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218-173
DATA SUBMITTAL COMPLIANCE REPORT 4115/2019 Permit to Drill 2181730 Well Name/No. KUPARUK RIV UNIT 113-081-1-01 MD 9480 ND 6484 REQUIRED INFORMATION Operator CONOCOPHILLIPS ALASKA, INC. API No. 50-029-20266-61-00 Completion Date 1/10/2019 Completion Status 1-0I1- Current Status 1 -OIL UIC No Mud Log No 1/1, Samples No V/ Directional Survey Yes Z DATA INFORMATION List of Logs Obtained: GR/Res Well Log Information: Log/ Electr Data Digital Dataset Type Med/Frmt Number Name ED C 30353 Digital Data ED C 30353 Digital Data ED C 30353 Digital Data ED C 30353 Digital Data ED C 30353 Digital Data ED C 30353 Digital Data ED C 30353 Digital Data ED C 30353 Digital Data ED C 30353 Digital Data ED C 30353 Digital Data ED C 30353 Digital Data ED C 30353 Digital Data ED C 30353 Digital Data ED C 30353 Digital Data Log Log Run Interval OH/ Scale Media No Start Stop CH Received 2/8/2019 2/8/2019 2/8/2019 2/8/2019 2/8/2019 2/8/2019 2/8/2019 2/8/2019 2/8/2019 2/8/2019 2/8/2019 2/8/2019 2/8/2019 2/8/2019 ED C 30353 Digital Data 2/8/2019 ED C 30353 Digital Data 2/8/2019 ED C 30353 Digital Data 2/8/2019 ED C 30353 Digital Data 2/8/2019 (from Master Well Data/Logs) Electronic File: 1D-081-1-01 2MD Final.cgm Electronic File: 1D-081-1-01 51VID Final.cgm Electronic File: 113-081-1-01 5TVDSS Final.ogm Electronic File: 113-081-1-01 2MD Final.pdf Electronic File: 1D-081-1-01 SMD Final.pdf Electronic File: 1D-081-1-01 5TVDSS Final.pdf Electronic File: 1D-081-1-01 - EOW - NAD27.pdf Electronic File: 10-081-1-01 - EOW - NAD27.txt Electronic File: 1D-081-1-01 Final Surveys TD 9480.csv Electronic File: 1D-081-1-01 Final Surveys TO 9480.xlsx Electronic File: 1D-08LI.01 Survey Listing.bd Electronic File: 1D -08L1-01 Surveys.txt Electronic File: 1 D -08L1- 01 _25_tapescan_BHI _CTK.txt Electronic File: 1 D -08L1- 01 _5_tapesca n_B H I_CT K. txt Electronic File: 1 D-081-1-01_output.tap Electronic File: 1D-08Li-01 2MD Final.tif Electronic File: 1D-08Li-01 5MD Final.tif Electronic File: 1D-081-1-01 5TVDSS Final.tif AOGCC Pagel of'}, Monday, April 15, 2019 DATA SUBMITTAL COMPLIANCE REPORT 4/15/2019 Permit to Drill 2181730 Well Name/No. KUPARUK RIV UNIT 113-081-1-01 Operator CONOCOPHILLIPS ALASKA, INC. API No. 50-029-20266-61-00 MD 9480 TVD 6484 Completion Date 1/10/2019 Completion Status 1 -OIL Current Status 1-0I1- UIC No Log C 30353 Log Header Scans 0 0 Mechanical Integrity Test Information Y / NA 2181730 KUPARUK RIV UNIT 1D-OSL1-01 LOG Geologic Markers/Tops YQ Daily Operations Summary O Cuttings Samples Y / INA I Laboratory Analyses Y N lJ COMPLIANCE HISTORY HEADERS ED C 30403 Digital Data 2/26/2019 Electronic File: 1D-081-1-01 -EOW-NAD27.pdf ED C 30403 Digital Data Description 2/26/2019 Electronic File: ID -081-1-01 - EOW - NAD27.t# ED C 30403 Digital Data 2/26/2019 Electronic File: 1 D-081-1-01 - EOW - NAD83.pdf ED C 30403 Digital Data 2/26/2019 Electronic File: 1 D-081-1-01 - EOW - NAD83.txt Log C 30403 Log Header Scans 0 0 2181730 KUPARUK RIV UNIT 1D-081-1-01 LOG HEADERS Well Cores/Samples Information: Sample Interval Set Name Start Stop Sent Received Number Comments INFORMATION RECEIVED Completion Report /� Directional / Inclination Data I' Y) Mud Logs, Image Files, Digital Data Y /NA 1 Core Chips YA Production Test InformatioreY / NA Mechanical Integrity Test Information Y / NA Composite Logs, Image, Data Files Core Photographs Y /9 A Geologic Markers/Tops YQ Daily Operations Summary O Cuttings Samples Y / INA I Laboratory Analyses Y N lJ COMPLIANCE HISTORY Completion Date: 1/10/2019 Release Date: 12/262018 Description Date Comments Comments Compliance Reviewer AOacc ate: Monday, April 15, 2019 BAF IGHES BAT GEcompany Date: February 21, 2019 Abby Bell AOGCC 333 West 7th Ave, Suite 100 Anchorage, Alaska 99501 218173 30403 Letter of Transmittal Michael Soper Baker Hughes, a GE Company 795 East 941h Avenue Anchorage, Alaska 99515 Please find enclosed the directional survey data for the following well(s): 1D-081-1 1D-081-1-01 RECEIVED FEB 2 6 2019 AOGCC (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.SoperC@BakerHughes.com ConocoPhillips ConocoPhillips (Alaska) Inc. -Kupl Kuparuk River Unit Kuparuk 1D Pad 1D -08L1-01 50-029-20266-61 Baker Hughes INTEQ Definitive Survey Report 05 February, 2019 2101 7 30403 BAd<ER UGHES a GE company Project Kuparuk River Unit, North Slope Alaska, United States S tUCaRIiFS Well 1D-08 1 D-08 @ 108.00usft ; 1D-08 @ 108.00usft True Minimum Curvature EDT 14 Alaska Production p 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 Well ConocoPhillips ConocoPhillips Definitive Survey Report Company: ConocoPhillips (Alaska) Inc. -Kupt Local Coordinate Reference: Project: Kuparuk River Unit TVD Reference: Site: Kuparuk 1D Pad MD Reference: Well: 1 D-08 North Reference: Wellbore: 1 D-0811-01 Survey Calculation Method: Design: 1 D-0811-01 Database: Project Kuparuk River Unit, North Slope Alaska, United States S tUCaRIiFS Well 1D-08 1 D-08 @ 108.00usft ; 1D-08 @ 108.00usft True Minimum Curvature EDT 14 Alaska Production p 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 Well 1D-08 Well Position +N/ -S 0.00 usft Northing: 5,959,064.00usft +E/ -W 0.00 usft Easting: 560,490.00usft Position Uncertainty 0.00 usft Wellhead Elevation: usft Latitude: Longitude: Ground Level: 70" 17' 55.408 N 149° 30'36.452 W 0.00 usft Wellbore 1D-081-1-01 Magnetics Model Name Sample Date Declination Dip Angle Field Strength I°I I°I (nT) BGGM2018 3/1/2019 16.75 80.86 57,424 Design 1D-0811-01-- -- c ... -• •. hR+%12 e- _ P _ ..'-i[L � .. - A'tr W G4<5e. n Rw'Y31d".>s WY -@n �s ... �-. r n .- c« .. e. t A mn r[> y Audit Notes: Version: 1.0 Phase: ACTUAL Tie On Depth. 6,466.75 /ertical Section: Depth From (TVD) +NI -S +E/ -W Direction (usft) (usft) (usft) (') 108.00 0.00 0.00 45.00 Survey Program u^. Date m. ,... _. From To Survey Survey (usft) (usft) Survey (Wellbore) Tool Name Description Start Date End Date 200.00 6,30000 Gyro (1D-08) GYD-CT-CMS Gyrodata contcasing m/s 3/24/2000 6,396.00 6,466.75 1D-08LI MWD -INC (I D -08L1) MWD-INC_ONLY MWD-INC—ONLY—FILLER 1/1/2019 1/1/2019 6474.00 6,505.10 1D -08L1-01 MWD-INC(11D-0811-01) MWD -INC ONLY MWDdNC_ONLY_FILLER 1/7/2019 1/7/2019 6,534.64 9,444.01 1D -08L1-01 MWD(1D-081-1-01) MWD MWD - Standard 1/8/2019 1/8/2019 2/5/2019 2: 07: 36PM Page 2 COMPASS 5000.14 Build 85D ConocoPhillips Company: ConocoPhillips (Alaska) Inc Kupt Project: Kuparuk River Unit Site: Kuparuk 1D Pad Well: 1D-08 Wellbore: 1D-0811-01 Design: 1D-0811-01 ConocoPhillipsis Definitive Survey Report Local Coordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Database: Ht� Well 1D-08 1 D-08 Q 108.00usft t 1D-08 @ 108.00usft f True s' Minimum Curvature 1 EDT 14 Alaska Production F ,. Survey 4 Map Map Vertical , MD Inc Azi TVD TVDSS -NI-S +El -W Northing Eating DLS Section Survey Tool Name Annotation (usH) (°) (°) (usH (usH) (usH) (usft) (ft) () (H) (°1100') (H) 6,466.75 17.08 168.57 6,464.45 6,356.45 -54,56 15.72 5,959,00958 560,506.16 31.09 -2746 MWD -INC _ONLY (2) TIP 6,474.00 III 20.49 168.39 6,471.31 6,363.31 -56.84 16.19 5,959,007.29 560,506.64 4704 -28.75 MWD -INC _ONLY (3) KOP 6,505.10 29.08 143.79 6,499.59 6,391.59 -68.33 21.77 5,958,995.86 560,512.32 42.64 -32.92 MWD-INC_ONLY (3) Interpolated Azimuth 6,534.64 42.98 134.82 6,523.44 6,415.44 -81.29 33.22 5,958,982.99 560,523.87 50.22 .33.99 MWD (4) 6,564.61 55.47 131.78 6,542.98 6.434.98 -96.78 49.74 5,958,967.64 560,540.51 42.37 -33.26 MWD (4) 6,594.51 66.17 131.56 6,557.53 6,449.53 -114.11 69.21 5,958,950.47 560,560.12 35.79 -31.74 MWD (4) } 6,625.01 78.56 130.42 6,566.76 6,458.76 -133.13 91.12 5,958,931.62 560,582.18 40.78 -29.71 MWD (4) 6,650.22 90.06 130.67 6,569.25 6,461.25 -149.41 110.15 5,958,915.50 560,601.33 45.63 -27.76 MWD (4) 6,679.38 101.09 129.61 6,566.42 6,458.42 -168.09 132.30 5,958,897.00 560,623.63 38.00 -25.31 MWD (4) 6,709.98 104.75 117.12 6,559.56 6,451.56 -184.47 157.13 5,958,880.82 560,648.60 41.53 -19.33 MWD (4) i 6,740.09 102.42 103.43 6,552.45 6,444.45 -194.57 184.52 5,958,870.94 560,676.06 44.86 .7.11 MWD (4) 6,770.48 101.78 91.73 6,546.06 6,438.06 -198.48 213.92 5,958,867.27 560,705.49 3770 10.92 MWD (4) t 6,800.04 100.24 79.17 6,540.39 6,432.39 .196.17 242.78 5,956,869.80 560,734.33 42.03 32.96 MWD (4) 6,827.08 100.37 67.92 6,535.54 6,427.54 .188.65 268.25 5,958,877.53 560,759.74 40.93 56.29 MWD (4) 6,856.57 99.90 57.41 6,530.34 6,422.34 -175.34 294.00 5,958,891.05 560,785.37 35.12 83.91 MWD (4) 6,886.35 99.62 55.67 6,525.29 6,417.29 -159.16 318.48 5,958,907.43 560,809.72 5.83 112.66 MWD (4) E 6,916.56 99.93 54.29 6,520.16 6,412.16 -142.08 342.87 5,958,924.70 560,833.96 4.62 141.98 MWD (4) -� 6,946.07 99.71 52.64 6,515.13 6,407.13 -124.77 366.23 5,958,942.20 560,857.18 5.56 170.74 MWD (4) 6,976.80 100.21 51.59 6,509.81 6,401.81 -106.18 390.12 5,958,960.97 560,880.92 3.74 200.77 MWD (4) 7,007.23 99.22 49.97 6,504.68 6,396.68 -87.22 413.35 5,958,980.12 560,904.00 6.17 230.61 MWD (4) 7,036.74 99.21 51.90 6,499.95 6,391.95 -68.86 435.97 5,958,998.66 560,926.46 6.46 259.58 MWD (4) 7,066.92 99.71 53.83 6,494.99 6,386.99 -50.89 459.70 5,959,016.82 560,950.05 6.52 289.07 MWD (4) 7,097.41 99.80 55.91 6,489.82 6,381.82 .33.60 484.27 5,959,034.31 560,97448 6.73 318.68 MIND (4) 7,127.89 99.65 57.80 6.484.67 6,376.67 -17.17 509.42 5,959,050.93 560,999.50 6.13 348.07 MWD (4) 7,156.74 99.44 60.10 6,479.89 6,371.89 -2.50 533.80 5,959,065.80 561,023.75 7.90 375.68 MWD (4) 7,186.44 99.02 62.50 6,475.12 6,367.12 11.58 559.51 5,959,080.08 561,049.34 8.10 403.82 MWD (4) 7,217.47 99.00 62.92 6,470.26 6,362.27 2563 586.75 - 5,959,094.35 561,076.46 1.34 433.01 MWD (4) 7,247.55 98.29 60.87 6,465.74 6,357.74 39.64 612.97 5,959,10857 561102.58 7.14 461.47 MWD (4) 7,27840 95.51 60.85 6462.04 6.354.04 54.55 639.72 5,959,12369 561129.20 9.01 490.92 MWD (4) 1 7,306.75 94.18 6046 6459.64 6,351.64 68.39 66435 5,959,13773 561153.71 4.89 518.12 MWD (4) 2/52019 2:07:36PM Page 3 COMPASS 5000.14 Build 85D ConocoPhillips Company: ConocoPhillips (Alaska) Inc. -Kupl Project: Kuparuk River Unit Site: Kuparuk 1D Pad Well: 1 D-08 Wellbore: 1 D-08 L1-01 Design: 1 D-0811-01 Survey ConocoPhillips Definitive Survey Report Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Database: Well 1D-08 1 D-08 @ 108.00usft 1 D-08 @ 108.00usft True Minimum Curvature EDT 14 Alaska Production 21WO19 2:07:36PM Page 4 Vertical DLS Section Survey Tool Name Annotation ('1100'1 (ft) 8.02 548.01 MWD (4) 12.04 Map Map MD Inc Azi TVD TVDSS +Nl-S +El -W Northing Easting (usft) V) (1) (usft) (usft) (usft) (usft) (ft) (ft) 7,337.70 92.18 58.99 6,457.93 6,349.93 83.97 691.03 5,959,153.52 561,180.27 7,366.27 90.55 55.96 6,457.25 6,349.25 99.33 715.11 5,959,169.07 561,204.22 7,396.44 90.65 54.54 6,456.93 6,348.93 116.52 739.90 5,959,186.46 561,228.86 7,427.73 90.71 52.05 6,456.56 6,348.56 135.22 764.98 5,959,205.36 561,253.79 7,456.87 91.07 48.97 6,456.11 6,348.11 153.75 787.46 5,959,224.07 561,276.12 7,487.26 93.35 48.50 6,454.93 6,346.93 173.78 810.29 5,959,244.27 561,298.78 7,518.31 93.19 46.41 6,453.16 6,345.16 194.73 833.12 5,959,265.42 561,321.45 7,548.24 92.33 44.53 6,451.72 6,343.72 215.70 854.43 5,959,286.55 561,342.59 7,577.78 91.26 42.23 6,450.80 6,342.80 237.16 874.71 5,959,308.17 561,362.69 7,608.64 87.05 36.79 6.451.25 6,343.25 260.95 894.33 5,959,332.11 561,382.12 7,637.35 87.91 35.65 6,452.51 6,344.51 284.09 911.28 5,959,355.39 561,398.88 7,667.91 87.39 36.13 6,453.77 6,345.77 308.82 929.18 5,959,380.26 561,416.57 7,696.55 90.34 39.37 6,454.33 6,346.33 331.46 946.71 5,959,403.04 561,433.92 7,728.95 88.68 40.91 6,454.61 6,346.61 356.23 967.59 5,959,427.97 561,454.60 7,762.91 89.85 43.27 6,455.05 6,347.05 381.42 990.35 5,959,453.35 561,477.15 7,788.79 91.20 46.47 6,454.81 6,346.81 399.76 1,008.61 5,959,471.83 561,495.26 7,811.31 91.07 48.72 6,454.36 6,346.36 414.94 1,025.23 5,959,487.14 561,511.76 7,847.94 91.26 51.29 6,453.62 6,34562 43848 1,053.28 5,959,510.90 561,539.62 7,877.21 87.69 51.02 6,453.89 6,345.89 456.83 1,076.08 5,959,529.44 561,562.26 7,902.39 87.70 52.79 6,454.90 6,346.90 472.36 1,095.88 5,959,545.12 561,581.93 7,932.96 88.25 55.13 6,455.98 6,347.98 490.33 1,120.58 5,959,563.29 561,606.49 7,963.67 87.73 54.70 6,457.06 6,349.06 507.97 1,145.69 5,959,581.13 561.631.46 7,993.41 87.73 52.45 6,458.23 6,350.23 525.61 1,169.60 5,959,598.96 561,655.22 8,021.65 89.94 51.96 6,458.81 6,350.81 542.92 1,191.91 5,959,616.44 561,677.39 8,047.73 89.08 48.37 6,459.03 6,351.03 559.62 1,211.93 5,959,633.30 561,697.27 8,076.95 88.71 46.02 6,459.60 6,351.60 579.47 1,233.37 5,959.653.32 561,718.54 8,108.43 88.19 44.22 6,460.45 6,352.45 601.67 1,255.66 5,959,675.70 561,740.66 8,137.70 87.61 43.99 6,461.52 6,353.52 622.68 1,276.02 5,959,696.87 561,760.84 8,167.64 86.87 44.46 6,462.96 6,354.96 644.11 1,296.88 5,959,718.46 561,781.53 8 1970 85.42 4545 6,464.94 6,35694 664.86 1.317.60 5.959,739.38 561.802.08 8,227.49 8397 4509 6,467.75 6,359.75 686.20 1339.14 5,959,760.89 561,823.45 21WO19 2:07:36PM Page 4 Vertical DLS Section Survey Tool Name Annotation ('1100'1 �ER f u�Es COMPASS 5000.14 Build 85D (ft) 8.02 548.01 MWD (4) 12.04 575.89 MWD (4) 4.72 605.58 MWD (4) 7.96 636.54 MWD (4) 10.64 665.54 MWD (4) 7.66 695.84 MWD (4) 6.74 726.81 MWD (4) 6.90 756.70 MWD (4) 8.58 786.21 MWD(4) 22.29 816.91 MWD (4) 4.97 845.25 MWD (4) 2.31 875.40 MWD (4) 15.30 903.80 MWD (4) 6.99 936.08 MWD (4) 7.76 969.99 MWD (4) 13.42 995.87 MWD (4) 10.01 1,018.36 MWD (4) 7.03 1,054.84 MWD (4) 12.23 1,083.93 MWD (4) 7.02 1,108.91 MAID (4) 7.86 1,139.08 MWD (4) 2.20 1,169.32 MWD(4) 7.56 1,198.70 MWD (4) 8.02 1,226.71 MWD (4) 14.15 1,252.68 MWD (4) 8.14 1,281.87 MWD (4) 5.95 1,313.33 MWD (4) 2.13 1,342.58 MWD (4) 2.93 1,372.48 MWD (4) 5.97 1,401.82 MWD (4) 4.91 1,432.13 MWD (4) �ER f u�Es COMPASS 5000.14 Build 85D ConocoPhillips BArR ConocoPhillips Definitive Survey Report Company: Project: Site: Well: Wellbore: Design: Survey ConocoPhillips (Alaska) Inc. -Kupl Kuparuk River Unit Local Co-ordinate Reference: TVD Reference: Well 1 D-08 1 D-08 @ 108.00usft Kuparuk 1D Pad MD Reference: 1D-08 @ 108.00usft p 1D-08 North Reference: True e 11D-0811-01 Survey Calculation Method: Minimum Curvature 11D-0811-01 Database: EDT 14 Alaska Production MD Inc e 2/5/2019 2'07:36PM Page 5 Annotation -. COMPASS 5000.14 Build 65D Map Map Vertical MD Inc An TVD TVDSS +N1 -S +El -W Northing Easting DLS Section Survey Tool Name (usft) (1) V) (usft) (usft) (usft) (usft) fel (ft) ("1100') (R) 8,257.45 82.10 45.00 6,471.39 6,363.39 707.21 1360.19 5,959,78207 561,844.32 625 1,461.87 MWD (4) 8.287.18 83.66 44.28 6,475.07 6,367.07 728.20 1,380.91 5,959,803.22 561,864.88 5.77 1,491.37 MWD (4) 8,316.97 86.07 43.96 6,477.74 6,369.74 749.50 1,401.57 5,959,824.69 561.885.36 8.16 1,521.04 MWD (4) 8,347.52 88.90 44.79 6,479.08 6,371.08 771.31 1,422.91 5,959,846.67 561,906.52 9.65 1,551.55 MWD (4) 8,378.01 91.32 44.94 6,479.02 6,371.02 792.92 1,444.42 5,959,868.45 561,927.85 7.95 1,582.04 MWD (4) 8,407.05 94.27 43.94 6,477.60 6,369.60 813.63 1,464.72 5,959,889.31 561,947.99 10.72 1,611.04 MIND (4) 8,436.17 95.32 43.15 6,475.17 6.367.17 834.66 1,484.71 5,959,910.51 561,967.81 4.51 1,640.05 MWD (4) 8,467.83 97.20 42.34 6,471.72 6,363.72 857.77 1,506.07 5,959,933.78 561,988.98 6.46 1,671.49 MIND (4) 8,497.02 98.50 40.87 6,467.73 6,359.73 879.39 1,525.27 5,959,955.56 562,008.00 6.69 1,700.36 MWD (4) 8,526.92 97.88 39.55 6,463.47 6,355.47 901.99 1,544.38 5,959,978.31 562,026.92 4.84 1,729.85 MIND (4) 8,556.43 96.64 38.26 6,459.74 6,351.74 924.77 1,562.76 - 5,960,001.23 562,045.12 6.04 1,758.95 MWD (4) 8,586.78 97.29 36.85 6,456.06 6,348.06 948.66 1,581.13 5,960,025.26 562,063.29 5.08 1,788.82 MWD (4) 8,618.39 97.08 34.97 6,452.11 6,344.11 974.06 1,599.52 5,960,050.80 562,081.47 5.94 1,819.79 MWD (4) 8,650.43 94.33 32.60 6,448.92 6,340.92 1,000.55 1,617.24 5,960,077.44 562,098.98 11.31 1,851.06 MWD(4) 8,677.75 91.81 29.10 6,447.46 6,339.46 1,023.97 1,631.23 5,960,100.96 562,112.78 15.77 1,877.50 MWD (4) 8,707.49 90.15 26.64 6,446.95 6,338.95 1,050.25 1,645.13 5,960,127.36 562,126.46 9.98 1,905.92 MWD (4) 8,738.04 87.57 22.04 6,447.56 6,339.56 1,078.07 1,657.71 5,960,155.27 562,138.82 17.26 1,934.49 MWD (4) 8,767.61 86.29 19.30 6,449.14 6,341.14 1,105.69 1,668.13 5,960,182.98 562,149.02 10.22 1,961.39 MWD (4) 8,797.69 85.82 17.05 6,451.21 6,343.21 1,134.20 1.677.49 5.960,211.56 562,158,15 7.62 1,988.17 MWD (4) 8,827.81 85.39 15.02 6,453.52 6,345.52 1,163.06 1,685.79 5,960,240.48 562,166.21 6.87 2,014.44 MWD (4) 8,858.43 84.47 12.41 6,456.23 6,348.23 1,192.69 1,693.02 5,960,270.16 562,173.20 9.01 2,040.50 MWD (4) 8,886.86 85.20 9.50 6,458.79 6,350.79 1,220.49 1,698.40 5,960,298.00 562,178.36 10.51 2,063.96 MWD (4) 8,916.87 87.51 8.25 6.460+69 6,352.69 1,250.07 1,703.02 5,960,327.62 662,182.74 8.75 2,088.15 MWD (4) 8,947.30 87.27 4.19 6,462.08 6,354.08 1,280.29 1,706.31 5,960,357.86 562,185.79 13.35 2,111.84 MIND (4) 8,976.67 89.45 4.05 6,462.92 6,354.92 1,309.57 1,708.42 5,960,387.15 562.187.66 7.44 2,134.04 MWD (4) 9,007.35 88.31 1.33 6,463.52 6,355.52 1,340.20 1,709.86 5,960,417.79 562,188.85 9.61 2,156.72 MIND (4) 9,037.80 89.17 0.13 6,464.19 6,356.19 1,370.64 1,710.25 5,960,448.23 562,189.00 4.85 2,178.52 MIND (4) 9,067.15 89.17 358.26 6,464.61 6,356.61 1,399.99 1,709.84 5,960,477.57 562,188.35 6.37 2,198.98 MIND (4) 9,097.39 86.44 355.77 6,465.77 6,357.77 1,430.16 1,708.26 5,960,507.72 562,186.53 12.21 2,219.20 MWD (4) 9,126.37 85.88 353.23 6,467.71 6,359.71 1,458.94 1,705.49 5,960,536.48 562,183.53 8.96 2,237.59 MWD (4) 9.156.17 87.69 353.42 6,469.39 6,361.39 1,488.49 1,702.03 5,960,566.00 562,179.84 6.11 2,256.04 MIND (4) 2/5/2019 2'07:36PM Page 5 Annotation -. COMPASS 5000.14 Build 65D ConocoPhillips a ConocoPhillips Definitive Survey Report rR �HEs Company: ConocoPhillips (Alaska) Inc. -Kupl Project: Kuparuk River Unit Site: Kuparuk 1 D Pad Well: 1 D-08 Wellbore: 1 D-0811-01 Design: 1D-0811-01 Survey Local Coordinate Reference: Well 10-08 TVD Reference: 1D-08 @ 108.00usft MD Reference: 1D-08 @ 108.00usft North Reference: True Survey Calculation Method: Minimum Curvature Database: EDT 14 Alaska Production Map Vertical Easting DLS Section Survey Tool Name Annotation (8) (-/100') (ft) 562,176.77 10.56 2,276.29 MWD (4) 562,175.56 12.80 2.296.73 MWD (4) 562,175.37 6.34 2,317.49 MWD (4) 562,175.47 8.12 2,338.53 MWD (4) 562,176.45 10.22 2,361.01 MWD (4) 562,178.44 7.74 2,383.84 MWD (4) 562,180.91 8.51 2,406.52 MWD (4) i 562,184.73 17.23 2,430.66 MWD (4) 562,190.10 7.40 2,455.28 MWD (4) 582,193.51 8.93 2,469.48 MWD (4) 562,200.85 0.00 2,499.65 PROJECTED to TD 2152019 2:07:36PM Page 6 COMPASS 5000.14 Build 85D Map MD Inc Azi TVD TVDSS +N/ -S +E/ -W Northing (usft) (1 (') (usft) (usft) (usft) (usft) (ft) 9,187.77 8929 356.35 6,470.22 6,362.22 151995 1699.22 5,960,59]43 9,217.65 90.55 359.96 6,470.26 6,362.26 1,549.80 1,698.26 5,960,627.28 9,246.97 88.71 0.22 6,470.45 6,362.45 1,579.12 1.698.30 5,960,656.59 9,276.42 86.47 1.06 6,471.69 6,363.69 1,608.54 1,698.63 5,960,686.01 9,307.05 88.37 3.55 6,473.07 6,365.07 1,639.11 1,699.86 5,960,716.59 9,337.21 86.50 4.95 6,474.42 6,366.42 1,669.16 1,702.09 5,960,746.64 9,366.81 84.06 5.58 6,476.85 6,368.85 1,698.53 1,704.80 5,960,776.03 9,397.26 87.21 9.79 6,479.17 6,371.17 1,726.61 1,708.86 5,960,806.14 9,427.05 86.71 11.94 6,480.75 6,372.75 1,757.82 1,714.47 5,960,835.40 9,444.01 85.23 12.26 6,481.94 6,373.94 1,774.36 1,718.02 5,960,851.96 9,480.00 85.23 12.26 6,484.93 6,376.93 1,809.41 1,725.63 5,960,887.07 Map Vertical Easting DLS Section Survey Tool Name Annotation (8) (-/100') (ft) 562,176.77 10.56 2,276.29 MWD (4) 562,175.56 12.80 2.296.73 MWD (4) 562,175.37 6.34 2,317.49 MWD (4) 562,175.47 8.12 2,338.53 MWD (4) 562,176.45 10.22 2,361.01 MWD (4) 562,178.44 7.74 2,383.84 MWD (4) 562,180.91 8.51 2,406.52 MWD (4) i 562,184.73 17.23 2,430.66 MWD (4) 562,190.10 7.40 2,455.28 MWD (4) 582,193.51 8.93 2,469.48 MWD (4) 562,200.85 0.00 2,499.65 PROJECTED to TD 2152019 2:07:36PM Page 6 COMPASS 5000.14 Build 85D REGEWED STATE OF ALASKA FEB 1 1 2019 ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT ANQCWC 1a. Well Status: OIIE] Gas[] SPLUG ❑ Other ❑ Abandoned ❑ Suspended ❑ 20AAC 25.105 20 C 25.110 GINJ ❑ WINJ ❑ WAG❑ WDSPL ❑ No. of Completions: ib. Well Class: Development 0 Exploratory ❑ Service ❑ Stratigraphic Test ❑ 2. Operator Name: ConocoPhillips Alaska, Inc. 6. Date Comp., Susp., or Abend.: 1/10/2019 14. Permit to Drill Number / Sundry: 218-173 r 3. Address: P.O. Box 100360 Anchorage, AK 99510-0360 7. Date Spudded: 1/6/2019 15. API Number: 50-029-20266-61-00 ' 4a. Location of Well (Governmental Section): Surface: 600' FNL, 602' FEL, Sec 23, TllN, R10E, UM Top of Productive Interval: 658' FNL, 587' FEL, Sec 23, T11 N, R10E, UM Total Depth: 1208' FSL, 1125' FWL, Sec 13, T11N, R10E, UM t 8. Date TO Reached: 1/9/2019 16. Well Name and Number: KRU 1D-081-1.01 ' 9. Ref Elevations: KBA08 - 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- 560506 y- 5959007 Zone- 4 Total Depth: x- 562201 y- 5960887 Zone- 4 11. Total Depth MD/TVD: 948016484 • 19. DNR Approval Number: LONS 79.016 12. SSSV Depth MDrrVD: N/A 20. Thickness of Permafrost MD/TVD: 1630/1630 5. Directional or Inclination Survey: Yes ❑ (attached) No ❑ Submit electronic and printed information per 20 AAC 25.050 13. Water Depth, if Offshore: N/A (ft MSL) 21. Re-drill/Lateral Top Window MDrrVD: 6474/6471 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 MHOLE SIZE CEMENTING RECORD D SETTING DEPTH TVD AMOUNT CASING FT TOP BOTTOM TOP BOTTOM PULLED 16 65 H-40 23 75 23 75 30 475 sx Arcticeet 11 cmt 103/4 45.5 K-55 23 2230 23 2230 133/4 2400 sx Permafrost cmt 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 6320 9480 6318 6485 3 Slotted Liner 24. Open to production or injection? Yes 0 No ❑ If Yes, list each interval open (MDrrVD of Top and Bottom; Perforation Size and Number; Date Panic): Slotted Liner @: COMPLETION 6332-9480 MD and 6331-6485 TVD ... 1/912019 PA rE t I, )cltn VE. flE.D Kt�X 25. TUBING RECORD SIZE DEPTH SET (MD) PACKER SET (MD/rVD) 3 112 6338 6294/6292 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. Was hydraulic fracturing used during completion? Yes ❑ No Q Per 20 AAC 25.283 (i)(2) attach electronic and printed information DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED 27, PRODUCTION TEST Date First Production: 1/28/2019 Method of Operation (Flowing, gas lift, etc.): GAS LIFT Date of Test: 1/31/2019 Hours Tested: 1 14.8 Production for Test Period Oil -Bbl: 1058 Gas -MCF: 3702 Water -Bbl: 1 2770 IChoke Size: 1 176 Gas -Oil Ratio: 3501 Flow Tubing Press. 250psi JCasinci Press: I 12 3 si Calculated 24 -Hour Rate Oil -Bbl: 1715 Gas -MCF: 6003 Water -Bbl: 1 4492 Oil Gravity -API (corr): 1 24 den Form 10-407 Revised 5/2017 VTI 711411 ` 141 9 CONTINUED ON PAGE 2 RBDMS tk FEB 13 2013��miiitt ORIGGI IARL only -1 28. CORE DATA Conventional Corals): Yes ❑ No ❑� Sidewall Cores: Yes ❑ No 0 If Yes, list formations and intervals cored (MD/TVD, From/ro), 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 ❑� Surface If yes, list intervals and formations tested, briefly summarizing test results. Permafrost - Top 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 At TO 9480 6484 Formation at total de the 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, productionnaleontoloaical report, I r 20 AAC 25 070, 32. 1 hereby certify that the foregoing is true and corrqclto the best of my knowledge. Authorized Name: r / 5T79'0eZ-J`—' Contact Name: William Lon Authorized Title:n eef Gj`p ,p/2tz-rpoC Contact Email: William.R.Lon co .com Authorized Contact Phone: 263-4372 Signature: Date: 2-41t INSTRUCTIONS General: This form and the required attachments provide a complete and concise record for each well drilled in Alaska. Submit a well schematic diagram with each 10407 well completion report and 10104 well sundry report when the downhole well design is changed. All laboratory analytical reports regarding samples or tests from a well must be submitted to the AOGCC, no matter when the analyses are conducted. Item 1a: Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Item 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 7D-08 Final CTD Completion 16" 659 H40 shoe 75' RKB 10-3/4" 45# K-55 shoe @ 223Y RKB C -sand pens 6384'-6472' 6479' - 6484' 7" 260 J-55 shoe @ 6669' RKB 31/2' TublM L-80 W IRT 312" I.amlin9 DS Nipple @ 493' RKB (2.875' ID) 312' Camw KBG MarMrels 0 2541', 378x. 46815335'. 5798', 6012' 5- Seal Bore Receptacle 44' bore 0 6118' RKB 610Cressover@6127RKB Camco DSL Ong Nipple@ 6175' RKB (to 2.813'7 Camw GLM Q 6227 RKB Baker GBH -22 Locator@ 6283' RKB Baker 8040 Seal Assembly @ 6269' RKB Baker FB -1 Pecker @ 6294' RKB Camw 0 Nipple @ 6328' (Mille4 Out - 2.80" ID) Baker W EG @ 6337- RKB UWahb:llJar,Ml9MRL) D-0BL3-01 TO @9480' MD Top of Liner @ 6320' MD KUP PROD WELLNAME 1D-08 WELLBORE 1D-08 ((��/r�a Wall Attribut I Max Anglg ) TD ConocoPhill(PS Held Name wMImre APury welsh ,es lua MDM. AIB re (We) Alaska.1 KUPAR UKRIVER UNIT 500292026600 PROD 89 2,10000 fi8B00 NIPPLE 1100 19/26/2011 LasIWG tone. varmre,l:ae4, PM Last Tag varuy wv+mtie tama0 Annolalbn--pre (.8) Era role wenWrc Lativi Last Tag: LMDTIEDTOOHGR 6,5100 122812018 iD-O8 Condijw RAI,GER n CCNDUCTORD O]So NIPPLE; tisg SURFACEIMu230.0 Dle LIFT I IAt° GASUFT sa GIS LIFT', 4BY.9 G9LEE aCs'5 CJ$uFT, e.TD93 GAS LIFT16.01V ECCATCRUtl SENLASSY.6,1051 PACKER:6.3w.J nE Bg rapaER KiL Ilsm ae,al.w, to laacsiD-OB SBE;& WY 6345 WOOD. D. eapPSTOCKe... IPER1;639s"..4720 FROVED384.0 IPERF, 6,4]D"Pubs 0 PwG6sw.o mERp.6Des ... D- IPER vpue6.852.0� is PRWUCTIM. MIA M.0 n Last Rev Reason Amours- End Dale Wounivrs Last MI By Rev Reason: Add milled out nipple 122019 iD-08 %r9usp Casing Strings Casing Descril OOlin) ID tin) TopIKKB) sel0ep[I, IXKBI 6e10epIM1 (NDI... WtlLen B... Glade Top Tbeaa CONDUCTOR 16 15.06 23.0 75.0 75.0 65.00 H40 WELDED Ceslnp Cewnption OD (in) ID pn) Top R11tB1 8M Oegh (M(e) set DeplM1 (NDL.. WNLen IL. Gmae Top Tnrca4 SURFACE 1014 939 22.8 22300 2,2294 45.50 K55 CaFlla Descrlplbn 00(in) III Top mus set Depabs l aN Demn RaDI... MLen p..Drg. Top Th,�M PRODUCTION ] 6.28 22.1 68690 6,86)5 28.00 J-55 BUTT CaDoscrllwsn moon) ID Bn) Tnpon.) set DelrgtXate BR DMn(. .MLen p._D,Me Top TM1rxtl TIE BACK LINER 51l2x 512 4.28 19.1 6,295.5 62940 15.50 1-80 BTCM 312 @ 6128.69 Liner Details NomimND Top Me) Top11VD)Iaae) Tople l('I Item Des Com Dnl 6J15-1 6,1083 147 SBR BTC PIN x PIN CASING SEAL BORE RE EPTACLE 4.000 6,1287 6,127.3 1.47 TOReducing 5" BTC Box 3-12" EUE Pin Moss over sub 2.992 STU1 6,132.7 146 TUBING !"X L -W EUE-Mod BM Tubing joint 2992 6.1750 ,738 1.46 NIPPLE CAMCODS'IANDING NIPPLE If T111320 2.812 6,186.4 6,04.9 1.45 TUBING 3.5"7 9.30, L-80 EUE-Mod 8N TuGng joins 2992 6,2270 6225.5 1.27 GAS LIFT CAMCO MMG GLM# 195AE07 2.920 6,2460 5244b 1.14 TUBING 3.5", 9.30, L-80 EUE-Mod Bra Tubing joint 2.992 6,2829 fi201.4 0.90 LOCATOR BAKER GERI LOCATOR SUB 2.990 6,2841 6282.6 0.89 PBR BAKER 80-0O SEAL ASSY wl 3-0 Space oa, 2.990 Tubing Strings TubinD OescNgan Shinq Ma.. Dlin) Top Odus Set 0epETm Sat De pM(TVD)L..mpord Grate IDP Delaw re TUBING WO 2014 312 299 16.4 6123.2 6.121.8 930 LBO IBT Completion Details Teemed Top Ind Nominal Top IM(BI DIKE) fl Ibm Dee Co. IDinj 16.5 154 065 HANGER FMC TUBING HANGER 2.910 492.9 4929 076 NIPPLE DS LANDING NIPPLE 2.675 6,11142 6,102.8 1.47 LOCATOR BAKER LOCATOR SUB 2992 6,105.1 6,103.6 1.47 SEALASSY BAKER 8040 SEALS WI 7' -FT SPACE OUT 2.990 iudn00eacnption Sleme Ma... ID (in i Top 0M81 Set DeptM1 @.. 9N DepM jN)1 L.. W1ItbX) Gratle TapCrnnection TUBING 312 299 62937 6,3380 8,336.5 920 NAO BUTT Completion Details Trp 0I Top Mq barest Topflut IRKB) (') ..a- Com Intel 62937 12922 082 PACKER BAKER'FB-1'PACKER 4.000 6296.2 6, .] 0.81 SBE BAKER SEAL BORE EXTENSION 4900 6,325.5 6,3248 I 0.78 NIPPLE CAMCO'D'NIPPLE (Milled Dutb2.80"1227118) 2.800 6,3373 635.9 I 0.78 JWLICU BAKER WIRELINE ENTRY GUIDE 2.992 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc) Toplrvo)" Ps 1op(XI(B) DIaB) (') Des onRUn Dale Mpq 6.d00.0 8,398.5 OA WHIPSTOCK NB HEW whipstock 112/2019 0000 6.550. 6,548.5 O.A PLUG a. "an ..use Plug 511411978 0000 perforations & Slots snq D ne Topmae) el Tolaae)D) BI BI I LRdMium Dela UM1o)M1X Type Co. 6364.08,382.5 6,4]05 -, 518/1978 4.0 IPERF i6472,01 64790D 6,4)7.5 8,082.5 C -2,10 -OB 5Ifl1197 4.0 IPERF 6,6360.0 6634.5 6,6395 A5,1D-00 51WI976 40 IPERFNIPPLE: 6644.0.0 6,642.5 6.650.5 A-5, ID418 6511978 1 40 IPERF Frac Summary SMrleme, Proppenl DaspnM 00) Pmppv,lln Foresdon Obi 78 72711978 stg# DaM Top DepM IIMe) Bhn laaBl UnkelFluMByetam Vol Oban(ab6 VOI8lmryleeq 1 7/2)/1978 6384.0 S% 0 Mandrel Inserts st ad N 1.VVD) Valve e TRO Run Tap Otl(B) (MB) Make Mosel Caere Sery Te. (Pont Be. Deb Com 1 2,541.4 2,5406 CAMCO i AS LIFT GLV 1224.0 1224)2018 29 3,786.3 3]852 CAMCO G 1 GASLIFT OV 0.0 12242018 2.9 $BTM0,000 3 4,688.3 4,687.1 CAMCO 1 MTUFT 00 121242018 29 5334.5 5,3333 CAMCD 1 GASLIFT DMY 0 0.0 12212018 28 5 5,798.3 5]970 CAMCD 1 GASLIFT DMY 0 0.0 3242014 2.9 6 6,011) KBG, 1GAS LIFT DMV DK -1A 0.000 0.03242010 2.9 ' Notes: General & Safety End pate I Automation 1212512002 NOTE: WAIVERED WELL: IA X OA COMMUNICATION 8/8/2010 NOTE. View Schematic wl Alaska Schema11C9.0 2/512019 NOTE. View Schematic wl Alaska Schematk 100 KUP PROD WELLNAME 1D-08 WELLBORE 1D -08L1 Conoco`Phillips Alaska. Irlc. IoaaLt alcthmll96:NZAM Last Tag VmtlulWmMc(xN=o A^^o1Xon DepthmSB) E^a 0. weuWr. Last MW By Last Targ 11D -08L1 Jenner Casing Strings NANGER:IaA— Laslnp DeuNplio^ OO lim SLOTTED LINER IT 2318 10 (p sap lNRBI Set Deja IMlBI aM D"S f1Vm 1.99 6,4792 8,912.0 6.3122 1000Len 11,lGrale 4.60 L-80 Top Th"d STL Liner Details D CONDUCTOR:Ab]SO Tpp INNR) I sop jND1(M0) I Tpp Incl pl Ihm Ces Lom li^ 6,4]92 6.4]62 22.95 Aluminum Liner Top Billel 1.920 1 JALLml BILLET I NIPPLE aS9 Frac Summary slan Da. vmpwm Deaipnw (le) PmppamMFormalion (let ]/21119]8 SMr Slan Dele T6707M MKI.) BIm MM) Link b Fluid System VDI Clean Meq Vol Slurry MM1 1 121/1918 6,384.0 6.4840 Notes: General & Safety End Dale I Annotalb^ 2/612019 j.UI1'. View SchemalicM Alaska Schematic 10.0 SURFACE: T1.9-3..0 GAS UmT: 3.5a1.a GAS LIFT: 3.. GAS UFT; S,SM.s GAS DFF: S.TMa GAS LIFT: 6.0117 LGCATSR,6.lW3 aEALA8S SIMM pe"a"s : B,AY.] TIE BALK LINEA S IS.a IR e 81 Y.BB, ta.td.%.5 ME: 6..3 NIPIRM: G.M5 WLEG: 6.. WMPSTGLK B..a PERF. 638a,b .`S0 FRAC', 6.. IPERF, 6.18.0 1140 PRODUCTION: T$. 1.6.800.0 UctTraO UNER LI:B4793-� e.slzp uperations Summary (with Timelog Depths) 1 D-08 110g: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Depth Start7me End Time our (m) Phase Op Cada Acllvib Code Time P -T -X Operation rtK8) Ertl Depth (M(13) 12131/2018 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 1213112018 1.20 MIRU MOVE RURD P Hook up truck to Sub Module, move 0.0 0.0 20:00 21:12 1 1 1 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 iD-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 1/112019 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 rig 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 test, 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 WHOBOP BOPE P Start full initial BOPE test. 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 1/112019 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 23:00 111/2019 1/2/2019 1.00 MIRU WHDBOP CTOP P Aftemp to bleed off well. Al gas. Line 0.0 0.0 23:00 00:00 up to bull head. Pump 70 BBIs seawater down well. Well on vac 1/2/2019 1/2/2019 0.50 MIRU WHOBOP PRTS P Pressure test both PDL's 0.0 0.0 00:00 00:30 1/2/2019 1/2x2019 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 112/2019 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 trait tool, M/U to coil and surface test. orient at surface to lest gyro 1/2/2019 112/2019 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 WHIP Page 1/10 Report Printed: 112112019 operations Summary (with Timelog Dupths) 1 D-08 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Depth Start'nme End Tlm Dia(hr) Phase Op Code Activity Cade Time P-T-x Operation (AKB) End Depth (MB) 1/2/2019 1/2/2019 0.20 PROD1 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 PROD1 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 CLOG P Log HRZ. for -11' correction 6,050.0 6,191.0 04:46 05:06 1/2/2019 11=019 0.10 PROD1 RPEQPT TRIP P PUH to catch GLM in CCL log 6,191.0 6,095.0 05:06 05:12 1/212019 1/212019 0.30 PROD1 RPEQPT DLOG P Log CCL 6095 to 6475 6,095.0 6,475.0 05:12 05:30 1/2/2019 1/2/2019 0.50 PROD1 RPEQPT CLOG P Comalate CCL Log, PUH 6,475.0 6,394.0 05:30 06:00 1122019 1/2/2019 0.20 PRODt RPEQPT TRIP P RBIH to set depth 6,394.0 6,405.0 06:00 06:12 12/2019 1212019 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 Surveys, 168.1°, 168.2°, and 167.8° 1/2/2019 1/212019 0.30 PROD1 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 12/2019 1.10 PROD1 RPEQPT TRIP P POOH, PJSM for BHA change 6,404.0 86.0 07:45 08:51 122019 1212019 0.30 PRODII 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 1/212019 0.30 PROD1 RPEQPT PULD P Unstab INJH, stand back 86.0 0.0 09:09 09:27 ColiTrak/GyroTrak tools. LD setting tools 1/2/2019 112/2019 0.50 PROD1 WHPST PULD P PU/MU milling BHAwith Weatherford 0.0 89.3 09:27 09:57 1.0 fixed bend motor. 112/2019 1122019 1.65 PROD1 WHPST TRIP P Tag up zero counters, RIH 89.3 6,140.0 09:57 11:36 1/212019 122019 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 122019 1.20 PROD1 WHPST TRIP P Continue IH, circulating 100 bbl High 6,206.0 6,380.0 11:48 13:00 Ys Pill (148 k LSRV) 1/22019 1/22019 0.30 PROD1 WHPST CIRC P Continue pumping High Vis Pill 6,380.0 - 6,380.0 13:00 13:18 1/212019 11212019 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' 1/212019 1/2/2019 0.75 PROD1 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 Inhofe to 6399.8' 1/2/2019 1/22019 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-9115 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 milling 1 foot for string reamer to ecil 1212019 1/2/2019 1.10 PROD1 WHPST MILL P Mill rathole to 6426, 1.85 BPM @ 6,403.0 6,426.0 20:48 21:54 3300 PSI FS, BHP=2937 1/2/2019 112/2019 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 1/22019 1/22019 0.30 PROD1 WHPST REAM P Ream down as drilled, 1.83 BPM'9 6,388.0 6,408.0 22:30 22:48 3237 PSI FS Page 2110 ReportPrinted: 1/21/2019 Operations Summary (with Timelog Depths) 1 D-08 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Sten Depth Start Tone End Tone Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (N(6) End Depth mKa) 1/2/2019 1/2/2019 0.20 PROD1 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 PRODt 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 PRODt WHPST REAM P Roll TF to as drilled. ream down. 6,399.0 6,412.0 23:12 23:36 Orient to 180 of as drilled. Take gyro survey to cor im toolface. Back ream up, PUW=32K 1/2/2019 1/212019 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 PROD1 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 113/2019 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 1/3/2019 1/3/2019 0.90 PROW WHPST TRIP P POOH for build section BHA#3 6,388.0 82.0 00:06 01:00 1/3/2019 1/3/2019 0.60 PROW 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 PIU BHA #3 with 2.4° AKO motor 0.0 75.0 01:36 02:18 113/2019 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 PROD1 DRILL DLOG P Log HRZ for-11.5' 6,130.0 6,167.0 03:36 03:48 1/32019 1/3/2019 0.10 PROD1 DRILL TRIP P Continue in well 6,167.0 6,374.0 03:48 03:54 1/3/2019 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 1/312019 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 1/32019 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 1132019 0.50 PROD1 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 1/3/2019 1/3/2019 0.20 PROW 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 1/32019 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-rerums 6,379.0 75.0 07:24 08:42 1/3/2019 1/312019 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 PROD1 DRILL PULD P Adjust AKO on motor from 2.40° to 0.0 0.0 09:00 09:42 2.46° 1/32019 1/3/2019 0.60 PROD1 DRILL PULD P PU/MU standard build section BHA #4 0.0 72.2 09:42 10:18 113/2019 1/3/2019 1.20 PROD1 DRILL TRIP P RIH 72.2 6,130.0 10:18 11:30 1/3/2019 1/3/2019 0.20 PROD1 DRILL DLOG P Log the HRZ correction of minus 11.5' 6,130.0 6,183.6 11:30 11:42 Page 3110 Report Printed: 1121/2019 Operations Summary (with Timelog Depths) 1 D-08 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log sten Depth start Time End Tama our(hr) Phase Op Code Acd*Code Time P -M Operation (WB) End Depth(WB) 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 11:54 113/2019 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 PROD1 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 1/312019 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 attempt higher build rale. 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 1/312019 0.20 PROD1 DRILL WPRT P TO 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 PROD1 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 peas, continue PUH 1/3/2019 1/312019 1.40 PROD1 DRILL TRIP P Open EDC, Continue POOH 6,379.0 82.0 16:36 18:00 1/3/2019 1/3/2019 0.70 PROD1 DRILL PULD P At surface, Flow check well, Dow 82.0 82.0 18:00 18:42 change out 113/2019 1/312019 0.50 PROD1 DRILL PULD P Unstab injector. Lay down motor, FVS, 82.0 0.0' 18:42 19:12 and bit 113/2019 1/3/2019 1.50 PRODt 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 11312019 1/3/2019 1.00 PRODt DRILL PULD P Dial motor to .5 and scribe. M/U BHA 0.0 76.2 20:42 21:42 #5 with agitator, USR, and Hycalog 3211 M -A2. Make up to coil and surface test 11312019 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' 1/312019 1/3/2019 0.20 PROW 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 PROW 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 PROD1 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 1/412019 1/4/2019 0.10 PROW DRILL WPRT P 6839', BHA wiper, PUW=33K 6,839.0 6,839.01 01:12 01:18 1/4/2019 1/4/2019 0.30 PROW DRILL DRLG P 6639', 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. DO recommends tripping for inspection 11412019 1/4/2019 0.20 PROD1 DRILL PULD T POOH, At surface, Flow check well 5,455.0 84.5 02:54 03:06 Page 4110 Report Printed: 1/21/2019 e Gperations Summary (with Timelog Depths) 1 D-08 • Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log ft De Start Depth start Tune End Tyne our (o phase Op Cotle Activitytle Tune P -T -X O peretlon EM Depth (IU(B) 1/4/2019 1/4/2019 0.60 PRODI DRILL PULD T Unstab injector, Back off quick 84.5 0.0 03:06 03:42 connect. Inspect BHA. Motor OK. Bit out 1-1. Put motor on bench and increase AKO setting. Double check all scribes. Tool out on scribe 1/412019 1/412019 0.60 PRODI DRILL PULD T PIU 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 1/4/2019 1.00 PROD1 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 1/42019 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 JRBIH 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 1/412019 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 PRODI 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 PRODI DRILL WPRT P Wiper to the EOB 6,750', PUW 35 k 7,260.0 6,750.0 12:24 12:39 1/42019 1/4/2019 0.30 PRODI DRILL WPRT P Wiper back in hole, RIW 18 k 6,750.0 7,260.0 12:39 12:57 1/42019 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 1/42019 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 PROD1 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, ]A=O, OA=179 1/4/2019 1/4/2019 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 PRODI 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 1/412019 1/42019 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 1/412019 0.20 PROD1 DRILL WPRT P 7846, Stall, BHA Wiper, PUW=39K 7,846.0 7,846.0 19:24 19:36 1/412019 1/4/2019 2.50 PROD1 DRILL DRLG P 7846', 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 PRODI 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=1.9K WHP=326 1/5/2019 1/5/2019 0.10 PROD1 DRILL WPRT P Pull BHA wiper, PUW=37K 8,163.0 8,163.0 00:54 01:00 1 Page 5/10 Report Printed: 1/21/2019 Operations Summary (with Timelog Depths) 1 D-08 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Sten Depth Start Time End Time wr(M phase Op Code Activity Cade Time P -T -X Operafion (MIS) End Depth (1N(B) 1/5/2019 1/5/2019 1.70 PROD1 DRILL DRLG P 8163', D611 1.87 BPM @4079 PSI FS, 8,163.0 8,323.0 01:00 02:42 BHP=3358 1/5/2019 1/5/2019 0.10 PROD1 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 6323', 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 1/512019 1/5/2019 4.00 PROD1 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 FROM 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 FROM 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 1/5/2019 1.00 PROD1 DRILL WPRT P Wiper back in hole, RIW 24 k 6,465.0 8,825.0 09:48 10:48 1/512019 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, OA=180 1/512019 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 1/5/2019 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, WFI BHP=2,793, IA=O, OA=179 1/5/2019 1/5/2019 0.50 PROD1 DRILL WPRT P Town engineer called TD, pump TO 8,913.0 8,913.0 14:42 15:12 sweep 1/5/2019 1/5/2019 1.00 PROD1 DRILL WPRT P Wiper up hole to the window 6, 100' 8,913.0 6,130.0 15:12 16:12 1/5/2019 1/512019 0.30 PROM DRILL CLOG 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 PROM DRILL WPRT P RBIH 6,154.0 6,900.0 16:30 16:42 1/5/2019 1/5/2019 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 PROM DRILL WPRT P Perform static pressure survey, 6,379.8 6,379.8 16:54 17:12 6329.67 TVD Sesor, Annular P 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 PROD1 DRILL WPRT P RIH to confirm TD, Tight spos 6912, 6,379.8 8,912.0 17:12 18:36 7400, 7960, and 7973 1/5/2019 1/5/2019 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 PROM DRILL TRIP P Trip out pumping beaded liner running 8,912.0 86.0 19:00 21:06 pill 50 661s, Paint flags @ 6508 and 3878 1/5/2019 1/5/2019 0.50 FROM DRILL OWFF P At surface, Flow check well, PJSM 86.0 86.0 21:06 21:36 1/5/2019 1/5/2019 0.70 FROM DRILL PULD P Unstab injector, Lay down BHA#6on 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 1/5/2019 1/6/2019 1.00 COMPZI CASING PUTB P P/U BHA#7 with non Dred bullnore, 2 0.0 300.0 23:00 00:00 Jts blank liner, 78 Jts slotted 2 3/8" liner, 3.63' pup, and 9' liner top billet. Perform Kick while running liner after 6 joints in hole. 1/6/2019 1/6/2019 2.90 COMPZI CASING PUTB P Continue picking up L1 completion 300.0 2,432.8 00:00 02:54 Page 6110 Report Printed: 112112019 Operations Summary (with Timelog Depths) 1 D-08 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Depth StartTm EM Time our(hr) Phase Op Code Activity Code Tine P -T-% Operawn (IKB) EM Deplh(M) 116/2019 1/6/2019 0.80 COMPZI 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 lest. Change out pack offs and floats in UQC 1/6/2019 1/6/2019 2.00 COMPZI 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 1/612019 1/6/2019 1.00 COMPZI 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 COMPZI CASING TRIP P POOH 6,390.0 6,110.0 06:42 06:57 1/6/2019 1/6/2019 0.20 COMPZI CASING DLOG P Log HRZ correction of+2.5' 6,110.0 6,148.0 06:57 07:09 1/6/2019 1/6/2019 1.00 COMPZI CASING TRIP P Continue POOH 6,148.0 44.2 07:09 08:09 1/6/2019 1/6/2019 0.50 COMPZI 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 PROD2 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 1/6/2019 0.20 PROD2 STK DLOG P Log the HRZ correction of -10' 6,125.0 6,138.0 11:27 11:39 116/2019 1/6/2019 0.30 PROM STK TRIP P Continue IH, lag 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'@ !fph, 2.0'@ 2 fph, and 3.0'@ 3 fph, 1/6/2019 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 PROD2 DRILL DRLG P Drill ahead @ 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 1/6/2019 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, 6,576.0 6,717.0 16:36 21:00 Diff --527 psi, WHP=60, BHP=3,100, IA=O, OA=178, 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, BHA wiper, PUW=34. Raise 6,717.0 6,717.0 21:00 21:06 1 1 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 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 117/2019 0.50 PROD2 DRILL TRIP P Continue trip out of well 2,095.0 78.0 00:00 00:30 Page 7110 ReportPrinted: 112112019 Operations Summary (with Timelog Depths) 1 D-08 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Stan Time Eno Time Dw(nr) Phase Op Code netiviy Code Time P-TA Opemlbn start Depth (m(B) End Depth (ftKB) 117/2019 1/7/2019 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!7/2019 1.00 PROD2 DRILL PULD P P/U BHA#9 with.5'AKO motor, 0.0 80.3 01:06 02:06 Strider and HCC TX25207 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 1/7/2019 1/7/2019 0.10 PROD2 DRILL WPRT P Stall motor, PUW 35 k, restart 7,015.0 7,015.0 08:30 08:36 117/2019 177/2019 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 1/7/2019 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 117/2019 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 1/7/2019 1/7/2019 0.30 PROD2 DRILL WPRT P Wiper up hole, PUW 36 k 7,255.0 6,855.0 10:42 11:00 117/2019 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 1/7/2019 17712019 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, IA=O, OA=170 1/7/2019 1/7/2019 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 177/2019 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, IA=O, OA=179, stall motor 7,963' and 7,972' 117/2019 1/7/2019 0.70 PROD2 DRILL WPRT P Wiper up hole, PUW 33 k 8,050.0 6,130.0 21:06 21:48 117/2019 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 0.5' 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 1/7/2019 1/7/2019 0.10 PROD2 DRILL WPRT P BHA Wiper, PUW=39K 8,099.0 8,099.0 23:30 23:36 1/7/2019 1/812019 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=1.8K 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 00:00 02:48 1 1 IBHP=3256 Page 8110 ReportPrinted: 172112019 a Operations Summary (with Timelog Depths) 0 1 D-08 li Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Depth sled Time End Time Dur (hr) Phase Op Code Activit' Code Time P -T -x Operation (flKe) EM DePM(MBI 1/812019 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.BK 1/812019 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 PROM 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=I.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 10:06 118/2019 1/8/2019 1.70 PROD2 DRILL DRLG P 8850', Drill, 1.89 BPM Q 3540 PSI 8,850.0 9,036.0 10:06 11:48 FS, BHP=3322 1/812019 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 1/812019 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 6,140.0 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 1/812019 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.I K, BHP= 3356 psi, WHP = 192 psi, circ = 3732 psi 1/8/2019 1/9/2019 1.20 PROD2 DRILL DRLG P Drilling, CWT= 1.6K, WOB = 1.4K, 9,436.0 9,469.0 22:48 00:00 BHP = 3386 psi, WHIP = 210 psi, circ = 3796 psi, pump 10x10 sweeps, drilled to midnight depth of 11912019 1/9/2019 0.50 PROD2 DRILL DRLG P Drilling, CWT = 4.3K, WOB =.4K, drill 9,436.0 9,480.0 00:00 00:30 to planned TD of 9480' 1/912019 1/9/2019 1.20 PROD2 DRILL WPRT P Wiper to tubing tail, PUW =40K, slight 9,480.0 6,130.0 0030 01:42 negative WOB pull at 6760' 1/9/2019 1/912019 0.30 PROD2 DRILL DLOG P Log HRZ for +1' coneclion, RIH to 6,130.0 6,390.0 01:42 02:00 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 1110 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 08:36 1/9/2019 1/9/2019 0.50 COMPZ2 CASING RURD P Prep floor to run liner, UT CT check 0.0 0.0 08:36 0906 flatspots 1/9/2019 1/9/2019 4.00 COMPZ2 CASING PUTB P PJSM, P/U 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 9/10 Report Printed: 112112019 Operations Summary (with Timelog Depths) 1 D-08 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Stan Time End Time Dur (hr) Phase Op Code Aa Wty Cotle Tme P -T -X Operation Start Depth (flKB) End Depth (MKS) 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 ontop of liner 1/9/2019 1/912019 1.00 56MP22 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 Q 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 1/9/2019 0.10 COMPZ2 CAS -NG TRIP P PUH remove liner length ledt in hole 9,480.0 6,299.0 16:18 16:24 from counter 1/9/2019 1/92019 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 1/92019 1/92019 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 1/9/2019 0.90 DEMOB WHDBOP DISP P MU nozzle, bullhead seawater to 0.0 0.0 18:54 19:48 window, 2 bpm 1192019 1/92019 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 1192019 1.50 DEMOB WHDBOP CIRC P Jet stack, clear floor, PJSM 0.0 0.0 20:24 21:54 1192019 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 1/1012019 1/10/2019 2.00 DEMOB WHDBOP NUND P Suck out stack, lock -out koomey, 0.0 0.0 00:00 02:00 continue RD checklist, ND BOP Rig Released 1/10/19 @ 2:00 AM Page 10110 Report Printed: 1/21/2019 ®I ConocoPhillips ConocoPhillips (Alaska) Inc. -Kup1 Kuparuk River Unit Kuparuk 7D Pad ID -OW -01 50-029-20266-61 Baker Hughes INTEQ Definitive Survey Report 05 February, 2019 BAER UGHES ConccoPhillips Conoco h11�Ip5 Survey Report Defiri Company. ConowPhllllps(Alaska) Inc.-Kupt Local co-ordinate Reference: Well 1D-08 Project: Kupamk River Unit TVD Reference. 10.08®108.00usS SM: Kupamk 10 Pad MD Reference: 1040 ®108.00usg Well: 1000 North Reference: Tore Welborn: 10-0811-01 Survey Calculation Method: Minimum GUNato. Del 1D 1.1-01 Database: EDT 14 Alaska Production Project Kupamk River Unit, North Slope Akeka, United States Map System: US State Plane 1927 (11 motion) System Datum: Mean Sea Level Geo Datum: NAD 1927(Ni CONUS) Using Wall Reference Point Map Zone: Alaska Zone 04 Using Sendai scale leder Wei 10-00 Weil Position +WS 0.00 an Northing: 5,959,064.001 tA[iude: 70°17'55ARSN .1 0.00 usfl Essiin9: 560,490.00usS Longitude: 149°3P 36.452W P ... Ron Uncertainty 0.00 an Wellhead Elevation: usfl Dround Level: 0.09usS Wellbore ID BLUGI Magnetics Madel Name 1kmPM Dote oscillations Dip Angle Filed! Sttengb (•) (°) It BOGM2016 31112019 16.75 80.86 57,424 Design 10-080-31 Audit Nates'. version: I Phase: ACTUA, Tie On Depth: 6,466]5 Vertical Section: Depth From (WO) •1,11Af +fbyl Okanogan (us") Iasi (-am (11 108 00 0.00 0.00 45.00 Survey Program Date From To Surrey Survey (asp) kdo Survey(Welihoroj Test Name Description S nr End Dab 200.00 6.300.00 Eton (10-08) GY0.CT-CMS Gyrations cont,carang Ws 31242000 6,396.00 6,465.75 ID -081-1 MWD4NC(1O0aL1) MWUINC_ONLY MWD -INC_ ONLY FILLER 11112018 1112019 6.47400 6.505.10 10-08L101 NAND NC(1 DO8L1-01) MW41NC_ONLY MW0.INL ONLY_FILLER 1,712019 122019 6,53464 9,444.01 1D4811-01 MWD (1D-0BLt-01) MWD MWD -Standard 122019 1182019 232019 2: 0735PM Paget COMPASS 5000.14 Buifd 85O surrey ConocoPhillips SItERhEs 4 ConocoPhilli s p Definitive, Survey Report Compaly: ConocoPhillips(Alaska) Inc.-Kupt Local Coartlinate Reference: We111D-08 Protect: Kupamk River Unit NO Reference: 1048@(08.00..6 Site: Kuparuk ID Pad No Reference: 10-08 Q 108,00ue6 Well: 1D.o8 North Reference: True Wellbore: 1D45LI41 Survey Calculation Methol Minimum Curvature Design 1DOBL1411 Database: EDT 14 Alaska Production surrey b 0192.07.'36PM Pass COMNSS 5000.149ui1tl 650 Map Verticel MO Inc Aa8 TVD TVO65 +NIS .114N Northing Northing Easgng OLS Section gurvey Tool Name AnnDld(lon fuss M (1) ("kelt) (usrt) 1ua6) funk) rt) rl (9100) tltl 6.466]6 1706 768.57 8.484.45 fi35fi.45 Si5e 1.5 t2 6959,009.58 550.506.16 3109 37,45 MW0.1NC_DNLY (2( TP 647400 2049 160.39 6,471.31 6,363.31 56.84 1619 5958.007. 560.506.64 4704 -28]5 MW0.1NC ONLY (3) KOP 6605.10 29.48 143]9 %ius 59 6,39159 _683 21]] 5956995.86 $W,51232 42.64 -32.92 MW0.1NC ONLY(3) In)eryola)ed Azimuth 6,634.64 4299 134.02 6,523.44 641544 41.M 33.22 5950902.00 560,623,87 SOTS -33.99 NAND (4) 6564.61 55.47 131.70 6,54200 6,434.98 41670 49.74 5,956,96764 560,540.51 4237 43.26 "D (4) 6594.51 66.17 131.56 6,55].53 6449.53 414.11 59,21 5.958 950.47 560550.12 35.78 4174 MAD (4) 6825.01 718.56 130.42 6,559.]6 6458.36 -133.13 8112 5.956931.62 550,582.18 40]8 -28.71 MJu➢(4) 6650.22 90.06 13667 6,569.25 6461.25 -149.41 110.15 5,958,915.51) 580,00133 45,63 -2]]6 MIND (4) 6679.38 101.08 4961 6555.42 6,458.42 468.09 13230 5,959,09700 564623.63 30.00 -25.31 MAD(4) 6,700.90 104]5 117.12 6.55956 6.451.56 484.47 157.13 5958... 500,600.00 41.53 -19.33 MOND (4) j 6.74008 102.42 103.43 6,55245 6464.45 -194.57 184.52 5,858,070.94 560.67605 44.86 -7.11 "D (4) 6,TPD. 1030 91.73 6.546.06 6.430.00 -19648 211M 5,95&86]3] 560.70549 37,70 10.92 WAND (4) 6,800.04 10024 n,17 6.540.38 6432.38 -19617 24270 5,95080000 560.734.33 42.03 to 96 MWD(4) 6,827.00 100.37 67.82 6,636.54 6427,54 -16&65 2f8.25 595897753 $W,759.74 40.93 5629 MWO(4) 6,066.5] 99.9D 57.41 6,530.34 642234 -175.34 284.01) 5.958,891.05 %.705.37 3512 8691 MAO(4) 6, seen 9662 55.67 6,525.. 64175 -159.16 316.46 5,959,907.43 550899.72 583 11266 over (4) 6916.66 99.93 5439 6.52016 641216 -142.08 342.87 5.900.924.70 560&3.96 4. 141.98 MIND (4) 6,9460] 99]1 52.64 6,515.13 6,40713 -1$]] 365.23 5959.942.20 560,&.4.10 5.% 17074 MND(4) 6.97680 103,21 51.58 6.509.01 6.401.61 _10SAB 3WA2 5,&4,900.9] 660.880 92 3.74 200.77 MWD(4) 7.00723 98.22 4ae7 6,501 GO 6,396.60 4].22 413.35 5,950,9W.12 560.904.40 6.17 230.61 Marc (4) ],035.)4 96.21 5193 6,489.95 639195 418.86 435.9] 5, 850896.66 scoa646 646 259,50 MD (4) 7,066.92 99.71 53.83 6.494.99 6,386.99 _50.09 45970 5.959,01682 660.95.05 652 28907 "D (4) 7,06741 Been 5591 6460.82 6,301.82 41AW 4849 5,959,034.31 5609]4.48 673 318.60 MVAD(4) 7,127.69 99.65 Vic 0464.67 6,336.67 -17.17 509.42 5.959,050.93 560,999.50 6.13 348.07 MAD (4) 7166.74 99" Win 6.4nM 6,371.80 -2.00 533.80 5,9repas.B0 (51,023]5 790 375.68 MWD(4) 7,106." 99.02 6250 6475.12 6,36712 11.58 559.51 5,erscoun8 561,04934 810 403.62 MAID (4) 721747 9800 6292 6470.26 636227 2663 586]5 5,959,094.35 561,0)646 134 433.01 MD (4) 724].55 98.2s 60.87 646514 6,35774 3964 61297 5,959,105.57 56110258 ].14 46147 MWO(4) ].2]&40 9551 W85 6462.04 6.354.04 54.55 639.)2 5.959,12369 581.12920 9.01 490.92 MWD(4) 7.00675 "As An 46 64WM 6,351" son 66435 5,859,13773 561153.71 499 518,12 MWD(4) b 0192.07.'36PM Pass COMNSS 5000.149ui1tl 650 ConocoPhillips 13AI( p ConocoPhillips Definitive Survey Report 9 Company. Conowlihi9ips(Alaska) Inc.-Kupt Local Coandinate Reference: MR 1D-08 Pmfeck Kupamk River Unit ND Reference: 1600®108.00usn Sne: Kupamk iD Pad MD Reference: 1608@108X0ush Was: 1D-00 North Resonance: Tme WMISon: 10.0811-01 Survey Calculation Mello@ Minimum Curvature Oeslpn: 1D0811-01 Database: EDT 14 Alaska Pro8uc9on Survey 27372019 2:0736PM Palle 4 COMPASS 5000.14 Build 95D Map Mp Vertical MD luau) Inc Aa] TVD TVOSS 4078 ewm Nintun9 Basing Dls Sec9on Survey Tool Name Annotation 1°) 19 (USM loan) (-am (ages Inl MI 1°11907 Inl 7.n7,70 8210 5&99 6457.93 6,34993 839] 691,03 5,959,153.52 561,180.2] 803 518.01 MW)(4) ],358.2] 90.55 55.96 645725 8,34935 8933 71511 5,858.189.07 561.2"05 12.M 575,09 hn,VD(4( 7..156,44 Was 54.54 fi4%.93 6,340.93 11652 738.90 5,859,107.46 581,22&85 4.R 60558 MND(4( 7,42]]3 90.71 52.05 6,453.56 5,340.56 135Y3 ]M.% 5,959,20536 %1253.79 ].96 63654 MD (4) ],456.0] 9107 48.97 6.456.11 6,348.11 15355 ]8].46 59%.224.0] 561276.12 1064 665.54 "D (4) 7.487.26 93.35 48.50 6,454.93 6,34693 17378 sings 5,959,24427 561,291178 7,65 695.84 MWD (4) ],51&3t 93.19 46.41 6.453.16 6.345.16 191)3 M12 5.959265,42 56132145 674 12601 MD (4) ],54&24 9233 0553 6,45112 6,343.72 215.70 85643 5,959385,55 561342,59 6.90 ]56.]0 MWD(4) ],5]].]8 91.26 4223 645&80 6.342.80 237.16 07471 5959308.17 551.362.&9 8.58 7a&21 Ini(4) 7,608.64 67X5 W79 6451.25 6313.25 mass 884.33 595933211 551,38212 22.29 81691 MWD(4) ],61]35 0791 35.65 645251 6344,51 204.60 911.28 5,95935539 5a139600 4.97 84525 MND(4) ].66].91 8739 36,13 6,453.71 6345]] 30682 929.18 5959363.26 561416.57 2.31 87540 1001D (4) 7.696.55 90.34 38137 6,45433 6.34633 33146 946.71 5,959.4010', 561433.92 1530 WOOD MD (4) 7.M95 88.69 40.91 645461 8,34561 356,23 .7,59 5.9.S9A2].97 561,45460 6.99 936.08 LAND (4) 7,75291 89.05 43.2] 6,45505 6,347.05 38142 907.35 595845335 561.477.15 ]]6 961 "D (4) ],]0&78 91.20 4847 6,454.81 6346.61 39976 1,07661 5,85947183 %1495,26 13.42 26597 MM(4) 7811.31 91X7 48,n 6.45136 63K,36 414,94 1,03523 5,858,487.14 551,511.76 10.01 1,018.36 MPo➢(4) 7,84794 91.26 51,29 645262 6,345,63 438.48 1.05338 5,959,510.0 %1539.62 703 1054.84 MND (4) ],8]731 8768 51 D2 6453.09 6,345.89 45&83 1076.00 5959,52644 56156226 1223 108393 MWD(4) 7.902,39 8]]0 5279 6.451.90 6,348,90 an.. 1095.66 5.959545,12 561581.93 702 1,10991 MID (4) 7.932.96 88.25 5513 6.455.90 6,34798 460.33 1.1M.56 5959,560.29 561.61 7.86 1,139.08 MWD(4) ],%38] 8753 54.70 645705 6,349.08 50.97 1,14569 5958,501.13 56193146 2.20 1,169.32 MD (4) 7,883.41 07.05 5245 6.45805 6,350.05 525.61 1,189.60 585958996 561655.2] 7.56 1,19850 MWD (4) 8X21.65 0994 5105 6.459.81 6.35001 542.92 1,191,91 5.959,616.44 %167739 6@ 1,728.71 long) (4) 8,01 Sam 4&37 6.959.03 6,351X3 559.62 121193 5,959633,30 561,607.21 14.15 1,42.60 MND(4) 8.07695 88,71 4602 645950 6,351.60 5]94] 1.233.3] 5959.85332 561.718.54 &14 1,281.87 MD 8.10043 88.19 44,22 6,460.45 6,352,45 601.67 1255.66 5,959,67570 551,74050 595 1,31533 MND(4) 8,137.70 07.61 4160 6461.52 6,353.52 623.fi8 1276.02 5.959,691 561.760. 213 1,N255 MND(4) 8.16705 07.87 44.46 6.462.96 6,354.96 644,11 1,29&88 5,959.718,46 561,78153 293 1.372.48 MWD(4) 6.197.04 0.42 4545 6,46494 0,356.94 sum 131750 5,95913930 561,802.08 5.97 1.40102 MWD(4) 8,22749 83.97 4507 646775 6,359.75 fiw. 133914 5,959.]60.89 561,82245 4.91 143213 "D (a) 27372019 2:0736PM Palle 4 COMPASS 5000.14 Build 95D r. ConoccIPhIlllps ConocoPhillips Definitive Survey Report Co.,., ConocoPhilllps (Alaska) Inc.-Kupl Local Coordinate Reference: Well 10.43 Pm1eH: Kupamk River Unil TVD Reference: 1646 ®103.00usO Sae: K.,.k I Pad MD Reference: 1643@103.00us3 Well: 1603 North Reference: Tme W.111I 10-DaLI41 Survey Calculation McMotl: Minimum Curvature Design: 10-08.1-01 Database: EDT 14 Alaska Production Survey Annotation 2 019 2,07.36W Page5 COMPASS 500014 Budd 830 Map Martical IMIDMap IMsrt) of Inc CI Art 1°I Lrtl -ft TVDSS IMaM 9075 fuse) �E/4g hart) NI Casting DLS flow) Soctlon Survey Tool Name (nl Irt) (M 82T,M 62.10 4500 6,47130 636339 707,21 1,36019 59%78207 561 W. 625 1,461.82 MW A) 0,287.18 B3.66 HM 8415.07 1 220,20 1,38091 5.95980332 561 suns 677 1.91.32 MWD(4) 0,31&97 86.07 43.55 6.471.24 6.369]4 249.50 1,40152 5,951 561.88536 616 1,52104 MWD(41 634752 60.90 "]M 6,42800 6,37108 171.31 1,42281 5,959,646.62 561.906.52 9.65 1,55155 WIND (4) 632&01 9132 44.94 6.429.02 6,31102 29292 1,444.42 5,959.66645 561,927.85 2.95 1,582.04 MND(4) 8,40]90 9427 43.94 6.422.60 6,369.60 013.63 1464.22 5,959.08931 55194709 10.72 lelt04 MID (4) 8.435.12 95.32 43.15 6,475.12 6.7.12 634.68 1484.21 5959.91051 561,962.61 451 1640.05 MWD(4) 8,467.83 92.23 42.34 8.4718 6,363.22 05217 1,59007 5,959933.78 %1,986. 646 1,87149 MWD(4) 8.497.02 98.50 4082 6.461.73 &359.73 07939 1,52522 5,9`.955.56 562008.80 6.69 1,200.36 MWD (4) 8,526.92 91.88 39.55 6463.47 6,355.42 901.99 1,544.38 5,959,928.31 562026.92 484 1.n9 55 MWD(4) 8,65643 ..84 39.5 645924 "1,74 92417 1562]6 6,960001,23 562075.12 6.04 125695 MWD(4) 8,58676 915 36.30 6456.66 8.316.06 man t581.13 6.960025.26 582,08329 508 1.788.82 04 (4) 8,61&39 9T. 34.97 6.52.11 6.304.11 4724.07 1,599.52 5,960.05060 56.08142 594 1,819]9 MD (4) 8650.43 9433 3207 6.448.92 6.34092 100055 1,517,24 5980,077.44 %2.096. 1131 185106 MND(4) W2]5 91.81 2910 6.4246 6,339.46 1033.92 163123 5,607.104.96 562,11270 1577 1,67150 MWD (4) 6.202.49 90.15 5.64 6,446.95 6,338.95 1,D50.25 1,645.13 5,860,121.36 5821546 9.99 1806.92 IMID(4) am" 87.52 2204 1 6,33956 1,01807 1,667.21 6SM 155P 562,130.02 1726 193449 MWD(41 8,76161 07.29 19.30 6,44914 6,34114 1,105.69 1.668.13 5960,18288 562149.02 1023 1,901.39 MWD(4) B.ID189 05.82 17.90 6.451.21 6.M.21 1,13420 1,62149 5.96031156 562158.15 7.62 1,986.12 04 (4) 8,82181 8539 Is.. 6.453.52 6.315.52 1163. 1,665.79 5,960,24048 582.161 6B7 2,01444 MD (4) 8.95043 8441 12.41 64%.23 6.340.5 1,192.69 168304 6,990,22018 562.173.5 9.01 2,04050 MID 6,9... 855 9.50 6,451 6.35019 1,MD49 17998.40 5.960.29800 562.178.36 10.51 2.396 M4A(4) 8,81687 0751 825 6.460.69 6362799 1,250.07 170302 5.960.32762 %210214 8]5 2080.15 MD (4) 8,912.30 8727 4.19 1 6364.00 150.29 1701 5960352.. 562165.79 1335 2111.84 MWD (4) 8.9M.62 8945 405 6462.93 6,35492 1,309.52 1206.42 5,960,382.15 56210766 744 2134.04 MWD(4) 9.007.25 86.31 1.33 648352 6,355.52 1,340.20 1,70965 5.961 562166.85 961 2.156]2 MWD(4) 9,031 Sl 0.13 6464.19 8,355.19 1,320304 171025 5,960,44823 562.189.00 4.85 2,125.52 MWD (4) 1 89.17 358.26 6.8461 63S,A1 1399.99 1709.84 5,960.4]75) 662,186.35 6.37 2.10.98 MND (4) 9.902.39 68.44 35532 6.465]2 635177 1.43016 V08.26 5..050722 562.13153 1221 2,219.5 WAD (4) 9,15.37 8590 am'. 6.462.71 6.35971 1,458.94 1705.49 5,960.53640 562183.53 81 2,Men MD (4) 91%,12 8TW 35342 6469.39 6,361.39 1,486.49 1702.03 595,590.00 562.17184 6.11 225&04 WAD (4) Annotation 2 019 2,07.36W Page5 COMPASS 500014 Budd 830 �,. ConocoPhillips BA COnOCoPhillips Definitive Survey Report Compuy. Conowithllllps(AM9ka) Inc -Kupl Local Co-ordinate Reference: Wall 1D-08 Pro1e4c Kupamk River Unit TVD R rence: 1008 ® 108.00us8 She: Kupamk 1 D Pad MD Reference: 10-08 ® 108.00usX Well: 10-00 North Reference: Tree Wellbore: 10-0311-01 Survey Catculadon MtMod: Minimum Curvature Design: 104811-01 Database: EDT 14 Alaska Production Survey 252018 203:311 Pape 8 COMPASS 5000.14 Buld 050 Map Man Map Vertical MD Inc Aai TVD 71,11M W4 .&M Eacting D"SedX on Survey Tool Name Annotation lasDl 1°I 1°I lusltl 1 -ft) lusnl Iuanl In) In) 1.110w) (t) 9,187.77 89.29 35635 6,430II 6362.22 1,51995 168832 4950,597.43 562.136]] 10,55 2,23629 MM(4) 9217,66 8055 359.95 6430.26 636226 1,549.80 1691926 5,%0.6]1.30 562.135.56 12.83 2,29633 MM (4) 9,246.93 0031 022 643045 8,35245 1,539.12 1,698.311 5rW'656.59 562135.33 6.34 2 317 Motto (4) 9.23642 88,47 1.06 6,43169 6,26368 1,606,54 1,698.63 5,960.68601 562135.43 0.12 2338.53 MJull(4) 9303.05 88.33 3S 6,433.03 ..5.03 1,639.11 1,69986 5,980316.59 662.138.45 10.22 2361.01 WtD(4) 9,337.21 Mint 4.95 8.43442 6.36642 186816 1,30209 5960346.64 562.130. 3.34 2383.84 MD (4) 9.366.81 84.09 550 6,436.85 63f1 1898.53 1.701.80 5.961) 776.03 562166.91 651 2409.52 MD (4) 8,397,26 87,21 9]9 6,439.17 6,331,13 1,728.61 1308.05 5.960.806,14 562,184.33 17,23 2430.66 WD (4) 8,427,06 06]1 11.84 5.480.35 6,3R]5 1,353.82 1314.43 5960.03540 582190la 340 2,45520 MM(4) 9.4.01 85.23 12.26 6481.94 6,333.84 1,334.36 1,318.02 5,9':1,351.96 582,193.51 8.93 2,46948 MWiI(4) 9,400.00 65.23 1226 6466.93 6,33693 1909.41 1325.63 5.960.66703 5b2300aii 0.00 2,49965 PROMCTED to TD 252018 203:311 Pape 8 COMPASS 5000.14 Buld 050 BAN(ER 0 PRINT DISTRIBUTION LIST UGHES a GE company COMPANY_ ConocoPhillips Alaska, Inc. WELL NAME 1D -08L1-01 FIELD Greater Kuparuk Area COUNTY North Slope Borough BHI DISTRICT Alaska AUTHORIZED BY Patrick Rider EMAIL Patrick.Rider@bakerhughes.com 218173 30 35 3 se sign and return one copy of this transmittal form to: ocoPhillips Alaska, Inc. I Osterkamp (WNS Petroleum Technician) G Street. horaRe. Alaska 99510 LOG TYPE GR - RES LOG DATE January 9, 2019 TODAYS DATE February 7, 2019 Revision STATUS Final Replacement: No Details: COMPANY ADDRESS (FEDEX MALL NOT DELIVER TO P.O. Box) PERSON ATTENTION V 1 BP North Slope. FDA, PBOC, PRR 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 ExxonMobil, Alaska Attn: Lynda M. Yaskell stellar Leonardo Elias 3201 C Street, Suite 505 Anchorage, AK 99503 1 1 Rev. Requested by: --- FIELD 1 FINALCD/DVD FINAL PRELIM LOGS (las, dlis, PDF, META, SURVEY I REPORT LOGS CGM, Final Surveys) (Compass) # OF PRINTS # OF COPIES # OF COPIES # OF COPIES 4 lu 4 4 4 4. State of Alaska -AOGCC Atm: Natural Resources Technician 11 333 W. 7th Ave, Suite 100 Anchorage, Alaska 99501 5 DNR - Division of011 & Gas xxx Atin: Resource Evaluation 550 West 7th Avenue, Suite 1100 Anchorage, Alaska 99501 **• Stamp "confidential' on all material deliver to DNR 6 BP Exploration (Alaska) Inc. Petrotechnical Data Center, IR2-1 900 E. Benson Blvd .Anchorage, Alaska 99508 r-UtIVED FEB 0 8 2019 TOTALS FOR THIS PAGE: 0 1 2 0 0 THE STATE 01ALASKA 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 ID -08L1-01 ConocoPhillips Alaska, Inc. Permit to Drill Number: 218-173 Surface Location: 600' FNL, 602' FEL, SEC. 23, TI IN, RI OE, UM Bottomhole Location: 1258' FSL, 1151' FWL, SEC. 13, TI IN, RI OE, UM Dear Mr. Ohlinger: 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 �.aogcc.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 l Chair ZL DATED this — day of December, 2018. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISb,JN PERMIT TO DRILL 20 AAC 25.005 1a. Type of Work: Drill ❑ Lateral ❑° Redrill ❑ Reentry ❑ 1b. Proposed Well Class: Exploratory -Gas ❑ Service - WAG Ll Service - Disp ❑ Stratigraphic Test ❑ Development - Oil ❑✓ - Service - Winj ❑ Single Zone ❑� Exploratory - Oil ❑ Development - Gas ❑ Service - Supply ❑ Multiple Zone ❑ 1 c. Specify if well is propggecHor: Coalbed Gas ❑ GaS.kydfptes ❑ Geothermal ❑ Shale Gas ❑ 2. Operator Name: ConocoPhillips Alaska, Inc. 5. Bond: Blanket ❑' - Single Well ❑ Bond No. 5952180 11. Well Name and Number: KRU 1D-081-1-01 3. Address: P.O. Box 100360 Anchorage, AK 99510-0360 6. Proposed Depth: MD: 9700' • TVD: 6424' 12. Field/Pool(s): Kuparuk River Pool / Kuparuk 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: 803' FNL, 571' FEL, Sec 23 T11 N, R10E, UM Total Depth: 1258' FSL, 1151' FWL, Sec 13, T11 N, R10E, 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: 14,270' 4b. Location of Well (State Base Plane Coordinates - NAD 27): Surface: x- 560490. y- 5959064 Zone- 4 10. KB Elevation above MSL (ft): 108 GL / BF Elevation above MSL (ft): 71 - 15. Distance to Nearest Well Open to Same Pool: 941' (1 D-04) ' 16. Deviated wells: Kickoff depth: 6666' - feet Maximum Hole Angle: 104 degrees 17. 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 -SO ST -L 3380' .6320' - 6211' 9700' 6424' 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 Articset 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 ❑ DivertOP Sketch er Sketch e Dril Seling Program abed Report B Time v. ysis Dri 1 ng FluidPrograpth lm e✓ 20 AAC 25.050 requ emot Shallow Hazard lents 4 21. Verbal Approval: Commission Representative: Date 22. 1 hereby certify that the foregoing is true and the procedure approved herein will not be ,A, ,'� deviated from without prior written approval. Contact Name: William Long / A-4— Authorized Name: James Ohlinger Contact Email: William. R. Lon COP. COM Authorized Title: Staff CTD Engineer Contact Phone: 907-263-4372 Authorized Signature: Date: /10ZOR Commission Use Only Permit to Drill 2 Number: API Number Permit Approyal Date: nj � (,�1/ See cover letter for other requirements. Conditions of approval : If box is checked, well may not be used to explore for, fest, or produce coalbed methane as hydrates, or gas contained in shales: Samplog req'd: Yes No Other: �� i� 5 f - f -p 3 Sp p j-iej H S mleasures: Yes M No ❑ Directionadl svy req'd: Yes No ❑ /tl-1 V1(i/67` P1 -Y V'f rr ',�Tr f�54-- ,f,/ Z5 -&O Spacing exception req'd: Yes ❑ No L!� Inclination -only svy req'd: Yes ❑ Nor✓ Post initial injection MIT req'd: Yes ❑ No 1-=I 79 vetrfar7CL -l-a 20,44C 26.DIS(b) IS q(-q"7Led fo al1/0 W fjY C k1'r OFfP0Mt-Ito br- eyv17 PO ct/ov9 APPROVED BY ` 1p Approved by: COMMISSIONER THE COMMISSION Date: GCS U L '21241 /� rm 10-401 Revised 5/2017his permit is va' ORIGINAL- Submit Form and - oval per 20 AAC 25.005(8) Attachments in Duplicate /zz/A Nt 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 -08L1-01 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: — 10-403 Sundry Application for KRU 113-08 — 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 1 D-081_1 and 1 D-081-1-01 — Detailed Summary of Operations — Directional Plans for 1D-081_1 and 1D-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. Since William R. Long Coiled Tubing Drilling Engineer ConocoPhillips Alaska Kuparuk CTD Laterals 1D-081-1 and 1 D -08L1-01 Application for Permit to Drill Document 1. Well Name and Classification........................................................................................................ 2 (Requirements of 20 AAC 25.005(Q and 20 AAC 25.005(b))...................................................................................................................2 2. Location Summary.......................................................................................................................... 2 (Requirements of 20 AAC 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 20 AAC 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)(6))..................................................................................................................................................3 9. Abnormally Pressured Formation Information.............................................................................4 (Requirements of 20 AAC 25.005(c)(9)).................................................................................................................................................. 4 10. Seismic Analysis............................................................................................................................. 4 (Requirements of 20 AAC 25.005(c)(10))................................................................................................................................................4 11. Seabed Condition Analysis............................................................................................................ 4 (Requirements of 20 AAC 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 20 AAC 25.005(c)(13))................................................................................................................................................4 Summaryof Operations...................................................................................................................................................4 LinerRunning...................................................................................................................................................................5 14. Disposal of Drilling Mud and Cuttings.......................................................................................... 5 (Requirements of 20 AAC 25.005(c)(14))................................................................................................................................................5 15. Directional Plans for Intentionally Deviated Wells....................................................................... 6 (Requirements of 20 AAC 25.050(b))...................................................................................................................................................... 6 16. Attachments....................................................................................................................................6 Attachment 1: Directional Plans for 1D-081-1 and 1D-081-1-01 laterals...........................................................................6 Attachment 2: Current Well Schematic for 1 D-08............................................................................................................6 Attachment 3: Proposed Well Schematic for 1 D-081-1 and 1 D-081-1-01 laterals.............................................................6 Page 1 of 6 December 20, 2018 PTD Application: 113-081-1 and 1D-081-1-01 Well Name and Classification (Requirements of 20 AAC 25.005(x7 and 20 AAC 25.005(b)) The proposed laterals described in this document are 1D-081-1 and 'ID -081-1-01. 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 1 D -08L1 and 1D -08L1 -P1. 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 1 D-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 ID -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 b-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)) 1-1 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 1 D-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 Aaalication: 1D-081_1 and 1D-081-1-01 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 16" 65 H-40 WELDED 23' 2-3/8" 4.7#1 L-80, ST -L slotted liner; 1D-081_1 6666' 9300' 6450' 6179' alumin, um billet on to 45.5 K-55 8TC 23' 2230' 2-3/8", 4.7#1 L-80, ST -L slotted liner; 1D -08L1-01 6320' 9700' I 6211' 6424' with deployment sleeve on to Existing CasinglUner Information Category OD Weight 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 8TC 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 1 D-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-081_1 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, 7" 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 7" 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 chokepressure) 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, 7" 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 7" 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-081_1-01 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-081_1-01 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 I . 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 11 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 -08L1 and 1D -08L1-01 • 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 AA 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 ID -0811-11 14,550' 1D-081-1-01 14,270' - Distance to Nearest Well within Pool Lateral Name Distance Well ID -081-11 2108' 1 D-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 ID -08L1 and 1D -08L1-01 laterals Page 6 of 6 November 26, 2018 ConocoPhillips _ConocoPhillips Export Company Kuparuk River Unit Kuparuk 1D Pad 1 D-08 113-081-1 -01 Plan: 1 D-081-1-01_wp02 Standard Planning Report 14 December, 2018 BT�a GHES GE company Conoco illips Database: EDT 14 Alaska Production Company: _ConocoPhillips Export Company Project: Kuparuk River Unit Site: Kuparuk 1 D Pad Well: 1D-08 Wellbore: 1D-081-1-01 Design: 1D-081-1-01_wp02 ConocoPhillips Planning Report Local Coordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Well 1 D-08 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 Gen Datum: NAD 1927 (NADCON CONUS) Using Well Reference Point Map Zone: Alaska Zone 04 Using geodetic scale factor BA ER F IGHES BAT site Kuparuk 10 Pad, KRU 1D-0811-01 Magnetics Site Position: Northing: 5,959,669.68 usft Latitude: 700 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 1 D-08 1D-0811-01 Magnetics Well Position +N/S 0.00 usft Northing: 5,959,064.00 usft ' Latitude: 70' 17'55+408 N +EI -W 0.00 usft Easting: 560,490.00 usft . Longitude: 149° 30'36.452 W Position Uncertainty 0.00 usft Wellhead Elevation: usft Ground Level: 0.00 usft Wellbore 1D-0811-01 Magnetics Model Name Sample Date Declination Dip Angle Field Strength (1C) (nT) BGGM2018 3/1/2019 TVD Below 16.75 80.88 57424 Dogleg Build Design 1D-081-1-01_wP02 Depth Audit Notes: Azimuth System +NAS Version: Phase: PLAN Te On Depth: 6,66600 Vertical Section: Depth From (TVD) -N/-S +E/ -W Direction V) (usft) (usft) (usft) (I (°/100usft) 0.00 0.00 0.00 45.00 Target 6,666.00 Plan Sections Measured TVD Below Dogleg Build Tum Depth Inclination Azimuth System +NAS +EI.W Rate Rate Rate TFO (usft) (I V) (usft) (usft) (usft) (°/100usft) ('[100h ift) ('Mo0usft) (1) Target 6,666.00 103.04 173.95 6,450.49 -202.10 31.67 0.00 0.00 0.00 0.00 6,736.00 103.69 141.55 6,433.88 -264.21 57.05 45.00 0.94 46.28 275.00 6,900.00 94.72 67.10 6,403.38 -299.87 202.57 45.00 -5.47 45.40 271.00 7,300.00 91.83 39.20 6,380.07 -62.64 518.83 7.00 -0.72 -6.97 265.00 7,500.00 91.77 53.20 6,373.75 75.37 662.75 7.00 -0.03 7.00 90.00 7,725.00 91.71 37.45 6,366.87 232.99 822.17 7.00 -0.03 -7.00 270.00 8,050.00 91.57 60.21 6,357.44 445.46 1,065.10 7.00 -0.04 7.00 90.00 8,450.00 95.14 32.38 6,333.55 718.48 1,350.98 7.00 0.89 -6.96 278.00 8,700.00 90.45 15.49 6,321.27 945.84 1,451.84 7.00 -1.87 -6.75 255.00 8,975.00 83.96 357.34 6,334.78 1,217.49 1,482.52 7.00 -2.36 -6.60 250.00 9,225.00 84.24 14.93 6,360.70 1,463.75 1,509.01 7.00 0.11 7.04 90.00 9,700.00 80.80 48.30 6,424.31 1,859.17 1,751.81 7.00 -0.72 7.03 98.00 1211412018 5 14:17PM Page 2 COMPASS 5000.14 Build 85D ConocoPhillips B q ConoCO�lillips Planning Report F�UERGHES a Glicompany Database: EDT 14 Alaska Production Local Co-ordinate Reference: Well 1D-08 Company: _ConocoPhillips Export Company TVD Reference: Mean Sea Level Project: Kuparuk River Unit MD Reference: 1 D-08 @ 108.00usft Site: Kuparuk 10 Pad North Reference: True Well: iD-08 Survey Calculation Method: Minimum Curvature Wellbore: 1D-0811-01 Design: 1 D-081-7-01_wp02 Planned Survey Measured TVD Below Vertical Dogleg Toolface Map Map Depth inclination Azimuth System +N/ -S +E/ -W Section Rate Azimuth Northing Easting (usft) (1) (1) (usft) (usft) (usft) (usft) (°/100usft) (°) (usft) (usft) 6,666.00 103.04 173.95 6,450.49 -202.10 31.67 -120.51 0.00 0.00 5,958,862.19 560,523.29 TIP/KOP 6,700.00 103.89 158.23 6,442.52 -234.08 39.58 -137.53 45.00 -85.00 5,958,830.27 560,531.46 6,736.00 103.69 141.55 6,433.88 -264.21 57.05 -146.48 45.00 -88.66 5,958,800.29 560,549.17 Start 45 dls 6,800.00 102.45 111.99 6,419.10 -301.04 106.40 -137.63 45.00 -89.00 5,958,763.86 560,598.81 6,900.00 94.72 67.10 6,403.38 -299.87 202.57 -68.80 45.00 -95.83 5,958,765.80 560,694.95 End 45 dis, Start 7dls 7,000.00 94.08 60.11 6,395.70 -255.56 291.82 25.63 7.00 -95.00 5,958,810.82 560,763.84 7,100.00 93.37 53.13 6,389.19 -200.69 375.09 123.32 7.00 -95.54 5,956,866.36 560,866.65 7,200.00 92.62 46.16 6,383.96 -136.06 451.13 222.79 7.00 -95.99 5,958,931.59 560,942.17 7,300.00 91.83 39.20 6,380.07 -62.64 518.83 322.57 7.00 -96.36 5,959,005.54 561,009.26 4 7,400.00 91.82 46.20 6,376.89 10.77 586.57 422.38 7.00 90.00 5,959,079.49 561,076.40 7,500.00 91.77 53.20 6,373.75 75.37 662.75 521.93 7.00 90.22 5,959,144.70 561,152.06 5 7,600.00 91.76 46.20 6,370.66 139.98 738.94 621.48 7.00 -90.00 5,959,209.91 561,227.71 7,700.00 91.72 39.20 6,367.62 213.39 806.68 721.30 7.00 -90.22 5,959,283.86 561,294.86 7,725.00 91.71 37.45 6,366.87 232.99 822.17 746.11 7.00 -90.43 5,959,303.58 561,310.19 6 7,800.00 91.70 42.70 6,364.64 290.34 870.41 820.78 7.00 90.00 5,959,361.31 561,357.97 7,900.00 91.67 49.70 6,361.70 359.48 942.52 920.65 7.00 90.16 5,959,431.02 561,429.50 8,000.00 91.61 56.70 6,358.83 419.32 1,022.51 1,019.52 7.00 90.36 5,959,491.49 561,509.00 8,050.00 91.57 60.21 6,357.44 445.46 1,065.10 1,068.13 7.00 90.56 5,959,517.98 561,551.38 7 8,100.00 92.06 56.74 6,355.85 471.59 1,107.69 1,116.72 7.00 -82.00 5,959,544.44 561,593.75 8,200.00 93.00 49.79 6,351.43 531.30 1,187.70 1,215.52 7.00 -82.11 5,959,604.79 561,673.28 8,300.00 93.90 42.84 6,345.40 600.20 1,259.85 1,315.25 7.00 -82.42 5,959,674.26 561,744.85 8,400.00 94.74 35.87 6,337.86 677.25 1,323.04 1,414.42 7.00 -82.84 5,959,751.81 561,807.42 8,450.00 95.14 32.38 6,333.55 718.48 1,350.98 1,463.33 7.00 -83.36 5,959,793.26 561,835.03 8 8,500.00 94.23 28.99 6,329.47 761.33 1,376.41 1,511.61 7.00 -105.00 5,959,836.31 561,860.11 8,600.00 92.36 22.23 6,323.72 851.30 1,419.54 1,605.72 7.00 -105.28 5,959,926.62 561,902.50 8,700.00 90.45 15.49 6,321.27 945.84 1,451.84 1,695.41 7.00 -105.67 5,960,021.41 561,934.04 9 8,800.00 88.06 8.91 6,322.56 1,043.51 1,472.96 1,779.42 7.00 -110.00 5,960,119.23 561,954.37 8,900.00 85.70 2.32 6,328.01 1,142.82 1,482.73 1,856.55 7.00 -109.91 5,960,218.61 561,963.34 8,975.00 83.96 357.34 6,334.78 1,217.49 1,482.52 1,909.19 7.00 -109.55 5,960,293.27 561,962.53 10 9,000.00 83.96 359.10 6,337.41 1,242.34 1,481.74 1,928.22 7.00 90.00 5,960,318.10 561,961.55 9,100.00 84.03 6.14 6,347.89 1,341.62 1,486.29 1,999.63 7.00 89.81 5,960,417.41 561,965.30 9,200.00 84.18 13.18 6,358.17 1,439.62 1,502.97 2,080.72 7.00 89.08 5,960,515.53 561,981.19 9,225.00 84.24 14.93 6,360.70 1,463.75 1,509.01 2,102.05 7.00 88.35 5,960,539.70 561,987.03 11 9,300.00 83.53 20.17 6,368.69 1,534.82 1,531.49 2,168.21 7.00 98.00 5,960,610.95 562,008.94 9,400.00 82.67 27.16 6,380.71 1,625.69 1,571.30 2,260.62 7.00 97.44 5,960,702.13 562,048.02 9,500.00 81.93 34.19 6,394.13 1,710.87 1,621.82 2,356.57 7.00 96.60 5,960,787.71 562,097.85 9,600.00 81.30 41.24 6,406.73 1,789.09 1,682.29 2,454.64 7.00 95.66 5,960,866.40 562,157.68 9,700.00 • 80.80 48.30 6,424.31 1,859.17 1,751.81 2,553.35 7.00 94.63 5,960,937.03 562,226.62 Planned TD at 9700.00 1211412018 5:14: 17PM Page 3 COMPASS 5000.14 Build 65D ConocoPhillips Database: EDT 14 Alaska Production Company: _ConocoPhillips Export Company Project: Kuparuk River Unit Site: Kuparuk 1 D Pad Well: 1D-08 Wellbore: 1D-0811-01 Design: 1D-08L1-01_wp02 Casing Points Hole Measured Vertical Depth Depth (usft) (usft) 9,700.00 6,424.31 23/8" Plan Annotations Hole Measured Vertical Depth Depth lush) (usft) 6.666.00 6,450.49 6,736.00 6,433.88 6,900.00 6,403.38 7,300.00 6,380.07 7,500.00 6,373.75 7,725.00 6,366.87 8,050.00 6,357.44 8,450.00 6,333.55 8,700.00 6,32127 8,975.00 6,334.78 9,225.00 6,360.70 9,700.00 6,424.31 ConocoPhillips Hole Planning Report Diameter Local Coordinate Reference: Well 1D-08 TVD Reference: Mean Sea Level MD Reference: 1D-08 @ 108.00usft North Reference: True Survey Calculation Method: Minimum Curvature Name BA (ER F�UGHES a GEc., p, y Casing Hole Diameter Diameter (in) (in) 2.375 3.000 -202.10 Local Coordinates -N/-S +E/ -W (usft) (usft) Comment -202.10 31.67 TIP/KOP -264.21 57.05 Start 45 dls -299.87 202.57 End 45 dis, Start 7dis -62.64 518.83 4 75.37 662.75 5 232.99 822.17 6 445.46 1,065.10 7 718.48 1,350.98 8 945.84 1,451.84 9 1,217.49 1,482.52 10 1,463.75 1,509.01 11 1,859.17 1,751.81 Planned TD at 9700.00 12/14/2018 5:14.17PM Page 4 COMPASS 5000.14 Build 85D ConocoPhillips ConocoPhillips Travelling Cylinder Report BAIUGHES a GEcompany Company: ConocoPhillips (Alaska) Inc. -Kupt 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 10.081-1-01 Reference Design: 10.081-1-01_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 I D-08 @ 108.00usft 1 D-08 (§ 108.00usft True Minimum Curvature 1.00 sigma EDT 14 Alaska Production Onset Datum Reference iD-081-1-01_wp02 Casing Filtertype: NO GLOBAL FILTER: Using user defined selection 8 filtering criteria To Interpolation Method: MD Interval 25.00usft Emor Model: ISCWSA Depth Range: 6,666.00 to 9,700.00usft Scan Method: Tray. Cylinder North Results Limited by: Maximum center -center distance of 1,159.20 usft Error Surface: Pedal Curve Survey Tool Program Date 12/14/2018 Casing Hole From To Diameter Diameter (usft) (usft) Survey (Wellbore) Tool New Description 200.00 6,400.00 Gyro (I D-08) GYD-CT-CMS Gyrodata cont.casing m/s 6,400.00 6,666.00 1D-08L1_wp02(I D-081-1) MWD MWD - Standard 6,666.00 9,700.00 iD-081-1-01_wp02(1D-081-1-01) MWD MWD - Standard Casing Points Measured Vertical Casing Hole Depth Depth Diameter Diameter (usft) (usft) Name (in) (in) 9,700.00 6,532.31 23/8" 2.375 3.000 Summary 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 1 D Pad iD-04-1D-04-1D-04 9,698.33 6,250.00 940.97 235.36 818.08 Pass - Major Risk 1D -04 -1D -04A -10-04A 9,698.33 6,250.00 940.97 235.09 818.36 Pass - Major Risk 1D-04-1D-04ALl- 1D-04ALl 9,698.33 6,250.00 940.97 235.09 818.36 Pass - Major Risk 1D-04-1D-04ALI-01-1D-04ALI-01 9,698.33 6,250.00 940.97 235.09 818.36 Pass - Major Risk iD-04-iD-04ALI-02-1D-04ALI-02 9,698.33 6,250.00 940.97 235.09 818.36 Pass - Major Risk 1 D-06 - 1 D-06 - 1 D-06 Out of range 1 D-07 - i D-07 - 1 D-07 Out of range 1D-08-iD-08-1D-08 6,710.49 5,825.00 749.49 9.38 744.91 Pass - Major Risk 1 D-08 - 1 D-081-1 - i D-08L7_Wp02 Out of range 10-10 - 1 D-10 -1 D-10 Out of range 1 D-102 - 1 D-102 - 1 D-102 Out of range 1 D-102 - 1 D-10211 - 1 D -1 02L1 Out of range 1D-102 - 1D-102PB1 - 1D-102PB1 Out of range 1 D-102 - 1 D-102PB2 - 1 D -1 02P02 Out of range 1 D-102 - 1 D-102PB3 - 1 D-102PB3 Out of range ID -11 - 113-11 - 1D-11 Out of range ID -11 - 113-1111 - 113-1111 Out of range 1 D-11 - 1 D-11 L2 - 1 D-11 L2 Out of range 1 D-11 - 1 D-11 1-2PB1 - 1 D-11 L2PB1 Out of range 1 D-121 -1 D-121 - 1 D-121 Out of range 1 D-124 -1 D-124 - 1 D-124 Out of range 1 D-126 - Plan: 1 D -126A- 1 D-1 26A (wp02) Out of range 1 D-127 -1 D-127 - 1 D-127 Out of range 10-128 -1 D-128 - 1 D-128 Out of range 10-129 -1 D-129 - 1 D-129 Out of range 1 D-130 - 1 D-130 -1 D-130 Out of range 1D-131 - 1D-131 - 1D-131 Out of range 1 D-132 - 1 D-132 - 1 D-132 Out of range CC - Min centre to center distance or covergent point, SF - min separation factor, ES - min ellipse separation 12/142018 1:00.42PM Page 2 COMPASS 5000.14 Build 85D Summary ConocoPhillips BA�(ER ConocoPhillips Travelling Cylinder Report oases site Error: 0.00 usft IGHES Distance Deviation Warning Site Name aGEcompany Company: ConocoPhillips (Alaska) Inc. -Kup1 Local Co-ordinate Reference: Well 1 D-08 (usft) (usft) (usft) Project: Kuparuk River Unit TVD Reference: 1 D-08 @ 108.00usft Reference Site: Kuparuk 1 D Pad MD Reference: 1 D-08 @ 108.00usft Site Error: 0.00 usft North Reference: True Reference Well: 1D-08 Survey Calculation Method: Minimum Curvature Measured Well Error: 0.00 usft Output errors are at 1,00 sigma TooMacea Reference Wellbore 113-081-1-01 Database: EDT 14 Alaska Production Centre to Reference Design: 1 D-08L1-01_wp02 Offset TVD Reference: Offset Datum Depth Summary Kupamk 1 D Pad - 1 D-04 - 1 D-04 - 1 D-04 Reference Offset Centre to No -Go Allowable oases site Error: 0.00 usft Measured Measured Centre Distance Deviation Warning Site Name Depth Depth Distance (usft) from Plan Offset Well - Wellbore - Design (usft) (usft) (usft) (usft) Reference Kuparuk 1 D Pad Semi Majo,AY13 1 D-133 - 1 D-133 - 1D-133 Out of range 10-133 - 1 D-133PB1 - 1 D-133PB1 Out of range 1 D-134 - 1 D-134 - 1 D-134 Measured Vertical Out of range 1 D-135 - 1 D-135 - 1 D-135 TooMacea West wells. Out of range 1 D-136 -1 D-136 - 1 D-136 Centre to No Go Out of range 10.137 - 1 D-137 - 1 D-137 Depth DepN Out of range 10-138 - 1 D-138 - 10.138 Anmutft Out of range 1D-138 - 1D-138PB7 - 10-138 WP2 Rde Size Cairns Out of range 1 D-138 -1 D-138PB1 - 1 D-138PB1 (um) (tm) Out of range 1 D-139 -1 D-139 - 1 D-139 loan) Oran) Out of range 1 D-36 - 1 D-36 - 1 D-36 (usft (in) Out of range 1 D-36 - 1 D36 - 1 D-38WP4(Baker) (usft &611.00 Out of range 1 D-36 - 1 D-3611 - 1 D-361-1 5,387.05 3370 Out of range 1 D-36 -1 0-3612 - 1 D -36L2 2,029.69 1,748.72 Out of range 1 D-37 - 1 D-37 - 1 D-37 230.97 1,033.17 Pass - Major Risk Out of range 1 D-37 - 1 D -37L1 - 1 D-371-7 6.050.00 5.411.57 Out of range 1 D-37 - 1 D-3712 - 1 D-371-2 38.42 2,03271 Out of range 1 D-37 - 1 D-37l2PB1 - 1 D-371-2PB1 1.129.60 231.49 Out of range 1 D-38 -1 D-38 - 1 D-38 6,525.04 6,075.00 Out of range 1 D-39 - 1 D-39 - 10.39 34.67 38.72 Out of range 1 D-40 - 1 D-40 - 1 D40 8.312 1,106.16 Out of range 1 D-40 - 1 D -40A - 1 D40A SODAS 6,526,09 Out of range 1 D-41 - 1 D-41 - 1 D-41 33.94 34.78 Out of range 1 D-41 - 10.41 Pat - 1 D41 Pat 1,757.73 6.312 Out of range 1 D-41 - 10.41 PB2 - 1 D41 PB2 961.87 Pass - Major Risk 9,666.00 Out of range 1 D-42 - 1 D42 - t D42 5,405.33 34.01 Out of range 1 D-42 - 1 D42 - 10.42 (Baker) 2.041.25 1.761.10 Out of range 1 D-42 - 1 D42L7 - 1 D-421-1 233.01 937.98 Pass - Major Risk Out of range 1 D42-1D42L1 Pat -1D -02L1 Pat 6,150.00 5,509.96 Out of range Offset Design Kupamk 1 D Pad - 1 D-04 - 1 D-04 - 1 D-04 oases site Error: 0.00 usft Survey Program: 206SEEKER MS Rule AssgreO: Major Risk Ousel Wellavon 0.00 U0 Reference OIfe. Semi Majo,AY13 Measured Vertical Measured Vertical Reference Onset TooMacea West wells. centre Casing- Centre to No Go Allowabk Warning Deem Depth DepN Depth Anmutft eNfb �-Vv Rde Size Cairns DtsWnce Deviation (um) (tm) sum) (usft) loan) Oran) (`) (usft) (usft (in) (Um) (use) (usft &611.00 6,523.02 6,025,00 5,387.05 3370 34+45 38.14 2,029.69 1,748.72 6912 1153,01 230.97 1,033.17 Pass - Major Risk 9.647.23 6,523.98 6.050.00 5.411.57 33.77 34.56 38.42 2,03271 1.750.54 6.312 1.129.60 231.49 10119.44 Pass - Major Risk 9.654.01 6,525.04 6,075.00 5,438.12 33.86 34.67 38.72 2,035.64 1,754.21 8.312 1,106.16 232,03 985.68 Pau - Major Risk SODAS 6,526,09 6,100.00 5,460.71 33.94 34.78 39.01 2,038.50 1,757.73 6.312 1,082.66 232.56 961.87 Pass - Major Risk 9,666.00 6,526.82 6.125.00 5,405.33 34.01 34.89 39.20 2.041.25 1.761.10 6.312 1.059.16 233.01 937.98 Pass - Major Risk 9,673.73 6,528.14 6,150.00 5,509.96 34.11 35.00 3a52 2,043.89 1,784.33 6.312 1,035.60 233.55 914.14 Pass - Major Risk eatio fi 6,529.14 6,175.0 5,534,66 34.19 35.10 39.75 2,046.42 1.767+40 6.312 1012,00 234.02 690.20 Pass - Malar Risk 9.68627 6.530,12 8,200,00 5,559.37 34,27 35,21 39.96 2,078.82 1,77a33 6.312 988.37 234.49 86621 Pass - Major Risk 9.692.39 6,531.09 6,225.00 5,584.11 34.34 35.31 40.16 2,051.08 1,773.15 6,312 954.69 234,93 842.17 Pass - Major Risk 9.69833 6532.05 6,250.00 5.608.87 34.42 35.41 40,33 2,053.17 1,775.88 6.312 940.97 235.36 810.08 Paas- Major Risk. CC, ES, SF CC - Min centre to center distance or covergent point, SF - min separation factor, ES - min ellipse separation 12/142018 1`00'42PM Page 3 COMPASS 5000.14 Build 85D Conocohillips Project: Kuparuk River Unit.ne Site: Kuparuk to Pad uToart Damn uq,.m nae WELLBORE DETAILS: 1D-08LI-01 REFERENCE INFORMTION Parent Wellbore: 1D -08L1 Co raa(Nf7 Relaere WN 1110%. T. xarn Well: iD48 anre,n: naa.asn TN: on MD: 6886.00 Vs (rvol Rehm.: ueen sm La l Wellbore: 1D-0eLtAt ani . +E/ -W f7pM m,, inl�N.reNMo�l Man:1D-08L1.01_wp02 (1D -0&1D -08L1-01) NoeN: eccuzm ��n Longitude 0.00 Cekuh 4m uemw "N.. C.N. 210C 13110 1500 1200 90C c � 6oc c 300 0 n a � -3UC O -60C -90C 1200 -150C -1600 .21 DO West( -)/East(+) (300 usB/in) BA, ICER rjUGHES Ea-,, lI n WELL DETAILS: I mm 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 Sec MD Inc. Azi TVDSS +N/ -S +E/ -W Dleg TFace VSect Annotation 1 6666.00 103.04 173.95 6450.49 -202.10 31.67 0.00 0.00 -120.51 TIP/KOP 2 6736.00 103.69 141.55 6433.88 -264.21 57.05 45.00 275.00 -146.48 Start 45 dls 3 6900.00 94.72 67.10 6403.38 -299.87 202.57 45.00 271.00 -66.80 End 45 cls, Start 7dls 4 7300.00 91.83 39.20 6360.07 -62.64 518.83 7.00 265.00 322.57 4 5 7500.00 91.77 53.20 6373.75 75.37 662.75 7.00 90.00 521.93 5 6 7725.00 91.71 37.45 6366.87 232.99 822.17 7.00 270.00 746.11 6 7 8050.00 91.57 60.21 6357.44 445.46 1065.10 7.00 90.00 1068.13 7 8 8450.00 95.14 32.38 6333.55 718.48 1350.98 7.00 278.00 1463.33 8 9 8700.00 90.45 15.49 6321.27 945.84 1451.84 7.00 255.00 1695.41 9 10 8975.00 83.96 357.34 6334.78 1217.49 1482.52 7.00 250.00 1909.19 10 11 9225.00 84.24 14.93 6360.70 1463.75 1509.01 7.00 90.00 2102.05 11 12 9700.00 80.80 48.30 6424.31 1859.17 1751.81 7.00 98.00 2553.35 Planned TD at 9700.00 210C 13110 1500 1200 90C c � 6oc c 300 0 n a � -3UC O -60C -90C 1200 -150C -1600 .21 DO West( -)/East(+) (300 usB/in) BA, ICER rjUGHES Ea-,, lI n I mm �i■■■■■■■■■■■■■,_� ■tee � I■■■■■■■■■■■■ II■■■■■■■■■■0 NO ON II■■■■■■■Ms IN MEN i■■■■■■r�i��i■■■■ON ■■ ■■■���,/®�rii�■■■■■■■■� 5925 - I PAP -110 850 5925 - 6000 ~I FI .I Q 6075 ID 8/I1) L - - _ J j J Q' I 6150 Q Q p 6225 63W mn 45 dls End 4 dls, S n 7d1 6375 .' 0 G450 J PTanl TD a 9700. 6525 ID -C VID-0 LI -01 TP P 6600 I D -O8 1 auln j can S a I I ABL I P 6675 DA8 - Vertical Vertical Section at 45.00° (75 usft/in) ID -08 @ Project: Kupatuk River Unit Site: KUparuk 1D Pad Well: 1DA8 csmw.m Tom. wnn upe .=; ilea• u.o,wy FyM s,.yu. saaa,eHr WELLBORE DETAILS 1D -()8L1 REFERENCE WFDRMAnDx BAT BA ER Parenl Wellbore: 1D-08 Leon MD: 8400.00 Domanae (xrel Rhea—: ME IDo6, Tme N. venicallTVD)Raaerye: 1608@ tom"ft serua�rvslRaxeMe. sml-lawx,000El ConocoPhillips Wellbore: 1D•08L7 aRauy:eosa• Meas OWhReM� aGE..Ece, Plan: 1DA8L1_wpO2 j1D-0811D•IIBLI) umM ecGrz mi Mu@ faire ID -08 @ 1D-08 Proposed Completion 16" 65# H-40 sho @ 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 3-1/2" Landing DS Nipple @ 493' RKB (2.875" ID) 3-1/2" Camco KBG Mandrels @ 2541', 3786', 4688', 53351, 5798', 6012' 5" Seal Bore Receptacle w/ 4" bore @ 6110' RKB 5"x3-12" 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 FBA Packer @ 6294' RKB Baker SBE @ 6296' RKB Comm D Nipple @ 6326'(2.75" ID) Baker WLEG @ 6337' RKB 7" Cast Iron Bridge Plug (6550' RKB) 1D-081-1-01 TD @ 9,700' MD Top of Liner @ 6320' MD 1 D-081-1 TD @ 9,300' MD Top of Aluminum Billet @ 6666' MD KUP PROD WELLNAME 1D-08 LBORE 1D-08 COhoc ✓ Well Attributes Max Angle & MD TO r R/VOI IIIIpS E*Id Mame wav OPINWI WNIbore Slalus ncl-) MOMIGO) MBtrnMKS) Alaska, Inc. KUPARUK RIVER UNIT 50029202fifi00 PROD 89 2.10000 i 6AAILU HANGER GPS UFi', GlS un; GAS LIFT; GAS UFT; GAS Un', GAS UFT; NIPPLE WLEG; IPERF;6pSG6.811.0� IPERF;6S M,M"— 5112 x Ban Lam St ad M I T., OV01 NWe retch P SB TAGRun Tap(NKEG MB) Mate Madel OU(Inl Sam TP Tyya (in) hxq Run USN Co. 1 2,541.4 2,5405 CAMCO KBG- 1 GASUFT GLV BTM 0.156 1,217.0 45QO14 2.9 3,)Afi.3 3, 5.2 CMCO KBG 1 GASLIFT LV BTM 0.1 —1=,.o 4IW2014 2.9 3 4.fiAA.3 4,66>.1 AMCO KBG i ASLIFT GLV BTM 0.17N 7,257.0 41312014 2.8 4 5,331.5 5,933.3 CAMCO KBG- 1 GAS LIFT OV BTM 0.250 0.0 4!3/2014 29 S 5,786.3 S.J9J.0 CAMCO KBG- 1 GAS LIFT DMV DK -1A 0.000 0.0 3I2d12014 2.9 fi,011J ,010.3 CAMCO 1 GAS LIfT DMY DK -IA 3/2412014 2.9 General a r TRANSMITTAL LETTER CHECKLIST WELL NAME: /�eLl / D " PTD: 2/8-1"73 Development _ Service _ Exploratory _ Stratigraphic Test _ Non -Conventional FIELD: 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. 1'7 7--0 373 , API No. 50-t�,e1_t--2-6 g164 - 4' t/ (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. (Company Name) must contact the AOGCC to obtain advance approval of such water well testing program. Regulation 20 AAC 25.071(a) authorizes the AOGCC to specify types of well logs to be run. In addition to the well logging program proposed by (Company Name) in the attached application, the following well logs are also required for this well: Well Logging Requirements Ver. 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 PTD#:2181730 Administration Appr Date SFD 12/24/2018 Engineering 17 Appr Date '28 VTL 12/24/2018 29 30 31 32 Geology Appr Date SFD 12/24/2018 -490100 Well Name: KUPARUK RIV UNIT 113-081-1-01 Program DEV Well bore seg Initial Class/rype DEV/PEND GeoArea 890 Unit 111169 On/Off Shore On Annular Disoo Nonconven, gasconforms to AS31.05,03061.40-2.A-D)---------------------NA.-------.......---------- Date: ----.....Permitfee Permit feeattached - . NA. �Z Lease number appropriate---- - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - Yes - - Entire well in A440025650.... Unique well. name and number ____________ _ .. _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes - - KUPARUK RIVER, KUPARUK RIV OIL-- 490100.... Well located in a. defined pool - - - - - - - - - - - - - - - - - - - - - - - - - - - - _ Yes - Kuparuk River Oil Pool, governed by Conservation Order No. 432D Well located proper distance from drilling unit boundary . . . . . . . . ............... Yes - - - _ Conservation Order No. 432D has no intenvell.spacing .restrictions. Wellbore will be more than 500' Well located proper dtstanee from other wells_ _ _ __ _ ___ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes - _ _ - _ from an external property line -where ownership or landownership changes. As proposed, well will - Sufficient acreage available in drilling unit. - - - _ - - - _ - ... Yes ..... conform to spacing. requirements..If deviated, is wellbore plat -included - - - - - - - - - - - - - - - - - - - - - - - - - - - - Yes Operator only affected party. - _ - ........................ Yes Operator has appropriate bond in force ----------- ---------- Yes. ---�--.. - Permit can be issued without conservation order- - - - - - - - - - --- - - --- - ---- Yes Permit can be Issued without administrative approval _ _ .. - - - Yes Can permit be approved before 15 -day wait- - - _ - - - - _ - - - - - Yes .Well located within area and strata authorized by. Injection Order # (put 10# in comments) (For_ NA All wellswithin1/4-mite area of review identified (For service well only). ... ..... NA. Pre -produced injector; duration of pre production less than 3 months -(For service well only) - NA- - - - - - - - - - - --------- Conductor string provided _ _ _ . _ _ _ _ _ _ _ - - - -- - -- - - - - - - - - - - - - - - NA- - ... - .. Conductor set for KRU_ 1D-08 _ _ . _ . _ _ ........ . Surface casingprotects all known USDWs - _ - - - - - - - - - ... NA ....... Surface rasing set in KRU iD-08 - CMT -vol adequate to circulate on conductor & surf csg . . . . . . . . . . . . ............ NA_ - - . - - - - Surface casing set and fully. cemented .. - - CMT vol adequate. to tie-in long string to surf csg...................... . . . . . NA CMT. will cover all known productive horizons- - - - - - - - - - - - - - - - - - - - - - - - - - - - - - No..... - . Productive.interval will be completed with. uncemented slotted liner Casing designs adequate for C, T, B & permafrost- - - - - - - - - - - - - - - - ------- Yes .... Adequate tankage or reserve pit ..... - - - - Yes ..... - - Rig has steel tanks; all waste to approved disposal wells If a. re -drill, has -a 10-403 for abandonment been approved ..... - - - - - NA - Adequate wellbore separation proposed - - -- - ---- - - - - - - - - - - - - - - - - - - - Yes _ - - - Anti -collision analysis complete; no major risk failures ..... If diverter required, does it meet. regulations. - - - - - .. NA . - Drilling fluid. program schematic & equip list adequate . . . .................. . . Yes - - - - - - - Max formation pressure is 3663 psig(11.2 ppg EMW ); will drill.w/ 8,6.ppg EMW and maintain overbal-w/ MPD - - - BOPEs, do they meet regulation - - - - - - - - - - - - - ---- - - - - - - - - . _ . - - - Yes- SOPE.press rating appropriate; test to.(put prig in comments)- - - - - - - - - - - - - - - - - Yes - - - - - MPSP is 3033 psig; will test BOPs to 3500-psig. Chokemanifoldcomplies w/API RP -53 (May 84)- - - - - _ _ _ - - - _ - _ _ _ . _ . - Yes - - ---- - - - - - - - - - - - - - - - - ------ - - - - - - - Work will occur without operation shutdown - . Yes Is presence of H2S gas. probable.... - .. ..... - - - - - - _ Yes _ - - - _ H2$ measures required. Mechanicalconditionof wells within AOR verified (For service well only) - - - - - - - - - NA_ _ ------ Permit can be issued w/o hydrogensulfide measures - - - - - - - - - - - - - - - No - - - - _ - - Wells.on.1D-Pad are.H2S-bearing. H2$ measures required. ....... Data presented on potential overpressure zones ... . .. .......... Yes ...... Max. potential res. pressure is 11.2 ppg EMW; expected res. pressure is 9.2 ppg EMW. Well will be - Seismic analysis of shallow gas zones_ - - - - - - - .... - - - NA- - - - - - drilled using B.6. ppg mud,. a roiled -tubing. ng, and managed pressure drilling technique to control .. _ . _ _ Seabed condition survey (if off -shore) . . . . . . . . . ...................... . NA ...... - formation pressures and stabilize shale sections withconstantBHP of about 11.8 ppg EMW, - ... _ Contact name/phone for weekly -progress reports [exploratory only] - - - - - - - - - - - - - - - - NA - - - NOTE: Chance of encountering free -gas while_driting due to gas injection performed in.this area.. - - ❑d Geologic Commissioner: Date: Engineering Commissioner: Date Public Date Co ISIS �Z 2C11 �4. /? -2-5L-le �z I Ii'e ,
