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Home My WebLink About218-079DATA SUBMITTAL COMPLIANCE REPORT 1/18/2019 Permit to Drill 2180790 Well Name/No. KUPARUK RIV UNIT 1 H-21AL2 Operator CONOCOPHILLIPS ALASKA, INC. MD 11128 TVD 6539 Completion Date 9/14/2018 Completion Status 1 -OIL REQUIRED INFORMATION Current Status 1 -OIL API No. 50-029-22355-61-00 UIC No Mud Log No V Samples No ✓ Directional Survey Yes DATA INFORMATION List of Logs Obtained: GR/Res Well Log Information: Log/ Electr Data Digital Dataset Log Log Run Interval Type Med/Frmt Number Name Scale Media No Start Stop ED C 29765 Digital Data 7530 11128 ED C 29765 Digital Data ED C 29765 Digital Data ED C 29765 Digital Data ED C 29765 Digital Data ED C 29765 Digital Data ED C 29765 Digital Data ED C 29765 Digital Data ED C 29765 Digital Data ED C 29765 Digital Data ED C 29765 Digital Data ED C 29765 Digital Data ED C 29765 Digital Data ED C 29765 Digital Data ED C 29765 Digital Data ED C 29765 Digital Data ED C 29765 Digital Data (from Master Well Data/Logs) OH/ CH Received 10/8/2018 Electronic Data Set, Filename: 1H-21AL2 GAMMA RES.las 10/8/2018 Electronic File: 1 H-21AL2 2MD Final.ogm 10/8/2018 Electronic File: 1 H-21AL2 5MD Final.cgm 10/8/2018 Electronic File: 1 H-21AL2 5TVDSS Final.cgm 10/8/2018 Electronic File: 1H-21AL2 2MD Final.pdf 10/8/2018 Electronic File: 1H-21AL2 5MD Final.pdf 10/8/2018 Electronic File: 1H-21 AL2 5TVDSS Final.pdf 10/8/2018 Electronic File: 1 H-21AL2 EOW - NAD27.pdf 10/8/2018 Electronic File: 1 H-21AL2 EOW - NAD27.txt 10/8/2018 Electronic File: 1H-21AL2 Final Surveys TD 11128'.csv 10/8/2018 Electronic File: 1H-21AL2 Final Surveys TO 11128'.xlsx 10/8/2018 Electronic File: 1H-21AL2 Survey Listing.bd 10/8/2018 Electronic File: 1H-21AL2 Surveys.txt 10/8/2018 Electronic File: 11-1- 21AL2_25 tapescan_BHI_CTK.bd 10/8/2018 Electronic File: 11-1- 21 AL2_5_tapescan_BH I_CTK.txt 10/8/2018 Electronic File: 1H-21AL2_output.tap 10/8/2018 Electronic File: 1H-21AL2 2MD Final.tif AOGCC Page I of 7- Friday, January 18, 2019 DATA SUBMITTAL COMPLIANCE REPORT 1/18/2019 Permit to Drill 2180790 Weli Name/No. KUPARUK RIV UNIT 1H-21AL2 MD 11128 TVD 6539 Completion Date 9/14/2018 Log C 29765 Log Header Scans ED C 29787 Digital Data ED C 29787 Digital Data ED C 29787 Digital Data ED C 29787 Digital Data Log C 29787 Log Header Scans Well Cores/Samples Information Name INFORMATION RECEIVED Completion Report 6 Production Test Information Y Geologic Markers/Tops l:/ COMPLIANCE HISTORY Completion Date: 9/14/2018 Release Date: Description Comments: Compliance Reviewed By: AOGC'C Interval Start Stop Operator CONOCOPHILLIPS ALASKA, INC. API No. 50-029-22355-61-00 Completion Status 1 -OIL Current Status 1-0I1- UIC No 0 0 2180790 KUPARUK RIV UNIT 1H-21AL2 LOG HEADERS 10/12/2018 Electronic File: 1H-21AL2 EOW - NAD27.pdf 10/12/2018 Electronic File: 1 H-21AL2 EOW - NAD27.W 10/12/2018 Electronic File: 1 H-21AL2 EOW - NAD83.pdf 10/12/2018 Electronic File: 1 H-21AL2 EOW - NAD83.txt 0 0 2180790 KUPARUK RIV UNIT 1H-21AL2 LOG HEADERS Directional / Inclination Data V Mechanical Integrity Test Information Y / NA Daily Operations Summary Date Comments Page 2 of 1, Sample Set Sent Received Number Comments Mud Logs, Image Files, Digital Data Y / Composite Logs, Image, Data Files (11) Cuttings Samples vY /® Date: Core Chips Y / 6) Core Photographs Y / 16)� Laboratory Analyses Y /{vP,l Friday, January 18, 2019 To: L I b U/ J 29787 Letter of Transmittal Date: — - ----- -- V October 11, 2018 a U company Meredith Guhl AOGCC 333 West 711 Ave, Suite 100 Anchorage, Alaska 99501 From: Michael Soper/Yosha Ragbirsingh Baker Hughes, a GE Company 795 East 94th Avenue Anchorage, Alaska 99515 Please find enclosed the directional survey data for the following well(s): KUPARUK RIVER UNIT 3H -31A 3H-31AL1 1H -21A 1H-21AL1 1H-23AL2 1H-21AL2-01 (14) Total prints GREATER MOOSES TOOTH UNIT MT6-03PH MT6-03 C kECEIVED MT6-05PB1 OCT MT6-05PB2 12 2018 MT6-05 AOGCC MT6-OSL1 M76-O8PB1 MT6-08 Enclosed for each well(s): 1 hardcopy print of directional survey reports (NAD27) to 1 compact disk containing electronic survey files Note: Please feel free to send us an email in place of return mail. Michael Soper, Baker Hughes, Project Engineer Michael.Soper@BHGE.com Yosha Rag birsingh, Baker Hughes, Survey Manager ConocoPhillips ConocoPhillips (Alaska) Inc. Kuparuk River Unit Kuparuk 1H Pad 1 H-21AL2 50-029-22355-61 Baker Hughes INTEQ Definitive Survey Report 02 October, 2018 BA ER F�UGHES a GE company 21 8079 29787 Project Kuparuk River Unit, North Slope Alaska, United States Map System: ConocoPhillips NA ER ConocoPhillips Definitive Survey Reportucfi� Survey Company: ConocoPhillips (Alaska) Inc. Local Co-ordinate Reference: Well 1H-21 Project: Kuparuk River Unit ND Reference: 1H-21 @ 96.00usft (1H-21) Site: Kuparuk 1H Pad MD Reference: 1H-21 @ 96.00usft (1H-21) Well: iH-21 North Reference: True Wellbore: 1H-21 Survey Calculation Method: Minimum Curvature Design: 1 H-21 Database: EDT 14 Alaska Production Project Kuparuk River Unit, North Slope Alaska, United States Map System: US Slate Plane 1927 (Exact solution) System Datum: Geo Datum: NAD 1927 (NADCON CONUS) Survey Map Zone: Alaska Zone 04 Survey (Wellbore) Well iH-21 Phase: ACTUAL Well Position -NI-S 0.00 usft Northing: GCT -MS +EI -W 0.00 usft Easting: Position Uncertainty 0.00 usft Wellhead Elevation: Wellbore 1H-21 AL2 8/19/2018 Magnetics Model Name Sample Date Depth From (ND) (usft) 41.60 Survey Program Date Mean Sea Level Using Well Reference Point Using geodetic scale factor 5, 980,024.57 usft Latitude: 70' 21 22.356 N 549,555 22usft Longitude: 149° 35'51 196 W usft Ground Level: 54.40 usft Declination Dip Angle Field Strength (1) P) (nT) 1 I 17.01 80.91 57,446 i Tie On Depth: 7,907.21 +NbS +E/ -W Direction (usft) (usft) (I 0.00 0.00 90.00 From BGGM2018 9/1/2018 Design 1H-21AL2 Survey Audit Notes: (usft) Survey (Wellbore) Version: 1.0 Phase: ACTUAL Vertical Section: 7,807.30 1H-21 Srvy i - SLD_GCT-MS (1 H-21) Depth From (ND) (usft) 41.60 Survey Program Date Mean Sea Level Using Well Reference Point Using geodetic scale factor 5, 980,024.57 usft Latitude: 70' 21 22.356 N 549,555 22usft Longitude: 149° 35'51 196 W usft Ground Level: 54.40 usft Declination Dip Angle Field Strength (1) P) (nT) 1 I 17.01 80.91 57,446 i Tie On Depth: 7,907.21 +NbS +E/ -W Direction (usft) (usft) (I 0.00 0.00 90.00 From To Survey End Date Survey (usft) (usft) Survey (Wellbore) Tool Name Description Start Date 102.20 7,807.30 1H-21 Srvy i - SLD_GCT-MS (1 H-21) GCT -MS Schlumberger GCT multishot 4/28/1993 7.826.00 7,876.23 1H -21A MWD-INC(1 H -21A) MWD-INC_ONLY MWD-INC—ONLY—FILLER 8/19/2018 7,907.21 7,907.21 1H -21A MWD (1 H-21 A) MWD MWD - Standard 8/19/2018 7,935.00 11,095.73 1H-21 AL2 MWD (I H-21 AL2) MWD MWD -Standard 8/29/2018 10/2/2078 2:56:36PM Page 2 COMPASS 5000.14 Build 85D Survey End Date 1 4/28/1993 8119/2018 8/21/2018 9/5/2016 10/2/2078 2:56:36PM Page 2 COMPASS 5000.14 Build 85D 10/Z2018 2:56:36PM Page 3 COMPASS 5000.14 Build 85D ConocoPhillips a ER a ConocoPhillips Definitive Survey Report FUGHS Company: ConocoPhillips (Alaska) Inc. Local Co-ordinate Reference: Well 11-1-21 Project: Kuparuk River Unit TVD Reference: 1H-21@96.00usft(1 H-21) Site: Kuparuk 1H Pad MD Reference: 1H-21 @ 96o0usft (1H-21) Well: 1H-21 North Reference: True Wellbore: 1H-21 Survey Calculation Method: Minimum Curvature Design: 1H-21 Database: EDT 14 Alaska Production Survey MD Inc Azi TVD TVDSS +N/ -S +E/ -W Map Map DLS Vertical (usft) (°) (I (usft) (usft) (usft) (usft) Northing Easting (°7100.) Section Survey Tool Name Annotation (ft) (ft) (ft) 7,90721 69.06 88.16 6,62].05 6,531.05 -108,76 3,77072 5,979,94077 553,326.21 40.46 3,770.72 MWD(3) TIP 7,935.00 81,65 86.54 6AMo6 6,538.06 -107.51 3,797.52 5,9]9,942.19 553,353.00 4565 3,797.52 MWD (4) KOP 7,966.17 59.11 85.67 6,644.46 6,548.46 -105.54 3,826.63 5,979,944.35 553.382.09 72.36 3,826.63 MWD(4) 7,995.40 44.33 93.35 6,662.53 6,566.53 -105.19 3,849.48 5,979,944.86 553,404.93 5454 3,849.48 MWD (4) 8,026.71 50.64 110.13 6,683]6 6,587.76 -110.02 3,671.87 5,979,940.18 553,427.36 44.23 3,871.87 MWD(4) 8,055.94 61.99 100.00 6,699.98 6,603.98 -116.18 3,895.31 5,979,934.17 553,450.83 48.29 3,895.31 MWD(4) 8,085.77 73.88 90.33 6,711.19 6,615.19 -118.55 3,922.76 5,979,931.97 553,478.29 49.86 3,922.76 MWD (4) 8,115.87 79.92 82.80 6,718.02 6,622.02 -116.78 3,951.98 5,979,933.94 553,507.50 31.55 3,951.98 MWD (4) 8,147.35 81.26 7967 6,723.16 6,627.16 -112.05 3,982.67 5,979,93888 553,538.16 1069 3,982.67 MWD(4) 8,176.12 83.58 77.38 6,726.96 6,630.96 -106.38 4,010.62 5,979,944.74 553,566.06 11.28 4,010.62 MWD (4) 8,205.33 64.07 74.39 6,730.10 6,634.10 -99.29 4,038.78 5,979,952.00 553,594.17 10.31 4,038.78 MWD(4) 8,236.07 85.82 76.08 6,732.81 6,636.81 -91.49 4,068.38 5,979,960.00 553,623.72 7.90 4,068.38 MWD (4) 8,26569 89.97 77.92 6,733.90 6,637,90 -84.84 4,097.22 5,979,966.85 553,652.51 15.32 4,097.22 MWD (4) 8,300.49 90.55 80.83 6,733.74 6,63].]4 -7842 4,131.42 5,979,973.49 553,686.65 8.53 4,131.42 MM (4) 8,330.87 90.34 89.88 6,733.50 6,63].07 -74.69 4,161.55 5,979,977.46 553,716.]] 13.35 4,161.55 MWD(4) 8,360.19 89.57 87.65 6,733.53 6,637.53 -72.73 4,190.81 5,979,979.57 553,746.01 9.81 4,190.81 MWD (4) 8,390.44 9077 90.85 6,733.44 6,637.44 -72.34 4,221.05 5,979,980.16 553,776.25 11.30 4,221.05 MAD (4) 8,420.38 92.24 92.37 6,732.65 6,63665 -73.18 4,250.97 5,979,979.52 553,806.16 7.06 4,250.97 MWD (4) 8,450.26 96.03 93.42 6,730.50 6,634.50 -74.68 4,280.72 5,979,97821 553,835.93 13.16 4,280.72 MWD (4) I 8,483.01 99.18 93.99 6,726.56 6,630.56 -76.59 4,310.15 5,979,976.50 553,865.36 10.76 4,310.15 MM (4) 8,510.50 102.21 95.76 6,720.90 6,624.90 -79.13 4,340A0 5,979,974.16 553,89522 11.46 4,340.00 MWD (4) j 8,540.27 102.96 9924 6,714.41 6,618.41 -82.92 4,368.80 5,979,970.56 553,924.04 11.68 4,368.80 MWD (4) 8,570.70 102.80 102.75 6,707.63 6,611.63 -88.58 4,39].91 5,979,965.09 553,953.19 11.26 4,397.91 MWD (4) 8,595.52 101.59 102.31 6,702.39 6,606.39 -93.84 4,421.59 5,979,959.99 553,976.91 5.17 4,421.59 MWD (4) 8,62547 99.03 98.50 6,697.02 6,601.02 -99.16 4,450.57 5,979,954.86 554,005.91 15.16 4,450.57 MAID (4) E 8,655.52 9825 95.19 6,692.51 6,596.51 -102.70 4,480.06 5,979,951.52 554,035.43 11.19 4,480.06 MWD (4) 8,690.67 100.62 93.40 6686.75 6,590]5 -105.29 4,514.63 5,979,949.15 554,070.01 8.41 4,514.63 MWD (4) i 5720.82 100.25 90.69 6,681.28 6,585.28 -105.35 4,544.26 5,979,948.29 554,099.64 8.92 4,544.26 MM (4) 8,749.49 99.52 88.16 6,676.36 6,580.36 -106.07 4,572.50 5,979,948.76 554,127.88 9.06 4,572.50 MWD (4) 8,780.46 99.47 8497 6,671.25 6,575.25 -104.24 4,60299 5,979,95019 554,15835 10.16 4,602.99 MWD (4) 10/Z2018 2:56:36PM Page 3 COMPASS 5000.14 Build 85D Survey MD ConocoPhillips Azi ConocoPhillips Definitive Survey Report +N/ -S Company: ConowPhillips (Alaska) Inc Local Co-ordinate Reference: Well 1 H-21 Project: Kuparuk River Unit TVD Reference: 1 H-21 @ 96.00usft (1 H-21) Site: Kuparuk 1H Pad MD Reference: 1H-21 @ 96.00usft (1H-21) Well: 1H-21 North Reference: True Wellbore: 1H-21 Survey Calculation Method: Minimum Curvature Design: 1H-21 Database: EDT 14 Alaska Production Survey MD Inc Azi TVD TVDSS +N/ -S +El -W Map Map DLS Vertical lush) (1) (1) 08110 (usft) (usft) (usft) Northing Easting (01100') Section Survey Tool Name (ft) (ft) (ft) 8,810.27 100.87 82.58 6,66&99 6,559.99 -101,06 4,632.16 5,979,954.16 554,187.49 9.18 4,632.16 MWD (4) 8,840.72 101.91 84.07 6,659.97 6,563.97 -97.59 4,661.80 5,979,957.83 554,217.11 5.89 4,661.80 MWD(4) 8,870.71 101.81 87.50 6,653.81 6,557.81 -95.43 4,691.07 5,979,960.18 554,246.36 11.20 4,691.07 MWD (4) 8,895.43 100.93 90.75 6,648.93 6,552.93 -95.06 4,715.30 5,979,960.71 554,270.58 13.37 4,715.30 MWD (4) 8,926.07 100.68 93.01 6,643.19 6,547.19 -96.05 4,745.37 5,979,959.92 554,300.66 7.29 4,745.37 MWD (4) 8,955.93 101.81 96.95 6,637.36 6,541.36 -98.59 4,774.54 5,979,957.57 554,329.85 13.48 4,774.54 MM (4) 8,987.30 10002 98.35 6,631.42 6,535.42 -102.69 4,805.07 5,979,95368 554,360,40 7.19 4,805.07 MWD (4) 9,017.09 97.45 96.42 6,626.90 6,530.90 -106.47 4,834.27 5,979,950.09 554,369.62 10.74 4,834.27 MWD (4) 9,046.83 97.07 94.29 6,623.14 6,527.14 -109.23 4,863.64 5,979,947.53 554,419.00 7.22 4,863.64 MWD(4) 9,076.71 95.10 92.22 6,619.97 6,523.97 -11091 4,893.30 5,979,94604 554,44867 9.54 4,893.30 MWD(4) 9,107.22 92.76 90.04 6,617.88 6,521.88 -111.51 4,923.73 5,979,94564 554,479.10 10.47 4,923.73 MWD (4) 9,137.18 92.79 WS5 6,616.43 6,520.43 -110.70 4,95364 5,979,946.65 554,509.00 10.64 4,953.64 MWD (4) 9,166.81 94.11 85.17 6,614.65 6,518.65 -108.84 4,983.14 5,979,948.90 554,538.48 7.20 4,983.14 MWD(4) 9,196.49 96.55 64.39 6,611.89 6,515.89 -105.95 5,012.57 5,979,951.79 554,567.89 8.63 5,012.57 MWD(4) 9,22662 98.32 82.24 6,607.99 6,511.99 -102.48 5,042.24 5,979,955.46 554,597.53 9.20 5,042.24 MWD (4) 9,257.13 9468 82.25 6,604.54 6,508.54 -98.39 5,072.27 5,979,959.75 554,627.54 11.93 5,072.27 MWD(4) 9,287.25 90.25 80.93 6,603.24 6,507.24 -93.99 5,102.03 5,979,964.34 554,657.26 15.35 5,102.03 MWD (4) 9,317.17 92.18 79.27 6,602.61 6,506.61 -88.84 5,131.49 5,979,969.68 554,68669 8.51 5,131.49 MWD (4) 9,346,97 90.68 76.72 6,601.87 6,505.87 -82.65 5,16063 5,979,97607 554,715.78 9.93 5,160.63 MWD (4) 9,376.99 91.87 74.29 6,601.20 6,505.20 -75.14 5,189.69 5,979,983.77 554,744.78 9.01 5,189.69 MWD (4) 9,404.7 91.60 71.57 6,600.38 6,504.38 -67.19 5,215.56 5,979,991.88 554,770.60 10.09 5,215.56 MWD (4) 9,436.86 90.77 68.14 6,599.70 6,503.70 -55.90 5,246.33 5,980,003.38 554,801.30 10.76 5,246.33 MWD (4) 9,468.31 90.83 64.32 6,599.26 6,503.26 -0323 5,275.10 5,980,016.24 554,82998 12.15 5,275.10 MM (4) 9,496.77 90.28 62.04 6,598.98 6,502.99 -30.39 5,300.50 5,980,02924 554,855.29 8.24 5,300.50 MWD (4) 9,525.87 90.95 61.43 6,598.67 6,502.67 -16.61 5,326.13 5,980,043.19 554,880.82 3.11 5,326.13 MWD (4) 9,557.31 89.79 58.26 6,598.47 6,502.47 -0.82 5,353.31 5,980,059.16 558907.90 10.74 5,353.31 MWD (4) 9,589.28 w 60.53 6,598.53 6,502.53 1545 5,380.82 5,980,075.61 554,935.30 7.13 5,380.82 MWD (4) 9,620.85 92.55 6027 6,597.83 6,501.83 31.05 5,408.27 5,980,09139 554,962.64 8.12 5,408.27 MWD (4) 9,655.18 93.04 64.25 6,596.15 6,500.15 47.w 5,438.61 5.980,107.54 554,992.87 11.67 5,438.61 MWD (4) 9,685.43 9040 65.66 6,595.24 6,499.24 59.80 5,466.00 5,980,120.52 555,020.17 9.89 5,466.00 MM (4) 9,719.83 87.57 67.58 6,595.85 6,499.85 73.45 5,497.56 5,980,134.37 555,051.64 9.94 5,497.56 MWD (4) Annotation 1022018 2:56:36PM Page 4 COMPASS 5000.14 Build 850 Survey MD ConocoPhillips A) ConocoPhillips Definitive Survey Report +N/ -S Company: Conocc Philli s (Alaska) Inc. Local Co-ordinate Reference: Well 1'H-2+1 Project: Kuparuk River Unit ND Reference: 1H-21 @ 96.00usft (1H-21) Site: Kuparuk 1 H Pad MD Reference: 1 H-21 @ 96.00usft (1 H-21) Well: 1H-21 North Reference: True Wellbore: 1H-21 Survey Calculation Method: Minimum Curvature Design: 1H-21 Database: EDT 14 Alaska Production Survey MD Inc A) ND NDSS +N/ -S -E/.W Map Map DLS Vertical (usft) (°) (usft) (usft) (usft) (usft) Northing Easting Section Survey Tool Name Annotation (ft) (ft) (°/100) (ft) 9,749]2 86.12 86 68.96 6,59]50 6,501.50 8449 5,525.29 5,980,145.60 555,079.29 6.74 5,52529 MWD (4) 9,779.97 87.67 73.88 6,599.14 6,503.14 94.10 5,553.91 5,980,15540 555,107.85 16.97 5,553.91 MWD (4) 9,810.12 Wile 78.02 6,599.52 6,503.52 101.42 5,583.15 5,980,162.91 555,137.03 17.39 5,583.15 MWD(4) 9,841.89 90.52 81.74 6,599.13 6,503.13 107.00 5,61441 5,980,168.70 555,168.26 11.77 5,614.41 MWD Il) 9,870.82 90.71 84.20 6,598.81 6,502.81 110.54 5,643.12 5,980,17243 555,196.94 8.53 5,643.12 MWD(4) 9,901.13 90.83 88.12 6,598.41 6,50241 112.57 5,67336 5,980,17466 555,227.16 12.94 5,673.36 MWD(4) 9,930.27 91.14 91.84 6,597.91 6,501.91 112.58 5,702.49 5,980,174.86 555,256.28 12.81 5,70249 MWD (4) 9,96083 91.26 94.92 6,597.27 6,501.27 110.78 5,732.98 5,980,173.26 555,286.79 10.08 5,732.98 MM (4) 9,991.88 91.04 99.25 6,596.64 6,500.64 106.95 5,763.78 5,980,169.63 555,317.61 13.96 5,763.78 MWD (4) 10,020.59 9178 102.82 6,595.94 6,499.94 101.46 5,791.95 5,980,164.33 555,345.81 12.70 5,791.95 MWD (4) 10,050.85 9205 106.93 6,594.92 6,498.92 93.70 5,821.17 5,980,156.76 555,375.08 1360 5,821.17 MWD(4) 10,080.40 91.90 110.26 6,593.91 6,497.91 84.28 5,849.16 5,980,147.53 555,403.12 11.27 5,849.16 MWD (4) 10,111.25 93.11 114.01 6,592.56 6,496.56 72.67 5,877.70 5.980,136.11 555,431.74 12.76 5,877.70 MM (4) 10,141.05 92.33 116.39 6,591.14 6,495.14 60.00 5,90463 5,980,123.62 555,458.75 8.40 5,904.63 MWD (4) 10,175.20 93.63 122.24 6,589.37 6,493.37 43.31 5,934.36 5,980,107.13 555,488.58 17.53 5,934.36 MWD (4) 10,201.21 93.10 124.98 6,587.84 6,491.84 28.94 5,955.98 5,980,092.90 555,510.30 10.71 5,955.98 MWD(4) 10,23167 92.77 129.04 6,586.28 6,490.28 1063 5,980.26 5,980,074.76 555,534.70 13.36 5,980.26 MWD (4) 10,260.76 93.25 132.91 6,584.75 6,488.75 -8.41 6,002.19 5,980,05586 555,556.75 13.39 6,002.19 MM (4) 10,290.55 93.47 137.09 6,583.00 6,48].00 -29.44 6,023.22 5,980,034.98 555,577.91 14.03 6,023.22 MM (4) 10,320.61 94.46 135.35 6.580.92 6,484.92 51.09 6,043.96 5,980,013.47 555,598.80 6.65 6,043.96 MWD (4) 10,351.38 94.40 132.25 6,578.55 6,482.55 -72.32 6,066.10 5,979,992.38 555,621.08 10.05 6,066.10 MWD (4) 10,380.91 92.83 133.08 6,576.69 6,480.69 -92.29 6,087.77 5,979,972.56 555,642.88 6.01 6,087.77 MWD(4) 10,410.83 89.85 133.12 6,575.99 6,479.99 -112.73 6,109.61 5,979,95227 555,664.85 9.% 6,109.61 MWD (4) 10,435.86 8748 13292 6,576.57 6,480.57 -129.80 6,12791 5,979,935.32 555,683.25 9.50 6,127.91 MWD (4) 10,470.75 86.43 130.70 6,578.42 6,48242 -153.02 6,153.87 5,979,912.27 555,709.37 7.03 6,153.87 MWD (4) 10,501.79 88.04 12846 6,579.92 6,483.92 -172.78 6,177.77 5,979,892.68 555,733.39 8.88 6,177.77 MAID (4) 10,536.77 90.25 12783 6,58044 6,484.44 -194.38 6,205.27 5,979,871.26 555,761.04 6.57 6,205.27 MWD (4) 10,559.36 9052 125.41 6,580.29 6,484.29 -207.85 6,223.40 5,979.85291 555,779.25 10.76 6,223.40 MWD (4) 10,591.72 91.35 123.35 6,579.76 6,483.76 -226.12 6,250.10 5,979,83982 555,806.07 6.86 6,250.10 MWD (4) 10,620.15 91.29 120.15 6,579.11 6,483.11 -241.08 6,27427 5,979,825.03 555,830.34 11.25 6,274.27 MM (4) 10,650.05 93.72 117.19 6,577.80 6.48180 -255.40 6,30047 5.979,81087 555.856.63 12.80 6,300.47 MWD (4) 10/2/2018 2:56:36PM Page 5 B tV HEE4 COMPASS 5000.14 Build 85D Survey ConocoPhillips Definitive Survey Report Local Co-ordinate Reference: ND Reference: MD Reference: North Reference: Survey Calculation Method: Database: Well 11-1-21 1 H-21 @ 96.00usft (1 H-21) 1H-21 @ 96.00usft (1H-21) True Minimum Curvature EDT 14 Alaska Production MD Inc ConocoPhillips Company:: ConocoPhillips (Alaska) Inc. Project: Kupamk River Unit Site: Kupamk 1 H Pad Well: 1H-21 Wellbore: 1 H-21 Design: 1H-21 Survey ConocoPhillips Definitive Survey Report Local Co-ordinate Reference: ND Reference: MD Reference: North Reference: Survey Calculation Method: Database: Well 11-1-21 1 H-21 @ 96.00usft (1 H-21) 1H-21 @ 96.00usft (1H-21) True Minimum Curvature EDT 14 Alaska Production MD Inc Azi ND NDSS -NI-S +E -W Map Map OLS Vertical/ (usft) (°) (usft) (usft) (usft) (usft) Northing Easting Section Survey Tool Name 94 (ft) (ft) (-/100') (ft) 10,680.76 94.40 113.29 6,575.62 6,479.62 -268.46 6,328.17 5,979,79800 555,884.42 1286 6,328.17 MWD (4) 10,711.25 92.18 107.90 6,573.87 6,4T,87 -279.17 6,356.66 5,979,787.48 555,912.97 19.09 6,356.66 MWD (4) 10,740.89 94.00 105.66 6,572.28 6,476.28 -287.71 6,384.99 5,979,779.13 555,941.35 913 6,384.99 MWD (4) 10,T0.93 9670 105.02 6,569.48 6,47348 -295.62 6,413.83 5,979,77141 555,970.24 9.23 6,413.83 MWD (4) 10,800.95 99.10 104.22 6,565.35 6,469.35 -303.13 6,442.60 5,979,764.09 555,999.06 8.42 6,442.60 MWD (4) 10,831.27 99.69 101.61 6,560.40 6,464.40 -309.81 6,471.75 5,979,757.60 556,028.25 8.71 6,471.75 MWD (4) 10,860.69 98.25 98.04 6.555.81 6,459.81 -314.77 6,500.38 5,979,75284 556,056,91 12.95 6,500.38 MWD (4) 10,890.73 98.11 95.11 6,551.54 6,455.54 318.17 6,529.92 5,979,74963 556,086.47 9.67 6,529.92 MWD (4) 10,921.21 94.98 95.05 6,548.06 6,452.06 -320.85 6,560.08 5,979,747.15 556,116.64 10.27 6,560.08 MWD (4) 10,950.85 94.40 92.88 6,545.64 6,449.64 -322.90 6,589.55 5,979,745.30 556,146.12 7.55 6,589.55 MWD (4) 10,980.93 9040 91.15 6,544.38 6,448.38 -323.95 6,619.57 5,979,744.44 556176.15 1449 6,619.57 MWD (4) 11,010.63 92.43 89.43 6,54365 6,447.65 -324.10 6,649.26 5,979,744.49 556,205,83 8.96 6,649.26 MWD (4) 11,040.70 90.40 85.20 6,542.90 6,446.90 -322.69 6,679.28 5,979,746.09 556,235.84 15.60 6,679.28 MWD (4) 11,070.57 91.54 82.44 6,542.40 6,446.40 -31948 6,708.97 5,979,749.51 556,265.50 10.00 6,70897 MWD (4) 11,095.73 94.39 81.54 6,541.10 6,445.10 -315.98 6,733.85 5,979,753.17 556.290.36 11.88 6,733.85 MWD (4) 11,12800 94.39 81.54 6,53863 6442.63 -311.25 6,765.67 5,979,758.11 556,322.15 0.00 6.765.67 PROJECTED to TD 10/2/2018 2: 56 36P Page 6 eAq(WHEwS Annotation COMPASS 5000.14 Build 85D STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION A {....,, WELL COMPLETION OR RECOMPLETION REPORT AND LOG la.Well Status: Oil❑ Gas❑ SPLUG❑ Other ❑ Abandoned ❑ Suspended❑ 20AAC 25.105 20AAC 25A 10 GINJ ❑ WINJ ❑ WAGE] WDSPL ❑ No. of Completions: 1b. Well Class: Development [2] Exploratory [3 Service ❑ Stratigraphic Test ❑ 2. Operator Name: ConocoPhillips Alaska, Inc. 6. Date Comp., Susp., or Abend.: 9/14/2018 14. Permit to Drill Number / Sundry: 218-079 r 3. Address: P.O. Box 100360 Anchorage, AK 99510-0360 7. Date Spudded: .8/3112018 15. API Number: 50.029-22355-61-00 4a. Location of Well (Governmental Section): Surface: 679' FNL, 793' FEL, Sec 33, T12N, R10E, UM Top of Productive Interval: 787' FNL, 2275' FEL, Sec 34, T12N, R10E, UM Total Depth: 993' FNL, 4587' FEL, Sec 35, T12N, R10E, UM 8. Date TO Reached: •9/512018 16. Well Name and Number: KRU 1H-21AL2 9. Ref Elevations: KB:96 GL:54 BF: 17. Field / Pool(s): Kuparuk River FieldlKuparuk River Oil P 10. Plug Back Depth MD/TVD: NIA 18. Property Designation: . ADL 25639, ADL 25638 4b. Location of Well (State Base Plane Coordinates, NAD 27): Surface: x- 549555 y- 5980024 Zone- 4 TPI: x- 553353 y- 5979942 Zone- 4 Total Depth: x- 556322 y- 5979758 Zone- 4 11. Total Depth MD/TVD: 11128/6539 19. DNR Approval Number: LONS 80-261 12. SSSV Depth MD/TVD: 178911783 20. Thickness of Permafrost MD/TVD: 1629/1626 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: , 7935/6634 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 CASING WT. PER GRADE SETTING DEPTH MD SETTING DEPTH TVD I HOLE SIZE CEMENTING RECORD AMOUNT FT. TOP BOTTOM TOP BOTTOM PULLED 16 62.5 H40 41 121 41 121 24 200 sx PF C Cmt 95/8 36 J55 40 4820 40 4247 12 114 930 sx PERM E, 450 sx Class G 7 26 J55 39 8296 39 6947 8112 299 sx Class G 2 318 4.6 L-80 8452 11128 6730 6539 3 Slotted Liner 24. Open to production or injection? Yes 0 No ❑ If Yes, list each interval open (MD/TVD of Top and Bottom; Perforation Size and Number; Date Perfd): WIA SLOTTED LINER @: �I�11+6 846441128 MD and 67295539 TVD COMPLET ION, Clio)a DATE \/ER- IFEG 25. TUBING RECORD SIZE DEPTH SET (MD) PACKER SET (MD/TVD) 31/2 7693 7664/6453 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. Was hydraulic fracturing used during completion? Yes EJ No [D%4&10 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: WAITING FOR HOOKUP Method of Operation (Flowing, gas lift, etc.): Date of Test: Hours Tested: Production for Test Period Oil -Bbl: Gas -MCF: Water -Bbl: Choke Size: Gas -Oil Ratio: Flow Tubing Press. Casinq Press: Calculated 24 -Hour Rate Oil -Bbl: Gas -MCF: Water -Bbl: Oil Gravity - API (torr): Form 10407 Revised 5/2017 �� CONTINUED ON PAGE 2 t^ RZZ, IVIJ yrt�`� � Clvi J u iJiB Submit ORIGINIAL only 28. CORE DATA Conventional Core(s): Yes ❑ No ❑� Sidewall Cores: Yes ❑ No 0 If Yes, list formations and intervals cored (MD/TVD, From/To), and summarize lithology and presence of oil, gas or water (submit separate pages with this form, if needed). Submit detailed descriptions, core chips, photographs, and all subsequent laboratory analytical results per 20 AAC 25.071. 29. GEOLOGIC MARKERS (List all formations and markers encountered): 30. FORMATION TESTS NAME MD TVD Well tested? Yes ❑ No ❑� If yes, list intervals and formations tested, briefly summarizing test results. Permafrost - Top Surface Surface Permafrost - Base 1629 1626 Attach separate pages to this form, if needed, and submit detailed test Top of Productive Interval 7935 6634 information, including reports, per 20 AAC 25.071. Fornation @ TPI -Kuparuk C Sand TD 11128 6539 Formation at total depth: Ku aruk C Sand 31. List of Attachments: Daily Operations Summary, Definitive Survey, Cement Report, Schematics Information to be attached includes, but is not limited to: summary of daily operations, wellbore schematic, directional or inclination survey, core analysis, paleontolooical report. production or well test results, r 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: William R. LongAuthorized Title: tall CTD Engineer Contact Email: William.R.Lon 000 .corn Authorized Contact Phone: 263-4372 Signature: Date: A 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 IH -21 Proposed CTD Schematic 16" 62e H-40 shoe 121' MD 45/8" 36e JSS shoe 0 4820 MD c.00ns�roP Padw� w rrsA-nro 81® cipswlewe agaym Yews -1598 M0 Gsand parte squeezed W cemend 7788' - 7656' MD 7818' .794F MD F T' 28e J65 shoe @ 8285' MD 31/7' Cemm TRDP=4A-RO SSSV at 1789 MD (2.812') 312" 9.8e J-55 EUE 8rd Tubing to surface 3 W' Cemm MMG gas It mangrel at 2571', 4355', 5143', 5927, 6710', 7183', 7602' Baker }12" PBR M 7&50' MD BakerHB packer at 7664' MD (2.89" ID) D -nipple at 7680• MD (Milled out to 2W) 3-12" Baker BOB @ 7692' MD 1MQ1AN=8]i5'MO IMlgetledege qup • B1V' Mp A... dlel^9315'MO exY KUP PROD 1H-21AL2 Cwvoi:4 Well Attribeb Max Angle' TD __"—^- •-Illlt�' Flela Name —1IW1e APYU- N111 -re 5ne" n'"3 MOIRi Act elm PIKIn Alaska. 1110. KIIPARI IKftIVEft UNIT 500292235561 PROD 102.96 054626 11,1280 ix -P Al]. 16'4101' 1pa9m AM Last Tag VelYal¢timec (xMp Ammmi'ronEnG Last Tag: SLM Dam Sepia("NB) 612612018 8,0620 Lea Moa By lama] . RANGER; 37a— Last Rev Reason Anndeilon Ena mm Loral Mctl er Rev Reason'. Installed Liner Top Packer 91182018 em5eej Casing Strings CONWGTO of -61210 Gaalnp 0ascrlpa0n IOlin) Tap InK01 Sot pop161kNp) Set OepM INDI... WIILan II... Gra]e Top TNreaa AU Liner 120"in, 2318 1.99 8,452.2 111250 460 L -BO STL SAFETYVLv; 1,789' Liner Details Nominal ID 0.LS UFT: z57ps T^p mKpl Top lWD)NAS) Top Incl l°) Inom pee eom fm 8,4522 6,7303 96.24 WHIPSTOCK- Aluminum billet 1.920 ANCHOR BILLET GAS un; 4.ss4e 8,473.6 6.7275 98.50 - Aluminum Billet 1920. ANCHOR BILLET 8,487.9 6,7252 9997 - Aluminum alllel 1.920 ANCHOR SURFACE;,n02AL A4� BILLET aesun:a.lua 8,812.] 8,8655 10095 Deployment ShGM Deployment Sleeve 1.920 Sleeve 14189.1 8,588.5 9335 Deployment SMity Deployment Sleeve 1920 GAS LIn; s,exs Sleeve GAS LIFT: p.M. ..UFT 7.1e27 GV9 LIFT, 1m72 PsA7P 1 Cementaplxm;7 1.9MB PA:o'ER7.WS.9 NMemaditm; vTW Pl.. 7,-0 PLUG. ]... GMT 802: ].M,0-7.81)0 NIPPLE; 7,asus 808; T.ess0 PERF: ].M0-7 ,6A0` PR000GT.. 98.9¢..3 A11 Lmr', 7.930.1 I1,.1a P12 -0i Llrer; ].AB.610aR).0 I PLZ Ulw, 8.653.?11, 1280 KUP PROD HeM N ConocoPhillips Neantvlbne, - ame Alaska, Ind. KUPARDK RIVER UNIT 1H-21 11121, lavm,B l¢7eaag Last Tag Vp,Imle[amnaNc (xlul) M,pp,M Ene wH wpU, Kate) Last Tag: SEM &2812018 8,062.0 tasLMM By lama] Last Rev Reason ...................... ...... HANGER:9].9- AnmM(bn Ene Oa@ Rev Reaam[ Intoe led Liner Tap Packer 911812018 Lael Mctl ey xembaej Casing Strings mins D6nlptlon OD f[) IG llol roPIGKU sal Other UI Set P (TVG1... wuLen ll.. GMe Top Th,eae CONDUCTOR 16 15.06 41.0 1219 121.0 62.50 E'D WELDED L GUCTOR; at. 121.0 Caai„g weCrlpl4n ED(Inl IG(im Top(flNB1 Set wpM (M1N8) ael0epm nVBl... yf4len (I... GraeO Top TbreaO SURFACE 9518 8.92 rU.Z 4,8200 4,221 36.00 J-55 BTC SAFET/VLV 1)x.0 Gesq wwrlpVw, OD(N)) 10 pir Top MKB) Srt DepN MKIB Set DI m1s) IMI -en (L -Grant Tap Thread PRODUCTION ] fi28 38.9 8,296.3 6,920 26.00 J-55 AB -MOD Tubing Strings RPinp Oes[ription String Ma... 10 (Inl iop (a") Set OepM (N.. SN wplh (TVD) (_ _ - ate) TUBING 3112 2.99 37.6 ],6929 6,4]5.2 9.30 Grade Top Cannmti R J-55 EUE8RDMOD Completion Details GASUR:2a2Ds rav Tw I TOPlncl TOPUteeg (RN BI (°) Nem Des com Nominel 101in1 .a UP.4... 37.6 3>fi 0.13 1 HANGER FMC GEN IV HANGER 3.500 178. 7.183.2 14.33 SAFETY VLV CAMCO TRDP4A430 SAFETY VALVE 2812 7,65 1 6,4419 BAKER PER 10 STROKE( HAS V2 RH 3900 SQUARE THREAD FOR PKR RETRIEVAL) 7,6639 6,452.7 3900 PACKER BAKER HB RETRIEVABLE PACKER 2.890 7,680.3 6,465.4 39.01 NIPPLE CAMCODNIPPLIENOGO IMIIIed0U1b2.30°]112/2018) 2.800 7,692.0 6,474.5 39.00 505 BAKER SHEAR OUT SUB 3.015 SURFACE: 40.N.=4� Other In Hole (Yinline retrievable plugs, valves, pampa, fish, etc.) Tap MEr Tap Ina roptft BI (G g rl ws com RunDM ID(In) Gras UFT:e,tala 7860.0 6,449.fi 3900 PLUG Cement Plug )/12/2018 0000 >,8260 6,5]BJ 386fi ignExpansion NorNem SOWtions High Expansion Waage 8119/2018 0000 GAS LIFT Baha Wedge Perforations d Slots SGa ILEO RSB Shd Den Top(We) Earn (GAS) TWTVDI (WE) ater" (KKBI I Un4M Lone wte bhahT I TYPo Cam 7,675.0 ],677.0 646TJ ,462.8 7/112018 3.0 CMTSQZ 2"Powerrow, sal 120 GAa uR'. T.tR) deg phasing ],768.0 )8580 6,533.5 037 UNIT D, &1611993 6.0 (PERE 2118" EneOeL deg. 3,1H-21 Phasing 7,918.0 79489 6.650] 6. Jd.2 1, UNI &2811993 29 PERE W54.5"HJ seg. -21 Phasing Cement Squeezes rap PVD) Ban DI Top(XKS) Btm IflKO) (NKB) Pass) On --d Gate Com Ger LIR: 1.6012 7,6W9 8,088.0 6,452.6 784.1 amen( 7114/2018 Spheres Mandrel Inserts St PBR; 7650 Cmma4u PACKER 7MS9 PACKER',)PA.B an Tap RVD) Ve1ve G1ch pdrlSW TRO sun N Tap.57 (2.49 M.G. Madel OD (In) SLIF Type Typo IM) soap Run Dent Gm 2.5] 5 2,495.5 CAM KBUG 1 GAS LIFT GLV BN5 0.1 1,2710 &112018 2 4,3549 3,8911.4 CAM KBUG 1 GAS LIFT OV BK5 0.25 e0 81112018 xmm,satimsonmiw PCW'. Tema 3 5,14. 1,4957 CAM KBUG 1 GAS LIFT DMV BKS 11000 00 6151200] 4 S 21.9 5,0899 AM 0 KBUG 1 GASLIFT DMY BK5 11.000 00 8151200] PLVO:L030.o CMT 802; 76156],BJIO 5 6,709.9 5,]02.6 CAMCO KBUG 1 GAS LIFT DMY BK5 11.000 00 SI13I1999 6 7,182] 6,0749 CAM 0 KBUG 1 IGAS LIFT DMY BK5 0.000 0 511311999 7 7602.2 64047 CAMCO MINI 1 12 GASLIFT DMY RK 0000 00 7,18/1993 NIPPLE; 7.63 Notes• General S Safety End sateAnnop,bn 9/272010 NOTE: Vim Schematic wl Alaska Schemer 0 INS. 7,W20 IPERP 7,78NP7,Na60L- Aua1 IDoa:768e8-10,5010 Nan PAe,�[^ we,ga; 7,us.D IP 7.910LL],s4I PRODUCTION: 3A682W.3 Operations Summary (with Timelog Depths) 1H-21 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log start Depth shut start Tine End Time Dar N ( ) Phase Op Code AclNity Code Tme P -T-% Operation End Depth (flKa) 8/17/2018 8/18/2018 12.00 MIRU MOVE MOB P Demob off 3H - Tucks on location @ 0.0 0.0 12:00 00:00 16:00. Leave 3H pad 18:30, Arrive 1 H 24:00 8/18/2018 8/18/2018 5.00 MIRU MOVE MOB P On 1H pad, Remove jeeps. Prep cellar 0.0 0.0 00:00 05:00 for spotting rig. Spot rig. Work rig up check list. 8/18/2018 8/18/2018 4.00 MIRU MOVE RURD P Safe out all landings and stairs, call 0.0 0.0 05:00 09:00 out scaffold for wellhead platform, call grease crew, c/o stem seal on B1 8/18/2018 8/18/2018 2.00 MIRU MOVE RURD T Operations limited due to rig issues on 0.0 0.0 09:00 11:00 same pad ***Note: Rig Accept time 0900- 8/18/2018 8/18/2018 1.00 MIRU WHDBOP NUND P NIU BOP 0.0 0.0 11:00 12:00 8/18/2018 8/18/2018 2.00 MIRU WHDBOP BOPE P Start BOP test, low 250 psilhigh 3000 0.0 0.0 12:00 14:00 psi/annular 2500 psi, test waived by Guy Cook (AOGCC) 8/18/2018 8/18/2018 1.50 MIRU WHDBOP PRTS T Problems with swab valve, call out 0.0 0.0 14:00 15:30 grease crew again 8/18/2018 8/18/2018 5.50 MIRU WHDBOP BOPE P Continue with BOP test, Fail / Pass on 0.0 0.0 15:30 21:00 C2, C1. Fail and replace R1, End of BOPE test 8/18/2018 8/18/2018 2.00 MIRU WHDBOP PRTS P Pressure test PDL's and TT line. 0.0 0.0 21:00 23:00 Install night rap and bleed off WHIP. Started at 480 PSI. Blled down in steps to zero. Observe well. Dead for ten minutes pressure slowly rising. Bleed and watch. Go to pressure deployment ops for Whipstock 8/18/2018 8/19/2018 1.00 PROD1 RPEQPT PULD P PJSM, M/U BHA#1 with high 0.0 0.0 23:00 00:00 expansion whip stock 8/19/2018 8/19/2018 1.00 PROD1 RPEQPT PULD P Continue pressure deployment BHA 0.0 73.5 00:00 01:00 #1 NS HEW Whipstock, Make up to coil and surface test. Inspect pack offs 8/19/2018 8/19/2018 1.50 PROD1 RPEQPT TRIP P RIH BHA#1, EDC open pumping min 73.5 7,565.0 01:00 02:30 rate on seawater. Returns to TT 8/19/2018 8/19/2018 0.20 PROD1 RPEQPT DLOG P Log K1 marker for+2.5' 7,565.0 7,595.0 02:30 0242 8/19/2018 8/19/2018 0.40 PROD1 RPEQPT DLOG P Trip into 7650 run CCL log down to 7,595.0 7,850.0 02:42 03:06 7850 8/19/2018 8/19/2018 0.30 PRODi RPEQPT TRIP P PUH to whipstock setting depth @ 7,850.0 7,833.7 03:06 03:24 7833.7, TOWS @ 7825. His Orientation. Set whipstock. See tool shift - 2300PSI. Set down 2.5K - Good 8/19/2018 8/19/2018 1.70 PROD1 RPEQPT TRIP P PUH to 7819. Open EDC Flush well @ 7,833.7 74.0 03:24 05:06 2 BPM, Start tripping out 6/19/2018 8/19/2018 0.50 PROD1 RPEQPT - PULD P Tag up at surface, check well for Flow 74.0 74.0 05:06 05:36 (no -flow) 8/19/2018 8/19/2018 1.00 PROD1 RPEQPT PULD P LD setting tools on a dead well 74.0 0.0 05:36 0636 8/19/2018 8/19/2018 0.30 PRODi WHPST PULD P PJSM, PD window milling BHA#2 0.0 76.9 06:36 06:54 8/19/2018 8/19/2018 0.20 PRODt WHPST PULD P Stab INJH, surface test Coiltrak tools, 76.9 76.9 06:54 07:06 (good -test), check pac-offs (good) 8/19/2018 8/19/2018 1.40 PROD? WHPST TRIP P Tag up, reset counters to zero, RIH 76.9 7,565.0 07:06 08:30 1 1 with window milling BHA #2 8/19/2018 8/19/2018 0.20 PROD1 WHPST DLOG P Log the Kt marker correction of plus 7,565.0 7,600.0 08:30 08:42 1 1 1 1.5' 6/19/2018 8/19/2018 0.60 PROD1 WHPST DISP P Finish displacing well to milling fluid 7,600.0 7,600.0 08:42 09:18 I Page 1130 ReportPrinted: 911 912 01 8 Operations Summary (with Timelog Depths) IH -21 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Time End Time Dur(hr) Phase Op code Acltmt Cotle y Time P -T- X operation Sart Depth (flKB) End Depth (ftKa) 8/19/2018 8/19/2018 0.20 PROD? WHPST TRIP P Continue IH, dry lag TOHEW (TOWS), 7,600.0 7,827.7 09:18 09:30 HEW 7827.3' 8/19/2018 8/19/2018 0.50 PROD1 WHPST TRIP P PUW 45 k, no pumps, bring pump on- 7,828.7 7,828.7 09:30 10:00 line, RIH 1.0' past TOWS, PUH, shut down pump, RBIH to confirm dry tag HEW pinch point. 7828.7'. 8/19/2018 8/19/2018 2.00 PROD1 WHPST MILL P PUH, and bring pump on line get 7,828.7 7,833.2 10:00 12:00 parameters, begin milling window @ 1 fph, 1.81 bpm at 4,056 psi, BHP=3,629, WHP=419, IA=O, OA=48. - Note: Center of the mill out of casing 7,831.2' 8/19/2018 8/19/2018 3.50 PROD1 WHPST MILL P Continue milling window off of 7,833.2 7,846.0 12:00 15:30 Northern Solutions HEW WS, 1.81 bpn at 4,000 psi, WHP=O, BHP=3,610, ]A=O, OA=50 *** Note: BOW @ 7,832' 8/19/2018 8/19/2018 0.10 PROD1 WHPST TRIP P TD rat hole 21' from TOWS, pull up 7,846.0 7,829.0 15:30 15:36 1 hole, PUW 45 k 8/19/2018 8/19/2018 0.80 PRODt WHPST REAM P Ream window area from 7,844'-7,829' 7,829.0 7,846.0 15:36 16:24 8/19/2018 8/19/2018 0.20 PROD1 WHPST REAM P Dry drift window area 7,814'to TD 7,846.0 7,846.0 16:24 16:36 7,846' 8/19/2018 8/19/2018 1.00 PROD1 WHPST TRIP P POOH, pumping 1.81 bpm 7,846.0 83.0 16:36 17:36 8/19/2018 8/19/2018 1.40 PRODt WHPST PULD P At surface, Flow check Lay down 83.0 0.0 17:36 19:00 window milling BHA on dead well. Mill out @ 2.79 Go. 2.80" NoGo. 8/1912018 8/19/2018 0.60 PROD1 DRILL PULD P M/U BHA#3 with RB HCC Bi center, 0.0 72.2 19:00 19:36 2.3+° AKO motor, and USR, M/U to coil and surface test. - Good 8/19/2018 8/19/2018 1.60 PROD1 DRILL TRIP P Trip in well, EDC open pumping min 72.2 7,565.0 19:36 21:12 rate. 8/19/2018 8/19/2018 0.10 PROW DRILL DLOG P Log K1 for for +1' 7,565.0 7,586.0 21:12 21:18 8/19/2018 8/19/2018 0.40 PROD1 DRILL TRIP P Continue in well, @ 7810 perform 1 to 7,586.0 7,846.0 21:18 21:42 1 pressure test. Pump 1.78 BPM, BHP=3633, WHP=O with open choke. ECD=10.7 PPG. Shut down pump. Close EDC. Clean pass through window, Tag up and drill from 7846 8/19/2018 8/19/2018 1.60 PROD1 DRILL DRLG P 7846', Drill, 1.74 BPM @ 3751 PSI FS, 7,846.0 7,912.0 21:42 23:18 BHP=3648 8/19/2018 8/19/2018 0.10 PROD1 DRILL WPRT P BHA wiper/weight check, PUW=50K 7,912.0 7,912.0 23:18 23:24 8/19/2018 8/20/2018 0.60 PROD1 DRILL DRLG P 7912', Drill, 1.75 BPM @ 3788 PSI 7,912.0 7,930.0 23:24 00:00 FS, BHP=3660 8/20/2018 8/20/2018 3.80 PRODt DRILL DRLG P 7930', Drill 1.75 BPM @ 3788 PSI FS, 7,930.0 8,054.0 00:00 03:48 BHP=3660 8/20/2018 8/20/2018 0.20 PROD1 DRILL WPRT P 8054 BHA Wiper trip, PUW=50K, 8,054.0 8,054.0 03:48 04:00 RIW=17.5K 8/20/2018 8/20/2018 3.20 PROD1 DRILL DRLG P8054', Drill 1.76 BPM @ 3970 PSI FS, 8,054.0 8,150.0 04:00 07:12 BH 1=3694 8/20/2018 8/20/2018 1.50 PROD1 DRILL TRIP P ITO Build Section, 10x10 sweep, 8,150.0 73.0 07:12 08:42 POOH 8/20/2018 8/20/2018 0.70 PROD1 DRILL PULD P Tag up, space out, PUD build section 73.0 73-0- 08:42 09:24 BHA#3 Page 2130 ReportPrinted: 9/19120181 Operations Summary (with Timelog Depths) IH -21 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log I Start Depth Start Time End Time Dur (M Phase Op Code Activity Code cane PJA Operation (ftKB) End Depth(PKB) 8/20/2018 8/20/2018 0.80 PROD1 DRILL PULD T -BHA hung up in well, trouble pulling 73.0 73.0 09:24 10:12 High Bend motor with SL, line up to pump thru the kill line and tango's, no success, close rams, bleed pressure from PDL, unstab, hook up suface power to tools, rotate TF 90" Left. Work tools free 8/20/2018 8/20/2018 0.70 PROD1 DRILL PULD P Continue PUD 73.0 0.0 10:12 10:54 8/20/2018 8/20/2018 1.20 PROD1 DRILL PULD P PJSM, PD lateral drilling BHA #4 0.0 78.2 10:54 12:06 w/0.5`- ako motor/ NOV Agitator 8/20/2018 8/202018 1.30 PROD1 DRILL TRIP P RIH, 568'test Agitator (great -test) 78.2 7,565.0 12:06 13:24 8/20/2018 8/20/2018 0.20 PROD1 DRILL DLOG P Log the K1 correction of plus 1.5' 7,565.0 7,593.0 13:24 13:36 8/20/2018 8/20/2018 0.10 PROD1 DRILL TRIP P Continue IH, 7,593.0 7,845.0 13:36 13:42 8/20/2018 8202018 0.10 PROD1 DRILL DLOG P Log the RA @ 7833.5' 7,845.0 81150.0 13:42 13:48 6/20/2018 8/202018 5.30 PROD1 DRILL DRLG P BOBD, 1.79 bpm @ 4,400 psi, 8,150.0 8,577.0 13:48 19:06 Diff --1,250, WHP=open choke, BHP=3,813, IA=O, OA=51 8/20/2018 8/20/2018 0.50 PROD1 DRILL WPRT P Wiper to the window, PUW 51 k 8,577.0 7,900.0 19:06 19:36 8/20/2018 8/202018 0.50 PROD1 DRILL WPRT P Wiper back in hole, RIW 17 k 7,900.0 8,577.0 19:36 20:06 8/20/2018 8/20/2018 2.70 PROD1 DRILL DRLG P BOBD, 1.80 bpm @ 4,245, Diff --1,230 8,577.0 8,950.0 20:06 22:48 psi, WHP=open choke, BHP=3,780, IA=208, OA=59 8/20/2018 812012018 0.50 PROD1 DRILL WPRT P Wiper up to the window, PUW 60 k 8,950.0 7,565.0 22:48 23:18 8/2012018 8/20/2018 0.20 PROD1 DRILL DLOG P log the K1 marker correction of plus 7,565.0 7,589.0 23:18 2330 5.0' 8/20/2018 8/20/2018 0.30 PROD1 DRILL WPRT P Continue IH, Jog the 7", 7,700'-7,815', 7,589.0 7,815.0 23:30 23:48 dosed EDC, 8/20/2018 8/21/2018 0.20 PROD1 DRILL WPRT P Continue wiper back in hole, Tough 7,815.0 7,880.0 23:48 00:00 spot 7880. Multiple setdowns with clean pickups, PUW=62K. Worked through Q .5 BPM 10 FPM. Continue to bottom 8/21/2018 8/21/2018 0.60 PROD1 DRILL WPRT P Continue wiper trip back to bottom 7,880.0 8,951.0 00:00 00:36 8/21/2018 8/21/2018 1.00 PROD1 DRILL DRLG P 8951', Drill, 1.78 BPM @ 4456 PSI 8,951.0 9,119.0 00:36 01:36 FS, BHP=3780PSI, RIW=18.5K 8/21/2018 8/21/2018 0.10 PROD1 DRILL WPRT P BHA Wiper, PUW=60K 9,119.0 9,119.0 01:36 01:42 8121/2018 8/21/2018 1.70 PROD1 DRILL DRLG P 9119', Drill, 1.78 BPM @ 4425 PSI FS, 9,119.0 9,325.0 01:42 03:24 BHP=3838 8/21/2018 8/21/2018 0.70 PRODi DRILL WPRT P Pull 800' wiper, PUW=70K, 10K 9,325.0 9,325.0 03:24 04:06 overpulis @ 8890, 8690, & 8570. Clean on way in 8/21/2018 8/21/2018 3.80 PROD1 DRILL DRLG P 93251, Drill, 1.79 BPM (off 4480 PSI 9,325.0 9,745.0 04:06 07:54 FS, BHP=3781 8121/2018 8/21/2018 1.10 PRODi DRILL WPRT P Wiper to window, work through tight 9,745.0 7,050.0 07:54 09:00 area 8088 to 8196 8/21/2018 8/212018 0.90 PROD1 DRILL WPRT P Pull into 7", recip and jet, pump 7,050.0 7,845.0 09:00 09:54 sweeps, circ to surface, RBIH, set down at 7828, TOW, PUH spin bit, set down 7786. Go through window 8/21/2018 8/21/2018 0.10 PROD1 DRILL DLOG P Log RA for+7' 7,845.0 7,870.0 09:54 10:00 Page 3/30 Report Printed: 911912018 Operations Summary (with Timelog Depths) "M 1 H-21 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log SW De� SW Start Tim End Tune Our (hr) Phase Op Cade ACEviry Code 7xna P -T -X Operation (OK End DeW (W8) 8/21/2018 8/21/2018 1.10 PROD1 DRILL WPRT P Continue in hole, initial set down @ 7,870.0 7,896.0 10:00 11:06 7871 work down to 7888. multiple setdowns to 7896, Unable to pass 7896 at different speeds and pump rates. Back ream up at 180° still unable to pass. 8121/2018 8/21/2018 0.60 PROW DRILL WPRT P Pull up hole to rased pipe. Circ 7,896.0 7,839.0 11:06 11:42 bottoms up. Check shaker. Nothing there. Discuss plan forward 8/21/2018 8/21/2018 1.40 PROD1 DRILL TRIP T Trip out for clean out BHA 7,839.0 84.0 11:42 13:06 8/21/2018 8121/2018 1.40 PROD1 DRILL PULD T PJSM, PUD BHA #4 84.0 0.0 13:06 14:30 8/21/2018 8/21/2018 0.90 PROD1 DRILL PULD T PJSM, PD BHA#5 with 1.5°AKO 0.0 68.3 14:30 15:24 motor, D-331 with rigdge set cutter, and agitator, Make up to coil and surface test. Check packoffs, Tag up 8/21/2018 8/2112018 1.10 PROD1 DRILL TRIP T RIH BHA#5, Surface test agitator @ 68.3 7,565.0 15:24 16:30 500% open EDC and continue in 8/21/2018 8/21/2018 0.50 PROD1 DRILL TRIP T Tie in to K1 marker, RIH 7,565.0 7,860.0 16:30 17:00 8/21/2018 8/21/2018 1.60 PROD1 DRILL TRIP T stacked out twice, able to work 7,894.0 8,490.0 17:00 18:36 through, increase pump rate, rih to stall, continue to work area, clean at 7896, rih to 8490 8121/2018 8/21/2018 1.50 PROD! DRILL TRIP T pumped bottoms up sweep, puh to 7", 8,490.0 7,858.0 18:36 20:06 taking 3 cleaning passes, attempt to dry drift through trouble area 7840 to 7858, online, continue to tag at different depths each time. 8/21/2018 8/21/2018 2.90 PROW DRILL TRIP T pump bottoms up and dean area 7,858.0 7,820.0 20:06 23:00 above problem area, rbih at full pump speed, tagged several times in same area (7840-7950) continue to pump sweeps and by to clean trouble area 8/21/2018 8/22/2018 1.00 PROD1 DRILL TRIP T puh to above window, circ buttoms up, 7,820.0 7,840.0 23:00 00:00 attempt to drift back through window, sveral time tagging at top of window, orient 15 degrees left, now able to drift window, online with pumps at full rate, rih. 8/22/2018 8/22/2018 2.00 PROD1 DRILL TRIP T RIH at full pump rate, still tag several 7,820.0 7,820.0 00:00 02:00 time, rih to 8450, pump sweeps, pun into the 7"gain, rbih smooth other then one tag at 7858, rih to 8450 again, puh to window. 8/22/2018 8/22/2018 2.00 PROD1 DRILL TRIP T rih and tagged at top of whip stock, 7,820.0 8,450.0 02:00 04:00 puh to tie in, +7.5 It, rbih, small tag at window, rih with full pump rate, mill through small tag at 7890, rih continue to work area. PUH above window, dry drift to 8000, no tags, online full rate, On to 8450, start trip run for inflatable. 8/2212018 8/22/2018 1.30 PROD1 DRILL TRIP T POOH, one overpull at top of window 8,450.0 68.0 04:00 0518 on bit, fill appears to be cleaned out, POOH 8/22/2018 8/22/2018 1.50 PROD1 DRILL PULD T PJSM, PUD BHA#5 68.0 0.0 05:18 06:48 8/22/2018 8/22/2018 1.20 PROD1 DRILL PULD T PD BHA#6 2 1/8" Inflatable plug, M/U 0.0 68.0 06:48 08:00 to coil and surface test tool -All good, Check pack offs 8122/2018 8/22/2018 1.70 PROD1 DRILL TRIP T RIH BHA #6IFC plug 68.0 7,565.0 08:00 09:42 Page 4130 Report Printed: 9119/2018 Operations Summary (with Timelog DeNths) 1 H-21 li p Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log SrartTima Enc Thne D r (hr) Phase Op Cotle Activity Code Tne P -T -X Opera Stan Depth (ftKB) End Oepth (110) 8/22/2018 8/22/2018 0.10 PROW DRILL DLOG T Log K1 for+1.5' 7,565.0 7,591.0 09:42 09:48 8/22/2018 8/22/2018 0.50 PROD1 DRILL TRIP T Continue in hole. Stop and shut EDC 7,591.0 8,450.0 09:48 10:18 @ 7771. Clean pass through window, Clean trip down to 8450 8/22/2018 8/22/2018 0.60 PROD1 DRILL OTHR T At septh depth, Pull stretch out of coil. 8,450.0 8,450.0 10:18 10:54 Slowly pressure up inflatable to 1500 PSI. wait ten minutes. Bring pumps online @ 1700 PSI pressure falls off and we are circulating. Packer will not pressure up. able to move packer up and down hole. Attemp pumping Faster. No pressure 8/22/2018 8/22/2018 2.00 PRODi DRILL TRIP T Trip out with BHA #6 8,450.0 71.0 10:54 12:54 8/222018 8/22/2018 1.10 PROD1 DRILL PULD T At surface, Tag up and space out, 71.0 0.0 12:54 14:00 PUD BHA#6. Element is damaged on inflatable packer. Pictures on S drive. Lay down packer 8/22/2018 8/22/2018 1.30 PROD? DRILL OTHR T Discuss options and alternatives. 0.0 0.0 14:00 15:18 Formulate plan forward 8/2212018 8/22/2018 1.00 PROD1 DRILL PULD T M/U BHA #7.1° WFT motor and 2.80 0.0 65.3 15:18 16:18 1 crayola mill to dress window 8/22/2018 8/22/2018 2.00 PROW DRILL TRIP T Trip in hole 65.3 7,555.0 16:18 18:18 8/22/2018 8/222018 0.10 PROD1 DRILL TRIP T K1 tie, =1 , Close EDC, rih 7,555.0 7,555.0 18:18 18:24 8/22/2018 8/22/2018 1.80 PROW DRILL MILL T rih to 7829, dress window several time 7,555.0 7,833.0 18:24 20:12 with 2.79 crayola mill and dry drift per plan forward 8/22/2018 8/22/2018 1.20 PROD1 DRILL TRIP T Trip out of hole for BHA#8 inflatable 7,833.0 71.0 20:12 21:24 plug. 8/22/2018 8/22/2018 1.20 PRODt DRILL PULD T At surface, Tag up and space out, 71.0 0.0 21:24 22:36 PUD BHA#7. 822/2018 8/232018 1.40 PROD1 DRILL PULD T PD BHA #8 2.5" Inflatable plug, M/U to 0.0 71.0 22:36 00:00 coil and surface test tool -All good, Check pack offs 8/23/2018 8/23/2018 1.90 PROD1 DRILL TRIP T trip in hole with BHA #8 71.0 7,555.0 00:00 01:54 8/23/2018 8/23/2018 0.20 PROD1 DRILL DLOG T tie into K1, +1 correction 7,555.0 7,587.0 01:54 02:06 8/23/2018 823/2018 1.60 PRODt DRILL OTHR T tagged up at 8368, 1ft short, Pull 7,587.0 8,368.0 02:06 03:42 stretch out of coil. Slowly pressure up inflatable to 1500 PSI. wait ten minutes. Bring pumps online, continue to pressure up to shear at 2300 psi over circ psi, pull 18k over window pu wt, shear off inflatable. 8/23/2018 8/23/2018 1.50 PROD1 DRILL TRIP T POOH 8,368.0 68.0 03:42 05:12 8/23/2018 823/2018 1.50 PROD1 DRILL PULD T Tag up and space out, PJSM PUD 68.0 0.0 05:12 06:42 1 1 1 BHA#8 Packer running tools 823/2018 8/23/2018 1.00 PRODt DRILL PULD T PD BHA#9 OH anchored billit. M/U to 0.0 72.9 06:42 07:42 coil track and surface test tool, Check packoffs 8/23/2018 8/23/2018 1.70 PROD1 DRILL TRIP T RIH BHA#9 72.9 71565.0 07:42 09:24 8/23/2018 8/23/2018 0.20 PROD! DRILL DLOG T Log K1 for+1' correction 7,565.0 7,603.0 09:24 09:36 Page 5/30 Report Printed: 911912018 Operations Summary (with Timelog Depths) 1 H-21 liplk Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Sten Time Ertl Time Dw (hr) Phase Op Coda Activity Code Tore P -T-% Operation Steil Depth MXB) End Depth (ftKB) 8/2312018 823/2018 0.50 PROD1 DRILL TRIP T Continue in hole, Shut EDC @ 7756. 7,603.0 8,327.0 09:36 10:06 Clean pass through window and down to 8327, Set whipstock @ 210° TOWS @ 8315, See tool shift @ 5111, Set down 2K 8/23/2018 8/23/2018 1.70 PROD1 DRILL TRIP T POOH, PUW=53K 8,327.0 74.0 10:06 11:48 8/23/2018 823/2018 1.10 PROD1 DRILL PULD T At surface, Tag up and space out, 74.0 0.0 11:48 12:54 PUD BHA#9 Anchor billet setting tools 8/23/2018 8/23/2018 1.00 PROD2 STK PULD P PD BHA#10 from Pre loaded PDL 0.0 80.5 12:54 13:54 with .5-AKO motor, Strider agitator, and new HCC bi-center bit with Dynamus cutters. 8/2312018 8/23/2018 1.70 PROD2 STK TRIP P Trip in hole, Shallow test Strider tool 80.5 7,565.0 13:54 15:36 1 @ 500', Continue in well. 8/23/2018 8/23/2018 0.10 PROD2 STK DLOG P Log Kt for +1' correction 7,565.0 7,594.0 15:36 15:42 8/23/2018 823/2018 0.40 PROD2 STK TRIP P Continue in well, Dry tag TOB @ 7,594.0 8,315.0 15:42 16:06 8315', PUH, PUW=54 8/23/2018 8/232018 1.90 PROD2 STK KOST P Pumps on 1.83 BPM @ 4286 PSI FS, 8,315.0 8,318.0 16:06 16:00 BHP=3742. Start milling off billet @ 8315.3. Mill per procedure 812312018 8/23/2018 2.00 PROD2 DRILL DRLG P 8318', Drill, 1.70 BPM @ 4145 PSI 8,318.0 8,421.0 18:00 20:00 FS, BHP=3724 - 8/23/2018 8/232018 0.20 PROD2 DRILL DRLG P PU to 8160 and dry drift billet 8,421.0 8,421.0 20:00 20:12 8/23/2018 8123/2018 2.00 PROD2 DRILL DRLG P 8421', Drill 1.72 BPM @ 4376 PSI FS, 8,421.0 8,546.0 20:12 22:12 BHP=3945 8/23/2018 8/23/2018 0.20 PROD2 DRILL WPRT P PU to lower flow and try to get through 8,546.0 8,546.0 22:12 22.24 stringer, srart mu swap 812312018 8/24/2018 1.60 PROM DRILL DRLG P 8546' Drill 1.60 BPM @ 4368 PSI FS, 8,546.0 8,662.0 22:24 00:00 BHP=4176, trouble getting direction to drop 8/24/2018 8/24/2018 1.50 PROD2 DRILL DRLG P 8662' Drill 1.60 BPM @ 4358 PSI FS, 8,662.0 8,690.0 00:00 01:30 BHP=4192 still having trouble getting direction to drop, consult with town, decission made to trip for BHA. 8/24/2018 8/24/2018 1.90 PROD2 DRILL TRIP T Trip for BHA 8,690.0 69.0 01:30 03:24 82412018 8/24/2018 1.10 PROD2 DRILL PULD T Tag up and space out, PJSM, PUD 69.0 0.0 03:24 04:30 BHA#10 8/24/2018 8/24/2018 1.00 PROD2 DRILL PULD T PD BHA#11 with .7°AKO motor, M/U 0.0 80.5 04:30 05:30 to coil and surface test 8/24/2018 824/2018 1.40 PROD2 DRILL TRIP T Trip in BHA# 11, Test agitator @ 500', 80.5 7,565.0 05:30 06:54 Continue in well 8/24/2018 8/24/2018 0.10 PROD2 DRILL DLOG T Log K1 for+2.5' 7,565.0 7,593.0 06:54 07:00 8/24/2018 8/24/2018 0.70 PROD2 DRILL TRIP T Continue in well, Stop at 7807 for 7,593.0 8,690.0 07:00 07:42 static, Annular pressure = 4200 PSI, 6524.6 TVD, 12.385 EMW. Continue in. Clean pass through window 824!2018 8/24/2018 2.50 PROD2 DRILL DRLG P 8690', Drill, 1.81 BPM @4577 PSI FS, 8,690.0 8,863.0 07:42 10:12 BHP=4429 8/24/2018 8/24/2018 0.70 PROD2 DRILL WPRT P 8863, Pull wiper to window with 8,863.0 7,805.0 10:12 10:54 sweeps. Pull up through window and jet 7" 8/24/2018 824/2018 1.00 PROD2 DRILL PRTS P 7805 Obtain static pressure, Bleed 7,805.0 7,805.0 10:54 11:54 down AP to 3800 PSI in three steps. Climbed from 3800 to 3905 in 30 minutes. 6523.1 TVD, 11.51 EMW 8/24/2018 8/24/2018 0.50 PROD2 DRILL TRIP PContinue wiper trip back to bottom. 7,805.0 8,862.0 11:54 12:24 Clean Page 6130 Report Printed: 9/19/2018 Summary (with Timelog Depths) 1 H-21 lipOperations Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log arartn End Time ( r) Duh Phase O Cotle p ActiN Cotle b Time P -T- X Operation Start Depth (aKB) End Depen (aKB) 8/24/2018 8/24/2018 2.40 PROD2 DRILL DRLG P 8862', Drill, 1.79 BPM @ 4232 PSI 8,862.0 8,985.0 12:24 1448 FS, BHP=4101 8/24/2018 8/24/2018 0.10 PROD2 DRILL WPRT P Pull mini wiper, PUW=55K 8,985.0 8,985.0 14:48 14:54 8/24/2018 8/24/2018 2.90 PROD2 DRILL DRLG P 8985', Drill, 1.79 BPM @ 4254PSI FS, 8,985.0 9,098.0 14:54 17:48 BHP=4084 8/24/2018 8124/2018 0.20 PROD2 DRILL WPRT P Pull mini wiper, PUW=55K 9,098.0 9,098.0 17:48 18:00 8/24/2018 8/24/2018 4.00 PROD2 DRILL DRLG P 9098', Drill, 1.79 BPM @ 4254PSI FS, 9,098.0 9,260.0 18:00 22:00 1 BHP=4084 8/24/2018 8/24/2018 0.90 PROD2 DRILL WPRT P wiper trip to 8460, PU wt 55k 9,260.0 9,860.0 22:00 2254 1 8/24/2018 8/25/2018 1.10 PROD2 DRILL DRLG P 9260', Drill, 1.80 BPM @ 4480 PSI 9,260.0 9,310.0 22:54 0000 FS, BHP=4100 8/25/2018 8/25/2018 3.00 PROD2 DRILL DRLG P 9310', Drill, 1.80 BPM @ 4480 PSI 9,310.0 9,414.0 00:00 0300 FS, BHP=4100 8/25/2018 8/25/2018 0.20 PROD2 DRILL WPRT P Wiper trip to 9314', PU WT 59K 9,414.0 9,414.0 03:00 03:12 8/25!2018 8/25/2018 PROD2 DRILL DRLG P 9414', Drill, 1.80 BPM @ 4430 PSI 9,414.0 9,467.0 03:12 03:12 FS, BHP=4138 8/25/2018 8/25/2018 1.50 PROD2 DRILL DRLG P 9467, motor stall, puh, .90 bpm =4356 9,467.0 9,467.0 03:12 04:42 circ psi, unbable to clear bit, rih to tag 8/25/2018 8/2512018 3.20 PROD2 DRILL TRIP T POOH for motor swap 9,467.0 75.0 04:42 07:54 8/25/2018 8/25/2018 2.10 PROD2 DRILL PULD T Tag up space out, PJSM PUD BHA 75.0 0.0 07:54 10:00 #11. Lay down motor, Stryder agitator, and FVS. Test in mouse hole. All seem normal. Run water through coil track no obstruction 8/25/2018 8/25/2018 1.40 PROD2 DRILL PULD T PJSM, P/U motor, bit, agitator, and 0.0 78.1 10:00 11:24 FVS. PD BHA#12. Pull checks out of UQC and change out. Make up to coil and surface test tool. Pump at surface to ensure BHA functional. Tag up and set counters 8/25/2018 8/25/2018 1.40 PROD2 DRILL TRIP T RIH BHA#12, Shallow test agitator at 78.1 7,565.0 11:24 12:48 500'- Good. Continue in 8125/2018 8/25/2018 0.10 PROD2 DRILL DLOG T Log Kt for+1.5' 7,565.0 7,592.0 12:48 12:54 8/25/2018 8/25/2018 1.40 PROD2 DRILL TRIP T Continue in well. Wt check @7790 7,592.0 9,469.0 12:54 14:18 49K, Clean pass through window. Stacking @ 8889, 9087, 9117, and 9176. Set down @ 9269 and 9376. reduce rate to .6 to get through 8/25/2018 8/25/2018 6.20 PROD2 DRILL DRLG P 9469, On bottom drilling, 1.78 BPM @ 9,469.0 9,813.0 14:18 20:30 4670 PSI FS, BHP=4165. Ratty with low ROP 8125/2018 8/25/2018 0.10 PROD2 DRILL WPRT P 100 fl wiper, PU WT is 61K 9,813.0 9,813.0 20:30 20:36 8/25/2018 8/25/2018 1.00 PROD2 DRILL DRLG P 9813', Drill, 1.78 BPM @ 4694 PSI 9,813.0 9,870.0 20:36 21:36 FS, BHP -4216 8/25/2018 8/26/2018 2.40 PROD2 DRILL WPRT P 9870' wiper, PU 800", 2 overpulls 9,870.0 7,710.0 21:36 00:00 around 9320 of 12k, some trouble getting back to bottom through this area. No WT on bit, Decide to POOH to TTL to clean up 7", PU WT is 58K. 8/26/2018 8/26/2018 1.40 PROD2 DRILL WPRT P Clean out T' 7,710.0 7,570.0 00:00 01:24 8/26/2018 8/26/2018 0.10 PROD2 DRILL DLOG P Tie in to KI +6.5 7,570.0 7,570.0 01:24 01:30 8/26/2018 8/26/2018 1.30 PROD2 DRILL TRIP P RIH, Clean through window, setdown 7,570.0 9,870.0 01:30 02:48 at 8755', Clean for remainder to 9870. Page 7130 Report Printed: 9119/2018 . Operations Summary (with Timelog Depths) 1 H-21 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Stark Time EM TMe Dir lnd Phaseop Code Activity Code Time P -T -X operation SI(Depth MB) End Depth (fiXB) 8/26/2018 8/26/2018 1.20 PROM DRILL DRLG P 9870', Drill, 1.78 BPM @ 4622 PSI 9,870.0 10,015.0 02:48 04:00 FS, BHP=4239 8/26/2018 8/26/2018 0.20 PROD2 DRILL WPRT P 10015 PU for short wiper 100' 10,015.0 10,015.0 04:00 04:12 8/26/2018 8/26/2018 1.10 PROD2 DRILL TRIP T Short trip to 9930, survey issues due 10,015.0 10,015.0 04:12 05:18 to magnetic storm. Start obtaining usable surveys. RBIH to drill 8/26/2018 8/26/2018 2.10 PROD2 DRILL DRLG P 10015 Drill, 1.81 BPM @ 4764 PSI 10,015.0 10,172.0 05:18 07:24 FS, BHP=4202 8/26/2018 8/26/2018 0.20 PROD2 DRILL WPRT P 10172 Pull BHA wiper, PUW=61K 10,172.0 10,172.0 07:24 07:36 8/26/2018 8/26/2018 1.00 PROD2 DRILL DRLG P 10172', Drill, 1.77 BPM @ 4747 10,172.0 10,260.0 07:36 08:36 8/26/2018 8/26/2018 2.00 PROD2 DRILL WPRT P Pull 1000' wiper with sweeps, 10,260.0 10,260.0 08:36 10:36 PUW=58K. Hard to get back to bottom 8/26/2018 8/26/2018 2.00 PROD2 DRILL DRLG P 10260', Drill, 1.79 BPM @ 4737 PSI 10,260.0 10,353.0 10:36 12:36 FS, BHP=4215 8/26/2018 8/26/2018 0.30 PROD2 DRILL WPRT P Stacking, Pull BHA Wiper, PUW=63K 10,353.0 10,353.0 12:36 12:54 8/26/2018 8/26/2018 3.50 PROD2 DRILL DRLG P 10353', Drill, 1.8 BPM @ 4239 PSI 10,353.0 10,488.0 12:54 16:24 FS, BHP=4239 PSI, RIW=-.4, DHWOB=1.6K 8/26/2018 8/2612018 0.20 PROD2 DRILL WPRT P Pull BHA Wiper, PUW=56K, 10,488.0 10,488.0 16:24 16:36 RIW=6.5K 8/26/2018 8/26/2018 2.50 PROD2 DRILL DRUG P 10488', Drill, 1.8 BPM @ 4241 PSI 10,488.0 10,573.0 16:36 19:06 FS, BHP=4237 PSI, RIW=-.4, DHWOB=1.6K 8/26/2018 8/27/2018 4.90 PROD2 DRILL WPRT P Wiper, PU WT=70K, PUH to TTL, 10,573.0 10,573.0 19:06 00:00 Time new mud swap for RIH, RBIH several trouble areas going through the C2, new mud at nozzle, big improvment, ph to bottom 8/27/2018 8/27/2018 2.40 PROD2 DRILL DRLG P 10573', Drill, 1.79 BPM @ 4600 PSI 10,573.0 10,647.0 00:00 02:24 FS, BHP=4225 8/27/2018 8/27/2018 0.10 PROD2 DRILL WPRT P Pull BHA Wiper, PUW=63K, 10,647.0 10,647.0 02:24 0230 RIW=6.5K 8/27/2018 8/27/2018 1.30 PROD2 DRILL DRLG P 10647', Drill, 1.79 BPM @ 4600 PSI 10,647.0 10,671.0 02:30 03:48 FS, BHP=4225 8/27/2018 8/27/2018 0.10 PROD2 DRILL WPRT P Pull BHA Wiper, PUW=61 K, 10,671.0 10,671.0 03:48 03:54 RIW=6.5K 8/27/2018 8/27/2018 0.50 PROD2 DRILL DRLG P 10671', Drill, 1.79 BPM @ 4419 PSI 10,671.0 10,676.0 03:54 04:24 FS, BHP=4230 8/27/2018 8/27/2018 0.40 PROM DRILL WPRT P PU for GEO Wiper 10,676.0 10,676.0 04:24 04:48 8/27/2018 8/27/2018 2.70 PROD2 DRILL DRLG P 10676', Drill, 1.79 BPM @ 4412 PSI 10,676.0 10,700.0 04:48 07:30 FS, BHP=4228 8/27/2018 8/27/2018 2.90 PROM DRILL TRIP P 10,700, Trip for bit, Pump sweeps, jet 10,700.0 75.0 07:30 1024 7" chase to surface 8/27/2018 8/27/2018 1.50 PROD2 DRILL PULD P Tag up and space out, PJSM. Run 75.0 0.0 10:24 11:54 blocks to free ice. PUD BHA#12. Lay down FVS, Agitator, motor, and bit. Bit out 3-3 with chipped reamers and nose 8/27/2018 8/27/2018 0.50 PROD2 DRILL BOPE P P/U test joint. Perform Bi weekly 0.0 0.0 11:54 12:24 1 1 1 1 function test on stack 8/27/2018 8/27/2018 1.30 PROD2 DRILL PULD P P/U FVS, Agitiator, motor, and Hyc bi 0.0 78.0 12:24 13:42 center bit, PD BHA#13. M/U to coil trek and surface test tool, Tag up and set counters 8/27/2018 8/27/2018 1.50 PROMP DRILL TRIP:12 Trip in hole, BHA #13, Shallow test 78.0 7,565.0 13:42 15 agitator - Good. Continue in Page 8130 ReportPrinted: 9/119120181 Operations Summary (with Timelog Depths) 1 H-21 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log start Time End Time dr mn Phase Op Code Activity Cade Time P -T-% Operation O. S aKa) M EDepth tsK 8/27/2018 8/272018 0.10 PROD2 DRILL DLOG P Log K1 for+1 foot 7,565.0 7,595.00 15:12 15:18 827/2018 827/2018 1.40 PROD2 DRILL TRIP P . Set down @ 7966 and 8058 requiring 7,595.0 10,700.0 15:18 16:42 pick up. Slacking but no set downs, RIH 8/27/2018 8/27/2018 1.20 PROD2 DRILL DRLG P 10700', Drill, 1.79 BPM @ 4869 PSI 10,700.0 10,720.0 16:42 17:54 FS, BHP=42236 8/27/2018 8/27/2018 0.10 PROD2 DRILL WPRT P PU for mini wiper, PU WT =65K 10,720.0 10,720.0 17:54 18:00 8/27/2018 8/27/2018 5.20 PROD2 DRILL DRLG P 10720', Drill, 1.79 BPM @ 4776 PSI 10,720.0 10,984.0 18:00 23:12 FS, BHP=4212 8/27/2018 8/27/2018 0.20 PROD2 DRILL WPRT P 100' Wiper, PU WT is 64K 10,984.0 10,984.0 23:12 23:24 8/272018 8/28/2018 0.60 PROD2 DRILL DRLG P 10984', Drill, 1.79 BPM @ 5016 PSI 10,984.0 10,994.0 23:24 00:00 FS, BHP=4253 828/2018 8/28/2018 2.00 PROD2 DRILL DRLG P 10984', Drill, 1.79 BPM @ 5016 PSI 10,994.0 11,100.0 00:00 02:00 FS, BHP=4253 8/28/2018 8/28/2018 1.80 PROD2 DRILL WPRT P 850" wiper, PU WT is 65K, pulled 11,100.0 11,100.0 02:00 03:48 heavy at 10980,10425 and 10305 8/28/2018 8/28/2018 3.10 PROD2 DRILL DRUG P 11,100', Drill, 1.79 BPM @ 5196 PSI 11,100.0 11,216.0 03:48 06:54 1 1 FS, BHP=4333 8/28/2018 8/28/2018 0.20 PROD2 DRILL WPRT P Short wiper, PU WT is 72K 11,216.0 11,216.0 06:54 07:06 8/28/2018 8/28/2018 1.70 PROD2 DRILL DRLG P 11,216', Drill, 1.79 BPM @ 5126 PSI 11,216.0 11,244.0 07:06 08:48 FS, BHP=4310 8/28/2018 8/28/2018 0.20 PROD2 DRILL WPRT P Short wiper, PU WT is 72K, Hard time 11,244.0 11,244.0 08:48 09:00 getting back down 8/282018 8/28/2018 2.50 PROD2 DRILL DRLG P 11,244', Drill, 1.79 BPM @ 5308 PSI 11,244.0 11,293.0 09:00 11:30 FS, BHP=4310 TD uncomfirmed 11,293'. PU Wt, 60 k lbs 828/2018 8/28/2018 0.90 PROD2 DRILL CIRC P Stage sweeps to bit while RBIH to TD 11,244.0 11,293.0 11:30 12:24 8/282018 8/28/2018 2.70 PROD2 DRILL WPRT P PUH on swab wiper trip chasing 11,293.0 T,700.0 12:24 15:06 sweeps to surface. Slight increase in string weight and motor work from 10,400-10,000. RBIH, all clean, continue to POOH. Pull heavy, 68 k lbs, @ 9,917' RBIH, stack out -2, PUH, CT wt to 74 k lbs, RBIH, stack out -5 k, PU to 75 k lbs, RBIH stack out -8 k, PU , clean, PU 75 k, RBIH, all clean, PUH, all clean. Pump additional sweeps, Pull 75 k lbs CT wt, no WOB, @ 8090 in the build, continue out of hole. larg neg WOB @ 7947', 7907', & 7817' with small Ct Wt overpulls, continue up hole, window clean. Make two passes to the tubing tail cleanin up the 7" RBIH 8/28/2018 8/28/2018 0.20 PROD2 DRILL TRIP P RIH to clean up build. 7,700.0 7,840.0 15:06 15:18 Set down in window - 7818', PU 45 k lbs, RBIH 19 ft/min, pumps doom while transiting the window, clean. 8/28/2018 8/28/2018 0.20 PROD2 DRILL DLOG P Tie into the RA tag for+13' correction. 7,840.0 7,860.0 15:18 15:30 Page 9130 Report Printed: 9/19/2018 Summary (with Timelog Depths) 1 H-21 lipOperations Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Sten'n EIE Tme Dur hr Phase O Cotle p Adivl Cafe ry Tyne P- - TX Operation Start Depth (flKa) End Depth(WEI) 8/28/2018 8/28/2018 0.30 PROD2 DRILL WPRT P Continue to RIH in an atempt to clean 7,840.0 8,295.0 15:30 15:48 up the build section. Multiple set downs and WOB spikes with asociated coil wt spikes, 7956', 7960', 7995',8024',8119', 8/28/2018 8/28/2018 1.50 PROD2 DRILL WPRT P Pump 2x 10x10 sweeps, spaced apart 8,295.0 7,751.0 15:48 17:18 and chased up hole while pulling to surface. Slight neg WOB @ 8193', and 8160'. 7899' pulled -18 k WOB, worked pipe. Window clean. 8/28/2018 8/28/2018 1.37 PROD2 DRILL WPRT P Continue POOH (Swab Wiper), 7,751.0 79.0 17:18 18:40 pumping 1.71 bpm @ 4,989 psi 8/28/2018 8/282018 1.33 PROD2 DRILL TRIP P Tag up, reset counter, set depths, RIH, 79.0 7,560.0 18:40 20:00 pumping 0.43 bpm @ 2,174 psi 8/28/2018 8/28/2018 0.20 PROD2 DRILL DI -OG P Log the K1 marker correction of plus 7,560.0 7,594.0 20:00 20:12 1.0', PUW=46 k 8/28/2018 8/282018 0.22 PROD2 DRILL TRIP P Continue IH 7,594.0 7,805.0 20:12 20:25 8/28/2018 8/282018 0.40 PROD2 DRILL TRIP P Obtain Static Pressure, bleed down to 7,805.0 7,805.0 20:25 20:49 11.6 ppg (3835 psi), 20 min 10.6 (3,601 psi) 8/28/2018 8/28/2018 2.50 PROD2 DRILL TRIP P Continue IH towards bottom, (7,964', 7,805.0 11,293.0 20:49 23:19 7,994', 8 8,029'), confirm TD 11,293' 8/28/2018 8/28/2018 0.50 PROD2 DRILL CIRC P PUW=68 k, send liner pill down coil 11,293.0 11,293.0 23:19 23:49 8/28/2018 8/29/2018 0.18 PROD2 DRILL TRIP P POOH, laying in 11.7 ppg beaded liner 11,293.0 10,946.0 23:49 00:00 running pill 8/29/2018 8292018 1.15 PROD2 DRILL TRIP P Continue POOH, laying in 11.7 ppg 10,946.0 7,720.0 00:00 01:09 beaded liner running pill up to 7,720' 8/292018 8/29/2018 1.50 PROD2 DRILL TRIP P Continue POOH, displacing well to 7,720.0 79.0 01:09 02:39 11.7 ppg completion fluid 8/29/2018 8/29/2018 0.50 PROD2 DRILL OWFF P At surface, check well for flow, PJSM 79.0 79.0 02:39 03:09 for LD tools. 8/292018 8/29/2018 1.25 PROD2 DRILL PULD P LD drilling BHA on a dead well. 79.0 0.0 03:09 04:24 Note: Inspected Coil (0.120") 8/29/2018 8/292018 1.00 COMPZ2 CASING PUTB P Prep RF for liner ops 0.0 0.0 04:24 05:24 8129/2018 8/29/2018 3.10 COMPZ2 CASING PUTB P Make up lower completion, nori ported 0.0 1,545.0 05:24 08:30 bull nose, 50 joints, 4.6 ppf L-80 slotted liner, (1545), under a shorty deployment sleeve, min ID Crew change w 19 joints in the hole, made up safety joint for hand over. Joint # 48 (31.76') slightly bent, decided to swap out, replaced with joint # 51 ( 31.77'). 8/29/2018 8/292018 1.30 COMPZ2 CASING PUTS P PJSM, MU BHA# 14,AL1 lowerliner 1,545.0 1,590.0 08:30 09:48 running assembly, skid cart, inspect pack offs - replaced, pull and replace upper checks, stab injector, bump up, reset counters. 8/29/2018 8/29/2018 1.60 COMPZ2 CASING RUNL P RIH pumping min rate, CT Wt 8.63 k 1,545.0 7,954.0 09:48 11:24 lbs at surface. Pu Wt 52 k lbs, Tie into flag for -8.3' conecflon. Continue to run in hole. Lost 7 bbls on the trip in. Page 10/30 Report Printed: 9/19/2018 Operations Summary (with Timelog Depths) IH -21 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log stall Time End Tire Dir (hr) Phase Op Code Activity c de Tama P -T -X Operation Start Depth (MB) End DepN NKB) 8/29/2018 8/29/2018 1.10 COMPZ2 CASING RUNL P Set down, 7954, slid through 1,545.0 8,4950 11:24 1230 Set down again 7986', tried multiple attempts and multiple speeds and SID weights, tried rolling the pump. No apparent progress. CT PU Wt 52 k lbs, WOB -13 k lbs until it breaks free and returns to -5.6 k lbs. 17 S/D's Picked up above original SID, RIH, slight bobble and bouoed through. SID @ 8355' slowly slid through, 8398', 8460' 8/29/2018 8/29/2018 0.60 COMPZ2 CASING RUNL P SD @ 8495', P/U, Pulled -23 k WOB, 8,495.0 8,500.0 12:30 13:06 cycled pipe to 74 K Ct Wt, pulled free, RBIH, setting down and draging heavy when PU to 75 k lbs. PUH to 8325' RBIH, lost ground, SID 8438'. Work pipe, -9 to -20 k WOB, CT Wt 48 - 68 k lbs when POOH. start making hole again slowly 8/29/2018 812912018 2.10 COMPZ2 CASING RUNL P Working pipe up to 80 k CT wt, - 24 K 8,500.0 9,432.0 13:06 15:12 1 1 WOB, on pickups, RIH, SID PU 8/29/2018 8/29/2018 5.00 COMPZ2 CASING RUNL P Continue working pipe towards 9,432.0 9,677.0 15:12 20:12 bottom, PUW 60 k, PUDHWOB=minus 12k 8/29/2018 8129/2018 0.80 COMPZ2 CASING RUNL P Continue IH @ 30 fpm to bottom 9,677.0 11,293.0 20:12 21:00 11,288' 8/29/2018 8/29/2p18 0.20 COMPZ2 CASING RUNL P PUW=62 k, set back down, minus 2.5 11,293.0 11,293.0 21:00 21:12 k, bring pump up to 1.5 bpm @ 3,900 psi, 0.75 bpm returns, PUW= 48 k, liner is gone, remove liner length from counters, 8/29/2018 8/29/2018 0.75 COMPZ2 CASING CIRC P Finish building and circulate 11.7 ppg 11,293.0 11,293.0 21:12 21:57 beaded liner running pill. 8/29/2018 8/29/2018 1.00 COMPZ2 CASING TRIP P POOH, laying in 11.7 ppg beaded liner 11,293.0 7,545.0 21:57 22:57 1 running pill to 7,650' 8/29/2018 8/2912018 0.20 COMPZ2 CASING DLOG P Log K1 marker correction of plus 16.5' 7,545.0 7,563.0 22:57 23:09 8/29/2018 8/30/2018 0.85 COMPZ2 CASING TRIP P POOH to surface 7,563.0 2,465.0 23:09 00:00 8/30/2018 8/30/2018 0.25 COMPZ2 CASING TRIP P Continue POOH 2,465.0 44.2 00:00 00:15 8/30/2018 8/30/2018 0.50 COMPZ2 CASING OWFF P At surface, check well for flow, PJSM 44.2 44.2 00:15 00:45 1 for liner ops 8/30/2018 8/30/2018 0.25 COMPZ2 CASING PULD P LD setting tools 44.2 0.0 00:45 01:00 8/30/2018 8/30/2018 0.25 COMM CASING PUTB P Prep RF for liner ops 0.0 0.0 01:00 01:15 8/30/2018 8/30/2018 2.00 COMPZ2 CASING PUTB P PU/MU AL1 liner segment #2w/3D jts 0.0 940.9 01:15 03:15 of slotted liner and ported bullnose 8/30/2018 8/3012018 0.75 COMPZ2 CASING PULD P PU/MU Coiltrak tools and BOT 3" GS, 940.9 985.1 03:15 04:00 stab INJH, surface test CTT (good - test) 8/30/2018 8/30/2018 3.00 COMPZ2 CASING RUNL P Tag up reset counters, RIH 985.1 9,751.0 04:00 07:00 window flag correction -6.43' Wt check above the window - 49 k lbs Tie into the K1 for a +5.5' correction, continue to RIH, tag bottom @ 9751' PU wt 54 k lbs, RBIH, stak 2 k Has, Release off liner, PU 43 k lbs, - TOL 8310' 8/30/2018 8/30/2018 1.10 COMPZ2 CASING CIRC P PUH, correct depths, circulate 18 bbl 9,751.0 8,795.0 07:00 08:06 1 beaded liner running pill to GS Page 11130 Report Printed: 911912018 Operations Summary (with Timelog Depths) „ 1 H-21 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Depth rt De Stint na rt Ti EM Tms ow (hr) Please op Cods MW4 Code TimP-T-X C peration 61d Depth (XKa) 8/30/2018 8/30/2018 0.50 COMPZ2 CASING DISP P PU 48 k lbs, POOH hole laying in 8,795.0 7,540.0 08:06 08:36 beaded liner running pill to 7,663' 8/30/2018 8/30/2018 0.20 COMPZ2 CASING DLOG P Tie into the K1 for a +2.5' correction 7,540.0 7,565.5 08:36 08:48 8/30/2018 8/30/2018 1.50 COMPZ2 CASING TRIP P Continue to POOH 7,565.5 50.0 08:48 10:18 8/30/2018 8/30/2018 0.70 COMM CASING PULD P Bump up, space out, Flow check, LD 50.0 0.0 10:18 11:00 1 BHA# 15 8/30/2018 8/30/2018 0.50 COMPZ2 CASING PUTB P Prep floor to run liner, PJSM 0.0 0.0 11:00 11:30 8/30/2018 8/30/2018 1.20 COMPZ2 CASING PUTB P PU ALl section #3 completion, 3 0.0 863.8 11:30 12:42 pups, 27 joints, ( 863.78'), under shorty with a ported bullnose. Kick drill, AAR, PJSM. clear flow. 8/30/2018 8/30/2018 1.20 COMPZ2 CASING PULD P PU BHA#15-AL1 section #3 863.0 908.0 12:42 13:54 completion, check pack offs, skid cart stab on bump up space out. 8/30/2018 8/30/2018 2.20 COMPZ2 CASING RUNL P RIH W BHA#13. Tie into flag for -0.2' 908.0 8,812.0 13:54 16:06 correction, PU 48 k lbs, continue to RIH. drive by the K1 for a +0.5' correction. Continue in hole, tag up, 8812', PU Wt 53 k lbs, RBIH, set down 2 k lbs WOB, online w pump, PU Wt 42 k lbs. TOL 7947- 8/30/2018 8/30/2018 1.40 COMPZ2 CASING TRIP P Park, reset counters, POOH. 8,812.0 59.9 16:06 17:30 8/30/2018 8/30/2018 0.50 COMPZ2 CASING OWFF P At surface, check well for flow, Crew 59.9 59.9 17:30 18:00 change, PJSM 8/30/2018 8/30/2018 0.50 COMPZ2 CASING PULD P LD setting tools 59.9 0.0 18:00 18:30 8/30/2018 8/30/2018 0.50 COMPZ2 CASING PULD P PU/MU, Open hole anchored billet w/ 0.0 72.9 18:30 19:00 BOT J -hydraulic setting tool 8/30/2018 8/30/2018 0.25 COMPZ2 CASING PULD P PU/MU, Coiltrak tools, stab INJH, 72.9 72.9 19:00 19:15 perform surface test (good -test) 8/30/2018 8/30/2018 2.00 COMPZ2 CASING RUNL P RIH, with BHA#17 Open Hole 72.9 7,565.0 19:15 21:15 Anchored Billet, @ 80 fpm/20 fpm jewelry 8/30/2018 8/30/2018 0.20 COMM CASING DLOG P Log the K1 marker no correction, 7,565.0 7,608.0 21:15 21:27 PUW 50 k 8/3012018 8/30/2018 0.20 COMM CASING RUNL P Continue IH, tagging TOL @ 7,947 psi 7,608.0 7,947.0 21:27 21:39 8/30/2018 8/30/2018 0.20 COMPZ2 CASING RUNL P Set down 4.5 k DHWOB, PUW 49 k, 7,947.0 7,947.0 21:39 21:51 repeat, PUH to 0.3 k DHWOB, bring pump up 1.4 bpm, seen tool shift 3,077 psi, creep in hole back to 4.5 k, 7,947', PUW 44 k 8/30/2018 8/30/2018 1.20 COMPZ2 CASING TRIP P POOH 7,947.0 53.3 21:51 23:03 8/30/2018 8/30/2018 0.50 COMPZ2 CASING OWFF P At surface, check well for flow, PJSM 53.3 53.3 23:03 23:33 8/3012018 8/31/2018 0.46 COMPZ2 CASING PULD P LD setting tools 53.3 0.0 23:33 00:00 8/31/2018 8/31/2018 1.00 PRODS DRILL CTOP P MU Nozzle, stab INJH, jet surface 0.0 0.0 00:00 01:00 lines and stack, while displacing coil to FW. Sim -ops: grease valves and bop equipment. 8/31/2018 8/31/2018 0.75 PRODS DRILL CTOP P Valve shop on location, service tree, 0.0 0.0 01:00 01:45 RD noale, remove BHI upper quick, cut/remove CTC, boot a -line Page 12/30 Report Printed: 9/19/2016 Operations Summary (with Timelog Depths) 1H-21 li p Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Scarf Time EM Time our (hr) Phase Cp Cotle Aclivify Code Time P -T -X Operation S�tl Depth (rt KB) End Depth (XKa) 8/31/2018 8/31/2018 0.25 PRODS DRILL CTOP P Stab INJH, use both pumps, pump 0.0 0.0 01:45 02:00 slack 8/31/2018 8/31/2018 0.25 PRODS DRILL CTOP P Test inner reel valve and pac-off, 0.0 0.0 02:00 02:15 unstab INJH 8/31/2018 8/31/2018 0.50 PRODS DRILL CTOP P PJSM, RU coiled tubing cutter 0.0 0.0 02:15 02:45 8/31/2018 8/31/2018 1.00 PRODS DRILL CTOP P Cut Coiled tubing back to locate wire 0.0 0.0 02:45 03:45 1 (140') 8/31/2018 8/31/2018 2.45 PRODS DRILL CTOP P Install CTC, pull test to 35 k good, 0.0 0.0 03:45 06:12 install UCC, pressure test good, tested wire 1700Mohms, 69.8 ohms. 8/31/2018 8/31/2018 1.30 PRODS WHDBOP CTOP P Prep for BOP test, grease and service 0.0 0.0 06:12 07:30 1 valves, flood upshell test - 3000 psi. 8/31/2018 8/31/2018 6.50 PRODS WHDBOP BOPE P Prep for BOP test, grease and service 0.0 0.0 07:30 14:00 valves, flood up. shell test - 3000 psi. " Start test 7:30 Tree swab leaking slightly Annular test took 52 minutes to trouble shoot some issues. 8/31/2018 8/31/2018 1.00 PRODS WHDBOP CTOP P Clear floor from BOP testing, Valve 0.0 0.0 14:00 15:00 check list. 8/31/2018 8/31/2018 0.50 PRODS DRILL SVRG P Took 30 minutes, rig service timet o 0.0 0.0 15:00 15:30 allow for Washington crane inspector Po finish work on injector. 8/31/2018 8/31/2018 1.20 PRODS DRILL CTOP P Skid cart, install nozzle, stab injector, 0.0 0.0 15:30 16:42 tum reel over to kill weight fluid. PJSM, Open up to well, fill 3 bbls, flow check - good, unstab injector, skid cart. 8/31/2018 8/31/2018 0.70 PRODS STK PULD P PU BHA #18. AL2 lateral drilling 0.0 72.2 16:42 17:24 assembly, Re Run Baker dynamus bit under a 0.4+°AKO motor. 8/31/2018 8/31/2018 0.50 PRODS STK TRIP P RIH 72.2 507.0 17:24 17:54 8/31/2018 8/31/2018 0.50 PROD3 STK TRIP T BHI MWD, check shots reviled 507.0 72.2 17:54 18:24 incontinency with the Hydraulic orienting Tool. Pull back to surface 8/31/2018 8/31/2018 0.50 PRODS STK PULD T PJSM, swap out HOT tools 72.2 0.0 18:24 18:54 8/31/2018 8/31/2018 0.25 PRODS STK PULD P MU UQC, surface test tools (good- 0.0 72.2 18:54 19:09 test), stab INJH, tag up reset counters 8/31/2018 8/31/2018 1.50 PRODS STK TRIP P RIH 509.0 7,565.0 19:09 20:39 8/31/2018 8/31/2018 0.20 PRODS STK DLOG P Log the K1 marker no correction 7,565.0 7,598.0 20:39 20:51 8/31/2018 8/31/2018 0.65 PRODS STK DISP P Finish displacing well to drilling fluid 7,598.0 7,805.0 20:51 21:30 8/31/2018 8/31/2018 0.20 PRODS STK TRIP P Close EDC, PUW 48 k 7,805.0 7,805.0 21:30 21:42 8/31/2018 8/31/2018 0.30 PRODS STK TRIP P Continue IH through window dry tag 7,805.0 7,935.0 21:42 22:00 TOB @ 7,935', PUH, attempt to roll TF 180°, RIH, stack out, PBUH, roll TF as drilled, park 7,932' 8/31/2018 8/31/2018 1.25 PRODS STK KOST P Bring pump online 1.75 bpm at 4,195 .7,935.0 7,937.0 22:00 23:15 psi, WHP=274, BHP=4074, IA=O, OA=47, kickoff billet as per RP 8/31/2018 8/31/2018 0.25 PRODS DRILL DRLG P Drill Ahead, 1.75 bpm at 4,140 psi, 7,937.0 7,939.3 23:15 23:30 Diff -516 psi, WHP=304, BHP=4,055 --L- I psi, IA=O, OA=49 r Page 13130 Report Printed: 911912018 Operations Summary (with Timelog Depths) 1 H-21 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log sten Tuee End Time Our (hr) Phase Op Cade Activity Code Time P-T-X Operation start Depthp (N(e) End Depth (flKa) 8/31/2018 8/31/2018 0.20 PRODS DRILL DRLG P Stack out weight, shut down pump, 7,939.3 7,939.3 23:30 23:42 PUH 56 k to 7,930', RBIH, dry tag 7,939.3' 8/31/2018 9/1/2018 0.30 PRODS DRILL DRLG P PUH 7,9301, PUW 52 k, bring pump on 7,939.3 7,939.6 23:42 00:00 -line 1.77 bpm at 4,288 psi, Diff=464 psi, WHP=261, BHP=4,037, IA=O, OA=49 9/1/2018 9/1/2018 1.00 PRODS DRILL DRLG P OBD, 1.77 bpm at 4,177 psi, Diff--467, 7,939.6 7,951.9 00:00 01:00 WHP=316, BHP=4,067, IA=O, OA=52 9/1/2018 9/1/2018 2.00 PRODS DRILL DRLG P OBD, 1.79 bpm at 4,154 psi, Diff=467 7,951.9 7,966.0 01:00 03:00 psi, WHP=314, BHP=4,054, IA=O, OA=53 9/1/2018 9/1/2018 1.75 PRODS DRILL DRLG P OBD, 1.76 bpm at 4,151 psi, Diff-467 7,966.0 7,972.0 03:00 04:45 psi, WHP=295, BHP=4,076, IA=7, OA=57 "` Note: Bit balling PUH creep in hole slowly, continue drilling ahead slowly @ 20 fph 9/1/2018 9/1/2018 2.00 PRODS DRILL DRLG P OBD, 1.77 bpm at 4,250 psi, Diff-467 7,972.0 8,028.0 04:45 06:45 psi, WHP=329, BHP=4,039, IA=19, OA=58 Pump 5x5 sweep 9/1/2018 9/112018 1.00 PRODS DRILL DRLG P OBD, CT 4403 psi, WH 317 psi, 4145 8,028.0 8,100.0 06:45 07:45 psi annular, IA 54 psi, OA 60 psi Ratty drilling cleaned up, ROP 70 ft/hr, CT Wt 16 it lbs, WOb 1.9 k lbs Some aluminum, clean cuttings, stickier than normal. Pump 5x5 sweep in anticipation of TD. 9/1/2018 9/1/2018 0.30 PROD3 DRILL WPRT P TO build early per DO and Geo. 8,100.0 7,957.0 07:45 08:03 PU 52 k lbs, sweeps out the bit, chase up hole to ITT, while slowly PUH. Orient low side for billet, small neg WOB tug while orienting, small neg WOB spike passing the billet at min rate. RBIH, dry drift billet, small WOB spike below the billet, assuming BHA binding up. 9/1/2018 9/1/2018 1.70 PRODS DRILL TRIP P PU, 50 k lbs, 7,957.0 71.0 08:03 09:45 POOH, billet clean again. Pull through window clean. Slow pass at rale cleaning up 7" to TT, Pull into tubing, Open EDC. POOH for let drilling BHA 9/1/2018 9/1/2018 2.30 PRODS DRILL PULD P PJSM, discussed high bend motor, 71.0 0.0 09:45 12:03 bump up, attempt to pull tool, hung up from the outset, PJSM, pop off, orient tool 180 °, reattempt with DS PDL winch, its a little faster, tool pulled free with no issue. - 1 hr added time due to hang up. PUD BHA#19. 9/1/2018 9/1/2018 1.30 PRODS DRILL PULD P PU BHA#20, AL2 lateral drilling 0.0 80.0 12:03 13:21 assembly, 0.6° AKO, W HVC - SR321M-A1 11mm w 3D nose cutters, test good, skid cart, stab injector, bump up, set counters 9/1/2018 9/1/2018 1.40 PRODS DRILL TRIP P RIH, close EDC, Test agitator Q 1.7 80.0 7,565.0 13:21 14:45 bpm and 500'- good, continue in hole. 9/1/2018 9/1/2018 0.20 PRODS DRILL DLOG P Tie into the K1 for a 0.5' correction, 7,565.0 7,590.0 14:45 14:57 9/1/2018 9/1/2018 0.50 PRODS DRILL TRIP P CT PU Wt, 44 k lbs, continue to RIH, 7,590.0 8,101.0 14:57 15:27 window and billet both clean, build clean. Page 14/30 ReportPrinted: 911912018 Operations Summary (with Timelog Depths) 1 H-21 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Slee Depth StartTime EW Time Dur(to Phase Op Code Activity Code Time e P -T -x Operation o (rt KnB) End Depth (WB) 9/1/2018 9/1/2018 1.90 PRODS DRILL DRLG P CT 4176 psi @ 1.77 bpm, annular 8,101.0 8,220.0 15:27 1721 4124 psi, Free spin diff 960 psi. OBD, CT Wt 15.6 k lbs, WOB 2.0 k lbs, ROP 70 ft/hr. 9/1/2018 9/1/2018 4.50 PRODS DRILL DRLG P OBD, 1.80 bpm at 4,851 psi, 8,220.0 8,505.0 17:21 21:51 Diff=1,100 psi, BHP=4,155, IA=212, OA=57 9/1/2018 9/112018 0.25 PRODS DRILL WPRT P Wiper up hole to 8, 100'w/sweeps, 8,505.0 8,100.0 21:51 22:06 1 PUW=53 k 9/12018 9/1/2018 0.25 PRODS DRILL WPRT P Wiper back in hole, RM 8,100.0 8,505.0 22:06 22:21 9/1/2018 9/2/2018 1.65 PRODS DRILL DRLG P BOBD, 1.82 bpm @ 4,707 psi, 8,505.0 8,612.0 22:21 00:00 Diff --1,000 psi, WHP=263, BHP=4,134, IA=213, OA=57, Avg. ROP=60 fph/2.6 k DHWOB 9122018 9/2/2018 1.30 PRODS DRILL DRLG P OBD, 1.79 bpm at 4,977 psi, 8,612.0 8,692.0 00:00 01:18 Diff=1,000 psi, WHP=251, BHP=4,170, IA=346, OA=60 9/2/2018 9/2/2018 0.80 PRODS DRILL DRLG P OBD, 1.78 bpm at 5,339 psi, 8,692.0 8,768.0 01:18 02:06 Diff --1,100 psi, WHP=256, BHP=4,156, IA=365, OA=60, Avg.Rop=65 fph/2.4 k DHWOB 912/2018 9/212018 1.80 PRODS DRILL DRLG P OBD, 1.80 bpm @ 5,209 psi, 8,768.0 8,930.0 02:06 03:54 DIT -1,050 psi, WHP=275, BHP=4,221, IA=396, OA=61, Avg. ROP=112 fph 9/2/2018 92/2018 1.00 PRODS DRILL WPRT P Wiper up hole to the window, PUMA 53 8,930.0 7,840.0 03:54 04:54 k, jog the 7" casing with sweeps up to 7,707'. circulate BU. 9/212018 9/2/2018 0.20 PRODS DRILL DLOG P Log the K1 marker correction of plus 7,840.0 7,877.0 04:54 05:06 4,5' 92/2018 9/2/2018 0.50 PRODS DRILL WPRT P Wiper back in hole, RIW 14 k 7,877.0 8,930.0 05:06 05:36 Seeing same MWD issues as yesterday, tool is rolling as we near the window and billet. Possibly geometry issues, not electrical. 922018 9/2/2018 2.40 PRODS DRILL DRLG P Free spin diff 970 psi*, initially 1,100 8,930.0 9,153.0 05:36 08:00 psi dropped once we were on bottom for a bit. IA 470 psi, OA 64 psi, CT 5142 psi, @ 1.78 bpm, Annular 4172 psi CT Wt - 6 k lbs, WOB 1-2 k lbs, ROP 60 - 150 ft/hr ` some siderite chips in the cuttings samples Average ROP over section - 93 ft/hr 9/2/2018 9/2/2018 0.20 PRODS DRILL WPRT P PU W154 k lbs, Geo wiper to 9,47', 9,153.0 9,153.0 08:00 08:12 RBIH, RIH Wt 12 k lbs `- 1,700' on the mud, solids @ 0.7, inlet density up to 8.87 ppg Geo asked for 16' decrease in TVD in the next 100' feet, 9/2/2018 9/2/2018 2.30 PRODS DRILL DRLG P CT 4953 psi, @ 1.78 bpm, Annular 9,153.0 9,299.0 08:12 10:30 4195 psi, Free spin diff 950psi OBD, CT Wt 0-2 k lbs, WOB 1.6 k lbs, ROP 100 ftlhr BHA wipers, PU's - 50 k lbs, hard stringers. resistivity increasing from 9180' on. Lots of tool face changes, Pick ups climbed from 50 to 68 k. Pump sweeps. Pick ups still climbing,.. Average ROP over section - 63 ft/hr Page 15130 Report Printed: 9/1912018 Summary (with Timelog Depths) 11-1-21 lipOperations Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Silt Time End Imre Our (hr) Phase op Code ActiNiy Code Time P -T -X Operation StaNDepbt (d De EM Depth (flxa) 9/2/2018 9/2/2018 0.50 FROM DRILL WPRT P PU Wt 71 k lbs. Pull wiper early. #1 9,299.0 8,100.0 10:30 11:00 -1.2 k WOB pull @ 9257', we'd had issues passing this spot earlier on BHAwipers Seeing free spin diff fluctuate from 960 psi to 1200 psi. It doesn't appear to be motor work, agitator kicking in and out?? 9/2/2018 9/2/2018 0.70 FROM DRILL WPRT P RBIH 8,100.0 9,299.0 11:00 11:42 SD - 8686' PU 52 k, RBIH, 500 Ib WOB spike at 8700, SD,- 8960', PU 50 k, SD,- 9228', PU 50 k, 9/2/2018 9/2/2018 3.40 FROM DRILL DRLG P CT 5121 psi, @ 1.79 bpm, Annular 9,299.0 9,490.0 11:42 15:06 4142 psi, Free spin diff 1140psi OBD, CT Wt -2-2 k lbs, WOB 1.3 k lbs, ROP 100 Whir Pickups -52-62 k lbs. Start exporting mud outside - 12:49 - in prep for mud swap. Started new mud @ 14:30 "'New mud at the bit - MT Average ROP over section - 76 f thr 9/2/2018 9/2/2018 2.20 FROM DRILL DRLG P PU to get new parameters 9,490.0 9,564.0 15:06 17:18 CT 4744 psi, @ 1.8 bpm, Free spin 940 psi - annular 4190 psi OBD CT -4-0 k lbs, WOB 1.6 to 2 k lbs. ROP 60 - 10 ft/hr On somthing hard starting 9546' 9/2/2018 9/2/2018 1.50 FROM DRILL DRLG P BOBD, 1.77 bpm at 4,180 psi, 9,564.0 9,621.0 17:18 18:48 Diff -1,100 psi, WHP=403, BHP=4,165, IA=317, OA=62 9/2/2018 9/2/2018 0.20 FROM DRILL WPRT P Pull Geo Wiper up hole PUW 61 k 9,621.0 9,520.0 18:48 19:00 9/2/2018 9/2/2018 0.20 FROM DRILL WPRT P Wiper back in hole, RIW 12.4 k 9,520.0 9,621.0 19:00 19:12 9/2/2018 9/2/2018 2.50 FROM DRILL DRLG P BOBO, 1.79 bpm at 4,650 psi, 9,621.0 9,702.0 19:12 21:42 Diff --1,120 psi, WHP=401, BNP=4,167, IA=320, OA=62 9/2/2018 9/2/2018 1.25 FROM DRILL WPRT P Wiper to the window, PUW 55 k, jog 9,702.0 7,840.0 21:42 22:57 1 the 7" with sweeps 9/2/2018 9/2/2018 0.20 FROM DRILL DLOG P Log the RA marker correction of plus 7,840.0 7,864.0 22:57 23:09 6.0' 9/2/2018 9/2/2018 0.20 FROM DRILL WPRT P Wiper back in hole, RIW 14 k 7,864.0 9,702.0 23:09 23:21 9/2/2018 9/3/2018 0.65 FROM DRILL DRLG P BOBD, 1.77 bpm at 4,583 psi, Diff 9,702.0 9,714.0 23:21 00:00 886, WHP=324, BHP=4,188, IA=292, OA=61 9/3/2018 9/3/2018 1.25 FROM DRILL DRLG P OBD, 1.77 bpm at 4,609 psi, 9,714.0 9,737.0 00:00 01:15 Diff=1,138 psi, WHP=332, BHP=4,197, IA=311, OA=61 9/3/2018 9/3/2018 1.20 FROM DRILL DRLG P OBD, 1.78 bpm at 4,690 psi, Diff -863, 9,737.0 9,745.0 01:15 02:27 WHP=362, BHP=4,182, IA=374, OA=62 9/3/2018 9/3/2018 2.00 FROM DRILL DRLG P OBD, 1.7 bpm at 4,576 psi, Diff -863 9,745.0 9,789.0 02:27 04:27 psi, WHP=367, BHP=4,190, IA=424, OA=62 9/3/2018 9/3/2018 1.70 PRODS DRILL DRLG P OBD, 1.82 bpm at 4,727 psi, Diff=883 9,789.0 9,843.0 04:27 06:09 psi, WHP=346, BHP=4,197, IA=489, OA=63 Page 16/30 Report Printed: 9/1912018 Summary (with Timelog Depths) 1 H-21 lipOperations Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log B Depth start Time End Time our (hr) Phase Op Code Activity Code Time P -T -X operate. (rt KB) ( End Depth (tlKB) 9/312018 9/3/2018 2.50 PRODS DRILL DRLG P PU to check parameters, CT Wt 52 k 9,843.0 9,908.0 0609 0839 lbs, IA 531 psi, OA 66 psi CT 4780 psi @ 1.80 bpm, Annular 4232 psi, free spin 960 psi OBD, CT Wt -2 k lbs, WOB 1 k lbs, ROP 10-60 9852' on something hard, high vibrations, drilled through 9861'- PU CT 52 k lbs, Choke acting up, swap to choke B, choke B acting up, blow down A. same issues on both, drill ahead 9/3/2018 9/3/2018 0.20 PRODS DRILL WPRT P On PU, rebooted the coke controler, 9,908.0 9,908.0 08:39 08:51 same issue, RBIH Running off choke A in manual mode. 9/3/2018 9/3/2018 2.70 PRODS DRILL DRLG P OBD, Ratty drilling, hard srtringers 9,908.0 9,987.0 08:51 11:33 with CT Wt -5k and 2 k WOB, ROP 2- 10 fUhr for 1-2 feet followed by CT Wt 4 K, WOB 0.8 k lbs & 40-100 ft/hr for 10-15'. Average ROP over interval 29 ft/hr 9/3/2018 9/3/2018 2.00 PRODS DRILL DRLG P PU WT 57 k lbs, bypass screens, RIH 9,987.0 10,018.0 11:33 1333 Wt 9 k lbs, CT 4240 psi, 1.71 bpm, Free spin 830 psi. WH 380 psi, annular 4218 psi. OBD, CT Wt 4 k lbs, WOB 1.4 k lbs, ROP9.2 Pump 15 bbls of 1 ppb beads, noticed .5 k lbs increase in WOB when on the hard stuff, no other observable benifits, CT weight, ROP, etc. Tried same pill with 4% lubes, less of a result. Beads in returns are causing annular flucuations that are hard to manage with the choke on manual. 9/3/2018 9/3/2018 4.00 PRODS DRILL DRLG P Drill ahead hard stringers followed by 10,018.0 10,100.0 13:33 17:33 soft. OBD, CT 4900 psi @ 1.78 pbm, Annular 4271 psi. WH 360 psi, IA 638, OA 70 psi CT Wt -4 k lbs, WOB 0.8 k Ibs, ROP 8 Average ROP 201t/hr over interval. 9/3/2018 9/3/2018 1.60 PRODS DRILL WPRT P Wiper to the window, PUW 50 k, jog 10,100.0 7,710.0 17:33 19:21 1 1 the 7" with sweeps, up to 7,710' 9/3/2018 9/3/2018 0.15 PRODS DRILL SVRG P Reboot Choke software, (5 min) 7,710.0 7,840.0 19:21 1930 9/3/2018 9/3/2018 0.20 PRODS DRILL DLOG P Log the RA marker correction plus 4.0' 7,840.0 7,868.0 19:30 19:42 9/3/2018 9/3/2018 0.80 PRODS DRILL WPRT P Wiper back in hole, RIW 12 k 7,868.0 10,100.0 19:42 20:30 9/3/2018 9/3/2018 1.15 PRODS DRILL DRLG P BOBD, 1.78 bpm at 4,837 psi, 10,100.0 10,125.0 20:30 21:39 Diff --863, WHP=306, BHP=4,216, IA=548, OA=68 Average ROP 17 ft/hr over interval. Page 17130 ReportPrinted: 9/19!2018 Operations Summary (with Timelog Depths) 1 H-21 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log StartTme End Tma our (hr) Phase Op Cafe Ad" Code Imre P -T -X Operation Start Depth (WB) End Depth (WS) 9/3/2018 9/3/2018 1.80 PRODS DRILL WPRT P Wiper up hole to the window, PUW 47 10,125.0 7,710.0 21:39 2327 k "' Note: Pull heavy @ 7,896'- 7,906' MD, CTWS=65 k, DHWOB= minus 12 k, RBIH to the EOB, PUH w/sweeps, cleanup area between billet and winodw, jog the 7" with sweeps, 9/312018 9/412018 0.56 PRODS DRILL TRIP P POOH 7,710.0 5,571.0 23:27 00:00 9/4/2018 9/4/2018 1.25 PRODS DRILL TRIP P Continue trip to surface 5,571.0 78.2 00:00 01:15 9/4/2018 9/4/2018 1.75 PRODS DRILL PULD P PUD (ODS -PDL) AL2 drilling BHA#20 78.2 0.0 01:15 03:00 Note: Checks failed, change of scope meeting in the ops cab, continue PUD w/failed checks checklist. 9/4/2018 9/4/2018 1.50 PRODS DRILL PULD P PD, pre -loaded DS PDL BHA# 21, 0.0 78.1 03:00 04:30 stab INJH, surface test Coiltrak tools (good -test) 9/4/2018 9/4/2018 1.50 PRODS DRILL TRIP P Tag up reset counters, RIH 78.1 7,298.0 04:30 06:00 9!4/2018 9/4/2018 0.20 PRODS DRILL DLOG P Tie into the K1 for no correction. 7,298.0 7,585.0 06:00 06:12 9/4/2018 9/4/2018 1.50 PR0D3 DRILL TRIP P PU Wt 43 k lbs, continue in hole, 7,585.0 10,125.0 06:12 07:42 window and billet clean. Still having erratic orienteer issues between the window and the billet. WOB spke (d1 8187', 4 k & 8540, 1 k. Had to slow down running speed from 50 to 17 ft/ min - 9100 SO - 9245', 9759' 10024', 9/4/2018 9/42018 2.30 PRODS DRILL TRIP P IA 152 psi, OA 59 psi, CT 5200 psi @ 10,125.0 10,251.0 07:42 10:00 1.77 bpm, free spinn 1100 psi, WH _ 301 psi, Annular 4282 psi. RIH Wt 8 k Ibs OBD, CT Wt 3 k Ibs, WOB 2 k lbs, ROP 30-160 ft/hr Average ROP over interval - 54 ft/hr 9/42018 9/4/2018 2.80 PRODS DRILL TRIP P OBD, CT Wt -3 k Ibs, WOB 0.6 k Ibs, 10,251.0 10,360.0 10:00 12:48 ROP 40 tUhr Surface and WOB slowly falling off. tried new mud pill, no change in parameters. PU weights - 55-59 k lbs Average ROP over interval - 39 ft/hr 9/4/2018 9/4/2018 1.20 PRODS DRILL TRIP P start pumping 1 ppb beaded pills built 10,360.0 10,425.0 12:48 14:00 of used mud. beaded pill at the bit 10360'. Weights and ROPs improved. PU weights - 50 k lbs Average ROP over interval - 54 fVhr 9/4/2018 9/4/2018 2.20 PRODS DRILL TRIP P Managed to break through what ever 10,425.0 10,525.0 14:00 16:12 was below us and get turned down below 92 °. CT Wt -6 to -1 k lbs, WOB 2 to 0.6 k lbs, ROP 20 to 90 ft/hr Settled in at - 86° PU Wt's 50 k lbs Average ROP over interval - 45 ft/hr 9/4/2018 9/4/2018 0.30 PRODS DRILL TRIP P PU on wiper trip #1 PU Wt 55 k Ibs - 10,525.0 9,526.0 16:12 16:30 1000' Page 18130 ReportPrinted: 9/19/2018 Operations Summary (with Timelog Depths) 1 H-21 0 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Slant Time End Time Dur (hr) Phase Op code Activity Code Time P -T -X Operation Start Depth (US) End Depth (ftKa) 9/4/2018 9/4/2018 1.50 PROD3 DRILL TRIP P RBIH 9,526.0 10,522.0 16:30 18:00 SD, 95611, PU, 50 k lbs, slow RIH speed to -25 ft/min, continue in hole Pump beaded sweep. 9/4/2018 9/4/2018 1.00 PROD3 DRILL WPRT P Pull wiper to the casing, PUW 63 k, 10,522.0 7,705.0 18:00 19:00 (Town working on well plan changes) 9/4/2018 9/4/2018 0.40 PROD3 DRILL WPRT P Jog the 7" x 2, PUW 42 k 7,705.0 7,840.0 19:00 19:24 9/4/2018 9/4/2018 0.20 PROD3 DRILL DLOG P Log the RA, plus 6', PUW 43 k 7,840.0 7,868.0 19:24 19:36 9/4/2018 9/4/2018 2.50 PROD3 DRILL WPRT P Wiper back in hole, RIW= 0 k, send 5 7,868.0 10,525.0 19:36 22:06 x5 sweep with beads, work pipe back to bottom. 9/4/2018 9/5/2018 1.90 PROD3 DRILL DRLG P BOBD, 1.79 bpm at 5,262 psi, 10,525.0 10,610.0 22:06 00:00 Diff -11,1150 psi, WHP=283, BHP=4,260.IA=575, OA=66 9/5/2018 9/5/2018 1.00 PROD3 DRILL DRLG P OBD, 1.77 bpm at 5,478 psi, 10,610.0 10,630.0 00:00 01:00 Diff -11,200, WHP=298, BHP=4,313, IA=622, OA=67 9/5/2018 9/512018 1.00 PROD3 DRILL DRLG P OBD, 1.77 bpm at 5,472 psi, 10,630.0 10,667.0 01:00 02:00 Diff --1,300 psi, WHP=283, BHP=4,302, IA=622, OA=67 9/5/2018 9/5/2018 0.50 PROD3 DRILL WPRT P PUW 80 k, Pull 1,000' wiper up hole to 10,667.0 9,660.0 02:00 02:30 9,660' 9/5/2018 9/5/2018 1.20 PROD3 DRILL WPRT P Wiper back in hole, RIW 2-6 k CTSW 9,660.0 10,667.0 02:30 03:42 9/5/2018 9/5/2018 2.30 PROD3 DRILL DRLG P BOBD, 1.75 bpm at 5,437 psi, 10,667.0 10,712.0 03:42 06:00 Diff --1,211 psi, WHP=277, BHP=4,419, IA=566, OA=69 9/5/2018 9/5/2018 1.90 PROD3 DRILL DRLG P Drill ahead with poor weight transfer 10,712.0 10,756.0 06:00 07:54 Average over interval 23 ft/hr 9/5/2018 9/5/2018 0.60 PROD3 DRILL WPRT P PU Wt 65 k on BHA wiper- 106' 10,756.0 10,756.0 07:54 08:30 Pull to 10,665'try to RBIH, SID, PU 46 k lbs, to 10,650', RBIH 9/512018 9/5/2018 2.00 PROD3 DRILL DRLG P Drilling ahead with poor weight 10,756.0 10,821.0 08:30 10:30 transfer CT Wt -8 k lbs, WOB 2.4 k lbs after a pick up but falls to 200 lbs quickly after a pick up. Having issues turning around after picking up. PU weights climbed to 70 k. Mix and pump 1 ppg beaded pill in new mud w 4% total lubes. ROP increased, RIH ease increased, PL's fell to 55 k lbs. Able to turn up and break through hard layer that we'd been getting deflected off. Average over interval 32 ft/hr 9/5/2018 9/5/2018 0.60 PROD3 DRILL WPRT P PU Wt 53k on 1 000'wiper#2 10,821.0 9,823.0 10:30 11:06 Pull to 10,665'try to RBIH, S/D, PU 46 k lbs, to 10,650', RBIH 9/5/2018 9/5/2018 0.60 PROD3 DRILL WPRT P RBIH RIH Wt fell from 13 k lbs at turn 9,823.0 10,821.0 11:06 11:42 around to 6 k lbs by 10,500' and 4 k lbs at 12 %min and TD 9/5/2018 9/5/2018 3.30 PROD3 DRILL DRLG P CT 5,420 psi @ 1.72 bpm, annular 10,821.0 10,932.0 11:42 15:00 4370 psi, WH 240 psi, Free spin diff 11,70 psi. WOB-8 to 0 k lbs, WOB 2 to 0.6 k lbs, ROP 80 to Average over interval 33 ft/hr Page 19/30 ReportPrinted: 9/19/2018 Operations Summary (with Timelog Depths) 1 H-21 • Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Siad Time Fnd Time Dur(hr) Pme Op Cade AceNty Cote Tune P -T-% 0 Aeration SW Depth (fit®) End Depth (fil(B) 9/5/2018 9/5/2018 2.50 PRODS DRILL DRLG P OBD, CT 5533 psi, @ 1.73 bpm, WH 10,932.0 11,007.0 15:00 17:30 287 psi, annular 4278 psi. CT Wt -7.5 k lbs, WOB 1.3 k lbs, ROP 35 Mr. Bleed IA from 745 to 586 psi - diesel. Average over interval 30 ft/hr 9/5/2018 9/5/2018 5.75 PRODS DRILL DRLG P OBD, 1.8 bpm at 5,265 psi, Diff --1,207 11,007.0 11,130.0 17:30 23:15 psi, WHP=246, BHP=4,268, IA=574, OA=74 "` Note: Losses 0.6 bpm slowly healing up to 0.1 bpm loss rate @ 11,110' 9/5/2018 9/5/2018 0.25 PRODS DRILL DRLG P TD AL2 Lateral, PUH slowly, PUW 55 +11,130.0 11,130.0 23:15 23:30 k, circulate beads doom coil. 9/5/2018 9/6/2018 0.50 PRODS DRILL WPRT P Perform Swab wiper, laying in beads 11,130.0 9,641.0 23:30 00:00 as we POOH to surface. 9/6/2018 9/6/2018 2.00 PRODS DRILL WPRT P Continue POOH 9,641.0 3,500.0 00:00 02:00 9/6/2018 9/6/2018 1.10 PRODS DRILL WPRT P Perform jog back in hole 500' 3,500.0 78.1 02:00 03:06 9/6/2018 9/6/2018 0.40 PROD3 DRILL SVRG P Tag up, inspect INJH, repair CTES 78.1 78.1 03:06 03:30 counter, reset counters 9/6/2018 9/6/2018 1.25 PRODS DRILL TRIP P RBIH, to confirm TD 78.1 7,570.0 03:30 04:45 9/6/2018 9/6/2018 0.20 PRODS DRILL DLOG P Log the K1 marker correction of plus 7,570.0 7,753.0 04:45 04:57 1.01 9/6/2018 9/6/2018 0.20 PRODS DRILL CTOP P Obtain Static BHP 11.39 ppg pressure 7,753.0 7,753.0 04:57 05:09 continued to drop, sensor Depth 6,484.67', AP=3,840 9/6/2018 9/6/2018 1.90 PRODS DRILL TRIP P Continue to RIH, Window clean, 705 7,753.0 11,128.0 05:09 07:03 Ib WOB bobble while passing the billet and a nother @ 8519'. Coil weight fell off rapidly from 9700'to 10,213' where we sat down. PU 45 k lbs. continue to RIH reducing tripping speed to - 14 ft/.min. WOB climbed seedily from 10,500' to 10,700' then fell off quickly. Tqag bottom at 11128', PU 43 k lbs, SID again with same results. 9/6/2018 9/6/2018 3.10 PRODS DRILL DSP P PU 43 k lbs, Stage beaded liner 11,128.0 70.0 07:03 10:09 running pill to the bit, POOH laying in liner running pill to 7,680' followed by 11.7 ppg KW fluid. Painted yellow TD flag @ 10176' Saw slight neg WOB spikes as we pulled through both the billet and window. Painted white window flag @ 6778' 9/6/2018 9/6/2018 1.30 PRODS DRILL DISP P PJSM, bump up, flow check- good, 70.0 0.0 10:09 11:27 PUD BHA#21 Bit came out graded 1-3 LT, lost tooth on gauge reamers. Well tight, no losses. 9/6/2018 9/6/2018 0.30 COMPZ3 DRILL BOPE P Perform BOP function test. 0.0 0.0 11:27 11:45 9/6/2018 9/6/2018 0.50 COMPZ3 CASING PUTS P Prep floor for running liner. PJSM. 0.0 0.0 11:45 12:15 9/6/2018 9/6/2018 1.70 COMPZ3 CASING PUTS P Pick up an run 30 joints (937.63) 2-3/8 0.0 938.9 12:15 13:57 ST -L 4.6 Ib/ft L-80 slotted liner with a non -ported bullnose under a shorty deployment sleeve. AL2 completion run #1 length over all - 938.87' - kick drill, AAR, clean floor from running liner. Page 20130 ReportPrinted: 9119/2018 Summary (with Timelog Depths) 1H-21 lipOperations Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Slert Time EM Time Dia (hr) Phase Op Cotle Activity Code Time P -T-% 0p !ion Start Oepm (fitDe EM Depth (Po(B) 9/6/2018 9/6/2018 1.00 C0MPZ3 CASING PULD P PU / MU BHA# 22, AL2 completion 938.0 983.1 13:57 14:57 tun #1, swap checks, skid cart, stab on, test good, bump up, set counters, 9/6/2018 9/6/2018 1.30 COMPZ3 CASING RUNL P RIH w AL2 completion run #1 983.1 7,673.0 14:57 16:15 9/6/2018 916/2018 0.20 C0MPZ3 CASING DLOG P PU 45 k lbs, tie into window flag for - 7,673.0 7,683.0 16:15 16:27 1 4.4' correction 9/6/2018 9/6/2018 1.30 COMPZ3 CASING RUNL P Continue to RIH, carried 16 k coil wt 7,683.0 11,128.6 16:27 17:45 all the way to bottom. Tag up, PU 53 k lbs, pumps on PU 43 k lbs. 9/6/2018 9/6/2018 2.25 COMM CASING TRIP P Reset counters, POOH painting flags. 11,128.6 44.2 17:45 20:00 9/6/2018 9/6/2018 0.50 COMM CASING OWFF P Check well for flow, PJSM 44.2 44.2 20:00 20:30 9/6/2018 9/6/2018 0.25 COMPZ3 CASING PULD P LD setting tools on a dead well 44.2 0.0 20:30 20:45 9/6/2018 9/6/2018 2.25 COMPZ3 CASING PUTS P PJSM, PU/MU AL2#2 Liner segment 0.0 1,376.4 20:45 23:00 45 jts of slotted liner, w/ported bullnose, and shorty deployment sleeve. 9/6/2018 9/6/2018 0.75 COMPZ3 CASING PULD P PJSM, PU/MU Coiltrak tools (good- 1,376.4 1,420.6 23:00 23:45 test) 9/6/2018 9/7/2018 0.25 COMM CASING RUNL P RIH', with BHA#23, AL2 liner segment 1,420.6 23:45 00:00 #2 w/45 its of slotted liner, shorty deployment sleeve, and ported bullnose. 917/2018 917/2018 1.00 COMPZ3 CASING RUNL P Continue IH with BHA#23 2,596.0 7,705.0 00:00 01:00 9/7/2018 9/7/2018 0.15 COMM CASING RUNL P Weight check PUW 49 k, correct to 7,705.0 7,705.0 01:00 01:09 1 the EOP flag minus 8.0' 9/7/2018 917/2018 0.35 COMM CASING RUNL P Continue IH 7,705.0 9,067.0 01:09 01:30 9/7/2018 9/7/2018 0.75 COMPZ3 CASING RUNL P Work pipe down hole, PUW 50-58 k 9,067.0 9,343.0 01:30 02:15 9/7/2018 9/7/2018 0.30 COMPZ3 CASING RUNL P Continue RIH 9,343.0 10,189.1 02:15 02:33 977/2018 9/7/2018 1.30 COMPZ3 CASING RUNL P Set down 10,189.13', PUW 58 k, set 10,189.3 8,812.7 02:33 03:51 back down 5.4 k, Bring pump on 1.45 bpm at 3,291 psi, 1.06 bpm returns, PUW 39 k, remove liner length from counters, finish building liner running pill. 9/7/2018 9/7/2018 2.30 COMM CASING TRIP P POOH, laying in 15 bbl beaded liner 8,812.7 40.0 03:51 06:09 running pill 9/7/2018 9/7/2018 0.60 COMM CASING PULD P Bumped up, flow check good, hole 50.0 0.0 06:09 06:45 static. 9/7/2018 9/7/2018 0.30 COMPZ3 CASING PUTS P Prep floor for liner running, PJSM. 0.0 0.0 06:45 07:03 9/7/2018 9/7/2018 1.00 COMPZ3 CASING PUTS P Pick up an run 10 joints (312.94') 2-3/8 0.0 324.8 07:03 08:03 ST -L 4.6 Ib/ft L-80 slotted liner with a non -ported bullnose under an anchored liner top billet. AL2 completion run #3 length over all - 324.76' - clean floor from running liner. 9/7/2018 9/7/2018 1.00 COMPZ3 CASING PULD P PU BHA #24, stab on, set counters 324.8 385.7 08:03 09:03 9/7/2018 9/7/2018 1.70 COMPZ3 CASING RUNL P RIH wAL2-0l section #3, EDC open, 385.7 7,785.0 09:03 10:45 Page 21130 ReportPrinted: 9/19/2018 . Operations Summary (with Timelog Depths) 1 H-21 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Tme End Time Dur (hr) Phase Op Cede Activity Code Time P -T -X Operation Stan Depth (fixe) End Depth rIKS) 9/7/2018 9/7/2018 0.20 COMPZ3 CASING DLOG P Tie in to window flag, -25' correction, 7,785.0 7,785.0 10:45 1057 discuss and compare, not making a correction, continue on to the K7. PU W143 k lbs. Park Close EDC. RIH to K1 9/712018 9/7/2018 0.10 COMPZ3 CASING RUNL P Continue to RIH wAL2-01sec1ion #3, 7,785.0 7,885.0 10:57 11:03 EDC open, 917/2018 9/7/2018 0.10 COMPZ3 CASING DLOG P Log Kt + 1' correction. 7,885.0 7,909.0 11:03 11:09 9/712018 9/7/2018 0.60 COMPZ3 CASING RUNL P RIH, tag up 8817.5 PU 48 k lbs, RBIH 7,909.0 8,812.0 11:09 11:45 S/D 3.67 K lbs WOB, on line with the punri 42 k lbs, Set Anchored billet slips oriented LS 9/7/2018 9/7/2018 1.70 COMPZ3 CASING TRIP P POOH 8,812.0 60.0 11:45 1327 9/7/2018 9/7/2018 1.00 COMPZ3 CASING PULD P Flow check, inspected pipe 27' back to 60.0 0.0 13:27 1427 coil connector wall thickness 1.81". LD BHA #24 over a dead well. - Crew change. 9/7/2018 9/7/2018 1.00 PROD4 STK PULD P PU BHA #25, AL@ -01 latteral drilling 0.0 80.0 14:27 15:27 assembly, check pack offs, 9/7/2018 9!7/2018 1.60 PROD4 STK TRIP P RIH, shallow test occilator tool, light 80.0 7,565.0 15:27 17:03 vibration felt on the coil at surface. Monitored frequency on pipe shed computer @ 1.5 bpm - 3500 CT pressure, 875 diff and 1.8 bpm - 5400 CT pressure, 1684 psi diff. Continue to RIH. 9/7/2018 9/7/2018 0.20 PROD4 STK DLOG P Tie into K1 for zero correction 7,565.0 7,595.0 17:03 17:15 9!712018 9/7/2018 1.20 PROD4 STK TRIP P Continue to RIH, displacing well to 7,565.0 7,595.0 17:15 18:27 1 drilling fluid, 9/7/2016 - 9/712018 0.15 PROD4 STK TRIP P Dry tag TOB @ 8,492' 7,595.0 8,492.0 18:27 18:36 9/7/2018 9/7/2018 1.50 PROD4 STK KOST P PUH, and start kicking off billtet @ 8,492.0 8,496.6 18:36 20:06 8491.5', 1.75 bpm at 5,172 psi, WHP=181, BHP=4,216, IA=4, OA=54 9/7/2018 9/7/2018 0.15 PROD4 STK KOST P Stall Motor, PUH 57 k, minus 2.3 k 8,496.6 8,473.0 20:06 20:15 DHWOB 917/2018 9/712018 0.15 PROD4 STK KOST P RBIH, RIW 15 k, 1.81 bpm @ 5,337 8,473.0 8,496.0 20:15 20:24 psi, Diff --11,230 psi, WHP=100, BHP=4,095, IA=5, OA=54 9/7/2018 9/7/2018 0.15 PROD4 STK KOST P Stall Motor, PUW 47 k, PUN to 8,478' 8,496.0 8,478.0 20:24 20:33 9/7/2018 9/7/2018 0.15 PROD4 STK KOST P RBIH, 1.8 bpm @ 5,387 psi, 8,478.0 8,500.0 20:33 20:42 Diff -1,210, WHP=124, BHP=4,235, IA=8, OA=54 9/7/2018 9!7/2018 0.60 PROD4 STK DRLG P Drill ahead 8,500.0 8,504.0 20:42 21:18 9/7/2018 9/7/2018 0.15 PROD4 STK DRLG P PUH, PUW 51 k, dry drift kickoff point 8,504.0 8,504.0 21:18 21:27 (clean) 9/7/2018 9/7/2018 0.45 PROD4 STK DRLG P BOBD, 1.8 bpm at 5,337 psi, 8,504.0 8,511.1 21:27 21:54 Diff -0,200, WHP=138, BHP=4,124, IA=24, OA=56 9/7/2018 9/8/2018 2.10 PROD4 STK WPRT T Stall motor, PUW=70 k, seems we are 8,511.1 8,511.1 21:54 00:00 detained, unable to turn orienter, work pipe, still stuck, make call to town team, discuss plan forward, bring pump on-line, 1.5 bpm at 4,830 psi, motor no longer stalled, circulate 5x5 around, Page 22/30 ReportPrinted: 9 /1 912 01 8 . Operations Summary (with Timelog Depths) 1 H-21 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Ten. End Time W (hr) Phase op CadeActivlry Code Toe P -T -X �. start Depth 0"(13) End Depth(f1KB) 9/8/2018 9/8/2018 1.00 PROD4 STK TRIP T Continue working pipe, spot lube pill 8,511.1 8,511.0 00:00 01:00 around BHA, continue working pipe. still detained. 9/8/2018 9/8/2018 1.00 PROD4 STK TRIP T Circulate lube pill up hole, work pipe, 8,511.0 8,511.0 01:00 02:00 still detained. Rotate HOT, torque seen on coil. no movement on motor. 9/8/2018 9/8/2018 0.75 PROD4 STK TRIP T Circulate 2nd 5x5 sweep 8,511.0 8,511.0 02:00 02:45 9/8/2018 9/8/2018 1.10 PROD4 STK TRIP T Work pipe, Pull 86 k, minus 16.5 k 8,511.0 8,511.0 02:45 03:51 DHWOB 9/8/2018 9/8/2018 0.50 PROD4 STK TRIP T Continue POOH 8,511.0 7,753.0 03:51 04:21 9/8/2018 9/8/2018 1.60 PROD4 STK TRIP T Open EDC, coutinue POOH 7,753.0 70.0 04:21 05:57 9/8/2018 9/8/2018 1.50 PROD4 STK PULD T Bump up, PUD BHA# 25. Bit had 70.0 0.0 05:57 07:27 chipped reamers but did not have damage indicating we had spun it against liner or slips. 9/8/2018 9/82018 1.40 PROD4 STK PULD T LD pre loaded BHA in DS PDL, 0.0 96.1 07:27 08:51 dropped 3' weight bar and 1.4' knuckle out of PDL. PU BHA# 26 to the HOT. Hung off three pups, LOA 23.66' with a ported bull nose over the hole (9.84', 7.84', 5.66'). Picked J setting tool / billet/ open hole anchors. PD, BHA, stab on, verify EDC open, bump up set counters. 9/8/2018 9/8/2018 2.60 PROD4 STK TRIP T RIH, 96.1 7,600.0 08:51 11:27 918/2018 9/8/2018 0.20 PROD4 STK -CFL-OG T Tie into the K1 for no correction. 7,600.0 7,620.0 11:27 11:39 -0 9/8/2016 9/8/2018 60 PROD4 STK TRIP T Continue to RIH with anchored billet 7,620.0 8,509.0 11:39 12:15 into 7" @ 7806', PU Wt 45 k lbs, close ECD, RIH to 8504', PU 46 k lbs, RBIH, Bit depth 8502.5', PU to neutral weight, online w pumps, shear - 4300 psi, RIH in attempt to stack weight. Push to bit depth of 8509' with -500 lbs WOB. Note TOB @ 8474' 9/8/2018 9/8/2018 1.50 PROD4 STK TRIP T POOH 8,509.0 71.0 12:15 13:45 9/8/2018 9/82018 1.10 PROD4 STK PULD T Bump up space out, PUD BHA # 26 71.0 0.0 13:45 14:51 9/8/2018 9/8/2018 1.10 PROD4 STK SVRG T Wait on arrival of billet w open hole 0.0 0.0 14:51 15:57 anchors. 9/8/2018 9/8/2018 1.60 PROD4 STK PULD T PU & PD BHA# 27. Open hole 0.0 75.5 15:57 17:33 anchored billet w 2 pups 7.72', & 1.57' with a ported bull nose. check pack offs 9/82018 9/8/2018 1.75 PROD4 STK TRIP T RIH, with BHA#27 75.5 7,580.0 17:33 19:18 9/8/2018 9/8/2018 0.20 PROD4 STK DLOG T Log the K1 marker correction of plus 7,580.0 7,605.0 19:18 19:30 0.5', PUW 43 k, close EDC 9/8/2018 9/8/2018 0.50 PROD4 STK TRIP T Continue IH, set down 8,474', 7,605.0 8,473.1 19:30 20:00 9/8/2018 9/82018 0.25 PROD4 STK TRIP T PUW 49 k, set back down 2.2 k, PUH 8,473.1 8,452.3 20:00 20:15 46 k, 0.5 k DHWOB, bring pump up to shear 4,900 psi 9/8/2018 9/8/2018 1.75 PROD4 STK TRIP T PUH=48 k, POOH 8,452.3 61.2 20:15 22:00 9/8/2016 9/8/2018 0.92 PROD4 STK PULD T Tag up space out, PUD & LD setting 61.2 0.0 22:00 22:55 tools Page 23/30 Report Printed: 9/19/2018 Operations Summary (with Timelog Depths) 1 H-21 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Stan Time End Time our (hr) phase op Cade MWiy Code Time P -T-% operation Stan Depth (W) End Depth(ftO) 9/8/2018 9/8/2018 0.30 PROD4 STK PULD T Reconfigure BHA (MU motor and bit) 0.0 0.0 22:55 23:13 9/8/2018 9/9/2018 0.78 PR0D4 STK PULD T PD kickoff drilling BHA #28 0.0 0.0 23:13 00:00 9/9/2018 9/9/2018 0.50 PROD4 STK 7ULD T MU Upper Quick, surface test Coiltrak 0.0 78.1 00:00 00:30 - tools (good -test) 9/9/2018 9/9/2018 1.50 15ROD4 STK TRIP T RIH, w/drilling BHA# 28, test agitator 78.1 7,570.0 00:30 02:00 1 @ 500' (good -test) 9/9/2018 9/9/2018 0.15 PROD4 STK DLOG T Log the K1 marker correction of zero 7,570.0 7,590.0 02:00 02:09 9/9/2018 9/9/2018 0.20 PR0D4 STK TRIP T Continue IH 7,590.0 8,452.5 02:09 02:21 9/9/2018 9/9/2018 0.15 PROD4 STK TRIP T Drytag TOB @ 8452.5' 8,452.5 8,436.0 02:21 02:30 9!9/2018 9/9/2018 0.15 PR0D4 STK TRIP T Bring pump on-line @ 1.80 bpm at 8,436.0 8,453.7 02:30 02:39 5,294 psi, Diff --1,360 psi, WHP=336, IA=O, OA=49 9/9/2018 9/9/2018 0.30 PROD4 STK KOST T Attempt to find billet, 150° ROHS as 8,453.7 8,455.0 02:39 02:57 per RP, chase WOB to 8,455' 9/9/2018 9/9/2018 1.50 PROD4 STK KOST P Start time milling 1.79 bpm @ 5,475 8,455.0 8,458.0 02:57 04:27 psi, Diff -1344 psi, WHP=149, BHP=4,157, ]A=O, OA=53 9/9/2018 9/9/2018 1.60 PROD4 DRILL DRLG P Start drilling ahead 16 fph 1.79 bpm at 8,458.0 8,565.0 04:27 06:03 5,438 psi, Diff --1,360 psi, WHP=149, BHP=4,173, IA=11, OA=55 9/9/2018 9/9/2018 0.20 PROD4 DRILL WPRT P PU 48 k lbs, PUH, to 8412', billet 8,565.0 8,565.0 06:03 06:15 clean, RBIH dry drift, window clean. 9/9/2018 9/9/2018 1.10 PROD4 DRILL DRLG P CT 4205 psi @ 1.77 bpm, Free spin 8,458.0 8,565.0 06:15 07:21 diff 1348 psi, IA 95 psi, GA 58 psi. OBD, CT wt 15 k lbs, WOB 1.8 k lbs, ROP 40 - 300 R/ hr. 9/9/2018 9/9/2018 1.40 PROD4 DRILL DRLG P Having difficulty dropping angle. cut 8,458.0 8,720.0 07:21 08:45 rate from 1.8 to 1.5 bpm. Targeting higher WOB. 8688' WOB Cloning, held WOB - 3-4 k Ib to 8562'. Allowed to mill off, time drilled to 8720' 9/9/2018 9/9/2018 1.00 PROD4 DRILL '5RLG P PU to acquire new parameters, Ct 8,720.0 8,756.0 08:45 09:45 4558 psi @ 1.5 bpm, annular 4206 psi. OBD, targeting 34 k LBS WOB. Drilled ahead with angle slowly dropping. 9/9/2018 9/9/2018 6.10 PROD4 DRILL DRLG P PU and increase pump rate to 1.78 8,756.0 8,860.0 09:45 15:51 bpm. Ct 5405 psi @ 1.78 bpm, free spin diff 1240 psi, annular 4244 psi. OBD, Ct Wt 15 k lbs, WOB 3.5 k lbs, ROP 10 ft/hr Drilled through two sections of wrapped gamma @ 8760', and 8810' 9/9/2018 9/9/2018 1.00 PROD4 DRILL DRLG P ROP climbed rapidly from 25 to over 8,860.0 8,935.0 15:51 16:51 120 ft/hr. CT 5815 psi, @ 1.79 bpm, Annular 4148 psi, IA457 psi, OA67 psi CT Wt 1.4 k lbs, WOB 3.4 k lbs, ROP 61 ft/hr Chase sweeps to the bit. 9/9/2018 9/9/2018 0.35 PROD4 DRILL WPRT P PU 53 k lbs, wiper #1,NOV agitator 8,935.0 8,477.0 16:51 17:12 working 1, swap computers 9/9/2018 9/9/2018 0.80 PROD4 DRILL WPRT P Wiper back in hole, RIW 15 k 8,477.0 8,935.0 17:12 18:00 Page 24/30 ReportPrinted: 9/19/2018 . Operations Summary (with Timelog Depths) IH -21 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log stmt Time End Time Dix (hr) Phase Op Code Activity Code Time P -T -X Operation st( Bpm End Depth(axe) 9/9/2018 9/9/2018 3.75 PROD4 DRILL DRLG P BOBD, 1.76 bpm @ 5,647 psi, 8,935.0 9,436.0 18:00 21:45 Diff -1,390 psi, WHP=181, BHP=4,244, IA=356, OA=67, Avg.ROP=80 fph *** Note: New Mud @ 9,089' 9/9/2018 9/9/2018 0.50 PROD4 DRILL WPRT P Wiper up hole to the window, PUW 53 9,436.0 8,100.0 21:45 22:15 k 9/9/2018 9/9/2018 0.15 PROD4 DRILL WPRT P Perform Jog in hole 100'@ 50 fpm 8,100.0 8,204.0 22:15 22:24 9/9/2018 9/9/2018 0.80 PROD4 DRILL WPRT P Continue wiper up hole, PUW 16 k, 8,204.0 7,845.0 22:24 23:12 jog clean 7" with sweeps 9/9/2018 9/9/2018 0.20 PROD4 DRILL DLOG P Log the RA marker correction of plus 7,845.0 7,869.0 23:12 23:24 7.0' 9/912018 911012018 0.60 PROD4 DRILLWPRT P Continue Wiper back in hole, RIW 15 7,869.0 9,436.0 23:24 00:00 k 9/10/2018 9/10/2018 0.30 PROD4 DRILL DRLG P BOBD, 1.79 bpm at 5,160 psi, 9,436.0 9,556.0 00:00 00:18 Diff --1,305 psi, WHP=438, BHP=4,338, IA=218, OA=64, *** Note: Needing to get build and tum. 9/10/2018 9/10/2018 0.15 PROD4 DRILL WPRT P PUW 52 k. BHA wiper up hole, PUW 9,556.0 9,556.0 00:18 00:27 52 k 9/10/2018 9/10/2018 0.20 PROD4 DRILL DRLG P BOBD, 1.78 bpm at 5,065 psi, 9,556.0 9,583.0 00:27 00:39 Diff --1,365, WHP=357, BHP=4,272, IA=353, OA=66 9/10/2018 9/1012018 0.15 PR0D4 DRILL WPRT P PUW 52 k, work pipe x 3, not able to 9,583.0 9,583.0 00:39 00:48 build angle or tum to the east. 9/1012018 9/10/2018 0.20 PROD4 DRILL DRLG P BOBD, 1.78 bpm at 5,065 psi, 9,583.0 9,614.0 00:48 01:00 Diff --1,366, WHP=357, BHP=4,272, IA=353, OA=66, CTSW - 5 k 9110/2018 9110/2018 0.15 PROD4 DRILL WPRT P PUW 52 k, work pipe x 3, not able to 9,614.0 9,614.0 01:00 01:09 build angle or turn to the east. 9/10/2018 9/10/2018 0.50 PROD4 DRILL DRLG P BOBD, 1.79 bpm at 5,090 psi, 9,614.0 9,639.0 01:09 01:39 Diff -1,360 psi, WHP=357, BHP=4,257, IA=357, OA=66 9/10/2018 9/10/2018 0.20 PROD4 DRILL WPRT P PUW 52 k, work pipe x 3. getting turn, 9,639.0 9,725.0 01:39 01:51 still having trouble building angle. 9110/2018 9/10/2018 0.30 PROD4 DRILL DRLG P BOBD, 1.79 bpm at 5,090 psi, 9,725.0 9,820.0 01:51 02:09 Diff -1,360 psi, WHP=357, BHP=4,257, IA=357, OA=66 9/1012018 9/10/2018 0.15 PROD4 DRILL WPRT P PUW 55 k, work pipe x 3, not able to 9,820.0 9,820.0 02:09 02:18 build, 9/10/2018 9/10/2018 0.30 PROD4 DRILL DRLG P BOBD, 1.79 bpm at 5,035 psi, 9,820.0 9,836.0 02:18 02:36 Diff -1,208 psi, WHP=366, BHP=4,337, IA=360, OA=66 018 0/2018 0.40 PROD4 DRILL WPRT P 1,000', wiper up hole, PUW 9,836.0 8,841.0 02:36 02:36 03 0300 9/10/2018 9/10/2018 0.30 PROD4 DRILL WPRT P Wiper back in hole, RIW 14 k, make 8,841.0 9,818.0 03:00 03:18 call to town for plan forward, decision was made to POOH for correction run. 9/10/2018 9/10/2018 3.00 PROD4 DRILL TRIP T Pump 5x5 sweep, POOH to surface 9,818.0 76.9 03:18 06:18 9/10/2018 9/10/2018 1.20 PROD4 DRILL PULD T Bump Up, PUD following failed EDC 76.9 0.0 06:18 07:30 1 1 procedure, LDBHA 9/10/2018 9/10/2018 0.70 PROD4 DRILL PULD T PD BHA #290.8*AKOw RR HC 0.0 78.2 07:30 08:12 P104 cutter bit, stab injector, bump up, set counters. 9/10/2018 9/10/2018 1.50 PROD4 DRILL TRIP T Verify SSSV pressure, RIH, close 78.2 7,570.0 08:12 09:42 EDC. shallow test agitator - good. continue in hole. Page 25130 Report Printed: 9/19/2018 Operations Summary (with Timelog Depths) 1H-21 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Stan lime rm!Time Dur(hr) Phase Op Code Actkft Code Time P -T-% Operaaon Stan Depth (91a1) Entl DepN (WB) 9/10/2018 9/10/2018 0.20 PROD4 DRILL DLOG T Tie into the K1 + 0.5' correction. 7,570.0 7,631.6 09:42 09:54 9/10/2018 9/10/2018 0.80 PROD4 DRILL TRIP T PU Wt, 44 k lbs, RIH, 7,631.6 9,836.0 09:54 10:42 9/10/2018 9/10/2018 0.40 PROD4 DRILL DRLG T CT 4750 psi, @ 1.8 bpm, free spin 9,836.0 9,877.0 10:42 11:06 857 psi, annular 4180 psi,WH 255 psi, Is 110 psi, OA60 psi. OBD, CT Wt 9 k lbs, WOB 1.5 k lbs, ROP 50-200 Mr. Directional driller attempted to steer south, dropped angle rapidly. PU 50 k lbs, reduced rate to 1.50 bpm attempting to target increased WOB, near bit inc continuing to fall rapidly. 9/102018 9/10/2018 0.90 PROD4 DRILL WPRT T PU Wt 50 k lbs, Geo wiper. Rig Geo 9,877.0 9,877.0 11:06 12:00 and DD greed to put 90% into tum to the south, RBIH, Drill ahead, PU, 50 k lbs, Geo wiper #2, Last survey to the left. RBIH, PU, to resurvey, RBIH. 9/10/2018 9/10/2018 0.20 PROD4 DRILL DRLG T CT 3967 @ 1.49 bpm, free spin 654 9,877.0 9,962.0 12:00 12:12 psi, WH 276 psi, annular 4198 psi Ct Wt 7 k lbs, WOB .57 k lbs, ROP 200 R/hr. 9/10/2018 9/10/2018 0.30 PROD4 DRILL WPRT T PU 50 k lbs, DD wiper to discuss close 9,962.0 9,962.0 12:12 12:30 approach. Discuss w engineering potential dose approach to hard line on the north. Decision made to drill ahead. RBIH 9/10/2018 9/10/2018 2.00 PROD4 DRILL DRLG T OBD, CT 3900 psi @ 1.50 bpm, Tree 9,877.0 10,195.0 12:30 14:30 spin 580 psi, Annular 4299 psi, WH 364 psi CT 1.8 k lbs, WOB 0.44 k Itis, ROP 115 ff/hr 13:50 and 10,141' increase rate to 1.78 bpm, WH 316, Annular 4307 psi, CT -7 k lbs, WOB 0.34 k lbs, ROP 110 ft/sec. Pump 5 x 5 sweep Average ROP over interval - 160 f/hr 9/10/2018 9/10/2018 0.20 PROD4 DRILL WPRT T PU 53 k lbs, Pull to 9994'- 201' wiper . 10,195.0 10,195.0 14:30 14:42 RBIH 9/10/2018 9/10/2018 1.40 PROD4 DRILL DRLG T RBIH Wt 4 k Itis, Ct 4847 psi, @ 1.81 10,195.0 10,270.0 14:42 16:06 bpm, free spin 887 psi, WH 257 psi, Annular 4219 psi. OBD, CT Wt -6.4 k lbs, WOB 0.9 k Ib, ROP 33 ft/hr. 9/10/2018 9/10/2018 0.20 PROD4 DRILL WPRT T PU 53 k lbs,- 1000' wiper 10,195.0 8,992.0 16:06 16:18 Pull through low spot @ 9150' Pump 10 bbls 1 ppg beds 9/10/2018 9/102018 0.80 PROD4 DRILL WPRT T RBIH, SID 9090' PU 58 lbs, to 9031', 8,992.0 10,195.0 16:18 17:06 RBIH, SD @ 9588' W WOB. SD @ 9679' 9/10/2018 9/10/2018 2.00 PROD4 DRILL DRLG T RBIH Wt 4 k lbs, Ct 4847 psi, @ 1.81 10,195.0 10,404.0 17:06 19:06 bpm, free spin 887 psi, WH 257 psi, Annular 4219 psi. OBD, CT Wt -6.4 k lbs, WOB 0.9 k Ib, ROP 30 - 170 ft/hr. Still drifting north, turn straight up, reduce pump rate, try sweeps to get more WOB. No sucess, 9/10/2018 9/10/2018 3.10 PROD4 DRILL WPRT T PU Wt 53 k lbs, POOH for higher bend 10,404.0 74.4 19:06 22:12 1 1 motor. Page 26130 Report Printed: 911912018 Operations Summary (with Timelog Depths) 1 H-21 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Stan Tens End Time Dw(hr) Phase Op Code Activity Code Time P -T -X Operation Stan Depth (11KB) End Depth(rtim) 9/10/2018 9/10/2018 1.30 PROD4 DRILL PULD T PUD BA#29, 74.4 0.0 22:12 23:30 9/10/2018 9/11/2018 0.50 PROD4 DRILL PULD T PD BA #30,1.2 ° AKO 0.0 74.4 23:30 00:00 9/11/2018 9/1112018 0.50 PROD4 DRILL PULD T Stab INJH, check pac-offs (good) 78.2 78.2 00:00 00:30 9/1112018 9/11/2018 1.25 PROD4 DRILL TRIP T RIH, with BHA# 30 78.2 7,570.0 00:30 01:45 9/11/2018 9/11/2018 0.20 PROD4 DRILL DLOG T Log the K1 markerwith no correction, 7,570.0 7,590.0 01:45 01:57 PUW 48 k, close EDC 9111/2018 9/11/2018 1.25 PROD4 DRILL TRIP T Continue IH, steering through 9,090' 7,590.0 10,404.0 01:57 03:12 and 9,590' area. 9/11/2018 9/11/2018 1.00 PROD4 DRILL DRLG T OBD, 1.79 bpm at 5,231 psi, 10,404.0 10,472.0 03:12 04:12 Diff =1,350 psi, WHP=213, BHP=4,342, IA=36, OA=58 9/112018 9/11/2018 0.40 PROD4 DRILL WPRT T Wiper up hole, UW=53 k 10,472.0 9,925.0 04:12 04:36 9111/2018 9/11/2018 0.40 PROD4 DRILL WPRT T Wiper back in hole, RIW 5 k 9,925.0 10,472.0 04:36 05:00 9/11/2018 9/11/2018 0.80 PROD4 DRILL DRLG T BOBD, 1.79 bpm at 5,466 psi, 10,472.0 10,491.0 05:00 05:48 Diff -1,244 psi, WHP=221, BHP=4,351, IA=181, OA=58 9/11/2018 9/112018 1.50 PROD4 DRILL WPRT T Wiper up hole, PUW=53 k, jet the 7" 10,491.0 7,806.0 05:48 07:18 with sweeps 9/11/2018 9/11/2018 0.15 PROD4 DRILL WPRT T After dicussing with town team, 7,806.0 7,565.0 07:18 07:27 decision was made to RBIH to drill ahead 9/11/2018 9/11/2018 0.20 PROD4 DRILL DRLG P Log the K1 correction plus 6.0' 7,565.0 7,598.0 07:27 07:39 9/11/2018 9/112018 1.40 1 PROD4 DRILL WPRT P Continue RIH 7,598.0 10,491.0 07:39 09:03 9/11/2018 9/11/2018 3.80 PROD4 DRILL DRLG P BOBD, 1.78 bpm at 5,293 psi, 10,491.0 10,610.0 09:03 12:51 Diff --1,272 psi, WHP=109, BHP=4,292, IA=263, OA=64 9/11/2018 9/112018 1.70 PROD4 DRILL WPRT P BHA wiper up hole, PUW 58 k 10,610.0 10,510.0 12:51 14:33 9/11/2018 911112018 0.50 PROD4 DRILL DRLG P BOBD. 1.80 bpm at 5,213 psi, 10,510.0 10,666.0 14:33 15:03 Diff -960 psi, WHP=159, BHP=4,316, IA=519, OA=69, trying to hold 85°-87° 9/112018 9/11/2018 1.00 PROD4 DRILL DRLG P OBD. 1.80 bpm at 5,213 psi, Diff --960 10,666.0 10,738.0 15:03 16:03 psi, WHP=164, BHP=4,318, IA=520, OA=69 9/11/2018 9/11/2018 1.50 PROD4 DRILL DRLG P OBD. 1.80 bpm at 5,213 psi, Diff=960 10,738.0 10,771.0 16:03 17:33 psi, WHP=167, BHP=4,323, IA=522, OA=69 9/1112018 9/112018 0.90 7R0D4 DRILL WPRT P 10771. BHAWiper, PUW=60K, Stack 10,771.0 10,771.0 17:33 18:27 out trying to get to bottom. Continue wiper to 10496. Pump sweeps. Work back to bottom 9/11/2018 9/11/2018 2.80 PROD4 DRILL DRLG P 10771', Drill, 1.76 BPM @ 5150 PSI 10,771.0 10,850.0 18:27 21:15 FS, BHP=4415, RIW=-6K, DHWOB=2K 9/11/2018 9/11/2018 0.10 PROD4 DRILL WPRT P 10850'. BHA wiper, PUW=65K 10,850.0 10,850.0 21:15 21:21 9/11/2018 9/11/2018 1.00 PROD4 DRILL DRLG P 10850', Drill, 1.78 BPM @ 5280PSI 10,850.0 10,881.0 2121 2221 FS, BHP=4400, RIW=4K 9/11/2018 9/11/2018 0.10 PROD4 DRILL WPRT P 10881, P/U and restart, PUW=61K 10,881.0 10,881.0 22:21 22:27 9/11/2018 9/12/2018 1.55 PROD4 DRILL DRLG P 10881', Drill, 1.78 BPM @ 5210 PSI 10,881.0 10,907.0 22:27 00:00 FS, BHP=4390 Page 27/30 Report Printed: 9/19/2018 Operations Summary (with Timelog Depths) IH -21 • Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Tme EM Time Dw(hr) Phase Op cotle Activity Go Time P-T-XOperation Start Depth (MB) End Depth dtKB) 9/12/2018 9/12!2018 0.20 PROD4 DRILL DRLG P billing, 1.78 BPM 0_ 5210 PSI FS, 10,907.0 10,910.0 00:00 00:12 BHP=4390PSI 9/12/2018 9/12/2018 0.60 PROD4 DRILL WPRT P 10910', Call TD, PUH pumping 10 X 10,910.0 10,910.0 00:12 00:48 10 Sweeps 9/12/2018 9/12/2018 3.10 PROD4 DRILL WPRT P Sweeps out, Chase to swab, 10,910.0 65.0 00:48 03:54 PUW=58K 9/12/2018 9/12/2018 1.50 PROD4 DRILL WPRT P Tag up at surface, Set counters, RBIH 65.0 7,570.0 03:54 05:24 9/12/2018 9/12/2018 0.15 PROD4 DRILL DLOG P Log the K1 correction 0.5' 7,570.0 7,591.0 05:24 05:33 9/12/2018 9/12/2018 0.15 PROD4 DRILL TRIP P Continue IH to above window. 7,591.0 7,800.0 05:33 05:42 9/12/2018 9/12/2018 0.20 PROD4 DRILL CTOP P Obtain pressure survey 6,520.79 7,800.0 7,800.0 05:42 05:54 Sensor/TVD, 11.32 ppg and slowly falling 9/12/2018 9/122018 2.50 PROD4 DRILL TRIP P Continue IH confirm TD 10,906, Iline 7,800.0 10,908.0 05:54 08:24 up liner pill down the coil 9/12/2018 9/12/2018 1.45 PR0D4 DRILL TRIP P POOH laying in beaded 11.55 ppg 10,908.0 6,500.0 08:24 09:51 completion fluid, painting EDP flags 9/12/2018 9/122018 1.20 PROD4 DRILL TRIP P Continue POOH, displacing well to 6,500.0 78.2 09:51 11:03 11.55 ppg completion fluid to surface 9/12/2018 9/12/2018 0.50 PROD4 DRILL OWFF P At surface, check well for flow, PJSM 78.2 78.2 11:03 11:33 9/12/2018 9/12/2018 0.50 15ROD4 DRILL PULD P LD drilling BHA, flush and blow down 78.2 0.0 11:33 12:03 tools 9/12/2018 9/12/2018 0.25 C0MPZ4 CASING PUTB P Prep Rig Floor for Liner Ops 0.0 0.0 12:03 12:18 9/12/2018 9/12/2018 1.30 PROD4 CASING RUNL P PU/MU.30 its of slotted liner, shorty 0.0 923.0 12:18 13:36 deployment sleeve, and non -ported bullnose. 9/12/2018 9/12/2018 0.50 PROD4 CASING PULD P PU/MU Coiltrak tools surface test 923.0 967.3 13:36 14:06 (good -test) 9/12/2018 9/12/2018 1.65 PROD4 CASING RUNL P RIH, with AL2 -01 Linersegment#1 w/ 967.3 8,474.0 14:06 15:45 30 its of slotted liner 9/12/2018 9/12/2018 0.20 PROD4 CASING RUNL P Log the K1 marker correction of plus 8,474.0 8,523.0 15:45 15:57 6.0' (correction at flat minus 4.0') 9/122018 9/12/2018 0.60 PROD4 CASING RUNL P Continue IH 8,523.0 10,500.8 15:57 16:33 9/12/2018 9/12/2018 0.20 PROD4 CASING RUNL P PUW 55 k, RBIH to 10,500.8', bring 10,500.8 9,577.8 16:33 16:45 pump online 1.4 bpm, PUW 41 k, remove liner length from counters 9/12/2018 9/12/2018 2.25 PROD4 CASING R UNL P POOH, Paint EDP flag 6600' 9,577.8 55.0 16:45 19:00 9/12/2018 9/12/2018 0.50 PROD4 CASING PULD P At surface, Flow check well, Lay down 55.0 0.0 19:00 19:30 BHA#31 1-2-01 1st liner run setting tools 9/12/2018 9/12/2018 0.50 PROD4 CASING SVRG P Change out mechanical disconnect on 0.0 0.0 19:30 20:00 safety joint 9/12/2018 9/12/2018 2.00 PROD4 CASING PUTB P PIU AL2 -01 intermediate liner runwith 0.0 1,112.8 20:00 22:00 ported bull nose, 36 As sloted liner, and shorty deployment sleeve 9/12/2018 9/12/2018 0.60 PROD4 CASING PULD P M/U Coiltrak to liner. M/U coil to tools 1,112.8 1,157.0 22:00 22:36 and surface test. Tag up and set counters 9/12/2018 9/13/2018 1.40 PROD4 CASING RUNL P Trip in hole BHA #32, AL2 -01 1,157.0 7,749.0 22:36 00:00 intermediate compleion, EDC closed pumping 11.4 revised KWF 9/13/2018 9/13/2018 0.70 PROD4 CASING RUNL P Continiue in well BHA#32 7,749.0 8,660.0 00:00 00:42 intermediate liner segment 9/13/2018 9/13/2018 0.10 PROD4 CASING DLOG P Log K1 for+3.5' correction 8,660.0 8,680.0 00:42 0048 Page 28130 Report Printed: 9/19/2018 AIML ,; Operations Summary (with Timelog Depths) 1 H-21 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Stmt Time End TM Dur(hr) Phase Op Code A4vity Code Time P -T -X Opme&m start Depth (WB) End Depth (WB) 9/13/2018 9/13/2018 0.30 PROD4 CASING RUNL P Continue in well. Cean pass through 8,680.0 9,577.0 00:48 01:06 window. tag TOL @ 9577, PUW=53K, DHWOB=-4K 9113/2018 9/13/2018 0.20 PROD4 CASING RUNL P Set back down, 11.4 PPG New NaBr 9,577.0 6,456.0 01:06 01:18 out of GS. Pump 1.55 BPM @ 4910 PSI. Lift off liner, PUW=43K, DHWOB=-1.2 PUH 10 feet. Subtract liner length left in hole. Circ 10 BBIs in, 9/13/2018 9/13/2018 1.90 PROD4 CASING TRIP P Trip out of well, Paint EOP flag @ 8,456.0 47.1 01:18 03:12 6900' 9/13/2018 9/13/2018 0.70 PROD4 CASING PULD P At surface, Flow check well, PJSM lay 47.1 0.0 03:12 03:54 down tools on dead well 9/13/2018 9/13/2018 2.60 PROD4 CASING PUTS P PJSM, PIU tubing, BHA #33 AL2 -01 0.0 794.9 03:54 06:30 upper liner segment with ported bull nose, 14 jts slotted liner, HAL Swell Packer, 1 jt solid liner, HAL Swell Packer, 3 jts slotted liner, HAL Swell Packer, 5 jts solid liner, and deployment sleeve w/6' SBR 9/13/2018 9/13/2018 0.70 PROD4 CASING PULD P M/U Coiltrak to liner. M/U coil to tools 794.9 839.1 06:30 07:12 and surface test. Tag up and set counters 9/13/2018 9/13/2018 1.50 PROD4 CASING RUNL P TIH BHA#33 AL2 -01 upper liner 839.1 7,942.0 07:12 08:42 segment 9/13/2018 9/13/2018 0.10 PROD4 CASING RUNL P Correct depth at window flag, -2.7' 7,942.0 7,942.0 08:42 08:48 correction, wt check 45k 9/13/2018 9/13/2018 0.10 PROD4 CASING RUNL P Continue TIH, log K1 +3' correction, 7,942.0 8,466.8 08:48 08:54 tag TOL @ 8466.77' 9/13/2018 9/13/2018 0.20 PROD4 CASING RUNL P Pump 1.4 BPM, 1167 psi differential 8,466.8 7,670.5 08:54 09:06 to release off liner, 34k up weight 9/13/2018 9/13/2018 1.80 DEMOB CASING TRIP P Displace well to SW pumping .64 7,670.5 2,700.0 09:06 10:54 BPM/1200 psi, recover 11.4 PPG NaBR and TOOH to 2700' 9/13/2018 9/13/2018 1.00 DEMOB CASING TRIP T Standby for LRS due to poor road 2,700.0 2,700.0 10:54 11:54 conditions 9/13/2018 9/13/2018 0.75 DEMOB WHDBOP FRZP P PJSM w/LRS, PT lines to 4000 psi, 2,700.0 2,700.0 11:54 12:39 line up LRS to pump 35 bbls diesel FP into coil 9/13/2018 9/13/2018 0.75 DEMOB WHDBOP FRZP P TOOH to surface 2,700.0 44.2 12:39 13:24 9/13/2018 9/13/2018 1.50 DEMOB WHDBOP PULD P Close Swap valve, LD, setting tools, 44.2 0.0 13:24 14:54 MU nozzle, "' Note: Final Tubing presure 670 psi 9/13/2018 9/13/2018 2.30 DEMOB WHDBOP CTOP P Stab INJH, PJSM, w/ Haliburton N2, 0.0 0.0 14:54 17:12 PT surface line to 4,000 psi, Blowdown CT strong. Bleed off N2, R/D HES N2 9/13/2018 9/13/2018 0.80 DEMOB WHDBOP CTOP P Unstab injector, remove UQC and cut 0.0 0.0 17:12 18:00 a -line 9/13/2018 9/13/2018 2.00 DEMOB WHDBOP CTOP P PJSM, remove inner reel iron, 0.0 0.0 18:00 20:00 pressure bulkhead, and wash pipe, continue loading out pits 9/13/2018 9/13/2018 2.00 DEMOB WHDBOP CTOP P PJSM, R/U CT grapple and 0.0 0.0 20:00 22:00 unstabbing cable. Unstab CT from injector pull back to storage reel and secure to reel 9/13/2018 9/13/2018 1.50 DEMOB WHDBOP CTOP P PJSM, R/U to pick storage reel. Prep 0.0 0.0 22:00 23:30 1 reel sump. Pull king pin 9/13/2018 9/14/2018 0.50 DEMOB WHDBOP CTOP - P PJSM with Peak, Pick reel and plac on 0.0 0.0 23:30 00:00 Peak sow bed truck 9/14/2018 9/14/2018 1.00 DEMOB MOVE CTOP P Continue CT string change 0.0 0.0 00:00 01:00 Page 29130 Report Printed: 911912018 Operations Summary (with Timelog Depths) 1H-21 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Stag Time End Time our (hr) Phase Op Code Activity Code Tme P -T -X Operation Stan Depth (ftKB) End Depth (ftKB) 9/14/2018 9/14/2018 5.00 DEMOB MOVE CTOP P Reel installed, Shim reel to carrier, 0.0 0.0 01:00 06:00 Tourque saddle lamps Pull stuffing box for brass change out. Remove pump in sub and quick test sub for tubo inspection. 9/14/2018 9114/2018 6.00 DEMOB MOVE CTOP P Finish securing reel, stab coil into 0.0 0.0 06:00 1200 INJH, Nipple down Stack. Work rig move check list, Rig released 12:00 noon Page 30/30 Report Printed: 9/19/2018 .I ConocoPhillips ConocoPhillips (Alaska) Inc. Kuparuk River Unit Kuparuk 1H Pad 1 H-21AL2 50-029-22355-61 Baker Hughes INTEQ Definitive Survey Report 02 October, 2018 BAKER JUGHES Emma, ,-. ConocoPhlllips e ConocoPhillips Definitive Survey Report Company: C.IstoPMlllps(Alaska) Inc. Project: Kupamk River Unit she Kupatuk IF Pan Well: 1H-21 Wellborn: 1H-21 Design: 1H-21 Project Kupamk River Unk, North Slope Alaska, United Steles Map System: US State Plane 1927 (Exact ironer) System Datum Geo Datum: NAD 1927 (NADCON CONUS) Map Zone: Alaska Zone 04 Well 1H-21 Local Co-ardlnate Reference. Well 1H-21 ND Reference: IN -21 ® 96.00usft (11-1-21) MD Reference: 111-21 @ 96.00uak (1H-21) N.Ah Reference: Time Survey Oalculntion Method Minimum Curvature Database. EDT 14 Alaska Production Well Position tW5 0.o0 waft Northing: Using 9eadetic scale factor .EJ -W 0.00 usfl Entitled: Position Uncertainty Longitude: 0.00 such Wellhead Elevakon: Wellbore 1H-21AU Magnetics Model Name (uetg Sample Data BGGM2018 9/112018 Design IH-21AL2 90.00 Audit Notes Mean Sea Level 1.0 Using MMI/ Reference Point Tta On Depth: 7,907.21 Using 9eadetic scale factor 5,990.024.57usft littlest: 549,555.22usfl Longitude: us8 Ground Level: Declination Dip Angle 1% fl 17.01 50 91 70° 21 22.356 N 149.35' 61.196 W 54,40 Us8 Field Strength Inn 57,446 Version: 1.0 Phase: ACTUAL Tta On Depth: 7,907.21 Vertical Section: Depth From (WO) vNl-0 aEhe Direction (us") loan) (uetg (•I 41.60 0.00 D.00 90.00 Survey Program Data - -- -- —---_----- From To Survey Survey (waft) (usfl) Survey(Wellborv) Tool Nemo Doucilptlon Start Dab End Data 102.20 7,807.30 1H-21 Srvy I- SLB _GCT -MS (1H-21) GCT -MS Schlumberger GCT ms9itiot 42811993 42&1993 7,826.00 7,876.23 11121A MW INC (1 H -21A) MWD -INC ONLY MW➢1NC_0NLY FILLER 8/192018 8/192018 7.90731 7,90721 1H -21A MM (1 H31A) MWD MWO- Slandard 8119/2018 8/2112018 7,935.00 11,095.73 1H-21AU MM (I H-21AL2) MWD MM -Standard 82912018 8152018 IDW018 25636PM Page 2 COMPASS 5000.14 Build 85D r. COIIOCOPhilll 5 p ConocoPhillipsI Definitive Survey Report X163 d '•"^^^ Company: ConocoPhllllps (Alaska) Inc. Local Coordinate Relenence: Wall 111-21 Project: Kupamk River Unit NO Reference: 1H-21@96.00uafl(i H-21) Sbe: Kupamk 1H Pad MD Reference'. 1H-21@M.00us%(1 H-21) Well: 111L1 None Reference: Tme Weliben: 1H-21 Survey Calculation Method: Minimum Curvature Deal, 11141 Database'. EDT 14 Alaska Pmducti0n Survey MD Inc Map Map Venlnl lesttl 1'1 Ara PI TVD lusnl TVOSS (usR1 94143 lain) .0-WNone, (usnl Eastin9 OLS Section Survey To.[ Name Animntun (rtl IS) (.1100.) Inl � 7,90721 69.05 %.16 662705 6,531.05 -106]6 3,77072 592994017 553326.21 4046 377072 MWOi3) TIP 7.935.41 0195 6650 6634.41 6,53608 -107.51 3.]9].52 syn 842.19 53.353.00 4585 3,797.52 MWO(4) KDP SII 7,956.1] 59]1 11,17 6,W,46 6,54846 405.54 3.626,63 5,978.900.35 553,382.09 7236 3.626.83 kiWD(4) 7 895.40 4.33 93,35 666153 65%53 -105.19 3,849.40 6,979.941.05 553404.03 54.54 3,M,Q MND MI 0,026.]1 5064 11013 666356 6,587.76 -11002 3,871S7 5,979,9a0t8 553.427.36 4.23 3071ffi MND(4) 8,05594 61.59 1LV.W 6.69998 6,41396 -116.10 3.895.31 5,9]9,83417 553,45083 48.29 3,89531 MWD (4) 809517 7308 4133 6.711.19 661519 -0185y 3.92258 5,978,931.97 553470.28 4991{ 3.922]6 MJN(4) 8,115.87 7992 0200 6,71892 6,62202 -11618 3,951.98 5,979.933,90 55,50].50 3155 3.951.98 MND(4) 0147.35 SI'M ]9.6] 6,723,16 6,627.16 -1125 3,982.67 5,979,938.88 553,538,16 1D.69 3,90267 MD (4) i 8.17612 83.511 77.30 6,726.96 6,00.% -114.38 4,01062 5,9]394,74 553,65c6 11.20 401062 MWD(4) 8.(6,33 84.07 7439 6530.10 663410 48.28 4.03858 5,878.86200 55159417 10.31 4,0870 MWD(4) 8,L'6.0] 85.82 ]f.% 6,732.01 663681 4148 4,068.38 5,9]9,%000 53,62352 7.90 4,068.38 MND(4) 8,185.69 0897 77.92 6.733.90 6,637.80 -01 M 4,41222 5,979.966.05 55365251 15.32 4,097M MD (4) 8,30049 905 0.83 6533.74 6,63214 -78.42 4,131.42 5,979,9)3.49 553.&83.0 853 4,131,12 MWD(4) 6,33087 90.34 MM 6Mw 6,637 50 -74.64 0,161.55 54139]].46 553,71672 13.35 4,161.55 MWD (4) 330.18 0.57 67.65 6533.53 66375 -0273 4,190.81 5,979,09.57 553,746.01 9.81 4190.81 MJrD (4) 8,3%.41 9071 %.0 6,733.4 6.6374 -]2.N 4,221.0.5 5,979,9O.16 55751.25 11.30 4,Y1105 MNO(4) 6420.38 8234 92.37 8531.0 Seal -7310 4250.6] 5,8]397352 553.80l 206 4,260,9] MWD(4) 645036 96.03 03.42 6730.5 6.634.50 -74.80 4,2W.72 5,9799]021 553.OWN 13.16 4,28072 MD(4) 848051 98,10 93.99 6526% 6Isiow -06.59 4,31015 5.9.4.,416.41 55,665.35 10.76 431015 MWD (4) I 8,510.5 102.21 9576 6.R0.% 6,62090 -79.13 4,340.0 5.87387416 553,89522 11,15 4,340.00 MWD (4) 8.540.2] 10296 88.24 8,7144 6.61041 ffi,B2 4,30.80 5,418,970.5 553,82451 11.66 4,30.41 MD (4) 6670]0 10291 102.75 6707.0 6.61163 2850 4397.81 59]990,09 553.9019 11,26 4,39]91 MWD (4) 8,565 101.99 10.31 6,70239 6,606.39 23.84 4421.59 5,979,90.99 50"691 5.17 4,421.59 MWD(4) i 8,05.47 99.0 9641 6,697,02 6601O 4816 4,45.57 5.979 951.86 551,05,51 15.16 4,450.57 MWD(4) 8,65.52 98.25 9119 6.692.51 659651 -10,70 4,40.% 59]3961.5 551035.43 11,19 440.06 MND(4) 8,690." 10082 8340 6.68555 6580]5 -10538 451463 5sn'sal 551.0Mod 0.41 4.514.63 MND(4) 8.M82 10025 90.69 098128 6.%5,28 -10.35 4,5426 5."951"29 5KMM 6.92 4, on 26 MWD 14) 8,74349 990 Sent 6676.M 8,50,36 406," 4,9250 5,9m9,94951 554,12786 941 4,9250 MWD(4) __-8,78046_ 9347 51.87 867125 6,57525 404.24 4,02.99 5,973850.79 54.15S,35 1016 4.02.99 MWD(4) 1(111018 2:58:36PRM Pape 3 COMPASS 5000.14 Budd 850 �.. ConocoPhillips �++ A ConocoPhilli � Definitive Survey Report Company: CDnocOPhillipa(Alaska) Inc. Local Co-ordinate Reference: Well 1H-21 Project Kuparuk River Unit ND ftetemnce: 1H-21@9660usft(1H-21) was: Kupamk lH Pad MD Reference: 1H-21@ 96.00us8(1R21) W.": 11-1-21 North Raft... Tme WalMere: IH -21 Survey Calculation Method Minimum Curvature Design: IH -21 Database: EDT 14 Alas" Production Survey 10?8018 2.5636PM Page 4 COMPASS 5000.14 Budd 80 Map MD Inc 1% Atl 1'1 TVD loan) i( -am uattl 497$ loam +E (Mam Waning Eaakto DLS Section SurvryTool Name Annotationluafry 1X1 IXI flog) 1111 8,810.27 10087 82.50 6,YS.99 6,569.99 -101.. 4632.16 5,979 95a 16 55418149 9.10 4,632.16 MND(4) 0,840.2 101.91 8407 6,65997 6.563,97 -97.59 4,001.80 5,979,957.63 554217,11 589 4,561.00 MD (4) 6.07071 101,81 0797 6.653.01 6,557.81 .90.1 4681.07 5,979.99118 550,2,6.35 11.20 4,69107 MND (4) 8.89543 Inc. 9375 6,640.93 6,552.93 65.06 4.715.30 5,979.330.71 554,27050 13.37 4,71530 MWD(4) 8,926D7 10056 0.01 6,643,19 6547.19 65,05 4,745.37 5,879.959.@ 554303.97 7,20 4,745.37 MW9(4) 8,955.93 101.01 9695 6.637.36 6541.30 1058 4,774.54 5,979,957.57 554,38,85 1346 414.54 M 10 (4) 0,987.30 10102 9835 6631.@ 6,53542 -102.68 4,80507 5,979953.68 554360.40 719 4,805,07 MD (4) 9,91709 9745 85.42 0,62690 6,520.80 AWA7 4,03437 5,979,950.09 554,309.62 1D.74 4,63427 MD (4) %U663 9707 94.29 6,623,14 6,527.14 -loan 4.863.64 5.979,9253 554.419.00 73L 486364 61WD(4) 9,076.71 85.10 92M 6,619.87 0.58.97 -110,91 4.69G,30 S.B79.948.01 554448.67 8.54 4.893.30 MWD(4) 92007.8 92.76 90.04 0,617.80 6.521.88 -11151 4.98.73 5,88,84564 554.2910 10.47 4.%3.73 M (4) 9,137.18 92.70 Was 6616.3 6520.43 -110.70 4,953.64 5,979845..65 5K5WW 10.64 4,56364 MND(4) 9.166.01 9411 0517 661497 61518.65 -1W,M 4,803.14 5.979 ,84690 554,530.40 7.20 4,803.14 MD (4) 9.18649 9655 8A. 6611,09 6515.88 -1095 5,012.57 5.97995159 5,6,567.69 8.63 5,54257 MD (4) 9,22662 8632 82.24 6,607.99 6,51199 40240 S,M2,24 5,979.95546 554.597M 9.20 5,04224 MD (4) 9,257.13 94.69 0Y 6604.54 6500.54 6839 59827 5879.95975 5,6,62],6 1163 5.07237 MrW(4) 9,26725 90,25 80.93 6.6O1N 6.50724 13,89 5,102.W 5,8]99,6 .34 554,6578 15.35 5,103.03 MrW(4) 8,317.17 MAS 7927 6.60201 6,506.61 -88.84 5131.49 5.979.968.68 5,6656,5.9 851 5,13148 MWD(4) 9,346.97 DOW Mn 6601.07 6597,67 6215 5.160.63 5,9799667 OR 71578 8.93 5,16063 MWD(4) 8,376.88 91.67 TAN 001.20 6,597.20 -75.14 5,18969 5,979,983.77 554.744.78 9.01 5,18969 MWD (4) 9,40467 9160 71.57 6.603.30 0,504.38 A7.19 5,215.56 5979.99106 554,77060 1097 5.215.56 MWD(4) 9436.86 901 68.14 6,59.70 6,503.70 E5o0 5,24633 51800,003130 54.80130 lon 5.24633 MJ00(4) 9,46931 90.03 6432 0,59.8 6,503.8 N.23 5275.10 5980 M624 5,6.08.98 1215 5,275.10 MD (4) 949677 9028 oz. 6,598,9 6,502,99 1108 5,30050 5,9800834 54,05529 8.24 5,30050 M (4) 952587 BO95 61.43 6500.67 6,5@.67 -1861 5,326 13 5,980,04319 554.88082 3.11 5=13 MWD (4) 9,557..31 Bnn 58.8 6598A7 6,5MA7 6.02 5,353.31 59PL,W9.16 954,97.9 1074 5.353.31 MWD(4) 9589.28 9097 COM 8.59.53 5.9253 1545 5.380.82 5880,07561 5 RM.30 T13 5,360.82 MWD(4) 9.620.86 9.55 Sov 6.597.83 6.501,03 31.05 540027 5.980,091.39 54,962,6 012 5,40127 AND (4) 9655.10 9354 64.25 659615 6,597,15 4797 5,430.61 5.WD,107.4 5489287 1167 5,43861 MWD(4) 8,605.43 WAO 65.65 669520 6,49.24 59.00 5.466.00 5,98],12052 555020.17 968 5466 OD MD (4) 9119.83 8757 6150 659.85 649.05 "345 5.497.56 5880.13437 555,051.,6 994 5,49756 MD (4) 10?8018 2.5636PM Page 4 COMPASS 5000.14 Budd 80 r `. ConocoPhillips • ConocoPhillips Definitive Survey Report Survey Company: ConocoPhlllip3(Alaska) Inc. Local Coartimm. Rerchnce: Well 111-21 Pm)ect: Kupamk River Unit TVO Reference: 1H-21@%.00uell(111-21) Sao Kupamk I Pad MD Reference: 11131@0.00us8(111-21) Well 1131 North Rehrence: True Wellbore: 11-21 Survey Calculation Method: Minimum Culvatore Design: 11-21 Database: EDT 14 Alaska Production Survey 10? 016256:WPM Paget COMPASS W00148.0850 Withinil MD inch) Inc 11 AL 1'1 (uhi TVDSS toad) aNf-5 (tion) .61079 loan) Northing TVD t East DU (91oe1 Semlon Survey Tool Name Annotation (ft) MI MI 9]49.]2 86.12 6898 .5V 50 650150 04.49 5,525.29 598014560 555ank29 674 5,52529 80070(41 9)78.07 e767 73.88 659914 6,50.14 84.10 5,55391 5.900 156.40 555.107.85 1697 5.53.91 MND(4) 9,810.12 9089 78.02 6.5em 6,50.52 101A2 5,583,15 5.9110162,91 65.1310 1139 5,593]5 MAID (4) 9.841.89 9052 8174 5.599.13 8,50.13 107.00 5,614.41 5,980,168.70 fw'1W. 1177 5,614.41 MNO(4) 9.8M,02 90.71 Utah 6,59601 650.01 110.54 5,643.12 S.M0.172.43 55,15.94 853 5,643.12 MAID (4) 9,901,13 9aw M12 6,59841 6,50241 112.57 5,873.36 5,980.1745 55,22116 13M Santa MWD (4) 9,9309 91.14 91" 6,597.91 6.501.91 1125 5.702299 5,980.174.5 55.2530 12.01 5,70249 "D (4) enacts 9128 9492 6,59737 6,501.27 110]8 5.732.98 S,ned'in'm 555,285.79 10.08 5,73298 MAID (4) 9,971.88 0104 9925 6596.64 6,50.64 1095 5,8076 5,880.169.51 555,317.61 1395 5,763]8 MAID (4) 10,02059 91]8 10282 6,691 6,49994 101,46 5.791.95 5,98016433 555,34561 1270 5.791.95 MMD(4) 10,050.5 9205 105.93 6.584,92 6.496.92 930 5,821.17 5,98015.76 55.3750 13.0 5,81 MAID (4) 10,080,40 9190 110.26 6.50.91 649791 0420 5,849.16 5,980.147.5 55aUA2 11.27 5,049.16 MIAD(4) 10,11125 9311 114.01 6.59256 6496.5 7287 5.877]0 5.950.13611 55.31,74 12]6 5,077.70 Myra (4) 10.14105 0233 0639 6.591.14 6495.14 60,00 5904.63 5,88].123.88 55Awn &Q 5,904.63 MID 10,17530 93.63 12224 5,59.37 0,49397 43.31 5,93a36 5,960,10113 55.400,50 17,53 5,93436 MWD(4) 1030131 0.10 1X90 6587,M 6,49184 28.94 5 M 5,960,09207 555,51030 1071 595590 MIND (4) 10,23187 W." 12904 650.28 6.49030 1063 5.98030 5,980,074.76 555,534.70 1335 5,0026 MAID (4) 10,26076 0325 13291 6HAn 6,48815 1141 6003.19 5.980.055.80 555.55)5 1339 0.02.19 WAD (4) 10.NO.5 047 13700 6,583.00 6.487.00 3944 602332 5,000498 555.57791 1403 6.42311 MNO(4) 1032081 94.45 135.35 6,26816.1 6,484,92 d1.09 6043.0 5,0001347 50'ett, 3 6fi5 604396 MND(4) 10.351'. 9040 13235 6.5785 6402.55 -72.32 6,05.10 5,979.9038 55.621.0 1005 6,066.10 Main (4) 10380.91 9283 1330 6,57669 6,407,07 b298 6,067.77 5979.972.5 55,64208 6.01 6,00777 MWD(4) 10410.0 88.85 1312 6.650 0,479.0 -11233 6,109b1 597995227 55.604.85 996 0,10,61 MD 10.43595 6748 13292 6578.57 648057 429.80 6,12791 5,979.93.32 555,68325 950 6,127.91 WAD (4) 10,47075 36.43 130.70 6,57642 6.48242 -15x0 6,15.07 5,97991227 555,70937 70 6,15387 WAD (4) ,owl," 88.04 im.46 6,57992 6463.92 -18.70 6,1]7.77 59798925 55573339 680 6.177.77 MAID (4) 1053.77 9025 127.03 Q590A4 6,484.44 -194.16 6,2M27 5.979 871.26 555.76104 6.57 6,20537 WARD (4) 10 $59.36 80.52 12541 650129 6,41K39 420785 622340 5,011dV91 555.77925 1078 6323.40 MAD (4) 10591.8 9135 123.35 6,57976 8.483.76 326,12 6350.10 5.879,0662 555.&607 607 635]0 MND(4) 10,62015 9139 120.15 6,579.11 6,483.11 341.00 6,274.27 5,979.025.03 55.0034 1125 6274,27 MWO(4) 1060w 93,72 117,19 6.577.80 640190 -255.40 630047 5.979.810.87 555.056.63 1207 63WA7 MAD (4) 10? 016256:WPM Paget COMPASS W00148.0850 r. ConoeoPhillips • COnoc Pilllllp5 Definitive Survey Repo" Company. ConocoPhilips (Alaska) Inc. PrepcL Kupamk Ricer Unit Sts: Kupamk 1H Pad Well: 111-21 Wellbore: 111-21 Dealln: 111-21 survey Local Cocrdlnate Reference: N4111H-21 TVD Rate....: 1H-21 @ 96.00 aft (14-21) MD Reference: 1H-21 @ Woodall (111-21) fiction RefeRMe: True Survey Calculation Method Minimum Curvature Database: EDT 14 Alaska Production Annotation 108 0182:5636PM Pepe6 COMPASS5000148unk1850 Map Map Vertical MO Inc Ab WDTVDSS 49743 sFJ4N NOftj Ease., OILS OILS 6ec11on SurvryT0ol Name 1-ft)1") (9 (ese) Josh) (..ft) W-111 I RI 1X1 Xl 10600.76 44.40 11].29 6,5]55 fit 64]9 fit -2664fi 6,32617 5919 ]9800 55.55,861.42 12% 632817 MWD (4) 10,711.25 9218 107W o5M87 6,477.87 -2]9,17 6,356.66 59]9787.48 556.9129] 1908 6,356.66 MWD MI 10,740.89 ouW 10565 6,5829 6,4M23 48].]1 6,384,99 5,979 779.13 55594.35 913 6,]64." MWD (4) 10,]]0.93 96]0 10502 6,569.8 6,473.48 -295.62 6,413.83 5,979771.41 555,9m024 923 6,4383 MD (4) 1oW0.95 89,10 Insi 6,555.35 6,461 303.13 6442.60 5,979,T64W 555997,97 842 6,442.60 MWD(41 1oNI27 99.69 101.61 6%040 6,464A0 309.41 6.471.75 5,979,75760 555.02625 8.71 6,4]1)5 Mstsi 10,66069 98,25 96.04 6.555.81 6,45981 314 77 5,500,3o 6.9111,762M 556,05591 12,95 6,50030 MAID (4) 10,69073 uAll 95,11 6.651.54 6.455.54 318.1] 6,55 .92 6,979749.63 556,085.47 9.67 6,52992 MAD (4) 1093121 9498 9697 6546.05 6,452.W 3P55 6,560,08 5,9]9.747,15 555,116.64 1027 8,550.08 PAID (4) 10,Ya0.as 94AD .As 6.545.64 6.964 32297 8,56055 59]9,]4520 556,1412 7.55 8,589.65 MM1D(4) 10,98093 9040 91.15 6,5.38 644938 I.RS 661957 59]9,]4a.. 665,176.15 1449 6.619.57 MD (4) H 010.63 9243 89.4] 6,543.65 6447.65 .124.10 664925 5,9]9]44,19 5%897.97 695 6,64926 WD (4) 11,040]0 90.40 8520 6.54260 6,446.60 32299 66]828 5,8]9,]4608 55623594 1560 6,67928 NAND (4) 110]0.57 9154 02. 6,542.40 8,498.40 319.6 6708.97 5,979.749.51 556265.50 1097 6,70697 MWD(4) 11 085]3 9439 81,64 5,541.10 (1 315.96 6,73385 5,979,75517 5`e 29036 11.88 6,]]3115 MIND (4) 11128.00 94.39 81.54 rssa 1 644261 11125 6,]656] 5,979 CiAll 556.32 % 0.00 6.]655] PROJECTED to TO Annotation 108 0182:5636PM Pepe6 COMPASS5000148unk1850 BAN<E PRINT DISTRIBUTION LIST UGHES a GE company COMPANY ConocoPhillips Alaska, Inc. WELL NAME 111-1-21AL2 FIELD Greater Kuparuk Area COUNTY North Slope Borough 21 8079 29 76 5 se sign and return one copy of this transmittal form to: ocoPhillips Alaska, Inc. i Osterkamp (WNS Petroleum Technician) G Street. forage, Alaska 99510 :knowledge receipt of this data. LOG TYPE GR - RES BHI DISTRICT Alaska --- LOG DATE September 12, 2018 AUTHORIZED BY Patrick Rider EMAIL Patrick.Rideranbakerhughes.com TODAYS DATE October 4, 2018 Revision STATUS Final Replacement: No Details: Rev. Requested by: COMPANY ADDRESS (FERE% WILL NOT DELIVER TO P.O. BOX) PERSON ATTENTION 4 1 BP North Slope. FOA. PBOC, PRB-20 (Office 109) D&G W O Wells Admin Brenda Glassmaker & Peggy O'Neill 900 E. Benson Blvd. Anchorage, Alaska 99508 2 ConocoPhillips Alaska Inc. AM: Ricky Elgarico ATO 708 700 G Street Anchorage, AK 99510 3 Exxon Mobil, Alaska Ann: Lynda M. Yaskell and/or Leonardo Elias 3201 C Street, Suite 505 Anchorage, AK 99503 4 State of Alaska - AOGCC Attn: Natural Resources Technician II 333 W. 7th Ave, Suite 100 (Anchorage, Alaska 99501 FIELD( FINAL CD/DVD FINAL PRELIM LOGS (las, dlis, PDF, META, SURVEY REPORT LOGS CGM, Final Surveys) (Compass) # OF PRINTS # OF COPIES # OF COPIES J#OFCOPIES RECEIVE® 0 0CT Big lulp AOGCC 01 0 0 1 0 10 0 1 1 0 0 5 DNR - Division ofoil & Gas *** 0 0 1 0 Q 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 0 0 1 0 0 TOTALS FOR THIS PAGE: 0 1 3 0 0 THE STATE 01ALASKA GOVERNOR BILI. WALKER Alaska Oil and Gas Conservation Commission Keith Herring CTD Engineer ConocoPhillips Alaska, Inc. PO Box 100360 Anchorage, AK 99510-0360 Re: Kuparuk River Field, Kuparuk River Oil Pool, KRU 1H-21AL2 ConocoPhillips Alaska, Inc. Permit to Drill Number: 218-079 (revised) Surface Location: 678' FNL, 793' FEL, SEC. 33, T12N, R10E, UM Bottomhole Location: 890' FNL, 4571' FEL, SEC. 35, T12N, R10E, UM Dear Mr. Herring: 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 www.aogcc.alaska.gov Enclosed is the approved application for the permit to redrill the above referenced development well. The permit is fora new wel lbore segment of existing well Permit No. 218-077, API No. 50-029-22355- 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, Cathy P. Foerster Commissioner DATED this Vlay of September, 2018. Ps ' E tI STATE OF ALASKA ALI .oi<A OIL AND GAS CONSERVATION COMMIa,>ION PERMIT TO DRILL 20 AAC 25 nn.r %fie vis ec, 1a. Type of Work:1 b. Proposed Well Class: Exploratory -Gas Service - WAG E]Service - Disp EJtc. Specify if well is proposed for: Drill El ❑Stmtigraphic Test ❑ Development - Oil Service - Winj ❑ Single Zone ❑✓ Coalbed Gas ❑ Gas Hydrates ❑ Redrill ❑ Reentry ❑ Exploratory - Oil ❑ Development -Gas ❑ Service - Supply ❑ Multiple Zone ❑ Geothermal ❑ Shale Gas ❑ 2. Operator Name: 5. Bond: Blanket Q . Single Well ❑ 11. Well Name and Number: ConocoPhillips Alaska, Inc. Bond No. 5952180 • Kuparuk Riv Unit 1H-21AL2 . 3. Address: 6. Proposed Depth: 12. Field/Pool(s): PO Box 100360 Anchorage, AK 99510-0360 MD: 11130' TVD: 6506' ' Kuparuk River Kuparuk River Oil 4a. Location of Well (Governmental Section): 7. Property Designation: 9 r67e Surface: 678' FNL, 793' FEL, Sec 33, Tl2N, R10E, UM i't4- ADL 25639 Top of Productive Horizon: 8. DNR Approval umber: 13. Approximate Spud Dale: 788' FNL, 2285' FEL, Sec 34, T12N, R1oE, UM LONS 80-261 7/11/2018 Total Depth: 9. Acres in Property: 14. Distance to Nearest Property: 890' FNL, 4571' FEL, Sec 35, T12N, R10E, UM 2560 7685' 4b. Location of Well (State Base Plane Coordinates - NAD 27): 10. KB Elevation above MSL (ft): 96 15. Distance to Nearest Well Open Surface: x- 549555 y- 5980025 • Zone- 4 GL / BF Elevation above MSL (ft): 54.4 to Same Pool: 526' to 1 H-13 16. Deviated wells: Kickoff depth: 7925 feet ' 17. Maximum Potential Pressures in psig (see 20 AAC 25.035) Maximum Hole Angle: 103.3 degrees Downhole: 3275 • Surface: 2645 - 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) Y 2-3/8" 4.6# L-80 ST -L 2730' 8400' 6640' 11130' 6506' Un -Cemented 19. PRESENT WELL CONDITION SUMMARY (To be completed for Reddll and Re -Entry Operations) Total Depth MD (ft): Total Depth TVD (ft): Plugs (measured): Effect. Depth MD (ft): Effect. Depth TVD (ft): Junk (measured): .8315 6962 N/A 8207 6877 N/A Casing Length Size Cement Volume MD TVD Conductor/Structural 121' 16" 200 SX PF C CMT 121' 121' Surface 4779' 9-5/8" 930 SX PERM E, 450 SX G 4820' 4247' Intermediate Production 8258' 7" 299 SX CLASS G CMT 8295' 6947' Liner Perforation Depth MD (ft): Perforation Depth TVD (ft): 7768-7858, 7918-7948 6534-6604, 6651-6674 Hydraulic Fracture planned? Yes❑ No ❑� 20. Attachments: Property Plat ❑ BDP Sketch Dive sir Sketch 8 Drilling Program B Seabed Report Time v. Depth Plot e Drilling Fluid Program 20 ASC ShallowHazard Analysis Aments B✓ 21. Verbal Approval: Commission Representative: Date 22. 1 hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Contact Name: Keith Herring Authorized Name: Keith Herring Contact Email: Keith.E.Herrin COP.Com Authorized Title: CTD Engineer Contact Phone: 907-263-4321 Authorized Signature: Date: 9 s' / Commission Use Only Permit to DrillO syr API Numbbee1r: Permit Approval See cover letter for other Number: I .l r 50-V _1 22375 —QQ Date: 7 M1 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: D' Wurty- (30�PE TEST '1b '3oo0Ys 1 Samples req'd: Yes ❑ No� — / Mud log req'd: Yes❑ No / [� UU ,� HzS measures: Yes r+ No El Directional svy req'd: Yes P, No❑ / Spacing exception req'd: Yes ❑(,I?' NoInclination-only svy req'd: Yes ❑ No Q Post initial injection MIT req'd: Yes[] No[--] Approved by APPROVED BY ` COMMISSIONER THE COMMISSION Date _�� Submit Form and Form 10-401 Lvised 512017 This permit is valid for [ f pproyal per 20 AAC 25.005(g) Attach is in Duplicate MIG!"I"'AL (�w-RteS�Pm �9ic•Ll;--. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 AAC 25.005 E.W E 0' .. 2018 1a. Type of Work: 1b. Proposed Well Class: Exploratory - Gas U Service - WAG Service - Disp E]1c..Specify if,well is pro osed for, Drill [:]Lateral ❑� Slratigraphic Tesi EJ Development -Oil M Service- Wil ❑ Single Zone [A Cue s; - r tes El Reddll ElReentry ❑ Exploratory- Oil ❑ Development - Gas ❑ Service- Supply ❑ Multiple Zone ❑ Geothermal LJ Shale Gas El 2. Operator Name: 5. Bond: Blanket ❑� Single Well ❑ 11. Well Name and Number: ConocoPhillips Alaska, Inc. Bond No. 5952180 Kuparuk Riv Unit 1H-21AL2 3. Address: 6. Proposed Depth: p' 6WO 12. Field/Pool(s): PO Box 100360 Anchorage, AK 99510-0360 MD: 11,100• TVDJ, ! 6494' Kuparuk River Kuparuk River Oil 4s. Location of Well (Governments[ Section): 7. Property Designation: Surface: 678' FNL, 793' FEL, Sec 33, T12N, R10E, UM L Zs(�I3 ADL 25639 7. 2-• !t Top of Productive Horizon: 8• DNR Approval umher: 13. Approximate Spud Date: 788' FNL, 2285' FEL, Sec 34, T12N, R10E, UM LONS 80-261 711112018 Total Depth: - 9. Acres in Property: 14. Distance to Nearest Property: 393' FNL, 773' FWL, Sec 35, T12N, R10E, UM 2560 7200' 4b. Location of Well (State Base Plane Coordinates - NAD 27): 10. KB Elevation above MSL (it): 96 15. Distance to Nearest Well Open Surface: x- 549555 y- 5980025 Zane- 4 GL 1 BF Elevation above MSL (ft): 54.4 to Same Pool: 978' to 1 H-13 16. Deviated wells: Kickoff depth: 7925 feet 17. Maximum Potential Pressures in psig (see 20 AAC 25.035) MaAmum Hole Angle: 103.3 degrees Downhole: 3275 Surface: 2645 18. Casing Program: Specifications Top - Setting Depth - Bottom Cement Quantity, c.f. or sacks Hole Casing Weight Grade Coupling I Length MD TVD MD TVD (Including stage data) 4.6# L50 ST -L 2700' 8400' 6640' 11,100' 6494' Un -Cemented 19. PRESENT WELL CONDITION SUMMARY (To be completetl for Redrill and Re -Fairy Operations) Total Depth MD (11): Total Depth TVD (ft): Plugs (measured): Effect Depth MD (ft): Effect. Depth TVD (ft): Junk (measured): 8315 6962 N/A 8207 6877 N/A casing Length Size Cement Volume MD TVD Conductor/Structural 121' 16" 200 SX PF C CMT, 121' 121' Surface 4779' 95/8° 930 SX PERM E, 450 SX G 4820' 4247' Intermediate Production 8258' 7° 299 SX CLASS G CMT 8295' 6947' Liner Perforation Depth MD (it): Perforation Depth TVD (fi): 7768-7858.79118-7948 65345604, 6651-6674 Hydraulic Fracture planned? Yes[] No Q 20. Attachments: Property Plat ❑ BOPSketch Diverter Sketch Drlling Program Time V. Depth Plot Shallow Hazard Analysis 8 Ssat ed Report B Drilling Fluld Program 8 20 AAC 25.050 requirements 21. Verbal Approgal: Commission Representative: Date 22. 1 hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Contact Name: William R_ Long Authorized Name: James Ohlinger Contact Email: Williarn.R.LonqaCOP.conn Authorized Title: Staff CTD Engineer% Contact Phone: 907-263-4372 Authorized Signature: (/ Date: i0few Commission Use Only Permit toDrill '7G) Number. "� r / API Numbe . 50- Z� ZiZ-J —�v--C Permit Approval Date: '�' GJ See cover letter for other requirements. Conditions of approval : If box is checked, well may not be used to explore for, test, or produce coalbed methane gas hydrates, or gas contained in shales: Other. $t,,)Erji Li BpPCTt'-57i'a A700 p5t Samples Yes �j p q ❑ No LTJ Mud log req'd: Yes❑, EI/Noy --,/.No HHS measures: Yes Directional svy req'd: Yes ff No E] Spacing exception req'd: Yes ❑ NoV inclination -only svy req'd: Yes ❑ No K Post initial injection MIT req'd: Yes El No[] APPROVED BY Ic If� Approved by: COMMISSIONER THE COMMISSION Date: 7 U P L�� 5u6mk Fen and Form 10-401 Revised 5/2017 This permit Is va o 2 s e a f roval per 20 AAC 25.005(g) AltachmenlydDuplicale ConocoPhillips Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 September 05, 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 a revised application for permit to drill KRU 1 H-21AL2 (PTD #218- 079) to move the bottom hole location due to geologic complexity and rock properties. To account for geological uncertainties, ConocoPhillips requests a variance from the requirements of 20 AAC 25.015 to allow the actual kick-off point to be anywhere along the length of the parent lateral instead of being limited to 500' from the original point. Attached to this application are the following documents: — Permit to Drill Application Forms (10-401) for 1 H-21AL2 — Detailed Summary of Operations — Directional Plans for 1 H-21 AL2 — Current wellbore schematic — Proposed CTD schematic If you have any questions or require additional information, please contact me at 907-263-4321. Sincerely, Keith Herring Coiled Tubing Drilling Engineer ConocoPhillips Alaska Kuparuk CTD Laterals 11-1-21A, 1H-21AL1, i1-1-21AL2, and 1H-21AL2-01 Application for Permit to Drill Document 1. Well Name and Classification........................................................................................................ 2 (Requirements of 20 AAC 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)(6))..................................................................................................................................................3 7. Diverter System Information ..........................................................................................................3 (Requirements of 20 AAC 25.005(c)(7))..................................................................................................................................................3 8. Drilling Fluids Program.................................................................................................................. 3 (Requirements of 20 AAC 25.005(c)(8)), _. _ ... .... ...................... ........ -..... ....... ............ .............................................. .......... ............ ..... 3 9. Abnormally Pressured Formation Information.............................................................................4 (Requirements of 20 AAC 25.005(c)(9)) ................ _................ _...... .............. ......... .............. ....... _- ....... . _............................................4 10. Seismic Analysis............................................................................................................................. 4 (Requirements of 20 AAC 25. 005(c)(10)) ................................................................................................................................................4 11. Seabed Condition Analysis............................................................................................................4 (Requirements of 20 AAC 25.005(c)(11)) ............................................. -.... ....................................................................... ...................... 4 12. Evidence of Bonding...................................................................................................................... 4 (Requirements of 20 AAC 25.005(c)(12))................................................................................................................................................4 13. Proposed Drilling Program.............................................................................................................4 (Requirements of 20 AAC 25.005(c)(13))................................................................................................................................................4 Summaryof Operations...................................................................................................................................................4 LinerRunning...................................................................................................................................................................6 14. Disposal of Drilling Mud and Cuttings.......................................................................................... 6 (Requirements of 20 AAC 25.005(c)(14))................................................................................................................._........................._..6 15. Directional Plans for Intentionally Deviated Wells (Requirements of 20 AAC 25.050(b)) .................................................. ................................................ 7 ................................................................... 7 16. Attachments....................................................................................................................................7 Attachment 1: Directional Plans for 11-1-21A, 11-1-21AL1, 11-1-21AL2, and 1H-21AL2-01 laterals.....................................7 Attachment 2: Current Well Schematic for 1 H-21............................................................................................................7 Attachment 3: Proposed Well Schematic for 1H -21A, 1H-21AL1, 1H-21AL2, and 1H-21AL2-01 laterals .......................7 Page 1 of 7 September 05, 2018 PTD Application: 1H -21A, 1H-21AL1, 1H-21AL2, and 1H-21AL2-01 1. Well Name and Classification (Requirements of 20 AAC 25.005(1) and 20 AAC 25.005(b)) The proposed laterals described in this document are 1H -21A, 1H-21AL1, 1H-21AL2, and 1H-21AL2-01. All laterals will be classified as "Development -Oil' wells. 2. Location Summary (Requirements of 20 AAC 25.005(c)(2)) These laterals will target the C sand package in the Kuparuk reservoir. See attached 10-401 forms for surface and subsurface coordinates of each of the laterals. 3. Blowout Prevention Equipment Information (Requirements of 20 AAC 25.005 (c)(3)) Please reference blowout prevention (BOP) schematics on file with the Commission for Nabors CDR3-AC. BOP equipment is as required per 20 AAC 25.036 for thru-tubing drilling operations. – Pipe rams, blind rams and the CT pack off will be pressure tested to 250 psi and to 3,000 psi. Using the maximum formation pressure in the area of 3,275 psi at the datum in 2H-12 (i.e. 10 ppg EMW), the maximum potential surface pressure in 1 H-21, assuming a gas gradient of 0.1 psi/ft, would be 2,645 psi. Seethe "Drilling Hazards Information and Reservoir Pressure" section for more details. – The annular preventer will be tested to 250 psi and 2,500 psi. 4. Drilling Hazards Information and Reservoir Pressure (Requirements of 20 AAC 25.005 (c)(4)) Reservoir Pressure and Maximum Downhole Pressure (Requirements of 20 AAC 25.005 (c)(4)(a)) The formation pressure in KRU 1 H-21 was measured to be 2,978 psi at the datum (9.1 ppg EMW) on 5/16/2015. The maximum downhole pressure in the 1 H-21 vicinity is the 1 H-12 at 3,275 psi at the datum or 10 ppg EMW. — Potential Gas Zones (Requirements of 20 AAC 25.005 (c)(4)(b)) No specific gas zones will be drilled; gas injection has been performed in this area, so there is a chance of encountering gas while drilling the 1 H-21 laterals. If significant 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)) V The major expected risk of hole problems in the 1 H-21 laterals will be shale instability across faults. Managed pressure drilling (MPD) will be used to reduce the risk of shale instability associated with fault crossings. 5. Procedure for Conducting Formation Integrity tests (Requirements of 20 AAC 25.005(c)(5)) The 1 H-21 laterals will be drilled under 20 AAC 25.036 for thru-tubing drilling operations so a formation integrity test is not required. Page 2 of 7 September 05, 2018 PTD Application: 1H -21A, 1H-21AL1, 1H-21AL2, and 1H-21AL2-01 6. Casing and Cementing Program (Requirements of 20 AAC 25.005(c)(6)) New Completion Details Lateral Name Liner Top Liner Btm Liner Top Liner Btm Liner Details Btm MD MD MD TVDSS TVDSS Conductor 1H -21A 8200' 11,500' 6538' 6526' 2%", 4.7#, L-80, ST -L slotted liner; Surface 121' 1640 670 Surface aluminum billet on to 1H-21AL1 7925' 11,550' 6536' 6644' 2%', 4.7#, L-80, ST -L slotted liner; 4247' 3520 2020 Production 7" aluminum billet on to 1H-21 AL2 8400' 11,130' ' 6640' 6506' 2%", 4.7#, L-80, ST -L slotted liner; 4980 4320 Tubing 3-1/2" 9.3 aluminum billet on to 1H-21 AL2 -01 7675' 11,150 6365' 6632' 2%", 4.7#, L-80, ST -L slotted liner, 10,540 deployment sleeve on to Existing Casing/Liner Information Category OD Weigh t Grade Connection Top MD Btm MD Top TVD Btm TVD Burst psi Collapse psi Conductor 16" 62.5 H-40 Welded Surface 121' Surface 121' 1640 670 Surface 9-5/8" 36 J-55 BTC Surface 4820' Surface 4247' 3520 2020 Production 7" 26 J-55 AB -MOD Surface 8296' Surface 6947' 4980 4320 Tubing 3-1/2" 9.3 J-55 EUE 8rd MOD Surface 7693' Surface 6475' 10,160 10,540 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: Water based Power -Vis milling fluid (8.6 ppg) — Drilling operations: Water based Power -Pro drilling 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: BHA's will be deployed using standard pressure deployments and the well will be loaded with 11.4 ppg NaCl/NaBR completion fluid in order to provide formation over -balance and maintain wellbore stability while running completions. If higher formation pressures are encountered the completion brine will be weighted up with sodium bromide or potassium formate. Managed Pressure Drilling Practice Managed pressure drilling (MPD) techniques will be employed to maintain a constant overbalanced pressure on the open hole formation and promote wellbore stability throughout the coiled tubing drilling (CTD) process. Mud weight is not, in many cases, the primary well control barrier. This is satisfied with the 5000 psi rated coiled tubing pack off and MPD choke. BOPE equipment provides the secondary well control as detailed in section 3 "Blowout Prevention Equipment Information". In the 1 H-21 laterals we will target a constant BHP of 11.4 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 Page 3 of 7 September 05, 2018 PTD Application: 11-1-21A, 1H-21ALI, 1H-21AL2, and 1H-21AL2-01 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. Pressure at the 1 H-21 Window (7825' MD, 6578' 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 KRU well 1H-21 is a Kuparuk producer equipped with 3-1/2" tubing and 7" production casing. The CTD sidetrack will utilize laterals to target the Kuparuk sands to the north and east of the existing 1 H-21 wellbore. The laterals will increase throughput and recovery from a potentially sheltered corner of a fault block. Prior to CTD operations, E -Line will punch holes in the 3-1/2" tubing tail below the production packer and the "D" nipple will be milled out to 2.80" ID. The existing perforations will be squeezed with cement and the 3-1/2" tubing tail will be cemented in place to provide a means to kick out of the 7" casing. Following the cement squeeze Nabors CDR3-AC will drill a pilot hole and set a mechanical whipstock in the 2.80" pilot hole. The whipstock will be used to cut a window in the 7" casing and drill CTD laterals. Page 4 of 7 September 05, 2018 Pumps On 1.8 bpm) Pumps Off Formation Pressure 9.1 3113 psi 3113 psi Mud Hydrostatic 8.6 2942 psi 2942 psi Annular friction i.e. ECD, 0.080psi/ft) 626 psi 0 psi Mud + ECD Combined no chokepressure) 3568 psi overbalanced -455psi) 2942 psi underbalanced -171psi) Target BHP at Window 11.4 3899 psi 3899 psi Choke Pressure Required to Maintain Target BHP 331 psi 957 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 KRU well 1H-21 is a Kuparuk producer equipped with 3-1/2" tubing and 7" production casing. The CTD sidetrack will utilize laterals to target the Kuparuk sands to the north and east of the existing 1 H-21 wellbore. The laterals will increase throughput and recovery from a potentially sheltered corner of a fault block. Prior to CTD operations, E -Line will punch holes in the 3-1/2" tubing tail below the production packer and the "D" nipple will be milled out to 2.80" ID. The existing perforations will be squeezed with cement and the 3-1/2" tubing tail will be cemented in place to provide a means to kick out of the 7" casing. Following the cement squeeze Nabors CDR3-AC will drill a pilot hole and set a mechanical whipstock in the 2.80" pilot hole. The whipstock will be used to cut a window in the 7" casing and drill CTD laterals. Page 4 of 7 September 05, 2018 PTD Application: 11-1-21A, 1H-21AL1, 1H-21AL2, and 1H-21AL2-01 Pre -CTD Work 1. RU Slickline: Drift tubing with dummy whipstock. 2. RU E -line: Punch holes in the 3%" tubing tail below the production packer. 3. RU Pumping Unit: perform injectivity test down the tubing. 4. RU Service Coil: Mill out "D" nipple and cement squeeze the perforations up to the holes in the tubing tail. 5. RU Slickline: Drift tubing with dummy whipstock. Tag top of cement and pressure test cement. 6. Prep site for Nabors CDR3-AC. Rie Work 1. MIRU Nabors CDR3-AC rig using 2" coil tubing. NU 7-1/16" BOPE, test. 2. Mill 2.80" cement pilot hole. 3. Set monobore whipstock. 4. IH -21A Lateral (C sand -North) a. Mill 2.80" window at 7825' MD. b. Drill 3" bi-center lateral to TD of 11,500' MD. c. Run 2%" slotted liner with an aluminum billet from TD up to 8200' MD. 1 H-21AL 1 Lateral (C sand - North) a. Kickoff of the aluminum billet at 8200' MD. b. Drill 3" bi-center lateral to TD of 11,550' MD. c. Run 2%" slotted liner with aluminum billet from TD up to 7925' MD. 6. 1 H-21 AL2 Lateral (C sand- East) a. Kickoff of the aluminum billet at 7925' MD. b. Drill 3" bi-center lateral to TD of 11.130' MD. c. Run 2%" slotted liner with aluminum billet from TD up to 8,400' MD. IH -21 AL2 -01 Lateral (C sand -East) a. Kick off of the aluminum billet at 8400' MD. b. Drill 3" bi-center lateral to TD of 11,150' MD. c. Run 2%" slotted liner with deployment sleeve from TD up to 7675' MD. 8. Freeze protect, ND BOPE, and RDMO Nabors CDR3-AC. Post -Rig Work 1. Return to production. Page 5 of 7 September 05, 2018 PTD Application: 1H -21A, 1H-21AL1, 1H-21AL2, and 1H-21AL2-01 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 slick -line. - 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 undeployment, the steps listed above are observed, only in reverse. Liner Running - 1 H-21 CTD laterals will be displaced to an overbalance completion fluid (as detailed in Section 8 "Drilling Fluids Program") prior to running liner. While running 2%" slotted liner, a joint of 2%" 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 2W rams will provide secondary well control while running 2%" liner. 14. Disposal of Drilling Mud and Cuttings (Requirements of 20 AAC 25.005(c)(14)) • No annular injection on this well. • All solid waste will be transported to the grind and inject facility at DS -4 Prudhoe Bay for disposal. • Incidental fluids generated from drilling operations will be injected in a Kuparuk Class II disposal well (1R-18 or 1 B disposal facilities) or Prudhoe DS -4 if a Kuparuk facility is unavailable. • All wastes and waste fluids hauled from the pad must be properly documented and manifested. • Contact Kuparuk Environmental Coordinator for questions regarding waste classification. (670-4200). Page 6 of 7 September 05, 2018 PTD Application: 1H -21A, 1H-21AL1, 1H-21AL2, and 1H-21AL2-01 15. Directional Plans for Intentionally Deviated Wells (Requirements of 20 AA 25.050(b)) - The Applicant is the only affected owner. - Please see Attachment 1: Directional Plans - Magnetic and inclination surveys will be taken every 30 ft. No gyro will be run. - MWD directional, resistivity, and gamma ray will be run over the entire open hole section. - Distance to Nearest Property Line (measured to KPA boundary at closest point) Lateral Name Distance 11-1-21A 5,900' 1 H-21 AL 1 5,900' 1H-21 AL2 7,685' 1 H-21AL2-01 7,200' - Distance to Nearest Well within Pool eral Name Distance Well 1H -21A 790' 1H-12 1H-21AL1 790' 11-1-12 1 H-21AL2 526' 1H-13 1 H-21 AL2 -01 978' IH -13 16. Attachments Attachment 1: Directional Plans for 1H -21A, 1H-21AL1, 1H-21AL2, and 1H-21AL2-01 laterals. Attachment 2: Current Well Schematic for IH -21. Attachment Proposed Well Schematic for IH -21A, 1H-21AL1, 1H-21AL2,and 1H-21AL2-01laterals. Page 7 of 7 September 05, 2018 ConocoPhillips PrgeGl: KupauRRMr0N1 uy.iweiG �?u� MOREDUAMAS 21AL2 W`l SRe: "wklHPetl PdRnl WeYbore: 1H31A o>aaa.RMled..m wH lNzl nmrvom Wb: 1H31� Twon MD 10/]0.75 yypm(ryplgyartrcG. IMYI@BGmurn014111 &aon(uSIPYunn: GM PARM WtlROn: 1ll.tlAL2 P1 AWNAL!_wpW(i"MHd W) Gym„�I lealew.w� alta e��NeNo1. 1161m96.0”) BAKER AKR 1K21 �9G.ODueR 111421) i ..oy-N.tmq•11»u mmuq Ott m -u ul.0 III WV IIIL' III��I ill��l I11-1811618 ConocoPhillips _ConocoPhillips Export Company Kuparuk River Unit Kuparuk 1H Pad IH -21 1H-21AL2 Plan: 1 H-21 AL2_wp04 Standard Planning Report 05 September, 2018 BER T: " GHES GE company �, ConocoPhillips BA <ER ConoC43 Phillips Planning Report HUGHES a GE company Database: EDT 14 Alaska Production Company: _ConocoPhillips Export Company Project Kupauk River Unit Site: Kupamk 1H Pad Well: 1H-21 Wellbore: 1H-21 AL2 Design: 1H41AL2wp04 Local Coordinate Reference: TVD Reference: MD Reference: Norm Reference: Survey Calculation Method: Well 1 H-21 Mean Sea Level 1H-21 @ 96.00usft (IH-21) True Minimum Curvature Project Kupamk River Unit, Norm Slope Alaska, United States Map System: US State Plane 1927 (Exact solution) System Datum: Mean Sea Level Geo Datum: NAD 1927 (NADCON CONUS) - Using Well Reference Point Map Zone: Alaska Zone 04 Using geodetic scale factor Site Kuparuk 1H Pad 1H-21 Site Position: Northing: 5,979,968.84 usft Latitude: 70° 21' 21.831 N From: Map Easting: 549,197.16 usft Longitude: 149° 36' 1.675 W Position Uncertainty: 0.00 usft Slot Radius: 0.000 in Grid Convergence: 0.38, Wen 1H-21 Well Position +NIS 0.00 usft Northing: 5,980,024.57 usft Latitude: 70° 21'22.356 N +E/.W 0.00 usft Easting: 549,555.22 usft Longitude: 149'35'51.196W Position Uncertainty Azimuth 0.00 usft Wellhead Elevation: usft Ground Level: 54.40 usft WaNbore 1H-21 AL2 Magnetics Model Name BGGM2018 Design Audit Notes: Version: Vertical Section: 1H-21AL2_wp04 1.0 Sample Date 9/1/2018 Phase: Depth From (TVD) (usft) -54,40 Declination Dip Angle V) (°) 17.01 PLAN Tie On Depth: -NIS +E/ -W (usft) (usft) 0.00 0.00 Field Strength mT) 8091 57,446 10,470.75 Direction (I 91.76 Plan Sections Measured TVD Below Dogleg Build Tum Depth Inclination Azimuth system +NI$ +EI -W Rate Rate Rata TFO (usft) el V) (usft) (usft) (usft) (°1100usft) (°1100usft) ('11100taft) V) 10,470.75 86.43 130.70 6,482.42 -153.02 6,153.87 7.03 0.00 0.00 0.00 10,590.00 88.81 111.05 6,487.42 -213.85 6,255.63 16.58 2.00 -16.48 -83.57 10,770.00 84.60 96.76 6,497.82 -256.96 6,429.57 8.26 -2.34 -7.94 -106.77 10,950.00 90.00 82.45 6,506.34 -255.67 6,608.83 8.49 3.00 -7.95 -69.75 11,130.00 90.00 67.00 6,506.34 -208.39 6,781.94 8.58 0.00 -8.58 -90.00 Target 9/5/2018 12:05:28AM Page 2 COMPASS 5000.14 Build 85 ConocoPhillips BAER ConocoPhillips Planning Report UGHES a GEcamp ey Database: EDT 14 Alaska Production Local Coordinate Reference: Well 1H-21 Company: _ConocoPhillips Export Company TVD Reference: Mean Sea Level Project Kuparuk River Unit MD Reference: iH-21@ee.00usft(I H-21) Site: Kupamk 1H Pad North Reference: True Well: IH -21 Survey Calculation Method: Minimum Curvature Wellbore: 1H-21AL2 Depth Inclination Azimuth Design: 1H-21AL2_wp04 +E/41y section Planned Survey Measured Vertical Measured -- Casing Hole Depth Depth Diameter Measured (usft) (usft) Name TVD Below (in) 11,130.00 Vertical Dogleg Toolface Map Map Depth Inclination Azimuth System +N/ -S +E/41y section Rate Azimuth Northing Easing (usft) (`) (•) (usft) (usft) (usft) (usft) ('/f6ouslp P) (usft) (usft) 10,470.75 86.43 130.70 6,482.42 -153.02 6,153.87 6,155.67 0.00 0.00 5,979,912.27 555,709.37 From unofficial surveys 10,500.00 86.99 125.87 6,484.10 -171.11 6,176.79 6,179.13 16.58 -83.57 5,979,894.34 555,732.40 10,590.00 88.81 111.05 6,487.42 -213.85 6,255.63 6,259.25 16.58 -83.29 5,979,852.13 555,811.52 Start 8 dls 10,600.00 88.57 110.26 6,487.65 -217.37 6,264.99 6,268.71 8.26 -106.77 5,979,848.66 555,820.90 10,700.00 86.21 102.33 6,492.21 -245.39 6,360.79 6,365.32 8.26 -106.75 5,979,821.29 555,916.87 10,770.00 84.60 96.76 6,497.82 -256.96 6,429.57 6,434.42 8.26 -106.39 5,979,810.17 555,985.72 3 10,800.00 85.49 94.36 6,500.41 -259.85 6,459.31 6,464.24 6.49 -69.75 5,979,807.48 556,015.48 10,900.00 88.49 86.41 6,505.68 -260.52 6,559.08 6,563.98 8.49 -69.54 5,979,807.47 556,115.24 10,950.00 90.00 82.45 6,506.34 -255.67 6,608.83 6,613.56 8.49 -69.12 5,979,812.65 556,164.95 4 11,000.00 90.00 78.16 6,506.34 -247.25 6,658.10 6,662.55 8.58 -90.00 5,979,821.39 556,214.16 11,100.00 90.00 69.58 6,506.34 -219.49 6,754.07 6,757.63 8.58 -90.00 5,979,849.78 556,309.94 11,130.00 90.00 67.00 6,506.34 . -208.39 6,781.94 6,785.14 8.58 -90.00 5,979,861.06 556,337.73 Amended TD at 11130.00 Casing Points Measured Vertical Measured Vertical Casing Hole Depth Depth Diameter Diameter (usft) (usft) Name (in) (in) 11,130.00 6,506.34 23/8" 2.375 3.000 Plan Annotations Measured Vertical Depth Depth (usft) (usft) 10,470.75 6,482.42 10,590.00 6,487.42 10,770.00 6,497.82 10,950.00 6,506.34 11,130.00 6,506.34 Local Coordinates -NI-S +E/4N (usft) (usft) Comment -153.02 6,153.87 From unofficial surveys -213.85 6,255.63 Start 8 dis -256.96 6,429.57 3 -255.67 6,608.83 4 -208.39 6,781.94 Amended TO at 11130.00 9/5/2018 12:05:28AM Page 3 COMPASS 5000.14 Build 85 COf1000Pilllllp5 Company: ConocoPhillips (Alaska) Inc. -Kupt Project Kupamk River Unit Reference Site: Kupamk 1 H Pad Site Error. 0.00 usft Reference Well: 1 H-21 Well Error. 0.00 usft Reference Welibom 1H-21AL2 Reference Design: 1H-21AL2 wPO4 ConocoPhillips BA�CER Travelling Cylinder Report ATR a GE company Local Coordinate Reference: Well 1H-21 TVD Reference: 11-1-21 ® 96.00usft (1H-21) MD Reference: 1H-21 @ 96.00usft (1H-21) North Reference: True Survey Calculation Method: Minimum Curvature Output errors are at 1.00 sigma Database: EDT 14 Alaska Production Offset TVD Reference: Offset Datum Reference 1H-21 AL2_wp04 Filter type: GLOBAL FILTER APPLIED: All wellpaths within 200'+ 100/1000 of reference Interpolation Method: MD Interval 25.00usft Error Model: ISCWSA Depth Range: 10,470.75 to 11,130.00usft Scan Method: Trev. Cylinder North Results Limited by: Maximum center -center distance of 1,308.84 usft Error Surface: Pedal Curve -, Survey Tool Program Deft 9/42018 From To Vertical (usft) (usft) Survey (W®ntloro) Tool Name Description 102.20 7,807.301H-21 Srvy 1-SLB_GCT-MS(1 H-21) GCT -MS Schlumberger GCT multishot 7,826.00 7,876.23 1H -21A MWD-INC(1 H -21A) MWD-INC_ONLY MWD -INC ONLY_FILLER 7,907.21 7,907.21 1H -21A MWD (1 H -21A) MWD MWD -Standard 7,935.00 10,470.75 1H-21AL2 MWD (1 H-21AL2) MWD MVVrD- Standard 10,470.75 11,130.00 11-1-21AL2_Wp04(1 H-21AL2) MWD MWD -Standard Casing Points KupamklHPad- 7H -13 -1H -13-1H-13 Measured Vertical Casing Hole Depth Depth Allowable Diameter Diameter (usft) (usft) Name (in) (in) 121.00 121.00 16" 16.000 24,000 4,820.00 4,246.83 9 518" 9.625 12.250 10,080.40 6,593.91 23/8" 2.375 3.000 Summary KupamklHPad- 7H -13 -1H -13-1H-13 Reference Offset Centre to No -Go Allowable Measured Measured Centre Distance Deviation Warning Site Name Depth Depth Distance (usft) from Plan Offset Wall -WeBhors-Design (usft) (usft) (usft) wNal (usft) press Kupamk 1H Pad pleat WeOhan CeMn easing- Cemre to NOGb All.bb Wamksg Dagah eeplk 1 H-09 - 1 H-09 -1 H-09 Math AamuM +Wd Out of range 1 H-108 - 1 H -108A - 1 H-1 08A Ce. Duunce D..110n Pam (ails) Nos) Out of range 1 H-108 -1 H-1088 - 1 H-1088 (usft) (1 Pass) luaft) lin) Out of range 11-1-11 - 1H-11 - IH -11 luau 1 10,47500 6570.68 8,525.W 5,603]7 57.18 Out of range 1H -13 -7H -13-1H-13 11,123.66 9,725.00 526.72 367.95 196.08 Pass -Major Risk 1H -15 -1H -15-1H-15 10,727.81 9,875.00 1,288.73 374.28 914.43 Pass -Major Risk 1 H-18 - 1 H-18 - 1 H-18 5.000 1,04830 31248 850.84 Pass - Major Risk 10,494.38 6,579.80 Out of Mage 7H-21-1H-21AL2-1H-21AL2 10,470.75 10,470.75 0.00 126.30 -0.22 FAIL - Major Risk 1H -21-1H-21 AL2-01-1H-21AL2-01_wp02 10,642.75 10,650.00 460.09 0.31 460.09 Pass -No Errors Offset Design KupamklHPad- 7H -13 -1H -13-1H-13 ORes Pail Error. use Survey Program: 97 -GCT -MS Rub Aayred: MajorRok eve Offset Well Error: e00 usll Reference onset Bemi Maior Fzrs Measured Varecai Meaa.r wNal Reference press TWface+ pleat WeOhan CeMn easing- Cemre to NOGb All.bb Wamksg Dagah eeplk cam Math AamuM +Wd a m Noks've Ce. Duunce D..110n Pam (ails) Nos) (am) lasnl (usft) (1 Pass) luaft) lin) (ura) kaftl luau 1 10,47500 6570.68 8,525.W 5,603]7 57.18 54.19 153.58 .52201 5.930.19 5.000 1,065.87 308.63 86868 Pass - Major Ptak 1&405.07 6.57926 8.550.0 5,618.73 5222 54.37 151.73 -522.94 595020 5.000 1,04830 31248 850.84 Pass - Major Risk 10,494.38 6,579.80 0,575.00 5,633.57 57.28 54.56 150.0 -523.96 5.970.29 5.000 1,031.2 316.0 032.07 Peas -Maior Risk 10=00 6.580.10 8.800.00 5,618.]5 57.29 54,75 14&86 325103 5.99043 5.000 1,013.98 31828 812.83 Pass - Mayr Risk 10.514.00 6.580.01 &625.00 5,652.97 57.35 54.93 14643 -526.24 6.010.67 5.000 997.24 323.09 785.20 Pan -MdjaRs8k 10,525.0 6,581.31 8,650.00 5.67.36 57.41 55.12 144.48 -52250 6,031.07 5.000 800.91 328.93 .7 53 Pass - Valor Risk CC - Min centre to center distance or covergent point, SF - min separation factor, ES - min ellipse separation 9/42018 10.30.47PM Page 2 COMPASS 5000.14 Build 85 Pro}et NUParuk RiwrUn0 MUBDRE DETAILS: 1"Al Site: NePXuk IHPatl �� rn tkP¢sf.ve PaeeM WM&oro: IH -21A NAnom: I"AU X'p ' Tie on MD: 10470.75 XKxx 9'4 IMps PW:IXSIALZwP0111HS1/1X3fAILYl .pi`mvaon WELLOETAILS: 1H-21 .NIS +EAW Northing Easting Latitude Longitude 0.00 0.00 5980024.57 549555.22 70' 21'22.356 N 149° 35 51.196 W rx MU no e9 ace V5W AnnDtabDn 1 10470.75 86.43 130.70 6162.42 -153.02 6153.87 7A3 0.00 6155.67 FmmurolficialsorMs 2 10590.00 88.81 111A5 6987.42 -213.85 6265.63 16.58 -83.57 6259.25 SWBdls 3 10770.00 84.60 96.76 6497.82 -266.96 6429.57 8.26 -106.77 6434.42 3 4 10950.00 90.00 8245 6506.34 -255.67 6608.83 8.49 -69.75 6613.56 4 5 11130.00 90.00 67.00 6506.34 408.39 6781.94 8.58 -90.00 6785.14 AmendedTDal11130.1 F Mean S FEFDFTCE NWP . �¢ aAIE�flN.Yw. 1'p 1." �� vn M o Im.- on P. Sw'mn5lPeMem'. sb.p4N omF) Mw'uefCgt..v.b¢n' IMifg93.U]¢IIfN30 megyy <.tmmPmor umT.mca.ao. West( -)/East(+) (700 usfdin) Vertical Section at 91.76" (100 ustl/in) ConocoPPhillips Aiaska.lnD. "I 1H-21 Well Attritwte8 Max S, MD TD weneore avwwl K,UPM"-U 500292235500 KUPARUK R0/ER UN1 Ile wwlswne Irc1 Mp II1Ke1 Ade 1315.0) PROD 4151 3.885.60 8.3150 Commed H29(ppm) oak Anlwltlbn SSSV TROP 100 926)2011 Last Y/O: FM pW KBAr41R1 Rig ReNar Dole 312811993 _ AnndYlon pepfa lMaB1 Eno pate Anndation Last Tag: SLM ],896.0 4262012 Rev Reason: WELL REVIEW )Law En61tl DMe oslwd 112012 Casing Strings cuing peaeeipdon swng o... sed�gm... CONDUCTOR 16 15062 mpinKSl set Depin lL-$w wpthlrvpl-smnp 41.0 t210 iT1.0 WL.. string... 9lnng iop send 62.S) H<0 WELDED Casing Deacnption 441ng 0... SMrq ID... SURFACE 95/8 8.921 Top IflK91 Set paPtplC.. SwpsplElNp1 402 4.8204 424].1 $tnnB wL.. S41ng... $Blip TOP T6N 35.00 655 BTC Casing pescnp4on inn90...,nng ip.. PRODUCTION J 6.276 T -p IKKO 4=t poTEI1... 8dpeplERVB1... 38.8 8.296.2 6,946.9 Siong WL.. 94inp _. Sinng Top Thm 1 26.00 .455 AB -MOD Tubino Strinas Toeing Dencrlpnan suing o... Ismnglo.-Top lnrcel set Dedra ry. sw Depla lrvDl-smog TUBING 31rz 2.992 3J.6 ].692.9 6,415.2 wt.. smrc... Stnig TOP Tn. 9.30 J-55 EUE8ROMOO COMPletion Details Top Depth IRTop Incl Top (n881 IRKS) lel 1°1 Rem pexripnon comment NemL Ip Dnl 37.6 37.6 0.13 HANGER FMC GEN IV HANGER 3.500 1,789.3 1,763.2' 14.35 SAFETY VLV QAMDD TROPIA-RO SAFETY VALVE 2812 OP OF PBR HAS 4 12' RH SQUARE 3. pan BAR Pan .119' STROKE R 000 ],850.1 8,441.9 39.00 KE THREAD FOR PKR RETRIEVAL) 7,663.9 6,452.] 39.00 PACKER BAKER He RETRIEVABLE PACKER 2.890 7,680.3 6,465.4 M95 NIPPLE CAMCO D NIPPLE NO GO 2.750 7,692.0 6.474.51 38.97 SOS BAKER SHEAR OUT SUB 3.015 Perforations B. Slots To flKB Bon MB Topm.) (MB) ann Trvo) (II I Zone Dee sod Dine Iso... Comment 7,768.0 7,858.0 6,533.5 6,603) UNIT D. CJ, C-3,11-21 WVVI993 6 O'IPERF 2 W ].9180 7.948.0 8,850.7 6,8A.T C-1, UNIT B. 1H-21 &281993 12.OIPERF EEMeg.phagN SWSdag.phasing Notes: General $ Safetv Entl pwe Annwwlon 92]rz010 NOTE: View Schematic wlAMeE2 Schema0q.0 Mandrel Details "De"n iep INp) Incl OD V.N. LwM SInITop IftK81! (' KD V) Mab M I hnl Seng Type T,, Port Ske T PnR. (In) (pail Ron Deb Com... ) 1 2.570.5 2.49$.4 31.02 CAMCO MUG 1 GAS LIFT GLV BKS 0.156 1,260.0 815!200] 2 4,354.9 3,890.4 40.04 CAMCO MUG 1 GAS LIFT OV BKS 0.250 0.0 8152007 3 5,143.4 4,695.7 39.97 CAMCO MUG 1 GAS LIFT OMY an 0.000 0.0 852007 4 5,921.9 5,089.9 39.72 CAMCO MUG 1 GAS LIFT OMY BKS 0.1100 0.0 8IN2007 5 6.709.9 5,702.6 37.75 CAMCO KBUG 1 GAS LIFT DMY BKS 0.000 0.0 511311999 6 ],182.7 6,074.9 38.17 CAMCO MUG 1 GAS LIFT O6(Y BKS 0.000 0.0 W1311999 7 7 OS2.2 6.404.7 39.04 CAMCO MMG-2 I W OAS LIFT DMY RK 0.000 0.0 7/18/993 1H-21 Proposed CTD Schematic 16" 62# H-40 shoe @ 121' MD 9-5/8" 36# J-55 shoe @ 4820' MD KOP @ 7826' MD :rfs squeezed w/ cement 158' MD 148' MD fop of Cement —7870' MD 7" 26# J-55 shoe @ 8296' MD 3-1/2" Camco TRDP=4A-RO SSSV at 1789' MD (2.812") 3-1/2" 9.3# J-55 EUE 8rd Tubing to surface 3-1/2" Carrico MMG gas lift mandrel at 2571', 4355', 5143', 5922', 6710', 7183', 7602' Baker 3-1/2" PBR at 7650' MD BakerHB packer at 7664' MD (2.89" ID) D -nipple at 7680" MD (Milled out to 2.80" ) 3-1/2" Baker SOS @ 7692' MD 114-21 A TD = 9745' MD Inflatable plug mid -element= 8364' MD Anchored billet = 8315' MD 1 H-21AL1 TD = 11293' MD 2-3/8" slotted liner w/ anchoredbillet --------------------------------------- TOL = 7935' MD BOL = 11293' MD IH,TD = 17130' MD Top of Billet 0 8,400' MD 1 H-21AL2-01 TD = 11150MD __________________Top of Liner 7,675'MD _____ TRANSMITTAL LETTER CHECKLIST WELL NAME: 76ea /W - PTD: PTD: 2_-1U ''U 72 Development Service _ Exploratory _ Stratigraphic Test _ Non -Conventional FIELD: POOL: Check Box for Appropriate Letter / Paragraphs to be Included in Transmittal Letter CHECK OPTIONS TEXT FOR APPROVAL LETTER i MULTI LATERAL The permit is for a new wellbore segment of existing well Permit No. / - D 7 API No. 50� Z�-fes/ -GU . v/ (If last two digits Production should continue to be reported as a function of the original in API number are API number stated above. between 60-69 In accordance with 20 AAC 25.005(f), all records, data and logs acquired for the pilot hole must be clearly differentiated in both well Pilot Hole name ( PH) and API number (50- - -� from records, data and logs acquired for well name on permit). The permit is approved subject to full compliance with 20 AAC 25.055. Approval to produce/inject is contingent upon issuance of a conservation Spacing Exception order approving a spacing exception. (Comnanv 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 (Comnanv Name) has designed and Well implemented a water well testing program to provide baseline data on water quality and quantity. (Company Name) must contact the AOGCC to obtain advance approval of such water well testing program. Regulation 20 AAC 25.071(a) authorizes the AOGCC to specify types of well logs to be run. In addition to the well logging program proposed by (Company Name) in the attached application, the following well logs are also required for this well: Well Logging Requirements ,Per Statute AS 31.05.030(d)(2)(B) and Regulation 20 AAC 25.071, composite curves for well logs run must be submitted to the AOGCC within 90 days after completion, suspension or abandonment of this well. Revised 2/2015 RTD ,;<a-09-9 Loepp, Victoria T (DOA) From: Loepp, Victoria T (DOA) Sent: Tuesday, September 04, 2018 6:51 PM To: Herring, Keith E Subject: Re: KRU 1H-21AL2 (PTD #218-079) Keith, Verbal approval is granted to drill ahead as outlined below. Please send a revision to the approved PTD tomorrow for the new BHL. Thanx, Victoria Sent from my iPhone On Sep 4, 2018, at 6:15 PM, Herring, Keith E <Keith. E. Herring@conocophillips.com> wrote: Good evening Victoria, While drilling KRU 1H-21AL2 (PTD #218-079) the wellbore was turned to the south to achieve better rock properties and avoid structural complexity near total depth. However, in doing so the wellbore will no longer maintain 500' within the permitted (X,Y) if operations continue. The image below, from WellArchitect, shows the original plan (green) versus the projected plan (red) with the distance between the two being 629 feet. In order to continue drilling ahead and meet the target objectives, COP requests "verbal" approval be given via email and a revised permit to drill for this lateral be submitted to the AOGCC within one business day. 1 apologize for the inconvenience and thank you for your time. <image004.jpg> Thanks, Keith Herring CTD Engineer 907.263.4321 (Office) 907.570.2410 (Mobile) 700 G Street, ATO — 664 Keith. P_ Herrin _•ro-conocnnhi II m, <image003.png> Loepp, Victoria T (DOA) From: Herring, Keith E <Keith.E.Herring @conocophiIli ps.com> Sent: Tuesday, September 04, 2018 6:16 PM To: Loepp, Victoria T (DOA) Cc: Ohlinger, James 1; Long, William R; Starck, Kai Subject: KRU 1H-21AL2 (PTD #218-079) Follow Up Flag: Follow up Flag Status: Flagged Good evening Victoria, While drilling KRU 1H-21AL2 (PTD #218-079) the wellbore was turned to the south to achieve better rock properties and avoid structural complexity near total depth. However, in doing so the wellbore will no longer maintain 500' within the permitted (X,Y) if operations continue. The image below, from WellArchitect, shows the original plan (green) versus the projected plan (red) with the distance between the two being 629 feet. In order to continue drilling ahead and meet the target objectives, COP requests "verbal" approval be given via email and a revised permit to drill for this lateral be submitted to the AOGCC within one business day. I apologize for the inconvenience and thank you for your time. Thanks, Keith Herring CTD Engineer 907.263.4321 (Office) 907.570.2410 (Mobile) 700 G Street, ATO — 664 Keith. F. Hcmzi (r conocophil ips.com i ConocoPhillips PTD 2/9-07'7 Loepp, Victoria T (DOA) From: Loepp, Victoria T (DOA) Sent: Tuesday, July 10, 2018 2:12 PM To: 'Long, William R' Cc: Ohlinger, James 1 (James.J.Ohlinger@conocophillips.com) Subject: KRU 1H-21AL2(PTD 218-079) PTD Approval Modifications William, Please make the following modifications to the approved PTD 218-079: Annular preventer test pressure is 2500 psig A variance to 20 AAC 25.015(b) is granted to allow the kickoff point to be any point along the parent lateral. Subsequent Form Required: 10-407 Include this approval with the original approved PTD. Thanx, Victoria Victoria Loepp Senior Petroleum Engineer State of Alaska Oil & Gas Conservation Commission 333 W. 7th Ave Anchorage, AK 99501 Work: (907)793-1247 V icto ria. LoeppC@a las ka. qoy CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Victoria Loepp at (907)793-1247 or Victoria. Loepo@olaska.aov THE STATE 01ALASKA GOVERNOR BILL WALKER 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 1H-21AL2 ConocoPhillips Alaska, Inc. Permit to Drill Number: 218-079 Surface Location: 678' FNL, 793' FEL, SEC. 33, T12N, RIOE, UM Bottomhole Location: 393' FNL, 773' FEL, SEC. 35, T12N, R10E, UM Dear Mr. Ohlinger: 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 www.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. 218-077, API No. 50-029-22355- 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 l Chair k, DATED this 5 day of July, 2018. STATE OF ALASKA ALF OIL AND GAS CONSERVATION COMMd )N PERMIT TO DRILL 20 AAc 25 nOfi RECEIVED JUN 29 2018 1 a. Type of Work: lb. Proposed Well Class: Exploratory - Gas L1 Service - WAG ❑ Service - Disp ❑ ic. Spec i p e for: Drill ❑ Lateral ❑✓ Stratigraphic Test ❑ Development -Oil ❑✓ - Service - Winj ❑ Single Zone ❑� Coalbed Gas Gas Hydrates ❑ Redrill ❑ Reentry ❑ Exploratory - Oil ❑ Development - Gas ❑ Service - Supply ❑ Multiple Zone ❑ Geothermal ❑ Shale Gas ❑ 2. Operator Name: 5. Bond: Blanket Q . Single Well ❑ 11. Well Name and Number: ConocoPhillips Alaska, Inc. Bond No. 5952180 - Kuparuk Riv Unit 1H-21AL2 3. Address: 6. Proposed Depth: P (ff%12. Field/Pool(s): PO Box 100360 Anchorage, AK 99510-0360 MD: 11,100' - TVD -S; 6494' - Kuparuk River Kuparuk River Oil - 4a. Location of Well (Governmental Section): 7. Property Designation: 17.7-6 Surface: 678' FNL, 793' FEL, Sec 33, T12N, R10E, UM L Z �' jb ADL 25639 Top of Productive Horizon: 8. DNR Approval umber: 13. Approximate Spud Date: 788' FNL, 2285' FEL, Sec 34, T12N, R10E, UM LONS 80-261 7/11/2018 Total Depth: 9. Acres in Property: 14. Distance to Nearest Property: 393' FNL, 773' FWL, Sec 35, T12N, R10E, UM 2560 7200' 4b. Location of Well (State Base Plane Coordinates - NAD 27): 10. KB Elevation above MSL (ft): 96 15. Distance to Nearest Well Open Surface: x- 549555 - y- 5980025 ' Zone- 4 GL / BF Elevation above MSL (ft): 54.4. to Same Pool: 978' t0 1 H-13 16. Deviated wells: Kickoff depth: 7925 feet • 17. Maximum Potential Pressures in psig (see 20 AAC 25.035) Maximum Hole Angle: 103.3 degrees Downhole: 3275 Surface: 2645 18. Casing Program: Specifications Top - Setting Depth - Bottom Cement Quantity, c.f. or sacks Hole Casing Weight Grade Coupling Length MD TVD MD TVD (including stage data) 3" 2-3/8" 4.6# L-80 ST -L 2700' 8400' - 6640' 11,100'. 6494' Un -Cemented 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): 8315 6962 N/A 8207 6877 N/A Casing Length Size Cement Volume MD TVD Conductor/Structural 121' 16" 200 SX PF C CMT 121' 121' Surface 4779' 9-5/8" 930 SX PERM E, 450 SX G 4820' 4247' Intermediate Production 8258' 7" 299 SX CLASS G CMT 8295' 6947' Liner Perforation Depth MD (ft): Perforation Depth TVD (it): 7768-7858, 7918-7948 6534-6604, 6651-6674 Hydraulic Fracture planned? Yes❑ No 7 P Sketch 20. Attachments: Property Plat ❑ DivertOer Sketch lling Program B DStysis eabed Report e Dri I ngeFluid Progv. Depth ram e AAC 20 25.050 requiremlot Shallow Hazard lents B 21. Verbal Approval: Commission Representative: Date 22. 1 hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without priorwritten approval. Contact Name: William R. Long Authorized Name: James Ohlinger Contact Email: William. R. Lon COP.com Authorized Title: Staff CTD Engineer Contact Phone: 907-263-4372 G1%*11-e Authorized Signature: !/ Date: Commission Use Only Permit to Drill 7 Number: d-67950-0 API Number: „ / / Z— ��-�5 Permit Approval See cover letter for other y rC�l'�J Date: ) requirements. Conditions of approval : If box is checked, well may not be used to explore for, test, or produce coalbed meth it hydrates, or gas contained in shales: Other: g�wE{►��y QpPETPs7iG 31:70 j�+1 Samplesreq'd: Yes❑ NoL Mud log req'd: Yes❑ No[2 HzS measures: Yes d No ❑Directional svy req'd: Yes d No,❑ Spacing exception req'd: Yes ❑ No 4/ Inclination -only svy req'd: Yes ❑ No LvJ Post initial injection MIT req'd: Yes ❑ No ❑ APPROVED BY -4 II% Approved by: n COMMISSIONER THE COMMISSION Date: Submit Form and Form 10-401 Revised 512017 This permit is valid for 24 months from the date of approval per 20 AAC 25.005(g) Attachments in Duplicate ConocoPhillips Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 June 27, 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 four laterals out of the KRU 1 H-21 (PTD# 193-046) using the coiled tubing drilling rig, Nabors CDR3-AC. CTD operations are scheduled to begin in July 2018- The objective will be to drill four laterals, KRU 1 H -21A, 1 H- 21AL1, 1H-21AL2, and 1H-21AL2-01, targeting the Kuparuk C -sand interval. To account for geological uncertainties, ConocoPhillips requests a variance from the requirements of 20 �- AAC 25.015 to allow the actual kick-off point to be anywhere along the length of the parent lateral instead of being limited to 500' from the original point. Attached to this application are the following documents: - Permit to Drill Application Forms (10-401) for 1H -21A, 1H-21AL1, 1H-21AL2, and 1H-21AL2-01 - Detailed Summary of Operations - Directional Plans for 1H -21A, 1H-21AL1, 1H-21AL2, and 1H-21AL2-01 - Current wellbore schematic - Proposed CTD schematic If you have any questions or require additional information, please contact me at 907-263-4372. Since William R. Long Coiled Tubing Drilling Engineer ConocoPhillips Alaska 1. 2. 3. 4. 5. 6. 7. Kuparuk CTD Laterals 1H -21A, 1H-21AL1, 1H-21AL2, and 1H-21AL2-01 Application for Permit to Drill Document Well Name and Classification ....................................... (Requirements of 20 AAC 25.005(1) and 20 AAC 25.005(b)) ......................... Location Summary ......................................................... (Requirements of 20 AAC 25.005(c)(2))........................................................ ................................................................ 2 ......................................................................................... 2 Blowout Prevention Equipment Information ........................ (Requirements of 20 AAC 25.005(0)(3)).................................................................. Drilling Hazards Information and Reservoir Pressure......... (Requirements of 20 AAC 25.005(c)(4)).................................................................. Procedure for Conducting Formation Integrity tests .......... (Requirements of 20 AAC 25.005(c)(5))................................................................... Casing and Cementing Program ............................................ (Requirements of 20 AAC 25.005(c)(6)).................................................................... Diverter System Information .................................................. (Requirements of 20 AAC 25.005(c)(7)).................................................................... 8. Drilling Fluids Program .................................................... (Requirements of 20 AAC 25.005(c)(8))............................................................ .............................................. 2 ................................................................ 2 ............................................. 2 ............................................................... 2 ............................................. 2 ............................. -................................ 2 ......... 2 .............2 ........................................ 3 ........................................................ 3 ...................................... 3 ..................................................... 3 .......... 3 ...............3 9. Abnormally Pressured Formation Information.............................................................................4 (Requirements of 20 AAC 25.005(c)(9)).... - . ... ....... ......... ... - ................................................................ -- ..................................... 4 10. Seismic Analysis............................................................................................................................. 4 (Requirements of 20 AAC 25.005(c)(10))................................................................................................................................................4 11. Seabed Condition Analysis............................................................................................................ 4 (Requirements of 20 AAC 25.005(c)(11))................................................................................................................................................4 12. Evidence of Bonding...................................................................................................................... 4 (Requirements of 20 AAC 25.005(c)(12))................................................................................................................................................ 4 13. Proposed Drilling Program.............................................................................................................4 (Requirements of 20 AAC 25.005(c)(13))................................................................................................................................................4 Summaryof Operations...................................................................................................................................................4 LinerRunning................................................................................................................ ......6 ............................................. 14. Disposal of Drilling Mud and Cuttings.......................................................................................... 6 (Requirements of 20 AAC 25.005(c)(14))......................................................................................................................I....................... 1.6 15. Directional Plans for Intentionally Deviated Wells....................................................................... 7 (Requirements of 20 AAC 25.050(b))......................................................................................................................................................7 16. Attachments....................................................................................................................................7 Attachment 1: Directional Plans for 1H -21A, 1H-21AL1, 1H-21AL2, and 1H-21AL2-01 laterals.....................................7 Attachment 2: Current Well Schematic for 1 H-21............................................................................................................7 Attachment 3: Proposed Well Schematic for 1H -21A, 1H-21AL1, 1H-21AL2, and 1H-21AL2-01 laterals .......................7 Page 1 of 7 June 27. 2018 PTD Application: 11-1-21 A, 1H iAL1, 1H-21AL2, and 1H-21AL2-01 1. Well Name and Classification (Requirements of 20 AAC 25.005(0 and 20 AAC 25.005(b)) The proposed laterals described in this document are 11-1-21 A, 11-1-21AL1, 1H-21AL2, and 1H-21AL2-01. All laterals will be classified as "Development -Oil' wells. 2. Location Summary (Requirements of 20 AAC 25.005(c)(2)) These laterals will target the C sand package in the Kuparuk reservoir. See attached 10-401 forms for surface and subsurface coordinates of each of the laterals. 3. Blowout Prevention Equipment Information (Requirements of 20 AAC 25.005 (c)(3)) Please reference blowout prevention (BOP) schematics on file with the Commission for Nabors CDR3-AC. BOP equipment is as required per 20 AAC 25.036 for thru-tubing drilling operations. — Pipe rams, blind rams and the CT pack off will be pressure tested to 250 psi and to 3,000 psi. Using the maximum formation pressure in the area of 3,275 psi at the datum in 21-1-12 (i.e. 10 ppg EMW), the maximum potential surface pressure in 1 H-21, assuming a gas gradient of 0.1 psi/ft, would be 2,645 psi. Seethe "Drilling Hazards Information and Reservoir Pressure" section for more details. — The annular preventer will be tested to 250 psi and 2,500 psi. 4. Drilling Hazards Information and Reservoir Pressure (Requirements of 20 AAC 25.005 (c)(4)) Reservoir Pressure and Maximum Downhole Pressure (Requirements of 20 AAC 25.005 (c)(4)(a)) The formation pressure in KRU 1 H-21 was measured to be 2,978 psi at the datum (9.1 ppg EMW) on 5/16/2015. The maximum downhole pressure in the 1 H-21 vicinity is the 1 H-12 at 3,275 psi at the datum or 10 ppg EMW. i Potential Gas Zones (Requirements of 20 AAC 25.005 (c)(4)(b)) 4 No specific gas zones will be drilled; gas injection has been performed in this area, so there is a chance of encountering gas while drilling the 1 H-21 laterals. If significant gas is detected in the returns the contaminated mud can be diverted to a storage tank away from the rig. Potential Causes of Hole Problems (Requirements of 20 AAC 25.005 (c)(4)(c)) The major expected risk of hole problems in the 1 H-21 laterals will be shale instability across faults. Managed pressure drilling (MPD) will be used to reduce the risk of shale instability associated with fault crossings. 5. Procedure for Conducting Formation Integrity tests (Requirements of 20 AAC 25.005(c)(5)) The 1 H-21 laterals will be drilled under 20 AAC 25.036 for thru-tubing drilling operations so a formation integrity test is not required. Page 2 of 7 June 27, 2018 PTD Application: 1H -21A, 1H-21AL1, 1H-21AL2, and 1H-21AL2-01 6. Casing and Cementing Program (Requirements of 20 AAC 25.005(c)(6)) New Completion Details Lateral Name Liner Top Liner Btm Liner Top Liner Btm Liner Details Btm MD MD MD TVDSS TVDSS Conductor 1H -21A 8200' 11,500' 6538' 6526' 2%", 4.7#, L-80, ST -L slotted liner, Surface 121' 1640 670 Surface aluminum billet on to 1H-21AL1 7925' 11,550' 6536' 6644' 2%", 4.7#, L-80, ST -L slotted liner; 4247' 3520 2020 Production7" aluminum billet on to 1H-21 AL2 8400' 11,100 6640' 6494' 2%", 4.7#, L-80, ST -L slotted liner; 4980 4320 Tubing3-1/2" 9.3 aluminum billet on to 1H-21 AL2 -01 7675' 11,150 6365' 6632' 2%", 4.7#, L-80, ST -L slotted liner, 10,540 deployment sleeve on to Existing Casing/Liner Information Category OD weigh t Grade Connection Top MD Btm MD Top TVD Btm TVD Burst psi Collapse psi Conductor 16" 62.5 H-40 Welded Surface 121' Surface 121' 1640 670 Surface 9-5/8" 36 J-55 BTC rfa Suce 4820' Surface 4247' 3520 2020 Production7" 26 J-55 AB -MOD Surface 8296' Surface 6947' 4980 4320 Tubing3-1/2" 9.3 J-55 EUE 8rd MOD Surface 7693' Surface 6475' 10,160 10,540 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: Water based Power -Vis milling fluid (8.6 ppg) — Drilling operations: Water based Power -Pro drilling 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: BHA's will be deployed using standard pressure deployments and the well will be loaded with 11.4 ppg NaCl/NaBR completion fluid in order to provide formation over -balance and maintain wellbore stability while running completions. If higher formation pressures are encountered the completion brine will be weighted up with sodium bromide or potassium formate. Managed Pressure Drilling Practice Managed pressure drilling (MPD) techniques will be employed to maintain a constant overbalanced pressure on the open hole formation and promote wellbore stability throughout the coiled tubing drilling (CTD) process. Mud weight is not, in many cases, the primary well control barrier. This is satisfied with the 5000 psi rated coiled tubing pack off and MPD choke. BOPE equipment provides the secondary well control as detailed in section 3 "Blowout Prevention Equipment Information". In the 1 H-21 laterals we will target a constant BHP of 11.4 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 Page 3 of 7 June 27. 2018 PTD Application: 1H -21A, 1H-21AL1, 1H-21AL2, and 1H-21AL2-01 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. Pressure at the 1 H-21 Window (7825' MD. 6578' TVD) l Isinn Mpn 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 KRU well 1H-21 is a Kuparuk producer equipped with 3-1/2" tubing and 7" production. casing. The CTE sidetrack will utilize laterals to target the Kuparuk sands to the north and east of the existing 1H-21 wellbore. The laterals will increase throughput and recovery from a potentially sheltered comer of a fault block. Prior to CTD operations, E -Line will punch holes in the 3-1/2" tubing tail below the production packer and the "D" nipple will be milled out to 2.80" ID. The existing perforations will be squeezed with cement and the 3-1/2" tubing tail will be cemented in place to provide a means to kick out of the 7" casing. Following the cement squeeze Nabors CDR3-AC will drill a pilot hole and set a mechanical whipstock in the 2.80" pilot hole. The whipstock will be used to cut a window in the 7" casing and drill CTD laterals. Page 4 of 7 June 27. 2018 Pumps On 1.8 bpm) Pumps Off Formation Pressure 9.1 3113 psi 3113 psi Mud Hydrostatic 8.6 2942 psi 2942 psi Annular friction i.e. ECD, 0.080psi/ft) 626 psi 0 psi Mud + ECD Combined no chokepressure) 3568 psi overbalanced -455psi) 2942 psi underbalanced -171psi) Target BHP at Window 11.4 3899 psi 3899 psi Choke Pressure Required to Maintain Target BHP 331 psi 957 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 KRU well 1H-21 is a Kuparuk producer equipped with 3-1/2" tubing and 7" production. casing. The CTE sidetrack will utilize laterals to target the Kuparuk sands to the north and east of the existing 1H-21 wellbore. The laterals will increase throughput and recovery from a potentially sheltered comer of a fault block. Prior to CTD operations, E -Line will punch holes in the 3-1/2" tubing tail below the production packer and the "D" nipple will be milled out to 2.80" ID. The existing perforations will be squeezed with cement and the 3-1/2" tubing tail will be cemented in place to provide a means to kick out of the 7" casing. Following the cement squeeze Nabors CDR3-AC will drill a pilot hole and set a mechanical whipstock in the 2.80" pilot hole. The whipstock will be used to cut a window in the 7" casing and drill CTD laterals. Page 4 of 7 June 27. 2018 PTD Application: 1H -21A, 1H-21AL1, 1H-21AL2, and 1H-21AL2-01 Pre -CTD Work 1. RU Slickline: Drift tubing with dummy whipstock. 2. RU E -line: Punch holes in the 3'/z" tubing tail below the production packer. 3. RU Pumping Unit: perform injectivity test down the tubing. 4. RU Service Coil: Mill out "D" nipple and cement squeeze the perforations up to the holes in the tubing tail. 5. RU Slickline: Drift tubing with dummy whipstock. Tag top of cement and pressure test cement. 6. Prep site for Nabors CDR3-AC. Rig Work 1. MIRU Nabors CDR3-AC rig using 2" coil tubing. NU 7-1/16" BOPE, test. 2. Mill 2.80" cement pilot hole. 3. Set monobore whipstock. 4. 1H -21A Lateral (C sand -North) a. Mill 2.80" window at 7825' MD. b. Drill 3" bi-center lateral to TD of 11,500' MD. c. Run 2%" slotted liner with an aluminum billet from TD up to 8200' MD. 5. 1H-21AL1 Lateral (C sand -North) a. Kickoff of the aluminum billet at 8200' MD. b. Drill 3" bi-center lateral to TD of 11,550' MD. c. Run 2%" slotted liner with aluminum billet from TD up to 7925' MD. 6. 1H-21AL2 Lateral (C sand -East) a. Kickoff of the aluminum billet at 7925' MD. b. Drill 3" bi-center lateral to TD of 11,100' MD. c. Run 2%" slotted liner with aluminum billet from TD up to 8,400' MD. 7. 1H-21AL2-01 Lateral (C sand- East) a. Kick off of the aluminum billet at 8400' MD. b. Drill 3" bi-center lateral to TD of 11,150' MD. c. Run 2%" slotted liner with deployment sleeve from TD up to 7675' MD. 8. Freeze protect, ND BOPE, and RDMO Nabors CDR3-AC. Post -Rig Work 1. Return to production. Page 5 of 7 June 27, 2018 PTD Application: 1H -21A, 1H-21AL7, 1H-21AL2, and 1H-21AL2-01 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 slick -line. - 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 undeployment, the steps listed above are observed, only in reverse. Liner Running - 1H-21 CTD laterals will be displaced to an overbalance completion fluid (as detailed in Section 8 "Drilling Fluids Program") prior to running liner. - While running 2%" slotted liner, a joint of 2%" 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%" rams will provide secondary well control while running 2% 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 18 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). Page 6 of 7 June 27, 2018 PTD Application: 1H -21A, 1H-21AL1, 1H-21AL2, and 1H-21AL2-01 15. Directional Plans for Intentionally Deviated Wells (Requirements of 20 AAC 25.050(b)) - The Applicant is the only affected owner. - Please see Attachment 1: Directional Plans - Magnetic and inclination surveys will be taken every 30 ft. No gyro will be run. - MWD directional, resistivity, and gamma ray will be run over the entire open hole section. Distance to Nearest Property Line (measured to KPA boundary at closest point) Lateral Name Distance 1H -21A 5,900' 1 H-21AL1 5,900' 1H-21AL2 7,200' 1 H-21AL2-01 7,200' Distance to Nearest Well within Pool Lateral Name Distance Well 1H -21A 790' 11-1-12 1H-21AL1 790' 1H-12 1 H-21AL2 978' 1 H-13 1H-21AL2-01 978' 1H-13 16. Attachments Attachment 1: Directional Plans for 1H -21A, 1H-21AL1, 1H-21ALZ and 1H-21AL2-01 laterals. Attachment 2: Current Well Schematic for IH -21. Attachment 3: Proposed Well Schematic for 1H -21A, 1H-21AL1, 1H-21AL2, and 1H-21AL2-01 laterals. Page 7 of 7 June 27, 2018 ConocoPhillips Project: Ku aruk River UOlf 1 P �'"""1MmTrve R"n1n WELLBORE DETAILS: 1H -21A REFERENCE INFORM4TION Site: Kupantk I Pad weml. xmn:1].m• aoutllnare lNfl RefeMnae Wall 1X21, Trace Nunn Weil: IH -21 w9�eae rhw src..yn. noun..] Parent Wellbore: 7H-21 VerIkA(vD1 Relelen"et 11 e10 e.9Dum 111+211 Wellbore: IH -21A D' p Mph: BJ.ef' Te on MD: ]00].30 &Gim Reluenae: .WN Plan: 1N•2tA wP03(7H•31/iN•27A) m�mi ueasu Will IH -21 NO ( uoe dIkpn NeOea'. M��9�w11H21) IH-101/IH-101 18-101/191-1011.1 IH-101/1pp-I01L2 IN-IOHI11- Ix-Im/fJ1-wlLs Imo n+wnx-l4 HI-mV�93-IDxa Ix-1mrul-la=i;a.. BAIUGHES a fiE<0mpam/ I' 1� nl.l xlu nn G/. 5600 5250 Ilbn✓III-Inn nl-tlNu.l19 - 'N�' �i 49001 fi52i ubns/111J_ �'. I III-I]/III-It I!LItllill l-II�II.J 4550 mos 4200 lel-19/1X-19ALL01 III P711H JAPbI 1 1111 h -IN Ix-19Itx19ALbn 385lp1 1111 Iltt AI'02. p141 IH-I9/III ISL° ul J I%I -roto: u1.iVu 1911 II ul dol -Int III Inllt-16AI I Mop II J /IFI 9n 1 HI- 3500-� i 19IIN 19iu�lt'01 -. ( °moo I` 111-IN111 IbTLxM31: _' � -- IFI-191 19ALJt, p lill 0 Ifl-19/Ix 3• � �1/I JjS �'i2A00 511. a ul-19nF��' In-rv.m 1 n IH-19/IHV 2450 - 4" y Ll1. ntnll. nr ro: 2100+ III -IWMI IO SOA 5(lUl� Ilk il`.i{II-1119 III Illi 111 -II' l> -G Ii50 III -I l:trlll -I, 1400 ulmmtZr M-1111111-111losM-1111111-111 O y 7001S - lu zlnualnl^ 350- u1.lun n -n nL?vui±Inl �m w r 'ly 'IK-rmnl Pt ur IH-b11WMINIH-0�I _ c � � it m21n14±1 IH-09/IHL4Lf .700 IH4vlli 4LIAD 11' `O 111-IVIII Il i .1050i . S` -1400) -17501 :opo -21 DO -1750 T1400 -1050 -701 350 0 510 700 IOSOIi 1400 1]50 2100 2450 2800`'3,150 35001 3850 4200 45504550 4� 5600 5950 6300 6650 7000 ]350 7700 8050 8400 8950 9100 9450 9800 I yYest(-)/F,�St(+) (350 us{t/In) IHu9,I11°9 1H-21 0 96.00usft It H-21) IH-0&1xO8 I - I Ix-uiw-u u1LLxHR xi.0lnx-0I IIL19/1x.1e vof� AW KUP 1H-21 COr1000Ph1llIp5 MEM=AV1elfAttribates Mau An 1IRIO) TO Wellbore Field Name 5002922"35500 KUPARUK RNER UNIT Well StatYa Incl l°) MOI3,88 Act 8315.0 PROD 41.54 3,885.60 8,315.0 Alaska, Inc. Comment R33(ppm)) Dale Annotallan End gate KBGrtl (X) Rig Rebase pate SSSV: THEIR 100 92612011 LaslWO: 312811993 Yhemalk- 111E somas! Mnotation Lasl Tag: SLM _ peptM1 XNp) End pale Ann.I.Sen xl Moa..End Oate ],8960 4126/2012 Rev Reason: WELL REVIEW agsbor1 6/1112012 -- Casin Strin s Casing Dr..6pre.n String 0... Stinging TOP 61NB) SeOesN It Set DepthlNp)., 8lring Wl._ 8Lin9-.Strin 9ToPThrd HANGER,m CONDUCTOR 18 15.062 41.0 121.0 121.0 fi2.50 H -4D WELDED Ca¢ing DewnpOon String 0... Btring 1p... Top IXKB) Setgeplhll...Set DeptM1lNp)_Bhing Wc., Sbing._Aring Top ibN SURFACE 9518 8921 40.2 4,820.4 4.24].1 3fi.00 J-55 BTC Cieing Description Sldng O... SRIng Ip... Top ryNBf $at 0eplr lf...5s, Uspig,v.,... Bltl ng nnig...-mg Top IFin PRODUCTION ] 6.2]6 38.8 8,296.2 6,9469 MAU J-55 AB -MOD Tubin Strin s nbm9 peacdplmn stdnSO.. Sting lD... TOP (XKB) Set papm 0_Set papm lrvDl .. Smng Wt.. sting._Smng Top TM1rd TUBING 3112 2.992 3].6 ],fi929 6,4]5.2 9.30 J-55 EUEBftOMOD LONpuCTOgfl, CDal lidion Details Top 0epl nV0) Topmcl Nom L.. Top (11115] (gKB) (°) In. D ... ript- commem 10 it.) SAFEWWV, 37.6 37.6 0.13 HANGER FMC GEN IV HANGER 3.500 leas 1,789.3 1,783.2 14.355AFETY VLV CAMCO TROP4A-3O SAFETY VALVE 2.812 7,650.1 6,441.9 39.00 PBR BAKER PBR w/ 10' STROKE (TOP OF PBR HAS 412" RH SQUARE 3.000 THREAD FOR PKR RETRIEVAL) GASUFT. 7.663.9 6,4U.7 39.00 PACKER BAKER HB RETRIEVABLE PACKER 2.890 2dn 7,680.3 6,465.4 38.95 NIPPLE CAMCO D NIPPLE NO GO 2.750 7,692.0 6.414.5 38.9]909 BAKER SHEAR OUT SUB 3.015 GAS OFf, 4,356 P@r(orations S Slot, Shm Top(WOU BM1ND) Dens TO IXKB) B1m XNB (XKB) (RUB) Zone Del. (¢h.- Tips Commwd ],]88.0 7,858.0 6,533.5 6,603) UNIT D, C4, &1&1993 6.0 (PERF 216" Enedet, 90 deg. phasing C3, 1H-21 ],918.0 ],948.0 6,650.7 6.6]4.2C-1,UNIT B, 82&1993 12.0 IPERF MS 4E" HJ2, W deg. phasing 1H-21 Notes: General & Safety End Dale Annoedion 92]120 10 NOTE.View Schematic Wl Alaska SchemaIRS.0 SURFACE, .01. GAR LIFT, B1AT GAE UI . 3.933 G STIR. E,710 GAS LIFT. SAM E45 UFT. T,aY3 PBR,T6YI :��lPACI(FA.].Sst MIALB.T.aell SOS T,m Mandrel Details.. IPFRF. )]m-0,SRS Top Depth rop pon IWO In. OD Valve Latch Ste TROR.. Sin To (XKe) IXKB) P) Masa Mod.! 9n) Sery Typa Type (in) (psi) RYng.. Com... 1 2,570.5 2.495.4 31.02 CAMCO KBUG 1 GAS LIFT GLV BKS OA! 1,260.0 &5200] IPERF ],91¢].918 _ 2 4,354.9 3,890.4 40.04 CAMCO KBUG 1 GAS LIFT OV BK5 0.250 0.0 BI520W 3 5,143.4 4,495.] 39.9] CAMCO KBUG 1 GAS LIFT DMyBM0.000 0.0 85200] 4 5,921.9 5,089.9 39.]2 CAMCO KBUG 1 GAS LIFT DMY BK5 0.000 0.0 551200] 5 6.709.9 5,702.6 3].75 CAMCO KBUG 1 GAS LIFT DMY BK5 0.000 0.0 5113/1999 6 ],182] 6,074.9 38.1] CAMCO KBUG 1 GAS LIFT DMY BK5 0.000 0.0 5113/1999 ] 7,802.2 6,404.7 39.04 CAMCO MMG-2 112 GAS LIFT DMV RK 0.000 0.0 711811993 PRODUCTION. BB,3I5� TO 1H-21 Proposed CTD Schematic 16" 62# H-40 shoe @ 121' MD 9-5/8" 36# J-55 shoe @ 4820' MD C -sand perfs 7768'- 7856' MD 7918' - 7948' MD MD 3-1/2" Cameo TRDP=4A-RO SSSV at 1789' MD (2.812") 3-1/2" 9.3# J-55 EUE 8rd Tubing to surface 3-1/2" Cameo MMG gas lift mandrel at 2571', 4355', 5143', 5922', 6710', 7183', 7602' Baker 3-1/2" PBR at 7650' MD BakerHB packer at 7664' MD (2.89" ID) D -nipple at 7680" MD (2.75" min ID, No -Go) 3-1/2" Baker SOS @ 7692' MD iH-2tA (North) Top of blllel a B2W' MD IH -MU (Nonh) OH Anchor Eillel ® 7825' MD IH -22 (Easy Top of Blllel 8,400 MD 1. 7" 26# J-55 w tH-2tAL2.01 IEast) Shoe @ 8296' MD Q Top of Liner 7,675 MD WELLBORE DETAILS: IH-21AL2 M �.� _ „ i'�ps Project: Kupak RNer Unit Site: k iX Pad m 114-21 Well: 1 X31 Wellbore: 1H.21AL2 MbbTrve 1 u.9nn.. wnn uw�.n s�are6.' g,aa; aa,Neu. Wn0c0 Plan: 1H-21AL2_wpe2(1H-21/1X-21AL2) um.1® WELLBORE DETAILS: IH-21AL2 Mean Parent Wellbore: 1H -21A Tie on MD: 7925.00 az REFERENCE INFORWTION IF) Releren[p'. WNI1X21, Try NMN SIE 0) R= Meen See.e OM IS)Rekrtnx' Sbl-)Q.WN.aXQ UE HES 9n R,ft. 1H 21@96.Wuep (1H 21) aGEcomparc/ ib6on wheel M.. Cum. WELL DETAILS: 1H-21 +N/ -S +E/ -W Northing Easting Latitude Longitude 0.00 0.00 H 5980024.57 549555.22 70° 21'22.356 N 149° 35' 51.196 W Sec MD Inc Azi TVDSS +NLS +E/ -W Dleg TFace VSect Annotation 1 7925.00 78.42 88.94 6535.91 -108.86 3787.60 0.00 0.00 3787.60 TIP/KOP 2 8023.00 34.32 88.94 6588.85 -107.39 3867.19 45.00 180.00 3867.19 Start 45 tits 3 8146.73 90.00 88.94 6644.39 -105.45 3972.33 45.00 0.00 3972.33 End 45 d1s, Start 7 dls 4 8300.00 90.00 78.21 6644.39 -88.32 4124.41 7.00 270.00 4124.41 4 5 8600.00 103.32 94.60 6609.45 -69.16 4420.06 7.00 50.00 4420.06 5 6 8800.00 93.27 104.46 6580.56 -102.06 4614.70 7.00 135.00 4614.70 6 7 9200.00 92.89 76.42 6558.64 -105.11 5010.11 7.00 270.00 5010.11 7 8 9400.00 90.87 90.29 6552.05 -82.05 5208.17 7.00 98.00 5208.17 8 9 9800.00 93.12 62.36 6537.84 11.47 5592.74 7.00 275.00 5592.74 9 10 10200.00 90.41 90.24 6525.28 105.14 5977.33 7.00 95.00 5977.33 10 11 10600.00 90.36 62.24 6522.53 199.32 6361.99 7,00 270.00 6361.99 11 12 11100.00 96.01 96.85 6493.86 288.89 6845.18 7.00 80.00 6845.18 Planned TD at 11100.00 Mean Parent Wellbore: 1H -21A Tie on MD: 7925.00 az REFERENCE INFORWTION IF) Releren[p'. WNI1X21, Try NMN SIE 0) R= Meen See.e OM IS)Rekrtnx' Sbl-)Q.WN.aXQ UE HES 9n R,ft. 1H 21@96.Wuep (1H 21) aGEcomparc/ ib6on wheel M.. Cum. West( -)/East(+) (300 usft/in) 6000 6100 H r �II I IN 21/IH ....' ++ 6 6 111'....... 6200 ��11.■■■.No .■C....� z_ x 6300 „ 1■■■.l�ll■t■..No TIPIK OP ..■...�I 6400'' No 1■�.■.�i�i.■.■.�..®■i TDa 1110000 21/IH 21.AL 6500 6600 ItIS ■t■ ►��.�. 6 a 6700 .� 1111 - n - Ala. I Sm 45 dl 6600 En 45 dl Sian dis IH-21/IH41 6900 1 4.21111-21A A 7000 Sea L 8 0 0 0 $ o 0 8 $ 8 0 $ 8 0 0 $ g 8 0 0 8 0 8 0 8 0 8 8 0 o e R West( -)/East(+) (300 usft/in) 6000 6100 H r �II I IN 21/IH 21A ++ 6 6 6200 z_ x 6300 TIPIK OP 6400'' Janne TDa 1110000 21/IH 21.AL 6500 6600 6 a 6700 5 - n - Ala. I Sm 45 dl 6600 En 45 dl Sian dis IH-21/IH41 6900 1 4.21111-21A A 7000 Sea L 8 0 0 0 $ o 0 8 $ 8 0 $ 8 0 0 $ g 8 0 0 8 0 8 0 8 0 8 8 0 o e R Vertical Section at 90.001 (100 usft/in) ConocoPhillips ConocoPhillips (Alaska) Inc. -Kupl Kuparuk River Unit Kuparuk 1H Pad 1 H-21 1H-21AL2 Plan: 1 H-21AL2_wp02 Standard Planning Report 25 June, 2018 BT�a GHES GE company ConocoPhillips BA, j(ER COnOCOPhllllp5 Planning Report �jUGHES a GErompany Database: EDT Alaska Sandbox Company: ConowPhillips (Alaska) Inc. -Kupl Project: Kuparuk River Unit Site: Kuparuk 1H Pad Well: IH -21 Wellbore: 1 H-21AL2 Design: 1H-21AL2_WP02 Local Coordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Well 1 H-21 Mean Sea Level 1 H-21 @ 96.00usft (1 H-21) True Minimum Curvature Project Kuparuk River Unit, North Slope Alaska, United States Map System: US State Plane 1927 (Exact solution) System Datum: Mean Sea Level Geo Datum: NAD 1927 (NADCON CONUS) Using Well Reference Point Map Zone: Alaska Zone 04 Using geodetic scale factor Site Kuparuk 1 H Pad Site Position: Northing: 5,979,968.84 usft Latitude: 700 21'21.831 N From: Map Easting: 549,197.16 usft Longitude: 149° 36'1.675 W Position Uncertainty: 0.00 usft Slot Radius: 0.000 in Grid Convergence: 0.38 ° Well 1H-21 Well Position +N/S 0.00 usft Northing: 5,980,024.57 usft ° Latitude: 70° 21'22.356 N +E/ -W 0.00 usft Easting: 549,555.22 usft • Longitude: 149" 35'51.196 W Position Uncertainty 0.00 usft Wellhead Elevation: usft Ground Level: 54.40 usft Wellbore 1H-21 AL2 -� Magnetics Model Name Sample Date Declination Dip Angle Field Strength (nT) BGGM2018 9/(/2018 17.01 80 91 57.446 p Design 1H-21AL2 w02 Audit Notes: Version: Phase: PLAN Tie On Depth: 7,925 00 Vertical Section: Depth From (TVD) +N/ -S +E/ -W Direction (usft) (usft) (usft) (1 -54.40 0.00 0.00 90.00 J an Sections Measured TVD Below Dogleg Build Turn Depth Inclination Azimuth System +N/ -S +E/ -W Rate Rate Rate TFO (usft) (°) (°) (usft) (usft) (usft) (-1100ft) (-1100ft) (°1100ft) V) 7,925.00 78.42 88.94 6,535.91 -108.86 3,787.60 0.00 0.00 0.00 0.00 8,023.00 34.32 88.94 6,588.85 -107.39 3,867.19 45.00 -45.00 0.00 180.00 8,146.73 90.00 88.94 6,644.39 -105.45 3,972.33 45.00 45.00 0.00 0.00 8,300.00 90.00 78.21 6,644.39 -88.32 4,124.41 7.00 0.00 -7.00 270.00 8,600.00 103.32 94.60 6,609.45 -69.16 4,420.06 7.00 4.44 5.46 50.00 8,800.00 93.27 104.46 6,580.56 -102.06 4,614.70 7.00 -5.02 4.93 135.00 9,200.00 92.89 76.42 6,558.64 -105.11 5,010.11 7.00 -0.10 -7.01 270.00 9,400.00 90.87 90.29 6,552.05 -82.05 5,208.17 7.00 -1.01 6.93 98.00 9,800.00 93.12 62.36 6,537.84 11.47 5,592.74 7.00 0.56 -6.98 275.00 10,200.00 90.41 90.24 6,525.28 105.14 5,977.33 7.00 -0.68 6.97 95.00 10,600.00 90.36 62.24 6,522.53 199.32 6,361.99 7.00 -0.01 -7.00 270.00 11,100.00 96.01 96.85 6,493.86 288.89 6,845.18 7.00 1.13 6.92 80.00 Target 6/252018 4:09:481"M Page 2 COMPASS 5000.14 Build 85 ConocoPhillips ConocoPhillips Planning Report Br a GEcompar y Database: EDT Alaska Sandbox Local Co-ordinate Reference: Well 1H-21 Company: ConocoPhillips (Alaska) Inc. -Kupl TVD Reference: Mean Sea Level Project: Kupamk River Unit MD Reference: 1H-21@ 96.00usft(I H-21) Site: Kuparuk 1H Pad North Reference: True Well: 1 H-21 Survey Calculation Method: Minimum Curvature Wellbore: 1 H-21AL2 Map Map Design: 11-i-21AL2_Wp02 System -NIS Planned Survey Measured TVD Below Vertical Dogleg Toolface Map Map Depth Inclination Azimuth System -NIS -E/-W Section Rate Azimuth Northing Easting (usft) (e) V) (usft) (usft) (usft) (usft) (°HOOft) (•) (usft) (usft) 7,925.00 78.42 88.94 6,535.91 -108.86 3,787.60 3,787.60 0.00 0.00 5,979,940.77 553,343.09 TIPIKOP 8,000.00 44.67 88.94 6,571.13 -107.66 3,852.58 3,852.58 45.00 -180.00 5,979,942.41 553,408.05 8,023.00 34.32 88.94 6,588.85 -107.39 3,867.19 3,867.19 45.00 -180.00 5,979,942.77 553,422.66 Start 46 dls 8,100.00 68.97 88.94 6,635.91 -106.29 3,926.64 3,926.64 45.00 0.00 5,979,944.27 553,482.10 8,146.73 90.00 88.94 6,644.39 -105.45 3,972.33 3,972.33 45.00 0.00 5,979,945.41 553,527.77 End 45 dls, Start 7 dis 8,200.00 90.00 85.21 6,644.39 -102.73 4,025.51 4,025.51 7.00 -90.00 5,979,948.48 553,580.93 8,300.00 90.00 78.21 6,644.39 -88.32 4,124.41 4,124.41 7.00 -90.00 5,979,963.54 553,679.72 4 8,400.00 94.49 83.58 6,640.47 -72.52 4,223.01 4,223.01 7.00 50.00 5,979,980.00 553,778.21 8,500.00 98.95 89.02 6,628.76 -66.10 4,322.05 4,322.05 7.00 50.21 5,979,987.07 553,877.19 8,600.00 103.32 94.60 6,609.45 -69.16 4,420.06 4,420.06 7.00 50.85 5,979,984.66 553,975.21 5 8,700.00 98.32 99.59 6,590.67 -81.32 4,517.46 4,517.46 7.00 135.00 5,979,973.14 554,072.68 8,800.00 93.27 104.46 6,580.56 A02.06 4,614.70 4,614.70 7.00 135.94 5,979,953.05 554,170.05 6 8,900.00 93.25 97.45 6,574.87 -121.02 4,712.65 4,712.65 7.00 -90.00 5,979,934.73 554,268.11 9,000.00 93.17 90.44 6,569.27 -127.89 4,812.20 4,812.20 7.00 -90.40 5,979,928.52 554,367.69 9,100.00 93.05 83.43 6,563.83 -122.56 4,911.85 4,911.85 7.00 -90.79 5,979,934.52 554,467.29 9,200.00 92.89 76.42 6,558.64 -105.11 5,010.11 5,010.11 7.00 -91.17 5,979,952.62 554,565.43 7 9,300.00 91.89 83.36 6,554.46 -87.58 5,108.41 5,108.41 7.00 98.00 5,979,970.79 554,663.60 9,400.00 90.87 90.29 6,552.05 -82.05 5,208.17 5,208.17 7.00 98.29 5,979,976.98 554,763.31 8 9,500.00 91.48 83.31 6,549.99 -76.47 5,307.93 5,307.93 7.00 -85.00 5,979,983.22 554,863.02 9,600.00 92.06 76.33 6,546.91 -58.82 5,406.25 5,406.25 7.00 -85.14 5,980,001.52 554,961.21 9,700.00 92.61 69.35 6,542.84 -29.36 5,501.66 5,501.66 7.00 -85.36 5,980,031.60 555,056.42 9,800.00 93.12 62.36 6,537.84 11.47 5,592.74 5,592.74 7.00 -85.64 5,980,073.03 555,147.22 9 9,900.00 92.49 69.34 6,532.94 52.31 5,683.82 5,683.82 7.00 95.00 5,980,114.47 555,238.01 10,000.00 91.82 76.31 6,529.19 81.80 5,779.23 5,779.23 7.00 95.34 5,980,144.58 555,333.22 10,100.00 91.12 83.28 6,526.62 99.50 5,877.56 5,877.56 7.00 95.60 5,980,162.93 555,431.42 10,200.00 90.41 90.24 6,525.28 105.14 5,977.33 5,977.33 7.00 95.78 5,980,169.24 555,531.14 10 10,300.00 90.41 83.24 6,524.57 110.82 6,077.10 6,077.10 7.00 -90.00 5,980,175.57 555,630.86 10,400.00 90.40 76.24 6,523.86 128.61 6,175.44 6,175.44 7.00 -90.05 5,980,194.02 555,729.07 10,500.00 90.38 69.24 6,523.18 158.26 6,270.87 6,270.87 7.00 -90.10 5,980,224.29 555,824.30 10,600.00 90.36 62.24 6,522.53 199.32 6,361.99 6,361.99 7.00 -90.15 5,980,265.95 555,915.13 11 10,700.00 91.57 69.14 6,520.84 240.45 6,453.05 6,453.05 7.00 80.00 5,980,307.68 556,005.91 10,800.00 92.76 76.04 6,517.06 270.34 6,548.34 6,548.34 7.00 80.12 5,980,338.19 556,100.99 10,900.00 93.91 82.96 6,511.24 288.52 6,646.44 6,646.44 7.00 80.38 5,980,357.02 556,198.96 11,000.00 95.00 89.89 6,503.47 294.74 6,745.88 6,745.88 7.00 80.78 5,980,363.89 556,298.34 11,100.00 96.01 96.85 6,493.86 288.89 6,845.18 6,845.18 7.00 81.32 5,980,358.70 556,397.68 Planned TD at 11100.00 6/252018 4:09:48PM Page 3 COMPASS 5000.14 Build 85 ConocoPhillips BA�(ER ConocoPhillips Planning Report UGHES a GEmmpary, Database: EDT Alaska Sandbox Local Co-ordinate Reference: Well 1H-21 Company: ConocoPhillips (Alaska) Inc. -Kupi TVD Reference: Mean Sea Level Project: Kupawk River Unit MD Reference: 1H-21 ® 96.00usft (1 H-21) Site: Kuparuk 1H Pad North Reference: True Well: 1H-21 Survey Calculation Method: Minimum Curvature Wellbore: 1H-21AL2 (usft) latitude Longitude Design: 1H-21AL2_wp02 -7,581.621,146,569.17 5,980,028.00 Targets 0.00 0.00 0.00 -7,722.411,143,812.92 5,979,869.00 1,693,283.00 70° 5' 54.714 N 140° 23'41.999 W - plan misses target center by 1137014.50usft at 11100.00usft MD (6493.86 TVD, 288.89 IN, 6845.18 E) Target Name - Polygon - hitlmes target Dip Angle Dip Dir. TVD +N/ -S +E/ -W Northing Easting Point -Shape (°) (I (usft) (usft) (usft) (usft) (usft) latitude Longitude 11-1-21AL2_T08 0.00 0.00 6,517.00 -7,581.621,146,569.17 5,980,028.00 1,696,038.00 70° 5'52.000 N 140° 22'22.853 W - plan misses target center by 1139751.17usft at 11100.00usft MD (6493.86 TVD, 288.89 N, 6845.18 E) Points 0.00 - Point 5,979,143.07 1,694,728.03 Point 0.00 -321.02 -2.11 1H-21AL2_T09 0.00 0.00 6,488.00 -7,503.521,147,008.74 5,980,109.00 1,696,477.00 70°5'52.106N 140'22'9.989W - plan misses target center by 1140190.19usft at 11100.00usft MD (6493.86 TVD, 288.89 N, 6845.18 E) 0.00 0.00 6,546.00 -7,804.241,145,599.59 - Point 1,695,070.00 70° 5'51.276 N 140° 22'51.447 W - plan misses target center by 1138783.16usft at 11100.00usft MD (6493.86 TVD, 288.89 N, 6845.18 E) - Point 1H-21AL2_T03 0.00 0.00 6,632.00 -7,887.471,144,423.90 5,979,708.00 11693,895.00 70° 5'52.208 N 140° 23'25.307 W - plan misses target center by 1137608.10usft at 11100.00usft MD (6493.86 TVD, 288.89 N. 6845.18 E) - Point 1H-21AL2_T05 0.00 0.00 6,552.00 -7,900.691,145,212.90 5,979,700.00 1,694,684.00 70° 5' 50.912 N 140° 23'2.883 W - plan misses target center by 1138397.18usft at 11100.00usft MD (6493.86 TVD, 288.89 N, 6845.18 E) - Point 1 H-21 CTD Polygon Nor 0.00 0.00 0.00 -7,723.091,143,764.91 5,979,868.00 1,693,235.00 70° 5'54.778 N 140° 23'43.370 W - plan misses target center by 1136966.50usft at 11100.00usft MD (6493.86 TVD, 288.89 N, 6845.18 E) - Polygon Point 1 0.00 0.00 0.00 5,979,868.00 1,693,235.00 Point 2 0.00 9.13 132.08 5,979,878.00 1,693,367.00 Point 0.00 272.48 84.80 5,980,141.01 1,693,317.99 Point 0.00 1,101.34 -31.78 5,980,969.00 1,693,195.94 Points 0.00 2,179.05 -272.73 5,982,044.99 1,692,947.89 Point 0.00 3,319.39 304.25 5,983,184.98 1,692,908.83 Point 0.00 3,223.79 90.17 5,983,092.00 1,693,303.84 Point 0.00 1,937.50 110.73 5,981,806.00 1,693,332.90 Point 0.00 811.57 385.37 5,980,682.02 1,693,614.96 Point 10 0.00 -70.95 447.59 5,979,800.02 1,693,683.01 Point 11 0.00 -231.58 388.53 5,979,639.02 1,693,625.02 Point 12 0.00 -332.56 231.84 5,979,537.01 1,693,469.01 Point 13 0.00 -325.97 -11.14 5,979,542.00 1,693,226.02 Point 14 0.00 0.00 0.00 5,979,868.00 1,693,235.00 1 H-21AL2_T07 0.00 0.00 6,524.00 -7,687.421,146,083.42 5,979,919.00 1,695,553.00 70° 5'51.693 N 140° 22'37.153 W - plan misses target center by 1139266.16usft at 11100.00usft MD (6493.86 TVD, 288.89 N, 6845.18 E) - Point 1 H-21AL2_TD7 0.00 0.00 6,645.00 -7,896.751,144,012.79 5,979,696.00 1,693,484.00 70' 5'52.726 N 140° 23'37.061 W - plan misses target center by 1137197.07usft at 11100.00usft MD (6493.86 TVD, 288.89 N, 6845.18 E) - Point 1H-21AL2_T04 0.00 0.00 6,582.00 -7,931.411,144,716.64 5,979,666.00 1,694,188.00 70° 5' 51.348 N 140° 23' 17.157 W - plan misses target center by 1137901.15usft at 11100.00usft MD (6493.86 TVD, 288.89 N, 6845.18 E) - Point 1 H-21 CTD Polygon Ea: 0.00 0.00 0.00 -7,722.411,143,812.92 5,979,869.00 1,693,283.00 70° 5' 54.714 N 140° 23'41.999 W - plan misses target center by 1137014.50usft at 11100.00usft MD (6493.86 TVD, 288.89 IN, 6845.18 E) - Polygon Point 1 0.00 0.00 0.00 5,979,869.00 1 693,283.00 Point 0.00 25.79 1,403.34 5,979,904.07 1,694,686.00 Point 0.00 397.55 3,275.00 5,980,288.17 1,696,554.98 Point 0.00 -885.89 3,166.56 5,979,004.16 1,696,455.04 Points 0.00 -735.54 1,440.34 5,979,143.07 1,694,728.03 Point 0.00 -321.02 -2.11 5,979,548.00 1,693,283.01 Point 0.00 0.00 0.00 5,979,869.00 1,693,283.00 1H-21AL2_TO6 0.00 0.00 6,546.00 -7,804.241,145,599.59 5,979,799.00 1,695,070.00 70° 5'51.276 N 140° 22'51.447 W - plan misses target center by 1138783.16usft at 11100.00usft MD (6493.86 TVD, 288.89 N, 6845.18 E) - Point 1H-21 AL2_T02 0.00 0.00 6,644.00 -7,875.161,144,225.95 5,979,719.00 1,693,697.00 70'5'52.620N 140°23'30.893W 825/2018 4:09:48PM Page 4 COMPASS 5000.14 Build 85 10-1 ConocoPhillips (usft) BAKER Comment ConocoPhillips Planning Report -108.86 HUGHES TIP/KOP 8,023.00 6,588.85 -107.39 aGEcompany Database: EDT Alaska Sandbox Local Coordinate Reference: Well 11-1-21 -105.45 Company: ConocoPhillips (Alaska) Inc. -Kupl TVD Reference: Mean Sea Level 6,644.39 Project: Kupawk River Unit MD Reference: 1H-21@96.00usft(1 H-21) Site: Kupamk 1H Pad North Reference: True 5 Well: 1 H-21 Survey Calculation Method: Minimum Curvature 4,614.70 Wellbore: 1 H-21 AL2 9,200.00 6,558.64 -105.11 Design: 1H-21AL2_wp02 7 9,400.00 6,552.05 - Point - -- 8 9,800.00 Casing Points 11.47 5,592.74 9 Measured Vertical 6,525.28 Casing Hale Depth Depth 10,600.00 Diameter Diameter (usft) (usft) Name (in) (in) 11,100.00 6,493.86 2 3/8" 6,845.18 2.375 3.000 Plan Annotations Measured Vertical Local Coordinates Depth Depth +N/S +E/ -W (usft) (usft) 625/2018 4:09:48PM Page 5 COMPASS 5000.14 Build 85 (usft) (usft) Comment 7,925.00 6,535.91 -108.86 3,78T60 TIP/KOP 8,023.00 6,588.85 -107.39 3,867.19 Start 45 dis 8,146.73 6,644.39 -105.45 3,972.33 End 45 dls, Start 7 dls 8,300.00 6,644.39 -88.32 4,124.41 4 8,600.00 6,609.45 -69.16 4,420.06 5 8,800.00 6,580.56 -102.06 4,614.70 6 9,200.00 6,558.64 -105.11 5,010.11 7 9,400.00 6,552.05 -82.05 5,208.17 8 9,800.00 6,537.84 11.47 5,592.74 9 10,200.00 6,525.28 105.14 5,977.33 10 10,600.00 6,522.53 199.32 6,361.99 11 11,100.00 6,493.86 288.89 6,845.18 Planned TD at 11100.00 625/2018 4:09:48PM Page 5 COMPASS 5000.14 Build 85 ConocoPhillips BA ER ConocoPhillips Travelling Cylinder Report I I IGHES aGErompany Company: ConocoPhillips (Alaska) Inc. -Kupl Project: Kuparuk River Unit Reference Site: Kuparuk 1 H Pad Site Error: 0.00 usft Reference Well: 1H-21 Well Error: 0.00 usft Reference Wellbore 1H-21AL2 Reference Design: 1 H-21AL2_wp02 Local Coordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Output emors are at Database: Offset TVD Reference: Well 1 H-21 1 H-21 96.00usft (1 H-21) 1H-21 (aj 96.00usft (1H-21) True Minimum Curvature 1.00 sigma EDT Alaska Prod Offset Datum Reference 1H-21 AL2 wp02 Filter type: GLOBAL FILTER APPLIED: All wellpaths within 200'+ 100/1000 of reference To Interpolation Method: MD Interval 25.00usft Error Model: ISCWSA Depth Range: 7,925.00 to 11,100.00usft Scan Method: Tray. Cylinder North Results Limited by: Maximum center -center distance of 1,305.84 usft Error Surface: Pedal Curve Survey Tool Program Date 6/25/2018 Depth From To (usft) (usft) (usft) (usft) Survey (Wellbore) Tool Name Description 102.20 7,807,301H-21 Srvy 1-SLB_GCT-MS(1 H-21) GCT -MS Schlumberger GCT multishot 7,807.30 7,925.00 1H-21 A_wp03(1 H -21A) MWD MWD -Standard 7,925.00 11,100.00 1H-21 AL2_wp02(1 H-21AL2) MWD MWD - Standard Casing Points Measured Vertical Depth Depth (usft) (usft) Reference 121.00 121.00 16" 4820.00 4,246.83 95/8' 11,100.00 6,589.86 23/8" Name Casing Hole Diameter Diameter 16 24 9-5/8 12-114 2-3/8 Summary Reference Offset Centre to No -Go Allowable Measured Measured Centre Distance Deviation Warning Site Name Depth Depth Distance (usft) from Plan Offset Well - Wellbore - Design (usft) (usft) (usft) (usft) Kuparuk 1 H Pad 1 H-05 -1 H-05 - 1 H-05 Out of range 1 H-05 - 1 H-105 - 1 H-105 Out of range 1 H-09 - 1 H-09 - 1 H-09 Out of range 1 H-102 - 1 H-102 - 1 H-102 Out of range 1 H-102 - 1 H-1021-1 - 1 H-1021-1 Out of range 1 H-102 - 1 H-10212 -1 H-1021-2 Out of range 1 H-102 - 1 H-1021-3 - 1 H-1021-3 Out of range 1 H-102 - 1 H-10214 - 1 H-1021-4 Out of range 1 H-11 - 1 H-11 - 1 H-11 Out of range 1 H-12 - 1 H-12 - 1 H-12 Out of range 1 H-13 - 1 H-13 - 1 H-13 10,571.72 9,450.00 980.87 356.45 641.38 Pass - Major Risk 1 H-15 - 1 H-15 - 1 H-15 Out of range 1 H-18 - 1 H-18 - 1 H-18 Out of range 1H -21 -1H -21-1H-21 8,110.00 8,150.00 101.44 12.19 89.98 Pass - Major Risk 1H-21-1H-21A-1H-21A_wp03 7,925.00 7,925.00 0.10 0.29 -0.13 FAIL - Minor 1/10 1H -21-1H-21 AL1 -1H-21 AL7_wp02 7,925.00 7,925.00 0.10 0.29 -0.13 FAIL -Minor 1/10 1H -21-1H-21 AL2 -01-1H-21 AL2-01_wp02 8,715.11 8,725.00 79.85 1.34 79.06 Pass - Minor 1/10 Rig: 1 H-108 - 1 H-1 08A - 1 H-1 08A wp01 Out of range CC - Min centre to center distance or covergent point, SF - min separation factor, ES - min ellipse separation 8/252018 10:04:02AM Page 2 COMPASS 5000.14 Build 85 j ConocoPhillips BA�IER ConocoPhillips Travelling Cylinder Report IGHES aGEmmpany Company: ConocoPhillips (Alaska) Inc.-Kupl Local Co-ordinate Reference: Well 1H-21 Project: Kupamk River Unit TVD Reference: 1H-21@96.00usft(1H-21) Reference Site: Kuparuk 1H Pad MD Reference: 1H-21 @ 96.00usft (1H-21) Site Error: 0.00 usft North Reference: True Reference Well: 1 H-21 Survey Calculation Method: Minimum Curvature Well Error: 0.00 usft Output errors are at 1.00 sigma Reference Wellbore 1H-21 AL2 Database: EDT Alaska Prod Reference Design: 1 H-21 AL2_wp02 Offset TVD Reference: Offset Datum Offset Design KuparuklHPad- 1H -13 -1H -13-1H-13 Most Sita snot ow.oft Survey Pros.: 97 -GCT -MS Role Asingrai: Major Risk Most Wall Error: 0.00 usa Ref.ronc. Was, Semi M,.r Aart Monter vertical Measured vertical Reference afset TooRii,s Offset Wellbore Centre Casing- cer. to No Go Allowable blaming Depth one, Dolan ospth Azimuth AWS ♦PFW Hot. Size C.M. Oiatance DeWMlon Joan) (usft) (.am loft) lash) (oaftl (9 (use) loan) ("1 (usft) (UM) (-it) 9,762.47 6,6635.82 8,275.00 5,454.92 51.36 52.33 89.22 -513.21 5,729.55 5 1,296]9 312.85 1061.26 Pass - Major Risk 9.113.55 6,835.25 8,300.00 5.46943 51A5 52.52 89.08 -514.19 5,749.89 5 1,286.77 312.55 1,055.06 Pas. - Major Risk 9,184.42 6,634.61 8,325.00 5,48,1.01 51.54 52.70 88.97 -515.13 5,110.17 5 1,218.92 312.43 1,043.00 Pass - Major Risk 9,800.00 6,633.84 8,350.00 5498.01 51.67 52.89 88.53 -516.06 5.7 0.0 5 1,261.26 312.01 1031.13 Pass - Major Risk 9.820.59 6632.14 8.315.00 5.513.42 51.83 53.08 90.78 -516.99 5,810.55 5 1,257.72 314.64 1,019.25 Pass - Major Risk 9,861.27 6,630.11 8,40000 5,528.28 52.17 53.26 94.46 -517.09 6830.65 5 1.248.01 319.16 1,001,50 Pass - Major Risk 9,904,33 6,628.76 8,42500 5.543.22 52.53 53.45 Gem -518.76 5,850.61 5 1.23804 323.57 995.63 Pass - Major Risk 9.949.72 6.626.93 B.460.00 5.558.25 52.94 53.63 102.23 -519.60 5,870,63 5 1,22136 327.T1 983.64 Pass -Major Risk 9,991.31 6,625.21 8,415.00 5,573.39 53.39 53.82 106.27 -520.40 5,890.51 5 1,211.09 331.74 971.49 Pass -Major Risk 10,046,92 6,623,83 8.500.00 5.588.61 5388 54.00 110.41 -521.18 5,910.33 5 1,206.00 336.14 959.22 Pan - Major Risk 10,098.58 6.622.65 8.525.00 5.601.11 54.41 54.19 11463 -622 l 5,930.19 5 1,194.61 339.99 97.00 Pass - Major Risk 10,152.28 6,621.76 8,550.00 5,618,13 54.98 54.37 118.93 -522.94 5.950.20 5 11183.00 343,16 934.99 Pass - Major Risk 10,200.00 6.621.28 8,575.00 5,633,57 55.50 54,55 1n.74 -523.95 5,970.29 5 1,111.06 345.35 92267 Pass - Major Risk 10.212.85 6.621.19 0.60000 5,648.35 55.65 54.15 122.28 -525,03 5.990.43 5 1,159.14 346.32 908.39 Pass - Major Risk 10,224.20 6521.11 8,625,00 6082.91 55.11 54.93 121.94 -52624 6,010.67 5 1,147.64 341.18 89438 Pass - Major Risk 10.235.62 6,621.03 8.650.00 5,611,36 55.90 55.12 121.63 -527.58 8031.07 5 1,136.64 348.01 88082 Pass -Major Risk 10,25000 6.620.92 8,615.00 5,691.60 56.% 55.31 121,12 -529.00 6.051,56 5 1,126.01 348.87 M7.78 Pass - Major Risk 10,258.49 6,620.86 8700.00 5,105.14 56.15 55.50 121.05 -530.45 6,072.13 5 1.115,84 349,55 854.18 Pass - Major Risk 10,269.93 6.620,18 8.72500 5.719.72 56.28 55.69 12039 -531.98 8092.80 5 1,106.04 35025 842.26 Pass - Major Risk 10,281.31 8620.10 8]50.00 5,133.58 56.41 55.88 120.55 -533.53 8.113.55 5 1,096.85 350.92 830.14 Pass - Major Risk 10,300,00 8,620,57 8,115,00 5747.40 56.61 56.07 119.83 -535.11 6,134.32 5 1.087.62 351.60 818.61 Pass - Major Risk 10300.00 6.620.57 8.800,00 5.761.15 seal 56.27 120.44 -536.63 6,155.15 5 1,018.84 352.08 808.63 Pan - Major Risk 10,315.48 6,620,46 8.82500 5,774.80 5879 5646 119.97 -538.10 6,176.04 5 1,070.41 352.64 795.53 Pass -Major Risk 10328.18 6,620,38 8,850,00 5,198.43 56.91 56.65 119.82 339.54 6.196.95 5 1,062.30 353.14 184.59 Pass - Major Risk 10,338.01 6,620,30 8,875,00 5.802.05 51,04 56.84 119.69 -540.94 6,211.85 5 1,054.49 353.58 773.93 Pan - Major Risk 10.350.00 6.620.21 8.900.00 5.815.55 51.11 57.03 119.52 -542,29 6,238.88 5 1,07.07 353.98 763.68 Pass -Major Risk 10,380.40 8,820.14 8925.00 5.828.91 57.29 57.23 119.49 -543.68 6.259,95 5 1.040.12 356.35 153.85 Pan - Major Risk 16371+49 6,620,06 9,950,00 5.842.26 57A1 5]42 119.43 -545.14 6,281.03 5 1,033.57 356.61 744.2 Pan -Major Risk 10,382.47 6619.99 8,975.00 5.855.66 51,53 57.61 119.40 -548,64 6,30209 5 1,027.35 354.95 735.32 Pass - Major Risk 10,400.00 6,619.86 9,000.00 5,869.12 57.72 57.81 118.93 -548.13 6.323.10 5 1021A1 355.02 726.57 Pass - Major Risk 10,400A0 6.619.88 9,025,00 5.882.65 57.72 58.00 119.72 -549.62 6,364.01 5 1,015.83 355.50 718.03 Pau - Major Risk 10,414.76 6.619.76 9.050.00 5.896.26 57,88 5819 119,48 -551AW 6,386.99 5 1,010.50 355.55 709.82 Pass - Major Risk 10425.31 6,619.69 9075.00 5,90990 58.00 58.39 119.57 -552,49 6,355,88 5 1005.51 356.61 701.98 Pass - Major Risk 10,435.76 8,619.62 9,100.00 5,923.62 58.11 58.58 119.68 -553.86 8406.15 5 1,000.81 355.88 694A6 Pan - Major Risk 10,450.00 8619.52 9.125.00 5.93243 58.27 58,17 119.54 -555,20 6,421.55 5 996.44 356.01 687.22 Paas -Major Risk 10,450.00 8619.52 9.150,00 5,951.28 58.27 58.97 120.42 -556.53 6,448.32 5 992.45 356.49 680.68 Pass - Major Risk 10,666.43 6,619.41 9,175.00 5,965,03 58.44 59.16 120.16 -557.08 8469.15 5 958.90 35648 814.28 Pass -Major Risk 10,476.51 8619.34 9.200.00 5.978.134 58.55 59,35 120.36 -559,23 6.490.03 5 985.94 356.62 668.87 Pass - Major Risk 10,406.50 8619.27 9,225.00 5,992.21 58.66 59.55 120.51 -560,61 6,511.03 5 983.66 35672 663.60 Pass -Major Risk 10,500.00 6,619,18 9,250.00 6,005.79 58.80 59.74 120.55 -561.97 6153198 5 981+41 358.85 858.81 Pass - Major Risk 10.500.00 8819.18 9,275.00 6,019,30 58.80 59.94 121.49 -563.33 6.552.91 5 919.86 357.12 655,30 Paas -Major Risk 10.515,90 8619.08 9,30000 6032.75 58.97 60.13 12133 -564.69 6,574.00 5 97875 356.86 651.55 Pass - Major Risk 10.525.50 6,619.01 9,325.00 6,045.21 59.07 60.33 12161 -566.04 6,595.02 5 978.11 350.85 648.63 Pass - Major Risk 10.534.98 6,610.95 9360.00 6,05972 59.17 60.52 121.91 -567.30 6.616.01 5 977,88 35682 646,21 Pass - Major Risk, CC 10,550.00 6,610.85 9.375.00 6,073.26 59.32 60.72 121.83 -%072 6,6313.99 5 978.12 356.43 643.98 Pass - Major Risk 10.550.00 6,610.85 9,400.00 6,086.81 59.32 60.91 122.82 -56981 6,657.92 5 918.85 356.89 643.10 Pass - Major Risk 10.56271 6,818.77 9425.00 6,100.57 59.45 61.10 122.91 -571.10 6,678.80 5 979,55 356,57 641.88 Pass - Major Risk 10,571.72 6,810.71 9.450.00 8.114.31 59.54 61.30 123.28 -572.35 6,699.65 5 980,87 356.45 641.38 Pass- Major Risk, ES, SF UQ - min centre to center olsmilce or covergent point, 5r - min separation razor, is - min enlpse Separation 625/2018 10:04:02AM Page 3 COMPASS 5000.14 Build 85 ConocoPhillips ConocoPhillips Travelling Cylinder Repot UGHES aGEmmpany Company: Project: Reference Site: Site Error: Reference Well: Well Error: Reference Wellbore Reference Design: ConocoPhillips (Alaska) Inc.-Kupl Kuparuk River Unit Kuparuk 1H Pad 0.00 usft 1H-21 0.00 usft 1H-21AL2 1H-21 AL2_Wp02 Local Coordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Output errors are at Database: Offset TVD Reference: Well 1 H-21 1H-21 96.00usft(1 H-21) 1H-21 Q 96,00usft (1H-21) True Minimum Curvature 1.00 sigma EDT Alaska Prod Offset Datum Dffset Design KupamklHPad- 1H -13 -1H -13-1H-13 Orhar site Eno,. 000 us survey Program: 9AOCT-Me Rub Assigned: Major Risk West Well Erten: 0.00.1. authoress. OIMN eaml Major Axis Measured Vertical Measured Wausau Reference Meer roanece♦ Oreet Wellbore Cemre casing- carries to No Go AlloxaMa VHm1ng Depth Depth Depth Depth Aeintuth -1i *VM Rob etre Centro aside.. Devbtlon war) jus") Just) just) just) (ust) (1) just) jean) r) (dam (ua"j jean) 1058063 6,518.65 947500 6,12607 59.63 61.49 123.65 -57346 6,720,49 5 98259 35630 841.42 Pass - Major Risk CC - Min centre to center distance or covergent point, SF - min separation factor, ES - min ellipse separation 8252018 10:04:02AM Page 4 COMPASS 5000.14 Build 85 TRANSMITTAL LETTER CHECKLIST WELL NAME: � — ZI�G 2— / PTD: Zl`s� G 7 2 / Development Service _ Exploratory _ Stratigraphic Test _ Non -Conventional FIELD: POOL: /`LA� ezjA- Check Box for Appropriate Letter / Paragraphs to be Included in Transmittal Letter CHECK OPTIONS TEXT FOR APPROVAL LETTER MULTI The permit is for a new wellbore segment of existing well Permit / LATERAL No. 7-IYj b%%, API No. 50-02 -Z2 -65/- !P6. Y/ (If last two digits Production should continue to be reported as a function of the original in API number are API number stated above. between 60-69 In accordance with 20 AAC 25.005(f), all records, data and logs acquired for the pilot hole must be clearly differentiated in both well Pilot Hole name ( PH) and API number (50— from from records, data and logs acquired for well name on permit). The permit is approved subject to full compliance with 20 AAC 25.055. Approval to produce/inject is contingent upon issuance of a conservation Spacing Exception order approving a spacing exception. (Company -Name) Operator assumes the liability of any protest to the spacing exception that may occur. All dry ditch sample sets submitted to the AOGCC must be in no greater Dry Ditch Sample than 30' sample intervals from below the permafrost or from where samples are first caught and 10' sample intervals through target zones. Please note the following special condition of this permit: production or production testing of coal bed methane is not allowed for Non -Conventional (name of well) until after (Company Name) has designed and Well implemented a water well testing program to provide baseline data on water quality and quantity. (Company Name) must contact the AOGCC to obtain advance approval of such water well testing program. Regulation 20 AAC 25.071(a) authorizes the AOGCC to specify types of well logs to be run. In addition to the well logging program proposed by (Company Name) in the attached application, the following well logs are also required for this well: Well Logging Requirements t/ ✓ Per Statute AS 31.05.030(d)(2)(B) and Regulation 20 AAC 25.071, composite curves for well logs run must be submitted to the AOGCC within 90 days after completion, suspension or abandonment of this well. Revised 2/2015 WELL PERMIT CHECKLIST Field & Pool KUPARUK RIVER, KUPARUK RIV OIL -490100 _ Well Name KUPARUK RIV UNIT 1H-21AL2_ _ - Program DEV __. _ _ _ _— Well bore seg ❑� PTD# 2180790 Comoanv CONOCOPHILLIPS ALASKA INC. _ _ _. Initial Classrrype DEV / PEND_ GeoArea 890 — _._ _ _— Unit 11160 _. _. On/Off Shore On _ Annular Disposal ❑ Appr Date SFD 7/2/2018 Engineering Appr Date MGR 7/5/2018 17 1 2 3 4 5 6 7 8 I9 10 11 12 13 14 15 16 18 19 120 121 122 23 24 225 26 27 X28 29 30 31 32 33 34 35 Geology 136 Appr Date 37 SFD 7/2/2018 38 39 Nonconven. gas conforms to AS31.05,0300.1.A),0.2.A-D) _ _ NA Permit fee attached _ .. _ ...... NA. .. _ _ _ ......... _ Lease number appropriate _ _ _ _ _ _ _ _ _ _ Yes Surf Loc &.Top Prod Int lie in ADL0025639; TO lies in ADL0025638. Unique well name and number _ _ _ _ _ _ _ Yes Well located in a defined pool _ _ Yes KUPARUK RIVER,_ KUPARUK. RIV OIL.- 490100 _ Well located proper distance. from drilling unit _boundary Yes Kuparuk River Oil Pool, governed by Conservation Order No. 432D .... Well located proper distance from other wells..... Yes Conservation Order No. 432D has no interwell spacing. restrictions. Wellbore. will be. more than 500' .Sufficient acreage available in drilling unit........ _ Yes from an external property line where ownership or landownership changes. As proposed, "it will If deviated, is wellbore plat included _ _ _ _ _ _ _ _ _ _ Yes conform to. spacing_ requirements. Operator only affected party. - - - - - - Yes Operator has appropriate bond in force _ _ _ _______ _ _ _ _ _ _ Yes Permit can be issued without conservation order.. _ _ _ _ _ _ Yes Permit can be issued without administrative.approval _ ... _ _ _ _ Yes Can permit be approved before 15 -day wart_ _ _ _ _ _ _ .... _ _ Yes Well located within area and strata authorized by Injection Order # (put. 10# in. comments) (For NA All wells. within 1/4. mile area of review identified (For service well only) _ _ NA. _ .. .. Pre -produced injector: duration of preproduction less than 3 months (For service well only) NA. Conductor string. provided . . . . . . . . . ................. _ _ _ _ NA Thru tubing CTD Sidetrack from existing wellbore Surface casing. protects all known USDWs _ _ _ _ _ _ ..... .... _ _ _ NA Thru tubing CTD Sidetrack from existing wellbore CMT, vol adequate to circulate. on conductor _& surf csg . . . . ............ _ NA. _ _ _ Thru tubing CTD Sidetrack from existing wellbore CMT vol adequate to tie-in long string to.su f esg. _ _ _ _ _ _ _ _ _ _ _ ... _ NA. _ Thru tubing CTD Sidetrack from existing wellbore CMT will cover. all known, productive horizons_ - - - - - - - _ _ _ _ _ _ _ .. NA. Sidetrack and lateral all inzone, slotted liner completion Casing designs adequate for C, T, B 8. permafrost _ _ _ _ _ _ _ _ _ Yes Adequate tankage. or reserve pit _ _ _ _ _ _ ... _ _ _ _ Yes If.a re -drill, has, at 10-403 for abandonment been approved _ _ ... _ _ Yes Adequate wellbore separation. proposed . ...... . . . . . . . . . . . . . . . ..... . Yes Ifdiverter required, does it meet regulations_ ....... NA Drilling Fluid. program schematic & equip list adequate_ _ _ _ _ _ _ .. _ - - _ Yes BOPEs, do they meet regulation _ - - - - - - _ ........ _ Yes BOPE press rating appropriate; test to.(put psig in comments)_ _ _ _ _ _ _ _ _ _ Yes _ _ _ _ _ BOPE test to 3000 psi. _ Choke manifold complies w/API. RP -53 (May 84) . . . ......... . .. . . . . . . . . . Yes Work Will occur with operation shutdown . . . . . . . . . . . ................... . Yes Is presence of H2S gas probable _ ... _ _ _ _ _ _ _ _ _____ _ Yes Mechanical. condition of wells within AOR verified (For service well only) . . . . .......... NA Permit can be issued w/o hydrogen sulfide measures. - ---- - - - - - - - - - - - _ ...No... _ _ _ _ _ Wells on 1H -Pad are. H2S-bearing. H2$ measures required, Data. presented on potential overpressure zones . ........ . ... - _ _ _ _ _ _ _ . Yes ..... Expected reservoir pressure is -9.1 ppg EMW, with a maximum up to -10.0 ppg EMW, Seismic analysis of shallow gas zones . . . . . . ...................... . . . . . . NA_ _ _ _ ... Well will be drilled using.8.6 ppg.mud, a coiled -tubing rig, and managed pressure drilling_ Seabed condition survey.(if off -shore) . . . . . . .... . .... . . .... . . . . . . . . . ...NA........ technique to control formation pressures and stabilize shale_ sections. NOTE:. Chance of ..... - - - - Contaet name/phone for weekly. progress reports [exploratory only] .. I ... I .. _ _ _ _ _ NA_ _ _ .... encountering gas while drilling 1his.we)Ibore dueto gas_ injection performedin this area. . . . . . . ....... . I Geologic ' Engineering Public Date: Date Date Commissioner: Commissioner: Commissi ner