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218-175
DATA SUBMITTAL COMPLIANCE REPORT 4/17/2019 Permit to Drill 2181750 Well Name/No. KUPARUK RIV UNIT 3H-23AL1 MD 12466 TVD 6018 Completion Date 1/18/2019 REQUIRED INFORMATION Operator CONOCOPHILLIPS ALASKA, INC. Completion Status 1 -OIL Current Status 1 -OIL API No. 50-103-20204-60-00 UIC No Mud Log No ✓ Samples No✓ Directional Survey Yes DATA INFORMATION List of Logs Obtained: GR/RES (from Master Well Data/Logs) Well Log Information: Log/ Electr Data Digital Dataset Log Log Run Interval OH I Type Med/Frmt Number Name Scale Media No Start Stop CH Received Comments ED C 30366 Digital Data 9320 12466 2/19/2019 Electronic Data Set, Filename: 3H-23AL1 ED C 30366 Digital Data ED C 30366 Digital Data ED C 30366 Digital Data ED C 30366 Digital Data ED C 30366 Digital Data ED C 30366 Digital Data ED C 30366 Digital Data ED C 30366 Digital Data ED C 30366 Digital Data ED C 30366 Digital Data ED C 30366 Digital Data ED C 30366 Digital Data ED C 30366 Digital Data ED C 30366 Digital Data ED C 30366 Digital Data AOGCC Page l of 3 Wednesday, April 17, 2019 GAMMA RES.Ias 2/19/2019 Electronic File: 3H-23AL1 21VID Final Log.cgm 2/19/2019 Electronic File: 3H-23AL1 SMD Final Log.cgm 2/19/2019 Electronic File: 3H-23AL1 5TVDSS Final 2/19/2019 Electronic File: 3H-23AL1 21VID Final.pdf 2/19!2019 Electronic File: 3H-23AL1 SMD Final.pdf 2/19/2019 Electronic File: 31-1-23AL7 5TVDSS Final.pdf 2/19/2019 Electronic File: 3H-23AL1 EOW - NAD27.pdf 2/19/2019 Electronic File: 3H-23AL1 EOW - NAD27.txt 2/19/2019 Electronic File: 3H-23AL1 Survey Listing.txt 2/19/2019 Electronic File: 3H-23AL1 Surveys.txt 2/19/2019 Electronic File: 31-1- 23AL1 BHGE_CTK_MWD_9558-12466 Final Surveys.csv 2/19/2019 Electronic File: 31-1- 23AL1_BHGE_ CTK_MWD_9558-12466_Final Surveys.xlsx 2/19/2019 Electronic File: 3H- 23AL1_25_tapescan_BHI _CTK.txt 2/19/2019 Electronic File: 31-1- 23AL1 _5_tapescan_BHI_CTK.txt 2/19/2019 Electronic File: 3H-23AL1_output.tap AOGCC Page l of 3 Wednesday, April 17, 2019 DATA SUBMITTAL COMPLIANCE REPORT 4117/2019 Permit to Drill 2181750 Well Name/No. KUPARUK RIV UNIT 3H-23AL1 Operator CONOCOPHILLIPS ALASKA, INC. API No. 50-103-20204-60-00 MD 12466 TVD 6018 Completion Date 1/18/2019 Completion Status 1-0IL CurrentStatus 1 -OIL UIC No ED C 30366 Digital Data 2/19/2019 Electronic File: 3H-23AL1 21VID Final Log.tif ED C 30366 Digital Data 2/19/2019 Electronic File: 3H-23AL1 51VID Final Log.tif ED C 30366 Digital Data 2/19/2019 Electronic File: 3H-23AL1 5TVDSS Final Log.tif Log C 30366 Log Header Scans 0 0 2181750 KUPARUK RIV UNIT 3H-23AL1 LOG HEADERS ED C 30401 Digital Data 2/26/2019 Electronic File: 3H-23AL1 - EOW - NAD83.pdf ED C 30401 Digital Data 2/26/2019 Electronic File: 3H-23AL1 - EOW - NAD83.txt ED C 30401 Digital Data 2/26/2019 Electronic File: 3H-23AL1 EOW - NAD27.pdf ED C 30401 Digital Data 2/26/2019 Electronic File: 3H-23AL1 EOW - NAD27.txt Log C 30401 Log Header Scans 0 0 2181750 KUPARUK RIV UNIT 3H-23AL1 LOG HEADERS Well Cores/Samples Information: Sample Interval Set Name Start Stop Sent Received Number Comments INFORMATION RECEIVED/// Completion Report Directional / Inclination Data OY Mud Logs, Image Files, Digital Data Y I�A Core Chips Y1/ Production Test Informatio Y NA Mechanical Integrity Test Information Y / NA Composite Logs, Image, Data Filesb� Core Photographs Y A Geologic Markers/Tops G Daily Operations Summary � Cuttings Samples Y 1!?-/ Laboratory Analyses Y tJA COMPLIANCE HISTORY Completion Date: 1/18/2019 Release Date: 1/3/2019 Description Comments: Date Comments AOGCC Page 2 of 3 Wednesday, April 17, 2019 DATA SUBMITTAL COMPLIANCE REPORT 4/17/2019 Permit to Drill 2181750 Well Name/No. KUPARUK RIV UNIT 3H-23AL1 Operator CONOCOPHILLIPS ALASKA, INC MD 12466 TVD 6018 Completion Date 1/18/2019 Compliance Reviewed By: Completion Status 1 -OIL Current Status 1 -OIL API No. 50.103.20204-60-00 Data. 4f[ —4 /1 UIC No AOGCC Page of Wednesday, Apn1 17, 2019 BA(ER F�UGHES a GE company Date: February 22, 2019 Abby Bell AOGCC 333 West 7th Ave, Suite 100 Anchorage, Alaska 99501 2181 . s 30401 Letter of Transmittal Harvey Finch Baker Hughes, a GE Company 795 East 94th Avenue Anchorage, Alaska 99515 se find enclosed the directional survey data for the following well(s): 3H-23AL1 RECEIVED FEB 2 6 2019 AOGCC I XTotal prints Enclosed for each well(s): 1 hardcopy print of directional survey reports (NAD27) 1 compact disk containing electronic survey files Note: Please feel free to send us an email in place of return mail. Harvey Finch, Baker Hughes, Wellplanner Harvey.Finch@BakerHughes.com ConocoPhillips ConocoPhillips (Alaska) Inc. -Kup2 Kuparuk River Unit Kuparuk 3H Pad 3H-23AL1 50-103-20204-60 Baker Hughes INTEQ Definitive Survey Report 12 February, 2019 BAT(ER UGHES a GE company 2101%5 30 40 1 ConocoPhillips ConocoPhillips Definitive Survey Report Company: _ConocoPhillips (Alaska) Inc. -Kup2 Local Co-ordinate Reference: Project: Kuparuk River Unit TVD Reference: Site: Kupamk 3H Pad MD Reference: e Well: 31-1-23 North Reference: Y Wellborn: 3H-23AL1 Survey Calculation Method: ) Design: 3H-23AL1 Database: Project -_T-'-- A Kuparuk River UnH, North Slope Alaska, United States Map System: US State Plane 1927 (Enact solution) System Datum: Geo Datum: NAD 1927 (NADCON CONUS) Map Zone: Alaska Zone 04 �i Well 3H-23 Well Position +Nl-S 0.00 usft Northing: (1 +E/ -W 0.00 usft Easting: Position Uncertainty Direction 0.00 usft Wellhead Elevation: _i Wellbore 3H-23ALi (% f I Magnetics Model Name 0.00 Sample Date Design Audit Notes: Version: Vertical Section: Survey Program From (usft) 76.50 7,640.00 9,558.00 9,651.43 BGGM2018 2/1/2019 3H-23AL1 Well 3H-23 3H -23A: @ 70.10usft (3H -23A:) 3H -23A: @ 70.10usft (3H -23A:) True Minimum Curvature EDT 14 Alaska Production Mean Sea Level Using Well Reference Point Using geodetic scale factor 6,000,637.79 usft 498,655 28usft usft krsa Latitude: 70° 24'46,715 N Longitude: 150° 0'39.424 W Ground Level: 0.00 usft Declination Dip Angle Field Strength (°) (1 (nT) 16.69 80.90 57,426 1.0 Phase: ACTUAL Tie On Depth: 9,537.23 Depth From (TVD) +NIS +E/ -W Direction (usft) (usft) (usft) (% 70.10 0.00 0.00 135.00 Date To Survey (usft) Survey (Wellbore) Tool Name Description Start Date 7,620.60 31-1-23 (3H-23) GCT -MS Schlumberger GCT multishot 1/12/2001 9,537.23 3H-23AATDB (31-4-23A) GCT -MS Schlumberger GCT multishot 9/18/2001 9,621.66 3H-23AL7 MWD -INC (3H-23AL1) MWD-INC_ONLY MWD-INC—ONLY—FILLER 1/17/2019 12,426.80 3H-23AL1 MWD(3H-23AL7) MWD MWD -Standard 1/18/2019 Survey End Data 1/17/2019 1/18/2019 2/12/2019 12:11:59PM Page 2 COMPASS 5000.14 Build 85D ConocoPhillips Company: _ConocoPhillips(Alaska) Inc.-Kup2 Project: Kuparuk River Unit Site: Kuparuk 3H Pad Well: 3H-23 Wellbore: 3H-23AL1 Design: 3H-23AL1 Survey 0 MD (usft) 9,53723 9,558.00 9,592.09 9,621.66 9,651 43 9,681.85 9,711.93 9,741.93 9,773 47 9,803.78 9,836.35 9,870,53 9,900.65 9,927.46 9,955.72 9,984.94 10,01471 10,046.11 10,076.16 10,105.27 10,135.14 10,165.85 10,194.52 10,224]7 10,254.87 10,285.01 10,314.82 10,345.0 10,375.67 10,405.11 Inc 64.41 64.38 72.03 82.42 92.55 94.40 95.54 94.36 91.90 90,18 89.23 87.76 88.71 87.51 91,26 91.57 90.52 89.05 87.48 84.24 84.43 86.53 8837 86.00 86.56 88.89 91.51 94.24 97.42 96.68 Azi 0 345.66 344.59 343.45 342.55 341.68 353.06 2.81 12.98 24.48 34.36 44.32 56.56 68.58 77.46 87.90 91.24 96.35 98.69 100.79 103.98 103.92 102.17 99.97 98.97 101.59 102.12 102.00 101.26 101.75 10386 ConocoPhillips Definitive Survey Report Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Database: Well 3H-23 3H -23A: @ 70.10usft (3H -23A:) 3H -23A: @ 70.10usft (3H -23A:) True Minimum Curvature EDT 14 Alaska Production .00 6.50 8.88 7.93 8.80 9.34 10.52 7 54 Annotation TIP KOP Interpolated Azimuth Interpolated Azimuth 2/11/2019 12: 11:59PM Page 3 COMPASS 5000.14 Build 85D Map Map Vertical ND NDSS +N/ -S +E/ -W Northing Easting DLS Section Survey Tool Name (usft) (usft) (usft) (usft) (ft) (ft) (^1109•) (ft) 5,967.14 5,897 .04 5,28742 4,127.09 6,005,925.42 494.529.56 1.80 6 ,657.06 MWD -INC _ONLY (3) 5,976.12 5 ,906.02 5,305.52 4,131.89 6,005,943.52 494,524.75 4.65 6,673.26 MWD -INC _ONLY (3) 5,988.75 5,918.65 5,335.93 4,140.61 6,005,973.93 494,516.09 22.83 6,700.93 MWD -INC ONLY(3) 5,995.27 5,925.17 5,363.47 4.149.04 6,006,001.47 494,507.63 35.06 6 ,726.35 W MD -INC ONLY (3) 5,996.57 5,926.47 5,391.74 4,158.16 6,006,029.74 494,498.51 34.15 6 WV VD MD(4) 5,994.72 5,924.62 5,421.32 4.164.79 6,006,059.31 494,491.88 37.83 6,778.40 MWD (4) 5,992.11 5,922.01 5,4512 3 4,165.87 6,006,089.22 494,490.81 32.51 6,800.31 MWD (4) 5,989.51 5,919.41 5,480.79 4,161.77 6,006,118.78 494,494.92 34.00 6,818.32 MWD (4) 5,987.79 5,91769 5,510.56 4,1516 7 6,006,148.55 494,505.02 37.23 6,832.23 MWD (4) 5,987.23 5,917.13 5,536.93 4,136.80 6,006,174.91 494,519.89 3308 6,840.36 MWD(4) 5,987.40 5,917.30 5,562.08 4.116.18 6,006,200.06 494,540.51 30.72 6,843.57 MWD(4) 5,988.30 5,918.20 5,583.80 4,089.89 6,006,221.77 494,566.80 36.05 6,840.33 MWD (4) 5,989.23 5,919.13 5,597.64 4,063.22 6,006,23561 494,59348 40.01 6,831.26 MWD(4) 5,990.12 5,920.02 5,605.46 4,037.62 6,006,243.42 494,619.08 33.40 6,818.69 MWD(4) 5,990.42 5,920.32 5,60966 4,009.63 6,006,247.01 494,647.06 39.25 6,80144 MWD (4) 5,989.70 5,9196 0 5,60928 -3,980.43 6,006,247.22 494,676.26 11.48 6,780.94 MWD (4) 5,989.16 5,919.06 5,607.31 3 ,950.74 6,005,245.25 494,705.95 17.52 6,758.56 MWD (4) 5,989.28 5,919.18 5,603.20 -3,919 61 6,006,241.13 494,737.07 8.80 6,733.64 MVVD(4) 5,990.19 5,920.09 5,598.12 -3,890.01 6,006,236.05 494,766 .67 8.72 6,709.12 MWD (4) 5,992.29 5,922.19 5,591.89 3,861.66 6,006,229 82 494,795.01 15.60 6,684.67 MWD(4) 5,995.24 5,925.14 5,584.73-3,832,81 6,006.22265 494,823.86 O67 6,659.21 MWD (4) 5,997.66 5,927.56 5,577.82-3.802.99 ,802.99 6,006,215.73 494,853.68 8.89 6,633.23 MWD (4) 5,998.93 5,928.83 5,572.32 3 ,774.88 6,006,210.23 494,881.76 10 -6,609.47 MWD(4) 0 6,0.42 5,930.32 5,567.35 3,745.08 6,006,205.26 494,911.57 6,564.88 MWD (4) 6,002.37 5,932.27 5,561.99 -3,715.53 6,006,199.89 494,941.12 6,560.20 MWD (4) 6,003.57 5,933.47 5,555.0 3,686.06 6,005193.70 494,970.59 -6,534.98 MM (4) 6,003.46 5,933.36 5,549.57 3,656.91 6,006,187.47 494,999.73 6,509.97 MWD (4) 6,001.95 5,931.85 5,543.48 3,627.30 6,006,18137 495,029.34 -6,484.72 MM (4) 5,998.84 5,928.74 5,537.41 3,597.50 6,006,17530 495,059.14 -6,459.36 MWD (4) 5,995.23 5,925.13 5,530.94 -3,56901 6,006,16882 49508763 -6,434.63 MM (4) .00 6.50 8.88 7.93 8.80 9.34 10.52 7 54 Annotation TIP KOP Interpolated Azimuth Interpolated Azimuth 2/11/2019 12: 11:59PM Page 3 COMPASS 5000.14 Build 85D ConocoPhillips ConocoPhillips Definitive Survey Report Company: _ConocoPhillips (Alaska) Inc. -Kup2 Local Co-ordinate Reference: Well 31-1-23 Project: Kuparuk River Unit TVD Reference: 3H -23A: @ 70.10usft (3H -23A:) Site: Kuparuk 3H Pad MD Reference: 3H -23A: @ 70.10usft (3H -23A:) Well: 31-1-23 North Reference: True Wellbore: 31-1-23AL1 Survey Calculation Method: Minimum Curvature Design: 3H-23AL1 Database: EDT 14 Alaska Production FluktgUG ES 2/1212019 12:11:59PM Page 4 COMPASS 5000.14 Build 85D Map Map Vertical MD Inc Azi TVD TVDSS +N! -S +E/.W Northing Easting DLS Section (usft) (I (°) (weft) (waft) (usft) (usft) (°1700') Survey Tool Name Annotation (ft) (4) (ft) 10,435.61 9428 105.89 5,992.31 5,922.21 5,523.14 -3,539.67 6,006,161.02 495,116% 1029 5,408.38 MWD(4) 10,465.15 93.54 109.23 5,990.30 5,920.20 5,514.25 3,511.58 6,006,152.12 495,145.05 11.56 -6,382.22 MWD (4) 10,495.61 91.57 111.64 5,98894 5,91884 5,503.63 3,483.06 6,006,141.50 495,173.56 10.21 -,354.55 MWD(4) 10,525.91 90.34 11479 5,988.44 5,918.34 5,491.69 3,455.23 6,006,129.55 495,201.39 11.16 -6,326.42 MAID (4) j 10,555.24 91.38 118.06 5,988.00 5,917.90 5,47864 3,428.97 6,006,11650 495,22764 1170 -6,298.63 MWD (4) ij 10,58544 92.21 120.80 5,987.05 5,916.95 5,463.81 3,402.68 6,006,10167 495,253.93 9.48 5,269.55 MWD (4) 10,615.16 91.57 123.32 5,986.07 5,915.97 5,448.04 3,377.51 6,006,085.90 495,279.09 8.74 5,240.61 MWD (4) 10,645.73 89.88 125.43 5,985.68 5,915.58 5,430.79 3,35228 6,006,068.64 495,304.31 8.84 5,210.57 MWD (4) 10,674.98 87.69 123.95 5,986.30 5,916.20 5,414.15 -3,328.24 6,006,051.99 495,328.35 9.04 5,181.80 MWD (4) 10,705.57 86.43 121.45 5,967.87 5,917.77 5,397.64 -3,302.53 6,006,035.49 495,354.05 9.14 5,151.95 MM (4) 10,736.35 86.86 124.16 5,98967 5,919.57 5,381.00 3,276.71 6,006,018.84 495,379.87 8.90 5,121.92 MWD (4) 10,766.90 86.68 128.12 5,991.40 5,921.30 5,363.01 3,252.08 6,006,000.85 495,404.49 12.96 5,091.79 MWD(4) 10,796.95 86.77 131,27 5,993.11 5,923.01 5,343.85 -3,229.00 6,00,961 69 495,427.57 10.47 5,061.92 MWD (4) 10,826.65 WW2 13402 5,994.83 5,924.73 5,323.77 3,207.19 6,005,961.60 495,449.37 9.26 5,032.30 MWD (4) 10,858.39 8742 137.09 5,996.48 5,926.38 5,301.14 3,185.00 6,005,938.97 495,471.55 9.98 5,00061 MWD (4) 10,892.76 8929 138.95 5,997.46 5,927.36 5,27560 3,162.02 6,005,91343 495,494.52 7.67 5,966.30 MWD (4) 10,91729 91.17 141.22 5,99736 5,92726 5,256.79 3,14628 6,005,894.62 495,510.26 12.02 5,941.87 MWD (4) 10,946.35 91.14 142.49 5,996.78 5,92668 5,233.94 -3,128.34 6005,871.77 495,528.20 4.37 -5,913.03 MWD (4) 10,972.33 90.12 143.89 5,996.49 5,926.39 5,213.14 3,112.77 6,005,850.97 495,543.76 6.67 -5,887.31 MWD (4) 11,002.67 88.83 145.55 5,996.77 5,926.67 5,la8.38 3,095.25 6,005,826.21 495,561.27 6.93 -5,857.41 MWD(4) 1103162 86.62 143.93 5,997.92 5,927.82 5,164.76 3,078.56 6,005,802.59 495,577.96 9.46 -5,828.90 WWD(4) 11,062.09 86.50 141.69 5,999.75 5,929.65 5,140.53 3,060.17 6,005,778.36 495,596.34 7.35 5,798.77 MWD(4) 11,093.01 88.00 138.90 6,001.23 5,931.13 5,11677 3,040.44 6,005,754.60 495,616.06 10.24 5,768.02 MAD (4) 11,122.35 88.22 136.33 6,002.20 5,932.10 5,095.12 3,02068 6,005,732.94 495,635.82 8.79 5,738.73 MM (4) 11,151A7 88.56 133.81 6,003.02 5,932.92 5,074.51 -3,000.12 6,005,712.33 495,656.37 8.73 5,709.63 MM (4) 11,18224 89.17 132.34 6,003.63 5,933.53 5,053.50 -2,977.65 6,005,691.32 495,678.84 5.17 5,678.88 MWD (4) 11,211.75 90.25 134.37 6,003.78 5,93368 5,033.24 -2,956.20 6,005,671.05 495,700.29 7.79 -5,649.39 MWD (4) 11,242.03 89.05 135.99 6003.96 5,933.86 5,011.77 -2,934.85 6,005,649.58 495,721.62 666 5519.11 MWD (4) 11,271.95 91.81 137.57 6,003.74 5,933.64 4,989.97 -2,914.37 6,005,627.78 495,742.10 10.63 -5,589.21 MWD (4) 11,302.35 92.67 140.15 6,002.55 5,932.45 4,96709 -2,894.38 6,005.604.91 495,762.08 8.94 -5,558.90 MAID (4) 11332.15 9369 142.84 6,000.90 5,930.80 4,94381 -287586 6,005,581.62 495,780.60 964 -5,529.34 MWD (4) FluktgUG ES 2/1212019 12:11:59PM Page 4 COMPASS 5000.14 Build 85D ConocoPhillips ConocoPhillips Definitive Survey Report �ER S I 11GHE5 Company: _ConocoPhillips (Alaska) Inc. -Kup2 Local Co-ordinate Reference: Well 31-1-23 Project: Kuparuk River Unit TVD Reference: 3H -23A: @ 70.10usft (3H -23A:) 1 Site: Kuparuk 3H Pad MD Reference: 3H -23A: @ 70.10usft (3H -23A:) Well: 31-1-23 North Reference: True Wellbore: 3H-23AL1 Survey Calculation Method: Minimum Curvature 1 Design: 3H-23AL1 Database: EDT 14 Alaska Production Survey 211 22 0 1 9 12: 11 59P Page 5 COMPASS 5000.14 Build 85D Map Map Vertical MD Inc Azi TVD TVDSS +N1 -S +EI -W Northing Easting OLS Section (usft) (9 C) (usft) (usft) (usft) (usft) (9100') Survey Tool Name Annotation (ft) (ft) (ft) 11,362.30 92.77 145.73 5,999.20 5,929.10 4,919.37 -2,858.29 6,005,557.18 495,793.16 10.04 -5,499.64 MWD (4) 11,382.79 90.52 147.01 5,998.61 5,928.51 4,902.32 -2,846.95 6,005,540.13 495,809.50 12.63 -5,479.56 MWD (4) 11,411.99 90.89 149.83 5,998.25 5,928.15 4,877.45 -2,831.66 6,005,515.26 495,824.78 9.74 -5,451.16 MWD(4) 11,441.95 89.97 151.78 5,998.02 5,927.92 4,851 30 -2,817.05 6,005,489.11 495,839.39 7.20 -5,422.34 MWD (4) 11,472.67 9178 15382 5,997.55 5,927.46 4,823.98 -2,803.01 6,005,461.79 495,85342 8.88 -5,393.10 MWD (4) 11,501.41 93.20 156.02 5,996.31 5,926.21 4,79298 -2,790.84 6,005,435]9 495,665.59 9.10 -5,366.10 MWD (4) 11,531.83 93.84 159.15 5,994.44 5,924.34 4,769.91 -2,779.26 6,005,40772 495,877.16 10.48 5,338.07 MWD (4) 11,563.49 93.38 163.44 5,992.44 5,922.34 4,739.99 -2,769.13 6,005,377.80 495,887,28 13.60 5,309.75 MWD (4) 11,587.34 92.37 164.73 5,991.25 5,921.15 4,717.08 -2,762.60 6,005,354.90 495,893.81 6.86 -5,288.94 MM (4) 11,616.85 91.51 166.59 5,990.25 5,920.15 4,688.51 -2,755.30 6,005,326.33 495,901.10 6.94 5,253.57 MWD (4) 11,648.30 90.68 169.14 5,989.65 5,919.55 4,657.77 -2,748.69 6,005,295.59 495,907.71 8.53 5,237.16 MWD (4) 11,677.10 89.85 167.64 5,989.51 5,91941 4,629.57 -2,742.87 6,005,267.39 495,913.52 6.26 5,213.10 MWD (4) 11,696.98 90.43 165.91 5,989.47 5,919.37 4,610.22 -2,738.30 6,005,248.04 495,918.08 8.70 -5,196.19 MWi)(4) 11,726.96 9175 163.00 5,988.89 5,918.80 4,581.35 -2,730.27 6,005,219.17 495,926.11 1066 -5,170.09 MWD(4) 11,757.16 92.70 161.28 5,987.72 5,917.62 4,552.62 -2,721.02 6,005,190.45 495,935.36 6.50 -5,143.24 MWD (4) 11,787.18 94.15 160.15 5,985.93 5,915.63 4,524.34 -2,711.12 6,005,162.17 495,945.25 6.12 -5,116.24 MM (4) 11,817.27 91.81 160.61 5,984.36 5,914.26 4,496.04 -2,701.03 6,005,133.86 495,955.33 7.93 -5,089.10 MWD (4) 11,847.14 90.40 16065 5,983.79 5,913.69 4,467.87 -2,691.12 6,005,10569 495,96523 4.72 5,062.17 MM (4) 11,877.49 88.86 159.40 5,983.98 5,913.88 4,439.34 -2,680.76 6,005,077.17 495,975.59 6.54 5,034.67 MWD (4) !. 11,904.11 8779 156.99 5,984.76 5,914.66 4,414.64 -2,670.87 6,005,052.47 495,985.47 9.90 -5,01022 MWD (4) 11932.08 89.05 156.77 5,985.53 5,915.43 4,388.93 -2,659.90 6,005,026.76 495,996.44 4.57 4,984.27 MWD (4) 11,966.42 8745 154.03 5,986.58 5,91648 4,357.72 -2,645.61 6,004,995.55 496,010.72 9.24 4,952.10 MM (4) 11,997.33 87.48 150.05 5,987.95 5,917.85 4,330.45 -2,631.14 6,004,968.28 496,025.19 12.86 4,922.59 MWD (4) 12,022.21 88.44 147.81 5,988.84 5,918.74 4,309.16 -2,618,30 6,004,946.99 496,036.01 9.79 -0,898.45 MM (4) 12,052.21 88.71 147.53 5,989.58 5,91948 4,283.82 -2,602.27 6,004,921.64 496,054.05 1.30 4,869.19 MWD (4) 12,085.08 89.82 149.79 5,99000 5,919.90 4,255.75 -2,585.17 6,004,893.58 496,071.13 266 4,837.26 MWD (4) 12,116.62 88.59 151.44 5,990.44 5,920.34 4,228.27 -2,569.70 6,004,866.10 496,08660 6.52 4.806.89 MWD (4) 12,147.11 87.82 15332 5,991.40 5,921.30 4,201.27 -2,555.57 6,004,839.10 496,100.72 666 4,777.81 MWD (4) 12,176.65 i 8748 152.48 5,992.61 5,922.51 4,174.99 -2,542.13 6,004,81262 496,114.16 107 4.749.72 MWD (4) 12,20703 86.93 152.36 5,99409 5,923.99 4,148.10 -2,528.08 6,004,78593 496,128.20 1.85 -.720.77 MWD (4) 12,247.94 85.70 151.96 5,99672 5,92662 4,112.00 -2509.01 6.00474983 496,147.26 3.16 -4,681.76 MWD(4) 211 22 0 1 9 12: 11 59P Page 5 COMPASS 5000.14 Build 85D ConocoPhillips eyccu H�s� ry.�E�M ConocoPhillips Definitive Survey Report Company: _ConocoPhillips (Alaska) Inc. -Kup2 Project Kupamk River Unit Site: Kuparuk 3H Pad Wait: 3H-23 Wellbore: 3H-23AL1 Design: 3H-23AL1 Survey Local Co-ordinate Reference: Well 3H-23 TVD Reference: 311-23A: Q 70.10usft (3H -23A:) MD Reference: 3H -23A: @ 70.10usft (3H -23A:) North Reference: True Survey Calculation Method: Minimum Curvature Database: EDT 14 Alaska Production Annotation 21122019 12:11:59PM Page 6 COMPASS 5000.14 Build 85D Map Map Vertical MD Inc Azi TVD TVDSS +N/S -E/-W Northing Eastin DLS Section Survey Tool Name (usft) P1 (°I (usft) (usft) (usft) usft) (ft) (ft) (./too,) (./too,) (ft) 12,276.99 85.05 150.98 5,999.06 5,92896 4,086.56 -2,495.18 6,004,724.39 496,161.08 4.04 4.653.99 MWD(4) 12,305.89 84.66 150.35 6,001.65 5,931.55 4,061.47 -2,481.08 6,004,699.30 496,175.18 2.56 4,626.28 MM (4) 12,33529 83.55 150.07 6,004.78 5,934.68 4,035.22 -2,466.06 6,004,673.05 496,190.20 376 4,597.10 MWD (4) 12,356.46 83.05 150.59 6,008.30 5,93820 4,009.19 -2,451.23 6,004,647.02 498205.02 2.38 4,568.20 MWD (4) 12,396.76 83.57 152.27 6,011.83 5,941.73 3,982.76 -2,436.83 6,004,620.59 496,219.41 5.77 4,539.34 MWD (4) 12,426.80 84.98 15266 6,014.82 5,944.72 3,956.26 -2,423.02 6,004,594.09 496,23322 4.87 4,510.83 MWD (4) 12,466.00 84,98 152.66 6,018.25 5,948.15 3,92157 -2,405.08 6,004,55940 496,251.14 0.00 4,47362 PROJECTED to TD Annotation 21122019 12:11:59PM Page 6 COMPASS 5000.14 Build 85D � NCU STATE OF ALASKA rp n ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1a. Well Status: Oil❑+ , Gas❑ SPLUG ❑ Other ❑ Abandoned ❑ Suspended ❑ 2 C25.105 20MC 25.110 GINJ ❑ WINJ ❑ WAGE] WDSPL ❑ No. of Completions: 1b. Well Class: Development R] Exploratory El Service ❑ Stratigraphic Test ❑ 2. Operator Name: ConocoPhillips Alaska, Inc. 6. Date Comp., Susp., or Abend.: 1/18/2019 14. Permit to Drill Number / Sundry: 218-175 3. Address: P.O. Box 100360 Anchorage, AK 99510-0360 7. Date Spudded: 1/14/2019 15. API Number: 50-103-20204-60-00 ' 4a. Location of Well (Governmental Section): Surface: 1019' FNL, 281' FWL, Sec 12, T12N, R8E, UM Top of Productive Interval: 995' FNL, 1433' FWL, Sec 2, T1214, R8E, UM Total Depth: 2379' FNL, 2121' FEL, Sec 2, T12N, R8E, UM 8. Date TD Reached: 1/17/2019 16. Well Name and Number: KRU 3H-23AL1 ' 9. Ref Elevations: KB:70 GL: 38 • BF: 17. Field / Pool(s): Kuparuk River Field/Kuparuk River Oil Pool 10. Plug Back Depth MD/TVD: N/A 18. Property Designation: ADL 25531 - 4b. Location of Well (State Base Plane Coordinates, NAD 27): Surface: x- 498655 • y- 6000638 ' Zone- 4 TPI: x- 494525 y- 6005944 Zone- 4 Total Depth: x- 496251 y- 6004559 Zone- 4 11. Total Depth MD/TVD: - 12466/6018 ' 19. DNR Approval Number: LONS 83-134 12. SSSV Depth MD/TVD: N/A 20. Thickness of Permafrost MD/rVD: 1627/1584 5. Directional or Inclination Survey: Yes ❑� ' (attached) No ❑ Submit electronic and printed information per 20 AAC 25.050 13. Water Depth, if Offshore: N/A (ft MSL) 21. Re-drill/Lateral Top Window MD/TVD: 955815976 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 SETTING DEPTH MD SETTING DEPTH TVD AMOUNT CASING FT GRADE TOP BOTTOM TOP BOTTOM HOLE SIZE CEMENTING RECORD PULLED 16 62.58 H-40 42 121 42 121 24 200 sx AS 11 95/8 36 J-55 41 4216 41 3181 12.25 900 sx ASIII, 600 sx Class G 7 26 L-80 36 9341 36 5882 8.5 250 sx Class G 23/8 4.6 L-80 9519 12466 5959 6018 3 slotted liner 24. Open to production or injection? Yes 0 No ❑ If Yes, list each interval open (MD/rVD of Top and Bottom; Perforation Size and Number; Date Perfd): SLOTTED LINER @: COMPLETION 8519-12466 MD and 5960-6018 TVD ... 1/18/2019 D 1/1 & //B VV; ;PIED 25. TUBING RECORD SIZE DEPTH SET (MD) PACKER SET (MD/TVD) 31/2 1 7507 7475/4958 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. Was hydraulic fracturing used during completion? Yes ❑ No [D Per 20 AAC 25.283 (i)(2) attach electronic and printed information DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED 27. PRODUCTION TEST Date First Production: 1/23/2019 Method of Operation (Flowing, gas lift, etc.): GAS LIFT Date of Test: 2/8/2019 Hours Tested: 8hrs Production for Test Period Oil -Bbl: 18 Gas -MCF: 7 Water -Bbl: 343 Choke Size: 176 Gas -Oil Ratio: 0.389MCF/bbl Flow Tubing Press. 204 sl Casino Press: 162 si Calculated 24 -Hour Rate Oil -Bbl: 55 Gas -MCF: 2 Water -Bbl: 1 1029 Oil Gravity- API (corr): Form 10-407 Revised 5/2017 �L Z/Z�< / / CONTINUED PAGP 2 RBDMS j FEB 1 0 1019 SubmtORIGI I L nII 28. CORE DATA Conventional Core(s): Yes ❑ No ❑� ' Sidewall Cores: Yes ❑ No 0 - If Yes, list formations and intervals cored (MDlrVD, 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 1627 1584 Attach separate pages to this form, if needed, and submit detailed test Top of Productive Interval 9558 5976 information, including reports, per 20 AAC 25.071. Formation @ TPI -Kuparuk At TD 12466 6018 Formation at total depth: Ku aruk A 31. List of Attachments: Daily Operations Summary, Definitive Survey, Schematic Information to be attached includes, but is not limited to: summary of daily operations, wellbore schematic, directional or inclination survey, core analysis, paleontoloa cal report, production or well test results. per 20 AAC 25.070, 32. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Authorized Name: James Ohlin er Contact Name: Ran McLau hli Authorized Title: Sta CTD Engineer Contact Email: an.mclau hlin co .com Authorized Contact Phone: 265-6218 Signature: Date: 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 512017 Submit ORIGINAL Only ConocoPhillips Nasiiz. 0l KUP PROD WELLNAME 3H -23A RIVER UNIT 1012212018 WELLBORE 3H-23 09 3wa, v+a2D19 a+sIn PN Casing Strings VSNSIWw++R ls[Odl Casing OncJgion CONDUCTOR OD (in) 16 I ID gni 15.06 Top(XNBI 42.0 Set )ep1N (.n., 1210 Set Depin 1TV0,... 121.0 WVLM II_.OnEe 62.58 H-40 Toplhrc WELDED Casts Dmmrn 009.1 IO(INi Tep C.N.1 Sei OepIN 111X91 Sel DepIN INOL.. WtlLm 11... Gg4e TOp U, 9518 892 413 4,216.3 3,185> 36.W J-55 BTC Casl�q CascNplbn OO lln) 109.1 Tap M.) .D w(1 get Oem IND)...WIILen(i G1aEa Top T..W PRODUCTION I 628 363 I 9.3410 6,197.2 26.M L-80 BTC -MOD XµGEP', 21.0 "COWUCTOR; NII 3014 O UFT;J,2139 3URFPCE;<t3 .21&3 - Fm. 4,MO Gly LIFE, 4,W90 WS UFT: 4238.3 .LIFT.1,4213 NIPPLE; 74n,i 3EAL M$Y',14195 PROOVCTION: 38.39,3it0 UNER', 7.4569MO KUP PROD WELLNAME 3H -23A WELLBORE 3H -23A r rr Well Atti ibut Ma:Angle 7 TD Conoco- "'''I' paid WeIl4 re NP VW WellO res luz MDII ActBM(M1NB) AIABKA. h1C KUPARUK RI VER UNIT 501032020401 PROD 8.34 3,809.Re 98)50 NIPPLE 1140 1101202018 HaSIWO: 3H -HS, sdaddd.a507PM Last Tag Vn'Nal eoMnaEa lacEtll Annotation DepIN Me) 1 End Dale paid.. cut Mad BV last Tag: RKB(943T CTMD) 9.53 .0 I11&2019 oi-il 'proven Last Rev Reason .................. ...-.......... .........___._....... .......... .................. Annotation End Data wellbore Las1MMBV .GENT no Rev Reason'. GLV work. 21312019 3H -23A larguep Casing Strings Corns Dasodp.n GD hnl IDlln) T'(SKel am cnmla,d) set WDMa l D. 11... Grine Topm— LINER 4112 39fi J,4J5.4 08)50 12.60 L-80 NSCT Liner Details Nominal D Top NK8 TOPOWDdem.) Topmcll°I Item Dee Co. Bnl 7 4 4,957.8 56.21 HE BA BAKER LIN R I JACK SLEEVE wIC-2 ZXP LINER 4.3]5 PACKER TOP PACKER 7,489.3 4,965.5 56.09 HANGER BAKER HMC LINER HANGER 4375 CONDUCTOR', 42_0-1210 7,496.0 4,960) 56.03I SBE BAKER SEAL BORE EXTENSION 4000 Tubing Strings NIPPLE: fQ1.9 Tubing De ... plion String Ma...ID(InI Top IM1KB) set Depth m.. set Depth OVD11... WY DNR) Grarle Tadd meenllan TUBING 3112 2.99 27.0 7,506.6 4,9752 9.30 J-55 EUE BRD Completion Details Qas LlFT:3$119 TOP ITVOI Top Incl Nominal Top admid (Ma) I°) Item Dec Con ID lint 270 27. 0.17 HANGER WKM GEN VI TUBING HANGER 3.500 507.4 50).7 1S2 NIPPLE CAMCO DS NIPPLE 2.812 7,4724 4,956.1 m1,t 1.1111, CAMCOO NIPPLE NO GO(MILLEDOUT 10280)1-8- 1 2.800 ],4]9.5 4,960.1 56.17 SEAL ASSY DAKILH LAJH-22 LOCATOR EAL ASSEMBLY, SEALS OU4" 3Dmu WAO' STROKE. STABBED INTO LINER TIEBACK Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) TOpn Tt Top Ind Top (ME) (nNel fl De: COm Run.,. ID Diol SURFACE: 4134.21e3� 49880 3,6100 56.65 DSIT Grapplefrom l JO" Bowen over shat. 2we1e lost 8 only 2/212019 0.000 1 was recovered in the catcher. Lost grappM could W On sN ii 2 Or A 3 latch. Fish', 4.LG90 9,5186 CTD 2318"Their " AL I liner. Lined upinlo U74Liner. Liner 11181019 1.992 G46 uFr:4,eeea top (Deployment sleeve) @ 9518 6 1 Perforations & Sloq GASUFT.6,21193 Sh" Den TaD) BM (IVOI (shoLslh Top INKS) "do"m lM1l(B) IME) el (ME) Linked Zone Dale 1 T. Com 9,5500 9,6000 A-1, H- 11191199] v 1PERF"' "'hips, deg. JA" 23A I ph GASLIFT. 7.4375 Mandrel Inserts a N TOp W, Top nV01 BN(el had. Mod. GD lint Seng Valwi ryye patch Type pods® ping TRORun paid Run Data Com NIPPLE. 7 474 t 3,213.9 2,639.3 MERIA TMPD 1 GAS LIFT GLV BK 0186 1,264.0 2/312019 2 4,988.0 3,610.0 MERIA TMPD i GAS LIFT GLV BK 01M 1,346.0 112911997 97thp ped FIN. 3 6,299.3 4,322. MERIA TMPD 1 GAS LIFT GLV BK 0188 1,333.0 112&1997 vlp ped FIN SEALASST:7,479.5 4 7,4273 4,931.1 CAMCO MMM 1112 GAS LIFT OV RK 0.156 0.0 2132019 Notes: General & Safety End Dare ammonium 1212711996 NOTE: WELL SIDETRACKED luscdo1D NOTfi View Schematic wl Alaska Schematic90 PROOUCTWN. 3158,0410 AL1 sMW LVIah 8.5106 f$adao IPERF: 9.55p.69�0� ONES; T,4TVAB,8]SD CTD2 WLnv; Wee KUP PROD WELLNAME 3H -23A WELLBORE 3H-23AL1 C/�s�y� „ 1•�" Well AHribeb Max Angie. + TD w~�'IIIrs FRIEName WeIIb gPVUW MIIde9ulus =Ij•j MD(X. ActBm(flKB) Alaska, IrIC. KLIPARUK RI VER UNIT 5010320204fi0 PROD 3>42 1037566 12.4620 34-ZNael'a1 A93'.15:011210 Ceasing Strings VVIXJ vlsneti=(.a Casl,g Deser,mm' AL151oned Liner OG)Inj 2318 1U1^I 199 T=P jRKBj 3el OeplM1 IflNR) 9.518.6 12,4650 gelo"PR(WD)...WVLen 6,018.3 (I...GFade 4.60 L-80 T=PTM1IeaU STL Liner DefalIs Nominal lD T=PIM1Ke) TOPIry TOP m=q°) IRm Oea c^m nm HANGER'. no 518.fi Ggaa) 5,959.1 fi4.44 Deployment 1000 Sleeve CORDUCTOR.<LG1310 NIPPLE W 4 G UFT:32139 SJRFACEH13Ha.P63� FM;<,MO EAS UFT. 4.9P6o .UFT:R.3 GPS UFT', 7,1219 NIPPLE, 7AM4 SE9LA99Y7,,H795 PRODUCTION: 39.39.3410 CTD2Y Uw,9.5109 (PERF; LINER; 7 47R Ama PLf H%@E Inx,9S196� 3.40 31-1-23A Final CTD Schematic shoe 121' MD "18" 36# J-55 shoe @ 4216' MO 7" 26# LA0 shoe 0 9341' MD TOWS � 9558' MD A -sand pens 9554 - 960d MD 41/2" 12.6# LA0 shoe @ 9875' MD 31/2" Carom DS nipple a 5oT MD (2.875" min ID) 31/2" 9.30 LA0 EUE 8rd Tubing to surface 3-1/2" Carrico gas IIB mandrels (813214', 4988'. 6299', 8 7427' MD 31/2" Carrico D landing nipple Q 7472' MO (Milled out to 2.80") Baker 3-1/2" GBH -22 seal assembly @ 7480' MO (3" ID) Lines Baker ZXP liner top packer @ 7475' MD Baker HMC liner hanger (817489' MD Baker 8040 SBE Q 7496' MD 3H-23AL1 TD: 12,466' MD TOL = 9518.6' MD, BOL=12,466' MD 2-M" slotted liner w/deployment sleeve Uperations Summary (with Timelog Depths) 3H-23 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Scan Depth Start Time End Time our (hr) Phase Op Code Activity Cafe Time P-T-% Operation (IMS) End Depth(MB) 1/10/2019 1/10/2019 3.00 MIRU MOVE RURD P Continue RD checklist, secure stack, 0.0 0.0 02:00 05:00 chain off reel, empty all pits, continue trucking items/product to 3H-Pad, disconnect majority of PUTZ 1/10/2019 1/10/2019 3.00 MIRU MOVE RURD P Compete RD checklist, breakdown TT 0.0 0.0 05:00 08:00 hard-line, secure stairs & landing, disconnect PUTZ 1/1012019 1/10/2019 1.50 MIRU MOVE RURD P Peak trucks arrive, load up shop & half 0.0 0.0 08:00 09:30 1 1 1 -way house 1/10/2019 1/10/2019 2.50 MIRU MOVE RURD P Pull sub & pits off well, jeep up, secure 0.0 0.0 09:30 12:00 well 1/10/2019 1/10/2019 7.00 MIRU MOVE MOB P Move to 3H-Pad (stopped at KOC for 0.0 0.0 12:00 19:00 Boeing flight) 1/10/2019 1/10/2019 3.70 MIRU MOVE MOB P Arrive on 3H-Pad 19:00 hrs, drop off 0.0 0.0 19:00 22:42 jeeps, sub & pits spotted, mats laid (-50 min to lay mats for sub & pits) 1/1012019 1/1112019 1.30 MIRU WHDBOP NUND P NU BOP 0.0 0.0 22:42 00:00 Rig Accept 1/10/19 @ 2400 hrs 1/11/2019 1/11/2019 2.50 MIRU WHDBOP RURD P Continue RU checklist, spot tiger-lank, 0.0 0.0 00:00 02:30 hook up PUTZ, blowdown steam, drop stairs & landings, spot shop & half- way house 1/11/2019 1/11/2019 2.00 MIRU WHDBOP RURD P Complete RU checklist, energize 0.0 0.0 02:30 04:30 Koomey, unlock injector & reel, begin MU tiger-tank hard-line, grease tree & tangos, grease Romeo & Bravo valves 1/11/2019 1/11/2019 2.50 MIRU WHDBOP PRTS P PJSM, fluid pack lines, perform shell 0.0 0.0 04:30 07:00 1 1 test 1/1112019 1/11/2019 6.20 MIRU WHDBOP BOPE P Begin BOPE test (witness waived by 0.0 0.0 07:00 13:12 Matt Herrera ofAOGCC) " 250 psi low 114800 psi high 1/11/2019 1/11/2019 1.30 MIRU WHDBOP PRTS P PT PDL's and TT line, Blow down, 0.0 0.0 13:12 14:30 raise mast 1/11/2019 1/11/2019 2.80 SLOT WELLPR CTOP P Skid injector to floor, Remove UQC. 0.0 0.0 14:30 17:18 Cut CT connector, cut 17' of pipe, re- head, pull test to 40K, re-head aline & lest 1/11/2019 1/11/2019 2.00 SLOT WELLPR CTOP P MU panel to adjacent wells, pre-load 0.0 0.0 17:18 19:18 PDL, bleed down IA for -45 min (down to 910 psi, plan to continue bleeding after setting WS) 111112019 1/11/2019 1.00 PRODi WHPST PULD P PJSM, PD BHA#1 WS Assembly 0.0 74.0 19:18 20:18 Difficulty opening master valve, open swab one, attempt to open master again, no good, open swab 2, pressure up on master from above (1000 psi), open master (870 psi below master) 1/11/2019 1/11/2019 1.00 PROD1 WHPST PULD T Attempt to bleed off PDL, unable, FVS 74.0 0.0 20:18 21:18 not MU in tool striing, equalize PDL, open rams,suck tools into PDL, shut swab 2, install FVS 1/11/2019 1/11/2019 0.80 PROD1 WHPST TRIP P PD BHA#1, slide in cart, check pack- 0.0 74.0 21:18 22:06 offs, MU to coil, tag up, set counters 1/11/2019 1/12/2019 1.90 PROD1 WHPST TRIP P RIH w/BHA #1 74.0 8,955.0 22:06 00:00 1/12/2019 1112/2019 0.10 PROD1 WHPST TRIP P Continue RIH w/ BHA#1 8,955.0 9,355.0 00:00 00:06 1/12/2019 1/12!2019 0.20 PROD1 WHPST DLOG P Log K1 for-7' correction 9,355.0 9,403.0 00:06 00:18 1 I Page 119 Report Printed: 1121/2019 Uperations Summary (with Timelog Depths) 3H-23 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log De Steri DeDepthTi Start me End Time Dur(hr) Phe. Dp Code Activity Code Time P -T -x operation (rt End Depth (lIKB) 1/12/2019 1/12/2019 0.20 PROD1 WHPST TRIP P PUW = 40K, PUH to HRZ 9,403.0 8,990.0 00:18 00:30 1/12/2019 1112/2019 0.80 PROD1 WHPST DLOG P Log CCL from HRZ down to 9446', set 8,990.0 9,446.0 00:30 01:18 down 5K CWT at 9446', PUW = 39K, RBIH, again stack 5K CWT @ 9446', PUW = 40K, decision made to POOH & PU cleanout assembly 1/12/2019 1/12/2019 1.70 PROD1 WHPST TRIP T POOH, tag up, PJSM 9,446.0 74.0 01:18 03:00 1/12/2019 1/12/2019 1.50 PROD1 WHPST PULD T PUD BHA #11, checks failed, close 74.0 0.0 03:00 04:30 EDC, begin PUD w/ failed checks '• whipstock shear pin came out with sheared fork retaining pin. HOT SHOT whip -stock to BOT for redress and return to CDR3 1/12/2019 1/12/2019 2.00 PROD? WHPST PULD T PD BHA#2 FCO Assembly, slide in 0.0 62.0 04:30 06:30 cart, check pack -offs, MU to coil, tag up, set Counters 1/12/2019 1/12/2019 1.70 PROD1 WHPST TRIP T RIH w/ BHA#2 & clean-out to WS 62.0 9,340.0 06:30 08:12 setting depth 1/12/2019 1/12/2019 0.30 PROD1 WHPST DLOG T Log K1 for -5.5'. PUW=33K 9,340.0 9,361.0 08:12 08:30 1/12/2019 1/12/2019 0.80 PROD1 WHPST TRIP T Continue in well, Mud at bit 9434'. see 9,361.0 9,622.0 08:30 09:18 stacking with slight motor work 9575. PUH then go right through to 9588. PUH. RBIH to 9622' 1/1212019 1/12/2019 0.60 PROD1 WHPST TRIP T 9622, PUH to run CCL pass, 1.9 BPM 9,622.0 8,987.0 09:18 09:54 1 @ 3641 PSI FS, BHP=3367 1/12/2019 1/12/2019 1.00 PROD1 WHPST DLOG T 8987', Run CCL to 9620. Bad data 8,987.0 9,620.0 09:54 10:54 from 9500' down. PUH and relog 1/12/2019 1/12/2019 2.30 PROD1 WHPST TRIP T 9620', Trip out, 1.82 BPM EDC closed. 9,620.0 44.0 10:54 13:12 At 1620' hole started unloading frac sand. Slowed pull speed. Performed jog from 500' back to 900'. PUH to 150 feet and jog back into 500'. Shaker cleared up. Open EDC tag up and space out 1/12/2019 1/12/2019 2.20 PRODt WHPST PULD T PJSM, PUD BHA#2, difficulty with DS 44.0 0.0 13:12 15:24 PDL (frozen up), switch to ODS PDL & carry on 1/12/2019 1/12/2019 1.60 PRODi WHPST PULD T PD BHA#3 WS Assembly, slide in 0.0 75.0 15:24 17:00 cart, MU to coil, tag up, set counters 1/12/2019 1/12/2019 1.70 PROD1 WHPST TRIP T RIH w/BHA #3 75.0 9,365.0 17:00 18:42 1/12/2019 1/12/2019 0.30 PROD1 WHPST DLOG P Log K1 for -7' 9,365.0 9,417.0 18:42 19:00 1/12/2019 1/12/2019 0.20 PRODi WHPST TRIP P Continue RIH, PUW = 37K from 9,417.0 9,558.0 19:00 19:12 9500', arrive at set depth, shut down pumps, close EDC, bring on pumps, shear @ 3500 psi, WS set, set down 5.5K, good, PUW = 36K 1/12/2019 1/12/2019 1.80 PRODi WHPST TRIP P POOH w/ BHA#3, open EDC, PJSM 9,558.0 63.0 19:12 21:00 1/12/2019 1/12/2019 1.00 PROD1 WHPST PULD P Begn PUD BHA#3, pull test SL, 63.0 0.0 21:00 22:00 parted ODS SL 1112/2019 1/12/2019 1.00 PROD1 WHPST PULD P Work to free froze -up SL on DS PDL, 0.0 0.0 22:00 23:00 unable to free with significant effort 1/12/2019 1/13/2019 1.00 PROD1 WHPST PULD T Drop lower section of ODS PDL, wire 0.0 0.0 23:00 00:00 - 15' up in next section, begin to break off second section Page 2/9 Report Printed: 1/21/2019 Uperations Summary (with Timelog Depths) 3H-23 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Depth Slert Time EM Time our (hr) phase Op Cale Acdvq Code Time P -T -X Opere n re(B) EM Depth (WS) 1/13/2019 1/13/2019 2.50 PROD1 WHPST PULD T Continue breaking down ODS PLD, 0.0 0.0 00:00 02:30 find SL, threads on upper swivel are stripped, re -head SL, reassemble PDL 1/13/2019 1/1312019 0.90 PROD1 WHPST PULD P PJSM to re -group, complete PUD BHA 0.0 0.0 02:30 03:24 #3 1/13/2019 1/13/2019 1.40 PROD1 WHPST PULD P PD BHA #4 Window Milling Assembly 0.0 75.0 03:24 04:48 (0.6° AKO motor, 2.80" string reamer, & 2.80" window mill), slide in cart, check pack -offs, MU to coil, tag up, set counters 1/13/2019 1/13/2019 1.80 PROD1 WHPST TRIP P RIHw/BHA#4 75.0 9,365.0 04:48 06:36 1/13/2019 1/13/2019 0.20 PROD1 WHPST DLOG P 9365 Log K1 for -7', PUW=35K, Close 9,365.0 9,387.0 06:36 06:48 EDC 1/13/2019 1/13/2019 0.40 PROD1 WHPST TRIP P Continue in, Dry tag pinch point @ 9,367.0 9,561.0 06:48 07:12 9560, PUH bring pumps online at 1.87 BPM @ 3687 PSI FS, BHP=3308. Call pinch point @ 9561 1/13/2019 1/13/2019 5.20 PROCI WHPST MILL P Pumping pinch point 9561. Mill 9,561.0 9,567.0 07:12 12:24 window per BOP rep. Call mill exit @ 9567.7 1/13/2019 1/13/2019 1.90 PROD1 WHPST MILL P 9567.7, Time mill 2.3 feet past mill exit 9,567.0 9,570.0 12:24 14:18 for string reamer to work 1/13/2019 1/13/2019 1.00 PROD1 WHPST MILL P 9570', Drill rathole down to 9583 9,570.0 9,583.0 14:18 15:18 1/13/2019 1/13/2019 2.40 PROD1 WHPST REAM P Start reaming passes. As drilled, 30L, 9,583.0 9,583.0 15:18 17:42 30R and 180° out of as drilled, dry drift, clean, tag bottom of rat -hole 1/13/2019 1/13/2019 2.20 PROD1 WHPST TRIP P POOH, continue rebuilding DS PDL, 9,583.0 74.0 17:42 19:54 PJSM, open EDC 1/13/2019 1/13/2019 1.60 PRODi WHPST PULD P PUD BHA 44, string reamer & mill 74.0 0.0 19:54 21:30 came out 2.80" no-go 1/13/2019 1/1312019 1.50 PROD1 DRILL PULD P PD BHA#5 Build/Turn Assembly (2.2' 0.0 72.0 21:30 23:00 AKO motor & RB Hughes bit), slide in cart, check pack -offs, good, Mu to coil, tag up, set counters 1113/2019 1/14/2019 1.00 PROD1 DRILL TRIP P Begin RIH w/ BHA #5 72.0 4,600.0 23:00 00:00 1/14/2019 1/14/2019 0.80 PROD1 DRILL TRIP P Begin RIH w/ BHA #5 4,600.0 9,355.0 00:00 00:48 1/14/2019 1/14/2019 0.30 PROD1 DRILL DLOG P Log K1 for -7.5' correction, PUW = 9,355.0 9,412.0 00:48 01:06 136K 1/14/2019 1/14/2019 0.20 PROD? DRILL TRIP P Continue RIH, resume reassembling 9,412.0 9,583.0 01:06 01:18 DS PDL 1/14/2019 1/14/2019 0.40 PRODt DRILL DRLG P Drilling, FS = 470 psi @ 1.9 bpm, 9,583.0 9,622.0 01:18 01:42 CWT =I4K, WOB=1K, WHP=313 psi, circ = 4300 psi, dp = 726 psi BHP = 3333 psi (rate out = 1.75 bpm, 10.7 ppg) BHP = 3449 psi (rate out = 1.44 bpm, 11.2 ppg) BHP = 3557 psi (rate out = 1.41 bpm, 11.4 ppg) PU to grab to new numbers, PUW = 35K Page 319 ReportPrinted: 1121/2019 Uperations Summary (with Timelog Depths) 3H-23 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log start DBPM Start Time End Time Our (hr) Phase Op Code A vay Coce Time P -T -X Operation (ftKB) End Depfn(ftKB) 1/14/2019 1/14/2019 1.80 PRODt DRILL DRLG P Drilling, FS = 467 psi @ 1.9 bpm, 9,622.0 9,864.0 01:42 03:30 CWT = 12.91K, WOB = 1.3K, annular = 3565 psi, WHP = 275 psi, circ = 4186 psi, rip = 652 psi, rate out = 1.55 bpm (increasing), continue to increae ECD at window No resistivity until 9682', MWD made adjustments & resolved issue 1/14/2019 1/14/2019 1.10 PROD1 DRILL DRLG P Drilling, 1.9 bpm in, 1.76 bpm out, 9,864.0 9,960.0 03:30 04:36 CWT = 11.6K, WOB = 2.2K„ annular = 3697 psi, WHIP = 333 psi, circ = 4181 psi, PUW = 34K from 9867 psi, drill to called EOB at 9960' Baker screen freezing -up, PU to reboot 1/14/2019 1/14/2019 2.20 PROD1 DRILL TRIP P Call EOB, POOH, PUW = 35K, open 9,960.0 66.0 04:36 06:48 1 1 EDC, AVG DLS 34.9° for build secion 1/14/2019 1/14/2019 1.00 PROD1 DRILL PULD P Tag up and space out, PUD BHA #5 66.0 0.0 06:48 07:48 1/14/2019 1/14/2019 0.20 PROD1 DRILL PULD P P/U Bit, Motor, agitator, and FVS. 0.0 0.0 07:48 08:00 Make up to toolstring and scribe 1/14/2019 1/14/2019 0.80 PROD? DRILL PULD P PD BHA #6, Lateral dilling BHA 0.0 78.0 08:00 08:48 with .5° AKO motor, new HCC P104 bi center, and agitator, make up to coil and surface test. 1/14/2019 111412019 1.50 PROD1 DRILL TRIP P RIH BHA#6, Test agitator @ 596', 78.0 9,360.0 08:48 10:18 Continue in hole. 1/14/2019 1/14/2019 0.10 PROD1 DRILL DLOG P 9360 Tie into K1 for -7.5', PUW=35K 9,360.0 9,385.0 10:18 10:24 j 1114/2019 1/14/2019 0.20 PRODt DRILL TRIP P Continue in well 9,385.0 9,585.0 10:24 10:36 1/14/2019 1/14/2019 0.20 PROD1 DRILL DLOG P Log the RA @ 9565.5', 9,585.0 9,616.0 10:36 10:48 TOWS=9557.15 1/14/2019 1/14/2019 1.20 PROD1 DRILL TRIP P Continue in well, Tag up @ 9960' and 9,616.0 10,064.0 10:48 12:00 drill. 1.87 BPM @ 4984 PSI FS, BHP=3764, Start new mud down coil 1/1412019 1/14/2019 2.40 PROD1 DRILL DRLG P New mud all around, PIU to get new 10,064.0 10,247.0 12:00 14:24 drilling parameters, 1.88 BPM @ 4892 PSI FS, BHP=3706, Holdinf 11.8PPG at window 1/14/2019 1/14/2019 0.10 PROD1 DRILL WPRT P Pull BHA wiper, PUW=45K 10,247.0 10,247.0 14:24 14:30 1/14/2019 1/14/2019 1.10 PROD1 DRILL DRLG P 10247', Drill, 1.86 BPM @ 4656 PSI 10,247.0 10,294.0 14:30 15:36 FS, BHP=380OPSI, RIW=5.9K, DHWOB=2.1 K 1/14/2019 1/14/2019 0.30 PROD1 DRILL WPRT P Wiper to 9900', PUW=39K 10,294.0 10,294.0 15:36 15:54 1/14/2019 1/14/2019 1.90 PROD1 DRILL DRLG P 10294', Drill 1.88 BPM @ 4605 PSI 10,294.0 10,400.0 15:54 17:48 FS, BHP=3749 1/14/2019 1114/2019 0.60 PROD1 DRILL WPRT P 10400', Wiper to 9600', PUW=38K 10,400.0 10,400.0 17:48 18:24 1/14/2619 1/14/2019 4.30 PROD1 DRILL DRLG P 104001, Drill, 1.9 BPM @ 4707 PSI 10,400.0 10,780.0 18:24 22:42 FS, BHP=3719, RIW=9.8K, DHWOB=I.5K 1/14/2019 1/14/2019 0.70 PROD1 DRILL WPRT P Wiper to 10,000'wilh sweeps, PUW- 10,780.0 10,780.0 22:42 2324 40K 1/14/2019 1/15/2019 0.60 PROD1 DRILL CIRC P Lost 1 generator, PUH & circluate 10,780.0 10,780.0 23:24 00:00 bottoms up, get gen back on-line, RBIH Page 419 ReportPrinted: 1121/2019 Uperations Summary (with Timelog Depths) 3H-23 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log start oepm Start Time End Time Our(hr) Phase Op Code Activity Code Time P -T -X Operation (flKB) End Depth (1lKB) 1/15/2019 1/15/2019 1.00 PROD1 DRILL DRLG P Drilling, CWT =7K, WOB=1K, 10,780.0 10,830.0 00:00 01:00 annular = 3780, WHIP =237 psi, circ 4785 1/15/2019 1/15/2019 2.90 PROD1 DRILL DRLG P Drilling, CWT=6K, WOB=1.6K, 10,830.0 10,983.0 01:00 03:54 annular = 3773 psi, WHP = 221 psi, circ = 4819 psi, PU's as required to maintain weight transfer, PUW = 45K, pump 5 x5 sweeps 1/15/2019 1115/2019 0.30 PROM DRILL DRLG Drilling, difficutly w/ weight transfer, 10,983.0 10,983.0 03:54 04:12 many PU's, annular= 3766 psi, WHIP = 255 psi, circ = 4773 psi, continue to have propant over shaker (-20%- 30% over lateral) " Phase 3 called @-3:50AM, allow sweeps to exit bit, then pull into cased hole 1/15/2019 1/15/2019 0.50 PROM DRILL TRIP T Pull into rased hole, PUW = 38K 10,983.0 9,515.0 04:12 04:42 1/15/2019 1/15/2019 6.70 PROD1 DRILL CIRC T Slowly pull up to top of 4.5", 9,515.0 9,515.0 04:42 11:24 circulating, waiting on weather (Phase 3), log K1 for ... 1/15/2019 1/15/2019 0.10 PROD1 DRILL CIRC T Open EDC, pump at 2.5 bpm for 4 min 9,515.0 9,515.0 11:24 11:30 (test for (U-10 liner release) Circ = 4805 psi, bore = 3582 psi, annular = 3539 psi, dp = 50 psi Close EDC 1/15/2019 1/15/2019 6.50 PROD1 DRILL CIRC T Continue circulating at 0.5 bpm 9,515.0 7,691.0 11:30 18:00 1/15/2019 1/15/2019 0.50 PROM DRILL CIRC T Phase 2 called, crew change, PJSM in 7,691.0 9,341.0 18:00 18:30 dog house 1/15/2019 1/15/2019 0.20 PROD1 DRILL DLOG T RIH, tie in for+3.5' correction. 9,341.0 9,389.0 18:30 18:42 1/15/2019 1/15/2019 0.50 PROD1 DRILL TRIP T RIH, window and build clean. 9,389.0 10,983.0 18:42 19:12 1/15/2019 1/15/2019 2.90 PROD1 DRILL DRLG P CT 4638 psi, Q 1.83 bpm in 1.80 bpm 10,984.0 11,209.0 19:12 22:06 out, BHP 3799 psi - 11.8 ppg EMW the window, Delta P 1040 psi, WH 200 psi, IA 946 psi, OA 87 psi. RIH Wt 1.5 k lbs OBD, CT 10.8 k lbs, WOB 1.5 k lbs, ROP 77 ft/hr 11,051' PU Wt 38 lbs 11,090' PU Wt 38 k lbs 11,115' PU Wt 40 k lbs -5x5 sweep 11,185' PU W140 k Ibis 11,193' PU Wt 43k Ibis 1/15/20191115/2019 0.20 PRODi DRILL WPRT P PU, 43k lbs - 500' wiper, pulled early 11,209.0 10,711.0 2206 22:18 #1 only 200' drilled 1/15/2019 1/15/2019 0.20 PROD1 DRILL WPRT P RBIH, RIH Wt 9.5 k lbs 10,711.0 11,9.0 20 22:18 22:30 Page 5/9 Report Printed: 1/21/2019 Uperations Summary (with Timelog Depths) 3H-23 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start DepM start Time End Time our (hr) Phase Op Code Activity Cade Time P -T-% Operation (M(B) End Do" (nKB) 1/15/2019 111512019 0.40 PROD1 DRILL DRLG P CT 4681 psi, @ 1.80 bpm in 1.82 bpm 11,209.0 11,238.0 22:30 22:54 out, BHP 3786 psi - 11.8 ppg EMW Q the window, Delta P 1102 psi, WH 220 psi, IA 953 psi, OA 137 psi. RIH Wt 9.5 k Itis OBD, CT 8 k lbs, WOB 1.3 k lbs, ROP 72 ft/hr 11,233' PU Wt 42 Itis, Having trouble drilling, added ' 2ppb alpine drill beads to high vis pill, pumped 10 bbls 1/15/2019 1/15/2019 0.10 PROM DRILL WPRT P PU WT 42 k lbs, 100' having a hard 11,238.0 11,238.0 22:54 23:00 time drilling, bypass screens, Add - 2 ppb alpine drill beads to high vis pill pit, RBIH 1/15/2019 1/16/2019 1.00 PROM DRILL DRLG P CT 5040 psi, @ 1.90 bpm in 1.90 bpm 11,238.0 11,277.0 23:00 00:00 out, BHP 3807 psi - 11.8 ppg EMW Q the window, Delta P 1207 psi, WH 201 psi, IA 955 psi, OA 146 psi. OBD, CT 4 k lbs, WOB 0.7 k lbs, ROP 60 Whir 11,256' PU Wt 39 k lbs - pumped 10 bbl beaded pill, regained CT wt 5-6 k lbs, and able to drill aheadw 1.3 k WOB, gamma dropped at the same time. Continue to drill ahead, sending - 10 bbl beaded pill every - 100 bbls. 1/16/2019 1/16/2019 4.00 PROD1 DRILL DRLG P CT 4796 psi, @ 1.95 bpm in 1.95 bpm 11,277.0 11,599.0 00:00 04:00 out, BHP 3877 psi - 11.8 ppg EMW the window, Delta P 1049 psi, WH 186 psi, IA 963 psi, OA 182 psi. OBD, CT 2 - (-7) k lbs, WOB 0.2 - 1.3 k lbs, ROP 60 ft/hr Struggling with weight transfer, beads seem to be working some but are short lived. Weight transfer with beads in he 4.5" lose weigh transfer and ROP as soon as beads are out of the 4.5". 1/16/2019 1/16/2019 0.30 PROD1 DRILL WPRT P PU, 41 k lbs, - 800' wiper#2 11,599.0 10,800.0 04:00 04:18 1/16/2019 1/16/2019 0.20 PROD1 DRILL WPRT P RBIH 10,800.0 11,590.0 04:18 04:30 1/16/2019 1/16/2019 0.50 PROM DRILL WPRT T Issue with orientor, amping up turning 11,590.0 11,590.0 04:30 05:00 either direction with no signs of rotating or rotating very slowly. Troubeshoot. 1/16/2019 1/16/2019 2.80 PROM DRILL TRIP T POOH for new tools, open EDC, tag 11,590.0 78.0 05:00 07:48 1 1 1 1 1 1 up, PJSM 1/16/2019 1/16/2019 1.20 PROD1 DRILL PULD T PUD BHA #6, checks failed, close 78.0 0.0 07:48 09:00 EDC, switch to PUD w/ failed checks, bit came out a 1-1 1/16/2019 1/16/2019 1.30 PROD? DRILL PULD T PD BHA#7 (Agitator, 0.5° motor, RB 0.0 78.6- 09:00 10:18 HYC A2 bit), slide in cart, check pack - offs, MU to coil, tag up, set counters Page 619 Report Printed: 1121/2019 Uperations Summary (with Timelog Depths) 3H-23 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Depth Start Time EndTime Dur (hr) Phase Op Code Actively owe Time P-T-X Operation (fiKB) End Depth (ftKB) 1/16/2019 1/16/2019 1.80 PROD1 DRILL TRIP T RIH w/BHA #7 78.0 9,360.0 1018 12:06 Shallow test agitator: depth = 537', 1.9 bpm, circ = 5150 psi, dip = 1250 psi 1/16/2019 1/16/2019 0.10 PRODt DRILL DLOG T Log K1 for-7.5' correction, PUW = 9,360.0 9,395.0 12:06 12:12 35K 1/16/2019 1/16/2019 0.70 PROD1 DRILL TRIP T Continue RIH, RIW = 11K 9,395.0 11,599.0 12:12 12:54 1/16/2019 1/16/2019 1.60 PROD1 DRILL DRLG P Drilling, FS = 1147 psi @ 1.9 bpm, 11,599.0 11,699.0 12:54 14:30 CWT = 7K, WOB = 1.2K, annular = 3837 psi, WHP = 174 psi, circ = 4862 psi, PUW = 40K, struggling w/ weight transfer, pump 10 bbl beaded pill, avg ROP = 63 fph New mud at bit at 11,600' (PowerPro System #2) 1/16/2019 1/1612019 0.20 PROD1 DRILL WPRT P 200'wiper, PUW =41K 11,699.0 11,699.0 14:30 14:42 1/16/2019 1/16/2019 1.60 PROM DRILL DRLG P Drilling, CWT =2K, WOB=.9K, 11,699.0 11,756.0 14:42 16:18 annular = 3854 psi, WHP = 298 psi, circ = 4916 psi, PUW = 45K from 11,723', difficulty getting weight to bit, pump 10 bbl beaded pill, PU's to stay drilling, avg ROP = 37 fph begin building 50 bbl 2%/2% lube pill 1/16/2019 1/16/2019 3.20 PROD? DRILL DRLG P Drilling, CWT =6K, WOB =.8K, 11,756.0 11,938.0 16:18 19:30 annular = 3895 psi, WHP = 288 psi, circ = 4749 psi ROP 57 ft/hr 1/16/2019 1/16/2019 0.30 PROD1 DRILL WPRT P PU Wt37 k bs, Wiper trip#1 -800' 11,938.0 11,107.0 19:30 19:48 1/16/2019 1/1612019 0.30 PROD1 DRILL WPRT P RBIH 11,107.0 11,938.0 19:48 20:06 1/16/2019 1/1612019 2.60 PROD1 DRILL DRLG P CT 5113 psi @ 1.91 bpm in, 1.91 bpm 11,756.0 12,115.0 20:06 22:42 out, BHP 3876 psi - 11.8 ppg EMW @ the window, Delta P 1199 psi Drilling, CWT = -6 to 1 k lbs, WOB = 1.83 k, ROP, WH 283 psi, IA 962 psi, OA 187 psi 1/16/2019 1/17/2019 1.30 PROD? DRILL DRLG P Started rotating the HOT while drilling 12,115.0 12,152.0 22:42 00:00 ahead in experimental drilling for lower dog legs. CT 5113 psi @ 1.91 bpm in, 1.91 bpm out, BHP 3876 psi - 11.8 ppg EMW @ the window, Delta P 1199 psi Drilling, CWT = -6 to 1 k lbs, WOB = 1.83 it, ROP, WH 283 psi, IA 962 psi, OA 187 psi 1/17/2019 1/17/2019 3.40 PROD1 DRILL DRLG P Continue to continuously rotate the 12,152.0 12,340.0 00:00 0324 HOT while drilling ahead in experiment, drilling for lower dog legs. CT 5188 psi @ 1.92 bpm in, 1.90 bpm out, BHP 3876 psi - 11.8 ppg EMW @ the window, Della P 1199 psi. Drilling, CWT = £ to 1 k lbs, WOB = 1.83 k, ROP = 55 ft/hr, WH 283 psi, IA 962 psi, OA 187 psi - 5 surveys with an average dog leg of 2.9° - previously had been averaging 7.5 ° 1/17/2019 1/17/2019 0.20 PRODt DRILL WPRT P PU Wt 39 k lbs on wiper #2 - 800' 12,340.0 11,540.0 03:24 03:36 1 1 I I 1/17/2019 1/17/2019 0.30 PROD1 DRILL WPRT P RBIH 11,540.0 12,340.0 03:36 03:54 1 1 I 1 Page 719 ReportPrinted: 112112019 Uperations Summary (with Timelog Depths) 3H-23 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Stan Depth Stan Tine End Time Dur (hr) Phase Op Code Activity Cade mme P -T -X Operation (WB) End Depth (tH(B) 1/17/2019 1/17/2019 1.10 PRODI DRILL DRLG P Continue to continuously rotate the 12,340.0 12,401.0 03:54 05:00 HOT- Bleed IA from 770 to 845 psi CT 5188 psi @ 1.92 bpm in, 1.92 bpm out, BHP 3975 psi - 11.9 ppg EMW the window, Delta P 1230 psi Drilling, CWT = 10 k lbs, WOB = 0.9 k, ROP100 fUhr, WH 155 psi, IA 845 psi, OA255 psi 1/17/2019 1/17/2019 2.40 PROD1 DRILL DRLG P Drilling, consistant drop in inclination 12,401.0 12,462.0 05:00 07:24 while oscillatiing HOT, confer w/ town, decision made to point up to 90° & resume HOT oscillation test, continue pumping 2 ppb beaded pills TO called at 12,462' 1/17/2019 1/17/2019 1.30 PROD1 DRILL CIRC P PU off bottom, pump away beads, 12,462.0 12,462.0 07:24 08:42 build HMS pill, pump 1 0x1 0 TO sweeps, PUW = 35K 1/17/2019 1/17/2019 3.70 PROD1 DRILL WPRT P Wiper to swab valve, jog 4.5" 12,462.0 78.0 08:42 12:24 1/17/2019 1/17/2019 1.80 PROD1 DRILL WPRT P RBIH 78.0 9,350.0 12:24 14:12 1/17/2019 1/17/2019 0.10 PROD1 DRILL DLOG P Log K1 for -7' correction 9,350.0 9,389.0 14:12 14:18 1/17/2019 1/17/2019 0.10 PROM DRILL TRIP P Continue RIH 9,389.0 9,540.0 14:18 14:24 1/17/2019 1/17/2019 0.20 PROM DRILL DLOG P Confirm 11.9 ppg kills well (allow to 9,540.0 9,540.0 14:24 14:36 drop to 11.7 ppg), shutdown pumps, close choke MD = 9539', TVD sensor = 5947', annular= 3613 psi, EMW = 11.7 ppg `Reboot Orion 1/17/2019 1/17/2019 1.10 PROD1 DRILL TRIP P Continue RIH, clean through window, 9,540.0 12,466.0 14:36 15:42 stack CWT at 12,421', PUW = 37K, confirm TO @ 12,466', PUW = 39K 1/17/2019 1/17/2019 3.00 PROD1 DRILL DISP P Lay LRP & KWF to surface, pulled 12,466.0 78.0 15:42 18:42 heavy at 12,410', up to 49K CWT & - 4.6K WOB, POOH paintig flags, yellow 9548.26' and white, 6578.30' 1/17/2019 1/17/2019 1.30 PROD1 DRILL PULD P At surface, flow ceck good, losses - 3 78.0 0.0 18:42 20:00 bbl/hr. Unslab injector, check pipe, -0.212" wall thickness with wear and flat spot back 12-15' measured 0.05" question results because of wear pattern on pipe. PUD & LD BHA#7 1/17/2019 1/17/2019 0.40 COMPZN CASING BOPE P Perform BOP functon test. 0.0 0.0 20:00 20:24 1/17/2019 1/17/2019 0.60 COMPZI CASING PUTS P Prep floor for running liner. PJSM, 0.0 0.0 20:24 21:00 1/17/2019 1/18/2019 3.00 COMPZI CASING PUTS P PU ALI completion, 89 joints 2-3/8" 0.0 0.0 21:00 00:00 STL slotted liner, 1/18/2019 1/18/2019 1.20 COMPZI CASING PUTB P Continue to PU ALI completion, 89 0.0 2,946.5 00:00 01:12 joints 2-3/8" STL slotted liner, 1/18/2019 1/18/2019 0.20 COMPZI CASING PUTB P Clean floor post making up liner. 2,946.5 2,946.5 01:12 01:24 1/18/2019 1/18/2019 0.70 COMPZI CASING PULD P PU BHA#8, ALI linner running 2,946.5 2,994.9 01:24 0206 assembly, check pack oft, good. Swap out Baker floats, stab injector, bump up set counters. Page 819 ReportPrinted: 1121/2019 Uperations Summary (with Timelog Depths) 3H-23 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Stan Depth Stan Time End Tame Our (hr) Phase Op Code FcOvity Code Time P -T -X Opereeon (flKB) End Depth(tlKB) 1/18/2019 1/18/2019 1.30 COMPZ1 CASING RUNL P RlH with AL1 liner 2,994.9 9,492.0 02:06 03:24 12466' PU Wt 35 k lbs, tie into window flag for -9.8' correction 1/18/2019 1/18/2019 2.80 COMPZ1 CASING RUNL P Continue to RIH 9,492.0 12,217.0 03:24 06:12 10821' S/D - PU Wt 39 k lbs 11,092' SID - PU Wt 39 k lbs 11434' PU 55 k lbs -10 k WOB 11637' PU 54 k lbs --14 k WOB Multiple times at 11928' 1/18/2019 1/18/2019 0.80 COMPZ1 CASING RUNL P Crew change, continue working liner 12,217.0 12,466.0 06:12 07:00 to bottom, begin pumpng down back- side, arrive on bottom, bring up pumps, release off liner, PUW = 37K, BOL = 12,466', TOL = 9518.6' 1/18/2019 1/1812019 0.50 COMPZ1 CASING DLOG P Obtain SBHP (depth change after 12,466.0 9,493.0 07:00 07:30 dropping off liner to EDP) Depth = 9493, TVD -sensor = 5941.9', annular = 3602 psi, EMW = 11.66 ppg (-25 min test) 1/18/2019 1118/2019 2.40 COMPZt CASING DISP P Open EDC, displace well to seawater 9,493.0 2,500.0 07:30 09:54 1/18/2019 1/18/2019 1.50 COMPZ1 CASING FRZP P PJSM, diesel freeze protect well from 2,500.0 42.0 09:54 11:24 2500' to surface, tag up, PJSM 1/18/2019 1/18/2019 1.10 COMPZ1 CASING PULD P PUD BHA #8, 1016 psi below master 42.0 0.0 11:24 12:30 1/18/2019 1/18/2019 0.70 DEMOB WHDBOP CIRC P MU nozzle, jet stack, break -off nozzle, 0.0 0.0 12:30 13:12 clear floor 1/18/2019 1/18/2019 0.30 DEMOB WHDBOP CTOP P Pull checks 0.0 0.0 13:12 13:30 1/18/2019 1/18/2019 2.30 DEMOB WHDBOP CTOP P Wrap & epoy a -line, stab on, pump 0.0 0.0 13:30 15:48 slack back (3 cycles, up to 5600 psi), break off injector MU hydraulic cutter, cut 119' pipe total, RD cutter 1/18/2019 1/18/2019 2.70 DEMOB WHDBOP CTOP P File & ream pipe, install CTC, pull test 0.0 0.0 15:48 18:30 to 35K, install UQC, re -head a -line 1/18/2019 1/18/2019 3.00 DEMOB WHDBOP CTOP P Pull and replae upper blind shear 0.0 0.0 16:30 21:30 rams - note, did not pressure test, pits de -inventoried. 1/18/2019 1/19/2019 2.50 DEMOB WHDBOP CTOP P Work rig down check list, DTH called 0.0 0.0 21:30 00:00 to RID hard line and remove TT. Handed control of both adjacent producers back to Pad Operator Jeanine, nipple down and secured BOP stack •` rig release at midnight - Page 919 ReportPrinted: 1121/2019 ConocoPhillips _ConocoPhillips (Alaska) Inc. -Kup2 Kuparuk River Unit Kuparuk 3H Pad 3H-23AL7 50-103-20204-60 Baker Hughes INTEQ Definitive Survey Report 12 February, 2019 BA (ER 410 UGHES 'i .CE Conocollhillips 6 cmoil:OpI maps Definitive Survey Report Co.,., ConocePhllllps(Alaska) Inc. -Kup2 Local Co-ordtaam Reference: 0411311-23 Project: Kupamk River Unit NO Reference: 3H23A:@70.10usft(311-23At) site: Kuparuk 3H Pad MO Reference: 3H23A: @ 20.10usfl(3H-23A:) Well: 31-23 North Reference: Thus Wellbore: 31-2301.1 Survey Calculation Method: Minimum Curvatura Design: 3H-23AL1 Dahbase: EDT 14 Alaska Production Prefect Kuparuk River Ung, Nash Slope Alaska, United States Map System: US State Plane 1927 (Exact sclmion) Syakem Datum: Mean Sea Level Geo Damm: NAD 1927 (NADCON CONUS) Using 0411 Reference Point Map Zone: Alaska Zone 04 Using geodetic scale hoer Well 3H-23 Well Posmen ♦W4 0.00 Lafi Nosing: 5,000.63]]9us6 Latgutle: 70°24'M.715N .Em 0.00 Left Swede, 498,65528usfl Longitutle: 150.0'39A24W Peahen Uncenaimy 0.00 usil Wellhead Salvador: uag Ground Level: 0.00 ash WeI1bMe 3W23AL1 Magnetim Modal Name Sample Data Declination Dip Angle Field Sbenglh PI N (nT) BGGM2D18 2112019 16.69 WAG 57,426 Design 311-23ALI Audit Notes: Version: 1.0 Phase: ACTUAL no On Depth: 9,53723 Vertical Section: Depth Front (WD) NjB +Eim Direction (usft) ILsftl (uml (9 70.10 0.00 0.00 135.00 Survey Pmgmm Date F.. To BLlvey Serve, (usX) (uard Survey(Wellbom) Tool Name Description Stan Data End DMB 76.50 7,620.60 3W23(31423) GCT-MS Schlumberger GCT mullishol 111212001 7,640.00 9,53723 3H-23AATDB(311-23A) GCT-MS Schlumberger GCT mullishol 911812001 9,558.00 9,621.66 3H-23ALi MWTi(3H-23ALi) MAD-INC-ONLY MWDJNG ONLY FILLER 1117@019 111712019 9,65113 12,426.00 311-23AL1 MM(311-23AL1) MAD MWD-Standard 1110@019 111812019 2/121201912, 11 OW Page 2 COMPASS 5000.14 Sued so Survey MO ConocoPhillips Atl ConocoPhillips Definitive Survey Report •N-N145.0m.0mMap Company: ConoccPhilips(Alaska) Inc.-Kup2 Local Ooandinate Reactance: MR 344-23 Pmlece Kupamk Rhos Unit TVD Reactance: 3H-23A:@70.10usR(31-1-23A:I She: Kupanuk 3H Pad MO Renitence: 3H-2M:®70.10.0(344-23X) Well: 344-23 North Reference: hue Wellhone 3H-23AL1 Survey Calculation Method; Minimum Curv91u1e Devito 3H-23AL1 Dalahase: EDT 14 Alaska Production Survey MO Inc Atl TVD miss •N-N145.0m.0mMap Map OLS Venical Northing Easting SectionBurve Tool Nonni v (..ft) (°I (°I (al(ien) (usn) (usR) IRI IRI 1°I+09•I In) 953 ]23 6441 34&W 5,967.06 58.70. 5,28742 4,12709 6.005,92542 49452955 1.80 .657. MWWNC_ONLY(3) 9.558 On .4.38 344.59 5,BM12 5,90602 5,305S2 A131.80 6,00594352 494524.75 4.65 1,6734 MND -INC CNLY(3) 9.52" 72.00 34345 5908.75 5,91&65 5,335.93 4,140.61 60.'5,9739.7 4945+604 22.83 E,700,93 VWYNNC ONLY(3) 9,62195 8242 343.55 5,995.27 5,9L.17 5363.47 4,,149.04 6,006,001.47 49450761 35,06 -a.m 8 MW INC ONLY(3) 8.351.43 9255 34168 5.98657 592647 5,391]4 4,150.16 8,0[8,029,74 49448051 34.15 5.752.80 MM (4) 9.135 94.40 35308 5'nu.8 5,924.62 5.42132 4.16V9 8,006059.31 494,491.88 3TW 417840 VIVID (4) 9711.93 9554 291 5,992.11 592201 5,45133 4.16587 6006039.21 4PI.490.01 3251 4,806.31 MW➢(4) 9741.93 94.36 1288 595.51 5.919,41 5,4W..79 -416177 60W,11L78 494.494.92 3400 5818.32 MhEi(4) 9,"3.47 91.93 2448 5,967.78 5.917.69 5.510.56 415167 6.006.148.5 494,55.02 37,23 6.63233 MAM (4) 9,5378 90.18 34.35 590733 5.917.13 5.535.93 4,13580 6.001 494,519.5 3300 6,040:5 MND(4) S.N5.35 09.23 44]2 5.907.40 591730 5.562.00 411&10 6,00G.2W,06 484,5495+ an ..34357 MND(4) 987053 07.76 53.56 5,98630 5,9162O 5,58300 4.089,09 6.036.221.77 494566.5 W'05 E.840.3J "D (4) 990618 3671 5.50 5,98923 5,91913 5,597.64 40..22 6 00 494,593.48 40.01 6.51.5 MND(4) 9.927.6 BT51 77.6 5,990.12 5,92002 5,60,46 4.037.62 6606,243.42 494,61906 33.40 6.810i5 MWD (4) 9,9558 9136 87.M 5.85.2 592032 5,65,06 4,009.63 600634701 4.Al 3925 E, 801.44 MNO(4) 9,98494 9157 9134 5.9BLm 5,819,5 5,80.28 4,980.43 0."34732 494.678.26 11.48 6780.94 MWD(4) 10014.71 90,52 95.35 5.95.16 6.919." 6,607.31 -3.950.74 6,0015.24525 494.705,95 17,52 6.753.% MMI) (4) mmm 5.06 965 5,95.28 5.919.18 5,603.20 -3,91961 6005,241.13 4KTI7.07 8.80 E, 73364 MAT) (4) 10.076.16 07.48 10079 5,990.19 5,947.9 5,58842 -3,89191 6,0".2%06 4. 7W.67 8]2 E70912 Men) (4) 10.10527 li 103.98 5,99229 5,922.19 5,59189 .7,861.66 6,"8.22902 40479501 155 6.68467 MND (4) 10.135.14 84.43 10192 5,90.24 592114 5584.73 6,83281 6,00622265 4.8.2. 067 6659.21 MND (4) 1.'185.. 86.53 1029 5,997,. 5,82756 5,57782 6480299 6,0".215.73 494o53E8 369 610323 Mee) (4) 10,19452 8&37 %.87 5.998193 592903 5,572.32 3774.80 B.",210.23 494881.70 10." E,60947 Must) (4) 102477 Win) W97 6.00D.2 5.93032 5,567.35 3745.00 8,00625.26 494.911.57 &5 £,584.88 MWD(4) 10,25487 ".% 101.59 6,002.37 5,93237 5,561,99 -3,715.53 6,006+99a9 49494112 0.80 8,580.20 MWD(4) 10,265.01 88,89 10212 6,003.57 5.933.47 5.5S58O 3,686.06 once 19370 499.97059 7,93 8,53498 MAID (4) 10,314,82 91.51 102." 6,0.3.96 5,933.36 5.549,57 -3,&5691 6,006.187.7 494,990.73 33n 6,509.97 MAD (4) 10315." 94.24 101.26 6001.95 5931&5 5,543.40 -3,627.30 6.006.10137 495028.34 934 $48472 MD (4) 1037567 97.42 101.75 5,am," 592874 5,53741 3,597,50 6.036,175.5 495.05.14 10.52 5.450.35 MAID (4) 10.0511 06.60 103.86 599523 5,925.13 5,530.94 J,5EB.01 6.06,16602 495,087.0 7.54 6,43463 MWD(4) Annotation TIP KOP InteryolatedA inuib Inaclpola(ed Azimuth 2H2201912'11:59PM Pape 3 COMPASS 500014 Sol 85D `. Cono4hillips ConocoPhillips Definitive survey Report Company: ConaccPhilips (Alaska) Ina-Kup2 Local Ceardhate Reference: Well 31-23 Project Kuperuk River that TVC Reference: 3H -23A:@ 7040ush(31143A:) She: Kupamk 3H Pad MD Reference: 3H-23A:®70.10ush(3H-23A:) Well: 311-23 North Reference: True Wellbore: 31143AL1 Survey Calculation Method: Minimum Curvature OesiBn'. 3H-23AL1 Database: EDT 14 Alaska Prohuctien Annotation 2/ 12i20191211:59Pod Patio COMPASS:AW 14 BuM 850 Map Map MO Inc Atl TVO TVOSS 414/6 aE1,W 01.8;Vertical Fasting Seollon Survey Tool Name (usal (1) 19 (-am Wheat (.ant 4-111)NO (ft111 ) (h) MOD.) R) 1043561 9420 105 89 599231 5,922.11 5,52314 1.53667 6oW,tfi1@ 495,11696 10.29 6400,39 M.ND (4) 1046545 9354 1823 5990.30 5.925,20 5,51435 3511.58 6,006,15212 495,14505 11.56 4t38232 NOV (4) 10.495.61 91.57 111. 5.96094 5.918,84 5,50363 -3483.00 6,006441.50 495173.56 1021 6,35455 MID (4) 10.525.91 9034 11419 5.989,44 5,818.34 5,49169 -3.455.23 6,00412955 495201.39 11,16 6326.42 MWD (4) 10,55524 9138 118.05 598,00 5917.90 547&64 -3.42897 6005,116.50 49522L64 1170 6,D&63 MWD(4) 10,585.. 9221 1208 5,90]05 5916,95 5,48.01 -3,402.8 608,10167 05,253.91 940 -6,269.55 MWD(4) 10,515.16 91,57 123.8 5,98&07 5915.97 5,44&04 -3,37751 60Wp05 DO 495.279.8 074 -624061 ~(4) 1064533 098 12543 59658 5,915.58 5,430.79 -3,35220 60W,M'064 495.3W31 660 b.210,57 MWD(4) 1067498 87.68 inaii 5.8830 6916.20 5414.15 4,32634 6.05,05199 495,32835 904 64018 MOD (4) 10,705.57 8.43 121.45 5.96707 5917,77 5397,64 430253 6000,03549 495,35405 9.14 6,151.95 MNP (4) 10 73635 868 12416 598967 5,919.57 5.381.00 4276.71 6006.018,84 49699.87 &8 6,121.@ MOD (4) 10,78.8 8.8 IM12 5991.40 5.92130 535301 4,252.06 &06,003,65 495400,49 1266 6.091.79 MWD(4) 10,79&% 8,27 131.27 5,993.11 5,92101 5,343.85 4,2298 60.15,901 69 495427.57 10,47 6,051.92 MWD (4) 1065.65 Se. 134.02 5.99463 592473 532377 -3,207.18 6,00ti,961,60 495449.37 926 -6.03230 MWD (4) 10.88.8 0742 13799 5,996,46 5,9530 5,30144 -3,185.00 6,005,938,97 495471.5 9.88 6,03061 MWD(4) 10.82.76 0928 13&95 5,997.46 6,92736 5,275.8 -3462.02 6,85,913.43 49549452 7.67 58630 MWO(4) 10,91729 9117 141.22 5.99]30 5.927.26 525&79 31a8.5 6,005.094.62 495.510.5 12.02 6,941.07 MhD (4) 8.94635 91.14 14249 588.78 5826.60 523184 3,128,34 6,005.67177 495.528,211 4.37 6,913.8 MVW)(4) 10.97233 9012 1438 5,9%. 5,9539 521314 3112.77 68505097 495.543.76 667 560731 MND (4] 11,00267 6083 14555 5,996P 5,95.67 5,1838 4,09525 6,905.8521 495,56127 693 58741 MMM (4) 11,8182 8662 14383 5.89792 5,927.82 5.164.76 3,07&58 6.08.8259 45.571.8 9.46 582&8 M (4) 11,00209 8.8 1418 5,99915 5,923.65 5,140.53 4,08.17 6,0'5.77836 495,5834 735 -!5 798.77 MD (4) 11X93.01 88.00 138.90 6.00123 5,93113 5,116.77 4,04044 6,0.15.75460 495616.06 1024 6160.02 MD 111235 88.1 13633 600230 593210 5,085.12 1.04060 6,001 455.63602 019 5738,73 MD (4) 11,15147 06.56 133.61 6.0302 5,93292 5,074.51 4,0812 6,LCg71233 4956837 0.73 -6,7098 MD (4) 11182.24 8.17 13234 6.0363 59339 50M,W -2,97765 6",out. 49567864 5.17 -5.670.8 "D (4) 11,211,75 005 10037 6,.70 6.933 Go 5.03324 -2,95.5 6,005671,05 49518.5 719 b.64939 MIND (4) 1'.242.03 8905 15.98 6$ 96 5.911,06 5,01117 -2.934.85 6,DOS 649.50 495,721.62 6.65 6,61911 MAD (4) 11271% 91.01 137.57 6,00174 5,933.64 498.97 -2,914.37 600562770 495.74210 1063 656921 MAD (4) 11302.5 9267 140.15 6X029 5,93245 449678 389436 6,005.604.91 495.7628 a. 5,55690 MWD(4) 113.15 9369 142.04 6.0608 5,930.80 4.9081 -2,075.86 6395.581.62 495,7818 9.64 562934 MAO(4) Annotation 2/ 12i20191211:59Pod Patio COMPASS:AW 14 BuM 850 `. �oc3Pon h1111ps ConocoPhillips Definitive Survey Report Company. ConocaPhillip5(Alaska) Inc -Kup2 Local Co-ordinate Wave... Wall 31133 Pni Kupamk River Unit ND Rehrenee: 3H43A: ® 70.1Dusn (3H -23A:) Site Kupamk 311 Pad MD Resonance: 31143A: @ 70.10usn (3H -23A:) Well: 3W23 Mahn RMerence: True Wellbore. 3H-23AL1 Survey Calculation Method: Minimum Cumnum Design: 3H-23AL1 Database: EDT 14 Alaska Pmdonon Survey Annotation N12201)12'if 59"M Pa0e 5 COMPASS 500014 Build 851) Map Map Willett MD Inc past ND NDSB SWS vE1-W Northing fasting DLS Beckon Survey Tool Ka. (ush) P) (1) (Maul Iw1q luap )inns Ins °1100' ( ) Ins 11.36230 9'e.91 145.73 5,989.00 5,929.10 4,919.37 -205039 6.005557 18 995]99.16 1009 5999.64 260(.141 11,382]9 90.52 147,01 599661 5920.51 490232 -2.114695 6,005,540.13 495809.0( 12.63 5479.55 MW9(4) 11,411.99 90.89 149.83 5,99825 5,920.15 4.0]].45 -2.03166 6.00551526 495824.]0 974 5,451]6 MWD(4) 11,441.% 89.97 151.78 5,988.2 5,927.92 4851,30 4.81705 6005,4119.11 4950.4.39 7,20 5.422.34 MWD (4) 11 ARW 9178 153.82 5.997.55 5,927,46 4,02398 'An301 6,005.46198 495.053.42 000 5.393.10 MWD(4) 11,501.41 9320 155.02 5.996.31 5.M,21 4]9]98 -2,790.84 6,0(5,435]9 495.865.59 910 5366.10 MW➢(4) 11,531,03 93.04 159.15 5.994.44 5,924.34 4,89.91 -2,779.26 6.005,40(.91 495.821.16 1048 5.338.07 MAID (4) 11,553.49 9338 163.H 5.992.44 5,91234 4,739.99 -2,769.13 60(5.317.30 495,887.28 13.0( 5,309]5 MWD(4) 11,587.34 9237 164.73 6..126 5,92115 4717.00 -2761.60 600(.354.0( 495,093.81 6.85 5,280.94 MAD (4) 1161685 91.51 166.59 5,99025 5,91!1.15 4.8851 -2755.30 6.056,326.33 495,901.10 694 5,2639 MD (4) 11,64030 90.64 169,14 5,98965 5919.55 4,657.77 $748.69 6.005.28559 405.90771 8.53 5237.16 MWD (4) 11.677.10 0985 16.54 5,98951 5919.41 4462957 -274287 6.005267.39 495.913.52 IS. 4,21310 MWD(4) 11 fiBG.9B 90.43 16591 5,98647 5,91937 4,610.22 -2]38,30 6.005248.04 495.918.08 0]0 SIN19 MWD(4) 112126.96 91 ?h 16300 588609 5,910.30 4.501.35 -2,73037 6,005219.17 495.9M.11 low 5.17909 1011 11]5746 82]0 16120 5907.8 5917.62 4,552.62 -2.721.02 6,005.190.45 495935.36 650 4,143.24 MWD(4) 11.707.16 94.15 160.15 5,985.93 5,915.03 4,526.34 571112 6,005,162.17 495.945.25 6.2 4.116.24 MWD(4) 11,01].2] 9181 160.61 5.984.36 5,914.26 4496.04 -2701.03 6,0(5,13366 49595541 793 5.0(9.10 MWD(4) 11,847.14 9040 160.65 4983.79 5.913.69 4,967.87 -2,691.12 6,0(5,12619 495,965.23 4.72 5,062.17 MAD (4) 11,87249 asm 159.40 5.9B390 5913.08 4.439.34 -2,680.8 6,005,07.17 495.97559 6.54 4,0(4.6] MAD (4) 11,904.11 0779 156.. 5,964.8 5,914.66 4,41464 -2,670.87 8.045,05247 495,98547 9.90 5.01022 MAD (4) 11,932.08 8905 15697 5,905.53 5,91543 4,381 -2659.93 n0oai, fib 496.996.44 4.57 4,904.27 MAD(4) 11,966.42 8745 154.03 5,98(k58 5,91640 4,35].72 -2645.61 6,004,995.55 496,01072 9.24 4,952.10 MAD (4) 11,.7.33 87.4 150.05 5,98].95 5,917.85 4,33045 -2463114 6,00486828 496.25.19 1286 492259 MAD(4) 1202221 Mau 147.01 5,986.&1 5,91974 4,309.16 -2610.30 6004,945.99 4..038.01 an 4,BB0A5 MWD (4) 12,66221 .71 14753 5,959.58 591940 4,203.02 -28.237 6.004921.64 496,0X.05 1.30 Ama'9 MWD(.) 12.0(5.08 89.2 149.79 5,9..0( 5,9'850 4,255.75 -2.505.17 6.004.09350 496071.13 266 4,83T.26 WD (4) 12116.62 88.59 151.44 5990.44 5,92034 4228.27 -2569]0 Som'su.tn 496.6+.0( 652 4B]fi.e9 MA0(4) 12.14711 07.82 153.32 5991.40 5,921.30 4,201.27 -2555.57 60D4,831K10 493,1N.R 666 477781 MAD (4) 1217565 0748 152.40 5.992.61 5991.51 4.174.99 -2.542.13 6,004.81282 496,114.16 307 4749.8 MWD(4) 12.20700 116.93 152.36 5.994.09 5,923.99 4146.10 -2520.08 6004.765.93 498.12626 1.85 47M9] MWD(4) 12247.94 0590 151 W 5.9261]2 5925.62 411200 -2509.01 6.0(4.89.03 496,14726 3.16 4,501,76 MAI)(4) Annotation N12201)12'if 59"M Pa0e 5 COMPASS 500014 Build 851) ConocoPhillips , O cOOOCOPI'I1ll1PS Definitive Survey Report C..,.,. Cen0coPhJOPs(ANsm)1re. -KuP2 Project Ku,nuk River Unit She: Ku,.k 3H Paid Well: 311-23 Wellhom: 311-23AL1 Deei,e: 3H-23AL1 survey local CoarJllbb Rahbnp: TVD R.N...: MD Reference: N nh Reference: Survey Calculation Method Dabhase: Vaal 3H.23 3H -23A: ® 70.10uatt (3H -23A:) 31133A. ® 7040u0t (311-23A:) True Minimum Curvature EDT 14 Alaska PmEuc08n Annotation 2/ 12201912.11: 59PM Pape 6 COMAISS 5000.14 Bu0tl BSD Map Wildcat MD Inc M TVD TVDSS .NIS eEfm NOMRIn9 EaWN, OLE S cakah Teal Nama IuaN Pl 17 lusnl lusnl (uzrc) loop 1°na9•) Survey Int Ihl Ip 72276.99 hA5 150.98 5,999.06 5,928.96 4,086.56 -2.495.18 6,00472439 496,161.08 404 -0,&5399 MWn(4) 12.305,89 04.06 15035 6,00165 5,931.56 4.06107 -248106 6,00169930 496,175.10 256 -0,626.20 MWD(4) 12,33629 .55 1WG7 6.004]6 5.93460 4.035 ,)2 3.46606 6 a 6n OS 496.190.20 &M 4.597.10 MWD(4) 12.35&46 0305 15059 6,008.30 5,93030 4010.19 -3,45123 6,004.647,02 491 2.38 4.588.20 MJv➢(4) 12,386.76 03.57 15227 6,011.03 5,941,23 3,892]6 -2,436.83 6,004,620.59 498.21941 5.77 4,539.M MJVD(4) 72426.80 84.M 15206 6.014.82 5,949.72 3,956.20 4,423,02 6,00459409 49&23322 4.07 4.510.83 MND(4) 1248&00 8499 15206 6.018,25 5,948.15 3.921,57 3,405.08 6..55940 456.251.14 .00 4,473.62 PROJECTED W TO Annotation 2/ 12201912.11: 59PM Pape 6 COMAISS 5000.14 Bu0tl BSD BA ER %' PRINT DISTRIBUTION LIST F UGHES a GE company COMPANY ConocoPbillips Alaska, Inc. WELL NAME 3H-23AL1 FIELD Greater Kuparuk Area COUNTY North Slope Borough BHI DISTRICT Alaska AUTHORIZED BY Patrick Rider EMAIL Patrick. RideraC)bakerhughes. corn STATUS Final Replacement: COMPANY ADDRESS (FEDEX WILL WT DELIVER TO P.O. BOX) PERSON ATTENTION V t BP North Slope. LOA, PROC. PRB-20 (Office 109) D&G WO Wells Admin Brenda Glassmaker & Peggy O'Neill 900 E. Reason Blvd. Anchorage, Alaska 99.508 2 ConocoPhillips Alaska Inc. Atm: Ricky Elgarico ATO 708 1700 G Street 3 [isxonsdobil, Alaska Ann: Lynda M. Vaskell and/or Leonardo Elias 3201 C Street, Suite 505 Anchorage, AK 99503 4.State of Alaska - AOGCC Attn: Natural Resources Technician 11 333 W. 7th Ave, Suite 100 .Anchorage, Alaska 99501 5 DNR - Division ofOil & Gas *** Attn: Resource Evaluation 550 West 7th Avenue, Suite 1100 Anchorage, Alaska 99501 *** Stamp "confidential" on all material deliver to DNR 6 BP Exploration (Alaska) Inc. Petrotechnical Data Center, LR2-1 900 E Benson Blvd. Anchorage, Alaska 99508 218175 30366 ie 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 January 17, 2019 TODAYS DATE February 15, 2019 Revision Details: Rev. Requested by: --- FIELD / - FIELDI FINAL CD/DVD FINAL PRELIM (las, chis, PDF, META, SURVEY REPORT LOGS LOGS CGM, Final Surveys) (Compass) # OF PRINTSgur rKIN # OF COPIES IN OF COPIES # OF COPIES !II 1 0 1 0 1 0 1 0 1 0 1 RECovED 0 1 1 0 0 0 TOTALS FOR THIS PAGE: 0 1 2 0 0 n THE STATE °fALASKA GOVERNOR MIKE DUNLEAVY James Ohlinger Staff CTD Engineer ConocoPhillips Alaska, Inc. PO Box 100360 Anchorage, AK 99510-0360 Alaska Oil and Gas Conservation Commission Re: Kuparuk River Field, Kuparuk River Oil Pool, KRU 3H-23AL1 ConocoPhillips Alaska, Inc. Permit to Drill Number: 218-175 Surface Location: 1019' FNL, 281' FWL, SEC. 12, T12N, R8E, UM Bottomhole Location: 682' FNL, 1361' FEL, SEC. 02, T12N, R8E, UM Dear Mr. Ohlinger: 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 v .aogcc.alaska.gov Enclosed is the approved application for the permit to redrill the above referenced development well. The permit is for a new wellbore segment of existing well Permit No. 196-186, API No. 50-103-20204- 01-00. Production should continue to be reported as a function of the original API number stated above. Per Statute AS 31.05.030(d)(2)(B) and Regulation 20 AAC 25.071, composite curves for well logs run must be submitted to the AOGCC within 90 days after completion, suspension or abandonment of this well. This permit to drill does not exempt you from obtaining additional permits or an approval required by law from other governmental agencies and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the AOGCC reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the AOGCC specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or an AOGCC order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. Sincerely, Hollis S. French Chair DATED this 3 day of January, 2019. 5 s w1' i;xV i 14 : -. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 AAC 25.005 1a. Type of Work: 1 1 b. Proposed Well Class: Exploratory - Gas Service - WAG Service - Disp ❑ 1c. Specify if well is proposed for: Drill ❑ Lateral ❑� Stratigmphic Test ❑ Development -Oil ❑� Service- Winj ❑ Single Zone [D Coalbed Gas ❑ Gas Hydrates ❑ Redrill ❑ Reentry0l Exploratory - Oil ❑ Development - Gas ❑ Service - Supply ❑ Multiple Zone ❑ Geothermal ❑ Shale Gas ❑ 2. Operator Name: 5. Bond: Blanket ❑' Single Well ❑ 11. Well Name and Number: ConocoPhillips Alaska, Inc. Bond No. 5952180 ' KRU 3H-23AL1 3. Address: 6. Proposed Depth: TVD 1 6006, 12. Field/Pool(s): P.O. Box 100360 Anchorage, AK 99510-0360 MD: 12600' TVDW. 5936' Kuparuk River Field / Kuparuk River Oil Pool 4a. Location of Well (Governmental Section): Surface: 1019' FNL, 281' FWL, Sec 12, T12N, R8E, UM 7. Property Designation:pp. Is. ADL 25531 Top of Productive Horizon: 8. DNR Approval Number: 13. Approximate Spud Date: 968' FNL, 1450' FWL, Sec 02, T12N, R8E, UM LONS 83-134 1/10/2018 9. Acres in Property: 14. Distance to Nearest Property: Total Depth: 682' FNL, 1361' FEL, Sec 02, T12N, R8E, UM 2560 9375' - 4b. Location of Well (State Base Plane Coorc inates - NADA): vlan Surface: x- 498655 y- 69@GW &000 ® Zone- 4 10. KB Elevation above MSL (ft): 70' GL / BF Elevation above MSL (ft): 38' 15. Distance to Nearest Well Open to Same Pool: 1163',3H -19A 16. Deviated wells: Kickoff depth: 9565 feet 17. Maximum Potential Pressures in psig (see 20 AAC 25.035) Maximum Hole Angle: 93 degrees Downhole: 4897 Surface: 4304 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 2850' 9560' 5907' 12600' 5936' 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): 9875' 6114' N/A 9875' 6114' N/A Casing Length Size Cement Volume MD TVD Conductor/Structural 79' 16" 200 sx AS II 121' 121' Surface 4175' 9-5/8" 900 sx ASIII, 600 sx G 4216' 3181' Production 9305' 7" 250 sx G 9341' 5882' Liner 2400' 4-1/2" 300 sx G 9875' 6114' Perforation Depth MD (ft): 95501- 9600' Perforation Depth TVD (ft): 5973'- 5994' Hydraulic Fracture planned? Yes F-1 No❑ 20. Attachments: Property Plat ❑ DivertOP Sketch er Sketch Program B DSeabed Report Time v. Depth ram e Drilling ng Fluid Proging e 20 AAC 25.050 requi emlot Shallow Hazard lentse 21. Verbal Approval: Commission Representative: Dale 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 McLaughlin Authorized Name: James Ohlinger Contact Email: ryan. mclau hlin co .Com Authorized Title: Staff CTD Engineer Contact Phone: 907-265-6218 Authorized Signature: Date: !!9 ��r �g Commission Use Only Permit to Drill API Number:Permit Approval See cover letter for other Number: '0\43 —:7 50- 103-�0—J.O+- O -O Date: f I 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: 00P 1,-5 - 1. -f &9&0 $-T Samples req'd: Yes F] No 2" Mud log req'd: Yes [] No� r �— �a HzS measures: Yes Evr No Ly Directional svy req'd: Yes No❑ ffnnt lar Pf-tet/<v/ t r s / ry Spacing exception req'd: Yes ❑ No[? Inclination -only svy req'd: Yes ❑ No,L�D/ Post initial injection MIT req'd: Yes ElNo LI APPROVED BY Approved by: COMMISSIONER THE COMMISSION Date: r� 10-401 Revised 5/2017 �%� //Z % 9 Submit Form and T'kfS mi is validf n h e a roval per 20 AAC 25.005(g) * Attachments in Duplicate ConocoPhillips Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 December 26, 2018 Commissioner - State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Dear Commissioner: ConocoPhillips Alaska, Inc. hereby submits applications for permits to drill one lateral out of the KRU 3H -23A (PTD# 196-186) using the coiled tubing drilling rig, Nabors CDR3-AC. CTD operations are scheduled to begin on January 10, 2018. The objective will be to drill one lateral, KRU 3H- 23AL1 targeting the Kuparuk A -sand interval. To account for geological uncertainties, ConocoPhillips requestvariance from the requirements of 20 AAC 25.015 to allow the actual kick-off point to be anywhere along t length of the parent lateral instead of • being limited to 500' from the original point. Attached to this application are the following documents: �vk b OA- f-- Permit to Drill Application Forms (10-401) for 3H-23AL1 �e - Detailed Summary of Operations - Directional Plans for 3H-23AL1 - Current wellbore schematic - Proposed CTD schematic If you have any questions or require additional information, please contact me at 907-265-6218. �,2 I Sincerely, Ryan McLaughlin Coiled Tubing Drilling Engineer ConocoPhillips Alaska Kuparuk CTD Lateral 3H-23AL1 Application for Permit to Drill Document 1. Well Name and Classification........................................................................................................ 2 (Requirements of 20 AA C 25.005(f) and 20 AA C 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)(5))..................................................................................................................................................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 AA C 25.005(c)(10)) ... ............. ............... ...... .......... . ............ ............ _......... ...........4 11. Seabed Condition Analysis............................................................................................................ 4 (Requirements of 20 AA C 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....................................................................... 5 (Requirements of 20 AAC 25.050(b))....... ........... ....._...._... ...._...... ...... _.............. . ........... ......... ...........5 16. Attachments....................................................................................................................................6 Attachment 1: Directional Plans for 3H-23AL1................................................................................................................6 Attachment 2: Current Well Schematic for 3H-23A.........................................................................................................6 Attachment 3: Proposed Well Schematic for 3H-23AL1..................................................................................................6 Page 1 of 6 December 05, 2018 PTD Application: 31-1-23AL1 1. Well Name and Classification (Requirements of 20 AAC 25.005(f) and 20 AAC 25.005(b)) The proposed lateral described in this document is 3H-23AL1. This lateral will be classified as "Development - Oil" wells. 2. Location Summary (Requirements of 20 AAC 25.005(c)(2)) These laterals will target the A sand package in the Kuparuk reservoir. See attached 10-401 form for surface and subsurface coordinates of 31-1-23AL1. 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 4,800 psi. Using the maximum formation pressure in the area of 4,897 psi in 31-1-22 (i.e. 15.5 ppg EMW), the maximum potential surface pressure in 31-1-23A, assuming a gas gradient of 0.1 psi/ft, would be 4304 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 31-1-23A was measured to be 3584 psi (11.7 ppg EMW) on 9/25/2018.1 The maximum downhole pressure in the 31-1-23A vicinity is the 31-1-22 at 4,897 psi (15.5 ppg EMW) measured on 6/17/2018. Potential Gas Zones (Requirements of 20 AAC 25.005 (c)(4)(b)) • The offset injection wells to 31-1-23A have injected gas, so there is a possibility of encountering free gas while drilling the 3H-23AL1 lateral. 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 31-1-23AL1 lateral 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 31-1-23AL1 lateral will be drilled under 20 AAC 25.036 for thru-tubing drilling operations so a formation integrity test is not required. N o -Cb (LtctN'� -t2s-t's Page 2 of 6 December 5, 2018 PTD Application: 3H-23AL1 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 3H-23AL1 9560' 12,600' 5,907' 5936' 2-3/8", 4.7#, L-80, ST -L slotted liner; 0' 121' 1640 670 Surface aluminum billet on to Existing CasingUner Information Category OD Weight Weight Grade Connection Top MD Btm MD Top TVD Btm TVD Burst psi Collapse psi Conductor 16" 62.5 H-40 Welded 0' 121' 0' 121' 1640 670 Surface 9-5/8" 36.0 J-55 BTC 0' 4216' 0' 3181' 3520 2020 Production 7" 26.0 L-80 BTC -MOD 0' 9341' 0' 5882' 7240 5410 Liner 4-1/2" 12.6 L-80 NSCT 7475' 9875' 4958' 6114' 8430 7500 Tubing 3-1/2" 9.3 J-55 EUE 8rd 0' 7506' 0' 4975' 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 11.9 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 3H -23A lateral we will target a constant BHP of 11.8 ppg EMW at the window. The constant BHP target will be adjusted through choke pressure and/or mud weight increases to maintain overbalanced conditions if increased reservoir pressure is encountered. Additional choke pressure or increased mud weight may also be employed for improved borehole stability. Any change of circulating friction pressure due to change in pump rates or change in depth of circulation will be offset with back pressure adjustments. Page 3 of 6 December 5, 2018 PTD Application: 3H-23AL1 Pressure at the 3H -23A Window (9565' MD. 5929'TVD) Usino 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 3H -23A is a Kuparuk A -sand producer equipped with 3-1/2" tubing and 4-1/2" production liner. The CTD sidetrack will utilize one lateral to target the Al sand to southeast of the 3H -23A parent wellbore. The lateral will increase recovery and add additional resources. Pre -CTD Work 1. RU Slickline: Drift tubing with dummy whipstock and C/O GLV's 2. RU Service Coil: Mill out "D" nipple at 7472' RKB from 2.75" to 2.80" ID 3. RU E -line: Perform Caliper log, set 3-1/2" x 4-1/2" thru-tubing whipstock 4. Prep site for Nabors CDR3-AC rig. Rin Work 1. MIRU Nabors CDR3-AC rig using 2" coil tubing. NU 7-1/16" BOPE, test. 2. 3H-13AL1 Lateral (Al sand - southeast) a. Mill 2.80" window at 9565' MD. b. Drill 3" bi-center lateral to TD of 12,600' MD. c. Run 2-3/8" slotted liner with liner top packer from TD up to 9560' MD. Page 4 of 6 December 5, 2018 Pumps On 1.8 bpm) Pumps Off A -sand Formation Pressure 11.7 3607 psi 3607 psi Mud Hydrostatic 8.6 2651 psi 2651 psi Annular friction i.e. ECD, 0.08psi/ft) 765 psi 0 psi Mud + ECD Combined no chokepressure) 3416 psi Underbalanced -191psi) 2651 psi Underbalanced -956psi) Target BHP at Window 11.8 3638 psi 3638psi' Choke Pressure Required to Maintain Target BHP 222 psi 987 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 3H -23A is a Kuparuk A -sand producer equipped with 3-1/2" tubing and 4-1/2" production liner. The CTD sidetrack will utilize one lateral to target the Al sand to southeast of the 3H -23A parent wellbore. The lateral will increase recovery and add additional resources. Pre -CTD Work 1. RU Slickline: Drift tubing with dummy whipstock and C/O GLV's 2. RU Service Coil: Mill out "D" nipple at 7472' RKB from 2.75" to 2.80" ID 3. RU E -line: Perform Caliper log, set 3-1/2" x 4-1/2" thru-tubing whipstock 4. Prep site for Nabors CDR3-AC rig. Rin Work 1. MIRU Nabors CDR3-AC rig using 2" coil tubing. NU 7-1/16" BOPE, test. 2. 3H-13AL1 Lateral (Al sand - southeast) a. Mill 2.80" window at 9565' MD. b. Drill 3" bi-center lateral to TD of 12,600' MD. c. Run 2-3/8" slotted liner with liner top packer from TD up to 9560' MD. Page 4 of 6 December 5, 2018 PTD Application: 3H-23AL1 3. Freeze protect, ND BOPE, and RDMO Nabors CDR3-AC rig. Post -Rig Work 1. 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 3H-23AL1 lateral will be displaced to an overbalancing fluid prior to running liner. See "Drilling Fluids" section for more details. - While running 2-3/8" slotted liner, a joint of 2-3/8" non -slotted tubing will be standing by for emergency deployment. A floor valve is made up onto this joint ahead of time, and the rig crew conducts a deployment drill with this emergency joint on every slotted liner run. The 2-3/8" rams will provide secondary well control while running 2-3/8" liner. 14. Disposal of Drilling Mud and Cuttings (Requirements of 20 AAC 25.005(c)(14)) • No annular injection on this well. • All solid waste will be transported to the grind and inject facility at DS -4 Prudhoe Bay for disposal. • Incidental fluids generated from drilling operations will be injected in a Kuparuk Class II disposal well (1 R-18 or 1 B disposal facilities) or Prudhoe DS -4 if a Kuparuk facility is unavailable. • All wastes and waste fluids hauled from the pad must be properly documented and manifested. • Contact Kuparuk Environmental Coordinator for questions regarding waste classification. (670-4200). 15. Directional Plans for Intentionally Deviated Wells (Requirements of 20 AAC 25.050(b)) - The Applicant is the only affected owner. - Please see Attachment 1: Directional Plans - Magnetic and inclination surveys will be taken every 30 ft. No gyro will be run. - MWD directional, resistivity, and gamma ray will be run over the entire open hole section. Page 5 of 6 December 5, 2018 PTD Application: 3H-23AL1 Distance to Nearest Property Line (measured to KPA boundary at closest point) Lateral Name Distance 3H-23AL1 9375' - Distance to Nearest Well within Pool Lateral Name Distance Well 3H-23AL1 1163' 1 31-1-19 16. Attachments Attachment 1: Directional Plans for 3H-23AL1 lateral Attachment 2.' Current Well Schematic for 3H -23A Attachment 3: Proposed Well Schematic for 3H-23AL1 lateral Page 6 of 6 December 5, 2018 ConocoPhillips _ConocoPhillips Export Company Kuparuk River Unit Kuparuk 3H Pad 3H-23 3H-23AL1 Plan: 3H-23AL1_wp02 Standard Planning Report 17 December, 2018 BER GHES TGE company ConocoPhillips ConocoPhillips Planning Report Database: EDT 14 Alaska Production Local Co-ordinate Reference: Company: _ConocoPhillips Export Company TVD Reference: Project: Kuparuk River Unit MD Reference: Site: Kuparuk 3H Pad North Reference: Well: 3H-23 Survey Calculation Method: Wellbore: 3H-23AL1 Design: 3 H-23ALI_wp02 BA ER F�UGHES a GEmmpany Well 3H-23 Mean Sea Level 3H -23A: @ 70.10uslt (3H -23A:) True 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 SRO Kupamk 3H Pad Dip Angle She Position: Northing: 6,000,110.73 usg Latitude: 70'24'41.531N From: Map Easting: 498,655.44 usft Longitude: 150° 0'39.416 W Position Uncertainty: 0.00 usft Slot Radius: 0.000 in Grid Convergence: -0.01 ° Well 3H-23 Well Position +N/S +EI -W Position Uncertainty Wellbore Magnetics Design Audit Notes: Version: Vertical Section: I 0.00 usft Northing: 0.00 usft Easting: 0.00 usft Wellhead Elevation: 3H-23AL1 Model Name Sample Date BGGM2018 2/1/2019 3H-23AL1_wp02 6,000,637.79 usft Latitude: 498,655.28 usft , Longitude: usft Ground Level: Declination Dip Angle 16.69 80.90 Phase: PLAN Tie On Depth: Depth From (TVD) +N/ -S +E/ -W (usft) (usft) (usg) 0.00 0.00 0.00 70" 24' 46.715 N 150' 0' 39.424 W 0.00 usg Field Strength (nT) 57 426 9, 537.23 Direction (°) 135.00 121172018 1:37:02PM Page 2 COMPASS 5000.14 Build 85D ConocoPhillips BIER ConocoPhillips Planning Report HUGHES a GEcompany Database: EDT 14 Alaska Production Local Co-ordinate Reference: Well 3H-23 Company: _ConocoPhillips Export Company TVD Reference: Mean Sea Level Project: Kupawk River Unit MD Reference: 3H -23A: @ 70.10usft (3H -23A:) Site: Kuparuk 3H Pad North Reference: True Well: 31-1-23 Survey Calculation Method: Minimum Curvature Wellbore: 3H-23AL1 Azimuth System Design: 3H-23AL1_wp02 Rate Rate Plan Sections Measured TVD Below Dogleg Build Turn Depth Inclination Azimuth System +N/ -S +E/ -W Rate Rate Rate TFO (usft) (') (1) (usft) (usft) (usft) (°/100usft) (°1100usft) ('1100usft) (•) Target 9,537.23 64.41 345.66 5,897.04 5,287.42 -4,127.09 0.00 0.00 0.00 0.00 9,565.00 64.38 344.59 5,909.05 5,311.62 -4,133.51 3.48 -0.11 -3.85 -92.01 9,590.00 67.88 344.59 5,919.16 5,333.65 -4,139.59 14.00 14.00 0.00 0.00 9,639.16 90.00 344.59 5,928.53 5,379.87 4,152.33 45.00 45.00 0.00 0.00 9,825.00 90.99 68.22 5,926.56 5,531.94 -4,076.84 45.00 0.53 45.00 89.00 10,000.00 92.03 80.43 5,921.92 5,579.12 -3,908.73 7.00 0.59 6.98 85.00 10,150.00 90.18 90.77 5,919.01 5,590.61 -3,759.41 7.00 -1.23 6.89 100.00 10,550.00 86.88 118.59 5,929.45 5,490.37 -3,376.42 7.00 -0.83 6.95 97.00 10,800.00 88.53 136.02 5,939.54 5,339.55 -3,178.51 7.00 0.66 6.97 85.00 10,900.00 85.59 142.38 5,944.68 5,264.00 -3,113.29 7.00 -2.94 6.36 115.00 11,000.00 90.10 147.74 5,948.44 5,182.13 -3,056.11 7.00 4.51 5.36 50.00 11,175.00 93.24 135.89 5,943.33 5,044.88 -2,948.19 7.00 1.80 -6.77 -75.00 11,425.00 90.10 153.12 5,935.97 4,842.19 -2,803.69 7.00 -1.26 6.89 100.00 11,600.00 86.55 164.85 5,941.10 4,679.22 -2,741.07 7.00 -2.03 6.70 107.00 11,850.00 86.71 147.32 5,955.93 4,451.98 -2,640.29 7.00 0.06 -7.01 -90.00 12,200.00 93.14 170.97 5,956.39 4,127.39 -2,516.64 7.00 1.84 6.76 75.00 12,600.00 92.78 142.93 5,935.31 3,763.50 -2,361.80 7.00 -0.09 -7.01 -90.00 12/172018 1:37:02PM Page 3 COMPASS 5000.14 Build 85D ConocoPhillipsBA ER ConocoPhillips Planning Report F�UGHES a GE..p W Database: EDT 14 Alaska Production Local Co-ordinate Reference: Well 31-1-23 Company: _ConocoPhillips Export Company TVD Reference: Mean Sea Level Project: Kuparuk River Unit MD Reference: 3H -23A: @ 70.10usft (3H -23A:) Site: Kuparuk 3H Ped North Reference: True Well: 311-23 Survey Calculation Method: Minimum Curvature Wellbore: 3H-23AL1 Design: 3H-23AL1_Wp02 Planned Survey Measured TVD Below Vertical Dogleg Toolface Map Map Depth Inclination Azimuth System tN/S *El -W Section Rate Azimuth Northing Easting (usft) (1) (e) (usft) (usft) (usft) (usft) ('1100usft) V) (usft) (usft) 9,537.23 64.41 345.66 5,897.04 5,287.42 -4,127.09 -6,657.06 000 0.00 6,005,925.42 494,529.56 TIP 9,565.00 64.38 344.59 5,909.05 5,311.62 -4,133.51 -6,678.72 3.48 -92.01 6,005,949.62 494,523.14 KOP 9,590.00 67.86 344.59 5,919.16 5,333.65 -4,139.59 -6,698.59 14.00 0.00 6,005,971.66 494,517.07 End 14 DLS, Start 45 DLS 9,600.00 72.38 344.59 5,922.56 5,342.72 -4,142.09 -6,706.77 45.00 0.00 6,005,980.72 494,514.57 9,639.16 90.00 344.59 5,928.53 5,379.87 -4,152.33 -6,740.29 45.00 0.00 6,006,017.87 494,504.34 4 9,700.00 90.46 11.97 5,928.28 5,440.11 4,154.14 -6,784.16 45.00 89.00 6,006,078.11 494,502.54 9,800.00 90.95 56.97 5,926.98 5,520.45 -4,099.00 -6,801.98 45.00 89.11 6,006,158.43 494,557.69 9,825.00 90.99 68.22 5,926.56 5,531.94 4,076.84 -6,794.43 45.00 89.70 6,006,169.91 494,579.84 End 45 DLS, Start 7 DLS 9,900.00 91.45 73.45 5,924.96 5,556.55 -4,006.04 -6,761.77 7.00 85.00 6,006,194.50 494,650.64 10,000.00 92.03 80.43 5,921.92 5,579.12 -3,908.73 -6,708.92 7.00 85.11 6,006,217.06 494,747.94 6 10,100.00 90.80 87.32 5,919.44 5,589.78 -3,809.39 -6,646.22 7.00 100.00 6,006,227.69 494,847.27 10,150.00 90.18 90.77 5,919.01 5,590.61 -3,759.41 -6,611.46 7.00 100.17 6,006,228.52 494,897.25 7 10,200.00 89.76 94.24 5,919.04 5,588.42 -3,709.47 -6,574.60 7.00 97.00 6,006,226.32 494,947.19 10,300.00 88.91 101.19 5,920.20 5,575.01 -3,610.44 -6,495.09 7.00 97.00 6,006,212.89 495,046.20 10,400.00 88.08 108.14 5,922.84 5,549.71 -3,513.79 -6,408.86 7.00 96.92 6,006,187.58 495,142.84 10,500.00 87.27 115.10 5,926.90 5,512.91 -3,420.96 -6,317.21 7.00 96.73 6,006,150.77 495,235.65 10,550.00 86.88 118.59 5,929.45 5,490.37 -3,376.42 -6,269.76 7.00 96.45 6,006,128.22 495,280.19 a 10,600.00 87.19 122.08 5,932.03 5,465.16 -3,333.33 -6,221.47 7.00 85.00 6,006,103.00 495,323.27 10,700.00 87.85 129.05 5,936.37 5,407.08 -3,252.11 -6,122.97 7.00 84.82 6,006,044.92 495,404.47 10,800.00 88.53 136.02 5,939.54 5,339.55 -3,178.51 -6,023.18 7.00 84.52 6,005,977.38 495,478.05 9 10,900.00 85.59 142.38 5,944.68 5,264.00 -3,113.29 -5,923.64 7.00 115.00 6,005,901.82 495,543.25 10 11,000.00 90.10 147.74 5,948.44 5,182.13 -3,056.11 -5,825.31 7.00 50.00 6,005,819.95 495,600.41 11 11,100.00 91.90 140.98 5,946.70 5,100.92 -2,997.88 -5,726.72 7.00 -75.00 6,005,738.74 495,658.62 11,175.00 93.24 135.89 5,943.33 5,044.88 -2,948.19 -5,651.95 7.00 -75.12 6,005,682.70 495,708.29 12 11,200.00 92.94 137.62 5,941.98 5,026.70 -2,931.09 -5,627.00 7.00 100.00 6,005,664.51 495,725.39 11,300.00 91.69 144.51 5,937.93 4,949.02 -2,868.34 -5,527.71 7.00 100.09 6,005,586.83 495,788.12 11,400.00 90.42 151.40 5,936.08 4,864.32 -2,815.33 -5,430.33 7.00 100.37 6,005,502.13 495,841.11 11,425.00 90.10 153.12 5,935.97 4,842.19 -2,803.69 -5,406.46 7.00 100.50 6,005,480.00 495,852.74 13 11,500.00 88.57 158.14 5,936.84 4,773.90 -2,772.76 -5,336.30 7.00 107.00 6,005,411.72 495,683.66 11,600.00 86.55 164.85 5,941.10 4,679.22 -2,741.07 -5,246.94 7.00 106.94 6,005,317.04 495,915.33 14 11,700.00 86.57 157.84 5,947.11 4,584.71 -2,709.15 -5,157.54 7.00 -90.00 6,005,222.53 495,947.22 11,800.00 86.65 150.82 5,953.03 4,494.79 -2,665.94 -5,063.40 7.00 -89.58 6,005,132.61 495,990.42 11,850.00 86.71 147.32 5,955.93 4,451.98 -2,640.29 -5,014.99 7.00 -89.16 6,005,089.80 496,016.06 16 11,900.00 87.62 150.70 5,958.41 4,409.17 -2,614.58 4,966.54 7.00 75.00 6,005,046.99 496,041.76 12,000.00 89.46 157.46 5,960.96 4,319.32 -2,570.91 4,872.13 7.00 74.83 6,004,957.14 496,085.40 12,100.00 91.31 164.21 5,960.29 4,224.92 -2,538.10 4,782.18 7.00 74.66 6,004,862.75 496,118.19 12200.00 93.14 170.97 5,956.39 4,127.39 -2,516.64 4,698.04 7.00 74.71 6004765.22 496,139.64 12/172018 1:37.02PM Page 4 COMPASS 5000.14 Build 85D ConocoPhillips Bq CERall ConocoPhillips Planning Report UGHES a GEmmpany Database: EDT 14 Alaska Production Local Co-ordinate Reference: Well 3H-23 Company: _ConocoPhillips Export Company TVD Reference: Mean Sea Level Project: Kuparuk River Unit MD Reference: 3H -23A: @ 70, 10usft (3H -23A:) Site: Kuparuk 3H Pad North Reference: True Well: 3H-23 Survey Calculation Method: Minimum Curvature Wellbore: 3H-23AL1 Design: 3H-23AL 1 _wp02 Planned Survey Measured TVD Below Vertical Dogleg Toolface Map Map Depth Inclination Azimuth System +WS +E/ -W Section Rate Azimuth Northing Basting (usft) (_) (°) (usft) (usft) (usft) (usft) (°1100usft) (°) (usft) (usft) 16 12,300.00 93.12 163.96 5,950.92 4,029.98 -2494.98 -4,613.65 7.00 -90.00 6,004,667.82 496,161.28 12,400.00 93.05 156.95 5,945.53 3,935.94 -2,461.59 -4,523.74 7.00 -90.38 6,004,573.78 496,194.64 12,500.00 92.94 149.94 5,940.30 3,846.67 -2,416.98 -4,429.07 7.00 -90.76 6,004,484.51 496,239.24 12,600.00 92.78 142.93 5,935.31 3,763.50 -2,361.80 4,331.24 7.00 -91.13 6,004,401.34 496,294.40 Planned TD at 12600.00 Casing Points Measured Vertical Casing Hole Depth Depth Diameter Diameter (usft) (usft) Name (in) (in) 12,600.00 5,935.31 2 3/8" 2.375 3.000 Plan Annotations -- _-- Measured Vertical Local Coordinates Depth Depth +N/ -S +E/ -W (usft) (usft) (usft) (usft) Comment 9,537.23 5,897.04 5,287.42 -4,127.09 TIP 9,565.00 5,909.05 5,311.62 4,133.51 KOP 9,590.00 5,919.16 5,333.65 4,139.59 End 14 DLS, Start 45 DLS 9,639.16 5,928.53 5,379.87 4,152.33 4 9,825.00 5,926.56 5,531.94 4,076.84 End 45 DLS, Start 7 DLS 10,000.00 5,921.92 5,579.12 -3,908.73 6 10,150.00 5,919.01 5,590.61 -3,759.41 7 10,550.00 5,929.45 5,490.37 -3,376.42 8 10,800.00 5,939.54 5,339.55 -3,178.51 9 10,900.00 5,944.68 5,264.00 -3,113.29 10 11,000.00 5,948.44 5,182.13 -3,056.11 11 11,175.00 5,943.33 5,044.88 -2,948.19 12 11,425.00 5,935.97 4,642.19 -2,803.69 13 11,600.00 5,941.10 4,679.22 -2,741.07 14 11,850.00 5,955.93 4,451.98 -2,640.29 15 12,200.00 5,956.39 4,127.39 -2,516.64 16 12,600.00 5,935.31 3,763.50 -2,361.80 Planned TD at 12600.00 121172018 1:37:02PM Page 5 COMPASS 5000.14 Build 8.5D parent WblPo . 3M -23A C. •k MElaelerese re4xlzxrti.uvu T.. an MD: 037.23 BArER gotIH G ES 11 1 111 P,.J..: KupamkRiverUnK 1 I ! . 1 4� 1 1 She: K.p,ukM Pad Wall: U43 Conocomillips Wafl3H-2MLl W�. 1 Plan:3H-=Lbl_.pR(3H4=H43ALl) uotieorautm WELLDETAILS: 31-1-23 W -S +El.W Northing Easting Latitude Longitude 0.00 0.00 6000637.79 498655.28 700 U 46.715 N 150* U 39.424 W sec mu Inc An IVUS5 +rq/-b -w-W uleg MRS Vbmt Annotsom 1 9537.23 64.41 345.66 5897.04 5287.42 -412709 0.0000 ODD -6657.06 TIP 2 9565,00 608 344.59 5909.05 5311.62 4133.51 3,4763 -92+01 -667872 KOP 3 9590,00 67.88 3459 5919.16 5333.65 4139,5914.0000 DOG -6698,59 =Ll End 14 DLS, Start 4 963916 9000 344.59 5928.53 5379.87 4152+3345 0000 OW -674029 4 5 982500 90.99 68.22 5926.56 5531.04 4076.84 45.0000 89,00 -6794.43 End 45 OLS, Start 6 10000,00 92.03 80,43 5921.92 5579.12 3908.73 7.0000 85.00 -6708.92 6 7 1015D.00 90.18 90.77 5919.01 5590.61 -3759.41 7.0000 10000 -6611.46 7 8 10550+00 86.88 118.59 5929.45 5490.37 -337642 7b000 97,00 -6269 76 a 9 10800+00 88,53 136,02 5939,54 5339.55 -3178S1 7,0000 85.00 -802118 M45 M67 M411M - , 6 7 7 9 10 10900.00 85.59 142,38 5944.68 5264.00 -3113.29 70000 115.00 -5923.64 10 11 11000.00 9010 14714 5948.44 518213 -3056.11 7.0000 50.00 -582531 11 12 11175.00 93.24 135,89 5943.33 5044.88 -2048.19 7.0000 -75M -5651.95 60" 12 13 11425.00 90.10 15112 5935.97 4842.19 -2803.69 7.0000 100.00 -5406.45 13 14 11600.00 86.55 164.85 5941.10 4679.22 -2741.07 7.0000 107.00 -5246.94 14 15 11850.00 86.71 147.32 5955.93 4451.98 -2640.29 7.0000 -9D.00 -5014.99 15 16 12200.00 93.14 170.97 KDP UP 5956.39 412739 -251614 7.0000 75.00 4698.04 16 17 12600.00 92.79 142.93 5935.31 3763.50 -2361.80 7.DDOD -90.00 4331.24 14 Planned TD at IN parent WblPo . 3M -23A C. •k MElaelerese re4xlzxrti.uvu T.. an MD: 037.23 BArER gotIH G ES West(-YEast(+) (200 uaftlin) mw 11 1 111 1 1 1 1 sseb pw SI 23AL TOI 3H 3- =Ll T82 UP . X%Ll M W MLI L, T" 3Ht23ALI lW 31413ALIJW 500 M45 M67 M411M - , 6 7 7 Ll 60" , - aslcs� 6120 KDP UP 8 9 10 11 1 12 13 14 is 16 IMMIMMIMMIMMMMMI 91RmEd}DELI .00 6210 W - m DIM, ow ll m Iffilm a1■■■■� I MESON 4 A, & & is j=A', J, J. .�lmommoommomm sommoommom 1kokmmom 'MENEM West(-YEast(+) (200 uaftlin) mw 11 1 111 1 1 1 1 sseb pw SI 23AL TOI 3H 3- =Ll T82 UP . X%Ll M W MLI L, T" 3Ht23ALI lW 31413ALIJW 500 M45 M67 M411M - , 6 7 7 Ll 60" , - aslcs� 6120 KDP UP 8 9 10 11 1 12 13 14 is 16 91RmEd}DELI .00 6210 W - m DIM, ow 6394 4 A, & & is j=A', J, J. Vertical Section at 135.000 (90 usft/iu) m$ E ConocoPhillips BA�<ER ConocoPhillips Travelling Cylinder Report UGHES a GE company Company: ConocoPhillips (Alaska) Inc. -Kup2 Project: Kuparuk River Unit Reference Site: Kuparuk 3H Pad Site Error: 0.00 usft Reference Well: 31-1-23 Well Error: 0.00 usft Reference Wellbore 31-1-23ALi Reference Design: 3H-23AL1 wP02 Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Output errors are at Database: Offset TVD Reference: Well 3H-23 3H -23A: @ 70.10usft (3H -23A:) 3H -23A: @ 70.10usfi (3H -23A:) True Minimum Curvature 1.00 sigma EDT 14 Alaska Production Offset Datum Reference 3H-23AL1_wp02 Centre to Filter type: NO GLOBAL FILTER: Using user defined selection & filtering criteria Depth Interpolation Method: MD Interval 25.00usft Error Model: ISCWSA Depth Range: 9,537.23 to 12,600.00usft Scan Method: Tray. Cylinder North Results Limited by: Maximum center -center distance of 1,452.99 usft Error Surface: Pedal Curve Survey Tool Program Date 12/11/2018 From To (usft) (usft) Survey (Wellbore) Tool Name Description 76.50 7,620.60 3H-23 (3H-23) GCT -MS Schlumberger GCT multishot 7,640.00 9,537.23 31-1-23A ATDB (31-1-23A) GCT -MS Schlumberger GCT multishot 9,537.23 12,600.00 3H-23AL1_wp02 (3H-23AL1) Casing Points Measured Vertical Centre to Casing Hole Depth Depth Centre Diameter Diameter (usft) (usft) Name (in) (in) 105.10 105.10 16" 16.000 26.000 4,206.10 3,175.69 95/8' 9.625 13.500 7,635.00 5,048.07 7" TOW 3.500 4.750 Summary Site Name Offset Well - Wellbore - Design Kuparuk 3H Pad 3H-18 - 31-1-18 - 3H-18 3H -19 -3H -19-3H-19 3H-20 - 31-1-2011 - 31-1-201-1 3H-20 - 31-1-2011-01 - 31-1-201-7-01 31-1-20 - 3H-2011-01 PBI - 3H -20L7-01 PB1 3H-20 - 31-1-201-1-02 - 31-1-2017-02 3H-20 - 31-1-2011-06 - 31-1-2017-06 3H-21 - 31-1-21 - 3H-21 31-1-22 - 3H-22 - 3H-22 3H-22 - 3H-221-1 - 311-221-7 3H-22 - 3H-221-1-02 - 31-1-221-1-02 31-1-22 - 3H-221-1-03 - 31-1-2217-03 31-1-22 - 3H-221-1-03PB7 - 3H-22Li-03PB1 3H-22 - 3H-2211-03PB2 - 3H-22L7-03PB2 3H-23 - 3H-23 - 3H-23 31-1-23 - 3H -23A- 31-1-23A 31-1-24 - 311-24 - 31-1-24 3H-25 - 31-1-25 - 3H-25 3H-25 - 3H -25A- 31-1-25A 3H-25-3H-25APB7-3H-25APB1 3H-25 - 3H-25APB2 - 3H-25APB2 3H-28 - 3H-28 - 3H-28 3H-28 - 3H -28A - 31-1-28A 3H-28 - 3H-28APB1 - 3H-28APB1 Reference Offset Centre to No -Go Allowable Measured Measured Centre Distance Deviation Depth Depth Distance (usft) from Plan (usft) (usft) (usft) (usft) 11,899.52 8,300.00 1,164.02 323.35 846.44 11,712.23 8,200.00 1,381.33 74.56 1,310.45 11,637.23 8,300.00 1,227.73 37.49 1,193.58 Warning Out of range Pass - Major Risk Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Pass- Major Risk Pass- Major Risk Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range CC - Min centre to center distance or covergent point. SF - min separation factor, ES - min ellipse separation 12/112018 11:05: 18AM Page 2 COMPASS 5000.14 Build 85D ConocoPhillips BATER ConocoPhillips Travelling Cylinder Report 1GHES BAT GEcompany Company: ConocoPhillips (Alaska) Inc. -Kup2 Project: Kuparuk River Unit Reference Site: Kuparuk 3H Pad Site Error: 0.00 usft Reference Well: 31-1-23 Well Error: 0.00 usft Reference Wellbore 31-1-23AL1 Reference Design: 3H-23AL1_Wp02 Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Output errors are at Database: Offset TVD Reference: Well 3H-23 3H -23A: @ 70.1 Ousft (31-1-23A:) 3H -23A: @ 70.1 Ousft (3H -23A:) True Minimum Curvature 1.00 sigma EDT 14 Alaska Production Offset Datum Summary Kuparuk3HPad- 3H -19 -3H -19-3H-19 Reference Offset Centre to No -Go Allowable 100 -GCT -Ms Measured Measured Centre Distance Deviation Warning Site Name Depth Depth Distance (usft) from Plan Semi Major Axis Offset Well - Wellbore - Design (usft) (usft) (usft) (usft) Kuparuk 3H Pad Measured Verrkal Measured 31-1-31 - 3H -31A- 3H -31A Refarenm ofsn T.W..+ Msn Wellbore Centre Cosine- Cookie to Out of range 3H-31 - 31-1-31AL1 - 31-1-31AL1 Wam1n9 Depth Depth Out of range 31-1-32 - 31-1-32 - 3H-32 Aahnuth rNld aPj-y4 Out of range 31-1-32 - 3H-32PB1 - 3H-32PB1 DisWnse DiniaOen Out of range 31-1-32 - Prelim: 31-1-32A - 31-1-32A wp01 (urn) (ush) taal Draft) r) Out of range Plan: 3H -35 -3H -35-3H-35 wp03 10,181.78 10,225.00 925.27 217.72 740.32 Pass - Major Risk Plan: 31-1-36_BC-31-1-36-3H-36wpO5 9,648.18 10,200.00 946.19 258.35 694.75 Pass - Major Risk Plan: 3H -37 -BC - 31-1-37 - 3H-37wpO4 5,193.17 -1,713.07 4.750 1,16850 318.51 Out of range Offset Design Kuparuk3HPad- 3H -19 -3H -19-3H-19 ORsnshe ERor. Goo aan survey Program: 100 -GCT -Ms RuM Aul9oed: Major Risk gran war Error. uW.0 Reference Oaut Semi Major Axis Measured Verrkal Measured Venisal Refarenm ofsn T.W..+ Msn Wellbore Centre Cosine- Cookie to No Go Afloeable Wam1n9 Depth Depth DePei Depth Aahnuth rNld aPj-y4 Hob in. Centre DisWnse DiniaOen (usft) tasftl (urn) (ush) taal Draft) r) (usf0 )usn) Del (ass) (oan) trial 11,505.29 6,007.07 8.650,00 6.271.12 53,73 5237 55.73 5,193.17 -1,713.07 4.750 1,16850 318.51 855.21 Pass -Major Risk 11,512.23 6,007.27 8,025,00 8,253.06 53.77 52.20 57.09 5,177.91 -1,704.95 4.750 1.166.52 317.94 854.34 Pass - Major Risk 11,520.08 6,007.51 8.800.00 6.234.99 53.82 52.03 58.52 51162166 -1.696.84 4.750 1.164.98 317.27 852.95 Pass - Major Risk 11.527.36 6,007.75 0.95.00 6,216A2 53.86 51.67 50.91 5,147.40 -1,680.72 4.750 1,163.87 316.60 852.08 Pass -Major Risk 11,537.23 6,000.11 0,525.00 6.180.78 53.91 51.53 62.41 6,116.89 -1,67249 4.750 1.16297 315.40 852.10 Pass - Major Risk, CC 11,537.23 8,008.11 8.550.00 6,190.85 53.91 51.70 61.47 5,132.15 A.680.81 4.750 1,163.20 315.83 851+64 Pass - Major Risk 11,548.80 6,008.50 8,50000 6,162.72 5198 51.35 64.09 5,101.64 -1,664.30 4.750 1.163.14 314.54 852.50 Pass - Major Risk 11,502.23 8,009.18 8.450.00 6.126.60 54.05 51.02 6&82 5,071.10 -1.648.17 4]07 1.164.82 313.14 055.51 Pass - Major Risk 11,552.23 6,009.18 8.475.00 6,144.65 54.05 51.19 ease 5.086.38 -1.656.27 4.750 1,163.01 313.56 853.52 Pass - Major Risk 11,559.87 6009.64 8425.00 6,106.55 54,09 50.86 69.24 5,055.81 -1,640.00 4.750 1,166.30 312.40 857.60 Pass - Major Risk 11,576.76 8,009.90 8400.00 6,090.51 54.13 50.69 69.62 5,tokoel -1631.99 4.750 1,10.20 311.02 860.40 Pass - Major Risk 11878.72 6027.55 8,375.00 6,072.49 55.90 50.52 9134 5.025.19 -1,623.92 4.750 1.166.73 324.52 848.06 Pass -Major Risk 11.807.23 6,027.95 0,325.00 6,036.44 56.03 50.10 59.74 4,994.50 -1,607.81 4.750 M64,53 323.72 846.68 Pass -Major Risk 11,887.23 6,027.95 8.350.00 6.054.45 56.03 50.35 50.82 5,Ooe85 .1,618.86 4.750 1,165.61 324.16 846.98 Pass -Major Risk 11899.52 6.028.49 0,300.00 6010.42 56.11 50.02 61.46 4,979.14 -1.599.79 4.750 1,164.02 323,35 846.44 Pa.- Major Risk. ES, SF 11.912.23 6,028.99 $250.00 5,90239 56.21 49.68 64.12 4,918.40 -1,503,77 4.750 1164.31 322.51 847.90 Pass - Major Risk 11,912.23 6,020.99 8,27500 6,000.41 56.21 49.05 63.20 4,963,77 As91.76 4.750 1,163.98 322.95 846.72 Pass - Major Risk 11920.66 6,029.30 6225.00 5,964.35 56,27 49.51 65.59 4,933.03 -1,575.00 4.750 1,165.00 32208 1349.29 Pass - Major Risk 11,927.77 6,02954 620.00 5,946.30 58.32 49.34 6&97 4,917+67 -1,567,05 4.750 11166.28 321.62 051.24 Pass - Major Risk 11,937.23 6.029.03 8.150.00 5,910.23 56.39 49.01 69.40 6886,89 -1551.09 4.750 1,169.90 320.71 855.83 Pass - Major Risk 11,937.23 6,029.83 6175.00 5,928.26 $6.39 49.18 68.49 4,902.29 -1,559.91 4.750 1,167.87 321.14 853.57 Pass - Major Risk 11,949.35 6.030.17 8.125.00 5.892.21 56.47 48.04 71.09 4,071.47 -1,544.06 4.750 1,172.29 320.10 059.% Pass -Major Risk 11,962.23 6,030.40 8.075.00 5.056.23 56.57 48.51 73.71 4,840.55 -1,52629 4.750 1,178.31 319.17 090.22 Pass - Major Risk 11962.23 6,030.48 8,100.00 5,074.21 56.57 46.67 72.83 4,056.02 -1,536.17 4.750 1,175.13 319160 863.55 Pass -Major Risk 11,971.30 6,030.88 0050.00 5,838.26 56.63 46.34 75.18 4,025.05 -1,520,42 4.750 1.181.90 318.61 972.88 Pass -Major Risk 11,978.70 6.030.79 8.025.00 5.820.30 56.68 48.17 76.53 4,809.53 -1512.57 4.750 1,185.87 918.05 978.09 Pass - Major Risk 11.907.23 6030.91 7.975.00 5,784.44 W.74 0.84 78.80 4.779.39 -1.496.94 4.750 1,191.96 317.02 890.20 Pass - Major Risk 11.907.23 6,030.91 0,000.00 5,80237 W.74 48.00 77.96 4,79397 -1,504.74 4.750 1,190.22 317.46 883.64 Pass - Major Risk 12,001.12 6,031.07 7,950.00 5,766.53 56.84 47.67 80.50 4]82.76 -1.489.17 4.750 1,199.90 316.29 896.21 Pass - Major Risk 12.012.23 6031.15 7,900.00 5,730.71 56,92 47.33 82.94 4,731.40 -1,473.74 4.750 1,211.15 315.15 910.56 Pass -Major Risk 12.012.23 6,031.15 7,925.00 5,748.62 56.92 47.50 82.13 4,747,15 -1,401.44 4.750 1,205.40 315.50 902.83 Pass - Major Risk 12.023.85 6,031.19 7.07500 5,712.83 57.00 47.16 84.52 4]15,79 -11468.08 4.750 1,217.22 314.39 917.89 Pass - Major Risk CC - Min Centre to center distance or covergent point, SF - min separation factor, ES - min ellipse separation 12/11/2018 11:05:16AM Page 3 COMPASS 5000.14 Build 85D AM KUP PROD 3H -23A C0n0C0 't1llIK15 Alaska. Im. TD WwB"'eff utas D Max gle&61 Fink Name WeIIMre M111RM WtlIMe3laluz KUPARUK RIVER UNIT 501032020401 PROD se", 1Mie&MD % (XKBI 4.54 94M.00 9,875.0 Hx End -- Release Date Comment 5(ppml Oate M IXI In. X.n IK 558V: NIPPLE Last W0: 511711994 31.09 1/2011994 NI asuchaw Giant Ala Last Tag Veniwlachunil (acWap Annotation EM Oah Depin(an.) taslMM 6y Last Tag- Rug (ES1200of Fill Ove, Top Pelts) 9252018 zembaej Last Rev Reason - - ---- --- pre.1 n .eDtle fast Mcd ey HANGER. n.o Rev Reason: Updated Tag Oeoh 9252018 zembaej Casing Strings Casing DesaiPlion DID(m) IDfmlJ(DKII ..IDepaS 1Kei set Depth( VTI-. wlRan(I Gnda Top Thread CONDUCTOR 16 15.06 ISLE 121.0 62.58 H-40 WELDED Casing Deszriglm OD(Inl 10(inlon sat Depth MKB) Set 0eplh UVD1... Vel IL.. O,.a TopThreadSURFACE 9" 8.92 4,216.3 3,181.4 MAD P55 BTC Lasing DesnlWan O01m) mppDI set Depin (nKel stl Oeats TvDL- W14en 0... Drage Toprnread PRODUCTION > 6.28 9341.0588232600L-80 BTGMOD Lasing Deacnption OD(In, ID (IntBI Set Depin(RK8) SN-Pa'RVDI.. WtM1en(I.. Gratia 1PTnreaeLINER 4112 3.96 9875.0 6,114.3 12fi0 L-80 NSCT Liner Details CONDUCTOR; a.OutO NanmauD Top(XKBI Top(TVO)(nKS) Topind('l It.. Oas Co. (in) 7.475.4 4,957.8 50.21 TIEBACK/ BAKER LINER TIEBACK SLEEVE wIC-22XP LINER 4.375 MaPLE:5m.4 PACKER TOP PACKER ],14519 .3 4,965.5 56.09 HANGER BAKER HMC LINER HANGER 4,375 CASLIFES2119 7,1496.0 4,969.3 Sfi.03 SBE BAKER SEAL BORE EXTENSION 4.000 Tubing Strings ening Oazeripron shine Ma... ID(inl Top(XND) ser Deem (x_ set Oepm (-(-.WtgbXll clad¢ Top connecimn TUBING 3112 2.99 2].0 ],506.6 6,9753 930 J-55 EUE BRD Cofnialetion Details bp(1VD1 Top Ind Nominal TOP(I.G) (pKit) L) vem Dss Co. In hnl 2].D 27.0 0.17 HANGER WKM GEN VI TUBING HANGER 3500 507.4 507.3 1.52 NIPPLE CAMEO DS NIPPLE 2.812 7,472A 4,95.1 56,24 NIPPLE CAMEO D NIPPLE NO GO 2,750 SURFACE 4f.34.2fa3- 7.47AS 4,960.1 56.17 SEALASSY BAKER GBH -22 LOCATOR SEAL ASSEMBLY; SEALS OD 4- 3.000 W110' STROKE, STABBED INTO LINER TIEBACK ws UFT, sill 0 1Perforations & Slots and oen cAs uFr:da38 Top (XNaI atm (nKe) Top(rvD) IItKe) Btmmc" IIIKB) LInMMZme Oate nnotsm 1 Type Cern 9,550.0 9.800.0 5,9727 5.994.3 A-2, A-1, 3H- 1/191199] 4.0 IPERF EAST 1:1111119s; 180 deg. PX 23A 12 Mandrel Inserts GAS GFT: 7,427,3 & w H Top 11W1 Wlas tatcn Pertains TRO Run Top(XKaI MIKE) Make Mosel O0 pn1 Sery Type Type (nl (ps0 Run Oate Cam 3.213.9 2.839.3 MERU TMPD 1 GAS LIFT GLV BK 0.1 1, 5.0 11 199] 2 4,980.0 3,fi10.0 MERLA TMPD 1 GASLIFT GLV BK 0.188 LULEA 112WI997 NIPFUL7.4734 3 6,299.3 43222 MERLA TMPD 1 GAS LIFT GW BK 0.188 1,333.0 112811997 4 1.427.3 14,931.1 CAMEO MMM 11/2 GAS LIFT OV RK O.1Sfi 0.0 313112002 Notes: General akfady End Dale Annonsion 1212711996 NOTE: WELL SIDETRACKED 11152010 NO E: M. SCIIBma1IC WI Alaska&hama11C9S sEu Assn, 7,4ns PRODUCTKIN: all Sul 0 IPERF:9.YQ69.aMD IMER:>,475..a75D 3H -23A Proposed CTD Schematic 9-5/8" 36# J-55 shoe @ 4216' MD 7" 26# L-80 shoe @ 9341' MD KCP @ 9565' MD sand perfs 19550'- 9600' MD 4-1/2" 12.6# L-80 shoe @ 9875' MD 3-1/2" Camco DS nipple @ 507' MD (2.875" min ID) 3-1/2" 9.3# L-80 EUE 8rd Tubing to surface 3-1/2" Camco gas lift mandrels @ 3214', 4988', 6299', & 7427' MD 3-1/2" Camco D landing nipple @ 7472' MD (2.75' min ID) Baker 3-1/2" GBH -22 seal assembly @ 7480' MD (3" ID) Liner too Baker ZXP liner top packer @ 7475' MD Baker HMC liner hanger @ 7489' MD Baker 80-40 SBE @ 7496' MD 31-1-23AL1 wp02 Plan TD: 12,600' MD TRANSMITTAL LETTER CHECKLIST WELL NAME: K R (,L �3 it — �?J A L PTD: a I S — 1 :;�Jr v/ Development —Service Exploratory _ Stratigraphic Test —Non -Conventional FIELD: C uD d V u K R" ✓P.i' POOL: �<,1 p di V u 1c R i V ¢. V- 00 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 l LATERAL No. I416 -1S6 , API No. 50-IDa aDaoL-j�-_OL-_O.z. (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(1), all records, data and logs acquired for the pilot hole must be clearly differentiated in both well Pilot Hole name ( PH) and API number (50- -� from records, data and logs acquired for well name on permit). The permit is approved subject to full compliance with 20 AAC 25.055. Approval to produce/inject is contingent upon issuance of a conservation Spacing Exception order approving a spacing exception. (Company—Name) Operator assumes the liability of any protest to the spacing exception that may occur. All dry ditch sample sets submitted to the AOGCC must be in no greater Dry Ditch Sample than 30' sample intervals from below the permafrost or from where samples are first caught and 10' sample intervals through target zones. Please note the following special condition of this permit: production or production testing of coal bed methane is not allowed for Non -Conventional (name of well) until after (Company Name) has designed and Well implemented a water well testing program to provide baseline data on water quality and quantity. (Companv Name) must contact the AOGCC to obtain advance approval of such water well testing program. Regulation 20 AAC 25.071(a) authorizes the AOGCC to specify types of / well logs to be run. In addition to the well logging program proposed by ✓/ (Company Name) in the attached application, the following well logs are also required for this well: Well Logging Requirements Per Statute AS 31.05.030(d)(2)(B) and Regulation 20 AAC 25.071, composite curves for well logs run must be submitted to the AOGCC within 90 days after completion, suspension or abandonment of this well. Revised 2/2015 WELL PERMIT CHECKLIST Field 8 Pool KUPARUK RIVER, KUPARUK RIV OIL -490100 PTD#:2181750 Company CONOCOPHILLIPS ALASKA INC. Initial Class/rype _Well Name: KUPARUK RIV UNIT 3H-23AL1 Program DEV Well bore seg J DEV/PEND GeoArea 890 Unit 11160 On/Off Shore On Annular Disposal ❑ Administration 17 Nonconven.. gas conforms to AS31,05,03%1.A),(j2.A-D) . . . . . . .. . . . . . . . . ... . .. NA... ... _ ..... - _ _ - _ ------ Commissioner Date 1 Permit fee attached . ......................................... NA- -- --.-..--.. - 2 Lease number appropriate.... - .......------ Yes .. .. -. - 3 Unique well name and number - - - - Yes - 4 Well located in a defined pool- - - - - - - - - - --------- - - - - - - - - - - - - - Yes 5 Well located proper distance from drilling unit boundary- - - - - - - - ... - - - - . _ Yes 6 Well bcated proper distance, from other wells - - -- - -.Yes 7 Sufficient acreage available in drilling. unit.... _ - - - .. - - - - _ Yes - - 8 If deviated, is wellbore plat included - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - No. - - - Directional -plan view of wellpath included. 9 Operator only affected party _ _ - - - - - . . . . . . ......... . Yes 10 Operator has appropriatebondin force - ------ - - - - - - - - - - - - - - - --- Yes - - - - - - Appr Date 11 Permit can be issued without conservation order- .... .. - - - - - Yes 12 Permit can be issued without administrative approval ... Yes - - - - - - - - - - - DLB 12/27/2018 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 welis.withirn 1/4.mite area of review identified (For service well only)---- - - - - - - - - - - - NA - - _ - _ - ... ....... .. . 16 Pre -produced injector; duratiop of pre -production less than 3 months -(For service well only) .. NA - - - - - - - - - - - - - - - - - - - - - - - - 18 Conductor stringprovided- - - . ............... - - - NA. Conductor set in KRU 31-1-23 - - - - - Engineering 19 Surface casingprotects all known USDWs ----- - - - - - - - - - -- - - - - - - - - - - --- NA ....... Surface casing set in KRU 3H-23 - - - - - - - - - - - - - - - - - - - - 20 CMT. vol adequateto circulate on conductor $ surf csg .................... . . . . NA_ - _ - - _ _ _ Surface casing set and fully cemented 21 CMT -vol adequate to tie-in long string tosud cs9------.................NA_-.-.--__--.---.--....... -.. ...-...... ... 22 CMT will cover all known productive horizons- - - - - - - - - - - - - - - - - - - - - - -------- No........ Productiveintervalwill be completed with. uncemented slotted liner - - - - - - - - - 23 Casing designs adequate for C, T, B & permafrost. . ..........- Yes - 24 Adequate tankageor reserve pit - - - - - - - - - - ------ - - - - - - - - - - - . _ Yes ..... _ . Rig has steel tanks; all waste -to approved disposal wells 25 If a -re -drill, has -a 107403 for abandonment been approved - - _ NA 26 Adequate wellbore separation proposed . - - - - - - - - - - - - - - - - - - ----- Yes - - - - Anti -collision analysis complete; no major risk failures - - - - - - - - - - - 27 If dJverterrequired, does it meet- regulations . . . ............... . . . . . . . . . . . . . NA - - _ ....... Appr Date 28 Drilling fluid. program schematic $ equip list adequate . . . ..... . .......... . . . . . Yes - - - - Max formation. pressure is. 4897 psig(15.5 ppg EMW ); will drill.w/ 8,6-ppg EMW and maintain overbal. w/ MPD VTL 1/2/2019 29 BOPEs, do they meet regulation . . . . . . . . . . . . . . . . . . ..... . . .. . ..... . . . . Yes - _ _ - - _ _ - - .. - ...................... 30 BOPE press rating appropriate; test to(putpsig in comments).... - - - ..... _ Yes - - - MPSP is 4304 psig; will test BOPS -to 480,0 psig. 31 Choke. manifold complies w/API. RP -53 (May 84)--- - - - - - - - - - - - - - - - - --- Yes 32 Work will occur without operation shutdown . . . . . . ........ . - - - - Yes 33 Is presence of 1-12S gas probable ....... - - - - - _ . _ Yes - - - _ - 1-12S measures required ............. . 34 Mechanical condition of wells within AOR verified (For service well only) ............. . NA_ 35 Permit can be issued w/o hydrogen -sulfide measures - - - - - - - - - - - - - - - - - N.o- - .. - - - - 31 -1 -Pad wells are 12S-bearing..HZS.measures are required. Geology 36 Data presented on potential overpressure zones.... - - - - - - - _ . - - - - Yes ..... - - - - - - - - - - - - - - - - - ApprDate X37 Seismic analysis of shallow gas zones- - - - -....................... --- NA- - -- -----..--....-. -- - - - - - ..... - _ - DLB 12/27/2018 38 Seabed .condition survey (if off -shore) - - - - . . ....... . .. . . . . - - - . NA................... 39 Contact namelphone for weekly -progress reports [exploratory only] .. . .. . ........ . . . NA_ - - - - Geologic Engineering Public Commissioner: Date: Commission Date Commissioner Date
