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Home My WebLink About218-077DATA SUBMITTAL COMPLIANCE REPORT 1/18/2019 Permit to Drill 2150770 Well Name/No. KUPARUK RIV UNIT 1H -21A MD 9745 TVD 6587 REQUIRED INFORMATION Completion Date 9/14/2018 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 29767 Digital Data ED C 29767 Digital Data ED C 29767 Digital Data ED C 29767 Digital Data ED C 29767 Digital Data ED C 29767 Digital Data ED C 29767 Digital Data ED C 29767 Digital Data ED C 29767 Digital Data ED C 29767 Digital Data ED C 29767 Digital Data ED C 29767 Digital Data ED C 29767 Digital Data ED C 29767 Digital Data ED C 29767 Digital Data ED C 29767 Digital Data ED C 29767 Digital Data ED C 29767 Digital Data Operator CONOCOPHILLIPS ALASKA, INC. API No. 50-029-22355-01-00 Completion Status 1 -OIL Current Status 1 -OIL UIC No Samples No✓usDirectional Survey Yes Z Log Log Run Scale Media No Interval OHI Start Stop CH 7530 9745 (from Master Well Data/Logs) Received 10/8/2018 Electronic Data Set, Filename: 11-1-21A GAMMA RES.las 10/8/2018 Electronic File: 1 H -21A 21VID Final Log.cgm 10/8/2018 Electronic File: 11-1-21A 5MD Final Log.cgm 10/8/2018 Electronic File: 11-1-21A 5TVDSS Final Log.cgm 10/8/2018 Electronic File: 1H -21A 2MD Final.pdf 10/8/2018 Electronic File: 11-1-21A 5MD Final.pdf 10/8/2018 Electronic File: 11-1-21A 5TVDSS Final.pdf 10/8/2018 Electronic File: 1H -21A EOW - NAD27.pdf 10/8/2018 Electronic File: 1 H -21A EOW - NAD27.txt 10/8/2018 Electronic File: 1 H -21A Final Surveys TO 9745.csv 10/8/2018 Electronic File: 1H -21A Final Surveys TD 9745.xlsx 10/8/2018 Electronic File: 1H -21A Survey Listing.txt 10/8/2018 Electronic File: 1H -21A Surveys.bd 10/8/2018 Electronic File: 11-1- 21 A_25_tapescan_BHI CTK.bd 10/8/2018 Electronic File: 1H-21A_5_tapescan_BHI _CTK.txt 10/8/2018 Electronic File: 1H-21A_output.tap 10/8/2018 Electronic File: 1 H -21A 2MD Final Log.tif 10/8/2018 Electronic File: 1 H -21A 5MD Final Log.tif AOGCC Page I of 3 Friday, January 18, 2019 DATA SUBMITTAL COMPLIANCE REPORT 1/18/2019 Permit to Drill 2180770 Well Name/No. KUPARUK RIV UNIT 1H -21A MD 9745 TVD 6587 Completion Date 9/14/2018 ED C 29767 Digital Data Log C 29767 Log Header Scans ED C 29785 Digital Data ED C 29785 Digital Data ED C 29785 Digital Data ED C 29785 Digital Data Log C 29785 Log Header Scans Well Cores/Samples Information Name INFORMATION RECEIVED Completion Report Y Production Test Information Y / NA Geologic Markers/Tops Y COMPLIANCE HISTORY Completion Date: 9/14/2018 Release Date: Description Comments: Interval Start Stop Operator CONOCOPHILLIPS ALASKA, INC. API No. 50-029-22355-01-00 Completion Status 1 -OIL Current Status 1-0I1- UIC No 10/8/2018 Electronic File: 1 H -21A 5TVDSS Final Log.tif 0 0 2180770 KUPARUK RIV UNIT 1H -21A LOG HEADERS 10/12/2018 Electronic File: 1 H -21A EOW - NAD27.pdf 10/12/2018 Electronic File: 11-1-21A EOW - NAD27.txt 10/12/2018 Electronic File: 11-1-21A EOW - NAD83.pdf 10/12/2018 Electronic File: 1 H -21A EOW - NAD83.txt 0 0 2180770 KUPARUK RIV UNIT 1H -21A LOG HEADERS Directional / Inclination Data Y Mechanical Integrity Test Information Y / NA Daily Operations Summary Y Date Comments Sample Set Sent Received Number Comments Mud Logs, Image Files, Digital Data Y / NA Core Chips Y / NA Composite Logs, Image, Data Files Y Core Photographs Y / NA Cuttings Samples Y / NA Laboratory Analyses Y / NA AOGCC Page 2 of 3 Friday, January 18, 2019 DATA SUBMITTAL COMPLIANCE REPORT 1/18/2019 Permit to Drill 2180770 Well Name/No. KUPARUK RIV UNIT 1H -21A Operator CONOCOPHILLIPS ALASKA, INC. API No. 50-029-22355-01-00 MD 9745 TVD 658 C mpletion ate 4/2018 Completion Status 1 -OIL Current Status 1 -OIL UIC No Compliance Reviewed By: Date: 1116119 AOGCC Page 3 of 3 Friday, January 18, 2019 To: ICHES a 49 GE company: 71 80 77 29785 Letter of Transmittal Date: ----- - - --------- October 11, 2018 Meredith Guhl AOGCC 333 West 711 Ave, Suite 100 Anchorage, Alaska 99501 From: Michael Soper/ Yosha Ragbirsingh Baker Hughes, a GE Company 795 East 94" Avenue Anchorage, Alaska 99515 Please find enclosed the directional survey data for the following well(s): KUPARUK RIVER UNIT GREATER MOOSES TOOTH UNIT 3H -31A MT6 03PH 3H-31AL1 MT6-03 O 1H -21A iH 21AL1 MT6 05P61 G ve G��` vt MT6-05PB2 f' 11 IH-21AL2 1H-21AL2-01 MT6-05G MT6-05L1 PIOGG MT6-08PB1 MT6-O8 (14) 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. Michael Soper, Baker Hughes, Project Engineer Michael.Soper@BHGE.com Yosha Ragbirsingh, Baker Hughes, Survey Manager Yosha.Ragbirsingh@BHGE.com ConocoPhillips ConocoPhillips (Alaska) Inc. Kuparuk River Unit Kuparuk 1H Pad IH -21A 50-029-22355-01 Baker Hughes INTEQ Definitive Survey Report 02 October, 2018 BA ER F UGHES a GE company 21 8077 29785 Project ConocoPhillips ConocoPhillips Definitive Survey Report Company: ConocoPhillips (Alaska) Inc. Local Co-ordinate Reference: Project: Kuparuk River Unit TVD Reference: Site: Kuparuk 1 H Pad MD Reference: Well: 1 H-21 North Reference: Wellbore: 1 H-21 Survey Calculation Method: Design: 1H-21 Database: Project Kuparuk River Unit, North Slope Alaska, United Slates Phase: ACTUAL Map System: US Stale Plane 1927 (Exact solution) System Datum: Geo Datum: NAD 1927 (NADCON CONUS) Map Zone: Alaska Zone 04 +E/ -W Well 1H-21 Well Position +N/ -S 0.00 usft Northing: (usft) +E/ -W 0.00 usft Easting: Position Uncertainty 0.00 usft Wellhead Elevation: Wellbore 1H -21A 0.00 Magnetics Model Name Sample Data Date BGGM2018 9/1/2018 Design 1H -21A From Audit Notes: Well 1 H-21 1H-21 @ 96.00usft (1H-21) 1 H-21 @ 96.00usft (1 H-21) True Minimum Curvature EDT 14 Alaska Production Mean Sea Level Using Well Reference Point Using geodetic scale factor 5,980,024.57 usft Latitude: 549,555.22usft Longitude: Usti Ground Level: Declination Dip Angle (I (°I 17.01 80.91 DA ER UGHES 70" 21' 22.356 N 149° 35' 51.196 W 54.40 usft Field Strength (nn 57,446 Version: 1.0 Phase: ACTUAL Tie On Depth: 7,807.30 Vertical Section: Depth From (TVD) +N/ -S +E/ -W Direction (usft) (usft) (usft) C) 41.60 0.00 0.00 0.00 Survey Program Date From To Survey Survey (usft) (usft) Survey (Wellbore) Tool Name Description Start Date End Date 102.20 7,807.30 1H-21 Srvy 1 - SLB_GCT-MS (11-1-21) GCT -MS Schlumberger GCT mullishot 4/28/1993 4/28/1993 7,826.00 7,876.23 1H -21A MWD -INC (IH -21A) MWD-INC_ONLY MWD-INC_ONLY_FILLER 8/19/2018 8119/2018 7,907.21 9,698.99 1H -21A MWD (1 H-21 A) MWD MWD -Standard 8/19/2018 8/21/2018 10/22018 2:54: 13PM Page 2 COMPASS 5000.14 Build 85D Survey ConocoPhillips COtIOCOPhIllIpS Definitive Survey Report -- � Company: ConocoPhillips (Alaska) Inc. Local Co-ordinate Reference: Well 1H-21 Project: Kupamk River Unit TVD Reference: 1H-21 @ 96.00usft (1 H-21) Site: Kuparuk 1 H Pad MD Reference: 1H-21 @ 96.00usR (1 H-21) Well: 1H-21 North Reference: True Wellborn: 1H-21 Survey Calculation Method: Minimum Curvature Design: 1H-21 Database: EDT 14 Alaska Production Survey DA ER 1�WHES Annotation - TIP KOP Interpolated Azimuth Interpolated Azimuth 10/22018 2.54: 13PM Page 3 COMPASS 5000.14 Build 85D Map Map Vertical MD Inc Azi TVD TVD55 +N/ -S +E/ -W Northing Easting DLS Section (°) (usft) (usft) (usft) (usft) (°1100') Survey Tool Name (usft) l9 (ft) (ft) (ft) 7,607.30 38.77 89.01 6,564.09 6,468.09 -11057 3,695.08 5,979,93646 553,250.59 0.82 -110.57 MWD -INC _ONLY (2) 7,826.00 3665 88.93 6,578.68 6,482.68 410.36 3,706.77 5,979,938.74 553,262.28 0.65 -110.36 MWD -NC _ONLY (2) 7,846.53 44.40 88.90 6,594.04 6,498.04 -110.10 3,720.38 5,979,939.09 553,275.88 27% -110.10 MWD -INC _ONLY (2) 7,876.23 56.53 8648 6,612.91 6,516.91 -109.57 3,743.23 5,979,93917 553,298.73 40.86 -109.57 MWD -INC _ONLY (2) 7,907.21 69.06 88.16 6,627.05 6,531.05 -108.76 3,770.72 5,979,94077 553,326.21 4645 -108.76 MWD (3) 7,935.71 81.97 86.50 6,634.16 6,538.16 -107.47 3,798.22 5,979,94224 553,353.70 45.65 -107.47 MWD(3) 7,966.59 90.09 78.04 6,636.30 6,540.30 -103.32 3,828.69 5,979,946.59 553,384.14 3791 -103.32 MM (3) 7,996.18 91.84 64.16 6,635.80 6,539.80 -93.76 3,856.62 5,979,956.33 553,412.00 47.27 -93.76 MWD (3) 8,026.21 88.03 52.38 6,635.84 6,53964 -78.00 3,882.11 5,979,972.26 553,437.38 41.22 -78.00 MM (3) 8,056.15 89.29 40.53 6,636.54 6,540.54 -57.41 3,903.76 5,979,992.99 553,458.90 39.79 -57.41 MWD (3) 8,087.67 90.52 29.04 6,636.59 6,540.59 -31.57 3,921.72 5,980,018.95 553,47668 36.66 J157 MWD (3) 8,116.97 92.73 17.13 6,63576 6,539.76 4.68 3,933.18 5,980,045.91 553,487.96 41.32 4,68 MWD (3) 8,15062 92.98 5.29 6,634.07 6,538.08 28.23 3,939.70 5,980,078.86 553,494.27 35.15 28.23 MWD (3) 8,160.65 93.13 3.66 6,632.47 6,536.47 58.13 3,942.04 5,980.108]6 553,496.41 5.44 58.13 MWD (3) 8,210.83 93.90 251 6,630.62 6,539.62 88.20 3,94366 5,980,13885 553,497.83 4.58 88.20 MWD (3) 8,240.87 94.48 1.49 6,62643 6,53243 118.15 3,944.71 5,980,168.79 553,498.68 3.90 118.15 MWD(3) 8,270.95 94.70 0.24 6,626.02 6,53002 148.12 3,995.16 5,980,198.77 553,49693 4.21 148.12 MWD (3) 8,300.98 94.98 359.12 6,623.49 6,527.49 178.05 3,944.99 5,980,22869 553,498.57 3.83 178.05 MWD (3) 8,331.10 95.14 357.90 6,620.83 6,524.83 208.04 3,944.21 5,990,258.67 553,497.59 4.07 208.04 MWD (3) 8,361.02 9563 356.63 6,618.02 6,522.02 23779 3,942.79 5,980,288.41 553,495.97 4.53 237.79 MM (3) 8,390.96 96.40 355.25 6,614.89 6,518.89 267.49 3,940.68 5,980,318.10 553,49367 5.26 26749 MWD (3) 8.421.18 97.17 353.46 6,611.32 6,515.32 297.35 3,937.73 5,980,347.93 553,490.52 6.41 297.35 MWD (3) 8,451.49 97.76 35242 6,607.38 6,511.38 327.18 3,934.04 5,980,377.73 553,486.63 3.92 327.18 MWD (3) 8,483.76 96.74 350.93 6,603.30 6,507.30 358.85 3,929.40 5,980,409.37 553,461.78 5.57 358.85 MVM (3) 8,512.90 96.68 350.92 6,599.90 6,503.90 387.43 3,924.84 5,980,437.91 553,477.03 0.21 38743 MWD (3) 8,543.45 9739 352.38 6,596.16 6,500.16 417.43 3,92049 5,980,46788 553,472.43 5.28 41743 MWD (3) 8573.93 97.49 354.24 6,592.21 6,496.21 447.44 3,916.92 5,980,497.87 553,468.71 6.06 447.44 MWD (3) 8,603.22 97.49 35460 6,588.39 6,492.39 47635 3,914.09 5,98(1,526.75 553,465.69 1.22 476.35 MWD(3) 8,634.28 9724 - 356.14 6,584.41 6,488.41 507.05 3,911.61 5,980,557.43 553,463.01 4.98 507.05 MWD(3) 8,66345 0770 356.79 6,580.62 6,484.62 535.91 3,909.82 5,980,586.28 553.461.03 2,71 535.91 MWO(3) DA ER 1�WHES Annotation - TIP KOP Interpolated Azimuth Interpolated Azimuth 10/22018 2.54: 13PM Page 3 COMPASS 5000.14 Build 85D ConocoPhillips BER ConocoPhillips Definitive Survey Report UGHES Company: ConocoPhillips (Alaska) Inc, Project: Kuparuk River Unit Site: Kuparuk 1H Pad j Well: 1H-21 Wellbore: 1H-21 Design: t 1H-21 Survey Local Co-ordinate Reference: ND Reference: MD Reference: North Reference: Survey Calculation Method: Database: Well 1 H-21 1H-21 @96.00usft(1 H-21) 1H-21 @96.00usft(1 H-21) True Minimum Curvature EDT 14 Alaska Production 10/212018 2:54:13PM Page 4 Annotation COMPASS 5000.14 Build 85D Map Map VerticalDSS MD Inc Azi ND N +N/ -S +EI -W DLS (usft) (1) V) (usft) (usft) (usft) (usft) Northing Easting (1)900) Section Survey Tool Name (ft) (ft) (ft) 8,694.48 95.10 357.81 6,577.16 6.481.16 566.71 3,90837 5,98061707 553,45938 899 566.71 MWD (3) 8,72367 9461 359.12 6,574.69 6,478.69 595.79 3,907.59 5,980,646.13 553,458.41 4.78 595.79 VW) (3) 8,754.39 93.87 0.39 6,572.42 6,476.42 626.42 3,90746 5,980,676.76 553,458.07 4.77 626.42 MWD (3) 8,784.45 93.56 358.99 6,570.47 6.47447 6%.42 3,907.30 5,980,706.76 553,457.71 4.76 656.42 MWD (3) 8,813.43 93.50 359.09 6,568.69 6,472.69 685.34 3,906.81 5,900,735.67 553,457.04 0.40 685.34 MWD (3) 8,844.54 92.55 356.92 6,567.04 6,471.04 716.39 3,905.73 5,980,766.70 553,455.75 7.61 716.39 MWD (3) 8,874.13 91.78 355.95 6,565.93 6,469.93 745.90 3,903.89 5,980,796.20 553,453.71 4.18 745.90 MWD (3) 8,904.52 90.95 354.15 6,56520 6,469.20 776.16 3,90127 5,980,82645 553,450.89 6.52 776.16 MWD (3) 8,934.56 91.47 356.02 6,564.57 6,468.57 806.08 3,898.70 5,980,856.35 553,448.12 6.46 806.08 MWD (3) 8,964.56 91.07 357.66 6,563.90 6,467.90 83603 3,897.05 5,980,886.28 553,446.27 5.63 836.03 MM (3) 8,997.54 89.88 355.90 6,563.63 6,467,63 868.96 3,895.19 5,980,919.19 553,444.20 6.44 868.96 MWD (3) 9,023.72 89.11 354.04 6,563.86 6,467.86 895.03 3,892.90 5,980,94525 553,441.73 7.69 895.03 MWD (3) 9,054.28 88.34 353.57 6,564.54 6,468.54 925.41 3,889.60 5,980,975.59 553,438.24 2.95 925.41 MWD (3) 9,06431 87.17 35262 6,565.72 6,469.72 955.19 3,885.99 5,981,005.35 553,434.43 5,02 955.19 MAD (3) 9,114.31 86.58 351.04 6,567.35 6,471.35 984.84 3,881.74 5,981,034.97 553,429.98 5.61 984.84 M (3) 9,144.40 86.19 350.52 6,569.25 6,473.25 1,014.49 3,876.93 5,981,06458 553,424.97 2.16 1,014.49 MWD (3) 9,176.43 86.22 350.58 6,57137 6,475.37 1,046.01 3,871.68 5,981,096.07 553,419.52 0.21 1,046.01 MWD (3) 9,204.75 85.94 348.29 6,573.31 6,4T.31 1,073.79 3,86650 5,981,123.80 553,414.16 8.13 1,073.79 MWD (3) 9,241.01 85.82 346.72 6575.91 6,479.91 1,109.09 3,858.67 5,981,159.06 553,4%.10 4.33 1109.09 MWD (3) 9,264.79 89.20 346.33 6,576.94 6,460.94 1,132.19 3,853.14 5,981,182.12 553,4%.41 14.31 1,132.19 MWD (3) 9,291.45 89.51 346.93 6,577.24 6,461.24 1,158.13 3,846.97 5,981,208.01 553,394.08 2.53 1,158.13 MWD(3) 9,325.67 87.61 343.81 6,578.10 6,482.10 1,191.22 3,838.34 5,981,241.04 553,385.22 10.67 1,191.22 MWD (3) 9,350.32 88.71 346.21 6,578.90 6,482.90 1,215.02 3,831.96 5,981,264.79 553,378.69 10.71 1,215.02 MWD (3) 9,387.09 88.40 347,25 6,579.82 6,483.82 1,250.80 3,823.53 5,981,300.51 553,370.02 2.95 1,250.80 MWD (3) 9,414.31 86.93 347.38 6,580.93 6,484.93 1,27233 3,817.55 5,981327.00 553,363.87 542 1,277.33 1(3) 9,444.10 89.11 351.19 6,581.96 6,485.96 1,306.58 3,81262 5,981,356.21 553,358.14 14.73 1,31D6.58 MWO(3) 9,473.85 88.03 352.39 6,582.70 6,48670 1,336.01 3,807.77 5,981,385.61 553,353.70 543 1,336.01 MAD (3) 9,502.52 89.14 354.05 6,58341 6,487.41 1,364.47 3,804.39 5,981,41404 553,350.13 6.96 1,364.47 MWD (3) 9,533.11 88.13 355.97 6,584.14 6,488.14 1,39493 3,801.73 5,981,444.48 553,347.27 7.09 1,394.93 MWD (3) 9,568.90 90.15 355.86 6,584.68 6,488.68 1,430.63 3,799.18 5,981,480.16 553,344.49 5.65 1,43063 MWD (3) 9,602.89 89.66 354.81 6,58473 6.485.73 1464.50 3,79642 5,981,51401 553,341.50 341 1464.50 1(3) 10/212018 2:54:13PM Page 4 Annotation COMPASS 5000.14 Build 85D ConocoPhillips Definitive Survey Report Local Coordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Database: Well 11-1-21 1 H-21 @ 96.00usft (1 1-1-21) 1H-21 @96.00usft(1 H-21) True Minimum Curvature EDT 14 Alaska Production +N/ -S +E/ -W Map Map ConocoPhillips Vertical Company: ConocoPhillips (Alaska) Inc. Northing I Project: Kuparuk River Unit Tool Name Annotation (� Site: Kuparuk 1H Pad (ft) (ft) Well: 1H-21 1,499.42 Wellbore: 1 H-21 553,337.52 544 Design: 1H-21 1,534.58 3,788.40 Survey 553,333.02 0.70 1,534.58 MWD (3) 1,559.95 3,785.35 MD Inc A:1 TVD NDSS Waft) I P) (1) (usft) (usft) i 9,638.01 89.23 352.95 6,585.07 6,489.07 9,673.43 89.14 353.18 6,585.58 6,489.58 9,698.99 89.05 353.11 6,585.98 6,489.98 9,745.00 89.05 353.11 6,585]4 6,490.75 ConocoPhillips Definitive Survey Report Local Coordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Database: Well 11-1-21 1 H-21 @ 96.00usft (1 1-1-21) 1H-21 @96.00usft(1 H-21) True Minimum Curvature EDT 14 Alaska Production +N/ -S +E/ -W Map Map DILSV1100)Section Vertical (usft) (usft) Northing Easting Tool Name Annotation (ft) (ft) Survey 1,499.42 3,792.67 5,981,548.90 553,337.52 544 1,499.42 MWD (3) 1,534.58 3,788.40 5,981,584.02 553,333.02 0.70 1,534.58 MWD (3) 1,559.95 3,785.35 5,981,609.37 553,32980 0.45 1,559.95 MWD (3) 1,60562 3,77983 5,981,655.00 553,323.98 0.00 1,60562 PROJECTED to TO 8A (ER UG`11ES 1022018 2: 54:13PM Page 5 COMPASS 5000.14 Build 850 .Vaa k.Vs..:j'V= STATE OF ALASKA OCT 0 9 20 ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND ' U`-' ta. Well Status: Oil❑ Gas❑ SPLUG ❑ Other ❑ Abandoned ❑ Suspended❑ 20AAC 25.105 20AAC 25.110 GINJ❑ WINJ❑ WAGE] WDSPL❑ No. of Completions: 1b. Well Class: Development 0 Exploratory ❑ Service E] Stratigraphic Test El 2. Operator Name: ConocoPhillips Alaska, Inc. 6. Date Comp., Susp., or Abend.: 9/1412018 14. Permit to Drill Number/ Sundry: 218-077 3. Address: P.O. Box 100360 Anchorage, AK 99510-0360 7. Date Spudded: 8/19/2018 15. API Number: 50.029.22355-01-00 4a. Location of Well (Governmental Section): Surface: 679' FNL, 793' FEL, Sec 33, T12N, R10E, UM Top of Productive Interval: 790' FNL, 2366' FEL, Sec 34, T1 2N, RI OE, UM Total Depth: 4354' FNL, 2289' FEL, Sec 27, T12N, R10E, UM 8. Date TD Reached: 8/21/2018 16. Well Name and Number: KRU 1H -21A 9. Ref Elevations: KB:96 GL:64 BF: 17. Field / Pool(s): Kuparuk River Field/Kuparuk River Oil Pool 10. Plug Back Depth MD/TVD: 835816618 18. Property Designation: ADL 25639 ' 4b. Location of Well (State Base Plane Coordinates, NAD 27): Surface: x- 649555 y- 5980024 Zone- 4 TPI: x- 553262 y- 5979939 Zone- 4 Total Depth: x- 553324 y- 5981655 Zone- 4 11. Total Depth MD/TVD: 9745/6587 19. DNR Approval Number: LONS 80-261 12. SSSV Depth MD/TVD: 178911783 20. Thickness of Permafrost MD/TVD: 1629/1626 5. Directional or Inclination Survey: Yes ❑� (attached) No ❑ Submit electronic and printed information per 20 AAC 25.050 13. Water Depth, if Offshore: N/A (ft MSL) 21. Re-drill/Lateral Top Window MDfrVD: 7826/6579 22. Logs Obtained: List all logs run and, pursuant to AS 31.05.030 and 20 AAC 25.071, submit all electronic data and printed logs within 90 days of completion, suspension, or abandonment, whichever occurs first. Types of logs to be listed include, but are not limited to: mud log, spontaneous potential, gamma ray, caliper, resistivity, porosity, magnetic resonance, dipmeter, formation tester, temperature, cement evaluation, casing collar locator, jewelry, and perforation record. Acronyms may be used. Attach a separate page if necessary GR/Res 23. CASING, LINER AND CEMENTING RECORD WT. PER GRADE SETTING DEPTH MD SETTING DEPTH TVD AMOUNT CASING Fr. TOP BOTTOM TOP BOTTOM HOLE SIZE CEMENTING RECORD PULLED 16 62.5 H-40 41 121 41 121 24 200 sx PF C Cmt 9518 36 J-55 40 4820 40 4247 12114 930 sx PERM E, 450 sx Class G 7 26 J-55 39 8296 39 6947 8112 299 sx Class G 24. Open to production or injection? Yes 0 No ❑ If Yes, list each interval open (MD/TVD of Top and Bottom; Perforation Size and Number; Date Perfd): INFLATABLE BRIDGE PLUG @ 8358'16618' NO LINER RUN GOINPLETION 11"TWas Wellbore open in other lateral completions. 411916 See 218-078 and 218-080 Completion Reports VERIFIED 25. TUBING RECORD SIZE DEPTH SET (MD) PACKER SET (MD/TVD) 31/2 7693 7664/6453 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. hydraulic fracturing used during completion? Yes ❑ No ❑� Per 20 AAC 25.283 (i)(2) attach electronic and printed information DEPTH INTERVAL (MD) 1AMOUNT AND KIND OF MATERIAL USED 27. PRODUCTION TEST Date First Production: WAITING FOR HOOKUP Method of Operation (Flowing, gas lift, etc.): Date of Test: Hours Tested: Production for Test Period Oil -Bbl: Gas -MCF: Water -Bbl: Choke Size: Gas -Oil Ratio: Flow Tubing P Casinq Press: I Calculated 24 -Hour Rate Oil -Bbl: Gas -MCF: Water -Bbl: Oil Gravity - API (corr): Form 10407 Revised 5/2017 117`1- !//B �`� ONTINUED ON PAGE 2 RB��S OCTO 9 ?018 Submit ORIGINAL only �.�,B.i�lttlrs /l� N� G 28. CORE DATA Conventional Core(s): Yes ❑ No ❑� Sidewall Cores: Yes ❑ No ❑Q If Yes, list formations and intervals cored (MD/TVD, From/To), and summarize lithology and presence of oil, gas or water (submit separate pages with this form, if needed). Submit detailed descriptions, core chips, photographs, and all subsequent laboratory analytical results per 20 AAC 25.071. 29. GEOLOGIC MARKERS (List all formations and markers encountered): 30. FORMATION TESTS NAME MD TVD Well tested? Yes ❑ No ❑Q If yes, list intervals and formations tested, briefly summarizing test results. Permafrost - Top Surface Surface Permafrost - Base 1629 1626 Attach separate pages to this form, if needed, and submit detailed test Top of Productive Interval 7826 6578 information, including reports, per 20 AAC 25.071. Formation @ TPI -Kuparuk C4 TD 9745 6586 Formation at total depth: Ku aruk C 31. List of Attachments: Daily Operations Summary, Definitive Survey, Schematics Information to be attached includes, but is not limited to: summary of daily operations, wellbore schematic, directional or inclination survey, core analysis, results.oaleontolooical reoort. production or well test 32. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Authorized Name: James Ohlin er Contact Name: William R. Lon Authorized Title: Staff CTD Engineer Contact Email: William.R.Lonoitloo .com Authorized Contact Phone: 263-4372 Signature: Date: O 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 10407 well completion report and 10404 well sundry report when the downhole well design is changed. All laboratory analytical reports regarding samples or tests from a well must be submitted to the AOGCC, no matter when the analyses are conducted. Item 1a: 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 KUP PROD Well Attribut ConocoPhillips FIeM Name — AlaSka.InC. KUPARUK RIVER UNIT 1H -21A 1X-31A,IWVtl1910:10:18AM Last Tag VeNula<Mrmec (cemll Miam on Last Tag: SI -1A EnE nate pepin lMlB) 6/28/2018 8,062.0 Last Mas By hmaj ........................................................... Last Rev Reason WSIFER: 3].8 lan EnE naM L861 Moe By Rev Reesonanstlletl Liner Rev Reason e Top Packer 9n&2018 zembaej Other In Hole Wireline retrievable plugs, valves, pumps, fish, etc.) Top(rvo) Top teal Top main )nne) (y Dea Co. Run Dare mua) COxOVCfOR:4i o-izfo 7,6]00 6,4574 3901 NaNam Noglem Solulion5 finer Top Packer W/1781 R -Nipple 9I18I2018 1.]81 Solhapns Liner Tap Packer SAFETY WVT 1 .3 7315.0 6,622.3 9505 Opeallone Bare feet lateral WN2018 1.992 Andaretl 8356.0 7618.3 95.58 InBatabl 'plug Isolate AbantlantleE A let MWO18 0800 GAa LFT: 2,5ms ws LFT; assre SVRFPCE: a03d Bi0.a� GAS LFT, 510,1 GPS LIFT: 5,9f19 WS LIR: a7W8 GAS LIFT: ].182.] G43 LIR: 1.a122 PBR: Topp camera sauanr, ?.M,9 east P Mli:].033.9 W nearer,BNO PLUG, 7.60, CML SOTies _IH,O)i0 RIPPLE: 7,680.9 SOS', 7.2.0 (PERF:7..M.a],asa- PROOVCTION:Y.9d,ffi3 8301 omL 7.ems 610,00.0 AL1 L'ner, ],WJ1-I I.M0 (Amn Xab MCIIaM', L315 0 3150 InTuhWeu9...00 Agnes. KIIP PROD 1H-21 /�/�✓ ' iw!' Well Attributes Max Angle 6' TO +us 1-541 MD 5 Ac[BM (XHBf ConoeoPhllhps FleIE Name WellWrepPUUWI PROD NaskB. Inc KUPARUK RIVER U+.., 500292235500 PROD 1.54 3,885.fiL 8,315.0 Cammew H35(ppm) nate pnnWanon EnE Oah KBUNBX RiO F"'Ine Dab SSSV: TROP Last 070: 3128+1993 1. 21,+as0N6 loan Nm Last Tag Vwa`alecaralaea laa+uail pnnoYXOn End Da+e CaPffiw) Last Tag: SLM 8/282018 8,082.0 Ixt Mcd BY lamaj ...................... ............. ...... ...... Last NOV Reason NA1aGFR:Tfi MnwatlOn EnJ sant Rev Reason. Installed Liner Top Packer 91182018 12at MOE BY 2emBeej Casing Strings Cazlnp Desc,lpllon OD(p ID (in) Top(I+1(B) SeI DepN 1KKBf aN OepIM1 (Nnf... WVLen CONDUCTOR 16 15.06 41.p 121.0 121.0 62.50 fl-. nn4e TW TM1read Hao WELDED C UCT0R: a1. 1210 Cea+np OxcNWon IOD(a) 109nf TOp ntltBf %f DepM (XNa) 9N OepM nY01... WtlLee B,..Gratle IT -Thread SURFACE 9518 8.92 40.2 4,820.4 4,247.1 WO 7-55 BTC SAFETYV-V.I.TMa Caaln00azc,1p11an O011n) IO gn) Tap XIKB) BM Depen 111NBf Set%qs"I'". WtlLen 0.,.Grtle TOp TarcaO PRODUCTION 7 6.28 38.9 8,296.3 6,94]0 2600 J-55 AB -MOD Tubing Strings Meme Des=rlpnon aping Ma-11u(ln, Top lnNBf se+oepm lrt.. sei B=p+1111VD1f_. w+p1JM1t TUBING 3112 299 376 7,6929 64752 9.30 J_55 TopConM- J-55 EUEBRDMOD Completion Details pAs urr:zsl0s GAs uFT: a,asae Tap mO) Topma TopM6) r.K.) (•) Its. on. eoln x-npl to in) 376 37.6 0.13 MANGER FMC GEN IV HANGER 3.500 1,]89.3 1,]83.2 1 33 BAFETYVLV CAMCOTRDP-4A-130 VALVE 2.812 7,650.1 8,4419 39.00 PBRBAKER PER w1 TR POFP A SQUARE THREAD FOR POP RETRIEVAL) 41 " 3.000 7,6639 8,452.) 3900 PACKER BAKER HB RETRIEVABLE PACKER 2.890 7,680.3 6,4654 39.01 NIPPLE CAMCO D NIPPLE NO GG (Milled out to 280"]1122018) 2.800 ],692.0 6,4]4.5 39.00 505 BAKER SHEAR OUT SUB 3015 SURPACEa02a,em.4� Other In Hole (W1 line retrievable plugs, WIVes, pumps, fish, VIC.) rop (132 TnP mal TaptnKB) to V f-) cea cam Run DNe ID9n) GAe 7,6600 6,449.fi 3900 PLUG Cement Plug ]1122018 0.000 7.826.0 6,5]87 38.66 High xpanfii0n NoMern Solutions High Expansion Wedge 811912018 0000 OFF; emla W uFT: S.@+A Wedge Perforations S Slob shw GAauFr:BTWa gene 6M(nKB) Top ("D) IIMal (TVD) (11KB) H-aadZone OW (znolsm f TYPo Com 7,6)7.0 6, 19 fip6. 711201 30 CMTSQZ 'deg phasi+g E 7,8580 6,5335 66 .7 UNI .C- 3,1H-21 WIVI 38.0 (PERF 118" nerjeL 90 deg. phasing 7,9480 6,501 6,6). -,U 1H 612811993 120 (PERF SW5S-21 phasing Squeezes TNP M.) sin MB) Top(-) OFKB) ban (TVD MKB) Des adn Dara I oin GAs LIFT, 70722 7,663.9 ILUMIJI 64526 6] einem 7114 18 Squeeze Mandrel Inserts at FOR 76501- au cerm,xatuwe; ].M9.9nKB PACIrER; IR098 seTop(1Vn1 Valve Latch PM&re ROD Run N Top MKB) Mal Meke MoaN OD (In) %ry Type Tpro IM) (PI) Run Dab CO 11 2,570.5 2.495.5 CAMCO KBUG 1 GAS LIFT GLV BKS .1 8 1,2]1.0 81112018 2 4,354.9 3,890.4 CAMCO BUG GAS LIFT OV BK5 0. 0.0 7112018 NMmsaanwm l.er4P Pacxer.zamo PLUGIP.6600 CMTBD2;T.6J54`7. 10671827 3 5,143.4 4.495) CAMCO GA9 LIFT DMY BK5 0. 00 20D) 4 6 1.9 5,0899 CAMCO GAS LIFT DMV BK5 0. 008151200] 5 6,7 99 5702.6 CAMCO GAS LIFT DMY BK5 IT 0.0 5IIN1999 60749 CAMC GAS LIFT DMY BKS 0.000 0. 511311999 ]6022 64047 CAMCO GASLIFT DMV RK 0.000 0.0 771&199 Notes: General d Safety NIMLe Tem a ELDah Annoiailon 91212010 NOTE. View Schema', wl Alaska S1hema6190 8057,m20 FERF;JTm.DT,,o AL Lier',]ega10$m0 Npn expnsMn We+y 7.B280 IpERF, 7.91B.61.948.0- PRODJCTWN.MaLeMs Operations Summary (with Timelog Depths) 1 H-21 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Stert Depth Start Time I End Time Dur(hr) phase Op CDde Ac vty Code Time P-T-XOpera'on (ItKB) End Depm(PKB) 8/17/2018 8/18/2018 12.00 MIRU MOVE MOB P Demob off 3H - Tucks on location @ 0.0 0.0 12:00 00:00 16:00. Leave 3H pad 18:30, Arrive 1 H 24:00 8/1812018 1811812018 5.00 MIRU MOVE MOB P On 1 H pad, Remove jeeps. Prep cellar 0.0 0.0 00:00 05:00 for spotting rig. Spot rig. Work rig up check list. 8/18/2018 8/18/2018 4.00 MIRU MOVE RURD P Safe out all landings and stairs, call 0.0 0.0 05:00 09:00 out scaffold for wellhead platform, call grease crew, clo stem seal on Bt 8/18/2018 8/18/2018 2.00 MIRU MOVE RURD T Operations limited due to rig issues on 0.0 0.0 09:00 11:00 same pad '*`Note: Rig Accept time 0900- 900-8/18/2018 T/1 8/201-8 8/18/2018 1.00 MIRU WHDBOP NUND P N/U BOP 0.0 0.0 11:00 12:00 8/18/2018 8/18/2018 2.00 MIRU WHDBOP BOPE P Start BOP test, low 250 psi/high 3000 0.0 0.0 12:00 14:00 psi/annular 2500 psi, test waived by Guy Cook (AOGCC) 8/18/2018 8/18/2018 1.50 MIRU WHDBOP PRTS T Problems with swab valve, call out 0.0 0.0 14:00 15:30 grease crew again 8/18/2018 8/18/2018 5.50 MIRU WHDBOP BOPE P Continue with BOP test, Fail / Pass on 0.0 0.0 15:30 21:00 C2, C1. Fail and replace R1, End of BOPE test 8/18/2018 8/18/2018 2.00 MIRU WHDBOP PRTS P Pressure test PDL's and TT line. 0.0 0.0 21:00 23:00 Install night rap and bleed off WHP. Started at 480 PSI. Blled down in steps to zero. Observe well. Dead for ten minutes pressure slowly rising. Bleed and watch. Go to pressure deployment ops for Whipstock 8/18/2018 8/19/2018 1.00 PROD1 RPEQPT PULD P PJSM, M/U BHA#1 with high 0.0 0.0 23:00 00:00 1 expansion whip stock 8/19/2018 8119/2018 1.00 PROD1 RPEQPT PULD P Continue pressure deployment BHA 0.0 73.5 00:00 01:00 - #1 NS HEW Whipstock, Make up to coil and surface test. Inspect pack offs 8/19/2018 8/19/2018 1.50 PROD1 RPEQPT TRIP P RIH BHA#1, EDC open pumping min 73.5 7,565.0 01:00 02:30 1 rate on seawater. Returns to TT 8/19/2018 8/19/2018 0.20 PROD1 RPEQPT DLOG P Log K1 marker for+2.5' 7,565.0 7,595.0 02:30 02:42 8/19/2018 8/19/2018 0.40 PROD1 RPEQPT DLOG P Trip into 7650 run CCL log down to 7,595.0 7,850.0 02:42 03:06 7850 8/19/2018 8/19/2018 0.30 PROD1 RPEQPT TRIP P PUH to whipstock setting depth @ 7,850.0 7,833.7 03:06 03:24 7833.7, TOWS @ 7825. HS Orientation. Set whipstock. See tool shift - 230OPSl. Set down 2.5K - Good 8/19/2018 8/19/2018 1.70 PROD1 RPEQPT TRIP P PUH to 7819. Open EDC Flush well @ 7,833.7 74.0 03:24 05:06 2 BPM, Start tripping out 8/1912018 8/19/2018 0.50 PROD1 RPEQPT PULD P Tag up at surface, check well for flow 74.0 74.0 05:06 05:36 (no -flow) 8/19/2018 8/19/2018 1.00 PROD1 RPEQPT PULD P LD setting tools on a dead well 74.0 0.0 05:36 06:36 8/19/2018 8/19/2018 0.30 PROD1 WHPST PULD P PJSM, PD window milling BHA#2 0.0 76.9 06:36 06:54 8/19/2018 8/1912018 0.20 PROD1 WHPST PULD P Stab INJH, surface test Coiitrak tools, 76.9 76.9 06:54 07:06 (good -test), check pac-offs (good) 8/19/2018 8/19/2018 1.40 PROD1 WHPST TRIP P Tag up, reset counters to zero, RIH 76.9 7,565.0 07:06 08:30 with window milling BHA#2 8/19/2018 8/19/2018 0.20 PROD1 WHPST DLOG P Log the K1 marker correction of plus 7,565.0 7,600.0 08:30 08:42 1 1 1 1.5' 8/19/2018 8/19/2018 0.60 PROD? WHPST DISP P Finish displacing well to milling fluid 7,600.0 7,600.0 08:42 09:18 1 Page 1130 ReportPrinted: 911912018 Operations Summary (with Timelog Depths) 1 H-21 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log SM Depth Sort Time End Tare Der(M Phase Op Code Activity Coda Time P -T -X Operation (nxa) End Deplh(0KB) 8/19/2018 1811912018 0.20 PROD1 WHPST TRIP P Continue IH, dry tag TOHEW (TOWS), 7,600.0 7,827.7 09:18 09:30 HEW 7827.3' 8119/2018 8/19/2018 0.50 PROD1 WHPST TRIP P PUW 45 k, no pumps, bring pump on- 7,828.7 7,828.7 09:30 10:00 line, RIH 1.0' past TOWS, PUH, shut down pump, RBIH to confirm dry tag HEW pinch point. 7828.7'. 8/19/2018 8/192018 2.00 PROD1 WHPST MILL P PUH, and bring pump on line get 7,828.7 7,833.2 10:00 12:00 parameters, begin milling window @ 1 fph, 1.81 bpm at 4,056 psi, BHP=3,629, WHP=419, IA=O, OA=48. - Note: Center of the mill out of casing 7,831.2- ,831.2'8/19/2018 T7 19 /2 o -iB 811912018 3.50 PROD1 WHPST MILL P Continue milling window off of 7,833.2 7,846.0 12:00 15:30 Northern Solutions HEW WS, 1.81 bpn at 4,000 psi, WHP=O, BHP=3,610, IA=O, 0A=50 •" Note: BOW @ 7,832' 8/19/2018 8/19/2018 0.10 PROD1 WHPST TRIP P TD rat hole 21' from TOWS, pull up 7,846.0 7,829.0 15:30 15:36 1 hole, PUW 45 k 8119/2018 8119/2018 0.80 PROD1 WHPST REAM P Ream window area from 7,844'-7,829' 7,829.0 7,846.0 15:36 16:24 8/19/2018 8/19/2018 0.20 PROD1 WHPST REAM P Dry drift window area 7,814'to TD 7,846.0 7,846.0 16:24 16:36 17,846- 8/19/2018 8/19/2018 1.00 PROD1 WHPST TRIP P POOH, pumping 1.81 bpm 7,846.0 83.0 16:36 17:36 8/19/2018 8/19/2018 1.40 PROD1 WHPST PULD P At surface, Flow check Lay down 83.0 0.0 17:36 19:00 window milling BHA on dead well. Mill out @ 2.79 Go. 2.80" NoGo. 8119/2018 8119/2018 0.60 PROD1 DRILL PULD P M/U BHA#3 with RB HCC Bi center, 0.0 72.2 19:00 19:36 2.3+° AKO motor, and USR, M/U to coil and surface test. - Good 8/19/2018 8/19/2018 1.60 PRODt DRILL TRIP P Trip in well, EDC open pumping min 72.2 7,565.0 19:36 21:12 rate. 8119/2018 8/1912018 0.10 PROD1 DRILL DLOG P Log Ki for for+1' 7,565.0 7,586.0 21:12 21:18 8119/2018 81192018 0.40 PROD1 DRILL TRIP P Continue in well, @ 7810 perform 1 to 7,586.0 7,846.0 21:18 21:42 1 pressure test. Pump 1.78 BPM, BHP=3633, WHP=O with open choke. ECD=10.7 PPG. Shutdown pump. Close EDC. Clean pass through window, Tag up and drill from 7846 8/19/2018 8/19/2018 1.60 PROD1 DRILL DRLG P 7846', Drill, 1.74 BPM @ 3751 PSI FS, 7,846.0 7,912.0 21:42 23:18 BHP=3648 811912018 8/192018 0.10 PROD1 DRILL WPRT P BHA wiper/ weight check, PUW=50K 7,912.0 7,912.0 23:18 23:24 8/19/2018 8/20/2018 0.60 PROD1 DRILL DRLG P 7912', Drill, 1.75 BPM @ 3788 PSI 7,912.0 7,930.0 23:24 00:00 FS, BHP=3660 8/20/2018 8/20/2018 3.80 PROD1 DRILL DRLG P 7930', Drill 1.75 BPM @ 3788 PSI FS, 7,930.0 8,054.0 00:00 03:48 BHP=3660 8/20/2018 8/20/2018 0.20 PROD1 DRILL WPRT P 8054 BHA Wiper trip, PUW=50K, 8,054.0 8,054.0 03:48 04:00 RIW=17.5K 812012018 8/20/2018 3.20 PROD1 DRILL DRLG P 8054', Drill 1.76 BPM @ 3970 PSI FS, 8,054.0 8,150.0 04:00 07:12 j j BHP=3694 8/20/2018 8/20/2018 1.50 PRODt DRILL TRIP P TD Build Section, 10x10 sweep, 8,150.0 73.0 07:12 08:42 1 POOH 8/20/2018 8/2012018 0.70 PRODt DRILL PULD P Tag up, space out, PUD build section 73.0 73.0 08:42 09:24 1 BHA#3 Page 2130 Report Printed: 9/1912018 Operations Summary (with Timelog Depths) 1H-21 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log start Depth startTme End Time Dw (hr) Phase Op code Activity Code Time P-TA Operation (1Me) End Depth (PotB) 8/20/2018 8/20/2018 0.80 PROD1 DRILL PULD T ***BHA hung up in well, trouble pulling 73.0 73.0 09:24 10:12 High Bend motor with SL, line up to pump thru the kill line and tango's, no success, close rams, bleed pressure from PDL, unstab, hook up suface power to tools, rotate TF 90° Left. Work tools free 8/20/2018 8120/2018 0.70 PROD1 DRILL PULD P Continue PUD 73.0 0.0 10:12 10:54 8/20/2018 8/20/2018 1.20 PROD1 DRILL PULD P PJSM, PD lateral drilling BHA #4 0.0 78.2 10:54 12:06 w/0.5°- ako motor/ NOV Agitator 8/20/2018 8/20/2018 1.30 PROD1 DRILL TRIP P RIH, 568'test Agitator (great-test) 78.2 7,565.0 12:06 13:24 8/20/2018 8/20/2018 0.20 PROD1 DRILL DLOG P Log the Kt correction of plus 1.5' 7,565.0 7,593.0 13:24 13:36 8/20/2018 8/20/2018 0.10 PROD1 DRILL TRIP P Continue IH, 7,593.0 7,845.0 13:36 13:42 8/20/2018 8/20/2018 0.10 PROD1 DRILL CLOG P Log the RA @ 7833.5' 7,845.0 8,150.0 13:42 13:48 8/20/2018 8/20/2018 5.30 PRODt DRILL DRLG P BOBD, 1.79 bpm @ 4,400 psi, 8,150.0 8,577.0 13:48 19:06 D6=1,250, WHP=open choke, BHP=3,813, IA=O, OA=51 8!20/2018 8/20/2018 0.50 PROD1 DRILL WPRT P Wiper to the window, PUW 51 k 8,577.0 7,900.0 19:06 19:36 8/20/2018 8/20/2018 0.50 PROD1 DRILL WPRT P Wiper back in hole, RIW 17 k 7,900.0 8,577.0 19:36 20:06 8/20/2018 8/20/2018 2.70 PRODt DRILL DRLG P BOBO, 1.80 bpm @ 4,245, Diff--1,230 8,577.0 8,950.0 20:06 22:48 psi, WHP=open choke, BHP=3,780, IA=208, OA=59 8/2012018 8/20/2018 0.50 PROD1 DRILL WPRT P Wiper up to the window, PUW 60 k 8,950.0 7,565.0 22:48 23:18 8/20/2018 8/20/2018 0.20 PROD1 DRILL DLOG P log the K1 marker correction of plus 7,565.0 7,589.0 23:18 23:30 1 5.0' 8/20/2018 8/20/2018 0.30 PROD1 DRILL WPRT P Continue IH, Jog the 7", 7,700'-7,815', 7,589.0 7,815.0 23:30 23:48 1 closed EDC, 8/20/2018 8/21/2018 0.20 PROD1 DRILL WPRT P Continue wiper back in hole, Tough 7,815.0 7,880.0 23:48 00:00 spot 7880. Multiple setdowns with clean pickups, PUW=62K. Worked through @.5 BPM 10 FPM. Continue to bottom 8/21/2018 8/21/2018 0.60 PROD1 DRILL WPRT P Continue wiper trip back to bottom 7,880.0 8,951.0 00:00 00:36 8/21/2018 8121/2018 1.00 PROD1 DRILL DRLG P 8951', Drill, 1.78 BPM @ 4456 PSI 8,951.0 9,119.0 00:36 01:36 FS, BHP=378OPSI, RIW=18.5K 8/21/2018 8/21/2018 0.10 PROD1 DRILL WPRT P BHA Wiper, PUW=60K 9,119.0 9,119.0 01:36 01:42 8/21/2018 8/21/2018 1.70 PROD1 DRILL DRLG P 9119, Drill, 1.78 BPM @ 4425 PSI FS, 9,119.0 9,325.0 01:42 03:24 BHP=3838 8/21/2018 8121/2018 0.70 PROD1 DRILL WPRT - P Pull 800'wiper, PUW=70K, 10K 9,325.0 9,325.0 03:24 04:06 overpulls @ 8890, 8690, & 8570. Clean on way in 8/2112018 8/21/2018 3.80 PROD1 DRILL DRLG P 9325', Drill, 1.79 BPM @ 4480 PSI 9,325.0 9,745.0 04:06 07:54 FS, BHP=3781 8/21/2018 8/21/2018 1.10 PROD1 DRILL WPRT P Wiper to window, work throughtight 9,745.0 7,050.0 07:54 09:00 area 8088 to 8196 8/21/2018 8/21/2018 0.90 PROD1 DRILL WPRT P Pull into 7", recip and jet, pump 7,050.0 7,845.0 09:00 09:54 sweeps, circ to surface, RBIH, set down at 7828, TOW, PUH spin bit, set down 7786. Go through window 8/21/2018 8/21/2018 0.10 PROD1 DRILL DLOG P Log RA for+7' 7,845.0 7,870.0 09:54 10:00 Page 3/30 Report Printed: 911912018 Operations Summary (with Timelog Depths) 1 H-21 ' e Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Sten Depth Start Time End Time our (hr) Phase Op Code AcdAy Code Time P -T-% Operation (MKe) End Depn(PoCB) 8/21/2018 8/21/2018 1.10 PROD1 DRILL WPRT P Continue in hole, initial set down @ 7,870.0 7,896.0 10:00 11:06 7871 work down to 7888. multiple setdowns to 7896, Unable to pass 7896 at different speeds and pump rates. Back ream up at 180° still unable to pass. 8/21/2018 8/2112018 0.60 PROD1 DRILL WPRT P Pull up hole to cased pipe. Circ 7,896.0 7,839.0 11:06 11:42 bottoms up. Check shaker. Nothing there. Discuss plan forward 8/21/2018 8/21/2018 1.40 PROD1 DRILL TRIP T Trip out for clean out BHA 7,839.0 84.0 11:42 13:06 8/21/2018 8/21/2018 1.40 PROD1 DRILL PULD T PJSM, PUD BHA #4 84.0 0.0 13:06 14:30 8/21/2018 6/21/2018 0.90 PROD1 DRILL PULD T PJSM, PD BHA#5 with 1.5° AKO 0.0 68.3 14:30 15:24 motor, D-331 with rigdge set cutter, and agitator, Make up to coil and surface test. Check packoffs, Tag up 8/21/2018 6/2112018 1.10 PROD1 DRILL TRIP T RIH BHA #5, Surface test agitator @ 68.3 7,565.0 15:24 16:30 1 500', open EDC and continue in 8/2112018 8/21/2018 0.50 PROD1 DRILL TRIP T Tie in to K1 marker, RIH 7,565.0 7,860.0 16:30 17:00 8/21/2018 8/21/2018 1.60 PROD1 DRILL TRIP T stacked out twice, able to work 7,894.0 8,490.0 17:00 18:36 through, increase pump rate, rih to stall, continue to work area, clean at 7896, rih to 8490 8121/2018 8/21/2018 1.50 PROD1 DRILL TRIP T pumped bottoms up sweep, puh to 7", 8,490.0 7,858.0 18:36 20:06 taking 3 cleaning passes, attempt to dry drift through trouble area 7840 to 7858, online, continue to tag at different depths each time. 8/21/2018 8/21/2018 2.90 PROD1 DRILL TRIP T pump bottoms up and clean area 7,856.0 7,820.0 20:06 23:00 above problem area, rbih at full pump speed, tagged several times in same area (7840-7950) continue to pump sweeps and try to clean trouble area 8/21/2018 8/22/2018 1.00 PRODt DRILL TRIP T pub to above window, circ buttons up, 7,820.0 7,840.0 23:00 00:00 attempt to drift back through window, sveral time tagging at top of window, orient 15 degrees left, now able to drift window, online with pumps at full rate, rih. 8/22/2018 8/22/2018 2.00 PROD1 DRILL TRIP T RIH at full pump rate, still tag several 7,820.0 7,820.0 00:00 02:00 time, rih to 8450, pump sweeps, pub into the 7"gain, rbih smooth other then one tag at 7858, rih to 8450 again, pub to window. 8/22/2018 8122/2018 2.00 PROD1 DRILL TRIP T dh and tagged at lop of whip stock, 7,820.0 8,450.0 02:00 04:00 puh to tie in, +7.5 it, rbih, small tag at window, rih with full pump rate, mill through small tag at 7890, rih continue to work area. PUH above window, dry drift to 8000, no lags, online full rate, rih to 8450, start trip run for inflatable. 8/22/2018 8/22/2018 1.30 PROD1 DRILL TRIP T POOH, one overpull at top of window 8,450.0 68.0 04:00 05:18 on bit, fill appears to be cleaned out, POOH 8/2212018 8/2212018 1.50 PROD1 DRILL PULD T PJSM, PUD BHA#5 68.0 0.0 05:18 06:48 8/22/2018 8/22/2018 1.20 PROD1 DRILL PULD T PD BHA#6 2 1/8" Inflatable plug, M/U 0.0 68.0 06:48 08:00 to coil and surface test tool -All good, Check pack offs 8/22/2018 8/2212018 1.70 PROD1 DRILL TRIP T RIH BHA #6IFC plug 68.0 7,565.0 08:00 09:42 Page 4130 Report Printed: 9/19120181 0 711 Operations Summary (with Timelog Depths) 1 H-21 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log wart Depth Start Time EM Time Dur (hr) phase Op Code Activit' Cate TMPTX Operation (MKB) End Depth (MKS) 8/22/2018 8/22/2018 0.10 PROD1 DRILL DLOG T Log K1 for+1.5' 7,565.0 7,591.0 09:42 09:48 8122/2018 8/22/2018 0.50 PROD1 DRILL TRIP T Conflnue in hole. Stop and shut EDC 7,591.0 8,450.0 09:48 10:18 @ 7771. Clean pass through window. Clean trip down to 8450 8/22/2018 8/22/2018 0.60 PROD1 DRILL OTHR T At septh depth, Pull stretch out of coil. 8,450.0 8,450.0 10:18 10:54 Slowly pressure up inflatable to 1500 PSI. wait ten minutes. Bring pumps online @ 1700 PSI pressure falls off and we are circulating. Packer will not pressure up. able to move packer up and down hole. Aftemp pumping Vaster. No pressure 8/22/2018 8/22/2018 2.00 PROD1 DRILL TRIP T Trip out with BHA #6 8,450.0 71.0 10:54 12:54 8/22/2018 8/22/2018 1.10 PROD1 DRILL PULD T At surface, Tag up and space out, 71.0 0.0 12:54 14:00 PUD BHA#6. Element is damaged on inflatable packer. Pictures on S drive. Lay down packer 8/22/2018 8/22/2018 1.30 PROD1 DRILL OTHR T Discuss options and alternatives. 0.0 0.0 14:00 15:18 Formulate plan forward 8/22/2018 8/22/2018 1.00 PROD1 DRILL PULD T M/U BHA#7. 1° WFT motor and 2.80 0.0 65.3 15:18 16:18 1 1 crayola mill to dress window 8/22/2018 8/22/2018 2.00 PROD1 DRILL TRIP T Trip in hole 65.3 7,555.0 16:18 18:18 8/22/2018 8/22/2018 0.10 PROD1 DRILL TRIP T K1 tie, =1 , Close EDC, rih 7,555.0 7,555.0 18:18 18:24 8/22/2018 8/22/2018 1.80 PROD1 DRILL MILL T rih to 7829, dress window several time 7,555.0 7,833.0 18:24 20:12 with 2.79 crayola mill and dry drift per plan forward 8/22/2018 8/22/2018 1.20 PROD? DRILL TRIP T Trip out of hole for BHA#8 inflatable 7,833.0 71.0 20:12 21:24 plug. 8/22/2018 82212018 1.20 PROD? DRILL PULD T Al surface, Tag up and space out, 71.0 0.0 21:24 22:36 PUD BHA V. 8/22/2018 8/2312018 1.40 PROD1 DRILL PULD T PD BHA #8 2.5" Inflatable plug, M/U to 0.0 71.0 22:36 00:00 coil and surface test tool -All good, Check pack offs 8/23/2018 8/23/2018 1.90 PROD1 DRILL TRIP T trip in hole with BHA #8 71.0 7,555.0 00:00 01:54 8/23/2018 8/23/2018 0.20 PRODi DRILL DLOG T tie into K1, +1 correction 7,555.0 7,587.0 01:54 02:06 8/23/2018 8/232018 1.60 PROD1 DRILL OTHR T tagged up at 8368, 1ft short, Pull 7,587.0 8,368.0 02:06 03:42 stretch out of coil. Slowly pressure up inflatable to 1500 PSI. wait ten minutes. Bring pumps online, continue to pressure up to shear at 2300 psi over circ psi, pull 18k over window pu wt, shear off inflatable. 8/23/2018 8/23/2018 1.50 PROD1 DRILL TRIP T POOH 8,368.0 68.0 03:42 05:12 8/23/2018 8/232618 1.50 PROD1 DRILL PULD T Tag up and space out, PJSM PUD 68.0 0.0 05:12 06:42 BHA#8 Packer running tools 8/23/2018 8/23/2018 1.00 PROD1 DRILL PULD T PD BHA#9 OH anchored billit. M/U to 0.0 72.9 06:42 07:42 coil track and surface test tool, Check packoffs 823/2018 8/232018 1.70 PROD1 DRILL TRIP T RIH BHA #9 72.9 7,565.0 07:42 09:24 8/23/2018 8/23/2018 0.20 PRODi DRILL DLOG T Log K1 for +1' correction 7,565.0 7,603.0 09:24 09:36 Page 5130 Report Printed: 9/19/2018 Operations Summary (with Timelog Depths) 1 H-21 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Tme Dur(hr) Phase Op Code A fty Code Time P44 operation (e(B) End Depth (110) 8/23/2018 8/23/2018 0.50 PROD1 DRILL TRIP T Continue in hole, Shut EDC @ 7756. 7,603.0 8,327.0 09:36 10:06 Clean pass through window and down to 8327, Set whipstock @ 210° TOWS @ 8315, See tool shift @ 5111, Set down 2K 8/23/2018 8/23/2018 1.70 PROD1 DRILL TRIP T POOH, PUW=53K 8,327.0 74.0 10:06 11:48 8/23/2018 8/23/2018 1.10 PROD1 DRILL PULD T At surface, Tag up and space out, 74.0 0.0 11:48 12:54 PUD BHA#9 Anchor billet setting tools 8/23/2018 8123/2018 1.00 PROD2 STK PULD P PD BHA#10 from Pre loaded PDL 0.0 80.5 12:54 13:54 with .5-AKO motor, Strider agitator, and new HCC bi-center bit with Dynamus cutters. 8/23/2018 8/2312018 1.70 PROD2 STK TRIP P Trip in hole, Shallow test Strider tool 80.5 7,565.0 13:54 15:36 1 @ 500', Continue in well. 8/2312018 8/23/2018 0.10 PROD2 STK DLOG P Log K1 for +1' correction 7,565.0 7,594.0 15:36 15:42 8/23/2018 8123/2018 0.40 PROD2 STK TRIP P Continue in well, Dry tag TOB @ 7,594.0 8,315.0 15:42 16:06 8315', PUH, PUW=54 8/23/2018 8/23/2018 1.90 PROD2 STK KOST P Pumps on 1.83 BPM @ 4286 PSI FS, 8,315.0 8,318.0 16:06 18:00 BHP=3742. Start milling off billet @ 8315.3. Mill per procedure 8/23/2018 8/2312018 2.00 PROD2 DRILL DRLG P 8318', Drill, 1.70 BPM @ 4145 PSI 8,318.0 8,421.0 18:00 20:00 FS, BHP=3724 8/2312018 8/23/2018 0.20 PROD2 DRILL DRLG P PU to 8160 and dry drift billet 8,421.0 8,421.0 20:00 20:12 8/23/2018 8/23/2018 2.00 PROD2 DRILL DRLG P 8421', Drill 1.72 BPM @ 4376 PSI FS, 8,421.0 8,546.0 20:12 22:12 BHP=3945 8/23/2018 8/23/2018 0.20 PROD2 DRILL WPRT P PU to lower flow and try to get through 8,546.0 8,546.0 22:12 2224 stringer, start mu swap '2W0'88/2412018 1.60 PROD2 DRILL DRLG P 8546' Drill 1.60 BPM @ 4368 PSI FS, 8,546.0 8,662.0 22:24 00:00 BHP=4176, trouble getting direction to drop 8/24/2018 8/2412018 1.50 PROM DRILL DRLG P 8662' Drill 1.60 BPM @ 4358 PSI FS, 8,662.0 8,690.0 00:00 01:30 BHP=4192 still having trouble getting direction to drop, consult with town, decission made to trip for BHA. 8/24/2018 8124/2018 1.90 PROM DRILL TRIP T Trip for BHA 8,690.0 69.0 01:30 03:24 8/24/2018 8/24/2018 1.10 PROD2 DRILL PULD T Tag up and spaceout, SM,PUD 69.0 0.0 03:24 04:30 BHA#10 8/24/2018 8/24/2018 1.00 PROD2 DRILL PULD T PD BHA#11 with .7° AKO motor, M/U 0.0 80.5 04:30 05:30 to coil and surface test 812412018 8/24/2018 1.40 PROM DRILL TRIP T Trip in BHA# 11, Test agitator @ 500', 80.5 7,565.0 05:30 06:54 Continue in well 8/2412018 8/24/2018 0.10 PROD2 DRILL DLOG T Log K1 for +25 7,565.0 7,593.0 06:54 07:00 8/24/2018 8/24/2018 0.70 PROD2 DRILL TRIP T Continue in well, Stop at 7807 for 7,593.0 8,690.0 07:00 07:42 static, Annular pressure = 4200 PSI, 6524.6 TVD, 12.385 EMW. Continue in. Clean pass through window 8/24/2018 8/24/2018 2.50 PROD2 DRILL DRLG P 8690', Drill, 1.81 BPM 94577 PSI FS, 8,690.0 8,863.0 07:42 10:12 BHP=4429 8124/2018 8/24/2018 0.70 PROD2 DRILL WPRT P 8863, Pull wiper to window with 8,863.0 7,805.0 10:12 10:54 sweeps. Pull up through window and jet 7" 8/2412018 8/24/2018 1.00 PROD2 DRILL PRTS P 7805 Obtain static pressure, Bleetl 7,805.0 7,805.0 10:54 11:54 down AP to 3800 PSI in three steps. Climbed from 3800 to 3905 in 30 minutes. 6523.1 TVD, 11.51 EMW 8/2412018 8/24/2018 0.50 PROD2 DRILL TRIP P Continue wiper trip back to bottom. 7,805.0 11:54 1224 Clean Z862.0 Page 6130 ReportPrinted: 911912018 Operations Summary (with Timelog Depths) 1H-21 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log start Depth Sbut rM End Time Dur(m) Please Op Code Aa RyCoda Time P -T -X Operation MKB) End DePM(IIXB) 8/24/2018 8/24/2018 2.40 PROD2 DRLG P 8862', Drill, 1.79 BPM @ 4232 PSI 8,862.0 8,985.0 12:24 14:48 FS, BHP=4101 8/24/2018 8/24/2018 0.10 PROD2 WPRT P Pull mini wiper, PUW=55K 8,985.0 8,985.0 14:48 14:54 8/24/2018 8/24!2018 2.90 PROD2 EDR DRLG P 8985', Drill, 1.79 BPM @ 4254PSI FS, 8,985.0 9,098.0 14:54 17:48 BHP=4084 8/24/2018 8/24/2018 0.20 PROD2 WPRT P Pull mini wiper, PUW=55K 9,098.0 9,098.0 17:48 18:00 8/24/2018 8/24/2018 4.00 PROD2 DRLG P 9098', Drill, 1.79 BPM @ 4254PSI FS, 9,098.0 9,260.0 18:00 22:00 BHP=4084 8/24/2018 8/24/2018 0.90 PROD2 DRILL WPRT P wiper trip to 8460, PU wt 551k 9,260.0 9,860.0 22:00 22:54 8/24/2018 8/25/2018 1.10 PROD2 DRILL DRLG P 9260', Drill, 1.80 BPM @ 4480 PSI 9,260.0 9,310.0 22:54 00:00 FS, BHP=4100 8/25/2018 8/2512018 3.00 PROD2 DRILL DRLG P 9310', Drill, 1.80 BPM @ 4480 PSI 9,310.0 9,414.0 00:00 03:00 FS, BHP=4100 8/25/2018 8/25/2018 0.20 PROD2 DRILL WPRT P Wiper trip to 9314', PU WT 59K 9,414.0 9,414.0 03:00 03:12 6/25/2018 8/25/2018 PROD2 DRILL DRLG P 9414', Drill, 1.80 BPM @ 4430 PSI 9,414.0 9,467.0 03:12 03:12FS, BHP=4138 8/25/2018 8/25/2018 1.50 PROD2 DRILL DRLG P 9467, motor stall, puh, .90 bpm =4356 9,467.0 9,467.0 03:12 04:42 circ psi, unbable to clear bit, rih to tag 8/25/2018 8/25/2018 3.20 PROD2 DRILL TRIP T POOH for motor swap 9,467.0 75.0 04:42 07:54 8/25/2018 8/25/2018 2.10 PROD2 DRILL PULD T Tag up space out, PJSM PUD BHA 75.0 0.0 07:54 10:00 #11. Lay down motor, Stryder agitator, and FVS. Test in mouse hole. All seem normal. Run water through coil track no obstruction 8/25/2018 8/25/2018 1.40 PROD2 DRILL PULD T PJSM, PIU motor, bit, agitator, and 0.0 78.1 10:00 11:24 FVS. PD BHA#12. Pull checks out of UQC and change out. Make up to coil and surface test tool. Pump at surface to ensure BHA functional. Tag up and set counters 6/25/2018 8/25/2018 1.40 PROD2 DRILL TRIP T RIH BHA#12, Shallow test agitator at 78.1 j 7,565.0 11:24 12:46 500'- Good. Continue in 8/25/2018 8/25/2018 0.10 PROD2 DRILL DLOG T Log K1 for+1.5' 7,565.0 7,592.0 12:48 12:54 8/25/2018 8/25/2018 1.40 PROD2 DRILL TRIP T Continue in well. Wt check @7790 7,592.0 9,469.0 12:54 14:18 49K, Clean pass through window. Stacking @ 8889, 9087, 9117, and 9176. Set down @ 9269 and 9376. reduce rate to .6 to get through 8/2512018 8/25/2018 6.20 PROD2 DRILL DRLG P 9469, On bottom drilling, 1.78 BPM @ 9,469.0 9,813.0 14:18 20:30 4670 PSI FS, BHP=4165. Ratty with low ROP 8/25/2018 8/25/2018 0.10 PROD2 DRILL WPRT P 100 R wiper, PU WT is 61 K 9,813.0 9,813.0 20:30 20:36 8/25/2018 8/25/2018 1.00 PROD2 DRILL DRLG P 9813', Drill, 1.78 BPM @ 4694 PSI 9,813.0 9,870.0 20:36 21:36 FS, BHP=4216 8/25/2018 8/26/2018 2.40 PROD2 DRILL WPRT P 9870' wiper, PU 800", 2 overpulls 9,870.0 7,710.0 21:36 00:00 around 9320 of 12k, some trouble getting back to bottom through this area. No WT on bit, Decide to POOH to TTL to clean up 7", PU WT is 58K. 8/26/2018 8/26/2018 1.40 PROD2 DRILL WPRT P Clean out 7" 7,710.0 7,570.0 00:00 01:24 8/262018 8/26/2018 0.10 PROD2 DRILL DLOG P Tie in to KI +6.5 7,570.0 7,570.0 01:24 01:30 8/26/2018 8/26/2018 1.30 PROD2 DRILL TRIP P RIH, Clean through window, set down 7,570.0 9,870.0 01:30 02:48 at 8755', Clean for remainder to 9870. Page 7130 ReportPrinted: 911912018 Operations Summary (with Timelog Depths) 1 H-21 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Depth Start Time I EM Time Our(hr) Phase Op Code Activity Code Time P -T -X Operation Me) End Deph(fIKS) 8/26/2016 8/26/2018 1.20 PROD2 DRILL DRLG P 9870', Drill, 1.78 BPM @ 4622 PSI 9,670.0 10,015.0 02:48 04:00 FS, BHP=4239 8/26/2018 8/26/2018 0.20 PROD2 DRILL WPRT P 10015 PU for short wiper 100' 10,015.0 10,015.0 04:00 04:12 8/26/2018 8/26/2018 1.10 PROD2 DRILL TRIP T Short trip to 9930, survey issues due 10,015.0 10,015.0 04:12 05:18 to magnetic storm. Start obtaining usable surveys. RBIH to drill 8/26/2018 8/26/2018 2.10 PROD2 DRILL DRLG P 10015 Drill, 1.81 BPM @ 4764 PSI 10,015.0 10,172.0 05:18 07:24 1 FS, BHP=4202 8/26/2018 8/26/2018 0.20 PROD2 DRILL WPRT P 10172 Pull BHA wiper, PUW=61K 10,172.0 10,172.0 07:24 07:36 1 6/26/2018 8/26/2018 1.00 PROD2 DRILL DRLG P 10172', Drill, 1.77 BPM @ 4747 10,172.0 10,260.0 07:36 08:36 8/26/2018 8/26/2018 2.00 PROM DRILL WPRT P Pull 1 000'wiper with sweeps, 10,260.0 10,260.0 08:36 10:36 PUW=58K. Hard to get back to bottom 8/26/2018 8/26/2018 2.00 PROD2 DRILL DRLG P 10260', Drill, 1.79 BPM @ 4737 PSI 10,260.0 10,353.0 10:36 12:36 FS, BHP=4215 8/26/2018 8/26/2018 0.30 PROD2 DRILL WPRT P Stacking, Pull BHA Wiper, PUW=63K 10,353.0 10,353.0 12:36 12:54 8/26/2018 8/26/2018 3.50 PROD2 DRILL DRLG P 10353', Drill, 1.8 BPM @ 4239 PSI 10,353.0 10,488.0 12:54 16:24 FS, BHP=4239 PSI, RIW=-.4, DHWOB=I.6K 8/26/2018 8/26/2018 0.20 PROD2 P Pull BHA Wiper, PUW=56K, 10,488.0 10,488.0 16:24 16:36 RIW=6.5K 8/26/2018 8/26/2018 2.50 PROD2 DRLG P 10488', Drill, 1.8 BPM @ 4241 PSI 10,488.0 10,573.0 16:36 19:06 FS, BHP=4237 PSI, RIW=-.4, PDRILLWPRT DHWOB=I.6K 8/26/2018 8/27/2018 4.90 5ROD2 WPRT P Wiper, PU WT=70K, PUH to TTL, 10,573.0 10,573.0 19:06 00:00 Time new mud swap for RIH, RBIH several trouble areas going through the C2, new mud at nozzle, big improvment, rih to bottom 8/27/2018 8/27/2018 2.40 PROD2 DRILL DRLG P 10573', Drill, 1.79 BPM @ 4600 PSI 10,573.0 10,647.0 00:00 02:24 FS, BHP=4225 8/27/2018 8/27/2018 0.10 PROD2 DRILL WPRT P Pull BHAWiper, PUW=63K, 10,647.0 10,647.0 02:24 02:30 RIW=6.51< 8/27/2018 8/27/2018 1.30 PROD2 DRILL DRLG P 10647', Drill, 1.79 BPM @ 4600 PSI 10,647.0 10,671.0 02:30 03:48 FS, BHP=4225 8/27/2018 8/27/2018 0.10 PROD2 DRILL WPRT P Pull BHAWiper, PUW=61K, 10,671.0 10,671.0 03:48 03:54 RIW=6.5K 8/27/2018 8/27/2018 0.50 PROD2 DRILL DRLG P 10671', Drill, 1.79 BPM @ 4419 PSI 10,671.0 10,676.0 03:54 04:24 FS, BHP=4230 8/27/2018 8/27/2018 0.40 PROD2 DRILL WPRT P PU for GEO Wiper 10,676.0 10,676.0 04:24 04:48 8/27/2018 8/27/2018 2.70 PROD2 DRILL DRLG P 10676', Drill, 1.79 BPM @ 4412 PSI 10,676.0 10,700.0 04:48 07:30 FS, BHP=4228 8/27/2018 8/27/2018 2.90 PROD2 DRILL TRIP P 10,700, Trip for bit, Pump sweeps, jet 10,700.0 75.0 07:30 10:24 7" chase to surface 8/27/2018 8/27/2018 1.50 PROD2 DRILL PULD P Tag up and space out, PJSM. Run 75.0 0.0 10:24 11:54 blocks to free ice. PUD BHA#12. Lay down FVS, Agitator, motor, and bit. Bit out 3-3 with chipped reamers and nose 8/27/2018 8/27/2018 0.50 PROD2 DRILL ROPE P P/U test joint. Perform Biweekly 0.0 0.0 11:54 12:24 function test on stack 8/27/2018 8/27/2018 1.30 PROD2 DRILL PULD P P/U FVS, Agitiator, motor, and Hyc bit 0.0 78.0 12:24 13:42 center bit, PD BHA#13. M/U to coil trak and surface test tool, Tag up and set counters 6/27/2018 8/27/2018 1.50 PROD2 DRILL TRIP P Trip in hole, BHA#13, Shallow test 78.0 7,565.0 13:42 15:12 agitator - Good. Continue in Page 8130 Report Printed: 9/1912018 Operations Summary (with Timelog Depths) 1 H-21 ...• Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Lop Start Depth Start Tone I End Time INA its) Phase Op coda Activity Code Tana P-T-X Opeatlon (Iti(B) End Depth (M) 8127/2018 8/27/2018 0.10 PROD2 DRILL DLOG P Log K1 for+1 foot 7,565.0 7,595.0 15:12 15:18 8127/2018 8/27/2018 1.40 PROD2 DRILL TRIP P . Set down @ 7966 and 8058 requiring 7,595.0 10,700.0 15:18 16:42 pick up. Stacking but no set downs, RIH 8/27/2018 8127/2018 1.20 PROD2 DRILL DRLG P 10700', Drill, 1.79 BPM @ 4869 PSI 10,700.0 10,720.0 16:42 17:54 FS, BNP=42236 8127/2018 8/2712018 0.10 PROD2 DRILL WPRT P PU for mini wiper, PU WT =65K 10,720.0 10,720.0 17:54 18:00 8/27/2018 8/27/2018 5.20 PROD2 DRILL DRLG P 10720', Drill, 1.79 BPM @ 4776 PSI 10,720.0 10,984.0 18:00 23:12 1 FS, BHP=4212 6/27/2018 8/27/2018 0.20 PROD2 DRILL WPRT P 100' Wiper, PU WT is 64K 10,984.0 10,984.0 23:12 23:24 8/27/2018 8/28/2018 0.60 PROD2 DRILL DRLG P 10984', Drill, 1.79 BPM @ 5016 PSI 10,984.0 10,994.0 23:24 00:00 FS, BHP=4253 8128/2018 8/26/2018 2.00 PROD2 DRILL DRLG P 10984', Drill, 1.79 BPM @ 5016 PSI 10,994.0 11,100.0 00:00 02:00 FS, BHP=4253 8/28/2018 8/28/2018 1.80 PROD2 DRILL WPRT P 850" wiper, PU WT is 65K, pulled 11,100.0 11,100.0 02:00 03:48 heavy at 10980,10425 and 10305 8/28/2018 8/28/2018 3.10 PROD2 DRILL DRLG P 11,100', Drill, 1.79 BPM @ 5196 PSI 11,100.0 11,216.0 03:48 06:54 FS, BHP=4333 8/28/2018 8128/2018 0.20 PROD2 DRILL WPRT P Short wiper, PU WT is 72K 11,216.0 11,216.0 06:54 07:06 8/28/2018 8/2812018 1.70 PROD2 DRILL DRLG P 11,216', Drill, 1.79 BPM @ 5126 PSI 11,216.0 11,244.0 07:06 08:48 FS, BHP=4310 8/28/2018 8/28/2018 0.20 PROD2 DRILL WPRT P Short wiper, PU WT is 72K, Hard time 11,244.0 11,244.0 08:48 09:00 getting back down 8/28/20188/28/2018 2.50 PROD2 DRILL DRLG P 11,244', Drill, 1.79 BPM @ 5308 PSI 11,244.0 11,293.0 09:00 11:30 FS, BHP=4310 TD uncomfirmed 11,293'. PU Wt, 60 k lbs 8/28/2018 8/28/2018 0.90 PROD2 DRILL CIRC P Stage sweeps to bit while RBIH to TD 11,244.0 11,293.0 11:30 12:24 8/28/2018 8/28/2018 2.70 PROD2 DRILL WPRT P PUH on swab wiper trip chasing 11,293.0 7,700.0 12:24 15:06 sweeps to surface. Slight increase in string weght and motor work from 10,400-10,000. RBIH, all clean, continue to POOH. Pull heavy, 68 k lbs, @ 9,917' RBIH, stack out -2, PUH, CT wt to 74 k lbs, RBIH, stack out -5 k, PU to 75 k lbs, RBIH stack out -8 k, PU , clean, PU 75 k, RBIH, all clean, PUH, all clean. Pump additional sweeps, Pull 75 k lbs CT wt, no WOB, @ 8090 in the build, continue out of hole. larg neg WOB @ 7947', 7907', & 7817' with small Ct Wt overpulis, continue up hole, window clean. Make two passes to the tubing tail cleanin up the 7" RBIH 8/28/2018 8/28/2018 0.20 PROD2 TRIP P KIM to clean up build. 7,700.0 7,840.0 15:06 15:18 Set down in window - 7818', PU 45 k ]DRILL lbs, RBIH 19 fUmin, pumps down while transiting the window, clean. 8/28/2018 8/28/2018 0.20 PROD2 DRILL DLOG P Tie into the RA tag for+13' correction. 7,840.0 7,860.0 15:18 15:30 1 1 Page 9130 ReportPrinted: 911912018 Operations Summary (with Timelog Depths) 1 H-21 • Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Depth Stat Tim End rare our (ho Phase Op Coda Actively Code Term, P -T -x Operation (Po®) End Depth (ft 8/28/2018 8/28/2018 0.30 PROD2 DRILL WPRT P Continue to RIH in an atempt to clean 7,840.0 8,295.0 15:30 15:48 up the build section. Multiple set downs and WOB spikes with asociated coil wt spikes, 7956', 7960', 7995', 8024', 8119', 8/28/2018 8128/2018 1.50 PROD2 DRILL WPRT P Pump 2x 10x10 sweeps, spaced apart 8,295.0 7,751.0 15:48 17:18 and chased up hole while pulling to surface. Slight neg WOB @ 8193', and 8160'. 7899' pulled -18 k WOB, worked pipe. Window clean. 8/28/2018 8/28/2018 1.37 PROD2 DRILL WPRT P Continue POOH (Swab Wiper), 7,751.0 79.0 17:18 18:40 pumping 1.71 bpm @ 4,989 psi 8/28/2018 8/28/2018 1.33 PROD2 DRILL TRIP P Tag up, reset counter, set depths, RIH, 79.0 7,560.0 18:40 20:00 pumping 0.43 bpm @ 2,174 psi 8/28/2018 8/28/2018 0.20 PROD2 DRILL DLOG P Log the Kt marker correction of plus 7,560.0 7,594.0 20:00 20:12 1.0', PUW=46 k 8/28/2018 8/28/2018 0.22 PROD2 DRILL TRIP P Continue IH 7,594.0 7,805.0 20:12 20:25 8/28/2018 8/28/2018 0.40 PROD2 DRILL TRIP P Obtain Static Pressure, bleed down to 7,805.0 7,805.0 20:25 20:49 11.6 ppg (3835 psi), 20 min 10.6 (3,601 psi) 8/28/2018 8/28/2018 2.50 PROD2 DRILL TRIP P Continue IH towards bottom, (7,964', 7,805.0 11,293.0 20:49 23:19 7,994', & 8,029'), confirm TD 11,293' 8/28/2018 8128/2018 0.50 PROD2 DRILL CIRC P PUW=68 k, send liner pill dawn coil 11,293.0 11,293.0 23:19 23:49 j 8/28/2018 8/29/2018 0.18 PROD2 DRILL TRIP P POOH, laying in 11.7 ppg beaded liner 11,293.0 10,946.0 23:49 00:00 running pill 8/29/2018 8/29/2018 1.15 PROD2 DRILL TRIP P Continue POOH, laying in 11.7 ppg 10,946.0 7,720.0 00:00 01:09 beaded liner running pill up to 7,720' 8/29/2016 8/29/2018 1.50 PROD2 DRILL TRIP P Continue POOH, displacing well to 7,720.0 79.0 01:09 02:39 11.7 ppg completion fluid 8/29/2018 8/29/2018 0.50 PROD2 DRILL OWFF P At surface, check well for flow, PJSM 79.0 79.0 02:39 03:09 1 for LD tools. 8/2912018 8/2912018 1.25 PROD2 DRILL PULD P LD drilling BHA on a dead well. 79.0 0.0 03:09 04:24 Note: Inspected Coil (0.120") 6/29/2018 8/29/2018 1.00 COMPZ2 CASING PUTB P Prep RF for liner ops 0.0 0.0 04:24 05:24 8/29/2018 8/29/2018 3.10 COMPZ2 CASING PUTB P Make up lower completion, norf ported 0.0 1,545.0 05:24 08:30 bull nose, 50 joints, 4.6 ppf L-80 slotted liner, (1546), under a shorty deployment sleeve, min ID Crew change w 19 joints in the hole, made up safety joint for hand over. Joint # 48 (31.76) slightly bent, decided to swap out, replaced with joint # 51 ( 31.77'). 8129/2018 8/29/2018 1.30 COMPZ2 CASING PUTB P PJSM, MU BHA# 14, AU lower liner 1,545.0 1,590.0 08:30 09:48 running assembly, skid cart, inspect pack offs - replaced, pull and replace upper checks, stab injector, bump up, reset counters. 8/29/2018 8/29/2018 1.60 COMPZ2 CASING RUNL P RIH pumping min rate, CT Wt 8.63 k 1,545.0 7,954.0 09:48 11:24 lbs at surface. Pu Wt 52 k lbs, Tie into flag for -8.3' correction. Continue to run in hole. Lost 7 bbls on the trip in. Page 10130 Report Printed: 9119/2018 AimOperations Summary (with Timelog Depths) IH -21 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log start Depth StartTime End Time Dur (hr) Phase Op Code Mbwty Cade Time P -T -X Opemaon MKB) End Depth(fIKB) 8/29/2018 8/29/2018 1.10 COMPZ2 CASING RUNL P Set down, 7954, slid through 1,545.0 8,495.0 11:24 12:30 Set down again 7986', tried multiple attempts and multiple speeds and SID weights, tried rolling the pump. No apparent progress. CT PU Wt 52 k lbs, WOB -13 k lbs until it breaks free and returns to -5.6 k lbs. 17 S/D's Picked up above original SID, RIH, slight bobble and bouced through. SID @ 8355' slowly slid through, 8398', 8460- 812912018 8/29/2018 0.60 COMPZ2 CASING RUNL P SD @ 8495', P/U, Pulled -23 k WOB, 8,495.0 8,500.0 12:30 13:06 cycled pipe to 74 K Ct Wt, pulled free, RBIH, setting down and draging heavy when PU to 75 k Ibs. PUH to 8325' RBIH, lost ground, SID 8438'. Work pipe, -9 to -20 k WOB, CT Wt 48 - 68 k lbs when POOH. start making hole again slowly 8/29/2018 8/29/2018 2.10 COMPZ2 CASING RUNL P Working pipe up to 80 k CT wt, - 24 K 8,500.0 9,432.0 13:06 15:12 - WOB, on pickups, RIH, SID PU 8/29/2018 8/29/2018 5.00 COMPZ2 CASING RUNL P Continue working pipe towards 9,432.0 9,677.0 15:12 20:12 bottom, PUW 60 k, PUDHWOB=minus 12k 8/29/2018 8/2912018 0.80 COMPZ2 CASING RUNL P Continue IH @ 30 fpm to bottom 9,677.0 11,293.0 20:12 21:00 11,288' 8/29/2018 21:00 8/29/2Q18 21:12 0.20 COMPZ2 CASING RUNL P PUW=62 k, set back down, minus 2.5 k, bring pump up to 1.5 bpm @ 3,900 11,293.0 11,293.0 psi, 0.75 bpm returns, PUW= 48 k, liner is gone, remove liner length from counters, 8/29/2018 6/29/2018 0.75 COMPZ2 CASING CIRC P Finish building and circulate 11.7 ppg 11,293.0 11,293.0 21:12 21:57 beaded liner running pill. 8/29/2018 8/29/2018 1.00 COMPZ2 CASING TRIP P POOH, laying in 11.7 ppg beaded liner 11,293.0 7,545.0 21:57 22:57 running pill to 7,650' 8/29/2018 8/29/2018 0.20 COMPZ2 CASING DLOG P Log K1 marker correction of plus 16.5' 7,545.0 7,563.0 22:57 23:09 8/29/2618 8/30/2018 0.85 COMPZ2 CASING TRIP P POOH to surface 7,563.0 2,465.0 23:09 00:00 8/30/2018 8/30/2018 0.25 COMPZ2 CASING TRIP P Continue POOH 2,465.0 44.2 00:00 00:15 8/30/2018 8/30/2018 0.50 COMPZ2 CASING OWFF P At surface, check well for flow, PJSM 44.2 44.2 00:15 00:45 for liner ops 8/302018 8/30/2018 0.25 COMPZ2 CASING PULD P LD setting tools 44.2 0.0 00:45 01:00 j 8/30/2018 8/30/2018 0.25 COMPZ2 CASING PUTB P Prep RF for liner ops 0.0 0.0 01:00 01:15 8/30/2018 8/30/2018 2.00 COMPZ2 CASING PUTB P PU/MU AL1 liner segment #2 w/30 Its 0.0 940.9 01:15 03:15 of slotted liner and ported bullnose 8/302018 8/30/2018 0.75 COMPZ2 CASING PULD P PU/MU Coiltrak tools and BOT 3" GS, 940.9 985.1 03:15 04:00 stab INJH, surface test CTT (good - test) 8/30/2018 8/30/2016 3.00 COMM CASING RUNL P Tag up reset counters, RIH 985.1 9,751.0 04:00 07:00 window flag correction -6.43' Wt check above the window - 49 k Ibs Tie into the K1 for a +5.5' correction, continue to RIH, tag bottom @ 9751' PU wt 54 k lbs, RBIH, stalk 2 k lbs, Release off liner, PU 43 k lbs, "' TOL 8310' 8/30/2018 8/30/2018 1.10 COMPZ2 CASING CIRC P PUH, correct depths, circulate 18 bbl 9,751.0 8,795.0 07:00 08:06 beaded liner running pill to GS Page 11130 Report Printed: 911912018 Operations Summary (with Timelog Depths) AM 1 H-21 W Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Stan Depth Stan Tima I Erd Tmre our (hr) Phase Op Catle Advity Code Time P -T -X Operetion (MI(B) End CePth MKB) 8/30/2018 8/30/2018 0.50 COMPZ2 CASING DISP P PU 48 k lbs, POOH hole laying in 8,795.0 7,540.0 08:06 08:36 beaded liner running pill to 7,663' 8/30/2018 8/30/2018 0.20 COMPZ2 CASING DLOG P Tie into the K1 for a +2.5' correction 7,540.0 7,565.5 08:36 08:48 8/30/2018 8130/2018 1.50 COMP22 CASING TRIP P Continue to POOH 7,565.5 50.0 08:48 10:18 8/30/2018 8/30/2018 0.70 COMP22 CASING PULD P Bump up, space out, Flow check, LD 50.0 0.0 10:18 11:00 BHA# 15 8/30/2018 8/30/2018 0.50 COMPZ2 CASING PUTB P Prep floor to run liner, PJSM 0.0 0.0 11:00 11:30 8/30/2018 8/30/2018 1.20 COMM CASING PUTB P PU AL1 section #3 completion, 3 0.0 863.8 11:30 12:42 pups, 27 joints, 1863.78'), under shorty with a ported bullnose. Kick drill, AAR, PJSM. clear flow. 8130/2018 8/30/2018 1.20 COMPZ2 CASING PULD P PU BHA #15 -AL1 section #3 863.0 908.0 12:42 13:54 completion, check pack offs, skid cart stab on bump up space out. 8/30/2018 8/30/2018 2.20 COMPZ2 CASING RUNL P RIH W BHA#13. Tie into flag for -0.2' 908.0 8,812.0 13:54 16:06 correction, PU 48 k lbs, continue to RIH. drive by the K1 for a +0.5' correction. Continue in hole, tag up, 8812', PU Wt 53 k lbs, RBIH, set down 2 k lbs WOB, online w pump, PU Wt 42 k lbs. ***TOL 7947' 8/30/2018 8/30/2018 1.40 COMPZ2 CASING TRIP P Park, reset counters, POOH. 8,812.0 59.9 16:06 17:30 8/30/2018 8/30/2018 0.50 COMPZ2 CASING OWFF P At surface, check well for flow, Crew 59.9 59.9 17:30 18:00 1 change, PJSM 8/30/2018 8/3012018 0.50 COMM CASING PULD P LD setting tools 59.9 0.0 18:00 18:30 8/30/2018 8/30/2018 0.50 COMP7_2 CASING PULD P PU/MU, Open hale anchored billet w/ 0.0 72.9 18:30 19:00 BOT J -hydraulic setting tool 8/30/2018 8/302018 0.25 COMM CASING PULD P PU/MU, Coiltrak tools, stab INJH, 72.9 72.9 19:00 19:15 perform surface test (good -test) 8/30/2018 8/30/2018 2.00 COMPZ2 CASING RUNL P RIH, with BHA#17 Open Hole 72.9 7,565.0 19:15 21:15 Anchored Billet, @ 80 fpm/20 fpm jewelry 8/302018 8/30/2018 0.20 COMPZ2 CASING DLOG P Log the K1 marker no correction, 7,565.0 7,608.0 21:15 21:27 1 PUW 50 k 8/302018 8/30/2018 0.20 COMPZ2 CASING RUNL P Continue IH, tagging TOL@ 7,947 psi 7,608.0 7,947.0 21:27 21:39 8/30/2018 8/30/2018 0.20 COMPZ2 CASING RUNL P Set down 4.5 k DHWOB, PUW 49 k, 7,947.0 7,947.0 21:39 21:51 repeat, PUH to 0.3 k DHWOB, bring pump up 1.4 bpm, seen tool shift 3,077 psi, creep in hole back to 4.5 k, 7,947', PUW 44 k 8/30/2018 8/30/2018 1.20 COMM CASING TRIP P POOH 7,947.0 53.3 21:51 23:03 8/30/2018 8/302018 0.50 COMPZ2 CASING OWFF P At surface, check well for flow, PJSM 53.3 53.3 23:03 23:33 8/302018 8/31/2018 0.46 COMPZ2 CASING PULD P LD setting tools 53.3 0.0 23:33 00:00 8/312018 8/31/2018 1.00 PROD3 DRILL CTOP P MU Nozzle, stab INJH, jet surface 0.0 0.0 00:00 01:00 lines and stack, while displacing coil to FW. Sim -ops: grease valves and bop iment. 8/312018 8/31/2018 0.75 PROM DRILL CTOP P shop on location, service tree, 0.0 0.0 01:00 01:45 ozzle, remove BHI upper quick, rRD move CTC, boot a -line Page 12130 ReportPrinted: 911912018 r Operations Summary (with Timelog Depths) 77 1H-21 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log start Dap" Stan TIMEnd Time Dw(ho Phase Op Code I Ardivily Code Time P -T -X Operation (t1K13) End Depth(N(B) 8/31/2018 8/31/2018 0.25 FROM DRILL CTOP Stab INJH, use both pumps, pump 0.0 0.0 01:45 02:00 slack 8/31/2018 8/31/2018 0.25 FROM DRILL CTOP Test inner reel valve and pao-off, 0.0 0.0 02:00 02:15 unstab INJH 8/31/2018 8131/2018 0.50 PRODS DRILL (TOP FP PJSM, RU coiled tubing cutter 0.0 0.0 02:15 02:45 6/31/2018 8/3112018 1.00 FROM DRILL CTOP Cut Coiled tubing back to locate wire 0.0 0.0 02:45 03:45 (140') 8/31/2018 8/31/2018 2.45 PRODS DRILL ( TOP Install CTC, pull test to 35 k good, 0.0 0.0 03:45 06:12 install UCQ, pressure test good, tested wire 170OMohms, 69.8 ohms. 8/31/2018 813112018 1.30 PRODS WHDBOP CTOP P Prep for BOP test, grease and service 0.0 0.0 06:12 07:30 valves, flood up. shell test - 3000 psi. 8/31/2018 8/31/2018 6.50 FROM WHDBOP BOPE P Prep for BOP test, grease and service 0.0 0.0 07:30 14:00 valves, flood up. shell test - 3000 psi. " Start test 7:30 Tree swab leaking slightly Annular test took 52 minutes to trouble shoot some issues. 8/31/2018 8/31/2018 1.00 PRODS WHDBOP CTOP P Clear floor from BOP testing, Valve 0.0 0.0 14:00 15:00 check list. 813112018 8/31/2018 0.50 PRODS DRILL SVRG P Took 30 minutes, rig service timet o 0.0 0.0 15:00 15:30 allow for Washington crane inspector Ito finish work on injector. -0 8/31/2018 8/31/2018 1.20 FROM DRILL CTOP P Skid cart, install nozzle, slab injector, 0 0.0 15:30 16:42 turn reel over to kill weight fluid. PJSM, Open up to well, fill 3 bbls, flow check - good, unstab injector, skid cart. 8/31/2018 8/31/2018 0.70 FROM STK PULD P PU BHA #18, AL2 lateral drilling 0.0 72.2 16:42 17:24 assembly, Re Run Baker dynamus bit under a 0.4+°AKO motor. 8/31/2018 8/31/2018 0.50 PRODS STK TRIP P RIH 72.2 507.0 17:24 17:54 8/3112018 8/31/2018 0.50 PRODS STK TRIP T BHI MWD, check shots reviled 507.0 72.2 17:54 18:24 incontinency with the Hydraulic orienting Tool, Pull back to surface 8/31/2018 8/31/2018 0.50 FROM STK PULD T PJSM, swap out HOT tools 72.2 0.0 18:24 18:54 8/31/2018 8/31/2018 0.25 PRODS STK PULD P MU UQC, surface test tools (good- 0.0 72.2 18:54 19:09 test), stab INJH, tag up reset counters 18 8/31/2018 1.50 PROD3 STK TRIP P RIH 509.0 7,565.0 20:39 18 8131/2018 0.20 PRODS P Log the K1 marker no correction 7,565.0 7,598.0 20:51 18 8/31/2018 0.65 PRODS DISP P Finish displacing well to drilling fluid 7,598.0 7,805.0 r20:51 21:30 18 8/31/2018 0.20 PRODS PSTKDLOG TRIP P Close EDC, PUW 48 k 7,805.0 7,805.0 21:42018 8/3112018 030 PROD3 TRIP P Continue IH through window dry tag 7,805.0 7,935.0 22:00 TOB @ 7,935', PUH, attempt to roll TF 180', RIH, stack out, PBUH, roll TF as drilled, park 7,932' 8/31/2018 8/31/2018 1.25 PROD3 STK KOST P Bring pump online 1.75 bpm at 4,195 7,935.0 7,937.0 22:00 23:15 psi, WHP=274, BHP=4074, IA=O, OA=47, kickoff billet as per RP 8/31/2018 8/31/2018 0.25 FROM DRILL DRLG P Drill Ahead, 1.75 bpm at 4,140 psi, 7,937.0 7,939.3 23:15 23:30 DiH=516 psi, WHP=304, BHP=4,055 I psi, IA=O, OA=49 Page 13130 Report Printed: 9/1 912 0 1 8 Operations Summary (with Timelog Depths) 1 H-21 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Stan DepM Sten Time End Tone Dur(hn Phase Op Cotle Activity Code rime P-T-X Operation Me) EM DePN Me) 8/31/2018 8/31/2018 0.20 PRODS DRILL DRLG P Stack out weight, shut down pump, 7,939.3 7,939.3 23:30 23:42 PUH 56 k to 7,930', RBIH, dry tag 7,939.3' 8/3112018 9/1/2018 0.30 PRODS DRILL DRLG P PUH 7,930', PUW 52 k, bring pump on 7,939.3 7,939.6 23:42 00:00 -line 1.77 bpm at 4,288 psi, Diff=464 psi, WHP=261, BHP=4,037, IA=O, OA=49 9/1/2018 9/1/2018 1.00 PRODS DRILL DRLG P OBD, 1.77 bpm at 4,177 psi, Diff-467. 7,939.6 7,951.9 00:00 01:00 1 WHP=316, BHP=4,067, IA=O, OA=52 9/1/2018 9/1/2018 2.00 PRODS DRILL DRLG P OBD, 1.79 bpm at 4,154 psi, Diff--467 7,951.9 7,966.0 01:00 03:00 1 psi, WHP=314, BHP=4,054, IA=O, OA=53 9/1/2018 9/1/2018 1.75 PRODS DRILL DRLG P OBD, 1.76 bpm at 4,151 psi, Diff=467 7,966.0 7,972.0 03:00 04:45 psi, WHP=295, BHP=4,076, IA=7, OA=57 "•' Note: Bit balling PUH creep in hole slowly, continue drilling ahead slowly @ 20 fph 9/1/2018 9/1/2018 2.00 PRODS DRILL DRLG P OBD, 1.77 bpm at 4,250 psi, Diff=467 7,972.0 8,028.0 04:45 06:45 psi, WHP=329, BHP=4,039, IA=19, OA=58 Pump 5x5 sweep 9/1/2018 9/1/2018 1.00 PRODS DRILL DRLG P OBD, CT 4403 psi, WH 317 psi, 4145 8,028.0 8,100.0 06:45 07:45 psi annular, IA 54 psi, OA 60 psi Ratty drilling cleaned up, ROP 70 ft/hr, CT Wt 16 k lbs, WOb 1.9 k Itis Some aluminum, clean cuttings, stickier than normal. Pump 5x5 sweep in anticipation of TD. 9112018 911/2018 0.30 PROD3 DRILL W PRT P TO build early per DO and Geo. 8,100.0 7,957.0 07:45 08:03 PU 52 k lbs, sweeps out the bit, chase up hole to ITT, while slowly PUH. Orient low side for billet, small neg WOB lug while orienting, small neg WOB spike passing the billet at min rate. RBIH, dry drift billet, small WOB spike below the billet, assuming BHA binding up. 9/1/2018 9/1/2018 1.70 PRODS DRILL TRIP P PU, 50 k lbs, 7,957.0 71.0 08:03 09:45 POOH, billet clean again. Pull through window clean. Slow pass at rate cleaning up 7" to TT, Pull into tubing, Open EDC. POOH for let drilling BHA 911/2018 9/1/2018 2.30 PRODS DRILL PULD P PJSM, discussed high bend motor, 71.0 0.0 09:45 12:03 bump up, attempt to pull tool, hung up from the outset, PJSM, pop off, orient tool 180', reattempt with DS PDL winch, its a little faster, tool pulled free with no issue. - 1 hr added time due to hang up. PUD BHA#19. 9/112018 9/1/2018 1.30 PRODS DRILL PULD P PU BHA#20, AL2 lateral drilling 0.0 80.0 12:03 13:21 assembly, 0.6° AKO, W HYC - SR321M-A1 11mm w 3D nose cutters, test good, skid cad, slab injector, bump up, set counters 9/1/2018 9/1/2018 1.40 PRODS DRILL TRIP P RIH, close EDC, Test agitator @ 1.7 80.0 7,565.0 13:21 14:45 bpm and 500'- good, continue in hole. 9/1/2018 9/1/2018 0.20 PROD3 DRILL DLOG P Tie into the K1 for a 0.5' correction, 7,565.0 7,590.0 14:45 14:57 9/1/2018 9/1/2018 0.50 PRODS DRILL TRIP P CT PU Wt, 44 k lbs, continue to RR, 7,590.0 8,101.0 14:57 15:27 window and billet both clean, build clean. Page 14130 ReportPrinted: 9119/2018 Operations Summary (with Timelog Depths) 1H-21 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log star/ Depth stertTme EMTkne Drr (hrc) Phase Op Code Activit' Code Tbne P -T-% Opeabon (RKB) End Depth MKB) 9/1/2018 9/1/2018 1.90 FROM DRILL DRLG P CT 4176 psi @ 1.77 bpm, annular 8,101.0 8,220.0 15:27 17:21 4124 psi, Free spin diff 960 psi. OBD, CT Wt 15.6 k lbs, WOB 2.0 k lbs, ROP 70 fUhr. 9/1/2018 9/1/2018 4.50 PRODS DRILL DRLG P OBD, 1.80 bpm at 4,851 psi, 8,220.0 8,505.0 17:21 21:51 Diff --1,100 psi, BHP=4,155, IA=212, OA=57 9/1/2018 91112018 0.25 PROD3 DRILL WPRT P Wiper up hole to 8,100'w/ sweeps, 8,505.0 8,100.0 21:51 22:06 1 PUW=53 k 9/1/2018 9/12018 0.25 FROM DRILL WPRT P Wiper back in hole, RIW 8,100.0 8,505.0 22:06 22:21 9/1/2018 9122018 1.65 FROM P BOBD,1.82 bpm @ 4,707 psi, 8,505.0 8,612.0 22:21 00:00 Diff=1,000 psi, WHP=263, BHP=4,134, IA=213, OA=57, Avg. ROP=60 fph/2.6 k DHWOB 9/2/2018 9/212018 1.30 PRODS FDRILLDRLG DRLG P OBD, 1.79 bpm at 4,977 psi, 8,612.0 8,692.0 00:00 01:18 Diff=1,000 psi, WHP=251, BHP=4,170, IA=346, OA=60 9/2/2018 9/2/2018 0.80 PRODS DRLG P OBD, 1.78 bpm at 5,339 psi, 8,692.0 8,768.0 01:18 02:06 Diff=1,100 psi, WHP=256, BHP=4,156, IA=365, OA=60, Avg.Rop=65 fph/2.4 k DHWOB 91212018 9/212018 1.80 PRODS DRILL DRLG P OBD, 1.80 bpm @ 5,209 psi, 8,768.0 8,930.0 02:06 03:54 Diff -1,050 psi, WHP=275, BHP=4,221, IA=396, OA=61, Avg. ROP=112 fph 9/2/2018 9/2/2018 1.00 FROM DRILL WPRT P Wiper up hole to the window. PUW 53 8,930.0 7,840.0 03:54 04:54 k, jog the 7" casing with sweeps up to 7,707'. circulate BU. 9/2/2018 9/2/2018 0.20 FROM DRILL DLOG P Log the K1 marker correction of plus 7,840.0 7,877.0 04:54 05:06 4.5' 9/2/2018 9/212018 0.50 PRODS DRILL WPRT P Wiper back in hole, RIW 14 k 7,877.0 8,930.0 05:06 05:36 Seeing same MWD issues as yesterday, tool is rolling as we near the window and billet. Possibly geometry issues, not electrical. 9/2/2018 9/2/2018 2.40 PRODS DRILL DRLG P Free spin diff 970 psi' , initially 1,100 8,930.0 9,153.0 05:36 08:00 psi dropped once we were on bottom for a bit. IA470 psi, OA64 psi, CT 5142 psi, @ 1.78 bpm, Annular 4172 psi CT Wt - 6 k lbs, WOB 1-2 k lbs, ROP 60 - 150 ft/hr' some siderite chips in the cuttings samples Average ROP over section - 93 fUhr 9/2/2018 9/2/2018 0.20 FROM DRILL WPRT P PU Wt 54 k lbs, Geo wiper to 9,47', 9,153.0 9,153.0 08:00 08:12 RBIH, RIH W112 k lbs - 1,700' on the mud, solids @ 0.7, inlet density up to 8.87 ppg Geo asked for 16' decrease in ND in the next 100' feet, 9/2/2018 9/2/2018 2.30 FROM DRILL DRLG P CT 4953 psi, @ 1.78 bpm, Annular 9,153.0 9,299.0 08:12 10:30 4195 psi, Free spin diff 950psi OBD, CT Wt 0-2 k lbs, WOB 1.6 k lbs, ROP 100 R/hr BHA vipers, PU's - 50 k lbs, hard stringers. resistivity increasing from 9180' on. Lots of tool face changes, Pick ups climbed from 50 to 68 k. Pump sweeps. Pick ups still climbing,.. Average ROP over section - 63 ft/hr Page 15130 ReportPrinted: 911912018 Operations Summary (with Timelog Depths) 1 H-21 log: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log stall Depth StarkTune 912/2018 End Time 9/2/2018 Dw(hr) 0.50 Phase PRODS Op Code DRILL mawy Code WPRT TIM P-T-X P Operation PU W171 k lbs, Pull wiper early. #1 (f") 9,299.0 End Depth(MKB) 8,100.0 10:30 11:00 -1.2 k WOB pull @ 9257', we'd had issues passing this spot earlier on BHAwipers Seeing free spin diff fluctuate from 960 psi to 1200 psi. It doesn't appear to be motor work, agitator kicking in and out?? 9/212018 9/2/2018 0.70 PRODS DRILL WPRT P RBIH 8,100.0 9,299.0 11:00 11:42 SO - 8686' PU 52 k, RBIH, 500 Ib WOB spike at 8700, SD,- 8960', PU 50 k, SD,- 9228', PU 50 k, 9/2/2018 9/2/2018 3.40 PRODS DRILL DRLG P CT 5121 psi, @ 1.79 bpm, Annular 9,299.0 9,490.0 11:42 15:06 4142 psi, Free spin diff 1140psi OBD, CT Wt -2-2 k lbs, WOB 1.3 k lbs, ROP 100 f thr Pickups -52-62 k lbs. Start exporting mud outside - 12:49 - in prep for mud swap. Started new mud @ 14:30 ""New mud at the bit - 9487' Average ROP over section - 76 fUhr 9/2/2018 9/2/2018 2.20 PRODS DRILL DRLG P PU to get new parameters 9,490.0 9,564.0 15:06 17:18 CT 4744 psi, @ 1.8 bpm, Free spin 940 psi - annular 4190 psi OBD CT -4-0 k lbs, WOB 1.6 to 2 k lbs. ROP 60 -10 fUhr On somthing hard starting 9546' 912/2018 912/2018 1.50 PRODS DRILL DRLG P BOBD, 1.77 bpm at 4,180 psi, 9,564.0 9,621.0 17:18 18:48 Diff--1,100 psi, WHP=403, BHP=4,165, IA=317, OA=62 9/2/2018 9/22018 0.20 PRODS DRILL WPRT P Pull Geo Wiper up hole PUW 61 k 9,621.0 9,520.0 18:48 19:00 9/22018 9/2/2018 0.20 PRODS DRILL WPRT P Wiper back in hole, RIW 12.4 k 9,520.0 9,621.0 19:00 19:12 9/2/2018 92/2018 2.50 PRODS DRILL DRLG P BOBD, 1.79 bpm at 4,650 psi, 9,621.0 9,702.0 19:12 21:42 Diff--1,120 psi, WHP=401, BHP=4,167, IA=320, OA=62 912/2018 9/22018 1.25 PRODS DRILL WPRT P Wiper to the window, PUW 55 k, jog 9,702.0 7,840.0 21:42 22:57 the 7" with sweeps 912!2018 9/212018 0.20 PRODS DRILL DLOG P Log the RA marker correction of plus 7,840.0 7,864.0 22:57 23:09 6.0' 9/2/2018 9/2/2018 0.20 PROD3 DRILL WPRT P Wiper back in hole, RIW 14 k 7,864.0 9,702.0 23:09 23:21 912/2018 913/2018 0.65 PRODS DRILL DRLG P BOBD, 1.77 bpm at 4,583 psi, Diff 9,702.0 9,714.0 23:21 00:00 886, WHP=324, BHP=4,188, IA=292, OA=61 9/3/2018 9/3/2018 1.25 PRODS DRILL DRLG P OBD, 1.77 bpm at 4,609 psi, 9,714.0 9,737.0 00:00 01:15 Diff--1,138 psi, WHP=332, BHP=4,197, IA=311, OA=61 9/3/2018 9/3/2018 1.20 PRODS DRILL DRLG P OBD, 1.78 bpm at 4,690 psi, Diff=863, 9,737.0 9,745.0 01:15 02:27 WHP=362, BHP=4,182, IA=374, OA=62 9/3/2018 9/3/2016 2.00 PRODS DRILL DRLG P OBD, 1.7 bpm at 4,576 psi, Diff--863 9,745.0 9,789.0 02:27 04:27 psi, WHP=367, BHP=4,190, IA=424, OA=62 9/3/2018 9/3/2018 1.70 PRODS DRILL DRLG P OBD, 1.82 bpm at 4,727 psi, Diff=883 9,789.0 9,843.0 04:27 06:09 psi, WHP=346, BHP=4,197, IA=489, OA=63 Page 16130 Report Printed: 911912018 Operations Summary (with Timelog Depths) 1H-21 ., e Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Stan Depth Stan Time End Torre Dw (m) Phase Op Code Activity Cosa Time P -T-% OperztiOn (flKB) End D" MKB) 9/3/2018 9/3/2018 2.50 FROM DRILL DRLG P PU to check parameters, CT Wt 52 k 9,843.0 9,908.0 06:09 08:39 lbs, IA531 psi, OA66 psi CT 4780 psi @ 1.80 bpm, Annular 4232 psi, free spin 960 psi OBD, CT Wt -2 k lbs, WOB 1 k lbs, ROP 10-60 9852' on something hard, high vibrations, drilled through 9861'- PU CT 52 k lbs, Choke acting up, swap to choke B, choke B acting up, blow down A. same issues on both, drill ahead 9/3/2018 9/312018 0.20 PRODS DRILL WPRT P On PU, rebooted the coke controler, 9,908.0 9,908.0 08:39 08:51 same issue, RBIH Running off choke Ain manual mode. 9/3/2018 9/3/2018 2.70 FROM DRILL DRLG P OBD, Ratty drilling, hard srtringers 9,908.0 9,987.0 08:51 11:33 with CT Wt -5k and 2 k WOB, ROP 2- 10 ft/hr for 1-2 feet followed by CT Wt -4 K, WOB 0.8 k lbs & 40-100 ft/hr for 10-15'. Average ROP over interval 29 fVhr 9/32018 9/32018 2.00 FROM DRILL DRLG P PU WT 57 k lbs, bypass screens, RIH 9,987.0 10,018.0 11:33 13:33 Wt 9 k lbs, CT 4240 psi, 1.71 bpm, Free spin 830 psi. WH 380 psi, annular 4218 psi. OBD, CT Wt -4 k lbs, WOB 1.4 k lbs, ROP9.2 Pump 15 bbls of 1 ppb beads, noticed .5 k lbs increase in WOB when on the hard stuff, no other observable benifds, CT weight, ROP, etc. Tried same pill with 4% lubes, less of a result. Beads in returns are causing annular flucuations that are hard to manage with the choke on manual. 9/3/2018 9/3/2018 4.00 PRODS DRILL DRLG P Drill ahead hard stringers followed by 10,018.0 10,100.0 13:33 17:33 soft. OBD, CT 4900 psi @ 1.78 pbm, Annular 4271 psi. WH 360 psi, IA 638, OA 70 psi CT Wt -4 k lbs, WOB 0.8 k lbs, ROP 8 Average ROP 20 ft/hr over interval. 9/3/2018 9/312018 1.80 PRODS DRILL WPRT P Wiper to the window, PUW 50 k, jog 10,100.0 7,710.0 17:33 19:21 1 the 7" with sweeps, up to 7,710' 9/3/2018 191312018 0.15 FROM DRILL SVRG P Reboot Choke software, (5 min) 7,710.0 7,840.0 19:21 19:30 1 9/3/2018 9/3/2018 0.20 FROM DRILL DLOG P Log the RA marker correction plus 4.0' 7,840.0 7,868.0 19:30 19:42 9/3/2018 9/3/2018 0.80 FROM DRILL WPRT P Wiper back in hole, RIW 12 k 7,868.0 10,100.0 19:42 20:30 9/3/2018 913/2018 1.15 PRODS DRILL DRLG P DODD, 1.78 bpm at 4,837 psi, 10,100.0 10,125.0 20:30 21:39 Diff -863, WHP=308, BHP=4,216, IA=548, OA=68 Average ROP 17 ft/hr over interval. Page 17130 Report Printed: 9/1 912 01 8 Uverations Summary (with Timelog Depths) 1H-21 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Stan Depth start Time End Tee our (hr) phase Op Code Activity Code Time P -T-% Operation W13) End Depth (ftKa) 9/3/2018 9/3/2018 1.80 PROD3 DRILL WPRT P Wiper up hole to the window, PUW 47 10,125.0 7,710.0 21:39 23:27 k **` Note: Pull heavy @ 7,896'- 7,906' MD, CTWS=65 k, DHWOB= minus 12 k, RBIH to the EOB, PUH w/sweeps, cleanup area between billet and winodw, jog the 7" with sweeps, 9/3/2018 914/2018 0.56 PROD3 DRILL TRIP P POOH 7,710.0 5,571.0 23:27 00:00 9/4/2018 9/4/2018 1.25 PROD3 DRILL TRIP P Continue trip to surface 5,571.0 78.2 00:00 01:15 9/4/2018 9/412018 1.75 PROD3 DRILL PULD P PUD (ODS -PDL) AL2 drilling BHA #20 78.2 0.0 01:15 03:00 Note: Checks failed, change of scope meeting in the ops cab, continue PUD w/failed checks checklist. 9/4/2018 9/4/2018 1.50 PROD3 DRILL PULD P PD, pre -loaded DS PDL BHA# 21, 0.0 78.1 03:00 04:30 stab INJH, surface test Coiltrak tools (good -test) 9/4/2018 9/4/2018 1.50 PROD3 DRILL TRIP P Tag up reset counters, RIH 78.1 7,298.0 04:30 06:00 9/4/2018 9/4/2018 0.20 PROD3 DRILL DLOG P Tie into the K1 for no correction. 7,298.0 7,585.0 06:00 06:12 914/2018 9/4/2018 1.50 PROD3 DRILL TRIP P PU Wt 43 k lbs, continue in hole, 7,585.0 10,125.0 06:12 07:42 window and billet clean. Still having erratic orienteer issues between the window and the billet. WOB spike @ 8187', 4 k & 8540, 1 k. Had to slow down running speed from 50 to 17 fV min - 9100 SD - 9245', 9759' 10024', 914/2018 9/4/2018 2.30 PROD3 DRILL TRIP P IA 152 psi, OA 59 psi, CT 5200 psi @ 10,125.0 10,251.0 07:42 10:00 1.77 bpm, free spinn 1100 psi, WH 301 psi, Annular 4262 psi. RIH Wt 8 k lbs OBD, CT Wt 3 k lbs, WOB 2 k lbs. ROP 30-160 fVhr Average ROP over interval - 54 Whir 9/4/2018 9/4/2018 2.80 PROD3 DRILL TRIP P OBD, CT Wt -3 k Ibs, WOB 0.6 k lbs, 10,251.0 10,360.0 10:00 12:48 ROP 40 ft/hr Surface and WOB slowly falling off. tried new mud pill, no change in parameters. PU weights - 55-59 k lbs Average ROP over interval - 39 ft/hr 9/4/2018 9/4/2018 1.20 PROD3 DRILL TRIP P start pumping 1 ppb beaded pills built 10,360.0 10,425.0 12:48 14:00 of used mud. beaded pill at the bit @ 10360'. Weights and ROPs improved. PU weights - 50 k lbs Average ROP over interval - 54 fVhr 9/4/2018 9/4/2018 2.20 PROD3 DRILL TRIP P Managed to break through what ever 10,425.0 10,525.0 14:00 16:12 was below us and get turned down below 92 °. CT Wt -6 to -1 k Ibs, WOB 2 to 0.6 k tbs, ROP 20 to 90 fUhr Settled in at - 86' PU Wt's 50 k Itis Average ROP over interval - 45 ft/hr 9/4/2018 191412018 0.30 PRO03 DRILL TRIP P PU on wiper trip #1 PU Wt 55 k IDS - 10,525.0 9,526.0 16:12 16:30 1000' Page 18130 Report Printed: 911912018 Operations Summary (with Timelog Depths) IH-21 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Stan Depth start Time Fid Time Dor(hr) Phase Op Code Activity Code Time P-T-X Operation (Pots) End Depth(aKB) 914/2018 9/4/2018 1.50 PROD3 DRILL TRIP P RBIH 9,526.0 10,522.0 16:30 18:00 SD, 9561', PU, 50 k lbs, slow RIH speed to -25 fUmin, continue in hole Pump beaded sweep. - 9/42018 9/4/2018 1.00 PROD3 DRILL WPRT P Pull wiper to the casing, PUW 63 k, 10,522.0 7,705.0 18:00 19:00 (Town working on well plan changes) 9/4/2018 9/42018 0.40 PROD3 DRILL WPRT P Jog the 7" x 2, PUW 42 k 7,705.0 7,840.0 19:00 19:24 9/4/2018 9/42018 0.20 PROD3 DRILL DLOG P Log the RA, plus 6', PUW 43 k 7,840.0 7,868.0 19:24 19:36 9/4/2018 91412018 2.50 PROD3 DRILL WPRT P Wiper back in hole, RIW= 0 k, send 5 7,868.0 10,525.0 19:36 22:06 x5 sweep with beads, work pipe back to bottom. 9/4/2018 9/5/2018 1.90 PROD3 DRILL DRLG P BOBD, 1.79 bpm at 5,262 psi, 10,525.0 10,610.0 22:06 00:00 Diff=1,150 psi, WHP=283, BHP=4,260.IA=575, OA=66 9/5/2018 9/5/2018 1.00 PROD3 DRILL DRLG P OBD, 1.77 bpm at 5,478 psi, 10,610.0 10,630.0 00:00 01:00 Diff-11,200, WHP=298, BHP=4,313, IA=622, OA=67 9/5/2018 9152018 1.00 PROD3 DRILL DRLG P OBD, 1.77 bpm at 5,472 psi, 10,630.0 10,667.0 01:00 02:00 Diff--1,300 psi, WHP=283, 6HP=4,302, IA=622, OA=67 9/5/2018 9/5/2018 0.50 PROD3 DRILL WPRT P PUW 80 k, Pull 1,000' wiper up hole to 10,667.0 9,660.0 02:00 02:30 9,660' 9/5/2018 9/5/2018 1.20 PRODS DRILL WPRT P Wiper back in hole, RIW 2-6 k CTSW 9,660.0 10,667.0 02:30 03:42 9/5/2018 9/5/2018 2.30 PROD3 DRILL DRLG P BOBD, 1.75 bpm at 5,437 psi, 10,667.0 10,712.0 03:42 06:00 Diff-1,211 psi, WHP=277, BHP=4,419, IA=566, OA=69 9/5/2016 9/52018 1.90 PROD3 DRILL DRLG P Drill ahead with poor weight transfer 10,712.0 10,756.0 06:00 07:54 Average over interval 23 fl/hr 915/2018 9/5/2016 0.60 PROD3 DRILL WPRT P PU Wt 65 k on BHA wiper - 106' 10,756.0 10,756.0 07:54 08:30 Pull to 10,665'try to RBIH, SID, PU 46 k lbs, to 10,650', RBIH 9/5/2018 9/5/2018 2.00 PROD3 DRILL DRLG P Drilling ahead with poor weight 10,756.0 10,821.0 08:30 10:30 transfer CT Wt -8 k lbs, WOB 2.4 k lbs after a pick up but falls to 200 lbs quickly after a pick up. Having issues turning around after picking up. PU weights climbed to 70 k. Mix and pump 1 ppg beaded pill in new mud w 4% total lubes. ROP increased, RIH ease increased, PU's fell to 55 k lbs. Able to turn up and break through hard layer that we'd been getting deflected off. Average over interval 32 R/hr 9/5/2018 9/5/2018 0.60 PROD3 DRILL WPRT P PU Wt 53k on 1000' wiper #2 10,821.0 9,823.0 10:30 11:06 Pull to 10,665'try to RBIH, SID, PU 46 k lbs, to 10,650', RBIH 9/5/2018 9/52018 0.60 PROD3 DRILL WPRT P RBIH RIH Wt fell from 13 k lbs at tum 9,823.0 10,821.0 11:06 11:42 around to 6 k lbs by 10,500' and 4 k lbs at 12 ft/mm and TD 9/5/2018 9/5/2018 3.30 PROD3 DRILL DRLG PCT 5,420 psi @ 1.72 bpm, annular 10,821.0 10,932.0 11:42 15:00 4370 psi, WH 240 psi, Free spin diff 11,70 psi. WOB -8 to 0 k lbs, WOB 2 to 0.6 k lbs, ROP 80 to Average over interval 33 ft/hr Page 19130 Report Printed: 9119/2018 Operations Summary (with Timelog Depths) 1H-21 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time our (hr) Phase Op Corte Actlary Code Time P-T-X Oparatim (MB) End Depth(ItKB) 9/512018 9/5/2018 2.50 PRODS DRILL DRLG P OBD, CT 5533 psi, @ 1.73 bpm, WH 10,932.0 11,007.0 15:00 17:30 287 psi, annular 4278 psi. CT Wt -7.5 k lbs, WOB 1.3 k lbs, ROP 35 R/hr. Bleed IA from 745 to 586 psi - diesel. Average over interval 30 R/hr 9/5/2018 9/5/2018 5.75 PRODS DRILL DRLG P OBD, 1.8 bpm at 5,265 psi, Diff-1,207 11,007.0 11,130.0 17:30 23:15 psi, WHP=246, BHP=4,268, IA=574, OA=74 *** Note: Losses 0.6 bpm slowly healing up to 0.1 bpm loss rate @ 11,110' 9/5/2018 9/5/2018 0.25 PRODS DRILL DRLG P TD AL2 Lateral, PUH slowly, PUW 55 11,130.0 11,130.0 23:15 23:30 k, circulate beads down coil. 9/5/2018 9/6/2018 0.50 PRODS DRILL WPRT P Perform Swab wiper, laying in beads 11,130.0 9,641.0 23:30 00:00 as we POOH to surface. 9/6/2018 9/6/2018 2.00 PRODS DRILL WPRT P Continue POOH 9,641.0 3,500.0 00:00 02:00 9/6/2018 9/6/2018 1.10 PRODS DRILL WPRT P Perform jog back in hole 500' 3,500.0 78.1 02:00 03:06 9/6/2018 9/6/2018 0.40 PRODS DRILL SVRG P Tag up, inspect INJH, repair CTES 78.1 78.1 03:06 03:30 counter, reset counters 9/6/2018 9/6/2018 1.25 PRODS DRILL TRIP P RBIH, to confirm TD 78.1 7,570.0 03:30 04:45 9/6/2018 9/6/2018 0.20 PRODS DRILL DLOG P Log the K1 marker correction of plus 7,570.0 7,753.0 04:45 04:57 1.0' 9/6/2018 9/6/2018 0.20 PRODS DRILL CTOP P Obtain Static BHP 11.39 ppg pressure 7,753.0 7,753.0 04:57 05:09 continued to drop, sensor Depth 6,484.67', AP=3,840 9/6/2018 9/6/2018 1.90 PRODS DRILL TRIP P Continue to RIH, Window clean, 705 7,753.0 11,128.0 05:09 07:03 Ib WOB bobble while passing the billet and a nother @ 8519'. Coil weight fell off rapidly from 9700' to 10,213' where we sat down. PU 45 k lbs. continue to RIH reducing tripping speed to - 14 ft/.min. WOS climbed stedily from 10,500' to 10,700' then fell off quickly. Tqag bottom at 11128', PU 43 k lbs, S/D again with same results. 9/6/2018 9/6/2018 3.10 PRODS DRILL DISP P PU 43 k lbs, Stage beaded liner 11,128.0 70.0 07:03 10:09 running pill to the bit, POOH laying in liner running pill to 7,680' followed by 11.7 ppg KW fluid. Painted yellow TD flag @ 10176' Saw slight neg WOB spikes as we pulled through both the billet and window. Painted white window flag @ 6778' 9/6/2018 9/6/2018 1.30 PRODS DRILL DISP P PJSM, bump up, flow check-good, 70.0 0.0 10:09 11:27 PUD BHA#21 Bit came out graded 1-3 LT, lost tooth on gauge reamers. Well tight, no losses. 9/6/2018 9/6/2018 0.30 COMPZ3 DRILL BOPE P Perform BOP function test. 0.0 0.0 11:27 11:45 9/6/2018 9/6/2018 0.50 COMPZ3 CASING PUTB P Prep floor for running liner. PJSM. 0.0 0.0 11:45 12:15 9/6/2018 9/6/2018 1.70 COMM CASING PUTB P Pick up an run 30 joints (937.63') 2-3/8 0.0 938.9 12:15 13:57 ST-L 4.6 Ib/ft L-80 slotted liner with a non-ported bullnose under a shorty deployment sleeve. AL2 completion run #1 length over all - 938.87'- kick drill, AAR, clean floor from running liner. Page 20130 Report Printed: 9/19/2018 Operations Summary (with Timelog Depths) 1 H-21 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Sten Depth StartTime EM Tme Our(hr) Phece Dip Cale Activity Cafe Time P -T -X operation (flKB) EM Depth(ftKB) 9/6/2018 9/6/2018 1.00 COMPZ3 CASING PULD P PU / MU BHA# 22, AL2 completion 936.0 983.1 13:57 14:57 run #1, swap checks, skid cart, stab on, test good, bump up, set counters, 9/6/2018 9/6/2018 1.30 COMPZ3 CASING RUNL P RIH w AL2 completion run #1 983.1 7,673.0 14:57 16:15 9/6/2018 9/6/2018 0.20 COMPZ3 CASING DLOG P PU 45 k lbs, lie into window flag for- 7,673.0 7,683.0 16:15 16:27 4.4' correction 9/6/2018 9/6/2018 1.30 COMPZ3 CASING RUNL P Continue to RIH, carded 16 k coil wt 7,683.0 11,128.6 16:27 17:45 all the way to bottom. Tag up, PU 53 k lbs, pumps on PU 43 k lbs. 9/6/2018 9/6/2018 2.25 COMPZ3 CASING TRIP P Reset counters, POOH painting flags. 11,128.6 44.2 17:45 20:00 9/6/2018 9/6/2018 0.50 COMPZ3 CASING OWFF P Check well for flow, PJSM 44.2 44.2 20:00 20:30 9/6/2018 916/2018 0.25 COMPZ3 CASING PULD P LD setting tools on a dead well 44.2 0.0 20:30 20:45 9/6/2018 9/6/2018 2.25 COMPZ3 CASING PUTB P PJSM, PU/MU AL2#2 Liner segment 0.0 1,376.4 20:45 23:00 45 its of slotted liner, w/ported bullnose, and shorty deployment sleeve. 9/612018 916/2018 0.75 COMPZ3 CASING PULD P PJSM, PU/MU Coiltrak tools (good- 1,376.4 1,420.6 23:00 23:45 test) 9/612018 9/7/2018 0.25 COMPZ3 CASING RUNL P RIH, with BHA #23, AL2 liner segment 1,420.6 23:45 00:00 #2 w/45 its of slotted liner, shorty deployment sleeve, and ported bullnose. 9/712018 9/712018 1.00 COMM CASING RUNL P Continue IH with BHA #23 2,596.0 7,705.0 00:00 01:00 9/712018 9/7/2018 0.15 COMP23 CASING RUNL P Weight check PUW 49 k, correct to 7,705.0 7,705.0 01:00 01:09 1 the EOP flag minus 8.0' 9/7/2018 9/7/2018 0.35 COMM CASING RUNL P Continue IH 7,705.0 9,067.0 01:09 01:30 9/7/2018 9/7/2018 0.75 COMPZ3 CASING RUNL P Work pipe down hole, PUW 50-58 k 9,067.0 9,343.0 01:30 02:15 9/712018 9/712018 0.30 COMPZ3 CASING RUNL P Continue RIH 9,343.0 10,189.1 02:15 02:33 9/7/2018 9/7/2018 1.30 COMPZ3 CASING RUNL P Set down 10,189.13', PUW 58 k, set 10,189.3 8,812.7 02:33 03:51 back down 5.4 k, Bring pump on 1.45 bpm at 3,291 psi, 1.06 bpm returns, PUW 39 k, remove liner length from counters, finish building liner running pill. 9/7/2018 9/7/2018 2.30 COMPZ3 CASING TRIP P POOH, laying in 15 bbl beaded liner 8,812.7 40.0 03:51 06:09 1 running pill 9/7/2018 9/7/2018 0.60 COMM CASING PULD P Bumped up, flow check good, hole 50.0 0.0 06:09 06:45 - static. 917/2018 9/7/2018 0.30 COMPZ3 CASING PUTS P Prep floor for liner running, PJSM. 0.0 0.0 06:45 07:03 9/7/2018 9/7/2018 1.00 COMPZ3 CASING PUTS P Pick up an run 10 joints (312.94') 2-3/8 0.0 324.8 07:03 08:03 ST -L 4.6 Ib/fl L-80 slotted liner with a non -ported bullnose under an anchored liner top billet. AL2 completion run #3 length over all - 324.76' - clean floor from running liner. 9/7/2018 9/7/2018 1.00 COMPZ3 CASING PULD P PU BHA #24, stab on, set counters 324.8 385.7 08:03 09:03 9/7/2018 9/712018 1.70 COMPZ3 CASING RUNL P RIH w AL2 -01 section #3, EDC open, 385.7 7,785.0 09:03 10:45 Page 21130 ReportPrinted: 9/1912016 Operations Summary (with Timelog Depths) 1H-21 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Sten Depth Stan Tme Ertl Time Der(ty) priest, Op Code Activity Cale- Time P -T -X Operation (ftKB) End Depth MI(S) 9/7/2018 917/2018 0.20 COMPZ3 CASING DLOG P Tie in to window flag, -25' correction, 7,785.0 7,785.0 10:45 10:57 discuss and compare, not making a correction, continue on to the K1. PU Wt 43 k lbs. Park Close EDC. RIH to K1 9/7/2018 9/7/2018 0.10 COMPZ3 CASING RUNL P Continue to RIH w AL2 -01 section#3, 7,785.0 7,885.0 10:57 11:03 EDC open, 9/7/2018 9/7/2018 0.10 COMPZ3 CASING DLOG P Log K1 + 1' correction. 7,885.0 7,909.0 11:03 11:09 9/7/2018 9/7/2018 0.60 COMPZ3 CASING RUNL P RIH, lag up 8817.5 PU 48 k lbs, RBIH 7,909.0 8,812.0 11:09 11:45 S/D 3.67 K lbs WOB, on line with the pumpPU 42 k lbs, Set Anchored billet slips oriented LS 9/7/2018 9/7/2018 1.70 COMPZ3 CASING TRIP P POOH 8,812.0 60.0 11:45 13:27 9/7/2018 9/7/2018 1.00 COMPZ3 CASING PULD P Flow check, inspected pipe 27' back to 60.0 0.0 1327 1427 coil connector wall thickness 1.81". LD BHA #24 over a dead well. - Crew change. 9172018 9/7/2018 1.00 PROD4 STK PULD P PU BHA#25, AL@ -01 latteral drilling 0.0 80.0 14:27 1527 1 assembly, check pack offs, 9/72018 9/7/2018 1.60 PROD4 STK TRIP P RIH, shallow test occilator tool, light 80.0 7,565.0 15:27 17:03 vibration felt on the coil at surface. Monitored frequency on pipe shed computer @ 1.5 bpm - 3500 CT pressure, 875 diff and 1.8 bpm - 5400 CT pressure, 1684 psi diff. Continue to RIH. 9/7/2018 917/2018 0.20 PROD4 STK DLOG P Tie into K1 for zero correction 7,565.0 7,595.0 17:03 17:15 9/7/2018 9/72018 1.20 PROD4 STK TRIP P Continue to RIH, displacing well to 7,565.0 7,595.0 17:15 1827 drilling Fluid, 9R/2018 - 9/7/2018 0.15 PROD4 STK TRIP P Dry tag TOB @ 8,492' 7,595.0 8,492.0 18:27 18:36 917/2018 9/7/2018 1.50 PROD4 STK KOST P PUH, and start kicking off billtet @ 8,492.0 8,496.6 18:36 20:06 8491.5', 1.75 bpm at 5,172 psi, WHP=181, BHP=4,216, IA=4, OA=54 9/7/2018 9/7/2018 0.15 PROD4 STK KOST P Stall Motor, PUH 57 k, minus 2.3 k 8,496.6 8,473.0 20:06 20:15 DHWOB 9/712018 9/7/2018 0.15 PROD4 STK KOST P RBIH, RIW 15 k, 1.81 bpm @ 5,337 8,473.0 8,496.0 20:15 20:24 psi, Diff -1,230 psi, WHP=100, BHP=4,095, IA=5, OA=54 9/7/2016 9/7/2018 0.15 PROD4 STK KOST P Stall Motor, PUW 47 k, PUH to 8,478' 8,496.0 8,478.0 20:24 20:33 9/7/2018 9/7/2018 0.15 PROD4 STK KOST P RBIH, 1.8 bpm @ 5,387 psi, 8,478.0 8,500.0 2033 20:42 Diff -1,210, WHP=124, BHP=4,235, IA=8, OA=54 9/7/2018 9/7/2018 0.60 PROD4 STK DRLG P Drill ahead 8,500.0 - 8,504.0 20:42 21:18 9/7/2018 9/7/2018 0.15 PROD4 STK DRLG P PUH, PUW 51 k, dry drift kickoff point 8,504.0 8,504.0 21:18 21:27 (clean) 917/2018 9/7/2018 0.45 PROD4 STK DRLG P BOBD, 1.8 bpm at 5,337 psi, 8,504.0 8,511.1 21:27 21:54 Diff=1,200, WHP=138, BHP=4,124, IA=24, OA=56 917/2018 9/8/2018 2.10 PROD4 STK WPRT T Stall motor, PUW=70 k, seems we are 8,511.1 8,511.1 21:54 00:00 detained, unable to turn orienter, work pipe, still stuck, make call to town team, discuss plan forward, bring pump on-line, 1.5 bpm at 4,830 psi, motor no longer stalled, circulate 5x5 around, Page 22130 Report Printed: 9119/2018 a Operations Summary (with Timelog Depths) 7777 1 H-21 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Stan Depth Start Time End Tare Dur (hr) Phase Op Code Activity Code Time P -T -x Operation (Wls) EM Depth MKB) 9/8/2018 9/8/2018 1.00 PROD4 STK TRIP T Continue working pipe, spot lube pill 8,511.1 8,511.0 00:00 01:00 around BHA, continue working pipe. still detained. 9/8/2018 9/8/2018 1.00 PROD4 STK TRIP T Circulate lube pill up hole, work pipe, 8,511.0 8,511.0 01:00 02:00 still detained. Rotate HOT, torque seen on coil. no movement on motor. 9/8/2018 9/8/2018 0.75 PROD4 STK TRIP T Circulate 2nd 5x5 sweep 8,511.0 8,511.0 02:00 02:45 9/8/2018 9/8/2018 1.10 PROD4 STK TRIP T Work pipe, Pull 86 k, minus 16.5 k 8,511.0 8,511.0 02:45 03:51 DHWOB 9/8/2018 9/8/2018 0.50 PROD4 STK TRIP T Continue POOH 8,511.0 7,753.0 03:51 04:21 9/8/2018 9/8/2018 1.60 PROD4 STK TRIP T Open EDC, coulinue POOH 7,753.0 70.0 04:21 05:57 9/8/2018 9/8/2018 1.50 PROD4 STK PULD T Bump up, PUD BHA # 25. Bit had 70.0 0.0 05:57 07:27 chipped reamers but did not have damage indicating we had spun it against liner or slips. 918/2018 9/8/2018 1.40 PROD4 STK PULD T LD pre loaded BHA in DS PDL; 0.0 96.1 07:27 08:51 dropped T weight bar and 1.4' knuckle out of PDL. PU BHA# 26 to the HOT. Hung off three pups, LOA 23.66' with a ported bull nose over the hole (9.84', 7.84', 5.66'). Picked J setting tool / billet / open hole anchors. PD, BHA, stab on, verify EDC open, bump up set counters. 9/8/2018 9/8/2018 2.60 PROD4 STK TRIP T RIH, 96.1 7,600.0 08:51 11:27 9/8/2018 9/8/2018 0.20 PROD4 STK CLOG T Tie into the K1 for no correction. 7,600.0 7,620.0 11:27 11:39 9/8/2018 918/2018 0.60 PROD4 STK TRIP T Continue to RIH with anchored billet 7,620.0 8,509.0 11:39 12:15 into 7" @ 7806', PU Wt 45 k lbs, close ECD, RIH to 8504', PU 46 k lbs, RBIH, Bit depth 8502.5', PU to neutral weight, online w pumps, shear - 4300 psi, RIH in attempt to stack weight. Push to bit depth of 8509' with -500 lbs WOB. '* Note TOB @ 8474' 9/8/2018 9/8/2018 1.50 PROD4 STK TRIP T POOH 8,509.0 71.0 12:15 13:45 9/812018 9/8/2018 1.10 PROD4 STK PULD T Bump up space out, PUD BHA # 26 71.0 0.0 13:45 14:51 9/8/2018 9/8/2018 1.10 PROD4 STK SVRG T Wait on arrival of billet w open hole 0.0 0.0 14:51 15:57 anchors. 9/6/2018 9/8/2018 1.60 PROD4 STK PULD T PU & PD BHA# 27. Open hole 0.0 75.5 15:57 17:33 anchored billet w 2 pups 7.72', & 1.57' with a ported bull nose. check pack offs 9/8/2018 9/8/2018 1.75 PROD4 STK TRIP T RIH, with BHA#27 75.5 7,580.0 17:33 19:18 9/8/2018 9/8/2018 0.20 PROD4 STK DLOG T Log the K1 marker correction of plus 7,580.0 7,605.0 19:18 19:30 05, PUW 43 k, close EDC 9/8/2018 9/8/2018 0.50 PROD4 STK TRIP T Continue IH, set down 8,474', 7,605.0 8,473.1 19:30 20:00 9/8/2018 9/8/2018 0.25 PROD4 STK TRIP T PUW 49 k, set back down 2.2 k, PUH 8,473.1 8,452.3 20:00 20:15 46 k, 0.5 k DHWOB, bring pump up to shear 4,900 psi 9/8/2018 9/8/2018 1.75 PROD4 STK TRIP T PUH=48 k, POOH 8,452.3 61.2 20:15 22:00 9/8/2016 9/8/2018 0.92 PROD4 STK PULD T Tag up space out, PUD & LD setting 61.2 0.0 22:00 22:55 I tools Page 23130 Report Printed: 9/1 912 01 8 Operations Summary (with Timelog DeNths) 1 H-21 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Depth I Start Time End Tme Dur(hr) Phase Op Code AzWily Cede Tim P -T -X Operation End Depth (MB) 9/8/2018 9/8/2018 0.30 PROD4 STK PULD T Reconfigure BHA (MU motor and bit) 0.0 0.0 22:55 23:13 9/8/2018 9/9/2018 0.78 PROD4 STK PULD T PD kickoff drilling BHA #28 0.0 0.0 23:13 00:00 9/9/2018 9/9/2018 0.50 PROD4 STK PULD T MU Upper Quick, surface test Coiltrak 0.0 78.1 00:00 00:30 - tools (good -test) 9/9/2018 9/9/2018 1.50 PROD4 STK TRIP T RIH, w/drilling BHA# 28, test agitator 78.1 7,570.0 00:30 02:00 1 1 1 @ 500' (good -test) 9/9/2018 9/9/2018 0.15 PROD4 STK DLOG T Log the Kt marker correction of zero 7,570.0 7,590.0 02:00 02:09 9/9/2018 9/9/2018 0.20 PROD4 STK TRIP T Continue IH 7,590.0 8,452.5 02:09 02:21 9/9/2018 9/9/2018 0.15 PROD4 STK TRIP T Dry tag TOB @ 8452.5' 8,452.5 8,436.0 02:21 02:30 9/9/2018 9/9/2018 0.15 PROD4 STK TRIP T Bring pump on-line @ 1.80 bpm at 8,436.0 8,453.7 02:30 02:39 5,294 psi, Diff --1,360 psi, WHP=336, IA=O, OA=49 9/9/2018 9/9/2018 0.30 PROD4 STK KOST T Attempt to find billet, 150° ROHS as 8,453.7 8,455.0 02:39 02:57 per RP, chase WOB to 8,455' 9/9/2018 9/9/2018 1.50 PROD4 STK KOST P Start time milling 1.79 bpm @ 5,475 8,455.0 8,458.0 02:57 04:27 psi, Diff -1344 psi, WHP=149, BHP=4,157, IA=O, OA=53 9/9/2018 9/9/2018 1.60 PROD4 DRILL DRLG P Start drilling ahead 16 fph 1.79 bpm at 8,458.0 8,565.0 04:27 06:03 5,438 psi, Diff --1,360 psi, WHP=149, BHP=4,173, IA=11, OA=55 9/9/2018 9/9/2018 0.20 PROD4 DRILL WPRT P PU 48 k His, PUH, to 8412', billet 8,565.0 8,565.0 06:03 06:15 1clean, RBIH dry drift, window clean. 9/9/2018 9/9/2018 1.10 PROD4 DRILL DRLG P CT 4205 psi @ 1.77 bpm, Free spin 8,458.0 8,565.0 06:15 07:21 diff 1348 psi, IA 95 psi, OA 58 psi. OBD, CT wt 15 k lbs, WOB 1.8 k lbs, ROP 40 - 300 N hr. 9/9/2018 9/9/2018 1.40 PROD4 DRILL DRLG P Having difficulty dropping angle. cut 8,458.0 8,720.0 07:21 08:45 rate from 1.8 to 1.5 bpm. Targeting higher WOB. 8688' WOB climing, held WOB - 34 k Ib to 8562'. Allowed to mill off, time drilled to 8720' 9/9/2018 919/2018 1.00 PROD4 DRILL DRLG P PU to acquire new parameters, Ct 8,720.0 8,756.0 08:45 09:45 4558 psi @ 1.5 bpm, annular 4206 psi. OBD, targeting 34 k LBS WOB. Drilled ahead with angle slowly dropping. 9/9/2018 9/9/2018 6.10 PROD4 DRILL DRLG P PU and increase pump rate to 1.78 8,756.0 8,860.0 09:45 15:51 bpm. Ct 5405 psi @ 1.78 bpm, free spin diff 1240 psi, annular 4244 psi. OBD, Cl Wt 15 k lbs, WOB 3.5 k lbs, ROP 10 ft(hr Drilled through two sections of wrapped gamma @ 8760', and 8810' 9/9/2018 9/9/2018 1.00 PROD4 DRILL DRLG P ROP climbed rapidly from 25 to over 8,860.0 8,935.0 15:51 16:51 120 ft/hr. CT 5815 psi, @ 1.79 bpm, Annular 4148 psi, IA 457 psi, OA 67 psi CT Wt 1.4 k His, WOB 3.4 k Itis, ROP 61 ft/hr Chase sweeps to the bit. 9/9/2018 191912018 0.35 PROD4 DRILL WPRT P PU 53 k Ilos, wiper#1,NOV agitator 8,935.0 8,477.0 16:51 17:12 11 working!, swap computers 9/9/2018 9/9/2018 0.80 PROD4 DRILL WPRT P Wiper back in hole, RIW 15 k 8,477.0 8,935.0 17:12 18:00 1 Page 24/30 ReportPrinted: 911912018 Operations Summary (with Timelog Depths) 1 H-21 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK nrne Log Stan DOPM Stat Time Endnme Dur" Phase Op Code Activity Code Time P-T-x Operation MM) End Depth (M) 9/9/2018 9/9/2018 3.75 PROD4 DRILL DRLG P BOBD, 1.76 bpm @ 5,647 psi, 8,935.0 9,436.0 18:00 21:45 Diff-1,390 psi, WHP=181, BHP=4,244, IA=356, OA=67, Avg.ROP=80 fph ." Note: New Mud @ 9,089' 9/9/2018 9/9/2018 0.50 PROD4 DRILL WPRT P Wiper up hole to the window, PUW 53 9,436.0 8,100.0 21:45 22:15 k 9/9/2018 9/9/2018 0.15 PROD4 DRILL WPRT P Perform Jog in hole 100'@ 50 fpm 8,100.0 8,204.0 22:15 22:24 - 9/9/2018 9/9/2018 0.80 PROD4 DRILL WPRT P Continue wiper up hole, PUW 16 k, 8,204.0 7,845.0 22:24 23:12 jog clean 7" with sweeps 9/9/2018 9/9/2018 0.20 PROD4 DRILL DLOG P Log the RA marker correction of plus 7,845.0 7,869.0 23:12 23:24 7.0' 9/9/2018 9/10/2018 0.60 PROD4 DRILL WPRT P Continue Wiper back in hole, RIW 15 7,869.0 9,436.0 23:24 00:00 k 9/10/2018 9/10/2018 0.30 PROD4 DRILL DRLG P BOBD, 1.79 bpm at 5,160 psi, 9,436.0 9,556.0 00:00 00:18 Diff=1,305 psi, WHP=438, BHP=4,338, IA=218, OA=64, — Note: Needing to get build and tum. 9/10/2018 9/10/2018 0.15 PROD4 DRILL WPRT P PUW 52 k. BHA wiper up hole, PUW 9,556.0 9,556.0 00:18 00:27 1 52 k 9/10/2018 9/10/2018 0.20 PROD4 DRILL DRLG P BOBD, 1.78 bpm at 5,065 psi, 9,556.0 9,583.0 00:27 00:39 Diff=1,365, WHP=357, BHP=4,272, IA=353, OA=66 9/10/2018 911012018 0.15 PROD4 DRILL WPRT P PUW 52 k, work pipe x 3, not able to 9,583.0 9,583.0 00:39 00:48 build angle or tum to the east. 9/1012018 9/1012018 0.20 PROD4 DRILL DRLG P BOBD, 1.78 bpm at 5,065 psi, 9,583.0 9,614.0 00:48 01:00 Diff-1,365, WHP=357, BHP=4,272, IA=353, OA=66, CTSW - 5 k 9/1012018 9/10/2018 0.15 PROD4 DRILL WPRT P PUJ 52 k, work pipe x 3, not able to 9,614.0 9,614.0 01:00 01:09 1 build angle or turn to the east. 9/10/2018 9/10/2018 0.50 PROD4 DRILL DRLG P BOBD, 1.79 bpm at 5,090 psi, 9,614.0 9,639.0. 01:09 01:39 Diff-1,360 psi, WHP=357, BHP=4,257, IA=357, OA=66 9/10/2018 9/10/2018 0.20 PROD4 DRILL WPRT P PUW 52 k, work pipe x 3. getting turn, 9,639.0 9,725.0 01:39 01:51 still having trouble building angle. 9/10/2018 9/10/2018 0.30 PROD4 DRILL DRLG P BOBD, 1.79 bpm at 5,090 psi, 9,725.0 9,820.0 01:51 02:09 Diff--1,360 psi, WHP=357, BHP=4,257, IA=357, OA=66 9/10/2018 9/10/2018 0.15 PROD4 DRILL WPRT P PUW 55 k, work pipe x 3, not able to 9,820.0 9,820.0 02:09 02:18 1 build, 9/1012018 9/1012018 0.30 PROD4 DRILL DRLG P BOBO, 1.79 bpm at 5,035 psi, 9,820.0 9,836.0 02:18 02:36 Diff-1,208 psi, WHP=366, - BHP=4,337, IA=360, OA=66 9/10/2018 9/10/2018 0.40 PROD4 DRILL WPRT P 1,000', wiper up hole, PUW 9,836.0 8,841.0 02:36 03:00 9/10/2018 9/10/2018 0.30 PROD4 DRILL WPRT P Wiper back in hole, RIW 14 k, make 8,841.0 9,818.0 03:00 03:18 call to town for plan forward, decision was made to POOH for correction run. 9/10/2018 9/10/2018 3.00 PROD4 DRILL TRIP T Pump 5x5 sweep, POOH to surface 9,816.0 76.9 03:16 06:18 9/10/2018 9/10/2018 1.20 PROD4 DRILL PULD T Bump Up, PUD following failed EDC 76.9 0.0 06:18 07:30 procedure, LDBHA 9/10/2018 9/10/2018 0.70 PROD4 DRILL PULD T PD BHA #290.8°AKOw RR HC 0.0 78.2 07:30 08:12 P104 cutter bit, stab injector, bump up, set counters. 9/10/2018 9/10/2018 1.50 PROD4 DRILL TRIP T Verify SSSV pressure, RIH, Gose 78.2 7,570.0 08:12 09:42 EDC. shallow test agitator - good. continue in hole. Page 25130 ReportPrinted: 9119/2018 Operations Summary (with Timelog Depths) 1 H-21 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Stan Depth Start Time EndTime Dur (hr) Phase Op code Activity Code Tuna P -T -X Opendion (MB) End Depth(fIKS) 9/10/2018 9/10/2018 0.20 PROD4 DRILL DLOG T Tie into the K1 + 0.5' correction. 7,570.0 7,631.6 09:42 09:54 9/10/2018 9/10/2018 0.80 PROD4 DRILL TRIP T PU Wt, 44 k Its, RIH, 7,631.6 9,836.0 09:54 10:42 9/10/2018 9/10/2018 0.40 PROD4 DRILL DRLG T CT 4750 psi, @ 1.8 bpm, free spin 9,836.0 9,877.0 10:42 11:06 857 psi, annular 4180 psi,WH 255 psi, Is 110 psi, OA 60 psi. OBD, CT Wt 9 k lbs, WOB 1.5 k lbs, ROP 50-200 fUhr. Directional driller attempted to steer south, dropped angle rapidly. PU 50 k lbs, reduced rate to 1.50 bpm attempting to target increased WOB, near bit Inc continuing to fall rapidly. 9/10/2018 9/10/2018 0.90 PROD4 DRILL WPRT T PU Wt 50 k lbs, Geo wiper. Rig Geo 9,877.0 9,877.0 11:06 12:00 and DO greed to put 90% into turn to the south, RBIH, Drill ahead, PU, 50 k Itis, Geo wiper #2, Last survey to the left. RBIH, PU, to resurvey, RBIH. 9/10/2018 9/10/2018 0.20 PROD4 DRILL DRLG T CT 3967 @ 1.49 bpm, free spin 654 9,877.0 9,962.0 12:00 12:12 psi, WH 276 psi, annular 4198 psi Ct Wt 7 k lbs, WOB .57 k lbs, ROP 200 ft/hr. 9/10/2018 9/10/2018 0.30 PROD4 DRILL WPRT T PU 50 k lbs, DO wiper to discuss close 9,962.0 9,962.0 12:12 12:30 approach. Discuss w engineering potential close approach to hard line on the north. Decision made to drill ahead. RBIH 9/10/2018 9/10/2018 2.00 PROD4 DRILL DRLG T OBD, CT 3900 psi @ 1.50 bpm, free 9,877.0 10,195.0 12:30 14:30 spin 580 psi, Annular 4299 psi, WH 364 psi CT 1.8 k lbs, WOB 0.44 k lbs, ROP 115 R/hr 13:50 and 10,141' increase rate to 1.78 bpm, WH 316, Annular 4307 psi, CT -7 k lbs, WOB 0.34 k Itis, ROP 110 f1sec. Pump 5 x 5 sweep Average ROP over interval - 160 f/hr 9/10/2018 9/10/2018 0.20 PROD4 DRILL WPRT T PU 53 k lbs, Pull to 9994'- 201' wiper 10,195.0 10,195.0 14:30 14:42 RBIH 9/10/2018 9/10/2018 1.40 PROD4 DRILL DRLG T RBIH Wt 4 k lbs, Ct 4847 psi, @ 1.81 10,195.0 10,270.0 14:42 16:06 bpm, free spin 887 psi, WH 257 psi, Annular 4219 psi. OBD, CT Wt -6.4 k lbs, WOB 0.9 k Ib, ROP 33 ft/hr. 9/10/2018 9/10/2018 0.20 PROD4 DRILL WPRT T PU 53 k Ibs,- 1000' wiper 10,195.0 8,992.0 16:06 16:18 Pull through low spot @ 9150' Pump 10 MIS 1 ppg beds 9/10/2018 9/10/2018 0.80 PROD4 DRILL WPRT T RBIH, S/D 9090' PU 58 lbs, to 9031', 8,992.0 10,195.0 16:18 17:06 RBIH, SO @ 9588'W WOB. SO @ 9679' 9/10/2018 9/10/2018 2.00 PROD4 DRILL DRLG T RBIH Wt 4 k Ibs, Ct 4847 psi, @ 1.81 10,195.0 10,404.0 17:06 19:06 bpm, free spin 887 psi, WH 257 psi, Annular 4219 psi. OBD, CT Wt -6.4 k lbs, WOB 0.9 k Ib, ROP 30 -170 ft/hr. Still drifting north, tum straight up, reduce pump rate, try sweeps to get more WOB. No sucess, 9/10/2018 9/1012018 3.10 PROD4 DRILL WPRT T PU Wt 53 k lbs, POOH for higher bend 10,404.0 74.4 19:06 22:12 motor. Page 26130 ReportPrinted: 911912018 Operations Summary (with Timelog Depths) 1 H-21 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log SWrtTlme EM Time our (hr) Phase Op Come Aetrvity Co Tune P-T-% Operation SM,1 Depth Me) End Depth (M(B) 9/10/2018 9110/2018 1.30 PROD4 DRILL PULD T PUD BA #29, 74.4 0.0 22:12 23:30 9/10/2018 9/11/2018 0.50 PROD4 DRILL PULD T PD BA#30, 1.2 ° AKO 0.0 74.4 23:30 00:00 9/11/2018 9/11/2018 0.50 PROD4 DRILL PULD T Stab INJH, check pac-offs (good) 78.2 78.2 00:00 00:30 9/11/2018 9/1112018 1.25 PROD4 DRILL TRIP T RIH, with BHA# 30 78.2 7,570.0 00:30 01:45 9/11/2018 9/11/2018 0.20 PROD4 DRILL DLOG T Log the K1 marker with no correction, 7,570.0 7,590.0 01:45 01:57 1 PUW 48 k, close EDC 9/11/2018 9/11/2018 1.25 PROD4 DRILL TRIP T Continue IH, steering through 9,090' 7,590.0 10,404.0 01:57 03:12 and 9,590' area. 9/11/2018 9/11/2018 1.00 PROD4 DRILL DRLG T OBD, 1.79 bpm at 5,231 psi, 10,404.0 10,472.0 03:12 04:12 Diff-'1,350 psi, WHP=213, BHP=4,342, IA=36, OA=58 9/11/2018 9/11/2018 0.40 PROD4 DRILL WPRT T Wiper up hole, PUW=53 k 10,472.0 9,925.0 04:12 04:36 9/11/2018 9/11/2018 0.40 PROD4 DRILL WPRT T Wiper back in hole, RIW 5 k 9,925.0 10,472.0 04:36 05:00 9/11/2018 9111/2018 0.80 PROD4 DRILL DRLG T BOBD, 1.79 bpm at 5,466 psi, 10,472.0 10,491.0 05:00 05:48 Diff--1,244 psi, WHP=221, BHP=4,351, IA=181, OA=58 9/11/2018 9/11/2018 1.50 PROD4 DRILL WPRT T Wiper up hole, PUW=53 k, jet the 7" 10,491.0 7,806.0 05:48 07:18 with sweeps 9/11/2018 9/11/2018 0.15 PROD4 DRILL WPRT T After dicussing with town team, 7,806.0 7,565.0 07:18 07:27 decision was made to RBIH to drill ahead 9/11/2018 9111/2018 0.20 PROD4 DRILL DRLG P Log the K1 correction plus 6.0' 7,565.0 7,598.0 07:27 07:39 9/11/2018 9/11/2018 1.40 PROD4 DRILL WPRT P Continue RIH 7,598.0 10,491.0 07:39 09:03 9/11/2018 9/11/2018 3.80 PROD4 DRILL DRLG P BOBD, 1.78 bpm at 5,293 psi, 10,491.0 10,610.0 09:03 12:51 Diff=1,272 psi, WHP=109, BHP=4,292, IA=263, OA=64 9111/2018 9/11/2018 1.70 PROD4 DRILL WPRT P BHA wiper up hole, PUW 58 k 10,610.0 10,510.0 12:51 14:33 9/11/2018 9/11/2018 0.50 PROD4 DRILL DRLG P BOBD. 1.80 bpm at 5,213 psi, 10,510.0 10,666.0 14:33 15:03 Diff-960 psi, WHP=159, BHP=4,316, IA=519, OA=69, trying to hold 85°-87° 9111/2018 9/11/2018 1.00 PROD4 DRILL DRLG P OBD. 1.80 bpm at 5,213 psi, Diff--960 10,666.0 10,738.0 15:03 16:03 psi, WHP=164, BHP=4,318, IA=520, OA=69 9/11/2018 9/11/2018 1.50 PROD4 DRILL DRLG P OBD. 1.80 bpm at 5,213 psi, Diff=960 10,738.0 10,771.0 16:03 17:33 psi, WHP=167, BHP=4,323, IA=522, OA=69 9/11/2018 911112018 0.90 PROD4 DRILL WPRT P 10771. BHA Wiper, PUW=60K, Stack 10,771.0 10,771.0 17:33 18:27 out trying to get to bottom. Continue wiper to 10496. Pump sweeps. Work back to bottom 9/11/2018 9/11/2018 2.80 PROD4 DRILL DRLG P 10771', Drill, 1.76 BPM Q 5150 PSI 10,771.0 10,850.0 18:27 21:15 FS, BHP=4415, RIW=-6K, DHWOB=2K 9/11/2018 9/1112018 0.10 PROD4 DRILL WPRT P 10850'. BHA wiper, PUW=65K 10,850.0 10,850.0 21:15 21:21 9/11/2018 9/112018 1.00 PROD4 DRILL DRLG P 10850', Drill, 1.78 BPM @ 5280PSI 10,850.0 10,881.0 21:21 2221 FS, BHP=4400, RIW=-4K 9/11/2018 9/11/2018 0.10 PROD4 DRILL WPRT P 10881, PIU and restart, PUW=61K 10,881.0 10,881.0 22:21 22:27 9/11/2018 9/12/2018 1.55 PROD4 DRILL DRLG P 10881', Drill, 1.78 BPM QD 5210 PSI 10,881.0 10,907.0 22:27 00:00 FS, BHP=4390 Page 27/30 Report Printed: 9/1912018 Operations Summary (with Timelog Depths) 11-1-21 • Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Sled Dew Time SMSTime End Tie Dur inn Phase OP Code Activity Code Time P.T.X Operation End OepN (fiKa) 9/12/2018 9/12/2018 0.20 PROD4 DRILL DRLG P billing, 1.78 BPM @ 5210 PSI FS, 10,907.0 10,910.0 00:00 00:12 BHP=439OPSI 9/12/2018 9/12/2018 0.60 PROD4 DRILL WPRT P 10910', Call TD, PUH pumping 10 X 10,910.0 10,910.0 00:12 00:48 10 Sweeps 9112/2018 9/12/2018 3.10 PROD4 DRILL WPRT P Sweeps out, Chase to swab, 10,910.0 65.0 00:48 03:54 PUW=58K 9/12/2018 9/12/2018 1.50 PROD4 DRILL WPRT P Tag up at surface, Set counters, RBIH 65.0 7,570.0 03:54 05:24 9/12/2018 9/12/2018 0.15 PROD4 DRILL DLOG P Log the K1 correction 0.5' 7,570.0 7,591.0 05:24 05:33 9/12/2018 9/12/2018 0.15 PROD4 DRILL TRIP P Continue IH to above window. 7,591.0 7,800.0 05:33 05:42 9/12/2018 9/12/2018 0.20 PROD4 DRILL CTOP P Obtain pressure survey 6,520.79 7,800.0 7,800.0 05:42 05:64 Sensor/TVD, 11.32 ppg and slowly falling 9/12/2018 9/12/2018 2.50 PROD4 DRILL TRIP P Continue IH confirm TD 10,908', [line 7,800.0 10,908.0 05:54 08:24 up liner pill down the coil 9/12/2018 911212018 1.45 PROD4 DRILL TRIP P POOH laying in beaded 11.55 ppg 10,908.0 6,500.0 08:24 09:51 completion fluid, painting EDP flags 9/12/2018 9/1212018 1.20 PROD4 DRILL TRIP P Continue POOH, displacing well to 6,500.0 78.2 09:51 11:03 11.55 ppg completion fluid to surface 9/12/2018 9/12/2018 0.50 PROD4 DRILL OWFF P At surface, check well for flow, PJSM 78.2 78.2 11:03 11:33 9/12/2018 9/12/2018 0.50 PROD4 DRILL PULD P LD drilling BHA, flush and blow down 78.2 0.0 11:33 12:03 tools 9/12/2018 9/12/2018 0.25 COMPZ4 CASING PUTB P Prep Rig Floor for Liner Ops 0.0 0.0 12:03 12:18 9/1212018 9/12/2018 1.30 PROD4 CASING RUNL P PU/MU.30Its of slotted liner, shorty 0.0 923.0 12:18 13:36 deployment sleeve, and non -ported bullnose. 9/12/2018 9/12/2018 0.50 PROD4 CASING PULD P PU/MU Coiltrak tools surface test 923.0 967.3 13:36 14:06 (good -test) 9/12/2018 9/12/2018 1.65 PROD4 CASING RUNL P RIH, with AL2 -01 Liner segment#1 w/ 967.3 8,474.0 14:06 15:45 30 Its of slotted liner 9/12/2018 9/1212018 0.20 PROD4 CASING RUNL P Log the K1 marker correction of plus 8,474,0 8,523.0 15:45 15:57 6.0' (correction at flat minus 4.0') 9/12/2018 9/12/2018 0.60 PROD4 CASING RUNL P Continue IH 8,523.0 10,500.8 15:57 16:33 9/12/2018 9/12/2018 0.20 PROD4 CASING RUNL P PUW 55 k, RBIH to 10,500.8', bring 10,500.8 9,577.8 16:33 16:45 pump online 1.4 bpm, PUW 41 k, remove liner length from counters 9/12/2018 9/12/2018 2.25 PROD4 CASING RUNL P POOH, Paint EDP flag 6600' 9,577.8 55.0 16:45 19:00 9/12/2018 9/12/2018 0.50 PROD4 CASING PULD P At surface, Flow check well, Lay down 55.0 0.0 19:00 19:30 BHA #31 L2-01 1 at liner run setting tools 9/12/2018 9/12/2018 0.50 PROD4 CASING SVRG P Change out mechanical disconnect on 0.0 0.0 19:30 20:00 safety joint 9/12/2D18 9/12/2018 2.00 PROD4 CASING PUTS P PIU AL2 -01 intermediate liner run with 0.0 1,112.8 20:00 22:00 ported bull nose, 36 Jts sloted liner, and shorty deployment sleeve 9/12/2018 9/12/2018 0.60 PROD4 CASING PULD P M/U Coiltrak to liner. M/U coil to tools 1,112.8 1,157.0 22:00 22:36 and surface test. Tag up and set counters 9/12/2018 9/13/2018 1.40 PROD4 CASING RUNL P Trip in hole BHA#32, AL2 -01 1,157.0 7,749.0 22:36 00:00 intermediate compleion, EDC closed pumping 11.4 revised KWF 9/13/2018 9/13/2018 0.70 PROD4 CASING RUNL P Continiue in well BHA #32 7,749.0 8,660.0 00:00 00:42 intermediate liner segment 9/13/2018 9/13/2018 0.10 PROD4 CASING DLOG P Log K1 for+3.5' correction 8,660.0 8,680.0 00:42 00:48 Page 28130 Report Printed: 911912018 Operations Summary (with Timelog Depths) IH -21 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log start Time Ertl Tone Our (hr) Phase Op Code Activity Corte Tim P -T -X Operation sten Depth OKB) End Depth (WB) 9/13/2018 9/13/2018 0.30 PROD4 CASING RUNL P Continue in well. Cean pass through 8,680.0 9,577.0 00:48 01:06 window. tag TOL @ 9577, PUW=53K, DHWOB=4K 9/13/2018 9/13/2018 0.20 PROD4 CASING RUNL P Set back down, 11.4 PPG New NaBr 9,577.0 8,456.0 01:06 01:18 out of GS. Pump 1.55 BPM @ 4910 PSI. Lift off liner, PUW=43K, DHWOB=-1.2 PUH 10 feel. Subtract liner length left in hole. Circ 10 BBIs in, 9/13/2018 9/13/2018 1.90 PROD4 CASING TRIP P Trip out of well, Paint EOP flag @ 8,456.0 47.1 01:18 03:12 6900' 9/13/2018 9/13/2018 0.70 PROD4 CASING PULD P At surface, Flow check well, PJSM lay 47.1 0.0 03:12 03:54 down tools on dead well 9/13/2018 9/132018 2.60 PROD4 CASING PUTB P PJSM, PIU tubing, BHA#33 AL2 -01 0.0 794.9 03:54 06:30 upper liner segment with ported bull nose, 14 jts slotted liner, HAL Swell Packer, 1 jt solid liner, HAL Swell Packer, 3 jts slotted liner, HAL Swell Packer, 5 jts solid liner, and deployment sleeve w16'SBR 9/13/2018 9/13/2018 0.70 PROD4 CASING PULD P M/U Coiltrak to liner. M/U coil to tools 794.9 839.1 06:30 07:12 and surface test. Tag up and set counters 9/13/2018 9/13/2018 1.50 PROD4 CASING RUNL P TIH BHA#33 AL2 -01 upper liner 839.1 7,942.0 07:12 08:42 segment 9/13/2018 9/132018 0.10 PROD4 CASING RUNL P Correct depth at window flag, -2.7' 7,942.0 7,942.0 08:42 08:48 correction, wt check 45k 9/13/2018 9/132018 0.10 PROD4 CASING RUNL P Continue TIH, log K1 +3' correction, 7,942.0 8,466.8 08:48 08:54 tag TOL @ 8466.77' 9/13/2018 9/13/2018 0.20 PROD4 CASING RUNL P Pump 1.4 BPM, 1167 psi differential 8,466.8 7,670.5 08:54 09:06 to release off liner, 34k up weight 9/13/2018 9/13/2018 1.80 DEMOB CASING TRIP P Displace well to SW pumping .64 7,670.5 2,700.0 09:06 10:54 BPM/1200 psi, recover 11.4 PPG NaBR and TOOH to 2700' 9/13/2018 9/13/2018 1.00 DEMOB CASING TRIP T Standby for LRS due to poor road 2,700.0 2,700.0 10:54 11:54 conditions 9/13/2018 9/13/2018 0.75 DEMOB WHDBOP FRZP P PJSM w/LRS, PT lines to 4000 psi, 2,700.0 2,700.0 11:54 12:39 line up LRS to pump 35 bbls diesel FP into coil 9/13/2018 9/13/2018 0.75 DEMOB WHDBOP FRZP P TOOH to surface 2,700.0 44.2 12:39 13:24 9/13/2018 9/13/2018 1.50 DEMOB WHDBOP PULD P Close Swap valve, LD, setting tools, 44.2 0.0 13:24 14:54 MU nozzle, Note: Final Tubing presure 670 psi 9/13/2018 9/13/2018 2.30 DEMOB WHDBOP CTOP P Stab INJH, PJSM, w/ Haliburton N2, 0.0 0.0 14:54 17:12 PT surface line to 4,000 psi, Blowdown CT strring. Bleed off N2, RID HES N2 9/13/2018 9/13/2018 0.80 DEMOB WHDBOP CTOP P Unstab injector, remove UQC and cut 0.0 0.0 17:12 18:00 a -line 9/13/2018 91132018 2.00 DEMOB WHDBOP CTOP P PJSM, remove inner reel iron, 0.0 0.0 18:00 20:00 pressure bulkhead, and wash pipe, continue loading out pits 9/13/2018 9/13/2018 2.00 DEMOB WHDBOP CTOP P PJSM, R/U CT grapple and 0.0 0.0 20:00 22:00 unstabbing cable. Unstab CT from injector pull back to storage reel and secure to reel 9/13/2018 9/13/2018 1.50 DEMOB WHDBOP CTOP P PJSM, RIU to pick storage reel. Prep 0.0 0.0 22:00 23:30 reel sump. Pull king pin 9/13/2018 9/14/2018 0.50 DEMOB WHDBOP CTOP P PJSM with Peak, Pick reel and plat on 0.0 0.0 23:30 00:00 '9/-14101:00 Peak sow bed truck 018 018 1.00 DEMOB MOVE CTOP P Continue CT string change 0.0 0.0 00:00 oo:o0 01:00 Page 29130 Report Printed: 9/19/2018 Gperations Summary (with Timelog Depths) IH -21 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Time End Time Dur (hr) Phase Op Code Activity Code me P -T-% Time Operation Dexh (flKB) End Depth(MB) 9/14/2018 9/14/2018 5.00 DEMOB MOVE CTOP P Reel installed, Shim reel to carrier, 0.0 0.0 01:00 06:00 Tourque saddle lamps Pull stuffing box for brass change out. Remove pump in sub and quick test sub for tubo inspection. 9/14/2018 9/14/2018 6.00 DEMOB MOVE CTOP P Finish securing reel, stab coil into 0.0 0.0 06:00 1200 INJH, Nipple down Stack, Work rig move check list, released 12:00 noon Page 30130 ReportPrinted: 9119/2018 I ConocoPhillips ConocoPhillips (Alaska) Inc. Kuparuk River Unit Kuparuk1H Pad 11-1-21A 50-029-22355-01 Baker Hughes INTEQ Definitive Survey Report 02 October, 2018 BA ER I UGHES a GE company Conocolthillips t 4 CODOCOPIIllipS Definitive Survey Report Company: ConocoPNil ips(Alaska) Inc. Local Co-amarme Redeem..: Well 1H-21 Project: Kupamk River Unit WO Reference: 111-21 @96.00us9(111-21) site: Kuparuk lH Pad MD Reference: 111-2196.00usg(111-21) Well: 1H-21 North Reference: True Wellbore: 11421 Survey Calculation Method: Minimum Curvature Dealgnt 1H-21 Database: EDT 14 Alaska Production Project Kupamk River Unit, North Slope Alaska, United States Map Syehm: US State Plane 1927 (Exact solution) System Datum: Mean Sea Level Geo Datum: NAD 1927 (RADCON CONUS) Using Well Rasmas. Point Map Zone: Alaska Zone 04 Using geodetic scale factor Well 1H-21 Well Position sNIS 090 Usd Northing: 5,980024,57usfi latitude: 70°21'22.3MN +E&W 0.00 ush Fisting: 549,555,23ush Longitude: 149°35'51.198W Position Uncertainty 0,00 usfi Wellhead Elevation: Usit Ground Level: 54.40 sift i Wagbore 111-21A _ Magnetiu Model Name Sample Data Declination DIp Angle FNM Strength (sTl BGGM2018 911/2918 1.01 39.91 51,446 Design 1H-21A Audit Notes: Version: 16 Phase: ACTUAL TR On Depth: 7,007.30 Walser Section. Depth From JVD) iWE vEIM Direction lien) (-it) (ueln (°) 4169 9.99 DAD 0.00 Survayprogrem am From Th Survey Survey , (audit) (uer4 Survey(Wellbom) TOW Name aaeNDtion SNd Dm End Dm 102.20 7,807.30 1H-21 Srvy1-SW GCT-MS (IH41) GCT-MS Schlumberger OCT mBichot 42811993 4/2811993 7,826.00 7,876.23 1H-21A MWD-INC (I H-21 A) MWD-INCONLY MWD-INC _ONLY _FILLER W1912010 W1912018 7907.21 9,69899 1H-21AMWD(1H-21A) MWD MWD-Standard 8/19/2010 W2112018 10?11018 2:54: 13PM Pepe 2 COMPASS 500014 SuiW SW 101.1016 2:54:13PM Page 3 COMPASS SOLO f4 &tial 650 �.. Conocc PhillipsER t COf1000Ph1Il1uG ps Definitive Report Survey Company: ConocoPhi6ips (Masks) Inc. Local Coordinate Reference. Well iH-21 Project: Kupamk River Unit TVD Reference'. 111-21@W.00usft(11-1-21) Sea: Kupamk lH Pad MD Reference: 1H-21@ 95.00us11(1HR1) Well: 111-21 North Renner.. True Wellbore: 111-21 Survey Calculation Method: Minimum CuwWm Design: 1H-21 Defenses: EDT 14 Masks Production Survey Map Map Map Vertical MD (hall Inc Axl 1'I NO luan) MOSS (daft) +NIS (usft) .&M (-am Seeing D" 1°1100.1 ti Section Survey Tool Marne Ann.lBtion Iln It" ].00].30 3092 99.01 CsfuLm 6468.0 -110.57 3.69.08 69]9,93846 553,25059 082 4109 MWPINC_ONLY(2) TIP 7,826.00 3866 Si (i 6,483.60 -110,M 3.705,]] 5,979,93814 553,262.20 065 -110.36 MAID -INC ONLY (2) KOP ],046.53 44.40 89.9. 6,594,04 6.498.04 -110,10 3,IC.30 5.979,939.09 553.275.88 27.96 41010 M 114C-ONLY(2) IntegolOIDd Azimuth 787(1. 5653 INS" 6612.91 6.516.91 -10957 3,743.23 5.9]8,9.)2 553.298.73 4086 IaL57 M NC_ONLY (2) Interya6ted Azimuth ],90].21 69'. 00.18 CW705 653105 Awn 3,770.]2 5,979,940.]] 553.326.21 4045 -10804 VMA)(3) ],936]1 81.7 BE ED 6.63416 6538,16 -107.0 3,]98,M 5,979,M 24 51 45.65 -107.47 MWD(3) 7.96659 90D9 78.07 6.636,30 6,540.30 10332 3,028.69 5,979,946.59 553,384.14 37.91 -101.32 MWD I3) ],89618 91,84 64.16 6.83680 6,539.80 9376 3.85662 5,979,95633 553,41200 0.27 -W.76 MWD(3) 603821 HA3 52.38 6fi3604 6539.84 -78.07 3,88211 5,970,9826 553437.30 41.Y1 -7800 MWD(3) 0,05615 89Y9 40.53 663654 6,54054 5/41 3,903.76 5979,99290 553450.90 3979 -57.41 MNW)C) 8,087.9 80.52 29.04 6.636.59 654059 .1,57 3.921.8 5,993.018.95 553.476.68 Welt 31.57 MAD (3) 8.116.97 928 17.13 6,61516 65sam 10 3,933.18 5,9..045.91 563.4996 41aft 4.68 MNC(3) 8150.62 92.98 629 6,634.9 6,530.00 am 393910 5,90098.. 553.4943] 35.15 28.23 MWD (3) 8.18065 93.13 366 6,63247 6536.0 50.13 3942.04 5,98010416 5534%.41 5.44 59,13 MND(3) 8,21083 0 S 251 6630,62 6,53462 88.20 3.94366 5,08013885 563497,83 4.58 0820 MWD (3) 8,2409 81'. 1.49 (1 6,53243 1`8.15 3.944.71 5980,16810 553,406.66 3.90 11613 IW)C) 8,90.0 04.70 024 665.03 6,53002 148.12 3,945.18 5.911 553.498.83 4.21 140,12 M Cn 0,300.98 94.90 359A2 6,6549 6,52749 170.05 3,944.99 5.98O.T29.69 553.498.57 381 90.05 MJ40(3) 8,331.10 95.14 3990 .=83 6.524.63 208.04 3.944.21 6,8110y5S.67 553,497.59 49 50.04 MD (3) 8,301.02 9563 35663 6,618.02 6,5II02 23].]9 3,94279 5,9PA,281,41 553,4969 453 23].]9 MID (3) 8.390.93 96.40 35525 6,614.89 6,51069 57.40 3,94060 5.980 ,31840 553,493.6] C. 57,49 "D (3) 8,421.18 979 35346 6,611,33 6,51632 2935 3.937.8 5.980.30.93 55340152 841 2.7AS MWD(3) 8,451.49 97M 35242 6.59.38 6511.38 3P.10 3834,14 5.980.377.73 553,486.83 3.92 32718 MrYD(3) 8483.46 96.74 350.93 6,603.30 6,59.30 359,65 382040 5,893,409,37 553.481.78 657 358.85 M (3) 8.512.90 .a8 350.92 Cgs. 6.503.90 3943 3,924.84 5,992.437.91 553,07.43 021 367,43 WMD(3) 0.543.45 9739 35238 6,596.16 6,5.3.16 41743 3,95.44 5,9..49.80 56474843 620 41743 NAND (3) 8,5]3.93 8749 35424 6.59.24 6,49631 40.44 3,01691 6980,4979 553,46911 605 44744 MWD(a) 6.60332 97.49 35460 fifil SAM 39 47635 3,91408 5,98052675 553,49.69 1.22 0635 "D (3) 8.63438 97.24 356.14 6,56441 6480.41 59.05 3,91161 5,00.5943 563,463,01 4.98 59.05 MD (3) 9.345 970 3%79 6,580.62 646462 53591 3909.92 5,98058530 55346103 271 $3691 MWDp3 101.1016 2:54:13PM Page 3 COMPASS SOLO f4 &tial 650 1022018 2:54:13PM Page 4 OUT% a Annotation COMPASS 5000.14 Budd 650 ConocoPhillips �, Conoc i111�J5 Definitive Survey Report Company: ConocoPhillps(Alaska) Inc. Local CoaakfiuM Reference: ~1 11-1-21 Prolem Nupank Riser Unit TVD Retinues: 1H-21 @96.0ousR(1 H-21) Sen: Kupank lH Pad MD Reference: 1H-21@ 96.00use(1 H-2 1) Well: 1H-21 North Reference: Tme Wellbore: 1H-21 Survey Calculation Method: Minimum Considers Dealt, 11-1¢1 Database: EDT 14 Alaska Production Survey Map Map Vertical No lush) Inc (1) Act (1) TVD (usfll TVD55 (Moll) .WS lase) +EW (tine) Nanning Ea(lad DL6 (-1100' ) Section Survey Tool Name (fll lel lel B,fi9d.4B 9510 357Bt 65]].1fi 6,401.16 566.71 3,968.68 5,981 )5),459 30 699 556.71 MrW (3) 8.72367 94.61 359.12 6.574.69 6,4]869 595.78 3,80)59 5980.64843 553459.41 4.78 50579 MMl](3) 8,75439 93.07 039 8.57242 6,47642 626.42 3907.46 5900,6]5]0 553,458.07 4.]] 626A2 WAS) (a) 8]84.45 93.56 359.08 6.5]0.4] 64]44] 656A2 3,80730 5,860,]05]6 553,457)) 4.76 656.42 MAID (3) 6,813.0 93.50 Small 6.568.39 6,47269 68534 3.96881 5,980.]35.6] 553457.04 0.40 605.34 MD SWIM 9255 356.92 6,56]04 6,471,04 718.39 3,905.73 5,980,]66,]0 553.455.75 7.61 71639 MWD(3) 887AA3 81.78 355.95 6,56593 6,469.93 745.90 3.903.89 5980.796.211 553.453.71 410 74590 MUW(3) 6,644.52 90.95 354.15 6.56520 6,469.20 ]]6.16 3,901.27 5.668.826.45 5534`0.09 652 ])skit Ski 8.9oam 91.47 355.02 6,564.57 6,468.57 am D8 3000.]0 SON 656.35 553,44512 6.46 Swat MASI(3) 8,954.5 91.07 35]66 5553.90 8,46]90 835.03 3897.05 5,900,88.20 553.44527 563 836.03 MAID (3) 8.00754 59.8 3590 6,563.63 6,467,63 855 3,ON18 5980919.19 553,444,20 6.44 88.5 WAS (3) 9.0]3]2 89.11 am" 6.563.833 6,46706 095.03 3,89290 5,980945.25 553441.73 7,69 09503 MID (3) 9,684.28 0834 35357 6,561.54 6.46954 82541 3,809.60 5.98.975.59 553,430.24 2.95 92541 SEND (3) 9064.31 87,9 352.63 Sam 7o 6.469]2 9518 3,885.99 5,001,035.35 553,439.43 5.02 55.19 MrW (3) 9.11431 685 351.04 6,55].35 6,471.35 9&.89 3,881.74 5,981034.87 553.429.5 5.61 54.84 MWDSI 9,144.40 819 35.52 6,58.25 5473.25 1D14.49 3,078.5 5.901031 553.42497 216 1,014.49 MND(3) 9,1i43 822 35.5 6,571.37 6475.37 1,098.01 "TIN 5,901,09607 553,418.52 021 1046.01 Mugu (3) 9.20435 Stu 34829 6573.31 6,4]].31 1,003.79 30550 5, 901, R3.Bo 55,41416 913 10]3,]9 LOAD (3) 9,241.01 8502 346.72 6,575.91 6479.91 1,10968 3,850.6] 5981159.06 553,48.10 4.33 1,109,68 AND (3) 9,251 ".an 346.33 5544.94 6,48.94 1,132.19 3,5314 5801,1828 55340041 14.31 1,132.19 VNO(3) 91201 A5 8.51 34693 6,577,24 548124 1159ll 3846.9] 5,98t2o601 553,394.00 2.5 1,150.13 MWD (3) 932587 6,61 343.81 6.570.10 6.48210 1,191.22 3838.34 5,981,241.04 553,395.22 tn6] 1,191.22 NAND (3) 9,350.32 M71 346.21 6,5]950 6,48290 121502 3.81.96 5.961.21]9 55,37968 10.71 1,21502 "D(3) 9,87.09 8910 347.25 6.5798 648.82 1251100 3,8353 5.51,300.51 553.37002 295 1,250.80 Mr01)(3) 9,414.31 0893 347.39 558.8 5.489.93 142]].33 3,017.55 5SWSV.00 58,3807 542 1,277.33 MAD (3) 9.41410 69.11 351.19 6,50195 6,4855 1,35.5 3,81202 5,981 ,35.21 58,3814 1473 1305.58 MAD (3) 8,47305 80.8 35239 6,52]0 6486.70 1,339.01 3807.7] 5,901,38561 58,353.]0 SAS 1awan MND(3) 9.502 52 8914 35,106 6,83.41 640]A1 1361.47 389.39 5,901.414.04 55335.13 6.5 1,331447 MWD(3) 9,8311 8.13 3897 6,58.14 SAW 14 1]94.93 3.801.73 5,961494.40 553,34727 7.09 1,34.83 "D (3) 98993 WAS 3586 6,584.8 6,48.60 1,930.63 3,799.18 5,981,480 IS 553.344.49 565 1,430.63 MWD (3) 98209 098 354.01 6,584]3 548873 1,464.50 3796.42 598151401 58,3418 341 1.464.50 arki 1022018 2:54:13PM Page 4 OUT% a Annotation COMPASS 5000.14 Budd 650 `. ConocoPhillips Corvc 'ltlflp5 Definitive Survey Report Co.,., Co ..Phillips (Alaska) Inc Prafeu: Kupamk R01er Unit •: aft: Kupamk I Pad Well: 11-21 W.M..; 111-21 Oolgn: 111-21 Surny MD (.00 Local C9 gnlmme Rehren.: TVD Reference: MD Resonance: North Reference: Survey Calculation Method: Database: VVell iH-21 IH -21 Q 96.00usR (111-21) 11131 @ 96,ODusg (11-21) TNG Mlnlmem CwareW. EDT 14 Alaska PmEudion Aryrotation 10R/1015 254'13PM Page 5 COMPr1S5 WOO 14 Slid SM Map Map VerticalOSS MD (.00 (°) AM A TVD TVD N .NIS ♦FYN Northing Easting OLS °1 Sectlon Survey Tool Name 1°) (uan) lusD) Juan) (uaRl (ft) In) 09• ( ) (D) 9,63801 89.33 35395 6585.07 fi4090I 146943 3,]82.6] 5.981,54890 5e3,33]53 S. 1,499.42 MD (3) 967343 89.14 353.10 esW59 6,48958 1,534.58 3.78840 5,98150402 553,333.02 970 1,531.50 MMD(3) 9698.99 69.05 353.11 assess 6,489.98 1,559.95 3.785.35 5,901609.37 663,3M80 045 1,559.95 MNp(3) 9.5.0 0905 353.11 6,586,74 8.490.75 1.60562 3979.83 5,01,65.90 553,323.90 0.00 1,605.62 PROJECTED b TD Aryrotation 10R/1015 254'13PM Page 5 COMPr1S5 WOO 14 Slid SM BAN(ER PRINT DISTRIBUTION LIST UGHES a GE company COMPANY ConocoPhillips Alaska, Inc. WELL NAME 1H -21A FIELD Greater Kuparuk Area COUNTY North Slope Borough BHI DISTRICT Alaska AUTHORIZED BY Patrick Rider EMAIL Patrick. Rider@bakerhughes.com STATUS Final Replacement: COMPANY ADDRESS (FEDEX MLL NOT DELIVER TO P.O. BOX) PERSON ATTENTION V 1 RP North Slope. EOA, PBOC. PRB-20 (Office 109) D&GWO Wells Admin Brenda Glassmaker& Pegg, 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 ExxonMobiLAlaska Attn: Lynda M. Vaskell and/or Leonardo Elias 3201 C Street, Suite 505 Anchorage, AK 919503 4 State of Alaska -AOGCC Attn: Natural Resources Technician It 333 W. 7th Ave, Suite 100 ,.Anchorage, Alaska 99501 v_ 21 $077 29 76 7 ie sign and return one copy of this transmittal form to: xoPhillips Alaska, Inc. Osterkamp (WNS Petroleum Technician) G Street. forage. Alaska 99510 LOG TYPE GR - RES LOG DATE September 12,2018_ TODAYS DATE October 4, 2018 Revision Details: Rev. Requested by: FIELD FINAL CD/DVD FINAL PRELIM LOGS (las, dlis, PDF, META, I SURVEY I REPORT LOGS CGM, Final Surveys) (Compass) # OF PRINTSX Ur PRIN # OF COPIES j# OF COPIES 1# OF COPIES 1] �FCoe 0 1 0 1 0 1 0 10 0 1 1 0 0 5 DNR - Division ofOil & Gas *** 0 0 1 0 Q Atm: Resource Evaluation 550 West 7th Avenue, Suite 1100 Anchorage, Alaska 99501 *** Stamp "confidential" on all material deliver to DNR 6IBP Exploration (Alaska) Inc. 0 0 1 0 0 Petrotechnical Data Center, IR2-I 900 E. Benson Blvd Anchorage, Alaska 99508 TOTALS FOR THIS PAGE: 0 1 3 0 0 PTD � IF-0�T-7 Loepp, Victoria T (DOA) From: Loepp, Victoria T (DOA) Sent: Tuesday, July 10, 2018 2:08 PM To: 'Long, William R' Cc: Ohlinger, James J (James.J.Ohlinger@conocophillips.com) Subject: KRU 1H-21A(PTD 218-077) PTD Approval Modifications William, Please make the following modifications to the approved PTD 218-077: Annular preventer test pressure is 2500 psig Subsequent Form Required: 10-407 Include this approval with the original approved PTD. Thanx, Victoria Victoria Loepp Senior Petroleum Engineer State of Alaska Oil & Gas Conservation Commission 333 W. 7th Ave Anchorage, AK 99501 Work: (907)793-1247 Victoria. LoeppTo7alaska.goy CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Victoria Loepp at (907)793-1247 or Victoria Loepo@alaska.00v THE STATE Alaska Oil and Gas 01AAS—K /0 Conservation Commission GOVERNOR BILL WALKER James Ohlinger Staff CTD Engineer ConocoPhillips Alaska, Inc. PO Box 100360 Anchorage, AK 99510-0360 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 www. aogcc.ala5ka.gov Re: Kuparuk River Field, Kuparuk River Oil Pool, KRU 1H -21A ConocoPhillips Alaska, Inc. Permit to Drill Number: 218-077 Surface Location: 678' FNL, 793' FEL, SEC. 33, TI 2N, RI OE, UM Bottomhole Location: 2624' FSL, 2563' FEL, SEC. 27, T12N, R10E, UM Dear Mr. Ohlinger: Enclosed is the approved application for the permit to redrill the above referenced development well. 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, L Hollis S. French Chair k` DATED this 5 day of July, 2018. STATE OF ALASKA ALA;. , OIL AND GAS CONSERVATION COMMIS N A4, PERMIT TO DRILL fh 'Y 20 AAC 25.005 LGENED JUN 2 9 2018 1 a. Typeof Work 1 I 11h. Proposed Well Class: Exploratory -Gas ❑ Service -WAG LJ Service - Disp ❑ ic. Specify It os' r: Drill LateralStratigraphic Test ElDevelopment - Oil ❑✓ Service - Winj ElSingle Zone EZ coalbed Gas as ydrates ❑ RI'm Exploratory - Oil ❑ Development - Gas ❑ Service - Supply ❑ Multiple Zone ❑ Geothermal ❑ Shale Gas ❑ 2. Operator Name: 5. Bond: Blanket Q - Single Well ❑ 11. Well Name and Number: ConocoPhillips Alaska, Inc. Bond No. 5952180 , Kuparuk Riv Unit 1H -21A - 3. Address: 6. Proposed Depth: 7Vp; (p •Z� 12. Field/Pool(s): PO Box 100360 Anchorage, AK 99510-0360 MD: 11,500' TVD�S' 6526' Kuparuk River Kuparuk River Oil - 4a. Location of Well (Governmental Section): 7. Property Designation: / Surface: 678' FNL, 793' FEL, Sec 33, T12N, R10E, UM ADL 25639 - Top of Productive Horizon: 8. DNR Approval Number: 13, Approximate Spud Date: 790' FNL, 2367' FEL, Sec 34, T12N, R10E, UM LONS 80-261 7/11/2018 Total Depth: 9. Acres in Property: 14. Distance to Nearest Property: 2624' FSL, 2563' FEL, Sec 27, T12N, R10E, UM 2560 5900' 4b. Location of Well (State Base Plane Coordinates - NAD 27): 10. KB Elevation above MSL (ft): 96 - 15. Distance to Nearest Well Open Surface: x- 549555 - y- 5980025 • Zone- 4 GL / BF Elevation above MSL (ft): 54.4 1 to Same Pool: 790' to 1H-12 16. Deviated wells: Kickoff depth: 7825 feet 17. Maximum Potential Pressures in psig (see 20 AAC 25.035) Maximum Hole Angle: 101.5 degrees Downhole: 3275 • Surface: 2645 - 18. Casing Program: Specifications Top - Setting Depth - Bottom Cement Quantity, c.f. or sacks Hole Casing Weight Grade I Coupling I Length MD TVD MD TVD (including stage data) 3" 2-3/8" 4.6# L-80 ST -L 3300' 8200' 6538' 11,500' 6526' Un -Cemented 19. PRESENT WELL CONDITION SUMMARY (To be completed for Redrill and Re -Entry Operations) Total Depth MD (ft): Total Depth TVD (ft): Plugs (measured): Effect. Depth MD (ft): Effect. Depth TVD (ft): Junk (measured): 8315 6962 N/A 8207 6877 N/A Casing Length Size Cement Volume MD TVD Conductor/Structural 121' 16" 200 SX PF C CMT 121' 121' Surface 4779' 9-5/8" 930 SX PERM E, 450 SX G 4820' 4247' Intermediate Production 8258' 7" 299 SX CLASS G CMT 8295' 6947' Liner Perforation Depth MD (ft): Perforation Depth TVD (ft): 7768-7858, 7918-7948 6534-6604, 6651-6674 Hydraulic Fracture planned? Yes❑ No ❑✓ 20. Attachments: Property Plat ❑ Sketch e DSleling Program B v. o Shallow u e DivertOP er Sketch abed Report Drilling Fluid Prgram 20 AAC 25.050 reqot irementse 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: William R. Long Authorized Name: James Ohlinger Contact Email: William. R.Lon COP.com Authorized Title: Staff CTD Engineer Contact Phone: 907-263-4372 4I/.4p/i Authorized Signature: _ Date: Commission Use Only Permit to Drill --�� //b Z API Number: Permit Approvaly See cover letter for other Number: E`0;7 50-(ir �%—Z.�3�S- ,/-�G Date: / requirements. Conditionsofapproval :1 Ifboxx is checked, well may not be used to explore for, test, or produce coalbed methane,, gas hydrates, or gas contained in shales: Other: p,.wa: ttly flxnWr�4 TO '3V00 P51 ,Lv� Samples req'd: Yes ❑ NIR' Mud log req'd: Yes,_❑,( Nog ✓ HzS measures: Yes it No,❑/ Directional svy req'd: Yesu No El Spacing exception req'd: Yes El No LJ Inclination -only svy req'd: Yes ❑ No F+ Post initial injection MIT req'd: Yes ❑ No ❑ APPROVED BY ' n C.• Approved by: COMMISSIONER THE COMMISSION Date: Submit Form and �orm 10-401 Revised 5/2017 This permit is valid for 24 months from the date of approval per 20 AAC 25.005(8) Aft hs'n Duplicate ConocoPhillips Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 June 27. 2018 Commissioner - State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Dear Commissioner: ConocoPhillips Alaska, Inc. hereby submits applications for permits to drill !9er laterals out of the KRU 1H-21 (PTD# 193-046) using the coiled tubing drilling rig, Nabors CDR3-AC. CTD operations are scheduled to begin in July 2018. The objective will be to drill four laterals, KRU 11-1-21A, 1 H- 21AL1, 1H-21AL2, and 1H-21AL2-01, targeting the Kuparuk C -sand interval. To account for geological uncertainties, ConocoPhillips requests a variance from the requirements of 20 AAC 25.015 to allow the actual kick-off point to be anywhere along the length of the parent lateral instead of being limited to 500' from the original point. Attached to this application are the following documents: - Permit to Drill Application Forms (10-401) for 1H -21A, 1H-21AL1, 1H-21AL2, and 1H-21AL2-01 - Detailed Summary of Operations - Directional Plans for 1H -21A, 1H-21AL1, 1H-21AL2, and 1H-21AL2-01 - Current wellbore schematic - Proposed CTD schematic If you have any questions or require additional information, please contact me at 907-263-4372 Sincerely, William R. Long Coiled Tubing Drilling Engineer ConocoPhillips Alaska Kuparuk CTD Laterals 1H -21A, 1H-21AL1, 1H-21AL2, and 1H-21AL2-01 Application for Permit to Drill Document 1. Well Name and Classification........................................................................................................ 2 (Requirements of 20 AAC 25.005(0 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)1..................................................................................................................................................3 7. Diverter System Information.......................................................................................................... 3 (Requirements of 20 AAC 25.005(c)(7))..................................................................................................................................................3 8. Drilling Fluids Program.................................................................................................................. 3 (Requirements of 20 AAC 25.005(c)(6))..................................................................................................................................................3 9. Abnormally Pressured Formation Information.............................................................................4 (Requirements of 20 AAC 25.005(c)(9))..................................................................................................................................................4 10. Seismic Analysis............................................................................................................................. 4 (Requirements of 20 AAC 25.005(c)(10)) ............. -................................... .............................................................................................. 4 11. Seabed Condition Analysis............................................................................................................ 4 (Requirements of 20 AAC 25.005(c)(11))................................................................................................................................................4 12. Evidence of Bonding......................................................................................................................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....................................................................... 7 (Requirements of 20 AAC 25.050(b))......................................................................................................................................................7 16. Attachments....................................................................................................................................7 Attachment 1: Directional Plans for 1H -21A, 1H-21AL1, 1H-21AL2, and 1H-21AL2-01 laterals.....................................7 Attachment 2: Current Well Schematic for 1 H-21............................................................................................................7 Attachment 3: Proposed Well Schematic for 1H-21 A, 1H-21AL1, 1H-21 AL2, and 1H-21AL2-01 laterals .......................7 Page 1 of 7 June 27, 2018 ( PTD Application: 1H -21A, 1H-21AL1, 1H-21AL2, and 1H-21AL2-01 1. Well Name and Classification (Requirements of 20 AAC 25.005(1) and 20 AAC 25.005(b)) The proposed laterals described in this document are 11-1-21 A, 1H-21AL1, 1H-21AL2, and 11-1-21AL2-01. All laterals will be classified as "Development -Oil' wells. 2. Location Summary (Requirements of 20 AAC 25.005(c)(2)) These laterals will target the C sand package in the Kuparuk reservoir. See attached 10-401 forms for surface and subsurface coordinates of each of the laterals. 3. Blowout Prevention Equipment Information (Requirements of 20 AAC 25.005 (c)(3)) Please reference blowout prevention (BOP) schematics on file with the Commission for Nabors CDR3-AC. BOP equipment is as required per 20 AAC 25.036 for thru-tubing drilling operations. - Pipe rams, blind rams and the CT pack off will be pressure tested to 250 psi and to 3,000 psi. Using the maximum formation pressure in the area of 3,275 psi at the datum in 2H-12 (i.e. 10 ppg EMW), the maximum potential surface pressure in 1H-21, assuming a gas gradient of 0.1 psi/ft, would be 2,645 psi. Seethe "Drilling Hazards Information and Reservoir Pressure" section for more details. - The annular preventer will be tested to 250 psi and 2,500 psi. 4. Drilling Hazards Information and Reservoir Pressure (Requirements of 20 AAC 25.005 (c)(4)) Reservoir Pressure and Maximum Downhole Pressure (Requirements of 20 AAC 25.005 (c)(4)(a)) The formation pressure in KRU 1 H-21 was measured to be 2,978 psi at the datum (9.1 ppg EMW) on ✓ 5/16/2015. The maximum downhole pressure in the 11-1-21 vicinity is the 11-1-12 at 3,275 psi at the datum or 10 ppg EMW. Potential Gas Zones (Requirements of 20 AAC 25.005 (c)(4)(b)) No specific gas zones will be drilled; gas injection has been performed in this area, so there is a chance of encountering gas while drilling the 1 H-21 laterals. If significant gas is detected in the returns the contaminated mud can be diverted to a storage tank away from the rig. Potential Causes of Hole Problems (Requirements of 20 AAC 25.005 (c)(4)(c)) ./ The major expected risk of hole problems in the 1 H-21 laterals will be shale instability across faults. Managed pressure drilling (MPD) will be used to reduce the risk of shale instability associated with fault crossings. 5. Procedure for Conducting Formation Integrity tests (Requirements of 20 AAC 25.005(c)(5)) The 1 H-21 laterals will be drilled under 20 AAC 25.036 for thru-tubing drilling operations so a formation integrity test is not required. Page 2 of 7 June 27, 2018 PTD Application: 1H -21A, 1H-21ALI, 1H-21AL2, and 1H-21AL2-01 6. Casing and Cementing Program (Requirements of 20 AAC 25.005(c)(6)) New Completion Details Lateral Name Liner Top Liner Btm Liner Top Liner Btm Liner Details Btm MD MD MD TVDSS TVDSS Conductor 1H -21A 8200' 11,500' • 6538'- 6526' . 2%', 4.7#, L-80, ST -L slotted liner; Surface 121' 1640 670 Surface aluminum billet on to 1H-21AL1 7925' 11,550' 6536' 6644' 2%", 4.7#, L-80, ST -L slotted liner; 4247' 3520 2020 Production 7" aluminum billet on to 1H-21AL2 8400' 11,100 6640' 6494' 2%", 4.7#, L-80, ST -L slotted liner; 4980 4320 Tubing 3-1/2" 9.3 aluminum billet on to 1H-21 AL2 -01 7675' 11,150 6365' 6632' 2%", 4.7#, L-80, ST -L slotted liner; 10,540 de to ment sleeve on to Existing Casing/Liner Information Category OD Weigh t Grade Connection Top MD Btm MD Top TVD Btm TVD Burst psi Collapse psi Conductor 16, 62.5 H-40 Welded Surface 121' Surface 121' 1640 670 Surface 9-5/8" 36 J-55 BTC Surface 4820' Surface 4247' 3520 2020 Production 7" 26 J-55 AB -MOD Surface 8296' Surface 6947' 4980 4320 Tubing 3-1/2" 9.3 J-55 EUE 8rd MOD Surface 7693' Surface 6475' 10,160 10,540 7. Diverter System Information (Requirements of 20 AAC 25.005(c)(7)) Nabors CDR3-AC will be operating under 20 AAC 25.036, for thru-tubing drilling operations. Therefore, a diverter system is not required. 8. Drilling Fluids Program (Requirements of 20 AAC 25.005(c)(8)) Diagram of Drilling System A diagram of the Nabors CDR3-AC mud system is on file with the Commission. Description of Drilling Fluid System — Window milling operations: Water based Power -Vis milling fluid (8.6 ppg) — Drilling operations: Water based Power -Pro drilling mud (8.6 ppg). This mud weight may not hydrostatically overbalance the reservoir pressure, overbalanced conditions will be maintained using MPD practices described below. — Completion operations: BHA's will be deployed using standard pressure deployments and the well will be loaded with 11.4 ppg NaCl/NaBR completion fluid in order to provide formation over -balance and maintain wellbore stability while running completions. If higher formation pressures are encountered the completion brine will be weighted up with sodium bromide or potassium formate. Managed Pressure Drilling Practice Managed pressure drilling (MPD) techniques will be employed to maintain a constant overbalanced pressure on the open hole formation and promote wellbore stability throughout the coiled tubing drilling (CTD) process. Mud weight is not, in many cases, the primary well control barrier. This is satisfied with the 5000 psi rated coiled tubing pack off and MPD choke. BOPE equipment provides the secondary well control as detailed in section 3 "Blowout Prevention Equipment Information". In the 1 H-21 laterals we will target a constant BHP of 11.4 EMW at the window. The constant BHP target will be adjusted through choke pressure and/or mud weight increases to maintain overbalanced conditions if increased reservoir pressure is encountered. Additional choke pressure or increased mud weight may also be employed Page 3 of 7 June 27, 2018 PTD Application: 1H -21A, 1H-21AL1, 1H-21AL2, and 1H-21AL2-01 for improved borehole stability. Any change of circulating friction pressure due to change in pump rates or change in depth of circulation will be offset with back pressure adjustments. Pressure at the 1 H-21 Window (7825' MD, 6578' TVD) Usinq MPD 9. Abnormally Pressured Formation Information (Requirements of 20 AAC 25.005(c)(9)) N/A - Application is not for an exploratory or stratigraphic test well. 10. Seismic Analysis (Requirements of 20 AAC 25.005(c)(10)) N/A - Application is not for an exploratory or stratigraphic test well. 11. Seabed Condition Analysis (Requirements of 20 AAC 25.005(c)(11)) N/A - Application is for a land based well. 12. Evidence of Bonding (Requirements of 20 AAC 25.005(c)(12)) Evidence of bonding for ConocoPhillips Alaska, Inc. is on file with the Commission. 13. Proposed Drilling Program (Requirements of 20 AAC 25.005(c)(13)) Summary of Operations Background KRU well 1H-21 is a Kuparuk producer equipped with 3-1/2" tubing and 7" production casing. The CTD sidetrack will utilize laterals to target the Kuparuk sands to the north and east of the existing 1 H-21 wellbore. The laterals will increase throughput and recovery from a potentially sheltered corner of a fault . block. Prior to CTD operations, E -Line will punch holes in the 3-1/2" tubing tail below the production packer and the "D" nipple will be milled out to 2.80" ID. The existing perforations will be squeezed with cement and the 3-1/2" tubing tail will be cemented in place to provide a means to kick out of the 7" casing. Following the cement squeeze Nabors CDR3-AC will drill a pilot hole and set a mechanical whipstock in the 2.80" pilot hole. The whipstock will be used to cut a window in the 7" casing and drill CTD laterals. Page 4 of 7 June 27, 2018 Pumps On 1.8 bpm) Pumps Off Formation Pressure 9.1 3113 psi 3113 psi Mud Hydrostatic 8.6 2942 psi 2942 psi Annular friction i.e. ECD, 0.080psi/ft) 626 psi 0 psi Mud + ECD Combined no chokepressure) 3568 psi overbalanced -455psi) 2942 psi underbalanced ^171psi) Target BHP at Window 11.4 3899 psi 3899 psi Choke Pressure Required to Maintain Target BHP 331 psi 957 psi 9. Abnormally Pressured Formation Information (Requirements of 20 AAC 25.005(c)(9)) N/A - Application is not for an exploratory or stratigraphic test well. 10. Seismic Analysis (Requirements of 20 AAC 25.005(c)(10)) N/A - Application is not for an exploratory or stratigraphic test well. 11. Seabed Condition Analysis (Requirements of 20 AAC 25.005(c)(11)) N/A - Application is for a land based well. 12. Evidence of Bonding (Requirements of 20 AAC 25.005(c)(12)) Evidence of bonding for ConocoPhillips Alaska, Inc. is on file with the Commission. 13. Proposed Drilling Program (Requirements of 20 AAC 25.005(c)(13)) Summary of Operations Background KRU well 1H-21 is a Kuparuk producer equipped with 3-1/2" tubing and 7" production casing. The CTD sidetrack will utilize laterals to target the Kuparuk sands to the north and east of the existing 1 H-21 wellbore. The laterals will increase throughput and recovery from a potentially sheltered corner of a fault . block. Prior to CTD operations, E -Line will punch holes in the 3-1/2" tubing tail below the production packer and the "D" nipple will be milled out to 2.80" ID. The existing perforations will be squeezed with cement and the 3-1/2" tubing tail will be cemented in place to provide a means to kick out of the 7" casing. Following the cement squeeze Nabors CDR3-AC will drill a pilot hole and set a mechanical whipstock in the 2.80" pilot hole. The whipstock will be used to cut a window in the 7" casing and drill CTD laterals. Page 4 of 7 June 27, 2018 Pre -CTD Work PTD Application: 1H -21A, 1H-21AL1, 1H-21AL2, and 1H-21AL2-01 -!�> ut >%�-4 1. RU Slickline: Drift tubing with dummy whipstock., S$ 2. RU E -line: Punch holes in the 3%" tubing tail below the production packer. l; 3. RU Pumping Unit: perform injectivity test down the tubing. 4. RU Service Coil: Mill out "D" nipple and cement squeeze the perforations up to the holes in the tubing tail. 5. RU Slickline: Drift tubing with dummy whipstock. Tag top of cement and pressure test cement. 6. Prep site for Nabors CDR3-AC. Rig Work 1. MIRU Nabors CDR3-AC rig using 2" coil tubing. NU 7-1/16" BOPE, test. 2. Mill 2.80" cement pilot hole. 3. Set monobore whipstock. 4. IH -21A Lateral (C sand -North) a. Mill 2.80" window at 7825' MD. . b. Drill 3" bi-center lateral to TD of 11,500' MD. ` c. Run 2%" slotted liner with an aluminum billet from TD up to 8200' MD. 5. 1 H-21 AL 1 Lateral (C sand -North) a. Kickoff of the aluminum billet at 8200' MD. b. Drill 3" bi-center lateral to TD of 11,550' MD. c. Run 2%" slotted liner with aluminum billet from TD up to 7925' MD. 6. 1 H-21AL2 Lateral (C sand -East) a. Kickoff of the aluminum billet at 7925' MD. b. Drill 3" bi-center lateral to TD of 11,100' MD. c. Run 2%" slotted liner with aluminum billet from TD up to 8,400' MD. 7. 1H-21AL2-01 Lateral (C sand - East) a. Kickoff of the aluminum billet at 8400' MD. b. Drill 3" bi-center lateral to TD of 11,150' MD. c. Run 2%" slotted liner with deployment sleeve from TD up to 7675' MD. 8. Freeze protect, ND BOPE, and RDMO Nabors CDR3-AC. Post -Rig Work 1. Return to production. Page 5 of 7 June 27. 2018 PTD Application: 1H -21A, 1H-21AL1, 1H-21AL2, and 1H-21AL2-01 Pressure Deployment of BHA The planned bottom hole assemblies (BHAs) are too long to simply isolate by closing the double swab valves on the Christmas tree. MPD operations require the BHA to be lubricated under pressure using a system of double swab valves on the Christmas tree, double deployment rams, double check valves and double ball valves in the BHA, and a slick -line lubricator can be used. This pressure control equipment listed ensures there are always two barriers to reservoir pressure, both internal and external to the BHA, during the deployment process. During BHA deployment, the following steps are observed. - Initially the double swab valves on the tree are closed to isolate reservoir pressure. The lubricator is installed on the BOP riser with the BHA inside the lubricator. - Pressure is applied to the lubricator to equalize across the swab valves. The swab valves are opened and the BHA is lowered in place via slick -line. - When the BHA is spaced out properly, the double deployment rams are closed on the BHA to isolate reservoir pressure via the annulus. A closed set of double ball valves and double check valves isolate reservoir pressure internal to the BHA. Slips on the double deployment rams prevent the BHA from moving when differential pressure is applied. The lubricator is removed once pressure is bled off above the deployment rams. - The coiled tubing is made up to the BHA with the double ball valves plus the double check valves in the closed position. Pressure is applied to the coiled tubing to equalize internal pressure and then the double ball valves are opened. The injector head is made up to the riser, annular pressure is equalized, and the deployment rams are opened. The BHA and coiled tubing are now ready to run in the hole. During BHA undeployment, the steps listed above are observed, only in reverse. Liner Running - 1H-21 CTD laterals will be displaced to an overbalance completion fluid (as detailed in Section 8 "Drilling Fluids Program") prior to running liner. - While running 2%" slotted liner, a joint of 2%" non -slotted tubing will be standing by for emergency deployment. A floor valve is made up onto this joint ahead of time, and the rig crew conducts a deployment drill with this emergency joint on every slotted liner run. The 2%" rams will provide secondary well control while running 2%" liner. 14. Disposal of Drilling Mud and Cuttings (Requirements of 20 AAC 25.005(c)(14)) • No annular injection on this well. • All solid waste will be transported to the grind and inject facility at DS -4 Prudhoe Bay for disposal. - • Incidental fluids generated from drilling operations will be injected in a Kuparuk Class II disposal well (1R-18 or 1B disposal facilities) or Prudhoe DS -4 if a Kuparuk facility is unavailable. • All wastes and waste fluids hauled from the pad must be properly documented and manifested. • Contact Kuparuk Environmental Coordinator for questions regarding waste classification. (6704200). Page 6 of 7 June 27, 2018 r PTD Application: 1H -21A, 1H-21AL1, 1H-21AL2, and 1H-21AL2-01 15. Directional Plans for Intentionally Deviated Wells (Requirements of 20 AAC 25.050(b)) - The Applicant is the only affected owner. - Please see Attachment 1: Directional Plans - Magnetic and inclination surveys will be taken every 30 ft. No gyro will be run. - MWD directional, resistivity, and gamma ray will be run over the entire open hole section. - Distance to Nearest Property Line (measured to KPA boundary at closest point) Lateral Name Dt t�ntrs 1H -21A 5,900' 1 H-21AL1 5,900' 1H-21AL2 7,200' 1 H-21 AL2 -01 7,200' Distance to Nearest Well within Pool Lateral Name Distance Well 1 H-21 A 790' IH -12 1H-21ALl 790' 11-1-12 1 H-21AL2 978' 1H-13 1 H-21 AL2 -01 978' 1H-13 16. Attachments Attachment 1: Directional Plans for 1H -21A, 1H-21AL1, 1H-21AL2, and 1H-21AL2-01 laterals. Attachment 2: Current Well Schematic for IH -21. Attachment 3: Proposed Well Schematic for IH -21A, 1H-21AL1, 1H-21AL2,and 1H-21AL2-01laterals. Page 7 of 7 June 27, 2018 ER Project: Kupa(uk River Unit Site: Kuparuk lH Pad InnMMmT'ue HwM um^nK NmN 1].OP Tp WELLBORE DETAILS: IH -21A aFFFaEucF INFORMATION ConrQmaa lNrE)Belamcm MM91H31,TMe NUIM1 Well: 1H31 uearoe=alak se.reln nau.een Parent Wellbom iH-21 To on MD: 7807.30 Val(M)evenvia 1H-21®9G0eafl (&2t) 6¢c'ui M) Feierercr. Ii -M.WN, ME) F�UGHES ConocoP Wellbore: 1H -21A t/`I{YYlhf ap MMM: exal Meat: Meaaretl Dv,b Wreire. IH21@96AWd H-21) aGEmmpolry ips Plan: 1H -21A wpD3 (1H•21I1H-21A) Mi l aenMml Cckuwi Ml Men. C .. 111-101/IH-101 1H-1011111-1011-1 It{.101/It1-101LE 111-Iu3llH-luxl.l IH-IYI/LII-I011.l 111-10'J111-I@Ll INd0Jlf4(02L: IHl 111111-14 141-IUII�i-IIr11J III -10'_/111-111:114, � III-IIN 111 I• l 560D� 1 6 III I "/III -11x13 5250 5250T 111 m rn. on: tlHhl111+�. 49� .. conn w-1 111-r w.moul.l r1I 4550 4200 ul ul-.r 4f1 u'1 a IW IH-19/IH-IYALjIIp III. � 1449:A1'P: III,I YII&19pL�-011'81 11-11 IH -I 1111.71111 10111W 111 91111.1,; r I Ir rlll�lri,\I I ryiW II W' 1)IAi]n � a - I '.. '3500 111-19/111-19�(.I il� 999M rF'!�. IH-INIH-IbAI)1�i1 '/I �] IH-IYIIH-19AL�lST) ADD c jN1 I414911I I I(1-I�JII1 \ '�ii•�. 11' Llnr{I -Ile p 111-19/111-IY 2450 3„ .Y � 9 i O �L v lu-lNm-m d tv u[4 - nl IOY.9ll-tnv _ _ _ LW� 111-111f 111 -IIS III-W"l l I I1 ❑SOI d III -C. II 11` O 7 1400]. IH-03IIFW}'"" III-III/111-III �+ INiD � 1 111 1'111-IR\I. ]ODi -1 II I,11,_l0� 350 1 _ �y ul,nvrm=ur 0� - I14-Yn1UONUy1H4,1 -35D 11131!111-'_i G. 111-04/11{M IHlH/IH+161-.100 - --" �� d4nlill-IT II{4M/IH-04Li-0I 111-r. 1 A r' -1050 -1400v 1 ul '.2rul-_. 11 G".11.11 -1750. su99 1v -21D0 _ _ 4]50 -1400 -1050 -]00 '-350 50 3500'. 3850 4200 4550 4900 5250 SeDO G650 ]000 ]350 ]]00 %050 ffJ00 8b0 9100 9450 9800 0 -350 ]00 1050, 1400 1]50 2100 2450 2800 31 ^— 0 5050 6300 0 U � _0�0 "on Wes[( -)/East(+) (350 u sft/in) """""'-"' 1H-21 96.00l (1H-21) IH+m/ware u{.uimdl IIIL2llll+✓_' IHLI/IH-01 IIIIP/IH-19 C0fl0 4;hIllip5 ," KUP 1H-21 WellAttrlbutes "Max An le$MU 7D Ataska INC ell re -1 —11l F'eltl Name -------- 500292235500 KUPARUK RIVER UNIT II I I PROD Incl l°I 41.51 MO IRKBI 3,88560 til ISt (11K31 83150 Lom ent N]S 1ppm Dale P E tlDate NB Grp (ftl PIgR Ieau Dal " MMICanf nnr vu SSSV. TRDP 100 94612011 LasI WO'. 3/2811993 ay m �rmrhsnhhih Las1Ta9 SLM De789fi01 sin - E446/2012 R Reason, WELL REVIEW �Laosbo stsi P6tl1 p11201: " casin Stri s HumeR.3e Lasing Description Sang o_. strip, ID... TaplNKelse10epO9... CONDUCTOR 16 15.062 41.0 121.0 sel Dep I (w S..', sting w,_. shin,.. String Top Th. 1210 62.50 H-40 WELDED Lacing Da¢nioNan String 0_. String lD... TOPIRKB) per hell "t 1iVD1... String WL.. string—Stn ng Top Thrtl SURFACE 9518 8.921 40.2 4,820.4 4,24].1 36.00 7-55 BTC Casing OeeMptlan Soln80... -mig W._ TOPIftKBI Set Dell, h_ se, 0eplM1 jlVOI String Wt.. String . strip, Tap Th. PRODUCTION > fi.2J6 38.8 8.2963 6,946.9 26.00 J,!55AB-MOD TUNno Strings CONDDLTOR, nnn Tubing 0 pilon St, 19 0 Snng lD 1, mr8) se, Deplhl s Dep,M1 CVD) S1nng WLTs g—T.SInng Top rho TURING dl2 2992 37.6 76929 e, 6,4`762 9.30 755 EUE8RDM0C — ---` - - — - — — Com lehon Details tion oenlnr— ITVD) Top incl Domi Top GS.D (h--) I Ill I itemDe¢enption Lommant Mlle Se EIYVLV, 37.6 37.6 0.13 HANGER FMC GEN IV HANGER 3.50 trw 1,789.3 1,`783.2 14.355AEETYVLV CAMCO TRDPdA-RO SAFETV—VALVE 2.81 ],650.1 6,441.9 39.00 PBR BAKER PBR .119 STROKE (T0P OF PBR HAS 414'RH S0UARE 3.00 THREAD FOR EKE RETRIEVAL) .U" 7.60.91 6,452.7 3900PACKER BAKER HE RETRIEVABLE PACKER 2.89 2nl `7.680.3 6,665.4 3895, NIPPLE CAMCO D NIPPLE NO GO 2.75 Bin (TVD) I,Ns1 xone 6.603.] UNIT D, C- C -3 IH -11 Leitch 16" 62# H-40 shoe @ 121' MD 9-5/8" 36# J-55 shoe 04820 4820' MD C -sand perfs 7768'- 7858' MD 7918'- 7948' MD hole 1119 1H-21 Proposed CTD Schematic 3-1/2" Camco TRDP=4A-RO SSSV at 1789' MD (2.812") 3-1/2" 9.3# J-55 EUE Srd Tubing to surface 3-1/2" Camco MMG gas lift mandrel at 2571', 4355', 5143', 5922', 6710', 7183', 7602' Baker 3-1/2" PBR at 7650' MD BakerHB packer at 7664' MD (2.89" ID) D -nipple at 7680" MD (2.75" min ID, No -Go) 3-1/2" Baker SOS @ 7692' MD iH-21A (NOM) Top or billet ®a2oo' Mp '- 1H-21AL1 (North) OH Anchor bille ® 7925' MD VE 7" 26# J-55 1 H -21 L2-01 (East) shoe @ 8296' MD IT^^ of Liner ®7,675 MD ConocoPhillips Proitil Kupi River Unit Site; KH lH Pad rum,elaonu. Nd16 u.e�noxenn. usr uer, F.0 WELLBDRE DETAILS'. iH-21A REFERENCE INFORWTION Parent Wellbore. 1H-21 coartwn(HEl Pill. wHI1H21,Tm None -21 Well: IH -21 snxom sius.+m Tie On MD'. 790T.30 Vemm Mo)Relercrce'. Nfen see level Wellbore: 1H -21A Plan: iH.21A-wpa3(114-2111e.Ne. aoArva: msr eoowmi +N/ -S +E/ -W senoe rysl aekreire.51x1-Ia.Wu, 9.00E1 w,eeem..d Deem . %fil 11141 H Ill rH 21) Easting Latitude Cekualkn MaMod AYnirtum Curare C_ Mean I BAF�t([ 0 GE ,, WELL DETAILS: 1 H-21 1� +N/ -S +E/ -W Northing Easting Latitude Longitude • ,I�v■■■■■■■OMNI 0.00 0.00 5980024.57 549555.22 70° 21'22.356 N 149° 35' 51.196 W ■■■■■■■■■I Sec MID Inc Azi TVD +N / -S +E/ - +E/ -W Dleg TFace VSect Annotation 1 7807.30 38.77 89.01 6468.09 -110.57 3695.08 0.00 0.00 -110.57 TIP „ 2 7825.00 38.67 88.94 6481.90 -110.37 3706.15 0.62 -156.38 -110.37 KOP 3 7846.00 42.87 88.94 6497.80 -110.12 3719.86 20.00 0.00 -110.12 End 20 cls, Start 45 dis 4 7950.73 90.00 88.94 6538.50 -108.39 3813.16 45.00 0.00 -108.39 4 I■■■■��\ 5 8150.00 90.00 359.27 6538.50 20.54 3938.11 45.00 270.00 20.54 End 45 d1s, Start 7 dis H-21 6 8350.00 94.75 346.08 6530.18 218.25 3912.74 7.00 290.00 218.25 6 7 8650.00 101.50 6.18 6487.38 512.78 3892.39 7.00 70.00 512.78 7 a 8 8850.00 90.68 357.24 6466.15 711.07 3898.15 7.00 220.00 711.07 8 9 9150.00 87.07 336.54 6472.11 1001.56 3830.52 7.00 260.00 1001.56 9 c 10 9450.00 89.05 357.46 6482.38 1292.08 3763.48 7.00 85.00 1292.08 10 r 11 9750.00 89.83 336.47 6485.34 1582.70 3696.21 7.00 272.00 1582.70 11 12 10000.00 89.84 353.97 6486.06 1823.49 3632.69 7.00 90.00 1823.49 12 13 10200.00 87.44 340.18 6490.84 2017.89 3588.09 7.00 260.00 2017.89 13 i 14 10450.00 87.55 357.69 6501.85 2262.05 3540.35 7.00 90.00 2262.05 14 1510600.00 88.69 8.14 6506.79 2411.56 3547.97 7.00 84.00 2411.56 15 16 10850.00 88.75 350.63 6512.43 2660.51 3545.30 7.00 270.00 2660.51 16 s 17 11100.00 88.81 8.14 6517.81 2909.47 3542.62 7.00 90.00 2909.47 17 18 11500.00 88.95 340.13 6525.82 3303.35 3502.16 7.00 270.00 3303.35 Planned TD at 11500.0 C_ Mean I BAF�t([ 0 GE ,, West( -)/East(+) (300 ustt/in) 6000 1� • ,I�v■■■■■■■OMNI 1®i111■ ■■■■■■■■■I b n 6200 1■■�■I!I■■■■■■■■■■■■I cl ~I h „ 6 I 6300 ■■■■III■■■■■■■■■■I ■ ■■I . 1 6400 TIP 1H 21/IH 21AC ■ ■■■■■■■■I OP" .,, I■■■■��\ Plan d TD 1 1150).0( 6500 .7 ■■■■■ ■■■■II H-21/ H-21 INN ■■.I■■■■■■■■ 4'" 0 11 12 13 INN ■■■I ■■■■■■■■■� 1IS 1■■■■■��; ��■■■■E .0 „ 1■■■■■l1■■■■M■N End4 dls,S n7d1 IH 2I/IH 21A -0I 1■■■■■l�i�i�%%■I 6800L IN H-21/ H-21 LI IN IH -2 /IH -2 6900 - - - - - - 7000 West( -)/East(+) (300 ustt/in) 6000 6100 b n 6200 cl ~I h 6 I 6300 S S_ 6400 TIP 1H 21/IH 21AC OP" Plan d TD 1 1150).0( 6500 .7 H-21/ H-21 S 4'" 0 11 12 13 660017 1IS 6700 End4 dls,S n7d1 IH 2I/IH 21A -0I 6800L H-21/ H-21 LI IH -2 /IH -2 6900 - - - - - - 7000 ea L s 0 0 0 0 0 0 0 0 0 0 0 0 0 0 Vertical Section at 0.001 (100 usft/in) ConocoPhillips ConocoPhillips (Alaska) Inc. -Kupl Kuparuk River Unit Kuparuk 1H Pad 1 H-21 1 H-21 A Plan: 1 H-21A_wp03 Standard Planning Report 25 June, 2018 BPIR HES company ConocoPhillips "Philps Planning Report BA �UEGRH ES a GE compny Database: EDT Alaska Sandbox Company: ConocoPhillips(Alaska) Inc.-Kupl Project: Kuparuk River Unit Site: Kupamk 1H Pad Well: 1H-21 Wellbore: 1H -21A Design: 1H-21 A_wp03 Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Well 1 H-21 Mean Sea Level 1H-21 @ 96.00usft (1H-21) True Minimum Curvature Project Kupawk River Unit, North Slope Alaska, United States Map System: US State Plane 1927 (Exact solution) - System Datum: Mean Sea Level Geo Datum: NAD 1927 (NADCON CONUS) - Using Well Reference Point Map Zone: Alaska Zone 04 ' Using geodetic scale factor She Kupamk 1H Pad Site Position: Northing: 5,979,968.84usft Latitude: 70' 21'21.831 N From: Map Easting: 549,197.16 usft Longitude: 149° 36' 1.675 W Position Uncertainty: 0.00 usft Slot Radius: 0.000 in Grid Convergence: 0.38 ' Well 1H-21 Well Position -N/-S 0.00 usft Northing: 5,980,024.57 usft Latitude: 70° 21'22.356 N +EI -W 0.00 usft Easting: 549,555.22 usft Longitude: 149° 35'51.196 W Position Uncertainty 0.00 usft Wellhead Elevation: usit Ground Level: 54.40 usft Wellbore 1H -21A Magnetics Model Name Sample Date Declination Dip Angle Field Strength (nT) BGGM2018 9/1/2018 17.01 80.91 57,446 Design 1H -21A wp03 Audit Notes: Version: Phase: PLAN Tie On Depth: 7,807.30 Vertical Section: Depth From (TVD) +NI -S +EI -W Direction (usft) (usft) (usft) (I -54.40 0.00 0.00 000 6/25/2018 4:04:44PM Page 2 COMPASS 5000.14 Build 85 i ConocoPhillips BA ER ConocoPhillips Planning Report F IGHES BAT GEmmpany Database: EDT Alaska Sandbox Local Co-ordinate Reference: Well IH -21 Company: ConocoPhillips (Alaska) Inc. -Kupl TVD Reference: Mean Sea Level Project: Kuparuk River Unit MD Reference: 1H-21 @ 96.00usft (1H-21) Site: Kuparuk 1 H Pad North Reference: True Wel): 1 11-21 Survey Calculation Method: Minimum Curvature Wellbore: 1 H-21 A Azimuth System Design: 1H-21A_wp03 Rate Rate Plan Sections Measured TVD Below Dogleg Build Turn Depth Inclination Azimuth System +N1 -S +El -W Rate Rate Rate TFO (usft) (°) (°) (usft) (usft) (usft) (°1100@) (-Mooft) (-1100ft) (°) Target 7,807.30 38.77 89.01 6,468.09 -110.57 3,695.08 0.00 0.00 0.00 0.00 7,825.00 38.67 88.94 6,481.90 -110.37 3,706.15 0.62 -0.56 -0.40 -156.38 7,846.00 42.87 88.94 6,497.80 -110.12 3,719.86 20.00 20.00 0.00 0.00 7,950.73 90.00 88.94 6,538.50 -108.39 3,813.16 45.00 45.00 0.00 0.00 8,150.00 90.00 359.27 6,538.50 20.54 3,938.11 45.00 0.00 -45.00 270.00 8,350.00 94.75 346.08 6,530.18 218.25 3,912.74 7.00 2.37 -6.59 290.00 8,650.00 101.50 6.18 6,487.38 .512.78 3,892.39 7.00 2.25 6.70 70.00 8,850.00 90.68 357.24 6,466.15 711.07 3,898.15 7.00 -5.41 -4.47 220.00 9,150.00 87.07 336.54 6,472.11 1,001.56 3,830.52 7.00 -1.20 -6.90 260.00 9,450.00 89.05 357.46 6,482.38 1,292.08 3,763.48 7.00 0.66 6.97 85.00 9,750.00 89.83 336.47 6,485.34 1,582.70 3,696.21 7.00 0.26 -7.00 272.00 10,000.00 89.84 353.97 6,486.06 1,823.49 3,632.69 7.00 0.00 7.00 90.00 10,200.00 87.44 340.18 6,490.84 2,017.89 3,588.09 7.00 -1.20 -6.90 260.00 10,450.00 87.55 357.69 6,501.85 2,262.05 3,540.35 7.00 0.05 7.01 90.00 10,600.00 88.69 8.14 6,506.79 2,411.56 3,547.97 7.00 0.75 6.96 84.00 10,850.00 88.75 350.63 6,512.43 2,660.51 3,545.30 7.00 0.02 -7.00 270.00 11,100.00 88.81 8.14 6,517.81 2,909.47 3,542.62 7.00 0.02 7.00 90.00 11,500.00 88.95 340.13 6,525.82 3,303.35 3,502.16 7.00 0.03 -7.00 270.00 625!2018 4:04:44PM Page 3 COMPASS 5000.14 Build 85 ConocoPhillips BA ER ConocoPhillips Planning Report BAT a GEcompry Database: EDT Alaska Sandbox Vertical Company: ConocoPhillips (Alaska) Inc. -Kupl Project: +N/ -S Kupamk River Unit Rate She: Northing Kuparuk 1H Pad 3,938.11 Well: (usft) 1H-21 (°/10oft) (1) Wellbore: (usft) 11-1-21A -110.57 3,695.08 Design: 0.00 1H-21A_wP03 5,979,938.46 553,250.59 Planned Survey 3,706.15 -110.37 0.62 Measured 5,979,938.73 553,261.66 TVD Below Depth Inclination Azimuth System (usft) (1 (o) (usft) 7,807.30 -109.30 38.77 89.01 6,468.09 0.00 TIP 553,319.26 553,441.92 -108.39 7,825.00 -108.39 38.67 88.94 6,481.90 553,368.64 KOP 3,892.39 512.78 7.00 7,846.00 5,980,563.04 42.87 88.94 6,497.80 1,292.08 End 20 dis, Start 45 dis 5,981,341.39 553,309.71 7,900.00 3,759.75 67.17 88.94 6,528.53 7,950.73 553,305.64 90.00 88.94 6,538.50 7.00 4 5,981,489.63 553,288.44 1,536.27 8,000.00 1,536.27 90.00 66.77 6,538.50 8,100.00 1,582.70 90.00 21.77 6,538.50 8,150.00 5,981,631.53 90.00 359.27 6,538.50 End 45 ells, Start 7 dis 8,200.00 91.20 355.98 6,537.98 8,300.00 93.57 349.39 6,533.81 8,350.00 94.75 346.08 6,530.18 6 8,400.00 95.93 349.39 6,525.53 8,500.00 98.25 356.05 6,513.17 8,600.00 100.45 2.78 6,496.91 8,650.00 101.50 6.18 6,487.38 7 8,700.00 98.81 3.91 6,478.57 8,800.00 93.40 359.44 6,467.93 8,850.00 90.68 357.24 6,466.15 8 8,900.00 90.07 353.79 6,465.82 9,000.00 88.86 346.89 6,466.76 9,100.00 87.66 340.00 6,469.81 9,150.00 87.07 336.54 6,472.11 9 9,200.00 87.38 340.03 6,474.53 9,300.00 88.03 347.01 6,478.54 9,400.00 88.70 353.98 6,481.40 9,450.00 89.05 357.46 6,482.38 10 9,500.00 89.18 353.96 6,483.15 9,600.00 89.43 346.97 6,484.37 9,700.00 89.70 339.97 6,485.13 9,750.00 89.83 336.47 6,485.34 11 9,800.00 89.83 339.97 6,485.48 9,900.00 89.83 346.97 6,485.78 10,000.00 89.84 353.97 6,486.06 12 10,100.00 88.63 347.08 6,487.40 10,200.00 87.44 340.18 6,490.84 13 10,300.00 87.45 347.18 6,495.30 10,400.00 87.51 354.19 6,499.70 10,450.00 87.55 357.69 6,501.85 +a Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Well 1 H-21 Mean Sea Level 1 H-21 @ 96.00usft (1 H-21) True Minimum Curvature -98.09 3,861.02 Vertical Dogleg Toolface Map Map -28.31 +N/ -S +E1 -W Section Rate Azimuth Northing Easting 3,938.11 (usft) (usft) (usft) (°/10oft) (1) (usft) (usft) 70.48 -110.57 3,695.08 -110.57 0.00 0.00 5,979,938.46 553,250.59 7.00 -110.37 3,706.15 -110.37 0.62 -156.38 5,979,938.73 553,261.66 -70.31 -110.12 3,719.86 -110.12 20.00 0.00 5,979,939.07 553,275.36 5,980,317.23 -109.30 3,763.76 -109.30 45.00 0.00 5,979,940.17 553,319.26 553,441.92 -108.39 3,813.16 -108.39 45.00 0.00 5,979,941.42 553,368.64 512.78 -98.09 3,861.02 -98.09 45.00 -90.00 5,979,952.03 553,416.43 -28.31 3,929.04 -28.31 45.00 -90.00 5,980,022.25 553,483.98 20.54 3,938.11 20.54 45.00 -90.00 5,980,071.15 553,492.73 70.48 3,936.04 70.48 7.00 -70.00 5,980,121.08 553,490.33 169.52 3,923.33 169.52 7.00 -70.03 5,980,220.02 553,476.96 218.25 3,912.74 218.25 7.00 -70.31 5,980,268.67 553,466.05 266.88 3,902.17 266.88 7.00 70.00 5,980,317.23 553,455.16 365.25 3,889.58 365.25 7.00 70.31 5,980,415.50 553,441.92 463.85 3,888.55 463.85 7.00 71.13 5,980,514.09 553,440.24 512.78 3,892.39 512.78 7.00 72.23 5,980,563.04 553,443.75 561.80 3,896.71 561.80 7.00 -140.00 5,980,612.07 553,447.75 661.12 3,899.59 661.12 7.00 -140.40 5,980,711.41 553,449.98 711.07 3,898.15 711.07 7.00 -140.88 5,980,761.34 553,448.20 760.90 3,894.23 760.90 7.00 -100.00 5,980,811.14 553,443.96 859.42 3,877.47 859.42 7.00 -100.02 5,980,909.53 553,426.54 955.17 3,849.01 955.17 7.00 -99.96 5,981,005.09 553,397.45 1,001.56 3,830.52 1,001.56 7.00 -99.75 5,981,051.35 553,378.66 1,047.95 3,812.04 1,047.95 7.00 85.00 5,981,097.61 553,359.88 1,143.70 3,783.72 1,143.70 7.00 84.83 5,981,193.17 553,330.92 1,242.23 3,767.22 1,242.23 7.00 84.55 5,981,291.57 553,313.77 1,292.08 3,763.48 1,292.08 7.00 84.35 5,981,341.39 553,309.71 1,341.92 3,759.75 1,341.92 7.00 -88.00 5,981,391.20 553,305.64 1,440.47 3,743.19 1,440.47 7.00 -87.95 5,981,489.63 553,288.44 1,536.27 3,714.76 1,536.27 7.00 -87.86 5,981,585.23 553,259.37 1,582.70 3,696.21 1,582.70 7.00 -87.81 5,981,631.53 553,240.52 1,629.12 3,677.66 1,629.12 7.00 90.00 5,981,677.82 553,221.67 1,724.93 3,649.23 1,724.93 7.00 89.99 5,981,773.43 553,192.61 1,823.49 3,632.69 1,823.49 7.00 89.97 5,981,871.87 553,175.42 1,922.05 3,616.25 1,922.05 7.00 -100.00 5,981,970.32 553,158.32 2,017.89 3,588.09 2,017.89 7.00 -99.91 5,982,065.95 553,129.54 2,113.70 3,560.04 2,113.70 7.00 90.00 5,982,161.57 553,100.86 2,212.22 3,543.88 2,212.22 7.00 89.69 5,982,259.97 553,084.05 2,262.05 3,540.35 2,262.05 7.00 89.38 5,982,309.77 553,080.18 6/252018 4.04:44PM Page 4 COMPASS 5000.14 Build 85 ConocoPhillips BA' � E*R ConocoPhillips Planning Report IJGHES aGEcompany Database: EDT Alaska Sandbox Local Coordinate Reference: Mil 11-1-21 Company: ConocoPhillips (Alaska) Inc. -Kupl TVD Reference: Mean Sea Level Project Kupamk River Unit MD Reference: 1H-21 @ 96.00usft (1H-21) Site: Kuparuk 1H Pad North Reference: True Well: 1 H-21 Survey Calculation Method: Minimum Curvature Wellbore: 11-1-21A Map Map Rate Azimuth Northing Design: 1H-21A_wp03 (1 (usft) lush) 7.00 Planned Survey 5,982,35971 553,079,36 7.00 83.86 5,982,459.31 553,086.81 Measured -90.00 5,982,558.94 TVD Below 7.00 -89.84 Vertical Depth Inclination 7.00 Azimuth System +N/ -S +E/ -W Section (usft) (1 (`) (usft) (usft) (usft) (usft) 10,50000 87.92 1.18 6,503.83 2,31200 3,539.86 2,312.00 10,600.00 8869 8.14 6,506.79 21411.56 3,547.97 2,411.56 15 7.00 -89.57 5,983,350.69 553,035.11 10,700.00 88.70 1.14 6,509.07 2,511.14 3,556.04 2,511.14 10,800.00 88.73 354.13 6,511.33 2,610.97 3,551.92 2,610.97 10,850.00 88.75 350.63 6,512.43 2,660.51 3,545.30 2,660.51 16 10,900.00 88.75 354.13 6,513.52 2,710.05 3,538.67 2,710.05 11,000.00 88.77 1.14 6,515.69 2,809.88 3,534.55 2,809.88 11,100.00 88.81 8.14 6,517.81 2,909.47 3,542.62 2,909.47 17 11,200.00 88.81 1.14 6,519.89 3,009.06 3,550.70 3,009.06 11,300.00 88.84 354.13 6,521.94 3,108.89 3,546.58 3,108.89 11,400.00 88.88 347.13 6,523.92 3,207.47 3,530.32 3,207.47 11,500.00 88.95 340.13 6,525.82 . 3,303.35 3,502.16 3,303.35 Planned TO at 11500.00 Dogleg Toolface Map Map Rate Azimuth Northing Easting (°/1008) (1 (usft) lush) 7.00 84.00 5,982,35971 553,079,36 7.00 83.86 5,982,459.31 553,086.81 7.00 -90.00 5,982,558.94 553,094.23 7.00 -89.84 5,982,658.73 553,089.45 7.00 -89.68 5,982,708.22 553,082.49 7.00 90.00 5,982,757.70 553,075.54 7.00 89.92 5,982,857.49 553,070.76 7.00 89.77 5,982,957.13 553,078.18 7.00 -90.00 5,983,056.76 553,085.59 7.00 -89.85 5,983,156.55 553,080.81 7.00 -89.71 5,983,255.01 553,063.90 7.00 -89.57 5,983,350.69 553,035.11 8252018 4:04:44PM Page 5 COMPASS 5000.14 Build 85 Targets ConocoPhillips Planning Report Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Well 1H-21 Mean Sea Level 1 H-21 @ 96.00usft (1 H-21) True Minimum Curvature Target Name -hiUmiss target Dip Angle Dip Dir. TVD +N/ -S +E/ -W Northing Easting -Shape (1) (1 (usft) (usft) (usft) (usft) (usft) 1H-21 A_Tot 0.00 0.00 6,538,00 -7,899.191,143,928.76 5,979,693.00 - plan misses target center by 1140018.15usft at 8150,00usft MD 16538.50 TVD, 20.54 N, 3938.11 E) - Point 1H-21A_T05 0.00 0.00 6,483.00 6,448.671,143,875.35 5,981,143.00 - plan misses target center by 1139955.59usft at 8150.00usft MD (6538.50 TVD, 20.54 N, 3938.11 E) - Point 1H-21A_T08 0.00 0.00 6,516.00 -4,981.011,143,651.03 5,982,609.00 - plan misses target center by 1139723.89usft at 8150.00usft MD (6538.50 TVD, 20.54 N, 3938.11 E) - Point 1H -21A T0O 0.00 0.00 6,526.00 4,487.731,143,618.29 5,983,102.00 - plan misses target center by 1139689.09usft at 8150.00usft MD (6538.50 TVD, 20.54 N, 3938.11 E) - Point 1H-21 A_T02 0.00 0.00 6,539.00 -7,770.011,144,053.63 5,979,823.00 - plan misses target center by 1140142.13usft at 8150.00usft MD (6538.50 TVD, 20.54 N, 3938.11 E) - Point 1H-21A_T07 0.00 0.00 6,507.00 -5,379.151,143,664.40 5,982,211.00 - plan misses target center by 1139739.07usft at 8150.00usft MD (6538.50 TVD, 20.54 N, 3938.11 E) - Point 1H-21 CTD Polygon Nor 0.00 0.00 0.00 ConocoPhillips Database: EDT Alaska Sandbox Company: ConocoPhillips (Alaska) Inc. -Kupl Project: Kupamk River Unit Site: Kuparuk lH Pad Well: 1H-21 Wellbore: 1H -21A Design: 1H-21A_wP03 Targets ConocoPhillips Planning Report Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Well 1H-21 Mean Sea Level 1 H-21 @ 96.00usft (1 H-21) True Minimum Curvature Target Name -hiUmiss target Dip Angle Dip Dir. TVD +N/ -S +E/ -W Northing Easting -Shape (1) (1 (usft) (usft) (usft) (usft) (usft) 1H-21 A_Tot 0.00 0.00 6,538,00 -7,899.191,143,928.76 5,979,693.00 - plan misses target center by 1140018.15usft at 8150,00usft MD 16538.50 TVD, 20.54 N, 3938.11 E) - Point 1H-21A_T05 0.00 0.00 6,483.00 6,448.671,143,875.35 5,981,143.00 - plan misses target center by 1139955.59usft at 8150.00usft MD (6538.50 TVD, 20.54 N, 3938.11 E) - Point 1H-21A_T08 0.00 0.00 6,516.00 -4,981.011,143,651.03 5,982,609.00 - plan misses target center by 1139723.89usft at 8150.00usft MD (6538.50 TVD, 20.54 N, 3938.11 E) - Point 1H -21A T0O 0.00 0.00 6,526.00 4,487.731,143,618.29 5,983,102.00 - plan misses target center by 1139689.09usft at 8150.00usft MD (6538.50 TVD, 20.54 N, 3938.11 E) - Point 1H-21 A_T02 0.00 0.00 6,539.00 -7,770.011,144,053.63 5,979,823.00 - plan misses target center by 1140142.13usft at 8150.00usft MD (6538.50 TVD, 20.54 N, 3938.11 E) - Point 1H-21A_T07 0.00 0.00 6,507.00 -5,379.151,143,664.40 5,982,211.00 - plan misses target center by 1139739.07usft at 8150.00usft MD (6538.50 TVD, 20.54 N, 3938.11 E) - Point 1H-21 CTD Polygon Nor 0.00 0.00 0.00 -7,723.091,143,764.91 5,979,868.00 -plan misses target center by 1139871.85usft at 8150.00usft MD (6538.50 TVD, 20.54 N, 3938.11 E) Polygon - Polygon Point 1 0.00 0.00 0.00 5,979,868.00 Point 2 0.00 9.13 132.08 5,979,878.00 Point 0.00 272.48 84.80 5,980,141.01 Point 0.00 1,101.34 -31.78 5,980,969.00 Point 0.00 2,179.05 -272.73 5,982,044.99 Point 0.00 3,319.39 -304.25 5,983,184.98 Point 7 0.00 3,223.79 90.17 5,983,092.00 Point 0.00 1,937.50 110.73 5,981,806.00 Point 9 0.00 811.57 385.37 5,980,682.02 Point 10 0.00 -70.95 447.59 5,979,800.02 Point 11 0.00 -231.58 388.53 5,979,639.02 Point 12 0.00 -332.56 231.84 5,979,537.01 Point 13 0.00 -325.97 -11.14 5,979,542.00 Point 14 0.00 0.00 0.00 5,979,868.00 1,693,400.00 1,693,337.00 1,693,103.00 1,693,067.00 1,693,524.00 1,693,119.00 1,693,235.00 1,693,235.00 1,693,367.00 1,693,317.99 1,693,195.94 1,692,947.89 1,692,908.83 1,693,303.84 1,693,332.90 1,693,614.96 1,693,683.01 1,693,625.02 1,693,469.01 1,693,226.02 1,693,235.00 1H-21A_TO6 0.00 0.00 6,487.00 -5,868.651,143,732.17 5,981,722.00 1,693,190.00 - plan misses target center by 1139809.27usft at 8150.00usft MD (6538.50 TVD, 20.54 N. 3938.11 E) - Point 1H-21A_T03 0.00 0.00 6,526.00 -7,523.741,144,018.25 5,980,069.00 1,693,487.00 - plan misses target center by 1140105.10usft at 8150.00usft MD (6538.50 TVD, 20.54 N. 3938.11 E) - Point 1H-21 CTD Polygon Ea: 0.00 0.00 0.00 -7,722.411,143,812.92 5,979,869.00 1,693,283.00 - plan misses target center by 1139919.85usft at 8150.00usft MD (6538.50 TVD, 20.54 N, 3938.11 E) - Polygon Point 1 0.00 0.00 0.00 5,979,869.00 1,693,283.00 Point 0.00 25.79 1,403.34 5,979,904.07 1,694,686.00 Point 0.00 397.55 3,275.00 5,980,288.17 1,696,554.98 Point 0.00 -885.89 3,166.56 5,979,004.16 1,696,455.04 Point 0.00 -735.54 1,440.34 5,979,143.07 1,694,728.03 Point 0.00 -321.02 -2.11 5,979,548.00 1,693,283.01 Point 0.00 0.00 0.00 5,979,869.00 1,693,283.00 1H-21A_T04 0.00 0.00 6,466.00 -7,029.631,144,010.52 5,980,563.00 1,693,476.00 B F UG,,ES a GE company Latitude Longitude 70° 5'52.827 N 1401 23'39.466 W 70° 66.986 N 140° 23'34.690 W 70" 6'21.565 N 140'23'34.709 W 701 6'26,402 N 140-23- 70' 40"23' 70" 5'53.896 N 140-23- 70* 40°23' 70" 6'17.680 N 140° 23' 701 5'54.778 N 140" 23' 701 6'12.828 N 140" 23'36.252 W 701 5'56.339 N 140" 23'35.286 W 70' 5' 54.714 N 140° 23'41.999 W 701 6' 1.147 N 140'23'33.361 W 6252018 4:04.44PM Page 6 COMPASS 5000.14 Build 85 ConocoPhillips BA ER ConocoPhillips Planning Report BAT a6Emmpany Database: EDT Alaska Sandbox Local Coordinate Reference: Well iH-21 Company: ConocoPhillips (Alaska) Inc. -Kupt TVD Reference: Mean Sea Level Project: Kuparuk River Unit MD Reference: 1 H-21 @ 96.00usft (1H-21) Site: Kupamk 1 H Pad North Reference: True Well: 1H-21 Survey Calculation Method: Minimum Curvature Wellbore: 11-1-21A Design: 1H-21 A_wp03 -Point - Casing Points Measured Vertical Casing Hole Depth Depth Diameter Diameter (usft) (usft) Name (in) (in) 11,500.00 6,525.82 23/8" 2.375 3.000 Plan Annotations Measured Vertical Local Coordinates Depth Depth +N/S +E/ -W (usft) (usft) (usft) (usft) Comment 7,807.30 6,468.09 -110.57 3,695.08 TIP 7,825.00 6,481 .90 -110.37 3,706.15 KCP 7,846.00 6,497.80 -110.12 3,719.86 End 20 dls, Start 45 dls 7,950.73 6,538.50 -108.39 3,813.16 4 8,150.00 6,538.50 20.54 3,938.11 End 45 dls, Start 7 dls 8,350.00 6,530.18 218.25 3,912.74 6 8,650.00 6,487.38 512.78 3,892.39 7 8,850.00 6,466.15 711.07 3,898.15 8 9,150.00 6,472.11 1,001.56 3,830.52 9 9,450.00 6,482.38 1,292.08 3,763.48 10 9,750.00 6,485.34 1,582.70 3,696.21 11 1Q000.00 6,486.06 1,823.49 3,632.69 12 10,200.00 6,490.84 2,017.89 3,588.09 13 10,450.00 6,501.85 2,262.05 3,540.35 14 10,600.00 6,506.79 2,411.56 3,547.97 15 10,850.00 6,512.43 2,660.51 3,545.30 16 11,100.00 6,517.81 2,909.47 3,542.62 17 11,500.00 6,525.82 3,303.35 3,502.16 Planned TD at 11500.00 6125/2018 4:04:44PM Page 7 COMPASS 5000.14 Build 85 'IConocoPhillips BA. ICER 0-1 ConoCoPhillip5 Travelling Cylinder Report UGHES a GE company Company: ConocoPhillips (Alaska) Inc. -Kupl Project: Kuparuk River Unit Reference Site: Kupamk 1H Pad Site Error. 0.00 usft Reference Well: 1H-21 Well Error: 0.00 usft Reference Wellbore 1H -21A Reference Design: 1 H-21 A_wp03 Local Co-ordinate Reference: TVD Reference: MO Reference: North Reference: Survey Calculation Method: Output errors are at Database: Offset TVD Reference: Well 1 H-21 1 H-21 @ 96.00usft It H-21) 1H-21 @ 96.00usft (1H-21) True Minimum Curvature 1.00 sigma EDT Alaska Prod Offset Datum Reference 1H-21&_wp03 Filter type: GLOBAL FILTER APPLIED: All wellpaths within 200'+ 100/1000 of reference Depth Interpolation Method: MD Interval 25.00usft Error Model: ISCWSA Depth Range: 7,807.30 to 11,500.00usft Scan Method: Tray. Cylinder North Results Limited by: Maximum center -center distance of 1,345.84 usft Error Surface: Pedal Curve Survey Toot Program Date 6/25/2018 From To (usft) (usft) Survey (Wellbore) Tool Name Description 102.20 7.807.301H-21 Srvyt-SLB_GCT-MS(1 H-21) GCT -MS Schlumberger GCT multishot 7,807.30 11,500.00 1H-21 A_wp03(1 H-21 A) MWD MWD -Standard Casing Points Measured VeNcal Casing Hole Depth Depth Diameter Diameter (usft) (usft) Name ("1 C) 121.00 121.00 16" 16 24 4,820.00 4,246.83 95/8" 9-5/8 12-1/4 11500.00 6,621.82 23/8" 2-318 3 Summary Reference Offset Centre to No -Go Allowable Measured Measured Centre Distance Deviation Warning Site Name Depth Depth Distance (usft) from Plan Offset Well - Wellbore- Design (usft) (usft) (usft) (usft) Kupamk 1 H Pad 1 H-05 -1 H-05 - 1 H-05 Out of range 1 H-05 -1 H-105 - 1 H-105 Out of range 1 H-07 - 1 H-07 - 1 H-07 Out of range 1 H-07 - 1 H -07A- 1 H -07A Out of range 1 H-07 - 1 H-07AP81 - 1 H-07APBI Out of range 1 H-07 - 1 H-07APB2 - 1 H-07APB2 Out of range 1 H-07 - 1 H-07APB3 - 1 H-07APB3 Out of range 1 H-09 - 1 H-09 - 1 H-09 Out of range 1 H-10 - 1 H -10A-1 H-1 OA Out of range 1 H-101 - 1 H-101 - 1 H-101 Out of range 1 H-101 - 1 H-101 L1 - 1 H-101 -1 Out of range 1 H-101 - 1 H-101 1-2 - 1 H-101 L2 Out of range 1 H-101 - 1 H-101 L3 - 1 H-101 L3 Out of range 1 H-101 - 1 H-101 1-4 - 1 H-101 L4 Out of range 11-1-102 -1 H-102 - 1 H-102 Out of range 1 H-102 -1 H-1021-1 - 1 H-1021-1 Out of range 1 H-102 - 1 H-1021-2 - 1 H-1021-2 Out of range 1 H-102 - 1 H-10213 - 1 H-10213 Out of range 1 H-102 -1 H-1021-4 - 1 H-1021-4 Out of range 1 H-11 - 1 H-11 - 1 H-11 Out of range 1 H-12 - 1 H-12 - 1 H-12 9,088.60 7,800.00 790.72 245.25 552.31 Pass - Major Risk 1 H-13 - 1 H-13 - 1 H-13 Out of range 1 H-14 - 1 H-14 - 1 H-14 Out of range 1 H-15 - 1 H-15 - 1 H-15 Out of range 1 H-18 -1 H-18 - 1 H-18 Out of range 1H -21 -1H -21-1H-21 7,825.00 7,825.00 0.00 1.04 -1.00 FAIL - Major Risk CC - Min centre to center distance or covergent point, SF - min separation factor, ES - min ellipse separation 6252018 9:22:49AM Page 2 COMPASS 5000.14 Build 85 �- ConocoPhillips BAT ConocoPhillips Travelling Cylinder Report IGI•IES a GEcompany Company: ConocoPhillips (Alaska) Inc. -Kupt Project: Kuparuk River Unit Reference Site: Kuparuk 1 H Pad Site Error: 0.00 usft Reference Well: 1 H-21 Well Error: 0.00 usft Reference Wellbore 1H -21A Reference Design: 1H-21A_wp03 Local Coordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Output errors are at Database: Offset TVD Reference: Well 1 H-21 iH-21 @ 96.00usft(1 H-21) 1 H-21 @ 96.00usft (1 H-21) True Minimum Curvature 1.00 sigma EDT Alaska Prod Offset Datum Summary Kuparuk lH Pad -1H -12 -1H -12-1H-12 Reference Offset Centre to No -Go Allowable -GCT -MS Measured Measured Centre Distance Deviation Warning Site Name Depth Depth Distance (usft) from Plan Semi Malo, Axis Offset Well - Wellbore - Design (usft) (usft) (usft) (usft) Kuparuk 1H Pad Measured Vertical Measured 1H -21-1H-21 AL1 -1H-21 AL1_wp02 8,514.67 8,525.00 6376 1.29 63.45 Pass - Minor 1/10 1 H-21 - 1 H-21 AL2 - 1 H-21AL2_wp02 Centre to No Go Allowable blaming Out of range 1 H-21 - iH-21 AL2 -01 - 1H-21AL2-01_wp02 Depth Depth Out of range 1 H401(UGNU) - 1 H-401 - 1 H-401 +EI -W Role size Centre Distance Out of range Plan: 1 H-112 - Plan: 1 H-112 - 1 H-112wp22 Duel 1 -aft) fuse (waft) Out of range Plan: 1 H-112 - Plan: 1 H-112 - 1 H-112wp23 PI lusnl (use) ("1 Out of range Rig: 1 H-108 - 1 H-1 08A - 1 H -1 08A wp01 lusnj 9,071.21 6.56472 Out of range Offset Design Kuparuk lH Pad -1H -12 -1H -12-1H-12 offset sire Error: 0.00 usft survey Program: 108 -GCT -MS Rule Assigned: Major Risk Drawl Well Effor 0.00 usft Reference Offset Semi Malo, Axis Measured Vertical Measured Vertical Reference Offset Toolface+ Offset Welborn Centre Casing- Centre to No Go Allowable blaming Depth Depth Depth Depth Azimuth +NIS +EI -W Role size Centre Distance Deviation Duel 1 -aft) fuse (waft) lose (UM) PI lusnl (use) ("1 lusm Dal lusnj 9,071.21 6.56472 8]25.00 6,42202 41.90 51]8 65.87 1345.37 5,12556 5 134177 257.08 1,108.07 Peso -Malar Risk 9.071.35 6,56432 8700.10 6.41372 41.90 51.57 6540 133874 5.10304 5 1319.36 255.77 1,085.09 Pass -Major Risk 9.071.47 8,564.73 8,675.00 6,404.95 4190 51.37 5186 1,332.05 5,080.50 5 1,297.06 256+46 1,062.10 Pass -Major Risk 9,071.59 8.56433 8,650.00 8,395.98 41.90 51,18 61.35 1,325.41 5,058.13 5 1,275,08 256.15 1,039.57 Pass -Major Risk 9,071.72 6,564.73 0.625.00 6,38778 41,90 50.99 63.78 1.318.84 5,035.83 5 1253.32 255.84 1017.18 Pass - Major Risk 8071.88 6.56474 0,600.00 6,377,21 41.90 5039 83.17 1,312.38 5,013.68 5 1,231.91 255.53 995.10 Pass - Major Risk 9,072.04 6,56435 8,575.00 8.357.32 41.90 50.60 62.54 1,305.98 499160 5 1,210.81 255.21 973.32 Pass - Major Risk 9,072.22 8,584.75 8,550,00 6.357.30 4190 50.41 61.87 1,299.62 4,969.60 5 1,189,94 254.89 951.77 Pass - Major Risk 9,072.48 8.564.76 8,525.00 6,37.10 41.90 50.22 61.16 1.293.45 4,947.63 5 1,169.35 254.57 looks Pass - Major Risk 9.072.82 6.564.77 8500.00 6,336.87 41.90 $0.03 60,41 1,287.56 4,92568 5 1,149.10 254.26 909.53 Pass - Major Risk 9.073.27 6,56479 8,475.00 6,32605 41.90 49,84 59.63 1,28192 4.903.77 5 1,129.19 253.94 888.91 Pass - Major Rusk 9,07335 6,56481 8.450.00 6,315.38 41.90 49.65 5881 1,276.32 4,881.86 5 1.109.51 253.62 888.53 Pass -Major Risk 9,074.24 7564.02 8,42500 6,304.72 41.90 49.46 57.96 1,27031 4,859,96 5 1,090,05 253.30 818.37 Pass - Major Risk 9,074.76 6,564,84 9,400,00 6,293.94 41.90 49.27 57.08 1,265.17 4,838.09 5 1,070,90 252.98 820.55 Pass - Major Risk 9.075.32 6,564,86 6,375.00 6.282.97 4180 49.00 MA5 1,259]4 4,816.29 5 1.052.14 252.67 809.12 Pass -Major Risk 9,075.92 6.564.80 8,350.00 6,27187 41.90 48,89 55.18 1,254.40 4,794.54 5 1+033.76 252.35 790.09 Pass -Major Risk 9078.55 6,564.91 0,325.00 6.260.56 41.90 4870 54.17 1,249,15 4,78.87 5 1,015.82 252.03 771.53 Pass - Major Risk 9.077.20 8,564.93 0,300.00 7248.87 41.90 45.51 53.10 1243.94 4.751.39 5 998.49 251.70 753,60 Pass - Major Risk 9,077,84 7564.95 8275.00 8236.85 41.90 48.32 51.99 1.23838 4,73009 5 981..0 251.38 736.32 Pass - Major Risk 9,078.43 6,564.97 8,250,00 6,224.47 41.90 48.13 50.82 1,233.55 4,709.01 5 98571 25105 71934 Pass - Major Risk 9.078.94 6.564,99 822500 6,211.73 41.90 47.95 49.61 1.228.21 4,688.17 5 950.35 250.72 703.92 Pass - Major Risk 9,079.42 6.565.01 8,200.00 6,198.65 4190 4738 48.36 1,222.80 4,887.44 5 935.53 250.39 68830 Pass - Mater Risk 9,079.89 7555.03 8,175.00 6.185.93 41.90 47.58 47.07 1,217.38 4.64630 5 921.13 250.06 673.99 Pan - Male, Risk 9.080.40 6,565.05 8.150.00 MnA3 41.90 0.39 45.73 1,212,00 4.625.94 5 907.19 249.73 65970 Pass - Malar Risk 9,080.92 6.565.07 0.125.00 7160.28 41.90 0.21 44.36 1.206,62 4,605.19 5 89372 249+40 645,% Pass -Miller Risk 8081,48 7565.09 5,100.00 8,17,45 41.90 47.02 42.95 1,201.27 4,584+41 5 881 249.7 632.81 Pass - Meier Risk 9,082.04 6,565,11 8,075,00 7131.71 4190 48.84 41.49 1,195.90 4,563.58 5 868.19 248.74 620.19 Pass -Major Risk 9.082.61 6,565.13 8,050.00 6.121.86 4190 46.65 40,00 1,190.54 4,54282 5 856.31 248AI 808.37 Pass -Major Risk 9.083.16 6.565.15 8,025.00 6,108.65 41.90 48.47 38.45 1,185.19 4.522.27 5 845.35 240.05 597.61 Pass -Major Risk 9,083.70 6,565.17 8,000.00 6,095.17 41.90 48.28 36.05 1,179,87 4,501.90 5 835.31 247.75 587.90 Pass - Major Risk 9,084.23 6,565.19 7,975.00 6.081.46 41.90 46.10 35.21 1,174,58 4,48168 5 826.15 20.42 579,23 Pass - Major Risk 8004.80 6,565.21 7.950.00 7067.41 41.90 45.92 33.53 1,169.40 4,461.66 5 815.04 247,11 57135 Pass - Mill, Risk 9,085.35 6,565.23 7.925.00 0,053.07 41.90 4574 31.81 1.154.32 4,441.82 5 810.97 248,80 565.55 Pass - Major Risk CC - Min centre to center distance or covergefd point, SF - min separation factor, ES - min ellipse separation 8/25/2018 9:22:49AM Page 3 COMPASS 5000.14 Build 85 Remark: AOGCC PTD No. 218-077 Coordinate Check 2 July 2018 INPUT OUTPUT Geographic, NAD27 State Plane, NAD27 5004 - Alaska 4, U.S. Feet KRU 1H-115 1/1 Latitude: 70 21 22.356 Northing/Y: 5980024.552 Longitude: 149 35 51.196 Easting/X: 549555.232 Convergence: 0 22 44.48731 Scale Factor: 0. 999902790 Corpscon v6.0.1, U.S. Army Corps of Engineers TRANSMITTAL LETTER CHECKLIST WELL NAME: u IH -2-174 / PTD: -077 liC Lj Development _ Service Exploratory _ Stratigraphic Test _ Non -Conventional FIELD: cpm ✓tti� ✓�Y� POOL: 4Lc 2 � Gcle 1C/tit�t� Check Box for Appropriate Letter / Paragraphs to be Included in Transmittal Letter CHECK OPTIONS TEXT FOR APPROVAL LETTER MULTI The permit is for a new wellbore segment of existing well Permit LATERAL No. API No. 50 - (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 days after completion, suspension or abandonment of this well. Revised 2/2015 WELL PERMIT CHECKLIST Field &Pool KUPARUK RIVER, KUPARUK RIV OIL - 490100 Date: Engineering Public Co issionej: Commissioner 7_s _ CD PTD#:2180770 --- PS ALASK Company CONOCOPH[ A INC. Initial Classrrype Well Name: KUPARUK RIV UNIT 1H-21A _ Program DEy Well bore seg a DEV/1-OIL GeoArea X90 Administration 17 Nonconven, gas conforms to AS31,05,03ftI.A),0 2.A-D) .. NA _ Unit 111 ___ On/Off Shore (Zn _ Annular spo - - 1 Permit fee attached - - _ - . - - - - _ _ NA - - - - 2 Lease number appropriate_ _ _ _ - _ _ - - _ - - , Yes Entire well in ADL 025639. 3 Unique well name and number _ _ - Yes- 4 Well located in.a defined-pool Yes KUPARUK RIVER,-KUPARUK RIV OIL - 490100 5 Well located proper distance from drijling unit boundary Yes - - _ Kuparuk River Oil Pool, governed by Conservation Order No. 432D 6 Well located proper distance from other wells Yes - Conservation Order No. 432D has no interwell. spacingrestrictions.Wellbore will be. more than 500' 7 Sufficient acreageavailable indrillingunit.... Yes - from an external property line where ownership or landownership. changes. As proposed, well will 8 If deviated, is wellbore platincluded- - _ - _ _ _ _ - _ - Yes - _ - - conform to spacing requirements. 9 Operator only affected Party _ - Yes - - - - - - - - - - - 10 Operator has. appropriate bond in force - - - _ _ - _ _ _ Yes..... Appr Date 11 Permit can be issued without conservation order- _ _ _ Yes SFD 7/2/2018 12 Permit can be issued without administrative. approval .... Yes 13 Can permit be approved before 15-day wail - ... - - - _ - Yes 14 Well located within area and.strata authorized by Injection Order # (put. 10# in. comments) (For- NA 15 All wells _within .1/4-mile area.of review identified (For service well only) _ - - NA 116 Pre-produced injector: duration of pre production less than 3 months (For service well only) NA. Engineering 18 Conductor string_provided - - - - ----- ------ - - - - - - - - NA .. Thru Lubin CTD Sidetrack from existing wellbore - - - 9 9 19 Surfacecasing protects all-known USDWs - - .... - NA - Thru tubing CTD Sidetrack from existing wellbore 20 CMT vol adequate to circulate-on conductor. is surf _csg .. - - _ _ - _ _ _ NA _ - - Thru tubing CTD Sidetrack from existing wellbore- 21 CMT vol adequate to tie-in long string to surf csg - - - - - _ - _ _ _ NA _ 22 CMT will cover-all known_ productive horizons - - - . - - _ - - NA - - _ Sloned liner completion, entire wellbore In productive zone 23 Casing designs adequate for C, T, B 8 permafrost- - .. - - - _ Yes - - Slotted liner completion 24 Adequate tankage or reserve pit .. _ - _ - .. - - .. _ - - _ -Yes 25 If a re-drill, has. a 10-403 for abandonment been approved - - ... - .. _Yes 26 .equate wellbore separation proposed .. - - Yes - - - -- - - 27 If diveder required, does it meet regulations - - - _ - - . NA Thru tubing CTD Sidetrack from existing wellbore Appr Date 28 Drilling Fluid program schematic &equip lisladequale........ - - - - - - -Yes MGR 7/5/2078 29 BOPES,-do they meet regulation - - - . - - -Yes 30 BOPE-press rating appropriate; test to-(put psig in comments). - _ - - - _ - - - _ Yes - - - . _ - 3000 psi 31 Choke. manifold come-lies w/APl RP-53 (May 84)- . _ - _ - - _ - . Yes 32 Work will occur without operation shutdown_ _ - _ . _ - - . _ - _ - _ _ _ Yes- 33 Is presence of H2$ gas probable - - .. ----- -.. .. ..-Yes 34 Mechanical condition of wells within AOR verified (For service well only) Geology 135 Permit can be issued w/o hydrogen sulfide measures -- ...---.. .. No _ - _ _ - - . Wells.on.lH-Pad are H2S bea[ing. H2S measu[es requited, i36 oo potential overpressure zones .. _ _ - _ _ - _ _ _ _ _ - Yes . -- ...----- - - - - . Expected reservojrpressure is –9.1 ppg EMW, with a maximum up to -10.0 ppg EMW. Appr Date 37 Seismic is analysis Seismic analysis of shallow gas zones .. - .NA_ _ . _ - - _ Well will be drilled using-8.6 ppg mud, a coiled-tubing rig, and. managed pressure drilling SFD 7/2/2018 38 Seabed condition survey (if off-shoe) - - - . _ - _ _ NA ...- - . -technique to. control formation pressures and stabilize Shale sections. NOTE; Chance of 39 Contact name/phone for weeklyprogressreports [exploratory only] - - - NA_ .. - _ _ _ encountering gas while drilling this due-to gas. injection in this r -wellbore Perfo[med area. Geologic Commissioner: Date: Engineering Public Co issionej: Commissioner 7_s _ CD Date ��'