3" 2-3/8" 4.7# L-80 ST -L 2634' • 6666' 6450' 9300' 6179' Slotted 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): 6880 6879 6550 6550 6549 N/A Casing Length Size Cement Volume MD TVD Conductor/Structural 52' 16" 475 sx Arlicset II cmt 75' 75' Surface 2207' 10-3/4" 2400 sx Permafrost cmt 2230' 2230' Production 6847' 7" 350 sx Class G 6869' 6868' Tieback 6276' 5-1/2" N/A 6295' 6294' Perforation Depth MD (ft): 6384-6472, 6479-6484, 6636-6641, Perforation Depth TVD (ft): 6383-6471, 6478-6483, 6635-6640, 6643-6651 6644-6652 Hydraulic Fracture planned? Yes ❑ No 0 - 20. Attachments: Property Plat ❑ BOP Sketch Divertter Sketch B Drillingv. Depth Report B Drilling eFluid Program ot a 20 AAC 25.050 requ emShallow Hazard lents e 21. Verbal Approval: Commission Representative: Date 22. 1 hereby certify that the foregoing is true and the procedure approved herein will not be /J d deviated from without prior written approval. Contact Name: William LonAo Authorized Name: James Ohlinger Contact Email: William. R. LonqaCOP.corn Authorized Title: Staff CTD Engineer �7 Contact Phone: 907-263-4372 Authorized Signature. Date: Commission Use Only Permit to Drill Number. Z1 • -177-150- API Number: — G 2 -?— Permit Approval ^ Date: L ^ , I See cover letter for other 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: Conditions Other: Bb� fry f �� ,3 SfJ0 �j $ t Samples req'd: Yes � No 2/ Mud log req'd: Yes ❑ No f HzS measures: Yes Nom❑] Directional svy req'd: YesQ No❑ eir" P r2- K. -k7 )4e t- flS' �' Spacing exception req'd: Yes El No 1_'I Inclination -only svy req'd: Yes ❑ No,[-��r Z JJL�O P Sz-aJ Post initial injection MIT req'd: Yes ElW APPROVED BY/� Approved by: COMMISSIONER THE COMMISSION Date: �Z L /Z orm 1p -0p1 Revised 5/2077 This ermit is valid fo 2 t f t Submit Form and pproval per 20 AAC 25.005(g) Attachments in Duplicate <I C1 Z./r, ConocoPhillips Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 December 20, 2018 Commissioner - State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Dear Commissioner: ConocoPhillips Alaska, Inc. hereby submits sundry application to set a whipstock and applications for permits to drill two laterals out of the KRU 1 D-08 (PTD# 177-053) using the coiled tubing drilling rig, Nabors CDR3-AC. CTD operations are scheduled to begin in January 2019. The objective will be to drill two laterals KRU 1 D-081_1 and 1D-081-1-01 targeting the Kuparuk C -sand interval. To account for geological uncertainties, ConocoPhillips requests a variance from the requirements of 20 AAC 25.015 to allow the actual kick-off point to be anywhere along the length of the parent lateral instead of being limited to 500' from the original point. Attached to the sundry application are the following documents: - 10403 Sundry Application for KRU 1D-08 - Operations Summary in support of the 10-403 sundry application - Proposed CTD Schematic - Current Well Bore Schematic Attached to permit to drill applications are the following documents: - Permit to Drill Application Forms (10-401) for 1D-081_1 and 1 D-081_1-01 - Detailed Summary of Operations - Directional Plans for 1 D -08L1 and 1 D-081_1-01 - Current wellbore schematic - Proposed CTD schematic If you have any questions or require additional information, please contact me at 907-263-4372. Sincerely, William R. Long Coiled Tubing Drilling Engineer ConocoPhillips Alaska Kuparuk CTD Laterals 1D -08L1 and 1D -08L1-01 Application for Permit to Drill Document 1. Well Name and Classification........................................................................................................ 2 (Requirements of20 AAC 25.005(1) and 20 AAC 25.005(b))... .. ..............._...., ._........................ ............ ...............................2 2. Location Summary ................... ..... .... ....... ..... ..... ..... ....... 2 (Requirements of 20AAC 25.005(c)(2)).. ..._..... .............. ............. ................ .................... ........ ....................... ......2 3. Blowout Prevention Equipment Information................................................................................. 2 (Requirements of 20 AAC 25.005 (c)(3)).. .......... ................... ..._........................ ._....................... .......... ............ .................2 4. Drilling Hazards Information and Reservoir Pressure.................................................................. 2 (Requirements of 20 AAC 25.005 (c)(4)) ...... ............................. ..................................... ...--...................................... . ..... _2 5. Procedure for Conducting Formation Integrity tests................................................................... 2 (Requirements of 20AAC 25.005(c)(5)) .... .........._.... ........... ......... _.... ..... ..._.......... ........__........2 6. Casing and Cementing Program.................................................................................................... 3 (Requirements of 20 AAC 25.005(c)(6)) .................... _........ ........._................ ._.._._............_.__..... ...............3 7. Diverter System Information.......................................................................................................... 3 (Requirements of 20 AAC 25.005(c)(7))... .. ....._..................... ......... _._....... .......... ................ ...._......................... ..... ...3 8. Drilling Fluids Program.................................................................................................................. 3 (Requirements of 20 AAC 25.005(c)(8)) ... ................. ........_,....... ......... ._............... .................. ................ ....... ..............3 9. Abnormally Pressured Formation Information.............................................................................4 (Requirements of 20 AAC 25.005(c)(9)) ... ............_..... ............. ._........................ ._.................... .................. _...............4 10. Seismic Analysis............................................................................................................................. 4 (Requirements of 20AAC25.005(c)(10)). _.._........... ...._._.......... ........__...... .............. ....................................... . ................4 11. Seabed Condition Analysis............................................................................................................4 (Requirements of 20AAC 25.005(c)(11)). ........... ......._........ ............._......................._................... ...........4 12. Evidence of Bonding...................................................................................................................... 4 (Requirements of 20 AAC 25.005(c)(12)) .... ............. ........... ....._.._.................. .............. .................... ..............4 13. Proposed Drilling Program.............................................................................................................4 (Requirements of 20AAC 25.005(c)(13)) .............. ............_...... .............. .._...._. ..._...._... .................. _.,._..........4 Summaryof Operations...................................................................................................................................................4 LinerRunning...................................................................................................................................................................5 14. Disposal of Drilling Mud and Cuttings.......................................................................................... 5 (Requirements of 20 AA C 25.005(c) (14)) ............... ............. .......... ........... _. _............... . _........... ........... _....... ............. 5 15. Directional Plans for Intentionally Deviated Wells....................................................................... 6 (Requirements of 20 AAC 25.050(6)) ........................ ...._......... ................ ................ .................... ........_._..... .. ............6 16. Attachments....................................................................................................................................6 Attachment 1: Directional Plans for 1D -08L1 and 1D -08L1-01 laterals...........................................................................6 Attachment 2: Current Well Schematic for 1D-08 ............................................................................................................6 Attachment 3: Proposed Well Schematic for 1D -08L1 and 1D-0811-01 laterals ..... ..................... ..._............................. 6 Page 1 of 6 December 20, 2018 PTD Application: 1D-081-1 and 1D-081-1-01 1. Well Name and Classification (Requirements of 20 AAC 25.005(f) and 20 AAC 25.005(b)) The proposed laterals described in this document are 1D -08L1 and 'ID -081-11-01. The laterals will be classified as "Development -Oil' wells. 2. Location Summary (Requirements of 20 AAC 25.005(c)(2)) These laterals will target the C sand package in the Kuparuk reservoir. See attached 10-401 form for surface and subsurface coordinates of the 1D-081-1 and 1D-081-1-01. 3. Blowout Prevention Equipment Information (Requirements of 20 AAC 25.005 (c)(3)) Please reference blowout prevention (BOP) schematics on file with the Commission for Nabors CDR3-AC. BOP equipment is as required per 20 AAC 25.036 for thru-tubing drilling operations. — Pipe rams, blind rams and the CT pack off will be pressure tested to 250 psi and to 3500 psi. Using the maximum formation pressure in the area of 3664 psi at the datum in 1 D-10 (i.e. 11.2 ppg EMW), the maximum potential surface pressure in 1D-08, assuming a gas gradient of 0.1 psi/ft, would be 3033 psi. See the "Drilling Hazards Information and Reservoir Pressure" section for more details. — The annular preventer will be tested to 250 psi and 2,500 psi. 4. Drilling Hazards Information and Reservoir Pressure (Requirements of 20 AAC 25.005 (c)(4)) Reservoir Pressure and Maximum Downhole Pressure (Requirements of 20 AAC 25.005 (c)(4)(a)) The formation pressure in KRU 1 D-08 was measured to be 3034 psi at the datum (9.2 ppg EMW) on 6/29/2016. The maximum downhole pressure in the 1 D-08 vicinity is the 1 D-10 at 3664 psi at the dataum (11.2 ppg EMW) measured on 2/15/2016. Potential Gas Zones (Requirements of 20 AAC 25.005 (c)(4)(b)) i The offset injection wells to 1 D-08 have injected gas, so there is a possibility of encountering free gas while drilling the 1 D-08 laterals. If gas is detected in the returns the contaminated mud can be diverted to a storage tank away from the rig. Potential Causes of Hole Problems (Requirements of 20 AAC 25.005 (c)(4)(c)) �, The major expected risk of hole problems in the 1D-08 laterals will be shale instability in the B shale. Managed pressure drilling (MPD) will be used to reduce the risk of shale instability associated with fault crossings. 5. Procedure for Conducting Formation Integrity tests (Requirements of 20 AAC 25.005(c)(5)) The 1 D-08 laterals will be drilled under 20 AAC 25.036 for thru-tubing drilling operations so a formation integrity test is not required. Page 2 of 6 November 26, 2018 PTD ADDlication: 1D-081_1 and 1D -08L1-01 6. Casing and Cementing Program (Requirements of 20 AAC 25.005(c)(6)) New Completion Details Lateral Name Liner Top Liner Btm Liner Top Liner Btm Liner Details Btm MD MD MD TVDSS TVDSS Conductor 1D-08LI 6666' 9300' 6450' 6179' 2-3/8", 4.7#, L-80, ST -L slotted liner; 23' 75' 1640 670 Surface aluminum billet on to 1D -08L1-01 6320' 9700' 6211' 6424' 2-3/8", 4.7#1 L-80, ST -L slotted liner; 2229' 3580 2090 Production 7" with deployment sleeve on to Existing Casing/Liner Information 7. Diverter System Information (Requirements of 20 AAC 25.005(c)(7)) Nabors CDR3-AC will be operating under 20 AAC 25.036, for thru-tubing drilling operations. Therefore, a diverter system is not required. 8. Drilling Fluids Program (Requirements of 20 AAC 25.005(c)(8)) Diagram of Drilling System A diagram of the Nabors CDR3-AC mud system is on file with the Commission. Description of Drilling Fluid System — Window milling operations: Chloride -based PowerVis mud (8.6 ppg) — Drilling operations: Chloride -based PowerVis mud (8.6 ppg). This mud weight may not hydrostatically overbalance the reservoir pressure; overbalanced conditions will be maintained using MPD practices described below. — Completion operations: The well will be loaded with 11.8 ppg NaBr completion fluid in order to provide formation over -balance and shale stability while running completions. Managed Pressure Drilling Practice Managed pressure drilling (MPD) techniques will be employed to maintain a constant overbalanced pressure on the open hole formation throughout the coiled tubing drilling (CTD) process. Mud weight is not, in many cases, the primary well control barrier. This is satisfied with the 5,000 psi rated coiled tubing pack off and MPD choke. BOPE equipment provides the secondary well control as detailed in section 3 "Blowout Prevention Equipment Information". In the 1D-08 laterals we will target a constant BHP of 11.8 ppg EMW at the window. The constant BHP target will be adjusted through choke pressure and/or mud weight increases to maintain overbalanced conditions if increased reservoir pressure is encountered. Additional choke pressure or increased mud weight may also be employed for improved borehole stability. Any change of circulating friction pressure due to change in pump rates or change in depth of circulation will be offset with back pressure adjustments. Page 3 of 6 November 26, 2018 OD Weight (ppCategory t Grade Connection Top MD Btm MD Top TVD Btm TVD Burst psi Collapse psi Conductor 16" 65 H-40 WELDED 23' 75' 23' 75' 1640 670 Surface 10-3/4" 45.5 K-55 $ C 23' 2230' 23' 2229' 3580 2090 Production 7" 26 J-55 BTC 22' 6869' 22' 6868' 4980 4320 Tieback 5-1/2" 15.5 L-80 BTC MOD 19' 6296' 19' 6294' 7000 4990 Tubing 3-1/2" 9.3 L-80 IBT 16' 6338' 16' 6337' 10,160 10,530 7. Diverter System Information (Requirements of 20 AAC 25.005(c)(7)) Nabors CDR3-AC will be operating under 20 AAC 25.036, for thru-tubing drilling operations. Therefore, a diverter system is not required. 8. Drilling Fluids Program (Requirements of 20 AAC 25.005(c)(8)) Diagram of Drilling System A diagram of the Nabors CDR3-AC mud system is on file with the Commission. Description of Drilling Fluid System — Window milling operations: Chloride -based PowerVis mud (8.6 ppg) — Drilling operations: Chloride -based PowerVis mud (8.6 ppg). This mud weight may not hydrostatically overbalance the reservoir pressure; overbalanced conditions will be maintained using MPD practices described below. — Completion operations: The well will be loaded with 11.8 ppg NaBr completion fluid in order to provide formation over -balance and shale stability while running completions. Managed Pressure Drilling Practice Managed pressure drilling (MPD) techniques will be employed to maintain a constant overbalanced pressure on the open hole formation throughout the coiled tubing drilling (CTD) process. Mud weight is not, in many cases, the primary well control barrier. This is satisfied with the 5,000 psi rated coiled tubing pack off and MPD choke. BOPE equipment provides the secondary well control as detailed in section 3 "Blowout Prevention Equipment Information". In the 1D-08 laterals we will target a constant BHP of 11.8 ppg EMW at the window. The constant BHP target will be adjusted through choke pressure and/or mud weight increases to maintain overbalanced conditions if increased reservoir pressure is encountered. Additional choke pressure or increased mud weight may also be employed for improved borehole stability. Any change of circulating friction pressure due to change in pump rates or change in depth of circulation will be offset with back pressure adjustments. Page 3 of 6 November 26, 2018 PTD Application: 1D -08L1 and 1D-081_1-01 Pressure at the 1D-08 Window (6420' MD. 6419' TVD) Usina MPD ' 9. Abnormally Pressured Formation Information (Requirements of 20 AAC 25.005(c)(9)) N/A - Application is not for an exploratory or stratigraphic test well. 10. Seismic Analysis (Requirements of 20 AAC 25.005(c)(10)) N/A - Application is not for an exploratory or stratigraphic test well. 11. Seabed Condition Analysis (Requirements of 20 AAC 25.005(c)(11)) N/A - Application is for a land based well. 12. Evidence of Bonding (Requirements of 20 AAC 25.005(c)(12)) Evidence of bonding for ConocoPhillips Alaska, Inc. is on file with the Commission. 13. Proposed Drilling Program (Requirements of 20 AAC 25.005(c)(13)) Summary of Operations KRU well 1 D-08 is a Kuparuk C Sand producer equipped with 3-1/2" tubing, T' production casing, and a 5-1/2" tieback liner. The CTD sidetrack will utilize two laterals to target the C -sands to the northeast and southwest of 1 D-08. The laterals will improve recovery and target resource not produced by the existing wellbore. CDR3-AC will set a high expansion wedge, a type of whipstock, in the T' casing. A window will be milled in the production casing that the L1 lateral will be drilled out of. The lateral will be completed with 2-3/8" slotted liner from TD up to the L1-01 lateral kick off point with an aluminum billet for kicking off. The L1-01 lateral will be kicked off from the L1 lateral and drilled to TD. It will be completed with 2-3/8" slotted liner from TD to inside of the window. CTD Drill and Complete 1D-08 Laterals: Pre -CTD Work 1. RU Slick -line: Conduct dummy whipstock drift. Install new gas lift design. 2. RU Service Coil: Mill out "D" nipple. 3. RU E -line: Caliper 7" casing and 3-1/2" tubing. 4. Prep site for Nabors CDR3-AC. Ria Work 1. MIRU Nabors CDR3-AC rig using 2" coil tubing. NU 7-1/16" BOPE, test. Page 4 of 6 November 26, 2018 Pumps On 1.8 bpm) Pumps Off C -sand Formation Pressure 9.2 3071 psi 3071 psi Mud Hydrostatic 8.6 2871 psi 2871 psi Annular friction i.e. ECD, 0.08psi/ft) 514 psi 0 psi Mud + ECD Combined no choke pressure 3385 psi Overbalanced -314psi) 2871 psi Underbalanced -200psi) Target BHP at Window 11.8 3939 psi 3939 psi Choke Pressure Required to Maintain Target BHP 554 psi 1068 psi 9. Abnormally Pressured Formation Information (Requirements of 20 AAC 25.005(c)(9)) N/A - Application is not for an exploratory or stratigraphic test well. 10. Seismic Analysis (Requirements of 20 AAC 25.005(c)(10)) N/A - Application is not for an exploratory or stratigraphic test well. 11. Seabed Condition Analysis (Requirements of 20 AAC 25.005(c)(11)) N/A - Application is for a land based well. 12. Evidence of Bonding (Requirements of 20 AAC 25.005(c)(12)) Evidence of bonding for ConocoPhillips Alaska, Inc. is on file with the Commission. 13. Proposed Drilling Program (Requirements of 20 AAC 25.005(c)(13)) Summary of Operations KRU well 1 D-08 is a Kuparuk C Sand producer equipped with 3-1/2" tubing, T' production casing, and a 5-1/2" tieback liner. The CTD sidetrack will utilize two laterals to target the C -sands to the northeast and southwest of 1 D-08. The laterals will improve recovery and target resource not produced by the existing wellbore. CDR3-AC will set a high expansion wedge, a type of whipstock, in the T' casing. A window will be milled in the production casing that the L1 lateral will be drilled out of. The lateral will be completed with 2-3/8" slotted liner from TD up to the L1-01 lateral kick off point with an aluminum billet for kicking off. The L1-01 lateral will be kicked off from the L1 lateral and drilled to TD. It will be completed with 2-3/8" slotted liner from TD to inside of the window. CTD Drill and Complete 1D-08 Laterals: Pre -CTD Work 1. RU Slick -line: Conduct dummy whipstock drift. Install new gas lift design. 2. RU Service Coil: Mill out "D" nipple. 3. RU E -line: Caliper 7" casing and 3-1/2" tubing. 4. Prep site for Nabors CDR3-AC. Ria Work 1. MIRU Nabors CDR3-AC rig using 2" coil tubing. NU 7-1/16" BOPE, test. Page 4 of 6 November 26, 2018 PTD Application: 1D -08L1 and 1D -08L1-01 2. 1D -08L1 Lateral i. Set high expansion wedge at 6420' MD. ii. Mill 2.80" window at 6420' MD. iii. Drill 3" bi-center lateral to TD of 9300' MD. iv. Run 2-3/8" slotted liner with an aluminum billet from TD up to 6666' MD. 3. 1D -08L1-01 Lateral i. Kickoff the aluminum billet at 6666' MD. ii. Drill 3" bi-center lateral to TD of 9700' MD. iii. Run 2-3/8" slotted liner from TD to inside the window. 4 Freeze protect, ND BOPE, and RDMO Nabors CRD3-AC. Post -Rig Work 1. Return to production Pressure Deployment of BHA The planned bottom hole assemblies (BHAs) are too long to simply isolate by closing the double swab valves on the Christmas tree. MPD operations require the BHA to be lubricated under pressure using a system of double swab valves on the Christmas tree, double deployment rams, double check valves and double ball valves in the BHA, and a slick -line lubricator can be used. This pressure control equipment listed ensures there are always two barriers to reservoir pressure, both internal and external to the BHA, during the deployment process. During BHA deployment, the following steps are observed. - Initially the double swab valves on the tree are closed to isolate reservoir pressure. The lubricator is installed on the BOP riser with the BHA inside the lubricator. - Pressure is applied to the lubricator to equalize across the swab valves. The swab valves are opened and the BHA is lowered in place via slickline. - When the BHA is spaced out properly, the double deployment rams are closed on the BHA to isolate reservoir pressure via the annulus. A closed set of double ball valves and double check valves isolate reservoir pressure internal to the BHA. Slips on the double deployment rams prevent the BHA from moving when differential pressure is applied. The lubricator is removed once pressure is bled off above the deployment rams. - The coiled tubing is made up to the BHA with the double ball valves plus the double check valves in the closed position. Pressure is applied to the coiled tubing to equalize internal pressure and then the double ball valves are opened. The injector head is made up to the riser, annular pressure is equalized, and the deployment rams are opened. The BHA and coiled tubing are now ready to run in the hole. During BHA un -deployment, the steps listed above are observed, only in reverse. Liner Running - The 1 D-08 laterals will be displaced to an overbalancing fluid prior to running liner. See "Drilling Fluids' section for more details. - While running 2-3/8" slotted liner, a joint of 2-3/8" non -slotted tubing will be standing by for emergency deployment. A floor valve is made up onto this joint ahead of time, and the rig crew conducts a deployment drill with this emergency joint on every slotted liner run. The 2-3/8" rams will provide secondary well control while running 2-3/8" liner. 14. Disposal of Drilling Mud and Cuttings (Requirements of 20 AAC 25.005(c)(14)) • No annular injection on this well. • All solid waste will be transported to the grind and inject facility at DS -4 Prudhoe Bay for disposal. • Incidental fluids generated from drilling operations will be injected in a Kuparuk Class II disposal well (1 R-18 or 1 B disposal facilities) or Prudhoe DS -4 if a Kuparuk facility is unavailable. - Page 5 of 6 November 26, 2018 PTD Application: 1D-081-1 and 1D-081-1-01 • All wastes and waste fluids hauled from the pad must be properly documented and manifested. • Contact Kuparuk Environmental Coordinator for questions regarding waste classification. (670-4200). 15. Directional Plans for Intentionally Deviated Wells (Requirements of 20 AAC 25.050(b)) - The Applicant is the only affected owner. ' - Please see Attachment 1: Directional Plans - Magnetic and inclination surveys will be taken every 30 ft. No gyro will be run. - MWD directional, resistivity, and gamma ray will be run over the entire open hole section. Distance to Nearest Property Line (measured to KPA boundary at closest point) Lateral Name Distance 1D-081-1 114,550'- 4,550'1D-081-1-01 11D -081-1-01 14,270' Distance to Nearest Well within Pool Lateral Name Distance Well 1 D -08L1 2108' ID -130 1D-081-1-01 941' 1D-04 16. Attachments Attachment 1: Directional Plans for 1D -08L1 and 1D -08L1-01 laterals Attachment 2: Current Well Schematic for 1D-08 Attachment 3: Proposed Well Schematic for 1D -08L1 and 1D -08L1-01 laterals Page 6 of 6 November 26, 2018 ConocoPhillips _ConocoPhillips Export Company Kuparuk River Unit Kuparuk 11) Pad 1 D-08 113-081-1 Plan: 1 D-081-1_wp02 Standard Planning Report 14 December, 2018 BER GHES TGE company ConocoPhillips BATHER ConocoPhillips Planning Report UGIiES a GEoxnpany Database: EDT 14 Alaska Production Company: _ConocoPhillips Export Company Project: Kuparuk River Unit Site: Kuparuk 1 D Pad Well: 1D-08 Wellbore: 1D-081_1 Design: 1D -08L1 wp02 Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Well 1D -OB Mean Sea Level 1 D-08 @ 108.00usft True - Minimum Curvature Project Kuparuk River Unit, North Slope Alaska, United States Map System: US State Plane 1927 (Exact solution) System Datum: Mean Sea Level Geo Datum: NAD 1927 (NADCON CONUS) Using Well Reference Point Map Zone: Alaska Zone 04 Using geodetic scale factor Site Kuparuk 1D Pad, KRU 1D-081_1 Magnetics Model Name Site Position: Northing: 5,959,669.68usft Latitude: 70° 18'1.318 N From: Map Easting: 561,086.44 usft Longitude: 149° 30'18.921 W Position Uncertainty: 0.00 usft Slot Radius: 0.000in Grid Convergence: 0.47 ° Well 1D-08 Well Position -NIS +E/ -W Position Uncertainty 0.00 usft Northing: 0.00 usft Easting: 0.00 usft Wellhead Elevation: Wellbore 1D-081_1 Magnetics Model Name Rate BGGM2018 _ Design 1D -08L1 wP02 Audit Notes: Version: Vertical Section: Sample Date 11/21/2018 5,959,064.00 usft Latitude: 70° 17' 55.408 N 560,490.00 usft Longitude: 149° 30'36.452 W usft Ground Level: 0.00 usft Declination 16 90 Phase: PLAN Depth From (TVD) -N/-S (usft) (usft) 0.00 0.00 Plan Sections Build Turn Rate Rate Measured TFO (°/100usft) TVD Below (°1100usft) (°) Depth Inclination Azimuth System +NI -S +E/ -W (usft) (°) (°) (usft) (usft) (usft) 6,400.00 0.77 300.67 6,290.53 -45.85 14.20 6,420.00 0.77 300.67 6,310.53 -45.71 13.97 6,445.00 3.99 173.49 6,335.51 -46.49 13.92 6,665.02 103.00 173.49 6,450.71 -201.14 31.56 6,735.02 103.66 205.88 6,434.15 -267.30 20.30 7,150.00 103.85 235.81 6,333.31 -568.39 -239.95 7,300.00 101.81 225.24 6,299.91 -661.27 -352.63 7,400.00 98.25 231.36 6,282.48 -726.70 -426.12 7,750.00 89.44 254.30 6,258.73 -884.60 -734.59 8,100.00 89.49 229.80 6,262.06 -1,047.40 -1,041.39 8,450.00 101.49 251.30 6,228.24 -1,217.95 -1,342.09 8,775.00 93.10 229.96 6,186.53 -1,375.48 -1,620.81 9,100.00 89.78 252.47 6,178.25 -1,530.85 -1,903.71 9,300.00 89.79 238.47 6,179.01 -1,613.67 -2,085.21 Dip Angle Field Strength V) (nT) 80.87 57.435 J Tie On Depth: 6,400.00 +E/ -W Direction (usft) (°I 0.00 225.00 Dogleg Build Turn Rate Rate Rate TFO (°/100usft) (°1100usft) (°1100usft) (°) 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 18.00 12.89 -508.71 225.00 45.00 45.00 0.00 0.00 45.00 0.94 46.27 85.00 7.00 0.05 7.21 86.00 7.00 -1.36 -7.04 260.00 7.00 -3.56 6.12 120.00 7.00 -2.52 6.55 110.00 7.00 0.01 -7.00 270.00 7.00 3.43 6.14 60.00 7.00 -2.58 -6.57 250.00 7.00 -1.02 6.93 98.00 7.00 0.00 -7.00 270.00 Target 12/142018 5:13:46PM Page 2 COMPASS 5000.14 Build 85D ConocoPhillips BA ER ConocoPhillips Planning Report F IGHES BAT Database: EDT 14 Alaska Production Company: _ConocoPhillips Export Company Project: Kuparuk River Unit Site: Kuparuk 1D Pad Well 1D-08 Wellbore: 1D-081-1 Design: 1D-081-1_wp02 Planned Survey TVD Reference: Mean Sea Level MD Reference: Measured North Reference: True Survey Calculation Method: TVD Below Depth Inclination Azimuth System (usft) �) (_) (usft) 6,400.00 14.20 0.77 300.67 6,290.53 5,959,018.27 TIP 13.97 22.45 0.00 6,420.00 5,959,018.41 0.77 300.67 6,310.53 18.00 KOP 5,959,017.63 -61.77 15.66 6,445.00 45.00 3.99 173.49 6,335.51 24.28 End 18 die, Start 46 dls 0.00 6,500.00 -201.14 28.74 173.49 6,387.87 6,600.00 5,958,863.14 73.74 173.49 6,448.88 6,665.02 85.00 103.00 173.49 6,450.71 174.66 4 88.78 5,958,796.90 -322.89 6,700.00 235.06 103.86 189.66 6,442.53 6,735.02 -63.96 103.66 205.88 6,434.15 5,958,660.44 End 45 dls, Start 7 dls 7.00 6,800.00 5,958,587.24 103.93 210.56 6,418.64 6,900.00 90.64 104.18 217.77 6,394.32 7,000.00 7.00 104.21 224.99 6,369.77 7,100.00 619.58 104.02 232.21 6,345.35 7,150.00 -352.63 103.85 235.81 6,333.31 5,958,399.98 6 7,200.00 103.22 232.27 6,321.60 7,300.00 101.81 225.24 6,299.91 7 7,400.00 98.25 231.36 6,282.48 8 7,500.00 95.81 237.97 6,270.24 7,600.00 93.29 244.53 6,262.30 7,700.00 90.72 251.05 6,258.80 7,750.00 89.44 254.30 6,258.73 9 Local Co-ordinate Reference: Well 1D-08 TVD Reference: Mean Sea Level MD Reference: 1 D-08 @ 108.00usft North Reference: True Survey Calculation Method: Minimum Curvature Map Eastin9 (usft) 560.50456 560,504.33 560,504.29 560,506.16 560,515.38 560,523.18 560,522.53 560,512.44 560,483.07 560,429.29 560,365.84 560,293.68 560,254.66 560,215.55 560,142.74 -726.70 -426.12 815.17 7.00 120.00 5,958,333.96 560,069.78' -784.05 -507.05 912.95 7.00 110.00 5,958,275.97 559,989.33 -831.96 -594.40 1,008.59 7.00 110.81 5,958,227.36 559,902.38' -869.71 -686.86 1,100.67 7.00 111.33 5,958,188.87 559,810.231 -884.60 -734.59 1,144.94 7.00 111.56 5,958,173.60 559,762.63 7,800.00 89.44 Vertical Dogleg Toolface Map +N/ -S +E/ -W Section Rate Azimuth Northing (usft) (usft) (usft) (°1100usft) (I (usft) -45.85 14.20 22.38 0.00 0.00 5,959,018.27 -45.71 13.97 22.45 0.00 0.00 5,959,018.41 -46.49 13.92 23.03 18.00 -135.00 5,959,017.63 -61.77 15.66 32.60 45.00 0.00 5,959,002.37 -137.27 24.28 79.90 45.00 0.00 5,958,926.94 -201.14 31.56 119.91 45.00 0.00 5,958,863.14 -235.03 30.64 144.53 45.00 85.00 5,958,829.25 -267.30 20.30 174.66 45.00 88.78 5,958,796.90 -322.89 -9.53 235.06 7.00 86.00 5,958,741.07 -403.10 -63.96 330.26 7.00 87.12 5,958,660.44 475.79 -128.00 426.95 7.00 88.87 5,958,587.24 -539.88 -200.69 523.66 7.00 90.64 5,958,522.58 -568.39 -239.95 571.58 7.00 92.40 5,958,493.75 -596.94 -279.29 619.58 7.00 -100.00 5,958,464.89 -661.27 -352.63 716.93 7.00 -100.83 5,958,399.98 Map Eastin9 (usft) 560.50456 560,504.33 560,504.29 560,506.16 560,515.38 560,523.18 560,522.53 560,512.44 560,483.07 560,429.29 560,365.84 560,293.68 560,254.66 560,215.55 560,142.74 -726.70 -426.12 815.17 7.00 120.00 5,958,333.96 560,069.78' -784.05 -507.05 912.95 7.00 110.00 5,958,275.97 559,989.33 -831.96 -594.40 1,008.59 7.00 110.81 5,958,227.36 559,902.38' -869.71 -686.86 1,100.67 7.00 111.33 5,958,188.87 559,810.231 -884.60 -734.59 1,144.94 7.00 111.56 5,958,173.60 559,762.63 7,800.00 89.44 250.80 6,259.22 -899.59 7,900.00 89.45 243.80 6,260.19 -938.16 8,000.00 89.46 236.80 6,261.14 -987.67 8,100.00 89.49 229.80 6,262.06 -1,047.40 10 -89.83 5,958,008.36 559,457.17 -1,121.01 8,200.00 92.98 235.87 6,259.90 -1,107.76 6,300.00 96.45 241.97 6,251.67 -1,159.19 6,400.00 99.84 248.16 6,237.50 -1,200.92 8,450.00 101.49 251.30 6,228.24 -1,217.95 11 5,957,835.41 559,157.89 -1,388.11 1,854.84 8,500.00 100.28 247.96 6,218.80 -1,235.04 8,600.00 97.75 241.35 6,203.12 -1,277.31 8,700.00 95.12 234.82 6,191.91 -1,329.83 8,775.00 93.10 229.96 6,186.53 -1,375.48 12 558,880.47 -1,640.17 2,143.53 7.00 8,800.00 92.86 231.69 6,185.23 -1,391.25 8,900.00 91.85 238.63 6,181.12 -1,448.29 9,000.00 90.82 245.55 6,178.78 -1,495.06 9,100.00 89.78 252.47 6,178.25 -1,530.85 13 -1,997.00 2,519.92 7.00 -90.00 9,200.00 89.78 245.47 6,178.64 -1,566.71 9,300.00 89.79 238.47 6,179.01 -1,613.67 -782.27 1,189.26 7.00 -90.00 5,958,158.22 559,715.07 -874.47 1,281.72 7.00 -89.97 5,958,118.92 559,623.20 -961.27 1,378.11 7.00 -89.90 5,958,068.72 559,536.80 -1,041.39 1,477.00 7.00 -89.83 5,958,008.36 559,457.17 -1,121.01 1,575.98 7.00 60.00 5,957,947.36 559,378.05 -1,206.30 1,672.66 7.00 60.13 5,957,895.25 559,293.18 -1,296.00 1,765.59 7.00 60.63 5,957,852.80 559,203.83 -1,342.09 1,810.21 7.00 61.51 5,957,835.41 559,157.89 -1,388.11 1,854.84 7.00 -110.00 5,957,817.95 559,112.01 -1,477.29 1,947.80 7.00 -110.63 5,957,774.96 559,023.18 -1,561.58 2,044.53 7.00 -111.67 5,957,721.77 558,939.33 -1,620.81 2,118.70 7.00 -112.40 5,957,675.66 558,880.47 -1,640.17 2,143.53 7.00 98.00 5,957,659.73 558,861.24 -1,722.12 2,241.82 7.00 98.09 5,957,602.03 558,779.76 -1,810.41 2,337.32 7.00 98.38 5,957,554.56 558,691.86 -1,903.71 2,428.61 7.00 98.54 5,957,518.02 558,598.85 -1,997.00 2,519.92 7.00 -90.00 5,957,481.42 558,505.87 -2,085.21 2,615.51 7.00 -89.97 5,957,433.75 558,418.04 12114!1018 5:13:46PM Page 3 COMPASS 5000.14 Build 85D ConocoPhillips BAj(ER ConocoPhillips Planning Report UGHES aGEcompany Database: EDT 14 Alaska Production Company: _ConocoPhillips Export Company Project: Kuparuk River Unit Site: Kuparuk 1 D Pad Well: 1D-08 Wellbore: 1 13-081-1 Design: lD-08L1_wp02 Planned Survey 6,290.53 Measured TVD Below Depth Inclination Azimuth System (usft) (°) (°) (usft) Casing Points KOP 6,445.00 6,335.51 Measured Vertical 13.92 Depth Depth 6,665.02 (usft) (usft) -201.14 9,300.00 6,179.01 2318" Plan Annotations Local Co-ordinate Reference: Well 1D-08 TVD Reference: Mean Sea Level MD Reference: 1D-08 @ 108.00usft North Reference: True Survey Calculation Method: Minimum Curvature Vertical Dogleg +N/ -S +EbW Section Rate (usft) (usft) (usft) (°/100usft) Name Measured Vertical Local Coordinates Depth Depth +NIS +E/ -W (usft) (usft) (usft) (usft) Comment 6,400.00 6,290.53 -45.85 14.20 TIP 6,420.00 6,310.53 -45.71 13.97 KOP 6,445.00 6,335.51 -46.49 13.92 End 18 dls, Start 45 dls 6,665.02 6,450.71 -201.14 31.56 4 6,735.02 6,434.15 -267.30 20.30 End 45 dls, Start 7 cis 7,150.00 6,333.31 -568.39 -239.95 6 7,300.00 6,299.91 -661.27 -352.63 7 7,400.00 6,282.48 -726.70 426.12 8 7,750.00 6,258.73 -884.60 -734.59 9 8,100.00 6,262.06 -1,047.40 -1,041.39 10 8,450.00 6,228.24 -1,217.95 -1,342.09 11 8,775.00 6,186.53 -1,375.48 -1,620.81 12 9,100.00 6,178.25 -1,530.85 -1,903.71 13 9,300.00 6,179.01 -1,613.67 -2,085.21 Planned TD at 9300.00 Toolface Map Map Azimuth Northing Easting (°1 (usft) (usft) Casing Hole Diameter Diameter (in) (in) 2.375 3.000 1211412018 5:13:46PM Page 4 COMPASS 5000.14 Build 85D ConocoPhillips Bp_ ICER ConocoPhillips Travelling Cylinder Report ATR aGEmmpany Company: ConomPhillips (Alaska) Inc. -Kupl Project: Kuparuk River Unit Reference Site: Kuparuk 1D Pad Site Error: 0.00 usft Reference Well: 1 D-08 Well Error: 0.00 usft Reference Wellbore 1D-081-1 Reference Design: 1D-08L1_wp02 Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Output errors are at Database: Offset TVD Reference: Well 1 D-08 1 D-08 0 108.00usft 1D-08 Q 108.00usft True Minimum Curvature 1.00 sigma EDT 14 Alaska Production Offeet Datum Reference 1D-08L1_wp02 Filter type: NO GLOBAL FILTER: Using user defined selection 8 filtering criteria Interpolation Method: MD Interval 25.00usft Error Model: ISCWSA Depth Range: 6,400.00 to 9,300.00usft Scan Method: Tray. Cylinder North Results Limited by: Maximum center -center distance of 1,119.20 usft Error Surface: Pedal Curve Survey Tool Program Date 12/14/2018 From To (usft) (usft) Survey (Wellbore) 200.00 6,400.00 Gyro(ID-08) 6,400.00 9,300.00 1D-08L1_Wp02(1D-081-1) Casing Points Summary Tool Name Description GVD-CT-CMS Gyrodata contcasing m/s MWD MWD - Standard Measured Vertical Casing Hole Depth Depth Diameter Diameter (usft) (usft) Name (in) (in) 9,300.00 6,287.01 2 3/8" 2.375 3,000 Site Name Offset Well - Wellbore - Design Kuparuk 1 D Pad 1 D-06 - 1 D-06 - 1 D-06 1 D-07 - 1 D-07 - 1 D-07 1 D-08 - 1 D-08 - 1 D-08 1 D-08 - 1 D -08L1-01 - 1 D-081-1-01_wp02 1 D-10 - 1 D-10 - 1 D-10 1 D-102 -1 D-102 - 1 D-102 1 D-102 -1 D-102LI - 1 D-10211 1 D-102 - 1 D-102PB2 - 1 D-102PB2 1 D-102 - 1 D-102PB3 - 1 D-102PB3 1 D-11 - 1 D-11 - 1 D-11 1 D-11 - 1 D-11 Lt - 1 D-11 L1 1 D-11 - 1 D-11 L2 - 1 D-11 L2 113-11-1D-11L2PB1-1D-11L2PB1 ID -124 - 1D-124 - 1D-124 1 D-126 - Plan: 1 D-1 26A - 1 D-126A(wp02) 1 D-127 - 1 D-127 - 1 D-127 1 D-128 - 1 D-128 - 1 D-128 1 D-129 - 1 D-129 - 1 D-129 1 D-130 - 1D-130 - 1 D-130 1 D-131 - 1 D-131 - 1 D-131 1 D-132 - 1 D-132 - 1 D-132 1 D-133 - 1 D-133 - 1 D-133 1D-133-1D-133PB1-1D-133PB1 1 D-134 - 1 D-134 - 1 D-134 1 D-136 - 1 D-136 - 1 D-136 1 D-137 -1 D-137 - 1 D-137 1 D-138 -1 D-138 - 1 D-138 1 D-138 - 1 D-138PB7 - 1 D-138 WP2 Reference Offset Centre to No -Go Allowable Measured Measured Centre Distance Deviation Warning Depth Depth Distance (usft) from Plan (usft) (usft) (usft) (usft) CC - Min centre to center distance or covergent point, SF - min separation factor, ES - min ellipse separation Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range 12/142018 11:45:04AM Page 2 COMPASS 5000.14 Build 85D ( ConocoPhillips Bpl(ER ConocoPhillips Travelling Cylinder Report UGHES a GEmrnpany Company: ConocoPhillips (Alaska) Inc. -Kupl Local Co-ordinate Reference: Well 10-08 Project Kuparuk River Unit TVD Reference: 1D-08 @ 108.00usft Reference Site: Kupamk 1D Pad MD Reference: 1D-08 @ 108.00usft Site Error: 0.00 usft North Reference: True Reference Well: 1D-08 Survey Calculation Method: Minimum Curvature Well Error: 0.00 usft Output errors are at 1.00 sigma Reference Wellbore 1D-081_1 Database: EDT 14 Alaska Production Reference Design: 1D-08L7_wpO2 Offset TVD Reference: Offset Datum Summary KupamklDPad- 1D -08 -ID -08-1D-08 Reference Offset Centre to No -Go Allowable Measured Measured Centre Distance Deviation Warning Site Name Depth Depth Distance (usft) from Plan Offset Well - Wellbore - Design (usft) (usft) (usft) (usft) Kuparuk 1D Pad Measured Vertical Measured Venlcal Reference 1 D-36 - i D-36 - 1 D-06 Met Walloons centre Casing- cars. to Out of range 1 D-36 - 1 D-36 - 1 D-36WP4(Baker) Minn north cepa Depta Out of range 1 D-36 - 1 D-361_1 - 1 D-36LI Anne a +N14 eV.w How aim Out of range I D-36 - 1 D-361_2 - 1 D-361_2 Deviation (ueff) (run) (usft) Out of range 1 D-37 -1 D-37 - 1 D-37 (..it) r) (¢aft) Ivee) Out of range 1 D-37 - 1 D-37LI - 1 D-371_1 nen( lualq 6,425.00 6.423.53 Out of range 1 D-37 - 1 D-371_2 - 1 D-371_2 0.01 0.01 -14.33 -45.68 Out of range 1 D-37 - 1 D-37L2PB1 - 1 D-37L2PB1 e04 088 -0.60 FAIL -Major Risk 6.449.80 Out of range 1 D-38 - 1 D-38 - 1 D-38 e,PI8.53 0.01 0.03 -13.84 Out of range 1 D-39 - 1 D-39 - 1 D-39 6.312 1.47 1.59 -0.22 FAIL - Major Risk Out of range 1 D-40 - 1 D40 - 1 D-40 6475.00 6,473.53 0.05 a.d Out of range 1 D-40 - 1 D40A - 1 D40A 13.33 6.312 6.69 2.84 Out of range 1 D-41 - 1 D41 - 1 D41 6.491.35 6.500.00 6,496.52 0.20 Out of range 1D -41-1D41 Pat -1D41 PB1 45.16 13.04 6.312 16.13 Out of range 1 D-41 - 1 D-41 PB2 -1 D41 PB2 8,513.11 6,507.02 6.525.00 6,52152 Out of range 1D42 -1042-1D42 -8.48 44.99 12.75 6.312 Out of range 1 D42 - 1 D42 - 1042 (Baker) 23.41 Pass - Major Risk 6.528.29 6,510.97 6,550.00 Out of range 1 D42-1D4211-1D42LI 009 -8.12 4sIs2 12.46 Out of range 10-42 - i D421_1 Pal - 1 D42L1 PBI 6.29 30.37 Pass - Major Risk 8,540.60 6.527.82 Out of range Offset Design KupamklDPad- 1D -08 -ID -08-1D-08 Gmnsiaefror. 0.99 use Survey Program: 20DGVDLT-CMS Rule Assigred: Major Rlsk Dffeat well Error O.Ouse Reference Offset semi Major mis Measured Vertical Measured Venlcal Reference Offset IrWace Met Walloons centre Casing- cars. to No Op AII.Me warning Minn north cepa Depta Anne a +N14 eV.w How aim Centre Divisor. Deviation (ueff) (run) (usft) Ivan) (pso) (..it) r) (¢aft) Ivee) (in) (usft) nen( lualq 6,425.00 6.423.53 6.425.00 6,423.53 0.01 0.01 -14.33 -45.68 13.91 6.312 e04 088 -0.60 FAIL -Major Risk 6.449.80 6,448.37 6,450.00 e,PI8.53 0.01 0.03 -13.84 45.50 13.62 6.312 1.47 1.59 -0.22 FAIL - Major Risk 6,473.61 6,471.59 6475.00 6,473.53 0.05 a.d -10.41 45.33 13.33 6.312 6.69 2.84 4.05 Pass -Major Risk 6494.69 6.491.35 6.500.00 6,496.52 0.20 0.06 -9.07 45.16 13.04 6.312 16.13 4.40 11.68 Pass - Major Risk 8,513.11 6,507.02 6.525.00 6,52152 0.27 0.07 -8.48 44.99 12.75 6.312 29.05 5.65 23.41 Pass - Major Risk 6.528.29 6,510.97 6,550.00 6,548.52 0.29 009 -8.12 4sIs2 12.46 6.312 44.84 6.29 30.37 Pass - Major Risk 8,540.60 6.527.82 6,575.00 6.573.52 0.29 0.10 4.91 -44.65 12.17 8.312 62.27 6.58 55.70 Pass - Major Risk 6550.0 6,533.93 6.600.00 6,598.51 0.29 0.12 4.77 -44.40 1188 6.312 81.41 6.75 74.68 Pass - Major Risk 6,559.62 6,539.67 6,625.00 6,823.51 0.20 0.13 -7.67 -44.30 11.60 6.312 101.67 6.67 95.00 Pass - Major Risk 8,568.74 6.543.52 6.650.0 6.648.51 0.14 0.15 4.59 .44.13 11.31 6.312 In.79 6.58 116.23 Pass - Major Risk 6575.00 6.547.58 6.675.0 6,673.51 611 0.16 -7.54 -4398 11.02 6.312 144.61 6.42 438.15 Pass - Major Risk 6.575.00 6,50.58 6,700.00 6,698.51 0.11 0.10 -7.49 -43.79 10.73 6.312 16693 6.42 160.64 Pass - Major Risk 6,575.00 6.WZ8 6725.00 6.723.50 0.11 0.19 -T46 43.62 10.44 6.312 189.91 8.42 18184 Pass - Major Risk 6.585.97 6,552.22 6,750.00 6,748.50 0.14 0.20 -7.42 -43.45 10.15 6.312 212.59 6.20 206,41 Pass -Major Risk 6,589.27 6.553.44 6,775.00 6,773.50 0.15 cm 4.40 4328 9.86 6.312 235.88 8.48 229.39 Pau - Major Risk 6,600.00 6.556.88 6.800.00 6.790.50 0.21 0.23 4.38 4110 9.57 6.312 258.73 7.03 252.84 Pass - Major Risk 6.600.00 6,556.85 6.825.00 6,823.49 0.21 0.25 -7.36 42.93 9.28 6.312 283.21 7.02 276.27 Pass - Major Risk 6.600.00 8,558.88 6,850.00 6,848.49 0.21 0.26 -7.34 42.78 9.00 6.312 308.93 7.01 299.98 Pass - Major Risk 6.600.00 6.556.88 6,875.00 6.873.49 0.21 0.28 -7.33 -42.59 8.71 6.312 330.83 7.00 323.84 Pass - Major Risk 8,500.m 6,556.88 6,000.00 6,878.49 0.21 0.28 -7.33 -42.58 8.65 6.312 335.63 7.00 32884 Pass - Major Risk CC - Min centre to center distance or covergent point. SF - min separation factor, ES - min ellipse separation 12/1472018 11:45:04AM Page 3 COMPASS 5000.14 Build 85D ConocoPhillips Project: Kupauk River Unit Site: Kuparuk 10 Pad amm�l.mT^•x^^^ Nepietle wna: re wq'na rile WELLBORE DETAILS: 1D-0811 REFERExcE IxrORugnoN Parent Wellbore: iD-0a co«sml. IVD) leeme Well OAe.Tae xonn Well: 1D-06 Wellbore: iD-0aLi 3�erein Aan.Bsn aPawe; ¢a.ar• Te on MD:6400.00 vetiml I Iva) rtkre .: Nem Sm Ln'e sxuon,B Reference: aoKbood Plan: iD-0eLt_wp0211D-0a11D-0BL1) em eix�aumi 1m �Oxe Releeee'. t0a8@1.w MEMO GLV Wtn fhbM: Nddrtum CwaWrc WELL DETAILS: 1D-08 +N/ -S +E/ -W Northing Easting Latitude Longitude 0.00 0.00 5959064.00 560490.00 70° 17' 55.408 N 149° 30' 36.452 W See MD Inc Azi TVDSS +N/ -S +E/ -W Dleg TPace VSect Annotation 1 6400.00 0.77 300.67 6290.53 -05.85 14.20 0.00 0.00 22.38 TIP 2 6420.00 0.77 300.67 6310.53 -45.71 13.97 0.00 0.00 22.45 KOP 3 6445.00 3.99 173.49 6335.51 -46.49 13.92 18.00 225.00 23.03 End 18 d1s, Start 45 dls 4 6665.02 103.00 173.49 6450.71 -201.14 31.56 45.00 0.00 119.91 4 5 6735.02 103.66 205.88 6434.15 -267.30 20.30 45.00 85.00 174.66 End 45 cls, Start 7 dls 6 7150.00 103.85 235.61 6333.31 -568.39 -239.95 7.00 86.00 571.58 6 7 7300.00 101.81 225.24 6299.91 -661.27 -352.63 7.00 260.00 716.93 7 8 7400.00 98.25 231.36 6282.48 -726.70 -426.12 7.00 120.00 815.17 8 9 7750.00 89.44 254.30 6258.73 -884.60 .734.59 7.00 110:00 1144.94 9 10 8100.00 89.49 229.80 6262.06 -1047.40 -1041.39 7.00 270.00 1477.00 10 11 8450.00 101.49 251.30 6228.24 -1217.95 -1342.09 7.00 60.00 1810.21 11 12 8775.00 93.10 229.96 6186.53 -1375.48 -1620.81 7.00 250.00 2118.70 12 13 9100.00 89.78 252.47 6176.25 -1530.85 -1903.71 7.00 98.00 2428.61 13 14 9300.00 89.79 238.47 6179.01 -1613.67 -2085.21 7.00 270.00 2615.51 Planned TD at 9300.00 BA ER F UGHES GEtompa,y West( -\/East(+) (300 usftlin) 5775 I.- IIIIIIII,VIII'llll'lllllllll1llll1lllllllll'llll� .No I■■■M■■■■ MEMO ■,�■■■■N 5650 IM■■M■■■■M■■■I SII ■ono 5925 ■M■■■■■O■■■Or��■ ■ I■MO■■■■■■■�I�II■■ 6000 iifi I■■■■■■■■■■`_��►�■■■■� d 6075 ■■■MEMM11�%►�i/I■■■■� ~I ° 6150 ■■■■■�!lO'►■��■■■■■ 6225 ° „I■■O��O.O �IMOOM■■ ,p--- 12 I■■MM!!�l��iii6�■■EMM■� KD „ Pia- TDa 9300. 6300 11 ID 08/ID OBG d 1 I die. -05. it1 7 6375 ID4 Vi0. LI -01 6450 4 Red ;ft.;Mn 7 Is 6525 West( -\/East(+) (300 usftlin) 5775 5650 5925 6000 d 6075 ~I ° 6150 6225 ° ,p--- 12 KD Pia- TDa 9300. 6300 11 ID 08/ID OBG d 1 I die. -05. it1 7 6375 ID4 Vi0. LI -01 6450 4 Red ;ft.;Mn 7 Is 6525 can S aa Le I OB/1 OB 6600 o Vertical Section at 225.000 (75 usfUin) ConocoPhillips 1D-08 Project: Nuparuk River Unit camummm.uonn tiseaRr=Nunn tses WELLBORE DETAILS'. 10-0811 ^nrcnrnw vro^m^non Site: KuparuklD Patl u.n., r.=m Parent Wellbore 1D-08 comsnam M11 104Xi, T. lTrol Well: 1D - OB L sr=nainara3>s=vr Tie on MD 6400.00 vertical 1 ) Rada rce: tPoa ce.00ualt SMbn(�)Relerercx: alol -IO WN, O.COEi WellEore: 1D -08L1 o�p Hple: eo.e]' ineasureeHNept^WRnM :IPOm@tp0arouX Plan: 1048L1_erp02(iD-08l1 D-DBLt( mo�aei c ie B F�UGHES GE<ar,w, 1D-08 Proposed Completion 16" 65# H-40 shoe @ 75' RKB 10-3/4" 45# K-55 shoe @ 2230' RKB C -sand perfs 6384'-6472' 6479'- 6484' 7" 26# J-55 shoe @ 6869' RKB 3-1/2" Tubing L-80 w/ IBT 3-12" Landing DS Nipple @ 493' RKB (2.875" ID) 3-12" Camco KBG Mandrels @ 2541', 3786', 4688', 5335', 5798', 6012' 5" Seal Bore Receptacle w/4" bore @ 6110' RKB 5"x3-1/2" Crossover @ 6129' RKB Camco DS Landing Nipple @ 6175' RKB (ID 2.813") Camco GLM @ 6227' RKB Baker GBH -22 Locator @ 6283' RKB Baker 80-40 Seal Assembly @ 6284' RKB Baker FB -1 Packer @ 6294' RKB Baker SBE @ 6296' RKB Camco D Nipple @ 6326'(2.75" ID) Baker WLEG @ 6337' RKB 7" Cast Iron Bridge Plug (6550' RKB) 1 D-081-1-01 TD @ 9,700' MD Top of Liner @ 6320' MD 1D-081-1 TD @ 9,300' MD Top of Aluminum Billet @ 6666' MD KUP PROD WELLNAME 1D-08 .LLBORE 1D-08 ConociiPhillip$ Alaska. Ino. Il Attributes Max Angle &MD TD Field Name WeIIWre APIIUIM Wtlltare 3latus nc11.1 MD(M1Ke) % tatm MKBI KUPARUK RIVER UNIT W0292@fifi00 PROD .89 2,100.00 6800.0 Comment K!3 (ppm) Dat'Mndation EM OMe KB+3MM) nignelmse Dah SSSV: NIPPLE 100 9I2fi/2011 Last WO: 31241201d 33.00 511411978 tam I mrzma r IIspe A. lLastTag M,wtalbn don. Me) End Der< I WCEWK I /Jit Mol By N.>N„ER. rea co IAJCI.G. 20160 NIPPLE:d91.g suRFACEgm2zxio GASUFT:gBi GAS DFT: 67M.3 GAS UFT', 4899.3 GAS UFT, 63:1as GAS UFT: s.3 GAS UFT: 6.911.7 ..it G1.2 SEAL Argi 6.106.11 PACKER 6M7 TIF RACK UNFRsrrz:3 rrz SBE:r NIFPLE:63265 VNEG:6337.3 IPES, 6s4.og.4JZD FRAC:6 Na.o (PERF; B.a]A68.i8s,0 PLUG; irsai /PERF; 6.GG.06.N1 D- /PERP 66M.G8.662D� PROOVCTION. 33 td M9.0 IMArenMMlm Last Tag'. Had i 6,435.0112(1018 10.08 1 fergusp Last Rev Reason EMDete WNIMc -11 MM By Rev Reason: Tag Fill 1122018 10.08 fergusp I Casing Strings eeti, Delc,i pho, m(nl ID (I,) TOPlnK81 semcPlM1(rcKB) set Depth(TVGL. Widen L.. Grade TOPTn,e,d CONDUCTOR 16 1506 23.0 75.0 75.0 65.00 E40 WELDED 4eing Deacriprbn Do (in) ID(in) Tors, MKB) Set Depth mKB) Set depth fri man (I Go. Top Thread SURFACE 1014 9.79 22.8 2,2360 2,229.4 45.50 K-55 Cming DOR;iebn OD rid ID(inl ToplrlKel Ses DepMmKe) set Bari fl DI... WN.en g... Grade Dep Thread PRODUCTION 7 6.28 22.1 6,869.0 6,8625 26.00 J-55 BUTT Casing Description 30 Let) WD n) Tap MKe) SN Depir MKB) ser CarM(TVD).. When ll.. Gratle Tetiread TIEBACKLINER51/2x 512 4.28 19.1 6,295.5 fi.2940 15.50 L-80 BTCM 3 112 @ 6120 69 Liner Details Nor Top mHel IDp (TvD)DKBI TWlnu pl It.. Dec Co. (in) 6110.1 6101 147 SBR BTC PIN x PIN CASING SEAL BORE RECEPTACLE 4000 6,1787 6.10 3 1.47 X Reducing 5" BTC Box x 3-117 EUE Pin cross over sub 2.992 ,1 4. .1 7 1.46 Tulare 3.5", 9.39, L-80 EUi Sel Tubing joint 2.992 6175.0 6.1735 1.46 NIPPLE CAMCO'DS'I.ANDING NIPPLE 9 TI 11320 2.812 .188.4 ,184. 1.45 Tubing 3.5", 9.39, LA0 EUE-Mod 8rd Tubing joint 2.992 ,227.0 6 2 . 1. J MANDREL CAMCO MING GEM 9195AE07 2.920 6.246.0 8$44.5 1.14 Tubiag 3.5'.9.39, LAO EUE-Mod Bid Tubing joint 2.992 6,2829 62814 090 LOCATOR BAKER GBH -22 LOCATOR SUB 2.990 62A4.1 6,262.6 0.89 PER BAKER 80-40SEALASSY w/3 -ft Space out 2.990 Tubing Strings Tuning Delc,,Pnon 9rmg Ma._1. var.) Se Depth Dr.. set DXp%(Terd I...v D.) Grade ropeerneonon TOBING W0201A 312 299 164 6,1232 612L8 9.30 L80 IBT Completion Details Daimler TMKS) Top 1na Me Des enm mj TRANSMITTAL LETTER CHECKLIST WELL NAME: Kezz I_]� > - C-:6 L, I PTD: -z/ca - [ ?2 - /Development —Service Exploratory _ Stratigraphic Test —Non -Conventional FIELD: 4' Vu' POOL:`' Check Box for Appropriate Letter / Paragraphs to be Included in Transmittal Letter CHECK OPTIONS TEXT FOR APPROVAL LETTER MULTI The permit is for a new wellbore segment of existing well Permit LATERAL No. ! 7'7-66` , API No. 50-bZ - Z626Z �. (If last two digits Production should continue to be reported as a function of the original in API number are API number stated above. between 60-69 In accordance with 20 AAC 25.005(f), all records, data and logs acquired for the pilot hole must be clearly differentiated in both well Pilot Hole name ( PH) and API number (50-_- -� from records, data and logs acquired for well name on permit). The permit is approved subject to full compliance with 20 AAC 25.055. Approval to produce/inject is contingent upon issuance of a conservation Spacing Exception order approving a spacing exception. (Company Name) Operator assumes the liability of any protest to the spacing exception that may occur. All dry ditch sample sets submitted to the AOGCC must be in no greater Dry Ditch Sample than 30' sample intervals from below the permafrost or from where samples are first caught and 10' sample intervals through target zones. Please note the following special condition of this permit: production or production testing of coal bed methane is not allowed for Non -Conventional (name of well) until after (Company Name) has designed and Well implemented a water well testing program to provide baseline data on water quality and quantity. (Companv 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 T CHECKLIST Field &Pool KUPARUK RIVER - 490000 .Well Name: KUPARUK RIV UNIT 1D-081.1 Program DEV Well bore seg PTD#: 2181720 Company CON_OCOPHILLIPS ALASKA INC Initial Class/rype DEV/ PEND GeoArea 890_ Unit -tlaQ On/Off Shore On Annular Disposal ❑ Administration X17 Nonconven, gas conforms to AS31,0300. 1.A),lj.2.A-D) . . . . . . . . ............. ,05 NA_ . - - - - - - - - - - _ - .......... 1 Permit fee attached.- -_------ ------ ---------------------NA-..-----...-----...-.............. 2 Lease number appropriate- - . ............... . . . . . . . . . . . . ..... Yes ...... Entire wellin ADL 25650... 3 Unique well. name and number _ - _ - - - - - - - - - - - _ - _ Yes - - - - 4 Well located in a. defined pool- - - - - - - - . . . . ........ . . . . . . . Yes - - - - _ - _ KUPARUK RIVER,_KUPARUK RIV OIL. -490100 - - 5 Well located proper distance from drilling unit boundary - - - - - - - _ - - Yes - - Kuparuk River Oil Pool, govemed by Conservation Order No. 432D 6 .Well located proper distance. from. other wells. - - - - - - - - - - - ---- - - - Yes - - - _ - - Conservation Order No. 432D has no interwell-spacing. restrictions, Wellbore will be more than 500' - 7 Sufficient acreage available in drilling unit- - - - - - - Yes - - - from an external property line where. ownership or landownership changes. As proposed,. well will 8 If deviated, is. wellbore plat included - - ........ Yes conform to.specing-requirements. 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 - - - SFD 12/21/2018 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# in. comments) (For NA - - - - - 15 All wells within 1(4. mile area of review identified (For service well only). - - - - - - - - - - - NA- - - - - - - - - - - -- - --- - --- 16 Pre -produced injector; duration of pre -production less than -3 months -(For service well only) .. NA... --- - ------- - - - - - - - - - - - - 18 Conductor string -provided - - - - - - - - - - - - - - - - - - - - - - - ----- - - - - - - - - - - NA- - - - - - - - Conductor set in KRU 1D-08 Engineering 19 Surface casing_ protects all known USDWs - _ - - - NA Surface casing set in KRU 1D-08 20 CMT, vol adequate to circulate on conductor & surf.csg - - - - - - - - - - - - - - - NA Surface casing set and fully cemented - - 21 CMT. vol adequate to tie-in long string to surf csg...... - - - ...... NA... 22 CMT. will cover all known productive horizons- - - - ... _ ... No... - Productiveintervalwill be completed withuncemented production liner 23 Casing designs adequate for C, T, B & permafrost - - - - Yes 24 Adequate tankage, or reserve pit - - - - - _ . Yes - - Rig has steel tanks all. waste to approved disposal wells - - 25 Jf a. re -drill, has -a 10-403 for abandonment keen approved _ - - - - - - _ - ....... NA- 26 Adequate wellbore separation proposed... - - - - - - - - - - Yes - - - - - Anti -collision analysis complete; no major risk failures 27 If diverter required, does it meet regulations- - - - - - - - - - - - NA- Appr Date 28 Drilling fluidprogram schematic & equip list adequate- - - - - - - - - - - - - - - -- - ---- Yes - - - - Max formation- pressure is 3664 psig(11.2 ppg EMW); will drill w/ 8.6.ppg EMW and. maintain overbal w/ MPD VTL 12/24/2018 29 BOPEs,.do they meet regulation ... - - - .. Yes 30 BOPE.press rating appropriate; test to (put psig in comments)_ - _ - _ _ - _ _ . Yes - - - - MPS is 3033 psig; will test BOPS to 3500 -prig . . . .......... . . . . . . . . . . . . ... . . . . . . 31 Choke manifold complies WAPI. RP -53 (May 64).. - - .. .. - - - - - - Yes 32 Work will occur without operation shutdown. _ _ Yes - - - - - - - - - - - - - 33 Is presence of H2$ gas. probable ....... Yes - - H2S measures required 34 35 .Mechanical condition of wells within AOR verified (For service well only) - .. - - - - - - - - Permit can be issued w/o hydrogen sulfide measures _ ... - - - - - - - - NA ------------ No - - - - - - - - - - - -- - Wells -on-lD-Pad are H2S-bearing. H2S measures required. Geology 36 Datapresentedon potential overpressure zones . ............... . . . - _ - _ _ Yes - - - - _ _ Max. potential -res. pressure is 11.2 ppg_ EMW; expected res. pressure is 9.2 ppg EMW. Well will be Appr Date 37 Seismic analysis of shallow gas -zones ..... _ - _ - - _ - - ... NA ... drilled using 8,6 ppg mud,.a coiled -tubing rig, and -managed -pressure drilling technique to control SFD 12/21/2018 38 Seabed condition survey _(if off -shore) ............ . . ..... _ - - - _ - - NA ....... formation pressures and. stabilize shale sections with constant BHP of. about 11.8 ppg EMW, - - 39 Contact namelphone for weekly_ progress reports [exploratory only] ........... NA. - ... - NOTE: Chance of encountering free gas whiledrillingdue to gas injection- performed in this area.. Geologic Date: Engineering Date Public Date Commissioner: miss /a �-/o lZ lZre llU