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Home My WebLink About219-016DATA SUBMITTAL COMPLIANCE REPORT 6/10/2019 Permit to Drill 2190160 Well Name/No. KUPARUK RIV UNIT 3M-261-1 MD 11676 TVD 6322 Completion Date 3/5/2019 REQUIRED INFORMATION Mud Log No DATA INFORMATION List of Logs Obtained: GR/Res Well Log Information: Log/ Electr Data Digital Dataset Type Med/Frmt Number Name ED C 30542 Digital Data ED C 30542 Digital Data ED C 30542 Digital Data ED C 30542 Digital Data ED C 30542 Digital Data ED C 30542 Digital Data ED C 30542 Digital Data ED C 30542 Digital Data ED C 30542 Digital Data ED C 30542 Digital Data ED C 30542 Digital Data ED C 30542 Digital Data ED C 30542 Digital Data ED C 30542 Digital Data ED C 30542 Digital Data ED C 30542 Digital Data ED C 30542 Digital Data ED C 30542 Digital Data AOGCC Operator CONOCOPHILLIPS ALASKA, INC. Completion Status 1-0I1 Samples No J Log Log Run Interval OH I Scale Media No Start Stop _ CH -- - - - _— 9015 11676 Page 1 of 3 Current Status 1 -OIL API No. 50-029-22431-60-00 UIC No Directional Survey Yes (from Master Well Data/Logs) Received Comments 4/3/2019 Electronic Data Set, Filename: 3M-261-1 GAMMA Monday, June 10, 2019 RES.las 4/3/2019 Electronic File: 31M-261-1 2MD Final Log.cgm 4/3/2019 Electronic File: 3M -26L1 5MD Final Log.cgm 4/3/2019 Electronic File: 3M-261-1 5TVDSS Final Log.cgm 4/3/2019 Electronic File: 3M-261-1 2MD Final.pdf 4/3/2019 Electronic File: 3M-261-1 5MD Final.pdf 4/3/2019 Electronic File: 3M-261-1 5TVDSS Final.pdf 4/3/2019 Electronic File: 3M-261-1 EOW NAD27.pdf 4/3/2019 Electronic File: 3M-261-1 EOW NAD27.txt 4/3/2019 Electronic File: 31M-261-1 Final Surveys TD 11676.csv 4/3/2019 Electronic File: 31M-261-1 Final Surveys TO 11676.xlsx 4/3/2019 Electronic File: 3M-2611 Survey Listing.txt 4/3/2019 Electronic File: 3M-261-1 Surveys.txt 4/3/2019 Electronic File: 3M- 261-1 _25_tapescan_81-11 CTK.txt 4/3/2019 Electronic File: 3M - 26L1 _5_tapescan_B H I_CTK.txt 4/3/2019 Electronic File: 3M-261-1_outpul.tap 4/3/2019 Electronic File: 3M-261-1 2MD Final Log.tif 4/3/2019 Electronic File: 3M-261-1 5MD Final Log.tif Monday, June 10, 2019 DATA SUBMITTAL COMPLIANCE REPORT 6/10/2019 Permit to Drill 2190160 Well Name/No. KUPARUK RIV UNIT 3M-261-1 MD 11676 TVD 6322 Completion Date 3/5/2019 ED C 30542 Digital Data Log C 30542 Log Header Scans ED C 30601 Digital Data ED C 30601 Digital Data ED C 30601 Digital Data ED C 30601 Digital Data Log C 30601 Log Header Scans Well Cores/Samples Information: Name INFORMATION RECEIVED Completion Report YO Production Test Informatio o// NA Geologic Markers/Tops I Y I COMPLIANCE HISTORY Completion Date: 3/5/2019 Release Date: 2/7/2019 Description Comments: Interval Start Stop Operator CONOCOPHILLIPS ALASKA, INC. API No. 50-029-22431-60-00 Completion Status 1-0I1- Current Status 1-0I1 UIC No 4/3/2019 Electronic File: 3M -26L1 5TVDSS Final Log.tif 0 0 2190160 KUPARUK RIV UNIT 3M-2611 LOG HEADERS 4/15/2019 Electronic File: 3M-261-1 EOW NAD27.pdf 4/15/2019 Electronic File: 3M-2611 EOW NAD27.txt 4/15/2019 Electronic File: 3M-2611 EOW NAD83.pdf 4/15/2019 Electronic File: 3M-2611 EOW NAD83.txt 0 0 2190160 KUPARUK RIV UNIT 3M-2611 LOG HEADERS Sample Set Sent Received Number Comments Directional / Inclination Data Y� Mechanical Integrity Test Information Y / NA Daily Operations Summary 3 Date Comments Mud Logs, Image Files, Digital Data Y / le) Core Chips Y Composite Logs, Image, Data Files 'Y Core Photographs Y Cuttings Samples Y � Laboratory Analyses Y NA AOGCC Page 2 of 3 Monday, lune 10, 2019 DATA SUBMITTAL COMPLIANCE REPORT 6/10/2019 Permit to Drill 2190160 Well Name/No. KUPARUK RIV UNIT 31YI-261-1 MD 11676 TVD 6322 C pletlon D 3/5/2019 Compliance Reviewed B3k. _ Operator CONOCOPHILLIPS ALASKA, INC. API No. 50-029-22431-60-00 Completion Status 1-0IL Current Status 1-0IL UIC No Date: l0 // f 11(� AOGCC Page 3 o(3 Monday, lune IQ 2019 BA ER F IGHES BAT GEcompany Date: April 12, 2019 m: Abby Bell AOGCC 333 West 7th Ave, Suite 100 Anchorage, Alaska 99501 2 1 90 16 30 60 1 Letter of Transmittal Harvey Finch Baker Hughes, a GE Company 795 East 941h Avenue Anchorage, Alaska 99515 find enclosed the directional survey data for the following well(s): 3M-261-1 3M-261.1-0110 3M-26L1-01PB1 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 PBakerHughes.com ConocoPhillips ConocoPhillips Alaska Inc—Kuparuk Kuparuk River Unit Kuparuk 3M Pad 3M-260 50-029-22431-60 Baker Hughes INTEQ Definitive Survey Report 20 March, 2019 BAER UGHES a GE company 21 90 16 3060 1 Well 3M-26 31V-26 @ 68.00usft (3M-26) 3M-26 (03 66.00usft (3M-26) True Minimum Curvature EDT 14 Alaska Production Map System: US Stale Plane 1927 (Exact solution) ConocoPhillips ConocoPhillips Definitive Survey Report Company: ConocoPhillips Alaska Inc—Kuparuk Local Co-ordinate Reference: Project: Kupamk River Unit TVD Reference: Site: Kuparuk 3M Pad MD Reference: Well: 31VI-26 North Reference: Wellbore: 3M-261-1 Survey Calculation Method: Design: 31VI-261-1 Database: Project Kuparuk River Unit, North Slope Alaska, United States 0.00 usft Well 3M-26 31V-26 @ 68.00usft (3M-26) 3M-26 (03 66.00usft (3M-26) True Minimum Curvature EDT 14 Alaska Production Map System: US Stale Plane 1927 (Exact solution) System Datum: Mean Sea Level Geo Datum: NAD 1927 (NADCON CONUS) (usR) Using Well Reference Point Map Zone: Alaska Zone 04 9,311.22 Using geodetic scale factor Well 3M-26 31J-2611 MWD-INC(31111-2611) 9,433.23 Well Position +N/ -S 0.00 usft Northing: 6,016,559.83usft Tool Name +E/ -W 0.00 usft Easting: 506,274.89usft Position Uncertainty 0.00 usft Wellhead Elevation: usft Wellbore 3M-2611 2/24/2019 2/24/2019 Magnetics Model Name Sample Date Declination (I BGGM2018 4/1/2019 16.63 Design 3M-2611 Audit Notes: Version: 1.0 Phase: ACTUAL Vertical Section: Depth From (TVD) (usft) 68 00 Survey Program Date From TO 149° 56' 55.644 W i (usR) lush) Survey (Wellbore) 71.01 9,311.22 3M-26 (31A-26) 9,313.00 9,402.68 31J-2611 MWD-INC(31111-2611) 9,433.23 11,642.07 3M-2611 MWD (31VI-261-1) DA ER F�UGNES Dip Angle Field Strength 1°1 (nT) x 80.93 57,424 Tie On Depth: 9,311.22 Latitude: 70° 27'23.296 N Longitude: 149° 56' 55.644 W i Ground Level: 0.00 usft j Dip Angle Field Strength 1°1 (nT) x 80.93 57,424 Tie On Depth: 9,311.22 +N/ -S +E/ -W Direction (usft) (usft) (^) 0.00 0.00 300.00 Survey Survey Tool Name Description Start Date End Date GCT -MS Schlumberger GCT muitishot 1/15/2001 MWD-INC—ONLY MWD-INC—ONLY—FILLER 2/24/2019 2/24/2019 MWD MWD- Standard 2/25/2019 2/25/2019 I 3!202019 2:29: 11PM Page 2 COMPASS 5000.14 Build 85D ConocoPhillips BA ER ConocoPhillips Definitive Survey Report t VDNtU Company: ConocoPhillips Alaska lnc_Kupamk Project Kuparuk River Unit Site: Kuparuk 3M Pad Well: 3M-26 Wellbore: 3M-261-7 Design: 3M-261-1 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 TIP KOP/TOWS 1 Interpolated Azimuth Interpolated Azimuth ' Interpolated Azimuth j 320/2019 2:29:11PM Page 3 COMPASS 5000.14 Suits 85D Map Map Vertical MD Inc Azi TVD TVDSS +N/ -S +E/ -W Northing Easling DLS Section (usft) (°) V) (usft usft ( ) (usft ) usft ( ) I°/100') Survey Tool NamE (ft) (ft) (ft) 9,311.22 4065 11.78 6,289.44 6,221.45 6,301.77 197.74 6,022,86113 506,467.30 144 2,979.64 MWD -INC ONLY(2) 9,313.00 40.82 11.80 6,290.79 6,222.79 6,302.91 197.97 6,022,862.27 506,467.53 1.84 2,980.00 MWD-INC_ONLY (2) 9,342.63 53.98 8.25 6,310.81 6,242.81 6,32434 201.69 6,022,88371 506,471.23 45.27 2,987.50 MWD -INC _ONLY (2) 9,372.29 66.58 579 6,325.48 6,257.48 6,349.86 204.80 6,022,90922 506,474.32 43.08 2,907.57 MWD -INC _ONLY (2) 9,402.68 80.91 3.72 6,333.97 6,265.97 6,378.86 207.19 6,022,938.22 506,476.69 4760 3,010.00 MWD-INC_ONLY (2) 9,433.23 90.40 1.83 6,336.28 6,268.28 6,409.25 208.66 6,022,%&61 506,478.13 31.67 3,023.92 MWD (3) 9,46247 91.54 348.89 6,335.78 6,267.78 6,438.33 206.30 6,022,997.68 506,475.75 44.42 3,040.50 MWD (3) 9,493.58 90.15 333.40 6,335.32 6,267.32 6,467.67 196.28 6,023,027.02 506,46570 49.98 3,063.86 MWD(3) 9,521.89 95.20 326.20 6,334.00 6,266.00 6,492.09 182.07 6,023,051.42 506,45147 31.04 3,088.37 MWD(3) 9,552.11 95.44 321.53 6,331.20 6,263.20 6,516.39 164.33 6,023,075.70 506,43372 15.41 3,115,88 MWD (3) 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 3,147.00 MWD (3) 9,616.00 93.93 318.26 6,325.52 6,257.52 6,565.07 123.36 6,023,124.34 506,392.71 7.28 3,175.70 MWD(3) 9,644.39 92.24 316.08 6,323.99 6,255.99 6,585.85 104.09 6,023,145.11 506,373.42 9.71 3,202.78 MM (3) 9,675.98 90.40 313.50 6,323.27 6,255.27 6,605.10 81.68 6,023,16234 506,350.99 10.3 3,233.31 MWD(3) 9,705.95 89.08 $10.80 6,323.40 6,255.40 6,628.21 59.46 6,023,18243 506,32876 10.03 3,262.61 MWD (3) 9,736.33 87.79 307.75 6,324.23 6,256.23 6,647.43 35.% 6,023,206.63 506,30524 10.90 3,292.58 MWD (3) 9,766.26 89.20 306.89 6,325.02 6,257.02 6,665.57 12.16 6,023,224.74 506,281.44 5.52 3,322.25 MWD (3) 9,796.47 89.14 304.51 6,32546 6,257.46 6,683.20 -12.37 6,023,242.35 506,25690 7.88 3,352.31 MWD (3) 9,82443 89.36 302.74 6,325.82 6,257.82 6,698.68 35.64 6,023,257.81 506,23361 6.38 3,380.21 MWD (3) 9,855.55 90.37 301.59 6,325.90 6,257.90 6,715.24 -61.99 6,023,274.35 506,20725 4.92 3,411.30 MWD (3) 9,88528 92.52 302.38 6,325.15 6,257.15 6,730.99 -8219 6,023,290.07 506,18264 7.70 3,441.01 MWD (3) 9,915.27 92.67 301.85 6,323.79 6255.79 6,746.92 -112.57 6,023,305.97 506,156.65 1.80 3,470.94 MWD (3) 9,945.22 94.09 304.37 6,322.02 6,254.02 6,763.25 -137.61 6,023,32228 506,131.60 9.62 3,500.79 MWD (3) 9,975.31 93.47 306.00 6,320.04 6,252.04 6,780.55 -162.14 6,023,339.56 506,107.05 5.78 3,530.70 MWD (3) 10,00522 9347 308.35 6,318.23 6,250.23 6,798.59 -185.93 6,023,357.58 506083.25 7.84 3,560.31 MM (3) 10,039.27 9433 308.04 6,315.91 6,247.91 6,819.59 -212.63 6,023,378.56 506.056.54 2.68 3,593.94 MWD (3) 10,061.24 95.38 308.72 6,314.05 6,246.05 6,833.18 -229.79 6,023,392.13 506,039.37 5.69 3,615.60 MWD(3) 10,094.96 95.51 307.91 6,310.85 6,242.85 6,853.99 -256.13 6,023,412.92 506,013.02 242 3,648.81 MWD (3) 10,120.49 94.49 306.50 6,30863 6,240.63 6,869.37 -276.38 6,023,428.28 505,992.75 6.80 3,674.04 MWD (3) 10,150.91 90.98 303.52 6,307.18 6,239.18 6,886.80 -301,26 6,023,445.68 505,96285 15.13 3,704.30 MWO(3) Annotation TIP KOP/TOWS 1 Interpolated Azimuth Interpolated Azimuth ' Interpolated Azimuth j 320/2019 2:29:11PM Page 3 COMPASS 5000.14 Suits 85D ConocoPhillips ConocoPhillips Definitive Survey Report Company: ConocoPhillips Alaska Inc_Kuparuk Local Coordinate Reference: Well 3M-26 Project: Kuparuk River Unit TVD Reference: 3M-26 @ 68.00usft (3M-26) Site: Kuparuk 3M Pad MD Reference: 3M-26 @ 68.00us% (31VI-26) Well: 310-26 North Reference: True Wellbore: 31M-261.1 Survey Calculation Method: Minimum Curvature Design: 31VI-2611 Database: EDT 14 Alaska Production Survay, Annotation BA ER i UGNES 320/2019 2:29: 11PM Page 4 COMPASS 5000.14 Build 85D Map Map Vertical MD Inc Azi TVD TVDSS +N/ -S +E/ -W DLS (usft) V) (1) (usft) (usR) (usR) (usR) Northing Easting (°/100' Section STool Name Survey y (ft) (ft) (ft) 10,180.50 90.61 301.50 6,306.76 6,238.76 6,902.70 -326.21 6,023,461.56 505,942.89 6.94 3,733.86 MWD(3) 10,210.70 89.60 298.33 6,306.71 6,238.71 6,917.76 -352.39 6,023,476.60 505,916.71 11.02 3,764.06 MWD (3) 10,240.59 88.25 294.53 6,307.27 6,239.27 6,93106 -379.14 6,023,489.87 505,889.95 13.49 3,793.88 MWD (3) 10,275.47 90.00 293.95 6,307.80 6,239.80 6,945.38 -410.94 6,023,504.16 505,858.14 5.29 3,828.57 MWD (3) 10,306.29 90.31 293.47 6,307.72 6,239.72 6,957.77 -439.16 6,023,516.53 505,829.91 1.85 3,859.21 MWD (3) 10,336.31 90.03 295.94 6,307.63 6,239.63 6,970.31 466.43 6,023,529.05 505,80264 8.28 3,889.10 MWD (3) 10,366.30 90.40 297.91 6,307.52 6,239.52 6,983.89 -493.17 6,023,54261 505,775.89 6.68 3,919.04 MVD (3) 10,395.59 88.16 297.39 6,307.89 6,239.89 6,997.48 -519.11 6,023,556.18 505,749.94 7.85 3,948.30 MWD(3) 10,426.04 87.39 299.80 6,309.07 6,241.07 7,012.05 545.82 6,023,570.71 505,723.22 8.30 3,978.72 MWD (3) 10,456.29 87.12 302.17 6,310.52 6,242.52 7,027.60 571.72 6,023,58624 505,697.30 7.88 008.93 MWD (3) 10,484.97 87.12 304.74 6,311.96 6,243.96 7,043.39 59562 6,023,602.01 505,673.40 8.95 4,037.52 MWD (3) 10,515.56 86.07 305.74 6,313.78 6,245.78 7,061.01 -620.56 6,023,61961 505,648.44 4.74 4,067.92 MWD (3) 10,545.24 86.71 304.56 6,315.64 6,247.64 7,078.06 544.78 6,023,63664 505,624.21 4.52 4,097.43 MWD (3) 10,575.83 87.05 302.11 6,317.31 6,249.31 7,094.85 -670.30 6,023,653.40 505,59868 8.07 4,127.92 MWD (3) 10,605.77 87 S5 300.34 6,318.72 6,250.72 7,110.35 595.87 6,023,668.88 505,573.10 6.14 4,157.82 MWD (3) 10,635.72 86.59 298.35 6320.25 6,252.25 7,125.01 -721.94 6,023,68351 505,547.02 7.37 4,187.72 MWD(3) 10,665.64 88.13 298A4 6,32163 6,253.63 7,139.22 -748.23 6,023,697.70 505,520.72 5.16 4,217.60 MWD (3) 10,69543 89.02 297.13 6,322.37 6,254.37 7,153.10 -774.58 6,023,711.56 505,494.36 5.32 4,247.36 MWD (3) 10,724.37 88.86 297.57 6322.91 6,254.91 7,166.39 -800.28 6,023,724.83 505,46865 1.62 4,276.26 MWD(3) 10,755.67 8844 298.84 6,32364 625564 7,181.18 -827.85 6,023,739.59 505,441.07 4.27 4,307.53 MWD (3) 10,781.66 89.54 299.51 6,324.10 6,256.10 7,193.65 -850.54 6,023,752.24 505,418.37 4.96 4,333.52 MWD (3) 10,810.77 90.43 299.40 6,324.11 6,256.11 7,208.16 -875.89 6,023,766.53 505,393.02 3.08 4,362.63 MM (3) 10,845.33 92.21 300.20 6,323.31 6,255.31 7,225.33 -905.87 6,023,783.68 505,363.02 5.65 4,397.17 MWD (3) 10,876.20 93.90 300.98 6,32167 6,253.67 7,241.02 -932.41 6,023,799.34 505,336.48 6.03 4,428.00 MWD (3) 10,900.15 92.49 302.39 6,320.33 6,252.33 7,253.58 -952.75 6,023,811.88 505,316.12 8.32 4,451.90 MWD (3) 10,929.97 92.15 305.02 6,319.12 6,251.12 7,270.11 -977.54 6,023,828.39 505,291.33 8.89 4,481.63 MWD (3) 10,959.45 9307 306.66 6,317.78 6,249.78 7,287.36 -1,001.41 6,023,845.61 505,267.44 6.37 4,510.92 MWD (3) 10,989.56 94.21 306.30 6,315.87 6,247.87 7,30522 -1,025.57 6,023,86345 505,243.27 3.97 4,540.78 MWD (3) 11,021.11 9126 305.39 6,314.37 6,246.37 7,32367 -1,051.11 6,023,881.88 505,217.71 9.78 4,572.13 MWD (3) 11,051 32 88.03 304.07 6,314.55 6246.55 7,340.88 -1,075.94 6,023,899.07 505,192.88 11.55 4,602.23 MWD (3) 11,082.11 89.82 303.49 6,315.13 6,247.13 7,358.00 -1,101.52 6,023 916 16 505,16728 6.11 4632.95 MWD(3) Annotation BA ER i UGNES 320/2019 2:29: 11PM Page 4 COMPASS 5000.14 Build 85D ConocoPhillips DA ER ConocoPhilli p s Definitive Survey Report ' `V2 , Company: ConocoPhillips Alaska Inc-Kuparuk Project: Kuparuk River Unit Site: Kuparuk 3M Pad Well: 3M-26 Wellbore: 3M-2617 Design: 3M-261-7 Survey Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Database: Well 3M-26 3M-26 Q 68.00usft (3M-26) 3M-26 @ 68.00usft (3M-26) True Minimum Curvature EDT 14 Alaska Production MD Inc Azl ND NDSS +N/ -S -E/.WNorthing Map Map DLS Vertical (usft) (') (°) (usft) (usft) (usft) (usft) Easting (°17000 Section Surve Y Tool Name (ft) (ft) (ft) 11,111.49 89.26 300.68 6,315.37 5,247.37 7,373.60 -1.12641 6,023,93174 505,142.38 975 4,662.30 MWD(3) 11,142.17 87.82 298.51 6,316.15 6,248.15 7,388.75 -1,153.08 6,023,94666 505,115.70 849 4,692.97 MWD(3) 11,169.73 88.87 297.73 6,316.94 6,248.94 7,401.73 -1,177.38 6,023,959.83 505,09140 4.75 4,720.50 MWD(3) 11,200.71 88.74 296.98 6,317.59 6,249.59 7,415.96 -1,204.89 6,023,974.03 505,063.88 2.46 4,751,44 MWD(3) 11,231.01 88.59 298.48 6,318.30 6,250.30 7,430.06 -1,231.70 6,023,988.10 505,037.05 4.97 4,781.71 MWD(3) 11,260.36 89.79 299.07 6,318.71 6,250.71 7,444.18 -1,257.42 6,024,002.21 505,011.33 4.56 4,811.05 MWD (3) 11,290.47 88.80 298.74 6,319.08 6,251.08 7,458.74 -1,283.78 6,024,016.74 504,984.96 3.47 4,841.15 MM (3) 11,319.96 89.29 300.28 6,319.57 6,251.57 7,473.26 -1,309.44 6,024,031.24 504,959.29 5.48 4,87063 MWD (3) 11,351.41 88.77 300.22 6,320.11 6,252.11 7,489.10 -1,335.60 6,024,04]05 504,932.12 1.66 4,902.08 MWD (3) 11,385.40 89.66 303.43 6,320.57 6,252.57 7,507.02 -1,365.47 6,024,064.95 504,903.23 9.80 4,936.04 MWD (3) 11,41597 9028 305.31 6,320.59 6,252.59 7,524.28 -1,390.70 6,024,082.18 504,877.99 848 4,966.52 MWD (3) 11,445.41 90.06 306.65 6,320.50 6,252.50 7,541.57 -1,414.53 6,024,099.45 504,854.15 4.61 4,99560 MWD (3) 11,476.13 90.85 308.15 6,320.25 5,252.25 7,560.23 -1,438.93 6,024.118.09 504,829.74 5.53 5,026.27 MWD (3) 11,506.08 88.83 307.53 6,320.33 6,252.33 7,57860 -1,462.58 6,024,136.44 504,806.07 7.09 5,055.93 MWD (3) 11,535.25 89.97 308.12 6,320.64 6,252.64 7,596.49 -1,485.62 6,024,154.31 504,783.02 4.40 5,084.83 MWD (3) 11,564.93 88.77 307.99 6,320.97 6,252.97 7,614.78 -1,508.99 6,024,17258 50475964 4.07 5,114.21 MM (3) 11,594.71 89.51 308.82 6,32141 6,253.41 7,633.28 -1,532.32 6,024,191.05 504,736.29 3.73 5,143.67 MWD(3) 11,625.65 89.23 309.26 6,321.75 6,253.75 7,652.77 -1,556.35 6,024,210.52 504,71225 169 5,174.22 MWD (3) 11,642.07 89.69 310.27 6,321.91 6,253.91 7,663.27 -1,568.97 6,024,221.01 504,699.62 6.76 5,190.41 MWD (3) 11,676.00 8969 310.27 6,322.09 6,254.09 7,685.20 -1,594.86 6.02424292 504673.71 0.00 5,22379 PROJECTEDto TD Annotation 320/2019 2:29:11PM Page 5 COMPASS 5000.14 Build 85D STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION RECEIVED APR 0 4 2019 WELL COMPLETION OR RECOMPLETION REPORT AND 1a. Well Status: Oil O Gas❑ SPLUG ❑ Other ❑ Abandoned ❑ Suspended❑ 1b. Well Class: 20A 025.105 20AAC25.110 Development Exploratory ❑ GINJ❑ WINJ❑ WAGE] WDSPL❑ No. of Completions: Service E] Stratigraphic Test EJ 2. Operator Name: ConocoPhillips Alaska, Inc. 6. Date Comp., Susp., or Aband.: 3/5/2019 14. Permit to Drill Number I Sundry: 219-016 • 3. Address: P.O. Box 100360 Anchorage, AK 99510-0360 7. Date Spudded: 2/23/2019 15. API Number: 50.029-22431.60.00 4a. Location of Well (Govemmental Section): Surface: 938' FNL, 1593' FEL, Sec 25, T13N, R8E, UM Top of Productive Interval: 5196' FNL, 1393' FEL, Sec 13, T13N, R8E, UM Total Depth: 3813' FNL, 3186' FEL, Sec 13, T13N, R8E, UM 8. Date TO Reached: 212412019 16. Well Name and Number: KRU 3M-261-1 9. Ref Elevations: KB:68 GL:27 , BF: 17. Field / Pool(s): Kuparuk River FieldlKuparuk River Oil Pool 10. Plug Back Depth MD/TVD: NIA 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- 506468 y- 6022862 Zone- 4 Total Depth: x- 604674 y- 6024243 Zone- 4 11. Total Depth Ni 11676/6322 4 19. DNR Approval Number: LONS 84.138 12. SSSV Depth Ni N/A 20. Thickness of Permafrost MD/TVD: 180611725 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: 931316291 22. Logs Obtained: List all logs run and, pursuant to AS 31.05.030 and 20 AAC 25.071, submit all electronic data and printed logs within 90 days of completion, suspension, or abandonment, whichever occurs first. Types of logs to be listed include, but are not limited to: mud log, spontaneous potential, gamma ray, caliper, resistivity, porosity, magnetic resonance, dipmeter, formation tester, temperature, cement evaluation, casing collar locator, jewelry, and perforation record. Acronyms may be used. Attach a separate page if necessary GR/Res 23, CASING, LINER AND CEMENTING RECORD WT. PER SETTING DEPTH MD SETTING DEPTH TVD AMOUNT CASING FT GRADE TOP BOTTOM TOP BOTTOM HOLE SIZE CEMENTING RECORD PULLED 16 62.5 H-40 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 9609 11676 6326 6322 3 Slotted Liner 24. Open to production or injection? Yes ❑� No ❑ If Yes, list each interval open (MDlrVD of Top and Bottom; Perforation Size and Number; Date Perfd): Slotted Liner@ 9621-11656 MD and 6325.6322...2125/2019 COMPLETION DE 1 VERIF1 D 25. TUBING RECORD SIZE DEPTH SET (MD) PACKER SET (MD/TVD) 31/2 9237 9206/6209 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. Was hydraulic fracturing used during completion? Yes E] No ❑� 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: 312212019 Method of Operation (Flowing, gas lift, etc.): GAS LIFT Date of Test: 3124/2019 Hours Tested: 8hrs Production for Test Period Oil -Bbl: 42.3 Gas -MCF: 41.7 Water -Bbl: 724 Choke Size: 1 176 Gas -Oil Ratio: 989mcf/Bbl Flow Tubing Press. 158 Casinq Press: 1 805 Calculated 24 -Hour Rate Oil -Bbl: 127 Gas -MCF: 12 Water -Bbl: 72 Oil Gravity - API (corr): 1 21.4 Form 10-407 Revised 5/2017 rT /_ 4/!_ / a�' CONTINUED ON PAGE 2 RBDMS tL) "' APR 0 5 2019 -Submit ORIGINAL ork1y� '" ` `11 r/ � 44.8. y{10/19 Il9t 28. CORE DATA Conventional Core(s): Yes ❑ No ❑� Sidewall Cores: Yes ❑ No ❑+ If Yes, list formations and intervals cored (MD/rVD, Fromrro), 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 0 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 9313 6290 information, including reports, per 20 AAC 25.071. Formation @ TPI -Kuparuk C TD 11676 6322 Formation at total depth: KUPARUK C 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, paleontolooical report. production or II test results per 20 AAC 25,070, 32. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Authorized Name: James Ohlin er Contact Name: William Lon Authorized Title: Staff CTD Engineer Contact Email: William. R.Lon co .com Authorized Contact Phone: 263-4372 Signature: Date: t INSTRUCTIONS General: This form and the required attachments provide a complete and concise record for each well drilled in Alaska. Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed. All laboratory analytical reports regarding samples or tests from a well must be submitted to the AOGCC, no matter when the analyses are conducted. Item 1 a: Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Item 1b: Well Class - Service wells: Gas Injection, Water Injection, Water -Alternating -Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Item 4b: TPI (Top of Producing Interval). Item 9: The Kelly Bushing, Ground Level, and Base Flange elevations in feet above Mean Sea Level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 15: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). Item 19: Report the Division of Oil & Gas / Division of Mining Land and Water: Plan of Operations (LO/Region YY -123), Land Use Permit (LAS 12345), and/or Easement (ADL 123456) number. Item 20: Report measured depth and true vertical thickness of permafrost. Provide MD and TVD for the top and base of permafrost in Box 29. Item 22: Review the reporting requirements of 20 AAC 25.071 and, pursuant to AS 31.05.030, submit all electronic data and printed logs within 90 days of completion, suspension, or abandonment, whichever occurs first. Item 23: Attached supplemental records should show the details of any multiple stage cementing and the location of the cementing tool. Item 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, or Other (explain). Item 28: Provide a listing of intervals cored and the corresponding formations, and a brief description in this box. Pursuant to 20 AAC 25.071, submit detailed descriptions, core chips, photographs, and all subsequent laboratory analytical results, including, but not limited to: porosity, permeability, fluid saturation, fluid composition, fluid fluorescence, vitrinite reflectance, geochemical, or paleontology. Item 30: Provide a listing of intervals tested and the corresponding formation, and a brief summary in this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Item 31: Pursuant to 20 AAC 25.070, attach to this form: well schematic diagram, summary of daily well operations, directional or inclination survey, and other tests as required including, but not limited to: core analysis, paleontological report, production or well test results. Form 10-407 Revised 5/2017 Submit ORIGINAL Only B CL \ hIl-al \ \CC! / CNJ ) \ \c / 0 / , t§ _ \ ) $N( ( ( % } f ! (0 co ! « ) \ \E\ \\ ■ )■ $■ ee-\ B emo: B ; 0 /\ CL \ hIl-al ; 0 /\ ConocoPhillips Alaska, lnI KUP PROD WELLNAME 314-26 RIVER UNIT NIPPLE WELLBORE wo: 1 14100 3M-26 914-25, w9rmle 12.x1 PM Last Tag VeOUIxMreEa(asOYj Annotation OBpNeduln 1 End Oak WeliCore Last Mw By Last Tag: RKI3 9,35]0 I12612019 loogusp ............ ......................_.............._......__............... Last Rev Reason Mnokf En°oak wellbore Leat Mos By HANGER,MCA Rev Reason: Pert TOg/Sed POGLYM gSeembly 325/2019 314-26 bwprthi Casing Strings Seeing Description o0(in1 II rop RtK1b set BaMb lnKe) set odeff, GND)'-VISLm g.., Gasses Tap Tbrcaa CONDUCTOR 16 1508 430 121.0 121.0 62.50 H30 WELDED Caslne oescionso DO(IM) .in) T"Shot) Bet Oepb Me) Sal OepM(NOj... WUlen (I... Grate Top Thread SURFACE 9518 8.92 41.1 4,8822 3, NO 36-00 J-55 BTC I pugs, Oesedptbn00Inas) 10 (in) Top lhKBj Set Deptl, (KKBj ser M H VIV) . Nltten g... Grade TOP TMotl PRODUCTION J 6.28 387 9,6147 6,525.6 Am L-80 BTC -MOD Tubing Strings Tubinp 0eacription string Ma... 10(Inj Top IKHBj SH Deplb (ft. SN DepN (TVOj (... WI(IWp Geade 'P Sennedkn W30 TUBING 3112 299 368 9,2322 8233.3 J-55 EUEBrdMOD CONDUCTOR:4o410 Completion Details TOP(TVOj Top Incl Nesminal Top(XKB) PIKE) I.; Ikm°es Co. 10 (in) 360 36.8 025 HANGER FMC GEN IV HANGER 35 NIPPLE. 2.0213 2,0212 1,9030 3725 NIPPLE CAMCO W-1 LANDING NIPPLE WI SELECTIVE PROFILE 2.812 9.2026 8207.0 40.37 LOCATOR BAKER 281122 LOCATOR SEALASSEMBLY 3. 00 9,2053 6.209.1 40.39 PACKER BAKER FB -1 PERM PACKER 401)0 9,208.6 6.211.6 40.41 SBE BAKER 8040 SEAL BORE EXTENSION 4.000 UPR PKB IME): 2.80x.0 9,2267 6,225.3 4049 NIPPLE CAMCO D NIPPLE NO GO, (MILLED OUT TO 2. BO-) 2800 9,236.3 6,232.7 40.52 SOS BAKER SHEAR OUT SUB 2992 POGLM' 28500 Other In Hole (1Mroline retrievable plugs, valves, pumps, fish, etc.) TPo(TVD) TP SPACER RPE: 2.94,1 PEREP:2Ll9.0 Co TOp (NKB) (N(Bj (') ON Cam Run DA I°(n) 2,942.0 2,4953 55.13 UPR PKR (ME) P2P UPR PKR (r PP35178) 31MM19 1.625 MR VNR (ME). x,mso 2,944.0 2,496. 5.1 PACER PIPE - wl nchOr Latch AssY4 5 3202019 1.640 821'OAL 2, 5 . 50 . 56.12 POGLM 1 . top of P packer to top of 0oltom Iakh ex 3202019 1.560 (V4 -pod) 2,9650 25085 56.11 LWR PKR(ME, P2P -WR ESP Q0 CPP35209, 4' GAL, 1.62510) 311712019 1.620 9,313.0 6,2908 40.82 HIP - NS HEW Tubing exit 21202019 THRU TBG SURFACE;au+.9B2x� 4500 BOWS 3840 FISH 3 % 6 718 X 718 SLIP LOSt Ided Air SLIP, was never 4126119M bund, could be in hole Perforations 8 Slots snot 0.45 LIFT; 8.1534 pens Top ITVD) BM (le) (abIXaM TPoS560 Btm (PotB) MKBj LInMM Zone Dell,01) TFP Can 2,9560 2,956.0 2.503.5 2,50 2,5035 3I1>I2D19 PERFP 2r CIRC UFM7177 SHOTS. SHOTS,PRI LOCAPOP IUEMS 9.324.0 9358.0 6,299.1 6,325.0 A-1,314-28 42011994 40 IPFRF sg un, deg.phasilg PACKER;GUO Mandrel Inserts set; REMe St so HA Top(BKB) Top (WD) corto MekO ModN Oo Did Sen Wlvs Type —PPOBBW Type (in) TRO Run (psg flan Date Com 9,153.3 6.169.3 CAMCO MMM tl2 GA LIFT GMY RK OWO 00 61311994 Notes: General & Safety "Close m Oak Anwmlon ]128/2010 NOTE:View Schematic wl Alaska 5chematic9.0 NIPPLE 5228] SOS: B,Z18.3 L101 LINER. 9=00 11,398U WHIPSTOCK TKRUTBG;Lie 8,3130 IPER1;9,44"NesO— FISH, 9,15 PROOVCTION; 9-088814]7 KUP PROD WELLNAME 31,11-26 WELLBORE 3M -26L1 Conoco`Phillips Alaska. lrc. aMI 411a0a)2n1, PM Last Tag Vw9u wvaum tan*wl AnnWafion peas main Ene Once WellOore Last MM By Last Tag'. 3M16L1 jennalt ...,.._..... ........... ......................... Casing Strings Casing 0escnpticn Caps, mpn) Top 1XNO) s.t DaW 1XNe) set Oepf1,irv0l_.MIen i...Gvsce TOPTnread pANOER; 3S.S LI LINER 23/8 1.99 9,609.3 11,6Jfi0 4.60 11 STL Liner Details Noml l t0 Top MRUN Top(I pass) Tap Incl l°I Prem Da. coin Nn) 9.609.3 fi,326.0 962) ALUMINUM Aluminum Liner Top Billet with Open Hole Anchors 1.920 BILLET 9,629.5 B3243 9313 ALUMINUM Mani Liner Top Billet mM OOpen Hole Anchors 1.920 BILLET 9,6413 6,324.1 11 1 Shorty Eeploymem sleeve 1920 SLEEVE CONDUCTOR. 45 o121 Perforations &Slots Owns Own TupjIM e(I IsnalJtl NIPPLE, zon z Top tnna) Btm trtxe) Xtxa) (mcg) unke4zone Dat. ) Tina coin 96420 tT654.0 6,324.1 6,3220 A-1, 3M -26L1 Z25I2019 SLOTS SIOMO Liner Notes: General & Safety -'— =F Annotation UFRPKR (ME], 2,e42o 4/1p019 PCOLM, x.950.0 JPPCas PIPE', Z... PERP, E,955.0 LWR PI(R(MEN ZMa SURFACE; 41.14.8KI WS LIFT; 9,1Gi.] LOCATOR, a=$ PACKER; 9,2063 9BE; 8}f98 NIPPLE, 9.. SOa; 9.25.5 PRODUCTION, as "In 4T .U. eastia, I a7la� L1-01 LINER: 9.TN.a11,J950 , r '\\II J I s.' --J L 7C l� 11 LINER. 9MG 3-11,e IN Operations Summary (with Timelog Depths) 3M-26 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log start Dept, Start Time End Time Dur (hr) Phase Op Code Activity Code Time P -T -X Opereton (tKB) End Depth (ftKB) 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 dg 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 & 112 -Way house, offload last of fluids 2118/2019 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 2118/2019 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 18:36 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 18:36 00:00 Pad (20.7 miles) 21:00 @ the Y 22:00 @ 1Q 23:15 @ CPF3 BFGS tum at midnight 2/19/2019 2119/2019 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 over well. 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 2119/2019 2/19/2019 1.10 MIRU MOVE MOB P Spot service unit 0.0 0.0 06:06 07:12 2119/2019 2119/2019 2.80 MIRU WHDBOP RURD P Work rig up check list, walkways, 0.0 0.0 07:12 10:00 Berming, RU PUTZ, steam, Duck ponds. 2/19/2019 2/192019 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 2/192019 2/19/2019 1.00 MIRU WHDBOP RURD P Fluid pack and shell test 0.0 0.0 12:30 13:30 2119/2019 2/192019 8.00 MIRU WHDBOP 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 2/1912019 0.50 MIRU WHDBOP PRTS P With PDL on stump, open master 0.0 0.0 22:30 23:00 valve, WHIP 1,400 psi, line up to tiger lank 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 PDL, 2/19/2019 2/20/2019 0.25 PROD1 RPEQPT PULD P PJSM, PU HEW 0.0 0.0 23:45 00:00 1 1 1 1 1 1- 2/202019 220/2019 1.00 PROD1 RPEQPT PULD P Continue PU HEW 0.0 0.0 00:00 01:00 1 I I Page 1116 Report Printed: 413/2019 Operations Summary (with Timelog Depths) - 3M-26 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time log Start Depth Start Time EM Tena Dw (hr) Phase Op Code Activdy Code Time P -T -X Operation MB) End Depth (1tKB) 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) 2/20/2019 2/20/2019 2.20 FROM RPEQPT TRIP P RIH, with open EDC, pumping min 73.5 8,970.0 01:30 0342 rate 0.39 bpm at 1,433 psi, WHP=1,304 2/20/2019 2/20/2019 0.50 PRODt RPEQPT DLOG P Log formation looking for the HRZ 8,970.0 9,112.0 03:42 04:12 1 1 correction plus 3.5' 2/20/2019 2/20/2019 0.20 FROM RPEQPT TRIP P Continue IH 9,112.0 9,214.0 04:12 04:24 2/20/2019 2/20/2019 0.33 FROM RPEQPT DLOG P Attempt to log the Kt, 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 FROM 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 2/20/2019 0.25 PRODt RPEQPT DLOG P Log CCL from 9,260'-9340', correlate 9,260.0 9,343.0 04:55 05:10 logs. 2/20/2019 2/20/2019 0.40 FROM 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 FROM 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 FROM 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 1004 of hole torque stable. 2/20/2019 2/20/2019 2.40 FROM RPEQPT RGRP T Sudden stop, SCADA System locked 2,866.0 2,866.0 10:04 1228 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 FROM RPEQPT TRIP P POOH 2,866.0 85.0 12:28 13:04 2/20/2019 2/20/2019 1.00 FROM RPEQPT PULD P PUD and LD BHA#1, whipstock 85.0 0.0 13:04 14:04 setting assembly. 2/20/2019 2/20/2019 1.00 PROD1 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 offs - good. Page 2/16 Report Printed: 41312019 Operations Summary (with Timelog Depths) 3M-26 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Stan Depm Start Time End Tama Dur (hr) Phase Op Code Activity Code Time P-T-X Operation (VS) End Depth (kKB) 2/20/2019 2/20/2019 2.60 PROD1 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 for 1 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 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, Diff--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 PROD? 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 Shut down pump, open EDC, 3,948 9,270.0 9,270.0 01:30 01:48 1 1 1 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, R/D 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 2/21/2019 0.30 PROD1 DRILL CTOP T RID inner reel iron, unstab break off 0.0 0.0 08:42 09:00 Upper quick connect, cut off CTC. 2/21/2019 2/21/2019 0.50 PROD1 DRILL CTOP T Install grapple 0.0 0.0 09:00 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 09:30 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 PROD1 DRILL CTOP T Suspend reel, remove saddle clamps. 0.0 0.0 13:12 13:48 2/21/2019 2121/2019 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 2/21/2019 1.20 PROD1 DRILL CTOP T Swap gripper blocks, elastomers, 0.0 0.0 14:30 15:42 clips, replace strippper 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 3116 ReportPrinted: 41312019 Operations Summary (with Timelog Depths) 3M-26 4b 1 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Stan Depth Start Tune I EM Time Dur (hr) Phase Op Code A any Code Time PJA Operation (111(13) End Depth (W13) 2/21/2019 2/21/2019 1.30 PRODt DRILL CTOP T Prep and pick new storage reel # 0.0 0.0 16:42 18:00 52794 2121/2019 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 1 1 INJH, apply traction 2/21/2019 2/21/2019 2.50 PROD1 DRILL CTOP T Install inner reel iron, sim-ops load out 0.0 0.0 20:30 23:00 banding and material from bomb -bay door. install king pin. 2/21/2019 2/22/2019 1.00 PROM DRILL CTOP T Install Bolster, spill dikes, position reel 0.0 0.0 23:00 00:00 for installing iron, remove grapple 2/222019 2/22/2019 3.00 PROM DRILL CTOP T Continued installing inner reel iron, 0.0 0.0 00:00 03:00 CTES counter 2/222019 2/222019 1.50 PROM DRILL CTOP T Ream Seam from coil, install CTC, 0.0 0.0 03:00 04:30 head up BHI UQC 2/22/2019 222/2019 2.50 PROD1 DRILL CTOP T MU High Pressure Bulkhead inside 0.0 0.0 04:30 07:00 reel, and lest a -line, tighten & secure inner reel iron 212212019 2/22/2019 1.20 PROD1 DRILL CTOP T Skid reel, PU pump in sub place on 0.0 0.0 07:00 08:12 stump,BO noule, pull test 35 k good. Check CTC. MU n=le stab injector 2/22/2019 2/22/2019 5.20 PROD1 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 bbis MethOH min rale, chase w water. 2/22/2019 2/22/2019 2.40 PROD1 DRILL CTOP T SO nomde, 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. 2/2212019 2/22/2019 2.20 PROD1 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=18,028'145.7 bbl Vol) 2/22/2019 2/22/2019 1.20 PROD1 DRILL CTOP T Test a -line (good -test), Dress coil, 0.0 0.0 18:00 19:12 Install CTC, PT 35 k 2/22/2019 2/22/2019 1.25 PROM DRILL CTOP T Re -head BHI UQC, test a -line (good- 0.0 0.0 19:12 20:27 test) 2/22/2019 2/22/2019 0.30 PROM DRILL CTOP T PT re -head to 4,500 psi, Break off pull 0.0 0.0 20:27 20:45 plate 2/22/2019 2/22/2019 2.30 PRODt DRILL CTOP P PJSM, PU/PD build section assembly 0.0 72.2 20:45 23:03 2/22/2019 222/2019 0.30 PROM 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 2/2312019 0.65 PROD1 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 2/2312019 0.70 PROM DRILL DLOG P Log formation correction of plus 93.5' 8,885.0 9,085.0 00:45 01:27 2/23/2019 2/23/2019 0.45 PROD1 DRILL 1 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: 4/3/2019 Operations Summary (with Timelog Depths) 3M-26 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Sten Depth Stan Time End Tim Dur (hr) Phase Op cute Activity Code Time P -T -X Operation ph<B) End Depth(ftKB) 2/23/2019 2/23/2019 5.90 PROD1 DRILL DRLG P BOBD, 1.85 bpm at 3,888 psi, 9,390.0 9,530.0 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 Itis RIH Wt 15k lbs, Ct 4010 psi @ 1.88 in 1.86 out WH 497 psi, IA 578 psi, OA 633 psi, OBD, diff 497 psi. WOB 3k lbs, ROP 3-5 8/hr, in ankedte, break out @ 9496' Drill ahead, stage 5x5 low high[ of the bit in anticipation of TD. "TD build - 9530' 2/23/2019 2/23/2019 2.10 PROM DRILL TRIP P PU W134 k Itis. 9,530.0 77.0 07:57 1003 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 clamps a little loose on DS. - 8 min Continue to POOH, 2/23/2019 2/23/2019 1.00 PROD? DRILL PULD P PUD, holding 12.1 ppg EMW, well is 77.0 0.0 10:03 11:03 very tight. LD BHA#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 9,030.0 12:03 13:45 test agitator. 2/23/2019 2/23/2019 0.50 PROD1 DRILL DLOG P Logged the peaks of tie in for +6' 9,030.0 9,380.0 13:45 14:15 correction Logged RA tag 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 Ibs, ROP - 121 ft/ hr. 2/23/2019 2/23/2019 0.75 PROD1 DRILL TRIP T PU wt 32 k Itis, Issue with MWD, TVD 9,580.0 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 PROD1 DRILL DRLG P CT 3991 psi @ 1.88 bpm in and 1.88 9,580.0 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 fUhr WH 430 psi, IA 631 psi, OA 683 psi, 2/23/2019 2/23/2019 3.25 PROD1 DRILL DRLG P OBD, 1.9 bpm at 4621 psi, Diff --1,068 9,695.0 9,987.0 17:30 20:45 psi, WHP=435, BHP=3,991, IA=988, OA=977, "' Note: On-sfte Geo calling fault crossing 9,900' 2/23/2019 2/23/2019 0.40 PROD1 DRILL WPRT P Wiper to the EOB, PUW 35 k 9,987.0 9,530.0 20:45 21:09 2/23/2019 2/23/2019 0.30 PROD? DRILL WPRT P Wiper back in hole, RIW 14 k 9,530.0 9,987.0 21:09 121,27 I Page 5116 Report Printed: 41312019 . Operations Summary (with Timelog Depths) 3M-26 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Stan Time End Time our (hr) Phase Op Code Activity Code Time P -T -X Operation start Depth (M<13) End Depth (itKa) 2/2312019 2/24/2019 2.56 PROD1 DRILL DRLG P OBD, 1.9 bpm at4621 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 2124/2019 2/24/2019 1.00 PROD1 DRILL DREG 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 PROM 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 0410 Diff=1,527 psi, WHP=424, BHP=4,004, IA=639, OA=809 2/24/2019 2/24/2019 0.55 PROM DRILL WPRT P Wiper up hole into the casing, PUW 10,418.0 9,330.0 04:10 0443 35 k 2124/2019 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 PROM DRILL DLOG P Log the RA marker correction of +1.5' 9,340.0 9,370.0 05:07 05:19 2/24/2019 2/2412019 0.40 PROD1 DRILL WPRT P RIH after tie in wiper, RIH Wt 32 k Itis 9,370.0 10,418.0 05:19 05:43 2/24/2019 2/24/2019 2.50 PROM 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 10785'- 36 Is lbs ROP 160 it/hr 2/24/2019 2124/2019 0.40 PROD1 DRILL WPRT P PUWl34 k lbs 10,816.0 9,816.0 08:13 08:37 Slight neg WOB tug @ 10200' with a - 40 psi increase in annular pressure 2/2412019 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 PROM 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 akerite 2/24/2019 2/24/2019 2.40 PROD1 DRILL DRLG P Break out of ankerite. 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 Itis 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 lbs, WOB 1 k Ibs, Bleed IA to 6 psi energized fluid, Bleed OA to 32 psi all fluid. Page 6/16 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 Dur(hr) Phase op Code Aovity Code Time P -T -X Operation (WO) EM Deph(WB) 2/24/2019 2/24/2019 0.50 PRODt DRILL DRLG P PU Wt 35 k lbs 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. 2/24/2019 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 2/24/2019 0.20 PROD1 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 PRODt 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 PROD? DRILL TRIP P PU Wt 33 k lbs, RBIH, window and 9,299.0 11,220.0 17:01 18:48 build clean. 2/24/2019 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 2/24/2019 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 PRODi DRILL DRLG P BOBO, 1.84 bpm at 5,022 psi, 11,446.0 11,604.0 19:45 21:03 Ddf=1,238 psi, WHP=432, BHP=4,086, IA=22, OA=96 2/24/2019 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 2/24/2019 1.00 PROD1 DRILL DRLG P BOBD, 1.31 bpm at 3,559 psi, 11,604.0 11,676.0 21:15 22:15 Di"- 09, BHP=4,107, IA=17, OA=100 2/24/2019 2124/2019 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' 2/24/2019 2/25/2019 0.50 PROD! 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 2/25/2019 2.00 PRODi 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 2/25/2019 1.65 PROD1 DRILL TRIP P Tag up, reset counters, RIH 78.3 9,055.0 02:00 03:39 2/25/2019 2/25/2019 0.25 PROD1 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 PRODi DRILL TRIP P Continue IH 9,257.5 11,676.0 04:12 05:12 2/25/2019 2/25/2019 1.40 PROD1 DRILL TRIP P Confirm TO 11,676', reciprocate pipe 11,676.0 11,592.0 05:12 06:36 while finishing liner running pill. 2/25/2019 2/25/2019 0.40 PROD1 DRILL DISP P Start Liner running pit down the coil, 11,592.0 11,671.0 06:36 07:00 1 1 1 1 1 112.29 pb, 50 bbis Page 7116 Report Printed: 41312019 Operations Summary (with Timelog Depths) 3M-26 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log steM1 Depth Start Time End Time our (hr) Phase Op Code Activay Code 7me P -T -X Operation (WS) End Depm (flK8) 2/25/2019 2/25/2019 2.60 PROM 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 pil @ 8170' 2/25/2019 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 respectively.ODS, Reel, etc. Bit graded out 1-2-bt-s-x-i-nr-td 2/25/2019 2/25/2019 3.30 COMPZ1 CASING PUTS P Prep floor for running Lower Ll 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 COMM CASING RGRP P Complete injector inspection / maint 2,034.7 2,034.7 14:12 14:42 2/25/2019 2/25/2019 0.90 COMPZI CASING PULD P PU BHA#5, Baker GS under Coil 2,034.7 2,080.0 14:42 15:36 Trak, Slab shorty, Inspect pack offs, replace checks, stab injector, bump up 2/25/2019 2/25/2019 1.20 COMPZ1 CASING RUNL P RIH W liner 2,080.0 9,190.0 15:36 16:48 2/25/2019 2/25/2019 0.20 COMPZI CASING DLOG P PU Wt 35 k lbs, Tie into window flag 9,190.0 9,184.2 16:48 17:00 for +1.16' 2/25/2019 2/25/2019 1.20 COMPZI 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, leff liner on bottom. 2/25/2019 2/25/2019 1.70 COMM CASING TRIP P PUH, park and reset counters to 11,676.0 96.0 18:12 19:54 account for dropping off liner. 2125/2019 2/25/2019 0.40 COMPZI CASING PULD P Flow check well, LD BHA over a dead 96.0 0.0 19:54 20:18 well. 2/25/2019 2/25/2019 0.80 COMPZ1 CASING PULD P PU Anchored billet, MU BHA 0.0 47.6 20:18 21:06 2/25/2019 2/25/2019 1.90 COMPZI CASING TRIP P RIH, with anchor billet, BHA #6 47.6 9,046.0 21:06 23:00 2/25/2019 2/25/2019 0.20 COMM CASING DLOG P Tie into the HRZ for+8.5' correction 9,046.0 9,089.0 23:00 23:12 2/25/2019 2/25/2019 0.50 COMPZI 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 2/2512019 212612019 0.30 COMPZI CASING TRIP P PU Wt 33 lbs, POOH 9,637.0 9,297.0 23:42 00:00 2/26/2019 2/26/2019 1.40 COMPZI 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 Li -01 lateral drilling 0.0 72.2 02:51 04:15 assembly 2/2612019 2/2612019 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: 41312019 Ant. Operations Summary (with Timelog Depths) 3M-26 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Time Em! Time our (hr) Phase Op Code Aavky Code Time P -T -X O p envkm Start Depth (WB) End Depen (flKB) 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 2/26/2019 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 2/26/2019 0.50 PROD2 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 2/26/2019 0.20 PROD2 DRILL KOST P Time mill 3 fl/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 2/26/2019 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 2/26/2019 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=5491/CTP=2,569 1.0 bpm/DP=1,053/CTP=3,429 1.5 bpm/DP=2,067/CTP=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 2/26/2019 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 2/26/2019 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 tention. 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 2/26/2019 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 dean 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 2/26/2019 2/26/2019 1.00 PROD2 DRILL PULD T PUD, kickoff/drilling BHA#7 72.2 0.0 16:42 17:42 2/26/2019 2/26/2019 1.30 PROD2 DRILL OTHR T Inspect BHA/ Motor/ Bit / FVS. Prep 0.0 -(To- .017:42 17:42j 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. WU to CT and surface test - Good. Stab on. OTS will not test. Unstab and replace O -Rings. run surface test and stab on. Tag up and set counters 2/26/2019 2/26/2019 2.10 PROD2 DRILL TRIP T Trip in hole, EDC open 81.3 9,060.0 21:00 23:06 2/26/2019 2126/2019 0.20 PROD2 DRILL DLOG T Log Gamma tie in for +4' corcection 9,060.0 9,098.0 23:06 23:18 EO.40 2/26/2019 2/262019 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: 4/3/2019 Operations Summary (with Timelog Depths) 3M-26 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log stain Depth Start Time End Time our (hr) Phase Op Code Activity Code Time P -T -X Operation (WB) End Depth (WB) 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 3.1 K 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 cutlers. 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 correction 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 2/27/2019 2/27/2019 1.00 PROD2 DRILL KOST T Mill tfph, 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 2fph, 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 it 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 1 1 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 Is 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 Diff -676, WHP=418, BHP=4,006, IA=23, OA=27, TO 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 7inch 9,808.0 9,235.0 12:30 13:00 clean 9,235'-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 2/27/2019 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 2/27/2019 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 Report Printed: 4/3/2019 Operations Summary (with Timelog Depths) 3M-26 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Depth SW Time End Time our (hr) Phase Op Code Activity Code Time P -T -X Operation (ftKB) End Depth(flKB) 2/27/2019 2/27/2019 0.10 PROD2 DRILL DLOG P Log gamma tie in for +4.5' correction 9,055.0 9,084.0 18:18 18:24 2/27/2019 2/27/2019 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 2/27/2019 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 PROD2 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 PROM DRILL WPRT P Pull BHA Wiper, PUW=35K 10,529.0 10,529.0 03:42 03:48 2/28/2019 2/28/2019 0.70 PROM DRILL DRLG P 10,529', Drill, 1.8 BPM @ 5386 PSI 10,529.0 10,552.0 03:48 04:30 j j FS, BHP=3993, RIW=3K, DHWOB=3K 2/28/2019 2/28/2019 0.10 PROM DRILL WPRT P BHA Wiper, PUW=38K, RIW=8.BK 10,552.0 10,552.0 04:30 04:36 2/28/2019 2/28/2019 1.00 PROD2 DRILL DRLG P 105521, 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 PROD2 DRILL WPRT P Wiper up hole into the casing 10,577.8 9,246.0 05:36 06:36 w/sweeps 2/28/2019 2/28/2019 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 PROD2 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 At surface, space out, PUD and LD 80.3 0.0 11:00 12:30 drilling assembly BHA #10 2/28/2019 2/28/2019 1.60 PROD2 DRILL PULD T PU/PD, cleanout assembly 0.0 62.4 12:30 14:06 2/28/2019 2/28/2019 1.70 PROD2 DRILL TRIP T RIH 62.4 9,040.0 14:06 15:48 2/28/2019 2/28/2019 0.20 PROD2 DRILL DLOG T Log formation (HRZ) correction of plus 9,040.0 9,067.0 15:48 16:00 2.0', dose 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 PROM DRILL WPRT T Wash down towards 9,900', Slack @ 9,320.0 9,900.0 17:00 17:42 9326, 9410, 9415, & 9436 2/28/2019 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 11/16 Report Printed: 4/3/2019 Operations Summary (with Timelog Depths) 3M-26 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Tiros our (hr) Phase Op Code AchM Cade Time P -T -X Operation (MB) End Depth (flKB) 2/28/2019 2/28!2019 1.60 PROD2 STK PULD T PJSM, M1U and PD BHA #12 OH 0.0 72.7 22:00 23:36 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 2,145.6- 2336 00:00 3/1/2019 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 3/1/2019 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 PROD2 STK TRIP T Continue in with OH anchor billet. 9,094.0 9,716.8 01:36 02:12 Stop at 9277 Gose EDC. PUW=32.5K. Continue in. Clean pass through window set down @ 9343'. PIU work pipe down. Cleared up past 9355. Continue into set depth @ 9716.75 3/1/2019 311/2019 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 2.5K. Looks good 3/1/2019 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 3/1/2019 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 05:42 07:12 3/1/2019 3/1/2019 1.70 PROD2 STK TRIP P RIH, with L1-01 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 31112019 0.30 PROD2 STK TRIP P Continue IH 9,068.0 9,704.0 09:08 09:24 3/1/2019 3/112019 0.20 PROD2 STK TRIP P Dry tag TOB, PUH obtain pump 9,704.0 9,703.0 09:24 09:36 pressures 3/1/2019 3/1/2019 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=24 311/2019 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=24 311/2019 3/1/2019 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 -520, WHP=237, BHP=3,953, IA=42, OA=58 3/1/2019 3/1/2019 1.50 PROD2 DRILL DRLG 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, OA=102 3/1/2019 3/1/2019 0.20 PROD2 DRILL WPRT P PUH, dry drift kickoff point dean 9,898.0 9,675.0 13:36 13:48 3/1/2019 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 BOBD, 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 3/112019 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 PROM DRILL WPRT P Pull through window, jog 7 inch x 2 9,246.0 9,300.0 15:30 15:36 with sweeps 3/1/2019 3/1/2019 1.50 PROD2 DRILL TRIP P POOH, with dosed EDC pumping 9,300.0 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 PROD2 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 Start Depth Start Time End Time our (hr) Phase op Code Activity Code Time P -T -X Operation (dKS) End Depth (RKB) 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 3/112019 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 3/112019 3/1/2019 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 3/112019 0.20 PROD2 DRILL DLOG P Log gamma tie in for+3.5'. PUW=33k 9,050.0 9,252.0 22:06 22:18 3/1/2019 3/1/2019 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 0000 BHP=4043 312/2019 3/2/2019 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 3/212019 31212019 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 3/2/2019 3/2/2019 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 3/2/2019 3/2/2019 0.50 PROD2 DRILL PULD T A surface, Tag up and space out. 65.0 85.0 04:48 05:18 PJSM PUD BHA#14 3/2/2019 3/212019 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 planfotward. 3/212019 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 foward is to pull chain link 3/2/2019 3/2/2019 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 312/2019 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 3/2/2019 3/212019 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. 3/2/2019 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 3/212019 3/2/2019 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 ReportPrinted: 4/3/2019 Operations Summary (with Timelog Depths) 3M-26 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time Our Inn Phase Dp Code Ac" Code Time P -T -x Operabon (ftKB) EM Depth(ftKB) 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 312/2019 3/212019 1.30 PROD2 DRILL TRIP T Trip in hole. Slop 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' 3/212019 3/212019 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 3/212019 3/2/2019 0.70 PROD2 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 3/2/2019 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 926334K 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, DHW0B=2.1K, ROP=120FPH 3/3/2019 3/3/2019 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 3/312019 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 3/3/2019 3/312019 0.25 PROD2 DRILL WPRT P Short Geo wiper up hole to 10,312' 10,374.0 10,312.0 05:09 05:24 3/3/2019 313/2019 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 3/3/2019 1.00 PROD2 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 3/3/2019 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 3/3/2019 0.15 PROD2 DRILL WPRT P Wiper back in hole, 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, 0A=121 3/3/2019 313/2019 0.20 PROM DRILL WPRT P Short BHA wiper up hole, PUW 39 k 10,638.0 10,638.0 09:27 09:39 3/312019 31312019 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 3/3/2019 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 Difh1,400 psi, WHP=244, BHP=4,062, IA -95, 0A=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 1 PUW 37 k 3/3/2019 3/3/2019 0.30 PROM DRILL WPRT P Circulate bottoms up, while jogging 9,300.0 9,246.0 12:57 13:15 1 1 the 7inch. x 4 3/3/2019 3/3/2019 0.15 PROD2 DRILL WPRT P RIH for tie in 9,246.0 9,340.0 13:15 13:24 Page 14/16 Report Printed: 413/2018 Operations Summary (with Timelog Depths) qW 3M-26 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Stan DWM Stan Time End Time our (hr) Phase Op Cotle Ativrly Cafe Time P -T -X Operation (flKB) End Depth(flKB) 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' 313/2019 3/3/2019 0.60 PROD2 DRILL WPRT P Conlime wiper back in hole, RIW 14 k 9,367.0 10,860.0 13:36 14:12 313/2019 3/312019 1.00 PROD2 DRILL DRLG P BOBO, 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, OA=121 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 11,103' 3/3/2019 31312019 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 3/312019 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 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 3/4/2019 314/2019 2.00 PROD2 DRILL TRIP P Tag up, reset counters, RBIH 78.0 9,040.0 06:06 08:06 3/4/2019 314/2019 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 31412019 1.20 PROD2 DRILL TRIP P Continue RIH 9,087.0 11,268.0 08:18 09:30 3/412019 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 TO, circulate beaded LRP 11,395.0 11,395.0 09:54 10:18 down coil, recip coil, Note: Static Pressure Survey Q 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 3/412019 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 3/4/2019 3/4/2019 3.00 COMPZ2 CASING PUTS P Pickup L1-01 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 3/412019 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: 413/2019 Operations Summary (with Timelog Depths) to 3M-26 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Bran Time End Tme Dur (hr) Phase Op Code Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth ntKB) 3/4/2019 19 1.20 COMPZ2 CASING RUNL P Continue IH 9,218.7 11,395.0 20:12 21:24 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 2206 Sensor Depth=6192.04', AP=3,952, Mud Weight=12.27 pp9 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 0318 1 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 0406 1 DOPE 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 secure. Rig down putz. Secure injector and reel. Rig Release 13:00 Page 16/16 Report Printed: 4/3/2019 ConocoPhillips ConocoPhillips Alaska Inc—Kuparuk Kuparuk River Unit Kuparuk 3M Pad 3M-261-1 50-029-22431-60 Baker Hughes INTEQ Definitive Survey Report 20 March, 2019 BAER 01 UGHES .- Conoc8it tulips ConocoPhillips Definitive Survey Report To Company: ConocoPhilh, Alaska lnc Kuparuk Local CDorWnam Reference: Mil 3W26 Protect: Kupamk River Unit WD Rehrence: 3M-26®68.00uaB(0M-26) Sha: Kupamk 3M Pad MD Reference: 3M-26®68.00usR(3M-26) WN: 3M-26 North Reference: True WWteoro: 3M-2611 Survey Calculation Method Minimum Curvature Osslgn: 31,4-2611 Database: EDT 14 Alaska Production Prole" Kimeruk River Unit, North Slope Ales", United Slates To End Dam Map 5ystem: US Stale Plane 1927 (Exact solution) System Datum: Mean Sea Level Gea Datum: NAD 1927 (NADCON CONUS) 11,642.07 Using Well Reference Paint Map Zone: Alaska Zune 04 Using,eadefc ewle factor Well JM-2fi Well Position .NTS 0.90 us% Northing: 6, 016,55983 usfl -V-W 0 D ush Salting: 606,274.8911se Position Unceminty 0.00 ush Wellhead Elevation: usfl Walloons 3M -26L1 MagnMlcs Model Name Sample Date Declination V) EGGM2018 41112019 16.63 Design 3M-2611 Audit Notes: Version: 1.0 Phase: ACTUAL TM On Dapth: 9,311.22 Vertical Section'. Depth From (WO) ♦Ml -e E/M Ndit) (u m) tush) 68.00 0.00 0 00 Survey Program From Wall 71.01 9,31300 9.433.23 TOW Nana GCT -MS MW INC ONLY MWD Description Schlumberger OCT mullishol MY INC_ ONLY FILLER MWD -Standard! latltutle: Longitude: Ground Level: Dip Angle 60.93 70° 27' 23,296 N lag. 56 55.644 W 0 OD us% Field Strength (nT) 57,424 Direction Survey Dme To End Dam (dare) SUrvey(WeIlbOR) 9,31122 3M-26 (310-26) 9,402.0 3M-261.1 MV INO(3W26L1) 11,642.07 3M -MLI MWD(3NL26L1) TOW Nana GCT -MS MW INC ONLY MWD Description Schlumberger OCT mullishol MY INC_ ONLY FILLER MWD -Standard! latltutle: Longitude: Ground Level: Dip Angle 60.93 70° 27' 23,296 N lag. 56 55.644 W 0 OD us% Field Strength (nT) 57,424 Direction Survey Survey Start Dace End Dam 111512001 2QV2019 212412019 22512019 22512019 3202019 229: ITEM Eage2 COMPASS 5000. 14 SUYd BSO Survey ConocoPhillips ConocoPhillips Definitive Survey Report Company. ConocoPhillips Alaska lnc Kupamk Local Co-ordinate Reference: WA," 3W26 Protect: Kupamk River Unit TVD Reference: 3M-26 @68.0ouen(3M-26) Site: Kupamk 3M Pad MO Reference: 3M -26@68.01(3242(i) Well: 324-26 Nerth Reference. True Wellbore: 324-2811 Survey Calculi Method: Minimum Ourvalure Design: 3M -25L1 Database: EDT 14 Maska Pm6uceon Survey eA. KFIi__ 4 Annotation TIP KOPrtOM Interyolate8N2imulh InteMolate6Avmulh Inter,dialec kone h 3 0192-MlIF14 Page3 COMPASS 5000.14 Build 850 �Sxbn MD Mc AM TVD TVDSS -Mi ♦EIm Northing Elating 91.8 server Test, W. (uelll M 11) (..ft) loan) jus") tuaM Ml MI (.11w) In) 9311,22 40.85 11.70 6,26940 fi22145 6,301.]] 110.70 61022,B61.13 505.461 144 2,91 MW0.1NC ONLY (2) 9.313.00 40.82 11.80 6,50]].79 6,M.79 6,302.91 197,97 6,0286227 5MA6].53 1.84 2,960.00 MWD -WC ONLY (2) 934263 53.98 925 6,310.81 6,242.81 6,324.34 201.10 6.01 B6311 508.47123 45.27 2.96750 M D -W ONLY (2) 9.37229 65.58 5.n 8,325.48 6,257.48 6,34988 204.10 6.022.909.22 510.474,32 43.06 2.10].5] hIWD-W ONLY (2) 940268 00.91 3.]2 6333.97 6,26597 637986 207.19 6022.93922 1XISAM69 47.60 3,01000 MW41NC ONLY (2) 9433.23 9040 183 6,336.26 6.51).26 640925 20866 6.02296951 506.470.13 3167 3,02292 MWD(3) 91 91.54 348.89 6,3M78 616]78 6,439.33 206.30 6,022997.60 5[8.475]5 44.42 3.040.50 MIND (3) 9A93.58 90.15 333.40 6,3W.M 6,267M 6,467.67 196.28 6,023,027.02 5e,4107D 49.98 3,6&3.68 MAD (3) 9,521.10 9620 3M.20 6,334.10 6,2*8,03 6,4W.P3 182.07 6.023.051.42 506.451.47 3110 3,088.37 MVVD(3) 9,552.11 9544 321.53 6.331.41 6,210..41 651639 164.33 6.423105]0 516.4328 1541 3.11510 M6D(3) 9,Sa553 95.47 319.85 6325.@ 6,250.8 6,54213 143.M 6,103,10142 505,41262 4.96 3,14710 MJA(3) 961600 93,93 318,M 6,32652 825/.52 6,565.4] 123.35 6,@3.124.34 516,39271 7.26 3,175.70 .JVD (3) 9,344.39 9224 316.08 6,=10 ti 6,515.05 104.09 6,023145.11 510,3]3.42 9]1 3,202]0 MMD(3) 96]698 90.40 313.50 6,32127 6.25527 6,608.10 8168 8.423.167.34 510.350.99 10.03 3,233.31 MWD(3) 970595 8968 310.93 6.32240 6.25540 6,62021 59.46 6,023.187.43 568328]8 10.03 3,262.61 MND(3) 9]35.33 Ili 307.75 6.324.23 625623 6,64743 35.85 6023.N6.63 510,30624 10.10 328258 ~(3) 9766]6 BB20 30510 6.325.02 8,257.02 8,616657 12.16 6,023.22474 506,28144 562 3,322.]5 MND (3) 9,]954] 0914 304,51 6.32546 (t257.46 6,60320 -1237 6,023,24235 506,253,50 ].08 3,35231 MWD(3) 9,84.43 saw 302]4 6,325.82 625282 669960 435.64 603.25].01 506.233.81 638 338021 MWD(3) 9.105.55 90.37 30159 6,325.90 6,257.90 6,71524 -51.98 60Y3.274.M 50510225 492 3,411.30 MWD(3) 9.65521) 92.9 3@.38 6.325.15 6257.15 8,730.99 47.19 6.023.MD7 506.18.04 ].]0 3."101 enNi 9,915,27 8.67 30186 6.323]9 8,255.79 1))49.8 -11257 6.02330897 5024.156.65 1,00 3.47094 MWDl3) 9,94522 "408 30.37 6,322.02 6,254.02 676325 -13261 6,02313Y22a 5013160 B.62 3,500]9 MWD(3) 9.975.31 9347 305M 5,320.04 6,252.04 6.700.55 Alois 6,023,33956 5X8'.05 5.76 3.530]0 MWO(3) 10.00 1 93.47 308.35 6,318.23 6,250.23 6,798.59 -185.93 6,83,357.58 5060815 7.84 3,560.31 MWD(3) 10.039.27 94M 300.04 6,315.91 6,247.91 6,61959 -212.63 6,023.370.55 506056.54 2.60 3.593.94 MWD(3) '0,M124 95.38 308]2 6,31405 6148.05 8,833.15 229.79 8.83.392.13 568.439.3] 569 3,615.60 caNO(3) totes. 95.51 M7..91 6,31085 6,242.85 6.853.99 356.13 6,834128 5e,013.02 2.42 3.E4"Al MWD P) 10.120.49 9449 3e.50 638.63 6240.63 6.81 876.31) 6@342828 510,88]5 fiat 3,67404 MND(3) 10,150.91 9098 3(13.9 6,307.18 6239.16 6,886.80 430126 6,023'4568 50,96285 1513 3,704.30 MWD(3) eA. KFIi__ 4 Annotation TIP KOPrtOM Interyolate8N2imulh InteMolate6Avmulh Inter,dialec kone h 3 0192-MlIF14 Page3 COMPASS 5000.14 Build 850 6202019 239.11PM Page 4 COMPASS 500014 Budd 85D ConocoPhillips �I 0 ConocoPhillips Definitive Survey Report Company: ConocoPhillips Alaska Inc Kupamk Local CocrdlnMe Rehrer4oe: 1kie113M-26 MD Project: Kupamk River Unit TVD Reference: 3M-26®66.00ua6(3M-26) 3VD58 Sne: Kupamk 3M Pad MD Rehlence: 3M-26®88.00ua6(3M-26) Easdng Well: 31.046 North Rehmnce: True (9 Wellbore: 3M -26L1 Survey C hulaticm Mal Minimum Curvature (u-ft)(uan) Design: 3M26L1Database: In) EDT 14 Alaska Production (.now) 6202019 239.11PM Page 4 COMPASS 500014 Budd 85D MD Inc Axl 1V0 3VD58 +WS evm Northln9 Easdng DLS Section (deft) (9 (1) (deft) (uan) (u-ft)(uan) In) Ill) (.now) Ire Survey Told flame Annotation 10.180.0 9061 301.50 53W,16 6,238.26 6,90270 x26.21 6,0Y 46156 Sc5.4269 694 3,233.16 MWn(3) 10,210.70 BRW 29833 6,30.71 6.238.71 6017,76 415239 6,023475.60 50591671 11.02 3,764.06 MAD (3) 10.240.59 8835 294.53 6,307.27 6239.1 6931.06 4179.14 6.M489.87 50.889.85 13.48 3,793.00 ""d(3) 10.275.47 6..W 293.95 6,30.80 6,239.0 6945.30 410.94 6.023 5G4.16 505.050.14 5.29 3,828.57 Mao (3) 10.30.29 90.31 293.47 6,30.8 6.239]2 6.957.77 K19.16 8.023.516.53 505.029.91 185 3,85921 NAND (3) 10,338.31 90.0 295.94 6.307.63 6,239.0 6,90.31 A GA3 6,01 5050264 638 3,009.10 MJJD(3) 10,31.16.30 .Po40 Dual 6,307.52 6.23952 6,903.89 -093.17 6,023,54261 505.775.89 6.66 3.919.04 MND(3) 10,395% 00.16 29180 6.39.09 6.2390 8.99740 518.11 6.023,5%.1.8 505,749.94 185 3,94830 MWD(3) 10,436.04 9.39 29B.8d, 6,309.07 6,241.9 7,012.05 54582 6023.570]1 505.83.22 &30 3,9012 MAD (3) 10,456.29 87.12 302.9 6,310.52 624252 7p1.1 371.8 6,023,50.24 505.697.30 7.88 4,W8.93 MWD (3) 1D,4B4 7 07.12 30414 6,311.0 6,243.96 7,043.39 395.62 6823.02.01 5 .673.0 &95 4.037.52 MWD(3) 10.51&0 86.9 30574 6,313.78 6,245]0 7,01.01 6200 6.2923.61961 505,648.44 4.74 4.07.92 MAD(3) 10.54534 86.71 301.56 6,315.64 6,247.64 7,98.0 64478 6,023.63&64 50,62421 452 4.07.43 MWD(3) 10,575.83 9.0 30211 6,31731 6.248.31 7,01.05 -67030 6,9365].40 50,568.0 0.9 4127.0 M'hD(3) 10,05.77 9.55 300.34 6,31&8 6.20.8 7,11035 5969 6,=,66880 50,58.10 614 4157.82 MWD(3) 10,635.8 8659 29935 6320.25 6,252.25 7,12601 -81.94 6,023.6&1.51 5054702 7.37 4,1078 Mr4D(3) 10,05.64 SBA3 29&44 ontia, 6,2.63 7,139.22 748.23 6,02369.70 505208 5.16 4,217.60 MWD(3) 10.695.43 8982 29.13 6,32237 6.254.37 7,15310 474.58 6.93,711.56 505.49435 5.32 4,247.36 MAD (3) 10,8437 86.0 287.57 6,32291 6,254.91 7168.39 60028 693,8483 50540,65 1..2 4,276.26 MND(3) 10,755.9 N.M 298.84 6,323.64 6,20.64 7,101.15 427.85 6.93,73959 505,441W 4.9 4adi also (3) 10781.0 BB.54 29951 6,324.10 6,25610 7,193.85 .850.54 6.93,752.24 505.410.37 4.0 4,333.52 MND(3) 10010.7 90.3 298.40 6,32111 6'.0.11 7,20.16 .875.89 693.70.53 505.10,02 3.08 4,%263 MND(3) 10,&5.33 92.21 Wom 6,323.31 6,25531 7,225.33 905.9 6,@3.783.0 505.303.02 5.65 4,397.9 MAD (3) 1096.0 0.90 00.98 6.321.67 6.25367 7,241.02 632.41 6,023]99.34 505,335.48 6.03 4,428,00 MM (3) 1090015 9249 W238 6.32033 6,25233 7,253.58 452.75 6,93,81188 6.5,31a 12 832 4451.90 MID (3) 10929.9 9215 059 6.31912 6,251.12 7.270.11 47754 6@3.9839 505.29133 869 448163 MD (3) 10,959.5 93.9 30.0 6,317]8 6.249]8 7,29.36 -LOAM 6023,845.61 0529.44 637 451D.92 NAND (3) 10.909.56 94.21 30.W 6,315.87 63479 7,0522 -1,95.9 62923.03.45 05.243.27 3.97 4,54070 MWD(3) 11,021.11 915 W5.W 6.314,37 6246.1 7,323.9 -101.11 693.80188 8629.71 978 45813 MWD (3) 11051.32 8&0 304.9 6,314.55 6.246.55 7,340.86 -1.075.94 6,93.899.9 50,192.30 11.55 40223 MND(3) 1108211 59.02 30349 6,315.13 6.247.13 7.35sW -1,10152 6,023.916.16 50.19.20 6.11 AlWaS MWD (3) 6202019 239.11PM Page 4 COMPASS 500014 Budd 85D ConocoPhillips 4 '�.m,.. ConocoPhillips Definitive Survey Report Company: Cono.Ph1111ps Alaska lnc_Kupamk Project: KUPamk River Unit see: Kupamk 3M Pad Well: 3M-26 Wellbore: 306-261-1 Design: 3M-261-1 survey Leal Co-ordinate Redman.: M11 3M-26 TVD Rehrence: 3M-26 @ 6800us0 (306-26) MO Reference: 3M-26 Q 68.00us8 (36426) North Refeia..: Tma Survey CalcuMtien Marded Minimum Curvature Database: EDT 14 Alaska P.d.0mn Annotation 3/1 192:29:11PM Pa0e5 COMPASS a. 14 BM7d 85D Map Map Vernal Mo ma nM TVD TVD66 .N(s ,WJ No(ftl Ea1111 DLs Section Survey Tool Name (I� PI 11 (.aft) (uslo (..ft) Ie'ry) iRl (•1100') I,o 11,11149 09 ifi 3CO E8 6,315.37 6,24].3] ]P3.60 -1126,41 6023931.]4 051 50514239 BTS 4,E<i2.30 MWO(3) 11,14217 8702 298 51 6,31&15 6,248.15 7,MIS -1,153.00 6,023,946.96 505,115.70 B.49 4.692.97 MWD(3) 11169]3 9697 2970. 6,31&94 6,248.94 7,401.73 -1,17730 Son 959,03 505091.40 4.75 4,T13.50 MWD(3) 11 R11D.71 88.74 295.90 6,31759 6,249.59 7,415.96 -1,20489 602397403 505,063.80 246 4.75104 MWD(3) 11,23101 80.59 298.40 6,31&30 6,250.30 7,430.06 -1,231.70 6.023,908.10 506037.06 497 4,78171 MND(3) 11,So.do 89.79 299.07 6,31871 6,250.71 7,444]8 -1,25742 6,02400221 506,011.33 456 4,811.05 MWD(3) 1129047 Won 230.74 6,319.08 6.251.00 7,458.74 -1.283.76 6.02401674 504984.96 3.47 4,841.15 MND(3) 11,319.58 8929 300.28 6,319.57 6.251.57 7,473.26 -1,309A4 6,024.031.24 504,85929 5.48 407063 MNO(3) 1135106 88'n 309.1 8.320.11 6,25211 7,409.10 -1,336.60 6024.047.05 504,9324 1.06 4,93200 MND(3) 11.38640 Do.. 303.43 632057 6,25257 7,507,02 4365.47 6,024,06495 506.902.23 880 4,936.. MND(3) 11415.97 9028 305.31 6,3ffi59 625259 7,52420 -0,358.]0 6,024.00210 5048]].99 649 4,95652 MNDC) 11.US.41 90.06 306.65 6.320.50 625250 7.541.57 -141461 6.024.023.45 504,854.15 461 4,995.80 MND(3) 11,476.13 90.86 308.15 6,320.25 6,26225 7,56023 -1.438.93 6.02411806 504.00..74 5.53 5,@6.27 MWD(3) 11,508.09 00.83 307,53 6,3X1.33 625233 7,506.80 -0.462.59 6024,135.44 S.,806.07 7.08 5,05693 MIND (3) 11.535.25 09.97 300.12 6320.64 625206 7,59849 -1.485.2 6024,154.31 Sd.790,02 440 5,004.03 MWD (3) H.564.83 min 307.89 6.320.97 6252.97 7.61478 -1,508.99 6,024,172.58 5..759.64 4.D7 5.114.21 MWD(3) 11,594.71 09.51 306.82 6,MlA1 6,253.41 7.63&28 -1,532.32 6,024.191.05 5.,7]B.N 3,73 5,143.67 MD (3) 11,62565 0923 306.26 6,321.75 6,253]5 7.652.77 -1556.3S 6,02421052 504.74.25 169 5,174.1 MWO(3) 11,642.07 89.69 31027 6.321.91 6,253.91 766327 -1,M8.97 6,024221501 504.9a9.62 676 5,190.41 MIND (3) 1187600 8869 310.27 6,322.09 6,254.09 T,685.XI -1,584.86 6.024242.92 51a.67371 008 5,M.79 PROJECTED W To Annotation 3/1 192:29:11PM Pa0e5 COMPASS a. 14 BM7d 85D BbHri-j ER 0 PRINT DISTRIBUTION LIST G GE company COMPANY ConocoPhillips Alaska, Inc. WELL NAME 3M -26L1 FIELD Greater Kuparuk Area COUNTY North Slope Borough BHI DISTRICT Alaska AUTHORIZED BY Patrick Rider EMAIL Patrick Riderna bakerhughes.com 219016 30542 ie sign and return one copy of this transmittal form to: ocoPhillips Alaska, Inc. i Osterkamp (WNS Petroleum Technician) G Street. oraee. Alaska 99510 this data. LOG TYPE GR - RES LOG DATE February 25, 2019 TODAYS DATE April 1, 2019 Revision STATUS Final Replacement: No Details: Rev. Requested by: --- COMPANY ADDRESS (FEDEX WILL NOT DELIVER TO P.O. BOX) PERSON ATTENTION nENTION V 1 BP North Slope. EOA, PBOC, PRB-20 (Office 109) D&G WO 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 Nl. Yaskell 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 •' Ann: Resource Evaluation 550 West 7th Avenue, Suite I V Anchorage, Alaska 99501 `"' Stamp "confidential" on al 6 BP Exploration (Alaska) Inc. Petrotechnical Data Center, LR2 900 E. Benson Blvd. Anchorage, Alaska 99508 FIELD FINAL CD/DVD FINAL PRELIM(las, LOGS dlis, PDF, META, SURVEY REPORT LOGS CGM, Final Surveys) (Compass) # OF PRINTSff OF PRIN # OF COPIES 1# OF COPIES 1# OF COPIES lu 1; 1; ji 4 4 M TOTALS FOR THIS PAGE: 0 1 2 0 0 THE STATE OfALASKA 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-26LI ConocoPhillips Alaska, Inc. Permit to Drill Number: 219-016 Surface Location: 938' FNL, 1593' FEL, SEC. 25, T13N, R8E, UM Bottomhole Location: 3855' FNL, 3195' FEL, SEC. 13, T13N, R8E, 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, / �V-t— Cathy P. Foerster Commissioner DATED this %Ada y of February, 2019. STATE OF ALASKA ALJ,_ A OIL AND GAS CONSERVATION COMMI, ON PERMIT TO DRILL 20 AAC 25.005 ECEWE JAN 3 0 2019 1a. Type of Work: Drill ElLateral Q Redrill ❑ Reentry ❑ 1b. Proposed Well Class: Exploratory - Gas Stratigraphic Test ❑ Development - Oil Q Exploratory - Oil ❑ Development - Gas ❑ Service - WAG LJ Service - Disp ❑IG: Service - Wini ElSingle Zone Q Service - Supply ❑ Multiple Zone ❑ Specify if wetl is proposed 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 3M -26L1 ' 3. Address: P.O. Box 100360 Anchorage, AK 99510-0360 6. Proposed Depth: MD: 11700' TVD: 6339' 12. Field/Pool(s): Kuparuk River Pool / - Kuparuk River Oil Pool 4a. Location of Well (Governmental Section): Surface: 938' FNL, 1593' FEL, Sec 25, T13N, R8E, UM " Top of Productive Horizon: 5195' FNL, 1394' FEL, Sec 13, T13N, R8E, UM Total Depth: 3855' FNL, 3195' FEL, Sec 13, T13N, RBE, UM 7. Property Designation: ZrA.U. awwm ADL 25522 OL25923 8. DNR Approval Number: LONS 84-138 13. Approximate Spud Date: 2/13/2019 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: 9314 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 I Coupling Length MD TVD MD TVD (including stage data) 3" 2-318" 4.7# L-80 ST -L 2100' 9600' 6331' 11700' 6339' 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): 9625' 6534' NIA Effect. Depth MD (ft): Effect. Depth TVD (ft): Junk (measured): 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 F� BOP SketchDrilling Diverter Sketch Program EJ Seabed Report B Time V. Depth Plot Drilling Fluid Program B Shallow Hazard Analysis 20 AAC 25.050 requirementse 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. HerringaCOP.com Authorized Title: Staff C Engineer Contact Phone: 907-263-4321 Authorized Signature: Date: //30/ Commission Use Only Permit to Drill l Number: pN tCJ ^ O 16 API Number : 50- 0 Z-2'Z1JL — GQ -O Permit Approval Date: ZI-71 I q See cover letter for other I requirements. Conditions of approval : If box is checked, well may not be used to explore for, test, or produce coalbetletha'n�e/, gas hydrates, or gas contained in shales: Er Other.B�� j -!S t to g U d U �'J �1-cJ Samples req'd: Yes ❑ No[7 Mud log req'd: Yes ❑ No [/ f! -n v7 v�Gt.V�Jl rr/Cl�r f'!r$,f fb z�pn�rNzfifneasures: Yes [r.}' No,❑-,/ Directional svy req'd: Yes [TNo❑ Spacing exception req'd: Yes ❑ No[?/ Inclination -only svy req'd: Yes ❑ No Eur Post initial injection MIT req'd: Yes ❑ NOD' APPROVED BY Approved by: C�.► COMMISSIONER THE COMMISSION Date: 2 - Submit n Form and r Form 10-401 Rimed 5/2017 Thi peYmit is valid f IhRq`r fr t a o approval per 20 AAC 25.005(8) Attachments in Duplicate .coli b_4_8_oz1,i5ji`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: - 10-403 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 -26L1 and 3M -26L1-01 - Detailed Summary of Operations - Directional Plans for 3M-261_1 and 3M -26L1-01 - 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-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)(8))..................................................................................................................................................3 9. Abnormally Pressured Formation Information.............................................................................4 (Requirements of 20 AAC 25.005(c)(9))..................................................................................................................................................4 10. Seismic Analysis............................................................................................................................. 4 (Requirements of 20 AAC 25.005(c)(10))- .... ................................................................................................................................. ... --4 11. Seabed Condition Analysis............................................................................................................ 4 (Requirements of 20 AAC 25.005(c)(11))................................................................................................................................................4 12. Evidence of Bonding...........................................................................................................I.......... 4 (Requirements of 20 AAC 25.005(c)(12))................................................................................................................................................4 13. Proposed Drilling Program.............................................................................................................4 (Requirements of 20 AAC 25.005(c)(13))................................................................................................................................................4 Summaryof Operations...................................................................................................................................................4 LinerRunning...................................................................................................................................................................6 14. Disposal of Drilling Mud and Cuttings.......................................................................................... 6 (Requirements of 20 AAC 25.005(c)(14))................................................................................................................................................ 6 15. Directional Plans for Intentionally Deviated Wells....................................................................... 6 (Requirements of 20 AAC 25.050(b))......................................................................................................................................................6 16. Attachments....................................................................................................................................6 Attachment 1: Directional Plans for 3M-261-1 R 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: 31VI-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-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 January 30, 2019 PTD Application: 3M -26L1 & 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 16" 62.5 Welded 0' 2-3/8", 4.7#, L-80, ST -L slotted liner; 3M -26L7 9600' 11,700' 6263' 6271' aluminum billet on to 36.0 dH-40 BTC 0' 4882' 2-3/8", 4.7#, L-80, ST -L slotted liner; 3M -26L1-01 9220' 12,500' 6152' 6232' deployment sleeve on to Existing Casing/Liner Information Category OD Weight Connection Top MD Btm MD Top TVD Btm TVD Burst psi Collapse psi Conductor 16" 62.5 Welded 0' 121' 0' 121' 1640 670 Surface 9-5/8" 36.0 dH-40 BTC 0' 4882' 0' 3624' 3520 2220 Production 7" 26.0 BTC -MOD 0'9615' 0' 6526' 7240 5410 Tubin 3-1/2" 9.3 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: 31VI-261_1 & 3M-261_1-01 Pressure at the 3M-26 Window (9314' MD. 6292' ND) 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] sand to the north and west of 3M-26. The laterals will increase A -sand resource recovery and throughput. MPS 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 -26L]-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 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] sand to the north and west of 3M-26. The laterals will increase A -sand resource recovery and throughput. MPS 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 -26L]-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 PTD Application: 3M -26L1 & 310-261-1-01 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 Rig Work 1. MIRU Nabors CDR3-AC rig using 2" coil tubing. NU 7-1/16" BOPE, test. 2. 3M -26L1 Sidetrack (AI 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 (AI 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 SB14P, 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 -26L1 & 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 AAC 25.005(c)(14)) • No annular injection on this well. • All solid waste will be transported to the grind and inject facility at DS -4 Prudhoe Bay for disposal. • Incidental fluids generated from drilling operations will be injected in a Kuparuk Class II disposal well (1R-18 or 1 B disposal facilities) or Prudhoe DS -4 if a Kuparuk facility is unavailable. • All wastes and waste fluids hauled from the pad must be properly documented and manifested. • Contact Kuparuk Environmental Coordinator for questions regarding waste classification. (670-4200). 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 IWell 3M-261_1 2391' 3M-17 3M-261-1-01 1580' 3Q -06A 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 January30, 2019 ConocoPhillips ConocoPhillips Alaska Inc—Kuparuk Kuparuk River Unit Kuparuk 3M Pad 3M-26 3M-261-1 Plan: 3M-26L1_wp04 Standard Planning Report 28 January, 2019 BA UGHES a GE company ConocoPhillips 3M-26 ConocoPhillips Database: OAKEDMPI Company: ConocoPhillips Alaska lnc Kuparuk Project: Kuparuk River Unit Site: Kupamk 3M Pad Well: 3M-26 Wellbore: 3M-2611 Design: 3M-26L1_wp04 ConocoPhillips 3M-26 Planning Report Local Co-ordinate Reference: Well 3M-26 TVD Reference: Mean Sea Level MD Reference: 3M-26 @ 68.00usft (3M-26) North Reference: True Survey Calculation Method: 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 Zane 04 Using geodetic scale factor RATER f S a GE company site Kuparuk 3M Pad 3M-26 Site Position: Northing: 6,016,202.17 usft Latitude: 70° 27' 19.780 N From: Map Easting: 506,126.99ustt Longitude: 149° 56'59.998 W Position Uncertainty: 0.00 usft Slot Radius: 0.000in Grid Convergence: 0.05 ' Wall 3M-26 Well Position +NIS 0.00 usft Northing: 6,016,559.83 usft Latitude: 70° 27'23.296 N +EI -W 0.00 usft Easting: 506,274.89 usft Longitude: 149° 56'55.644 W Position Uncertainty 0.00 usft Wellhead Elevation: usft Ground Level: 0.00 usft Wellbore 3M-261.1 Magnetics Model Name BGGM2018 Design Audit Notes: Version: Vertical Section: 3M-26L1_wp04 Sample Date 4/1/2019 Phase: Depth From (TVD) (usft) 0.00 Declination f°l 16.63 PLAN .NJ -S (usft) 0.00 Dip Angle 1°I 80.93 Te On Depth: +E/ -W (usft) 0,00 Field Strength (ri 57,424 9,311.00 Direction (9 300.00 1282019 2: 14 48P Page 2 COMPASS 5000.14 Build 85D ConocoPhillips ConocoPhillips Planning Report JUGHES a GEcompany Database: OAKEDMP1 Local Coordinate Reference: Well 3M-26 Company: ConocoPhillips Alaska Inc_Kuparuk 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-2611 Design: 3M-26L1_wp04 Azimuth System Plan Sections Measured TVD Below Dogleg Build Turn Depth Inclination Azimuth System .NIS +EI -W Rate Rate Rate TFO (usft) (') (') (usft) (usft) (usft) ('/t00usft) ('1100usft) ('1100usft) (_) Target 9,311.00 40.85 11.78 6,221.28 6,301.63 197.71 0.00 0.00 0.00 0.00 9,314.00 40.81 11.81 6,223.55 6,303.55 198.11 1.52 -1.32 1.16 150.08 9,335.00 45.01 11.81 6,238.93 6,317.54 201.03 20.00 20.00 0.00 0.00 9,434.98 90.00 11.81 6,276.20 6,405.65 219.46 45.00 45.00 0.00 0.00 9,535.00 97.05 327.24 6,269.72 6,501.31 201.92 45.00 7.05 -44.56 280.00 9,700.00 93.00 316.38 6,255.22 6,630.24 100.43 7.00 -2.46 -6.58 250.00 9,800.00 92.98 309.37 6,250.00 6,698.14 27.29 7.00 -0.02 -7.01 270.00 9,900.00 90.01 303.03 6,247.39 6,757.14 -53.33 7.00 -2.97 -6.34 245.00 10,000.00 90.01 296.03 6,247.38 6,806.40 -140.29 7.00 0.00 -7.00 270.00 10,100.00 91.22 289.13 6,246.30 6,844.77 -232.56 7.00 1.21 -6.89 280.00 10,200.00 93.60 295.72 6,242.09 6,882.86 -324.85 7.00 2.38 6.59 70.00 10,300.00 92.36 288.82 6,236.88 6,920.68 -417.21 7.00 -1.24 -6.90 260.00 10,400.00 89.96 295.40 6,234.85 6,958.29 -509.78 7.00 -2.40 6.58 110.00 10,600.00 88.75 309.35 6,237.12 7,065.11 -678.27 7.00 -0.60 6.97 95.00 10,700.00 88.76 302.35 6,239.29 7,123.62 -759.25 7.00 0.01 -7.00 270.00 10,900.00 87.59 316.30 6,245.69 7,249.98 -913.51 7.00 -0.59 6.98 95.00 11,200.00 87.75 295.29 6,258.03 7,424.32 -1,155.27 7.00 0.05 -7.01 270.00 11,300.00 87.77 302.29 6,261.94 7,472.41 -1,242.79 7.00 0.02 7.01 90.00 11,500.00 89.04 288.35 6,267.54 7,557.69 -1,423.06 7.00 0.64 -6.97 275.00 11,700.00 89.07 302.35 6,270.86 7,643.08 -1,603.33 7.00 0.01 7.00 90.00 1/28/2019 2.14:48PM Page 3 COMPASS 5000.14 Build 850 ConocoPhillips BAR ConocoPhillips Planning Report UGHES aGEcompany Database: OAKEDMPI Local Co-ordinate Reference: Well 3M-26 Company: ConocoPhillips Alaska Inc_Kupamk TVD Reference: Mean Sea Level Project: Kuparuk River Unit MD Reference: 3M-26 @ 68.00usft (3M-26) Site: Kuparuk 3M Pad North Reference: Tme Well: 3M-26 Survey Calculation Method: Minimum Curvature Wellbore: 3M-281-1 Design: 3M -26L7 wp04 Planned Survey Measured TVD Below Vertical Dogleg Toolface Map Map Depth Inclination Azimuth System +N/3 +E/ -W Section Rate Azimuth Northing Easting (usft) C) 11 (usft) (usft) (usft) (usft) (°I100usft) (1) (usft) (usft) 9,311.00 40.85 11.78 6,221.28 6,301.63 197.71 2,979.60 0.00 0.00 6,022,860.99 506,467.27 TIP 9,314.00 40.81 11.81 6,223.55 6,303.55 198.11 2,980.21 1.52 150.08 6,022,862.91 506,467.67 KOP 9,335.00 45.01 11.81 6,238.93 6,317.54 201.03 2,984.67 20.00 0.00 6,022,876.91 506,470.58 Start 20 DLS 9,400.00 74.26 11.81 6,271.43 6,371.84 212.39 3,001.99 45.00 0.00 6,022,931.21 506,481.89 9,434.98 90.00 11.81 6,276.20 6,405.65 219.46 3,012.77 45.00 0.00 6,022,965.02 506,488.93 End 20 DLS, Start 45 DLS 9,500.00 94.87 342.92 6,273.38 6,469.84 216.53 3,047.40 45.00 -80.00 6,023,029.20 506,485.95 9,535.00 97.05 327.24 6,269.72 6,501.31 201.92 3,075.79 45.00 -81.25 6,023,060.66 506,471.32 End 45 DLS, Start 7 DLS 9,600.00 95.48 322.94 6,262.63 6,554.28 164.95 3,134.29 7.00 -110.00 6,023,113.59 506,434.31 9,700.00 93.00 316.38 6,255.22 6,630.24 100.43 3,228.14 7.00 -110.47 6,023,189.49 506,369.73 6 9,800.00 92.98 309.37 6,250.00 6,698.14 27.29 3,325.43 7.00 -90.00 6,023,257.33 506,296.54 7 9,900.00 90.01 303.03 6,247.39 6,757.14 -53.33 3,424.75 7.00 -115.00 6,023,316.25 506,215.88 8 10,000.00 90.01 296.03 6,247.38 6,806.40 -140.29 3,524.69 7.00 -90.00 6,023,365.43 506,128.89 9 10,100.00 91.22 289.13 6,246.30 6,844.77 -232.56 3,623.78 7.00 -80.00 6,023,403.72 506,036.59 10 10,200.00 93.60 295.72 6,242.09 6,882.86 -324.85 3,722.76 7.00 70.00 6,023,441.73 505,944.27 11 10,300.00 92.36 288.82 6,236.88 6,920.68 -417.21 3,821.66 7.00 -100.00 6,023,479.47 505,851.89 12 10,400.00 89.96 295.40 6,234.85 6,958.29 -509.78 3,920.63 7.00 110.00 6,023,517.00 505,759.30 13 10,500.00 89.35 302.37 6,235.46 7,006.57 -597.28 4,020.55 7.00 95.00 6,023,565.19 505,671.77 10,600.00 88.75 309.35 6,237.12 7,065.11 -678.27 4,119.95 7.00 94.96 6,023,623.66 505,590.74 14 10,700.00 88.76 302.35 6,239.29 7,123.62 -759.25 4,219.34 7.00 -90.00 6,023,682.09 505,509.71 16 10,800.00 88.16 309.32 6,241.98 7,182.11 -840.25 4,318.73 7.00 95.00 6,023,740.51 505,428.68 10,900.00 87.59 316.30 6,245.69 7,249.98 -913.51 4,416.11 7.00 94.81 6,023,808.31 505,355.37 16 11,000.00 87.61 309.30 6,249.88 7,317.82 -986.77 4,513.48 7.00 -90.00 6,023,876.09 505,282.06 11,100.00 87.66 302.29 6,254.02 7,376.22 -1,067.76 4,612.82 7.00 -89.71 6,023,934.42 505,201.03 11,200.00 87.75 295.29 6,258.03 7,424.32 -1,155.27 4,712.65 7.00 -89.42 6,023,982.43 505,113.48 17 11,300.00 87.77 302.29 6,261.94 7,472.41 -1,242.79 4,812.49 7.00 90.00 6,024,030.44 505,025.93 18 11,400.00 88.39 295.32 6,265.30 7,520.54 -1,330.31 4,912.35 7.00 -85.00 6,024,078.49 504,938.38 11,500.00 89.04 288.35 6,267.54 7,557.69 -1,423.06 5,011.25 7.00 -84.77 6,024,115.58 504,845.61 19 11,600.00 89.05 295.35 6,269.21 7,594.87 -1,515.81 5,110.16 7.00 90.00 6,024,152.66 504,752.84 11,700.00 89.07 302.35 6,270.86 7,643.08 -1,603.33 5,210.07 7.00 89.88 6,024,200.80 504,665.28 Planned TD at 11700.00 1128/2019 2,14'48PM Page 4 COMPASS 5000 14 Build 85D ConocoPhillips ConocoPhillips Planning Report BAF�UGHES aGErompany Database: 0AKEDMPI Company: ConocoPhillips Alaska Inc Kuparuk Project: Kuparuk River Unit Site: Kupamk 3M Pad Well: 3M-26 Wellbore: 3M-2611 Design: 3M-261-1_Wp04 Casing Points Plan Annotations Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Well 3M-26 Mean Sea Level 3M-26 a 68.00usft (3M-26) True Minimum Curvature Measured Vertical Casing Hole Depth Depth Diameter Diameter (usft) (usft) Name (in) (in) 11,700.00 6270.86 23/8' 2.375 3.000 Measured Vertical Depth Depth (usft) (usft) 9,311.00 6,221.28 9,314.00 6,223.55 9,335.00 6,238.93 9,434.98 6,276.20 9,535.00 6,269.72 9,700.00 6,255.22 9,800.00 6,250.00 9,900.00 6,247.39 10,000.00 6,247.38 10,100.00 6,246.30 10,200.00 6,242.09 10,300.00 6,236.88 10,400.00 6,234.85 10,600.00 6,237.12 10,700.00 6,239.29 10,900.00 6,245.69 11,200.00 6,258.03 11,300.00 6,261.94 11,500.00 6,267.54 11,700.00 6,270.86 Local Coordinates -NI-S -E/-W (usft) lusft) 6,301.63 197.71 6,303.55 198.11 6,317.54 201.03 6,405.65 219.46 6,501.31 201.92 6,630.24 100.43 6,698.14 27.29 6,757.14 -53.33 6,806.40 -140.29 6,844.77 -232.56 6,882.86 -324.85 6,920.68 -417.21 6,958.29 -509.78 7,065.11 -678.27 7,123.62 -759.25 7,249.98 -913.51 7,424.32 -1,155.27 7,472.41 -1,242.79 7,557.69 -1,423.06 7,643.08 -1,603.33 Comment TIP KOP Start 20 OLS End 20 DLS, Start 45 DLS End 45 DLS, Start 7 DLS 6 7 8 9 10 11 12 13 14 15 16 17 18 19 Planned TD at 11700.00 128/2019 2 14: 48PM Page 5 COMPASS 5000.14 Build 85D ConocoPhillips BAT ConocoPhillips Andoollision Report IGHES a GE compary Company: ConocoPhillips Alaska Inc—Kuparuk Project: Kupamk 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 -26L1 Reference Design: 3M-26L1_wp04 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 OAKEDMPI Offset Datum Reference 3M-26L1_wp04 Filter type: NO GLOBAL FILTER: Using user defined selection 8 filtenng criteria Reference Offset Distance Interpolation Method: MD Interval 25.00usft Error Model: ISCWSA Depth Range: 9,311.00 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 Warning Levels Evaluated at: 2.79 Sigma Casing Method: Added to Error Values Survey Tool Program Date 1/28/2019 From To (uaft) (usft) Survey (Wellbore) Tool Name Description 71.01 9,311.00 3M-26 (3M-26) GCT -MS Schlumberger GCT multishot 9,311.00 11,700.00 3M-261-1_wp04(310-2611) MWD MWD -Standard Summary Reference Offset Distance Measured Measured Between Between Site Name Depth Depth Centres Ellipses Offset Well - Wellbore - Design (usft) (usft) (usftl (usft) Kuparuk 3M Pad 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-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-23AL1-3M-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-23AL3PB7-3M-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-23APB1-3M-23APB7 3M-23 - 3M-23APB1 - 3M-23AP81 3M-23 - 3M-23APB1 - 3M-23APB1 3M-23 - 3M-23APB2 - 3M-23APB2 3M-23 - 3M-23APB2 - 3M-23APB2 3M-23 - 3M-23APB2 - 3M-23APB2 separation factor, ES - min ellipse Separation Warning 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 Out of range Out of range Out of range Out of range Out of range 11282019 2:34:59PM Page 2 COMPASS 5000.14 Build 85D ConocoPhillips BAER ConocoPhillips Anticollision Report UGHES a GEcompany Company: ConocoPhillips Alaska Inc Kuparuk Project: Kupawk River Unit -2 Reference Site: Kupawk 3M Pad Site Error: 0.00 usft Reference Well: 3M-26 Well Error: 0.00 usft Reference Wellbore 3M-261-7 Reference Design: 3M-26L1_wpO4 Summary Site Name Offset Well - Wellbore - Design Kuparuk 3M Pad 3M-24 - 3M-2411 - 3M-2411 3M-24 - 3M -24L1-01 - 3M-2411-01 3M-24 - 3M -24L1-01 PBI - 3101-241-7-01 P131 3M-24 - 3M -24L1-02 - 3M-241-1-02 3M-24 - 3M-2411-03 - 3M-241-7-03 3M-24 - 3M -24L7 Pet - 310-241-7 PB1 3M -24-3M-2411 P132 -3M-241-1 P02 3M-24-3W24L1 PB3-3M-2411 PB3 31VI-25 - 3M-25 - 3M-25 3M-25 - 3M-25 - 3M-25 3M -25A- 3M -25A - 3M -25A 3M-26 - 3M-26 - 3M-26 3M-26 - 3M-2611-01 - 3M-26L1-01_wp03 3M-27 - 3M-27 - 3M-27 3M -27 -3M -27A -3M -27A 3M-27-3M-27AL1-3M-27A1-1 3M-27 - 3M-27AL2 - 3M-27AL2 3M-27 - 3M-27AL2-01 - 3M-27AL2-01 3M-27 - 3M-27AL2PB1 - 3M-27AL2PB1 3114-27-3M-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) 310-26 @ 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 (usft) (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 9,324.99 9,325.00 0.24 -0.75 0.245 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 Out of range Offset Design Kuparuk 3M Pad -3M-26-3M-26-3M-26 offsetsne Emor. 090 usft Survey Program: 71 -OCT -Ms Reference Onset semi Major Avis Distance ORan Well Emr: 0.00 us8 Neasured Verical Measured vertical Reference Wee, Aa4mah Offset Wellbore Caere Samseen Between Minimum Separation Depth Depen Depth Depth from NOM H (Elft Cemres Ellipses Se n Mming Factor iusRl ((em) /usRl lusRl lush) (.ft) 111 (..to st4 (usn) Ipsnl lusRl PAD) 9.324.99 6,299.72 9,325.00 6299.89 Goo 0.19 46980 6,310,57 199.58 0.24 -0.75 099 0,245 STOP Drilling, CC, ES. SF 8.349.61 6,316.64 9,350.00 6,318.81 aot 0.54 -180.87 6,326A4 20293 2.90 0.33 2.57 L 130 Take Immediate Aden 9,372.40 8,329.13 9,37500 6,338.09 0.01 0.89 -160.54 6,342.13 206.24 10.16 5.91 4.25 2.390 Camlan Monitor Ck.* 9,392.20 6337.08 9,400.00 6,357.48 0.02 1.22 -160.63 6.357.56 209.57 21.60 15.99 562 3.847 9,411.00 6,341.95 9,424.92 6376.95 0.03 1.56 -168.81 6.372.73 212.97 3693 30.02 6.31 5.761 9,42228 6,343.55 9,450.00 6.396.61 0.04 1.90 -168.89 6,387.92 218.44 53.32 45.89 7.43 7.176 9,430.00 6,344.20 9,475.00 6,416.20 0.06 2.24 -169.39 6.403.06 219.89 72.09 64.21 7.87 9.156 9,446.47 6.344.11 9,500.00 6,435]9 0.07 2.58 -174.46 8610.20 223.35 91.71 83.42 8.29 11.058 9,461.00 6,343]4 9,525.00 6,455.38 0.09 2.92 1,4.91 6.433.34 220.80 11135 103.26 8.50 13.154 9,471.00 6,343.32 9,550.00 8,474.98 0.11 3.26 171.90 6,448.48 230.25 132.11 123.37 8.74 15,113 9,461.62 0,342.74 9.575.00 6.494.57 0.12 3.60 165.59 6,463.62 233.71 152.84 143.92 8.92 17.137 9,491.16 8,342.08 9,600.00 6.514.16 0.13 3.93 159.86 6470.78 237.16 173.92 164.06 9.06 19.198 9,499.68 6,341,41 9,625.00 8,533]5 0.14 4.27 154.22 6.493.90 240.61 195.36 186.19 9.17 21.315 CC - Min centre to Center distance or covergent point, SF - min separation factor, ES - min ellipse separation 128/2019 2:34:59PM Page 3 COMPASS 500014 Build 851) 1-7 lJt5U 3 al HIP U, 1a O (u!/Flsn OSZ) (+)4]loN/1941noS O� �@ O)� O � a _ o N O C C N N A - - O o i Cd09 9 O�NMd'N a0m' W QF-YWQW mIU-- - e -- d - - VJ ymNml�l��@I�ml`I�mmOIM �tOONO =i VJ O)0 -@NN mN @Cf7 Ne�0Of Of (pNN �'OO 2500 �I�mm�1�NNNNNNNN��l�«� NNN�O+I M aNJMMMt�CJM�rn+I@«OQhh CD Z & o m o 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 ---- j(O 0 0 0 0 0 0 0 0 0 0 0 0 0 0R 0 0 0 0 0 LL00000. 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CepIM1 (.KB) End GM Last Mctl By Last Tag: RKS 9,383.0 41912018 mmbaej Last Rev Reason AnndMbn End OabLast Mad By Rev Reason: Tag el 26' Pothole 4110/2018 mri XANGER. ]6.3 Casing Strings casing Ocsc,l ption OD tint IDlin) Top IXNB) sal Depin INN6) 3el 0ep,n 1NDI... WIILen 11... Grade Top Thmd CONDUCTOR i6 t5 W2 430 12t0 121.0 62.50 H 40 WELDED Casln9 Glscnptbn Up Did lalin) TOP IXKB) SN DIpM IM1NB) Stt Oegn INDI... WULen U... G,atle Top Tnrmd SURFACE 9Z ti 921 41.1 4.082.2 3,623fi 36.00 Y55 BTC Casing Descnptbn GD (Ia ID'"" Top IXIIBI S&DryMIM1NB) SN—M"tTV01... WtlLIn IL.. Grade Top11 "d PRODUCTION i 6.2]6 38] 9,616] 6,525.6 26 US L -6U BTC -MOD Tubing Strings Tubbg Cexnplion snio9 Mz_.IDII^I Tnp NND ser Oepin N.. Net Dep0lrvDI L..Wt l mnU Gede Top Connection TUBING 3112 2992 386 923]2 6.2333 9.30 J-55 EUEBrtlMOD Completion Details Top TV-) TOPma shonne Top(XKeI (INE) 1°I uem Des Co. 10 (in) I 36.0 36.8 0.26 HANGER FMC GEN N HANGER 3.500 2,021.2 1,9030 3].25 NIPPLE CALICO W-1 LANDING NIPPLE W/ SELECTIVE PROFILE 2.812 CONDUCTOR, 430-12r0 9,2026 6,207.0 40.37 LOCATOR BAKER GBH -42 LOCATOR SEAL ASSEMBLY 3.000 9,205.3 6,209.1 40.39 PACKER BAKER F&1 PERM PACKER 4.000 9,208fi 6.1116 40.41 SBE BAKER 801 REAL BORE EXTENSION 4.000 9,226.7 6.2253 40.49 NIPPLE CALICO D NIPPLE NO GO 2.750 NIPPLE x021 2 %23F 3 6,232 7 40.52 SOS BAKER SHEAR OUT SUB 2.992 Other In Hole (Wireline retrievable plugs, valpea, pumps, fish, etc.) Top U-va Top Incl Top INKE) INNED DesCo. I Dale In UN 9,4500 63966 3640 FISH 3X6(18X(1BSLIPLostfrorn AV6LIP,wasr ver 426/1994 I round: could be In hole Perforations & Slots snot Dens Top fbing atm I Isnotem Tap IXNB) Ban mn) IXKBI (11KBI 2bne Dale ) Type Com 9,324.1) 9,350.0 6,299.1 6,325.0 A-1,,Sdi 411anig4 4011ERF 412" BH Csg Gun, 180 deg. I phasing SURFACE, 41InI8822— Mandrel Inserts st at NTop(TVD) Top high 1nKB) I M.N. I Model GD6n) 5!w Valve Type blcM1 Type RI Iln) TRO Bun fled) Run Cale Lom GAuUFTefS.J 1 9.1533 61693 tAMCO MMM 112 GAS LIFT DMV RK On00 00 6/3/1994 Notes: aterreral 8 Safety 6210 Date Annmzlmn ]1282011) NOTE: Visw Schematic w/Alaska Schematic9.0 PADINSe.ID53 SBE:9,2W.8 NIPPMIluci 7 SOS:9,2M.J IPERF:a,sP..bSSO FISH', 9490.0 PRODUCPON:398a.eta7 3M-26 Proposed CTD Schematic 62# H-40 a @ 121' 9-5/8" 36# J-55 shoe @ 4882' MD 9314' MD via parts 9358' MD 7" 26# L-80 shoe @ 9614' MD I 3-1/2" 9.3# J-55 EDE 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 (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 310-2611-01 wp03 TD @ 12,500' MD Liner top @ 9220' MD 3M -26L1 wp04 TD @ 11,700' MD Liner top @ 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 J; 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 3M -26L1 and 3M -26L1-01 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: Boyer, David L (DOA) Cc: Lona. William R Subject: RE: [EXTERNAL]PTD"s for KRU 311-261-3 & Ll -01 Wells Date: Tuesday, February 5, 2019 11:36:46 AM Attachments: imaoe001.dno 3M -26L1 wo04 MD - NAD27 bR 3M -26L1-01 wo03 MD - NAD27.txt Hi Dave, Please see attached. Thanks, Keith Herring CTD Engineer 907.263.4321 (Office) 907.570.2410 (Mobile) 700 G Street, ATO — 664 Keith.F-Ile, rina(nkonocoohillins.crnn ConocOPhillips Alaska From: Boyer, David L (DOA) <david.boyer2@alaska.gov> Sent: Tuesday, February 5, 2019 11:28 AM To: Herring, Keith E <Keith. E. Herring@conocophillips.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 1J-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 Points Source coordinate system Target coordinate system State Plane 1927 - PJaska Zone 4 AJbers Equal Area (-150) Datum: Datum: NAD 1927 - North America Datum of 1927 (Mean) NAD 1927 - North Amenca Datum of 1927 (Mean) Type values into the spreadsheet or copy and paste columns of data from a spreadsheet using the keyboard shortcuts Ctd+C to opy and Ctrl+V to paste. Then click on the appropriate arrow button to transform the points to the desired coordinate system. Finish TRANSMITTAL LETTER CHECKLIST WELL NAME: K R V_3 M — -o�,G l- I PTD: :�k 19 -0 16 development _ Service Exploratory _ Stratigraphic Test _ Non -Conventional FIELD: KL( b 0. r t f 1< R; ✓P V- POOL: h u p eL v u Lc R 1 vel— O i 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. (43—(q 3, API No. 50-6ZCt-(_- oo - Op ✓s (If last two digits Production should continue to be reported as a function of the original in API number are API number stated above. between 60-69 In accordance with 20 AAC 25.005(f), all records, data and logs acquired for the pilot hole must be clearly differentiated in both well Pilot Hole name ( PH) and API number (50- - _, from records, data and logs acquired for well name on permit . The permit is approved subject to full compliance with 20 AAC 25.055. Approval to produce/inject is contingent upon issuance of a conservation Spacing Exception order approving a spacing exception. (Company Name) Operator assumes the liability of any protest to the spacing exception that may occur. All dry ditch sample sets submitted to the AOGCC must be in no greater Dry Ditch Sample than 30' sample intervals from below the permafrost or from where samples are first caught and 10' sample intervals through target zones. Please note the following special condition of this permit: production or production testing of coal bed methane is not allowed for Non -Conventional (name of well) until after (Company Name) has designed and Well implemented a water well testing program to provide baseline data on water quality and quantity. (Company Name) must contact the AOGCC to obtain advance approval of such water well testing program. Regulation 20 AAC 25.071(a) authorizes the AOGCC to specify types of / well logs to be run. In addition to the well logging program proposed by (Company Name) in the attached application, the following well logs are also required for this well: Well Logging Requirements 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 da s after completion, suspension or abandonment of this well. Revised 2/2015 WELL PERMIT CHECKLIST Field & Pool KUPARUK RIVER, KUPARUK RIV OIL -490100 Well Name: KUPARUK RIV UNIT 31M-2611 Program DEV _ Well bore seg PTD#: 2190160 Company CONOCOPHILL-IPS ALASKA. INC. Initial Class/TVDe DEV / PEND GeoArea 890 Unit 11160 On/Off Shore On Annular Disposal Permit fee attached - . _ - _ NA. Lease number appropriate- _ - - _ . - - - - - Yes - - - - ----- - - - - - - - - - - - ............ - . Unique well -name and number - - - - - - - - - _ Yes - - - - - - - - Well located in a. defined pool- - - _ - - - - ...... Yes Well located proper distance from drilling unit.boundery.. . . . ................... Yes - - - - ........ - - - - _ - .... - ......... - - Well located proper distance. from other wells....... - - - - - - - - - - - - - - Yes - _ - - - - - - - - - .. - .......... Sufficient acreage available in drilling unit_ - - - - - - - ....... Yes - - ..... - . - ------ - - - - - - - - - - - - - - - -- - ------ If deviated, is wellbore platincluded- _ - - - - - - - - - No.. No land plat. Directional -plan view &.cross-section view included, Geologic 9 Operator only affected party-------------------------------- -------- Yes.. -.. -... ----...----------.. -. ......------------.... _ Date: 10 Operator has. appropriate bond in force - _ - Yes - - - - - - - - - - - - - - ..... . d e.)4. 11 Permit can be issued without conservation order. - - - - - Yes - - ............... Appr Date 12 Permit. can be issued without administrativeapproval- - - - - - - _ - - - - Yes DLB 2/5/2019 13 Can permit be approved before 15 -day wait - ...... Yes 14 Well located within area and strata authorized by Injection Order # (put 10# in -comments) -(For- NA 15 All wells. within 1/4mite-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 Nonconven, gas conforms to A$31,05.030G.. 1.A),0,2.A-D) ......... . . . . . . . . . . . . . NA- 18 Conductor string.provided - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - NA - - Conductor setfor.KRU 3M-26 - - - Engineering 19 Surface.casing. protects all known USDWs - - - - - - - NA Surface casing set for KRU 3M-26 20 CMT vol adequate to circulate on conductor & surf csg - _ NA. Surface casing set and fully_ cemented 21 CMT. vol adequate to tie-in long string to surf csg - - - - - - - NA.. 22 CMT. will cover all known productive horizons.- - _ .... No Productive.interval will be completed with. uncemented slotted liner 23 _ Casing designs adequate for C, T, B &. permafrost... .. - - - _ - Yes I24 Adequate tankage. or reserve pit ...... Yes - Rig has steel tanks; all waste to approved disposal wells- - - - 25 if a.re-drill, has -a 10-403 for abandonment been approved - - - - - - - - - - - - - - - - - NA - 26 Adequate wellbore separation proposed... - - - - - - - - - . Yes .. Anti -collision analysis complete; no major risk failures - - 27 If diverter required, does it meet regulations. - - - - - - - - - - - - - - - - NA - - - - - - - - - - - - - - - - - - - - - --- - Appr Date 28 Drilling fluid program schematic & equip list adequate- - - - - - - - - - - - - - - - - - - Yes - - - Max formation. pressure is -4280 psig(13.1 ppg EMW ); will drill w/ 8,6-ppg and maintain overbal w/ MPD VTL 2/7/2019 29 BOPEs, do they meet regulation - - - - - - - - . - - . Yes - - - - - - - - - - - - 30 BOPE press rating appropriate; test to (put psig in comments). ......... _ - - - Yes - MP$P is 3650 psig; will test BOPs to 4000psig 31 Choke.manifold Complies w/API RP -53 (May 84)- - .. - .. - - - _ - - - Yes - - - 32 Work will occur without operation shutdown- - - - - - - - - - - - - - _ - - ..... Yes ... ----- - - - - - - - - - - - - - - - - - - - - - - - - - 33 Is presence of HIS gas probable .......... . ......... . - - - - - Yes - - - - HIS measures required.. 34 Mechanteal-condition of wells within AOR verified (For -service well only) .............. NA .............. - 35 Permit can be issued w/o hydrogen. sulfide measures - - - - - - - - - - _ No - - _ 3M -Pad wells are H2S7bearing, HIS measures are required. Geology 36 Data. presented on potential overpressure zones - - - _ - - - - - - - _ - - _ Yes Appr Date 37 Seismic analysis. of shallow gas zones .. .. .. ................. NA. DLB 2/5/2019 38 Seabed condition survey (if off -shore) ...... . .... . . . .................. NA 39 Contact name/phone for weekly. progress reports_ [exploratory only] . - . - - - - NA- - - - - - - - Geologic Engineering Public Commissioner: Date: Commissioner: Date Commissioner Date 0rs x/711 d e.)4. z-;7-,7