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HomeMy WebLinkAbout219-017DATA SUBMITTAL COMPLIANCE REPORT 6/10/2019 Permit to Drill 2190170 Well Name/No. KUPARUK RIV-UNIT 3M-261-1-01 f131 Operator CONOCOPHILLIPS ALASKA, INC. API No. 50-029-22431-61-00 0 MD 11395 TVD 6341 Completion Date 3/5/2019 Completion Status 1-0I1- Current Status 1-0I1 UIC No REQUIRED INFORMATION / / / Mud Log No v Samples No ✓ Directional Survey Yes �/ DATA INFORMATION List of Logs Obtained: GR/Res (from Master Well Data/Logs) Well Log Information: Logi Electr Data Digital Dataset Log Log Run Interval OHI Type Med/Frmt Number Name Scale Media No Start Stop CH Received Comments ED C 30540 Digital Data 9015 11395 4/3/2019 Electronic Data Set, Filename: 31M -26L1-01 GAMMA RES.Ias ED C 30540 Digital Data 4/3/2019 Electronic File: 3M-261-1-01 2MD Final Log.cgm ED C 30540 Digital Data 4/3/2019 Electronic File: 3M-261-1-01 51VID Final Log.cgm ED C 30540 Digital Data 4/3/2019 Electronic File: 310-261-1-01 5TVD Final Log.ogm ED C 30540 Digital Data 4/3/2019 Electronic File: 3M-261-1-01 2MD Final Log.pdf ED C 30540 Digital Data 4/3/2019 Electronic File: 3M-261-1-01 5MD Final Log.pdf ED C 30540 Digital Data 4/3/2019 Electronic File: 3M-261-1-01 5TVD Final Log.pdf ED C 30540 Digital Data 4/3/2019 Electronic File: 3M-261-1-01 EOW NAD27.pdf ED C 30540 Digital Data 4/3/2019 Electronic File: 3M-261-1-01 EOW NAD27.txt ED C 30540 Digital Data 4/3/2019 Electronic File: 3M-261-1-01 Final Surveys TD 11395.csv ED C 30540 Digital Data 4/3/2019 Electronic File: 3M-261-1-01 Final Surveys TD 11395.xlsx ED C 30540 Digital Data 4/3/2019 Electronic File: 3M-261-1-01 Survey Listing.bd ED C 30540 Digital Data 4/3/2019 Electronic File: 3M -26L1-01 Surveys.txt ED C 30540 Digital Data 4/3/2019 Electronic File: 3M -26L1- 01 _25_tapescan_BH I_CTK.txt ED C 30540 Digital Data 4/3/2019 Electronic File: 3M-261-1- 01 _5_tapescan_BH I_CTK.txt ED C 30540 Digital Data 4/3/2019 Electronic File: 3M-261-1-01_output.tap ED C 30540 Digital Data 4/3/2019 Electronic File: 3M-261-1-01 2MD Final Log.tif ED C 30540 Digital Data 4/3/2019 Electronic File: 3M-261-1-01 5MD Final Log.tif AOGCC Page I of Monday, June 10, 2019 DATA SUBMITTAL COMPLIANCE REPORT 6110/2019 Permit to Drill 2190170 Well Name/No. KUPARUK RIV UNIT 3M -26L1-01 Operator CONOCOPHILLIPS ALASKA, INC. API No. 50-029-22431-61-00 MD 11395 TVD 6341 Completion Date 3/5/2019 ED C 30540 Digital Data Log C 30540 Log Header Scans Log C ED C ED C ED C ED C ED C ED C ED C ED C ED C ED C ED C ED C ED C ED C ED C ED C ED C ED C 30541 Log Header Scans 30541 Digital Data 30541 Digital Data 30541 Digital Data 30541 Digital Data 30541 Digital Data 30541 Digital Data 30541 Digital Data 30541 Digital Data 30541 Digital Data 30541 Digital Data 30541 Digital Data 30541 Digital Data 30541 Digital Data 30541 Digital Data 30541 Digital Data 30541 Digital Data 30541 Digital Data 30541 Digital Data Completion Status 1-0I1- Current Status 1-0I1- UIC No 4/3/2019 Electronic File: 31VI-2611-01 5TVD Final Log.tif 0 0 2190170 KUPARUK RIV UNIT 3M-261-1-01 LOG HEADERS 0 0 2190170 KUPARUK RIV UNIT 3M-2611-01 PBI LOG HEADERS 9015 10577 4/3/2019 Electronic Data Set, Filename: 3M-261-1-01PB1 GAMMA RES.Ias 4/3/2019 Electronic File: 3M-261-1-01 PB1 2MD Final Log.cgm 4/3/2019 Electronic File: 3M -261-1-01P61 5MD Final Log.cgm 4/3/2019 Electronic File: 31M-261-1-01PI31 5TVDSS Final Log.cgm 4/3/2019 Electronic File: 3M-2611-01 PB1 2MD Final.pdf 4/3/2019 Electronic File: 31VI-261-1-01P61 51VID Final.pdf 4/3/2019 Electronic File: 3M-2611-01 PB15TVDSS Final.pdf 4/3/2019 Electronic File: 3M-2611-011081 EOW - NAD27.pdf 4/3/2019 Electronic File: 3M-261-1-01PI31 EOW - NAD27.txt 4/3/2019 Electronic File: 3M-261-1-01PI31 Final Surveys TD 10577.csv 4/3/2019 Electronic File: 3M-26L1-01PB1 Final Surveys TD 10577.xlsx 4/3/2019 Electronic File: 31Vl-26L1-01PB1 Survey Listing.txt 4/3/2019 Electronic File: 3M-2611-011381 Surveys.txt 4/3/2019 Electronic File: 3M-2611- 01 PB1_25_tapescan_BHI_CTK.txt 4/3/2019 Electronic File: 3M-2611- 01 PB1_5_tapescan_BHI_CTK.txt 4/3/2019 Electronic File: 3M-26L1-01PB1_output.tap 4/3/2019 Electronic File: 3M-261-1-01PB1 21VID Final Log.tif 4/3/2019 Electronic File: 3M-261-1-01PB1 5MD Final Log.tif AOGCC Page 2 of 4 Monday, lune 10- 2019 DATA SUBMITTAL COMPLIANCE REPORT 611012019 Permit to Drill 2190170 Well Name/No. KUPARUK RIV UNIT 3M-261-1-01 Operator CONOCOPHILLIPS ALASKA, INC. API No. 50-029-22431-61-00 MD 11395 TVD 6341 Completion Date 3/5/2019 Completion Status 1-0I1- Current Status 1-0I1- UIC No ED C 30541 Digital Data 4/3/2019 Electronic File: 3M-261-1-01PB1 5TVDSS Final Log.tif ED C 30602 Digital Data 4/15/2019 Electronic File: 3M-261-1-01 EOW NAD27.pdf ED C 30602 Digital Data 4/15/2019 Electronic File: 3M-261-1-01 EOW NAD27.txt ED C 30602 Digital Data 4/15/2019 Electronic File: 3M-261-1-01 EOW NAD83.pdf ED C 30602 Digital Data 4/15/2019 Electronic File: 314-261-1-01 EOW NAD83.t# Log C 30602 Log Header Scans 0 0 2190170 KUPARUK RIV UNIT 3M-261-1-01 LOG HEADERS Log C 30603 Log Header Scans 0 0 2190170 KUPARUK RIV UNIT 3M-261-1-01 PB1 LOG HEADERS ED C 30603 Digital Data 4/15/2019 Electronic File: 3M-261-1-01 PB1 EOW - NAD27.pdf ED C 30603 Digital Data 4/15/2019 Electronic File: 3M-261-1-01 Pi EOW - NAD27.txt ED C 30603 Digital Data 4/15/2019 Electronic File: 3M-261-1-01PB1 EOW NAD83.pdf ED C 30603 Digital Data 4/15/2019 Electronic File: 3M-261-1-01PB1 EOW NAD83.bd Well Cores/Samples Information: Sample Interval Set Name Start Stop Sent Received Number Comments INFORMATION RECEIVED Completion Report l./ Directional / Inclination Data pY t Mud Logs, Image Files, Digital Data Y t6A Core Chips Y / Production Test Informatio© / NA Mechanical Integrity Test Information`Y / NA Composite Logs, Image, Data Files & Core Photographs Y/ Geologic Markers/Tops Daily Operations Summary Cuttings Samples Y/ V Laboratory Analyses Y /� COMPLIANCE HISTORY Completion Date: 3/5/2019 Release Date: 2/7/2019 Description Date Comments AOGCC Page 3 of 4 Monday, June 10, 2019 DATA SUBMITTAL COMPLIANCE REPORT 6/10/2019 Permit to Drill 2190170 Well Name/No. KUPARUK RIV UNIT 3M-261-1-01 Operator CONOCOPHILLIPS ALASKA, INC. API No. 50.029-22431-61-00 MD 11395 TVD 6341 Completion Date 3/5/2019 Completion Status 1-0I1 Current Status 1-0I1- UIC No Comments: Compliance Reviewed By: _ Date: AOG('C Page 4 of Monday, June 10, 2019 BA ER BAT a GEcompany a Date: April 12, 2019 Abby Bell AOGCC 333 West 7th Ave, Suite 100 Anchorage, Alaska 99501 219Q17 30602 Letter of Transmittal Harvey Finch Baker Hughes, a GE Company 795 East 94th Avenue Anchorage, Alaska 99515 Tease find enclosed the directional survey data for the following well(s): 3M -26L1 3M -26L1 -01M 3M-26L1-01PB1 RECEIVED APR 1 Z 2019 aoGCC (3) Total prints Enclosed for each well(s): 1 hardcopy print of directional survey reports (NAD27) 1 compact disk containing electronic survey files Note: Please feel free to send us an email in place of return mail. Harvey Finch, Baker Hughes, Wellplanner Harvey.Finch@BakerHughes.com ConocoPhillips ConocoPhillips Alaska Inc—Kuparuk Kuparuk River Unit Kuparuk 3M Pad 3M -26L1-01 F��3Y�b�Zk�iQdil• Baker Hughes INTEQ Definitive Survey Report 20 March, 2019 BAT(ER UGHES a GE company 21 go 17 30 602 Iw/ �k IConocoPhillips ER YyGHES Cono1Ip5 Definitive Survey Report Company: ConocoPhillips Alaska Inc—Kuparuk Project: Kupamk River Unit Site: Kuparuk 3M Pad Well: 3M-26 Wellboro: 31M-261.1-01 Design: 3M -26L1-01 Project Kuparuk River Unit, North Slope Alaska, United States Map System: US State Plane 1927 (Exact solution) System Datum Geo Datum: NAD 1927 (NADCON CONUS) Map Zone: Alaska Zone 04 Well 3M-26 Local Coordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Database: Well Position +N/ -S 0.00 usft Northing: Longitude: +E/ -W 0.00 usft Easting: Position Uncertainty Field Strength 0.00 usft Wellhead Elevation: Wellbore 3M -26L1-01 Direction l') I 1 i Magnetics Model Name Sample Date Design Audit Notes: Version: Vertical Section: BGGM2018 4/1/2019 3M-2611-01 1.0 Phase: ACTUAL Depth From (TVD) (usft) 68.00 Well 3rd -26 310-26 @ 68.00usft (3M-26) 3M-26 @ 68.O0usft (3M-26) True Minimum Curvature EDT 14 Alaska Production Mean Sea Level Using Well Reference Point Using geodetic scale factor 6,016,559.83 usft 506,274.89usft usft Declination (I 16.63 Tie On Depth: 9 696.33 +N/ -S +E/ -W (usft) (usft) 0.00 0.00 320/2019 2:23:46PM Page 2 COMPASS 5000.14 Build 850 i Latitude: 70" 27' 23.296 N Longitude: 149° 56'55.644 W Ground Level: 0.00 usft Dip Angle Field Strength (°) (nT) t 80.93 57.424 Direction l') I 1 i 30000 i 320/2019 2:23:46PM Page 2 COMPASS 5000.14 Build 850 ConocoPhillips BA���cc HU a 1.. ConocoPhillips Definitive Survey Report .......__----....--_--.._.._.^ ----------_-----7 Company: ConocoPhillips Alaska Inc_Kuparuk Local Co-ordinate Reference: Well 310-26 I ". Project: Kuparuk River Unit TVD Reference: 310-26 @ 66.00usft (3M-26) ) site: Kuparuk 3M Pad MD Reference: 310-26 @ 68.00usft (310-26) Well: 310-26 North Reference: True Wellborn: 310-2611-01 Survey Calculation Method: Minimum Curvature I Design: 310-2611-01 Database EDT 14 Alaska Production Survey Program �^ Date From To Survey Survey i (usft) (usft) Survey (Wellbore) Tool Name Description Start Date End Date 71.01 9,311.22 3M-26 (3M-26) GCT -MS Schlumberger GCT multishot 77 1/15/2001 i i 9,313.00 9,402.68 3M-261.1 MWD -INC (310-2617) MWD -INC ONLY MWD -INC _ONLY _FILLER 2/24/2019 2/24/2019 9,433.23 9,585.53 3M-2611 MWD(3M-261-1)MWD MWD -Standard 2/25/2019 2/25/2019 9,608.00 9,635.67 3M-2611-01PB1 MWD -INC (310-2611-01 MWD -INC ONLY MWD-INC_ONLY FILLER i 2/28/2019 2/28/2019 f� p 9,666.91 9,696.33 310-261-1-01PB1 MWD(3M-26L7-01PB7 MWD MWD - Standard 2/28/2019 2/28/2019 9,703.00 11,361.04 310-2611-07 MWD(3M-261.1-01) MWD MWD -Standard 3/4/2019 3/4/2019 j C Survey P Map Map Vertical MD Inc Pad TVD TVDSS +N/ -S +E/ -W Northing Easting DLS Section (usft) (°) (°) tusk) (usft) (usft) (usft) (°/100') Survey Tool Name Annotation (ft) (ft) (ft) 9,696.33 94.52 347.01 6,318.59 6,250.59 6,636.64 8699 6,023,195.88 506,358.28 31,18 3,241.26 MM (5) TIP 9,703.00 9422 349.07 6,318.09 6,250.09 6,643.15 87.61 6,023,202.38 506,356.89 31.12 3,245.70 MM (6) KOP 9,731.27 86.00 344.44 6,31803 6,25003 6,670.63 81.14 6,023,229.86 506,350.40 33.37 3,265.05 MWD (6) 9,761.47 87.08 335.74 6,319.86 6,251.86 6,698.95 70.88 6,023,258.17 506,340.12 28.98 3,288.09 MWD (6) 9,791 77 89.11 328.40 6,320.87 6,252.7 6,725.68 56.71 6,023,284.89 506,325.93 25.12 3,313.73 MM (6) 9,822.83 88.83 318.34 6,321.43 6,253.43 6,750.57 38.20 6,023,309.76 506,307.40 32.40 3,342.20 MWD (6) 9,852.37 90.18 308.15 6,321.68 6,25368 6,770.78 1671 6,023,329.95 506,285.90 34.79 3,370.92 MVD (6) 9,881.42 93.53 300.65 6,320.74 6,252.74 6,787.17 -7.22 6,023,34632 506,261.95 28.26 3,399.84 MWD(6) 9,911.39 94.95 292.50 6,318.52 6,250.52 6,800.54 -33.93 6,023,359.65 506,235.24 27,53 3,429.65 MWD(6) I 9,937.15 96.09 282.56 6,316.04 6,248.04 6,808.25 -58.35 6,023,367.35 506,210.82 38.66 3,454.65 MWD(6) 9,969.69 97.22 275.56 6,312.26 6,244.26 6,813.34 -90.24 6,023,37241 506,178.92 21.65 3,484.82 MWD (6) 9,999.17 94.18 27628 6,309.33 6,241.33 6,816.11 -119.44 6,023,375.15 506,149.72 10.36 3,511.49 MWD(6) ' 10,031.48 92.43 271.81 6,37.47 6,239.47 6,818.10 -151.63 6,023,377.12 506,117.53 12.01 3,540.37 MWD (6) { 10,07664 9227 275.79 6,305.62 6,237.62 6,821.09 -196.69 6,023,380.07 506,072.52 8.81 3,580.84 MWD (6) 10,106.69 93.81 278.94 6,304.02 6,236.02 6,824.94 -226.40 6,023,383.89 506,042.76 11.65 3,600.54 MWD (6) 10,131.13 94.58 282.24 6,30224 6,234.24 6,829.42 -250.36 6,023,388.35 506,018.81 13.83 3,631.52 MWD (6) 10,16147 90.58 285.95 6,300.87 6,23287 6,836.80 -279.74 6,023,395.70 505,98942 17.97 3,660.65 MWD (6) ,Wa,2019 2:23:46PM Page 3 COMPASS 5000.14 Build 85D ConocoPhillips Company: ConocoPhillips Alaska Inc_Kuparuk Project: Kuparuk River Unit I Site: Kupamk 3M Pad Well: 310-26 Wellbore: 3M-261-1-01 Design: W 3M-261-1-01 Survey �,...,....�.�.......__.,..-. ,. MD Inc Azl TVD (usft) O O (usft) 10,190.56 89.75 288.33 6,30079 10,221.48 86.90 283.81 6,301.69 10,251.17 85.57 279.65 6,303.64 10,280.78 85.37 276.50 6,305.72 10,313.50 86.65 273.23 6,307.71 10,341.36 88.28 271.27 6,308.95 10,370.96 89.35 272.34 6,309.56 10,400.05 9043 275.25 6,309.62 10,43561 93.94 278.46 6,30826 10,461.41 94.86 281.61 6,306.28 10,49766 95.10 286.11 6,303.13 10,526.94 92.15 288.57 6,30128 10,558.08 88.37 290.54 6,301.14 10,591.22 85.a5 293.00 6,302.81 10,621.43 87.30 299.17 6,304.62 10,650.71 86.75 301.92 6,306.14 10,681.14 88.10 306.43 6,307.50 10,710.88 88.13 30877 6,308.48 10,741.17 85.92 310.95 6,310.05 10,771.36 88.92 314.42 6,311.41 10,802.30 90.52 318.44 6,311.56 10,836.50 9000 320.00 6,311.41 10,866.91 91.10 323.20 6,311.12 10,906.81 86.53 312.49 6,311.94 10,935.57 89.75 308.94 6,312.88 10,963.26 88.71 304.31 6,313.25 10,991.00 89.08 298.93 6,313.79 11,02120 88.83 293.39 6,31434 11,051.01 88.89 288.73 6,314.93 11,080.16 89.08 285.21 6,31545 11,110.46 9034 281.34 6,31560 3/202019 2:23:46PM �ER ! LIGHFS Annotation COMPASS 5000.14 Build 85D ConocoPhillips Definitive Survey Report Local Co-ordinate Reference: ^Well 310-26 TVD Reference: 310-26 @ 68.00usft (3M-26) MD Reference: 3M-26 @ 66.00usft (3M-26) North Reference: True Survey Calculation Method: Minimum Curvature Database: EDT 14 Alaska Production Map Map Vertical TVDSS •Nl-S -El-W Northing Easting DLS Section Survey Tool Name (usft) (usft) (usft) (ft) (ft) (°/100') Iftl 6,23279 6,845.37 -3D754 6,023,40425 505,961.62 8.66 3,689.02 AVID (6) 6,233.69 6,853.92 -337.22 6,023,412.78 505,931.93 17.28 3,719.01 MWD(6) 6,235.64 6,859.94 -356.22 6,023,418.78 505,902.92 14.68 3,747.13 MWD (6) 6,237.72 6,864.09 -395.46 6,023,422.90 W5,873.68 10.95 3,774.53 MWD(6) 6,239.72 6,866.86 428.00 6,023,425.64 505,841.15 10.01 3,804.09 MWD (6) 6,24095 6,867.95 455.81 6,023,426.71 505,813.34 9.14 3,828.72 MWD (6) 6,241.56 6,868.89 485.39 6,023,427.62 505,783.76 5.11 3,854.80 MWD (6) 6,241 62 6,870.81 514.41 6,023,429.52 505,754.74 10.67 3,880.90 MM (6) 6,24026 6,875.05 -549.68 6,023,433.73 505,719.47 13.37 3,913.55 MM (6) 6,23628 6,879.53 575.01 6,023,438.19 505,694.14 1268 3,937.74 MWD (6) 6,235.13 6,888.18 -610.06 6,023,446.80 505,659.09 12.38 3,972.42 MM (6) 6,233.28 6,896.89 537.95 6,023,455.49 505,631.20 13.11 4,000.92 MWD (6) 6,233.14 6,907.31 -667.29 6,023,465.88 505,601.85 1369 4,031.54 MWD (6) 6,234.81 6,919.58 -698.02 6,023,478.13 505,571.11 10.62 4,064.29 MWD (6) 6,236.62 6,932.84 -725.09 6,023,491.36 505,544.03 20.94 4,094.36 MWD (6) 6,238.14 6,947.69 -750.27 6,023,506.20 505,518.84 9.57 4,12360 MWD(6) 6,239.50 6,964.77 -77541 6,023,52324 505,49369 15.46 4,15391 MWD (6) 6,240.48 6,982.90 -798.96 6,023,541.36 505,470.13 7.86 4,183.37 MWD(6) 6,242.05 7,002.28 -822.18 6,023,560.72 505,446.90 10.24 4,213.17 MWD (6) 6,243.41 7,022.73 -844.34 6,023,581.14 505,424.72 15.18 4,242.58 MWD(6) 6,243.56 7,045.14 -665.66 6,023,603.53 505,403.38 13.98 4,272.25 MWD (6) 6,243.41 7,071.03 -888.00 6,023,629.41 505,381.03 4.81 4,304.55 MWD (6) 6,243.12 7,094.86 -906.88 6,023,653.22 505,362.12 11.13 4,332.81 MWD (6) 6,243.95 7,124.39 -933.61 6,023,682.71 W5,335.38 29.17 4,370.72 MWD(6) 6,249.88 7,143.13 -955.39 6,023,701.44 505,313.58 16.66 4,398.96 MWD (6) 6,245.25 7,159.64 -977.60 6,023,717.93 505,291.35 17.14 4,426.45 MWD (6) 6,245.79 7,174.18 -1,001.21 6,023,732.45 505,26774 19.44 4,454.16 Vivo (6) 6,246.34 7,187.49 -1,028.30 6,023,745.73 505,240.64 18.36 4,484.28 MWD (6) 6,246.93 7,198.19 -1,05611 6,023,756.41 505,212.82 1563 4,513.71 MWD (6) 6,24745 7.206.70 -1,083.98 6,023,764.89 505,184.95 1209 4,542.10 MWD (6) 6,24760 7.21365 -1,11346 6,023.771.82 505,155.46 13.43 4,571.12 MWD (6) Page 4 �ER ! LIGHFS Annotation COMPASS 5000.14 Build 85D ConocoPhillipsER F V2 ES ConocoPhillips Definitive Survey Report Company: ConocoPhillips Alaska lnc_Kuparuk Project: Kuparuk River Unit Site: Kuparuk 3M Pad Well: 3M-26 Wellbore: 3M -26L1-01 Design: 3M-261.7-01 Survey Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Database: Well 3M-26 3M-26 @ 68.00usft (3M-26) 3M-26 @ 68.00usft (3M-26) True Minimum Curvature EDT 14 Alaska Production Annotation 3802019 2:23:46PM Page 5 COMPASS 5000.14 Build 85D Map Map Vertical MD Inc Azi ND NDSS +N/ -S +E/ -W DLS r (usft) (1 (1) (usft) (usft) (usft) (usft) Northing Easting (°1100') Section Survey Tool Name Ifti (ft) (ft) 11,141.15 9061 281.30 6,31535 6,24735 7,219.68 -1,143.56 6,023,77782 505,125.37 0.89 4,600.19 MWD(6) 11,170.36 88.31 284.04 6,315.62 6,247.62 7,226.08 -1,172.05 6,023,784.20 505,096.87 12.25 4,628.07 MWD(6) 11,201.43 Item 288.75 6,316.48 6,248.48 7,234.85 -1,201,84 6,023,792.94 505,067.08 15.17 4,65824 MWD (6) 11,231.08 85.05 290.52 6,318.14 6,250.14 7,244.79 -1,229.71 6,023,80266 505,039.20 13.16 4,687.36 MWD (6) 11,260.50 81.02 292.11 6,321.71 6,253.71 7,255.40 -1,256.91 6,023,813.45 505,011.99 14.71 4,716.22 MM (6) 11,290.46 81.56 296.11 6,326.24 6,258.24 7,267.50 -1,283.94 6,023,825.52 504,984.96 13.32 4,745.67 MWD(6) 11,320.50 81,40 298.88 6,330.70 6,262.70 7,28121 -1,31029 6,023,83921 504,958.60 9.13 4,775.35 MM (6) 11,350.29 81.70 301.54 6,335.07 6,267.07 7,296.04 -1,33575 6,023,854.01 504,933.13 8.89 4,804.81 MWD (6) 1136104 8221 30277 6,336.58 6,268.58 7,301.70 -1,344.76 6,023,859.67 504,924.11 12.28 4,815.45 MWD(6) 11,395.00 82.21 302.77 6,341.18 6,273.18 7,31991 -1,373.05 6,023,877.85 504,89581 000 4,849.06 PROJECTED to TD Annotation 3802019 2:23:46PM Page 5 COMPASS 5000.14 Build 85D BATIGHES a GEcompany Date: April 12, 2019 Abby Bell AOGCC 333 West 711 Ave, Suite 100 Anchorage, Alaska 99501 219017 30 60 3 Letter of Transmittal Harvey Finch Baker Hughes, a GE Company 795 East 94th Avenue Anchorage, Alaska 99515 se find enclosed the directional survey data for the following well(s): 3M-261-1 3M -261-1-01s 3M-261-1-01PB1 RECEIVED APR 16 2019 AOGCC (3) Total prints Enclosed for each well(s): 1 hardcopy print of directional survey reports (NAD27) 1 compact disk containing electronic survey files Note: Please feel free to send us an email in place of return mail. Harvey Finch, Baker Hughes, Wellplanner Harvey.Finch@BakerHughes.com ConocoPhillips ConocoPhillips Alaska Inc_Kuparuk Kuparuk River Unit Kuparuk 3M Pad 3M -26L1-01 PB1 50-029-22431-70 Baker Hughes INTEQ Definitive Survey Report 20 March, 2019 BA UGHES a GE company 219017 30 603 ConocoPhillips ConocoPhillips Definitive Survey Report Company: ConocoPhillips Alaska Inc_Kuparuk Local Co-ordinate Reference: Project: Kuparuk River Unit TVD Reference: Site: Kuparuk 3M Pad MD Reference: Well: 3M-26 North Reference: Wellbore: 3M-26L1-01PB1 Survey Calculation Method: ` Design: 3M -26L1-01 PB1 Database: Project Kuparuk River Unit, North Slope Alaska, United States i Map System: US State Plane 1927 (Exact solution) System Datum: Geo Datum: NAD 1927 (NADCON CONUS) Map Zone: Alaska Zone 04 Well 3M-26 70'27'23.296 N Well Position -NI-S 0.00 usft Northing: usft +Ei-W 0.00 usft Easting: Position Uncertainty 0.00 usft Wellhead Elevation: Wellbore 3W2611-01 PB1 t Magnetics Model Name Sample Date Field Strength BGGM2018 4/1/2019 Design 3M-26L1-01PB1 Audit Notes: Version: 1.0 Phase: ACTUAL Vertical Section: Depth From (TVD) (usft) 68.00 BAKER Q UGHES Well 3M-26 3M-26 @ 68.00usft (3M-26) 3M-26 Q 68.00usft (3M-26) 1 True Minimum Curvature EDT 14 Alaska Production Mean Sea Level i Using Well Reference Point Using geodetic scale factor 6 016 559.83 usft Latitude: 70'27'23.296 N 506,274.1 usft Longitude: 149° 56'55.644 W usft Ground Level: 0.00 usft _._ _. .... _.._.._.r r t Declination Dip Angle Field Strength (1 (1) wn 16.63 80.93 57,424 Tie On Depth: 9,585.53 +N/ -S (usft) 0.00 +E/ -W (usft) 0.00 Direction (1) 20.00 3202019 2:50:44PM Page 2 COMPASS 5000.14 Build 850 ConocoPhillips Company: Project: Site: Well: f Wellbore: Design: Survey Program From (usft) 71.01 9,313.00 9,433.23 9,608.00 9,666.91 Survey ConocoPhillips Alaska Inc-Kuparuk Kuparuk River Unit Kuparuk 3M Pad 3M-26 3M -261.1-01P131 31V -2611-01P81 ConocoPhillips Definitive Survey Report Local Coordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Database: Well 3M-26 3M-26 @ 68.00usft (3M-26) 3M-26 @ 68.00usft (3M-26) True Minimum Curvature EDT 14 Alaska Production 3/202019 2:50:44PM Page 3 BA ER tUGNES ) Survey End Date 2/24/2019 2/25/2019 2/26/2019 2/28/2019 Annotation TIP KOP/TOB Interpolated Azimuth COMPASS 5000.14 Build 85D Date To Map Map Survey (usft) Survey (Wellbore) Tool Name Description Start Date 9,311.22 3M-26 (310-26) GCT -MS Schlumberger GCT multishot 1/15/2001 9,402.68 310-261-1 MWD-INC(3M-261-7) MWD-INC_ONLY MWD -INC -ONLY -FILLER 2/24/2019 9,585.53 3M-2611 MWD(31\11-261-1)MWD (usft) MWD -Standard 2/25/2019 9,635.67 3M-2617-01 P81 MWD-INC(3M-26L1-01 MWD -INC -ONLY MWD -INC -ONLY -FILLER 2/28/2019 10,517.63 310-2611-01P81 MWD(3M-261.1-01PB1 MWD MWD - Standard 2/28/2019 3/202019 2:50:44PM Page 3 BA ER tUGNES ) Survey End Date 2/24/2019 2/25/2019 2/26/2019 2/28/2019 Annotation TIP KOP/TOB Interpolated Azimuth COMPASS 5000.14 Build 85D Map Map Vertical MD Inc Azi TVD TVDSS +N/ -S +E/ -W Northing Fastin DLS Section Survey Tool Name (usft) (°) (°) (usft) (usft) (usft) (usft) (ft) (ft)g (°/100') (ft) 9,585.53 95.47 319.86 6,328.02 6,260.02 6,542.13 143.26 6,023,101.42 506,412.62 4.98 6,196.59 MWD (3) 9,608.00 94.34 318.68 6,326.10 6,258.10 6,559.09 128.65 6,023,118.37 506,398.00 726 6,207.53 MWD -INC _ONLY (4) 9,635.67 95.69 327.50 6,323.67 6,255.67 6,581.11 112.11 6,023,140.37 506,381.45 32.13 6,222.56 MWD.INC_ONLY (4) 9,666.91 94.46 337.81 6,320.90 6,252.90 6,606.71 97.84 6,023,167.95 506,367.15 33.11 6,243.62 MWD(5) 9,696.33 94.52 347.01 6,318.59 6,250.59 6,636.64 88.99 6,023,19588 506,358.28 31.18 6,266.84 MWD (5) 9,727.46 93.07 356.60 6,316.53 6,248.53 6,667.35 84.57 6,023,226.58 506,353.83 31.09 6,294.18 MWD (5) 9,757.39 92.61 6.52 6,315.04 6,247.09 6,697.19 85.38 6,023,256.42 505,354.62 33.14 6,322.50 MWD (5) 9,789.27 89.08 15.65 6,314.57 6,246.57 6,72844 91.50 6,023,28767 506360.72 30.70 6,353.96 MWO(5) 9,819.50 9086 20.98 6,314.59 6,246,69 6,757.12 101.00 6,023,316.36 506,370.19 18.59 6,384.16 MWD (5) 9,84926 93.56 23.75 6,313.44 6,245.44 6,784.62 112.31 6,023,343.86 506,381.47 12.99 6,413.87 MWD(5) 9,88340 92.21 23.67 6,311.72 6,243.72 6,815.84 126.02 6,023,375.09 506,395.16 3.96 6,447.89 MWD (5) 9,913.27 98.13 29.09 6,309.03 6,241.03 6,842.47 139.22 6,023,401.73 506,408.33 26.82 6,477.43 MWD (5) 9,943.15 96.82 29.93 6,305.14 6,237.14 6,868.25 153.81 6,023,427.52 506,422.90 5.20 6,506.65 MWD (5) 9,974.17 91.87 31.37 6,302.79 6,234.79 6,894.85 169.58 6,023,454.13 505,438.64 16.61 6,537.04 MWD(5) 10,004.09 93.04 33.28 6,301.51 6,233.51 6,920.11 185.56 6,023,47940 505,454.60 T,18 6,566.24 MWD(5) 10,032.63 89.11 34.40 6,300.98 6,232.98 6,943.81 201.45 6023,503.11 506,470.47 1432 6,593.94 MWD (5) 10,063.80 85.61 31.78 6,302.41 6,234.41 6,969.89 218.44 6,023,529.20 506,487.44 14.02 6,624.26 MWD (5) 10,092.95 8428 2793 6,304.98 6,236.98 6,995.06 232.90 6,023,554.39 506,501.87 13.92 6,65286 MWD(5) 10,12343 8477 24.99 6,307.89 6,239.89 702222 24641 6,023,581.55 506,515.36 9.74 6,68301 mvvC(5) 3/202019 2:50:44PM Page 3 BA ER tUGNES ) Survey End Date 2/24/2019 2/25/2019 2/26/2019 2/28/2019 Annotation TIP KOP/TOB Interpolated Azimuth COMPASS 5000.14 Build 85D 3/20/2019 2:50:44PM Page 4 COMPASS 5000.14 Build 85D ConocoPhillips ConocoPhillips Definitive Survey Report 3 Company: ConocoPhillips Alaska Inc_Kupamk Local Co-ordinate Reference: Well 3M-26 ^� project: Kuparuk River Unit TVD Reference: 3M-26 @ 68.00usft (3M-26) Site: Kuperuk 3M Pad MD Reference: 3M-26 @ 68.00usft (3M-26) i Well: 3M-26 North Reference: True Wellborn: 3M-2611-01PB1 Survey Calculation Method: Minimum Curvature ( Design: 3M-2611-01 PB1 Database: EDT 14 Alaska Production '! Survey-...�..._.-__..,�._.-...� ._..-.._,_...._.. ._ ..®m� Map Map Vertical - MD Inc Azi TVD TVDSS +N/ -S +El -W Northing Eastin 0 DLS Section Survey Tool Name Annotation (usft) (1) (1) (usft) (usft) (usft) (usft) (ft) (ft) (=1100•) (ft) E 10,15343 87.02 22.66 6,310.04 6,24204 7,049.59 25850 6,023,608.93 506,52743 1078 6,712.86 MWD (5) 10,183.26 89.23 20.65 6,311.01 6,243.01 7,077.30 269.50 6,023,636.65 506,538.40 10.01 6,74266 MWO(5) 10,212.99 9144 19.02 6,310.84 6,242.84 7,105.26 279.59 6,023,65461 506,548.46 9.24 6,772.39 MWD (5) 10,243.29 93.04 16.85 6,309.66 6,24166 7,134.06 288.91 6,023,693.42 506,557.76 8.89 6,802.64 MWD (5) 10,273.33 9547 17.98 6,307.43 6,23943 7,16265 297.87 6,023,722.01 506,566.70 8.92 6,832.56 MWD (5) 10,303.08 97.79 14.54 6,303.99 6,23599 7,191:01 3 A!i 6,023,750.37 506,57495 13.88 6,862.05 MWD (5) 10,333.57 101.72 14.80 6,298.83 6,230.63 7,220.07 313.76 6,023,779.44 506,582.53 12.92 6,891.96 MWD(5) 10,363.43 104.80 16.58 6,291.98 6,223.98 7,24805 321.61 6,023,807.42 506,590.36 11.83 6,920.94 MWO(5) 10,393.55 107.35 19.71 6,283.64 6,215.64 7,275.55 330.62 6,023,834.93 506,599.35 13.09 6,949.86 MWD (5) 10,425.54 108.92 22.81 6,273.68 6,205.68 7,303.88 341.64 6,023,863.26 506,610.34 1043 6,980.24 MWD(5) 10,46065 108.89 24.93 6,26230 6,194.30 7,334.25 355.08 6,023,893.64 506,623.75 5.71 7,013.38 MWD (5) 10,48843 107.62 27.06 6,253.60 6,18560 7,357.96 366.64 6,023,917.36 506,635.30 8.60 7,039.62 MWD (5) 10,51763 106.84 29.81 6,244.95 6,176.95 7382.48 379.92 6,023.94189 506,648.55 9.38 7,067.20 MWD (5) 10.57700 10684 29.81 6,227.75 6,159.75 7,431.79 408.17 6,023,991.21 506,676.76 000 7,123.20 PROJECTED IO TO 3/20/2019 2:50:44PM Page 4 COMPASS 5000.14 Build 85D STATE OF ALASKA APR 0 4 2019 ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT ANDqMCC 1a. Well Status: Oil I] Gas❑ SPLUG ❑ Other ❑ Abandoned ❑ Suspended❑ 20 C 25A05 20AAC 25.110 GINJ ❑ WINJ ❑ WAGE] WDSPL❑ No. of Completions: lb. Well Class: Development E] Exploratory ❑ Service ❑ Stratigraphic Test ❑ 2. Operator Name: ConocoPhillips Alaska, Inc. 6. Date Comp., Susp., or Abend.: 3/6/2019 14. Permit to Drill Number / Sundry: 219-017 3. Address: P.O. Box 100360 Anchorage, AK 99510-0360 7. Date Spudded: 2127/2019 15. API Number: , 50-029-22431-61-00 4a. Location of Well (Governmental Section): Surface: 938' FNL, 1593' FEL, Sec 25, T13N, R8E, UM Top of Productive Interval: 4856' FNL, 1504' FEL, Sec 13, T13N, R8E, UM Total Depth: 4178' FNL, 2964' FEL, Sec 13, T13N, R8E, UM 8. Date TD Reached: 3/4/2019 16. Well Name and Number: KRU 3M-26L1-0113M-26L1-01PB1 9. Ref Elevations: KB:68 - GL:27 BE: 17. Field / Pool(s): Kuparuk River FieldlKupurak River Oil Pool 10. Plug Back Depth MD/11/D: 9703/6318 18. Property Designation: ADL 25522, ADL 25523 4b. Location of Well (State Base Plane Coordinates, NAD 27): Surface: x- 506275 y- 6016560 Zone- 4 TPI: x- 506357 y- 6023202 Zone- 4 Total Depth: x- 504896 y- 6023878 Zone- 4 11. Total Depth MD/fVD: 11395/6341 • 19. DNR Approval Number: LONS 84-138 12. SSSV Depth MD/TVD: N/A 20. Thickness of Permafrost MDlfVD: 1806/1725 r 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: 960816326 22. Logs Obtained: List all logs run and, pursuant to AS 31.05.030 and 20 AAC 25.071, submit all electronic data and printed logs within 90 days of completion, suspension, or abandonment, whichever occurs first. Types of logs to be listed include, but are not limited to: mud log, spontaneous potential, gamma ray, caliper, resistivity, porosity, magnetic resonance, dipmeter, formation tester, temperature, cement evaluation, casing collar locator, jewelry, and perforation record. Acronyms may be used. Attach a separate page if necessary GR/Res 23. CASING, LINER AND CEMENTING RECORD WT. PER GRADE SETTING DEPTH MD SETTING DEPTH TVD AMOUNT CASING FT TOP BOTTOM TOP BOTTOM HOLE SIZE CEMENTING RECORD PULLED 16 62.5 H40 43 121 43 121 24 340sx ASI CMT 9.625 36 J-55 41 4882 41 3624 12.25 950sx ASIII, 530sx G CMT 7 26 L-80 39 9615 39 6526 8.5 250sx Class G 2.375 4.6 L-80 9220 11395 6220 6341 3 Slotted Liner 24. Open to production or injection? Yes ❑ No ❑ If Yes, list each interval open (MD/TVD of Top and Bottom; Perforation Size and Number; Date Perfd): Slotted Liner @: r 9438-11372 MD and 6336-6338 TVD ... 3/4/20'19 COMPLETION DA -f � _-ze 9 V RIFIED 25. TUBING RECORD SIZE DEPTH SET (MD) PACKER SET (MDfTVD) 3 112 9237 9205/6209 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. Was hydraulic fracturing used during completion? Yes E]No I] 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: 3/22/2019 Method of Operation (Flowing, gas lift, etc.): GAS LIFT Date of Test: 3/2412019 Hours Tested: 8hrs Production for Test Period Oil -Bbl: 42.3 Gas -MCF: 41.7 Water -Bbl: 724 Choke Size: 176 Gas -Oil Ratio: 989mcf/Bbl Flow Tubing Press. 158 Casino Press: 8 Calculated 24 -Hour Rate Oil -Bbl: 127 Gas -MCF: 12 Water -Bbl: 2172 Oil Gravity-API(corr): 21.4 Form 10-407 Revised 5/2017 (--L ¢����/ 9 CONTINUED ON PAGE 2 RBDMS�"� APR 0 5 2010 Submit ORIGINIAL only a:1, e. Irlll/n C% 28. CORE DATA Conventional Core(s): Yes ❑ No ❑� Sidewall Cores: Yes ❑ No ❑� If Yes, list formations and intervals cored (MD/TVD, From/To), and summarize lithology and presence of oil, gas or water (submit separate pages with this form, if needed). Submit detailed descriptions, core chips, photographs, and all subsequent laboratory analytical results per 20 AAC 25.071. 29. GEOLOGIC MARKERS (List all formations and markers encountered): 30. FORMATION TESTS NAME MD TVD Well tested? Yes ❑ No ❑� If yes, list intervals and formations tested, briefly summarizing test results. Permafrost - Top Surface Surface Permafrost - Base 1806 1725 • Attach separate pages to this form, if needed, and submit detailed test Top of Productive Interval 9703 6318 information, including reports, per 20 AAC 25.071. Formation @ TPI-Kuparuk A 3M26-L1-01PB1 10577 6227 TD 11395 6341 Formation at total depth: Ku aruk A 31. List of Attachments: Daily Operations Summary, Definitive Survey, Cement Report, Schematic Information to be attached includes, but is not limited to: summary of daily operations, wellbore schematic, directional or inclination survey, core analysis, paleontoloairal report production or well test results, per 20 AAC 25.07 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 Authorized Title: Staff CTD Engineer Contact Email: William. R. Long0cop.com Authorized Contact Phone: 263-4372 Signature: Date: '% *07 or" 1141' 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 10-107 well completion report and 10404 well sundry report when the downhole well design is changed. All laboratory analytical reports regarding samples or tests from a well must be submitted to the AOGCC, no matter when the analyses are conducted. Item 1 a: Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Item 1b: Well Class - Service wells: Gas Injection, Water Injection, Water -Alternating -Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Item 4b: TPI (Top of Producing Interval). Item 9: The Kelly Bushing, Ground Level, and Base Flange elevations in feet above Mean Sea Level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 15: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). Item 19: Report the Division of Oil & Gas / Division of Mining Land and Water: Plan of Operations (LO/Region YY -123), Land Use Permit (LAS 12345), and/or Easement (ADL 123456) number. Item 20: Report measured depth and true vertical thickness of permafrost. Provide MD and TVD for the top and base of permafrost in Box 29. Item 22: Review the reporting requirements of 20 AAC 25.071 and, pursuant to AS 31.05.030, submit all electronic data and printed logs within 90 days of completion, suspension, or abandonment, whichever occurs first. Item 23: Attached supplemental records should show the details of any multiple stage cementing and the location of the cementing tool. Item 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, or Other (explain). Item 28: Provide a listing of intervals cored and the corresponding formations, and a brief description in this box. Pursuant to 20 AAC 25.071, submit detailed descriptions, core chips, photographs, and all subsequent laboratory analytical results, including, but not limited to: porosity, permeability, fluid saturation, fluid composition, fluid fluorescence, vitrinite reflectance, geochemical, or paleontology. Item 30: Provide a listing of intervals tested and the corresponding formation, and a brief summary in this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Item 31: Pursuant to 20 AAC 25.070, attach to this form: well schematic diagram, summary of daily well operations, directional or inclination survey, and other tests as required including, but not limited to: core analysis, paleontological report, production or well test results. Form 10-407 Revised 5/2017 Submit ORIGINAL Only III IIIIII N W O me p_ SIV � �M Nt0 o ❑fpD�O �N mm� mom VW r N O) Vl 1m� iOJ m0m� FLLtl III IIIIII N W me p_ SIV � �M Nt0 ¢m r N O) Vl KUP PROD WELLNAME 3M-26 WELLBORE 3M-26 ConocoPhillips Alaska. INe W -m, 4RJ2019122448 PM Last Tag verEC lw.MnoE[taRell AmmaronDeptntnKel ErA livewenlore taal maE ar Last Tag. RKB 9,35)0 1/2612019 3M-26 [MB's, Last Rev Reason AnmAlnn 1 End Dah WenWrc task Mod BY NANGER, NU Rev Reason: Pen TbySat POGLYM Assembly ,25/2019 3M-26 I.Tra Casing Strings Callan, laimm"lbnGo fl.)ingot TOP InKat Sat caush MKB) Bet Death OVER tsial(L Gmade Top TMW CONDUCTOR 16 15.06 430 121.0 121.0 6250 H40 WELDED Cninp Oeaceiption Oa Iia In (in) pMB) Set Duch MIXIS Stl OepM"'N... WrLen IT Tap Taman IT,, janada SURFACE 9518 8.92 41.1 4,882.2 3,623.6 36.00 J-55 STC e"I" Dea[,ivHon oo (im m (in Tap pIKB) semepm (arca) lel Daph trv01... widen p_. G,N. Tun, TM1,wtl PRODUCTION 7 6.28 387 9,614.7 6525.6 26.00 L-80 BTC -MOD Tubing Strings Tubing Description Janina m•... tD hal rop (lane) del Dapin (tt. sn Oevin ITVO) I... wt pxn) Gmde Top couu.cmn TUBING 3112 299 368 92372 62333 930 J-55 EUE8rbMOD LONDUCTOR. as W21C Completion Details Top (ID) Top Incl Nominal Top have) HIKE) I') Ihm Cel can IDIin) 36.8 36.8 026 HANGER FMC GEN IV HANGER 3500 NIPPUF. Joao 2,0212 1,903D 3725 NIPPLE CANDO W -i LANDING NIPPLE WI SELECTIVE PROFILE 2812 9,2028 6,207.0 40.37 LOCATOR BAKER GBH -22 LOCATOR SEAL ASSEMBLY 3.000 9,205.3 6.209.1 40.39 PACKER BAKER FBA PERM PACKER 4.000 9208.6 6,2116 40.41 SBE BAKER 80-00 SEAL BORE EXTENSION 4.000 JPRPKR(mEL2920 92267 6,225.3 4049 NIPPLE CAMCO D NIPPLE NO GO, (MILLED OUT TO 2.80') 2.800 9236.3 6,2327 4052 SOS BAKER$HEAR OUT SUB 2.992 POal 2951 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Too UVD) Ton Incl SPACER PIPE: 29M0 FERIT Z9%0 Top ("a) MET (1) Des eom Run Dam ID (In) 2,942.0 2,4957 56.13 HER PER (ME) P2P UPR PKR (u CPP35178) 3202019 1.625 LWR PKR (ME):2E�+.0 2,9440 2,4968 56.13 $PACER PIPE - w/ Anchor LatchAny p ) 3202019 1640 8.21' OAL 2,9500 2,500.2 56.12 POGLM t mmp packeno topbosom lath ov ,2N2019 1560 UA" pan) 2,9650 2508.5 5611 LWR EKE (ME) P2P -WR PKR(r CPP3 , 4' OAL, 1625- ID) ,1712019 1.620 9,3130 6,290.8 —Ton W K- NS HEW Tubing exit 212 012 0 1 9 THIRD TBG WRFACE:41Aaasc — 9,4500 6,396.6 3640 FISH 3 X 6 718 X T LIP Lost fromAir SLIP, was never 42611994 Lound; could be in hole Perforations 8 Slots Brix an LET Dens rap (rvD) S. NNI) pnomm habitual) atm (n Kat 11M8) MIKE) Llnkins. Dab 1 TYpe Con 2,9560 2,956.0 2.503.5 2,5035 ,172019 PERFP Z'CIRC CHARGE SHOTS, O°PHASE)@ 2956 ENS LocnTOR; e,To2a 9,324.0 9,3580 6,299.1 6,3258 A-1,3M-2fi 42611994 4.0 [PERE 41 "BH Sg un, degphasillg PACKER; 9X53 Mandrel Inserts SBE; a"$ Bt atl N Tap(l"JI) TlMlal) gains MMeI OD 9M gery Malve YM Lal[n Ypa PonSize Ila) 1RO flan (psq Run Pete Lom 9,153.3 6,169.3 CAMCO MMM 112 GAS LIFT DMV RK 0.000 0.0 61311994 Notes: General & Safety Ena Dela moratorium 712812010 NOTE. View Schematic ut Alaska Sclearrin9.0 NIPPIE; 9,LF.] a05:9.Z'b.9 TT Llp LINER; 9220 0-11,31sa WHIPBTCCK-THRVTSG: 9.9130 IPERF:9321D9,1cB.0� FIEX; 9.15]0 PRDOUCTION; 98.0-9,6141 KUP PROD WELLNAME 3111-26 WELLBORE 3M -26L1-01 on ► dQ1K5AFK bute Max Angle' TDCW NVOrr,IIII USWU.ncl r) MDISNpIKBI Alaska. InCIVER UNIT 500292249161 PRUU 722 996969 113950 00 LA-�L1O1,<NAI912N ie PM Last Tag VerbyaAaneiClcxmll Anmdinn1 DepN MKS) End Dale Wellbore "M Mod BY Last Tag: JM-2fiL1-01 jennan Casing Strings .......... ca:me DesCrlpllon OD(nl ID pnl Top IXK G) Sn Depin(RKBI SNDepin lTw�._wVLan(I... ureas x.0 L1.01 LINER 20W 1.99 9,220.0 11,395.0 6,341.2 4.60 11,T L-80 ELL N41GEP: 83 Liner Details I NpmmauD Top IRKBI raplrvDIZZU iop l4U4L ..P cC—pp 9,220.0 6,220.. 3 4046 DEPLOYMENT ShDM Depbyment Sleeve 1920 SLEEVE Perforations & Slots sllw D R ro(ISKE) BIm 13VD1 Isnpmm ToplKKal Bim I11NB (KKBI IM(BI LlnAea IDne Daie ) Type COm 94380 11,3110 6,3362 OIII. A-, - L- 3/4/2019 SLOTS SiOned Liner CONDUCTOR: 061210 JI 01 Notes: General 8 Safety En a Mh AnooNtion .II 20212 4/1/2019 NOTE: View SCheRuIft wl MOSM ScheRuRic10.0 UPR PIW (ME)'. z832D POOLM;2 0 SPACER PIPE; 28N.D PERPP: ZRRLO MR Pm (ME); 2,8X.0 SURFACE; 41. tdMR, 2— GNSLM1T:3,1533 LCCATOR: SM. PACKER:%2RG3 3eE: B.21M.8 ji NIPPLE; 9Y 7 SOS', 52983 PROWCTK)N', SS.Be.SIeI I �k SLOTS. %M 11,3]10 � r 11� Ui T LINER:9,..0 I.M. %-,,erations Summary (with Timelog 1,-pths) 3M-26 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Star) Depth Start Time End Time our(hr) Phase Op Cods AolAy Cole Time P -T-% Operation (110) End Deplh(flKB) 2/18/2019 2/18/2019 1.70 MIRU MOVE DMOB P Complete RD from 1J-10, load out 0.0 0.0 11:00 12:42 DTH trucks, secure rig landings and stairs, secure cellar 2/18/2019 2/18/2019 1.00 MIRU MOVE RURD P Trucks arrive at 12:45PM, load up 0.0 0.0 12:42 13:42 shop & 1/2 -Way house, offload last of fluids 2/18/2019 2/18/2019 1.60 MIRU MOVE RURD P PJSM, pull sub & pits off well 0.0 0.0 13:42 15:18 2/18/2019 2/18/2019 1.00 MIRU MOVE MOB P Move from 1J -Pad to 3M -Pad (20.7 0.0 0.0 15:18 16:18 miles) 2/18/2019 2/18/2019 2.30 MIRU MOVE MOB P Hold up at J pad access road per 0.0 0.0 16:18 1836 security 2/18/2019 2/19/2019 5.40 MIRU MOVE MOB P Continue to move from 1J -Pad to 3M- 0.0 0.0 1836 0000 Pad (20.7 miles) 21:00 @ the Y 22:00 @ IQ 23:15 Q CPF3 BFGS tum at midnight 2/19/2019 2/19/2019 2.20 MIRU MOVE MOB P Arrive on pad. 0.0 0.0 00:00 02:12 2/19/2019 2/19/2019 1.00 MIRU MOVE MOB P Meet W DSO, receive permission to 0.0 0.0 02:12 03:12 spot overwell. Go on jack, drop assist & primary sows. De -jeep. 2/19/2019 2/19/2019 0.90 MIRU MOVE MOB P While prepping herculite discover Ops 0.0 0.0 03:12 04:06 has built two temporary well enclosures around stick built scaffolding that are narrower than our cellar and an gas line, Cat heater jumper, has been run between both adjacent wells that we can not clear with the cellar. 2/19/2019 2/19/2019 2.00 MIRU MOVE MOB P Spot sub over well 0.0 0.0 04:06 06:06 2/19/2019 2/19/2019 1.10 MIRU MOVE MOB P Spot service unit 0.0 0.0 06:06 07:12 2/19/2019 2/19/2019 2.80 MIRU WHDBOP RURD P Work rig up check list, walkways, 0.0 0.0 07:12 10:00 Banning, RU PUTZ, steam, Duck ponds. 2/19/2019 2/19/2019 1.50 MIRU WHDBOP NUND P Nipple up, Check tree bolts, C/O 0.0 0.0 10:00 11:30 risers, harvest RKBs, 2/19/2019 2/19/2019 1.00 MIRU WHDBOP RURD P Complete rig up, take on sea water. 0.0 0.0 11:30 12:30 Rig Accept 12:30 2119/2019 2/19/2019 1.00 MIRU WHDBOP RURD P Fluid pack and shell test 0.0 0.0 12:30 13:30 2/19/2019 2/19/2019 8.00 MIRU WHOBOP BOPE P Test BOPE, 250/4000 psi, AOGCC 0.0 0.0 13:30 21:30 Witness Jeff Jones. Fail pass Tango #2- grease and retest, Romeo #2 Fail / Pass. 2/19/2019 2/19/2019 1.00 MIRU WHDBOP PRTS P Test PDL's and tiger tank line 0.0 0.0 21:30 22:30 2/19/2019 2/19/2019 0.50 MIRU WHDBOP PRTS P With PDL on stump, open master 0.0 0.0 22:30 23:00 valve, WHP 1,400 psi, line up to tiger tank line, bleed off gas to 1,000 psi, shut in blow down tiger tank line, WHP back up to 1,400 psi. 2/19/2019 2/19/2019 0.75 PROD1 RPEQPT PULD P PJSM, PU BHI tools and load into 0.0 0.0 23:00 23:45 1 PDL, 2/19/2019 2/20/2019 0.25 PROD1 RPEQPT PULD P PJSM, PU HEW 0.0 0.0 23:45 00:00 2/20/2019 2/20/2019 1.00 PROD1 RPEQPT PULD P Continue PU HEW 0.0 0.0 00:00 01:00 i Page 1/16 ReportPrinted: 4/3/2019 trperations Summary (with Timelog Depths) 1W3M-26 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Staff Depth Stad Tune End Time our (hr) Phase Op Cods Activity Code Tune P-T-X Operation (MKB) End OePlh(MKE) 2/20/2019 2/20/2019 0.50 PROM RPEQPT PULD P Slide cart forward, install float valves 0.0 73.5 01:00 01:30 into UQ, MU to CoilTrak tools, perform surface test (good-test) 2120/2019 2/20/2019 2.20 FROM RPEQPT TRIP P RIH, with open EDC, pumping min 73.5 8,970.0 01:30 03:42 rate 0.39 bpm at 1,433 psi, WHP=1,304 2/20/2019 2/20/2019 0.50 PROM RPEQPT DLOG P Log formation looking for the HRZ 8,970.0 9,112.0 03:42 04:12 correction plus 3.5' 2/20/2019 2/20/2019 0.20 PROM RPEQPT TRIP P Continue IH 9,112.0 9,214.0 04:12 04:24 2/20/2019 2/2012019 0.33 PROD1 RPEQPT DLOG P Attempt to log the K1, couldn't see it. 9,214.0 9,345.0 04:24 04:43 continue IH past setting depth to 9,345- 2/20/2019 2/20/2019 0.20 PRODt RPEQPT TRIP P PUW 41 k, Pull up hole to 9,260' 9,345.0 9,260.0 04:43 04:55 2/20/2019 2120/2019 0.25 PROW RPEQPT DLOG P Log CCL from 9,260'-9340', correlate 9,260.0 9,343. 04:55 05:10 logs. 2/20/2019 2/20/2019 0.40 PROD1 RPEQPT WPST P RIH to setting deph, TOWS @ 9312'. 9,343.0 9,312.0 05:10 05:34 Close EDC, Online w pump, see tool shear @ 3899 psi. S/D 5.3 k lbs, PU clean, 35.9 k lbs 2/20/2019 2/20/2019 1.80 PROM RPEQPT DISP P Open EDC, line up on milling fluid at 9,312.0 9,227.0 05:34 07:22 2.45 bpm. PUH slowly as milling fluid is pumped to the bit. 2/20/2019 2/20/2019 0.20 PROD1 RPEQPT TRIP P POOH chasing milling fluid to surface. 9,227.0 7,539.0 07:22 07:34 2/20/2019 2/20/2019 1.60 PROD1 RPEQPT RGRP T Stop, investigate marks on coil. Some 7,539.0 7,245.0 07:34 09:10 light gouging indicative of slipped blocks while pulling up hole. Observed out of hole torque fluctuating in an abnormal manor. Performed visual inspection of injector no obvious issues, some cracked elastomers. Roll out of hole slowly, observed new larger set of gouges, 7448' form EOP, filed and flagged green. Re Inspected chains, slowly pulled out of hole while power washing. One gripper block came out of it clip from the pressure washer force. Stopped, repaired. Found retainer clip smashed, no spring memory. PUH slowly, no indications of issues. PUH -200' with no pipe marks. 2/20/2019 2/20/2019 0.90 PROM RPEQPT TRIP P POOH, no indicaion of new marks, out 7,245.0 2,866.0 09:10 10:04 of hole torque stable. 2/20/2019 2/2012019 2.40 PROM RPEQPT RGRP T Sudden stop, SCADA System lacked 2,866.0 2,866.0 10:04 12:28 out the storage reel and injector. Error code - Injector motor differential speed detected or possible slip. Investigated and found the right angle drive drillers side encoder had seized. The drive shaft to the encoder had sheared off. Parked, closed bag, replaced encoder PUH slowly inspecting pipe, all clear. 2/20/2019 2/20/2019 0.60 PROM RPEQPT TRIP P POOH 2,866.0 85.0 12:28 13:04 2/20/2019 2/20/2019 1.00 PROM RPEQPT PULD P PUD and LD BHA#1, whipstock 85.0 0.0 13:04 14:04 setting assembly. 2/20/2019 2120/2019 1.00 FROM WHPST PULD P PU and PD BHA#2 Window milling 0.0 76.0 14:04 15:04 assembly, 1° Weatherford fixed bend motor, string mill 2.79" no go, DSM 2.80 no go. Inspect pack oils - good. Page 2116 Report Printed: 413/2019 Operations Summary (with Time9®g Depths) 3M-26 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Star) Depth start rime End Time our (hr) Phase Op Code Activity Coae Time P -T -X Operation (Wa) End Depth dtKa) 2/20/2019 2/20/2019 2.60 PRODt WHPST PULD P RIH, park @ 344', close EDC, 0.0 9,050.0 15:04 17:40 continue to RIH pumping 1.03 bpm, holding 12.1 ppg EMW maintaining 1 fort returns. Start encountering damaged pipe @ 7892 bit depth, 7822 Epic End of Pipe four whip end. Additional @ Set down @ 8001, 8250, 2/20/2019 2/20/2019 0.20 PROD1 WHPST DLOG P Log formation from 9,050'-9,084', 9,050.0 9,084.0 17:40 17:52 j correction of plus 3.0', PUW 36 k 2/20/2019 2/20/2019 0.15 PROD1 WHPST TRIP P Continue IH, dry tag pinch point at 9,084.0 9,317.0 17:52 18:01 9,316.8', PUH, obtain pump parameters 2/20/2019 2/20/2019 3.80 PROD1 WHPST MILL P Start Milling window exit, 1.84 bpm @ 9,317.0 9,320.0 18:01 21:49 3.900 psi, Dili -596, WHP=551, BHP=3,997, IA=950, OA=888 2/20/2019 2/20/2019 1.35 PROD1 WHPST MILL P Stall motor, PUH and restart, 1.79 9,320.0 9,321.0 21:49 23:10 bpm at 3,962 psi, Diff -649, WHP=535, IA=950, OA=889 '"` Note: Bleed down IA and OA 2/20/2019 2/20/2019 0.60 PROD1 WHPST MILL P Drill rat hole, 1.8 bpm at 3,883 psi, 9,321.0 9,327.0 23:10 23:46 Diff --630, WHP=553, BHP=3,953, IA=614, OA=723 2/20/2019 2/21/2019 0.22 PROD1 WHPST REAM P TO rat hole 9,327', PUH 33 k, Ream 9,327.0 9,327.0 23:46 00:00 window exit @ HS TF. 2/21/2019 2/21/2019 1.50 PROD1 WHPST REAM P Continue reaming window exit HS, 30° 9,327.0 9,270.0 00:00 01:30 LOHS, 30` ROHS, 180°, perform dry drift (clean), open EDC 2/21/2019 2/21/2019 0.30 PROD1 WHPST TRIP P Shutdown pump, open EDC, 3,948 9,270.0 9,270.0 01:30 01:48 psi BHP, 12.06 ECD 2/21/2019 2/21/2019 2.00 PROD1 WHPST TRIP P POOH, chasing sweep to surface 9,270.0 77.3 01:48 03:48 2/21/2019 2/21/2019 1.50 PROD1 WHPST PULD P PJSM, PUD & LD milling assembly 77.3 0.0 03:48 05:18 2/21/2019 2/21/2019 1.00 PROD1 DRILL CIRC T MU nozzle, Stab onand roll coil to 0.0 0.0 05:18 06:18 water. Crew swap 2/21/2019 2/21/2019 1.00 PROD1 DRILL DISP T PJSM, Halliburton N2 rigged up and 0.0 0.0 06:18 07:18 PT'd to 4000 psi. Blow down reel w 1500 SCF/min foor 10 min, trap pressure, Blow down surfce lines, RID halliburton. 2/21/2019 2/21/2019 1.40 PROD1 DRILL CTOP T Prep grapple end and string wire rope 0.0 0.0 07:18 08:42 while bleeding down coil 2/21/2019 2/212019 0.30 PROD1 DRILL CTOP T R/D inner reel iron, unstab break off 0.0 0.0 0842 09:00 Upper quick connect, cut off CTC. 2/21/2019 2/212019 0.50 PROD1 DRILL CTOP T Install grapple 0.0 0.0 0900 09:30 2/21/2019 2/21/2019 2.00 PROD1 DRILL CTOP T Lock out reel break out inner reel iron / 0.0 0.0 0930 11:30 bulkhead, Pull test grapple, PJSM 2/21/2019 2/21/2019 1.70 PROD1 DRILL CTOP T Secure coil, cut excess 0.0 0.0 11:30 13:12 2/21/2019 2/21/2019 0.60 PRODt DRILL CTOP T Suspend reel, remove saddle clamps. 0.0 0.0 1312 13:48 2/21/2019 2/212019 0.70 PROD1 DRILL CTOP T Skid cart,instal stripper pole, drop 0.0 0.0 13:48 14:30 stripper, lay over and drop cart. 2/21/2019 2121/2019 1.20 PROD1 DRILL CTOP T Swap gripper blocks, elastomers, 0.0 0.0 14:30 15:42 clips, replace stdppper brass, pick up stripper. 2/21/2019 2/21/2019 1.00 PROD1 DRILL CTOP T PJSM w crew and Peak truck drivers. 0.0 0.0 15:42 16:42 Drop od reel on truck. Page 3/16 ReportPrinted: 4/3/2019 Operations Summary (with Timeiog Depths) 3M-26 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Depth StartTime End Time DW pv) Phase Op Code Activity Code Time P -T -X Operation MKB) End Depth (ftKB) 2/21/2019 2/21/2019 1.30 PROD1 DRILL CTOP T Prep and pick new storage reel # 0.0 0.0 16:42 18:00 52794 2/21/2019 2/21/2019 2.25 PROM DRILL CTOP T Secure reel into saddles, remove 0.0 0.0 18:00 20:15 rigging, shiim reel, torque to spec, install graple, remove reel wrapping, and pull test. 2/21/2019 2/21/2019 0.25 PROD1 DRILL CTOP T PJSM, stab coiled tubing through 0.0 0.0 20:15 20:30 INJH, apply traction 2/21/2019 2/21/2019 2.50 PRODI DRILL CTOP T Install inner reel iron, sim-ops load out 0.0 0.0 20:30 23:00 banding and material Nom bomb -bay door. install king pin. 2/21/2019 2/22/2019 1.00 PRODI DRILL CTOP T Install Bolster, spill dikes, position reel 0.0 0.0 23:00 00:00 for installing iron, remove grapple 2/22/2019 2122/2019 3.00 PROD1 DRILL CTOP T Continued installing inner reel iron, 0.0 0.0 00:00 03:00 CTES counter 2/22/2019 2/22/2019 1.50 PRODI DRILL CTOP T Ream Seam from coil, install CTC, 0.0 0.0 03:00 04:30 1 head up BHI UQC 2/22/2019 2122/2019 2.50 PRODI DRILL CTOP T MU High Pressure Bulkhead inside 0.0 0.0 04:30 07:00 reel, and test a -line, tighten & secure inner reel iron 2122/2019 2122/2019 1.20 PROD? DRILL CTOP T Skid reel, PU pump in sub place on 0.0 0.0 07:00 08:12 stump,BO nozzle, pull test 35 k good. Check CTC. MU nozzle stab injector 2/22/2019 2/22/2019 5.20 PROD? DRILL CTOP T C/O pack offs, lock reel install CTES 0.0 0.0 08:12 13:24 counter, PJSM W LRS pump 5 bbls MethOH min rate, chase w water. 2/22/2019 2/22/2019 2.40 PROD1 DRILL CTOP T BO nozzle, cut off CTC, boot wire, 0.0 0.0 13:24 15:48 Line up to reverse circulate, PT inner reel iron, one leak, hammer up, test inner eel iron and stripper, bleed off. ramp to to 2.5 bpm x5, no indication of wire movement. 2122/2019 2122/2019 2.20 PRODI DRILL CTOP T PJSM, unstab, start cutting pipe to 0.0 0.0 15:48 18:00 remove shipping dammage. ""' Note: Trim 378' Coiled Tuibing, (New Length=18,028/45.7 bbl Vol) 2/22/2019 2122/2019 1.20 PRODI DRILL CTOP T Test a -line (good -test), Dress coil, 0.0 0.0 18:00 19:12 1 Install CTC, PT 35 k 2122/2019 2122/2019 1.25 PRODI DRILL CTOP T Re -head BHI UQC, test a -line (good- 0.0 0.0 19:12 20:27 1 test) 2122/2019 2122/2019 0.30 PRODI DRILL CTOP T PT re -head to 4,500 psi, Break off pull 0.0 0.0 20:27 20:45 plate 2122/2019 2122/2019 2.30 PRODI DRILL CTOP P PJSM, PU/PD build section assembly 0.0 72.2 20:45 23:03 2122/2019 2122/2019 0.30 PRODI DRILL CTOP P MU to BHI CoilTrak tools„ perform 0.0 72.2 23:03 23:21 surface test (good -test), stab INJH, tag up, reset counter depths. 2/22/2019 2/23/2019 0.65 PRODI DRILL CTOP P RIH 72.2 5,035.0 23:21 00:00 2/23/2019 2/23/2019 0.75 PRODI DRILL TRIP P Continue IH 5,035.0 8,885.0 00:00 00:45 2/23/2019 2/23/2019 0.70 PRODI DRILL DLOG P Log formation correction of plus 93.5' 8,885.0 9,085.0 00:45 01:27 2/23/2019 2123/2019 0.45 PRODt DRILL DRLG P OBD, 1.9 bpm at 4078 psi, Diff=490 9,085.0 9,390.0 01:27 01:54 psi, WHP=489, BHP=3,979, IA=66, OA 25, stall motor twice getting started, 9,329' and 9,342' 2/23/2019 2/23/2019 0.15 PROD1 DRILL WPRT P Stall motor, PUH and restart 9,390.0 9,390.0 01:54 02:03 Page 4116 Report Printed: 4/312019 Operations Summary (with Timelog Depths' 47 3M-26 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log-7tart -Depth Sted7me End Time 0w(hr) Phase Op Code Activity Code Time P -T -X Operation (M1KB) 9,390.0 End Depth(ftKB) 9,530.0 2/23/2019 2/23/2019 5.90 PROD1 DRILL DRLG P BOBD, 1.85 bpm at 3,888 psi, 02:03 07:57 Diff -521 psi, WHP=349, BHP=3,976, IA=241, OA 209, Stall motor, PUH and restart X2, BOBD, 1.85 bpm at 3,888 psi, Diff -5211 psi, WHP=349, BHP=3,976, IA=241, OA209 Crew change. PU and restart, PU Wt 35 k lbs RIH Wt 15k lbs, C14010 psi @ 1.88 in 1.88 out WH 497 psi, IA 578 psi, OA 633 psi, OBD, diff 497 psi. WOB 3k lbs, ROP 3-5 ft/hr, in ankerke, break out @ 9496' Drill ahead, stage 5x5 low night of the bit in anticipation of TD. " TO build - 9530' 2/23/2019 2/23/2019 2.10 PROD1 DRILL TRIP P PU Wt 34 k lbs. 9,530.0 77.0 07:57 10:03 Saw -2.4 and - 3.3k WOB tug @ 9405 & 9395' respectively. Widow clean, Park at 9241', open EDC, continue to POOH Park at 6071', inspect reel bolts, find saddle damps a little loose on DS. - 8 min Continue to POOH, 2/23/2019 2123/2019 1.00 PROD1 DRILL PULD P PUD, holding 12.1 ppg EMW, well is 77.0 0.0 10:03 11:03 verytight. LDBHA#3 Bit came out 2/23/2019 2/23/2019 1.00 PROD1 DRILL PULD P PU and PD BHA#4, ).5 ° AKO under 0.0 78.0 11:03 12:03 an NOV agitator and hyc A3 bit. Skid cart, check pack offs - good. Inspect and retorque iner reel iron. Bump up and set counters. 2/23/2019 2/23/2019 1.70 PROD1 DRILL TRIP P RIH to 500', Park, Close EDC, Shallow 78.0 9,030.5- 12:03 13:45 test agitator. 2/23/2019 2123/2019 0.50 PROD1 DRILL DLOG P Logged the peaks of tie in for +13' 9,030.0 9,380.0 13:45 14:15 correction Logged RA lag in BOWS - 2/23/2019 2/23/2019 0.20 PROD1 DRILL TRIP P Continue to RIH through build 9,380.0 9,530.0 14:15 14:27 2/23/2019 2/23/2019 0.30 PROM DRILL DRLG P RIH CT Wt 16.7 k lbs, CT 4704 psi, @ 9,530.0 9,580.0 14:27 14:45 1.88 bpm in and 1.88 bpm out holding 12.0 ppg EMW @ the window. Annular 3997 psi, Diff 1097 psi, OBD, CT Wt 1 k lbs, WOB 1.31 k lbs, ROP - 121 fU hr. 2/23/2019 2/23/2019 0.75 PROD1 DRILL TRIP T PU wt 32 k lbs, Issue with MWD, TVDE9,580.0 9,580.0 14:45 15:30 calculation has a glitch. Rebook MWD computer. PUH slowly to 9266'. Get restarted, all systems go, RBIH, 2/23/2019 2/23/2019 2.00 PROM DRILL DRLG 15 CT 3991 psi @ 1.88 bpm in and 1.88 9,695.0 15:30 17:30 bpm out, diff 1067 psi, BHP 4613 psi - 12.0 EMW @ the window. CT Wt 13 k lbs, WOB 2.6 k lbs, ROP 150 ft/hr WH 430 psi, IA 631 psi, OA 683 psi, 2/2312019 2/23/2019 3.25 PROM DRILL DRLG P OBD, 1.9 bpm at 4621 psi, Diff -11,068 9,695.0 9,987.0 17:30 20:45 psi, WHP=435, BHP=3,991, IA=988, OA=977, - Note: On-site Geo calling fault crossing 9,900' 2123/2019 2/23/2019 0.40 PRODt DRILL WPRT P Wiper to the EOB, PUW 35 k 9,987.0 9,530.0 20:45 21:09 2123/2019 2123/2019 0.30 PROD1 DRILL WPRT P Wiper back in hole, RIW 14 k 9,530.0 9,987.0 21:09 21:27 Page 5/16 ReportPrinted: 41312019 Operations Summary (with Timeiog Depths) fr`rs 3M-26 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Depth StartTime End Time our (hr) Phase Op Code Actimly Code Time P -T-% Operatlon (NCB) End Depth (AKB) 2/23/2019 2/24/2019 2.56 PROD1 DRILL DRLG P OBD, 1.9 bpm at 4621 psi, Diff --1,100 9,987.0 10,113.0 21:27 00:00 psi, WHP=443, BHP=3,997, IA=988- 435, OA=977-621, Bleed down IA and OA 2/24/2019 2/24/2019 1.00 PROD1 DRILL DRLG P OBD, 1.8 bpm at 4,817 psi, Diff=1,281 10,113.0 10,129.0 00:00 01:00 psi, WHP=443, BHP=3,992, IA=545, OA=725 2/24/2019 2/24/2019 1.00 PROD1 DRILL DRLG P OBD, 1.76 bpm at 4,834 psi, 10,129.0 10,139.7 01:00 02:00 Diff=1,281 psi, WHP=443, BHP=3,997, IA=617, OA=795 2/24/2019 2/24/2019 1.00 PRODt DRILL DRLG P OBD, 1.8 bpm at 4,895 psi, Diff -1,281 10,139.7 10,297.0 02:00 03:00 psi, WHP=444, BHP=3,994, IA=618, OA=795 2/24/2019 2/24/2019 1.17 PROD1 DRILL DRLG P OBD, 1.85 bpm at 5,009 psi, 10,297.0 10,418.0 03:00 04:10 Diff --1,527 psi, WHP=424, BHP=4,004, IA=639, OA=809 2/24/2019 2/24/2019 0.55 PROD1 DRILL WPRT P Wiper up hole into the casing, PUW 10,418.0 9,330.0 04:10 04:43 35 k 2/24/2019 2/24/2019 0.40 PROD1 DRILL WPRT P Pull through window at reduced speed 9,330.0 9,246.0 04:43 05:07 10 fpm @ 0.40 bpm, jogged the the 7 inch, 9,246'-9,300' with sweep, RIH to logged depth 2/24/2019 2/24/2019 0.20 PRODt DRILL DLOG P Log the RA marker correction of+1.5' 9,340.0 9,370.0 05:07 05:19 2/24/2019 2/24/2019 0.40 PROD1 DRILL WPRT P R I H after tie in wiper, RI Wt 32 k lbs 9,370.0 10,418.0 05:19 05:43 2/24/2019 2/24/2019 2.50 PROD1 DRILL DRLG P Ct 48483 psi @ 1.88 bpm in, 1.88 bpm 10,418.0 10,816.0 05:43 08:13 out, BHP 3975 psi, holding 12.0 ppg EMW at the window. Diff pressure 1209 psi, WH 351 psi, IA 778psi, OA 891 psi. OBD, CT Wt 9.9 k lbs, WOB 2.3 k lbs, ROP PU 10640'35 k lbs PU 10786- 36 k Ibs ROP 160 ft/hr 2/24/2019 2/24/2019 0.40 PROM DRILL WPRT P PUWt 34 k Has 10,816.0 9,816.0 08:13 08:37 Slight neg WOB tug @ 10200' with a - 40 psi increase in annular pressure 2/24/2019 2/24/2019 0.40 PROD1 DRILL WPRT P RBIH 9,816.0 10,816.0 08:37 09:01 2/24/2019 2/24/2019 0.80 PROD1 DRILL DRLG P CT 4867 psi, @ 1.88 bpm in and 1.88 10,816.0 10,924.0 09:01 09:49 bpm out. BHP 3990 psi holding 12.0 ppd EMW @ the window. Diff 1213 psi, WH 391 pi, CT Wt 5 k lbs, WOB 2 k lbs 10925', 2/24/2019 2/24/2019 2.70 PROD1 DRILL DRLG P PU Wt 36k lbs, on something hard 3.8 10,924.0 10,959.0 09:49 12:31 k WOB, 10ft/hr Drill ahead in aker@e 2/24/2019 2/24/2019 2.40 PROM DRILL DRLG P Break out of ankedte. Ratty 10,959.0 11,121.0 12:31 14:55 drilling,still hitting stringers. CT wt 9 k lbs, WOB 1.7 k lbs, ROP variable, OBD CT 5212 psi, @ 1.87 bpm in and 1.87 bpm out, BHP 4069 psi. 2/24/2019 2/24/2019 0.50 PROD1 DRILL DRLG P PU Wt 35 k lbs to allow DD to adjust 11,121.0 11,217.0 14:55 15:25 for stops, RBIH CT 5044 psi @ 1.88 bpm in and 1.87 bpm out, diff 1193 psi, WH 295 psi. CT Wt 3.8 k Ibs, WOB 1 k IDS, Bleed IA to 6 psi energized fluid, Bleed OA to 32 psi all fluid. Page 6/16 Report Printed: 4/312019 Operations Summary (with Timet®g Depths) 3M-26 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Depth start Time End Time Dur (m) Phase Op Code Activity Code Time P -T -X Operation (fil®) End Depth(fIKB) 2124/2019 2/24/2019 0.50 PROM DRILL DRLG P PU Wt 35 k Itis to allow DD to adjust 11,121.0 11,217.0 15:25 15:55 for stops, RBIH CT 5044 psi @ 1.88 bpm in and 1.87 bpm out, diff 1193 psi, WH 295 psi. CT Wt 3.8 k lbs, WOB 1 k lbs, Bleed IA to 6 psi energized fluid, Bleed OA to 32 psi all fluid. 2/2412019 2/24/2019 0.70 PROD1 DRILL DRLG P PU Wt 38 k lbs, PUH wiping to the TT 11,217.0 9,040.0 15:55 16:37 to clean up the 7" and tie in for depth control. Hole clean, lots of solids at the shaker. Jog 7", PUH pumping bottoms up. 2/24/2019 2124/2019 0.20 PRODt DRILL DRLG P Tie into the HRZ for a +3.5' correction. 9,040.0 9,085.0 16:37 16:49 2/24/2019 2/24/2019 0.20 PROD1 DRILL TRIP P RIH and park at 9299.88 CTMD - 9,085.0 9,299.0 16:49 17:01 6244.06 psi, Measure BHP Trap 3950 psi, pressure slowly falling, bleed to 3837 psi, Observe pressure climb slowly to 3906 psi, 12.02 EMWand slowly climbing. 2/24/2019 2/24/2019 1.78 PRODt DRILL TRIP P PU Wt 33 it lbs, RBIH, window and 9,299.0 11,220.0 17:01 15:48 build clean. 2/2412019 2/24/2019 0.35 PROD1 DRILL DRLG P BOBD, 1.87 bpm @ 5,117 psi, 11,220.0 11,410.0 18:48 19:09 Diff=1,286 psi, WHP=371, BHP=4,059, IA=16, OA=96 2/24/2019 2/24/2019 0.40 PROD1 DRILL DRLG P Lower pump rate to drop angle, 1.5 11,410.0 11,446.0 19:09 19:33 bpm at 4,260 psi, WHP=413, BHP=4,080, IA=17, OA=98 2/24/2019 212412019 0.20 PROD1 DRILL WPRT P BHA wiper up hole,PUW 39 k 11,446.0 11,446.0 19:33 19:45 2/24/2019 2/24/2019 1.30 PROD1 DRILL DRLG P BOBD, 1.84 bpm at 5,022 psi, 11,446.0 11,604.0 19:45 21:03 Diff -1,238 psi, WHP=432, BHP=4,086, IA=22, OA=96 2124/2019 2/24/2019 0.20 PROD1 DRILL WPRT P BHA wiper up hole, PUW 40 k 11,604.0 11,604.0 21:03 21:15 2/24/2019 212412019 1.00 PROD1 DRILL DRLG P BOBD, 1.31 bpm at 3,559 psi, 11,604.0 11,676.0 21:15 22:15 Diff -609, BHP=4,107, IA=17, OA=100 2/24/2019 2/24/2019 1.25 PROD1 DRILL WPRT P TD L1 lateral 11,676', PUW 38 k, 11,676.0 9,274.0 22:15 23:30 Circulate 10x10 TD sweep, chase sweep to the window, perform 300'jog back in hole from 9,530'-9,830' 2124/2019 2125/2019 0.50 PROD1 DRILL WPRT P Jog the 7 inch, with 5x5 bbl sweep 9,274.0 9,274.0 23:30 00:00 9,246'-9,305' 2/25/2019 2125/2019 2.00 PROD1 DRILL WPRT P Continue swab wiper, performing 500' 9,274.0 78.3 00:00 02:00 jog back in hole from 1,000' 2/25/2019 2125/2019 1.65 PROM DRILL TRIP P Tag up, reset counters, RIH 78.3 9,055.0 02:00 03:39 2125/2019 2/25/2019 0.25 PROM DRILL DLOG P Log formation for depth control 9,055.0 9,257.5 03:39 03:54 correction of plus 7.0', RIH to above window 2/25/2019 2/25/2019 0.30 PROD1 DRILL TRIP P Perfrom static pressure survey above 9,257.5 9,257.5 03:54 04:12 window bit depth @ 9,297.54', Pressure sensor depth 6,242.21', 11.99 ppg/3,888 psi AP 2/25/2019 2/25/2019 1.00 PROD1 DRILL TRIP P Continue IH 9,257.5 11,676.0 04:12 05:12 2/25/2019 2/25/2019 1.40 PROM DRILL TRIP P Confirm TD 11,676', reciprocate pipe 11,676.0 11,592.0 05:12 06:36 while finishing liner running pill. 2125/2019 2125/2019 0.40 PROM DRILL DISP P Start Liner running pit down the coil, 11,592.0 11,671.0 06:36 07:00 1 1 1 112.29 pb, 50 We Page 7116 Report Printed: 4/312019 Operations Summary (with Tlmelog Depths) 3M-26 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Stan Depth Start Time End Time our (hr) Phase Op Code Acetify Code Time P -T -X Opemm (f loi) End Depth (WS) 2/25/2019 2/25/2019 2.60 PROD1 DRILL TRIP P POOH laying in liner running pill and 11,671.0 87.0 07:00 09:36 panting Flags 9668.34' Paint yellow TO flag 7178.26 'Paint white window flag TOP of liner running pit @ 8170' 2/2512019 2/25/2019 1.30 FROM DRILL PULD P Flow check, LD BHA #4 over a dead 87.0 0.0 09:36 10:54 well. Pull checks and rebuild. Check pipe, 0.133, 0.175, 0.175, 0.176" @ A,B,C,D respectivety.ODS, Reel, etc. Bit graded out 1-2-bt-s-x-i-nr-td 2/2512019 2125/2019 3.30 COMM CASING PUTB P Prep floor for running Lower L1 0.0 2,034.7 10:54 14:12 completion, PU 65 joints L-80 2-3/8" 4.6 ppf slotted liner+ 2 pups ( 20.76) over a non ported bull nose under a shorty deployment sleeve, Liner length, 2033.5', LOA 2034.73' Clear floor of liner running equipment. 2/25/2019 2/25/2019 0.50 COMPZ1 CASING RGRP P Complete injector inspection / maint 2,034.7 2,034.7 14:12 14:42 2/25/2019 2125/2019 0.90 COMPZ1 CASING PULD P PU BHA#5, Baker GS under Coil 2,034.7 2,080.0 14:42 15:36 Trak, Stab shorty, Inspect pack offs, replace checks, stab injector, bump up 2/25/2019 2/2512019 1.20 COMPZI CASING RUNL P RIH W liner 2,080.0 9,190.0 15:36 16:48 1 2/25/2019 2/25/2019 0.20 COMPZ1 CASING DLOG P PU Wt 35 k lbs, Tie into window flag 9,190.0 9,184.2 1648 17:00 for+1.16' 2/25/2019 2/2511019 1.20 COMPZ1 CASING RUNL P Continue to RIH with Lt lower 9,184.2 11,676.0 17:00 18:12 completion. Drive by HRZ for+0.5' correction. Land completion, PU 46 k lbs, RBIH stack 5 k WOB, 1.5 bpm, CT 3000 psi, PU 30 k lbs, letf liner on bottom. 2125/2019 2/25/2019 1.70 COMPZ1 CASING TRIP P PUH, park and reset counters to 11,676.0 96.0 18:12 19:54 1 1 account for dropping off liner. 2/25/2019 2/25/2019 0.40 COMPZ1 CASING PULD P Flow check well, LD BHA over a dead 96.0 0.0 19:54 20:18 1 well. 2/2512019 2/25/2019 0.80 COMPZ1 CASING PULD P PU Anchored billet, MU BHA 0.0 47.6 20:18 21:06 212512019 2/25/2019 1.90 COMPZ1 CASING TRIP P RIH, with anchor billet, BHA #6 47.6 9,046.0 21:06 23:00 2125/2019 2125/2019 0.20 COMPZ1 CASING DLOG P Tie into the HRZ for +8.5' correction 9,046.0 9,089.0 23:00 23:12 212512019 2125/2019 0.50 COMPZ1 CASING RUNL P Continue to RIH to 9259', PU Wt 35 k 9,089.0 9,637.0 23:12 23:42 lbs, close EDC, Run throug hwindow, clean, tag TOL @ 9637' SID 2 k WOB, PU to neutral weight, on line with the pump, shear @ 2300 psi, WOB 4.6 k 2/25/2019 2/26/2019 0.30 COMPZ1 CASING TRIP P PU Wt 33 Ibs, POOH 9,637.0 9,297.0 23:42 00:00 2/26/2019 2/26/2019 1.40 COMPZ1 CASING TRIP P Continue POOH 9,297.0 72.2 00:00 01:24 2/26/2019 2/26/2019 0.70 COMPZI CASING PULD P PJSM, LD setting tools on a dead well 72.2 0.0 01:24 02:06 2/26/2019 2/26/2019 0.75 PROD2 DRILL CTOP P PU Test Joint, perform function test 0.0 0.0 02:06 02:51 2/26/2019 2/26/2019 1.40 PROD2 DRILL PULD P PJSM PU L1-01 lateral drilling 0.0 72.2 02:51 04:15 assembly 2/26/2019 2126/2019 1.55 PROD2 DRILL TRIP P RIH, with build assembly 72.2 9,040.0 04:15 05:48 2/26/2019 2/26/2019 0.20 PROD2 DRILL DLOG P Log formation correction of plus 5.5' 9,040.0 9,087.0 05:48 06:00 Page 8116 Report Printed: 413/2019 Operations Summary (with Timelog Depths) 3M-26 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Stan Depth Star) Time End Time our (hr) Phase Op Code Activity came Time P -T -X Operation (flKB) End Depth (ftKB) 2/26/2019 2/26/2019 1.20 PROD2 DRILL DISP P Continue IH, displacing well to drilling 9,087.0 9,300.0 06:00 07:12 fluid 2/26/2019 2126/2019 0.30 PROD2 DRILL TRIP P RIH, dry tag TOB @ 9,625.5', PUH 9,300.0 9,625.5 07:12 07:30 obtain pump parameters 2/26/2019 2/26/2019 0.90 PROD2 DRILL KOST P Kickoff billet, 1.85 bpm at 4,386 psi, 9,625.5 9,626.5 07:30 08:24 Diff --530 psi, WHP=276, BHP=4,012, IA=24, OA=31, time mill 1 ft/hr 2/26/2019 2126/2019 0.50 PROW DRILL KOST P Time mill 2 ft/hr, 1.86 bpm at 4,386 9,626.5 9,627.5 08:24 08:54 psi, Diff=503, WHP=280, BHP=4005, IA=24, OA=28 2/26/2019 2126/2019 0.20 PROD2 DRILL KOST P Time mill 3 ft/hr, 1.86 bpm at 4,386 9,627.5 9,627.8 08:54 09:06 psi, Diff=501, WHP=283, BHP=3994, IA=24, OA=28 2/26/2019 2/2612019 0.15 PROD2 DRILL KOST T Stall Motor, PUH, stuck on bottom, 9,627.8 9,627.8 09:06 09:15 work pipe no movement, notify Town Team 2/26/2019 2/2612019 3.00 PROD2 DRILL OTHR T Bring pump online obtain pump 9,627.8 9,627.8 09:15 12:15 parameters, rotate TF between HS and 90° ROHS, work pipe no movement. 0.5 bpm/ DP=549i/CTP=2,569 1.0 bpm/DP=1,053/CTP=3,429 1.5 bpm/DP=2,0671CTP=4,756 1.8 bpm/DP=2,155/CTP=6,155 2/26/2019 2/26/2019 0.50 PROD2 DRILL OTHR T Circulate 5x5 sweep around, work 9,627.8 9,627.8 12:15 12:45 pipe 53 k, minus 15 k DHWOB, rotate TF to the left without much resistance, can not rotate TF right when pumping any rate. with low rate 0.69 bpm, it will rotate to the right with high amps. MU high lube high vis pill. 2/26/2019 2/2612019 0.85 PROD2 DRILL OTHR T Circulate High lube pill down coil, work 9,627.8 9,627.8 12:45 13:36 pipe 90° ROHS, move up hole 7.0', continue circulating lube pill down coil. 2/26/2019 2126/2019 0.50 PROD2 DRILL OTHR T Shut down and let soak, worked pipe 9,627.8 9,627.8 13:36 14:06 with a 90° LOHS, 53 k to -7.5 k, pulled free in lention. 2/26/2019 2/26/2019 0.30 PROD2 DRILL TRIP T POOH, with HS TF 9,627.8 9,340.0 14:06 14:24 2126/2019 2/26/2019 0.20 PROD2 DRILL DLOG T Log RA marker correction of plus 3.0' 9,340.0 9,356.0 14:24 14:36 2/26/2019 2/26/2019 0.30 PROD2 DRILL TRIP T POOH, jog the 7 inch clean 9,356.0 9,246.0 14:36 14:54 2/26/2019 2/26/2019 1.80 PROD2 DRILL TRIP T Continue POOH 9,246.0 72.2 14:54 16:42 2126/2019 2126/2019 1.00 PROD2 DRILL PULD T PUD, kickoff/drilling BHA#7 72.2 0.0 16:42 17:42 2126/2019 2/2612019 1.30 PROD2 DRILL OTHR T Inspect BHA/ Motor/ Bit / FVS. Prep 0.0 0.0 17:42 19:00 anchor billet to run 2/26/2019 2/26/2019 2.00 PROD2 DRILL PULD T PJSM, PD BHA #8 Open hole anchor/ 0.0 81.3 19:00 21:00 Billet. M/U to CT and surface test - Good. Stab on. QTS will not test. Unstab and replace O -Rings. run surface test and stab on. Tag up and set counters 2/26/2019 2/2612019 2.10 PROD2 DRILL TRIP T Trip in hole, EDC open 81.3 9,060.0 21:00 23:06 2/26/2019 2/26/2019 0.20 PROD2 DRILL DLOG T Log Gamma tie in for +4'correction 9,060.0 9,098.0 23:06 23:18 2/2612019 2/26/2019 0.40 PROD2 DRILL TRIP T Continue in well. Close EDC @ 9261', 9,098.0 9,621.0 23:18 23:42 PUW=33K Page 9116 Report Printed: 4/312019 . Operations Summary (with Timelog Depths) 3M-26 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Depth Steri End Time Our(hr) Phase Op Code Activity Code Time P -T -X Operation (Wls) End Depth (10(13) 2/26/2019 2/26/2019 0.20 PROD2 DRILL TRIP T Tag Billet #1 @ 9621.66 with 1.3K 9,621.0 9,629.3 23:42 23:54 DHWOB. Push down and observe movement. Get to 9629.3 with 3.1K DHWOB. Pull slack out of CT 9626.9' oriented to 30' ROHS. Pumps on .5 BPM. Observe tool shift @ 3950 PSI. Push down 2K. Looks good Estimate TOB @ 9606.5' 2/26/2019 2/27/2019 0.10 PROD2 DRILL TRIP T Trip out of hole after setting anchor 9,629.3 9,550.0 23:54 00:00 billet#2 2/27/2019 2/27/2019 1.80 PROD2 DRILL TRIP T Continue trip out after setting ON 9,550.0 86.0 00:00 01:48 anchored billet #2 2/27/2019 2/27/2019 1.30 PROD2 DRILL PULD T At surface, Tag up and space out. 86.0 0.0 01:48 03:06 PUD BHA #8 billet set. 2/27/2019 2/27/2019 1.00 PROD2 DRILL PULD T PD BHA# 9 with 2'AKO motor and 0.0 72.2 03:06 04:06 RR HCC Bi center with Dynamus cutters. Make up to coil and surface test 2/27/2019 2/27/2019 1.70 PROD2 DRILL TRIP T Trip in hole BHA #9 72.2 9,040.0 04:06 05:48 2/27/2019 2/27/2019 0.20 PROD2 DRILL DLOG T Log formation connection of plus 5.0' 9,040.0 9,074.0 05:48 06:00 2/27/2019 2/27/2019 0.35 PROD2 DRILL TRIP T Continue IH, dry tag TOB at 9,608' 9,074.0 9,608.0 06:00 06:21 2/27/2019 2/27/2019 0.15 PROD2 DRILL TRIP T PUH PUW 34 k, obtain pump 9,608.0 9,608.0 06:21 06:30 pressures 2127/2019 2/27/2019 1.00 PROD2 DRILL KOST T Mill 1fph, 1.85 bpm at 4,445 psi, 9,608.0 9,609.0 06:30 07:30 Diff -530, WHP=258, BHP=3,963, IA=17, OA=21 2/27/2019 2/27/2019 0.90 PROD2 DRILL KOST T Mill 21ph, 1.85 bpm at 4,490 psi, 9,609.0 9,611.0 07:30 08:24 Diff=530, WHP=258, BHP=3,963, IA=17, OA=21 "Note: stacking surface weight, pump 5 bbl lube (2.5%/2.5%) pill, continue milling ahead gaining 2.0 k surface weight with pill. 2/27/2019 2/27/2019 0.15 PROD2 DRILL KOST T PUH, PUW 33 k, restart with lube pill 9,611.0 9,611.0 08:24 08:33 exiting bit 2/27/2019 2/27/2019 0.50 PROD2 DRILL KOST P Mill 1-2 f fph, 1.85 bpm at 4,490 psi, 9,611.0 9,612.0 08:33 09:03 Diff --530, WHP=258, BHP=3,963, IA=17, OA=21 2/27/2019 2/27/2019 1.00 PROD2 DRILL KOST P Time mill 10 ft/hr, 1.85 bpm at 4,490 9,612.0 9,665.0 09:03 10:03 psi, Diff --530, WHP=258, BHP=3,963, IA=17, OA=21 2/27/2019 2/27/2019 0.20 PROD2 DRILL KOST P PUH for dry drift, PUW 34 k 9,665.0 9,665.0 10:03 10:15 2/27/2019 2/27/2019 2.25 PROD2 DRILL DRLG P Drill ahead, 1.85 bpm at 4,595 psi, 9,665.0 9,808.0 10:15 12:30 DI"- 76, WHP=418, BHP=4,006, IA=23, OA=27, TD Build Section 2 it above plan "' Note: Avg DGLS 32.13- 2/27/2019 2/27/2019 0.50 PROD2 DRILL WPRT P Wiper up hole into casing, jog 71nch 9,808.0 9,235.0 12:30 13:00 clean 9,236-9,300'w/sweep 2/27/2019 2/27/2019 1.50 PROD2 DRILL TRIP P Open EDC, POOH pumping 1.85 bpm 9,235.0 78.2 13:00 14:30 at 3,742 psi, following MP 2127/2019 2/27/2019 1.00 PROD2 DRILL PULD P At surface, spaceout, PUD build 78.2 0.0 14:30 15:30 assembly 2/27/2019 2/272019 1.10 PROD2 DRILL PULD P PU/PD, L1-01 Lateral drilling 0.0 80.3 15:30 16:36 assembly 2/27/2019 2/27/2019 1.70 PROD2 DRILL TRIP P RIH, Surface test agitator 1.8 BPM @ 80.3 9,055.0 16:36 18:18 5244 PSI FS, - 1500 PSI Diff Page 10116 ReportPrinted: 413/2019 . Operations Summary (with `fimelog Depths) 3M-26 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log start Depth StartTune End Time our (hr) Phase Op Code Activity Code Time P -T -X Operation (ma) End Depth (MB) 2/27/2019 2/27/2019 0.10 PROM DRILL DLOG P Log gamma tie in for +4.5'correction 9,055.0 9,084.0 18:18 18:24 2/27/2019 2127/2019 0.50 PROM DRILL TRIP P Continue in hole. Clean pass through 9,084.0 9,808.0 18:24 18:54 window. Tag up @ 9808' 2/27/2019 2/27/2019 0.90 PROD2 DRILL DRLG P 9808', Drill, 1.8 BPM @ 5196 PSI FS, 9,808.0 9,928.0 18:54 19:48 BHP=3990 2/27/2019 2/27/2019 0.10 PROD2 DRILL WPRT P BHA wiper, PUW=32K 9,928.0 9,928.0 19:48 19:54 2/27/2019 227/2019 3.40 PROD2 DRILL DRLG P 9928', Drill, 1.8 BPM @ 5049 PSI FS, 9,928.0 10,208.0 19:54 23:18 BHP -3995 2/27/2019 2/27/2019 0.50 PROM DRILL WPRT P Wiper trip to 9810 with 5 X 5sweeps, 10,208.0 10,208.0 23:18 23:48 PUW=36K 2/27/2019 2/28/2019 0.20 PROD2 DRILL DRLG P 10,208', Drill 1.8 BPM @ 5109 PSI 10,208.0 10,233.0 23:48 00:00 FS, BHP=3992 2/28/2019 2/28/2019 3.70 PROD2 DRILL DRLG P 10,233 Drill, 1.8 BPM @ 5110 PSI FS, 10,233.0 10,529.0 00:00 03:42 BHP=4031 2/28/2019 2/28/2019 0.10 PROD2 DRILL WPRT P Pull BHA Wiper, PUW=35K 10,529.0 10,529.0 03:42 03:48 228/2019 2/28/2019 0.70 PROD2 DRILL DRLG P 10,529', Drill, 1.8 BPM @ 5386 PSI 10,529.0 10,552.0 03:48 04:30 FS, BHP=3993, RIW=3K, DHWOB=3K 2/28/2019 2/28/2019 0.10 PROD2 DRILL WPRT P BHA Wiper, PUW=38K, RIW=8.8K 10,552.0 10,552.0 04:30 04:36 2/28/2019 2/28/2019 1.00 PROD2 DRILL DRLG P 10552', Drill 1.79 BPM @ 5393 PSI 10,552.0 10,577.8 04:36 05:36 FS, BHP=4020 2/28/2019 2/28/2019 1.00 PROM DRILL WPRT P Wiper up hole into the casing 10,577.8 9,246.0 05:36 06:36 w/sweeps 2/28/2019 228/2019 0.50 PROD2 DRILL WPRT P Pull through window, jog 7inch, 9,246.0 9,055.0 06:36 07:06 excessive cutting on sharker, continue jogging, PUH for tie in. 2/28/2019 2/28/2019 0.20 PROD2 DRILL DLOG P Log HRZ correction of plus 2.5' 9,055.0 9,096.4 07:06 07:18 2/28/2019 2/28/2019 0.60 PROD2 DRILL TRIP T RIH, set down bottom of the window 9,096.4 9,320.0 07:18 07:54 9,320'x 3 2/28/2019 2/28/2019 1.30 PROM DRILL WPRT T Discuss with town team, decision was 9,320.0 9,246.0 07:54 09:12 made to POOH for cleanout BHA, continue jogging 7" clean w/sweeps 2/28/2019 2/28/2019 1.80 PROD2 DRILL TRIP T POOH, performing 500' jogs at 9,246.0 80.3 09:12 11:00 7,000', 5,000', 3,500', 2/28/2019 2/28/2019 1.50 PROD2 DRILL PULD T Al surface, space out, PUD and LD 80.3 0.0 11:00 12:30 drilling assembly BHA#10 2/28/2019 2282019 1.60 PROD2 DRILL PULD T PU/PD, cleanout assembly 0.0 62.4 12:30 14:06 228/2019 2/28/2019 1.70 PROD2 DRILL TRIP T RIH 62.4 9,040.0 14:06 15:48 228/2019 228/2019 0.20 PROD2 DRILL DLOG T Log formation (HRZ) correction of plus 9,040.0 9,067.0 15:48 16:00 2.0', close EDC 2/28/2019 2/28/2019 1.00 PROD2 DRILL TRIP T Continue IH, dry tag 9,320.5', PUH 9,067.0 9,320.0 16:00 17:00 bring pump online 1.81 bpm at 4,382 psi, Diff --466, WHP=255, BHP=3,940, IA=22, OA=45 2/28/2019 2/28/2019 0.70 PROD2 DRILL WPRT T Wash down towards 9,900', Stack @ 9,320.0 9,900.0 17:00 17:42 9326, 9410, 9415, & 9436 228/2019 2/28/2019 3.30 PROD2 DRILL TRIP T 9900', Pump 5 X 5 sweeps trip out 9,900.0 68.0 17:42 21:00 pumping 1.8 BPM, Jog 7" with additional sweeps. Jog @ 5000', 1000', and surface. 2/28/2019 2/28/2019 1.00 PROD2 DRILL PULD T Tag up space out. PJSM PUD clean 68.0 0.0 21:00 22:00 out BHA#11. D-331 out @ 2.79 No Go Page 11116 ReportPrinted: 4/312019 Operations Summary (with Timelog Depths) 3M-26 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log scan cepm Stan Time End Time Our (hr) Phase Op Code Activity Code Time RT -X Operetlon (MB) End Depth (WO) 2128/2019 2/28/2019 1.60 PROD2 STK PULD T PJSM, M/U and PD BHA#12 OR 0.0 72.7 22:00 2336 anchor billet. make up to coil and surface test 2/28/2019 3/1/2019 0.40 PROD2 STK TRIP T Trip in hole BHA#12 72.7 2,145.0 23:36 00:00 3/12019 3/1/2019 1.40 PROD2 STK TRIP T Continue in BHA#12 OH Anchor billet, 2,145.0 9,054.0 00:00 01:24 EDC open pumping min rate 3/1/2019 311/2019 0.20 PROD2 STK DLOG T Log gamma tie in for+ 3.5' 9,054.0 9,094.0 01:24 01:36 3/1/2019 3/1/2019 0.60 PROM STK TRIP T Continue in with OH anchor billet. 9,094.0 9,716.8 01:36 0212 Stop at 9277 close EDC. PUW=32.5K. Continue in. Clean pass through window set down @ 9343'. P/U work pipe down. Cleared up past 9355. Continue into set depth @ 9716.75 3/1/2019 3112019 0.10 PROD2 STK WPST T 9716.8. At set depth. Pull slack out of 9,716.8 9,716.8 02:12 02:18 CT Orient to 180° ROHS. Bring pumps on @.5 BPM. See tool shift @ 3800 PSI. Set down 2.51K. Looks good 3112019 3/1/2019 1.90 PROD2 STK TRIP T Trip out with setting tools. Open EDC 9,716.8 68.0 02:18 04:12 @ 9293 3/1/2019 311/2019 1.50 PROD2 STK PULD T Tag up and space out. PJSM PUD 68.0 0.0 04:12 05:42 BHA#12 billet setting tools 3/1/2019 3/1/2019 1.50 PROD2 STK PULD P PD, kickoff/build assembly 0.0 72.2 0542 0712 3/1/2019 3/1/2019 1.70 PROD2 STK TRIP P RIH, with Lt -01 build assembly BHA 72.2 9,040.0 07:12 08:54 #13 3/1/2019 3/1/2019 0.20 PROD2 STK DLOG P Log formation correction of plus, 9,040.0 9,068.0 08:54 09:06 Close EDC 3/1/2019 3/1/2019 0.30 PROD2 STK TRIP P Continue IH 9,068.0 9,704.0 09:06 09:24 3/12019 3/1/2019 0.20 PROM STK TRIP P Dry tag TOB, PUH obtain pump 9,704.0 9,703.0 09:24 09:36 pressures 3/12019 3112019 1.00 PROD2 STK KOST P Time mill 1 ft, 1.86 bpm at 4,586 psi, 9,703.0 9,704.0 09:36 10:36 Diff --520, WHP=237, BHP=3,953, IA=22, OA=24 3/1/2019 3/1/2019 0.75 PROD2 STK KOST P Time mill 2 ft, 1.86 bpm at 4,586 psi, 9,704.0 9,705.0 10:36 11:21 Diff -520, WHP=237, BHP=3,953, IA=35, OA=24 3/1/2019 311/2019 0.75 PROD2 STK KOST P Time mill 3 ft, 1.86 bpm at 4,586 psi, 9,705.0 9,706.0 11:21 12:06 Diff --620, WHP=237, BHP=3,953, IA=42, OA=58 3/1/2019 3/1/2019 1.50 PROM DRILL DRUG P Drill ahead, 1.85 bpm at 4,586 psi, 9,706.0 9,898.0 12:06 13:36 Diff -532, WHP=242, BHP=4,001, IA=51, 01 3/12019 311/2019 0.20 PROD2 DRILL WPRT P PUH, dry drift kickoff point clean 9,898.0 9,675.0 13:36 13:48 3/12019 3/1/2019 0.20 PROD2 DRILL WPRT P Wiper back in hole, RIW 13 k 9,675.0 9,898.0 13:48 14:00 3/1/2019 3/1/2019 1.25 PROD2 DRILL DRLG P BOBO, 1.85 bpm at 4,586 psi, 9,898.0 9,965.0 14:00 15:15 Diff -532, WHP=242, BHP=4,001, IA=51, OA=102 3/1/2019 3/1/2019 0.25 PROM DRILL WPRT P TD, build section, pull wiper to the 9,965.0 9,246.0 15:15 15:30 casing w/5x5 sweep 3/1/2019 3/1/2019 0.10 PROD2 DRILL WPRT P Pull through window, jog 7Inch x 2 9,246.0 9,300.0 15:30 15:36 with sweeps 3/1/2019 311/2019 1.50 PROD2 DRILL TRIP P POOH, with closed EDC pumping9,300.0 72.2 15:36 17:06 1.87 bpm at 4,613 psi, Diff=547, following MP, performing jogs at 3,500' and 1,000' 3/1/2019 3/1/2019 1.70 PROM DRILL PULD P PUD, build assembly 72.2 0.0 17:06 18:48 Page 12116 ReportPrinted: 4/3/2019 Operations Summary (with Timelog Depths) 3M-26 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Stad Depth Starl TIM I End Time our (hr) Phase Op code Activity Code Time P -T -x Operation (ftKB) End Depth (SMB) 3/1/2019 3/1/2019 0.40 PROD2 DRILL SVRG P Make up drillers side PDL and 0.0 0.0 18:48 19:12 pressure test - Good. Rack back DS PDL 3/1/2019 3/1/2019 1.10 PROD2 DRILL PULD P M/U and Pd BHA#14 with .5° fixed 0.0 80.2 19:12 20:18 bend iron side motor and rebuilt HYC Bi center 3211 M -A2 bit. make up to coil and surface test. Tag up and set counters 3/1/2019 3/12019 1.80 PROD2 DRILL TRIP P Trip in hole BHA#14. Surface test 80.2 9,050.0 20:18 22:06 agitator @ 513' 3/1/2019 3/1/2019 0.20 PROD2 DRILL DLOG P Log gamma tie in for +35. PUW=33k 9,050.0 9,252.0 22:06 22:18 3/1/2019 3112019 0.30 PROD2 DRILL TRIP P Continue in well. Clean trip through 9,252.0 9,968.0 22:18 22:36 window and past 8347' 3/1/2019 3/2/2019 1.40 PROD2 DRILL DRLG P 9968', Drill. 1.8 BPM @ 5282 PSI FS, 9,968.0 10,017.0 22:36 00:00 BHP=4043 3/22019 3/22019 0.50 PROD2 DRILL DRLG P 10017', Drill ahead, 1.8 BPM @ 5297 10,017.0 10,037.0 00:00 00:30 PSI FS, BHP=4010 3212019 32/2019 0.10 PROD2 DRILL WPRT P P/U to get pressures for reduced 10,037.0 10,037.0 00:30 00:36 pump rate, Very high downhole vibrations 3/22019 31212019 0.90 PROD2 DRILL DRLG P 10037 Drill 1.65 BPM @ 4720 PSI FS, 10,037.0 10,054.0 00:36 01:30 BHP=4018. Low ROP with low differential 2K DHWOB 3/2/2019 3/2/2019 0.70 PROD2 DRILL DRLG P Unable to get differential pressure. Try 10,054.0 10,056.0 01:30 02:12 to stall motor. Vibration dropped to zero Pump sweeps 312/2019 3/2/2019 2.60 PROD2 DRILL TRIP T Trip out chaseing sweeps, 1.81 BPM 10,056.0 85.0 02:12 04:48 @ 5332 PSI FS. PUW=32K. Pre load Drillers side PDL 3/212019 3/2/2019 0.50 PROD2 DRILL PULD T A surface, Tag up and space out. 85.0 85.0 04:48 05:18 PJSM PUD BHA#14 32/2019 3/22019 0.50 PROD2 DRILL RGRP T On step #46 Roll chains "In the hole 85.0 85.0 05:18 05:48 direction", were unable to move chains, shut down operations, PJSM for planforward. 3/2/2019 3/2/2019 2.50 PROD2 DRILL RGRP T Inspect INJH, found half on bearing, 85.0 85.0 05:48 08:18 continue searching for second half, looks like there could be something in idler bearing. work chains to free up. remove few gripper blocks, plan toward is to pull chain link 32/2019 3122019 2.70 PROD2 DRILL RGRP T PJSM, pull link out of chain, inspect 85.0 85.0 08:18 11:00 for parts, couldn't locate any, put chain back together. 3/2/2019 3/2/2019 0.50 PROD2 DRILL RGRP T With gripper blocks removerd partially, 85.0 85.0 11:00 11:30 strip up INJH, re -install gripper blocks.secure coiled tubing 3/2/2019 3/2/2019 1.50 PROD2 DRILL PULD T PUD, Drilling assembly BHA#14, 85.0 0.0 11:30 13:00 inspect BHI, motor has failed. LD Tools 322019 3/2/2019 2.00 PROD2 DRILL PULD T Continue Inspecting drilling BHA, 0.0 0.0 13:00 15:00 break tools down in mouse hole, BHI CoilTrak tools, MU and suck up BHA #15 into lubricator. 3/212019 3/2/2019 3.00 PROD2 DRILL RGRP T Continue inspecting INJH, take INJH 0.0 0.0 15:00 18:00 chain apart, found broken chain bearing in sproket, MU injector chain 3/2/2019 3122019 1.50 PROD2 DRILL RGRP T Injector ready to go. Install nozzle run 0.0 0.0 18:00 19:30 pipe down for inspection. Trim 12' for coil deformation and rehead. NAD NPT 10 Hrs. Page 13116 Report Printed: 4/312019 Operations Summary (with Timelog Depths) 3M-26 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time our (hr) Phase Op Code Activity Code Time P -T -X Operation (Mil) End Depth (WB) 3/2/2019 3/2/2019 2.00 PROD2 DRILL PULD T Prep floor PJSM M/U BHA# 15 0.0 78.3 19:30 21:30 with .8° AKO BHI motor, Agitator, and RB HCC TX25207 bit with dynamus cutters. PD. M/U to coil and surface test 3/2/2019 3/2/2019 1.30 PROM DRILL TRIP T Trip in hole. Stop at 500' PUH 300 and 78.3 4,236.0 21:30 22:48 inspect pipe with hands on injector. Good. trip in and test agitator @ 800' 3/2/2019 3/2/2019 0.20 PROD2 DRILL TRIP T Stop. PUH inspecting pipe, gripper 4,236.0 4,070.0 22:48 23:00 1 blocks, and chains. All good 3/2/2019 3/2/2019 0.70 PROM DRILL TRIP T Continue in well. 4,070.0 9,045.0 23:00 23:42 3/2/2019 3/2/2019 0.10 PROD2 DRILL DLOG T Log gamma tie in for+4' 9,045.0 9,084.0 23:42 23:48 31212019 3/3/2019 0.20 PROD2 DRILL TRIP T Continue in well. Pull weight check @ 9,084.0 9,252.0 23:48 00:00 9263 34K 3/3/2019 3/3/2019 0.40 PROD2 DRILL TRIP T Continue in well, Clean pass through 9,252.0 10,053.0 00:00 00:24 window and past billets 3/3/2019 3/3/2019 1.30 PROD2 DRILL DRLG P 10053', Drill, 1.8 BPM @ 5218 PSI 10,053.0 10,215.0 00:24 01:42 FS, BHP=4029, RIW=12.5K, DHWOB=2.1K, ROP=120FPH 3/3/2019 MOM 1.10 PROD2 DRILL WPRT P Wiper trip (Geo wiper), PUW=42K 10,215.0 10,215.0 01:42 02:48 3/3/2019 3/3/2019 1.50 PROD2 DRILL DRLG P 10245', Drill, 1.8 BPM @ 5204 PSI 10,215.0 10,311.0 02:48 04:18 FS, Trouble getting going. Hole taking fluid on bottom. Pick ups sticky 3/3/2019 3/3/2019 0.10 PROD2 DRILL WPRT P Pull BHA wiper up past 10215. 10,311.0 10,311.0 04:18 04:24 PUW=34K. Slight bobble RIH past 10215 3/3/2019 3/3/2019 0.75 PROD2 DRILL DRLG P 10311', Drill, 1.8 BPM @ 5227 PSI FS, 10,311.0 10,374.0 04:24 05:09 BHP=4093, RIW=12.3 313/2019 3/3/2019 0.25 PROM DRILL WPRT P Short Geo wiper up hole to 10,312' 10,374.0 10,312.0 05:09 05:24 3/3/2019 3/3/2019 0.25 PROD2 DRILL WPRT P Wiper back in hole, RIW 12 k 10,312.0 10,374.0 05:24 05:39 3/3/2019 3/312019 1.00 PROM DRILL DRLG P BOBD, 1.8 bpm at 5,200 psi, 10,374.0 10,460.0 05:39 06:39 Diff --1,160 psi, WHP=243, BHP=4,059, IA=94, OA=122 3/3/2019 313/2019 0.15 PROD2 DRILL WPRT P Wiper up hole, PUW 35 k 10,460.0 9,994.0 06:39 06:48 3/3/2019 3/312019 0.15 PROD2 DRILL WPRT P Wiper back in hale, RIW 12 k 9,994.0 10,460.0 06:48 06:57 3/3/2019 3/3/2019 2.50 PROD2 DRILL DRLG P BOBD, 1.8 bpm at 5,543 psi, 10,460.0 10,638.0 06:57 09:27 Diff=1,400 psi, WHP=244, BHP=4,062, IA -95, OA=121 3/3/2019 3/3/2019 0.20 PROD2 DRILL WPRT P Short BHA wiper up hole, PUW 39 k 10,638.0 10,638.0 09:27 09:39 313/2019 3/3/2019 1.00 PROD2 DRILL DRLG P BOBD, 1.8 bpm at 5,543 psi, 10,638.0 10,730.0 09:39 10:39 Diff=1,400 psi, WHP=244, BHP=4,062, IA -95, OA=121 3/312019 3/3/2019 0.20 PROD2 DRILL WPRT P Short BHA wiper up hole, PUW 39 k 10,730.0 10,730.0 10:39 10:51 3/3/2019 3/3/2019 1.50 PROD2 DRILL DRLG P BOBD, 1.8 bpm at 5,543 psi, 10,730.0 10,860.0 10:51 12:21 Diff=1,400 psi, WHP=244, BHP=4,062, IA -95, OA=121 3/3/2019 3/3/2019 0.60 PROD2 DRILL WPRT P Wiper up hole to the window w/sweep, 10,860.0 9,300.0 12:21 12:57 1 1 PUW 37 k 3/312019 3/3/2019 0.30 PROD2 DRILL WPRT P Circulate bottoms up, while jogging 9,300.0 9,246.0 12:57 13:15 the 7inch. x 4 3/3/2019 31312019 0.15 PROD2 DRILL WPRT P RIH for tie in 9,246.0 9,340.0 13:15 13:24 I I Page 14116 Report Printed: 4/3/2019 Operations Summary (with Timei®g Depths) 3M-26 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Stan Depth Stan Time End Tore Dur (hr) Phase Op Code Activity Coae Time P-T-X Operation (WB) End DepM (Po(B) 3/3/2019 3/3/2019 0.20 PROD2 DRILL WPRT P RIH, log RA marker correction of plus 9,340.0 9,367.0 13:24 13:36 3.0' 3/3/2019 3/3/2019 0.60 PROD2 DRILL WPRT P Contiine wiper back in hole, RIW 14 k 9,367.0 10,860.0 13:36 14:12 3/312019 3/3/2019 1.00 PROD2 DRILL DRLG P BOBD, 1.8 bpm at 5,543 psi, 10,860.0 10,973.0 14:12 15:12 Diff=1,400 psi, WHP=244, BHP=4,062, IA-95, OA=121 3/312019 3/3/2019 1.00 PROD2 DRILL DRLG P OBD, 1.8 bpm at 5,543 psi, 10,973.0 11,070.0 15:12 16:12 Diff-1,400 psi, WHP=244, BHP=4,062, IA-95, 0A=1 21 3/3/2019 3/3/2019 1.20 PROD2 DRILL DRLG P OBD, 1.8 bpm at 5,543 psi, 11,070.0 11,126.0 16:12 17:24 Diff=1,400 psi, WHP=244, BHP=4,062, IA-95, OA=121. New mud at bit 11103' 3/3/2019 3/3/2019 0.40 PROD2 DRILL WPRT P BHA Wiper, PUW=39K, New mud 11,126.0 11,126.0 17:24 17:48 around obtain new baseline pressures, Have to work back to bottom 3/3/2019 3/312019 2.90 PROD2 DRILL DRLG P 11126', Drill, 1.84 BPM @ 5137 PSI 11,126.0 11,258.0 17:48 20:42 1 1 1 FS, BHP=4058 3/3/2019 3/3/2019 0.80 PROD2 DRILL WPRT P Wiper trip, PUW=37K, -600' 11,258.0 11,258.0 20:42 21:30 3/3/2019 3/4/2019 2.50 PROD2 DRILL DRLG P 11,258', Drill, 1.82 BPM @ 5147 PSI 11,258.0 11,319.0 21:30 00:00 FS, BHP=4103, RIW=5.4K, DHWOB=2.3K 3/4/2019 3/4/2019 2.90 PROD2 DRILL DRLG P 11319', Drill, 1.82 BPM Q 5147 PSI 11,319.0 11,395.0 00:00 02:54 FS, BHP=4105 3/4/2019 3/4/2019 3.20 PROD2 DRILL WPRT P 11395', Csll TD, Pump sweeps and 11,395.0 78.0 02:54 06:06 chase to swab, PUW=38K 3/42019 3/4/2019 2.00 PROD2 DRILL TRIP P Tag up, reset counters, RBIH 78.0 9,040.0 06:06 08:06 3/4/2019 3/4/2019 0.20 PROD2 DRILL DLOG P Log formation correction of plus 5.5' 9,040.0 9,087.0 08:06 08:18 3/412019 3/4/2019 1.20 PROD2 DRILL TRIP P Continue RIH 9,087.0 11,268.0 08:18 09:30 3/4/2019 3/4/2019 0.40 PROD2 DRILL TRIP P Work pipe past 11,268' with multiple 11,268.0 11,395.0 09:30 09:54 pump rates, rotate TF, past through area successfully (x8), continue IH 3/4/2019 3/4/2019 0.40 PROD2 DRILL CIRC P Confirm TD, circulate beaded LRP 11,395.0 11,395.0 09:54 10:18 down coil, recip coil, Note: Static Pressure Survey @ 9,303' CTMD, Sesor depth 6,246.41' TVD, 12.05 EQMW, WHP=961 3/4/2019 3/4/2019 2.75 PROD2 DRILL TRIP P POOH laying in beaded LRP up into 11,395.0 78.0 10:18 13:03 the casing and tubing up to 7,190' 3/4/2019 3/42019 0.50 PROD2 DRILL PULD P At surface, check well for flow, static 78.0 78.0 13:03 13:33 1 1 1 loss rate 0 3/4/2019 3/4/2019 0.60 PROD2 DRILL PULD P Flush/LD drilling assembly on a dead 78.0 0.0 13:33 14:09 well. 3/4/2019 3/4/2019 0.40 COMPZ2 CASING PULD P Prep RF for liner OPS, PJSM 0.0 0.0 14:09 14:33 3142019 3/4/2019 3.00 COMPZ2 CASING PUTB P Pickup Ll-01 liner assembly 0.0 2,175.0 14:33 17:33 3/4/2019 3/4/2019 1.20 COMPZ2 CASING PULD P PU/MU CoilTrak tools, surface test 2,175.0 2,219.2 17:33 18:45 (good) 3/4/2019 3/4/2019 1.30 COMPZ2 CASING RUNL P RIH w/1-1-01 2-3/8" slotted/solid liner 2,219.2 9,218.2 18:45 20:03 completion, shorty deployment sleeve, and non-ported bullnose. 3/4/2019 3/42019 0.15 COMPZ2 CASING RUNL P Correct to the EOP flag 0.5', PUW 36 9,218.2 9,218.7 20:03 20:12 k Page 15/16 Report Printed: 4/3/2019 . Operations Summary (with Timelog Depths) 3M-26 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Stan Time EM Time Dur(hr) Phase Op Code Activity Code Time P -T -X Opera6an Stan Oepm (WB) EM Depth W13) 3/4/2019 3/4/2019 1.20 COMPZ2 CASING RUNL P Continue IH 9,218.7 11,395.0 20:12 21:24 3/4/2019 3/4/2019 0.20 COMPZ2 CASING RUNL P Liner on bottom, bring pump on-line 11,395.0 9,197.0 21:24 21:36 1.5 bpm at 4,496 psi, 1.2 bpm returns, Diff -860 psi, PUW=30 k, 0 k DHWOB, Remove liner length from counters, TOL=9220' 3/4/2019 3/4/2019 0.50 COMPZ2 CASING RUNL P ***Obtain SBHP, 9,197' CTMD, 9,197.0 9,197.0 21:36 22:06 Sensor Depth=6192.04', AP=3,952, Mud Weight=12.27 ppg 3/4/2019 3/4/2019 1.40 DEMOB WHDBOP DISP P Displace well to SW 9,197.0 9,197.0 22:06 23:30 3/4/2019 3/5/2019 0.50 DEMOB WHDBOP TRIP P Trip out of well, PUW=28K 9,197.0 6,445.0 23:30 00:00 3/5/2019 3/5/2019 1.50 DEMOB WHDBOP TRIP P Continue tripping out, Pump 30 BBIs 6,445.0 54.0 00:00 01:30 diesel, Freeze protect tubing from 2500' 3/5/2019 3/5/2019 1.80 DEMOB WHDBOP PULD P At surface, Tag up and space out. 54.0 0.0 01:30 03:18 PUD BHA#16 Liner running tools 3/5/2019 3/5/2019 0.80 DEMOB WHDBOP CLEN P M/U nozzle stab on injector and flush 0.0 0.0 03:18 04:06 BOPE and rig surface lines 3/5/2019 3/5/2019 1.90 DEMOB WHDBOP CTOP P Break off injector, Vac stack in prep for 0.0 0.0 04:06 06:00 bore scope. Run bore scope inspection of stack. Pour methanol in tree 3/5/2019 3/5/2019 2.50 DEMOB MOVE MOB P Work rig down checklist. Blow down 0.0 0.0 06:00 08:30 TT line and unhook from rig. Off load last of fluid from pits. 3/5/2019 3/5/2019 1.50 DEMOB WHDBOP MOB P Tighten tree bolts - most bolts loose 0.0 0.0 08:30 10:00 3/5/2019 3/5/2019 3.00 DEMOB WHDBOP MOB P Nipple down BOPE stack. Lift and 0.0 0.0 10:00 13:00 I secure. Rig down putz. Secure injector and reel. Rig Release 13:00 Page 16/16 ReportPrinted: 4/3/2019 ConocoPhillips ConocoPhillips Alaska Inc_Kuparuk Kuparuk River Unit Kuparuk 3M Pad 3M -26L1-01 50-029-22431-61 Baker Hughes INTEQ Definitive Survey Report 20 March, 2019 BA ER F UGHES GE wmp m ConocoPllllips ConocoPhillips Definitive Survey Report System Damm: Oonn'w.. ConmeoPhllkps Alaska Inc Kuparuk Local Coordinate Reference: MU 3M-26 Praises: Kupamk River Unit NO Reference. 3M-26 ® 68.00us6 (3M-26) She: Kupamk 3M Pad MD Reference: 3M-26®68.00uss(314-26) Well: 3M-26 North Reference: True WIIIOOR: 3M-2611-01 Survey Calculation Method: Minimum Curvature Oes19n: 3M -26L1-01 Dabbase'. EDT 14 Alaska Production Prefect Kupamk River Unit, North Slope Alaska, United States Map System: US State Plane 1927 (Exact solution) System Damm: Geo Datum: NAD 1927 (NADCON CONDS) Map Zone: Alaska Zone 04 Well 3M.26 Well Patent .Wce 0.00 Left Northrop: .EI -W 0.00 usp Easuld, Position Uncertainty 000 uss Wellhead Elevation: Wellhmre 3M-261.1-01 Ma9netice Motlal Naar sample Ooh UGCM2016 4112019 Design 3M -26L1-01 Audit Notes: Version: 1.0 Phase: ACTUAL Vertical Section: Depth From (ND) (meal 6800 Mean Sae Level Using Well Reterena Paint Using 9emtleac scale room, 6,016.569.63usfl 606.224.s9usfl us% Te On output: 9 696.33 .N S ILanl 0.00 .PJ -W loaft) 0.00 �I�WHES Latkutle: 7O'27'23.296N Longitude: 149° 56' 55.644 W G...d Level: 0,00 usn Dip An& f) 60 93 Olreadin V) 30100 Field Saengm ren 5),424 3202019 2'23'41ti Page 2 COMPASS 6W0.14 &M S5O j*ID,4 Sundry Eltd Data, 2248019 2858019 288/2619 2888019 3148019 Anno19110n TIP KOP 3208019 2:23:461all,F Page 3 COMPASS 5000.14 Budd 05D ConocoPhillips C0n0cci illiilPS Definitive Survey Report Co.": ConocoPhillips Alaska Inc Kupamk Local Coordnate Reference: Well 3M-26 Project: KUPamk River Unit TVD Reference 311@611.001(3M-26) Shic Kupalnk 3M Pad MD Reference: Bali @66.0Dus0(3M-26) Well: 3101-26 North Reference True Walloon 3M-2611-01 Survey Calculation Method Minimum Curvature Oealge: 3M-261-1-01 Database: EDT 14 Alaska Production Sunday Program Date From To Survey (waft) (dealt) Survey WWII Tool Name Description mn Order 71.01 9,311.22 3M.26(3M-26)GCT-MS Schlum60rpr OCT mu0ishot 111512001 9,313.00 9,401 3M-26L1 MWD4NC(3M-261-1) MWD-INCONLY MWbINCONLY_FILLER 28412019 9,433.23 9,505.53 3M-26Li MM(3M-26L1) MWD MWD-Sherai 28512019 9,60000 9,635.67 3M-261-141PR1 MWD-INC(3M86L1-01 MW41NC_ONLY MWDINC ONLY FILLER 21262019 9,666.91 9,696.33 310-261.1-01PR1 MNN(3M-261-141P81 MWD MWD-Standard 2868019 9,703.00 11,36104 3M-26L1-01 MWD(314-2611-01) MWD MWD-Standard 314/2019 survey ftla MD luap Mc P) IkL TVD fl ImtB TVDSS form(um) a 4 aV.W (-am Nodding Ia86aB OLS 1.1100.) k� ft.. (t) (n) (,1ctiors 9.696.33 9.69633 94.52 347,01 6,31859 6,25059 Bem,u ",so 6023,Ire 86 SC6.350.36 3115 32415 MWUIS) 9.70807 9422 34907 631807 6250-09 6.643,15 87.61 6,02320238 50635609 3112 324570 MW➢(6) 9,]31.2] BBDO 34444 6,318,03 6207,03 6.670.63 81,14 6,@3229.07 506BWQ 3337 35505 MJrD I.) 9,]51,4] 0706 335]e 6319.86 6,25186 6,690.95 T.A. 6,023250.17 506,34012 2898 Battle MJUD(6) 9,791.n 89,11 328,40 6,320.07 62528] 6,]E 60 5671 68Y128489 596325,93 26.12 3313.]3 MINE (6) 9,SM83 88.03 31834 6321.43 6,5343 Broiler 38.20 6023309] 508,307.40 Mori 3.31 NAND (6) 9,052.37 90.18 308.15 6,32160 6,25360 (1 16.71 60283595 5116,20,90 3479 3.37082 MWD (6) 9,061.42 93.53 301 635,]4 6252.74 6.787.17 -7Y2 6,023,34632 507,26195 2626 3.39904 "D (8) 9.81139 94.95 29230 6,31862 6,25052 6000.$0 33.93 6.023.tlii 5M,23524 27,53 3,42965 MD (6) 9.9]]15 96.09 20256 6,316.04 6,248.04 6,800.25 -Som 6,023,36]35 50621002 38.65 3454.65 sm(6) 9,96969 372m 27556 6,3125 624426 6,81334 4624 61B337241 506.170.92 2165 3,48482 MWDIB) 9,999,17 94.18 25.28 630933 624133 6,816.11 -11944 60233815 5[6.140.]2 10. 3,51149 MWD(6) 10,0148 9243 271.01 6,30]4] 6,23947 6.61810 -15163 6,423.37112 505,117.53 1 ,dl 3,5403] MND(6) 10.07664 91 275.79 630562 6,23762 6,021P9 -196M 6,423380.07 Said 0M.52 B81 3,580.84 MND(6) 10 loom 9381 270.94 6,304.02 6230,42 662494 -226,40 6@3383.69 506,042.76 1125 3,60854 Novel (6) 10,131.13 9458 n2,24 6.302.24 6,23424 682942 -25035 6,02438035 50,016.81 1383 3.63152 BOND (6) 10 161,47 BO56 no 95 6307,07 6232.87 6,836.80 -279.]4 6, 0p, 39570 505989.42 1]9] 3.65066 ME j*ID,4 Sundry Eltd Data, 2248019 2858019 288/2619 2888019 3148019 Anno19110n TIP KOP 3208019 2:23:461all,F Page 3 COMPASS 5000.14 Budd 05D Survey Conocolphlllips ConocoP11ll1ps Defnitive Survey Report Map CompanyDonocoP6llllps Alaska Inc_Kugmk Local Coroonhnafe Reference: 'A1,11 3W26 Pta)eM: Kuparuk Riyer Unit T Reference: 368-26@68.00uafl(3M-26) Sita: Kupmuk 3M Pad MD Reference: 3M46 @ 68.00usn (3M-26) Well: 3M-26 North Refinance: True Wellbore: 310-26L141 Survey Calculation Method: Minimum CurvaWre D.ipn: 3M -26L1 -Dl Database EDT 14 Alaska Production Survey 9292019 2246PM Pape 4 eA, �nM�s Anr otellon COMPASS 5000.14 BuAE ilM Map Map wm..l MD Ix Ail TyD 7 S5 4WaS avm DI.S NortMn6 Eastn6 Season Survey Tool Name 168014 (7 (') (ian) (..ft) (uaf) (.M) (e) let 0e00•) (rt) 10,190m 8915 Islam 6300.79 6232.79 6,64537 J0754 602340425 505.96162 &65 3,68902 "D (6) 10.221.48 65.93 28381 630169 6233.69 6,85392 407.22 602341278 505.931.93 17.20 3719D1 Wall) (6) 10,251.17 85,9 2798.5 6.30364 6.23564 6,85994 256.5 6.413,41&76 505.902.92 1/68 3]4].13 MWD(6) 10,290]8 06.31 276.50 6305.72 6231.n 6.85409 1%. 6,023,42290 SW,65. 1095 3nl53 Ml (6) 10,311lit ... 273.23 6,30].]1 6,239.n 6,6... 426,00 6.23,425.64 605,641.15 1001 3,804.09 MWD(6) 10,341.35 Sam 2]12] 6,308,95 6,240.95 6,657,95 40,81 6,023.426.71 505 1111M 914 3828.72 Mal (6) 10.370.96 89.35 27324 6,309.55 6,241.56 6.669 485.39 6.023.427.62 50,183.5 5.11 3,854.80 MAD (6) 10.400.05 50.43 27535 6.309,62 6.241.62 6,87D.01 514.41 6A234M.52 50,154]4 1067 3.850.90 MAD (6) 10.435.61 93.94 218.46 6,309.5 8040.24 6,875.05 449.68 6023433.73 Ila 719.47 1337 3.813.56 MMA(6) 10.461,41 94.65 51.61 6,3W.5 8,238.28 6,87953 -51501 6,423436.19 50569414 1260 3.93],]4 Mhn(A) 10,4e]. 9510 2..11 630.1.13 6.23513 6,688,18 .1006 602$446.. 505,65908 12.38 3.9n.42 MND(6) 1055.94 92.15 2M.57 6,30138 6.23328 6,6..69 -637.95 6023,455.49 505,631.20 13.11 4,000.M MAD(6) 10,550.06 88J7 50.54 6,301.14 6,233.14 6907.31 -667.29 6,023,4... 505.801.85 13.69 4,031.54 MIND (6) 10,`015 85.85 293.00 6.30281 6,234.81 6,919.58 4{9&02 6 D 478.13 5055]1]1 10.62 4.054.5 MND(6) 10.621.43 87.30 59.17 6.304.62 6,25.62 6,932.84 42509 6 O491.5 505.544.03 20.94 4,064.36 MIND (6) 10,650.71 Win 301.92 6.306.14 6.236.14 6,941.69 -75027 605,5..20 505,518.04 957 4,123.. MID (6) 10,681.14 8&10 3..43 6.30.50 6,239.50 6,964.]] -775.41 G.m SSN 505.49369 15.46 4.153.91 MND I.) 10,710. 80.13 3..]] 6300.40 6,240.46 6962.90 -79696 6,0554136 505,4]0.13 7.. 4,18337 MJID(6) 10]41A7 85.82 31095 6.31005 6,242.05 7,00228 KC10 6,023 551n 685688.91 1a.N 4,213.17 MAID (6) 1,11136 88.92 31442 6,311.41 6,243A1 7,05]3 444.34 6,023.581.4 M5,424.n 15.18 4,24258 MAT) (6) 1068230 8052 318.M 6,311.56 6,243.56 7,04514 265.66 6,02360368 505.403.36 13.96 4,21225 WIND (6) 100..50 90.06 320.. 6.311.41 6,24341 1.071.03 -e58= 6.023.82941 5..3alm 401 4,304.55 "D (6) 10.5.91 91,10 3.. 631112 6243.12 7,094. E06.99 6@3.653.22 !kte 0.12 1113 4,33281 MO 1909.81 86.53 31249 6311.94 6243.95 7,12439 45.61 605..2.71 505.335.5 5.11 4,370.72 MA)(6) 10.935.57 M.75 30&24 6312.80 6,244.00 7,14313 455.39 6023701.44 505.31358 16.06 4,390.96 MAID (6) 10,963.5 88.71 304.31 6.31325 62455 7,159.64 4n.M 6,05.]1].93 505.5135 17.14 4,45,45 MAD (6) 10.991.00 ..08 290,93 6,313.79 6,245.79 7,174.18 -1,00121 6,.3.732.45 505,5].]4 19.44 4.454.16 MND(5) 11.0215 M.. 29339 6,31434 6,246.34 7,181.49 -1029.30 6,M,]45.]3 5.,240.64 10.68 4,48428 Main) (6) 11.01.01 06.69 288.13 6,314.93 6,2W.93 7.19019 -105611 6,@3,]..41 5..262 1563 4,513.71 MAD(6) 11,080.16 8906 55.21 6.31&45 6,24745 7,201 -1,003.90 6.5.764.69 505.184.95 12.09 4,542]0 MAD (6) 11.11046 90.24 281.34 6,315.0 6,247.60 ],213.[5 -1.11346 605.]]1.82 5.,155.6 13.43 4,57112 MAD (6) 9292019 2246PM Pape 4 eA, �nM�s Anr otellon COMPASS 5000.14 BuAE ilM ConocoPhillipsfl ConocoPhillips Definitive Surrey Report CetnWrry: Con000PhitBps Alaska lnc_Kuparvk Project Kuperuk River Unit SKe: Kuperuk 3M Rod Wall: 388-26 We0Ed2: 3M-261.1-01 Daly.: 3M -26L1-01 Survey Local Co-ordinate Reference: 24%11388-26 TVD Reference'. 3M-26 ® 60.00uu (3M-26) MD Reference: 3W6 @ 68.00usfl (3M-26) Nedh Reference: True Surrey calculation Method: Minimum Gurvature Database'. EDT 14 Kaska Production Annotation 410 19 2:2946PM Pane 5 COMPASS 5000. 14 Budd 80 Map Map Vertical MD Ind AL 118) TVDSS aWS �E/3N Nodhlny Eastlny OILS, Section Survey Tool Name latl 1°1 (1) lum" (USO) (eat) luarc) (t) In) (°1100.) It1 11,141.15 90.61 281.30 6.31535 624735 2,21968 -1,143.56 6023777/12 Sus 125 009 4,600.19 MWD (6) 11,9036 BB.31 284.04 6,315.62 6,24762 7226.06 -118.05 6,023.784.20 505,095.87 1225 464607 "D(6) 112']139] 8053 288]5 6,316.48 6248.40 7,234,85 -1,2pt84 6,023.792.94 505067.08 15.9 4,65624 MAD (6) 11,231.88 8505 2m.52 6,318.14 6,250.14 7,244.79 -12n,71 6f23.frot 505.039.20 lads 4,61 MVA)Rh 11,260.`39 81➢2 282.11 5,321.71 6,253.71 7,255.40 -1,256.91 6.023,81345 506.011.98 1471 4,716.22 MWD(S) 11,290.45 8156 2[6.11 6326.24 8,258.24 7,267.50 -1,203.94 68P.B2552 50 w"Is 13.32 4,745.67 MMU (6) 11,32650 81.40 Mr. 6,330.70 6,28220 7.28121 -1,310.29 6021,83621 504,950.60 9.13 4)75.35 MAD (6) 11,350.9 8170 301.54 6,335.07 8,267.07 7,238.4 -1.335.75 6p23854.01 504833.13 8.89 4.804.81 MWC(5) 11,351.04 8231 302.77 6.336.50 6.268.58 7,301,70 -1,344]6 6.023.859.67 504.924.11 12.28 4,01545 MAD (6) 11.395.00 B221 30227 6,341.10 6,273.18 731891 -137305 6,023,877.85 506895.81 0.88 4Mean PROJECTED to TO Annotation 410 19 2:2946PM Pane 5 COMPASS 5000. 14 Budd 80 ConocoPhillips ConocoPhillips Alaska Inc_Kuparuk Kuparuk River Unit Kuparuk 3M Pad 3M-26L1-01PB1 50-029-22431-70 Baker Hughes INTEQ Definitive Survey Report 20 March, 2019 �. ConocoPhillips W'IucNEs E, ConocoPhillips Definitive Survey Report Company: Cono,Philllps Alaska Inc Kupamk Project: Kuparuk River Unit She: Kupamk 3M Pad Well: 3M-26 Wellbore: 3M-26L1-Ot PBI Design: 3M-26Li-01 PBI proieq Kupamk River Unit North Slope Alaska, United States Map System: US State Plane 1927 (Exact solution) System Datum Geo Datum: NAD 1927 (NADCON CONUS) Map Zone: Alaska Zone 04 WeII 3M-26 Local Coordinate Reference: WeII 3M-26 WD Reverence: 3M-26 @ 611 (3M-26) MO Reference: 3M-26 @ 68 00usft (3M-261 North Reference: True Survey Calculation Method: Minimum Curvature Database: EDT 14 Alaska Production Well Position ANIS 0,00 usft Northing: .H -W 0.00 ush Easung: Position Uncertainty 600 usft Wellhead Elevation: Wellbore 31VI-2611-01PB1 Magnetics Model Name Sample Dune BGGM2018 41112019 Design 3M-26L1-01PBt Audit Notes: Version: 1.0 Phase: ACTUAL Vertical section: Depth From (WD) loan) 68.00 Mean Sea Level Using Well Reference Paint Using geodetic scale factor 6.016,559.83usft 506,274.89ush usft Declination 1') 1663 Latitude: Longitude: Ground Level: Dip Angle (1) 80.93 Te On Depth: 9,585 53 ♦Nt8 +E -W Direction (sent luaft) 1'I 0.00 000 20,00 70° 27 23,296 N 149` 56' 55.644 W 608 Icy Field strength (nn 57,424 3208019 2:W 44PM Page 2 COMPASS WOO. 14 Build 85D ConocoPhillips Fn 4 conoc4itillli In Definitive Survey Report Company. Cono.Philips Alaska Inc_Kupemk Local Coordinate Rekrence: Mil 3M-26 Profeq: Kupamk River Unit TVD Reference: 3M-26®68.00usfl(3M-26) Site Kupaimk 3M Pad MD Reference: 36111 WCOusift(31si Well: 3si North sustenance: Time Wellbore: 3ML26Lt-01PB1 Survey Calculation Mei Minimum Curvature Design'. 3M-26L1-01PB1 Oakbase: EDT 14 Alaska Production Survey P.Q.. Data F.. Ta Sunday Survey (-slay (-am Survey DVallbore) Tool Name D..d d.n Start Daft End Dak 71,01 9,311.22 3M.26 (3W26) GCT-MS Schlumbeger GCT multiii 111512001 9,313.00 9,02.68 3M-26L1 MWD4NC (31hi-26L1) MWD-INC ONLY MWAINC_ONLY _FILLER MV2019 2/242019 9,433.23 9,585.53 3M-26L1 MWD(3M-26L1) MWD MWD-Standard 2)2512019 2/2512019 9.608.00 9,635.67 311-260-01P81 MWD-INC(3M-201.1-01 MW41NC_ONLY MW0.1NC_ONLY _FILLER Willi V2812019 9.666.91 10,517.63 3M-261.1-0iPB1 MWD(3M-26L1-01PB1 MWD MVtl0.SkrWad 412812019 212812019 Survey Map Map Vertical MD (MND Info Y) AL TVD (1) (usf) 1VD55 di ♦6048 (..ft) +E/4N land) Northing Easting DI-5 Pltov) Section Survey Tool Name Mnr3lStion Ip 1111 DB 6585.53 95.0 319.85 6,328.02 fi26002 6,542.13 143.26 6,023101.42 560412.62 4.. fi196.59 MD TIP 9,608.00 94.34 318.0 6,326.10 6.258.10 6,559.09 128.65 6,023,1111,37 50539&00 7.26 6,207.53 MNOINC_ONLY (4) KOP7OB 9.605.67 9569 327,50 6.323.67 6.255.67 6,591.11 11211 6@3.140.37 505.361.45 3213 6,222.56 MWOINC ONLY (4) Iekryolated ASImuth 9.M.91 9446 337.81 6.320.90 6.252.90 6,608.71 97,84 6.@3.167.96 506,367.15 3311 6.24362 MWD (6) 9,6%.33 94.52 347.01 6,310.59 6260.59 6636.64 as% &026.196.88 Y6.358.28 31.18 6,256.04 MWD (5) 9,727146 93.07 356.60 6,316.53 fi248.53 8.667.35 8457 6.23226.59 590.353.83 31.09 6,29410 MWD (5) 9.75]39 9261 6.52 6.315.04 6,MTN 6,697.19 05.]0 6@3256.42 506,354.62 33.14 6,32250 Mi (5) 9,789.27 69.06 Mai 6,314.57 6,246.57 6.72844 9,50 6,02326]67 508,360.72 W.M 6.353.96 MN➢(5) 681960 Mi -0 6,314.59 634&59 6,757.12 101.00 SOM31fi26 5.,370.19 181% 6.364.16 MUMD(5) 9.849.28 91.56 n..75 6313.44 6,245.44 6.754.62 11231 6.023.343% 501 12.M 6,41387 MVID(5) 9.65340 9221 2367 631152 6.24372 6,618.84126.0 6.@3,37509 5.,39&16 3.96 ...7a.MWD(5) 9,9132] 98.13 29.09 6.309.03 6,241.03 6,042.0 13a. 8.023,401]3 505.400.33 26.82 6,0]43 Mi (5) 9943.15 96.02 29.93 6.30.5.14 6,237.14 fie..25 15381 6.M.427,52 50&42290 5.20 6506.5 Mi (5) 9,974.17 91,07 31.37 6.YR.i9 6.234]9 6894.&5 169.. 6,023454.13 6416,430.64 16.81 6,537.04 MW0(5) 10,004.09 93.00 33.28 61 Sit 6,213.51 6,9..1, 18!5.56 6,023479.3 506.454.60 7,48 6.566.24 MWD (6) l&032.W 89.11 34.40 6,360.90 6232.90 6943.81 20145 6,023,W3.11 506,0047 1432 6,59394 MWD (5) 1006300 85.61 31]8 6302.41 6234.41 6969.09 2%. 6,023,529.20 506.487.44 8.02 6,62426 MWD(5) ,009295 64.28 2193 6,304.90 6,236.98 6.996,06 232.90 6,023554.39 560.50187 13.92 6,652.86 MJVD(5) 10,123.43 04.T7 24.99 6,307.89 6,239.89 7,02222 246.41 4023,501.56 50,516.36 9.74 6,6113.01 MMV(5) 3/202019 2,50 44PM Page 3 COMPASS 5000.14 Build 85D `. ConocoPhillips 9 ConocoPhillips Definitive Survey Report Company: Con...Poll, Alaska Inc_Kupamk Project: Kupamk River Unit 58e: Kupamk 3M Pad Well: 3M-26 wellbore. 3M -26L1 -O t P B t Design: 314-2611-01 P81 Survey Local CooMinate Reference: ND ReMrence: MD Reference. North Reference: Survey Calculation Method Database: We93M-26 3M-26 @ 68.00us8 (31A-26) 3M46 (M 68.00usR (361-26) True Minimum Curvffiure EDT 14 Alaska Production Annotation 3.20.2019 2:50'44744 Palls COMPASS WOO 148u11d 80 Me,h]., MO luatry Inc Aal 3V0 N w sN,6 ♦E/M Norte EaaHn9 DLB Se<Illon Burvry Tool Name h) 17 team IMMq luau)) IMaR) m) IR) (°1100•) (ft) 1015343 .702 22.14 6,31000 624204 7,049.59 35¢.50 6.023.608,93 50,52)43 10]9 6,712M IMO(5) 10,18326 8823 200 6,311.01 6,N3.01 1.077.30 Mew 6023.6ffi65 50538,40 1001 5.]4256 MD (6) 10.212.99 914" 1902 6.31084 6242,84 1.10525 279.59 6,0X,6..61 50,54646 924 6,1]239 MWD(5) 10,243.X 93.. 16.85 6,3066 6,2410 7,1MW 28891 6,023.69342 50.55116 6,89 6,0264 MWD(5) 1073.33 9541 11.69 6,307.43 6,239,3 7,162b5 293.60 8,023,72201 56,55510 692 6,83256 M011)(5) 10,303. 81.79 1450 6303.99 6.23599 7 191a 360]5 SA23,15091 50,514.95 13.69 6.862.05 MVA) (5) 10,33351 101,72 14.80 6,26643 623083 7ZIOb7 313.16 SA23]7944 50,582.53 1292 6.391.96 MWD(5) 10,0343 1..80 16.59 6,29198 6,2X.90 7,2460 32191 6423.807.42 50,50.X 11.8.3 6,92,7.94 MND(5) 10,393.55 10735 19,71 6,26161 6,21564 1275.55 330.62 60X43493 50,56035 Met 6,94846 MD (6) 6042654 10893 2201 621349 6,205fie 1,30388 341.64 6,M86a2fi 50.61034 10.43 6,98024 MD (5) 10.460.65 108.60 24.93 626230 6,194]0 1,]3425 355.0 6,0X,893.. 506X.75 5.71 1,01338 MWD(5) 1046043 10142 21.0 625340 6.1060 7,351.0 30664 6,023.91135 506.635.30 660 7.09.62 MAD(5) 10517.63 10.. 29.81 6244,95 6.11695 1,30248 31692 5,02394189 50,6,48.55 9.39 1,0120 M6D(5) 10,57.00 10,. 29.81 6X1.75 6,15975 1.431.79 40117 6.X.99121 50,676.M 0.0 112320 PROJECTED to To Annotation 3.20.2019 2:50'44744 Palls COMPASS WOO 148u11d 80 UA (ER PRINT DISTRIBUTION LIST 1-�UGHES a GE company COMPANY ConocoPhillips Alaska, Inc. WELL NAME 3M -26L1-01 FIELD Greater Kuparuk Area COUNTY North Slope Borough BHI DISTRICT Alaska AUTHORIZED BY Patrick Rider EMAIL Patrick. Rider@bakerhughes.com STATUS Final Replacement: COMPANY ADDRESS (FEDEXMLL NOT DELIVER TO P.O. BOX) PERSON ATTENTION t �BP North Slope. EOA, PBOC, PRB-20 (Office 109) '.D&GWO Wells Admin Brenda Glassmaker & Peggy O'Neill 900 E. Benson Blvd. Anchorage, Alaska 99508 2 ConocoPhillips Alaska Inc. Attn: Ricky Elgarico ATO 708 700 G Street Anchorage, AK 99510 3 ExxonMohil, Alaska Attn: Lynda M. Yaskell and/or Leonardo Elias 3201 C Street, Suite 505 Anchorage, AK 99503 4 State of Alaska -AOGCC Attn: Natural Resources Technician If 333 W. 7th Ave, Suite 100 Anchorage, Alaska 99501 5 DNR - Division of Oil & Gas *** Attn: Resource Evaluation 550 West 7th Avenue, Suite 1100 Anchorage, Alaska 99501 *** Stamp "confidential" on all material deliver to DNR 6 BP Exploration (Alaska) Inc. Petrotechnical Data Center, LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 21 90 17 305110 Please sign and return one copy of this transmittal form to: ConocoPhillips Alaska, Inc. Tom Osterkamp (WNS Petroleum Technician) 700 G Street. Anchorage, Alaska 99510 to acknowledge receipt of this data. LOG TYPE GR - RES LOG DATE March 4, 2019 TODAYS DATE April 1, 2019 Revision No Details: Rev. Requested by: -- FIELD I FINALCD/D VD FINAL PRELIM LOGS las, dlis, PDF, META, (las, SURVEY REPORT LOGS Final Surveys) (Compass) # OF PRINTS # OF COPIES # OF COPIES # OF COPIES TOTALS FOR THIS PAGE: 0 1 2 0 0 R«R PRINT DISTRIBUTION LIST UCHES a GE company COMPANY ConocoPhillips Alaska, Inc. WELL NAME 3M-26L1-01PB1 FIELD Greater Kuparuk Area COUNTY North Slope Borough BHI DISTRICT Alaska AUTHORIZED BY Patrick Rider EMAIL Patrick Rider.aDbakerhuohes.com 21 90 1 � 30541 ;e sign and return one copy of this transmittal form to: 3coPhillips Alaska, Inc. Osterkamp (WNS Petroleum Technician) G Street. forage, Alaska 99510 LOG TYPE GR - RES LOG DATE February 28, 2019 TODAYS DATE April 1, 2019 Revision STATUS Final Replacement: No Details: Rev. Requested by: --- COMPANY ADDRESS (FEDEX HALL NOT DELIVER TO P.O. BOX) PERSON ATTENTION V t BP North Slope. LOA, PBOC, PRB-20 (Office 109) D&GWO Wells Admin Brenda Glassmaker & Peggy O'Neill 900 E. Benson Blvd. Anchorage. Alaska 99508 2 ConocoPhillips Alaska Inc. Attn: Ricky Elgarico ATO 708 700 G Street Anchorage, AK 99510 3 ExxonMobil, Alaska Attn: Lynda M. Vaskell and/or Leonardo Elias 3201 C Street, Suite 505 Anchorage, AK 99503 4 State of Alaska - AOGCC .Attn: Natural Resources "technician 11 333 W. 7th Ave, Suite 100 Anchorage, Alaska 99501 5 DNR - Division of Oil & Gas *** Attn: Resource Evaluation 550 West 7th Avenue, Suite 1100 Anchorage, Alaska 99501 *** Stamp "confidential" on all material 6 BP Exploration (Alaska) Inc. Petrotechnical Data Center, LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 TOTALS FOR THIS PAGE — FIELDI FINAL CD/DVD FINAL PRELIM (las, dlis, PDF, META, SURVEY REPORT LOGS LOGS CGM, Final Surveys) (Compass) # OF PRINTS # OF COPIES 1# OF COPIES 19 OF COPIES lu 4 0 1 2 0 0 V OF TE1 % T. THE STA R M O fALASKA 0 LAS NOR GOVERNOR MIKE DUNLEAVY FA' Kai Starck Staff CTD Engineer ConocoPhillips Alaska, Inc. PO Box 100360 Anchorage, AK 99510-0360 Re: Kuparuk River Field, Ku COnOcoPhllll s Paruk River Oil Pool KRU 3 PermittoDrillNum Number' M-26-7-Ol Surface Location: 938 219 017 revised Borface L e L FNL 1593' FEL, SEC. 25, TUN, Location: 3893' FNL, 3157' FEL, SEC. RBE, UM Dear Ms. Starck: 13, T13N, R8E Alaska Oil and Ga.4 Conservation Commission Anch333 West Seventh Avenue orage, 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 The permit is for a new wellbore segment of existing 00. is should continue to be re well, well Permit No. 193-193, AN No. 50 -029 - Ported as a function of the original AN number stated above. In accordance with 20 22431 -00 - differentiated in both AAC 25.005(1), all records, records, data well n data and logs acquired for and logs acquire or KRU 3141-26-1-01 PBI and the Plugback must be clearly well 3M-26 -I-0 P 1. AN number 50 -029 - Per Statute AS 31.05.030 22431-70-00 from be submitted to the AO (d)(2)(B) and Regulation 20 GCC within 90 days after 20 AAC 25.071, composite curves for well to This permit to pletion, suspension or abandon i s run must from other drill does not exempt you from abandonment of governmental obtaining this well. the required a ppr vals have been gencies and does unot au g additional Permits ilor nd° a Y law permits and a authorize conducting approval required b Permit in the event it was erroneously issued. In addition g operations the AOGCC reserves until all other Operations must be conducted in accord the right to withdraw Administrative Code unless the AO accordance with applicable provision of AS authorizes and Title 20, Cha ter AS 31.05, Title 20 specifically authorizes a variance. Failure to 5 of the order, or the terms and conditions of this Chapter 25 of the Alaska permit May Alaska Administrative comply with an Sincerely, y result in the revocation or suspension or an AOGCC Pension of the permit. -49� Daniel T. Seamount, Jr. Commissioner DATED this 5� of March, 2019 STATE OF ALASKA AL; A OIL AND GAS CONSERVATION COMMil, ,ON PERMIT TO DRILL 20 AAC 25.005 RECEIVE® REt/t S� FEB 2 9 2019 1 a. Type of Work: Drill ❑ Lateral R Redrill ❑ Reentry ❑ ((�� 11b. Proposed Well Class: Exploratory - Gas ❑ Service - WAG ❑ Service - Disp ❑ Stratigraphic Test ❑ Development - Oil ❑� Service - Winj ❑ Single Zone ❑' Exploratory - Oil ❑ Development - Gas ❑ Service - Supply ❑ Multiple Zone ❑ 1 c Specify if well is prpposed for: Coalbed Gas ❑ Gas Hydrates ❑ Geothermal ❑ Shale Gas ❑ 2. Operator Name: ConocoPhillips Alaska, Inc. 5. Bond: Blanket ❑� Single Well ❑ Bond No. 5952180 11. Well Name and Number: KRU 3M -26L1-01 3. Address: P.O. Box 100360 Anchorage, AK 99510-0360 6. Proposed Depth: T -ID- 45-313 MD: 11700' A TVD. ;6245'55 12. Field/Pool(s): Kupamk River Pool / ' River Oil Pool 4a. Location of Well (Governmental Section): Surface: 938' FNL, 1593' FEL, Sec 25, T13N, R8E, UM Top of Productive Horizon: 4853' FNL, 1504' FEL, Sec 13, T13N, R8E, UM Total Depth: 3893' FNL, 3157' FEL, Sec 13, T13N, R8E, UM 7. Property Designation: i 'p-R,,b, WWRKuparuk ADL 25522, 25523 8. DNR Approval Number: LONS 84-138 13. Approximate Spud Date: , 3/1/2019 9. Acres in Property: 2560 14. Distance to Nearest Property: 1210' 4b. Location of Well (State Base Plane Coordinates - NAD 27): Surface: x- 506275 y- 6016560 Zone- 4 10. KB Elevation above MSL (ft): 68' .. GL / BF Elevation above MSL (ft): 27' 15. Distance to Nearest Well Open to Same Pool: 2391' (3M-17) 16. Deviated wells: Kickoff depth: 9705 , feet Maximum Hole Angle: 97 ♦ degrees 17. Maximum Potential Pressures in psig (see 20 AAC 25.035) Downhole: 4280 Surface: 3650 18. Casing Program: Specifications Top - Setting Depth - Bottom Cement Quantity, c.f. or sacks Hole Casing Weight Grade Coupling Length MD TVD MD TVD (including stage data) 3" 2-3/8" 4.7# L-80 ST -L 2480' 9220' 6220' 11700' 6245' Slotted 19. PRESENT WELL CONDITION SUMMARY (To be completed for Redrill and Re -Entry Operations) Total Depth MD (ft): Total Depth TVD (ff): Plugs (measured): Effect. Depth MD (ft): Effect. Depth TVD (ft): Junk (measured): 9625' 6534' N/A 9522' 6453' 9450' Casing Length Size Cement Volume MD TVD Conductor/Structural 78' 16" 340 sx ASI CMT 121' 121' Surface 4841' 9-5/8" 950 sx ASIII, 530 sx G CMT 4882' 3624' Production 9576' 7" 250 sx Class G 9615' 6526' Perforation Depth MD (ft): 9324'- 9358' Perforation Depth TVD (ft): 6299'- 6325' Hydraulic Fracture planned? Yes[] No ❑w 20. Attachments: Property Plat ❑ BOP Sketch Diverter Sketch Drilling Program e Seabed Report Time v. Depth Plot B Drilling Fluid Program Shallow Hazard Analysis 20 AAC 25.050 requirements 4 21. Verbal Approval: Commission Representatives (G'fO r/ -6L �,OeF1 Date Z/Z F/!9 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 Long Authorized Name: Kai Starck Contact Email: William. R. Lon COP.com Authorized Title: taff CTD Engineer Contact Phone: 907-263-4372 Authorized Signature: _ --- Date: 2-17_01&`21q Commission Use Only Permit to Drill Number: 2117 " 0/7 API Number:Permit 50- Q2 ' � 1 — 61- I Appro11-7119 Date: 1 I See cover letter for other requirements. Conditions of approval : If box is checked, well may not be used to explore for, test, or produce coalbed methane,, gas hydrates, or gas contained in shales: Other: 130P t cr 5 f 7/0 -I DOO P 5 / I -)Samples req'd: Yes ❑ L.0 NoMud log req'd: Yes ❑ NoR' /j-r)ntil ar pre v,''" /Y✓ AC -6f 40 2,5—&0 n H,S measures: Yes Q' No❑ Directional svy req'd: Yes [V NoF1 f% YGI r7c:? r0 OG to 201" C Z t . O J 506 ycinAxception req'd: Yes ❑ No[t� Inclination -only svy req'd: Yes E] WE( r,,� 1,5 �rg r) tfC% fo GZ//o w fh t k/C///ko Post initial injection MIT req'd: Yes El Nocj ct o ir7T cLlon f�1, t to b APPROVED BY Approved by: COMMISSIONER THE COMMISSION Date: 3l' J V7-L3/j / Submit Form and C3- / /,Nm 10-401 Revised 5/2077 Tis p rmit is valid for 24 r t ep pf p oval per 20 AAC 25.005(g')) Aflac ents in Duplicate n' 111) V R� 1 I Y k L�7 �. 03104"119 ConocoPhillips Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 February 28, 2019 Commissioner - State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Dear Commissioner: ConocoPhillips Alaska, Inc. hereby submits a revised permit to drill for lateral L1-01 of the KRU 3M-26 (PTD# 193-193) using the coiled tubing drilling rig, Nabors CDR3-AC. Nabors CDR3-AC is currently rigged up on KRU 3M-26. We have successfully completed the original scope of 3M -26L1 (PTD# 219-016) to the west. Yesterday we kicked off and began drilling KRU 31VI-261-1-01 (PTD# 219- 017) to the north. Last night we were unable to find sand in the northern fault block. We plan to make a clean out run and set an anchored billet to plug back this lateral. We would like to re -drill the 31VI-2611-01 to the west paralleling the 3M -26L1 wellbore. To account for geological uncertainties, ConocoPhillips requests a variance from the requirements of 20 AAC 25.015 to allow the actual kick-off point to be anywhere along the length of the parent lateral instead of being limited to 500' from the original point. Attached to the revised permit to drill application are the following documents: - Revised Permit to Drill Application Form (10-401) for 31VI-261-1-01 - Detailed Summary of Operations - Directional Plan for 3M -26L1-01 - Proposed CTD Schematic If you have any questions or require additional information, please contact me at 907-2634372. Sincerely, William R. Long Coiled Tubing Drilling Engineer ConocoPhillips Alaska Kuparuk CTD Laterals Revised° 3M-261-1 & 3M-261-1-01 Application for Permit to Drill Document 1. Well Name and Classification........................................................................................................ 2 (Requirements of 20 AAC 25.005(1) and 20 AAC 25.005(b))...................................................................................................................2 2. Location Summary .......................................................................................................................... 2 (Requirements of 20 AAC 25.005(c)(2))..................................................................................................................................................2 3. Blowout Prevention Equipment Information................................................................................. 2 (Requirements of 20 AAC 25.005(c)(3)).................................................................................................................................................2 4. Drilling Hazards Information and Reservoir Pressure.................................................................. 2 (Requirements of 20 AAC 25.005(c)(4)).................................................................................................................................................2 5. Procedure for Conducting Formation Integrity tests................................................................... 2 (Requirements of 20 AAC 25.005(c)(5))..................................................................................................................................................2 6. Casing and Cementing Program.................................................................................................... 3 (Requirements of 20 AAC 25.005(c)(6))..................................................................................................................................................3 7. Diverter System Information ..........................................................................................................3 (Requirements of 20 AAC 25.005(c)(7))..................................................................................................................................................3 8. Drilling Fluids Program.................................................................................................................. 3 (Requirements of 20 AAC 25.005(c)(6))..................................................................................................................................................3 9. Abnormally Pressured Formation Information............................................................................. 4 (Requirements of 20 AAC 25.005(c)(9))..................................................................................................................................................4 10. Seismic Analysis............................................................................................................................. 4 (Requirements of 20 AAC 25.005(c)(10))................................................................................................................................................4 11. Seabed Condition Analysis............................................................................................................ 4 (Requirements of 20 AAC 25.005(c)(11))................................................................................................................................................4 12. Evidence of Bonding ................ (Requirements of 20 AAC 25.005(c)(12))... ........................................... 4 ............................................................ 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....................................................................... 6 (Requirements of 20 AAC 25.050(b))...................................................................................................................................................... 6 16. Attachments....................................................................................................................................6 Attachment 1: Directional Plans for 3M-261-1 & 3M-261-1-01 laterals..............................................................................6 Attachment 2: Current Well Schematic for 3M-26...........................................................................................................6 Attachment 3: Proposed Well Schematic for 3M-261-1 & 3M-261-1-01 laterals................................................................6 Page 1 of 6 28 -Feb -2019 Revised PTD Application: 3M-261-1 & 3M-261-1-01 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 3M -26L1 & 3M-261-1-01. All laterals will be classified as "Development" wells. 2. Location Summary (Requirements of 20 AAC 25.005(c)(2)) These laterals will target the A sand package in the Kuparuk reservoir. See attached 10-401 form for surface and subsurface coordinates of the 3M-261-1 & 3M-261-1-01. 3. Blowout Prevention Equipment Information (Requirements of 20 AAC 25.005 (c)(3)) Please reference blowout prevention (BOP) schematics on file with the Commission for Nabors CDR3-AC. BOP equipment is as required per 20 AAC 25.036 for thru-tubing drilling operations. - Pipe rams, blind rams and the CT pack off will be pressure tested to 250 psi and to 4,000 psi. Using the maximum formation pressure in the area of 4280 psi in 3M-17 (i.e. 13.1 ppg EMW), the maximum potential surface pressure in 3M-26, assuming a gas gradient of 0.1 psi/ft, would be 3650 psi. See the "Drilling Hazards Information and Reservoir Pressure" section for more details. - The annular preventer will be tested to 250 psi and 2,500 psi. 4. Drilling Hazards Information and Reservoir Pressure (Requirements of 20 AAC 25.005 (c)(4)) Reservoir Pressure and Maximum Downhole Pressure (Requirements of 20 AAC 25.005 (c)(4)(a)) The formation pressure in KRU 3M-26 was measured to be 3992 psi (12.2 ppg EMW) on 8/25/2018. The maximum downhole pressure in the 3M-26 vicinity is to the south in the 3M-17 producer at 4280 psi (13.1 ppg EMW) from November of 2014. Potential Gas Zones (Requirements of 20 AAC 25.005 (c)(4)(b)) None of the offset injection wells to 3M-26 have injected gas, so there is a low probability of encountering free gas while drilling the 3M-26 laterals. If gas is detected in the returns the contaminated mud can be diverted to a storage tank away from the rig. Potential Causes of Hole Problems (Requirements of 20 AAC 25.005 (c)(4)(c)) The major expected risk of hole problems in the 3M-26 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 3M-26 laterals will be drilled under 20 AAC 25.036 for thru-tubing drilling operations so a formation integrity test is not required. Page 2 of 6 28 -Feb -2019 Revised PTD Application: 3M-261_1 & 3M -26L1-01 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 3M-261-1 9600' 11,700' 6263' 6271' 2-3/8",4.7#, L-80, ST -L slotted liner; 0' 121' 1640 670 Surface aluminum billet on to 3M-261-1-01 9220' 11,700' 6152' 6245' 2-3/8", 4.7#, L-80, ST -L slotted liner; 3624' 3520 2220 Production 7" deployment sleeve on top Existing Casing/Liner Information Category OD Weight Grade Connection Top MD Btm MD Top TVD Btm TVD Burst psi Collapse psi Conductor 16, 62.5 H-40 Welded 0' 121' 0' 121' 1640 670 Surface 9-5/8" 36.0 J-55 BTC 0' 4882' 0' 3624' 3520 2220 Production 7" 26.0 L-80 BTC -MOD 0' 9615' 0' 6526' 7240 5410 Tubing 3-1/2" 9.3 J-55 EUE-8rd MOD 0 9237' 0 6233' 7180 7400 7. Diverter System Information (Requirements of 20 AAC 25.005(c)(7)) Nabors CDR3-AC will be operating under 20 AAC 25.036, for thru-tubing drilling operations. Therefore, a diverter system is not required. 8. Drilling Fluids Program (Requirements of 20 AAC 25.005(c)(8)) Diagram of Drilling System A diagram of the Nabors CDR3-AC mud system is on file with the Commission. Description of Drilling Fluid System — Window milling operations: Water -Based PowerVis milling fluid (8.6 ppg) — Drilling operations: Water-based PowerVis mud (8.6 ppg). This mud weight will not hydrostatically overbalance the reservoir pressure, overbalanced conditions will be maintained using MPD practices described below. — Completion operations: The well will be loaded with 12.4 ppg K -Formate completion fluid in order to provide formation over -balance and well bore stability while running completions. 0 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 5,000 psi rated coiled tubing pack off and MPD choke. BOPE equipment provides the secondary well control as detailed in section 3 "Blowout Prevention Equipment Information". In the 3M-26 laterals we will target a constant BHP of 12.2 ppg EMW at the window. The constant BHP target will be adjusted through choke pressure and/or mud weight increases to maintain overbalanced conditions if increased reservoir pressure is encountered. Additional choke pressure or increased mud weight may also be employed for improved borehole stability. Any change of circulating friction pressure due to change in pump rates or change in depth of circulation will be offset with back pressure adjustments. Page 3 of 6 28 -Feb -2019 Revised PTD Application: 31VI-261_1 & 31VI-261-1-01 X Pressure at the 3M-26 Window !9314' MD. 6292' TVDI Usina MPD r 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 3M-26 is a Kuparuk A -sand producer equipped with 3-1/2" tubing and 7" production casing. The CTD sidetrack will utilize two laterals to target the A 1 sand to the +teeth fin west of 3M-26. The laterals will increase A -sand resource recovery and throughput. CDR3-AC will set a mechanical whipstock (High Expansion Wedge) inside the 7' casing at the planned kick off point of 9,313' MD. The 3M -26L1 lateral will exit through the 7" at 9,313' MD and TD at 11,676' MD, targeting the A] sand to the west. It will be completed with 2-3/8" slotted liner from TD up to 9608' MD with an aluminum billet for kicking off the 3M -26L1-01 lateral. The 3M -26L1-01 lateral will drill to a TD of 11,700' MD targeting the Al sand to the west. It will be completed with 2-3/8" slotted liner from TD up into the 3-1/2" tubing at 9920' MD with a deployment sleeve. Page 4 of 6 28 -Feb -2019 Pumps On 1.8 bpm) Pumps Off A -sand Formation Pressure 12.2 3992psi 3992psi Mud Hydrostatic 8.6 2813 psi 2813 psi Annular friction i.e. ECD, 0.080psi/ft) 745 psi 0 psi Mud + ECD Combined no chokepressure) 3558 psi underbalanced -434psi) 2813psi underbalanced -1179psi) Target BHP at Window 12.2 3992 psi 3992 psi Choke Pressure Required to Maintain Target BHP 434 psi 1179 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 3M-26 is a Kuparuk A -sand producer equipped with 3-1/2" tubing and 7" production casing. The CTD sidetrack will utilize two laterals to target the A 1 sand to the +teeth fin west of 3M-26. The laterals will increase A -sand resource recovery and throughput. CDR3-AC will set a mechanical whipstock (High Expansion Wedge) inside the 7' casing at the planned kick off point of 9,313' MD. The 3M -26L1 lateral will exit through the 7" at 9,313' MD and TD at 11,676' MD, targeting the A] sand to the west. It will be completed with 2-3/8" slotted liner from TD up to 9608' MD with an aluminum billet for kicking off the 3M -26L1-01 lateral. The 3M -26L1-01 lateral will drill to a TD of 11,700' MD targeting the Al sand to the west. It will be completed with 2-3/8" slotted liner from TD up into the 3-1/2" tubing at 9920' MD with a deployment sleeve. Page 4 of 6 28 -Feb -2019 Revised PTD Application: 3M-261_1 & 3M -26L1-01 Pre -CTD Work 1. RU Slickline: C/O GLV's, Dummy whipstock drift run 2. RU Service Coil: Mill out "D" nipple and conduct fill cleanout 3. RU E -line: Caliper 7" production casing and 3-1/2" tubing 4. Prep site for Nabors CDR3-AC Ria Work 1. MIRU Nabors CDR3-AC rig using 2" coil tubing. NU 7-1/16" BOPE, test. 2. 3M -26L1 Sidetrack (A1 sand -West) i. Set top of whip -stock at 9313' MD ii. Mill 2.80" window at 9313' MD. iii. Drill 3" bi-center lateral to TD of 11,676' MD. iv. Run 2%" slotted liner with an aluminum billet from TD up to 9608' MD. 3. 3M-26L1-01PB1 Lateral (Al sand -North) i. Kickoff of the aluminum billet at 9608' MD. ii. Drill 3" bi-center lateral to TD of 10576' MD. iii. Sand faulted out, plug back. Set aluminum billet on open hole anchor at 9705' MD. 4. 3M -26L1-01 Lateral (A1 sand - West) i. Kick off of the aluminum billet at 9705' MD. ii. Drill 3" bi-center lateral to TD of 1 1.700' MD. iii. Run 2%" slotted liner with deployment sleeve from TD up to 9920' MD. 5. Obtain SBHP, freeze protect, ND BOPE, and RDMO Nabors CDR3-AC. Post -Rig Work 1. Return to production Pressure Deployment of BHA The planned bottom hole assemblies (BHAs) are too long to simply isolate by closing the double swab valves on the Christmas tree. MPD operations require the BHA to be lubricated under pressure using a system of double swab valves on the Christmas tree, double deployment rams, double check valves and double ball valves in the BHA, and a slick -line lubricator can be used. This pressure control equipment listed ensures there are always two barriers to reservoir pressure, both internal and external to the BHA, during the deployment process. During BHA deployment, the following steps are observed. - Initially the double swab valves on the tree are closed to isolate reservoir pressure. The lubricator is installed on the BOP riser with the BHA inside the lubricator. - Pressure is applied to the lubricator to equalize across the swab valves. The swab valves are opened and the BHA is lowered in place via 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 Page 5 of 6 28 -Feb -2019 Revised PTD Application: 3M-261_1 & 3M -26L1-01 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 - The 3M-26 laterals will be displaced to an overbalancing fluid (12.4 ppg K -Formate) prior to running liner. See "Drilling Fluids" section for more details. - While running 2-3/8" slotted liner, a joint of 2-3/8" non -slotted tubing will be standing by for emergency deployment. A floor valve is made up onto this joint ahead of time, and the rig crew conducts a deployment drill with this emergency joint on every slotted liner run. The 2-3/8" rams will provide secondary well control while running 2-3/8" liner. 14. Disposal of Drilling Mud and Cuttings (Requirements of 20 AAC 25.005(c)(14)) • No annular injection on this well. • All solid waste will be transported to the grind and inject facility at DS -4 Prudhoe Bay for disposal. • Incidental fluids generated from drilling operations will be injected in a Kuparuk Class II disposal well (1 R-18 or 1 B disposal facilities) or Prudhoe DS -4 if a Kuparuk facility is unavailable. • All wastes and waste fluids hauled from the pad must be properly documented and manifested. • Contact Kuparuk Environmental Coordinator for questions regarding waste classification. (670-4200). 15. Directional Plans for Intentionally Deviated Wells (Requirements of 20 AAC 25.050(b)) - The Applicant is the only affected owner. - Please see Attachment 1: Directional Plans - Magnetic and inclination surveys will be taken every 30 ft. No gyro will be run. - MWD directional, resistivity, and gamma ray will be run over the entire open hole section. - Distance to Nearest Property Line (measured to KPA boundary at closest point) Lateral Name Distance 3M -26L1 1210' 3M -26L1-01 1210' Distance to Nearest Well within Pool Lateral Name Distance Well 3M-261_1 2391' 3M-17 3M -26L7-01 2391' 3M-17 16.Attachments Attachment 1: Directional Plans for 3M -26L1 & 3M -26L1-01 laterals Attachment 2: Current Well Schematic for 3M-26 Attachment 3: Proposed Well Schematic for 3M -26L1 & 3M -26L1-01 laterals Page 6 of 6 28 -Feb -2019 ConocoPhillips ConocoPhillips Alaska Inc—Kuparuk Kuparuk River Unit Kuparuk 3M Pad 3M-26 3M-261-1-01 Plan: 3M-26L1-01_wp05 Standard Planning Report 28 February, 2019 BER GHES TGE company �. ConocoPhillips B ER ConocoPhillips Planning Report FTUGHES a GEmmpany Database: EDT 14 Alaska Production Company: ConocePhillips Alaska Inc_Kuparuk Project: Kuparuk River Unit Site: Kupamk 3M Pad Well: 3M-26 Wellbore: 3M -26L7-01 Design: 3 M -28L1-01 _wp05 Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Well 3M-26 Mean Sea Level 3M-26 @ 68.00usft (3M-26) 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 Well 3M-26 Well Position +N/ -S +E/ -W Position Uncertainty 0.00 usft Northing: 0.00 usft Easting: 0.00 usft Wellhead Elevation: Wellbore 3M-261.1-01 Turn Magnetics Site Kuparuk 3M Pad Sample Date Measured BGGM2018 Site Position: Northing: 6,016,202.17 ,it Latitude: 700 27' 19.780 N From: Map Easting: 506,126.99 usft Longitude: 149° 56'59.998 W Position Uncertainty: 0.00 usft Slot Radius: 0.000 in Grid Convergence: 0.05 ` Well 3M-26 Well Position +N/ -S +E/ -W Position Uncertainty 0.00 usft Northing: 0.00 usft Easting: 0.00 usft Wellhead Elevation: Wellbore 3M-261.1-01 Turn Magnetics Model Name Sample Date Measured BGGM2018 4/1/2019 Design 3M-26L1-01_wp05 (') Audit Notes: Inclination Azimuth Version: +N/ -S Phase: Vertical Section: (I Depth From (TVD) (usft) (usft) (usft) 9,696.33 94.52 a 00 6,016,559.83 usft 506,274.89 usft usft Declination V) 16.63 Latitude; Longitude: Ground Level: Dip Angle (1) PLAN Tie On Depth: +N/ -S +E/ -W (usft) (usft) 0.00 - _ _ _ 0.00 Plan Sections Build Turn Rate Rate Measured TFO (°1100usft) TVD Below (°1100usft) (') Depth Inclination Azimuth System +N/ -S +E/ -W (usft) (I (I (usft) (usft) (usft) 9,696.33 94.52 347.01 6,250.59 6,636,64 88.99 9,705.00 94.13 349.68 6,249.94 6,645.11 87.24 9,735.00 86.33 345.18 6,249.82 6,674.36 80.72 9,835.00 91.79 315.67 6,251.50 6,760.32 31.92 9,965.00 97.05 276.89 6,241.09 6,816.73 -81.96 10,035.00 96.93 271.96 6,232.56 6,822.09 -151.21 10,145.00 89.23 271.96 6,226.65 6,825.83 -260.90 10,495.00 89.30 296.46 6,231.18 6,911.08 -597.59 10,615.00 87.86 304.74 6,234.16 6,972.08 -700.76 10,815.00 87.92 318.75 6,241.56 7,104.81 -849.51 11,065.00 91.60 301.63 6,242.62 7,265.51 -1,039.75 11,240.00 89.45 289.57 6,241.01 7,340.98 -1,197.27 11,700.00 89.54 321.77 6,245.19 7,605.70 -1,566.04 8093 70° 27'23.296 N 149° 56'55.644 W 0.00 usft Field Strength (nT) 57 424 9,696.33 - ----] Direction (`) 300.00 Dogleg Build Turn Rate Rate Rate TFO (°1100usft) (°1100usft) (°1100usft) (') 0.00 0.00 0.00 0.00 31.04 -4.50 30.80 98.23 30.00 -26.00 -14.98 210.00 30.00 5.46 -29.51 280.00 30.00 4.04 -29.83 279.00 7.00 -0.16 -7.05 269.00 7.00 -7.00 0.00 180.00 7.00 0.02 7.00 90.00 7.00 -1.21 6.90 100.00 7.00 0.03 7.00 90.00 7.00 1.47 -6.85 282.00 7.00 -1.23 -6.89 260.00 7.00 0.02 7.00 90.00 Target 2/28/2019 134: 58PM Page 2 COMPASS 5000.14 Build 85D ConocoPhillips ConocoPhillips Planning Report �F�UGHES a GEmmp W Database: EDT 14 Alaska Production Local Co-ordinate Reference: Well 3M-26 Company: ConocoPhillips Alaska Inc Kuparuk TVD Reference: Mean Sea Level Project: Kuparuk River Unit MD Reference: 31V-26 @ 68.00usft (310-26) Site: Kuparuk 3M Pad North Reference: True Well: 3M-26 Survey Calculation Method: Minimum Curvature Wellbore: 3M-261-1-01 Design: 3M-26L1-01_wp05 Planned Survey f Measured TVD Below Vertical Dogleg Toolface Map Map Depth Inclination Azimuth System -NIS +EAW Section Rate Azimuth Northing Easting (usft) r) (°) (usft) (usft( (usft) (usft) (°I10ousft) (°) (usft) (usft) 9,696.33 94.52 347.01 6,250.59 6,636.64 88.99 3,241.26 0.00 0.00 6,023,195.88 506,358.28 TIP 9,700.00 94.36 348.14 6,250.31 6,640.21 88.20 3,243.72 31.04 98.23 6,023,199.45 506,357.49 9,705.00 94.13 349.68 6,249.94 6,645.11 87.24 3,247.00 31.04 98.32 6,023,204.34 506,356.52 KOP 9,735.00 86.33 345.18 6,249.82 6,674.36 80.72 3,267.27 30.00 -150.00 6,023,233.59 506,349.98 Start 30 dls 9,800.00 89.86 325.99 6,252.00 6,733.22 53.99 3,319.86 30.00 -80.00 6,023,292.42 506,323.20 9,835.00 91.79 315.67 6,251.50 6,760.32 31.92 3,352.52 30.00 -79.36 6,023,319.50 506,301.11 4 9,900.00 94.68 296.35 6,247.79 6,798.30 -20.31 3,416.74 30.00 -81.00 6,023,357.43 506,248.85 9,965.00 97.05 276.89 6,241.09 6,816.73 -81.96 3,479.34 30.00 -82.10 6,023,375.80 506,187.20 End 30 dls, Start 7 dls 10,000.00 97.00 274.42 6,236.81 6,820.15 -116.52 3,510.99 7.00 -91.00 6,023,379.20 506,152.64 10,035.00 96.93 271.96 6,232.56 6,822.09 -151.21 3,541.99 7.00 -91.30 6,023,381.10 506,117.95 6 10,100.00 92.38 271.96 6,227.29 6,824.30 -215.94 3,599.16 7.00 -180.00 6,023,383.26 506,053.23 10,145.00 89.23 271.96 6,226.65 6,825.83 -260.90 3,638.86 7.00 -180.00 6,023,384.76 506,006.27 7 10,200.00 89.24 275.81 6,227.38 6,829.56 -315.76 3,688.23 7.00 90.00 6,023,388.44 505,953.41 10,300.00 89.25 282.81 6,228.71 6,845.72 -414.37 3,781.72 7.00 89.95 6,023,404.51 505,854.79 10,400.00 89.27 289.81 6,230.00 6,873.78 -510.28 3,878.81 7.00 89.86 6,023,432.49 505,758.87 10,495.00 89.30 296.46 6,231.18 6,911.08 -597.59 3,973.06 7.00 89.77 6,023,469.71 505,671.54 8 10,500.00 89.24 296.80 6,231.25 6,913.32 -602.06 3,978.06 7.00 100.00 6,023,471.95 505,667.07 10,600.00 88.04 303.70 6,233.62 6,963.65 -688.36 4,077.96 7.00 100.00 6,023,522.20 505,580.73 10,615.00 87.86 304.74 6,234.16 6,972.08 -700.76 4,092.91 7.00 99.83 6,023,530.62 505,568.33 9 10,700.00 87.87 310.69 6,237.33 7,024.02 -767.92 4,177.05 7.00 90.00 6,023,582.50 505,501.13 10,800.00 67.91 317.69 6,241.02 7,093.63 -839.53 4,273.87 7.00 89.78 6,023,652.05 505,429.47 10,815.00 87.92 318.75 6,241.56 7,104.81 -849.51 4,288.11 7.00 89.52 6,023,663.21 505,419.48 10 10,900.00 89.17 312.93 6,243.72 7,165.74 -908.69 4,369.82 7.00 -78.00 6,023,724.08 505,360.25 11,000.00 90.64 306.08 6,243.89 7,229.31 -985.80 4,468.39 7.00 -77.85 6,023,787.59 505,283.10 11,065.00 91.60 301.63 6,242.62 7,265.51 -1,039.75 4,533.21 7.00 -77.84 6,023,823.73 505,229.12 11 11,100.00 91.17 299.22 6,241.77 7,283.23 -1,069.92 4,568.19 7.00 -100.00 61023,841.43 505,198.94 11,200.00 89.94 292.33 6,240.80 7,326.68 -1,159.91 4,667.86 7.00 -100.06 6,023,884.80 505,108.92 11,240.00 89.45 289.57 6,241.01 7,340.98 -1,197.27 4,707.35 7.00 -100.13 6,023,899.07 505,071.56 12 11,300.00 89.45 293.77 6,241.59 7,363.13 -1,253.01 4,766.70 7.00 90.00 6,023,921.17 505,015.80 11,400.00 89.46 300.77 6,242.54 7,408.92 -1,341.84 4,866.52 7.00 89.96 6,023,966.88 504,926.95 11,500.00 89.48 307.77 6,243.46 7,465.20 -1,424.42 4,966.18 7.00 89.89 6,024,023.08 504,844.33 11,600.00 89.50 314.77 6,244.35 7,531.12 -1,499.53 5,064.19 7.00 89.83 6,024,088.93 504,769.17 11,700.00 89.54 321.77 6,245.19 7,605.70 -1,566.04 5,159.08 7.00 89.77 6,024,163.45 504,702.60 Planned TD at 11700.00 2282019 1:34:58PM Page 3 COMPASS 5000.14 Build 85D ConocoPhillips ConocoPhillips Planning Report BAIUGHES aGEcompany Database: EDT 14 Alaska Production Company: ConocoPhillips Alaska lnc_Kuparuk Project: Kuparuk River Unit Site: Kuparuk 3M Pad Well: 3M-26 Wellbore: 310-261.1-01 Design: 3M-261-1-01_wp05 Casing Points Measured Depth (usft) 1,700.00 Plan Annotations Measured Depth (usft) 9,696.33 9,705.00 9,735.00 9,835.00 9,965.00 10,035.00 10,145.00 10,495.00 10,615.00 10,815.00 11,065.00 11,240.00 11,700.00 Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Well 3M-26 Mean Sea Level 3M-26 Q 68.00usft (310-26) True Minimum Curvature Vertical Casing Hole Depth Diameter Diameter (usft) Name (in) (in) 6,245.19 23/8" 2.375 3.000 Vertical Local Coordinates Depth -NI-S +EI -W (usft) (usft) (usft) Comment 6,250.59 6,636.64 88.99 TIP 6,249.94 6,645.11 87.24 KOP 6,249.82 6,674.36 80.72 Start 30 dls 6,251.50 6,760.32 31.92 4 6,241.09 6,816.73 -81.96 End 30 dls, Start 7 dls 6,232.56 6,822.09 -151.21 6 6,226.65 6,825.83 -260.90 7 6,231.18 6,911.08 -597.59 8 6,234.16 6,972.08 -700.76 9 6,241.56 7,104.81 -849.51 10 6,242.62 7,265.51 -1,039.75 11 6,241.01 7,340.98 -1,197.27 12 6,245.19 7,605.70 -1,566.04 Planned TD at 11700.00 228/2019 1:34:58PM Page 4 COMPASS 5000 14 Hind 85D �. ConocoPhillips BA�(ER ConocoPhillips Anticollision Report HUGHES a GE company Company: ConocoPhillips Alaska Inc Kuparuk Project: Kuparuk River Unit_2 Reference Site: Kuparuk 3M Pad Site Error: 0.00 usft Reference Well: 3M-26 Well Error: 0.00 usft Reference Wellbore 3M-261_1-01 Reference Design: 3M-26L1-01_wp05 Summary Site Name Offset Well - Wellbore - Design Kuparuk 3M Pad 3M-23 - 3M-23AL3PB1 - 3M-23AL3PB1 3M-23 - 3M-23AL4 - 3M-23AL4 3M-23 - 3M-23AL4 - 3M-23AL4 3M-23 - 3M-23AL4 - 3M-23AL4 3M-23 - 3M-23AL4-01 - 3M-23AL4-01 3M-23 - 3M-23AL4-01 - 3M-23AL4-01 3M-23 - 3M-23AL4-01 - 3M-23AL4-01 3M-23-3M-23APB7-3M-23APB1 3M-23 - 3M-23APB1 - 3M-23APB1 3M-23-3M-23APB1-3M-23APB1 3M-23 - 3M-23APB2 - 3M-23APB2 3M-23-3M-23APB2-3M-23APB2 3M-23-3M-23APB2-3M-23APB2 3M-24 - 3M-24 - 3M-24 3M-24 - 3M -24L7 - 3M -24L1 3M-24 - 3M -24L1-01 - 3M -24L1-01 3M-24-3M-24L1-01PB1-3M-24L1-01PB1 3M-24 - 3M-241-1-02 - 3M-241.1-02 3M-24 - 3M-241-7-03 - 3M-241-1-03 3M-24 - 3M -24L7 PB1 - 3M -24L1 PBI 3M-24 - 3M -24L1 PB2 - 3M -24L1 PB2 3M-24 - 3M -24L1 PB3 - 3M -24L1 PB3 3M-25 - 3M-25 - 3M-25 3M-25 - 3M-25 - 3M-25 3M -25A- 3M -25A- 3M -25A 3M-26 - 3M -26L1 - 3M -26L7 3M-26 - 3M -26L1 - 3M -26L7 3M-26-3M-261.1-01PB1-3M-261-1-01 PBI 3M-27 - 3M-27 - 3M-27 3M-27 - 3M -27A - 3M -27A 3M-27 - 3M-27AL1 - 3M-27AL7 3M-27 - 3M-27AL2 - 3M-27AL2 3M-27 - 3M-27AL2-01 - 3M-27AL2-07 3M-27 - 3M-27AL2PB1 - 3M-27AL2PB1 3M-27 - 3M-27AL3 - 3M-27AL3 Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Output errors are at Database: Offset TVD Reference: Well 3M-26 3M-26 @ 68.00usft (3M-26) 3M-26 @ 68.00usft (3M-26) True Minimum Curvature 2.00 sigma EDT 14 Alaska Production Offset Datum Reference Offset Distance Measured Measured Between Between Separation Depth Depth Centres Ellipses Factor (usft) (usft) (usft) (usft) 10,104.44 10,050.00 20.03 19.11 11,680.54 11,575.00 48.53 -72.78 9,700.00 9,700.00 0.05 -0.20 Warning Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range 21.710 CC 0.400 STOP Drilling, ES, SF 0.205 STOP Drilling, CC, ES, SF Out of range Out of range Out of range Out of range Out of range Out of range Out of range Offset Design Kuparuk 3M Pad -3M -26 -3M -261_1 -3M -26L1 Offset sire E.I. 0,00 usft Survey Program: 71�CT-MS, 9313-M4WI14CONLY, 9433 WD ORaet Well Ertor: 0.00 usft Rehrence Oaset Seml MaJpr Axis pialance M...ned Vertical Measured Vemimi RafemmM @/eet Anmutb Offset Wellbore Centre Between aetween Minimum Seperetlon Wamin9 Depth Depth Nish Depth from North +1418 +EJ -W cemres Ellipses Separation Factor (usft) (usft' (usft) Neff) (usft) (usft) C) Iusin (usft) (usft) (usft) Iuaft) 9,708.62 6,317.74 9,725.00 6,323.84 0.17 0.88 -108.40 664041 44.84 42.91 41.90 101 42,335 9,731.11 6,317.65 9,750.00 6,324.68 0.27 1.12 -110.86 6655.76 25.12 58.92 57.56 1.36 43.270 9,760.95 6,319.17 9,775.00 6,325.14 0.35 1.37 -117.17 6,670.78 5.14 73.18 71.28 1.90 38.561 9,798,14 6,320.00 9,800.00 6,325.51 0.48 1.66 -127.20 6,Ba5.19 -15.28 84.46 81.93 2.53 33.399 9,811.53 6,319.28 9,825.00 6,325.83 0.73 1.97 440.36 6,698,99 -30.12 91.70 88.56 3.14 29.182 9,888.79 6,316.66 9,SW+W 6,325.92 1,11 2.31 -155.99 6,712.33 57.26 93.77 90.22 3.55 26.385 9,935.00 6.312.51 9,87500 6,325,53 1.56 2.67 -172.46 6,725.51 -78,51 90.08 86.63 3.48 25.891 9,971.92 6,308.24 9,90000 6,324.49 1,94 3.05 174.75 6,738.83 -99.63 81.08 78.07 301 26.931 $896.46 6,305.24 9,925.00 6,323.30 2.18 3.47 169.75 6752.10 -120.78 70.56 67.42 3.14 22465 CC - Min centre to center distance or covergent point, SF - min separation factor, ES - min ellipse separation 228/2019 1:55:22PM Page 3 COMPASS 5000.14 Build 85D ConocoPhillips BATER ConocoPhiiiips Anticollision Report IGHES a GE company Company: ConocoPhillips Alaska lnc_Kupawk Project: Kuparuk River Unit -2 Reference Site: Kuparuk 3M Pad Site Error: 0.00 usft Reference Well: 3M-26 Well Error: 0.00 usft Reference Wellbore 36.11-2611-01 Reference Design: 3M-26L1-01_wp05 Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Output errors are at Database: Offset TVD Reference: Well 3M-26 3M-26 @ 68.00usft (3M-26) 3M-26 @ 68.00usft (3M-26) True Minimum Curvature 2.00 sigma EDT 14 Alaska Production Offset Datum Reference 3M-26L1-01_wp05 GCT -MS 9,313.00 Filter type: NO GLOBAL FILTER: Using user defined selection & filtering criteria 9,585.53 3M-261_1 MWD(3M-26L1) Interpolation Method: MD Interval 25.00usft Error Model: ISCWSA Depth Range: 9,696.33 to 11,700.00usft Scan Method; Tray. Cylinder North Results Limited by: Maximum center -center distance of 1,363.20 usft Error Surface: Combined Pedal Curve Warring Levels Evaluated at: 2.79 Sigma Casing Method: Added to Error Values Survey Tool Program From To (usft) (usft) Summary Date 2/28/2019 Survey (Wellbore) Tool Name Description 71.01 9,311.22 3M-26 (3M-26) GCT -MS 9,313.00 9,402.68 3M-261_1 MWD-INC(3M-26L7) MWD-INC_ONLY 9,433.23 9,585.53 3M-261_1 MWD(3M-26L1) MWD 9,608.00 9,635.67 3M-26L1-01PB1 MWD -INC (314-261-1-01P MWD-INC—ONLY 9,666.91 9,696.33 3M-26L7-01PB1 MWD (3M-26L1-01PB1) MWD 9,696.33 11,700.00 3M-26L1-01_wp05(3M-261-1-01) MWD Site Name Offset Well - Wellbore -Design Kuparuk 3M Pad 3M-07 - 3M-07 - 3M-07 3M-07 - 3M-07 - 3M-07 3M-07 - 3M-07 - 3M-07 3M-08 - 3M-08 - 3M-08 3M -08 -3M -08-3M-08 3M-11 - 3M-11 - 3M-11 3M-11 - 3M-11 - 3M-11 3M-12 - 3M-12 - 3M-12 3M-12 - 3M-12 - 3M-12 3M-12 - 3M-12 - 3M-12 3M-17 - 3M-17 - 3M-17 3M-17 - 3M-17 - 3M-17 31111-19 - 3M-19 - 3M-19 3M-20 - 3M-20 - 3M-20 3M-23 - 3M-23 - 3M-23 3M-23 - 3M-23 - 3M-23 3M-23 - 3M-23 - 3M-23 3M-23 - 3M -23A - 3M -23A 3M -23 -3M -23A -3M -23A 3M -23 -3M -23A -3M -23A 3M-23 - 3M-23AL1 - 3M-23AL1 3M-23 - 3M-23AL7 - 3M-23AL1 3M-23 - 3M-23AL7 - 3M-23AL1 3M-23 - 3M-23AL2 - 3M-23AL2 3M-23 - 3M-23AL2 - 3M-23AL2 3M-23 - 3M-23AL2 - 3M-23AL2 3M-23 - 3M-23AL3 - 3M-23AL3 3M-23 - 3M-23AL3 - 3M-23AL3 3M-23 - 3M-23AL3 - 3M-23AL3 3M-23 - 3M-23AL3PB1 - 3M-23AL3PB1 Schlumberger GCT multishot MWD-INC_ONLY—FILLER MWD - Standard MWD-INC_ONLY_FILLER MVVD - Standard MWD - Standard Reference Offset Distance Measured Measured Between Between Depth Depth Centres Ellipses (usft) (usft) (usft) lush) Separation Warring Factor Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range CC - Min centre to center distance or covergent point, SF - min separation factor, ES - min ellipse separation 2282019 1:55:22PM Page 2 COMPASS 5000.14 Build 85D ConocoPhillips Project: Kupamk River Unit_2Flo Site: Kupamk 3M Pad eom„"ems uep•nK E,ra WELLBORE DETAILS. 3M-26LI-01 REFERENCE INFORWTION Parent Wellbore: 3M -26L1-01 PBi Cp rwle(Rfl&N..: WM3MM,T.i,w Well: 3M-26 su.ppin.sans•. Teen MD: 8696.33 VeNmI OVD) Relamc: Wm Ike Level Wellbore: 3M -26L1-91 a awl•. war SepApa IVs) Rxemnee: SM -faroµ att6) Plan: 3W2GL1-01_wpO6(3M-2613M-26L1-01) e.off 4 nte+1•etl Dapn Rele�mu: 3LSRs a 68Mo (31kn) Celw'efm tMMA: Mnmvm C.'... WELL DETAILS: 3M-26 +N/ -S +E/ -W Northing Easting Latitude Longitude 0.00 0.00 6016559.83 506274.89 70" 27'23.296 N 149' 56'55.644 W Sec MD Inc Azi -S +E/ -W Dleg TFace vsect Anno-151on 1 9696.33 94.52 347.01 6250.59 6636.64 88.99 0.00 0.00 3241.26 TIP 2 9705.00 94.13 349.68 6249.94 6645.11 87.24 31.04 98.23 3247.00 KOP 3 9735.00 86.33 345.18 6249.82 6674.36 80.72 30.00 210.00 3267.27 Start 30 dls 4 9835.00 91.79 315.67 6251.50 6760.32 31.92 30.00 280.00 3352.52 4 5 9965.00 97.05 276.89 6241.09 6816.73 -81,96 30.00 279.00 3479.34 End 30 d1s, Start 7 dls 6 10035.00 96.93 271.96 6232.56 6822.09 -151.21 7.00 269.00 3541.99 6 7 10145.00 89.23 271.96 6226,65 6825.83 -260.90 7.00 180.00 3638.86 7 8 10495.00 89.30 296.46 6231.18 6911.08 -597.59 7.00 90.00 3973.06 8 9 10615.00 87.86 304,74 6234.16 6972.08 -700.76 7.00 100.00 4092.91 9 10 10815.00 87,92 318.75 6241.56 7104.81 -849.51 7.00 90.00 4288.11 10 11 11065.00 91.60 301.63 6242.62 7265.51 -1039.75 7.00 282.00 4533.21 11 12 11240.00 89.45 289.57 6241.01 7340.98 -1197.27 7.00 260.00 4707.35 12 13 11700.00 89.54 321.77 6245.19 7605.70 -1566.04 7.00 90A0 5159.08 Planned TD at 117001 C F Mean Sea 8251 8101 ]951 ]801 765( 750( =735( 0 u, =;20( t]osc O 2-675( z O GC660C 645[ 630[ 6150 BAF�I a GEwmpany S o e o West( -)/East(+) (150 usf /in) 5960 4 6045 11 ■■■■■■■■■�®■■■■I I1��®el 6110 +1-42+1-111111BI P' nneit�7.1 61753M- 3M-26LIA1 6240 6305 -4 ■■■■MEN 'IIP 4 ■■ 6370 ■■■■■�■■■■■ KCPEnd 0 dls, n s ■,l''��I M-26 1 fart 30 Is S o e o West( -)/East(+) (150 usf /in) 5960 4 6045 6110 +1-42+1-111111BI P' nneit�7.1 61753M- 3M-26LIA1 6240 6305 -4 'IIP 4 - 1 6370 KCPEnd 0 dls, n s M-2 M-26 1 fart 30 Is 6435 6500 3 -26 PauBl I 3M- 61 1_ u1t2 6565 -263 -26 6€3@ Vertical Section at 300.00° (65 usft/in) ConocoPhillips N 3M -23/3M-21 1M-WIM-33AIAL1 3M-26 ® 68.00usfl (314-26) Project: Kuparuk River Dnit 2,��k Site: Kuparuk 3M Pad tee„ �� WELLBORE DETAILS: 3M-261.1-01la RENCE NIORMAnON Wellbore: 3M-261.1-01P81krerce:3M-Z6QD6A ererca: M 3WM, T.WNI:-26Parent Te cn MD: 9696.33 gl(3WM) Wellbore: 3M•26L1-81 op ayx: e"w ere:we: sbl-AWN. UAOE) Plan: 3M-261-1-01 wp06 (3M-2fipM-261.1-01) eoosa dere:.x: 3W26 a sMooan l3W%1 Mem t M.lMol Mkimum CYNNNB BA CER F�UGHES G(F mpar, 750 -9100 -845) -7600 -]ISO fi500 -5850 5200 -4:%$D -5900 -3350 .E6tlP LASD 1'00 a -55D 0 650 1300 IM 3600 1250,3900 4550 5200 5850 6500 7150 9800 \8450 9100 9950 10400 11050 11700 Seca W-141M-M.L01 .1 11 61.1 3M-26 Proposed CTD Schematic 62# H-40 e @ 121' 9-5/8" 36# J-55 shoe @ 4882' MD MD via perfs 9358' MD 7" 26# L-80 shoe @ 9614' MD 3-1/2" 9.3# J-55 ELIE 8rd Tubing to surface 3-1/2" Camco W-1 Landing Nipple @ 2021" RKB (2.812" min ID) 3-1/2" Camco MMM gas lift mandrel @ 9153' RKB Baker GBH -22 Locator Seal Assembly @ 9202' RKB (3.0" ID) Baker FB1 Perm packer @ 9205' RKB (4.0" ID) Baker SBE @ 9209' RKB (4" ID) 3-1/2" Camco D Nipple @ 9227' RKB (Milled Out to 2.80") Baker SOS @ 9236' RKB (2.992" ID) 3-1/2" tubing tail @ 9237' RKB 31VI-261-1-01 TO @ 11,700' MD Liner Top @ 9220' MD Li-01PB1 10576' MD )red Billet MD (Pr000 3M-2611 TD @ 11,676' MD Liner top @ 9608' MD P70 ,2/9—C2I� Loepp, Victoria T (DOA) From: Loepp, Victoria T (DOA) Sent: Thursday, February 28, 2019 3:43 PM To: 'Long, William R' Cc: Boyer, David L (DOA) Subject: KRU 3M -26L1-01 (219-017) Revised PTD - Verbal Approval to Proceed William, Thanx for delivering the revised PTD for drilling this well to a new BHL. Verbal approval is granted to spud this lateral as early as tonight. Victoria Loepp Victoria Loepp Senior Petroleum Engineer State of Alaska Oil & Gas Conservation Commission 333 W. 7th Ave Anchorage, AK 99501 Work: (907)793-1247 Victoria Loepp(ODalaska.go 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 Victo(a.Loepas alaska.gov From: Long, William R <William.R.Long@conocophillips.com> Sent: Thursday, February 28, 2019 10:41 AM To: Loepp, Victoria T (DOA) <victoria.loepp@alaska.gov> Cc: Starck, Kai<Kai.Starck@conocophillips.com>; Ohlinger, James J <James.J.OhlirlconocophiIli ps.com>; Herring, Keith E <Keith.E.Herring@conocophillips.com>; McLaughlin, Ryan <Ryan.McLaughlin@conocophillips.com> Subject: Change of Well Plan for KRU 3M -26L1-01 (219-017) Victoria, Nabors CDR3-AC is currently rigged up on KRU 3M-26. We have successfully completed the original scope of 3M-261.1 (219-016) to the west. Yesterday we kicked off and began drilling KRU 3M -26L1-01 (219-017) to the north. Last night we were unable to find sand in the northern fault block. We plan to make a clean out run and set an anchored billet to plug back this lateral. We would like to re -drill the 3M -26L1-01 to the west paralleling the 3M -26L1 wellbore. Please find attached a current proposed well bore schematic and the original spider plot showing the directions of the 3M -26L1 and 3M-261_1-01 laterals. May we have verbal approval to move 3M-261-1-01 lateral to the west near the 3M -26L1 lateral? Well plans are currently being generated. Would you like an Application for Sundry Approvals for Change of Approved Program for the new well plan once it is finalized, or will verbal approval be sufficient for this change. Thanks, William R. Long Staff CTD Engineer ConocoPhillips 907-263-4372 (office) 281-723-6000 (cell) William.R.Lona@ConocoPhillips.com CD3 -115 RWO Procedure Alpine Producer PTD #209-006 Pre -Rig Work 1. Pull WRSV. 2. Get additional SBHP. 3. Cut Premier Packer at "11532' RKB in correct location to make it tubing retrievable. 4. Confirm deepest GLM is open. 5. Confirm latest packoff tests passed. 6. Coil Cleanout to 19,000' RKB to prepare for TCP run on -rig. 7. Install BPV. Rig Work MIRU 1. MIRU Nordic 1. Pull BPV. Kill well by circulating KWF long way around. 2. Record shut-in pressures on the T & IA. Plug and packer should provide competent barrier. If there is pressure, bleed off IA and/or tubing pressure and pull BPV. Complete 30 -minute NFT. Verify well is dead. a. Primary barrier: KWF and competent casing. b. Secondary barrier: Packoffs and Tree OR BOP. (BPV in place and confirmed in direction of flow while swapping tree to BOP and vice versa.) 3. Set BPV, confirm BPV with rolling test if needed, NO Tree, NU BOPE and test to 250/2,600 psi. Test annular 250/2,600 psi. a. MPSP of 2525 PSIG calculated from SBHP of 3201 psig at 11575' RKB (6755' TVD) on 2/22/2018. Retrieve Tubing Section 4. Pull BPV, MU landing joint and BOLDS. 5. Pull 4-1/2" x 3-1/2" tubing with jewelry down to mule shoe WLEG at 12026' RKB. Retrieve Tubing Section 6. Make cleanout run to 19,000' RKB if needed in addition to pre -rig coil cleanout run. 7. Makeup 3,000 of TCP guns and RIH on DP to depth of 19,000'. 8. Correlate on depth. Fire guns. TOOH. Install in 41/2" x 3-1/2" Tubing Completion 9. MU 4-1/2" x 3-1/2" completion with non -sealing overshot, nipples, packer, single gauge, GLMs, and SCSSSV. RIH and confirm overshot has engaged tubing stub. 10. Space out, land tubing hanger and install packoffs. 11. Drop ball and rod and set packer top @ approximately 11515' RKB (66737' TVD) w/ completion. a. TOC calculated at 11200 RKB (6579' TVD). 12. Pressure test tubing to 3000 psi for 5 minutes. 13. Pressure test inner annulus to 2500 psi for 30 minutes on chart. ND BOP, NU Tree 14. Confirm pressure tests, then shear out SOV with pressure differential. 15. Install BPV. Confirm BPV. 16. ND ROPE. NU tree. 17. Freeze protect well. 18. RDMO. Page 1 of 1 TRANSMITTAL LETTER CHECKLIST WELL NAME: LC R OL, 3 M -as 1-1-01 PTD: 'd. 14 - O I-* Development Service Exploratory _ Stratigraphic Test —Non -Conventional FIELD: K t 1 p&y M K RI Ytr POOL: �a y Lk— R i Vl N� n i l Check Box for Appropriate Letter / Paragraphs to be Included in Transmittal Letter CHECK OPTIONS TEXT FOR APPROVAL LETTER MULTI LATERAL The permit is for a new wellbore segment of existing well Permit No. (93 -IM , API No. 50-OZ9-2Z4.31 (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 29 AAC 25.005(f) all records, data and logs Pi `must P1 u.9 go,c (< acquired for the be clearly differentiated in both well Phot !I@!& name (KRtk 3M-26 LI -01 PB 1 -Eltrand API number (50- OZ4 27+31 - 40 OD) from records, data and logs acquired for well name on permit). The permit is approved subject to full compliance with 20 AAC 25.055. Spacing Approval to produce/inject is contingent upon issuance of a Exception conservation 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: Non- production or production testing of coal bed methane is not allowed for 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 / 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 v/ 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 PTD#:2190170 Company NOCOPHILLIPS ALASKA INC._.. Initial Classffype Well Name: KUPARUK RIV UNIT 3M-261_1-01 Program DEV Well bore seg DEV / PEND GeoArea 890 Unit 11160 On/Off Shore On Annular Disposal ❑ Administration 1 Permitfee attached NA 2 Lease number appropriate- - ........ - .. - - - - - - - Yes - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - 3 Unique well name and number---- -- ---------- Yes -.- -- ---- -- ---- -- - -- - - -- -- - 4 Well located in a. defined pool........... - - - - - . . Yes - - 5 Well located proper distance from drilling unit-boundary ....... .. . . . . ... . . . . . . . Yes - - 6 Well located proper distance from other wells . . . . . . . . . . . ............. . . . Yes - - - - - - - - - - - - - 7 Sufficient acreage available in driUing unit- - . - - - _ - - _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes - - - - - - - - - - - - - - - - - 8 If deviated, is wellbore platincluded- - - - - - - - - .......... . . . NO.... - _ - No land plat._ Directional plan & cross-section views included.. 9 Operator only affected party .. - - _ . Yes ... .... . ...... . . . ......... ..... . 10 Operator has appropriate bond in force .. . ............ . . . . . . . . . . . . . . Yes 11 Permit can be issued without conservation order- - - - - - - ............... . . . Yes- Appr Date 12 Permit on be issued without administrative approved - - - - - - - - - - - - - - - - - - ---- Yes ..... .. .. _ . - .... ... . 13 Can permit be approved before 15-day wait. - - - - - Yes - - - - - - - - - - - - - - - - - - - - - - - - DLB 3/4/2019 14 Well located within area and strata authorized by Injection Order # (put. 10# in comments) (For. NA------- - - - - - - - - - - 15 All welis.within 1/4-mile area of review identified (For service well only) .... NA .. .. 16 Pre-produced injector: duration of pre-Production Less than 3 months (For service well only) _ _ NA - - - - - - - - - - - - - - - - - 17 18 Nonconven, gas conforms to AS31.05,030Q. 1.A),Q.2.A-DJ .... - - - - - - Conductor string. provided - - - - - - _ NA...- NA ....... Conductorsetfor.KRll 310-28 ...... . Engineering 19 Surface casing. protects all known USDWs - - - - - - - _ - - _ NA - - - - - - - Surface casing set for KRU 3M-26- - 20 CMT vol adequateto circulate on conductor & surf csg _ - _ .... - - - - .... - . NA _ _ - _ . _ - Surface casing set and fullycemented- - - - - - 21 CMT vot adequate, to tie-in long string to surf csg- - - - _ _ - ...... ---- --- ----- NA...... ...... .. ... . 22 CMT will cover all known productive horizons. ... _ .... - - _ No - _ - - - _ - Productiveintervalwill be completed with -uncemented slotted liner - - 23 Casing designs adequate for C, T, 8 &_permafrost. . . . . . ......... . Yes 24 Adequate tankage of reserve pit - - - . . . . . ................... Yes .... Rig has steel tanks; all waste to approved disposal wells 25 If a. re-drill, has.a 10.403 for abandonment been approved _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ NA- 26 Adequate wellbore separation proposed - - - - - - - - - - - - _ Yes - - - - Anti-collision analysis complete; no major risk failures 27 1f diverter required, does it meet regulations- - - - - - - - - - . - .. NA... - Appr Date 28 Drilling fluidprogramschematic & equip list adequate..... - _ _ _ _ _ _ _ _ _ _ _ _ _ Yes - - - - Max formation pressure is. 4280 psig(13.1 ppg EMW ),, will drill w/ 8,6-ppg and maintain overbal w/ MPD - - VTL 3/1/2019 29 BOPEs, do they meet regulation - - - -------- - - - - - - - - - . _ _ _ _ . Yes - - - - - 30 BOPE.press rating appropriate; test to _(put psig in comments)- ---- - -- - - - - - - - - - - - - Yes - - - _ MPSP is 3650 psig; will test BOPs_to 4000-psig 31 Choke. manifold complies w/API. RP-53 (May 84)- - - - - - - - - - - - - - - - - - - - - - - - - - Yes - .... - .. .. . . 32 Work will occur without operation shutdown. - ......... - - - Yes - - - - - - - - - - - - - - - - - - - - - - - - - - - 33 Is presence of H2$ gas probable - - - - - - - - - - - - - - - - - - - - --------- Yes - - - H2$ measures required_ - - - - - - 34 Mechanical condition of wells within AOR verified (For service well oNy) .............. NA ...... 35 Permit can be Issued w(o hydrogen. sulfide measures -- - - - - - - - - - - - - - - - - - - - - - - No - 3M-Pad wells are.H2Scbearing, H2S measures are required. Geology 36 Datapresentedon potential overpressure zones- - - - - -- - - - - - - - - - -- - - - - - - - - - Yes - - - - - - - Appr Date 37 Seismic analysis of shallow gaszones. . . . . . . . . . . ................. NA.. - - - - - - - - DLB 3/4/2019 38 Seabed condition survey (if off-shore) - - - - - - - - - - - - - - - - -- - - - - -------- - - NA 39 Contact name/phone for weekly-progress reports, [exploratory only] - - - - - - - - - - - - -----NA ... .... . Geologic Engineering Public Revised 3/1/19: SHL changed from the North to the West. Unable to find sand in northern fault block. VTL Date: Date Commissioner: Commissioner. Commissioner Date I� THE STATE °fALASKA GOVERNOR MIKE DUNLEAVY James Ohlinger Staff CTD Engineer ConocoPhillips Alaska, Inc. PO Box 100360 Anchorage, AK 99510-0360 (- Alaska Oil and Gas Conservation Commission Re: Kuparuk River Field, Kuparuk River Oil Pool, KRU 3M -26L1-01 ConocoPhillips Alaska, Inc. Permit to Drill Number: 219-017 Surface Location: 938' FNL, 1593' FEL, SEC. 25, TUN, R8E, UM Bottomhole Location: 2613' FNL, 5174' FEL, SEC. 18, TUN, R9E, UM Dear Mr. Ohlinger: 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 v .aogcc.olaska.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. 193-193, API No. 50-029-22431- 00-00. Production should continue to be reported as a function of the original API number stated above. Per Statute AS 31.05.030(d)(2)(B) and Regulation 20 AAC 25.071, composite curves for well logs run must be submitted to the AOGCC within 90 days after completion, suspension or abandonment of this well. This permit to drill does not exempt you from obtaining additional permits or an approval required by law from other governmental agencies and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the AOGCC reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the AOGCC specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or an AOGCC order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. Sincerely, Cathy P. Foerster Commissioner DATED this7d y of February, 2019. STATE OF ALASKA AL ,CA OIL AND GAS CONSERVATION COMMi—JON PERMIT TO DRILL 20 AAC 25.005 RECEIVED cahi �0 2019 1 a. Type of Work: Drill ❑ Lateral El Redrill ❑ ReentryEll i"� [� f \ ' 1b. Proposed Well Class: Exploratory - Gas ❑ Service - WAG Service - Disp ❑ Straligraphic Test ❑ Development -Oil ❑✓ Service- Win! ❑ Single Zone 0 Exploratory - Oil ❑ Development - Gas ❑ Service - Supply ❑ Multiple Zone ❑ 1c. Specify if well is propo'se'd -for: Coalbed Gas ❑ Gas Hydrates ❑ Geothermal ❑ Shale Gas ❑ 2. Operator Name: ConocoPhillips Alaska, Inc. 5. Bond: Blanket Q Single Well ❑ Bond No. 5952180 11. Well Name and Number: KRU 310-2611-01 3. Address: P.O. Box 100360 Anchorage, AK 99510-0360 6. Proposed Depth: MD: 12500' TVD: 6300' 12. Field/Pool(s): Kuparuk River Pool / T P. Kuparuk River Oil Pool t; A. 619 4a. Location of Well (Governmental Section): Surface: 938' FNL, 1593' FEL, Sec 25, Tl 3N, R8E, UM Top of Productive Horizon: 4944' FNL, 1427' FEL, Sec 13, T13N, R8E, UM Total Depth: 2613' FNL, 5174' FEL, Sec 18, T13N, R9E, UM 7. Property Designation: PnL Z S S ADL 25522 A, A OL Z5gA3 8. DNR Approval Number: n+✓ dam. LONS 84-138 13. Approximate Spud Date: 2/13/2019 9. Acres in Property: 2560 14. Distance to Nearest Property: 2120' 4b. Location of Well (State Base Plane Coordinates - NAD 27): Surface: x- 506275 y- 6016560 Zone- 4 10. KB Elevation above MSL (ft): 68' GL / BF Elevation above MSL (ft): 27' 15. Distance to Nearest Well Open to Same Pool: 1580' (3Q -06A) 16. Deviated wells: Kickoff depth: 9600 feet Maximum Hole Angle: 103 degrees 17. Maximum Potential Pressures in psig (see 20 AAC 25.035) Downhole: 4280 Surface: 3650 18. Casing Program: Specifications Top - Setting Depth - Bottom Cement Quantity, c.f. or sacks Hole Casing Weight Grade Coupling Length MD TVD MD TVD (including stage data) 3" 2-3/8" 4.7# L-80 ST -L 3280' 9220' 6220' 12500' 6300' Slotted 19. PRESENT WELL CONDITION SUMMARY (To be completed for Redrill and Re -Entry Operations) Total Depth MD (ft): Total Depth TVD (ft): Plugs (measured): Effect. Depth MD (ft): Effect. Depth TVD (ft): Junk (measured): 9625' 6534' N/A 9522' 6453' 9450' Casing Length Size Cement Volume MD TVD Conductor/Structural 78' 16" 340 sx ASI CMT 121' 121' Surface 4841' 9-5/8" 950 sx ASIII, 530 sx G CMT 4882' 3624' Production 9576' 7" 250 sx Class G 9615' 6526' Perforation Depth MD (ft): 9324'- 9358' Perforation Depth TVD (ft): 6299' - 6325' Hydraulic Fracture planned? Yes ❑ No ❑Q ' 20. Attachments: Property Plat ❑ SOP Sketch Divertter Sketch Drilling Program v. Depth ot B Seabed Report e Drilling Flud Program t B Shallow Hazard Analysis 20 AAC 25.050 requirements 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: James Ohlinger Contact Email: Keith. E. Herrin COP. corn Authorized Title: Staff CTD Engineer Contact Phone: 907-263-4321 Authorized Signature: Date: Commission Use Only Permit to Drill Number: C)2 JAPI Number: 50-0 — — 1j` _ Permit Approval Date: Z 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: L7 Other: BOR r<Sfi to 412U0 pf"5 Samples req'd: Yes ❑ No(R" Mud log req'd: Yes❑No %fP n v/u� i -el fr5 t � assures: Yes [r No ❑l Directional svy req'd: Yes No[—] r/QryCf,t - p D sACZJNo[]� d/S/" rn � Post initial injection MIT mq'd: Yes[] N92' br- QN ppbin* GlLb'y1 CJS t c 1—?- � t 1,91 -ftra-Cll APPROVED BY Approved by: COMMISSIONER THE COMMISSION Date: — / Submit Form and Form 10-0Ot evised 5/2017 This permit is valid to.2 flfEq`dt `rOffn')til�atfv�at f pproval per 20 AAC 25.005(8) nachments it Duplicate V71 2-17117 oe ��. 8. 0�100�19 ConocoPhillips Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 January 30, 2018 Commissioner - State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Dear Commissioner: ConocoPhillips Alaska, Inc. hereby submits sundry application to set a whipstock and applications for permits to drill two laterals out of the KRU 3M-26 (PTD# 193-193) using the coiled tubing drilling rig, Nabors CDR3-AC. CTD operations are scheduled to begin in early February 2019. The objective will be to drill two laterals, KRU 3M-261_1 and 31VI-261-1-01, targeting the Kuparuk A -sand interval. To account for geological uncertainties, ConocoPhillips requests a variance from the requirements of 20 AAC 25.015 to allow the actual kick-off point to be anywhere along the length of the parent lateral instead of being limited to 500' from the original point. Attached to the sundry application are the following documents: - 10403 Sundry Application for KRU 3M-26 - Operations Summary in support of the 10-403 sundry application - Current Wellbore Schematic - Proposed CTD Schematic Attached to permit to drill applications are the following documents: - Permit to Drill Application Forms (10-401) for 3M-261_1 and 31VI-261-1-01 - Detailed Summary of Operations - Directional Plans for 3M-261_1 and 3M-261-1-01 - 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 3M -26L1 & 3M -26L1-01 Application for Permit to Drill Document 1. Well Name and Classification........................................................................................................ 2 (Requirements of 20 AAC 25.005(1) and 20 AAC 25.005(b))...................................................................................................................2 2. Location Summary.......................................................................................................................... 2 (Requirements of 20 AAC 25.005(c)(2))..................................................................................................................................................2 3. Blowout Prevention Equipment Information................................................................................. 2 (Requirements of 20 AAC 25.005(c)(3)).................................................................................................................................................2 4. Drilling Hazards Information and Reservoir Pressure.................................................................. 2 (Requirements of 20 AAC 25.005(c)(4)).................................................................................................................................................2 5. Procedure for Conducting Formation Integrity tests................................................................... 2 (Requirements of 20 AAC 25.005(c)(5))..................................................................................................................................................2 6. Casing and Cementing Program.................................................................................................... 3 (Requirements of 20 AAC 25.005(c)(6))..................................................................................................................................................3 7. Diverter System Information.......................................................................................................... 3 (Requirements of 20 AAC 25.005(c)(7))..................................................................................................................................................3 8. Drilling Fluids Program ........................................... (Requirements of 20 AAC 25.005(c)(8)) ............................................... 9. Abnormally Pressured Formation Information......... (Requirements of 20 AAC 25.005(c)(9))................................................... 10. Seismic Analysis......................................................... (Requirements of 20 AAC 25.005(c)(10))................................................. 11. Seabed Condition Analysis ........................................ (Requirements of 20 AAC 25.005(c)(11)).................................................. .......................................................... 3 ................................................................................ 3 .................................................................... 4 ............................................................................................... 4 12. Evidence of Bonding................................................................... (Requirements of 20 AAC 25.005(c)(12))......................................................................... .............................................. 4 ................................................................ 4 ..................... 4 .............................. 4 ................................ 4 ............................................. 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....................................................................... 6 (Requirements of 20 AAC 25.050(b))...................................................................................................................................................... 6 16. Attachments....................................................................................................................................6 Attachment 1: Directional Plans for 3M-261-1 & 3M-261-1-01 laterals..............................................................................6 Attachment 2: Current Well Schematic for 3M-26...........................................................................................................6 Attachment 3: Proposed Well Schematic for 3M-261-1 & 3M-261-1-01 laterals................................................................6 Page 1 of 6 January 30, 2019 PTD Application: 3M-261-1 & 3M-261-1-01 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 3M-261-1 & 3M-261-1-01. All laterals will be classified as "Development"wells. 2. Location Summary (Requirements of 20 AAC 25.005(c)(2)) These laterals will target the A sand package in the Kuparuk reservoir. See attached 10-401 form for surface and subsurface coordinates of the 3M -26L1 & 3M-261-1-01. 3. Blowout Prevention Equipment Information (Requirements of 20 AAC 25.005 (c)(3)) Please reference blowout prevention (BOP) schematics on file with the Commission for Nabors CDR3-AC. BOP equipment is as required per 20 AAC 25.036 for thru-tubing drilling operations. — Pipe rams, blind rams and the CT pack off will be pressure tested to 250 psi and to 4,000 psi. Using the maximum formation pressure in the area of 4280 psi in 3M-17 (i.e. 13.1 ppg EMW), the maximum potential surface pressure in 3M-26, assuming a gas gradient of 0.1 psi/ft, would be 3650 psi. See the "Drilling Hazards Information and Reservoir Pressure" section for more details. — The annular preventer will be tested to 250 psi and 2,500 psi. 4. Drilling Hazards Information and Reservoir Pressure (Requirements of 20 AAC 25.005 (c)(4)) Reservoir Pressure and Maximum Downhole Pressure (Requirements of 20 AAC 25.005 (c)(4)(a)) The formation pressure in KRU 3M-26 was measured to be 3992 psi (12.2 ppg EMW) on 8/25/2018. The maximum downhole pressure in the 3M-26 vicinity is to the south in the 3M-17 producer at 4280 psi (13.1 ppg EMW) from November of 2014. Potential Gas Zones (Requirements of 20 AAC 25.005 (c)(4)(b)) None of the offset injection wells to 3M-26 have injected gas, so there is a low probability of encountering free gas while drilling the 3M-26 laterals. If gas is detected in the returns the contaminated mud can be diverted to a storage tank away from the rig. Potential Causes of Hole Problems (Requirements of 20 AAC 25.005 (c)(4)(c)) The major expected risk of hole problems in the 3M-26 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 3M-26 laterals will be drilled under 20 AAC 25.036 for thru-tubing drilling operations so a formation integrity test is not required. Page 2 of 6 January 30, 2019 PTD Application: 311/1-261-1 & 31M-261-1-01 6. Casing and Cementing Program (Requirements of 20 AAC 25.005(c)(6)) New Completion Details Lateral Name Liner Top Liner Btm Liner Top Liner Btm Liner Details Btm MD MD MD TVDSS TVDSS Conductor 3M -26L1 9600' 11,700' 6263' 6271' 2-3/8", 4.7#, L-80, ST -L slotted liner; 0' 121' 1640 670 Surface aluminum billet on to 3M -26L1-01 9220' 12,500' 6152'6232' 4882' 2-3/8", 4.7#, L-80, ST -L slotted liner; 3624' 3520 2220 Production 7" deployment sleeve on to Existing Casing/Liner Information Category OD Weight Grade Connection Top MD Btm MD Top TVD Btm TVD Burst psii Collapse psi Conductor 16" 62.5 H-40 Welded 0' 121' 0' 121' 1640 670 Surface 9-5/8" 36.0 J-55 BTC 0' 4882' 0' 3624' 3520 2220 Production 7" 26.0 L-80 BTC -MOD 0' 9615' 0' 6526' 7240 5410 Tubing 3-1/2" 9.3 J-55 EUE-8rd MOD 0 9237' 0 6233' 7180 7400 7. Diverter System Information (Requirements of 20 AAC 25.005(c)(7)) Nabors CDR3-AC will be operating under 20 AAC 25.036, for thru-tubing drilling operations. Therefore, a diverter system is not required. 8. Drilling Fluids Program (Requirements of 20 AAC 25.005(c)(8)) Diagram of Drilling System A diagram of the Nabors CDR3-AC mud system is on file with the Commission. Description of Drilling Fluid System — Window milling operations: Water -Based PowerVis milling fluid (8.6 ppg) — Drilling operations: Water-based PowerVis mud (8.6 ppg). This mud weight will not hydrostatically overbalance the reservoir pressure, overbalanced conditions will be maintained using MPD practices described below. — Completion operations: The well will be loaded with 12.4 ppg K -Formate completion fluid in order to provide formation over -balance and well bore stability while running completions. Managed Pressure Drilling Practice Managed pressure drilling (MPD) techniques will be employed to maintain a constant overbalanced pressure on the open hole formation 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 5,000 psi rated coiled tubing pack off and MPD choke. BOPE equipment provides the secondary well control as detailed in section 3 "Blowout Prevention Equipment Information". In the 3M-26 laterals we will target a constant BHP of 12.2 ppg EMW at the window. The constant BHP target will be adjusted through choke pressure and/or mud weight increases to maintain overbalanced conditions if increased reservoir pressure is encountered. Additional choke pressure or increased mud weight may also be employed for improved borehole stability. Any change of circulating friction pressure due to change in pump rates or change in depth of circulation will be offset with back pressure adjustments. Page 3 of 6 January 30, 2019 PTD Application: 3M-261_1 & 3M -26L1-01 Pressure at the 3M-26 Window (9314' MD. 6292' TVD) Usina MPD 9. Abnormally Pressured Formation Information (Requirements of 20 AAC 25.005(c)(9)) N/A - Application is not for an exploratory or stratigraphic test well. 10. Seismic Analysis (Requirements of 20 AAC 25.005(c)(10)) N/A - Application is not for an exploratory or stratigraphic test well. 11. Seabed Condition Analysis (Requirements of 20 AAC 25.005(c)(11)) N/A - Application is for a land based well. 12. Evidence of Bonding (Requirements of 20 AAC 25.005(c)(12)) Evidence of bonding for ConocoPhillips Alaska, Inc. is on file with the Commission. 13. Proposed Drilling Program (Requirements of 20 AAC 25.005(c)(13)) Summary of Operations Background KRU well 3M-26 is a Kuparuk A -sand producer equipped with 3-1/2" tubing and 7" production casing. The CTD sidetrack will utilize two laterals to target the A 1 sand to the north and west of 3M-26. The laterals will increase A -sand resource recovery and throughput. CDR3-AC will set a mechanical whipstock (High Expansion Wedge) inside the 7" casing at the planned kick off point of 9,314'MD. The 3M -26L1 lateral will exit through the 7" at 9,314' MD and TD at 11,700' MD, targeting the Al sand to the west. It will be completed with 2-3/8" slotted liner from TD up to 9600' MD with an aluminum billet for kicking off the 3M -26L1-01 lateral. The 3M -26L1-01 lateral will drill to a TD of 12,500' MD targeting the Al sand to the north. It will be completed with 2-3/8" slotted liner from TD up into the 3-1/2" tubing at 9920' MD with a deployment sleeve. Page 4 of 6 January 30, 2019 r+PD Pumps On 1.8 bpm) Pumps Off A -sand Formation Pressure 12.2 3992psi 3992psi Mud Hydrostatic 8.6 2813 psi 2813 psi Annular friction i.e. ECD, 0.080psi/ft) 745 psi 0 psi Mud + ECD Combined no chokepressure) 3558 psi underbalanced -434psi) 2813psi underbalanced -1179psi) Target BHP at Window 12.2 3992 psi 3992 psi Choke Pressure Required to Maintain Target BHP 434 psi 1179 psi r 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 3M-26 is a Kuparuk A -sand producer equipped with 3-1/2" tubing and 7" production casing. The CTD sidetrack will utilize two laterals to target the A 1 sand to the north and west of 3M-26. The laterals will increase A -sand resource recovery and throughput. CDR3-AC will set a mechanical whipstock (High Expansion Wedge) inside the 7" casing at the planned kick off point of 9,314'MD. The 3M -26L1 lateral will exit through the 7" at 9,314' MD and TD at 11,700' MD, targeting the Al sand to the west. It will be completed with 2-3/8" slotted liner from TD up to 9600' MD with an aluminum billet for kicking off the 3M -26L1-01 lateral. The 3M -26L1-01 lateral will drill to a TD of 12,500' MD targeting the Al sand to the north. It will be completed with 2-3/8" slotted liner from TD up into the 3-1/2" tubing at 9920' MD with a deployment sleeve. Page 4 of 6 January 30, 2019 r+PD PTD Application: 31VI-261_1 & 31VI-261-1-01 Pre -CTD Work 1. RU Slickline: C/O GLV's, Dummy whipstock drift run 2. RU Service Coil: Mill out "D" nipple and conduct fill cleanout 3. RU E -line: Caliper 7" production casing and 3-1/2" tubing 4. Prep site for Nabors CDR3-AC Ria Work 1. MIRU Nabors CDR3-AC rig using 2" coil tubing. NU 7-1/16" BOPE, test. 2. 3M -26L1 Sidetrack (Al sand -West) i. Set top of whip -stock at 9314' MD ii. Mill 2.80" window at 9314' MD. iii. Drill 3" bi-center lateral to TD of 11,700' MD. iv. Run 2%" slotted liner with an aluminum billet from TD up to 9600' MD. 3. 3M -26L1-01 Lateral (A1 sand -North) i. Kick off of the aluminum billet at 9600' MD. ii. Drill 3" bi-center lateral to TD of 12,500' MD. iii. Run 2%" slotted liner with deployment sleeve from TD up to 9920' MD. 4. Obtain SBHP, freeze protect, ND BOPE, and RDMO Nabors CDR3-AC. Post -Rig Work 1. Return to production Pressure Deployment of BHA The planned bottom hole assemblies (BHAs) are too long to simply isolate by closing the double swab valves on the Christmas tree. MPD operations require the BHA to be lubricated under pressure using a system of double swab valves on the Christmas tree, double deployment rams, double check valves and double ball valves in the BHA, and a slick -line lubricator can be used. This pressure control equipment listed ensures there are always two barriers to reservoir pressure, both internal and external to the BHA, during the deployment process. During BHA deployment, the following steps are observed. — Initially the double swab valves on the tree are closed to isolate reservoir pressure. The lubricator is installed on the BOP riser with the BHA inside the lubricator. — Pressure is applied to the lubricator to equalize across the swab valves. The swab valves are opened and the BHA is lowered in place via 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. Page 5 of 6 January 30, 2019 PTD Application: 3M-261_1 & 3M-261_1-01 Liner Running - The 3M-26 laterals will be displaced to an overbalancing fluid (12.4 ppg K -Formate) prior to running liner. See "Drilling Fluids" section for more details. - While running 2-3/8" slotted liner, a joint of 2-3/8" non -slotted tubing will be standing by for emergency deployment. A floor valve is made up onto this joint ahead of time, and the rig crew conducts a deployment drill with this emergency joint on every slotted liner run. The 2-3/8" rams will provide secondary well control while running 2-3/8" liner. 14. Disposal of Drilling Mud and Cuttings (Requirements of 20 AA 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). 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 3M-261-1 1210' 3M-261-1-01 2120' Distance to Nearest Well within Pool Lateral Name Distance Well 3M-261-1 2391' 3M-17 3M-261-1-01 1580' 3Q -06A 16.Attachments Attachment 1: Directional Plans for 3M -26L 1 & 3M-261_1-01 laterals Attachment 2: Current Well Schematic for 3M-26 Attachment 3: Proposed Well Schematic for 3M -26L 1 & 3M -26L 1-01 laterals Page 6 of 6 January 30, 2019 ConocoPhillips ConocoPhillips Alaska Inc—Kuparuk Kuparuk River Unit Kuparuk 3M Pad 3M-26 3M-261-1-01 Plan: 3M-26L1-01_wp03 Standard Planning Report 28 January, 2019 BT�aGEcompany GHES ConocoPhillips BA_ ICER ConocoPhillips Planning Report UGHES a GE.rapany Database: OAKEDMPI Company: ConocoPhillips Alaska lnc_Kuparuk Project: Kupamk River Unit Site'. Kupamk 3M Pad Well: 3M-26 Wellbore: 3M-261-1-01 Design: 3M-261-1-01_wp03 Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Well 3M-26 Mean Sea Level 3M-26 @ 68.00usft (3M-26) True Minimum Curvature 'roject Kupamk River Unit, North Slope Alaska, United States Map System: US State Plane 1927 (Exact solution) System Datum: Mean Sea Level ieo Datum: NAD 1927 (NADCON CONUS) Using Well Reference Point gap Zone: Alaska Zone 04 Using geodetic scale factor ifte Kupamk 3M Pad 3M-26 TVD Below its Position: Northing: 6,016,202.17 usft Latitude: 70° 27' 19.780 1 mm: Map Easting: 506,126.99usft Longitude: 149° 56'59.998 V 'cation Uncertainty: 0.00 usft Slot Radius: 0.000in Grid Convergence: 0.05 ° Well 3M-26 TVD Below Dogleg Well Position +N/ -S 0.00 usft Northing: 6,016,559.83 usft Latitude: 70° 27' 23.296 N System +E/ -W 0.00 usft Easting: 506,274.89 usft Longitude: 149° 56' 55.644 W Position Uncertainty (usft) 0.00 usft Wellhead Elevation: usft Ground Level: 0.00 usft Wellbore 3M-261-1-01 Magnetics Model Name Design Audit Notes: Version: Vertical Section: Plan Sections BGGM2018 3M-26L1-01_wp03 Sample Date 4/1/2019 Phase: Depth From (TVD) (usft) 0.00 Declination Dip Angle (1 (1) 16.63 PLAN Tie On Depth: +N/ -S +E/ -W (usft) (usft) 0.00 0.00 80.93 Field Strength (nT) 57,424 9,600.00 Direction (') 20.00 Measured TVD Below Dogleg Build Turn Depth Inclination Azimuth System +N/S +E/ -W Rate Rate Rate TFO (usft) (°) (°) (usft) (usft) (usft) (°1100usft) (°1100usft) (°1100usft) (1) Target 9,600.00 95.48 322.94 6,262.63 6,554.28 164.95 0.00 0.00 0.00 0.00 9,630.00 90.83 328.45 6,260.97 6,579.01 148.09 24.00 -15.49 18.37 130.00 9,660.00 91.45 335.63 6,260.37 6,605.49 134.03 24.00 2.06 23.92 85.00 9,800.00 93.98 9.18 6,253.55 6,742.10 115.77 24.00 1.80 23.96 85.00 9,975.00 93.89 21.45 6,241.51 6,910.17 161.79 7.00 -0.05 7.02 90.00 10,125.00 102.95 26.82 6,219.56 7,045.42 222.31 7.00 6.04 3.58 30.00 10,275.00 93.40 31.24 6,198.24 7,175.02 294.32 7.00 -6.36 2.95 155.00 10,425.00 88.13 40.33 6,196.23 7,296.52 381.91 7.00 -3.51 6.06 120.00 10,800.00 88.33 66.59 6,208.02 7,517.73 680.42 7.00 0.05 7.00 90.00 11,050.00 89.90 49.16 6,211.91 7,650.14 891.29 7.00 0.63 -6.97 -85.00 11,350.00 94.53 28.66 6,200.18 7,882.05 1,078.58 7.00 1.54 -6.83 -77.00 11,550.00 89.67 15.51 6,192.81 8,066.80 1,153.50 7.00 -2.43 5.57 -110.00 11,950.00 85.96 43.29 6,208.37 8,411.61 1,347.69 7.00 -0.93 6.94 98.00 12,100.00 89.25 33.31 6,214.65 8,529.06 1,440.44 7.00 2.19 -6.65 -72.00 12,300.00 86.86 19.51 6,221.46 8,707.63 1,529.14 7.00 -1.19 -6.90 -100.00 12,500.00 86.96 33.53 6,232.30 8,885.88 1,618.08 7.00 0.05 7.01 90.00 1282019 2:17:34PM Page 2 COMPASS 5000.14 Build 85D ConocoPhillipsBA ER ConocoPhillips Planning Report TYEGHES a GFmmpa Database: OAKEDMP1 Local Coordinate Reference: Well 3M-26 Company: ConocoPhillips Alaska Inc_Kupawk TVD Reference: Mean Sea Level Project: Kupawk River Unit MD Reference: 3M-26 @ 68.00usft (3M-26) Site: Kupamk 3M Pad North Reference: True Well: 3M-26 Survey Calculation Method: Minimum Curvature Wellbore: 3M -26L1-01 Map Map Design: 3M -26L1-01 wp03 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) (°) (°) (usft) (usft) (usft) (usft) (°NOOusft) (°) (usft) (usft) 9,600.00 95.48 322.94 6,262.63 6,554.28 164.95 6,215.43 0.00 0.00 6,023,113.59 506,434.31 TIPIKOP 9,630.00 90.83 328.45 6,260.97 6,579.01 148.09 6,232.90 24.00 130.00 6,023,138.31 506,417.42 Start 24 DLS 9,880.00 91.45 335.63 6,260.37 6,605.49 134.03 6,252.97 24.00 85.00 6,023,164.77 506,403.35 3 9,700.00 92.27 345.20 6,259.07 6,643.11 120.65 6,283.74 24.00 85.00 6,023,202.37 506,389.93 9,800.00 93.98 9.18 6,253.55 6,742.10 115.77 6,375.10 24.00 85.31 6,023,301.36 506,384.97 End 24 DLS, Start 7 DLS 9,900.00 93.95 16.19 6,246.63 6,839.37 137.66 6,473.99 7.00 90.00 6,023,398.63 506,406.77 9,975.00 93.89 21.45 6,241.51 6,910.17 161.79 6,548.77 7.00 90.49 6,023,469.44 506,430.84 5 10,000.00 95.40 22.33 6,239.48 6,933.29 171.08 6,573.67 7.00 30.00 6,023,492.57 506,440.11 10,100.00 101.44 25.90 6,224.84 7,023.53 211.46 6,672.28 7.00 30.07 6,023,582.83 506,48D.41 10,125.00 102.95 26.82 6,219.56 7,045.42 222.31 6,696.56 7.00 30.60 6,023,604.73 506,491.24 6 10,200.00 98.18 29.06 6,205.81 7,110.53 256.85 6,769.56 7.00 155.00 6,023,669.86 506,525.72 10,275.00 93.40 31.24 6,198.24 7,175.02 294.32 6,842.98 7.00 155.41 6,023,734.38 506,563.13 7 10,300.00 92.53 32.76 6,196.95 7,196.20 307.55 6,867.40 7.00 120.00 6,023,755.56 506,576.34 10,400.00 89.01 38.82 6,195.60 7,277.25 365.99 6,963.56 7.00 120.08 6,023,836.66 506,634.71 10,425.00 88.13 40.33 6,196.23 7,296.52 381.91 6,987.10 7.00 120.16 6,023,855.94 506,650.61 8 10,500.00 88.14 45.58 6,198.67 7,351.36 432.97 7,056.10 7.00 90.00 6,023,910.82 506,701.62 10,600.00 88.18 52.59 6,201.88 7,416.78 508.45 7,143.40 7.00 89.83 6,023,976.30 506,777.04 10,700.00 88.24 59.59 6,205.02 7,472.51 591.34 7,224.12 7.00 89.60 6,024,032.09 506,859.88 10,800.00 88.33 66.59 6,208.02 7,517.73 680.42 7,297.07 7.00 89.38 6,024,077.37 506,948.91 9 10,900.00 88.95 59.62 6,210.41 7,562.92 769.52 7,370.01 7.00 -85.00 6,024,122.64 507,037.96 11,000.00 89.58 52.64 6,211.69 7,618.61 852.49 7,450.73 7.00 -84.83 6,024,178.40 507,120.88 11,050.00 89.90 49.16 6,211.91 7,650.14 891.29 7,493.62 7.00 -84.74 6,024,209.95 507,159.65 10 11,100.00 90.69 45.75 6,211.66 7,683.94 928.12 7,537.98 7.00 -77.00 6,024,243.78 507,196.45 11,200.00 92.25 38.92 6,209.08 7,757.79 995.41 7,630.39 7.00 -77.02 6,024,317.68 507,263.66 11,300.00 93.79 32.08 6,203.81 7,839.03 1,053.37 7,726.56 7.00 -77.19 6,024,398.96 507,321.55 11,350.00 94.53 28.66 6,200.18 7,882.05 1,078.58 7,775.60 7.00 -77.55 6,024,442.00 507,346.72 11 11,400.00 93.33 25.36 6,196.75 7,926.49 1,101.23 7,825.10 7.00 -110.00 6,024,486.45 507,369.33 11,500.00 90.89 18.79 6,193.06 8,019.04 1,138.76 7,924.91 7.00 -110.23 6,024,579.02 507,406.78 11,550.00 89.67 15.51 6,192.81 8,066.80 1,153.50 7,974.84 7.00 -110.47 6,024,626.80 507,421.48 12 11,600.00 89.18 18.98 6,193.31 8,114.55 1,168.33 8,024.77 7.00 98.00 6,024,674.55 507,436.26 11,700.00 88.22 25.92 6,195.58 8,206.89 1,206.48 8,124.59 7.00 97.97 6,024,766.91 507,474.33 11,800.00 87.29 32.86 6,199.51 8,293.90 1,255.48 8,223.11 7.00 97.81 6,024,853.95 507,523.26 11,900.00 86.39 39.81 6,205.03 8,374.28 1,314.60 8,318.87 7.00 97.54 6,024,934.38 507,582.31 11,950.00 85.96 43.29 6,208.37 8,411.61 1,347.69 8,365.26 7.00 97.15 6,024,971.73 507,615.36 13 12,000.00 87.05 39.96 6,211.42 8,448.91 1,380.83 8,411.65 7.00 -72.00 6,025,009.06 507,648.47 12,100.00 89.25 33.31 6,214.65 8,529.06 1,440.44 8,507.36 7.00 -71.80 6,025,089.25 507,708.00 14 12,200.00 88.04 26.42 6,217.01 8,615.71 1,490.19 8,605.79 7.00 -100.00 6,025,175.93 507,757.67 12,300.00 86.86 19.51 6,221.46 8,707.63 1,529.14 8,705.49 7.00 -99.84 6,025,267.88 507,796.54 1282019 2:17:34PM Page 3 COMPASS 5000.14 Build 850 ConocoPhillips BA_ ICER ConocoPhillips Planning Report IGHES aGEmmparry Database: Company: Project: Site: Well: Wellbore: Design: Planned Survey OAKEDMPI ConocoPhillips Alaska lnc Kupamk Kuparuk River Unit Kuparuk 3M Pad 3M-26 3M-2611-01 3M-26L1-01_wp03 Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Measured TVD Below Map Map Vertical Depth Inclination Azimuth System -N/-S -E/-W Section (usft) (°) (°) (usft) (usft) (usft) (usft) 1s 7.00 89.62 6,025,446.18 507,885.33 12,40000 86.89 26.52 6,226.92 8,799.48 1,568.15 8,805.15 12,500.00 86.96 33.53 6,232.30 8,885.88 1,618.08 8,903.42 Planned TD at 12800.00 115.77 End 24 DLS, Start 7 DLS 6,241.51 Casing Points Measured Depth (usft) 12,500.00 Plan Annotations Measured Depth (usft) 9,600.00 9,630.00 9,660.00 9,800.00 9,975.00 10,125.00 10,275.00 10,425.00 10,800.00 11,050.00 11,350.00 11,550.00 11,950.00 12,100.00 12,300.00 12,500.00 Vertical Depth (usft) 6,232.30 2 3/8" Name Well 3M-26 Mean Sea Level 3M-26 @ 68.00usft (3M-26) True Minimum Curvature Dogleg Toolface Map Map Rate Azimuth Northing Easting (°/100usft) (°) (usft) (usft) 7.00 90.00 6,025,359.75 507,83547 7.00 89.62 6,025,446.18 507,885.33 Vertical Local Coordinates Diameter Diameter Depth +N/ -S +E/ -W 3.000 (usft) (usft) (usft) Comment 6,26263 6,554.28 164.95 TIP/KOP 6,260.97 6,579.01 148.09 Start 24 OLS 6,260.37 6,605.49 134.03 3 6,253.55 6,742.10 115.77 End 24 DLS, Start 7 DLS 6,241.51 6,910.17 161.79 5 6,219.56 7,045.42 222.31 6 6,198.24 7,175.02 294.32 7 6,196.23 7,296.52 381.91 8 6,208.02 7,517.73 680.42 9 6,211.91 7,650.14 891.29 10 6,200.18 7,882.05 1,078.58 11 6,192.81 8,066.80 1,153.50 12 6,208.37 8,411.61 1,347.69 13 6,214.65 8,529.06 1,440.44 14 6,221.46 8,707.63 1,529.14 15 6,232.30 8,885.88 1,618.08 Planned TD at 12500.00 Casing Hole Diameter Diameter (in) (in) 2.375 3.000 12WO19 2:17:34PM Page 4 COMPASS 5000.14 Build 65D s, ConocoPhillips BA ER ConocoPhillips Anticollision Report Ty HES Ty GE company Company: ConocoPhillips Alaska Inc Kupamk Project: Kuparuk River Unit -2 Reference Site: Kuparuk 3M Pad Site Error: 0.00 usft Reference Well: 3M-26 Well Error: 0.00 usft Reference Welfbore 3M-2611-011 Reference Design: 3M-261-1-01_wp03 Reference 3M-2611-01_wP03 Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Output errors are at Database: Offset TVD Reference: Fitter type: NO GLOBAL FILTER: Using user defined selection 8 filtering criteria Interpolation Method: MD Interval 25.00usft Error Model: Depth Range: 9,600.00 to 12,500.00usft Scan Method: Results Limited by: Maximum center -center distance of 1,443.20 usff Error Surface: Warning Levels Evaluated at: 2.79 Sigma Casing Method: Survey Tool Program From (usft) 71.01 9,311.00 9,600.00 Summary Date 1/28/2019 To (usft) Survey (Wellbore) 9,311.00 3M-26 (3M-26) 9,600.00 3M-26Ll_wp04(3M-261-1) 12,500.00 3M -26L1-01 wp03 (3M-2611-01) Site Name Offset Well - Wellbore - Design Kuparuk 3M Pad 3M-17 - 3M-17 - 3M-17 3M-20 - 3M -20.3M-20 3M-23 - 3M-23 - 3M-23 3M-23 - 3M-23 - 3M-23 3M-23 - 3M-23 - 3M-23 3M -23 -3M -23A -3M -23A 3M-23 - 3M -23A- 3M -23A 3M -23 -3M -23A -3M -23A 3M-23-3M-23AL1-3M-23AL1 3M-23-3M-23AL7-3M-23AL1 3M-23-3M-23AL1-3M-23AL1 3M-23 - 3M-23AL2 - 3M-23AL2 3M-23 - 3M-23AL2 - 3M-23AL2 3M-23 - 3M-23AL2 - 3M-23AL2 3M-23 - 3M-23AL3 - 3M-23AL3 3M-23 - 3M-23AL3 - 3M-23AL3 3M-23 - 3M-23AL3 - 3M-23AL3 3M-23 - 3M-23AL3PB1 - 3M-23AL3PB1 3M-23-3M-23AL3PB1-3M-23AL3PB1 3M-23 - 3M-23AL3PB1 - 3M-23AL3PB1 3M-23 - 3M-23AL4 - 3M-23AL4 3M-23 - 3M-23AL4 - 3M-23AL4 3M-23 - 3M-23AL4 - 3M-23AL4 3M-23 - 3M-23AL4-01 - 3M-23AL4-01 3M-23 - 3M-23AL4-01 - 3M-23AL4-01 3M-23 - 3M-23AL4-01 - 3M-23AL4-01 3M-23 - 3M-23AP81 - 3M-23APB1 3M-23 - 3M-23APB1 - 3M-23APB1 3M-23 - 3M-23APB1 - 3M-23APB1 3M-23 - 3M-23APB2 - 3M-23APB2 3M-23 - 3M-23APB2 - 3M-23APB2 3M-23 - 3M-23APB2 - 3M-23APB2 3M-25 - 3M-25 - 3M-25 Tool Name GCT -MS MWD MWD Well 3M-26 3M-26 @ 68.00usft (3M-26) 3M-26 @ 68.00usft (3M-26) True Minimum Curvature 2.00 sigma OAKEDMP1 Offset Datum ISCWSA Tray. Cylinder Nonh Combined Pedal Curve Added to Error Values Description Schlumberger GCT multishot MWD - Standard MWD - Standard Reference Offset Distance Measured Measured Between Between Separation Warning Depth Depth Centres Ellipses Factor fust[) (usft) (usft) (usft) Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range CC - Min centre to center distance or covergent point, SF - min separation factor, ES - min ellipse separation 1282019 2:53:05PM Page 2 COMPASS 5000.14 Build 85D ConocoPhillips BAT ConocoPhillips Anticollision Report 11GHES a GEcompany Company: ConocoPhillips Alaska lnc_Kuparuk Project: Kuparuk River Unit -2 Reference Site: Kuparuk 3M Pad Site Error: 0.00 usft Reference Well: 3M-26 Well Error: 0.00 usft Reference Wellbore 3M-2611-01 Reference Design: 3M-2611-0l_wp03 Summary Site Name Offset Well - Wellbore - Design Kuparuk 3M Pad 3M-26 - 31,11-2617 - 3M-26L7_Wp04 3M-26 - 3M -26L1 - 3M-261-1_wp04 3M-27 - 3M-27 - 3M-27 3M -27 -3M -27A -3M -27A 3M-27-3M-27AL7-3M-27AL1 3M-27 - 3M-27AL2 - 3M-27AL2 3M-27 - 3M-27AL2-01 - 3M-27AL2-01 3M-27-3M-27AL2PB7-3M-27AL2PB1 3M-27 - 3M-27AL3 - 3M-27AL3 Local Coordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Output errors are at Database: Offset TVD Reference: Well 3M-26 31V-26 @ 68.00usft (3M-26) 3M-26 @ 68.00usft (3M-26) True Minimum Curvature 2.00 sigma OAKEDMPI Offset Datum Reference Offset Distance Measured Measured Between Between Separation Warning Depth Depth Centres Ellipses Factor (waft) (usft) (usft) (usft) 9,900.00 10,600.00 846.63 809.76 9,950.00 10,975.00 1,195.05 1,141.53 22.967 CO. ES 22.328 SF Out of range Out of range Out of range Out of range Out of range Out of range Out of range Offset Design Kuparuk 3M Pad -3M-26-3M-2611-3M-2611wp04 .main Sea Error ooto usft Surrey Program: 71 -DCT -MS, 9311 -MWD Onset Well Error. 0.00 use Reference ORut Seml MilOr Axis piston[. Measured Vertical statehood vertical Neflrenm Ogaet AzImNM1 Mae, wallet... centre BMxeen BeLveen Minimum Snparati.n Warning Depth Depth Depth Depth rmm North hy/8 rEIM Centre. Ellipses Saparatbn Facts Juan) lues) (open (oan) luso) (usft) 19 lush) lusftl loan) leak) hurt) 91600.00 6,330.63 9.600.00 6,330.63 0.06 0,00 -37,06 6,554.28 164.95 0.00 -0.22 0.22 0.000 STOP Men, 9,624.89 6,329.08 9.625.00 47326.37 0.16 0.13 -".75 6,573.93 149.67 1.53 1,02 0.51 2.994 Nomal Operations 9,649.15 6,326.62 9,050.00 5326.39 0.24 0.26 -95.22 6,593.15 133.01 5.98 5.32 0.66 9.043 9,672.19 6,328.04 8675,09 6,324.67 0.33 0.44 -96.73 6,611.93 117.39 13.26 12.40 986 15.463 9.693.49 6,327.32 9,700,00 6,323.22 0A1 0.62 -96.22 6.630.24 100.43 23.29 22.29 1.00 23.235 9,712.74 6,326.54 8725A0 6,321,91 0.47 0.85 -94,33 6,64805 82.94 3388 34.75 1.12 32.025 9,729.80 6,32535 9750.00 6,320.61 0.53 1,08 -91.84 5665.31 64.90 50.69 49.54 1.16 43.939 9.744.72 5324.97 9,775.00 6.319.30 call 1.35 -89.25 6,682.02 46.35 67.41 66.28 1.12 satin 9,757,63 6.324.25 9.800.00 6,318.00 0.61 1.65 -88.80 8.690.14 27.29 05.71 84.77 0.94 90,988 9,768.73 5323,59 8825.00 6,316.86 0.64 1.99 -84.66 6.713.72 7.77 105.30 104,83 0.47 225.800 9,775,00 6,32330 9.850.00 6,316.05 0.65 2.33 -83.70 6,728.75 -12.19 126.00 124,53 t A7 85.981 9,786.32 6.322.47 9,875.00 6,315.58 0,87 2,73 -81.42 6]43.23 -32.56 147.43 145,66 1.77 83.398 9793.17 47322.02 9,900.00 6.315.39 0.68 3.13 -80.22 6,757,14 -53.33 169.64 187.35 2.29 74.231 8900.00 5321,55 9,925,00 6.315.39 569 3.60 -78.95 6,770.45 -74.49 192.46 189.67 2.79 65995 9.805.62 5321.16 9,950.00 6.315,38 0.69 4.08 -76.09 5783.10 -96.05 215,75 212.44 3.30 65.285 9,811.93 5320]2 8975.00 6,315.36 070 4.62 .7871 6.795.09 -117.99 239.38 23557 3.81 62367 9,817.42 5320.34 10,000.00 6,315.38 0.70 5.17 -70.52 6,806.40 -14029 263.31 258.98 4.33 60.042 9,625.00 6.319.82 10,025.00 6,315.31 0.70 5.81 -70.12 6,817.03 -162.91 287.51 282.72 4.79 60.044 882500 6,319.62 10,050.00 6,315,10 0.70 6.44 .78.22 8.826.97 -185.85 31109 306.33 5.56 56.096 9,829,41 6,319.51 10,075.00 6,314.77 0,70 Tilt -77.95 6,836.2 -209.07 336.45 330.26 6.19 54.315 9,032.07 6.319.33 10.100.00 6,314.30 0,71 7.93 -77.78 6,04LT/ -232.56 361.16 354.29 6.86 52.529 9,834.61 6.319.15 10,125.00 6.313.64 0.71 8.82 -77.58 6,853.30 -256.05 385.89 379,19 7.70 50.112 9,837.53 6.310.95 10.150.00 6,312.72 0.71 972 -77.32 6,052.50 -279,27 410.50 401.98 8,54 48.048 9.940.01 6,318.72 10,175,00 5311.53 0.71 10,93 -77.01 5872.35 4t02,22 435.00 425.31 9.89 44.095 8,844.43 6,318.47 10,200.00 6,310.09 071 12.14 -76.66 6,882.06 -324.85 459.36 448.50 10.86 42,295 8850.00 6.318.08 10,225.00 6,308.59 0.71 14.69 -76,16 6.893.35 -347.50 483.75 470.60 13.15 36.783 0,850,00 6,318.08 10,250.00 5307.22 0.71 17.23 -76.10 6,903.16 -370.45 508,30 492.55 15.75 32.263 8850.00 6.318+08 10.275.00 6,305.98 0,71 21.02 -76.05 6.912.27 493.70 533.02 513.51 19.51 27.318 9.850.00 6,318.08 10.300.0 5304.68 071 24.80 -76.02 6,920,68 -417.21 557.86 534,59 23.27 23.974 9,855.62 5317.63 10.32500 SWISS 071 26.20 -75.51 6,929.08 440.74 502.65 558.42 24,24 24.040 9.858.67 6,317.48 10,350,00 6.303.34 071 27.59 -75.37 6.938.16 464,03 607.40 581.76 25,64 23.607 9.861.04 8,317.32 10,375,00 6,302.97 071 28,72 -75.24 6,90.90 487cli 632.04 605.22 26,03 23.550 9,863.71 6,317.14 10,400.00 6,302.05 071 29.84 -75.10 6,958.29 -50078 656.57 628.53 28.01 23.412 9,666.69 6,316.93 10,425.00 6.302.90 0.71 30.85 -74.96 6,969.35 -532.20 63.96 651.70 29.18 23.940 CC - Min centre to center distance or covergent point, SF - min separation factor, ES - min ellipse separation 1)282019 2:53:05PM Page 3 COMPASS 5000.14 Build 85D ProSite: Kull River Until Site: Kuparuk 3M Pad �'^,� �, Well: 3M-26 Cimo 'Qill�ll�ps Plan:3M-26111-01owp83eill M3M$BI3M-2611-01) WELLBORE DETAILS: 3M-2611-01 Parent Well 3M-28Li Tie on MD: 9600.00 c Mean Sea REFERENCE MFORNATION WELL DETAILS: 3M-26 ll (VS)RNxenro: W -IO ON DOE) +N/ -S +E/ -W Northing UGHES Easting Latitude Longitude 0.00 0.00 6016559.83 506274.89 70' 27' 23.296 N 149' 56' 55.644 W Sec MD Inc Azi TVDSS +N/ -S +E/ -W Dleg TFace VSect Annotation 1 9600.00 95.48 322.94 6262.63 6554.28 164.95 0.00 0.00 6215.43 TIP/KOP 2 9630.00 90.83 328.45 6260.97 6579.01 148.09 24.00 130.00 6232.90 Start 24 DLS 3 9660.00 91.45 335.63 6260.37 6605.49 134.03 24.00 85.00 6252.97 3 4 9800.00 93.98 9.18 6253.55 6742.10 115.77 24.00 85.00 6375.10 End 24 DLS, Start 7 D 5 9975.00 93.89 21.45 6241.51 6910.17 161.79 7.00 90.00 6548.77 5 6 10125,00 102.95 26.82 6219.56 7045.42 222.31 7.00 30,00 6696.56 6 7 10275.00 93.40 31.24 6198.24 7175.02 294.32 7.00 155.00 6842.98 7 8 10425.00 88.13 40.33 6196.23 7296.52 381.91 7.00 120.00 6987.10 8 9 10800.00 88.33 66.59 6208.02 7517.73 680.42 7.00 90.00 7297.07 9 10 11050.00 89.90 49.16 6211.91 7650.14 891.29 7.00 -85.00 7493.62 10 11 11350.00 94.53 28.66 6200.18 7882.05 1078.58 7.00 -77.00 7775.60 11 12 11550.00 89.67 15.51 6192.81 8066.80 1153.50 7.00 -110.00 7974.84 12 13 11950.00 85.96 43.29 6208.37 8411.61 1347.69 7.00 98.00 8365.26 13 1412100.00 ' 89.25 33.31 6214.65 8529.06 1440.44 7.00 -72.00 8507.36 14 15 12300.00 86.86 19.51 6221.46 8707.63 1529.14 7.00 -100.00 8705.49 15 16 12500.00 86.96 33.53 6232.30 8885.88 1618.08 7.00 90.00 8903.42 Planned TD at 12500.0 c Mean Sea REFERENCE MFORNATION Co drall(WE) Rafimm Well 3N.M, Tue NwN VeAM RD) Rtlwmx: Nava Sa. l BA(ER ll (VS)RNxenro: W -IO ON DOE) UGHES Neaeuetl DNNb ReMenre: 3l@Sal 13M26) a(:Ftnnipany Cahn n NkWd', hlnM C awe West(-)/East(+) (250 usB/in) 5700 1■■■■■■■■■■■■ - MMI I■■■■■■■■■� `'� •III ' �■� 5795 I I s I■■■...■'�1!'�■■ ,�� I III E- ' _ _ 4 9 965 , 1�1■�■■, ■. iiOJ®�■�■ � �■. I■■\► �- V��!,� _ III 6080 31 MOP Sia 24 DI S 6175 III.---- West(-)/East(+) (250 usB/in) 5700 5795 I I s I E- _ _ 4 9 965 , 6080 31 MOP Sia 24 DI S 6175 6270 ...6 7 8 0 11 2 13 14 ; �•..; _. _ __ 6365 P nned. Dm 1 5000 En 124 DIS. S. 7 DL 4-26 3M-2 1 3A1 -26 0i LI -01 - 6460 3 6555 3M-2 1-01 Fault M-261 1 01 1au115 6650 evel 1 1- o� Vertical Section at 20.001 (95 us87in) ConocoPhillips Project: Kuparuk River URIL2 Site: Kuparvk 3M Pad czlaw.mra. wnn narmr wnh rear waam rwe WELLBORE DETAILS: 3M -26L1 REFERENCE INFORwAnoN Parent Wellbore: 3M-26 Coa6nNe (NE) Reiwxe: WNI3A426. Trve NMh Well: 3M-26 waren: nuas„� Te on MD: 8317.00 3u. Volwl rvb R M 1 267 ) Wellbore: 3M-26Li on sole: eoa> s«ron BNnpa: abllomµoo6E N61 1 %an: 3M•26L1 wpO4 (3M -2613M -26U) nksu I 267 R NA air b unm6� W. 13650 13000 rf __ 12350.1 . --- 116501 104001 9750, 9100 F, 8450+ 780011; 7150, + 6500 t � ssso — 5200 - I`M P p 4550• "I '3A 3M-26 @ 68.OWu ft (3M-26) TI-i'<Y�]N uq 13ATOER S a GE.Mry ,an -JN-IION-II AS KUP PROD 3M-26 ConociiPllllip511 Attributes Max Angle & MD TD wellbore A%INN %e10 Name WeIIMreaaas l•) MDInKBI Act Blm'"NO All I.C. Ina 500292243100 KUPARUK RIVER UNIT PROD 56.75 ),333.50 9,625.0 Comment Has(pan) U..AnnolNion Entl Dale NBGN 11q "RNmee oats SSSV:NIPPLE I STWO: 41 W 1117/1894 JMM. 4P.1 a 5aB:OS AM Last Tag Ann.tatio DMA,(nKB) FJb Date Last I By Last Tag: RKB 9,363.0 VW2018 axol Last Rev Reason - Annota ion End Ooh Lal M w By Rev Reason: Tag Al 25' Rafiole 411012018 =1c.ej HANGe6 Sae Casing Strings casing Oe—poon oO pn mlinl Topinrca Sell puh MING) 9elOrotl,IrvoL.. wuLen p... Grade Top Th,ead CONDUCTOR 16 15.062 43.0 121.0 121.0 62.50 H 40 WELDED Ceslnp Desmlptian ODanl ..,uU Top,.—, Jet OeptL (Itl(B) 4l OepM ITV01... WtlLen (I... G,mle Top TMmd SURFACE 95/8 8.921 41.1 4,882.2 3,623.6 36.D0155 TO Cening Cacdpnon ODfinl 1o9n1 Top IryK6) ser oo"".K01 JN Oep,n lI—, 111—n ll... GwOe Tap TM1rea9 PRODUCTION ) 6.27fi 38] 9614) 6,5256 2600 L-80 STOMOD Tubing Strings rubmg cewnp,Ion semg Ma...lDlm roplrtNe) Set DMptn rc.. set oep,n lTv l...wl Lou, Grade TopconnMion TUBING 31/2 2.992 36.8 9,23).2 6,233.3 9.30 d55 EUESrdl Completion Details Top 11N Topmn Nominal Top JWBJ Iryrcel 1°I nem Oez tom 10(in 36.8 35.3 0.26 HANGER FMC GEN IV HUNGER 3.500 2,0212 1,9030 37.25 NIPPLE CAMCO W-1 LANDING NIPPLE W/ SELECTIVE PROF ILE 2.812 CONDUCTOR: 430-1210 9202.6 6,2070 4037 LOCATOR BAKER GBH -22 LOCATOR SEAL ASSEMBLY 3.000 9,205.3 6,209.1 4029 PACKER BAKER FBI PERM PACKER 4.000 9.2011 6,2116 40.41 SBE BAKER 8040 SEAL BORE EXTENSION 4.000 9,226.7 6,2253 4049 NIPPLE CAMCO D NIPPLE NO GO 2.750 NIPPLE:2 I 92363 6.2327 4652 SOB BAKER SHEAR OUT SUB 2.992 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) roPlrvq I TOPIoa T.P flKeI (nKRI 19 I oee Co. Run Date DIN 94560 6,3966 3640 FISH 3X6]/6 X Ho SLIP Lost imm Air SLIP, was never 4/26/1994 found, could be in hole Perforations & Slots snm Dons Top.1WI BIm ITwB fsn I gdo1 Top324 Btm3680 (flog) bne I& 1 Tyce 8,324,0 8,3580 8,299.1 .,0 8,32 .0 k1,3M38 4128/1994 'a 401PERF 4112 "BH Csg Gun, 160 tlag. gGu p0ialne SUMFwCE: al 1-4.aR1— Mandrel Inserts n NTnplrvol Top (nKBl (flKBI Mage Model ODlln) sery valve Type Trw Type Pon Mu finl Tr (psi) Run Dale RunDa Com GASLI sas 91693 CAMCO MMM 11/2 GAS LIFT Ley RK O.o00 60 6/311994 :Gen Notes: General &Safety Em Dale Annotation 7128/2010 NOTE: Vi wSchemalicw/Alaska Scremanc90 WCATON.9,JP16 PACKFR:9.dM.J SBE BiOBfi NIPPLE 9,TM] S0&: 9,23&J IpERF:9.R409358.0— Hal PRODUCTION:Waa.8147 3M-26 Proposed CTD Schematic 16" 62# H -4C shoe @ 121' 9-5/8" 36# J-55 shoe @ 4882' MD KOP @ 9314' MD via 7" wedge d parts - 9358' MD 7" 26# L-80 shoe @ 9614' MD r 3-1/2" 9.3# J-55 EUE 8rd Tubing to surface 3-1/2" Cameo W-1 Landing Nipple @ 2021" RKB (2.812" min ID) 3-1/2" Cameo MMM gas lift mandrel @ 9153' RKB Baker GBH -22 Locator Seal Assembly @ 9202' RKB (3.0" ID) Baker FB1 Perm packer @ 9205' RKB (4.0" ID) Baker SBE @ 9209' RKB (4" ID) 3-1/2" Cameo D Nipple @ 9227' RKB (2.75" min ID, No -Go) Note: Will be drilled out to 2.80" ID pre -CTD Baker SOS @ 9236' RKB (2.992" ID) 3-1/2" tubing tail @.9237' RKB 3M-261-1-01 wp03 TD @ 12.500' MD Liner top @ 9220' MD Lt wp04 11,700' MD )p @ 9600' MD Loepp, Victoria T (DOA) From: Long, William R <William.R.Long@conocophillips.com> Sent: Wednesday, February 6, 2019 1:31 PM To: Loepp, Victoria T (DOA) Cc: Starck, Kai; Ohlinger, James 1; Herring, Keith E; McLaughlin, Ryan Subject: KRU 3M-26 CTD Permit Status Victoria, It is likely we will be moving CDR3-AC by this weekend to the next well. Due to drilling tool availability for 1J-10 we are going to have to go to 3M-26 next. Would it be possible to get permit to drill approval for 31M-261-1 and 3M-261-1-01 by Friday? Thanks, William R. Long Staff CTD Engineer ConocoPhillips 907-263-4372 (office) 281-723-6000 (cell) William.R.Long@ConocoPhillips.com From: Herring. Keith E To: mer, David L(DOA) Cc: Lona William R Subject: RE: [EXTERNAL]PTD"s for KRU 3M -26L3 & Ll -01 Wells Date: Tuesday, February 5, 2019 11:36:46 AM Attachments: imaoe001.Dna 3M-261-1 wD04 MD - NAD27 tM 3M-2611-01 wo03 MD - NAD27.t t Hi Dave, Please see attached. Thanks, Keith Herring CTD Engineer 907.263.4321 (Office) 907.570.2410 (Mobile) 700 G Street, ATO — 664 Ke[h.E.Herrins(aesmoconhiIIiDs.coni I"- ' ConoCOPhilljps AlasE,i1 From: Boyer, David L (DOA) <david.boyer2@alaska.gov> Sent: Tuesday, February 5, 2019 11:28 AM To: Herring, Keith E <Keith. E. Herring@conocophiIli ps.com> Subject: [EXTERNAL]PTD's for KRU 3M-261-1 & L1-01 Wells Hi Keith, I just finished up the geologic review for the four U-10 laterals and am ready to begin the next CDR3-AC wells on the schedule. Would it be possible to send over digital survey files in Excel or ASCII format for both wells so I can load them into our Geographics program? We can extract what we need from the whole file but only load MD, inclination, and azimuth. Thank you, Dave Boyer AOGCC Transform Paints I K R Ct 3 M_ a,,6 1- 1- O 1! Source coordinate system Staie Plane 1927 - Alaska Zone 4 Datum NAD 1927 - North kneirca Datum of 1927 (Mean) 0 Target coordinate system Abets Equal Area (-150) Datum: NAD 1927 - North America Datum of 1927 (Mean) Type vakies into the spreadsheet or copy and paste columns of data from a spreadsheet usrng the keyboard shod cL43 CldZto copy and Ctrl+V to paste. Then c6ck on the appropriate arrow button to transform the points to the desired coordinate system. < Back Fsish Cancel Help TRANSMITTAL LETTER CHECKLIST WELL NAME: K K (L 3 M —a.6 L 1 Q 2 PTD: :�K 1!9 T-0 1 � VDevelopment _ Service _ Exploratory _ Stratigraphic Test _ Non -Conventional FIELD:yupa Vu, R ; 1/e I.— POOL: Ku 12 oy cc K R t V2 !o` 0 1 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. 193– 19.3 API No. 50-02 -21!k3 ( 00 -00. (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 ermit . The permit is approved subject to full compliance with 20 AAC 25.055. Approval to produce/inject is contingent upon issuance of a conservation Spacing Exception order approving a spacing exception. (Company Name) Operator assumes the liability of any protest to the spacing exception that may occur. All dry ditch sample sets submitted to the AOGCC must be in no greater Dry Ditch Sample than 30' sample intervals from below the permafrost or from where samples are first caught and 10' sample intervals throu 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 Requirem nts 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 Engineering Public Well Name: KUPARUK RIV UNIT 3M -26L1 -0i Program DEV Well bore seg PTD#: 2190170 Company CONOCOPHILLIPS ALASKA INC _ Initial Class/fype DEV/PEND GeoArea 890Unit 11160 On/Off Shore On Annular Disposal ❑ Administration 1 Permit fee attached- - - ---- - - - - ---- - - - - - - - - - ...... NA. - - - - - - - -- - - - - .... - - - ...... - - - . - .. - ...... 2 Lease number approp-riate--------------- - ...... Yes_-.__-_.......__--..-.-_____.....-__...___......-_.. 3 Unique well. name and number ........ ....... .. _.... ---. Yes....---------...-....---...------...--------..... 4 Welllocated in a. defined pool - .. - - - - - ... - - .. Yes -----------..-..---- 5 Well located proper distance from drilling unit boundary - - - _ - ... Yes - .... 6 Well located - proper distance from other wells.. - - - - - - - _ - - - - - - - - - Yes - 7 Sufficient acreageayailable in drilling unit- - - - - - - _ - ...... Yes - 8 if deviated, is. wellbore platincluded- - - - .. - - - - - - No - - - - No land plat.. Directional. plan &. cross-section views. included.... 9 Operator only affected party . . . . ..... . . . . .. . . . ..... - - ... Yes - 10 Operator has. appropriate bond in force - - - - - .... - Yes 11 Permit can be issued without conservation order. - - - - - - - - - - Yes Appr Date 12 Permit can be issued without administrative. approval - ... - - - - Yes - DLB 2/6/2019 13 Can permit be approved before 15 -day wait- - - - - - - - - - Yes - 14 Well located within area and strata authorized byInjectionOrder # (put 10# in.comments).(For. NA. - 15 All wells within 1/4 -mile areaof review Identified (For service well only) ...... - NA 16 Pre -produced injector; duration of pre production less than 3 months. (For service well only) .. NA 17 Nonconven, gas conforms to AS31,05.030G 1.A),Q.2.A-D) ....... . . . ..... . . . . . NA 18 Conductor stringprovided. . . . . . ..... . . . . . . .. . . . . . ...... NA. - - .....Conductor set for KRU 3M-26 Engineering 19 Surface casing -protects all.known USDWs - ... - - _ - - - - _ ..... NA.... - - - Surface casing set for KRU 3M-26_ 20 CMT. vol adequate to circulate on conductor & surf-esg . . . . ..... . . . . . . .... . . . NA ... - _ - Surface casing set and fully cemented 21 CMT -vol adequate to tie-iiilong string to surf csg. . . . . . . . . . . . ...... . NA 22 CMT. will cover all known productive horizons . . . ..... . . . . . . ... . . . . . . . . ..... No...... - - Productive.interval will be completed with, uncemented slotted liner. 23 Casing designs adequate for C, T, B &-permafrost- - - - - - - -- - - - - - - - - - - - - - - - - Yes 24 Adequate tankage or reserve pit _ _ _ _ _ _ _ _ _ _ _ _ _ _ - - - Yes - - - - Rig has steel tanks; all. waste -to approved disposal wells 25 If a_re-drill, has_a 1 O403 for abandonment been approved - - - - - - - ---- - - - - - - ---NA.. 26 Adequate wellbore separation proposed. - - - - - - - - _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes _ ..... Anti -collision analysis complete; no major risk failures 27 Jf diverter required, does it meet regulations - - - - - - - - - - - - - - - - -- - - - - - - - - NA Appr Date APP 28 Drilling fluidprogramschematic & equip list adequate.. - - - _ _ _ _ _ - - - - - - Yes - formation re si - - ppg and maintain overbal w/ MPD - - - - � Max frationessuris 4280 13.1 - pressure - - R �9( - RP9 EMW );will drill w/ a,6. VTL 2/7/2019 29 BOPEs, do they meet regulation - - - - - - --- - - - - - --- - - - - -- - - - Yes 30 ROPE press rating appropriate; test to (put psig in comments)- - - - - - - - _ Yes ... MPSP is 3650 psig; will test BOPs_to 4000-psig 31 Chokemanifold complies w/API RP -53 (May 84)- - - - - - - - _ _ - _ - - - - . Yes 32 Work will occur without operation shutdown- - - - --- - - - - - --- - - - - - - ------ Yes 33 Is presence of 1-12S gas probable - - - - - -- - - - - - - - - - - - -- - - - - - - - Yes .... H2$ measures required - - 34 Mechanfcal.condition of wells within AOR verified (For service well only) - ... _ _ - . NA _ .... - - - - . 35 Permit can be issued w/o. hydrogen sulfide measures . ..... . . . . . . .. ..... . .. X0... - .. 31VI-Pad wells are. 1 -128 -bearing, H2S measures are required. Geology 36 Data. presented on potential overpressure zones - - -- - - - - - - ----- - - - - - - - -- - - Yes Appr Date 37 Seismic analysis of shallow gas.zones- - . NA..----... DLB 2/6/2019 38 Seabed condition survey (if off -shore) . . . . .... . . . . . ...... . . ... . ... . . . . . NA 39 Contact name/phone for weeklyprogressreports]expioratory only] - ......... - - NA Geologic Engineering Public Commissioner: Date: Commissioner: Date Commissioner Date WI nW s 2 I ��� / 2114 -./bar 2 7! i