The URL can be used to link to this page

Home My WebLink About219-036DATA SUBMITTAL COMPLIANCE REPORT 7/112019 Permit to Drill 2190360 Well Name/No. KUPARUK RIV UNIT 3F-011.1 Operator ConocoPhillips Alaska, Inc. API No. 50-029-21446-60-00 MD 11463 TVD 5825 Completion Dale 3/26/2019 Completion Status 1-0I1- Current Status 1-0I1- UIC No REQUIRED INFORMATION Mud Log No Samples No Directional Survey Yes ✓ DATA INFORMATION List of Logs Obtained: GR / Res Well Log Information: Log/ Electr Data Digital Dataset Log Log Run Interval OH/ Type Med/Frmt Number Name Scale Media No Start Stop CH ED C 30658 Digital Data 7934 11463 ED C 30658 Digital Data ED C 30658 Digital Data ED C 30658 Digital Data ED C 30658 Digital Data ED C 30658 Digital Data ED C 30658 Digital Data ED C 30658 Digital Data ED C 30658 Digital Data ED C 30658 Digital Data ED C 30658 Digital Data ED C 30658 Digital Data ED C 30658 Digital Data ED C 30658 Digital Data ED C 30658 Digital Data ED C 30658 Digital Data ED C 30658 Digital Data ED C 30658 Digital Data AOG('C Page 1 of 3 (from Master Well Data/Logs) Received _ Comments 4/25/2019 Electronic Data Set, Filename: 3F-01 L1 GAMMA Monday, July 1, 2019 RES.Ias 4/25/2019 Electronic File: 317-011-1 2MD Final.cgm 4/25/2019 Electronic File: 3F-011-1 51VID Final.cgm 4/25/2019 Electronic File: 3F-011-1 5TVDSS Final.cgm 4/25/2019 Electronic File: 3F-011-1 21VID Final.pdf 4/25/2019 Electronic File: 317-011-1 5MD Final.pdf 4/25/2019 Electronic File: 3F-011-1 5TVDSS Final.pdf 4/25/2019 Electronic File: 3F-011-1 EOW NAD27.pdf 4/25/2019 Electronic File: 317-011-1 EOW NAD27.txt 4/25/2019 Electronic File: 3F-011-1 Survey Listing.txt 4/25/2019 Electronic File: 3F-011-1 Surveys.txt 4/25/2019 Electronic File: 3F-011-1_Final Surveys TO @ 11463.csv 4/25/2019 Electronic File: 3F-011-1_Final Surveys TO @ 11463.xlsx 4/25/2019 Electronic File: 3F- Ot L1_25_tapescan_BHI_CTK.txt 4/25/2019 Electronic File: 3F- Ot L1_5_tapescan_BHI_CTK.txt 4/25/2019 Electronic File: 317-01 L1_output.tap 4/25/2019 Electronic File: 317-01 Lt 2MD Final.tif 4/25/2019 Electronic File: 3F-01 L1 51VID Final.tif Monday, July 1, 2019 DATA SUBMITTAL COMPLIANCE REPORT 7/1/2019 Permit to Drill 2190360 Well Name/No. KUPARUK RIV UNIT 3F -01L1 Operator ConocoPhillips Alaska, Inc. API No. 50-029-21446.60.00 MD 11463 TVD 5825 Completion Date 3/26/2019 Completion Status 1 -OIL Current Status 1 -OIL UIC No ED C 30658 Digital Data 4/25/2019 Electronic File: 3F-011-1 5TVDSS Final.tif Log C 30658 Log Header Scans 0 0 2190360 KUPARUK RIV UNIT 3F-0111 LOG HEADERS ED C 30795 Digital Data 5/17/2019 Electronic File: 3F-0111 EOW NAD27.pdf ED C 30795 Digital Data 5/17/2019 Electronic File: 3F-011-1 EOW NAD27.txt ED C 30795 Digital Data 5/17/2019 Electronic File: 3F-01 L1 EOW NAD83.pdf ED C 30795 Digital Data 5/17/2019 Electronic File: 3F-011-1 EOW NAD83.txt Log C 30795 Log Header Scans 0 0 2190360 KUPARUK RIV UNIT 3F-011-1 LOG HEADERS Well Cores/Samples Information: Sample Interval Set Name Start Stop Sent Received Number Comments INFORMATION RECEIVED Completion Report Production Test Information Y'o NA Geologic Markers/Tops YO COMPLIANCE HISTORY Completion Date: 3/26/2019 Release Date: 3/11/2019 Description Comments: Directional / Inclination Data IS Mud Logs, Image Files, Digital Data Y /9) Core Chips Y /I�D Mechanical Integrity Test Information Y / NA Composite Logs, Image, Data Files O Core Photographs Y % lA Daily Operations Summary G) Cuttings Samples Y /QA Laboratory Analyses Y le) Date Comments AUG('(' Paget of Monday, .July I, 2019 DATA SUBMITTAL COMPLIANCE REPORT 7/1/2019 Permit to Drill 2190360 Weli Name/No. KUPARUK RIV UNIT 3F -01L1 MD 11463 TVD (58/25�/��I pletion Date 3/26/2019 Compliance Reviewed By: Operator ConocoPhillips Alaska, Inc. API No. 50-029-21446-60-00 Completion Status 1-0I1 Current Status 1- L UIC No Date: /1/19 A06('C Page 3 of 3 Monday. July I, 2019 BA ER BAT a GEcompany Date: May 16, 2019 Abby Bell AOGCC 333 West 7`h Ave, Suite 100 Anchorage, Alaska 99501 219036 30 79 5 Letter of Transmittal Harvey Finch Baker Hughes, a GE Company 795 East 94`h Avenue Anchorage, Alaska 99515 Please find enclosed the directional survey data for the following well(s): 3F -01L3 3F -01L1-01 RECEIVE® MAY 1 12019 AOGCC (1) Total print 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. Harvey Finch, Baker Hughes, Wellplanner Harvey.Finch@BakerHughes.com V / ConocoPhillips ConocoPhillips Alaska Inc—Kuparuk Kuparuk River Unit Kuparuk 3F Pad 3F-01 L1 50-029-21446-60 Baker Hughes INTEQ Definitive Survey Report 22 April, 2019 BAER UGHES a GE company 2 190 36 30795 ConocoPhillips BAER ConocoPhillips Definitive Survey Report IUGHF$ Company: ConocoPhillips Alaska Inc_Kuparuk Local Co-ordinate Reference: Well 3F-01 Project: Kuparuk River Unit TVD Reference: 3F-01 @ 93.00usft (3F-01) Site: Kupamk 3F Pad MD Reference: 3F-01 @ 93.00usft (3F-01) Well: 3F-01 North Reference: True Wellbore: 3F-01-1 Survey Calculation Method: Minimum Curvature Design: 3F-01 -1 Database: EDT 14 Alaska Production Project Kuparuk River Unit, North Slope Alaska, United States Map System: US State Plane 1927 (Enact 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 3F-01 Well Position +N/S 0.00 usft Northing: 5,985,734.98 usft Latitude: 70° 22' 20.086 N +E/-W 0.00 usft Easting: 508,662.35usft Longitude: 149" 55'46.549 W Position Uncertainty 0.00 usft Wellhead Elevation: usft Ground Level: 0.00 usft Wellbore 3F-01-1 Magnetics Model Name Sample Date Declination Dip Angle Field Strength O (1) K) BGGM2018 4/1/2019 16.61 80.87 57.419 Design 3F-01-1 Audit Notes: Version: 1'0 Phase: ACTUAL Tie On Depth: 8,200.00 Vertical Section: Depth From (TVD) +N/-S +E/-W Direction (usft) (usft) (usft) (^) 03.00 0.00 0.00 180.00 Survey Program Date From To Survey Survey (usft) Wait) Survey(Wellbore) Tool Name Description Start Date End Date 100.00 8,200.00 3F-01(3F-01)GCT-MS Schlumberger GCT multishot 8/18/2000 8,245.50 8,320.79 3F-01L1 MWD INC (3F-011-1) MWD-INC—ONLY MWD-INC—ONLY—FILLER 3/23/2019 3/23/2019 8,352.20 11.423.21 3F-011-1 MWD (3F-01-1) MWD MWD - Standard 3/24/2019 3/24/2019 4/22/2019 1:05:50PM Page 2 COMPASS 5000.14 Build 85D Survey ConocoPhillips ConocoPhillips Definitive Survey Report Company: ConocoPhillips Alaska Inc Kupamk Local Coordinate Reference: Well 3F-01 Project: Kupamk River Unit TVD Reference: 3F-01 @ 93.00usft (3F-01) Site: Kuparuk 3F Pad MD Reference: 3F-01 Q 93.00usft (3F-01) Well: 3F-01 North Reference: True Wellbore: 3F-011.1 Survey Calculation Method: Minimum Curvature Design: 3F-0111 Database: EDT 14 Alaska Production Survey ER i ucNs Annotation TIP TOWS/KOP Interpolated Azimuth Interpolated Azimuth Interpolated Azimuth 4/222019 1.05:50PM Page 3 COMPASS 5000.14 Build 85D Map Map Vertical MD hie Azi TVD TVDSS •N/ -S +E/ -W DLS (weft) (1) (°) (usft) (uaft) (weft) (usft) Northing Esau (°1100') Section Survey Tool Name (ft) (ft) (ft) 8,200.00 46.23 136.05 5,880.18 5,787.18 -3.837.39 3,658.19 5,981,90221 512,324.61 0.34 3,837.39 MWD -INC _ONLY (2) 8245.50 46.29 135.95 5,911.64 5,818.64 -3,861.03 3,681.02 5,981,87859 512,347.47 0.21 3,861.03 MWD -INC ONLY(2) 8270.57 53.49 135.78 5,927.78 5,834.78 -3,874.78 3,694.37 5,981,86466 512,360.63 28.72 3,874.78 MWD -INC _ONLY (2) 8,290.69 63.59 135.67 5,938.26 5,845.26 -3,88786 3,706.33 5,981,852.60 512,372.81 50.20 3,88706 MWD-INC-ONLY(2) 8,320.79 78.63 135.54 5,947.98 5,854.98 3,907.35 3,726.20 5,981,832.34 512,392.70 49.97 3,907.35 MWD -INC -ONLY (2) 8,352.20 93.59 135.41 5,950.10 5,857.11 3,92962 3,748.11 5,981,81009 512,414,63 47.63 3,929.62 MWD (3) 8,382.39 96.24 13631 5,947,52 5,854.52 3,951.21 3,769.06 5,981,788.53 512,435.60 9.27 3,951.21 MWD (3) 8,412.00 98.16 137.27 5,943.81 5,850.81 -3,972.62 3,789.17 5,981,767.15 512,455.74 7.24 3,972.62 MWD (3) 8,441.78 99.84 137.86 5,939.15 5,846.15 -3,994.32 3,80902 5,981,745.46 512,475.61 5.97 3,994.32 MWD (3) 8,472.59 100.03 13933 5,933.83 5,840.83 4.017.09 3,829.09 5,981,722.73 512,495.70 4.74 4,017.09 MWD(3) 8502.27 100.18 141.31 5,92863 5,835.63 4,039.57 3,847.74 5,981,700.27 512,514.38 6.59 4,039.57 MWD (3) 8,535.01 100.87 143.59 5,922.64 5,829.64 4.06509 3,867.36 5,981,674.77 512,53402 7.16 4,065.09 MWD (3) 8,565.43 10046 145.41 5,917.01 5,824.01 4,089.43 3,884.72 5,981,6WA8 512,55141 603 4,089.43 MWD (3) 8,595.51 99.72 147.81 5,911.74 5,818.74 4.114.15 3,901.01 5,981,62576 512,567.73 8.23 4,114,15 MWD (3) 8,625.61 99.15 149,39 5,90681 5,813.81 3,139.50 3,916.48 5,981,600.43 512,583.23 5.51 4,139.50 MWD (3) 8,655.71 98.97 151.80 5,902.07 5,809.07 4,165.39 3,931.08 5.981,574.56 512,597.85 793 4,165.39 MWD (3) 8,685.52 99.07 153.79 5,89739 5,804.39 4,191.57 3,944.54 5,981,548.39 512,611.30 6.60 4,191.57 MWD (3) 8,715.54 98.82 156.19 5,892.73 5,799.73 4,218.44 3,957.07 5,981,521.54 512,623.91 7.94 4218.44 MWD (3) 8,745.43 9897 158.% 5,866.10 5,795.10 4,245.65 3,968.55 5,981,494.35 512,635.41 6.20 4,245.65 MWD(3) 8,779.23 9826 160.63 5,883.04 5,79004 4,276.92 3,980.34 5,981,463.10 512,647.24 7.81 4,276.92 MWD (3) 8,8%.95 9744 162.66 5,878,84 5,785.84 -030.80 3,989.92 5,981,434.23 512,656.85 7.07 4,305.60 MWD(3) 8,845.75 97.09 165.13 5,874.32 5,781.32 4,339.92 3,939.77 5,981,400.13 512,666,74 6.91 4,339,92 MWD(3) 8,875.87 9668 166.94 5,87070 5,777.71 4,368.94 4,006.99 5,981,371.12 512,673,99 6.12 4,368.94 MWD (3) 8,905.99 96.68 169.06 5.867.20 5,774.20 4,398.20 4,013.20 5,981,341.87 512,680.24 6.99 4,398.20 MWD (3) 8,935.11 96.78 17164 5,863.79 5,770.79 4426.68 4,018.20 5,981,313.40 512,685.27 6.76 4,42668 MWD (3) 8,970.34 97.60 173.26 5,859.38 5,766.38 4,461.30 4,022.98 5,981,27878 512,690.08 6.67 4,461.30 MWD (3) 9,000.93 9779 175.73 5,855.28 5,762.28 4,491A7 4,025.88 5,981,24862 512,693.% 8.03 4,491.47 MWD(3) 9,036.23 99.51 17831 5,650.28 5,757.28 4,526.37 4,027.70 5,981,21373 512,694.88 7.52 4,526.37 MWD (3) 9,075.83 96.19 180.17 5,845.21 5,752.21 4,56563 4,028.22 5,981,174.47 512,695.45 748 4,565.63 MWD (3) 9,100.82 95.45 178.82 5,842.68 5,749.68 4,59049 4,02844 5,981,14961 512,695.70 6.14 4,590.49 MWD (3) ER i ucNs Annotation TIP TOWS/KOP Interpolated Azimuth Interpolated Azimuth Interpolated Azimuth 4/222019 1.05:50PM Page 3 COMPASS 5000.14 Build 85D Survey ConocoPhillips ConocoPhillips Definitive Survey Report Company: ConocoPhillips Alaska Inc_Kuparuk Local Co-ordinate Reference: Well 3F-01 Project: Kuparuk River Unit TVD Reference: 3F-01 @ 93.00usft (3F-01) Site: Kupamk 3F Pad MD Reference: 3F-01 @ 93.00usft (3F-01) Well: 3F-01 North Reference: True Wellbore: 3F-0111 Survey Calculation Method: Minimum Curvature Design: 3F-01 -I Database: EDT 14 Alaska Production Survey BA ER t _MN 4/22/2019 1:05.50PM Page 4 COMPASS 5000.14 Build 85D Map Map Vertical MD Inc Azl TVD TVDSS +N/S +E/ -W DLS (usft) (') (°) (usft) (waft) (uaft) (usit) Northing Fasdn9 (•1100') Section Survey Tool Name Annotation (ft) (ft) (ft) 9,130.92 95.88 177.99 5,839.70 5,746.70 4,620.43 4,029.27 5,981,119.67 512,696.56 3.09 4,620.43 MWD (3) 9161.01 95.45 17780 5,836.73 5,743.73 4,650.36 4,03037 5,981,089.76 512,697.70 1.56 4,650.36 MAD (3) 9,190.73 95.30 177.23 5,833.95 5,740.95 4,679.92 4,031,66 5,981,060.20 512,69902 1.98 4,679.92 MWD(3) 9,220.85 93,62 176.22 5,83161 5,738.61 4,709.90 4,033.37 5,981,030.23 512,700.77 8.50 4,709.90 MWD(3) 9,25521 9301 176.53 5,82962 5,736.62 4.744.13 4,035.54 5,980,996.00 512,702.97 199 4,744.13 MWD(3) 9,290.95 90.61 175,32 5,82849 5,73549 4,779.76 4,038.06 5,980,960.38 512,705.55 7.52 4,779.76 MWD (3) 9,32495 89.82 175.99 5,828.36 5,735.37 4,813.66 4,040.65 5,989926.48 512,708.17 3.05 4,813.66 MWD(3) 9,355.19 90.43 176.29 5,82810 5,735.30 4,843.83 4,042.69 5,980,896.31 512,710.24 2.25 4,843.83 MWD (3) 9,385.29 90.52 176.60 5,828.05 5,735.05 4,873.87 4,044.56 5,980,866.28 512,712.14 107 4,873.87 MWD (3) 9,415.29 90.31 176,56 5,827.83 5,73483 4,903.82 4,046.35 5,900,836.34 512,713.96 0.71 4,903.82 MWD (3) 9445.33 91,10 177.42 5,82246 5,734.46 4,933.81 4,047.92 5,980,806.35 512,715.58 3.89 4,933.81 MWD (3) 9,460.95 8804 176.66 5.827.73 5,73473 4,969.38 4,049,76 5,960,770.79 512,717.46 8.85 4,969.38 MWD (3) 9,512.91 89.48 178.35 5,828.42 5,735.42 -5,001.30 4,051.15 5,980,738.87 512,718.88 6.95 5,001.30 MWD (3) 9,540.38 89.08 179.19 5,828.77 5,735.77 -5,026.76 4,051.74 5,980,711.41 512,719.50 3.39 5,028.76 MND (3) 9,570.19 89.02 17823 5,829.26 5,736.26 5,058.56 4,052.41 5,960,68162 512,720.21 3.23 5,058.56 MWD (3) 9,601.35 89.20 180.22 5.829.74 5,736.75 5,089.71 4,052.84 5,990.65047 512,720,67 6.41 5,089.71 MM (3) 9,635.27 88.37 181.19 5,830.46 5,73746 -5,123.62 4,05242 5,980,616.55 512,720.29 3.76 5,123.62 MWD (3) 9,665.33 87.72 181.52 5,831.49 5,738.49 -5,153.65 4,051.71 5,960,586.53 512,71981 2.42 5,15365 MWD (3) 9,697.43 87.32 182.97 5,832.88 5,739.88 -5,185.70 4,050.45 5,980,554.49 512,718.39 4.66 5,185.70 MWD (3) 9,730.17 88.10 184.18 5,834.19 5,741.19 -5,218.35 4,04841 5,980,521.84 512,716.39 4.39 5,218.35 MWD (3) 9,765.85 85.30 18558 5836,24 5,743.24 5,253.84 4,045.38 5,980,486.35 512,71341 8.77 5,253.84 MWD (3) 9,790.25 86.21 186.51 5,838.05 5,745.05 5,278.03 4,042.82 5,980,462.16 512,710.87 5.33 5,27803 MWD (3) 9,820.22 8736 187.92 5,83973 5,746.73 5,307.72 4,039.06 5,980,432.47 512,70715 6.50 5,307.72 MM (3) 9,850.83 87.45 189.22 5,841.11 5,748.11 5,33795 4,034.50 5,980,402.23 512,702.63 4.25 5,337.95 MND (3) 9,885.95 88.12 189.50 5,84247 5,749.47 -5,372.58 4,02880 5,980,367.60 512,696.96 2.07 5,372.58 MM (3) 9,915.79 88.09 188.98 5,843.46 5,750.46 5,402.02 4,024.01 5,980,338.16 512,692.21 1.74 5,402.02 MWD (3) 9,945.91 87.97 188.61 5,844.49 5,751.49 5,431.77 4,01941 5,980,308.41 512,687.64 1.29 5,431.77 MWD (3) 9,97585 8745 187.71 5,845,69 5,752.69 -5,461.38 4,01516 5,980,278.80 512,683.43 347 5,461.38 MND(3) 10,006.33 W87 186.24 5,847.20 5,754.20 5,491.59 4,011.46 5,960,248.58 512,679.76 5.18 5,491.59 MWD (3) 10,035.47 8763 184.37 5,848.60 5,75560 -5,520.57 4,008.77 5,960,21960 512,677.11 6.92 5,520.57 MND(3) 10,066.13 90.71 18370 5,849.04 5,75604 -5,551.15 4,006.62 5,960,189.02 512,674.99 10.28 5,551.15 MWD (3) BA ER t _MN 4/22/2019 1:05.50PM Page 4 COMPASS 5000.14 Build 85D Survey ConocoPhillips ConocoPhillips Definitive Survey Report Company: ConocoPhillips Alaska Inc_Kupanuk Local Co-ordinate Reference: Well 3F-01 Project: Kupamk River Unit TVD Reference: 3F-01 @ 93.00usft (3F-01) Site: Kuparuk 3F Pad MD Reference: 3F-01 @ 93.00usft (3F-01) Well: 3F-01 North Reference: True Wellbore: 3F-0117 Survey Calculation Method: Minimum Curvature Design: 3F -01L7 Database: EDT 14 Alaska Production Survey Annotation Bf UR 412212019 1:05:50PM Page 5 COMPASS 5000.14 Build 65D Map Map Vertical MD Inc Azi TVD TVDSS +N/S +E/ -W DLS (usR) (1) V) (usR) (usR) (usft) (usft) Northing Essting (•F100y Section Survey Tool Name (R) (R) ( 095] 10,9 92.92 183.11 5,848.10 5,755.10 -5,580.74 4,004 .85 5,960,159.43 512,673.26 7.71 5,5,5 80.74 MWD (3) 10,126.05 9406 180.04 5,646.26 5,753.26 -5,610.93 4,004.02 5,980,12925 512,672.46 10.80 5,610.93 MWD(3) 10,156.09 96.55 180.11 5,843.48 5,75048 -5,640.84 4,003.99 5,980,099.34 512,672.46 8.29 5,640.84 MWD (3) 10,185.41 94.64 17668 5,840.62 5,747.62 5,670.00 4,004.80 5,980,070.18 512,673.31 13.34 5,67000 MWD (3) 10,215.71 96.34 176.10 5,837.73 5,744.73 5,700.10 4,006.70 5,980,04009 512,67525 5.93 5,700.10 MWD(3) 10,245.57 97.11 173.62 5,834.23 5,741.23 5,72964 4,009.36 5,980,010.56 512,677.94 8.64 5,729.64 MWD (3) 10,275.49 97.69 17036 5,830.37 5,737.37 5.75901 4,013.49 5,979,98119 512,682,10 10.98 5,759.01 MWD (3) 10,305.97 97.35 168.50 5,826.38 5,733.38 -5,788.72 4,019.03 5,979,951.50 512,68768 6.15 5,788.72 MWD(3) 10,336.05 97.20 167.19 5,822.57 5,729,57 5,81788 4,02532 5,979,92234 512,693.99 4.35 5,81288 MWD (3) 10,379.12 95.40 163.01 5,817.85 5.724.85 5,859.24 4,036.32 5,979,881.00 512,70505 10,51 5,85924 MWD (3) 10,410.67 96.16 162.30 5,81466 5,72166 5,689.20 4,045.68 5,979,851.05 512,714.44 334 5,889.2D MVID(3) 10,439.95 96.45 165.43 5,81144 5,718.44 -5,917.16 4,053.77 5.979,823.11 512,722.56 10.66 5.917.16 MWD (3) 10,470.32 96.40 168.55 5,80604 5,715.04 5,946.56 4,060.56 5,979,793.72 512,729.39 1021 5,946.58 MWD (3) 10,500.37 96,64 170.41 5,804.63 5,711.63 5,975.91 4,066.01 5,979,764.38 512,734.87 6.20 5,975.91 MWD (3) 10,530.10 95.91 171.56 5,801.38 5,708.38 5,005.10 4,070.64 5,979,735.20 512,739.53 4.56 6,005.10 MWD (3) 10,%0.20 91.20 171.42 5,799.52 5,706.52 -6,034.80 4,075.09 5,979,705.50 512,744.01 15.65 6,034,80 MWD (3) 10,589.85 9203 173.63 5,798.68 5,705.68 -6,064.18 4,078.94 5,979,676.13 512,747.90 7.96 6,064.18 MWD (3) 10,619.65 91.69 175.23 5,797.71 5,704.71 -6,093.83 4,081.83 5,979,646.49 512,750.83 5.49 6,093.83 MWD (3) 10,649.74 90.92 177.87 5,797.03 5,704.03 -6,123.85 4,083.64 5,979,616.47 512,752.67 9.14 6,123.85 MWD (3) 10.681.03 89.23 178.99 5,796.99 5,703.99 -6,155.13 4,084.50 5,979,585.20 512,753.56 6.48 6,155.13 MWD (3) 10,710.15 88.16 180.29 5,797.65 5,704.65 -6,184.24 4,084.68 5,979,556.09 512,753.78 5.78 6,184.24 MWD (3) 10,739.68 86.93 182.72 5,798.91 5,705.91 -6,213.73 4,083.91 5,979,526.60 512,753.04 9.22 6,21373 MWD (3) 10,767.25 86.31 184.55 5,800.54 5,707,54 -6,241.19 4,08217 5,979,499.14 512,751.33 7.00 6,241.19 MWD (3) 10,800.19 86.86 186.82 5,802.50 5,709.50 -6,27391 4,078.91 5,979,466.42 512,748.11 7.08 6,27391 MWD(3) 10,833.73 90.43 188.85 5,803.29 5,710.30 -6,307.12 4,074.34 5,979,43321 512,743.58 12.24 6,307.12 MWD (3) 10,850.86 92.15 190,70 5,802.91 5,709.91 -6,324.00 4,071.43 5,979,416.33 512,74069 14.74 6,324.00 MWO(3) 10,879.86 92.33 193.80 5,801.78 5,70878 -6,352.31 4,065.28 5,979,388.01 512,734.57 10.70 6,352.31 MWD (3) 10,911.18 89.95 193.51 5,83129 5,70829 6,38274 4,05289 5,979,357,58 512,727.22 9.24 6,382.74 MWD(3) 10,940.66 86.25 192.83 5,802.39 5,709.40 -6,411.43 4,051.23 5,979,328.88 512,720.59 11.26 6.411.43 MWD(3) 10,968.81 85.69 191.20 5,804.37 5,711.37 6,438.91 4,04543 5,979,30140 512,71483 544 6,436.91 MW0(3) 11,000.80 86.13 189.84 5,80666 5.,713.66 547028 4.039.61 5,979,270.03 512,709.04 446 6,47028 MWO(3) Annotation Bf UR 412212019 1:05:50PM Page 5 COMPASS 5000.14 Build 65D ConocoPhillips OA ER ConocoPhilli S Definitive Survey Report UGU ES Company: ConocoPhillips Alaska Inc Kuparuk Local Co-ordinate Reference: Well 3F-01 Project: Kuparuk River Unit TVD Reference: 3F-01 @ 93.O0usft (3F-01) Site: Kuparuk 3F Pad MD Reference: 3F-01 Q 93.O0usft (3F-01) Well: 3F-01 North Reference: True Wellborn; 3F-0117 Survey Calculation Method: Minimum Curvature Design: 31F-0111 Database: EDT 14 Alaska Production Survey _. MD Inc Azl TVD TVD$$ +N16 +iNorthing Map Map OLS Vertical (uaft) C) (') (usft) (usft) Well (usft) Eastin9 (°1100') Section Surve Tool Name y (ft) (ft) (ft) 11,031.58 87.02 187.13 5,808.49 5,715.49 6,500.66 4,03507 5,979,23064 512,704.54 9.25 850066 MWD (3) KW 67 87.35 183.06 5,809.92 5,716.92 6,529.60 4,032.49 5,979,21071 512,701.99 1402 6,529.60 MAID (3) 11,092.31 8236 179.89 5,811.38 5,71838 6,561.19 4,031.68 5,979,179.12 512,701.22 10.01 6.561.19 MWD (3) 11,125.13 88.31 17870 5,812.62 5,719.62 6,593.98 4,032.08 5,979,146.33 512.701.66 4.64 6,593.98 MWD (3) 11,154.94 88.50 177.03 5,813.45 5,720.45 6,623.76 4,033.19 5,979,116.55 512,702.80 564 6,623.76 MWD(3) 11,185.99 87.08 175.48 5,814.65 5,721.65 6,654.72 4,035.22 5,979,085.60 512,704.87 6.77 6,654.72 MWD (3) 11=11 87.85 178.89 5,816.16 5,723.16 6,688.76 4,036.89 5,979,051.57 512,706.58 10.24 6,68876 MWD (3) 11,249.86 89.17 181.28 5,816.93 5,723.93 6,718.50 4,036.85 5,979,02183 512,706.57 9.17 6,718.50 MWD (3) 11,280.63 87.57 183.69 5,817.81 5,724.81 6,749.22 4,035.52 5,978,991.11 512,705.27 9.40 6,74922 MWD (3) 11,311.01 86.93 18578 5,819.27 5,726.27 6.779.46 4,03301 5,978,960.87 512,702.80 7.19 6,779.46 MWD (3) 11,341.13 86.07 188.40 5,821.11 5,728.11 6,80929 4,02930 5,978,931.04 512,699.13 9.14 6.809.29 MWD (3) 11,370.49 86.93 190.36 5,822.88 5,729.88 6,838.20 4,024.53 5.978,902.12 512,694.38 7.36 6,838.20 MWD (3) 11,400.79 89.36 193.56 5,823.85 5,730.85 6,867.82 4,018.25 5,978,872.60 512,688.14 13.14 6,867.82 MWD (3) 11,42321 8843 196.20 5,824.28 5,731.28 6,889.49 4,012.49 5,978,850.83 512,682.41 12.48 6,889.49 MWD (3) 11,463.00 88.43 196.20 5,825.37 5,732.37 6,927.68 4,001.40 5,978,812.62 512,671.36 0.00 6,927.68 PROJECTED to TO Annotation 4222019 1:05:50PM Page 6 COMPASS 5000.14 Build 85D RGENED STATE OF ALASKA APR 2 J 2019 ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT A 1a. Well Status: Oil El • Gas❑ SPLUG ❑ Other [I Abandoned ❑ Suspended ❑ 20AAC 25.105 20AAC 25.110 GINJ❑ WINJ❑ WAGE] WDSPL❑ No. of Completions: 1b. Well Class: Development 2] Exploratory F_] Service ❑ Stratigraphic Test El 2. Operator Name: ConocoPhillips Alaska, Inc. 6. Date Comp., Susp., or Aband.: 3/26/2019 14. Permit to Drill Number / Sundry: 219-036 3. Address: P.O. Box 100360 Anchorage, AK 99510-0360 7. Date Spudded: 3/20/2019 15. API Number: 50-029-21446.60-00 4a. Location of Well (Governmental Section): Surface: 89' FNL, 162' FWL, See 29, T112N, R9E, UM Top of Productive Interval: 3950' FNL, 3829' FWL, Sec 29, T12N, R9E, UM Total Depth: 1737' FNL, 4139' FWL, Sec 32, T12N, R9E, UM 8. Date TD Reached: 3/22/2019 16. Well Name and Number: KRU 3F-011.1 ' 9. Ref Elevations: KB:93 GL:52 ' BF: 17. Field / Pool(s): Kuparuk River Field/Kupamk River Oil Pool - 10. Plug Back Depth MD(rVD: .11448/5825 18. Property Designation: ADL 25643, ALK 2574 4b. Location of Well (State Base Plane Coordinates, NAD 27): Surface: x- 508662 - y- 5985735 Zone- 4 TPI: x- 512347 y- 5981879 Zone- 4 Total Depth: x- 512671 y- 5978813 Zone- 4 11. Total Depth MD/TVD: • 11463/5825 • 19. DNR Approval Number: LONS 83.129 12. SSSV Depth MD1TVD: N/A 20. Thickness of Permafrost MD/TVD: 1593/1523 5. Directional or Inclination Survey: Yes ❑� • (attached) No ❑ Submit electronic and printed information per 20 AAC 25.050 13. Water Depth, if Offshore: NIA (ft MSL) 121. Re-drill/Lateral Top Window MD/TVD: 1 8245/5912 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 CASING FT GRADE SETTING DEPTH MD SETTING DEPTH TVD HOLE SIZE AMOUNT CEMENTING RECORD PULLED TOP BOTTOM TOP BOTTOM 16 62.5 H-40 37 115 37 115 24 348sx AS 11 95/8 36 J-55 37 3971 37 3062 12 114 1020sx PF "E", 400sx PF "C" Top Job Performed w/50sx PF "C" 7 26 J-55 35 8646 35 6187 81/2 325sx Class G, 250 sx PF "C 24. Open to production or injection? Yes R] No ❑ If Yes, list each interval open (MD/TVD of Top and Bottom; Perforation Size and Number; Date Perfd): SLOTTED LINER @: COMPLUION 9028-11448 MD and 58525825 TVDDq,TE • -I 'Wy/.��_/ W -IM&W �r� --- 25. TUBING RECORD SIZE DEPTH SET (MD) PACKER SET (MDITVD) 3112 8303 7974/5723, 8280/5936 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. Was hydraulic fracturing used during completion? Yes No EJ 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: 4/5/2019 Method of Operation (Flowing, gas lift, etc.): GAS LIFT Date of Test: 417/2019 Hours Tested: 19hrs Production for Test Period Oil -Bbl: 26 Gas -MCF: 75 Water -Bbl: 2440 Choke Size: 146 Gas -Oil Ratio: 2.88 Mcf/bbl Flow Tubing Press. 152 Casino Press: 716 Calculated 24 -Hour Rate Oil -Bbl: , 33 Gas -MCF: 95 Water -Bbl: �j 1 3082 Oil Gravity- API (corr): 23.4 Form 10-407 Revised 5/2017 VTL 5�i �/9 CONTINUED ON PAGE 2 RBDMS APR 2 6 201%ubmit ORIGINIAL /� K'.7,11on 28. CORE DATA Conventional Core(s): Yes ❑ No 0 Sidewall Cores: Yes ❑ No ❑� If Yes, list formations and intervals cored (MD/TVD, From/To), and summarize lithology and presence of oil, gas or water (submit separate pages with this form, if needed). Submit detailed descriptions, core chips, photographs, and all subsequent laboratory analytical results per 20 AAC 25.071. 29. GEOLOGIC MARKERS (List all formations and markers encountered): 30. FORMATION TESTS NAME MD TVD Well tested? Yes ❑ No ❑� If yes, list intervals and formations tested, briefly summarizing test results. Permafrost - Top Surface Surface Permafrost - Base 1593 1523 Attach separate pages to this form, if needed, and submit detailed test Top of Productive Interval 8245 5911 information, including reports, per 20 AAC 25.071. Formation @ TPI -Kuparuk TD 11463 5825 Formation at total depth: Ku aruk 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, paleontolooicalr r ion or well test results, oer 20 AAC 26,070, 32. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Authorized Name: James Ohlin er Contact Name: _Ryan McLaughlin Authorized Title: Staff CTD Engineer Contact Email: ryan.mclaughlinacop.com Authorized Contact Phone: 265-6218 Signature: Date: 41isl= INSTRUCTIONS General: This form and the required attachments provide a complete and concise record for each well drilled in Alaska. Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed. All laboratory analytical reports regarding samples or tests from a well must be submitted to the AOGCC, no matter when the analyses are conducted. Item 1 a: Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Item 1b: Well Class - Service wells: Gas Injection, Water Injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Item 4b: TPI (Top of Producing Interval). Item 9: The Kelly Bushing, Ground Level, and Base Flange elevations in feet above Mean Sea Level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 15: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). Item 19: Report the Division of Oil & Gas / Division of Mining Land and Water: Plan of Operations (LO/Region YY-123), Land Use Permit (LAS 12345), and/or Easement (ADL 123456) number. Item 20: Report measured depth and true vertical thickness of permafrost. Provide MD and TVD for the top and base of permafrost in Box 29. Item 22: Review the reporting requirements of 20 AAC 25.071 and, pursuant to AS 31.05.030, submit all electronic data and printed logs within 90 days of completion, suspension, or abandonment, whichever occurs first. Item 23: Attached supplemental records should show the details of any multiple stage cementing and the location of the cementing tool. Item 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, or Other (explain). Item 28: Provide a listing of intervals cored and the corresponding formations, and a brief description in this box. Pursuant to 20 AAC 25.071, submit detailed descriptions, core chips, photographs, and all subsequent laboratory analytical results, including, but not limited to: porosity, permeability, fluid saturation, fluid composition, fluid fluorescence, vitrinite reflectance, geochemical, or paleontology. Item 30: Provide a listing of intervals tested and the corresponding formation, and a brief summary in this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Item 31: Pursuant to 20 AAC 25.070, attach to this form: well schematic diagram, summary of daily well operations, directional or inclination survey, and other tests as required including, but not limited to: core analysis, paleontological report, production or well test results. Form 10-407 Revised 5/2017 Submit ORIGINAL Only 3F-01 Final CTD Schematic i 6" 62# H-40 shoe 9-5/8" 40# 1.55 shoe 3971' MD C -sand parts 8086' - 8219' MD KOP (a3 8243' MD A -sand parts 8417'- 8423' MD 8428'- 8468' MD 8498'- 8526' MD 7" 26# J-55 shoe 8646' MD 3-1/2" Camco DS nipple @ 518' MD (2.875" min ID) 3-112"9.3# L-80 EUE 8rd Tubing to surface 3-1/2" Camco gas lift mandrels @ 3163', 4851', 5997', 6841', 7474', 7896' MD Baker 3-112" PBR @1 7960' MD (3" ID) Baker FHL packer @ 7974' MD (4.0" ID) 3-1/2" Camce MMG production mandrels @ 8012' MD AVA BP Ported Nipple Q 8266' MD (2.3" min ID) XO 3.5" to 2.875" Baker FBA packer @ 8280' MD (4.0" ID) Baker SBE @ 8283' MD 3-1/2" Camce D landing nipple @ 8295' MD (2.25" min ID, No -Go) w/2.25" CA -2 Plug, 30' of sand on top of plug to 8265', cement from 8265' to KOP (8243') Camco SOS @ 8303' MD 3F-011-1-01 TD: 11,401' MD TOL: 8,236' MD BOL: 11,401' MD 2-3/8" slotted liner w/deployment sleeve 3F-011_1 TD: 11,463' MD TOL: 9028' MD BOL: 11,448' MD 2-3/8" slotted liner w/liner top billet KUP PROD WELLNAME 3F-01 WELLBORE 3F-01 rs Well Attribut, Max Angle, 1 TD Cw�ocoPhdli 71d means WellbereAPUUWI WellWresraWs ampu. GCIB (ttNBI Alaska, 1]ro KUPARUK RIVER UNIT 500292144600 PROD 2.85 3,100.00 87300 NIPPLE 1120 181112015 ILa,AWO: v., 114-37-11s2:m AM Last Tag Vassal s LvnN(sman Animal DeptnikKBl I End Date WelllwreLu[M"By East Tag: SLM 8486.0 7/912017 F-01 zCi b ej w,NDER; sso Last Rev Reason Armsetion End Dat WenEore I ISM MW By REV REASON: POST RIG GLV INSTALL 141111LI9 3F-01 aappteh Casing Strings Ca:me Dencrism 000n1 ID bN Top mKBI set Wpm (rtrce) 0"' b(Nol en. p... Top rnrnd 6pmi250 11 CONDUCTOR 16 1506 37.0 115.0 1150 62.50 H40 wELOED 11 Calm. Oescriesom OD(m) ID bnl Top@KB) Set open (MO) SM Depth Uvin_. WBIen(I Top Tnread CONDUCTOR, 3704150 1j,atle SURFACE 9518 8.92 37.0 3,970.6 3,061.6 36.00 J-55 BTC Wsinp..'as. OD 9111 ID bn) TepglllB) SM Damm heel SM Oepm (TVDL-Len p.,.Greee TOPTnre.5 xIPPIE; sort A. Ita PRODUCTION 7 6.28 35.0 8,646.1 518].1 26.00 J-55 BTC Tubing Strings I m"S Descnpnon sbina as._ID(inl Top aper set Depm(Ren sal Oapm ITVDI(... wrylom) Grade Top Cmrech, TUBING -WO 3112 2.99 33.0 ),9685 5)19.1 it L.EUEBrdo Does Un: 3,1626 Completion Details Into RVDI Top incl Nomsal Tov poon (past (•) nem Des cam 10 (in) 330 33.0 J(U HANGER FMC TUBING HANGER 2.992 5181 5180 399 NIPPLE CAMCO 2.87S 'IDS' NIPPLE 2875 SURFACE: 3703.91 7,9558 5,7102 4583 1 LOCATOR BAKER LOCATOR 38M 7,956.6 5,710.8 1 4582 SEAL ASSY BAKER SEAL ASSY me PBR, 3-6"Stick-u D 2990 GAS UFr:4a50.s ruelnp Dasonp4on shin-Ma...1. n) Top(flKel BM Depth W.8M DeathRVDI (... wt llUfl) Dreae rap connmlbn TUBING -Original 312 2.99 7,960.2 8,3034 5,9516 9.20 J-55 EUE BRD 3.5"x2.875" @8279' Completion Details GAS LET. S..a Top RVD) Top Ind Nominal rop(Ne) Inge) 1') Ism Des Can mpn) 7,989.2 5,7133 45.81 PBR BAKER PBR 3.000 7073.9 57229 45.75 PACKER BAKER FHL PACKER 3000 OASUFT;5840.4 8,2659 59257 46.32 NIPPLE AVA BPL PORTED 05B NIPPLE 30 62682 5,927.3 4633 XO -Reducing 7-69SOVER 35TO2875" 2.441 8,278.4 5 934.3 4634 LOCATOR BAKER LOCATOR 0 G98 LIR:].0]43 8.280.2 5,935.6 4634 PACKER BAKER Fe -i PACKER 4.000 8,283.4 5,9378 4635 SBE BAKER SEAL BORE EXTENSION 4.0D0 8,2952 5,945.9 4636 NIPPLE CAMCO D NIPPLE NO GO 2250 Gas LIFT; Tell 8,3027 5,951 .1 4638 SOS CAMCO SHEAROUT SUB 2441 Other In Hole (What retrievable plugs, valves, pumps, fish, etc.) Top (WO) Top incl LOCATOR', nests Top (SKID (flan) rl Des Com Run Date ID On) 8,2430 5.909.9 46.29 WHIP T K- Set .5"mon-bore XL top AD 8243' bottom 8253.5' 31192019 1000 st; SEAL As7R PER; ],NL2 MONOBORE 8,265.0 5,925.1 46.32 Sand Plug Dump bailed sand on 5" A2 phug w/-5' Of Sam a caN 31412019 0000 PPCKER; ],9]0a ql tOp. P1Oditloncash,0 Po0 8.6,0000"" 0 8.295.0 5,945.8 46.36 plug Set225"GAS Plug 311/2019 0.000 Ma:OucnON:amV Perforations & Slots snot Wna ]ep(WD) Etm nvD) pnobm Top("" B1. MIKE) hmm DUKE) unxwzae Dam ) Type Cam Wmax FNe. ma Ones IPERF sorooe.x+eo 8.066.0 8,219.0 5,787.1 5,8933 03,0-2.0-1, UNIT B. 31 112712985 12.0 IPERF 120 deg. Phasing, 5' HJ II Csg Gun 8,417.0 8,423.0 8,029.8 6,033 9 A4, Y41 11/2711985 4.0 IPERF 90 tleg' phasing, 4' HJ II Gag Gun 8,428.0 $468.0 ,037 4 8,084.6 A3, 3F-01 11127/1985 4.0 (PERF 0 deg, Dhasing, d' HJ II Csg Gun 8,4980 8,526.0 6,085.4 6,104.7 A-2,31`-01 11/2711985 40 IPERF 90 tleg. phasing, 4"HE II WNIPsiOCK-MOHOBORE: sg Gun e.z4a.o Cement Squeezes Tap Union) me"VD) NIPPLE, 8,$50 p+K TopB) Btm(nKm ("a) (nKB) Des stun Dale Cam 8000.11 8,265.0 5,7410 5,925.1 Protluua 31812019 JS Onto, DO PPG CLASS G CEMENT PUMPED denspass&26.9 PACKER', emD2 Casing Cement INTO FORMATION $123.0 8,285.0 5,828.8 5,925.1 Cement Plug 31&2019 thOLO158 `RU CLASS G CEMEN I LAID IN SBE; 6.m54 IZ TUBING I I I Mantlrel Inserts an MIPLE;BiG2 am Pyp;6�q H Top(ND) Valve Latin PORsiae TRO Run I" (Ron (amin Metea ..'ed dery Type rate, him (Rad Run Data Lom 3,162.8 2,5]1.1 CAMCO MMG1112 GAS LIFT GLV RK SAM 1,204.0 41112019 2 4,850.5 3,624.8 CAMCO MMG 1112 GAS LIFT OV RK 0.250 0.0 41112019 sm. 40321 3 5,996.9 4,370.4 CAMCO MMG 112 GAS LIFT DMY RK 0.000 0.0 41112019 4 6,8404 4.940.4 CAMCO MMG 112 GAS LIFT DMY RK 0.0011 0.0 4112019 5 7,474) 5,3765 CAMCO MMG 112 GAS LIFT DMY RK 0.000 0.0 411/2019 6 7,8963 5,6688 CAMCO MMG 112 GAS LIFT DMY RK 0.000 0.0 411/2019 7 8,0117 5,749.3 CAMCO KBUG 1 PROD DMY BK 0.000 0.0 5118/1988 IVERF: a411oe,ezm_ Notes: General & Safety End DMa Annomlmn 5142003 NOTE:WAIVERED WELL: IA x OA COMMUNICATION IPESEA0 80s489U- IPEflF; a4WOd,5m.0� PRODUCTION, DECES81 ConocoMillips Alaska,(Llc. KUP PROD WELLNAME 3F-01 UNIT WELLBORE 3F -01L1 1141L1, i21R01911:31E0M1 ICasingStrings VVYaI VJW1u0c Iaa�Il casino 0e:cription o0 (int LI LINER 20W to lip rov lRKel 199 Q028.2 9H oepM (xl(M) AI MpM jNo1... WVLen 11.=80 5,8250 =60 (I Ism Top Thread Lb0 STL ""NGE",>.o Liner Details xolnmmtD Top (nKR) Top lrvo lxKa( 1,11(-)xem see Co. lint 9,028.2 5,851.5 98.35 nncnor AMinuln Liner I Up Billet L 20 o is 11.4].8 5825.0 88.43 Other BWI Nee,(n0n-p00ed) 1.992 Perforations &Slots cONOUCTOX', 3]0.1150 SIIOL OMs Tolnl(6101 a go (nt (9Mbll1 NIFPLE:SI&I TM (BRE) 8.Rars) LInkMZone OYp Type Co. 9,03]0 11,44]0 5,850.2 5,824.9 3I2Y2019 SLOTS GLSLIFT: 3,I.s SURFRCE; 37 .M.- GIS UFT; 4,8'505 We LIFT: 5&69 Ges LIFT. EM4 .uFT: T4]49 60.5 UFT: 7.&M9 LOCATOR;],9S60 SEAL R59M 791 PBR: ], m2 PAC1gER;],9]30 Posergen Caine C. e.1MO.0nKe PRooucrloN; 9.017 On. Pos. EM0 MH IPERF: 8,0660&.2190� WHIPSTOCKMONCIRORE: 82430 NIPPLE: 6,M9 Esser PIog 62850 PTCKER: 9,,832 SEE',&2854 NIPPLE:&i8S2 PAs, 8.0 508:&AE] IPERF, 8417,0 4290 IPERF: 9@0.09,,Ns0-- IPERP 8495.08.526.0 PRODUCTION. 350&610.1 SLOTS: 9.OS7 D -11,M]0 r LI LINER, 9.029.?11,4180� 1 Operations Summary (with Timelog Depths) 3F-01 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Stan Depth Start Time End Time Dur (hr) Phase Op Code Aouviy Cada Time P -T -X Operation (Utt) End Depth (Wit) 3/15/2019 3/15/2019 2.00 MIRU MOVE RURD P Continue RD checklist, move shop & 0.0 0.0 15:00 17:00 1/2 -Way house from 2G-Pag to 317 - Pad, secure stairs & landings, secure BOP's 3/15/2019 3/15/2019 3.00 MIRU MOVE RURD P Complete RD checklist, RU to NES 0.0 0.0 17:00 20:00 trucks, pull modules off well, jeep -up modules, ready to move 3/15/2019 3/1612019 4.00 MIRU MOVE MOB P Begin move from 2G -Pad to 3F -Pad 0.0 0.0 20:00 00:00 3/16/2019 3/1612019 3.50 MIRU MOVE MOB P Arrive at 3F -Pad 0.0 0.0 00:00 03:30 3/1612019 3/16/2019 4.50 MIRU MOVE MOB P Spot sub & pits over well, lay mats, 0.0 0.0 03:30 08:00 drop stairs 311612019 3/16/2019 1.50 MIRU MOVE RURD P Begin RU checklist, get COMMS up, 0.0 0.0 08:00 09:30 set -down shop & lay mats, install scaffolding & platform around well 3/16/2019 3/16/2019 2.50 MIRU MOVE NUND P Continue RU checklist, spot tiger -tank 0.0 0.0 09:30 12:00 & MU hard-line, begin NU BOPE, MU PUTZ, grease tree valves & Tangos, complete NU BOP `• Rig Accept: 3/16/19 @ 1200 hrs 3/16/2019 3/16/2019 2.10 MIRU WHDBOP OTHR P Complete RU checklist, grease Bravo 0.0 0.0 12:00 14:06 & Romeo valves, fluid pack lines 3/16/2019 3/16/2019 0.40 MIRU WHDBOP PRTS P Perform shell test 5000 psi 0.0 0.0 14:06 14:30 3/16/2019 3116/2019 7.00 MIRU WHDBOP BOPE P Begin BOP test (250 low 13500 high) 0.0 0.0 14:30 21:30 F/P Lower 2", cycled once and passed. •• Witnessed by Matt Herrera of the AOGCC 3/1612019 3/16/2019 1.00 MIRU WHDBOP RURD P PT tiger tank lin and PDL to 250 / 0.0 0.0 21:30 22:30 3500 psi - goad, checked pack offs 3/16/2019 3/16/2019 1.00 MIRU WHDBOP RURD P Blow down post BOP test, open well 0.0 0.0 22:30 23:30 and confirm zero pressure. Pick up elevators, prep floor for picking up tools. 3/16/2019 3/17/2019 0.50 SLOT WELLPR PULD P PJSM, PU BHA#1 and load into a 0.0 63.0 23:30 00:00 dead well. 3/17/2019 3/17/2019 0.80 SLOT WELLPR PULD P Compete BHA#1 and load into a dead 0.0 63.0 00:00 00:48 1 1 1 well, Bump up, set counters. 3/17/2019 3/17/2019 1.20 SLOT WELLPR TRIP P RIH W BHA #1. 63.0 7,960.0 00:48 02:00 311712019 3/17/2019 0.30 SLOT WELLPR DLOG P Tie into K1 for -4.5' correction Note 7,960.0 8,011.0 02:00 02:18 Kt is 7963' 3/17/2019 3117/2019 1.00 SLOT WELLPR DISP P Pump seawater flush, CT 6100 psi, @ 8,011.0 8,027.0 02:18 03:18 2.4 bpm, - 220 bbls total 3/17/2019 311712019 0.50 SLOT WELLPR DISP P Start pumping cement milling fluid, 1 8,027.0 8,032.0 03:18 03:48 ppb Power Pro with 0.5% tubes 7761 low torque. 3/17/2019 3/17/2019 0.20 SLOT WELLPR TRIP P After 15 bbls drilling fluid out the bit, 8,032.0 8,119.0 03:48 04:00 park,ctose EDC, RIH, tag bottom @ 8119' Page 1116 ReportPrinted: 4/8/2019 Operations Summary (with Timelog Depths) 3F-01 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Stan Depm Start Time End Time our (hr) Phase Op Code Activity Code Time P -T -X Operation (aKB) End Depth (fiKB) 3/17/2019 3/17/2019 1.00 SLOT WELLPR DRLG P PU Wt 29 k lbs, Set rate, CT 3512 psi 8,119.0 8,129.0 04:00 05:00 @ 1.89 bpm, diff 454, BHP 3121 psi - 10.37 EMW @ sensor. WH 73 psi, RIH Wt 13 k lbs OBD, CT Wt 10.7 k lbs, WOB 0.8 klbs, 40 ft/hr w 100 lbs of motor work. Stall 8124' PU 30 k lbs Stall 8124' PU 34 k lbs Set ROP to 20 it/ hr, drill ahead Stall 8130' PU 32 k lbs 3/17/2019 3/17/2019 1.70 SLOT WELLPR DRLG P Continue milling, pumping 1.87 bpm, 8,129.0 8,151.9 05:00 06:42 CWT =11.2K, WOB=.5K, pump= 3562 ps, Stalls at: 8129', 8132', 8137', PUW = 26K from 8151', wiper to 8076' 3/17/2019 3/17/2019 1.50 SLOT WELLPR DRLG P Drilling, FS = 440 psi @ 1.87 bpm, 8,151.9 8,172.0 06:42 08:12 stall getting started, PUW = 26K, annular = 3173 psi, bleed down IA from 1077 (1 hr, drops to 350 psi, shut-in & climbs back to 1050 psi). Stalls at: 8161', 8166' (PUW = 29K) 3/17/2019 3/17/2019 0.40 SLOT WELLPR WPRT P Wiper(300'while circulating bottoms 8,172.0 8,172.0 08:12 08:36 1 1 up), PUW = 28K 3/17/2019 3/17/2019 0.90 SLOT WELLPR DRLG P Drilling cement, FS = 448 psi @ 1.9 8,172.0 8,190.0 08:36 09:30 bpm, CWT = 8.9K, WOB = 0.51K, annular = attempt more WOB to increase ROP, 0.8K WOB @ 36 fph, pump sweeps 3/17/2019 3/17/2019 0.60 SLOT WELLPR WPRT P Wiper, PUW = 28K, losing milling fluid 8,190.0 8,190.0 09:30 1006 over shakers, circulate bottoms up, losing prime on MP, resolve, swap shaker screens, reslove issue 3/17/2019 3/17/2019 1.60 SLOT WELLPR DRLG P Drilling, FS = 458 psi @ 1.93 bpm, 8,190.0 8,230.0 10:06 1142 CWT = 8.3K, WOB = 0.9K, stall 8196', PUW = 31 K, bleed down OA Stall at 8196', 8197.5', 8199', 8204', 8217', 3/17/2019 3/17/2019 0.30 SLOT WELLPR WPRT P Wiper, PUW = 28K, circulate bottoms 8,230.0 81230.0 11:42 12:00 up, set-downl OK WOB at 8000' (No Jewelry at that depth. Update: GLM at corected depth of 8000') 3/17/2019 3/17/2019 1.20 SLOT WELLPR DRLG T Difficulty getting started @ 8230' (7 8,230.0 8,230.0 12:00 13:12 stalls -8230', various speeds), attempt getting started at 1 fph 8229.8', stall, confer w/ town 3/17/2019 3/17/2019 0.10 SLOT WELLPR WPRT T PUH to log K1, PUW = 29K 8,230.0 7,969.0 13:12 13:18 3/17/2019 3/17/2019 0.10 SLOT WELLPR DLOG T Log Kt for+1' correction 7,969.0 7,997.0 13:18 13:24 3/17/2019 3/17/2019 0.30 SLOT WELLPR DRLG T Attempt to get started at 8230', stall, 7,997.0 8,230.0 13:24 13:42 confer w/ town, decision made to POOH & inspect tools 3/17/2019 3/17/2019 2.10 SLOT WELLPR TRIP T Pumps sweeps, POOH, PJSM, flow- 8,230.0 62.0 13:42 15:48 check 3/17/2019 3/17/2019 0.50 SLOT WELLPR PULD T LD BHA#1 62.0 0.0 15:48 16:18 3/17/2019 3/17/2019 0.50 SLOT WELLPR PULD T PU BHA#2 (new motor & D331 w/ 0.0 62.0 16:18 16:48 ridge -set mill), bit come out a 2-2 1 (broken & chipped cutters), slide in cart, MU to coil, tag up, set counters Page 2/16 ReportPrinted: 4/8/2019 Operations Summary (with Timelog Depths) 3F-01 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Stan Depth Stan Time End Time our (hr) Phase Op Code Activity Code Time P -T -X Operation (W13) End Depth (ftKS) 3/17/2019 3/17/2019 1.40 SLOT WELLPR TRIP T RIH w/BHA #2 62.0 7,970.0 16:48 18:12 3/17/2019 3/17/2019 0.20 SLOT WELLPR DLOG T Log K1 for -6' correction 7,970.0 7,998.0 18:12 18:24 3/17/2019 3/17/2019 1.90 SLOT WELLPR TRIP T Continue in hole w D331 ridge set, 7,998.0 8,231.5 18:24 2018 SD 8032', 3.5 k WOB, and again at 8040'7.5 k WOB - PU wt 34 k lbs. On bottom, 5 stalls 8231.4 to 8231.9. No hole made, variability in tag depth simply CT stack. PU and restart @ 8231.4' auto drill at 1 ft/ hr - stall 8231.6', PU and attempt tp auto drill @ 0.5' per hr, stall @ 8231.6', clean pick ups - 29 k lbs. 3/17/2019 3/17/2019 0.30 SLOT WELLPR DLOG T PU hole, 29 k lbs, Log K1 for zero 8,231.5 7,996.0 20:18 20:36 correction 3/17/2019 3/17/2019 1.20 SLOT WELLPR DLOG T Swap MWD over to CCL mode, log 7,996.0 8,230.0 20:36 21:48 CCL from 7848'- 8179'@ 16 ft/min CCL on with the July 2019 caliper and the tubing detail. Consult with town engineering. 3/17/2019 3/17/2019 1.40 SLOT WELLPR TRIP T POOH for venturi basket. 8,230.0 75.0 21:48 23:12 3/17/2019 3/18/2019 0.80 SLOT WELLPR PULD T LD BHA #2 over a dead well. D331 0.0 0.0 23:12 00:00 starting to ring out just past the tip. Agressive damage to that area only,diamond cutters missing in a ring and matrix removed. 2.79 NO, 2.80 go. 3/18/2019 3/18/2019 0.60 SLOT WELLPR PULD T Stand by for BOT hand bringing 0.0 0.0 00:00 00:36 venturi out -Hold Sunday Safety meeting in dog house. 3/18/2019 3/18/2019 1.00 SLOT WELLPR PULD T Pick BHA #3, Venturi with 1 ° bent sub 0.0 64.9 00:36 01:36 and 3/4 mule shoe under a HOT. Bent sub high sided. Note mule shoe scoop -180 ° out from bent sub. Skid cart, inspect pack offs - good, bump up,set counters. 3/18/2019 3/18/2019 1.60 SLOT WELLPR TRIP T RIH. 64.9 7,970.0 01:36 03:12 3/18/2019 3/18/2019 0.20 SLOT WELLPR DLOG T Tie into the Kl for a -7' correction. 7,970.0 7,997.3 03:12 03:24 3/18/2019 3/18/2019 0.20 SLOT WELLPR TRIP T continue to RIH, park, close EDC. 7,997.3 8,095.9 03:24 03:36 3/18/2019 3/18/2019 0.90 SLOT WELLPR WASH T Run in to 8200'- 8230' HS, 90, 180, 8,095.9 8,231.6 03:36 04:30 270, then worked from 8220'to bottom at HS, 90, 180, 270 while pumping 2 bpm. 3/18/2019 3/18/2019 1.70 SLOT WELLPR TRIP T Down on the pump, PU above TOC, 8,231.6 65.0 04:30 06:12 1 open EDC, POOH 3/18/2019 3/18/2019 0.50 SLOT WELLPR PULD T LD BHA #2, 3 fish in basket, upload 65.0 0.0 06:12 06:42 pictures & confer with town 3/18/2019 3/18/2019 0.70 SLOT WELLPR WAIT T Determine path forward, decision 0.0 0.0 06:42 07:24 made to make additional Venturi run 3/18/2019 3/18/2019 0.40 SLOT WELLPR PULD T PU BHA #4 Venturi with 1 ° bent sub 0.0 65.0 07:24 07:48 and 3/4 mule shoe under a HOT 3/18/2019 3/18/2019 1.50 SLOT WELLPR TRIP T RIH w/BHA #4 65.0 7,970.0 07:48 09:18 3/18/2019 3/18/2019 0.20 SLOT WELLPR DLOG T Log 1<1 for -6.5' correction, close EDC, 7,970.0 8,200.0 09:18 09:30 PUW = 30K, RIH to 8200' Page 3/16 ReportPrinted: 41812019 Uperations Summary (with Timelog Depths) 3F-01 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Stan DBPN Stan Time EM Time our (hr) Phase Op Code Activity Code Time P -T -X Operabon (WS) End Depth (M(B) 3/18/2019 3/18/2019 1.00 SLOT WELLPR WASH T Perform Venturi passes from 8200'to 8,200.0 8,230.0 09:30 10:30 8230' (d3 HIS, 90°, 180°. & 270°, 5 fpm, PUH to 8000', wash past GLM, wash down to TD twice work just off bottom, PUH & wash past 8000' one additional time 3/18/2019 3/18/2019 1.20 SLOT WELLPR TRIP T POOH, open EDC, PJSM 8,230.0 65.0 10:30 11:42 3/1812019 3/18/2019 0.50 SLOT WELLPR PULD T Flow check, LD BHA #4, cement 65.0 0.0 11:42 12:12 pieces in basket, no metal, decison made to PU bi-center bit 3/18/2019 3/18/2019 0.90 SLOT WELLPR PULD T PJSM, PU BHA#5 Cement Drilling (0° 0.0 62.0 12:12 13:06 AKO motor, RR HYC 2.98" bi-center), slide in cart, MU to coil, tag up, set counters 3118/2019 3/18/2019 1.50 SLOT WELLPR TRIP T RIH w/BHA #5 62.0 7,960.0 13:06 14:36 3/18/2019 3/18/2019 0.20 SLOT WELLPR DLOG T Log K1 for -T correction, Gose EDC, 7,960.0 7,998.0 14:36 14:48 PUW = 29K 3/18/2019 3/18/2019 0.10 SLOT WELLPR TRIP T Continue RIH 7,998.0 8,231.0 14:48 14:54 3/18/2019 3/18/2019 1.10 SLOT WELLPR DRLG P Drilling, FS = 331 psi, @ 1.9 bpm, 8,231.0 8,258.0 14:54 16:00 CWT = 11.8K, WOB = 0.7K, pump = 3462 psi, PUW = 27K from, pump 5x5 sweeps, recip from 8100' to TD, PUW = 27K 3/18/2019 3/18/2019 1.70 SLOT WELLPR TRIP P POOH, flow -check, PJSM 6,258.0 65.0 16:00 17:42 3/18/2019 3/18/2019 0.70 SLOT WELLPR PULD P LD BHA#5 65.0 0.0 17:42 18:24 3/18/2019 3/18/2019 1.30 SLOT WELLPR WAIT P Discuss caliper plan forward, agree on 0.0 0.0 18:24 19:42 190 min activation time for caliper, hand returns to truck to program tool SIMOPS: inspect & torque storage reel bolts 3/18/2019 3/18/2019 0.60 SLOT WELLPR PULD P PJSM, PU BHA#6 PDS 24 Arm 0.0 56.0 19:42 20:18 Memory Caliper, slide in cart, MU to coil, tag up, set counters 3/18/2019 3118/2019 1.50 SLOT WELLPR TRIP P RIH w/BHA #6 56.0 7,970.0 20:18 21:48 3/18/2019 3/18/2019 0.10 SLOT WELLPR DLOG P Lag K1 for -7' correction 7,970.0 7,993.0 21:48 21:54 3/1812019 3/18/2019 0.60 SLOT WELLPR TRIP P Continue RIH, PUW = 28K, RIH to 7,993.0 8,256.8 21:54 22:30 3/18/2019 3/1812019 0.70 SLOT WELLPR WAIT P Wait on caliper activation 8,256.8 8,256.8 22:30 23:12 3/18/2019 3/1812019 0.20 SLOT WELLPR DLOG P Log 8256.8'to 7800' 8,256.8 7,705.0 23:12 23:24 3/18/2019 3/1812019 0.30 SLOT WELLPR DLOG P Stop, allow arms to close, RIH & log 7,705.0 7,705.0 23:24 23:42 K1 for +1.5' correction (up -hole per PDS rep) 3/18/2019 3/19/2019 0.30 SLOT WELLPR TRIP P Begin POOH w/ BHA #6 7,705.0 6,476.0 23:42 00:00 3/19/2019 3/19/2019 1.10 SLOT WELLPR TRIP P Complete POOH, flow -check, PJSM 6,476.0 75.0 00:00 01:06 3/19/2019 3/19/2019 0.60 SLOT WELLPR PULD P LDBHA#6 memory caliper, good 75.0 0.0 01:06 0142 data. Page 4116 Report Printed: 4/812019 Operations Summary (with Timelog Depths) 3F-01 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log SMO Depen Start Time End Time our (hr) Phase Op Code Activity Code Tune P44 Operetlon ^8) End Depth ^15) 3/19/2019 3/19/2019 0.60 SLOT WELLPR PULD P PJSM, PU BHA V, dummy WS drift, 0.0 49.0 01:42 02:18 17.85' long 2.64" OD barbell shaped to mimic setting tool and WS. " Inspected coil 20' back from CTC, tested wall thickness@ 12' back from CTC, ODS 1.76", Reel 1.78", DW 1.79", DS 1.88" slight gouges, from down hole - 9' back. 3/19/2019 3/19/2019 1.50 PRODi WHPST TRIP P RIH w/ BHA#7 49.0 7,966.0 02:18 03:48 3/19/2019 3/19/2019 0.20 PROD1 WHPST DLOG P Log K1 for -6' correction 7,966.0 8,003.0 03:48 04:00 3/19/2019 3/19/2019 0.20 PROM WHPST TRIP P Continue in hole with dummy 8,003.0 8,258.6 04:00 04:12 whipstock. tag depth of 8258.55' & 1.16 k Ibs WOB, PU Wt 27 k - clean. 3/19/2019 3/19/2019 1.40 PROM WHPST TRIP P POOH w dummy WS drift 6,258.6 50.0 04:12 05:36 3/19/2019 3/19/2019 0.90 PROM WHPST PULD P Bump up, crew change, LD BHA #7 50.0 0.0 05:36 06:30 3/19/2019 3/19/2019 1.20 PROM WHPST PULD P PU BHA #8, BOT 3.5 " whipstock. 0.0 70.0 06:30 07:42 3/19/2019 3/19/2019 1.80 PROM WHPST TRIP P RIH w3.5"BOT whipstock 70.0 7,180.0 07:42 09:30 3/19/2019 3/19/2019 0.10 PROM WHPST DLOG P Tie into the K1 for a -7' correction. 7,180.0 8,000.0 09:30 09:36 3/19/2019 3/19/2019 0.20 PROM WHPST WPST P RIH to 8200', PU Wt 29 k lbs. Close 8,000.0 8,254.0 09:36 09:48 EDC, orient HS, RIH to bit depth 8253.4' Online w the pump @ 0.50 bpm, WOB built from 64 lbs to 4.6 k Ibs, sheared at 3,700 psi, WOB fell to 1.9 k lbs, SD to 3.5 k lbs. "Top of WS 8243' 0"ROHS 3/19/2019 3/19/2019 1.20 PROD1 WHPST TRIP P PU 37 k lbs, POOH 8,254.0 70.0 09:48 11:00 3/19/2019 3/19/2019 0.80 PRODt WHPST PULD P LD BHA#8, WS setting assembly 70.0 0.0 11:00 11:48 3/19/2019 3/19/2019 0.70 PROD1 WHPST PULD P PU BHA#9, l at window milling 0.0 70.0 11:48 12:30 assembly, bump up, set depths, 3/19/2019 3/19/2019 1.20 PROD1 WHPST TRIP P RIH, swapping coil over to milling fluid 70.0 7,985.0 12:30 13:42 3/19/2019 3/19/2019 0.20 PROD1 WHPST TRIP P Tie into the K1 for a -7' correction. 7,985.0 8,005.0 13:42 13:54 3/19/2019 3/19/2019 0.80 PROM WHPST DISP P Open EDC, circulate milling fluid to 7,985.0 8,092.0 13:54 14:42 surface, close EDC. 3/19/2019 3/19/2019 0.10 PROD? WHPST TRIP P RIH, dry tag TOWS 8245.2, PO Wt 29 8,092.0 8,245.2 14:42 14:48 klbs 3/19/2019 3/19/2019 0.20 PROD1 WHPST WPST P PU, set rate, RBIH 8,245.2 8,245.2 14:48 15:00 CT 4249 psi, @ 1.90 bpm, diff 481 psi, BHP 3434 psi, 11.25 ppg EMW at the window, Open choke, WH 18 psi, IA 941, OA 567. Stall 3 times, Get started on 8245.19' 3/19/2019 3/19/2019 2.20 PROD? WHPST WPST P OBD, CT Wt 11 k Ibs, WOB 0.48 k Ibs, 8,245.2 8,247.0 15:00 17:12 50 Ibs of motor work. Increase ROP to 0.8 N hr, CT 11 k Ibs, WOB 2.53 k Ibs Page 5/16 Report Printed: 41812019 Operations Summary (with Timelog Depths) 3F-01 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Time End Time our(m) Phase Op Coda Activity Code Tune PJ4 Operation Stan Deplh (MB) End Dept ntKS) 3/19/2019 3119/2019 4.80 PROD1 WHPST WPST P Continue milling window exit as per 8,247.0 8,251.2 17:12 22:00 RP and BOT rep. 1.9 bpm at 4,100 psi, Diff -489 psi,WHP=-16, BHP=3418, IA=956, OA=617 "' Note: Increased motor work @ 8,248.7', 8,249.2', and 8,249.4', motor work milled off nomally. 3/19/2019 3/19/2019 0.15 PROD1 WHPST TRIP P TD first window run, PUH to ream 8,251.2 8,243.0 22:00 2: window area, PUW=30 k "' Note: No indication of 7" contact 3/19/2019 3/19/2019 0.60 PROD1 WHPST REAM P Make reaming passes @ 60 fph x 3 8,243.0 8,251.2 22:09 22:45 3/19/2019 3/20/2019 1.25 PRODi WHPST TRIP P POOH, with closed EDC, pumping 1.9 8,251.2 1,255.0 22:45 00:00 bpm at 4,010 psi 3/20/2019 3/20/2019 0.25 PROD? WHPST TRIP P Continue POOH w/window milling 1,255.0 74.7 00:00 00:15 BHA#9 3/2012019 3/20/2019 0.75 PRODt WHPST PULD P PU/MU BHI X-Treme 1.25° bend 74.7 0.0 00:15 01:00 motor and FAT Radius mill 3/20/2019 3/20/2019 0.50 PROD? WHPST PULD P PU/MU Window Milling section #2 0.0 78.7 01:00 01:30 BHA#10 320/2019 3/20/2019 0.25 PROD1 WHPST PULD P Stab onto well, perform surface lest 78.7 78.7 01:30 01:45 (good -test) 3/20/2019 3/20/2019 1.40 PROD1 WHPST TRIP P RIH, w/BHA#10 78.7 7,980.0 01:45 03:09 3/20/2019 3/20/2019 0.20 PROD1 WHPST DLOG P Log formation (Kt marker) correction 7,980.0 8,252.0 03:09 03:21 of minus 7.0' 320/2019 320/2019 0.20 PROD1 WHPST TRIP P Continue IH, dry tag @ 8,252.05' 8,252.0 8,252.0 03:21 03:33 3/20/2019 320/2019 0.20 PROD1 WHPST TRIP P PUH, obtain pump parameters 8,252.0 8,251.9 03:33 03:45 3/20/2019 3/20/2019 2.20 PROD1 WHPST MILL P OSM, 1.86 bpm at 3,955 psi, Diff --464. 8,251.9 8,253.3 03:45 05:57 WHP=14. BHP=3,413, IA=950, OA=600 320/2019 3/20/2019 1.30 PRODi WHPST MILL P Engage auto drill 8,253.3 8,254.9 05:57 07:15 OBM, CT 4253 psi @ 1.85 bpm in and 1.85 bpm out, BHP 3490 psi. WH 117 psi, IA 961, OA 636 psi. CT 10.4 k lbs, WOB 2.1 - 2.99 k lbs 3/20/2019 3/202019 0.80 PROD1 WHPST MILL P Drill off, out of 7" @ 8254.9' 8,254.9 8,255.9 07:15 08:03 1 Reamer out @ 8255.5' 320/2019 3/20/2019 1.90 PRODt DRILL DRLG P Drilling ahead 8,255.9 8,270.0 08:03 0957 CT 4261 psi @ 1.85 bpm in and 1.85 bpm out, 666 psi diff, BHP 3498 psi, CT 9.2 k lbs, WOB 2.5 k lbs, ROP 8 fthr. Geologist confirms formation in sample. " TO Build @ 8270' 320/2019 3/20/2019 1.60 PROD1 DRILL REAM P Perform Reamming up passes at 330, 8,270.0 8,243.0 09:57 11:33 30, and 180°, down passes @ 0' ROHS. Launch TD sweeps. 3/2012019 3/2012019 0.40 PROD1 DRILL CIRC P Dry drift clean, PUH, open EDC, 8,243.0 8,123.0 11:33 11:57 chase sweeps out of coil. 3/20/2019 3/20/2019 1.40 PROD1 DRILL TRIP P POOH. 8,123.0 68.0 11:57 13:21 3/20/2019 3/20/2019 1.10 PROD1 DRILL PULD P PUD BHA #10, WH 640 psi. 68.0 0.0 13:21 14:27 3/20/2019 3/2012019 0.60 PROD1 DRILL CIRC P Pull checks, stab injector, jet stack 0.0 0.0 14:27 15:03 Page 6116 ReportPrinted: 418/2019 Uperations Summary (with Timelog Depths) 3F-01 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Time End Time our (hr) Phase Op Code Activity CM& Time P -T -X Operation Start Depth (RKB) End Depth (ftKB) 3/20/2019 3/20/2019 0.40 PROD1 DRILL CTOP P Reverse circulate, unstab, replace 0.0 0.0 15:03 15:27 upper quick connect. 3/20/2019 3/20/2019 1.00 PROD1 DRILL PULD P PU & PD BHA#11, Li build drilling 0.0 72.0 15:27 16:27 assembly. 3/20/2019 3/20/2019 1.80 PROD1 DRILL TRIP P RIH, 72.0 7,975.0 16:27 18:15 3/20/2019 3/20/2019 0.20 PROD1 DRILL DLOG P Tie into the K1 for -6' correction. 7,975.0 7,996.0 18:15 1827 3/2012019 3/20/2019 0.40 PROD1 DRILL TRIP P Continue RIH, tag bottom 8,270' 7,996.0 8,270.0 18:27 18:51 3/20/2019 3/2012019 0.60 PROD1 DRILL DRLG P OBD, 1.86 bpm at 4,244 psi, Diff-- 8,270.0 8,295.0 18:51 19:27 464, WHP=120, BHP=3538, IA=962, OA=638 3/20/2019 3120/2019 0.15 PROM DRILL WPRT P Tools hung up in window area, PUH, 8,295.0 8,295.0 19:27 19:36 PUW 33 k, Restart 3/2012019 3/20/2019 0.25 PRODi DRILL DRLG P OBD, 1.86 bpm at 4,244 psi, Diff-- 8,295.0 8,303.0 19:36 19:51 464, WHP=120, BHP=3538, IA=962, OA=638 320/2019 312012019 0.15 PROD1 DRILL WPRT P PUH, PUW 33 k, restart 8,303.0 8,303.0 19:51 20:00 3120/2019 3120/2019 1.60 PROM DRILL DRLG P OBD, 1.86 bpm at 4,244 psi, Diff= 8,303.0 8,340.0 20:00 21:36 464, WHP=120, BHP=3538, IA=962, OA=638 3/2012019 3/20/2019 0.15 PROD1 DRILL WPRT P PUH, PUW 33 k, restart 8,340.0 8,340.0 21:36 21:45 3/20/2019 320/2019 0.35 PROD1 DRILL DRLG P OBD, 1.86 bpm at 4,244 psi, Diff- 8,340.0 8,357.5 21:45 22:06 464, WHP=120, BHP=3538, IA=962, OA=638 3/20/2019 3/20/2019 0.25 PROD1 DRILL WPRT P TD build section (Avg. DLGS 49.26° 8,357.5 8,245.0 22:06 22:21 DLGS), PUW 33 k, pull wiper to the window, chasing 5X5 sweep 320/2019 3/2012019 1.50 PROD1 DRILL WPRT P POOH 8,245.0 78.0 22:21 23:51 3/20/2019 31212019 0.16 PROD1 DRILL PULD P Tag up, spaoeout, PJSM for PUD build 78.0 78.8 23:51 00:00 assembly 3/2112019 3/212019 0.60 PROM DRILL PULD P PUD, build assembly 78.8 0.0 00:00 00:36 3/2112019 3/2112019 1.20 PRODt DRILL PULD P PD, L1 Lateral section assembly 0.0 78.3 00:36 01:48 3/212019 321/2019 1.55 PROM DRILL TRIP P RIH, w/Lateral Drilling BHA#12, 0.5° 78.3 7,975.0 01:48 03:21 ako motor, agitator, bi-center bit. 3121/2019 3/21/2019 0.20 PROM DRILL DLOG P Log the K1 for depth control (minus 7,975.0 8,000.0 03:21 03:33 6.0'), PUW 30 k 3/212019 321/2019 0.20 PROD1 DRILL TRIP P Continue IH 8,000.0 8,265.0 03:33 03:45 3212019 3/212019 0.20 PROD1 DRILL DLOG P Log the RA marker 8,265.0 8,265.0 03:45 03:57 Note: Offical Window Depths TOWS=8245.5' RA Marker -8251.5' BOW=8252.5' EOB=8357.5' 3/21/2019 3/212019 0.20 PROM DRILL TRIP P Continue IH 8,265.0 8,357.5 03:57 04:09 3121/2019 2.50 PRODt DRILL DRLG P OBD, 1.87 bpm at 5,150 psi, 8,357.5 8,616.0 04:09 06:39 Diff --1,376, WHP=53, BHP=3533, 13/21/2019 1 IA=958, OA=618 PU 30 k Ibs - 8588' Page 7116 Report Printed: 4/812019 Operations Summary (with Timelog Depths) 3F-01 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log start Depth a swarm End rme our (hr) Phase Op Code Activity Cafe Time P -T -x operation (flK End Depth (flKa) 3/21/2019 3/21/2019 1.30 FROM DRILL DRLG P OBD,CT 5386 psi, 1.89 by min 1.83 8,616.0 8,760.0 06:39 07:57 bpm out, WHP=44, BHP=3538, IA=970, OA=641 pump 5x5 sweep 3/21/2019 3/21/2019 0.20 PROD1 DRILL WPRT P PU 30 k Ib, wiper trip #1 -460' 8,760.0 8,300.0 07:57 08:09 3/21/2019 3/21/2019 0.10 PRODt DRILL WPRT P RBIH, RIH Wt 8.7 k lbs 8,300.0 8,760.0 08:09 08:15 **bleed IA for 1 hr 3/21/2019 3/21/2019 1.20 PROD1 DRILL DRLG P CT 5265 psi @ 1.90 bpm in and 1.89 8,760.0 8,903.0 08:15 09:27 bpm out, BHP 3569 psi, 11.45 EMW @ the window. WH 49 psi, IA 806 psi, OA 643 psi. OBD, CT Wt 6 k lbs, WOB 1.6 k lbs Average ROP while on bottom - 119 TUhr 3/21/2019 3/21/2019 0.90 PROD1 DRILL DRLG P 1.87 bpm in, returns fell to 1.35 bpm. 8,903.0 8,954.0 09:27 10:21 P, 34 k lbs, RBIH, loses increased, returns fell to 1 bpm. Drill ahead, high WOB with low diff, PU, 35 k lbs, restart drill ahead, ratty drilling, High ROP low WOB, then stack out. PU, 35 k lbs. Losses healing as we drill ahead, 1.88 bpm in, 1.75 bpm out. Average ROP while on bottom - 56 ft/hr 3/21/2019 3/21/2019 0.70 PROM DRILL DRLG P CT 525 psi, 1.88 bpm in and 1.82 bpm 8,954.0 9,070.0 10:21 11:03 out, free spin diff 1399 psi, BHP 3562 psi, CT Wt 6 k lbs, WOB 0.8 k lbs, Launch 5x5 in anticipation of wiper trip. Average ROP while on bottom - 166 ft/hr 3/21/2019 3/21/2019 0.20 PROD1 DRILL WPRT P PU Wt 33 k lbs, 9,070.0 8,850.0 11:03 11:15 Pull wiper chasing 5x5 sweep. Wipe above original loss zone -8905' 3/21/2019 3/21/2019 0.10 PROD1 DRILL WPRT P RBIH 8,850.0 9,070.0 11:15 11:21 3/21/2019 3/21/2019 3.00 PROD1 DRILL DRLG P Initiate Continuous rotation of the 9,070.0 9,543.0 11:21 14:21 HOT, new stearable script, Limit ROP to 160 ft/hr or less. CT 5230 psi @ 1.87 bpm in and 1.82 bpm out. Free spin diff 1360 psi, BHP 3625, Ct Wt 5.5 k lbs, Had to slide and increase WOB to arrest from 9463'- 9476' Pump 5x5 sweep and chase with new mud. Average ROP while on bottom - 157 ftlhr 3/21/2019 3/21/2019 0.30 PROD? DRILL WPRT P PU Wt 32 k lbs - Wiper # 2, - 1145' 9,543.0 8,400.0 14:21 14:39 PUH chasing sweeps "new mud at the bit - 9543' 3/21/2019 3/21/2019 0.60 PROD1 DRILL WPRT P RBIH, RIH Wt 7.9 k lbs 8,400.0 9,543.0 14:39 15:15 3/21/2019 3/21/2019 2.75 PROD1 DRILL DRLG P CT 4995 psi @ 1.89 bpm in and 1.96 9,070.0 9,543.0 15:15 18:00 bpm out. Free spin diff 1327 psi, BHP 3552, Ct W14.7 k lbs, Average ROP while on bottom - ft/hr 3/21/2019 3/21/2019 0.65 PRODt DRILL WPRT P Wiper up hole, PUW 32 k 9,543.0 8,270.0 18:00 18:39 3/21/2019 3/21/2019 0.20 PROD? DRILL DLOG P Log the RA marker correction of plus 8,270.0 8,287.2 18:39 18:51 3.01 3/21/2019 31212019 0.60 FROM DRILL WPRT P Wiper back in hole, RIW 9 k 8,287.2 9,973.0 18:51 19:27 Page 8116 Report Printed: 4/812019 Operations Summary (with Timelog Depths) 3F-01 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Stan Depth Stan Time I End Time our (hr) phase Op Code Activity Calla Time P -T -X Operetion (flKa) End Depth (WS) 3/21/2019 3/21/2019 0.25 PROD? DRILL DRLG P BOBD, 1.89 bpm at 5,000 psi, 9,973.0 10,023.0 19:27 19:42 Diff=1,190, WHP=138, BHP=3,606, IA=911, OA=599 3/21/2019 3/21/2019 2.20 PROD1 DRILL DRLG P Geo steer from 86° NBI to 97', 10,023.0 10,270.0 19:42 21:54 discontinue conlinous rotation drilling (test interval 9,070'-10,023'), continue drilling ahead @ 345° TF, 1.89 bpm at 5,277 psi, ROP=165 fph, off bottom Diff -1,190, WHP=97, BHP=3,631, IA=610, OA=588 3/2112019 3121/2019 0.25 PROM DRILL WPRT P Wiper up hole PUW 33 k 10,270.0 9,570.0 21:54 22:09 3/2112019 3/2112019 0.30 PROM DRILL WPRT P Wiper back in hole, RIW 8 k 9,570.0 10,270.0 22:09 22:27 3/21/2019 3/21/2019 1.30 PRODi DRILL DRLG P BOBD, 1.89 bpm at 4.987 psi, 10,270.0 10,398.0 22:27 23:45 Diff=1,102, WHP=69, BHP=3,631, IA=611, OA=605 3/21/2019 3/21/2019 0.15 PROD1 DRILL WPRT P PUH, and restart, BHA wiper 10,396.0 10,398.0 23:45 23:54 3/21/2019 3/22/2019 0.10 PROD1 DRILL DRLG P BOBD, 1.89 bpm at 4.987 psi, 10,398.0 10,410.0 23:54 00:00 Diff=1,102, WHP=69, BHP=3,631, IA=611, OA=605 3/22/2019 3/22/2019 2.00 PROM DRILL DRLG P OBD, 1.89 bpm at 5,125 psi, 10,410.0 10,551.0 00:00 02:00 Diff -1,264, WHP=90. BHP=3,633, IA=616, OA=624 3/22/2019 3/22/2019 0.15 PROM DRILL WPRT P PUH, restart, BHA wiper PUW 30 k 10,551.0 10,551.0 02:00 02:09 3122/2019 3122/2019 1.60 PROM DRILL DRLG P BOBD, 1.89 bpm at 5,008 psi, 10,551.0 10,673.0 02:09 03:45 Diff --1,089, WHP=106, BHP=3,693, IA=616, OA=624 3/22/2019 3122/2019 0.30 PROM DRILL WPRT P Wiper up hole, PUW 32 k 10,673.0 9,473.0 03:45 04:03 3/22/2019 3/22/2019 0.40 PRODi DRILL WPRT P Wiper back in hole, RIW 8 k 9,473.0 10,673.0 04:03 04:27 3/22/2019 3/22/2019 0.90 PROD1 DRILL DRLG P CT 4973 psi, @ 1.89 bpm in, 1.89 10,673.0 10,754.0 04:27 05:21 bpm, free spin 1025 psi, BHP 3623 psi. OBD, CT Wt 2.9 k Ibs, WOB 1.3 k lbs, ROP -130 @10754 sudden loss in returns, 1.89 bpm in, returns fell to -0.45 bpm PU Wt 31 k lbs, PU slowly, returns not healing, 3122/2019 3/22/2019 1.70 PROD1 DRILL WPRT P PUH to the window. adjust choke to 10,754.0 8,077.0 05:21 07:03 11.1 ppg EMW at the window to manage losses while pulling to the window. 3/2212019 3/22/2019 0.20 PROD1 DRILL DLOG P Tie int othe RA tag for a +4.5 8,077.0 8,291.0 07:03 0715 correction 3/22/2019 3/22/2019 0.90 PROD1 DRILL TRIP P RBIH, 8,291.0 10,754.0 07:15 0809 S/D @ 8769' Higher gamma area, 1.8 k WOB, bounced through. 1.85 bpm in and 1.73 bpm out fell to 1.14 bpm out at bottom 3/22/2019 3/22/2019 1.40 PROD1 DRILL DRLG P CT 4790 psi, at 1.86 bpm in and 1.14 10,754.0 10,888.0 08:09 09:33 bpm out, free spin diff 978 psi, WH 109 psi holding 11.1 ppg. Drill ahead, returns heal to 1.4 bpm whie holding 11.1 EMW Page 9116 Report Printed: 4!8/2019 operations Summary (with Timelog Depths) 3F-01 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log sten Depth start Time End Time Dur (ho Phase Op Code Activity Code Time P-T-X Operation (MB) End Depth (flx8) 3/22/2019 3/22/2019 2.40 FROM DRILL DRLG P Ecountered additional losses, returns 10,888.0 11,109.0 0933 1157 fell to 0.25 bpm. PU, 33 it lbs, RBIH, drill ahead with multiple pick ups, CT PU WT 35-33 k lbs. targeting 11.0 ppg EMW @ the window, returns healing CT 4962 psi, 1.86 bpm in and 1.51 bpm out. BHP 3593 psi 3/22/2019 3/22/2019 0.40 PROD1 DRILL WPRT P PU Wt 34 k lbs -#1 - 1000' 11,109.0 10,009.0 11:57 12:21 1.88 bpm in, 1.48 bpm out while pulling 50 fl/min losses -0.25 bpm 3/22/2019 3/22/2019 0.30 PROD1 DRILL WPRT P RBIH 10,009.0 11,109.0 12:21 12:39 WellWorc shows .5 bbl solids returned. 3/22/2019 3/22/2019 4.40 PROD1 DRILL DRLG P CT 4625 psi, @ 1.88 bpm in and 1.60 11,109.0 11,401.0 12:39 17:03 bpm out, free spin diff 980 psi, BHP 3506 psi, holding 11.0 ppg @ the window. 111 90'PU 35 k Itis 11414' PU 40 k lbs 3/22/2019 3/22/2019 0.50 FROM DRILL DRLG P OBD, 1.88 bpm at 4,800 psi, 11,401.0 11,462.0 17:03 17:33 Diff--1,190, WHP=132, BHP=3,565, IA=595, OA=588 3/22/2019 3/22/2019 2.50 FROM DRILL WPRT P Encountered 100% losses, PUH, 11,462.0 8,240.0 17:33 20:03 PUW 36 k, pull slow wiper up hole, circulate 10x10 sweep, confer with town team, called TD early 11,462', continue wiper up hole, returns slow to return. pull slow wiper to the window chasing sweep. 3/22/2019 3/22/2019 2.00 FROM DRILL WPRT P Pull through the window, bring pump 8,240.0 2,400.0 20:03 2203 back up to lull rate, continue pulling swab wiper @ 25 fpm, maintaining 0.75 bpm returns. @ 6,500', WHIP steadly climbing, increase pulling speed to 80 fpm, maintaining 0.85 bpm returns, 3/22/2019 3/22/2019 0.70 PROD1 DRILL WPRT P Increase pulling speed to 90 fpm 2,400.0 78.2 22:03 22:45 maintaining 0.9 bpm returns. 3/22/2019 3/22/2019 0.20 PROD? DRILL TRIP P Tag up, reset counter depths, RIH 78.2 1,529.0 22:45 22:57 3/22/2019 3/22/2019 0.45 FROM DRILL TRIP P Set down, PUH clean, inspect INJH, 1,529.2 1,529.2 22:57 23:24 seems to be pac-off tube, continue RIH 3/22/2019 3/23/2019 0.60 PROD1 DRILL TRIP P RBIH, pumping 0.62 bpm/0.20 bpm 1,529.2 3,195.0 23:24 00:00 returns, w/ Lateral drilling BHA#12 3/23/2019 3/23/2019 0.80 PROD1 DRILL TRIP P Continue RIH w/ BHA#12 to confirm 3,195.0 7,980.0 00:00 00:48 TD 3/23/2019 3/23/2019 0.20 PROM DRILL DLOG P Log the K1 (minus 6.0) PUW 30 It 7,980.0 8,000.7 00:48 01:00 3/23/2019 3/23/2019 0.20 FROM DRILL TRIP P Continue IH 8,000.7 8,215.0 01:00 01:12 3/23/2019 3/23/2019 0.15 PROM DRILL TRIP P Perform Pressure Survey - 3 min - 8,215.0 8,215.0 01:12 01:21 Falling quickly, come back online with pump. Press Sesor @ 5,856.9 TVD AP=3,012 9.899 ppg 3/23/2019 3/23/2019 1.35 PROD? DRILL TRIP P Continue IH, holding 11.0 ppg at the 8,215.0 11,463.0 01:21 02:42 window, pumping 1.7 bpm at 4,014 psi, 0.50 bpm returns, WHP=328, Page 10/16 Report Printed: 4/8/2019 Operations Summary (with Timelog Depths) 3F-01 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log 9i art Start Time End Time Dur(hr) Phase Op Code Ad.ty Code Time P -T -X Operation End Depth(flKa) 3/23/2019 3/23/2019 1.80 FROM DRILL TRIP P Tag bottom @ 11,463', PUW 35 k, 11,463.0 5,778.0 02:42 04:30 painting EOP flags TD flag (Yellow 9073.25'), Window flag (White 5778.25') 3/23/2019 3/23/2019 1.00 PRODi DRILL TRIP P Continue to POOH. while tuning coil 5,778.0 93.0 04:30 05:30 over to 10.5 pgg KWF. 3/23/2019 3/23/2019 2.00 FROM DRILL DISP P Park and pump 50 DIM, of viscosified 93.0 93.0 05:30 07:30 (100k Cp LSRV) 10.5 ppb liner running pill down the kill line /back side, followed by 50 additional bbls of 10.5 ppb normal visc liner running pill. 3/23/2019 3/23/2019 0.90 FROM DRILL PULD P PJSM, Flow check, initial losses -12 93.0 0.0 07:30 08:24 bbl/hr. LD BHA#12 over a dead well. 3/23/2019 3/23/2019 0.40 COMPZ1 CASING PUTS P Pre floor for running liner 0.0 0.0 08:24 08:48 3/23/2019 3/23/2019 0.40 COMPZt CASING BOPE P BOP function test 0.0 0.0 08:48 09:12 3/23/2019 3123/2019 3.40 COMPZ1 CASING PUTS P PU 2-318 "4.6 # STL slotted liner, 81 0.0 2,410.8 09:12 12:36 joints over a non ported bull nose ( LOA 2410.84'), clean floor of liner running equipment. 3/23/2019 3/23/2019 1.10 COMPZ1 CASING PULD P PU Li liner running BHA (GS stabbed 2,410.8 2,464.1 12:36 13:42 into an aluminum liner top billet), skid cart, stab injector, inspect pack offs, bump up, set counters. "'118 bbls KWlost while picking up liner and BHA 3/23/2019 3/23/2019 2.50 COMPZ1 CASING RUNL P RIH W L1 completion, lined up across 2,464.1 11,456.0 13:42 1612 the top, pumping KW away with just the charge pump pressure, lined up down the coil @ 0.5 bpm, caught returns @ 4065', 0.6 bpm losses. Tie into white window flag for -10.78' correction. Pu wt 32 k bs, RIH WOB - 5.39 k lbs SID shallow @ 11,456', PU and RBIH, SID 11,452', PU 44 k and S/D 11448' Consult town, Pump of Iinerl.5 bpm, 800 psi diff, PU 30k bs. TOL @ 9028' bottom of liner 11448' 3/23/2019 3123/20191.50 COMPZ1 CASING TRIP P PUH after dropping off L1 completion, 11,456.0 8,218.0 16:12 17:42 park, reset counters. 3123/2019 3/2312019 0.90 COMPZ1 CASING DISP P Tum well over to mud 8,218.0 8,218.0 17:42 18:36 3/23/2019 3/23/2019 1.30 COMPZ1 CASING TRIP P POOH 8,218.0 44.2 18:36 19:54 3/23/2019 3/23/2019 0.80 COMPZ1 CASING PULD P At surface, spaceout, PUD/LD setting 44.2 0.0 19:54 20:42 tools 3/2312019 3/2312019 1.00 PROD2 STK PULD P PU/PD, L1-01 Lateral Drilling 0.0 78.3 20:42 21:42 Assembly, BHA#14 3/23/2019 3/23/2019 0.30 PROD2 STK TRIP P Tag up, reset counters, close EDC, 78.3 486.0 21:42 22:00 RIH @ 486' surface test mud motor/agitator (good -test) 312312019 3/23/2019 1.40 PROD2 STK TRIP P Continue RIH 486.0 7,980.0 22:00 23:24 3/23/2019 3/23/2019 0.20 PROD2 STK DLOG P Log the K1 marker (minus 6.5') 7,980.0 8,000.8 23:24 23:36 3/23/2019 3124/2019 0.40 PROD2 STK TRIP P Continue IH 8,000.8 8,618.0 23:36 00:00 1 1 I 3/24/2019 1312412019 0.60 PROD2 STK TRIP P Continue IH, dry tag TOB 8,618.0 9,026.0 00:00 00:36 I I Page 11116 Report Printed: 41812019 0 Operations Summary (with Timelog Depths) +, tee.. 3F-01 0 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time our (hr) Phase Op Code AMvity Code Time P -T -X Operation (ftKB) End Depth (MB) 3/24/2019 3/24/2019 0.20 PROD2 STK TRIP P PUH PUW 30 k, obtain pump 9,026.0 9,026.0 00:36 00:48 parameters 3/24/2019 3/24/2019 0.60 PROD2 STK KOST P Kickoff Billet, 1.88 bpm at 4,272 psi, 9,026.0 9,027.0 00:48 01:24 Diff=903, WHP=155, BHP=3,405, IA=603, OA=584, Time mill 2 tenths @ 6 min 3/24/2019 3/24/2019 0.70 PROD2 STK KOST P Increase ROP to 2 fph, 1.88 bpm at 9,027.0 9,028.0 01:24 0206 4,287 psi, Diff=935, WHP=149, BHP=3,408, IA=605, OA=593, 0.7 k=DHWOB, CTSW= 12 k 3/24/2019 3/24/2019 0.60 PROD2 STK KOST P Increase ROP to 3 fph, 1.88 bpm at 9,028.0 9,029.0 02:06 02:42 4,376 psi, Diff=1,008, WHP=147, BHP=3,399, IA=607, OA=599, 0.74 k=DHWOB, CTSW=11.1 k 3/24/2019 3/24/2019 0.30 PROD2 STK KOST P Increase ROP to 10 fph, 1.88 bpm at 9,029.0 9,036.0 02:42 03:00 4,376 psi, Diff=1,008, WHP=147, BHP=3,399, IA=607, OA=599, 0.74 k=DHWOB, CTSW=11.1 k 3/24/2019 3/24/2019 0.90 PROD2 DRILL DRLG P Drill ahead 1.88 bpm @ 4,325 psi, 9,036.0 9,142.0 03:00 0354 Diff=990, WHP=118, BHP=3,402, IA=609, OA=604, 3/24/2019 3/24/2019 0.30 PROD2 DRILL WPRT P PU Wt 39 k lbs, PUH to dry drift billet. 9,142.0 9,142.0 03:54 0412 9070' Pull -1k WOB RBIH See WOB spike @ 9075'to 1.3 k lbs, same area we started the continuous rotation test during the Li lateral drilling Billet drifted clean 3/24/2019 3/24/2019 2.40 PROD2 DRILL DRLG P CT 4310 psi @ 1.9 bpm in and 1.9 9,142.0 9,426.0 04:12 06:36 bpm out. BH 3374 psi, holding 11.0 EMW @ the window. OBD, CT 6.3 k Is, WOB 2.1 0500 - increase choke to target 11.2 ppg EMW @ the window, BHP 3477 psi Average ROP over section = 118 ft/hr 3/24/2019 3/24/2019 0.40 PROD2 DRILL WPRT P PUWt 33 k lbs, - Wiper#1 - short 9,426.0 9,426.0 06:36 07:00 wiper to just below the billet - 379' Turn around @ 6:48 and 9047' RBIH, No evidence of issues at 9070' - clean 3/24/2019 3/24/2019 0.90 PROD2 DRILL DRLG P CT 4629 psi @ 1.9 bpm in and 1.9 9,426.0 9,552.0 07:00 0754 bpm out. free spin diff 948 psi, BH 3475 psi, holding 11.2 EMW @ the window OBD, CT 9 k lbs, WOB 2.8 Average ROP over section = 140 ft/hr 3/24/2019 3/24/2019 2.50 PROD2 DRILL DRLG P Initiate continuous rotation of the HOT 9,552.0 9,826.0 07:54 1024 - AKA and from here forward - RotoTrak CT 5016 psi @ 1.89 bpm in and 1.89 bpm out, 3461 psi BHP, 11.2 ppg EMW @ the windowCT Wt 0.2 k lbs, 2.4 k lbs WOB. Average ROP over section = 110 ft/hr 3/24/2019 3/24/2019 0.30 PROD2 DRILL WPRT P PU Wt 32 k lbs, Wiper trip #2 - 778' 9,826.0 9,048.0 10:24 10:42 3/24/2019 3/24/2019 0.20 PROD2 DRILL WPRT P RBIH 9,048.0 9,826.0 10:42 10:54 WellWorc indicates 0.27 bbls cutting returned on the trip. Page 12/16 Report Printed: 4/8/2019 Operations Summary (with Timelog Depths) 3F-01 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log start Deprh Sten Time End Time Dur(hp Phase Op Code Activit' Code Time P -T -X Operation (ftKB) End Depth(ftKB) 3/24/2019 3/24/2019 0.40 PROD2 DRILL DRLG P RotoTrak 9,826.0 9,875.0 10:54 11:18 CT psi 5128 psi @ 1.89 bpm in and 1.89 bpm out, free spin 886 psi, 3492 psi BHP, 11.2 ppg EMW @ the window CT Wt -0.2 k lbs, 3.1 k lbs WOB. Average ROP over interval 122 ft/hr 3/24/2019 3/24/2019 3.50 PROD2 DRILL DRLG P RotoTrak 9,875.0 10,226.0 11:18 14:48 ** Losses, returns fell to 0.2 bpm, PU Wt 33 k lbs, Reduced choke to hole 11.0 ppg EMW at the window. Losses slowly healed retruns climbed 1ol.6 bpm RBIH and drill ahead. CT psi 5064 psi @ 1.89 bpm in and 1.60 bpm out, free spin 885 psi, 3439 psi BHP, 11.0 ppg EMW @ the window CT Wt -3 k lbs, 2.2 k lbs WOB. 3/24/2019 3/24/2019 0.60 PROD2 DRILL WPRT P PU Wt 32 k lbs, Wiper trip #3, long 10,226.0 8,270.0 14:48 15:24 wier to the window for tie in. Saw negative WOB tug @ 9066'- 1k lbs 3/24/2019 3/24/2019 0.20 PROD2 DRILL DLOG P Tie into the RA tag for a +3.5 8,270.0 8,302.0 15:24 15:36 correction. 3/24/2019 3/24/2019 0.60 PROD2 DRILL WPRT P RBIH, Window clean 8,302.0 10,226.0 15:36 16:12 Saw WOB bobble @ 9072'0.4 k lbs Billet clean 3/24/2019 3/24/2019 0.80 PROD2 DRILL DRLG P RotoTrak 10,226.0 10,335.0 16:12 17:00 CT 4693 psi, @ 1.89 bpm in and 1.73 bpm out, free spin 931 psi, BHP 3438 psi, 11.0 ppg EMW @ the window. CT Wt -1.9 k lbs, 2.5 k WOB. 3/24/2019 3/24/2019 0.20 PROD2 DRILL WPRT P PUH, PUW 33 k, restart 10,335.0 10,335.0 17:00 17:12 3/24/2019 3/24/2019 1.50 PROD2 DRILL DRLG P BOBD, 1.87 bpm at 4,800 psi, 10,335.0 10,501.0 17:12 18:42 Diff=941 psi, WHP=108, BHP=3,471, IA=623, OA=654, RotoTrak Drilling 10,335'-10341' (6') 10,357'-110,398'(41') 10,407'-10,428' (21) 110,448'-10'501'(53') 3/24/2019 3/24/2019 0.20 PROD2 DRILL WPRT P PUH, PUW 32 k, restart 10,501.0 10,501.0 18:42 18:54 3/24/2019 3/24/2019 2.00 PROM DRILL DRLG P BOBO, 1.88 bpm at 4,900 psi, 10,501.0 10,653.0 18:54 20:54 Diff --940 psi, WHP=94, BHP=3,481, IA=623, OA=655 RotoTrak 10,501'-10,567' (66') 10,633'-10.653'(20') 3/24/2019 3/24/2019 0.30 PROD2 DRILL WPRT P Wiper up hole to 9,653', PUW 33 k 10,653.0 9,653.0 20:54 21:12 3/24/2019 3/24/2019 0.30 PROD2 DRILL WPRT P Wiper back in hole, RIW 7 k 9,653.0 10,653.0 21:12 21:30 3/24/2019 3/24/2019 0.50 PROD2 DRILL DRLG P BOBO, 1.88 bpm at 4,238 psi, 10,653.0 10,705.0 21:30 22:00 Diff=940 psi, WHP=94, BHP=3,481, IA=623, OA=655 3/24/2019 3/24/2019 0.20 PROD2 DRILL WPRT P Losses increased from 0.15 bpm - 10,705.0 10,705.0 22:00 22:12 0.65 bpm @ 10,694', PUW 35 k, restart Page 13116 Report Printed: 4/812019 Operations Summary (with Timelog Depths) 3F-01 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Stan Depth Start Time End Time Dur(hr) Phase Op Code Activity Code rime P-T-X Operabon (Po(B) End Depth(NKB) 3/24/2019 3/25/2019 1.80 PROD2 DRILL DRLG P BOBD, 1.88 bpm at 4„922 psi, 10,705.0 10,901.0 22:12 00:00 Diff-940 psi, WHP=153, BHP=3,474, IA=622, OA=656, encounter another loss zone @ 10,726', MM IN=1.87 bpm, MM OUT=1.53 (losses 0.35 bpm) RotoTrak 10,705'-10,750' (45) 10,765'-10,830'(65') 10,850'-10,901' (51') 3/25/2019 3/25/2019 0.30 PROD2 DRILL DRLG P OBD, 1.88 bpm at 4„922 psi, Diff--,940 10,901.0 10,922.0 00:00 00:18 psi, WHP=153, BHP=3,474, IA=622, OA=656, encounlerd drop in return rate Q 10,913' and 10,922' 3/25/2019 3/25/2019 0.30 PROD2 DRILL DRLG P BOBD, 1.88 bpm at 4_922 psi, 10,922.0 10,971.5 00:18 00:36 Diff=940 psi, WHP=153, BHP=3,474, IA=622, OA=656 3/252019 3/25/2019 0.20 PROD2 DRILL WPRT P 100% losses, PUH, PUW 35 k 10,971.5 10,505.0 00:36 00:48 3/25/2019 3/25/2019 0.30 PROD2 DRILL WPRT P RBIH, circ 5x5 sweep, down the coil 10,505.0 10,900.0 00:48 01:06 3/2512019 3252019 0.50 PROD2 DRILL WPRT P Pull wiper up hole to 9,900', 10,900.0 9,900.0 01:06 01:36 3/25/2019 325/2019 0.50 PROD2 DRILL WPRT P Wiper back in hole, RIW 10 k 9,900.0 10,971.0 01:36 02:06 3/25/2019 325/2019 0.50 FROM DRILL DRLG P BOBD, 1.77 bpm at 4,460 psi, 10,971.0 11,019.0 02:06 02:36 Diff--829, WHP=273, BHP=3,456, IA=608, OA=638 3/25/2019 3/25/2019 0.20 PROD2 DRILL WPRT P Wiper up hole 250', PUW 40 k 11,019.0 11,019.0 02:36 02:48 3/252019 3/25/2019 0.55 PROD2 DRILL DRLG P BOBD, 1.77 bpm at 4,460 psi, 11,019.0 11,058.0 02:48 03:21 Diff-829, WHP=273, BHP=3,456, IA=608, OA=638 325/2019 3/25/2019 0.35 PROD2 DRILL WPRT P ROP increased >180 fph, PUW 32 k, 11,058.0 10,837.0 03:21 03:42 pull short wiper up hole Note: Choke Fully closed 10,610'- 10,810'. WHP=850 psi, open choke, maintaining 11.0 ppg at the window 3/25/2019 3/25/2019 0.25 PROD2 DRILL WPRT P Wiper back in hole, set down @ 10,837.0 11,058.0 03:42 03:57 1 1 10,929' and 10,960', PUH clean 3/25/2019 3/25/2019 0.60 PROD2 DRILL DRLG P BOBD, 1.78 bpm at 4,500 psi, 11,058.0 11,123.6 03:57 04:33 Diff=880, WHP=230, BHP=3475, IA=607, OA=632, 3125/2019 3/25/2019 1.30 PROD2 DRILL WPRT P Wiper trip to the window, PUW 33 k 11,123.6 8,266.0 04:33 05:51 WellWorc shows 0.68 bbls of cuttings removed. 3/25/2019 3/2512019 0.20 PROD2 DRILL DLOG P Tie into the RA lag for a + 5.5' 8,266.0 8,299.0 05:51 06:03 correction. 3/25/2019 3/2512019 1.00 PROD2 DRILL TRIP P RBIH to drill marginal returns 1.4 to 8,299.0 11,123.6 06:03 07:03 0.6 bpm returns whie holding 1.9 bpm n. 3/25/2019 3/25/2019 2.70 PROD2 DRILL DRLG P RotoTrak 11,123.6 11,400.0 07:03 09:45 CT 4806 psi @ 1.9 bpm in and 1 bpm out. Reduce choke setting to hold 10.9+ EMW @ the window. Retuns fluctuated from 1.4 to 1.5 bpm. CT Wt 8 klbs, WOB 1.2 klbs 11193' PU 38 k lbs, 11 253'PU 36 k Has, 11381 PU 37 k Has. launch 5x5 sweep in anticipation of TD. ROP over interval = 103 f 1hr Page 14116 Report Printed: 41812019 Operations Summary (with Timelog Depths) 3F-01 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Stan Depth startTime End Time Our (hr) Phase Op Code Ac" Code Time P-T-X Opembon mKB) End DepN(MB) 3/2512019 3/25/2019 1.20 PROD2 DRILL WPRT P Wiper trip to the window, PUW 33 k 11,400.0 8,015.0 09:45 10:57 PUH chasing sweeps to surface 3/2512019 3/25/2019 1.90 PROD2 DRILL WPRT P Continue out of hole on wiper trip. 8,015.0 78.0 10:57 12:51 3/2512019 3/25/2019 1.40 PROD2 DRILL TRIP P Bump u, set counters, RBIH to 78.0 7,985.0 12:51 14:15 measure BHP and confirm TD 3/25/2019 3/25/2019 0.20 PROD2 DRILL DLOG P Tie into the K1 for a -6' correction 7,985.0 8,006.0 14:15 14:27 3/25/2019 3/25/2019 0.30 PROD2 DRILL DLOG P Park at 8236.05 CTMD and 5871.85 8,006.0 8,236.0 14:27 14:45 TVD, trap 3312 psi, observe pressure. initial 3312 psi 10.84 ppg 1 min 3293 psi 10.78 ppg 2 min 3287 psi 10.76 ppg 5 min 3239 psi 10.61 ppg 10 min 3185 psi 10.43 ppg Bled off fluid to 70 psi well head 13 min 3155 psi 10.33 ppg - BHP did not appear to break trend Bled WH to 371 psi, BHP did break trend 15 min 3126 psi 10.24 ppg 20 min 3083 psi 10.1 ppg 3/25/2019 3/25/2019 1.20 PROD2 DRILL TRIP P PU Wt 30 k lbs, continue to RIH 8,236.0 11,401.0 14:45 15:57 "' Confirm TD @ 11,401' 3/25/2019 3/25/2019 2.00 PROD2 DRILL DISP P PU Wt 34 k lbs, Complete building 11,401.0 11,395.0 15:57 17:57 weighted lier running pil I(LRP) and pump to bit. 3/25/2019 3/25/2019 1.10 PROD2 DRILL DISP P PUH laying in 10.5 ppg LRP while 11,395.0 8,178.3 17:57 19:03 painting flags Yellow flag 8178.29' 3/25/2019 3/25/2019 1.80 PROD2 DRILL TRIP P Continue to POOH displacing the well 8,178.3 73.0 19:03 20:51 to 10.5 KW Paint whit flag @ 3/25/2019 3125/2019 0.80 PROD2 DRILL PULD P LD BHA #14 over a dead well. 73.0 0.0 20:51 21:39 3/25/2019 3/2512019 0.40 COMPZ2 DRILL PUTB P Prep floor for running liner 0.0 0.0 21:39 22:03 325/2019 3/2612019 1.95 COMPZ2 DRILL PUTB P PU AL1-01 liner-107 joints of 2- 0.0 1,028.8 22:03 00:00 3/8"4.6 # STL slotted liner under a shorty deployment sieve with a non ported bull nose 3/26/2019 3/26/2019 3.75 COMPZ2 CASING PUTB P PU AL1-Ot liner-107 joints of 2- 1,028.8 3,164.0 00:00 03:45 318"4.6 # STL slotted liner under a shorty, deployment sieve with a non ported bull now *** Note: Lost 28 bbl while PU liner 3/26/2019 326/2019 0.75 COMPZ2 CASING PULD P PU CoilTrak tools, change out upper 3,164.0 3,209.4 03:45 04:30 checks, change out pac-offs, surface test tools (good-test) 3/262019 3/26/2019 1.00 COMPZ2 CASING RUNL P RIH, with Li-01 liner, 107 jts of slotted 3,209.4 8,100.0 04:30 05:30 liner, shorty deployment sleeve, and non-ported bullnose. 3/26/2019 3/2612019 0.15 COMPZ2 CASING RUNL P Correct to the EDP flag, minus 10.0' 8,100.0 8,16-0 0 05:30 05:39 1 3/26/2019 3/26/2019 1.50 COMPZ2 CASING RUNL P Continue IH with liner assembly 8,100.0 10,876.0 05:39 07:09 1 3/26/2019 3/26/2019 1.15 COMPZ2 CASING RUNL P Work liner to bottom, PUW 41-44k, tag 10,876.0 11,401.0 07:09 08:18 1 bottom, PUH, tag bottom again Page 15/16 Report Printed: 41812019 Operations Summary (with Timelog Depths) 3F-01 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time Dw(hr) Phase Op Code Aclvity Cafe Time Pi Operetlon (RKS) End Depth [WS) 3/26/2019 3/26/2019 0.30 COMPZ2 CASING RUNL P Bring pump online 1.6 bpm, 990 psi 11,401.0 8,214.7 08:18 08:36 diff, PUW 30 k, remove liner length from counters, PUH for static. 3/26/2019 3/26/2019 0.50 COMPZ2 WHDBOP DISP P "' Note: SBHP @ 8,214.7', Sensor 8,214.7 8,185.2 08:36 09:06 depth 8,200.3' CTMD, 5880.43' TVD, 10.41 pp9. 3179 psi, •: LRS on location, PJSM, rig up air and confirm line is free, rig up to customer line and PT to 4,500 psi 3/26/2019 3/26/2019 1.10 DEMOB WHDBOP DISP P Line up to circulate SW down the coil 8,185.2 8,185.0 09:06 1012 3/26/2019 3/26/2019 1.00 DEMOB WHDBOP TRIP P POOH, ,while displacing well 8,185.0 44.2 1012 1112 3/26/2019 3/26/2019 1.45 DEMOB WHDBOP FRZP P At surface, spaceout, PUD & LD 44.2 0.0 11:12 12:39 setting tools. Note: Final Tubing Pressure 372 psi, SW 8,185'-2,500', Deisel 2,500'-0' 3/26/2019 3/26/2019 1.50 DEMOB WHDBOP RURD P Install Nozzle, stab back on with INJH, 0.0 0.0 12:39 14:09 1 1 1 jet stack 3/26/2019 3/26/2019 0.75 DEMOB WHDBOP RURD P *** Note: Wellhead bolts loose torque 0.0 0.0 14:09 14:54 up tree bolts 3/26/2019 3/26/2019 3.10 DEMOB WHDBOP RURD P RDMO, work the rig move checklist 0.0 0.0 14:54 18:00 3/26/2019 3/26/2019 DEMOB WHDBOP RURD P Crew change, Comtinue working Rid 0.0 18:00 18:00 down chaeck list, Nipple down stack and secure for transport, Pits offloaded, Putz rig down. Blow down steam. RIG RELESE 20:00 Page 16116 ReportPrinted: 4/812019 F`EE CEI VED APR 2 9 2019 ConocoPhillips A%CCC ConocoPhillips Alaska Inc_Kuparuk Kuparuk River Unit Kuparuk 3F Pad 3F-01 L1 50-029-21446-60 Baker Hughes INTEQ BAF�UGHES a GE company Definitive Survey Report 22 April, 2019 ConocoPhillips Company: ConocoPhillips Alaska Inc_Kuparuk Project: Kuparuk River Unit Site: Kuparuk 3F Pad Well: 3F-01 Wellbore: 3F-0111 Design: 3F-0111 Project Kuparuk River Unit, North Slope Alaska, United States ConocoPhillips Definitive Survey Report Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Database: Map System: US State Plane 1927 (Exact solution) System Datum: Geo Datum: NAD 1927 (NADCON CONUS) - Map Zone: Alaska Zone 04 Survey (Wellbore) Well 3F-01 3F-01 (3F-01) Well Position +W -S 0.00 usft Northing: 8.352.20 +EI -W 0.00 usft Easting: Position Uncertainty 0.00 usft Wellhead Elevation: Wellbore A� 3F-011.1 �! Magnetics Model Name Sample Date BGGM2018 4/1/2019 Design 3F-0111 Audit Notes: Version: 1.0 Phase: ACTUAL Vertical Section: Depth From (TVD) (usft) 93.00 Survey Program Date From To (usft) (usft) Survey (Wellbore) 100.00 8,200.00 3F-01 (3F-01) 8245.50 8,320.79 3F-01111 MWD INC(3F-011-1) 8.352.20 11,423.21 3F-0111 MWD (3F-01 L1) Well 3F-01 3F-01 @ 93.00usft (3F-01) 3F-01 @ 93.00usft (3F-01) 'True Minimum Curvature EDT 14 Alaska Production Mean Sea Level Using Well Reference Point Using geodetic scale factor 5,985,734.98usft 508,662.35usft usft Declination r) 16 61 Tie On Depth: 8,200.00 +N/ -S (usft) 0.00 Tool Name GCT -MS MWD-INC—ONLY MWD +E/ -W (US8) 0.00 Description Schlumberger GCT multishot MWD-INC—ONLY—FILLER MWD - Standard Latitude: Longitude: Ground Level: Dip Angle (I 80.87 70' 22' 20.086 N 149° 55'46.549 W 0.00 usft Field Strength mT) 57419 Direction C) 180.00 i i Survey Survey Start Date 8/18/2000 End Date 3/23/2019 3/23/2019 3/24/2019 3/24/2019 4222019 1:05:50PM Page 2 COMPASS 5000.14 Build 85D ConocoPhillips BA ER ConocoPhillips Definitive Survey Report Company: ConocoPhillips Alaska Inc_Kuparuk Local Co-ordinate Reference: Well 3F-01 Project: Kuparuk River Unit TVD Reference: 3F-01 @ 93.00usft (3F-01) Site: Kuparuk 3F Pad MD Reference: 3F-01 @ 93.00usft (3F-01) Well: 3F-01 North Reference: True Wellbore: 3F-01 L1 Survey Calculation Method: Minimum Curvature Design: 3F-01 L1 Database: EDT 14 Alaska Production Survey Annotation TIP TOWS/KOP Interpolated Azimuth Interpolated Azimuth Interpolated Azimuth 4/222019 1:05:50PM Page 3 COMPASS 5000.14 Build 85D Map Map Vertical MD Inc AN TVD TVDSS +WS +EI -W Northing Easttng DLS Section (wft) (°) (°) (usft) (usH) (waft) (usH) (ft) (H) (°/700) IHI Survey Too[ Namr 8,200.00 46.23 136.05 5,880.18 5,787.18 -3,837.39 3,658.19 5,981,902.21 512,324.61 0.34 3,837.39 MWD-INC_ ONLY (2) 8,245.50 46.29 135.95 5,911.64 5,818.64 -3,861.03 3,681.02 5,981,878.59 512,347.47 0.21 3,881.03 MWD -INC _ONLY (2) 8,270.57 53.49 135.78 5,927.78 5,834.78 -3,874.78 3,694.37 5,981,864.86 512,360.83 28.72 3,874.78 MWD -INC ONLY(2) 8,290.69 63.59 135.67 5,938.26 5,845.26 -3,887.06 3,706.33 5,981,852.60 512,372.81 50.20 3,887.06 MWD -INC ONLY(2) 8,320.79 78.63 135.54 5,947.98 5,854.98 -3,907.35 3,726.20 5,981,832.34 512,392.70 49.97 3,907.35 MWD -INC ONLY(2) 8,352.20 93.59 135.41 5,950.10 5,857.11 -3,929.62 3,748,11 5,981,810.09 512,414.63 47.63 3,929.62 MWD (3) 8,382.39 96.24 136.31 5,947.52 5,854.52 -3,951.21 3,769.06 5,981,788.53 512,435.80 9.27 3,951.21 MWD (3) 8,412.00 98.16 137.27 5,943.81 5,850.81 -3,972.62 3,789.17 5,981,787.15 512,455.74 7.24 3,972.62 MWD (3) 8,441.78 99.84 137.86 5,939.15 5,846.15 -3,994.32 3,809.02 5,981,745.46 512,475.61 5.97 3,994.32 MWD (3) 8,472.59 100.03 139.33 5,933.83 5,84D.83 4.017.09 3,829.09 5,981,722.73 512,495.70 4.74 4,017.09 MWD (3) 8,502.27 100.18 141.31 5,928.63 5,835.63 4.039.57 3,847.74 5,981,700.27 512,514.38 6.59 4,039.57 MWD (3) 8,535.01 100.87 143.59 5,922.64 5,829.64 4.065.09 3,867.36 5,981,674.77 512,534.02 7.16 4,085.09 MWD (3) 8,565.43 100.48 145.41 5,917.01 5,824.01 4,089.43 3,884.72 5,981,650.46 512,551.41 6.03 4,089.43 MWD (3) 8,595.51 99.72 147.81 5,911.74 5,818.74 -4,114.15 3,901.01 5,981,825.76 512,567.73 8.23 4,114.15 MWD (3) 8,625.61 99.15 149.39 5,906.81 5,813.81 -4.139.50 3,916.48 5,981,600.43 512,583.23 5.51 4,139.50 MWD (3) 8,655.71 98.97 151.80 5,902.07 5,809.07 -4,165.39 3,931.08 5,981,574.56 512,597.85 7.93 4,165.39 MWD (3) 8,685.52 99.07 153.79 5,897.39 5,804.39 -4,191.57 3,944.54 5,981,548.39 512,611.34 6.80 4,191.57 MWD(3) 8,715.54 98.82 156.19 5,892.73 5,799.73 -4,218.44 3,957.07 5,981,521.54 512,623.91 7.94 4,218.44 MWD (3) 8,745.43 98.97 158.08 5,888.10 5,795.10 -4,245.65 3,968.55 5,981,494.35 512,635.41 6.20 4,245.65 MWD (3) 8,779.23 98.26 160.63 5,883.04 5,790.04 -4,276.92 3,980.34 5,981,463.10 512,647.24 7.81 4,276.92 MWD (3) 8809.95 97.44 162.66 5,678.84 5,785.84 4.305.80 3,989.92 5,981,434.23 512,656.85 7.07 4,305.80 MWD (3) 8,845.75 97.09 165.13 5,874.32 5,781.32 4,339.92 3,999.77 5,981,400.13 512,686.74 6.91 4,339.92 MWD (3) 8,875.87 96.68 166.94 5,870.70 5,777.71 -4.368.94 4,008.99 5,981,371.12 512,673.99 6.12 4,368.94 MWD (3) 8,905.99 Wall 169.06 5,867.20 5,774.20 4,398.20 4,013.20 5,981,341.87 512,880.24 6.99 4,398.20 MWD (3) 8,935.11 96.78 171.04 5,863.79 5,770.79 -4,426.68 4,018.20 5,981,313.40 512.685.27 6.76 4,426.68 MWD (3) 8,970.34 97.60 173.26 5,859.38 5,768.38 -4,461.30 4,022.98 5,981,278.78 512,690.08 6.67 4,461.30 MWO(3) 9,000.93 97.79 175.73 5,855.26 5,762.28 -4,491.47 4,025.88 5,961,248.62 512,693.03 8.03 4,491.47 MWD (3) 9,036.23 98.51 178.31 5,850.28 5,757.28 -4,526.37 4,027.70 5,981,213.73 512,694.88 7.52 4,526.37 MWD (3) 9,075.83 96.19 180.17 5,845.21 5,752.21 4.56563 4,028.22 5,981174.47 512,695.45 7.48 4.565.63 MWD (3) 9,100.82 95.45 178.82 5,842.88 5,749.58 -4,59049 4,026.44 5,981,14961 512695.70 6.14 4,590.49 MWD (3) Annotation TIP TOWS/KOP Interpolated Azimuth Interpolated Azimuth Interpolated Azimuth 4/222019 1:05:50PM Page 3 COMPASS 5000.14 Build 85D ConocoPhillips an ConocoPhillips Definitive Survey Report Company: ConocoPhillips Alaska Inc_Kuparuk Local Co-ordinate Reference: Well 3F-01 Project: Kuperuk River Unit ND Reference: 31F-01 @ 93.00usft (3F-01) Site: Kuparuk 3F Pad MD Reference: 3F-01 @ 93.00usft (3F-01) Well: 31F-01 North Reference: True Wellbore: 3F-011-1 Survey Calculation Method: Minimum Curvature Design: 3F-01-1 Database: EDT 14 Alaska Production Survey Map Map Vertical MD Inc Aad ND NDSS 4lUS +EI -W Northing Northing Fasting DLS Section (usH) (°) (') Neff) (usR) (ustt) WOO Survey Tool Name Annotation (ft) (M 9,130.92 95.88 177.99 5,839.70 5,746.70 -4,620.43 4,029.27 5,981,119.67 512,696.56 3.09 4,620.43 MM (3) 9,161.01 95.45 177.80 5,836.73 5,743.73 -4,650.36 4,030.37 5,981,089.76 512,697.70 1.56 4,650.36 MWD (3) 9,190.73 95.30 177.23 5,833.95 5,74D.95 4,679.92 4,031.66 5,981,060.20 512,699.02 1.98 4,679.92 MWD (3) 9,220.85 93.62 176.22 5,831.61 5,738.61 -4,709.90 4,033.37 5,981,030.23 512,700.77 6.50 4,709.90 MWD (3) 9,255.21 93.01 176.53 5,829.62 5,736.62 4,744.13 4,035.54 5,980,996.00 512,702.97 1.99 4,744.13 MWD (3) 9,290.95 90.61 175.32 5,828.49 5,735.49 4,779.76 4,038.08 5,980,960.38 512,705.55 7.52 4,779.76 MWD (3) 9,324.95 89.82 175.99 5,828.36 5,735.37 4,813.66 4,040.65 5,980,928.48 512,708.17 3.05 4,813.66 MWD (3) 9,355.19 90.43 176.29 5,828.30 5,735.30 4,843.83 4,042.69 5,980,896.31 512,710.24 2.25 4,843.83 MWD (3) 9,385.29 90.52 176.60 5,828.05 5,735.05 4,873.87 4,044.56 5,980,866.28 512,712.14 1.07 4,873.87 MWD (3) 9,415.29 90.31 176.56 5,827.83 5,734.83 4,903.82 4,046.35 5,980,836.34 512,713.96 0.71 4,903.82 MWD (3) 9,445.33 91.10 177.42 5,827.46 5,734.46 4,933.81 4,047.92 5,980,806.35 512,715.58 3.89 4,933.81 MWD (3) 9,480.95 88.04 176.66 5,827.73 5,734.73 4,969.38 4,049.76 5,980,770.79 512,717.46 8.85 4,969.38 MWD (3) 9,512.91 89.48 178.35 5,828.42 5,735.42 -5,001.30 4,051.15 5,980,738.87 512,718.88 6.95 5,001.30 MWD (3) 9,540.38 89.08 179.19 5,828.77 5,735.77 -5,028.76 4,051.74 5,980,711.41 512,719.50 3.39 5,028.76 MWD (3) 9,570.19 89.02 178.23 5,829.26 5,736.26 -5,058.56 4,052.41 5,980,681.62 512,720.21 3.23 5,058.56 MWD (3) 9,601.35 89.20 180.22 5,829.74 5,738.75 -5,089.71 4,052.84 5,980,650.47 512,720.67 6.41 5,089.71 MWD (3) 9,635.27 88.37 181.19 5,830.46 5,737.46 -5,123.62 4,052.42 5,980,616.56 512,720.29 3.76 5,123.62 MWD (3) 9,665.33 87.72 181.52 5,831.49 5,738.49 -5,153.65 4,051.71 5,980,586.53 512,719.61 2.42 5,153.65 MWD (3) 9,697.43 87.32 182.97 5,832.88 5,739.88 -5,185.70 4,050.45 5,980,554.49 512,718.39 4.68 5,185.70 MWD (3) 9,730.17 88.10 184.18 5,834.19 5,741.19 -5,218.35 4,048.41 5,980,521.84 512,716.39 4.39 5,218.35 MWD (3) 9,765.85 85.30 185.58 5,836.24 5,743.24 -5,253.84 4,045.38 5,980,486.35 512,713.41 8.77 5,253.84 MWD (3) 9,790.25 86.21 186.51 5,838.05 5,745.05 5,278.03 4,042.82 5,980,462.16 512,710.87 5.33 5,278.03 MWD (3) 9,820.22 87.36 187.92 5,839.73 5,746.73 -5,307.72 4,039.06 5,980,432.47 512,707.15 6.07 5,307.72 MWD (3) 9,850.83 87.45 189.22 5,841.11 5,748.11 -5,337.95 4,034.50 5,960,402.23 512.702.63 4.25 5,337.95 MWD (3) 9,885.95 88.12 189.50 5,842.47 5,749.47 5,372.58 4,028.80 5,98D,367.60 512,696.96 2.07 5,372.58 MWD (3) 9,915.79 88.09 188.98 5,843.46 5,750.46 -5,402.02 4,024.01 5,980,338.16 512,892.21 1.74 5,402.02 MWD (3) 9,945.91 87.97 188.61 5,844.49 5,751.49 -5,431.77 4,019.41 5,980,308.41 512,687.64 1.29 5,431.77 MWD (3) 9,975.85 87.45 187.71 5,845.69 5,752.69 -5,461.38 4,015.16 5,980,278.80 512,683.43 3.47 5,461.38 MWD(3) 10,006.33 86.87 186.24 5,847.20 5,754.20 -5,491.59 4,011.46 5,980,248.58 512,679.76 5.18 5,491.59 MWD (3) 10835.47 87.63 18937 5,648.60 5,755.60 -5,520.57 4,008.77 5,980,219.60 512,677.11 6.92 5,520.57 MWD (3) 10.066.13 90.71 183.70 584904 5,756.04 -5551.15 480662 5,980.189.02 512.674.99 10.28 5,551.15 MWD(3) 4222019 1:05.50PM Page 4 COMPASS 5000.14 Build 850 ConocoPhillips BA ER ConocoPhillips Definitive Survey Report H Es Company: ConocoPhillips Alaska Inc_Kuparuk Local Co-ordinate Reference: Well 3F-01 Project: Kuparuk River Unit TVD Reference: 3F-01 @ 93.00usft(3F-01) Site: Kuparuk 3F Pad MD Reference: 3F-01 Q 93.00usft (3F-01) Well: 3F-01 North Reference: True Wellbore: 3F-01 L1 Survey Calculation Method: Minimum Curvature Design: 3F-01 L1 Database: EDT 14 Alaska Production Survey 41222019 1:05:50PM Page 5 COMPASS 5000.14 Build 85D Map Map Vertical MD Inc Azl TVD TVDSS +NIS +El -W Northing Easting OLS Section (usft) (°) l°) (usft) (usft) (usft) (usft) (°1100') Survey Tool Name Annotation (ft) IN) (ft) 10,095.79 92.92 183.11 5,848.10 5,755.10 -5,580.74 4,004.85 5,980,159.43 512,673.26 7.71 5,580.74 MWD (3) 10,126.05 94.06 180.04 5,846.26 5,753.26 -5,610.93 4,004.02 5,980,129.25 512,672.46 10.80 5,610.93 MWD(3) 10,156.09 96.55 180.11 5,843.48 5,750.48 -5,640.64 4,003.99 5,980,099.34 512,672.46 8.29 5,640.84 MWD (3) 10,185.41 94.64 176.68 5,840.62 5,747.62 -5,670.00 4,004.80 5,980,070.18 512,673.31 13.34 5,670.00 MWD (3) 10,215.71 96.34 176.10 5,837.73 5,744.73 -5,700.10 4,006.70 5,980,040.09 512,675.25 5.93 5,700.10 MWD (3) 10,245.57 97.11 173.62 5,834.23 5,741.23 -5,729.64 4,009.36 5,980,010.56 512,677.94 8.64 5,729.64 MWD (3) 10,275.49 97.69 170.36 5,830.37 5,737.37 -5,759.01 4,013.49 5,979,981.19 512,682.10 10.98 5,759.01 MWD (3) 10,305.97 97.35 168.50 5,826.38 5,733.38 -5,788.72 4,019.03 5,979,951.50 512,687.68 6.15 5,788.72 MIND (3) 10,336.05 97.20 167.19 5,822.57 5,729.57 5,817.88 4,025.32 5,979,922.34 512,693.99 4.35 5,617.88 MWO(3) 10,379.12 95.40 163.01 5,817.85 5,724.65 -5,859.24 4,036.32 5,979,881.00 512,705.05 10.51 5,859.24 MWD (3) 10,410.67 96.18 162.30 5,814.66 5,721.66 5,889.20 4,045.68 5,979,851.05 512,714.44 3.34 5,889.20 MWD (3) 10,439.95 96.45 165.43 5,811.44 5,718.44 -5,917.16 4,053.77 5,979,823.11 512,722.56 10.66 5,917.16 MWD (3) 10,470.32 96.40 168.55 5,808.04 5,715.04 -5,946.56 4,060.56 5,979,793.72 512,729.39 10.21 5,946.56 MWD (3) 10,500.37 96.64 170.41 5,804.63 5,711.63 -5,975.91 4,066.01 5,979,764.38 512,734.87 6.20 5,975.91 MWD (3) 10,530.10 95.91 171.56 5,801.38 5,708.38 -6,005.10 4,070.64 5,979,735.20 512,739.53 4.56 6,005.10 MWD (3) 10,560.20 91.20 171.42 5,799.52 5,706.52 -6,034.80 4,075.09 5,979,705.50 512,744.01 15.65 6,034.80 MWD (3) 10,589.85 92.03 173.63 5,798.68 5,705.68 -6,064.18 4,078.94 5,979,676.13 512,747.90 7.96 6,064.18 MWD (3) 10,619.65 91.69 175.23 5,797.71 5,704.71 -6,093.83 4,081.83 5,979,846.49 512,750.83 5.49 6,093.83 MWD (3) 10,849.74 90.92 177.87 5,797.03 5,704.03 -6,123.85 4,083.64 5,979,616.47 512,752.67 9.14 6,123.85 MWD (3) 10,681.03 89.23 178.99 5,796.99 5,703.99 -6,155.13 4,084.50 5,979,585.20 512,753.56 6.48 6,155.13 MWD (3) 10,710.15 88.16 180.29 5,797.65 5,704.65 -6,184.24 4,084.68 5,979,556.09 512,753.78 5.78 6,184.24 MWD (3) 10,739.68 86.93 182.72 5,798.91 5,705.91 -6,213.73 4,083.91 5,979,526.6D 512,753.04 9.22 6,213.73 MWD (3) 10,767.25 86.31 184.55 5,800.54 5,707.54 -6,241.19 4,082.17 5,979,499.14 512,751.33 7.00 6,241.19 MWD(3) 10,800.19 86.86 186.82 5,802.50 5,709.50 -6,273.91 4,078.91 5,979,468.42 512,748.11 7.08 6,273.91 MWD (3) 10,833.73 90.43 188.85 5,803.29 5,710.30 -6,307.12 4,074.34 5,979,433.21 512,743.58 12.24 6,307.12 MWD (3) 10,850.88 92.15 190.70 5,802.91 5,709.91 -6,324.00 4,071.43 5,979,416.33 512,740.69 14.74 6,324.00 MWD(3) 10,879.86 92.33 193.80 5,801.78 5,708.78 -6,352.31 4,065.28 5,979,388.01 512,734.57 10.70 6,352.31 MWD (3) 10,911.18 89.45 193.51 5,801.29 5,708.29 -6,382.74 4,057.89 5,979,357.58 512,727.22 9.24 6,382.74 MWD(3) 10,940.66 86.25 192.63 5,802.39 5,709.40 -6,411.43 4,051.23 5,979,328.88 512,720.59 11.26 6,411.43 MWD (3) 10.968.81 85.69 191.20 5,604.37 5,711.37 -6438.91 4045.43 5,979,301.40 512.714.83 5.44 6438.91 MWD(3) 11000.80 86.13 189.84 5.80666 5,713.66 -6,470.28 4.039.61 5,979270.03 512,709.04 4.46 6,470.28 MWD (3) 41222019 1:05:50PM Page 5 COMPASS 5000.14 Build 85D ConocoPhillips ConocoPhillips Definitive Survey Report Company: ConocoPhillips Alaska Inc_Kuparuk Local Co-ordinate Reference: Well 3F-01 Project: Kuparuk River Unit TVD Reference: 3F-01 @ 93.00usft(3F-01) Site: Kuparuk 3F Pad MD Reference: 3F-01 @ 93.00usft (3F-01) Well: 3F-01 North Reference: True Wellbore: 3F-01 L1 Survey Calculation Method: Minimum Curvature Design: 3F-01 -1 Database: EDT 14 Alaska Production Survey Map Map Vertical MD Inc Azi TVD TVDSS +NI -S +E/.W Northing Fasting DES Section (usft) (°) P) (usft) (usft) (usft) (usft) (°/100') Survey Tool Name (ft) (ft) (ft) 11,031.58 87.02 187.13 5,808.49 5,715.49 -6,500.66 4,035.07 5,979,239.64 512,704.54 9.25 6,500.66 MWD (3) 11,060.67 87.35 183.06 5,809.92 5,716.92 -8.529.60 4,032.49 5,979,210.71 512,701.99 14.02 6,529.60 MWD (3) 11,092.31 87.36 179.89 5,811.38 5,718.38 -6,561.19 4,031.68 5,979,179.12 512,701.22 10.01 6,561.19 MWD (3) 11,125.13 88.31 178.70 5,812.62 5,719.62 -6.593.98 4,032.08 5,979,146.33 512,701.66 4.64 6,593.98 MWD (3) 11,154.94 88.50 177.03 5,813.45 5,720.45 -6,623.76 4,033.19 5,979,116.55 512,702.80 5.64 6,623.76 MWD (3) 11,185.99 87.08 175.48 5,814.65 5,721.65 -6.654.72 4,035.22 5,979,085.60 512,704.87 6.77 6,654.72 MWD (3) 11,220.11 87.85 178.89 5,816.16 5,723.16 -6,688.76 4,036.89 5,979,051.57 512,706.58 10.24 6,688.76 MWD (3) 11,249.86 89.17 181.28 5,816.93 5,723.93 -6,718.50 4,036.85 5,979,021.83 512,706.57 9.17 6,718.50 MWD (3) 11,280.63 87.57 183.69 5,817.81 5,724.81 -6,749.22 4,035.52 5,978,991.11 512,705.27 9.40 6,749.22 MWD (3) 11,311.01 86.93 185.78 5,819.27 5,726.27 -6,779.46 4,033.01 5,978,960.87 512,702.80 7.19 6,779.46 MWD(3) 11,341.13 86.07 188.40 5,821.11 5,728.11 .6,809.29 4,029.30 5,978,931.04 512,699.13 9.14 6,809.29 MWD (3) 11,370.49 86.99 190.36 5,822.88 5,729.88 -6,838.20 4,024.53 5,978,902.12 512,694.38 7.36 6,838.20 MIND (3) 11,400.79 89.36 193.56 5,823.85 5,730.85 -6,867.82 4,018.25 5,978,872.50 512,688.14 13.14 6,867.82 MWD (3) 11,423.21 88.43 196.20 5,824.28 5,731.28 .6,889.49 4,012.49 5,978,850.83 512,682.41 12.48 6,889.49 MWD(3) 11.463.00. 88.43 196.20 5,825.37 . 5,732.37 -6,927.68 4,001.40 5,978,812.62 512,671.36 0.00 6,927.68 PROJECTED to TD Annotation nAd(ER UGI 4222019 1:05:50PM Page 6 COMPASS 5000.14 Build 05D BA ER PRINT DISTRIBUTION LIST F�UGHES a GE company COMPANY Con lcoPhillips Alaska, Inc. WELL NAME 3F -01L1 FIELD Greater Kuparuk Area COUNTY North Slope Borough BHI DISTRICT Alaska AUTHORIZED BY Patrick Rider EMAIL Patrick.Riden< akerhughes.com STATUS Final Replacement: • 1'$UJi1 ZM, ADDRESS (FEDEX WILL WT DELIVER TO P.O. BOX) PERSON ATTENTION Vh Slop I BPNorie. EOA, PROC, PRB-20 (Office 109) D&GWO Wells Admin Brenda Glassmaker & Peggy O'Neill 900 F. Benson Blvd. Anchorage, Alaska 99508 2 ConocoPhillips Alaska Inc. Attn: Ricky F,Igarien A'f0 708 700 G Street Anchorage, AK 99510 3 ExxonNI bil, Alaska .Attn: Lynda M. Yaskell and/or Leonardo Elias 3201 C Street, Suite 505 Anchorage, AK 99503 219036 30658 se sign and return one copy of this transmittal form to: DcoPhillips Alaska, Inc. Osterkamp (WNS Petroleum Technician) G Street. forage, Alaska 99510 LOG TYPE GR - RES LOG DATE March 23, 2019 TODAYS DATE April 23, 2019 Revision No Details: Rev. Requested by: FIELD FINAL CD/DVD FINAL PRELIM LOGS (las, dlis, PDF, META, SURVEY REPORT LOGS CGM, Final Surveys) (Compass) # OF PRINTSAs Ur rKIN # OF COPIES 1# OF COPIES # OF COPIES lu 4 4 4 V d An- 4 State of Alaska - AOGCC 1 1 Attn: Natural Resources Technician If 333 W. 7th Ave, Suite 100 Anchorage, Alaska 99501 5 DNR - Division ofOil & Gas a'* 1 Atm: Resource Evaluation 550 West 7th Avenue, Suite 1100 Anchorage, Alaska 99501 *a• Stamp "confidential" on all material deliver to DNR 6 BP Exploration (Alaska) Inc. Petrotechnical Data Center, tR2-I 900 E. Benson Blvd Anchorage, Alaska 99508 TOTALS FOR THIS PAGE: 0 1 2 0 0 THE STATE 01ALASKA GOVERNOR MIKE DUNLEAVY James Ohlinger Staff CTD Engineer ConocoPhillips Alaska, Inc. PO Box 100360 Anchorage, AK 99510-0360 m Alaska Oil and Gas Conservation Commission 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 www.00gcc.alaska.gov Kuparuk River Field, Kuparuk River Oil Pool, KRU 3F -01L1 ConocoPhillips Alaska, Inc. Permit to Drill Number: 219-036 Surface Location: 89' FNL, 162' FWL, SEC. 29, T12N, R9E, UM Bottomhole Location: 1783' FNL, 4130' FWL, SEC. 32, T12N, R9E, UM Dear Mr. Ohlinger: 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 185-225, API 50-029-21446-00- 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, y n 0. l&� Jessaie L. Chmielowski Commissioner DATED this II I day of March, 2019 STATE OF ALASKA r ,ASKA OIL AND GAS CONSERVATION COR ,SSION PERMIT TO DRILL 20 AAC 25.005 iIAft 0 G 2019 1a. Type of Work: 1 b. Proposed Well Class: Exploratory - Gas ❑ Service - WAG ❑ Service - Disp ❑ to. Specigif4Jen 1s' a r. Drill ❑ Lateral ❑✓ Slratigraphic Test ❑ Development - Oil ❑Z Service - Winj ❑ Single Zone Coalbed Gas ❑ Gas Hydrates ❑ Reddll ❑ Reentry ❑ Exploratory - Oil ❑ Development - Gas ❑ Service - Supply ❑ Multiple Zone ❑ Geothermal ❑ Shale Gas ❑ 2. Operator Name: 5. Bond: Blanket 0 ' Single Well ❑ 11. Well Name and Number: ConocoPhillips Alaska, Inc. Bond No. 5952180 KRU 3F-01 L1 ' 3. Address: 6. Proposed Depth: 12. Field/Pool(s): P.O. Box 100360 Anchorage, AK 99510-0360 MD: 11500' TVD: 5791' Kuparuk River Field / Kuparuk River Oil Pool 4a. Location of Well (Governmental Section): 7. Property Designation: Surface: 89' FNL, 162' FWL, Sec 29, Tl2N, R9E, UM ADL 25643 ALK 2574 Top of Productive Horizon: 8. DNR Approval Number: 13. Approximate Spud Date: 3949' FNL, 3828' FWL, Sec 29, TI 2N, R9E, UM LONS 83-129 3/19/2019 9. Acres in Property: 14. Distance to Nearest Property: Total Depth: 1783' FNL, 4130' FWL, Sec 32, T12N, R9E, UM 2560 23,400' - 41b. Location of Well (State Base Plane Coordinates - NAD 27): 10. KB Elevation above MSL (ft): 93' ' 15. Distance to Nearest Well Open Surface: x- 508662. y- 5985735 . Zone- 4 GL / BF Elevation above MSL (ft): 52' to Same Pool: 284', 2U-13 ' 16. Deviated wells: Kickoff depth: 8243 ' feet 17. Maximum Potential Pressures in psig (see 20 AAC 25.035) Maximum Hole Angle: 102 degrees Downhole: 3302 • Surface: 2722 - 18. Casing Program: Specifications Top - Setting Depth - Bottom Cement Quantity, c.f. or sacks Hole Casing Weight Grade I Coupling Length MD TVD MD TVD (including stage data) 3" 2-3/8" 4.7# L-80 ST -L 2400' 9100' 5837' 11500' 5791' Slotted Liner 19. PRESENT WELL CONDITION SUMMARY (To be completed for Redrill and Re -Entry Operations) Total Depth MD (ft): Total Depth TVD (ft): Plugs (measured): Effect. Depth MD (ft): Effect. Depth TVD (ft): Junk (measured): 8730' 6245' N/A 8646' 6187' N/A Casing Length Size Cement Volume MD TVD Conductor/Structural 80' 16" 348 sx AS II 115' 115' Surface 3873' 9-5/8" 1020 sx PF "E", 400 sx PF "C" 3908' 3068' Top Job performed w/50 sx PF "C" Production 8750' 7" 325 sx G 8784' 6259' Perforation Depth MID (ft): 8066'-8219', 8417'-8423', 8428'-8468', 8498'-8526' Perforation Depth TVD (ft): 5787'-5893', 6030'-6034', 6037'-6065', 6085'-6105' Hydraulic Fracture planned? Yes ❑ No 7 ' 20. Attachments: Property Plat ❑ BOP Sketch Divertter Sketch B ysis DSleabed Report e Drilling Fluid Progring Program Time v. Depth am e 20 AAC 25.050 requiremot Shallow Hazard lenlse✓ 21. Verbal Approval: Commission Representative: Date 22. 1 hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Contact Name: Ryan McLaug n Authorized Name: James Ohlinger Contact Email: rVan.nncIauqh[inCcDcoP.corn Authorized Tide: Staff CTD Engineer��yy Contact Phone: 907-265-6218 Authorized Signature: 4 Date: 1elf Commission Use Only Permit to Drill q CJ -�/ Number. Ll L 'L-'�p API Number: 50-QZ�—Z17`-E b'C�-� 'cC.j I Permit Approval Date: See cover letter for other requirements. Conditions of approval : If box is checked, well may not be used to explore for, test, or produce coalbed methane, gas hydrates, or gas contained in shales: Other: Samples req'd: Yes ❑ No 2/'Mud log req'd: Yes ❑ Nog ,60P try 71- to 3500 0!--, S r c r Pr -:'V _✓2 pIr V -r5 �a 25 acing measures: Yes No�❑/ Directional svy req'd: Yes u No[] /_ Spacing excepl�in req'd: Yes ❑ No Lh Inclination -only svy req'd: Yes ❑ Ne Post initial injection MIT req'd: Yes ❑ No [jR' v`— APPROVED BY Q Approved by: C I H C MMISSION Date: lr77- 3 7// 9 Form 10-401 Revised 5/20 7 This permit is valid for 24 moot o D ve Submit Form and 20 AAC 25.005(8) Attachments in Duplicate ConocoPhillips Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 March 5, 2019 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 applications for permits to drill two laterals out of the KRU 3F-01 (PTD# 185-225) using the coiled tubing drilling rig, Nabors CDR3-AC. CTD operations are scheduled to begin on March 19th, 2019. The objective will be to drill two laterals, KRU 3F- 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 this application are the following documents: — Permit to Drill Application Forms (10-401) for 3F-01 L1 & 3F-01 L1-01 — Detailed Summary of Operations — Directional Plans for 3F-01 L1 & 3F-01 L1-01 — Current wellbore schematic — Proposed CTD schematic If you have any questions or require additional information, please contact me at 907-265-6218. Sincerely, Ryan McLaughlin Coiled Tubing Drilling Engineer ConocoPhillips Alaska Kuparuk CTD Lateral 3F-011-1, 3F-011-1-01 Application for Permit to Drill Document 1. Well Name and Classification........................................................................................................ 2 (Requirements of 20 AAC 25.005(f) 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)).. - - . ............ ... - - I ....................................................................................................................3 7. Diverter System Information ..........................................................................................................3 (Requirements of 20 AAC 25.005(c)(7))..................................................................................................................................................3 8. Drilling Fluids Program.................................................................................................................. 3 (Requirements of 20 AAC 25.005(c)(8))..................................................................................................................................................3 9. Abnormally Pressured Formation Information.............................................................................4 (Requirements of 20 AAC 25.005(c)(9))..................................................................................................................................................4 10. Seismic Analysis............................................................................................................................. 4 (Requirements of 20 AAC 25.005(c)(10))...............................................................................................................................................A 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 ........... (Requirements of 20 AAC 25.050(b))................................................................... 5 5 16. Attachments....................................................................................................................................6 Attachment 1: Directional Plans for 3F-01 L1, 3F-01 L1-01..............................................................................................6 Attachment 2: Current Well Schematic for 3F-01 L1, 3F-01 L1-01....................................................................................6 Attachment 3: Proposed Well Schematic for 3F-011-1, 3F-011-1-01................................................................................6 Page 1 of 6 March 5, 2019 PTD Application: 3F-01 1-1. 3F-01 L1-01 1. Well Name and Classification (Requirements of 20 AAC 25.005(1) and 20 AAC 25.005(b)) The proposed laterals described in this document are 317-011-1 & Y-011-1-01. 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 3F-01 L1 & 3F-01 L1-01. 3. Blowout Prevention Equipment Information (Requirements of 20 AAC 25.005 (c)(3)) Please reference blowout prevention (BOP) schematics on file with the Commission for Nabors CDR3-AC.. BOP equipment is as required per 20 AAC 25.036 for thru-tubing drilling operations. - Pipe rams, blind rams and the CT pack off will be pressure tested to 250 psi and to 3,500 psi. Using the maximum formation pressure in the area of 3,302 psi in 3F-04 (i.e. 10.6 ppg EMW), the maximum potential surface pressure in 3F-01, assuming a gas gradient of 0.1 psi/ft, would be 2722 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 3F-01 was measured to be 2596 psi (8.5 ppg EMW) on 10/7/2018. The maximum downhole pressure in the 3F-01 vicinity is the 3F-04 at 3302 psi (10.6 ppg EMW) measured on 11/17/2014. --- --- Potential Gas Zones (Requirements of 20 AAC 25.005 (c)(4)(b)) Z The offset injection wells to 3F-01 have injected gas, so there is a possibility of encountering free gas while drilling the 3F-01 L1 and 3F-01 L1-01 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 317-011-1 and 31F-011-1-01 laterals will be shale instability across faults. 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 3F-01 L1 & 3F-01 L1-01 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 March 5, 2019 PTD Application: 3F -01L1, 3F-011_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 3F -01L7 9100' 11,500' 5744' 5698' 2-3/8", 4.7#, L-80, ST -L slotted liner, 0' 115' 1640 670 Surface aluminum billet on to 3F-011_7-07 8243' 11,520' 5817' 5659' 2-3/8", 4.7#, L-80, ST -L slotted liner; 3062' 3520 2020 Production 7" shorty deployment sleeve on to Existing Casing/Liner Information Category OD Weight f Grade Connection Top MD Btm MD Top TVD Btm TVD Burst psi Collapse psi Conductor 16" 62.5 H-40 Welded 0' 115' 0' 115' 1640 670 Surface 9-5/8" 36.0 J-55 BTC 0' 3971' 0' 3062' 3520 2020 Production 7" 26.0 J-55 BTC 0' 8646' 0' 3187' 4980 4320 Tubing 3-1/2" 9.3 L-80 EUE 8rd 0' 7969' 0' 5719' 10160 10540 Tubing 3.5" x 2.875" 8279' 9.2 J-55 EUE 8rd 7960' 8303' 5713' 5952' 6980 7400 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 11.4 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 3F-01 L1 & 3F-01 L1-01 laterals we will target a constant BHP of 11.4ppg 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 March 5, 2019 I• a ; .. 16�:it[.Ti1[cl�iyl�i�c3�rS1�QrSl Pressure at the 3F-01 Window (8243' MD, 5pv4' TVD) Using 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 Background Well KRU 3F-01 is a Kuparuk A/C -sand producer equipped with 3-1/2" tubing. The CTD sidetrack will utilize two lateral to target the C -sand to south of the 3F-01 parent wellbore. The laterals will increase recovery and add additional resources. Pre -CTD Work 1. RU Slickline: Pull TPC, MIT -T, set plug at 8295', bail sand on top of plug 2. RU Coil: Pump Cement, mill/underream cement in 3-1/2" tubing 3. RU Slickline: Dummy whipstock Drift 4. RU E -Line: Caliper, set whipstock @ 8243' MD 5. Prep site for Nabors CDR3-AC rig. Rig Work 1. MIRU Nabors CDR3-AC rig using 2" coil tubing. NU 7-1/16" BOPE, test. 2. 3F-01 L1 Lateral (C sand -south) a. Mill 2.80" window at 8243' MD b. Drill 3" bi-center lateral to TD of 11,500' MD. Page 4 of 6 March 5, 2019 Pumps On (leg bpm) Pumps Off C -sand Formation Pressure 8.5 2565 psi 2565 psi Mud Hydrostatic 8.6 2596 psi 2596 psi Annular friction i.e. ECD, 0.08psi/ft) 659 psi 0 psi Mud + ECD Combined no choke ressure 3252 psi Overbalanced -687psi) 2596 psi Overbalanced -31psi) Target BHP at Window 11.4 3441 psi 3441 psi Choke Pressure Required to Maintain Target BHP 189 psi 845 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 Background Well KRU 3F-01 is a Kuparuk A/C -sand producer equipped with 3-1/2" tubing. The CTD sidetrack will utilize two lateral to target the C -sand to south of the 3F-01 parent wellbore. The laterals will increase recovery and add additional resources. Pre -CTD Work 1. RU Slickline: Pull TPC, MIT -T, set plug at 8295', bail sand on top of plug 2. RU Coil: Pump Cement, mill/underream cement in 3-1/2" tubing 3. RU Slickline: Dummy whipstock Drift 4. RU E -Line: Caliper, set whipstock @ 8243' MD 5. Prep site for Nabors CDR3-AC rig. Rig Work 1. MIRU Nabors CDR3-AC rig using 2" coil tubing. NU 7-1/16" BOPE, test. 2. 3F-01 L1 Lateral (C sand -south) a. Mill 2.80" window at 8243' MD b. Drill 3" bi-center lateral to TD of 11,500' MD. Page 4 of 6 March 5, 2019 PTD Application: 3F -01L1, 3F-01 L1-01 c. Run 2-3/8" slotted liner with aluminum billet from TD up to 9,100' MD. 3. 3F-01 L1-01 Lateral (C sand -south) a. Kickoff of the aluminum billet at 9,100' MD. b. Drill 3" bi-center lateral to TD of 11,520' MD. c. Run 2-3/8" slotted liner with deployment sleeve from TD up to 8,243' MD. 4. Freeze protect, ND BOPE, and RDMO Nabors CDR3-AC rig. Post -Rig Work 5. Return well 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 3F-01 L1 & 3F-01 L1-01 laterals will be displaced to an overbalancing fluid prior to running liner. See "Drilling Fluids" section for more details. — While running 2-3/8" slotted liner, a joint of 2-3/8" non -slotted tubing will be standing by for emergency deployment. A floor valve is made up onto this joint ahead of time, and the rig crew conducts a deployment drill with this emergency joint on every slotted liner run. The 2-3/8" rams will provide secondary well control while running 2-3/8" liner. 14. Disposal of Drilling Mud and Cuttings (Requirements of 20 AAC 25.005(c)(14)) • No annular injection on this well. • All solid waste will be transported to the grind and inject facility at DS -4 Prudhoe Bay for disposal. • Incidental fluids generated from drilling operations will be injected in a Kuparuk Class II disposal well (1R-18 or 1 B disposal facilities) or Prudhoe DS -4 if a Kuparuk facility is unavailable. • All wastes and waste fluids hauled from the pad must be properly documented and manifested. • Contact Kuparuk Environmental Coordinator for questions regarding waste classification. (6704200). 15. Directional Plans for Intentionally Deviated Wells (Requirements of 20 AAC 25.050(b)) Page 5 of 6 March 5, 2019 PTD Application: 3F-011-1, 3F-011-1-01 - 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 I Distance 3F-011-1 23,400' • 3F-011-1-01 23,400' Distance to Nearest Well within Pool Lateral Name Distance Well 3F-01 L1 284' 21-1-13 3F -01L1-01 283' 2U-13 16. Attachments Attachment 1: Directional Plans for the 3F -01L1 &3F -01L1-01 laterals Attachment 2: Current Well Schematic for 3F-01 Attachment 3: Proposed CTD Well Schematic for the 3F -01L1 & 3F -01L1-01 laterals Page 6 of 6 March 5, 2019 ConocC klllips Project Kuparuk RWeranB_2 SIM; Kuparuk 3F Patl wee+.xem leer Myo WELLBORE DETAILS: 3F-Ot 11-01 REITRExcENFORWIN Parent Wellbore' 3F-01 L1 coael�e lxrtlnelemvmve' walval, 3mexmn Well: 0FA1 �rl,n Se+Nn sale wr vertaMflWlReb rtr 3Fd1g93000v(yol) Wallba0: 3FAIL141 oymgy.eom• wn..alauls Tb on MD Salim IV5l Reknm: 5bb (oWx,OME) yenum ")Relelence 3FUIQ93Woc(Mn1) Plan'.OFA1L1A1_wp06(3FA113F.01L1A1) yy+aoeyMl 9ulw9,m `.. zrw3inrnl Wesl(-)fEast(+)(45031sfUm) Eek Wmnm.rI. Hvi.—C—r— D-IlOF1SIL1 F-ISAFIbI 3M-IV9�-INtI P IV M1IN 3Pmnvm -w-lanes-lo lo, llpwv 450 V' iP-Iv.lmtv'li ll5o i -...III K191m •Py I-ILfY IS -W H� IIV1 'IP.IN19 18U0 -_ � 3Y INJY Io ..p - 13FAYi1FLF •p 1 SOV I 2250 III 5M, W nIXXr Tom. b233 156re 1 YY W W/`N IH 3150 3Y1 Ple I 2W IIRw-II 3V 11/3P 11 � 9pJp Poo l rU � �• 3600 BT n R. IJ Q a 31cp]IJH JS00 ` •� I 4950 v -3850 3Y-1 Vn,.l enl.a -1 r Ili rr � ,0 A100 arnl+l m vml-¢- b3p m Also !n 7200 5900 S4W •: zwsd wor gg` wnw.•w ] olnr ou.l ]Y+Imrtml.lnl -7650 I I -8100- i -8550'.. wamm:m I '.._..ter. -9150 9900 211-11011 IV. 10350 W300 -3150 -2'1011 -2250 -1800 -1350 zueam,ma zomrzum 9,-e aPm pmad.njsF-o3) BAKER 011 gUGHES aGEcoinpany +w.mnw ox zwmrzwm zW ursw-u F ` s906 3V 16RV.16 ry 1350 +W-0R„W-06 6350 2WL1ILVp '. mairma ''.. 9ulw9,m `.. zrw3inrnl Wesl(-)fEast(+)(45031sfUm) wNKoaW NK9 eM6 9fOl/A{bl I I � zW ursw-u F ` s906 0 4% 900 1350 1800 2250 2M 3150 3600 6050 4500 1950 Stec 5850 6300 6350 7200 7650 8100 8550 9000 9450 9900 10350 10800 11250 11700 '. mairma ''.. 9ulw9,m `.. zrw3inrnl Wesl(-)fEast(+)(45031sfUm) wNKoaW NK9 ]ODSTI-05 N-0Kll-01 9fOl/A{bl ConocoPhillips _ConocoPhillips Export Company Kuparuk River Unit Kuparuk 3F Pad 3F-01 3F-011-1 Plan: 3F-01 L1_wp06 Standard Planning Report 27 February, 2019 BER GHES TGE company ConocoPhillips Database: EDT 14 Alaska Production Company: _ConocoPhillips Export Company Project: Kupawk River Unit Site: Kupawk 3F Pad Well: 3F-01 Wellbore: 3F-0111 Design: 3F-01L1_wp06 ConocoPhillips 8,200.00 Planning Report Direction Local Co-ordinate Reference: Well 3F-01 TVD Reference: Mean Sea Level MD Reference: 3F-01 @ 93.00usft (3F-01) North Reference: True Survey Calculation Method: _ Minimum Curvature Project Kupawk River Unit, North Slope Alaska, United States Map System: US State Plane 1927 (Exact solution) System Datum: Mean Sea Level Geo Datum: NAD 1927 (NADCON CONUS) Using Well Reference Point Map Zone: Alaska Zone 04 Using geodetic scale factor BA ER I UGHFS a GEmmpany Site Kupawk 3F Pad Site Position: Northing: 5,985,734.46 usft • Latitude: 70° 22'20.081 N From: Map Easting: 508,662.33 usft • Longitude: 149° 55'46.550 W Position Uncertainty: 0.00 Usti Slot Radius: 0.000in Grid Convergence: 0.07 ° Wellbore Magnetics Design Audit Notes: Version: Vertical Section: 3F-0111 Model Name Sample Date Declination l°) BGGM2018 4/1/2019 16.61 3F-01L1_wp06 Phase: PLAN Depth From (ND) +N/ -S (usft) (usft) 0.00 0.00 Dip Angle Field Strength (nT) 8087 57,419 Tie On Depth: 8,200.00 +E/ -W Direction (usft) -- Well 3F-01 Well Position +NIS 0.00 usft Northing: 5,985,734.98 usft Latitude: 70° 22'20.086 N +E/ -W 0.00 usft Easting: 508,662.35 usft Longitude: 149" 55'46.549 W Position Uncertainty 0.00 usft Wellhead Elevation: usft Ground Level: 0.00 usft Wellbore Magnetics Design Audit Notes: Version: Vertical Section: 3F-0111 Model Name Sample Date Declination l°) BGGM2018 4/1/2019 16.61 3F-01L1_wp06 Phase: PLAN Depth From (ND) +N/ -S (usft) (usft) 0.00 0.00 Dip Angle Field Strength (nT) 8087 57,419 Tie On Depth: 8,200.00 +E/ -W Direction (usft) (°) 0.00 180.00 21272019 11:44.07AM Page 2 COMPASS 5000.14 Build 85D Plan Sections BA UGI ES a GEcompany Measured ConocoPhillips ConocoPhillips Planning Report Database: EDT 14 Alaska Production Local Coordinate Reference: Well 3F-01 Company: _ConocoPhillips Export Company TVD Reference: Mean Sea Level Project: Kuparuk River Unit MD Reference: 3F-01 @ 93.00usft (3F-01) Site: Kuperuk 3F Pad North Reference: True Well: 3F-01 Survey Calculation Method: Minimum Curvature Wellbore: 3F-011-1 (usft) (°) Design: 3F-011-1_wp06 (usft) Plan Sections BA UGI ES a GEcompany Measured TVD Below Dogleg Build Turn Depth Inclination Azimuth System +WS +El -W Rate Rate Rate TFC (usft) (°) (°) (usft) (usft) (usft) (°1100usft) ('1100usft) (°/100usft) (•) 8,200.00 46.23 136.05 5,787.18 -3,837.39 3,658.19 0.00 0.00 0.00 0.00 8,243.00 46.29 135.96 5,816.91 -3,859.74 3,679.76 0.21 0.14 -0.21 -47.33 8,268.00 55.04 135.96 5,832.74 -3,873.62 3,693.19 35.00 35.00 0.00 0.00 8,361.24 97.00 135.96 5,854.76 -3,937.22 3,754.70 45.00 45.00 0.00 0.00 8,432.00 101.88 136.84 5,843.16 -3,987.75 3,802.82 7.00 6.89 1.24 10.00 8,540.00 98.60 143.76 5,823.94 -4,069.48 3,870.63 7.00 -3.03 6.41 115.00 9,050.00 95.82 179.65 5,757.79 4,541.91 4,026.27 7.00 -0.55 7.04 92.00 9,150.00 94.56 172.74 5,748.73 4,641.22 4,032.88 7.00 -1.25 -6.92 260.00 9,330.00 93.15 185.29 5,736.58 4,820.42 4,035.96 7.00 -0.79 6.97 96.00 9,510.00 93.07 172.67 5,726.78 -4,999.76 4,039.16 7.00 -0.04 -7.01 270.00 9,750.00 88.66 188.88 5,723.13 -5,238.85 4,035.90 7.00 -1.84 6.76 105.00 9,850.00 87.46 181.98 5,726.53 -5,338.28 4,026.44 7.00 -1.20 -6.90 260.00 9,950.00 85.67 188.76 5,732.53 -5,437.60 4,017.11 7.00 -1.79 6.78 105.00 10,200.00 93.13 172.92 5,735.17 -5,686.59 4,013.46 7.00 2.99 -6.34 295.00 10,400.00 97.80 186.19 5,716.04 -5,885.17 4,015.09 7.00 2.33 6.63 70.00 10,500.00 94.80 192.55 5,705.06 -5,983.18 3,998.89 7.00 -3.00 6.36 115.00 10,650.00 92.55 182.27 5,695.43 -6,131.41 3,979.62 7.00 -1.50 -6.85 258.00 10,900.00 83.81 167.09 5,703.42 -6,379.25 4,002.61 7.00 -3.49 -6.07 240.00 11,100.00 86.40 180.90 5,720.57 -6,576.92 4,023.36 7.00 1.29 6.91 80.00 11,270.00 93.07 190.76 5,721.36 -6,745.74 4,006.12 7.00 3.93 5.80 56.00 11,500.00 99.70 175.99 5,695.64 -6,973.13 3,992.53 7.00 2.88 -6.42 295.00 Target 227/2019 11:44:07AM Page 3 COMPASS 5000.14 Build 85D ConocoPhillips ConocoPhillips Planning Report F U HES a GEmmpary Database: EDT 14 Alaska Production Local Co-ordinate Reference: Well 3F-01 Company: _ConocoPhillips Export Company TVD Reference: Mean Sea Level Project: Kuparuk River Unit MD Reference: 3F-01 @ 93.00usft (3F-01) Site: Kuparuk 3F Pad North Reference: True Well: 3F-01 Survey Calculation Method: Minimum Curvature Wellbore: 3F-011.1 Dogleg Toolface Design: 3F-01L1_wp06 Map Depth Planned Survey Measured TVD Below Vertical Dogleg Toolface Map Map Depth Inclination Azimuth System +NIS +E1 -W Section Rate Azimuth Northing Easting (usft) (°) (°) (usft) (usft) (usft) (usft) (°1100usft) (°) (usft) (usft) 8,200.00 46.23 136.05 5787.18 -3,837.39 3,658.19 3,837.39 0.00 0.00 5,981,902.21 512,324.61 TIP 8,243.00 46.29 135.96 5,816.91 -3,859.74 3,679.76 3,859.74 0.21 -47.33 5,981,879.89 512,346.21 KOP/TOWS 8,268.00 55.04 135.96 5,832.74 -3,873.62 3,693.19 3,873.62 35.00 0.00 5,981,866.02 512,359.65 Start 45 DLS 8,300.00 69.44 135.96 5,647.60 -3,893.93 3,712.83 3,893.93 45.00 0.00 5,981,845.74 512,379.31 8,361.24 97.00 135.96 5,854.76 -3,937.22 3,754.70 3,937.22 45.00 0.00 5,981,802.50 512,421.23 End 45 DLS/Start 7 DLS 8,400.00 99.67 136.44 5,849.15 -3,964.90 3,781.24 3,964.90 7.00 10.00 5,981,774.86 512,447.79 8,432.00 101.88 136.84 5,843.16 -3,987.75 3,802.82 3,987.75 7.00 10.07 5,981,752.03 512,469.40 5 8,500.00 99.83 141.22 5,830.35 -4,038.16 3,846.59 4,038.16 7.00 115.00 5,981,701.68 512,513.23 8,540.00 98.60 143.76 5,823.94 -4,069.48 3,870.63 4,069.48 7.00 115.82 5,981,670.39 512,537.30 6 8,600.00 98.43 148.01 5,815.05 -4,118.59 3,903.90 4,118.59 7.00 92.00 5,981,621.32 512,570.62 8,700.00 98.05 155.07 5,800.70 -0,205.54 3,951.03 4,205.54 7.00 92.63 5,981,534.43 512,617.85 8,800.00 97.55 162.12 5,787.11 4,297.72 3,987.16 4,297.72 7.00 93.64 5,981,442.30 512,654.08 8,900.00 96.93 169.15 5,774.49 4,393.76 4,011.76 4,393.76 7.00 94.60 5,981,346.30 512,678.79 9,000.00 96.21 176.16 5,763.03 4,492.23 4,024.46 4,492.23 7.00 95.49 5,981,247.86 512,691.60 9,050.00 95.82 179.65 5,757.79 -4,541.91 4,026.27 4,541.91 7.00 96.29 5,981,198.18 512,693.47 7 9,100.00 95.20 176.19 5,752.99 4,591.64 4,028.08 4,591.64 7.00 -100.00 5,981,148.46 512,695.34 9,150.00 94.56 172.74 5,748.73 4,641.22 4,032.88 4,641.22 7.00 -100.33 5,981,098.89 512,700.20 8 9,200.00 94.19 176.23 5,744.92 -0,690.83 4,037.68 4,690.83 7.00 96.00 5,981,049.29 512,705.05 9,300.00 93.40 183.20 5,738.30 4,790.55 4,038.17 4,790.55 7.00 96.27 5,980,949.59 512,705.66 9,330.00 93.15 185.29 5,736.58 4,820.42 4,035.96 4,820.42 7.00 96.73 5,980,919.71 512,703.48 9 9,400.00 93.14 180.38 5,732.75 -4,890.20 4,032.51 4,890.20 7.00 -90.00 5,980,849.93 512,700.11 9,500.00 93.08 173.37 5,727.32 -4,989.85 4,037.95 4,989.85 7.00 -90.27 5,980,750.31 512,705.67 9,510.00 93.07 172.67 5,726.78 -4,999.76 4,039.16 4,999.76 7.00 -90.65 5,980,740.39 512,706.89 10 9,600.00 91.43 178.75 5,723.25 -5,089.39 4,045.88 5,089.39 7.00 105.00 5,980,650.78 512,713.71 9,700.00 89.58 185.51 5,722.36 -5,189.26 4,042.16 5,189.26 7.00 105.24 5,980,550.92 512,710.11 9,750.00 88.66 188.88 5,723.13 -5,238.85 4,035.90 5,238.85 7.00 105.30 5,980,501.32 512,703.91 11 9,800.00 88.05 185.44 5,724.57 -5,288.43 4,029.68 5,288.43 7.00 -100.00 5,980,451.74 512,697.74 9,850.00 87.46 181.98 5,726.53 -5,338.28 4,026.44 5,338.28 7.00 -99.90 5,980,401.89 512,694.56 12 9,900.00 86.56 185.37 5,729.14 -5,388.10 4,023.24 5,388.10 7.00 105.00 5,980,352.08 512,691.42 9,950.00 85.67 188.76 5,732.53 -5,437.60 4,017.11 5,437.60 7.00 104.82 5,980,302.57 512,685.34 13 10,000.00 87.15 185.59 5,735.66 -5,487.10 4,010.87 5,487.10 7.00 -65.00 5,980,253.07 512,679.17 10,100.00 90.14 179.26 5,738.03 -5,586.92 4,006.65 5,586.92 7.00 -64.80 5,980,153.25 512,675.07 10,200.00 93.13 172.92 5,735.17 -5,686.59 4,013.46 5,686.59 7.00 -64.65 5,980,053.60 512,681.99 14 10,300.00 95.50 179.53 5,727.63 -5,786.03 4,020.02 5,786.03 7.00 70.00 5,979,954.19 512,688.67 10,400.00 97.80 186.19 5,716.04 -5,885.17 4,015.09 5,885.17 7.00 70.50 5,979,855.05 512,683.84 15 10,500.00 94.80 192.55 5,705.06 -5,983.18 3,998.89 5,983.18 7.00 115.00 5,979,757.03 512,667.77 16 2272019 11:44:07AM Page 4 COMPASS 5000.14 Build 85D ConocoPhillips BAKER ConocoPhillips Planning Report HUGHES aGEcompany Database: EDT 14 Alaska Production Local Co-ordinate Reference: Well 3F-01 Company: _ConocoPhillips Export Company TVD Reference: Mean Sea Level Project: Kuparuk River Unit MD Reference: 3F-01 @ 93.00usft (3F-01) Site: Kuparuk 3F Pad North Reference: True Well: 3F-01 Survey Calculation Method: Minimum Curvature Wellbore: 3F-011.1 87.29 173.18 Design: 3F-O1L1_wp06 167.09 18 Planned Survey Measured TVD Below Dogleg Depth Inclination Azimuth (usft) (I (I 10,600.00 93.31 185.70 10,650.00 92.55 182.27 17 -6,379.25 5,713.12 10,700.00 90.80 179.24 10,800.00 87.29 173.18 10,900.00 83.81 167.09 18 5,979,608.79 512,648.67 11,000.00 85.07 174.01 11,100.00 86.40 180.90 19 6,281.08 7.00 11,200.00 90.32 186.70 11,270.00 93.07 190.76 20 5,979,361.01 512,671.94 11,300.00 93.96 188.85 11,400.00 96.87 182.46 11,500.00 99.70 175.99 Planned TD at 11500.00 Casing Points 4,018.94 6,477.36 4,023.36 6,576.92 5,723.43 -6,676.60 4,016.74 5,721.36 5,745.74 4,006.12 5,719.52 -6,775.24 4,001.02 5,710.07 -6,874.24 3,991.21 5,695.64 . -6,973.13 3,992.53 6,676.60 6,745.74 7.00 TVD Below Dogleg System / +N/.S (usft) ( (usft) 5,697.99 -6,081.60 5,695.43 -6,131.41 5,693.97 -6,181.37 5,695.65 -6,281.08 5,703.42 -6,379.25 5,713.12 -6,477.36 5,720.57 -6,576.92 4,018.94 6,477.36 4,023.36 6,576.92 5,723.43 -6,676.60 4,016.74 5,721.36 5,745.74 4,006.12 5,719.52 -6,775.24 4,001.02 5,710.07 -6,874.24 3,991.21 5,695.64 . -6,973.13 3,992.53 6,676.60 6,745.74 7.00 Vertical Dogleg Toolface Map Map -E1-W Section Rate Azimuth Northing Easting (usft) (usft) (°/100usft) (1) (usft) (usft) 3,983.09 6,081.60 7.00 -102.00 5,979,658.60 512,65208 3,979.62 6,131.41 7.00 -102.49 5,979,608.79 512,648.67 3,978.96 6,181.37 7.00 -120.00 5,979,558.84 512,648.06 3,985.56 6,281.08 7.00 -120.09 5,979,459.15 512,654.77 4,002.61 6,379.25 7.00 -119.99 5,979,361.01 512,671.94 4,018.94 6,477.36 4,023.36 6,576.92 5,723.43 -6,676.60 4,016.74 5,721.36 5,745.74 4,006.12 5,719.52 -6,775.24 4,001.02 5,710.07 -6,874.24 3,991.21 5,695.64 . -6,973.13 3,992.53 6,676.60 6,745.74 7.00 80.00 5,979,262.92 512,688.38 7.00 79.33 5,979,163.37 512,692.92 7.00 56.00 5,979,063.70 512,686.41 7.00 55.83 5,978,994.56 512,675.88 6,775.24 7.00 -65.00 5,978,965.05 512,670.81 6,874.24 7.00 -65.12 5,978,866.05 512,661.11 6,973.13 7.00 -65.72 5,978,767.17 512,662.55 Measured Vertical Casing Hole Depth Depth Diameter Diameter (usft) (usft) Name (in) (in) 11,500.00 5,695.64 23/8" 2.375 3.000 Plan Annotations Measured Depth (usft) 8,200.00 8,243.00 8,268.00 8,361.24 8,432.00 8,540.00 9,050.00 9,150.00 9,330.00 9,510.00 9,750.00 9,850.00 9,950.00 10,200.00 10,400.00 10,500.00 10,650.00 10,900.00 11,100.00 11,270.00 11,500.00 Vertical Local Coordinates Depth ♦N/ -S +E/ -W (usft) (usft) (usft) 5,787.18 -3,837.39 3,658.19 5,816.91 -3,859.74 3,679.76 5,832.74 -3,873.62 3,693.19 5,854.76 -3,937.22 3,754.70 5,843.16 -3,987.75 3,802.82 5,823.94 -4,069.48 3,870.63 5,757.79 -4,541.91 4,026.27 5,748.73 -4,641.22 4,032.88 5,736.58 4,820.42 4,035.96 5,726.78 4,999.76 4,039.16 5,723.13 -5,238.85 4,035.90 5,726.53 5,338.28 4,026.44 5,732.53 -5,437.60 4,017.11 5,735.17 -5,686.59 4,013.46 5,716.04 -5,885.17 4,015.09 5,705.06 -5,983.18 3,998.89 5,695.43 -6,131.41 3,979.62 5,703.42 -6,379.25 4,002.61 5,720.57 -6,576.92 4,023.36 5,721.36 -6,745.74 4,006.12 5,695.64 -6,973.13 3,992.53 Comment TIP KOP/TOWS Start 45 DLS End 45 DLS/Start 7 DLS 5 6 7 8 9 10 11 12 13 14 15 16 17 18 19 20 Planned TO at 11500.00 2272019 11:44:07AM ' Pao 5 COMPASS 5000.14 Build 85D �. ConocoPhillips BA ER ConocoPhillips Anticollisian Report F�UGHES a GEcompary Company: ConocoPhillips Alaska lnc_Kuparuk Project: Kupamk River Unit -2 Reference Site: Kupamk 3F Pad Site Error: 0.00 usft Reference Well: 3F-01 Well Error: 0.00 usft Reference Wellbore 3F-011.1 Reference Design: 3F-01L1_wp06 Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Output errors are at Database: Offset TVD Reference: Well 3F-01 3F-01 @ 93.00usft (3F-01) 3F-01 ® 93.00usft(3F-01) True Minimum Curvature 2.00 sigma EDT 14 Alaska Production Offset Datum Reference 3F-01L1_wp06 2U Pad -2U -13 -2U -13-2t,-13 Fitter type: NO GLOBAL FILTER: Using user defined selection & filtering criteria Interpolation Method: MD Interval 25.00usft Error Model: ISCWSA Depth Range: 8,200.00 to 11,500.00usft Scan Method: Tray. Cylinder North Results Limited by: Maximum center -center distance of 1,340.70 usft Error Surface: Combined Pedal Curve Warning Levels Evaluated at: 2.79 Sigma Casing Method: Added to Error Values Survey Tool Program Date 2/26/2019 From TO (usft) (usft) Survey (Wellbore) Tool Name Description 100.00 8,200.00 3F-01 (3F-01) GCT -MS Schlumberger GCT multishot 8,200.00 11,500.00 3F-011-7_wpO6(3F-011-1) GCT -MS Schlumberger GCT multishm Summary Site Name Offset Well - Wellbore - Design Kuparuk 2U Pad 2U-13 - 2t,-13 - 2t,-13 2U-13 - 2t,-13 - 2U-13 Kuparuk 3F Pad 3F-01 - 3F-01 - 3F-01 3F-01 - 3F-01 L1-01 - 3F-011.1-01_wp06 3F-01 - 3F-01 L1-01 - 3F-011.1-01_wp06 Reference Offset Distance Measured Measured Between Between Separation Warning Depth Depth Centres Ellipses Factor (usft) (usft) (usftl (usft) 10,993.98 7,550.00 284.06 114.92 11,008.62 7,525.00 285.34 115.20 8,504.99 8,650.00 271.30 266.91 9,149.89 9,150.00 2.34 -71.93 11,266.21 11,275.00 33.62 -108.13 1.679 Caution Monitor Closely, CC 1.677 Caution Monitor Closely, SF 61.800 CC, ES, SF 0.032 STOP Drilling, CC, SF 0.237 STOP Drilling, ES Offset Design Kuparuk 2U Pad -2U -13 -2U -13-2t,-13 onsetsae Ern, 0.00 unit survey program: 2000CT-MS onsetwell Error: 000 unit Reference 011see Seml MajwA[Is Distance Measured VertiW Measured vertical Reference Oneet aiiimutb Onset Vlellbore Cemre Between Between Minimum separation blaming Depth pert, Dept, Depth from North +NIS 'EFW Centres Ellipses separation Factor (uam (usft) (usfrj (usft) (usft) (usft) (°) (-am (usft) (usft) (use) p.am 10,80940 5,789.12 7.957.00 6.271.89 105.10 8507 -1177 4,270.20 3,947.54 473.82 35634 11748 4.033 10813.30 5789.33 7,950.00 6,26661 105.12 84.98 -1245 -6,273.83 394V2 46866 350.58 118.98 3.969 10,826.69 5.790.13 7,925.00 6,247.76 105.18 M65 -14.91 -6,286.80 3034.66 450.41 330.09 120.82 3.744 10,839.26 5,790.98 7,900.00 6,228.90 105.23 84.33 -17.49 6,299.T/ 3,924.59 432.53 309]8 12275 3.524 1.851.09 5,791.86 7,875.00 6,210.05 105.28 84.01 -20.20 -6,312.74 3,914.53 415.10 289.70 125.40 3.310 10,862.23 5,792.77 7,850.00 6.191.20 105.33 83.60 -23.05 -6,325.71 3904.46 398.20 269.93 120.27 3.104 10.872.74 5,793.70 7,825.00 6,17294 105.30 83.36 -26.00 -6,338.68 3,891.40 381.93 250.55 131.38 2.907 Normal Operations 10882.67 5,794.64 7,800.00 6,153.49 105.42 83.04 -29.31 4,351.65 3,884.33 366.40 231.67 134.73 2.719 Normal Operations 10,892.09 5.795.58 7,775.00 6.134.67 105.46 82.71 .72.75 -6,364.66 3.874.24 351.76 213.44 130.31 2.543 Normal Operations 10,901.15 5.796.54 7,750.00 6,115.94 fa5.50 82.39 .36.31 -.377.74 3.864.10 338.19 196.08 142.11 2.380 Caution Monitor Closely 10,910.76 5.797.58 7.725.00 6,097.28 105.55 82.06 -39.16 $,390.80 3.853.92 325.83 179.72 10.11 2.230 Caution Monitor Closely 10,920.89 5.798.62 7.700.00 6,078.70 105.59 81.74 .4232 4,404.13 3,843.68 314.80 161.61 150.19 2096 Caution Monitor Closely 10,93154 5.799.71 7,675.00 8,00032 105.64 81.41 -45.48 4,417.42 3.833.34 305.25 151.01 154.25 1.978 Caution Monitor Closely 10.942.75 5,800.03 7,650.00 6,041.87 105.69 81.08 -48.93 4,430.77 3,822.85 297.38 139.22 158.15 1.880 Caution Manitor Closely 10.954.55 5,601.98 7,825.00 6,023.66 105.74 80.76 -5252 4,441.10 3,81230 291.26 129.52 161.74 1.801 Caution Manitor Closely 10.987.00 5.803.16 7.600.00 6,005.57 105.80 80.43 -58.21 4,457.64 3,801.40 28700 12214 164.05 1.741 Caution Monitor Closely 10.980.12 5.804.36 7.575.00 5,907.60 105.86 60.10 -59.94 4.471.16 3,790.47 284.60 117.24 167.36 1.701 Caution Monitor Closely 10,993.98 5.805.59 7.550.00 5.959.74 105.92 79.77 43.84 4.484.71 3,779.42 284.06 114.92 169.14 1.679 Caution Monitor Closely, CC, ES 111008.62 5.806.85 7,525.00 5951.98 105.99 79+44 4725 4,498.31 3,788.25 285.34 115.20 170.14 1.677 Caution Monitor Closely, SF 11.024.10 5808.12 7.500.00 5.934.33 106.06 79.11 -70.70 -6611.94 3]58.98 288.37 118.01 170.35 1.693 Caution Monitor Closeiv 2262019 2: 12 31P Page 2 COMPASS 5000.14 Build 85D Conoc(3PhilGps Pro1e0t: Kuparuk RNer UnIL2 She: Kuparuk3FPad aY*' �°e*a," A. u4P Fea NELLSORE DETAILS: 3F-011.1 WEMCE nFDRMTDN Parent Wblbore: 3F-01 ce*eNgWFlkelaeaa wxioiiasaeF Well: 3F-ot mnnsemaa Te on MD: 8200.00 Nao1QW)etlaalo. NmawbM Wellbore: w*� ®aSOW Plan: fF-01L1_Wpe9(9F-019F-011.1) 8f3F41 �voaum�e Nmeeapukalaenm..xa oF4q 508662.35 700 22' 20.086 N 149* 0"binNeee.N oa,alae 1 I� IL� BA ER I LIGHES a^*E.,., West( -)/East(+) (250 usfVin) WELLDETAILS: 3F-01 +N/ -S +E/ -W Northing Easting Latitude Longitude 0.00 0.00 5985734.98 508662.35 700 22' 20.086 N 149* 56'55+644 W Sec MD Inc Azi TvDSS -NIS -Ei-W Dleg TFaw VSecl Annotation 1 8200.00 46.23 136.05 5787.18 -3837.39 3658.19 0.00 0.00 3837.39 TIP 2 8243.00 46.29 135.96 5816.91 -3859.74 3679.76 0.21 47.33 3859.74 KOPITOWS 3 8268.00 55.04 135.96 5832.74 3873.62 3693.19 35.00 0.00 3873.82 Start 45 US 4 8361.24 97.00 135.96 5854.76 -3937.22 3754.70 45.00 0.00 3937.22 End 45 DLS/Start 7DLS 5 8432.00 101.88 136.84 5843.16 -3987.75 3802.82 7.00 10.00 3987.75 5 6 8540.00 98.60 143.76 5823.94 4069.48 3870.63 7.00 115.00 4069.48 6 7 9050.00 95.82 179.65 5757.79 4541.91 4026.27 7.00 92.00 4541.91 7 8 9150.00 94.56 172.74 5748.73 4641.22 4032.88 7.00 260.00 4641.22 8 9 9330.00 93.15 185.29 5736.58 4820.42 4035.96 7.00 96.06 4820.42 9 10 9510.00 93.07 172.67 5726.78 4999.76 4039.16 7.00 270.00 4999.76 10 11 9750.00 88.66 188.88 5723.13 -3238.85 4035.90 7.00 105.00 5238.85 11 12 9850.00 87.46 181.98 5726.53 -5338.28 4026.44 7.00 260.00 5338.28 12 13 9950.00 85.67 188.76 5732.53 3437.60 4017.11 7.00 105.00 5437.60 13 14 10200.00 93.13 172.92 5735.17 -5686.59 4013.46 7.00 295.00 5686.59 14 15 10400.00 97.80 186.19 5716.04 3885.17 4015.09 7.00 70.00 5885.17 15 16 10500.00 94.80 192.55 5705.06 4983.18 3998.89 7.00 115.00 5983.18 16 17 10650.00 92.65 182.27 5695.43 -6131.41 3979.62 7.00 258.00 6131.41 17 18 10900.00 83.81 167.09 5703.42 3379.25 4002.61 7.00 240.00 6379.25 18 19 11100.00 86.40 180.90 5720.57 -6576.92 4023.36 7.00 80.00 6576.92 19 20 11270.OD 93.07 190.76 5721.36 -6745.74 4006.12 7.00 56.00 6745.74 20 21 11500.00 99.70 175.99 5695.64 4973.13 3992.53 7.00 295.00 6973.13 Planned TO at 11500.00 1 I� IL� BA ER I LIGHES a^*E.,., West( -)/East(+) (250 usfVin) Vertical Section at 180.000 (95 usftlin) ..................................N/.. .........■■■■■■■■..■■■■■■■.!N ■■■■.NONE a Ems= BE OMEN �m.■■■■■.■■■■.■■ OMEN ■■..■.►®■.■■ mom ME 0 ME 1►M...®.■..M.._MMMM_. NNE EWAN _��_®�®__�MEME00 ��®. �■�■��■�i■�■■..■■■. ■II ■..■IN �'��! MEN= MMINMEM M No IS OMEN IN NE MEMO MI mom 0 0 ____®..__________ Vertical Section at 180.000 (95 usftlin) KUP PROD 3F-01 CD�IOWP�II��IPS Alaska, inc. Alaska. Well Attributes Max Angle8,MD TO FIeW Name WelNare GPIIUWI WtlIMaStalus nd l'1 MD hS, ACIBM Ga., KUPARUK RIVER UN IT 5002921446W PROD 285 3,100.00 8,]30.0 Gammen/ H:SIWmI Dab Annaellon Fntl Dale SSSV NIPPLE 120 &12015 LastWO: 4242014 KBGM(In Pep Due 41.00 912511985 3.. IgIWA1B803'.61 AM Last Tag Show c"andk(Muall Ansulupn End Due Dept M1 lnKaI USIMWBY Last Tag: IRKS (est 19 of Fill, leaving 441' of Open pedal 5'212018 850],0 aembaej ... _........_.....a_.......__..__. wNoEa. a3o coxpwroa. n.a.nso xIPPLe s141 GAS urr; 3.+sz.e SURFACE; W.GIM6- O.A6 uFi:4.aW.5 GAS UR; s�.9 GAS UFT:6.Np.4 GAS UFT; Ta4a-=3A GAS UFT; 7,191 LOCATOR2a56e SEAL ASSY.],a546 PBR,)YA2 PACKER: TaT1a PRODUCTION: 6011] (PERF; 9,0040a,3140� 174NEWSTYLETPe reEE.E: a,MS3 wwle; e.a'sa MFPIE: e.msz SOs;e932T (PERF; 0.41 - RERF;BK38.08.4Ba.0� IPERF: BAm.G8.5S.e- PRODUCTION; EOB.616.1 Last Rev Reason Annolmion I End Due lest Mad By Per Reason: Open C Sands. SWapped ON TPI for TPC 101912018 J= Casing Strings Casing 0sscripllon OD An) ID(nl CONDUCTOR 16 15.06 TOp atata Set Biter(ftKBI Set Oepin lNDl... WIRer 11... Grade Top ThI.M 3>.0 1150 115.0 6250 N40 WELDED Desire Oex",.a OD llnl 101ml SURFACE 95M 8.92 Top 91Ke) Set OepN Gue., selDpin.I..... WI ....... Tp I.. 37.0 3,970.6 3,061.6 36.00 J45 BTC C.In9 Dncrloish OD(Inl I011nl PRODUCTION 7 6.28 TOPITI su Depin(IIKeI sa Pope II Wt. --s11... Grade rap TMW 35A 8646.1 6107.1 26.00 J-55 BTC Tubing Strings Tuning Description Suug Me_.101in1 TOP InKe1 set Depin ln.. set Depth(nEG( MURNI) G,atle Tpeonneclion TUBING -WO 312 299 330 7,968.5 5]19.1 9.30 L-80 EUEBrnd Completion Details rop(rvDl Re1nu xnminel TiN(!KI3 InN8 (-I lmm Des Com ID Ont MM0 33A 0.03 HANGER FM TUBINGHANGER 2.992 518,1 518.0 3.99 NIPPLE BANCO 2.875 -'DS' NIPPLE 2.875 7,955.8 5,710.2 45.83 LOCATOR BAKER LOCATOR 3.830 7,956.6 5,]10.8 45.82 EAL Y BAKER SEAL ASSYthe PER, 3-ft•Stiloup- 2.990 Tuere Deno Mich sand Ma...whih TUBING - Onginel 312 2.99 3.5"x2.875' @8279' TaP push ],9fi02 Set DepM (D.. 8,303.4 9u DepM (72'01 (._WI 5.951.fi aw 920 grade J-55 TaInCennttlun EUE 8720 Completion Details T.?UVDI Top /net Nomlw TOP(BUB) MKE) r' stem Des Com ID (in) 7,960.2 5,713.3 45.81 PER BAKER PER 3.000 ],9]3.9 5,722.9 45.75 PACKER BAKER FHL PACKER 3.000 $265.9 5,925.7 46.32 NIPPLE AVA BPL PORTED 056 NIPPLE 2.300 8,2681 5,927.3 46.33 XURedudng CROSSOVER 3.6- TO 2.875" 2.441 8,2784 5,934.3 46.34 LOCATOR BAKER LOCATOR 3.000 8280.2 5,935.6 46.34 PACKER BAKER FE -1 PACKER 4.000 5, 7. 4.35 TIRE BAKER SEAL BORE EXTENSION 4.000 8,295.2 5, 45.9 46.36NIPPLE CAMCO D NIPPLE NO GO 2.250 8,302 ] 5,951.1 46.38 SOS CAMCO SHEAROUT SUB 2.441 Omer In Hold (Wireline retrievable plugs, valves, pumps, fish, etc.) roP nxel Top m01 InKBI ropincl 19 De: com Run Dae 1D Oo1 8,265.3 5,925.3 46.322.]5 "NEW 2.75"NEWSNLE TPC(129"OAL12.30"ID)CSands 10192018 STYLE TPC Open LEEVE 2.300 Perforations & Slots Toenflen Blm(nKa) TOPOVEi (ftKBI Run RVDI Want UnkMlane Date ana Dens IUKKam I Type Com 8.066.0 8.219.0 5787.1 5,893.3 C3A2, O1, UNIT B, 3F-01 1112]11985 12.0 IPERF 120 deg. passing, 5" HJ II 'S'Gua 8.417.0 8,423.0 6,029.8 6,033.9 A4, W-01 112711985 4.0 IPERF W deg. phasing. 4" HJ II Gag Gun 8428.0 8,4 8.0 7.4 8064.8 A-3, 3F -On 112711985 4.0 IPERF 90 deg. Phasing, r HJ II Gag Gun 0.490.0 8.5280 6,085.4 6,1047 A-2. 3F-01 112711985 4.0 ]PERF 90 deg. phasing, 4" HJ 11 Csg Gun Mandrel Inserts St on Tap IND) VeNe Unch Portslx TRO Run N TOp(RKB) treat Make MWN raise) as. Type Type (in) (psi) Run Date Com 1 3,162.8 2,5]1.1 BAMCO MMG 112 GAS GLV RK 0AWt242120182 4,850.5 3,624.8 CAMCO MMG 112 GASLIFT GLV RK 0.188120183 5.996.9 4,370.4 CAMCO MMG 112 GASLIFT LV RK 01 2014 6,8404 4,940.4 CAMCO MMG 112 GASLIFT GLV RK SAM/2018PACKER;e,mpa 5 ],474.3 S,Wfi.S CAMCO MMG 112 GASLIFT GLV RK 0.18812010IKE:6�3.4 6 ],896.3 5668.8 CAMCO MMG 112 GASLIFT OV RK 01881120187 80117 5.]49.3 CAMCO KBUG 1 PROD DMY BK 0.00018/1988 Notes: General &So" End Date Annatrunn 5142003 NOTE: WAIVERED WELL: IA IT OA COMMUNICATION 3F-01 Proposed CTD Schematic 16" 62# H-40 Shoe 9-5/8" 40# 1-55 shoe @ 3971' MD C -sand perfs 8066 - 8219' MD KOP @ 8243' MD -sand perfs 6417' -8423' MD 8428'- 8468' MD 8498'- 8526' MD 7.126# J-55 shoe @ 8646' MD 3.1/2" Camco DS nipple @ 518' MD (2.875" min ID) 3-1/2" 9.3# L-80 EUE 8rd Tubing to surface 3-1/2" Camco gas lift mandrels @ 3163', 4851', 5997', 6841', 7474', 7896' MD Baker 3-1/2" PBR @ 7960' MD (3" ID) Baker FHL packer @ 7974' MD (4.0" ID) 3-1/2" Camco MMG production mandrels @ 8012' MD AVA BP Ported Nipple @ 8266' MD (2.3" min ID) XO 3.5" to 2.875" Baker FBA packer @ 8280' MD (4.0" ID) Baker SBE @ 8283' MD 3-1/2" Camco D landing nipple @ 8295' MD (2.25" min ID, No -Go) Camco SOS @ 8303' MD 3F -01L7-01 wp06 TO @ 11,520' MD Top of Liner @ 8,243' MD 3F -01L1 wp06 IT @ 11,500' MD Billet @ 9,100' MD TRANSMITTAL LETTER CHECKLIST WELL NAME: f�� —� dV Z -- PTD: PTD: t Development _ Service _ Exploratory _ Stratigraphic Test _ Non -Conventional FIELD: ku u—!. POOL: 1 "u Check Box for Appropriate Letter / Paragraphs to be Included in Transmittal Letter CHECK OPTIONS TEXT FOR APPROVAL LETTER MULTI The permit is for a new wellbore segment of existing well Permit LATERAL No.�API No. 50-�iL - Z-- Ute• (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 throu h 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 (CompanyName) has designed and Well implemented a water well testing program to provide baseline data on water quality and quantity. (Company) must contact the AOGCC to obtain advance approval of such water well testing program. Regulation 20 AAC 25.071(a) authorizes the AOGCC to specify types of well logs to be run. In addition to the well logging program proposed by (Company Name) in the attached application, the following well logs are also required for this well: Well Logging Requirements Per Statute AS 31.05.030(d)(2)(B) and Regulation 20 AAC 25.071, composite curves for well logs run must be submitted to the AOGCC within 90 days after completion, suspension or abandonment of this well. Revised 2/2015 WELL PERMIT CHECKLIST Field & Pool KUPARUK RIVER, KUPARUK RIV OIL -490100 Public Well Name: KUPARUKRIV PTD#:2190360 Company COC�O PHILLIPS ALASKA INC Initial Class/Type —UNIT 31 Program DEV Well bore seg DEV / PEND GeoArea $99 Unit 11160 On/Off Shore On Annular Disposal Administration 17 Nonconven, gas conforms to AS31,05,030(L1.A),(J,2.A-DJ . . . . . . ....... . ..... . . . NA. 1 Permit fee attached ---------------------------------- NA... 2 Lease number appropriate_ _ _ _ ___ _ _ _ _ _ _ _ _ _ _ _ Yes _ _ _ Entire Well lies within ADL0025643.- 3 _ .. Unique well name and numberYes ---�� ------� ---. - - - - - - - - - - - - - - - - - - - - Well located in a_defiined pool _ .... _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes _ _ _ Kuparuk River Oil Pool, governed by Conservation Order No. 432D 5 Well located proper distance from drilling unit boundary_ - _ - _ . - - - - _ _ _ _ Yes _ _ _ _ .. Conservation Order No. 432D has no interwell. spacing.restrictions, Wellbore will be. more than 500' 6 Well located proper distance from other wells _ _ _ ... _ _ . _ .. - . - _ _ .. Yes _ - _ - from an external property linek whereownershipor. landownership_ changes. As proposed,. well will 7 Sufficient acreage available in drilling unit- _ _ .... _ _ .. _ _ Yes _ _ _ _ conform to. spacing. requirements. 8 If deviated, is wellbore plat. included _ _ _ _ _ _ _ _ _ _ _ _ _ _ __ _ _ _ _ __ Yes 9 Operator only affected party- --- - - - - - - - - - _ _ .. Yes 10 Operator has appropriate bond in force .. _ - _ ... _ _ _ _ _ _ _ _ _ _ _ _ ...... Yes _ _ _ ....- Appr Date 11 Permit can be issued without conservation order _ _ _ . .... . . . . . . .. _Yes SFD 3/6/2019 12 Permit. can be issued without administrative approval ... .... _ . _ . Yes 13 Can permit be approved before 15-day wait_ _ .. _ _ ... _ _ Yes 14 .Well located within area and. strata authorized by injection Order # (put 10# in comments) (For NA 15 All wells.within 1/4.mile area of reyiew identified (For service well only) _ _ _ _ ____ _ _ _ _ _ _ _ NA 16 18 Pre-produced injector; duration of pre production less_ than. 3 months (Fpr service welt only) _ . Conductor string -provided _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ NA. NA _ - - Conductor set-in KRU 3F-01 Engineering 19 Surface casing all known USDWs - _ .... _ NA _ .... _ _Surface casing set in KRU 3F-01 20 CMT vol adequate to circulate on conductor & surf.csg _ _ _ _ _ __ _ _ _ _ ... _ _ _ _ _ _ _ _ _ _ NA.. _ _ - _ .. Surface casing set and fully cemented _ 21 CMT. vol adequate to tie-in long string to surf csg _ _ _ _ _ .. _ _ _ . _ - - - , NA_ 22 CMT. will coverall known productive horizons_ - - - .. _ _ _ - No _ .. _ - - - Productiveintervalwill-be completed with. uncemented production liner 23 Casing designs adequate for C, T, S.$perrnafrost- _ _ _ _ _ _ _ _ _ ... _ Yes 24 Adequate tankage or reserve pit _ _ _ _ _ _ _ _ _ _ _ _ _ ... - Yes _ . Rig has steel tanks; all waste to approved disposal wells. 25 If a_re-drill has 10403 for abandonment been approved __ _ _ _ _ _ _ _ _ _ _ _ NA 26 Adequate wellbore separation proposed _ _ _ _ _ .. Yes ... _ _ _ Anti-collision analysis complete; no major risk failures _ 27 If djverter required, does it meet regulations. _ _ _ _ _ _ _ - - NA Appr Date 28 Drilling fluidprogramschematic.& equip list adequate. _ Yes .... Max formation pressure is, Z302 psig(10.6 ppg EMW), will drill w/ 8,6-ppg and maintain overbal w/ MPD VTL 3/7/2019 '29 BOPEs, do they meet regulation _ _ _ _ _ - - _ _ _ _ YeS.... 30 ROPE-press rating appropriate; test to.(put prig in comments)_ _ _ _ _ . _ _ _ Yes _ _ _ MPSP is2722 psig; will test 8OPs to 3500_psig 31 Chokemanifoldcomplies w/APLRP-53 (May $4)_ _ _ _ _ _ _ .. _ _ _ _ .. Yes 32 Work will occur without operation shutdown_ _ _ _ ...... . . . . . . . ...... . .. . Yes 33 Is presence of H2$ gas probable _ ___ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes _ . H2S measures required. 34 Mechanical condition of wells within AOR yerified (for service well only) ___ _ _ _ _ _ _ _ _ _ _ _ NA Geology 35 Permit can be issued w/o hydrogen. sulfide measures __ _ _ _ _ _ _ _ _ _ _ _ No _ ... _ _ 317-Pad wells are H2S-bearing..1-12S measures are required. 36 Datapresentedon. potential overpressure zones _ _ _ _ .. _ _ . - Yes ... _ Max. potential. res. pressure is 10.6 ppg EMW; expectedres. pressure is 8.5 ppg EMW, Well will be Appr Date 37 Seismic analysis of shallow gas zones_ _ _ .. _ _ _ _ _ _ _ _ _ _ _ _ _ _ NA. _ _ _ _ ... drilled using 8,6 ppg mud, -a coiledrtubing. rig, and managed pressure drilling technique to control. SFO 3/6/2019 38 Seabed condition survey.(if offshore) - - - - - - - - - - - - --- - - - - - - - . _ _ _ NA_ _ _ _ _ .... formation pressures and. stabilize shale sections with.constard 6HP of about 11.4 ppg EMW... 39 Contact name/phone for weekly-progress reports_ [exploratory only] .... .. _ .. NA _ _ - _ NOTE: Chance of encountering free-gas while driUing due to gas injection performed in.tbis area.. _ Geologic Date: Engineering Public Commissioner: Commissioner: Date/ Commissioner Date 1�j 3/'f' 3111/0� q 31oll I