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DATA SUBMITTAL COMPLIANCE REPORT 3/25/2020 Permit to Drill 2191390 Well Name/No. KUPARUK RIV UNIT 2M-211-1-01 Operator ConocoPhillips Alaska, Inc. MD 13791 TVD 5870 Completion Date 11/29/2019 Completion Status 1 -OIL Current Status 1-011- REQUIRED -OILREQUIRED INFORMATION Mud Log No Z Samples No I API No. 50-103-20156-61-00 UIC No Directional Survey Yes I--,' DATA INFORMATION List of Logs Obtained: GR/Res (from Master Well Data/Logs) Well Log Information: Log/ Electr Data Digital Dataset Log Log Run Interval OH I Type Med/Frmt Number Name Scale Media No Start Stop CH Received Comments ED C 31790 Digital Data 1/6/2020 Electronic File: 2M-211-1-01 EOW NAD27.pdf ED C 31790 Digital Data 1/6/2020 Electronic File: 2M-211-1-01 EOW NAD27.txt ED C 31790 Digital Data 1/6/2020 Electronic File: 2M-211-1-01 EOW NAD83.pdf ED C 31790 Digital Data 1/6/2020 Electronic File: 2M-211-1-01 EOW NAD83.txt Log 31790 Log Header Scans 0 0 2191390 KUPARUK RIV UNIT 2M-21 L1-01 LOG HEADERS ED C 31904 Digital Data 9908 13807 1/13/2020 Electronic Data Set, Filename: 2M-21L1- 01_GAMMA RES.Ias ED C 31904 Digital Data 1/13/2020 Electronic File: 2M-211-1-01 2MD Final.cgm ED C 31904 Digital Data 1/13/2020 Electronic File: 2M-211-1-01 51VID Final.cgm ED C 31904 Digital Data 1/13/2020 Electronic File: 2M-211-1-01 5TVDSS Final.cgm ED C 31904 Digital Data 1/13/2020 Electronic File: 2M-211-1-01 21VID Final.pdf ED C 31904 Digital Data 1/13/2020 Electronic File: 2M-211-1-01 51VID Final.pdf ED C 31904 Digital Data 1/13/2020 Electronic File: 2M-211-1-01 5TVDSS Final.pdf ED C 31904 Digital Data 1/13/2020 Electronic File: 2M-211-1-01 EOW NAD27.pdf ED C 31904 Digital Data 1/13/2020 Electronic File: 2M-21 L1-01 EOW NAD27.txt ED C 31904 Digital Data 1/13/2020 Electronic File: 2M-211-1-01 Final Surveys @ 13807.csv ED C 31904 Digital Data 1/13/2020 Electronic File: 2M-211-1-01 Final Surveys @ 13807.xlsx ED C 31904 Digital Data 1/13/2020 Electronic File: 2M-211-1-01 _Survey Listing.txt ED C 31904 Digital Data 1/13/2020 Electronic File: 2M-211-1-01 _Surveys.txt AOGCC Paget of 3 Wednesday, March 25, 2020 DATA SUBMITTAL COMPLIANCE REPORT 3/25/2020 Permit to Drill 2191390 Well Name/No. KUPARUK RIV UNIT 2M-211-1-01 Operator ConocoPhillips Alaska, Inc. API No. 50-103-20156-61-00 MD 13791 TVD 5870 Completion Date 11/29/2019 Completion Status 1 -OIL Current Status 1 -OIL UIC No ED C 31904 Digital Data 1/13/2020 Electronic File: 2M -21L1- 01 _252apescan_BH I_CTK.txt ED C 31904 Digital Data 1/13/2020 Electronic File: 2M-211-1- 01 _5_ta pes ca n_B H I_C T K. txt ED C 31904 Digital Data 1/13/2020 Electronic File: 2M-211-1-01_output.tap ED C 31904 Digital Data 1/13/2020 Electronic File: 2M-211-1-01 2MD Final.tif ED C 31904 Digital Data 1/13/2020 Electronic File: 2M-211-1-01 5MD Final.tif ED C 31904 Digital Data 1/13/2020 Electronic File: 2M-211-1-01 5TVDSS Final.tif Log 31904 Log Header Scans 0 0 2191390 KUPARUK RIV UNIT 2M-21 L1-01 LOG HEADERS Well Cores/Samples Information: Name INFORMATION RECEIVED Completion Report Y Production Test Information Y / NA Geologic Markers/Tops Y COMPLIANCE HISTORY Completion Date: 11/29/2019 Release Date: 10/17/2019 Description Comments: Interval Start Stop 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 Wednesday, March 25, 2020 DATA SUBMITTAL COMPLIANCE REPORT 3/25/2020 Permit to Drill 2191390 Well Name/No. KUPARUK RIV UNIT 21VI-211-1-01 Operator ConocoPhillips Alaska, Inc. API No. 50-103-20156-61-00 MD 13791 TVD 5870 Completion Date 11/29/2019 Completion Status 1-0I1- Current Status 1-0I1- UIC No ZS - Compliance Reviewed By: _ Date:—� AOGCC Page 3 of 3 Wednesday, March 25, 2020 Baker � PRINT DISTRIBUTION LIST Hughes COMPANY ConocoPhillips Alaska, Inc. WELL NAME 2M -21L1-01 FIELD Greater Kuparuk Area COUNTY North Slope Borough BHI DISTRICT Alaska AUTHORIZED BY Patrick Rider EMAIL Patrick. Rider(cDbakerhughes.com 21 91 3 9 31904' Please sign and return one copy of this transmittal form to: ConocoPhillips Alaska, Inc. Tom Osterkamp (WNS Petroleum Technician) 700 G Street. Anchorage, Alaska 99510 Ito acknowledge receipt of this data. LOG TYPE GR - RES LOG DATE November 28, 2019 TODAYS DATE January 9, 2020 Revision STATUS Final Replacement: No Details: COMPANY ADDRESS (FEDEX WILL NOT DELIVER TO P.O. BOX) PERSON ATTENTION Rev. Requested by: FIELD / FINAL CD/DVD FINAL PRELIM LOGS (las, alis, PDF, META, SURVEY REPORT LOGS CGM, Final Surveys) (Compass) -T—OF PRINTS 9 UF PKIN 16 1 # OF COPIES # OF COPIES 1# OF COPIES 1� 4 4 4 4 4 4 1 BP North Slope. EOA, PBOC, PRB-20 (Office 109) D&GWO Wells Admin Brenda Glassmaker & Peggy O'Neill 900 E. Benson Blvd. Anchorage, Alaska 99508 2 ConocoPhillips Alaska Inc. Attn: Ricky Elgarico ATO 708 700 G Street Anchorage, AK 99510 3 ExxonMobil, Alaska Attn: Lynda M. Yaskell and/or Leonardo Elias 3201 C Street, Suite 505 Anchorage, AK 99503 4' State of Alaska - AOGCC iAttn: Natural Resources Technician 11 1333 W. 7th Ave, Suite 100 Anchorage, Alaska 99501 5 DNR - Division of Oil & Gas *** 1 Attn: Resource Evaluation 550 West 7th Avenue, Suite 1100 Anchorage, Alaska 99501 '*** Stamp "confidential" on all material deliver to DNR 6' BP Exploration (Alaska) Inc. Petrotechnical Data Center, LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 L`-,7CjLzl� JAN jE v 13 2420 TOTALS FOR THIS PAGE: 0 1 2 0 0 Date: Baker Hughes C January 3, 2020 I Abby Bell AOGCC 333 West 7th Ave, Suite 100 Anchorage, Alaska 99501 9139 3170 Letter of Transmittal Harvey Finch Baker Hughes 795 East 94th Avenue Anchorage, Alaska 99515 Please find enclosed the directional survey data for the following well(s): 2M-21L1PB1 2M -21L1 2M -21L1-01 (3) Total prints Enclosed for each well(s): 1 hardcopy print of directional survey reports (NAD27) 1 compact disk containing electronic survey files Harvey Finch Baker Hughes Wellplanner Harvey.Finch@bakerhughes.com 219139 31790 ConocoPhillips ConocoPhillips Alaska Inc_Kuparuk Kuparuk River Unit Kuparuk 2M Pad 2M-21 L1-01 50-103-20156-61 Baker Hughes INTEQ Baker Hughes,`] Definitive Survey Report 03 January, 2020 1/3/2020 1. 10:11PM Page 2 COMPASS 5000.14 Build 85H Con ocoP h i I I i ps Baker Hughes] Conoco Phillips Definitive Survey Report Company: ConocoPhillips Alaska Inc—Kuparuk Local Co-ordinate Reference: Well 2M-21 Project: Kuparuk River Unit ND Reference: 2M-21 @ 140.00usft Site: Kuparuk 2M Pad MD Reference: 2M-21 @ 140.00usft Well: 2M-21 North Reference: True Wellbore: 2M-211-1-01 Survey Calculation Method: Minimum Curvature Design: 2M-211-1-01 Database: EDT 14 Alaska Production Project Kuparuk River Unit, North Slope Alaska, United States Map System: US State Plane 1927 (Exact solution) System Datum: Mean Sea Level Geo Datum: NAD 1927 (NADCON CONUS) Using Well Reference Point Map Zone: Alaska Zone 04 Using geodetic scale factor Well 2M-21 Well Position +N/ -S 0.00 usft Northing: 5.948,985.88 usft Latitude: 70° 16' 18.585 N +E/ -W 0.00 usft Easting: 488,319.18usft Longitude: 150° 5' 40.098 W Position Uncertainty 0 00 usft Wellhead Elevation: usft Ground Level: 105.30 usft Wellbore 2M-21 L1-01 Magnetics Model Name Sample Date Declination Dip Angle Field Strength (1) (% (nT) BG G M 2018 12/l/2019 16.17 80.77 57,384 Design 2M-21 L1-01 Audit Notes: Version: 1.0 Phase: ACTUAL Tie On Depth: 10,198.66 Vertical Section: Depth From (TVD) +N/ -S +E/ -W Direction (usft) (usft) (usft) (I 34.70 0.00 0.00 23.79 1/3/2020 1. 10:11PM Page 2 COMPASS 5000.14 Build 85H ConocoPhillips Baker Hughes ConocoPhillips Definitive Survey Report Company: ConocoPhillips Alaska Inc-Kuparuk Local Co-ordinate Reference: Well 2M-21 Project: Kuparuk River Unit Map TVD Reference: 2M-21 @ 140.00usft Site: Kuparuk 2M Pad z Azi MD Reference: 2M-21 @ 140.00usft +N/ -S +E/ -W Well: 2M-21 DLS North Reference: True (usft) Wellbore: 2M-211-1-01 (usft) Survey Calculation Method: Minimum Curvature (usft) Northing Design: 2M-211-1-01 Section Database: EDT 14 Alaska Production Survey Program Date (ft) (ft) From To 10.198.66 Survey Survey (usft) (usft) Survey (Wellbore) Tool Name Description Start Date End Date 200.00 10,000.00 2M-21 srvy 1 - SLB_GCT-MS (2M-21) GCT -MS Schlumberger GCT multishot 11/28/1991 11/28/1991 10,084.93 10,118.78 2M-211-1 MWD -INC (2M-211-1) MWD-INC_ONLY (INC>10°) MWD-INC_ONLY_FILLER ( INC>10°) 11/14/2019 11/14/2019 10,138.05 10,198.66 2M-211-1 MWD (2M-211-1) MWD OWSG OWSG MWD - Standard 11/15/2019 11/22/2019 10,214.43 10,252.13 2M-21 L1-01 MWD -INC (2M-211-1-01) MWD-INC_ONLY (INC>10°) MWD-INC_ONLY_FILLER ( INC>10°) 11/22/2019 11/28/2019 10,265.06 13,753.27 2M-211-1-01 MWD (2M-211-1-01) MWD OWSG OWSG MWD - Standard 11/29/2019 11/29/2019 Survey Map Map Vertical MD Incn z Azi TVD TVDSS +N/ -S +E/ -W DLS (usft) (usft) (usft) usft usft (usft) (usft) Northing Easting (°/100') Section Survey Tool Name Annotation (ft) (ft) (ft) 10.198.66 95.20 36.91 5.894.47 5.754.47 7.070.70 2,995.98 5,956,051 21 491.325.83 58.48 7.678.43 MWD OWSG (3) TIP 10.214.43 94.15 45.51 5.89319 5.753.19 7,082.51 3,006.33 5.956,063 01 491,336.19 54.76 7,693.42 MWD-INC_ONLY (INC>100) (4) KOP 10,245.36 94.93 45.00 5.890.74 5.750.74 7,104.21 3,028.22 5,956,084.68 491.358.12 3.01 7,722.11 MWD -INC -ONLY (INC>10°) (4) Interpolated Azimuth 10,265.06 96.12 43.83 5.888.84 5.748.84 7.118.22 3,041.95 5,956,098.66 491,371.87 8.45 7,740.46 MWD OWSG (5) 10,299.89 9289 38.15 5.886.10 5.746.10 7..144.42 3.064.71 5.956.124.82 491,394.66 18.71 7,773.61 MWD OWSG (5) 10,324.83 9083 34.64 5.885.29 5,745.29 7,164.48 3,079.49 5,956,144.86 491,409.48 16.31 7,797.94 MWD OWSG (5) 10,349.88 89.79 34.73 5,88516 5.745.16 7,185.08 3,093.75 5.956,165 43 491,42377 4.17 7,822.53 MWD OWSG (5) 10,381.31 9206. 37.73 5.884.65 5,744.65 7.210.42 3.112.32 5.956,190.74 491,442.37 11.97 7,853.22 MWD OWSG (5) 10,410.72 9181 33.63 5,88366 574366 7.23429 3.129.46 5.956,214.59 491,459 55 13.96 7,881.97 MWD OWSG (5) 10,444.04 90.03 37.14 5.883.12 5,743.12 7,261.45 3.148.75 5.956,241.71 491,478.88 11.81 7,914.60 MWD OWSG (5) 10,476.72 91.60 37.46 5.882.66 5,742.66 7,287.44 3.168.55 5,956,267.67 491,498.72 4.90 7,946.37 MWD OWSG (5) 10,514.09 91.17 37.79 5.881.75 5,741.75 7.317.03 3.191.36 5.956,297.22 491,521.57 1.45 7,982.65 MWD OWSG (5) 10,531.18 9102 37.36 5.881 43 5.741 43 7.330.57 3.201 77 5.956,310 74 491,532 01 2.66 7,999.24 MWD OWSG (5) 10,563.45 9018 40.76 5,881.09 5.741.09 7,355.62 3,222.10 5,956,335.76 491,552.37 10.85 8,030.37 MWD OWSG (5) 10,596.34 88.40 41.45 5,881.50 5,741.50 7,380.40 3.243.73 5,956,360.51 491,574.03 5.80 8,061.76 MWD OWSG (5) 10,621.63 86.96 42.07 5,882.52 5.742.52 7,39925 3,260.55 5,956,379 33 491,590.89 620 8,085.80 MWD OWSG (5) 10,652.44 86.03 41.29 5.884.40 5.744.40 7.422.22 3.281.00 5,956,402 26 491,611.37 3.94 8.115.06 MWD OWSG (5) 10.680.80 86.84 43.30 5,886.17 5,746.17 7,443.15 3.300.05 5,956,423.16 491,630.45 7.63 8,141.90 MWD OWSG (5) 10,711.44 91.91 46.04 5,886.50 5,746.50 7.464.93 3,321.58 5,956,444.91 491,652.01 18.81 8.170.52 MWD OWSG (5) 1/3/2020 1: 10: 11 PM Page 3 COMPASS 5000.14 Build 85H ConocoPhillips Baker Hughes ConocoPhillips Definitive Survey Report Company: ConocoPhillips Alaska Inc Kuparuk Local Co-ordinate Reference: Well 2M-21 Project: Kuparuk River Unit TVD Reference: 2M-21 @ 140.00usft Site: Kuparuk 2M Pad MD Reference: 2M-21 @ 140.00usft Well: 2M-21 North Reference: True Wellbore: 2M-211-1-01 Survey Calculation Method: Minimum Curvature Design: 2M-211-1-01 Database: EDT 14 Alaska Production Survey Annotation 1/3/2020 1: 10: 11 PM Page 4 COMPASS 5000.14 Build 85H Map Map Vertical MD Inc Azi TVD TVDSS +N1-3 +El -W DLS (usft) (°) (°) (usft ) usft ( ) (usft) (usft) Northing East) (°1100') Section Survey Tool Name (ft) (ft) (ft) 10,741.59 89.17 47.35 5,886.22 5,746.22 7.485.61 3,343.52 5,956,465.55 491,673.98 10.07 8,198.29 MWD OWSG (5) 10,771 48 90.06 47.07 5,886.42 5,746.42 7,505.91 3,365.45 5,956,485.82 491,695.94 312 8,225.71 MWD OWSG (5) 10,801.12 86.93 43.67 5,887.20 5,747.20 7,526.72 3,386.53 5,956,506.59 491,717.05 15.59 8,253.26 MWD OWSG (5) 10,831.94 85.98 40.14 5,889.10 5,749.10 7,549.61 3,407.08 5,956,529.45 491,737.63 11.84 8,282 49 MWD OWSG (5) 10,862.20 86.50 39.49 5,891.09 5,751.09 7,572.81 3,426.41 5,956,552.61 491,757.00 2.75 8,311.51 MWD OWSG (5) 10,892.40 88.71 40.31 5,892.35 5,752.35 7.59595 3,445.76 5,956,575.72 491,776.38 7.80 8,340.50 MWD OWSG (5) " 10,921.82 88.25 39.13 5,893.13 5,753.13 7,618.57 3,464.56 5,956,598.31 491,795.21 4.30 8,368.78 MWD OWSG (5) 10,952.50 89.63 39.57 5,893.70 5,753.70 7,642.29 3,484.01 5,956,622.00 491,814.69 4.72 8,398.33 MWD OWSG (5) 10,982.72 92.12 39.79 5,893.24 5,753.24 7,665.55 3,503.30 5,956,64522 491,834.02 8.27 8,427.39 MWD OWSG (5) 11,012.68 92.61 38.14 5,892.00 5,752.00 7,688.82 3,522.12 5,956,668.46 491,852.88 5.74 8,456.28 MWD OWSG (5) 11,042.46 90.25 36.16 5,891.26 5,751.26 7,712.55 3,540.10 5,956,692.16 491,870.89 10.34 8,485.24 MWD OWSG (5) 11,081.14 89.88 32.00 5,891.21 5,751.21 7,744.58 3,561.77 5,956,724.15 491,892.61 10.80 8,523.29 MWD OWSG (5) 11,105.06 90.74 24.09 5,891.08 5,751.08 7,765.67 3,573.00 5,956,745.22 491,903.87 33.26 8,547.12 MWD OWSG (5) 11,132.05 90.71 30.27 5,890.74 5,750.74 7,789.67 3,585.32 5,956,769.20 491,916.23 22.90 8,574.05 MWD OWSG (5) 11,162.22 88.65 25.24 5,890.91 5,750.91 7,816.36 3,599.37 5,956.795.86 491,930.32 18.02 8,604.14 MWD OWSG (5) 11,192.11 89.29 22.89 5,691.45 5,751.45 7,843.64 3,611.55 5,956,823.13 491,942.54 8.15 8,634.02 MWD OWSG (5) 11,222.57 92.64 24.70 5,890.93 5,750.93 7,871.50 3,623.84 5,956,850.97 491,954.87 12.50 8,664.47 MWD OWSG (5) v 11,253.68 88.22 26.33 5,890.70 5,750.70 7,899.57 3,637.24 5,956,879.01 491,968.31 15.14 8,695.55 MWD OWSG (5) 11,284.28 88.65 28.10 5,891.54 5,751.54 7,926.77 3,651.23 5,956,906.19 491,982.34 5.95 8,726.09 MWD OWSG (5) 11,314.43 85.94 28.47 5,892.96 5,752.96 7,953.29 3,665.49 5,956,932.68 491,996.65 9.07 8,756.11 MWD OWSG (5) 11,344.46 89.26 29.68 5,894.22 5,754.22 7,979.51 3,680.07 5,956,958.87 492,011.27 11.77 8,785.98 MWD OWSG (5) 11,374.35 93.78 29.44 5,893.42 5,753.42 8,005.49 3,694.81 5,956,984.63 492,026.04 15.14 8,815.70 MWD OWSG (5) 11,405.11 92.27 27.29 5,891.80 5,751.80 8,032.52 3,709.40 5,957,011.83 492,040.67 8.53 8,846.32 MWD OWSG (5) 11,434.56 93.02 26.89 5,890.44 5,750.44 8,058.71 3,722.80 5,957,038.00 492,054.11 2.89 8,875.69 MWD OWSG (5) 11,463.21 89.85 25.75 5,889.72 5,749.72 8,084.38 3.735.50 5,957,063.65 492,066.84 11.76 8,904.29 MWD OWSG (5) 11,494.78 88.62 23.55 5,890.15 5,750.15 8,113.07 3,748.66 5,957,092.31 492,080.05 7.98 8,935.86 MWD OWSG (5) 11,523.52 84.99 23.52 5,891.75 5,751.75 8,139.37 3,760.12 5,957,118.59 492,091.55 12.63 8,964.55 MWD OWSG (5) 11,553.65 86.74 20.71 5,893.92 5,753.92 8,167.21 3,771.43 5,957,146.41 492,102.90 10.97 8,994.58 MWD OWSG (5) 11,592.26 93.07 21.65 5,893.98 5,753.98 8,203.19 3,785.37 5,957,182.37 492,116.90 16.57 9,033.13 MWD OWSG (5) 11,613.38 90.34 21.14 5,893.36 5,753.36 8,222.84 3,793.07 5.957,202.01 492,124.63 13.15 9,054.22 MWD OWSG (5) 11,654 14 85.63 2072 589479 5.754.79 8,260.88 3,807.62 5,957,240.02 492,139.23 11 60 9,094.89 MWD OWSG (5) Annotation 1/3/2020 1: 10: 11 PM Page 4 COMPASS 5000.14 Build 85H ConocoPhillips Baker Hughes> ConocoPhillips Definitive Survey Report Company: ConocoPhillips Alaska Inc Kuparuk Local Co-ordinate Reference: Well 2M-21 Project: Kuparuk River Unit TVD Reference: 2M-21 @ 140.00usft Site: Kuparuk 2M Pad MD Reference: 2M-21 @ 140.00usft Well: 2M-21 North Reference: True Wellbore: 2M-211-1-01 Survey Calculation Method: Minimum Curvature Design: 2M-211-1-01 Database: EDT 14 Alaska Production Survey Annotation 1/3/2020 1:10:11PM Page 5 COMPASS 5000.14 Build 85H Map Map Vertical MD Inc Azi TVD TVDSS +N/ -S +El -W OLS (usft) (°) (°} (usft usft ( ) (usft ) (usft)(ft) Northing Easting (°/100') Section Survey Tool Name (ft) (ft) 11,687.66 87.57 25.31 5,896.78 5,756.78 8,291.67 3,820.70 5,957,270.78 492,152.36 14.84 9,128.34 MWD OWSG (5) 11,714.11 87.29 28.18 5,897.96 5,757.96 8,315.26 3,832.59 5,957,294.36 492,164.29 10.89 9,154.73 MWD OWSG (5) 11,744.35 88.53 32.94 5,899.07 5,759.07 8,341.28 3,847.95 5,957,320.34 492,179.68 16.26 9,184.73 MWD OWSG (5) 11,774.00 90.92 30.73 5,899.21 5,759.21 8,366.46 3,863.59 5,9571345.50 492,195.36 10,98 9,214.08 MWD OWSG (5) 11,805.94 89.91 26.72 5,898.98 5,758.98 8,394.46 3,878.93 5,957,373.48 492,210.75 12.95 9,245.89 MWD OWSG (5) 11,834.15 86.77 22.27 5,899.80 5.759.80 8,420.11 3,890.62 5,957,399.11 492,222.47 19.30 9,274.08 MWD OWSG (5) 11,864.03 88.16 17.56 5,901.12 5,761.12 8,448.17 3,900.78 5,957,427.15 492,232.68 16.42 9,303.85 MWD OWSG (5) 11,893.50 88.16 17.14 5,902.06 5,762.06 8,476.29 3,909.57 5,957,455.24 492,241.51 1.42 9,333.12 MWD OWSG (5) 11,923.92 88.19 11.47 5,903.03 5,763.03 8,505.74 3,917.08 5,957,484.68 492,249.06 18.63 9,363.10 MWD OWSG (5) 11,954.02 90.15 8.37 5,903.47 5,763.47 8,535.38 3,922.26 5,957,514.31 492,254.29 12.18 9,392.31 MWD OWSG (5) 11,984.75 87.45 4.09 5,904.11 5,764.11 8.565.91 3,925.59 5,957,544.83 492,257.67 16.46 9,421.59 MWD OWSG (5) 12,013.91 86.99 1.66 5,905.53 5,765.53 8,595.00 3,927.06 5,957,573.92 492,259.18 8.47 9,448.80 MWD OWSG (5) 12,046.59 88.19 4.14 5,906.90 5,766.90 8,627.60 3,928.71 5.957,606.52 492,260.88 8.42 9,479.30 MWD OWSG (5) 12,075.40 87.94 5.74 5,907.88 5,767.88 8,656.29 3,931.19 5,957,635.19 492,263.40 5.62 9,506.55 MWD OWSG (5) 12,103.82 87.64 6.53 5,908.97 5,768.97 8,684.52 3,934.22 5,957,663.42 492,266.48 2.97 9,533.61 MWD OWSG (5) 12,139.34 88.80 9.55 5,910.08 5,770.08 8,719.67 3,939.19 5,957,698.56 492,271.50 9.10 9,567.78 MWD OWSG (5) 12,168.84 89.97 13.13 5,910.39 5,770.39 8,748.59 3,944.99 5,957,727.47 492,277.35 12.77 9,596.57 MWD OWSG (5) 12,20026 87.91 14.81 5,910.97 5,770.97 8,779.07 3,952.57 5,957,757.93 492,284.97 8.46 9,627.53 MWD OWSG (5) 12,229.69 87.42 18.94 5,912.17 5,772.17 8,807.21 3,961.10 5,957,786.05 492,293.55 14.12 9,656.71 MWD OWSG (5) 12,258.78 84.65 20.42 5,914.18 5,774.18 8,834.53 3,970.87 5,957,813.36 492,303.36 10.79 9,685.65 MWD OWSG (5) 12,288.93 89.63 21.94 5,915.69 5,775.69 8,862.60 3,981.75 5,957,841.40 492,314.28 17.27 9,715.72 MWD OWSG (5) 12,318.86 92.12 21.96 5,915.23 5,775.23 8,890.35 3,992.94 5,957,869.14 492,325.51 8.32 9,745.63 MWD OWSG (5) 12,348.54 91.17 23.60 5,914.38 5,774.38 8,917.70 4,004.42 5,957,896.47 492,337.04 6.38 9,775.29 MWD OWSG (5) 12,379.08 90.95 22.51 5,913.81 5,773.81 8,945.80 4,016.38 5,957,924.54 492,349.04 3.64 9,805.83 MWD OWSG (5) 12,408.76 89.69 21.76 5,913.65 5,773.65 8,973.29 4,027.56 5,957,952.02 492,360.26 4.94 9,835.49 MWD OWSG (5) 12,436.88 92.00 21.22 5,913.23 5,773.23 8,999.45 4,037.86 5,957,978.16 492,370.60 8.44 9,863.59 MWD OWSG (5) 12,464.97 93.63 20.40 5,911.85 5,771.85 9,025.68 4,047.83 5,958,004.36 492,380.61 6.49 9,891.60 MWD OWSG (5) 12,494.06 89.57 16.67 5,911.04 5,771.04 9,053.24 4,057.07 5,958,031.91 492,389.89 18.95 9,920.55 MWD OWSG (5) 12:524.29 90.43 15.49 5,911.04 5,771.04 9,082.28 4,065.44 5.958,060.94 492,398.31 4.83 9,950.50 MWD OWSG (5) 12,554.35 92.46 14.11 5,910.28 5,770.28 9,111.33 4,073.12 5,958,089.97 492,406.03 8.16 9,980.18 MWD OWSG (5) 1258471 95.38 1361 5.908.21 5,768.21 9,14074 4,080.37 5.958.119 36 492,413.33 9.76 10,010 01 MWD OWSG (5) Annotation 1/3/2020 1:10:11PM Page 5 COMPASS 5000.14 Build 85H ConocoPhillips Baker Hughes ConocoPhillips Definitive Survey Report Company: ConocoPhillips Alaska Inc-Kuparuk Local Co-ordinate Reference: Well 2M-21 Project: Kuparuk River Unit TVD Reference: 2M-21 @ 140.00usft Site: Kuparuk 2M Pad MD Reference: 2M-21 @ 140.00usft Well: 2M-21 North Reference: True Wellbore: 2M-211-1-01 Survey Calculation Method: Minimum Curvature Design: 2M-211-1-01 Database: EDT 14 Alaska Production Survey Annotation 1/3/2020 1:10:11 PM Page 6 COMPASS 5000.14 Build 85H Map Map Vertical MD Inc Azi TVD TVDSS +N/ -S +E/ -W Northing Easting DLS Section Survey Tool Name (usft) (°) (°) (usft) (usft) (usft) (usft) (ft) (ft) (°/100') (ft) 12,614.93 97.95 12.52 5.904.70 5,764.70 9.169.97 4,087.16 5,958,148.59 492,420.16 9.23 10,039.50 MWD OWSG (5) 12,644.92 100.40 10.88 5,899.92 5,759.92 9,198.96 4,093.16 5,958,177.56 492,426.21 9.79 10,068.45 MWD OWSG (5) 12,674.55 96.85 13.34 5,895.48 5,755.48 9,227.60 4,099.31 5,958,206.18 492,432.40 14.52 10,097.13 MWD OWSG (5) 12,709.34 93.80 14.48 5,892.25 5,752.25 9,261.22 4,107.64 5,958,239.79 492,440.78 9.35 10,131.25 MWD OWSG (5) 12,739.73 91.97 13.53 5,890.72 5,750.72 9,290.66 4,114.98 5.958,269.22 492,448.17 6.78 10,161.16 MWD OWSG (5) 12,774.48 91.26 15.59 5,889.74 5,749.74 9,324.28 4,123.71 5,958,302.82 492,456.95 6.27 10,195.45 MWD OWSG (5) 12,804.21 91.35 17.81 5,889.06 5,749.06 9,352.75 4,132.25 5,958,331.27 492,465.53 7.47 10,224.94 MWD OWSG (5) 12,839.19 91.05 19.27 5,888.33 5,748.33 9,385.91 4,143.37 5,958,364.41 492,476.70 4.26 10,259.76 MWD OWSG (5) 12,888.57 89.97 23.41 5,887.89 5,747.89 9,431.89 4,161.34 5,958,410.36 492,494.74 8.66 10,309.08 MWD OWSG (5) 12,916.80 89.05 26.06 5,888.13 5,748.13 9,457.52 4,173.15 5,958,435.97 492,506.59 9.94 10,337.31 MWD OWSG (5) 12,944.53 90.06 27.32 5,888.35 5,748.35 9,482.30 4,185.60 5,958,460.73 492,519.08 5.82 10,365.00 MWD OWSG (5) 12,974.75 90.18 28.64 5,888.28 5,748.28 9,508.98 4,199.78 5,958,487.39 492,533.30 4.39 10,395.14 MWD OWSG (5) 13,005.03 90.71 31.28 5,888.05 5,748.05 9,535.21 4,214.90 5,958,513.59 492,548.45 8.89 10,425.24 MWD OWSG (5) 13,035.42 90.68 33.58 5,887.68 5,747.68 9,560.86 4,231.20 5,958,539.21 492,564.79 7.57 10,455.28 MWD OWSG (5) 13,083.49 89.57 36.98 5,887.57 5,747.57 9,600.10 4,258.96 5,958,578.40 492,592.60 7.44 10,502.38 MWD OWSG (5) 13,119.43 89.94 39.84 5,887.73 5,747.73 9,628.26 4,281.28 5,958,606.52 492,614.97 8.02 10,537.15 MWD OWSG (5) 13,149.34 88.37 40.28 5.888.17 5,748.17 9,651.14 4,300.53 5,958,629.38 492,634.25 5.45 10,565.86 MWD OWSG (5) 13,179.87 86.68 39.06 5,889.49 5,749.49 9,674.62 4,320.00 5,958,652.82 492,653.76 6.82 10,595.20 MWD OWSG (5) 13,208.51 8859 38.37 5,890.67 5,750.67 9,696.95 4,337.90 5,958,675.12 492,671.69 7.09 10,622.84 MWD OWSG (5) 13,241.10 88.65 35.92 5,891.45 5,751.45 9,722.92 4,357.57 5,958,701.05 492,691.40 7.52 10,654.54 MWD OWSG (5) 13,272.85 90.62 33.79 5,891.66 5,751.66 9,748.97 4,375.71 5,958,727.07 492,709.58 9.14 10,685.70 MWD OWSG (5) 13,304.01 91.41 31.81 5,891.10 5,751.10 9,77515 4,392.59 5,958,753.23 492,726.49 6.84 10,716.47 MWD OWSG (5) 13,334.42 90.83 30.43 5,890.51 5,750.51 9,801.18 4,408.30 5,958,779.23 492,742.25 4.92 10,746.62 MWD OWSG (5) 13,364.55 91.38 28.00 5,889.93 5,749.93 9,827.47 4,423.00 5,958,805.50 492,756.99 6.27 10,776.61 MWD OWSG (5) 13,394.19 91.56 25.70 5,889.17 5,749.17 9,853.91 4,436.38 5,958,831.91 492,770.41 7.78 10,806.19 MWD OWSG (5) 13,419.28 90.28 23.49 5,888.76 5,748.76 9,876.71 4,446.82 5,958,854.70 492,780.88 10.18 10,831.28 MWD OWSG (5) 13,449.36 90.40 21.76 5,888.59 5,748.59 9,904.48 4,458.40 5,958,882.44 492,792.50 5.77 10,861.35 MWD OWSG (5) 13,479.13 91.14 18.91 5,888.19 5,748.19 9,932.39 4,468.74 5,958,910.33 492,802.88 9.89 10,891.06 MWD OWSG (5) 13,504.31 90.12 16.51 5,887.91 5,747.91 9,956.37 4,476.40 5,958,934.30 492,810.58 10.36 10,916.09 MWD OWSG (5) 13,538.83 90.89 14.23 5,887.60 5,747.60 9,989.65 4,485.55 5,958,967.56 492,819.78 6.97 10,950.24 MWD OWSG (5) 13,570.29 91 38 1258 5.886.98 574698 10.020.25 4,49284 5,958,998.15 492,827 11 547 10,981 17 MWD OWSG (5) Annotation 1/3/2020 1:10:11 PM Page 6 COMPASS 5000.14 Build 85H Con ocoP h i l l i ps Baker Hughes ConoCoPhillips Definitive Survey Report Company: ConocoPhillipsAlaska Inc—Kuparuk Project: Kuparuk River Unit Site: Kuparuk 2M Pad Well: 2M-21 Wellbore: 2M-21 L1-01 Design: 2M-21 L1-01 Survey Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Database: Well 2M-21 2M-21 @ 140.00usft 2M-21 @ 140.00usft True Minimum Curvature EDT 14 Alaska Production Annotation 1/3/2020 1:10:11PM Page 7 COMPASS 5000.14 Build 85H Map Map Vertical MD Inc Azi TVD TVDSS +Nl-S +E/ -W DLS (usft) (°) (°) (usft usft ( ) (usft) (usft) Northing East) (°/100') Section Survey Tool Name (ft) (ft) (ft) 13,603.93 93.28 1201. 5,885.61 5,745.61 10,053.09 4,500.00 5,959,030.97 492,834.32 5.90 11,014.11 MWD OWSG (5) 13,634.96 94.99 9.00 5,883.38 5,743.38 10,083.51 4,505.64 5,959,061.38 492,840.01 11.13 11,044.23 MWD OWSG (5) 13,664.97 95.16 7.57 5,880.72 5,740.72 10,113.09 4,509.95 5,959,090.95 492,644.36 4.78 11,073.03 MWD OWSG (5) 13,694.69 94.40 4.84 5,878.24 5,738.24 10.142.53 4,513.15 5,959,120.39 492,847.61 9.50 11,101.26 MWD OWSG (5) 13,727.26 94.64 2.64 5,875.68 5,735.68 10,174.93 4.515.26 5,959,152.78 492,849.78 6.77 11,131.76 MWD OWSG (5) 13,753.27 95.66 0.50 5,873.34 5,733.34 10,200.82 4,515.97 5,959,178.67 492,850.53 9.08 11,15574 MWD OWSG (5) 13,791.00 95.66 0.50 5,869.62 5,729.62 10,238.37 4,516.30 5,959,216.21 492,850.91 0.00 11,190.23 PROJECTED to TD Annotation 1/3/2020 1:10:11PM Page 7 COMPASS 5000.14 Build 85H r STATE OF ALASKA EHEC 3 0 2019 ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT, A'l 40 1a. Well Status: Oil ❑ . Gas El SPLUG ❑ Other ❑ Abandoned ❑ Suspended❑ 1b. Well Class: 20AAC 25.105 20AAC 25.110 Development [] Exploratory ❑ GINJ ❑ WINJ ❑ WAG[] WDSPL ❑ No. of Completions: Service ❑ Stratigraphic Test ❑ 2. Operator Name: 6. Date Comp., Susp., or 14. Permit to Drill Number / Sundry ConocoPhillips Alaska, Inc. Aband.. 11/29/2019 219-139 ` 3. Address: 7. Date Spudded: 15. API Number: P.O. Box 100360 Anchorage, AK 99510-0360 11/22/2019 50-103-20156-61-00 4a. Location of Well (Governmental Section): 8. Date TD Reached: 16. Well Name and Number Surface. 114' FSL, 479' FWL, Sec 27, T11N, R8E, UM 11/27/2019 KRU 2M -21L1-01 Top of Productive Interval: 9. Ref Elevations: KB: 140 17. Field / Pool(s): _ 1928' FSL, 1768' FEL, Sec 22, T11N, R8E, UM GL. 105.30 • BF Kuparuk River Field/West Sak Oil Pool Total Depth: 10, Plug Back Depth MD/TVD: 18. Property Designation: 209' FNL, 264' FEL, Sec 22, T11N, R8E, UM N/A ADL 25586, ADL 25571 4b. Location of Well (State Base Plane Coordinates, NAD 27): 11 Total Depth MD/TVD 19. DNR Approval Number: Surface. x- 488319 y- 5948985 Zone- 4 •13791' MD/ 5870' TVD' LONS 84-132 TPI: x- 491348 y- 5956075 Zone- 4 12. SSSV Depth MD/TVD: 20. Thickness of Permafrost MD/TVD: Total Depth: x- 492851 y- 5959216Zone- 4 N/A 1529' MD/1492' TVD 5. Directional or Inclination Survey: Yes ❑� (attached) No ❑ 13. Water Depth, if Offshore. 21. Re-drill/Lateral Top Window MD/TVD: Submit electronic and printed information per 20 AAC 25.050 N/A (ft MSL) 10231' MD/ 5892' 22. Logs Obtained: List all logs run and, pursuant to AS 31.05.030 and 20 AAC 25.071, submit all electronic data and printed logs within 90 days of completion, suspension, or abandonment, whichever occurs first. Types of logs to be listed include, but are not limited to: mud log, spontaneous potential, gamma ray, caliper, resistivity, porosity, magnetic resonance, dipmeter, formation tester, temperature, cement evaluation, casing collar locator, jewelry, and perforation record. Acronyms may be used. Attach a separate page if necessary GR/Res 23. CASING, LINER AND CEMENTING RECORD WT. PER GRADE SETTING DEPTH MD SETTING DEPTH TVD AMOUNT CASING FT TOP BOTTOM TOP BOTTOM HOLE SIZE CEMENTING RECORD PULLED 16" 62.58 H-40 39' 123' 39' 123' 24" 220 sx ASII 9-5/8" 543 sx PF E, 660sx Class G, 36 J-55 49' 3926' 49' 2825' 12.25" 110 sx PF C Top Job 7" 26 L-80 44' 1797' 49' 1703' 8.5" 542 sx Class G 7" 26 J-55 1795' 10599' 1701' 6119' 8.5" 280 sx Class G 2-3/8" 4.6 L-80 10004' 13791' 5845' 5870' 3" 24. Open to production or injection? Yes ❑ No ❑ 25 TUBING RECORD If Yes, list each interval open (MD/TVD of Top and Bottom: Perforation SIZE DEPTH SET (MD) PACKER SET (MD/TVD) Size and Number, Date Perfd): 31/2 10030' 9916'/5804' Slotted Liner @ 10004'-13791' MD and 5845'-5870' TVD 10004'/5845' 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. COMPLETION Was hydraulic fracturing used during completion? Yes ❑ No ❑ tRkm Per 20 AAC 25.283 (i)(2) attach electronic and printed information DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED 27 PRODUCTION TEST Date First Production: Method of Operation (Flowing, gas lift, etc.): 12/2/2019 GAS LIFT Date of Test: Hours Tested: Production for Oil -Bbl: Gas -MCF' Water -Bbl Choke Size: Gas -Oil Ratio: 12/3/2019 7 Test Period --- 00� 56 350.25 1457 176 (Bean) 5144 Flow Tubing Casing Press: Calculated Oil -Bbl: Gas -MCF: Water -Bbl: Oil Gravity - API (corr): Press. 255 1304 24 -Hour Rate 166 854 4655 Form 10-407 Revised 5/2017 VEL 31¢1 D CONTINUED ON PAGE 2 �,/ Submit ORIGINI or�f9; ��� BDMS DEC 3 1 2019 3I 28. CORE DATA Conventional Core(s): Yes ❑ No ❑ Sidewall Cores: Yes ❑ No [ If Yes, list formations and intervals cored (MD/TVD, From/To), and summarize lithology and presence of oil, gas or water (submit separate pages with this form, if needed). Submit detailed descriptions, core chips, photographs, and all subsequent laboratory analytical results per 20 AAC 25.071 29. GEOLOGIC MARKERS (List all formations and markers encountered): 30. FORMATION TESTS NAME MD TVD Well tested? Yes ❑ No If yes, list intervals and formations tested, briefly summarizing test results. Permafrost - Top Surface Surface Permafrost - Base 1529 1492 Attach separate pages to this form, if needed, and submit detailed test Top of Productive Interval information, including reports, per 20 AAC 25.071. Formation @ TPI - 10231 5892 ' Kuparuk C Sand TD -Kalubik 13791 5870 Formation at total depth: Kalubik 31. List of Attachments Daily Operations Summary, Definitive Survey, Cement Report, Schematic Information to be attached includes, but is not limited to: summary of daily operations, wellbore schematic, directional or inclination survey, core analysis, paleontological report, production or well test results, per 20 AAC 25.070. 32 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Authorized Name. James Ohlin er Contact Name: Shane Germann Authorized Title: StaffTD Engineer Contact Email: Shane.Germann@conocophillips.com Authorized G Contact Phone: 263-4597 Signature. Date, INSTRUCTIONS General: This form and the required attachments provide a complete and concise record for each well drilled in Alaska. Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed. All laboratory analytical reports regarding samples or tests from a well must be submitted to the AOGCC, no matter when the analyses are conducted. Item 1 a. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Item lb: 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 2M-21 Final CTD Schematic 16" 62# H-40 shoe (d) 123' MD 9-5/8" 36# J-55 shoe @ 3926' MD IKOP @ 10,085' MD C -sand perfs 10,109'-10,124' MD 10,135'-10,150' MD Failed HEW set attempt L1PB1 KOP @ 10,114' MD A -sand perfs 10,170'-10,179' MD 10,195'-10,212' MD 10,232'-10,292' MD I-55 shoe MD 3-1/2" 9.3# L-80 EUE 8rd Tubing to surface 3-1/2" Camco MMG gas lift mandrels @ 3330', 6008', 7863', 9042', 8 9874' MD Baker 3-1/2" PBR 9902' MD (3" ID) Baker FHL Packer @ 9916' MD (4" ID) 3-'/;" X landing nipple at 9938' MD w/ RHC Plug (2.813" min ID) Otis 3-112" PBR 9989' MD (2.97" ID) Otis HVT Packer @ 10,004MD (3.25" ID) 3-'/" Camco D -nipple at 10,020' MD Otis WLEG @ 10,029' MD 2M-21 L7 -01 TD= 13,791' MD TOL= 10,004' MD BOL= 13,791' MD 2-3/8" slotted liner w/ deployment sleeve ------------------------------ --------------------- 2M-2111-11 D= 13,764' MD TOIL= 10,231' MD BOL= 13,764' MD 2M-21L1PB7 2-3/8" slotted liner w/ billet TD= 10,980' MD Unlined Operations Summary (with Timelog Depths) 2M-21 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time Dur (hr) Phase Op Code Activity Code Time P -T -X Operation (ftKB) End Depth (ftKB) 11/7/2019 11/7/2019 4.00 MIRU MOVE MOB P Complete RDMO at 1F 0.0 0.0 00:00 04:00 11/7/2019 11/7/2019 1.00 MIRU MOVE MOB P Peak on location, Load up shop on 0.0 0.0 04:00 05:00 trailer 11/7/2019 11/7/2019 2.50 MIRU MOVE MOB P PJSM w/ Peak and rig crew. Move rig 0.0 0.0 05:00 07:30 off well. Jeep up 11/7/2019 11/7/2019 6.50 MIRU MOVE MOB P Leave 1 F pad enroute to 2M pad 0.0 0.0 07:30 14:00 11/7/2019 11/7/2019 2.00 MIRU MOVE MOB T Arrive at 2M pad. De Jeep modules, 0.0 0.0 14:00 16:00 Start spotting up sub. Discovered damaged king pin on sub. Formulate plan forward 11/7/2019 11/7/2019 2.00 MIRU MOVE MOB P Continue spotting modules on 2M-21 0.0 0.0 16:00 18:00 11/7/2019 11/7/2019 2.00 MIRU MOVE RURD P MIRU. Safe out rig, Connect PUTZ. 0.0 0.0 18:00 20:00 Work Rig up check lists 11/7/2019 11/7/2019 2.50 MIRU WHDBOP NUND P Nipple up stack, Valve crew here to 0.0 0.0 20:00 22:30 service tree. Spot check tree bolts Obtain stack height measurements. Service rig valves, RIG ACCEPT 21:00 11/7/2019 11/8/2019 1.50 MIRU WHDBOP BOPE P PJSM, for BOPE test, Test pressure 0.0 0.0 22:30 00:00 4000 PSI high, 250 PSI Low. Test witness wived by Austin McLeod, AOGCC, All components passed initial inspection 11/8/2019 11/8/2019 4.50 MIRU WHDBOP BOPE P Continue full BOPE test per checklist / 0.0 0.0 00:00 04:30 Procedure. 250 PSI low / 4000PSI high. Test witness waived by Austin Mcleod, AOGCC. No failures. All components passed initial inspection. Drawdown test @ 22 seconds 11/8/2019 11/8/2019 1.25 MIRU WHDBOP CTOP P Rig down test joint, Skid injector to 0.0 0.0 04:30 05:45 floor. Stab injector on well. Break circulation in coil. PT Inner reel iron and stripper 11/8/2019 11/8/2019 1.00 MIRU WHDBOP CTOP P Unstab INJH, walk tiger tank line, fluid 0.0 0.0 05:45 06:45 pack lines, test PDL's and tiger tank liner (good test), 11/8/2019 11/8/2019 0.75 PROD1 WHPST PULD P NS on location, load WFD motors into 0.0 0.0 06:45 07:30 pipeshed. 11/8/2019 11/8/2019 1.50 PROD1 WHPST PULD P PJSM, PD milling assembly BHA #1 0.0 76.9 07:30 09:00 11/8/2019 11/8/2019 1.00 PROD1 WHPST PULD P PJSM, remove bulster from rig, set up 76.9 76.9 09:00 10:00 dike under reel area, continue PD milling assembly. 11/8/2019 11/8/2019 1.90 PROD1 WHPST TRIP P RIH, with BHA#1 w/1.0° ako motor, 76.9 9,930.0 10:00 11:54 2.74" DSM, and 2.73" string reamer, pumping SW "' Note: Initial Pressures 930 psi/1,078 psi/94 11/8/2019 11/8/2019 0.30 PROD1 WHPST DLOG P Log formation (-17.0'), continue 9,930.0 9,956.0 11:54 12:12 flushing well to SW 11/8/2019 11/8/2019 1.30 PROD1 WHPST DISP P RIH. Displace well to Milling Fluid. 9,956.0 10,125.0 12:12 13:30 unable to get full returns pumping 2.6 bpm 0.74 bpm returns with open choke, 11/8/2019 11/8/2019 1.00 PROD1 WHPST DISP P Pump 120k LSRV 50 bbl pill down 10,125.0 10,125.0 13:30 14:30 coil, shut in choke and squeeze away, choke shut WHP=54 psi and slowly climbing WHP=596, open choke 2.6 bpm in and 0.95 bbl returns. Page 1/25 Report Printed: 12/3/2019 Operations Summary (with Timelog Depths) 2M-21 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time Dur (hr) Phase Op Code Activity Code Time P -T -X Operation (ftKB) End Depth (WB) 11/8/2019 11/8/2019 0.40 PROD1 WHPST DISP P Pump second 120k LSRV 50 bbl pill 10,125.0 10,138.0 14:30 14:54 down coil, shut in choke and squeeze away, choke shut WHP=680, open choke pumping 1.89 bpm at 4,229', 0.97 returns. shut down pump 11/8/2019 11/8/2019 0.40 PROD1 WHPST TRIP P RIH and dry tag Wedge @ 10,138'/ 10,138.0 10,138.0 14:54 15:18 2.5 k DHWOB PU Wt 33 k lbs. RIH to mill 11/8/2019 11/8/2019 0.20 PROD1 WHPST WPST P Ct 4,073 psi psi @ 1.9 /0.8 bpm in/out 10,138.0 10,137.5 15:18 15:30 Free spin 745 psi, BHP 3348 psi, targeting 11.8 ppg EMW @ the window. WH 0 psi, IA 1078 psi, OA 92 psi. Start seeing WOB @ 10,137.5' WOB climbed to 0.23 k 11/8/2019 11/8/2019 0.75 PROD1 WHPST WPST P Continue Milling Window Exit off of 10,137.5 10,138.6 15:30 16:15 HEW with NS rep Sag Wagner. 1.89 bpm OFB FS Diff=745, WHP=O, BHP=3,372, IA=1078, OA=93 11/8/2019 11/8/2019 1.85 PROD1 WHPST WPST P Continue Milling Window Exit off of 10.138.6 10,140.9 16:15 18:06 HEW with NS rep Sag Wagner, 1.89 bpm OFB FS Diff=745. WHP=O, B H P=3.372. I A= 599. OA= 93 *' Note: Bleed IA down from 1,078 psi to 599 psi 11/8/2019 11/8/2019 1.30 PROD1 WHPST WPST P 10,140.0. Call BOW, 1.9 BPM @ 10.140.9 10.142.7 18:06 19:24 4184PSI FS, BHP=3331, Continue to time mill for string reamer 11/8/2019 11/8/2019 3.00 PROD1 WHPST WPST P String reamer has exited. Start milling 10,142.7 10,165.0 19:24 22:24 rathole. Low ROP with 2-3K DHWOB. Decide to pull for Bi -Center and 1 ° AKO motor due to low ROP with mill. 11/8/2019 11/8/2019 1.00 PROD1 WHPST WPST P Start reaming passes. As drilled 30L, 10,165.0 10,165.0 22:24 23:24 30R, and low side 11/8/2019 11/8/2019 0.10 PROD1 WHPST WPST P Dry drift widow clean. Tag TD 10,165.0 10,165.0 23:24 23:30 11/8/2019 11/9/2019 0.50 PROD1 WHPST TRIP P Window complete. Trip for 1 ° AKO 10,165.0 7,900.0 23:30 00:00 motor and Bi -Center bit, PUW=31 K 11/9/2019 11/9/2019 1.30 PROD1 WHPST TRIP P Continue out after completing window 7,900.0 70.0 00:00 01:18 11/9/2019 11/9/2019 0.80 PROD1 WHPST PULD P Tag up and space out. PJSM. PUD 70.0 0.0 01:18 02:06 BHA#1. Lay down mills and WFD motor. Mill out @ 2.73 No -Go. Reamer out @ 2.72 Bo -Go 11/9/2019 11/9/2019 1.00 PROD1 DRILL PULD P PD BHA#2 with 1°AK0 motor and 0.0 62.6 02:06 03:06 RR Hughes Bi center. Make up to coil and surface test tool. 11/9/2019 11/9/2019 1.90 PROD1 DRILL TRIP P Trip in well, BHA#2, Bleed down IA 62.6 9,920.0 03:06 05:00 from 927 PSI, All gas got down to 790 after 90 minutes 11/9/2019 11/9/2019 0.10 PROD1 DRILL DLOG P Log K1 tie in for +175, Shut EDC, 9.920.0 9,950.0 05:00 05:06 PUW=30K 11/9/2019 11/9/2019 0.10 PROD1 DRILL TRIP P Continue in well to drill, Clean pass 9,950.0 10,161.0 05:06 05:12 through window 11/9/2019 11/9/2019 0.50 PROD1 DRILL DRLG P Pumps online, 1.9 BPM @ 3725 PSI 10,161.0 10,205.0 05:12 05:42 FS, BHP=3156, Return rate .9 BPM slowly climbing. RIW=14K 11/9/2019 11/9/2019 0.30 PROD1 DRILL WPRT P TD rat hole, wiper up hole, PUW=28K, 10,205.0 9,920.0 05:42 06:00 jog 7 inch x 3 11/9/2019 11/9/2019 0.20 PROD1 DRILL DLOG P Log formation for depth control (+0.5') 9,920.0 9,942.0 06:00 06:12 Page 2/25 Report Printed: 12/3/2019 Operations Summary (with Timelog Depths) 2M-21 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time Dur (hr) Phase Op Code Activity Code Time P -T -X Operation (ftK6) End Depth (ftKB) 11/9/2019 11/9/2019 0.15 PR5D1 DRILL TRIP P RIH to log RA 9,942.0 10,155.0 06:12 06:21 11/9/2019 11/9/2019 0.20 PROD1 DRILL DLOG P Log the RA@ 10,141' 10,155.0 10,169.0 06:21 06:33 "* Note: TOWS 10,134' TOW 10,137' BOW 10,140' RA 10.141' 11/9/2019 11/9/2019 1.40 PROD1 DRILL TRIP P POOH 10,169.0 870.0 06:33 07:57 11/9/2019 11/9/2019 0.20 PROD1 DRILL CTOP T Brown out on rig lost highline power, 870.0 870.0 07:57 08:09 warm up gens, bring power back on, phone CPF 2/Highline to come out and check switch gear trailer. Found E -Stop had been tripped. Bring Highline back on @ 09:38am 11/9/2019 11/9/2019 0.20 PROD1 DRILL TRIP P Continue POOH 870.0 62.6 08:09 08:21 11/9/2019 11/9/2019 0.75 PROD1 DRILL PULD P At surface, PUD build assembly BHA 62.6 0.0 08:21 09:06 #2 11/9/2019 11/9/2019 1.20 PROD1 DRILL PULD P PD, second buid assembly BHA #3 0.0 72.2 09:06 10:18 11/9/2019 11/9/2019 1.90 PROD1 DRILL TRIP P Function open deployment rams, tag 72.2 9,915.0 10:18 12:12 up, reset counters, RIH, seeing collars on trip in hole. stop and close EDC, bring pump online min rate continue IH 11/9/2019 11/9/2019 0.20 PROD1 DRILL DLOG P Log formation for depth control 9,915.0 9,932.0 12:12 12:24 (+17.5') 11/9/2019 11/9/2019 0.20 PROD1 DRILL TRIP P Continue IH 9,932.0 10,205.0 12:24 12:36 11/9/2019 11/9/2019 1.15 PROD1 DRILL DRLG P OBD. 1.89 bpm at 4,233 psi. OB 10,205.0 10,305.0 12:36 13:45 Diff=546 psi, WHP=576, BHP=3,492. IA=782. OA=95, on closed choke. 11/9/2019 11/9/2019 0.20 PROD1 DRILL WPRT P Wiper up hole to 10,205'. PUW 29 k 10,305.0 10,205.0 13:45 13:57 11/9/2019 11/9/2019 0.20 PROD1 DRILL WPRT P Wiper back in hole, RIW 9.2 k 10,205.0 10,305.0 13:57 14:09 11/9/2019 11/9/2019 2.10 PROD1 DRILL DRLG P BOBD, 1.87 bpm at 4,996 psi, FS 10,305.0 10,362.0 14:09 16:15 Diff=584 psi, WHP=300, BHP=3,603, IA=776, OA=96, (66% losses) 11/9/2019 11/9/2019 0.20 PROD1 DRILL WPRT P BHA Wiper up hole, PUW 33 k 10,362.0 10,362.0 16:15 16:27 11/9/2019 11/9/2019 0.70 PROD1 DRILL DRLG P BOBD. 1.87 bpm at 4,678 psi. FS 10,362.0 10,391.0 16:27 17:09 Diff=545 psi, WHP=271, BHP=3,563, IA=785, OA=96 11/9/2019 11/9/2019 0.30 PROD1 DRILL TRIP P Getting excesive DLS with 2.5" AKO 10,391.0 10,098.0 17:09 17:27 motor. Trip out to dial down motor 11/9/2019 11/9/2019 2.80 PROD1 DRILL CIRC P Pump 100 BBI high vis pill 130K 10.098.0 10,098.0 17:27 20:15 LSRV. Squeeze away. Got to 12.6 EMW at window 11/9/2019 11/9/2019 1.80 PROD1 DRILL TRIP P 10098, Trip out choke closed, maitain 10,098.0 96.0 20:15 22:03 BHP 11/9/2019 11/9/2019 0.95 PROD1 DRILL PULD P At surface, Tag up and space out. 96.0 0.0 22:03 23:00 PJSM PUD BHA#3 11/9/2019 11/9/2019 0.80 PROD1 DRILL PULD P Swap motors 2.5° to 2.3° AKO. PD 0.0 72.1 23:00 23:48 BHA#4, Make up to coil and surface test. 11/9/2019 11/10/2019 0.20 PROD1 DRILL TRIP P Trip in well BHA #4 72.1 450.0 23:48 00:00 I Page 3/25 Report Printed: 12/3/2019 Operations Summary (with Timelog Depths) 2M-21 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time our (hr) Phase Op Code Activity Code Time P -T -X Operation (ftKB) End Depth (ftKB) 11/10/2019 11/10/2019 1.10 FROM DRILL TRIP P Continue in well, Slow tripping speed 450.0 6,500.0 00:00 01:06 to 80 FPM. High bend motor finding joints 11/10/2019 11/10/2019 1.40 PROD1 DRILL TRIP P Bypass MM to clear. Full of window 6,500.0 9,915.0 01:06 02:30 debrie. Had to knock off. and clear 11/10/2019 11/10/2019 0.10 PROD1 DRILL DLOG P Log K1 for +16'correction, PUW=32 9,915.0 9,930.0 02:30 02:36 11/10/2019 11/10/2019 0.80 PROD1 DRILL TRIP P Continue in hole, Clean pass through 9,930.0 10,390.0 02:36 03:24 window. Set down @ 10,330. P/U with negative WOB, PUW=41 K. Pull up to 10250. RBIH and work pipe dowm. Setdown @ 10,335, 10,340. 10.345' then goto bottom at 10,390 11/10/2019 11/10/2019 0.20 FROM DRILL WPRT P At TD. Wiper trip to 10,300, 10,390.0 10,391.0 03:24 03:36 PUW=31 K. Clean to back bottom 11/10/2019 11/10/2019 2.90 PROM DRILL DRLG P 10,391', Drill, 1.9 BPM @ 4700 PSI 10,391.0 10,487.0 03:36 06:30 FS, BHP=3425. 1.6 BPM returns, RIW=12.06K, Diff=522 PSI 11/10/2019 11/10/2019 0.10 PROM DRILL WPRT T Highline power failure, while on 10,487.0 10,487.0 06:30 06:36 bottom, bring gen's on line, switch to gen power 11/10/2019 11/10/2019 0.10 PROD1 DRILL DRLG P PUH 80', PUW 38 k, RBIH, OBD 1.9 10,487.0 10.509.0 06:36 06:42 bpm at 4,737 psi, FS Diff=506, WHP=219, BHP=3,555 11/10/2019 11/10/2019 0.30 PROD1 DRILL WPRT P Wiper up hole to 10,205', PUW 38 k 10,509.0 10,205.0 06:42 07:00 11/10/2019 11/10/2019 0.30 PROM DRILL WPRT P Wiper back in hole, RIW 7 k 10,205.0 10,509.0 07:00 07:18 11/10/2019 11/10/2019 4.40 PROM DRILL DRLG P BOBD, 1.9 bpm at 5,017 psi, FS 10,509.0 10,577.0 07:18 11:42 Diff=517 psi, WHP=145, BHP=3,641, IA=797, OA=97, "' Note: 76% returns. 1.9 bpm in/1.44 bpm out 11/10/2019 11/10/2019 0.70 PROM DRILL WPRT P Pull to the window, PUW 38 k, jog the 10,577.0 10,100.0 11:42 12:24 7 inch 11/10/2019 11/10/2019 1.60 PROD1 DRILL TRIP P POOH 10,100.0 72.2 12:24 14:00 11/10/2019 11/10/2019 1.75 FROM DRILL PULD T PUD, build assembly, unstabbed 72.2 72.2 14:00 15:45 INJH, tools became stuck in tree, attempt to free up BHA, line up and pump, function closed swab valve, function closed annular. function closed deployment rams, MU test cable to tools oreient TF 90° with no success 11/10/2019 11/10/2019 0.75 PROD1 DRILL TRIP T PD, build assembly, RIH 100', pull 72.2 172.0 15:45 16:30 back out of hole, space out 11/10/2019 11/10/2019 1.50 PROM DRILL PULD P PUD, build assembly. No further 172.0 0.0 16:30 18:00 issues with PUD 11/10/2019 11/10/2019 1.20 PROD1 DRILL PULD P BJSM, PD BHA#5 with .5° AKO motor 0.0 78.2 18:00 19:12 and HYC B8 bi center. M/U to coil and surface test - Good. Strip on injector. Tag up 11/10/2019 11/10/2019 1.80 PROM DRILL TRIP P Trip in well. Shallow test agitator @ 78.2 9,925.0 19:12 21:00 500'. Continue in 11/10/2019 11/10/2019 0.10 PROD1 DRILL DLOG P 9925' Tie into K1 for+24.5'. Inspect 9,925.0 9,959.0 21:00 21:06 counter on injector. Looks good, PUW=32K 11/10/2019 11/10/2019 0.30 PROD1 DRILL TRIP P Continue in well. Clean pass through 9,959.0 10,575.0 21:06 21:24 window and down to build TD @ 10,575' Page 4/25 Report Printed: 12/3/2019 Operations Summary (with Timelog Depths) 2M-21 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time Dur (hr) Phase Op Code Activity Code Time P -T -X Operation (ftKB) End Depth (ftKB) 11/10/2019 11/10/2019 1.60 PROD1 DRILL DRLG P 10575', Drill, 1.77 BPM @ 5264 PSI 10,575.0 10,680.0 21:24 23:00 FS, BHP=3550, RIW=9.7K 11/10/2019 11/10/2019 0.50 PROM DRILL WPRT P 10680. Pull wiper trip 10175' 10,680.0 10,679.0 23:00 23:30 PUW=36K. Clean trip up and down 11/10/2019 11/11/2019 0.50 PROM DRILL DRLG P 10679', Drill, 1.79 BPM @ 5353 PSI 10,679.0 10,702.0 23:30 00:00 FS, BHP=3541, RIW-2.1K, Return Rate 1.43 BPM 11/11/2019 11/11/2019 1.30 PROM DRILL DRLG P 10702', Drill, 1.78 BPM @ 5353PSI 10,702.0 10,780.0 00:00 01:18 FS, Returns @ 1.42 BPM 11/11/2019 11/11/2019 0.80 PROM DRILL WPRT P 10,780'. Wiper to window with 5 X 5 10.780.0 10,162.0 01:18 02:06 sweeps, PUW=39K, Jet 7" casing up to 10160'. 11/11/2019 11/11/2019 0.10 PROM DRILL DLOG P Log RA marker for=4' correction 10,162.0 10,180.0 02:06 02:12 11/11/2019 11/11/2019 0.20 PROM DRILL WPRT P Continue wiper back to bottom to drill 10,180.0 10,783.0 02:12 02:24 11/11/2019 11/11/2019 0.70 PROD1 DRILL DRLG P 10,783', Drill, 1.81 BPM @ 5312 PSI 10,783.0 10,880.0 02:24 03:06 FS, BHP=3442. Returns 1.4 BPM ROP has increased. 115 to 160 11/11/2019 11/11/2019 0.60 PROD1 DRILL WPRT P 10880'wiperto 10180'. PUW=35K 10,880.0 10,879.0 03:06 03:42 11/11/2019 11/11/2019 0.90 PROM DRILL DRLG P 10879', Drill. 1.82 BPM @5366 PSI 10,879.0 11.000.0 03:42 04:36 FS, BHP=5366, Returns @ 1.35 - 11.1 PPG EMW 11/11/2019 11/11/2019 1.00 PROD1 DRILL WPRT P 11,000', Wiper to window with sweeps 11,000.0 10,162.0 04:36 05:36 Tie in, PUW=38K 11/11/2019 11/11/2019 0.20 PROM DLOG P Log RA marker (+3.0') 10,162.0 10,176.0 05:36 05:48 11/11/2019 11/11/2019 0.30 PROM WPRT P Wiper back in hole, RIW 7 k 10,176.0 10,338.0 05:48 06:06 11/11/2019 11/11/2019 0.20 PROM DRILL WPRT T Set down @ 10,338', attempt to pass 10,338.0 10,033.0 06:06 06:18 x 6 with no success, PUH into casing 11/11/2019 11/11/2019 2.00 PROM DRILL WPRT T Jog to clean 7inch with mulitple 10,033.0 10,115.0 06:18 08:18 sweeps. 11/11/2019 11/11/2019 0.75 PROM DRILL WPRT T Close choke, RIH, intiial set down 10.115.0 10.338.0 08:18 09:03 10,155', work to pass area, continue IH with muliple set downs, 10,163', 10,176', 10,212'. 10,224', 10,274', and 10,338', unable to pass through tight area, confer with town team. 11/11/2019 11/11/2019 2.00 PROM DRILL TRIP T POOH for cleanout run on closed 10,338.0 72.2 09:03 11:03 choke maintaining MP schedule. 11/11/2019 11/11/2019 1.00 PROM DRILL PULD T PUD, lateral drilling BHA #5, 72.2 0.0 11:03 12:03 *" Note. Bit Grade 1-5 11/11/2019 11/11/2019 1.40 PROM DRILL PULD T PD, cleanout assembly BHA #6 0.0 62.4 12:03 13:27 11/11/2019 11/11/2019 2.00 PROM DRILL TRIP T RIH, cleanout assembly BHA#6 62.4 9,915.0 13:27 15:271w/D331 w/o Res - 11/11/2019 11/11/2019 0.30 PROM DRILL DLOG T Log the K1 (+47.5' BHI) (nabors 9,915.0 9,957.6 15:27 15:45 counter +3.5') 11/11/2019 11/11/2019 0.65 PROM DRILL CTOP T Repair or swap out INJH counter 9,957.6 9,957.6 15:45 16:24 11/11/2019 11/11/2019 0.20 PROD1 DRILL TRIP T Continue IH through window (clean) 9,957.6 10,333.0 16:24 16:36 11/11/2019 11/11/2019 0.20 PROM DRILL TRIP T Set down @ 10,333', PUH, obtain 10,333.0 10,333.0 16:36 16:48 pump parameters, 11/11/2019 11/11/2019 1.00 PROM DRILL WASH T Work through tight spot, 1.83 bpm at 10,333.0 10,366.0 16:48 17:48 4,969 psi, FS Diff=480, WHP=1056, BHP=3,693, IA=781, OA=97 Page 5125 Report Printed: 12/3/2019 Operations Summary (with Timelog Depths) 2M-21 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time Dur (hr) Phase Op Code Activity Code Time P -T -X Operation (ftKB) End Depth (ftKB) 11/11/2019 11/11/2019 0.10 PROD1 DRILL BKRM T Back ream up hole. Get overpull @ 10,366.0 10,319.0 17.48 17:54 10341' with -3K DHWOB 11/11/2019 11/11/2019 0.20 PROD1 DRILL WASH T Wash back down hole. Stack out @ 10,319.0 10,242.0 17:54 18:06 10334. Work down to 10336'. 1 of three gens goes down due to overheat. PUH slowly getting another gen online 11/11/2019 11/11/2019 0.80 PROD1 DRILL WASH T Wash down, Stack out @ 10314. Work 10,242.0 10,040.0 18:06 18:54 at different speeds and TF's. No luck PUH through window to see if we might be dragging something. Pass through clean. 11/11/2019 11/11/2019 0.30 PROD1 DRILL TRIP T RBIH. Clean pass through window. 10,040.0 10,317.0 18:54 19:12 Stack out @ 10317 11/11/2019 11/11/2019 2.40 PROD1 DRILL MILL T Try multiple speeds / TF's no good 10,317.0 10,320.0 19:12 21:36 Bring on pumps 1.88 BPM @ 5169 PSI FS, BHP=3611, Choke still closed. 3K DHWOB with 400 PSI motor work. Consult with town 11/11/2019 11/11/2019 1.20 PROD1 DRILL TRIP T Trip out to set whipstock in back up 10,320.0 10,069.0 21:36 22:48 window location. PUH slowly waiting on Hi vis pill to slow fluid losses 11/11/2019 11/12/2019 1.20 PROD1 DRILL CIRC T Squeeve Hi Vis 146K LSRV into well. 10,069.0 10,069.0 22:48 00:00 see 12.6 Pushing pill. Reduce rate to not exceed 12.6 11/12/2019 11/12/2019 0.30 PROD1 DRILL CIRC T Continue squeezing 148K LSRV into 10,069.0 10.069.0 00:00 00:18 wellbore 11/12/2019 11/12/2019 1.80 PROD1 DRILL TRIP T Pill in place, POOH for NS HEW 10,069.0 57.0 00:18 02:06 1whipstock 11/12/2019 11/12/2019 1.30 PROD1 DRILL PULD T At surface, PJSM, PUD BHA # 6 FCO 57.0 0.0 02:06 03:24 11/12/2019 11/12/2019 1.00 PROD1 DRILL WPST T PJSM, M/U NS HEW whipstock. Make 0.0 73.5 03:24 04:24 up to coil track and PD. Skid injector. M/U to coil and surface test 11/12/2019 11/12/2019 1.85 PROD1 DRILL WPST T RIH with BHA#7 73.5 9,940.0 04:24 06:15 11/12/2019 11/12/2019 0.20 PROD1 DRILL WPST T Log formation (+5.0') , RIH to setting 9,940.0 10,105.0 06:15 06:27 depth 11/12/2019 11/12/2019 0.50 PROD1 DRILL WPST T Bring mud pump up to shear 3,663 10,105.0 10,130.0 06:27 06:57 psi/1,985 psi Dlff, no DHWOB noted, continue IH pushing Wedge to 10,130' 11/12/2019 11/12/2019 1.90 PROD1 DRILL WPST T POOH. clean to surface, pumping min 10,130.0 75.0 06:57 08:51 rate with open EDC 11/12/2019 11/12/2019 1.00 PROD1 DRILL WPST T At surface, PUD setting tools 75.0 0.0 08:51 09:51 11/12/2019 11/12/2019 1.25 PROD1 DRILL CTOP T LD and service CoilTrak tools, change 0.0 0.0 09:51 11:06 planitary oil, inspect reel and INJH, change pac-offs, continue to standby for orders 11/12/2019 11/12/2019 1.00 PROD1 DRILL PULD T Change of plans, PJSM, swap out 0.0 0.0 11:06 12:06 Tools in PDL, with no DGS or HOT, Phone out BOT w/under-reamer and straight mud motor. 11/12/2019 11/12/2019 2.50 PROD1 DRILL CTOP T Continue Rig Maintance, Bulster 0.0 0.0 12:06 14:36 arrived on location. PJSM, loc-out equipment and attempt to install repaired bulster, with no success. 11/12/2019 11/12/2019 1.00 PROD1 DRILL UREM T PU/PD, under -reamer assembly 0.0 65.7 14:36 15:36 11/12/2019 11/12/2019 1.50 PROD1 DRILL UREM T RIH, w/DB under -reamer max 65.7 9,925.0 15:36 17:06 expansion 6.12" on a BOT straight motor. Page 6/25 Report Printed: 12/3/2019 4 Operations Summary (with Timelog Depths) 2M-21 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time Dur (hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth (ftKB) 11/12/2019 11/12/2019 0.20 PROD1 DRILL UREM T Log formation for depth control (+5.0'), 9,925.0 9,956.0 17:06 17:18 PUW 30 k 11/12/2019 11/12/2019 0.40 PROD1 DRILL UREM T Continue IH 9,956.0 10,096.0 17:18 17:42 11/12/2019 11/12/2019 0.40 PROD1 DRILL UREM T Bring pump online 1.8 bppm at 5,141 10,096.0 10,113.0 17:42 18:06 psi, FS Dlff=934, WHP=1,138, BHP=3,735. IA=760, OA=91, work down hole @ 1 fpm 11/12/2019 11/12/2019 0.30 PROD1 DRILL UREM T Under-ream up hole @ 1 fpm 10,113.0 10,103.0 18:06 18:24 11/12/2019 11/12/2019 0.30 PROD1 DRILL UREM T Park @ 10,099', circulate 60 bbl down 10,103.0 10,103.0 18:24 18:42 the bake side 1.4 bpm at 1.246 psi, 11/12/2019 11/12/2019 0.30 PROD1 DRILL UREM T Under-ream down at 1 fpm to 10,113' 10,103.0 10,113.0 18:42 19:00 11/12/2019 11/12/2019 0.50 PROD1 DRILL UREM T Under-ream up at 1 fpm 10,113.0 10,103.0 19:00 19:30 11/12/2019 11/12/2019 0.70 PROD1 DRILL UREM T Park @ 10,099', circulate 60 bbl down 10,103.0 10,100.0 19:30 20:12 the bake side 1.4 bpm at 1,246 psi. 11/12/2019 11/12/2019 1.80 PROD1 DRILL UREM T Line up down the back side, POOH 10,100.0 65.7 20:12 22:00 pumping 0.7 bpm 11/12/2019 11/12/2019 1.30 PROD1 DRILL PULD T At surface, spaceout, PUD Under- 65.7 0.0 22:00 23:18 reamer/cleanout assembly, Lay down under reamer and straight BOT motor 11/12/2019 11/13/2019 0.70 PROD1 DRILL WPST T M/U NS HEW whipstock. PD BHA#9 0.0 0.0 23:18 00:00 Whipstock 11/13/2019 11/13/2019 0.50 PROD1 DRILL WPST T Continue PD BHA#9. NS HEW whip 73.5 73.5 00:00 00:30 stock. M/U to CT and surface test. 11/13/2019 11/13/2019 2.00 PROD1 DRILL WPST T RIH BHA #9 Whipstock, EDC Open 73.5 9,933.0 00:30 02:30 11/13/2019 11/13/2019 0.10 PROD1 DRILL WPST T Log K1 for +4.5 9,933.0 9,960.0 02:30 02:36 11/13/2019 11/13/2019 0.20 PROD1 DRILL WPST T RIH to set depth 10111.78, TOWS 9,960.0 10.111.8 02:36 02:48 10103' Oriented to HS. Close EDC. Pressure up setting tool. See tool shift @ 3800 PSI with 3.8K DHWOB. Set down to 5.8K. 11/13/2019 11/13/2019 1.80 PROD1 DRILL WPST T Open EDC, POOH BHA#9 setting 10,111.8 76.0 02:48 04:36 tools 11/13/2019 11/13/2019 0.90 PROD1 DRILL WPST T At surface, Tag up and space out. 76.0 0.0 04:36 05:30 PJSM PUD BHA#9 whip stock setting tools 11/13/2019 11/13/2019 0.90 PROD1 DRILL WPST T M/U & PDBHA#10. Window milling 0.0 76.0 05:30 06:24 BHA with 2.74" Window mill and 2.73" string reamer. make up to coil and surface test. Tag up and set counters 11/13/2019 11/13/2019 1.70 PROD1 DRILL WPST T Trip in hole, EDC open 76.0 9,930.0 06:24 08:06 11/13/2019 11/13/2019 0.20 PROD1 DRILL WPST T Log K1 for+4', PUW=31 K, Close EDC 9,930.0 9,967.0 08:06 08:18 11/13/2019 11/13/2019 0.10 PROD1 DRILL WPST T Continue in well, Dry tag whip stock 9,967.0 10,107.6 08:18 08:24 pinch point @ 10.107.6 11/13/2019 11/13/2019 4.60 PROD1 DRILL WPST T PUH, Bring pumps online. 1.85 BPM 10.107.6 10,110.6 08:24 13:00 @ 4451 PSI FS, BHP=3084, Returns 1.65 BPM. Tag pinch point @ 10107.2- Mill window per procedure / NS window rep. 11/13/2019 11/13/2019 0.50 PROD1 DRILL WPST T Call BOW. Time mill for string reamer 10,110.6 10,111.6 13:00 13:30 1to exit 11/13/2019 11/13/2019 1.00 PROD1 DRILL WPST T Milling rathole, Speed up 10.111.6 10,126.0 13:30 14:30 1 Page 7125 Report Printed: 12/3/2019 Operations Summary (with Timelog Depths) 2M-21 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Time End Time Dur (hr) Phase Op Code Activity Code Time P-T-X Operation Start Depth (WB) End Depth (M[3) 11/13/2019 11/13/2019 1.60 PROM DRILL WPST T TD rathole, Start reaming passes HS, 10,126.0 10,126.0 14:30 16:06 30R, 30L, 180°, Dry drift. Pump 5 X 5 sweeps 11/13/2019 11/13/2019 2.00 PROM DRILL WPST T Looks good, POOH, PUW30K 10,126.0 78.0 16:06 18:06 11/13/2019 11/13/2019 0.70 PROD1 DRILL WPST T Crew change, PJSM, PUD BHA#10, 78.0 0.0 18:06 18:48 mill & string reamer came out 2.73" no -go 11/13/2019 11/13/2019 0.70 PROM DRILL PULD T PD BHA#11 Build Assembly (2.5° 0.0 72.0 18:48 19:30 AKO motor, RB Dynamus bit) BHA became lammed in stack attempting to space-out (tagged po- go), pump across the top, work slick- line, no good, open Romeo 1, pump, work slick-line, no good, open Romeo 3, pump, continue to work slick-line, snap slick-line (never pulling past design limits) 11/13/2019 11/13/2019 0.70 PROD1 DRILL DLOG T Decision made to kill well, obtain 72.0 72.0 19:30 20:12 SBHP, begin arranging pits Hydrostatic = 2553 psi, WHIP = 215 psi (stabalized), TVD window = 5742', EMW = 9.27 ppg 11/13/2019 11/13/2019 1.30 PROM DRILL PULD T Complete fluid transfer in pits, water 72.0 72.0 20:12 21:30 back KWF to 9.5 ppg (140 bbl total) 11/13/2019 11/13/2019 1.30 PROM DRILL DISP T Bullhead 9.6 ppg KWF to window, 72.0 72.0 21:30 22:48 WHP = 1500 psi @ 1.3 bpm 11/13/2019 11/13/2019 0.70 PROM DRILL DISP T Flow check, well charged up, bleed off 72.0 72.0 22:48 23:30 multiple times, well is dead, PJSM 11/13/2019 11/14/2019 0.50 PROM DRILL PULD T Blow down PDL, pop off, MU tugger 72.0 72.0 23:30 00:00 line to BHA, work BHA up, open DBV's, continue PU tools over dead well, slide in cart 11/14/2019 11/14/2019 0.40 PROD1 DRILL PULD T Slide in cart, check pack-offs, MU to 72.0 72.0 00:00 00:24 coil, tag-up, set counters 11/14/2019 11/14/2019 2.00 PROD1 DRILL TRIP T RIH w/ BHA #11 72.0 9,920.0 00:24 02:24 11/14/2019 11/14/2019 0.10 PROM DRILL DLOG T Log K1 for+5' correction 9,920.0 9.953.0 02:24 02:30 11/14/2019 11/14/2019 0.30 PROM DRILL DISP T Complete RIH, drilling ahead while 9,953.0 10,126.0 02:30 02:48 swapping to drilling fluid, PUW = 32K. close EDC 11/14/2019 11/14/2019 2.20 PROM DRILL DRLG T Drilling,FS = 519 psi @ 1.9 bpm, CWT 10.126.0 10,221.0 02:48 05:00 = 9AK @ 0.7K WOB, annular = 3226 psi, choke fully open, pump = 4375 psi, 10.45 ppg ECD at bit Binding up @ 10,133% stacking WOB w/ no motor-work, PUW = 34K, work through, again bind up at 10,141', continue drilling (BHA continues to bind-up across window occasionaly) Increase LSRV of DuoVis system to -50K, begin breaking down DS PDL 11/14/2019 11/14/2019 0.20 PROD1 DRILL WPRT T BHA wiper at 100' drilled. PUW = 35K, 10,221.0 10,221.0 05:00 05:12 pull -8K WOB. 11/14/2019 11/14/2019 4.90 PROM DRILL DRLG T Drilling, 1.88 BPM @ 4441 PSI FS. 10,221.0 10,325.0 05:12 10:06 BHP=3263, AVG DLS=50.1 ° Page 8/25 Report Printed: 12/3/2019 Operations Summary (with Timelog Depths) 2M-21 oil Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time Dur (hr) Phase Op Code Activity Code Time P -T -X Operation (WB) End Depth (ftKB) 11/14/2019 11/14/2019 0.40 PROD1 DRILL WPRT T Wiper trip to window with tie in, 10,325.0 9,920.0 10:06 10:30 PUW=35K. Observed dragging on DHWOB sensor near window 11/14/2019 11/14/2019 0.20 PROM DRILL DLOG T Log K1 for+1.5'. RIH to 10125'. Log 9,920.0 10,144.0 10:30 10:42 RA in @ 101115. TOWS=10104, BOW=10111 11/14/2019 11/14/2019 0.10 PROD1 DRILL WPRT T RBIH to drill 10,144.0 10,321.0 10:42 10:48 11/14/2019 11/14/2019 0.30 PROD1 DRILL DRLG T 10321', Drill. 1.9 BPM @ 5200 PSI 10,321.0 10,329.0 10:48 11:06 FS, BHP=3571 11/14/2019 11/14/2019 3.40 PROD1 DRILL TRIP T DLS trending higher. Trip to dial down 10,329.0 73.0 11:06 14:30 motorAKO. PUW=35K 11/14/2019 11/14/2019 1.00 PROD1 DRILL PULD T Tag up and space out, PJSM PUD 73.0 0.0 14:30 15:30 BHA# 11, bit came out a 1-2 11/14/2019 11/14/2019 0.50 PROD1 DRILL BOPE P Perform Bi Weekly BOPE function test 0.0 0.0 15:30 16:00 -All components passed initial inspection 11/14/2019 11/14/2019 1.10 PROM DRILL PULD T PJSM, PD BHA#12 with 2.3° AKO 0.0 72.0 16:00 17:06 motor and HCC Bi center, change out pack -offs 11/14/2019 11/14/2019 1.70 PROD1 DRILL TRIP T RIH w/ BHA #12 72.0 9,925.0 17'06 18:48 11/14/2019 11/14/2019 0.30 PROM DRILL DLOG T Log K1 for+5' connection 9,925.0 10,329.0 18:48 19:06 11/14/2019 11/14/2019 2.00 PROD1 DRILL DRLG T Drilling, FS = 583 psi @ 1.9 bpm. 10,329.0 10.430.0 19:06 21:06 CWT = 4.51< @ 1.7K WOB, annular = 3639 psi, WHP = 122 psi. 11.8 ppg @ window, pump = 5578 psi 11/14/2019 11/14/2019 0.30 PROD1 DRILL WPRT T Pull 240' wiper, PUW = 37K 10,430.0 10.430.0 21:06 21:24 11/14/2019 11/14/2019 2.00 PROD1 DRILL DRLG T Drilling, FS = 550 psi @ 1.9 bpm, 10,430.0 10,512.0 21:24 23:24 CWT = 7.21< @ 0.5K WOB, annular = 3645 psi, WHP = 162 psi, pump = 5344 psi, reduce WOB in attempt to lower DLS. drill to called EOB at 10,512', pump sweeps 11/14/2019 11/15/2019 0.60 PROM DRILL TRIP T Begin POOH. PUW = 35K 10,512.0 9,400.0 23:24 00:00 11/15/2019 11/15/2019 1.90 PROM DRILL TRIP T Complete POOH, negative DWOB 9.400.0 72.0 00:00 01:54 tugs from 10,500 to 10,163', tag up. open EDC. PJSM 11/15/2019 11/15/2019 0.80 PROD1 DRILL PULD T PUD BHA #12, bit came out a 1-2 72.0 0.0 01:54 02:42 11/15/2019 11/15/2019 1.30 PROD1 DRILL DRLG T PD BHA#13 L1 Drilling Assembly 0.0 78.0 02:42 04:00 (NOV agitator, 0.5` AKO motor, & RB Dynamus bit), slide in cart, check pack -offs, change out checks in UQC. MU to coil, tag up, set counters 11/15/2019 11/15/2019 1.80 PROD1 DRILL TRIP T RIH w/ BHA#13, close EDC 78.0 9,930.0 04:00 05:48 Shallow test agitator: 1.8 bpm, FS = 1016, pump = 5873 psi 11/15/2019 11/15/2019 0.10 PROM DRILL DLOG T Log K1 for+19.5'. Inspect /clean 9,930.0 9,986.0 05:48 05:54 counter, PUW=32K 11/15/2019 11/15/2019 0.40 PROD1 DRILL TRIP T Continue in well, Clean pass through 9,986.0 10,514.0 05:54 06:18 window and down to TD @ 10514 11/15/2019 11/15/2019 1.10 PROD1 DRILL DRLG T 10,514', Drill, 1.75 BPM @ 5597 PSI 10,514.0 10,610.0 06:18 07:24 FS, BHP=3618, returns 1.6 BPM 11/15/2019 11/15/2019 0.50 PROD1 DRILL WPRT T 10.610', Wiper trip to below window. 10,610.0 10,610.0 07:24 07:54 PUW=33K 11/15/2019 11/15/2019 1.50 PROM DRILL DRLG T 10610, Drill, 1.78 BPM @ 5776 PSI 10,610.0 10,710.0 07:54 09:24 FS, BHP=3663. Returns @ 1.6 BPM Page 9/25 Report Printed: 12/3/2019 Operations Summary (with Timelog Depths) 2M-21 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time Dur (hr) Phase Op Code Activity Code Time P -T -X Operation (ftKB) End Depth (ftKB) 11/15/2019 11/15/2019 0.50 PROD1 DRILL WPRT T 10710', Wiper to TT with tie into RA 10,710.0 10,125.0 09:24 09:54 marker with sweeps. PUW=33K 11/15/2019 11/15/2019 0.10 PROM DRILL DLOG T Log RA marker for +2' correction 10,125.0 10,149.0 09:54 10:00 11/15/2019 11/15/2019 0.30 PROD1 DRILL WPRT T Continue wiper trip back to bottom 10.149.0 10.711.0 10:00 10:18 11/15/2019 11/15/2019 1.50 PROD1 DRILL DRLG T 10,711', Drill, 1.71 BPM @ 5431 PSI 10,711.0 10,810.0 10:18 11:48 FS, BHP=3661, Returns 1.5 BPM 11/15/2019 11/15/2019 0.50 PROD1 DRILL WPRT T 10,810. 1000' wiper. with sweeps. 10,810.0 10,810.0 11:48 12:18 PUW=32K 11/15/2019 11/15/2019 1.70 PROM DRILL DRLG T 10,810', Drill, 1.73 BPM @ 5587 PSI 10,810.0 10,910.0 12:18 14:00 FS, BHP=3677, Returns @ 1.61 BPM 11/15/2019 11/15/2019 0.60 PROD1 DRILL WPRT T 10,910 Wiper to 7" with sweeps. 10,910.0 10,125.0 14:00 14:36 PUW=35K 11/15/2019 11/15/2019 0.10 PROD1 DRILL DLOG T Gamma tie in for+1.5' correction 10,125.0 10,150.0 14:36 14:42 11/15/2019 11/15/2019 0.30 PROD1 DRILL WPRT T Run back in hole to drill 10,150.0 10,908.0 14:42 15:00 11/15/2019 11/15/2019 1.10 PROD1 DRILL DRLG T 10908', Drill, 1.79 BPM @ 5628 PSI 10.908.0 11,010.0 15:00 16:06 FS, BHP=3482, Returns 1.7 BPM 11/15/2019 11/15/2019 0.60 PROM DRILL WPRT P 11010' Wiper trip to window, PUW 38K 11,010.0 11,010.0 16:06 16:42 11/15/2019 11/15/2019 1.20 PROD1 DRILL DRLG P Drilling, CWT = 2.5K @ 11K WOB, 11,010.0 11,110.0 16:42 17:54 annular = 3484 psi, open choke, pump = 6017 psi, 1.8 bpm in, 1.67 bpm out 11/15/2019 11/15/2019 0.70 PROM DRILL WPRT P Wiper to tubing tail, PUW = 38K, jog 11,110.0 10,115.0 17:54 18:36 7". stack at 10,104', PU, clean through window 11/15/2019 11/15/2019 0.20 PROM DRILL DLOG P Log RA tag for+7' correction 10,115.0 10,140.0 18:36 18:48 11/15/2019 11/15/2019 0.40 PROD1 DRILL WPRT P Continue RIH, RIW = 10.9K 10,140.0 11,110.0 18:48 19:12 11/15/2019 11/15/2019 1.40 PROD1 DRILL DRLG P Drilling. FS = 1065 psi @ 1.8 bpm, 11.110.0 11,210.0 19:12 20:36 CWT = 7.8K @ 2K WOB, annular = 3471 psi, pump = 5894 psi, 1.6 bpm out 11/15/2019 11/15/2019 0.60 PROM DRILL WPRT P Wiper to EOB, PUW = 38K, RIW = 11,210.0 11,210.0 20:36 21:12 13.4K 11/15/2019 11/15/2019 1.60 PROM DRILL DRLG P Drilling, FS = 1140 psi @ 1.8 bpm, 11,210.0 11,310.0 21:12 22:48 CWT = 10.61K @ 0.81K WOB. annular = 3514 psi, pump = 5832 psi, 1.63 bpm out, pump sweeps 11/15/2019 11/15/2019 1.00 PROM DRILL WPRT P Wiper to tubing tail. PUW = 34K, jog 11,310.0 10.125.0 22:48 23:48 7", stack weight at 10,111' (3X), attempt at 15 fpm & 10L, get right through, pump 5x5 sweeps 11/15/2019 11/15/2019 0.10 PROD1 DRILL DLOG P Log RA tag for+3' correction 10,125.0 10,146.0 23:48 23:54 11/15/2019 11/16/2019 0.10 PROM DRILL WPRT P Continue RIH 1,046.0 10,335.0 23:54 00:00 11/16/2019 11/16/2019 1.20 PROD1 DRILL WPRT P Cointinue RIH to EOB, sweeps exit bit, 10,335.0 11,310.0 00:00 01:12 jog back to BOW, RBIH to drill 11/16/2019 11/16/2019 1.20 PROM DRILL DRLG P Drilling, FS = 1084 psi @ 1.8 bpm, 11,310.0 11,410.0 01:12 02:24 CWT = 8.9K @ 1 K WOB, annular = 3507 psi, pump = 5925 psi, 1.57 bpm returns, pump sweeps as required 11/16/2019 11/16/2019 0.70 PROM DRILL WPRT P Wiper 10,560', PUW = 38K, RIW = 11,410.0 11,410.0 02:24 03:06 1 I Page 10/25 Report Printed: 12/3/2019 Operations Summary (with Timelog Depths) 2M-21 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time Dur (hr) Phase Op Code Activity Code Time P -T -X Operation (ftKB) End Depth (ftKB) 11/16/2019 11/16/2019 1.40 PROD1 DRILL DRLG P Drilling, FS = 1085 psi @ 1.8 bpm, 11,410.0 11,510.0 03:06 04:30 CWT = 8K @ 1.9K WOB, annular = 3510 psi (11.1 ppg at window), pump = 6039 psi Returns drop to 1 bpm at 11,435', PU, returns quickly healed to 1.6 bpm drilling ahead, pump 5x5 sweeps 11/16/2019 11/16/2019 1.70 PROD1 DRILL WPRT P Wiper, PUW = 33K, jog 7", wipe up to 11,510.0 9,930.0 04:30 06:12 7000' 11/16/2019 11/16/2019 0.10 PROM DRILL DLOG P Log K1 for+ 5' correction 9,930.0 9,958.0 06:12 06:18 11/16/2019 11/16/2019 0.60 PROM DRILL WPRT P 9958'. Continue wiper trip back to 9.958.0 11,511.0 06:18 06:54 bottom 11/16/2019 11/16/2019 1.10 PROM DRILL DRLG P 11511', Drill, 1.8 BPM @ 5711 PSI FS. 11,511.0 11,622.0 06:54 08:00 BHP=3495, Diff=204 11/16/2019 11/16/2019 0.60 PROM DRILL WPRT P 11622'. 1000' wiper, PUW=34K. 11,622.0 11,621.0 08:00 08:36 RIW=11.8 11/16/2019 11/16/2019 1.60 PROM DRILL DRLG P 11621', Drill, 1.79 BPM @ 5758 PSI 11,621.0 11,710.0 08:36 10:12 FS, BHP=3514, Diff=325 11/16/2019 11/16/2019 1.00 PROD1 DRILL WPRT P 11710'. Long wiper to TT with tie in. 11,710.0 10,125.0 10:12 11:12 Pump 5 X 5 sweeps, PUW=36K 11/16/2019 11/16/2019 0.10 PROM DRILL DLOG P 10125', Tie into RA marker for+3 10,125.0 10,147.0 11:12 11:18 11/16/2019 11/16/2019 0.50 PROD1 DRILL WPRT P 10147', Continue in hole, RIW=12.1K 10,147.0 11,710.0 11:18 11:48 11/16/2019 11/16/2019 1.50 PROM DRILL DRLG P 11710', Drill, 1.79 BPM @ 5763 PSI 11.710.0 11,808.0 11:48 13:18 FS, BHP=3494. New PwrPro system at bit 11,780' 11/16/2019 11/16/2019 0.80 PROD1 DRILL WPRT P 11808'. 1000' wiper. PUW=50K 11,808.0 11,808.0 13:18 14:06 11/16/2019 11/16/2019 1.90 PROD1 DRILL DRLG P 11808', drill. 1.78 BPM @ 5336 PSI 11,808.0 11,910.0 14:06 16:00 FS, BHP=3561, Diff=177 PSI 11/16/2019 11/16/2019 1.00 PROM DRILL WPRT P 11910'. Wiper to TT with tie in. 11,910.0 10,128.0 16:00 17:00 PUW=36K 11/16/2019 11/16/2019 0.10 PROM DRILL DLOG P Log RA for+3' 10,128.0 10,140.0 17:00 17:06 11/16/2019 11/16/2019 0.60 PROM DRILL WPRT P Continue RIH 10,140.0 11,910.0 17:06 17:42 11/16/2019 11/16/2019 4.20 PROM DRILL DRLG P Drilling, FS = 960 psi @ 1.8 bpm, 11,910.0 12,110.0 17:42 21:54 CWT = 1.3K @ 1 K WOB, annular = 3571 psi, pump = 5640 psi, 1.6 bpm returns, pump sweeps as required Increase to 200' drill intervals 11/16/2019 11/16/2019 0.80 PROM DRILL WPRT P Wiper (850'), PUW = 35K 12,110.0 12,110.0 21:54 22:42 11/16/2019 11/17/2019 1.30 PROM DRILL DRLG P Drilling, FS = 976 psi @ 1.8 bpm, 12,110.0 12,167.0 22:42 00:00 CWT = 4.3K, @ 1.6K WOB, annular = 3573 psi, pump = 5698 psi, 1.62 bpm out, returns reduce to 1.5 bpm at 12.107 & 12,157'& ROP drops to -25 fph 11/17/2019 11/17/2019 2.00 PROM DRILL DRLG P Drilling, CWT = -2.8K @ 2K WOB, 12,167.0 12,221.0 00:00 02:00 annular = 3552 psi, pump = 5706 psi. 1.5 bpm returns, continued low ROP 11/17/2019 11/17/2019 2.00 PROM DRILL DRLG P Drilling, continued low ROP, 15-20 fph, 12,221.0 12,310.0 02:00 04:00 CWT = 7K @ 2.7K WOB, annular = 3595 psi, pump = 5947 psi, 1.5 bpm out, pump sweeps as required Page 11/25 Report Printed: 12/3/2019 Operations Summary (with Timelog Depths) 2M-21 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time Dur (hr) Phase Op Code Activity Code Time P -T -X Operation (ftKB) End Depth (ftKB) 11/17/2019 11/17/2019 1.00 PROM DRILL WPRT P Wiper to tubing tail, PUW = 36K, pump 12,310.0 10,125.0 04:00 05:00 additional 5x5 sweeps, log 7", clean through window up/down 11/17/2019 11/17/2019 0.10 PROD1 DRILL DLOG P Log RA tag for +2.5' correction 10,125.0 10,147.0 05:00 05:06 11/17/2019 11/17/2019 1.10 PROD1 DRILL WPRT P Continue RIH 10,147.0 12,311.0 05:06 06:12 11/17/2019 11/17/2019 2.60 PROM DRILL DRLG P 12311', Drill, 1.75 BPM @ 5452 PSI 12,311.0 12,422.0 06:12 08:48 FS, BHP=3621 11/17/2019 11/17/2019 0.70 PROM DRILL WPRT P 12422. BHA wiper. 400', PUW=38K 12,422.0 12.420.0 08:48 09:30 11/17/2019 11/17/2019 1.70 PROM DRILL DRLG P 12420', Drill. 1.79 BPM @ 5648 PSI 12,420.0 12,510.0 09:30 11:12 FS, BHP=3566, 12490' started loosing returns .9 BPM. 11/17/2019 11/17/2019 1.00 PROM DRILL WPRT P 12510', 1000'wipertrip, PUW=41K. 12,510.0 12,508.0 11:12 12:12 Returns @1 BPM 11/17/2019 11/17/2019 3.30 PROM DRILL DRLG P 12508', Drill, 1.75 BPM @ 5648 PSI 12,508.0 12,710.0 12:12 15:30 FS, BHP=5648, Returns @ 1.2 BPM 11/17/2019 11/17/2019 1.00 PROM DRILL WPRT P 12710% Wiper to window with tie in, 12,710.0 10,125.0 15:30 16:30 PUW=39K, jog 7", stack on window multiple times, get through at 15 fpm, oriented 10 LOHS 11/17/2019 11/17/2019 0.10 PROM DRILL DLOG P Log RA tag for +4.5' correction 10,125.0 10,140.0 16:30 16:36 11/17/2019 11/17/2019 1.70 PROM DRILL WPRT P Cotinue RIH 10,140.0 12.710.0 16:36 18:18 11/17/2019 11/17/2019 1.60 PROM DRILL DRLG P Drilling, FS = 955 psi @ 1.8 bpm, 12,710.0 12,800.0 18:18 19:54 CWT = 5K @ 0,2K WOB, annular = 3550 psi, pump = 5531 psi, 0.8 bpm returns (47%), drill ahead in attempt to heal losses, returns to 1.16 bpm @ 12,769' 11/17/2019 11/17/2019 2.80 PROM DRILL DRLG P Drilling, 1.1 bpm out. CWT = 0.9K @ 12,800.0 12,874.0 19:54 22:42 1.8K WOB, annular = 3615 psi, pump = 5817 psi PUW = 39K from 12,819' 11/17/2019 11/18/2019 1.30 PROD1 DRILL DRLG P Drilling, 1 bpm out, CWT = -6.8K @ 12,874.0 12,910.0 22:42 00:00 2.2K WOB, annular = 3581 psi, pump = 5253 psi, pump sweeps 11/18/2019 11/18/2019 1.40 PROM DRILL WPRT P Wiper (850'), PUW = 41 K, RM 12,910.0 12,910.0 00:00 01:24 variable (+2K to -2K), difficulty working to bottom, work at reduced speed 11/18/2019 11/18/2019 2.10 PROM DRILL DRLG P Drilling, FS = 1000 psi @ 1.7 bpm. 12,910.0 12,960.0 01:24 03:30 annular = 3597 psi, pump = 5365 psi. 1.1 bpm out, cuttings ratio = 1.0 Variable ROP, 10 fph - 90 fph 11/18/2019 11/18/2019 1.20 PROD1 DRILL DRLG P Drilling, 1 bpm returns. CWT = -61K @ 12,960.0 12,977.0 03:30 04:42 2.51K WOB, annular = 3555 psi, pump = 5195, avg ROP = 14 fph Low ROP, decision made to pull to check bit, pump sweeps 11/18/2019 11/18/2019 3.80 PROM DRILL TRIP P Trip for bit, PUW = 38K 12,977.0 78.0 04:42 08:30 11/18/2019 11/18/2019 1.00 PROD1 DRILL PULD P Tag up, PJSM. PUD BHA#13, Bit out 78.0 0.0 08:30 09:30 2-4 11/18/2019 11/18/2019 0.50 PROM DRILL BHAH P Swap bit & Agitator 0.0 0.0 09:30 10:00 Page 12/25 Report Printed: 12/3/2019 Operations Summary (with Timelog Depths) 2M-21 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time our (hr) Phase Op Code Activity Code Time P -T -X Operation (ftKB) End Depth (ftKB) 11/18/2019 11/18/2019 1.00 PROD1 DRILL PULD P PJSM, PD BHA #14..5° AKO motor, 0.0 78.2 10:00 11:00 agitator, and RB HCC Dynapilot bit. M/U to coil and surface test. Strip on. Change out pack offs. Tag up and set counters 11/18/2019 11/18/2019 1.80 PROM DRILL TRIP P Trip in well, BHA#14, Surface test 78.2 9.925.0 11:00 12:48 agitator @ 450 feet, Continue in well 11/18/2019 11/18/2019 0.10 PROD1 DRILL DLOG P Log K1 for+5' correction, PUW=31K 9,925.0 9,958.0 12:48 12:54 11/18/2019 11/18/2019 1.30 PROD1 DRILL TRIP P Continue in well Set down in window 9,958.0 12,977.0 12:54 14:12 PUH orient to 10°LOHS. Go through window clean. Clean trip to bottom @ 50 - 30 FPM RIW=6.4K 11/18/2019 11/18/2019 4.10 PROM DRILL DRLG P 12977', Drill, 1.78 BPM @ 5306 PSI 12,977.0 13,087.0 14:12 18:18 FS, BHP=3555. Returns @ 1.1 BPM 11/18/2019 11/18/2019 2.20 PROM DRILL DRLG P Drilling, FS = 894 psi @ -3.3K, @ 0.7K 13,087.0 13,154.0 18:18 20:30 WOB, annular = 3548 psi, pump = 5370 psi. 1.0 bpm returns, low ROP (down to 9 fph), PUW = 39K from 13,154' 11/18/2019 11/18/2019 0.80 PROD1 DRILL DRLG P Drilling, CWT = -6.5K @ 0.8K WOB, 13,154.0 13,170.0 20:30 21:18 annular = 3598 psi, pump = 5500 psi, 1.12 bpm returns, pump 5x5 sweeps 11/18/2019 11/18/2019 1.50 PROD1 DRILL WPRT P Wiper (850'), PUW = 40K, slow RBIH 13,170.0 13,170.0 21:18 22:48 to bottom, snubbing @ reduced rate 11/18/2019 11/19/2019 1.20 PROD1 DRILL DRLG P Drilling, FS = 879 psi @ 1.8 bpm, 13,170.0 13,219.0 22:48 00:00 CWT = -4.3K @ 1 K WOB. annular = 3587 psi, pump = 5505 psi, 1.0 bpm returns Struggling with weight transfer, pump 10x10 beaded pill, drill to midnight depth of 13219 11/19/2019 11/19/2019 2.00 PROM DRILL DRLG P Drilling, CWT = -2.2K @ 0.4K WOB, 13,219.0 13,241.0 00:00 02:00 annular = 3638 psi, pump = 5625 psi. 1.0 bpm returns, beads exit bit to limited effect, pump additional 20 bbl beaded pill 11/19/2019 11/19/2019 0.70 PROM DRILL WPRT P BHA wiper, PUW = 41 K, slow working 13,241.0 13,241.0 02:00 02:42 back to bottom, snubbing 11/19/2019 11/19/2019 1.60 PROM DRILL DRLG P Drilling, FS = 936 psi @ 1.8 bpm, 13,241.0 13.280.0 02:42 04:18 CWT = -1 K @ 0.2K WOB, continue stuggling w/ weight transfer & low ROP, rate out drops to 0.9 bpm. builds back to 1 bpm quickly Drilling break at 13,251', pump sweeps, returns to 1.2 bpm 11/19/2019 11/19/2019 2.50 PROM DRILL WPRT P Pull wiper to tubing tail, PUW = 42K, 13,280.0 9,925.0 04:18 06:48 jog 7", wiper up to 7000' 11/19/2019 11/19/2019 0.10 PROM DRILL DLOG P Log K1 for +65 correction 9,925.0 9,955.0 06:48 06:54 11/19/2019 11/19/2019 2.00 PROM DRILL WPRT P 9955, Continue wiper trip in hole to 9,955.0 13,281.0 06:54 08:54 drill. Pass window @ 10° LOHS 11/19/2019 11/19/2019 1.70 PROD1 DRILL DRLG P 13281', Drill, 1.8 BPM @ 5637 PSI 13,281.0 13,340.0 08:54 10:36 FS, BHP=3673. Closed choke 11/19/2019 11/19/2019 5.30 PROD1 DRILL DRLG P 13340'. Drilling break, ROP from 19 13340.0 13.480.0 10:36 15:54 FPH to 36 FPH, RIW-6K, DHWOB=1.1 K, Pumping sweeps 11/19/2019 11/19/2019 1.00 PROD1 DRILL WPRT P 13480', 1000' wiper, PUW=43K. Clean 13,480.0 13,480.0 15:54 16:54 up. Stacking slow going 300 feet from bottom Page 13125 Report Printed: 12/3/2019 Operations Summary (with Timelog Depths) 2M-21 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time Dur (hr) Phase Op Code Activity Code Time P -T -X Operation (ftKB) End Depth (ftKB) 11/19/2019 11/19/2019 3.50 PROD1 DRILL DRLG P 13480', Drill. 1.79 BPM @5548 PSI 13,480.0 13,623.0 16:54 20:24 FS, BHP=3709 Choke closed 11/19/2019 11/19/2019 0.10 PROM DRILL WPRT P BHA wiper, PUW=46K 13,623.0 13,623.0 20:24 20:30 11/19/2019 11/19/2019 2.00 PROM DRILL DRLG P 13623', Drill, 1.78 BPM @ 5750 PSI 13,623.0 13,680.0 20:30 22:30 FS, BHP=3725 PSI. Choke closed 11/19/2019 11/20/2019 1.50 PROM DRILL WPRT P Wiper to window. PUW = 48K 13,680.0 10,422.0 22:30 00:00 Observe motor -work at various dpethPUH, begin observing sustained motor -work beginning at EOB & up 11/20/2019 11/20/2019 0.20 PROM DRILL WPRT P Continue wiper up -hole, observe 10.422.0 10,100.0 00:00 00:12 significant motor -work PUH through build (up to 1500 psi), no indication on WOB or CWT, reduce speed to 25 fpm, motor -work falls off at 10.184', pull through window clean 11/20/2019 11/20/2019 0.20 PROD1 DRILL WPRT P Jog 7" casing, RBIH to log RA, stack 10,100.0 10,125.0 00:12 00:24 at window (HS), orient 10°L @ 15 fpm, through clean 11/20/2019 11/20/2019 0.10 PROM DRILL DLOG P Log RA for +65 correction 10,125.0 10,148.0 00:24 00:30 11/20/2019 11/20/2019 1.80 PROM DRILL WPRT P Continue wiper in-hole, reduce speed 10,148.0 13,680.0 00:30 02:18 beginning at 13.252' 11/20/2019 11/20/2019 2.70 PROM DRILL DRLG P Drilling, FS = 807 psi @ 1.8 bpm. 13,680.0 13,722.0 02:18 05:00 CWT = -7K @ 1.1 WOB. annular 3699 psi (12.0 ppg ECD), pump = 5422 psi, pump sweeps as required Low ROP (5-20 fph), drilling "break" at 13,694', up to 65 fph Avg ROP over interval = 15.5 fph, PUW = 47K 11/20/2019 11/20/2019 2.30 PROM DRILL DRLG P Drilling, CWT = -7K @ 0.9K WOB, 13,722.0 13.733.0 05:00 07:18 annular= 3731 psi, WHP = 733 psi, pump = 5881 psi, avg ROP = —5 fph 11/20/2019 11/20/2019 2.00 PROM DRILL DRLG P Drilling, CWT = -3K @ 0.51K WOB, 13.733.0 13.750.0 07:18 09:18 annular = 3737 psi, pump 5x10 beaded pill, continued low ROP (5-10 fph) Decsion made to call TD, pump 5x5 sweeps, decsion changed to point straight down. 11/20/2019 11/20/2019 4.00 PROM DRILL DRLG P Drlling, pointed straight down cross 13,750.0 13,787.0 09:18 13:18 cutting C4 -Sands, difficulty dropping past 88` inclination 11/20/2019 11/20/2019 1.90 PROM DRILL WPRT P TD called at 13,787, PUW = 48K, 13,787.0 9.925.0 13:18 15:12 pump 5x5 sweeps, await sweeps to bit. wiper to window, clean through window 11/20/2019 11/20/2019 0.10 PROM DRILL DLOG P Log K1 for+5.5' correction 9,925.0 9,947.0 15:12 15:18 11/20/2019 11/20/2019 0.20 PROD1 DRILL WPRT P RIH to window. clean up & jog 7" 9,947.0 10,100.0 15:18 15:30 11/20/2019 11/20/2019 0.50 PROD1 DRILL DLOG P Obtain SBHP: MD = 10,100', 10,100.0 10,100.0 15:30 16:00 TVD—sensor = 5866.4, allow annular to drop to 2881 psi (still dropping, though slowly). EMW = 9.44 ppg, confer with town, decsion made to build KWF to 9.7 ppg 11/20/2019 11/20/2019 1.60 PROD1 DRILL WPRT P RI to confirm TD, begin building LRP 10,100.0 13,784.0 16:00 17:36 1 1 I I & diluting KWF Page 14/25 Report Printed: 12/3/2019 Operations Summary (with Timelog Depths) 2M-21 Oil. Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time Dur (hr) Phase Op Code Activity Code Time P -T -X Operation (ftK8) End Depth (ftKB) 11/20/2019 11/20/2019 1.80 PROD1 DRILL DISP P POOH pumping LRP, 15 bbls total, top 13,784.0 9,925.0 17:36 19:24 left at 12550' Park@12308.21' paint Yellow TD flag 11/20/2019 11/20/2019 0.10 PROD1 DRILL DLOG P Tie int tohe K1 for a + 10' correction 9,925.0 9,954.3 19:24 19:30 11/20/2019 11/20/2019 1.50 PROM DRILL DISP P Open EDC. Line up down the back 9,954.3 9,937.0 19:30 21:00 side, Bullhead 33 bbls LRP, Initial stabilized WH 1447 psi @ 1.4 bpm. Chase LRP with 75 bbls KWF 11/20/2019 11/20/2019 0.50 PROD1 DRILL OWFF P Park and flow check, Bled down 9,937.0 9,937.0 21:00 21:30 charged pressure in steps, S/I pressure dropped steadily, 7.6 bbls total bled, Flow check at the stack good. 11/20/2019 11/20/2019 1.80 PROD1 DRILL TRIP P POOH over pumping pipe 9,937.0 103.0 21:30 23:18 displacement with KW - 0.76 bpm in. CT 1010 psi, WH 0, IA 773 psi, OA 95 psi out Park at 8578 and paint a white window flag Continue out of hole - lost 10 bbls on the trip 11/20/2019 11/20/2019 0.10 PROM DRILL OWFF P Park shallow, check for flow, well on a 103.0 103.0 23:18 23:24 vac. PJSM Loss rate 1 bbl in 10 minutes 11/20/2019 11/21/2019 0.60 PROD1 DRILL PULD P Inspect pipe, found flat spot -12' back 103.0 0.0 23:24 00:00 wall thickness 0.126' lay down BHA #14, L1 latteral drilling BHA over a dead well. 11/21/2019 11/21/2019 0.30 PROM DRILL PULD P Continue to LD BHA#14 over a dead 0.0 0.0 00:00 00:18 well. Fill hole - 1 bbl / 2 total since flow check. 11/21/2019 11/21/2019 0.50 COMPZ1 CASING PUTB P Prep rig floor for running liner 0.0 0.0 00:18 00:48 11/21/2019 11/21/2019 2.00 COMPZ1 CASING PUTB P Pick up lower L1 completion, 38 joints 0.0 1,505.5 00:48 02:48 R3 2-3/8" slotted liner over a non - ported bull nose under a shorty deployment sleeve. 1504.27' liner , 1505.52' LOA. 11/21/2019 11/21/2019 0.20 COMPZ1 CASING PUTB P Clear floor post liner run, 1,505.5 1,505.5 02:48 03:00 11/21/2019 11/21/2019 0.70 COMPZ1 CASING PULD P Pickup BHA#15, lower L1 completion 1,505.5 1,549.7 03:00 03:42 running assembly, inspect pack ffs - good. 11/21/2019 11/21/2019 6.20 COMPZ1 CASING RUNL P Bump up, set depth, RIH with lower L1 1,549.7 13,784.0 03:42 09:54 completion, begin stacking weight at 10,972', work pipe, pump down coil & back -side to aid in working liner down, begin making good progress from -11,815', difficulty working past 13,532'& 13,554' Arrive on bottom, bring up pumps, release off liner (PUW = 36K), TOL - 12,278.5' 11/21/2019 11/21/2019 3.40 COMPZ1 CASING TRIP P POOH, pumping 50 bbl LRP, flow- 13,784.0 44.0 09:54 13:18 check, PJSM 11/21/2019 11/21/2019 0.30 COMPZ1 CASING PULD P LD BHA#15 44.0 0.0 13:18 13:36 Page 15125 Report Printed: 12/3/2019 Operations Summary (with Timelog Depths) 2M-21 . ,,.• Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time Dur (hr) Phase Op Code Activity Code Time P -T -X Operation (ftKB) End Depth (ftKB) 11/21/2019 11/21/2019 2.40 COMPZ1 CASING PUTB P Clear & prep floor, PU Upper 0.0 2,040.0 13:36 16:00 Completion (non -ported bullnose, 51 jnts slotted liner, & liner -top billet) Static losses at 6 bph 11/21/2019 11/21/2019 0.30 COMPZ1 CASING PULD P PU BHA#16 Running Tools, slide in 2,040.0 2,084.0 16:00 16:18 cart, MU to coil, tag up, set counters 11/21/2019 11/21/2019 5.70 COMPZ1 CASING RUNL P RIH w/ upper completion, tie into 2,084.0 12,180.0 16:18 22:00 window flag for -1' correction. PU Wt 34 k lbs. Continue in hole First set down, 10,757' - PU Wt 38 k lbs. Start working liner @ 11,298' PU Wts to 50 k lbs 11,450' PU Wt 54 k lbs WOB -18.3 k lbs 11,662' PU Wt 56 k lbs WOB -18.3 k lbs 11,850' PU Wt 58 k lbs WOB -20.8 k lbs 12,180' PU Wt 63 k lbs WOB -20.8 k lbs 11/21/2019 11/21/2019 1.50 COMPZ1 CASING RUNL P Decision made to POOH, break liner 12,180.0 12,272.0 22:00 23:30 and re -attempt. POOH with upper completion. CT PUH wt54k At 10,929, CT wt dropped from 33.4 k to 26.9 k lbs, WOB at -6.7 k spiked to - 11 k then fell to -1.5 k lbs. RBIH and tag slight WOB bobble@ 11,328. PU wt 29k lbs, no liner, continue in hole, WOB slowly building to 4.7 k. Sharp increase in WOB to 7.5 k, CT wt to -5k, bit depth 12,272' PU Wt 29 k, RBIH, stack out 2 more times. Pump off liner, going thrugh the motions, PU Wt 30 k lbs, WOB -0.39 k 11/21/2019 11/21/2019 0.20 COMPZ1 CASING TRIP P PUH, set depth, PUH 12,272.0 9,899.0 23:30 23:42 11/21/2019 11/21/2019 0.20 COMPZ1 CASING TRIP P Log K1 for +9.5' correction. 9,899.0 9,922.0 23:42 23:54 11/21/2019 11/22/2019 0.10 COMPZ1 CASING TRIP P POOH circulating KW down the coil 9,922.0 8,819.0 23:54 00:00 11/22/2019 11/22/2019 1.50 COMPZ1 CASING TRIP P Continue to POOH, losses @ - 0.2 8,819.0 68.0 00:00 01:30 bpm 11/22/2019 11/22/2019 0.50 COMPZ1 CASING PULD P Bump up, flow check good, LD BHA 68.0 0.0 01:30 02:00 #16 over a dead well. GS clean, no billet top retrieved. 11/22/2019 11/22/2019 1.00 PROD2 STK CIRC P Pull checks, Install nozzle, stab 0.0 0.0 02:00 03:00 injector, jet stack while turning reel over to water, un stab 11/22/2019 11/22/2019 0.70 PROD2 STK BOPE P Install large port down jet nozzle, stab 0.0 0.0 03:00 03:42 injector, reverse circulate, test inner reel valve and stripper to 250/4000 psi -Test #13. 11/22/2019 11/22/2019 1.00 PROD2 STK CTOP P Un Stab, install night cap, Valve crew 0.0 0.0 03:42 04:42 service tree, grease valves in preparation for BOP test 11/22/2019 11/22/2019 0.80 PROD2 WHDBOP PRTS P Flood up and shell test. 0.0 0.0 04:42 05:30 Page 16/25 Report Printed: 12/3/2019 Operations Summary (with Timelog Depths) 2M-21 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time Dur (hr) Phase Op Code Activity Code Time P -T -X Operation (ftKB) End Depth (ftKB) 11/22/2019 11/22/2019 0.30 PROD2 WHDBOP BOPE T Witness waived by Matt Herrera of the 0.0 0.0 05:30 05:48 AOGCC Test pressure 250/4000 psi low/high. Test 1.1-eaking past Swab 2, call out valve crew to grease, carry on with test 11/22/2019 11/22/2019 0.50 PROD2 WHDBOP BOPE P Test 2. Blind/Shear, BOP TV2, Charlie 0.0 0.0 05:48 06:18 4, 5, 8, &12 11/22/2019 11/22/2019 0.60 PROD2 WHDBOP BOPE T Test 3. BOP TV 1, Charlie 3, 7, & 11, 0.0 0.0 06:18 06:54 not holding pressure, trouble -shoot, bleeding pressure past swab 1, test against master valve, good test 11/22/2019 11/22/2019 0.40 PROD2 WHDBOP BOPE P Test 4. Manual choke D & Super 0.0 0.0 06:54 07:18 1choke C 11/22/2019 11/22/2019 3.00 PROD2 WHDBOP BOPE T Test 5. Romeo 3, Bleeder 3, Tango 2, 0.0 0.0 07:18 10:18 Charlie 2, & 10, unable to get good high test, trouble -shoot, chart not rotating, grab new test chart, valve crew arrives, re -grease swabs & tangos, re -grease Charlie 2, 7, & 10, hammer up flow block to swab 1 Re -test #1 post greasing, good, then re -test #5, difficulty on low, come up to high, holding, re -test low, good, high, good test 11/22/2019 11/22/2019 0.50 PROD2 WHDBOP BOPE T Test 6. Charlie 1, 9, Bravo 5, and 0.0 0.0 10:18 10:48 Tango 1 — install TIW test joint, unable to hold pressure on low, shut in TP2. rock solid, losing pressure at test pump, carry on isolating at test pump, good low, good high 11/22/2019 11/22/2019 2.20 PROD2 WHDBOP BOPE P Test 7. Lower 2" pipe slip rams, TIW 0.0 0.0 10:48 13:00 #1, Romeo 1, Bleeder 1 Test 8. Annular BOP Test 9. Upper 2" pipe slip rams, Bravo 6,&8 Test 10. Bravo 7 — swap out 2" test joint for 2-3/8" Test 11. 2-3/8" pipe slip rams. TIW#2 — check N2 levels, swap to 2" test joint Test 12. Draw down accumulator. stabilized starting pressure 2350 psi, time to 200 psi increase 24 sec, full recovery time until pumps shut down 53 sec, N2 bottles — average of 4, 1950 psi. Tested all gas detectors, pits, cellar, rig floor all functioned properly, Verified flow alarms - PVT 11/22/2019 11/22/2019 1.70 PROD2 STK CTOP P Clear floor, blow -down, cut CTC off, 0.0 0.0 13:00 14:42 protect e -line end, pump back slack (2 bpm, twice, hear wire move), roll coil to KWF 11/22/2019 11/22/2019 1.80 PROD2 STK CTOP P Pop-off, cut 70' feet of coil to find wire 0.0 0.0 14:42 16:30 (new coil length = 17,936'), bevel & ream pipe, install CTC 11/22/2019 11/22/2019 1.20 PROD2 STK CTOP P Pull test CTC to 35K, re -head a -line. 0.0 0.0 16:30 17:42 pressure test, crew change. PJSM 11/22/2019 11/22/2019 1.00 PROD2 STK CIRC P Stab on, pump slac forward. 0.0 0.0 1742 18:42 11/22/2019 11/22/2019 1.00 PROD2 STK PULD P PU BHA# 17. Fresh 0.5° AKO motor 0.0 78.2 18:42 19:42 and agitator over a Hcy B9 bit Page 17/25 Report Printed: 12/3/2019 Operations Summary (with Timelog Depths) 2M-21 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time Dur (hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth (ftK6) 11/22/2019 11/22/2019 1.90 PROD2 STK TRIP P RIH, shallow test agitator. 964 psi @ 78.2 9,919.0 19:42 21:36 1.88 bpm. Contiue to RIH displacing coil to duovis 11/22/2019 11/22/2019 0.20 PROD2 STK DLOG P Tie int othe K1 for a + 4' correction 9,919.0 9,955.0 21:36 21:48 11/22/2019 11/22/2019 1.00 PROD2 STK DISP P Turn welbore over to DoVis, closd 9,955.0 10,027.0 21:48 22:48 EDC PU Wt 31 k lbs 11/22/2019 11/22/2019 0.20 PROD2 STK TRIP P RIH, lots of magnetic interference @ 10,027.0 10,234.6 22:48 23:00 10,100',5 k WOB spike @ 10143' Continue in to TOL S/D 4.8 k WOB @ 10,236' PU Wt 33 k lbs. PUH set rate, establish retunes RBIH, encounter high vibrations (5) possibly have broken ring from billet on the bit. 11/22/2019 11/23/2019 1.00 PROD2 STK KOST P CT 4446 psi @ 1.79 / 1.31 bmp in/out, 10,234.6 10,235.6 23:00 00:00 Free spin diff 1175 psi, BHP 3181 psi, 10.35 EMW @ the window w choke wide open, WH 0 psi, IA 771 psi, OA 66 psi. CT RIH Wt 15.37 k lbs. WOB 0.3 k lbs, get into billet, sharp spike in motor work that fell quickly to more typical value, fed a few tenths, all smooth, engage auto driller at 1 ft/hr Tool face HS 11/23/2019 11/23/2019 0.50 PROD2 STK KOST P Increase ROP to 2 ft/hr 10,235.6 10,236.6 00:00 00:30 CT Wt 15.3 k lbs, WOB 0.3 lbs 11/23/2019 11/23/2019 0.40 PROD2 STK KOST P Increase ROP to 3 ft/hr 10,236.6 10,237.6 00:30 00:54 CT Wt 15.3 k lbs. WOB 0.39 lbs 11/23/2019 11/23/2019 0.60 PROD2 STK KOST P Start to push on it, targeting 20 ft/hr 10,237.6 10,250.0 00:54 01:30 and up to WOB of 1.2 k lbs 10,244' star to push on itROP to 38 ft/hr WOB 1.2 k/lbs 11/23/2019 11/23/2019 0.20 PROD2 DRILL DRLG P Drilling ahead, CT 4762 psi, 1.79/1.55 10,250.0 10,265.0 01:30 01:42 bpm in/out, WOB 1.9 k Isb CT Wt 13.4 k Isb. ROB variable to 100 ft/hr. BHP 3204 psi, EMW 10.4 ppg, WH Opsi, IA 788 psi, OA 96 psi 11/23/2019 11/23/2019 0.20 PROD2 DRILL WPRT P 10,265', stall, PU Wt 36 k lbs, PUH, 10,265.0 10,265.0 01:42 01:54 RBIH, dry drift billet, a little ratty but OK, RBIH 11/23/2019 11/23/2019 3.00 PROD2 DRILL DRLG P CT 4283 psi 1.79/1.47 bpm in/out, free 10,265.0 10,447.0 01:54 04:54 spin 1119 psi, BHP 3157, WH 0 psi, CT Wt 10 k Isb, WOB 2.8 k lbs. ROP variable to 100 ft/hr 10,339' PU 36 k lbs 10,396' PU 40 k lbs 10,415' PU 35 k lbs - start new mud Power Pro down the coil New mud at the bit - 10447' 11/23/2019 11/23/2019 1.90 PROD2 DRILL DRLG P Drilling, CWT = 8.81K @ 2K WOB, bore 10,447.0 10,560.0 04:54 06:48 pressure spike at -10,440', returns began to slowly drop to 1.45 bpm, 250' wiper from 10,500', stall at 10,521'. PUW = 37K 11/23/2019 11/23/2019 0.70 PROD2 DRILL WPRT P Wiper to tubing tail, PUW = 35K, jog 10,560.0 10,111.0 06:48 07:30 7" casing Stack at bottom of window (HS), orient 10°L, stack again, attempt 10°L @ 15 fpm, stack again (2X), attempt 10R, no good, come to 2K WOB, work HOT back & forth, no good, attempt HS, no good Page 18/25 Report Printed: 12/3/2019 Operations Summary (with Timelog Depths) 2M-21 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time Dur (hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth (ftKB) 11/23/2019 11/23/2019 0.20 PROD2 DRILL WPRT P Unable to pass through window, PUH 10,111.0 9,930.0 07:30 07:42 to log K1 11/23/2019 11/23/2019 0.10 PROD2 DRILL DLOG P Log K1 for+2' correction 9,930.0 9,951.0 07:42 07:48 11/23/2019 11/23/2019 0.30 PROD2 DRILL WPRT P RBIH, & get through window at 10L @ 9,951.0 10,560.0 07:48 08:06 15 fpm clean, stacked weight @10,146', clean past billet, pump 5x5 sweeps, RIW = 10.5K 11/23/2019 11/23/2019 0.30 PROD2 DRILL DRLG P Drilling, FS = 1036 psi @ 1.8 bpm, 10,560.0 10,583.0 08:06 08:24 CWT = 10.3K @ 1.1 K WOB, annular = 3386 psi (choke open), pump = 4658 psi, 1.5 bpm returns 11/23/2019 11/23/2019 2.90 PROD2 DRILL DRLG P PU for new numbers, PUW = 32K 10,583.0 10,760.0 08:24 11:18 Drilling, FS = 1144 psi @ 1.8 bpm, CWT = 10.21K @ 0.5K WOB, annular = 3386 psi, pump = 4749 psi, 1.52 bpm returns. PUW = 40K from 10,699' Two stalls at 10,722' (torquing up drilling through hard spots), pump sweeps, avg ROP = 61 fph 11/23/2019 11/23/2019 0.60 PROD2 DRILL WPRT P Wiper to BOW, PUW = 37K, RIW = 10,760.0 10,760.0 11:18 11:54 11.2K 11/23/2019 11/23/2019 2.20 PROD2 DRILL DRLG P Drilling, FS = 1079 psi @ 1.8 bpm, 10,760.0 10,960.0 11:54 14:06 CWT = 9.8K @ 1.4K WOB, annular = 3428 psi, pump = 5033 psi, 1.5 bpm returns, avg ROP = 91 fph 11/23/2019 11/23/2019 0.50 PROD2 DRILL WPRT P Wiper to tubing tail, PUW = 35K, drag 10,960.0 10,125.0 14:06 14:36 a bit of negative WOB off bottom & up through window, jog 7", clean down through window 11/23/2019 11/23/2019 0.10 PROD2 DRILL DLOG P Log RAfor +1.5'correction 10,125.0 10,144.0 14:36 14:42 11/23/2019 11/23/2019 0.30 PROD2 DRILL WPRT P Wiper back in-hole, RIW = 10.3K 10,144.0 10,960.0 14:42 15:00 11/23/2019 11/23/2019 1.40 PROD2 DRILL DRLG P Drilling, FS = 1280 psi @ 1.86 bpm, 10,960.0 11,160.0 15:00 16:24 CWT = 9.5K @ 1.75K WOB, annular = 3489 psi, pump = 5241 psi, 1.55 bpm returns, cuttings ratio = 0.94, pump sweeps, pump up the volume, avg ROP = 143 fph, CR = 0.93 11/23/2019 11/23/2019 0.50 PROD2 DRILL WPRT P 800' wiper, PUW = 35K, RIW = 10.9 11,160.0 11,160.0 16:24 16:54 11/23/2019 11/23/2019 1.70 PROD2 DRILL DRLG P CT 4653 psi 1.78 / 1.57 bpm in/out, 11,160.0 11,367.0 16:54 18:36 Free spin 1142 psi, BHP 3315 psi CT Wt 11.1 k lbs, 2.3 k lbs. Crew change PU, 39 k lbs, free spin 1096 psi OBD, pump 5x5 in anticipation of wiper to window average ROP over interval, 121 ft/hr 11/23/2019 11/23/2019 0.90 PROD2 DRILL WPRT P PU Wt 35 k lbs, PUH on long wiper to 11,367.0 10,041.0 18:36 19:30 window. Brief -2.8 k WOB tug @ 11,287'- 100 lbs of motor work Jog build section, pull through window @ 10 ft/min and 0.5 bpm -1 k WOB tug pulling through the window Jet 7" 11/23/2019 11/23/2019 0.30 PROM DRILL WPRT P RBIH, S/D 10111, 3x, orient 10 L, RIH 10,041.0 10,126.0 19:30 19:48 clean 11/23/2019 11/23/2019 0.20 PROD2 DRILL WPRT P Tie in to RA tag +2.5' correction 10,126.0 10,154.0 19:48 20:00 Page 19/25 Report Printed: 12/3/2019 Operations Summary (with Timelog Depths) 2M-21 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time our (hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth (ftKB) 11/23/2019 11/23/2019 0.70 PROD2 DRILL WPRT P RI H post window wiper 10,154.0 11,367.0 20:00 20:42 Set down 4x, first at 10,931, and again at 10937, orient 300 ROHS RIH and S/D @ 10,937 and 10, 947' Pick ups clean Reduced pump to min rate, RIH clean. Back up on the pump continue to RIH CT RIH Wt 10 k lbs 11/23/2019 11/23/2019 2.70 PROD2 DRILL DRLG P CT 4549 psi @ 1.76/1.54 bpm in/out, 11,367.0 11,541.0 20:42 23:24 free pin 1027 psi, BHP 3515 psi, 11.1 ppg EMW @ the window, open choke, WH 0 psi, IA 798 psi, OA 96 psi. CT Wt 0 k lbs, WOB 2.7 k lbs. 11.389' PU 39 k lbs 11,410' PU 37 k lbs 11429'36 k lbs & -3 k lbs WOB 11/23/2019 11/24/2019 0.60 PROD2 DRILL WPRT P Hard stall, PU Wt 48 k lbs, Returns fell 11,541.0 10,172.0 23:24 00:00 to 6%. 1.8 in, 0.12 bpm out. PUH on wiper, losses slowly healing. 11/24/2019 11/24/2019 0.20 PROD2 DRILL WPRT P Continue to PUH to window 10,172.0 10,040.0 00:00 00:12 11/24/2019 11/24/2019 0.40 PROD2 DRILL WPRT P Jet 7 " RBIH. S/D 2x @ BOW window. 10,040.0 10,125.0 00:12 00:36 First HS, second 10 L, third attempt passed cleanly. 11/24/2019 11/24/2019 0.20 PROD2 DRILL DLOG P Log the RA tag for a +2' correction 10,125.0 10.145.0 00:36 00:48 S/D while loggingg, 4k WOB @ 10.143 (corected) PU and pop through 11/24/2019 11/24/2019 0.40 PROD2 DRILL TRIP P RIH 10,145.0 11.541.0 00:48 01:12 11/24/2019 11/24/2019 2.20 PROD2 DRILL DRLG P CT 4562 psi. 1.80 / 0.93 bpm in/out. 11,541.0 11,635.0 01:12 03:24 free spin 1127 psi, BHP 3388 psi, 10.8 ppg EM @ the window, 11 ppg at the bit. WH 0, IA 789, OA 95 psi. CT 10 k lbs, WOB 11/24/2019 11/24/2019 0.20 PROD2 DRILL WPRT P PU Wt 35 k lbs 11,635.0 10,952.0 03:24 03:36 11/24/2019 11/24/2019 0.30 PROD2 DRILL WPRT P RBIH RIH Wt 11.5 k lbs 10,952.0 11,635.0 03:36 03:54 11/24/2019 11/24/2019 1.10 PROD2 DRILL DRLG P CT 4656 psi @ 1.81 / 1.11 bpm in /out. 11,635.0 11,708.0 03:54 05:00 free spin 1074 psi, BHP 3468 psi . 11 ppg EMW at the window, 11.3 ppg at the bit. OBD, CT 6.9 kl bs. WOB 1.4 k lbs 11/24/2019 11/24/2019 3.00 PROD2 DRILL DRLG P Drilling, CWT = 9AK @ 3.4K WOB, 11,708.0 11,835.0 05:00 08:00 annular = 3493 psi, pump = 4709 psi, 1.2 bpm returns. lower ROP beginning -11,775' BHA wiper from 11,761', PUW =40K Wrapping gamma cut at 11,747' (157 API), -2' section, pump sweeps, encounter a bit of aired up mud 11/24/2019 11/24/2019 0.90 PROD2 DRILL WPRT P Wiper to tubing tail, PUW = 42K, jog 11,835.0 10,125.0 08:00 08:54 7", stack at BOW (3X) 11/24/2019 11/24/2019 0.10 PROD2 DRILL DLOG P Log RA for+3' correction, stack out at 10,125.0 10,140.0 08:54 09:00 1 1 1 1 1 110,141'during tie-in 11/24/2019 0.70 PROD2 DRILL WPRT P Cotinue RIH, stack 1 K weight at 10,140.0 11,835.0 09:00 111/24/2019 09:42 11,666', clean past got gamma at 11,747', RIW = 9.5K Page 20/25 Report Printed: 12/3/2019 Operations Summary (with Timelog Depths) 2M-21 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time Dur (hr) Phase Op Code Activity Code Time P -T -X Operation (ftKB) End Depth (ftKB) 11/24/2019 11/24/2019 2.40 PROD2 DRILL DRLG P Drilling, FS = 1106 psi @ 1.8 bpm, 11,835.0 11,936.0 09:42 12:06 CWT = 8.65K @ 1.5K WOB, annular = 3515 psi, pump = 4906. 1.12 bpm returns, avg ROP = 42 fph 11/24/2019 11/24/2019 2.60 PROD2 DRILL DRLG P Drilling, CWT = -5K @ 1.2K WOB, 11,936.0 12,035.0 12:06 14:42 annular = 3542 psi, pump = 4653 psi, 1.27 bpm returns, pump 5x5 sweeps. ROP picking up at -12,009'. abg ROP = 40 fph 11/24/2019 11/24/2019 0.60 PROD2 DRILL WPRT P 800' wiper, PUW = 34K, RIW = 9.8K 12,035.0 12,035.0 14:42 15:18 11/24/2019 11/24/2019 3.70 PROD2 DRILL DRLG P Drilling, FS = 1260 psi, @ 1.8 bpm. 12,035.0 12,226.0 15:18 19:00 CWT = -1.5K @ 1.75K WOB, annular = 3591 psi, pump = 5176 psi, 1.35 bpm returns Crew change PU, 12,179' PU Wt 36 k lbs, CT 4830 psi @ 1.83/1.38 bpm in/out, diff 1034 psi, BHP 3621 psi, WH 0, IA 797, OA 94 psi. CT -5 k lbs, WOB 2 k lbs. launch 5x5 in anticipation of wiper. Average ROP over interval - 51 ft/hr 11/24/2019 11/24/2019 1.00 PROD2 DRILL WPRT P PU wt 38 k lbs, PUH on long wiper to 12,226.0 10,072.0 19:00 20:00 the window for tie in. Hole, billet and window clean. 11/24/2019 11/24/2019 0.80 PROD2 DRILL CIRC P Jet 7", chase bottoms up 10,072.0 9.914.0 20:00 20:48 11/24/2019 11/24/2019 0.20 PROD2 DRILL DLOG P Tie into the K1 for +2.5' correction 9,914.0 9,952.4 20:48 21:00 11/24/2019 11/24/2019 0.90 PROD2 DRILL TRIP P RBIH, 10,103' WOB spike to 2 k lbs. 9,952.4 12,226.0 21:00 21:54 billet clean, Caried 12k CT wt while RIH '* Add 2 ppb alpine beads to high vis sweeps 11/24/2019 11/25/2019 2.10 PROD2 DRILL DRLG P CT 4948 psi @ 1.78 / 1.26 bpm in/out, 12,226.0 12,285.0 21:54 00:00 free spin 1207 psi, BHP 3633 psi, 11.3 ppg EMW @ the window. 11.87 ppg @ the bit. OBD, CT 0 k lbs. WOB to 3 k lbs, 11/25/2019 11/25/2019 1.70 PROD2 DRILL DRLG P CT 4948 psi @ 1.78 / 1.26 bpm in/out, 12,285.0 12,299.6 00:00 01:42 free spin 1207 psi, BHP 3633 psi. 11.3 ppg EMW @ the window. 11.87 ppg @ the bit OBD, CT 0 k lbs, WOB to 3 k lbs. 11/25/2019 11/25/2019 0.60 PROD2 DRILL DRLG P While on bottom motor work fell from 12,299.6 12,302.0 01:42 02:18 1300 psi to 1076 psi. PU, diff climbed to a stady 1224 psi. Pump inlet pressure dropped mirroring the diff 11/25/2019 11/25/2019 0.20 PROD2 DRILL WPRT P PU Wt 35 k lbs, Pull 300' wiper. pump 12,302.0 12,302.0 02:18 02:30 5x5 sweep RIH Wt 9.5 k lbs 11/25/2019 11/25/2019 1.70 PROD2 DRILL DRLG P CT 5164 psi, @ 1.83/1.5 bpm in/out, 12,302.0 12,312.0 02:30 04:12 diff 1198 psi. OBD, diff fell 193 psi with 3.7 k WOB Multiple attempts to drill ahead, PU's 35 k lbs. No sucess. Rotate the HOT while drilling w 3 k WOB, suddent spike in WOB and motor work, able to drill ahead, ROP/diff fell of, rotated again with similar results, drilled ahead. 11/25/2019 11/25/2019 1.60 PROD2 DRILL DRLG P CT 4879 psi @ 1.8/1.47 bpm in/out, 12,312.0 12,351.0 04:12 05:48 diff 1029 psi, BHP 3633 psi, 11.3 ppg EMW at the window, 11.8 ppg @ the bit. CT -4 k lbs. WOB 2.2 k lbs Page 21125 Report Printed: 12/3/2019 Operations Summary (with Timelog Depths) 2M-21 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time Dur (hr) Phase Op Code Activity Code Time P -T -X Operation (ftKB) End Depth (ftKB) 11/25/2019 11/25/2019 2.70 PROD2 DRILL DRLG P Crew change, drilling, CWT = -3.5K @ 12,351.0 12,403.0 05:48 08:30 1.9K WOB, annular = 3645 psi, pump = 5253 psi. 1.5 bpm returns, lower ROP w/ low differential 11/25/2019 11/25/2019 1.40 PROD2 DRILL DRLG P Drilling, low ROP, down to 4 fph, CWT 12,403.0 12,430.0 08:30 09:54 = -3.6K @ 2.9K WOB, pump = 5080 psi. oriented HS, working through hard spot back up through, extremely low ROP (to 4 fph), pump 5x5 sweeps 11/25/2019 11/25/2019 0.70 PROD2 DRILL WPRT P 800' wiper, PUW = 35K, bit oriented 12,430.0 12,430.0 09:54 10:36 LS pulling up -hole, RIW = 7.8K 11/25/2019 11/25/2019 3.10 PROD2 DRILL DRLG P Drilling, FS = 1204 psi @ 1.9 bpm, 12,430.0 12,488.0 10:36 13:42 CWT = 6.6K @ 1.8K WOB. 11.5 ppg at window, 1.56 bpm returns, PUW = 36K from 12,484', clay over shakers, decsion made to trip for bit, avg ROP = 19 fph 11/25/2019 11/25/2019 3.00 PROD2 DRILL TRIP P POOH for new bit (closed EDC), PUW 12,488.0 78.0 13:42 16:42 = 33K, jog 7", open EDC at surface), PJSM *' Pre -load PDL 11/25/2019 11/25/2019 1.20 PROD2 DRILL PULD P PUD BHA #17, bit came a 2-5 78.0 0.0 16:42 17:54 11/25/2019 11/25/2019 1.20 PROD2 DRILL PULD P PD BHA#18 (new CoilTrack & 0.0 78.0 17:54 19:06 Dynamus bit), inspect pack offs - good. 11/25/2019 11/25/2019 2.10 PROD2 DRILL TRIP P Bump up, set ounters, RIH, Shallow 78.0 9,932.8 19:06 21:12 test agitator - good - 1 k diff, Baker counter feed locked up at 1745', troublshot and repaired continued in hole. WOB spikes, setting down on collars. 11/25/2019 11/25/2019 0.20 PROD2 DRILL DLOG P Tie into the K1 + 5.5' 9,932.8 9,953.6 21:12 21:24 11/25/2019 11/25/2019 0.90 PROD2 DRILL TRIP P Continue in hole, window, billet, and 9,953.6 12,488.0 21:24 22:18 open hole clean 11/25/2019 11/25/2019 0.70 PROD2 DRILL DRLG P CT 5012 psi @ 1.78/1.43 bpm in/out, 12,488.0 12,507.0 22:18 23:00 diff 1051 psi, BHP 3730 psi, Get kicked down, trying to target higher WOB, pump beaded sweep Encounter High ROP drilling break snubbing -5 k lbs, max 1.4 k WOB 11/25/2019 11/25/2019 0.50 PROD2 DRILL WPRT P PU Wt 35, PUH on short wiper while 12,507.0 12,507.0 23:00 23:30 beads travel to bit. RBIH 11/25/2019 11/26/2019 0.50 PROD2 DRILL DRLG P CT 4189 psi @ 1.5/1.4 bpm in/out, diff 12,507.0 12,538.0 23:30 00:00 839 psi, BHP 3665 psi, CT Wt -5 k lbs, WOB 1.9 k lbs 11/26/2019 11/26/2019 1.40 PROD2 DRILL DRLG P CT 4189 psi @ 1.5/1.4 bpm in/out, diff 12,538.0 12,591.0 00:00 01:24 839 psi, BHP 3665 psi, CT Wt -5 k lbs, WOB 1.9 k lbs Drilling break at 12,596'. resistivity trending back up 11/26/2019 11/26/2019 1.20 PROD2 DRILL DRLG P Increase pump rate to 1.8 bpm, drill 12,591.0 12,658.0 01:24 02:36 ahead CT 5180 psi @ 1.78/1.45 bpm in/out, BHP 3689 psi, CT Wt -4 k lbs, WOB 2.6 k lbs 11/26/2019 11/26/2019 0.60 PROD2 DRILL WPRT P PU as directed by Geo, circ sample 12,658.0 12,658.0 02:36 03:12 bottoms up, catch sample and deliver to Geo. Page 22/25 Report Printed: 12/3/2019 - Operations Summary (with Timelog Depths) 2M-21 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time Dur (hr) Phase Op Code Activity Code Time P -T -X Operation (ftKB) End Depth (ftKB) 11/26/2019 11/26/2019 1.20 PROD2 DRILL DRLG P CT 5113 psi @ 1.78/1.47 bpm in/out, 12,658.0 12,749.0 03:12 04:24 driff 1089 psi, BHP 3762, 11.56 EMW @ the window, 12.25 ppg @ the bit. CT -2 k lbs, WOB 1.5 k lbs 11/26/2019 11/26/2019 0.60 PROD2 DRILL WPRT P PU Wt 41 k lbs, PUH on short 800' 12,749.0 12,749.0 04:24 05:00 wiper. 11/26/2019 11/26/2019 3.70 PROD2 DRILL DRLG P Drilling, FS = 1087 psi @ 1.8 bpm, 12,749.0 12,950.0 05:00 08:42 CWT = -51K @ 1.3K WOB, annular = 3775 psi pump = 5270 psi. 1.55 bpm returns, pump 5x5 beaded sweeps 11/26/2019 11/26/2019 1.50 PROD2 DRILL WPRT P Wiper to tubing tail, PUW = 36K, clean 12,950.0 9,935.0 08:42 10:12 all the way, log 7" 11/26/2019 11/26/2019 0.10 PROD2 DRILL DLOG P Log K1 for+6' correction 9,935.0 9,946.0 10:12 10:18 11/26/2019 11/26/2019 1.10 PROD2 DRILL WPRT P RBIH, clean through window, clean 9,946.0 12,950.0 10:18 11:24 past billet, RIW variable (getting into negative weight near bottom, at reduced speed) 11/26/2019 11/26/2019 2.60 PROD2 DRILL DRLG P Drilling, FS = 1100 psi @ 1.86 bpm, 12,950.0 13,063.0 11:24 14:00 CWT = 5.2K @ 0.9K WOB, 11.6 ppg at window, pump = 5730 psi, 1,54 bpm returns, pump 10 bbl beaded pill to good effect, continue pumping beaded pills as required, avg ROP = 43 fph PUW = 36K from 13060' 11/26/2019 11/26/2019 1.90 PROD2 DRILL DRLG P Drilling, CWT = OK @ 1 K WOB, 11.7 13,063.0 13,150.0 14:00 15:54 @ the window, pump = 5700 psi, continue to pump beaded pills. 1.64 bpm returns 11/26/2019 11/26/2019 0.70 PROD2 DRILL WPRT P 800' wiper, PUW = 35K, near neutral 13,150.0 13.150.0 15:54 16:36 weight with beads coming around @ reduced -20 fpm 11/26/2019 11/26/2019 2.90 PROD2 DRILL DRLG P Drilling, FS = 1089 psi @ 1.85 bpm. 13,150.0 13,294.0 16:36 19:30 CWT = -2.5K @ 1.2K WOB, 11.6 ppg at window, pump = 5374 psi, 1.55 bpm returns, avg ROP = 50 fph 11/26/2019 11/26/2019 1.00 PROD2 DRILL DRLG P Drilling, CWT = -7.7K @ 1.3K WOB, 13,294.0 13,350.0 19:30 20:30 annular = 3787 psi, pump = 5334 psi. 5x5 beaded sweeps, avg ROP = 56 fph 11/26/2019 11/26/2019 1.70 PROD2 DRILL WPRT P Wiper to window. PUW = 35K, jog 7" 13.350.0 9.935.0 20:30 22:12 11/26/2019 11/26/2019 0.10 PROD2 DRILL DLOG P Log K1 for +35 correction 9,935.0 9,956.0 22:12 22:18 11/26/2019 11/26/2019 1.30 PROD2 DRILL WPRT P RBIH, clean window, billet and open 9,956.0 13,350.0 22:18 23:36 hole 11/26/2019 11/27/2019 0.40 PROD2 DRILL WPRT P 5299 psi @ 1.78/1.5 bpm in/out, diff 9,956.0 13,350.0 23:36 00:00 1034 psi. BHP 3817 psi, 11.4 ppg ECD at the window, 12.3 ppg @ the bit. CT Wt -5 k lbs. 1 k lbs 11/27/2019 11/27/2019 5.90 PROD2 DRILL WPRT P 5299 psi @ 1.78/1.5 bpm in/out, diff 13,350.0 13,608.0 00:00 05:54 1034 psi, BHP 3817 psi, 11.4 ppg ECD at the window, 12.3 ppg @ the bit. CT Wt -5 k lbs. 1 k lbs Pumping beaded active mud pills with little observable effect. 11/27/2019 11/27/2019 0.30 PROD2 DRILL WPRT P PU Wt 36 k lbs, PUH on short 800' 13,608.0 12,817.0 05:54 06:12 wiper 11/27/2019 11/27/2019 0.60 PROD2 DRILL WPRT P RBIH - 3-4 k lbs 12,817.0 13,608.0 06:12 06:48 Page 23125 Report Printed: 12/3/2019 Operations Summary (with Timelog Depths) 2M-21 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time our (hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth (ftKB) 11/27/2019 11/27/2019 4.90 PROD2 DRILL DRLG P CT 4399 pis, @ 1.56/1.37 bpm out, 13,608.0 13,735.0 06:48 11:42 diff 772 psi, BHP 3794 psi, WH 0, IA 810, OA 98. CT -3 k lbs, WOB 1.1 k lbs. 11/27/2019 11/27/2019 0.90 PROD2 DRILL WPRT P PU 38 k lbs, atempting to restart 13,735.0 13,735.0 11:42 12:36 unable to RBIH Pull up hole on wiper while displacing sweep to bit. 11/27/2019 11/27/2019 3.10 PROD2 DRILL DRLG P CT 3928 psi, @ 1.79/1.56 bpm in/out, 13,735.0 13,804.0 12:36 15:42 diff 924 psi, BHP 3928, CT -8 k WOB 0.8 k lbs, 11/27/2019 11/27/2019 3.70 PROD2 DRILL WPRT P PU 35 k lbs, chase TD sweeps to bit 13,804.0 78.2 15:42 19:24 and out of hole. 11/27/2019 11/27/2019 0.20 PROD2 DRILL TRIP P Tag up, reset counters depths 78.2 78.2 19:24 19:36 11/27/2019 11/27/2019 1.60 PROD2 DRILL TRIP P RIH 78.2 9,935.0 19:36 21:12 11/27/2019 11/27/2019 0.20 PROD2 DRILL DLOG P Log formation for depth control (+8.0') 9,935.0 9,946.0 21:12 21:24 11/27/2019 11/27/2019 0.20 PROD2 DRILL TRIP P Continue IH 9,946.0 10,061.0 21:24 21:36 11/27/2019 11/27/2019 0.50 PROD2 DRILL TRIP P Obtain SBHR 9.969 ppg EDC @ 10,061.0 10,061.0 21:36 22:06 10,061' CTMD, 5,848.8 TVD, 3,029 psi 9:25p - 3304 psi 9:30p - 3248 psi 9:35p - 3194 psi 9:40p - 3120 psi 9:45p - 3091 psi 9:50p - 3041 psi 9:53p - 3029 psi Confer with town team 10.3 ppg KWF 11/27/2019 11/27/2019 1.40 PROD2 DRILL TRIP P Continue IH through window 350 10,061.0 13,807.0 22:06 23:30 ROHS w/1.2k bobble @ 10,112'. 1.0 k weight bobble @ billet as we passed by 10,236' 11/27/2019 11/28/2019 0.50 PROD2 DRILL CIRC P Confirm TD 13,807', work pipe while 13,807.0 13,591.0 23:30 00:00 circulating beaded LRP to bit. 11/28/2019 11/28/2019 0.20 PROD2 DRILL TRIP P RBIH to bottom 13,802' 13,591.0 13,802.0 00:00 00:12 11/28/2019 11/28/2019 3.30 PROD2 DRILL TRIP P POOH, laying in beaded 10.3 ppg liner 13,802.0 78.2 00:12 03:30 running pill EOP flags 12,043' (yellow), 8,278' (white) 11/28/2019 11/28/2019 0.50 PROD2 DRILL OWFF P At surface, open valve on riser, 78.2 78.2 03:30 04:00 monitor for flow, PJSM 11/28/2019 11/28/2019 0.50 PROD2 DRILL PULD P Unstab INJH, inspect CT above CTC 78.2 0.0 04:00 04:30 0.127" continue LD drilling assembly 11/28/2019 11/28/2019 0.50 COMPZ2 CASING PUTB P Prep floor for running liner 0.0 0.0 04:30 05:00 11/28/2019 11/28/2019 2.20 COMPZ2 CASING PUTB P PU Lower L1-01 liner, 45 joints R3 0.0 1,704.7 05:00 07:12 over a solid bull nose under a shorty deployment sleeve. Liner 1793.47' LOA 1704.72'. 115 joints loaded in the shed, ran 45, confirmed 70 joints in shed. 11/28/2019 11/28/2019 0.50 COMPZ2 CASING PUTB P PU BHA#19 1,704.7 1,839.0 07 12 07:42 1 1 I I Page 24/25 Report Printed: 12/3/2019 Operations Summary (with Timelog Depths) 2M-21 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time our (hr) Phase Op Code Activity Code Time P -T -X Operation (ftKB) End Depth (ftKB) 11/28/2019 11/28/2019 3.70 COMPZ2 CASING RUNL P RIH W Lower L1-01 completion. Tie 1,839.0 13.807.0 07:42 11:24 into window flag for no correction, CT PU wt 30 k lbs. First set down 11,852', PU 49 k lbs, Work liner to about 12,050' RIH clean from 12,051' down. 11/28/2019 11/28/2019 0.80 COMPZ2 CASING TRIP P PU, set counters, POOH 13,807.0 9,900.0 11:24 12:12 11/28/2019 11/28/2019 0.20 COMPZ2 CASING DLOG P Tie into the K1 for+4.5' correction 9,900.0 9,930.9 12:12 12:24 11/28/2019 11/28/2019 0.20 COMPZ2 CASING DLOG P Log CCL to tubing tail, +7' correton to 9,930.9 10,008.0 12:24 12:36 convert PDC to original RKB. 11/28/2019 11/28/2019 1.70 COMPZ2 CASING TRIP P POOH painting flags, pumping down 10,008.0 64.0 12:36 14:18 the back side. yellow @10,024.22. White flag at 8044 11/28/2019 11/28/2019 0.50 COMPZ2 CASING PULD P Park short, Flow check - good. LD 0.0 0.0 14:18 14:48 BHA #19 over a dead well. 11/28/2019 11/28/2019 0.20 COMPZ2 CASING PUTB P Prep floor for running liner. 0.0 0.0 14:48 15:00 11/28/2019 11/28/2019 1.90 COMPZ2 CASING PUTB P Pick up Upper L1-01 completion, 50 0.0 1,992.5 15:00 16:54 R3 joints of slotted liner (1983.17') under a shorty deployment sieve, over a 8.09' pup and a ported bull nose LOA 1992.51'. 11/28/2019 11/28/2019 0.40 COMPZ2 CASING PULD P Pick up BHA#19 1,992.5 2,056.5 16:54 17:18 11/28/2019 11/28/2019 1.40 COMPZ2 CASING RUNL P RIH with upper L1-01 completion. 2,056.5 10,037.0 17:18 18:42 11/28/2019 11/28/2019 0.15 COMPZ2 CASING RUNL P Log formation for depth control (+27) 10,037.0 10,037.0 18:42 18:51 11/28/2019 11/28/2019 0.70 COMPZ2 CASING RUNL P Continue RIH 10,037.0 12,012.0 18:51 19:33 11/28/2019 11/28/2019 0.20 COMPZ2 CASING RUNL P Tag top of liner @ 12,012', PUW 44 k, 12,012.0 10,019.8 19:33 19:45 set back down @ 12,012', bring pump up of 5,540' 1,766 psi diff, PUW 28 k. TOL @ 10,019.8- 11/28/2019 11/28/2019 0.50 DEMOB WHDBOP DISP P Line up and circulte SW to the bit. 10,019.8 10,019.8 19:45 20:15 11/28/2019 11/28/2019 1.60 DEMOB WHDBOP TRIP P POOH, displacing well to SW. LRS on 10,019.8 2,500.0 20:15 21:51 location, spot in, RU to customer line, PT 4,000 psi 11/28/2019 11/28/2019 1.00 DEMOB WHDBOP DISP P PSJM, load reel with 32 bbl of diesel 2,500.0 2,500.0 21:51 22:51 11/28/2019 11/28/2019 0.80 DEMOB WHDBOP TRIP P POOH, displacing well to deisel from 2,500.0 44.2 22:51 23:39 2,500' 11/28/2019 11/29/2019 0.35 DEMOB WHDBOP PULD P At surface. PUD setting tools. 44.2 44.2 23:39 00:00 FTP=400 psi 11/29/2019 11/29/2019 1.50 DEMOB WHDBOP PULD P Continue PUD/LD setting tools, 44.2 0.0 00:00 01:30 11/29/2019 11/29/2019 1.50 DEMOB WHDBOP CTOP P Install nozzle, jet stack and surface 0.0 0.0 01:30 03:00 lines with FW 11/29/2019 11/29/2019 0.70 DEMOB WHDBOP SVRG P Run bore -O -scope, prep to changout 0.0 0.0 03:00 03:42 Annular Element. 11/29/2019 11/29/2019 3.80 DEMOB WHDBOP SVRG P PJSM, swap annulara preventer 0.0 0.0 03:42 07:30 element 11/29/2019 11/29/2019 4.50 DEMOB WHDBOP DMOB P Work RD checklist. Blow down, nipple0.0 0.0 07:30 12:00 down Rig release 12:00 Page 25/25 Report Printed: 12/3/2019 ConocoPhillips ConocoPhillips Alaska Inc—Kuparuk Kuparuk River Unit Kuparuk 2M Pad 2M-21 L1-01 50-103-20156-61 Baker Hughes INTEQ Definitive Survey Report 28 December, 2019 Baker Hughes u ` 12/28/2019 11: 14 08A Page 2 COMPASS 5000.14 Build 85H ConocoPhillips Baker Hughes 1 ConocoPhillips Definitive Survey Report Company: ConocoPhillips Alaska Inc Kuparuk Local Co-ordinate Reference: Well 2M-21 Project: Kuparuk River Unit TVD Reference: 2M-21 @ 140 00usft Site: Kuparuk 2M Pad MD Reference: 2M-21 @ 140,00usft Well: 2M-21 North Reference: True Wellbore: 21M-2111-01 Survey Calculation Method: Minimum Curvature Design: 2M-211-1-01 Database: EDT 14 Alaska Production Project Kuparuk River Unit, North Slope Alaska, United States Map System: US State Plane 1927 (Exact solution) System Datum: Mean Sea Level Geo Datum: NAD 1927 (NADCON CONUS) Using Well Reference Point Map Zone: Alaska Zone 04 Using geodetic scale factor Well 2M-21 Well Position +N/ -S 0 00 usft Northing: 5.948,985 88usft Latitude: 70` 16' 18.585 N +E/ -W 0,00 usft Easting: 488,319 18usft Longitude: 150` 5'40 098 W Position Uncertainty 0.00 usft Wellhead Elevation: usft Ground Level: 105.30 usft Wellbore 2M-21 L1-01 Magnetics Model Name Sample Date Declination Dip Angle Field Strength V) V) (nT) BGGM2018 12/1/2019 16 17 8077 57.384 Design 2M-211-1-01 Audit Notes: Version: 1 0 Phase: ACTUAL Tie On Depth: 10.198.66 Vertical Section: Depth From (TVD) +N/ -S +E/ -W Direction (usft) (usft) (usft) (I 34 70 0.00 0.00 2379 12/28/2019 11: 14 08A Page 2 COMPASS 5000.14 Build 85H ConocoPhillips Conoc6Phiiiips Definitive Survey Report Company: ConocoPhillips Alaska Inc-Kuparuk Local Co-ordinate Reference: Well 2M-21 Project: Kuparuk River Unit Map TVD Reference: 2M-21 @ 140.00usft MD Site: Kuparuk 2M Pad TVD MD Reference- 2M-21 @ 140.00usft +El -W Well: 2M-21 North Reference: True (I (°) Wellbore: 2M-211-1-01 (usft) Survey Calculation Method: Minimum Curvature Easting (°/100') Design: 2M-211-1-01 Database: EDT 14 Alaska Production Survey Program Date (ft) (ft) From To 45.51 5,893.19 5,753.19 Survey Survey (usft) (usft) Survey (Wellbore) Tool Name Description Start Date End Date 200.00 10,000.00 2M-21 srvy 1 - SL13_GCT-MS (2M-21) GCT -MS Schlumberger GCT multishot 11/28/1991 11/28/1991 10,084.93 10,118.78 2M-21 L1 MWD -INC (2M-21 L1) MWD-INC_ONLY (INC>10°) MWD-INC_ONLY_FILLER ( INC>10°) 11/14/2019 11/14/2019 10.138.05 10,198.66 2M-21 L1 MWD (2M-21 L1) MWD OWSG OWSG MWD - Standard 11/15/2019 11/22/2019 10,214.43 10,252,13 2M-21 L1-01 MWD -INC (2M-21 L1-01) MWD-INC_ONLY(INC>10°) MWD -INC -ONLY -FILLER ( INC>10°) 11/22/2019 11/28/2019 10,265.06 13,753.27 2M-21 L1-01 MWD (2M-21 L1-01) MWD OWSG OWSG MWD- Standard 11/29/2019 11/29/2019 Survey 43.83 5,888.84 5,748.84 7,118.22 3,041.95 5,956,098.66 12/28/2019 11:14:08AM Page 3 COMPASS 5000.14 Build 85H Map Map Vertical MD Inc Azi TVD TVDSS +N/ -S +El -W DLS (usft) (I (°) (usft) (usft) (usft) (usft) Northing Easting (°/100') Section Survey Tool Name Annotation (ft) (ft) (ft) 10,214.43 9415 45.51 5,893.19 5,753.19 7,082.51 3,006.33 5,956,063.01 491,336.19 5476 7,693.42 MWD-INC_ONLY (INC>10°) (4) 10,228.10 94.49 4528 5,892.16 5,752.16 7,092.08 3,016.03 5,956,072.57 491,345.91 301 7,706.09 MWD-INC_ONLY(INC>10°)(4) TIP 10,23149 9458 4523 5,89189 5,751.89 7,094.46 3,018.43 5,956,074.94 491,348.32 301 7,709.23 MWD-INC_ONLY(INC>10°)(4) KOP 10,245 36 9493 45.00 5,89074 5,750.74 7,104.21 3,028-22 5,956,084.68 491,358.12 301 7,722.11 MWD-INC_ONLY (INC>10°) (4) 10,265.06 96.12 43.83 5,888.84 5,748.84 7,118.22 3,041.95 5,956,098.66 491,371.87 8.45 7,740.46 MWD OWSG (5) 10,299.89 92.89 38.15 5,88610 5,746.10 7,144.42 3,064.71 5,956,124.82 491,394.66 18.71 7,773.61 MWD OWSG (5) 10,324.83 90.83 34.64 5,885.29 5,745.29 7,164.48 3,079.49 5,956,144.86 491,409.48 16.31 7,797.94 MWD OWSG (5) 10,349.88 89.79 34.73 5,885.16 5,74516 7,185.08 3,093.75 5,956,165.43 491,423.77 4.17 7,822.53 MWD OWSG (5) 10,381.31 s 92.06 37.73 5,884.65 5,744.65 7,210.42 3,112.32 5,956,190.74 491,442.37 11.97 7,853.22 MWD OWSG (5) 10,410.72 91.81 33.63 5,883.66 5,743.66 7,23429 3,129.46 5,956,214.59 491,459.55 13.96 7,881.97 MWD OWSG (5) 10,444.04 90.03 3714 5,883.12 5,743.12 7,261.45 3,148.75 5,956,241.71 491,478.88 11.81 7,914.60 MWD OWSG (5) 10,476.72 91.60 3746 5,882.66 5,742.66 7,28744 3,168.55 5,956,267.67 491,498.72 4.90 7,946.37 MWD OWSG (5) 10,514.09 91.17 3779 5,881.75 5,741 75 7,317,03 3,191.36 5,956,297.22 491,521.57 1.45 7,982.65 MWD OWSG (5) 10,531.18 91.02 37.36 5,881.43 5,741.43 7,330.57 3,201.77 5,956,310.74 491,532.01 2.66 7,999.24 MWD OWSG (5) 10,563,45 90.18 40.76 5,881.09 5,741.09 7,355.62 3,222.10 5,956,335.76 491,552.37 10.85 8,030.37 MWD OWSG (5) 10,596.34 88.40 41.45 5,881 50 5,741.50 7,380.40 3,243.73 5,956,360.51 491,574-03 5.80 8,061 76 MWD OWSG (5) 10,621.63 8696 42.07 5,88252 5,742.52 7,399.25 3,260.55 5,956,379.33 491,590.89 6.20 8,085.80 MWD OWSG (5) 10,652.44 86.03 41.29 5,884.40 5,744.40 7,422.22 3,281.00 5,956,402.26 491,611.37 3.94 8,115.06 MWD OWSG (5) 10,680.80 86.84 43.30 5,886.17 5,746.17 7.44315 3,30005 5,956,423.16 491.630.45 763 8,141.90 MWDOWSG (5) 12/28/2019 11:14:08AM Page 3 COMPASS 5000.14 Build 85H Co nocoP h l l I t p$ Brsker H::yhes ConocoPhilllps Definitive Survey Report Company: ConocoPhillips Alaska Inc-Kuparuk Local Co-ordinate Reference: Well 2M-21 Project: Kuparuk River Unit TVD Reference: 2M-21 @ 140.00usft Site: Kuparuk 2M Pad MD Reference: 2M-21 @ 140.00usft Well: 2M-21 North Reference: True Wellbore: 2M -21L1-01 Survey Calculation Method: Minimum Curvature Design: 2M -21L1-01 Database: EDT 14 Alaska Production Survey Map Vertical MD Inc Azi TVD TVDSS +N/ -S +E/ -W Northing Northing East) DLS Section (usft) (°) (1) (usft) (usft) (usft) (usft) (1100') Survey Toot Name Annotation (ft) (ft) (ft) 10,711.44 91.91 46.04 5,886,50 5,746.50 7,46493 3,32158 5,956,44491 491,652.01 1881 8,170.52 MWD OWSG (5) 10,741.59 89.17 47.35 5,886.22 5,746.22 7,485.61 3,343.52 5,956,465.55 491,673.98 1007 8,19829 MWD OWSG (5) 10,771 48 90.06 4707 5,886.42 5,746.42 7,505.91 3,365,45 5,956,485.82 491,695.94 3 12 8,225.71 MWD OWSG (5) 10.801.12 86.93 43.67 5,887.20 5,747.20 7,526.72 3,38653 5,956,506.59 491,717.05 1559 8,253.26 MWD OWSG (5) - 10,831.94 85.98 40.14 5,889.10 5,749.10 7,549.61 3,407.08 5,956,529.45 491,737.63 11.84 8,282.49 MWD OWSG (5) 10,862.20 86.50 39.49 5,891.09 5,751.09 7,572.81 3,42641 5,956,552.61 491,757.00 2.75 8,311,51 MWD OWSG (5) 10,892.40 88.71 40.31 5,892.35 5,752.35 7,595.95 3,445.76 5,956,575.72 491,776.38 7.80 8,340.50 MWD OWSG (5) - 10,921.82 88.25 39.13 5,89313 5,75313 7,618.57 3,464.56 5,956,598.31 491,795.21 4.30 8,368.78 MWD OWSG (5) 10,952.50 89.63 39.57 5,893.70 5,753.70 7,642.29 3,484.01 5,956,622.00 491,814.69 4,72 8,398.33 MWD OWSG (5) - 10,982 72 92,12 39.79 5,893.24 5,753.24 7.665.55 3,503.30 5,956,645.22 491,834.02 8.27 8,427.39 MWD OWSG (5) 11,012.68 92.61 3814 5,892.00 5,752.00 7,688.82 3,522.12 5,956,668.46 491,852.88 5.74 8,456.28 MWD OWSG (5) 11,042.46 90.25 3616 5,891 26 5,751.26 7,712.55 3,540.10 5,956,692 16 491,870.89 1034 8,485.24 MWD OWSG (5) 11,081.14 89.88 32.00 5,891.21 5,751.21 7,744.58 3,561.77 5,956,724.15 491,892.61 10.80 8,523.29 MWD OWSG (5) 11,105.06 90.74 24.09 5,891.08 5,751.08 7,765.67 3,573.00 5,956,745.22 491,903.87 33.26 8,547 12 MWD OWSG (5) 11,132.05 90.71 30.27 5,890.74 5,750.74 7,789.67 3,585.32 5,956,769.20 491,916.23 22.90 8,574,05 MWD OWSG (5) 11,162.22 88.65 25.24 5,890.91 5,750.91 7,816.36 3,599.37 5,956,795.86 491,930.32 18.02 8,604.14 MWD OWSG (5) ,. 11,192.11 89.29 22.89 5,891.45 5,751.45 7,843.64 3,611.55 5,956,823.13 491,942.54 8.15 8,634.02 MWD OWSG (5) - 11.222.57 92.64 24.70 5,890.93 5,750.93 7,871.50 3,623.84 5,956,850.97 491,954.87 12.50 8,664,47 MWD OWSG (5) 11,253.68 88.22 26.33 5,890.70 5,750.70 7,899.57 3,637.24 5,956,879.01 491,968.31 1514 8,695.55 MWD OWSG (5) 11,284.28 88.65 28.10 5,891,54 5,751.54 7,926.77 3,651 23 5.956,906.19 491,982.34 5,95 8,726.09 MWD OWSG (5) 11,314.43 85.94 28.47 5,892.96 5,752.96 7,953.29 3,665.49 5,956,932.68 491,99665 9.07 8,75611 MWD OWSG (5) 11,344.46 89.26 29.68 5,894.22 5,754.22 7,979.51 3,680.07 5,956,958.87 492,011.27 11 77 8,785.98 MWD OWSG (5) 11,374.35 93.78 2944 5,893.42 5,753.42 8,005.49 3,694.81 5,956,984.83 492,026.04 15.14 8,815.70 MWD OWSG (5) 11,405.11 92.27 27.29 5,891.80 5,751.80 8,032.52 3,709.40 5,957,011.83 492,040.67 8.53 8,846.32 MWD OWSG (5) 11,434.56 93.02 26.89 5,890.44 5,750.44 8,058.71 3,722.80 5,957,038.00 492,054.11 2.89 8,875.69 MWD OWSG (5) 11,463.21 89.85 25.75 5,889.72 5,749.72 8,084.38 3173550 5,957,063.65 492,066.84 11.76 8,904.29 MWD OWSG (5) 11,494.78 88.62 23.55 5,89015 5.750.15 8,113.07 3,748.66 5,957,092.31 492,080.05 7.98 8,935.86 MWD OWSG (5) 11,523.52 84.99 23.52 5,891 75 5,751.75 8,139.37 3,760.12 5,957,118.59 492,091.55 1263 8,964.55 MWD OWSG (5) = 11,553.65 86.74 2071. 5,893.92 5,753.92 8,167.21 3,771.43 5,957,146.41 492,102.90 1097 8,994.58 MWD OWSG (5) - 11,592.26 93.07 21.65 5,893.98 5,753.98 8,203.19 3,785.37 5,957,182.37 492,116.90 16.57 9,033.13 MWD OWSG (5) 11,613.38 90.34 21.14 5,893.36 5,753.36 8,22284 3.793 07 5.957202.01 492,124 63 13.15 9,054.22 MWD OWSG (5) 12/28/2019 11:14:08AM Page 4 COMPASS 5000.14 Build 85H ConoeoPhillips C o n oco P h I l l I ps Definitive Survey Report Baker Hughes Company: ConocoPhillips Alaska Inc-Kuparuk Local Co-ordinate Reference: Well 2M-21 Project: Kuparuk River Unit TVD Reference: 2M-21 @ 140.00usft Site: Kuparuk 2M Pad MD Reference: 2M-21 @ 140.00usft Well: 2M-21 North Reference: True Wellbore: 2M-21 Lt -01 Survey Calculation Method: Minimum Curvature Design: 2M-211-1-01 Database: EDT 14 Alaska Production Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/ -S +E/ -W Northing East) DLS Section (us8) (°) 1°) (ustt) (usft) (usft) (unit) (°1100-) Survey Tool Name Annotation (ft) Ift Intl 11,654.14 85.63 20.72 5,89479 5,754.79 8,26088 3,80762 5,957,240.02 492,139.23 1160 9,094.89 MWD OWSG (5) 11,687.66 87.57 25.31 5,896.78 5,756.78 8,291.67 3,820.70 5,957,270.78 492,152.36 14.84 9,128.34 MWD OWSG (5) 11,71411 87.29 28.18 5,897.96 5,757.96 8,315.26 3,832.59 5,957,294.36 492,164.29 10.89 9,154.73 MWD OWSG (5) 11,744.35 88.53 32.94 5,899.07 5,759.07 8,341.28 3,847.95 5,957,320.34 492,179.68 16.26 9,184.73 MWD OWSG (5) 11,774.00 90.92 30.73 5,899.21 5,759.21 8,366.46 3,863.59 5.957,345.50 492,195.36 10.98 9,214.08 MWD OWSG (5) 11,805.94 89.91 26.72 5,898.98 5,758.98 8,394.46 3,878.93 5,957,373.48 492,210.75 12.95 9,245.89 MWD OWSG (5) 11,834.15 86.77 22.27 5,899-80 5,759,80 8,420.11 3,890.62 5,957,399.11 492,222.47 19.30 9,274.08 MWD OWSG (5) 11,864.03 88.16 17.56 5,901.12 5,761.12 8,448.17 3,900.78 5,957,427.15 492,232.68 16.42 9,303.85 MWD OWSG (5) 11,893.50 88.16 17.14 5,902.06 5,762.06 8,476.29 3,909.57 5,957,455.24 492,241.51 1.42 9,333.12 MWD OWSG (5) 11,923.92 88.19 11 47 5,903.03 5,763.03 8,505.74 3,917.08 5,957,484.68 492,249.06 18.63 9,36310 MWD OWSG (5) 11,954.02 90.15 8.37 5,903.47 5,763.47 8,535.38 3,922.26 5,957,514.31 492,254.29 12.18 9,392.31 MWD OWSG (5) 11,984.75 87,45 4.09 5,904.11 5,76411 8,565,91 3,925.59 5,957,544.83 492,257.67 16.46 9,421.59 MWD OWSG (5) 12,013.91 86.99 1.66 5,905.53 5,765.53 8,595.00 3,92206 5,957,573.92 492,259.18 8.47 9,448,80 MWD OWSG (5) 12,046.59 88.19 4.14 5,906.90 5,766.90 8,627,60 3,92871 5,957,606.52 492,260.88 8.42 9,479.30 MWD OWSG (5) 12,075.40 87.94 5.74 5,907.88 5,767.88 8,656.29 3,931 19 5,957,635.19 492,263.40 5.62 9,506.55 MWD OWSG (5) 12,103.82 87.64 6.53 5,908.97 5,768.97 8,684.52 3,934.22 5,957,663.42 492,266.48 2.97 9,533.61 MWD OWSG (5) 12,139.34 88.80 955 5,910.08 5,770.08 8,719,67 3,93919 5,957,698.56 492,271 50 910 9,567.78 MWD OWSG (5) 12,168.84 89.97 13.13 5,91039 5,770.39 8,748.59 3,944.99 5,957,727.47 492,277.35 12.77 9,596.57 MWD OWSG (5) 12,200.26 87.91 14.81 5,910.97 5,770.97 8,779.07 3,952.57 5,957,757.93 492,284.97 8.46 9,627,53 MWD OWSG (5) 12,229.69 87.42 18.94 5,912.17 5,77217 8,807.21 3,961,10 5,957,786.05 492,293.55 14.12 9,656.71 MWD OWSG (5) 12,258.78 84.65 20.42 5,914.18 5,774.18 8,834.53 3,970.87 5,957,813.36 492,303.36 10.79 9,685.65 MWD OWSG (5) 12,288.93 89.63 21 94 5,915.69 5,775.69 8,862.60 3,981.75 5,957,841.40 492,314.28 17.27 9,71572 MWD OWSG (5) - 12,318.86 92.12 21.96 5,915.23 5,775.23 8,890.35 3,992.94 5,957,869.14 492,325.51 8.32 9,745.63 MWD OWSG (5) 12,348.54 91.17 23.60 5,914.38 5,774.38 8,91770 4,004.42 5,957,896.47 492,337.04 6.38 9,775.29 MWD OWSG (5) 12,379.08 90.95 22.51 5,913.81 5,773.81 8,945.80 4,016.38 5,957,924.54 492,349.04 3.64 9,805.83 MWD OWSG (5) - 12,408.76 89.69 21 76 5,913.65 5,773.65 8,973.29 4,027,56 5,957,952.02 492,360.26 4.94 9,835.49 MWD OWSG (5) ` 12,436.88. 92.00 21.22 5,913.23 5,773.23 8,999.45 4,03786 5,957,978.16 492,370.60 8.44 9,863.59 MWD OWSG (5) 12,464.97 93.63 2040. 5,911.85 5,771.85 9,025.68 4,047.83 5,958,004.36 492,380.61 6.49 9,891.60 MWD OWSG (5) 12,494.06 89.57 16.67 5,911.04 5,771.04 9,053.24 4,057.07 5,958,031.91 492,389.89 18.95 9,920.55 MWD OWSG (5) 12,524.29 90.43 15.49 5,911.04 5,771.04 9,082.28 4,065.44 5,958,060.94 492,398.31 4.83 9,950.50 MWD OWSG (5) 12,55435 92.46 1411 5,910.28 5.770.28 9,11133 4,07312 5,958,089.97 492,406.03 816 9,980.18 MWD OWSG (5) - 12128/2019 11:14:08AM Page 5 COMPASS 5000.14 Build 85H ConocoPhillips B.k., ConocoPhillips Definitive Survey Report Company: ConocoPhillips Alaska Inc-Kuparuk Local Co-ordinate Reference: Well 2M-21 Project: Kuparuk River Unit TVD Reference: 2M-21 @ 140.00usft Site: Kuparuk 2M Pad MD Reference: 2M-21 @ 140.00usft Well: 2M-21 North Reference: True Wellbore: 2M -21L1-01 Survey Calculation Method: Minimum Curvature Design: 2M-211-1-01 Database: EDT 14 Alaska Production Survey Map Map Vertical MD Inc Azi TVD TVDSS +Nl-S +EI -W Northing Easting DLS Section (usft) (°) (°) (usft) (usft) (usft) (usft) (°I100') Survey Tool Name Annotation (ft) (ft) (ft) 12,584.71 95.38 13.61 5,908.21 5,768.21 9,140.74 4.08037 5,958,119.36 492,413 33 976 10,010.01 MWD OWSG (5) 12,614.93 97.95 12.52 5,904.70 5,764.70 9,169.97 4,087.16 5,958,148.59 492,420.16 9.23 10.039,50 MWD OWSG (5) 12,644.92 100.40 10.88 5,89992 5,759.92 9,198.96 4,09316 5,958,177.56 492,426.21 9.79 10,068,45 MWD OWSG (5) 12,674.55 96.85 13.34 5,895.48 5,755.48 9,227.60 4,099.31 5,958,206.18 492,432.40 14.52 10,097.13 MWD OWSG (5) 12,709.34 93.80 14.48 5,892.25 5,752.25 9,261.22 4,107.64 5,958,239.79 492,440.78 9.35 10,131.25 MWD OWSG (5) 12,739.73 91.97 13.53 5,890.72 5,750.72 9,290.66 4.114.98 5,958,269.22 492,448.17 6.78 10,161 16 MWD OWSG (5) . 12,774.48 91.26 15.59 5,88974 5,749.74 9,324.28 4,123.71 5,958,302.82 492,456.95 6.27 10,195.45 MWD OWSG (5) 12,804.21 91.35 17.81 5,889.06 5,74906 9,352.75 4,132.25 5,958,331.27 492.465.53 747 10,224.94 MWD OWSG (5) 12.839 19 91.05 19.27 5,888.33 5,748.33 9,385.91 4,143.37 5,958,364.41 492,476,70 4.26 10,259.76 MWD OWSG (5) 12,888.57 89.97 23.41 5,887-89 5,747.89 9,431.89 4,161.34 5,958,410.36 492,494.74 8.66 10,309.08 MWD OWSG (5) 12,916.80 89.05 26.06 5,88813 5,748.13 9,457,52 4,17315 5,958,435.97 492,506.59 9.94 10,337.31 MWD OWSG (5) 12,944.53 90.06 2732 5,888.35 5,748.35 9,48230 4,185.60 5,958,460.73 492,519.08 5.82 10,365.00 MWD OWSG (5) 12,974 75 90.18 28.64 5,888.28 5,748.28 9,508.98 4,199 78 5,958,487.39 492,533.30 4.39 10,395.14 MWD OWSG (5) 13,005.03 90.71 31.28 5,888.05 5,748.05 91535.21 4,214.90 5,958,513.59 492,548.45 8.89 10,425.24 MWD OWSG (5) 13,035.42 90.68 33.58 5,887.68 5,747.68 9,560.86 4,231.20 5,958,539.21 492,564.79 7.57 10,455.28 MWD OWSG (5) 13,083.49 89.57 36.98 5,887.57 5,747.57 9,600.10 4,258.96 5,958,578.40 492,592.60 7.44 10,502.38 MWD OWSG (5) 13,119.43 89.94 39.84 5,88773 5,74773 9,628.26 4,281.28 5,958,606.52 492,614 97 8.02 10,537.15 MWD OWSG (5) 13,149 34 88.37 40.28 5,888.17 5,748.17 9,651 14 4,300.53 5,958,629.38 492,634.25 5.45 10,565.86 MWD OWSG (5) 13,179.87 86.68 39.06 5,889.49 5,749.49 9,674.62 4,320.00 5,958,652.82 492,653.76 6.82 10,595.20 MWD OWSG (5) 13,208.51 88.59 38.37 5,890.67 5,750.67 9,696.95 4,337.90 5,958,675.12 492,671.69 7.09 10,622.84 MWD OWSG (5) 13,241 10 88.65 35.92 5,891 45 5,751.45 9,722.92 4,357.57 5,958,701.05 492,691.40 7.52 10,654.54 MWD OWSG (5) 13,272.85 90.62 33.79 5,891.66 5,751.66 9,748.97 4,375.71 5,958,727,07 492,709.58 9.14 10,685.70 MWD OWSG (5) - 13,304.01 91.41 31.81 5,891.10 5,751.10 9,775.15 4,392.59 5,958,753.23 492,726.49 6.84 10,716.47 MWD OWSG (5) 13,334.42 90.83 30.43 5,890.51 5,750.51 9,801.18 4,408.30 5,958,779.23 492,742.25 4.92 10,746.62 MWD OWSG (5) 13,364,55 91.38 28.00 5,889.93 5.749.93 9,827.47 4,423.00 5,958,805.50 492,756.99 8.27 10,776.61 MWD OWSG (5) 13,394.19 91.56 25.70 5,889.17 5,749.17 9,853.91 4,436.38 5,958,831.91 492,770.41 7.78 10,806.19 MWD OWSG (5) 13,419.28 90.28 23.49 5,888.76 5,748.76 9,876.71 4,446.82 5,958,854.70 492,780.88 10.18 10,831.28 MWD OWSG (5) 13,449 36 90.40 21.76 5,888.59 5,748.59 9,904.48 4,458.40 5,958,882 44 492,792.50 5.77 10,861.35 MWD OWSG (5) 13,479.13 91 14 18.91 5,888.19 5,748.19 9,932.39 4,468.74 5,958,910.33 492,802.88 9.89 10,891.06 MWD OWSG (5) 13,504.31 90.12 16.51 5,887.91 5,747.91 9,956.37 4,476.40 5,958,934,30 492,810.58 10.36 10,916.09 MWD OWSG (5) 13.538 83 90.89 1423 5,887.60 5,747.60 9,989.65 4.485.55 5,958,967 56 492,819 78 6.97 10,950.24 MWD OWSG (5) 12/2812019 11:14:08AM Page 6 COMPASS 5000.14 Build 85H ConocoPhillips Baker Hughes_ ConocoPhillips Definitive Survey Report Company: ConocoPhillips Alaska Inc Kuparuk Project: Kuparuk River Unit Site: Kuparuk 2M Pad Well: 2M-21 Wellbore: 2M-21 Ll -01 Design: 2M-21 L1-01 Survey MD Inc Azi TVD TVDSS (usft) (1) (1) (usft) (usft) 13.570.29 91 38 1258 5,88698 5,74698 13,603.93 9328 1201 5.885.61 5,74561 13,634% 9499 900 5,88338 5.743.38 13.664 97 95.16 757 5,880 72 5,74072 13,694.69 9440 484 5.878.24 5,73824 13,72726 94.64 264 5.875.68 5,735.68 13,753 27 95.66 0.50 587334 5,73334 13.791 00 9566 050 5.869.62 5.72962 Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Database: Well 2M-21 2M-21 @ 140 00usft 2M-21 @ 140 00usft True Minimum Curvature EDT 14 Alaska Production Map Map +N/ -S +E/ -W Northing (usft) (usft) (ft) 10.020.25 449284 5,958 998 15 10,053.09 4,50000 5,959.03097 10,08351 4,50564 5.959,061 38 10,113 09 4,50995 5.959, 090 95 10,142 53 4.513 15 5.959,120 39 10.174 93 4.51526 5.959,152 78 10,200 82 4.51597 5,959.178 67 10.238 37 4,51630 5,959.216 21 Well 2M-21 2M-21 @ 140 00usft 2M-21 @ 140 00usft True Minimum Curvature EDT 14 Alaska Production Map Vertical Easting DLS Section Survey Tool Name (ft) (°1100') (ft) 492.827 11 547 10,981 17 MWD OWSG (5) 492,834 32 590 11.014 11 MWD OWSG (5) 492.840.01 11 13 1104423 MWD OWSG (5) 492,844 36 478 11.073.03 MWD OWSG (5) 492,84761 950 11,10126 MWD OWSG (5) 492,849 78 677 11.131 76 MWD OWSG (5) 492.850 53 908 11 15574 MWD OWSG (5) 492,850 91 000 11.190 23 PROJECTED to TD Annotation 12/28/2019 11.14:08AM Page 7 COMPASS 5000.14 Build 85H THE STATE `'ALASKA GOVERNOR MIKE DUNLEAVY James Ohlinger Staff CTD Engineer ConocoPhillips Alaska, Inc. PO Box 100360 Anchorage, AK 99510 Alaska Oil and Gas Conservation Commission Re: Kuparuk River Field, Kuparuk River Oil Pool, KRU 2M-21 Ll -01 ConocoPhillips Alaska, Inc. Permit to Drill Number: 219-139 Surface Location: 114' FSL, 479' FWL, SEC. 27, TI IN, R8E, UM Bottomhole Location: 481' FSL, 83' FEL, SEC. 15, TI IN, R8E, UM Dear Mr. Ohlinger: 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 www.aogcc.alaska.gov Enclosed is the approved application for the permit to redrill the above referenced development well. The permit is for a new wellbore segment of existing well Permit No. 191-129, API No. 50-103-20156- 00-00. Production should continue to be reported as a function of the original API number stated above. Per Statute AS 31.05.030(d)(2)(B) and Regulation 20 AAC 25.071, composite curves for well logs run must be submitted to the AOGCC within 90 days after completion, suspension or abandonment of this well. This permit to drill does not exempt you from obtaining additional permits or an approval required by law from other governmental agencies and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the AOGCC reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the AOGCC specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or an AOGCC order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. Sincerely, I" W re M. rice Chair DATED thOl day of October, 2019. STATE OF ALASKA AL, .A OIL AND GAS CONSERVATION COMM! ON PERMIT TO DRILL 20 AAC 25.005 1 a. Type of Work: 1 b. Proposed Well Class: Exploratory - Gas ❑ Service - WAG ❑ Service - Disp ❑ 1 c. Specify if well is proposed for: Drill ❑ Lateral ❑Q Stratigraphic Test ❑ Development -Oil ❑� • Service - Winj ❑ Single Zone ❑' • Coalbed Gas ❑ Gas Hydrates ❑ Redrill ❑ Reentry ❑ Exploratory - Oil ❑ Development -Gas ❑ Service - Supply ❑ Multiple Zone ❑ Geothermal ❑ Shale Gas ❑ 2. Operator Name: 5. Bond: Blanket ❑✓ - Single Well ❑ 11. Well Name and Number: ConocoPhillips Alaska, Inc. Bond No. 5952180 • KRU 2M-21 L1-01 , 3. Address: 6. Proposed Depth: 12. Field/Pool(s): P.O. Box 100360 Anchorage, AK 99510-0360 MD: 14,500' TVD: 5749' Kuparuk River Pool / Kuparuk River Oil Pool 4a. Location of Well (Governmental Section): 7. Property Designation: ZS7. i, Surface: 114' FSL, 479' FWL, Sec. 27, T11N, R8E, UM • Ate -255440 libl- ;_-55 Top of Productive Horizon: 8. DNR Approval Number: I 13. Approximate Spud Date: 1989' FSL, 1749' FEL, Sec. 22, T11N, R8E, UM LONS 84-132 /L' �/' 10/17/2019 9. Acres in Property: 14. Distance to Nearest Propertv: Total Depth: 481' FSL, 83' FEL, Sec. 15, T11N, R8E, UM 2560 9650' 4b. Location of Well (State Base Plane Coordinates - NAD 27): 10. KB Elevation above MSL (ft): 140' 15. Distance to Nearest Well Open Surface: x- 488319 y- 5948985 • Zone- 4 GL / BF Elevation above MSL (ft): 105' to Same Pool: 489' (2A-19) " 16. Deviated wells: Kickoff depth: 10,300 feet 17. Maximum Potential Pressures in psig (see 20 AAC 25.035) Maximum Hole Angle: 93 degrees Downhole: 4113 • Surface: 3523 18. Casing Program: Specifications Top - Setting Depth - Bottom Cement Quantity, c.f. or sacks Hole Casing Weight Grade Coupling Length MD TVD MD TVD (including stage data) 3" 2-3/8" 4.7# L-80 ST -L 4490' 10,010' 5707' 14,500'. 5757' 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): 10,599 6119 N/A 10,599 6119 N/A Casing Length Size Cement Volume MD TVD Conductor 84' 16" 220 Sx ASII 123' 123' Surface 3877' 9-5/8" 543 Sx PF E, 660 Sx Class G 3926' 2825' 110 Sx PF C Top Job Tie -Back String 1753' 7" 542 sx Class G 1797' 1703' Production 10,555' 7" 280 Sx Class G 10,599' 6119' Perforation Depth MD (ft): 10,109' - 10,150' Perforation Depth TVD (ft): 5892' - 5911' 10,170'- 10,292' 5921'- 5977' Hydraulic Fracture planned? ❑ 0 20. Attachments: Property Plat ❑ BOP Sketch Drilling Program Time v. Depth Plot H �✓ Shallow Hazard Analysis Diverter Sketch Seabed Report Drilling Fluid Program 20 AAC 25.050 requirements 21. Verbal Approval: Commission Representative: Date 22. 1 hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Contact Name: Shane Germann Authorized Name: James Ohlinger Contact Email: Shane. Germann COP.com Authorized Title: Staff CTD Engineer Contact Phone: 907-263-4597 Authorized Signature: Date: I0 1p Commission Use Only Permit to Drill �� API Number: ��— Permit Approval See cover letter for other Number: �%L < 50 /� %� '�L ( ��� �t>�' C Date: O l� requirements. Conditions of approval : If box is checked, well may not be used to explore for, test, or produce coalbed methane, gas hydrates, or gas contained in shales: Other:L90 P fGs /"D 67 620 5 t ` Samples req'd: Yes ElNo❑ Mud log req'd: Yes E] No [� l O ;Z,570 L) HzS measures: Yes 0 No E] Directional svy req'd: Yes No E] �h nvl a r P/"CVId� Spacifig eXce tiori req'd: Yes ❑ No ET Inclination -only svy req'd: Yes E] Noy /T l�� %—/\(� Yl C�' f D ,2 ,2 Jc- (' L S b Post initial injection MIT req'd: Yes ❑ No R' /59 1 a)-frd fio cell o%✓ the- /C/'ck- 0 FF�v o � T �-c L apo/�,f aln� �hc Pe4rrh� l a frp-4l � APPROVED BY Approved by: COMMISSIONER THE COMMISSION Date: q V%Z /O 1 7 / `�///'� Submit orm and Form 10-4 se 2017 d Tghis permit i valicj farn -.},, I, 1 i,!i; �\ ILJJ R G+N-Attf approval per 20 AAC 25.005(8) Attachments in Duplicate �1 ilL /r•.,/�//- ConocoPhillips Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 October 9, 2019 Commissioner - State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Dear Commissioner: ConocoPhillips Alaska, Inc. hereby submits applications for permits to drill two laterals out of the KRU 2M-21 (PTD# 191-129) using the coiled tubing drilling rig, Nabors CDR3-AC. CTD operations are scheduled to begin in late October 2019. The objective will be to drill two laterals, KRU 2M - 21L1 and 2M-21 1-1-01, 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 permit to drill applications are the following documents: — Permit to Drill Application Forms (10-401) for 2M-21 L1 and 2M-21 L1-01 — Detailed Summary of Operations — Directional Plans for 2M-21 L1 and 2M-21 L1-01 — Current Wellbore Schematic — Proposed CTD Schematic If you have any questions or require additional information, please contact me at 907-263-4597. Sincerely, Shane Germann Coiled Tubing Drilling Engineer ConocoPhillips Alaska Kuparuk CTD Laterals 2M-21 L1 & 2M-21 L1-01 Application for Permit to Drill Document 1. Well Name and Classification........................................................................................................ 2 (Requirements of 20 AAC 25.005(1) and 20 AAC 25.005(b))................................................................................................................... 2 2. Location Summary.......................................................................................................................... 2 (Requirements of 20 AAC 25.005(c)(2)).................................................................................................................................................. 2 3. Blowout Prevention Equipment Information................................................................................. 2 (Requirements of 20 AAC 25.005(c)(3))................................................................................................................................................. 2 4. Drilling Hazards Information and Reservoir Pressure.................................................................. 2 (Requirements of 20 AAC 25.005(c)(4))................................................................................................................................................. 2 5. Procedure for Conducting Formation Integrity tests................................................................... 2 (Requirements of 20 AAC 25.005(c)(5)).................................................................................................................................................. 2 6. Casing and Cementing Program.................................................................................................... 3 (Requirements of 20 AAC 25.005(c)(6)).................................................................................................................................................. 3 7. Diverter System Information.......................................................................................................... 3 (Requirements of 20 AAC 25.005(c)(7)).................................................................................................................................................. 3 8. Drilling Fluids Program.................................................................................................................. 3 (Requirements of 20 AAC 25.005(c)(8)).................................................................................................................................................. 3 9. Abnormally Pressured Formation Information............................................................................. 4 (Requirements of 20 AAC 25.005(c)(9)).. . ........................ ....... .......... ............... ...... ............................................................................ 4 10. Seismic Analysis............................................................................................................................. 4 (Requirements of 20 AAC 25.005(c)(10))................................................................................................................................................ 4 11. Seabed Condition Analysis............................................................................................................ 4 (Requirements of 20 AAC 25.005(c)(11))................................................................................................................................................4 12. Evidence of Bonding...................................................................................................................... 4 (Requirements of 20 AAC 25.005(c)(12))................................................................................................................................................4 13. Proposed Drilling Program............................................................................................................. 4 (Requirements of 20 AAC 25.005(c)(13))................................................................................................................................................ 4 Summaryof Operations...................................................................................................................................................4 LinerRunning...................................................................................................................................................................5 14. Disposal of Drilling Mud and Cuttings.......................................................................................... 6 (Requirements of 20 AAC 25.005(c)(14))................................................................................................................................................ 6 15. Directional Plans for Intentionally Deviated Wells....................................................................... 6 (Requirements of 20 AAC 25.050(b))...................................................................................................................................................... 6 16. Attachments.................................................................................................................................... 6 Attachment 1: Directional Plans for 2M-21 L1&2M-21 L1-01 laterals..............................................................................6 Attachment 2: Current Well Schematic for 2M-21...........................................................................................................6 Attachment 3: Proposed Well Schematic for 2M-21 L1 & 2M-21 L1-01 laterals................................................................6 Page 1 of 6 October 9, 2019 PTD Application: 21VI-21 L1 & 21VI-21 L1-01 1. Well Name and Classification (Requirements of 20 AAC 25.005(f) and 20 AAC 25.005(b)) The proposed laterals described in this document are 2M -21L1 & 2M-211-1-01. All laterals will be classified as "Development"wells. 2. Location Summary (Requirements of 20 AAC 25.005(c)(2)) These laterals will target the C sand package in the Kuparuk reservoir. See attached 10-401 form for surface and subsurface coordinates of the 21VI-21 L1 & 2M-21 L1-01. , 3. Blowout Prevention Equipment Information (Requirements of 20 AAC 25.005 (c)(3)) Please reference blowout prevention (BOP) schematics on file with the Commission for Nabors CDR3-AC. BOP equipment is as required per 20 AAC 25.036 for thru-tubing drilling operations. - Pipe rams, blind rams and the CT pack off will be pressure tested to 250 psi and to 4,000 psi. Using the maximum formation pressure in the area of 4113 psi in 2A-06 (i.e. 12.6 ppg EMW), the maximum potential surface pressure in 2M-21, assuming a gas gradient of 0.1 psi/ft, would be 3523 psi. See the "Drilling Hazards Information and Reservoir Pressure" section for more details. - The annular preventer will be tested to 250 psi and 2,500 psi. 4. Drilling Hazards Information and Reservoir Pressure (Requirements of 20 AAC 25.005 (c)(4)) Reservoir Pressure and Maximum Downhole Pressure (Requirements of 20 AAC 25.005 (c)(4)(a)) The formation pressure in KRU 2M-21 was measured at the datum to be 2869 psi (8.83 ppg EMW) on 7/8/2018. The maximum downhole pressure in the 2M-21 vicinity is to the northeast in the 2A-06. Pressure was measured to be 4113 psi, at the datum, (12.6 ppg EMW) in June of 2004. Potential Gas Zones (Requirements of 20 AAC 25.005 (c)(4)(b)) I --- The offset injection wells to 2M-21 have injected gas, so there is a possibility of encountering free gas while drilling the 2M-21 laterals. If gas is detected in the returns the contaminated mud can be diverted to a storage tank away from the rig. Potential Causes of Hole Problems (Requirements of 20 AAC 25.005 (c)(4)(c)) The major expected risk of hole problems in the 2M-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 2M-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 6 October 9, 2019 PTD Application: 21VI-21 L1 & 21VI-21 L1-01 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 21VI-21 L1 10,300' 15,500' 5769' 5835' 2-3/8", 4.7#, L-80, ST -L slotted liner; Surface 123' 1640 670 Surface aluminum billet on to 21VI-21 L1-01 10,010' 14,500' 5707' 5757' 2-3/8", 4.7#, L-80, ST -L slotted liner; 2825' 3520 2020 Production 7" deployment sleeve on to Existing Casing/Liner Information Category OD Weight f Grade Connection Top MD Btm MD Top TVD Btm TVD Burst psi Collapse psi Conductor 16" 62.5 H-40 Welded Surface 123' Surface 123' 1640 670 Surface 9-5/8" 36.0 J-55 BTC Surface 3926' Surface 2825' 3520 2020 Production 7" 26.0 J-55 BTC 1795' 10,599'. 1701' 6119' 4980 4320 Tie -Back 7" 26.0 L-80 H d563 Surface 1797' Surface 1703' 7240 5410 Tubing 3-1/2" 9.3 L-80 EUE-8rd Surface 10,029' Surface 5856' 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 PowerVis milling fluid (8.6 ppg) — Drilling operations: Water-based PowerVis mud (8.6 ppg). This mud weight will not hydrostatically overbalance the reservoir pressure, overbalanced conditions will be maintained using MPD practices described below. — Completion operations: The well will be loaded with 11.8 ppg NaCl / NaBr completion fluid in order to provide formation over -balance and well bore stability while running completions. Managed Pressure Drilling Practice Managed pressure drilling (MPD) techniques will be employed to maintain a constant overbalanced pressure on the open hole formation and promote wellbore stability throughout the coiled tubing drilling (CTD) process. Mud weight is not, in many cases, the primary well control barrier. This is satisfied with the 5,000 psi rated coiled tubing pack off and MPD choke. BOPE equipment provides the secondary well control as detailed in section 3 "Blowout Prevention Equipment Information". In the 2M-21 laterals we will target a constant BHP of 11.8 ppg EMW at the window. The constant BHP target will be adjusted through choke pressure and/or mud weight increases to maintain overbalanced conditions if increased reservoir pressure is encountered. Additional choke pressure or increased mud weight may also be employed for improved borehole stability. Any change of circulating friction pressure due to change in pump rates or change in depth of circulation will be offset with back pressure adjustments. Page 3 of 6 October 9, 2019 PTD Application: 21VI-21 L1 & 21VI-21 L1-01 Pressure at the 21VI-21 Window (10,120' MD, 5898' 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 KRU well 21VI-21 is a Kuparuk A/C -Sand producer equipped with 3-1/2" tubing and 7" production casing. The CTD sidetrack will utilize two laterals to target the C -sands to the north and south of 2M-21. The laterals will increase C -sand resource recovery and throughput. Prior to CTD rig up, E -Line will set a mechanical whipstock (High Expansion Wedge) inside the 7" casing at the planned kick off point of 10,120' MD. The 21VI-21 L1 lateral will exit through the 7" casing at 10,120' MD and drill to a planned TD at 15,500' MD, targeting the C sand to the south. The lateral will be completed with 2-3/8" slotted liner from TD up to 10,300' MD with an aluminum billet for kicking off. The 21VI-21 L1-01 lateral will kick off at 10,300' MD and drill to a planned TD of 14,500' MD targeting the C sand to the north. It will be completed with 2-3/8" slotted liner from TD up into the 3-1/2" tubing at 10,010' MD with a deployment sleeve. CTD Drill and Complete 2M-21 Laterals: Pre -CTD Work 1. RU Slickline: Dummy whipstock drift, C/O GLV's 2. RU E -Line: Caliper 3. RU CTU: Mill out D -Nipple to 2.80" ID, cleanout if fill is encountered. 4. RU E -Line: Set top of high expansion wedge at 10,120' MD 5. Prep site for Nabors CDR3-AC. Page 4 of 6 October 9, 2019 Pumps On 1.9 bpm) Pumps Off C -sand Formation Pressure 8.8 2699 psi 2699 psi Mud Hydrostatic 8.6 2638 psi 2638psi' Annular friction i.e. ECD, 0.080psi/ft) 810 psi 0 psi Mud + ECD Combined no chokepressure) 3448 psi overbalanced —749psi) 2638 psi underbalanced —61psi) Target BHP at Window 11.8 3619 psi 3619psi' Choke Pressure Required to Maintain Target BHP 0 psi 981 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 KRU well 21VI-21 is a Kuparuk A/C -Sand producer equipped with 3-1/2" tubing and 7" production casing. The CTD sidetrack will utilize two laterals to target the C -sands to the north and south of 2M-21. The laterals will increase C -sand resource recovery and throughput. Prior to CTD rig up, E -Line will set a mechanical whipstock (High Expansion Wedge) inside the 7" casing at the planned kick off point of 10,120' MD. The 21VI-21 L1 lateral will exit through the 7" casing at 10,120' MD and drill to a planned TD at 15,500' MD, targeting the C sand to the south. The lateral will be completed with 2-3/8" slotted liner from TD up to 10,300' MD with an aluminum billet for kicking off. The 21VI-21 L1-01 lateral will kick off at 10,300' MD and drill to a planned TD of 14,500' MD targeting the C sand to the north. It will be completed with 2-3/8" slotted liner from TD up into the 3-1/2" tubing at 10,010' MD with a deployment sleeve. CTD Drill and Complete 2M-21 Laterals: Pre -CTD Work 1. RU Slickline: Dummy whipstock drift, C/O GLV's 2. RU E -Line: Caliper 3. RU CTU: Mill out D -Nipple to 2.80" ID, cleanout if fill is encountered. 4. RU E -Line: Set top of high expansion wedge at 10,120' MD 5. Prep site for Nabors CDR3-AC. Page 4 of 6 October 9, 2019 PTD Application: 2M-21 L1 & 2M-211_1-01 Rio Work 1. MIRU Nabors CDR3-AC rig using 2" coil tubing. NU 7-1/16" BOPE, test. 2. 2M-21 L1 Lateral (C sand - South) a. Mill 2.80" window at 10,120' MD. b. Drill 3" bi-center lateral to TD of 15,500' MD. c. Run 2-3/8" slotted liner with an aluminum billet from TD up to 10,300' MD. 3. 2M-21 L1-01 Lateral (C sand - North) a. Kick off of the aluminum billet at 10,300' MD. b. Drill 3" bi-center lateral to TD of 14,500' MD. c. Run 2%" slotted liner with deployment sleeve from TD up to 10,010' MD. 4. Obtain SBHP, freeze protect, ND BOPE, and RDMO Nabors CRD3-AC. Post -Rio Work 1. Return to production Pressure Deployment of BHA The planned bottom hole assemblies (BHAs) are too long to simply isolate by closing the double swab valves on the Christmas tree. MPD operations require the BHA to be lubricated under pressure using a system of double swab valves on the Christmas tree, double deployment rams, double check valves and double ball valves in the BHA, and a slick -line lubricator can be used. This pressure control equipment listed ensures there are always two barriers to reservoir pressure, both internal and external to the BHA, during the deployment process. During BHA deployment, the following steps are observed. - Initially the double swab valves on the tree are closed to isolate reservoir pressure. The lubricator is installed on the BOP riser with the BHA inside the lubricator. - Pressure is applied to the lubricator to equalize across the swab valves. The swab valves are opened and the BHA is lowered in place via slick -line. - When the BHA is spaced out properly, the double deployment rams are closed on the BHA to isolate reservoir pressure via the annulus. A closed set of double ball valves and double check valves isolate reservoir pressure internal to the BHA. Slips on the double deployment rams prevent the BHA from moving when differential pressure is applied. The lubricator is removed once pressure is bled off above the deployment rams. - The coiled tubing is made up to the BHA with the double ball valves plus the double check valves in the closed position. Pressure is applied to the coiled tubing to equalize internal pressure and then the double ball valves are opened. The injector head is made up to the riser, annular pressure is equalized, and the deployment rams are opened. The BHA and coiled tubing are now ready to run in the hole. During BHA undeployment, the steps listed above are observed, only in reverse. Liner Running - The 2M-21 laterals will be displaced to an overbalancing fluid (11.8 ppg NaCl / NaBr) prior to running liner. See "Drilling Fluids" section for more details. - While running 2-3/8" slotted liner, a joint of 2-3/8" non -slotted tubing will be standing by for emergency deployment. A floor valve is made up onto this joint ahead of time, and the rig crew conducts a deployment drill with this emergency joint on every slotted liner run. The 2-3/8" rams will provide secondary well control while running 2-3/8" liner. Page 5 of 6 October 9, 2019 PTD Application: 2M-21 L1 & 21VI-21 L1-01 14. Disposal of Drilling Mud and Cuttings (Requirements of 20 AAC 25.005(c)(14)) • No annular injection on this well. ' • All solid waste will be transported to the grind and inject facility at DS -4 Prudhoe Bay for disposal. • Incidental fluids generated from drilling operations will be injected in a Kuparuk Class II disposal well (1 R-18 or 1 B disposal facilities) or Prudhoe DS -4 if a Kuparuk facility is unavailable. • All wastes and waste fluids hauled from the pad must be properly documented and manifested. • Contact Kuparuk Environmental Coordinator for questions regarding waste classification. (670-4200). 15. Directional Plans for Intentionally Deviated Wells (Requirements of 20 AAC 25.050(b)) - The Applicant is the only affected owner. - Please see Attachment 1: Directional Plans - Magnetic and inclination surveys will be taken every 30 ft. No gyro will be run. - MWD directional, resistivity, and gamma ray will be run over the entire open hole section. - Distance to Nearest Property Line (measured to KPA boundary at closest point) Lateral Name Distance 21VI-21 L1 12,600' 2M-21 L1-01 9650' - Distance to Nearest Well within Pool Lateral Name Distance Well 21VI-21 L1 946' 2M-18 2M-21 L1-01 489' 2A-19 16.Attachments Attachment 1: Directional Plans for 2M-21 L 1 & 2M-21 L 1-01 laterals Attachment 2: Current Well Schematic for 2M-21 Attachment 3: Proposed Well Schematic for 2M-21 L 1 & 2M-21 L 1-01 laterals Page 6 of 6 October 9, 2019 WeII KRU XX-XX Nabors CDR3-AC: 4-Ram BOP Configuration 2" Datel April 24, 2019 Coiled Tubing and 2-3/8" BHA Quick Test Sub to Ot Top of 7" Otis Distances from top o' Excluding quick -test Top of Annular CL Annular Bottom Annular Flani CL Blind/Shears CL 2" Combi's CL 2-3/8" Combi's CL 2" Combi's CL of Top S Top of Swa CL Swab 1 Flow Tee CL SSV CL Master LDS Ground Tree Size 3 1/8 ne ConocoPhilli s p ConocoPhillips Alaska Inc—Kuparuk Kuparuk River Unit Kuparuk 2M Pad 2M-21 501032015600 2M-211-1-01 Plan: 2M-21 L1-01_wp05 (Draft A) Standard Planning Report 07 October, 2019 BER T' GHES GE company ConocoPhillips BA ER ConocoPhillips Planning Report BAT a GE company Database: EDT 14 Alaska Production Company: ConocoPhillips Alaska Inc-Kuparuk Project: Kuparuk River Unit Site: Kuparuk 2M Pad Well: 2M-21 Wellbore: 2M-21 Li -01 Design: 2M-21 L1-01_wp05 (Draft A) Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Well 2M-21 Mean Sea Level 2M-21 @ 140.00usft True Minimum Curvature Project Kuparuk River Unit, North Slope Alaska, United States Map System: US State Plane 1927 (Exact solution) System Datum: Mean Sea Level Geo Datum: NAD 1927 (NADCON CONUS) - Using Well Reference Point Map Zone: Alaska Zone 04 Using geodetic scale factor Site Kuparuk 2M Pad Site Position: Northing: 5,948,985.89 usft Latitude: 70° 16' 18.578 N From: Map Easting: 487,859.45 usft Longitude: 150° 5'53.484 W Position Uncertainty: 0.00 usft Slot Radius: 0.000 in Grid Convergence: -0.09 ° Well 2M-21 Well Position +N/ -S 0.00 usft Northing: 5,948,985.88 usft Latitude: 70° 16' 18.585 N +E/ -W 0.00 usft Easting: 488,319.18 usft - Longitude: 150° 5'40.098 W Position Uncertainty 0.00 usft Wellhead Elevation: usft Ground Level: 105.30 usft Wellbore 2M-211-1-01 Magnetics Model Name Sample Date Declination Dip Angle Field Strength (1 (°) (nT) BGG M2018 12/1/2019 16.17 80.77 57,384 Design 2M-21L1-01_wp05(Draft A) Audit Notes: Version: Phase: PLAN Tie On Depth: 10,300.00 Vertical Section: Depth From (TVD) +N1 -S +E/ -W Direction (usft) (usft) (usft) (I -105.30 0.00 0.00 20.00 Plan Sections i Measured TVD Below Dogleg Build Turn i Depth Inclination Azimuth System +N/ -S +El -W Rate Rate Rate TFO (usft) (°) (°) (usft) (usft) (usft) (°/100usft) (°/100usft) (°1100usft) (°) Target 10,300.00 89.25 49.04 5,769.20 7,154.62 3,037.66 0.00 0.00 0.00 0.00 10,370.00 93.49 51.49 5,767.53 7,199.34 3,091.46 7.00 6.06 3.50 30.00 10,500.00 90.35 42.95 5,763.17 7,287.50 3,186.72 7.00 -2.42 -6.57 -110.00 10,800.00 90.34 30.95 5,761.34 7,526.81 3,366.71 4.00 0.00 -4.00 -90.00 11,150.00 90.33 44.95 5,759.26 7,802.12 3,581.40 4.00 0.00 4.00 90.00 11,375.00 89.78 29.21 5,759.05 7,981.07 3,716.62 7.00 -0.25 -7.00 -92.00 11,875.00 88.08 9.27 5,768.47 8,450.65 3,880.55 4.00 -0.34 -3.99 -95.00 12,275.00 89.53 25.21 5,776.85 8,831.34 3,998.73 4.00 0.36 3.98 85.00 12,675.00 91.75 9.37 5,772.34 9,212.00 4,117.22 4.00 0.55 -3.96 -82.00 13,125.00 91.66 27.37 5,758.83 9,637.13 4,258.39 4.00 -0.02 4.00 90.00 13,525.00 91.60 11.37 5,747.36 10,013.11 4,390.57 4.00 -0.02 -4.00 -90.00 14,025.00 91.50 31.37 5,733.69 10,476.19 4,571.78 4.00 -0.02 4.00 90.00 14,500.00 83.11 359.13 5,756.59 10,927.39 4,695.30 7.00 -1.77 -6.79 -105.00 1017/2019 1:40:27PM Page 2 COMPASS 5000.14 Build 85H 101' ConocoPhillips BA ER ConocoPhillips Planning Report BAT a GE company Database: EDT 14 Alaska Production Company: ConocoPhillips Alaska Inc_Kuparuk Project: Kuparuk River Unit Site: Kuparuk 2M Pad Well: 2M-21 Wellbore: 2M-21 L1-01 Design: 2M-21 1-1-01_wp05 (Draft A) Planned Survey Vertical Dogleg Toolface Map Measured +E/ -W Section TVD Below Azimuth Depth Inclination Azimuth (usft) System +N/ -S (usft) (°) (°) (usft) (usft) 10,300.00 89.25 49.04 5,769.20 7,154.62 TIP/KOP 7.00 30.00 5,956,179.70 491,421.50 10,370.00 93.49 51.49 5,767.53 7,199.34 Start DLS 7.00 TFO -110.00 7,937.93 7.00 10,400.00 92.77 49.52 5,765.89 7,218.39 10,500.00 90.35 42.95 5,763.17 7,287.50 Start DLS 4.00 TFO -90.00 -90.02 5,956,422.90 491,642.73 10,600.00 90.35 38.95 5,762.55 7,363.01 10,700.00 90.35 34.95 5,761.94 7,442.91 10,800.00 90.34 30.95 5,761.34 7,526.81 Start DLS 4.00 TFO 90.00 491,811.94 3,546.70 8,510.81 10,900.00 90.34 34.95 5,760.74 7,610.71 11,000.00 90.34 38.95 5,760.15 7,690.61 11,100.00 90.34 42.95 5,759.56 7,766.12 11,150.00 90.33 44.95 5,759.26 7,802.12 Start DLS 7.00 TFO -92.00 3,716.62 8,770.91 7.00 11,200.00 90.21 41.45 5,759.03 7,838.56 11,300.00 89.96 34.45 5,758.88 7,917.37 11,375.00 89.78 29.21 5,759.05 7,981.07 Start DLS 4.00 TFO -95.00 4.00 -94.96 5,957,164.36 11,400.00 89.69 28.21 5,759.16 8,002.99 11,500.00 89.34 24.23 5,760.00 8,092.68 11,600.00 89.00 20.24 5,761.45 8,185.22 11,700.00 88.66 16.25 5,763.49 8,280.15 11,800.00 88.33 12.27 5,766.12 8,377.02 11,875.00 88.08 9.27 5,768.47 8,450.65 Start DLS 4.00 TFO 85.00 11,900.00 88.17 10.27 5,769.29 8,475.28 12,000.00 88.53 14.26 5,772.17 8,572.93 12,100.00 88.89 18.24 5,774.43 8,668.89 12,200.00 89.26 22.23 5,776.05 8,762.69 12,275.00 89.53 25.21 5,776.85 8,831.34 Start DLS 4.00 TFO -82.00 12,300.00 89.67 24.22 5,777.02 8,854.05 12,400.00 90.23 20.26 5,777.11 8,946.59 12,500.00 90.79 16.30 5,776.22 9,041.52 12,600.00 91.34 12.34 5,774.36 9,138.38 12,675.00 91.75 9.37 5,772.34 9,212.00 Start DLS 4.00 TFO 90.00 12,700.00 91.75 10.37 5,771.58 9,236.62 12,800.00 91.74 14.37 5,768.53 9,334.24 12,900.00 91.73 18.37 5,765.50 9,430.12 13,000.00 91.70 22.37 5,762.50 9,523.81 13,100.00 91.67 26.37 5,759.56 9,614.84 13,125.00 91.66 27.37 5,758.83 9,637.13 Start DLS 4.00 TFO -90.00 13,200.00 91.66 24.37 5,756.65 9,704.57 13,300.00 91.65 20.37 5,753.76 9,796.99 13,400.00 91.63 16.37 5,750.89 9,891.84 13,500.00 91.61 12.37 5,748.06 9,988.65 13,525.00 91.60 11.37 5,747.36 10,013.11 Start DLS 4.00 TFO 90.00 Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Well 2M-21 Mean Sea Level 2M-21 @ 140.00usft True Minimum Curvature 3,884.79 Vertical Dogleg Toolface Map Map +E/ -W Section Rate Azimuth Northing Easting (usft) (usft) (°/100usft) (°) (usft) (usft) 3,037.66 7,762.09 0.00 0.00 5,956,135.07 491,367.64 3,091.46 7,822.51 7.00 30.00 5,956,179.70 491,421.50 3,114.57 7,848.32 7.00 -110.00 5,956,198.71 491,444.64 3,186.72 7,937.93 7.00 -110.11 5,956,267.70 491,516.88 3,252.24 8,031.30 4.00 -90.00 5,956,343.10 491,582.52 3,312.33 8,126.93 4.00 -90.02 5,956,422.90 491,642.73 3,366.71 8,224.37 4.00 -90.05 5,956,506.71 491,697.23 3,421.08 8,321.81 4.00 90.00 5,956,590.51 491,751.73 3,481.18 8,417.44 4.00 90.02 5,956,670.31 491,811.94 3,546.70 8,510.81 4.00 90.05 5,956,745.72 491,877.57 3,581.40 8,556.51 4.00 90.07 5,956,781.66 491,912.32 3,615.62 8,602.46 7.00 -92.00 5,956,818.04 491,946.60 3,677.08 8,697.53 7.00 -92.02 5,956,896.74 492,008.17 3,716.62 8,770.91 7.00 -92.03 5,956,960.37 492,047.81 3,728.63 8,795.62 4.00 -95.00 5,956,982.28 492,059.85 3,772.80 8,895.01 4.00 -95.00 5,957,071.89 492,104.16 3,810.62 8,994.90 4.00 -94.96 5,957,164.36 492,142.12 3,841.92 9,094.81 4.00 -94.90 5,957,259.24 492,173.57 3,866.54 9,194.26 4.00 -94.82 5,957,356.05 492,198.33 3,880.55 9,268.24 4.00 -94.72 5,957,429.66 492,212.45 3,884.79 9,292.83 4.00 85.00 5,957,454.27 492,216.73 3,906.02 9,391.86 4.00 84.97 5,957,551.89 492,238.11 3,933.99 9,491.60 4.00 84.85 5,957,647.79 492,266.23 3,968.56 9,591.57 4.00 84.76 5,957,741.53 492,300.94 3,998.73 9,666.39 4.00 84.70 5,957,810.13 492,331.21 4,009.18 9,691.31 4.00 -82.00 5,957,832.82 492,341.70 4,047.03 9,791.21 4.00 -81.99 5,957,925.29 492,379.68 4,078.39 9,891.14 4.00 -81.99 5,958,020.16 492,411.19 4,103.11 9,990.61 4.00 -82.02 5,958,116.97 492,436.06 4,117.22 10,064.63 4.00 -82.10 5,958,190.57 492,450.28 4,121.51 10,089.22 4.00 90.00 5,958,215.17 492,454.60 4,142.91 10,188.27 4.00 90.03 5,958,312.75 492,476.16 4,171.07 10,288.00 4.00 90.15 5,958,408.58 492,504.46 4,205.86 10,387.94 4.00 90.27 5,958,502.20 492,539.39 4,247.09 10,487.58 4.00 90.39 5,958,593.16 492,580.77 4,258.39 10,512.39 4.00 90.51 5,958,615.43 492,592.10 4,291.10 10,586.96 4.00 -90.00 5,958,682.82 492,624.91 4,329.14 10,686.81 4.00 -90.09 5,958,775.16 492,663.08 4,360.63 10,786.71 4.00 -90.20 5,958,869.95 492,694.72 4,385.43 10,886.17 4.00 -90.32 5,958,966.72 492,719.67 4,390.57 10,910.90 4.00 -90.43 5,958,991.16 492,724.85 101712019 1:40:27PM Page 3 COMPASS 5000.14 Build 85H ConocoPhillips BA ER ConocoPhillips Planning Report HUGHES a GE company Database: EDT 14 Alaska Production Company: ConocoPhillips Alaska Inc_Kuparuk Project: Kuparuk River Unit Site: Kuparuk 2M Pad Well: 2M-21 Wellbore: 2M-21 L1-01 Design: 2M-21 1-1-01_wp05 (Draft A) Planned Survey Vertical Depth Measured Dogleg Toolface Depth Inclination Azimuth (usft) (I (o) 13,600.00 91.60 14.37 13,700.00 91.59 18.37 13,800.00 91.57 22.37 13,900.00 91.54 26.37 14,000.00 91.51 30.37 14,025.00 91.50 31.37 Start DLS 7.00 TFO -105.00 14,100.00 90.14 26.30 14,200.00 88.32 19.54 14,300.00 86.53 12.77 14,400.00 84.78 5.97 14,500.00 83.11 359.13 Planned TD at 14500.00 F - Casing Points Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Well 2M-21 Mean Sea Level 2M-21 @ 140.00usft True Minimum Curvature TVD Below Vertical Depth Vertical Dogleg Toolface Map Map System +N/ -S +E/ -W Section Rate Azimuth Northing Easting (usft) (usft) (usft) (usft) (°/100usft) (°) (usft) (usft) 5,745.27 10,086.18 4,407.26 10,985.29 4.00 90.00 5,959,064.21 492,741.65 5,742.49 10,182.08 4,435.43 11,085.03 4.00 90.08 5,959,160.05 492,769.96 5,739.74 10,275.77 4,470.22 11,184.97 4.00 90.19 5,959,253.67 492,804.89 5,737.02 10,366.80 4,511.46 11,284.62 4.00 90.31 5,959,344.64 492,846.27 5,734.35 10,454.74 4,558.95 11,383.50 4.00 90.41 5,959,432.49 492,893.90 5,733.69 10,476.19 4,571.78 11,408.04 4.00 90.52 5,959,453.92 492,906.75 5,732.61 10,541.86 4,607.93 11,482.12 7.00 -105.00 5,959,519.53 492,943.01 5,733.96 10,633.90 4,646.86 11,581.91 7.00 -105.07 5,959,611.49 492,982.07 5,738.45 10,729.79 4,674.64 11,681.53 7.00 -104.98 5,959,707.33 493,010.00 5,746.03 10,828.11 4,690.87 11,779.47 7.00 -104.68 5,959,805.62 493,026.38 5,756.59 10,927.39 4,695.30 11,874.28 7.00 -104.16 5,959,904.88 493,030.97 Measured Vertical Depth Depth (usft) (usft) Name 14,500.00 5,756.59 2-3/8" Plan Annotations Measured Vertical Local Coordinates Depth Depth +N/ -S +E/ -W (usft) (usft) (usft) (usft) Comment 10,300.00 5,769.20 7,154.62 3,037.66 TIP/KOP 10,370.00 5,767.53 7,199.34 3,091.46 Start DLS 7.00 TFO -110.00 10,500.00 5,763.17 7,287.50 3,186.72 Start DLS 4.00 TFO -90.00 10,800.00 5,761.34 7,526.81 3,366.71 Start DLS 4.00 TFO 90.00 11,150.00 5,759.26 7,802.12 3,581.40 Start DLS 7.00 TFO -92.00 11,375.00 5,759.05 7,981.07 3,716.62 Start DLS 4.00 TFO -95.00 11,875.00 5,768.47 8,450.65 3,880.55 Start DLS 4.00 TFO 85.00 12,275.00 5,776.85 8,831.34 3,998.73 Start DLS 4.00 TFO -82.00 12,675.00 5,772.34 9,212.00 4,117.22 Start DLS 4.00 TFO 90.00 13,125.00 5,758.83 9,637.13 4,258.39 Start DLS 4.00 TFO -90.00 13,525.00 5,747.36 10,013.11 4,390.57 Start DLS 4.00 TFO 90.00 14,025.00 5,733.69 10,476.19 4,571.78 Start DLS 7.00 TFO -105.00 14,500.00 5,756.59 10,927.39 4,695.30 Planned TD at 14500.00 Casing Hole Diameter Diameter (in) (in) 2.375 3.000 10/7/2019 1:40:27PM Page 4 COMPASS 5000.14 Build 85H ConocoPhillips BATH ConocoPhillips Anticollision Report F UGI ES a GE company Company: ConocoPhillips Alaska Inc_Kuparuk Project: Kuparuk River Unit_2 Reference Site: Kuparuk 2M Pad Site Error: 0.00 usft Reference Well: 2M-21 Well Error: 0.00 usft Reference Wellbore 2M-21 L1-01 Reference Design: 2M-21 L1-01_wp05 (Draft A) Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Output errors are at Database: Offset TVD Reference: Well 2M-21 2M-21 @ 140.00usft 2M-21 @ 140.00usft True Minimum Curvature 2.00 sigma EDT 14 Alaska Production Offset Datum Reference 2M-21L1-01_wp05 (Draft A) 2A Pad - 2A -19 -2A -19-2A-19 Filter type: GLOBAL FILTER APPLIED: All welipaths within 2004 100/1000 of reference Reference Interpolation Method: MD Interval 25.00usft Error Model: ISCWSA Depth Range: 10,300.00 to 14,500.00usft Scan Method: Tray. Cylinder North Results Limited by: Maximum ellipse separation of 3,000.00 usft Error Surface: Combined Pedal Curve Warning Levels Evaluated at: 2.79 Sigma Casing Method: Added to Error Values Survey Tool Program Date 10/7/2019 2A Pad - 2A -19 -2A -19-2A-19 From To Reference (usft) (usft) Survey (Wellbore) Tool Name Description 200.00 10,100.00 2M-21 srvy 1 - SLB_GCT-MS (2M-21) GCT -MS Schlumberger GCT multishot 10,100.00 10,300.00 2M-21L1_wp05 (Draft A) (2M-21 L1) MWD OWSG OWSG MWD -Standard 10,300.00 I 14,500.00 2M-21 L1-01_wp05(Draft A)(2M-21 11-01) MWD OWSG OWSGMWD- Standard Onset Well - Wellbore - Design (usft) (usft) fusft) Summary Kuparuk 2A Pad - 2A -19 -2A -19-2A-19 Reference Offset Distance Offset Site Error. 0.00 Usti Survey Program: 141 -GCT -MS Measured Measured Between Between Separation Warning Site Name Depth Depth Centres Ellipses Factor Onset Well - Wellbore - Design (usft) (usft) fusft) (usft) Kuparuk 2A Pad Distance 2A-07 - 2A-07 - 2A-07 Measured Vertical Reference Offset Out of range 2A-19 - 2A-19 - 2A-19 12,372.45 9,150.00 497.35 255.44 2.056 Caution Monitor Closely, SF 2A-19 - 2A-19 - 2A-19 12,389.27 9,125.00 493.82 254.26 2.061 Caution Monitor Closely, ES 2A-19 - 2A-19 - 2A-19 12,438.86 9,050.00 489.25 258.45 2.120 Caution Monitor Closely, CC 2A-19 - 2A -19A - 2A -19A 12,287.32 9,250.00 508.68 260.95 2.053 Caution Monitor Closely, SF 2A-19 - 2A -19A - 2A -19A 12,398.70 9,100.00 492.31 254.20 2.068 Caution Monitor Closely, ES 2A-19 - 2A -19A - 2A -19A 12,447.78 9,025.00 489.28 260.35 2.137 Caution Monitor Closely, CC 2A-20 - 2A-20 - 2A-20 12,800.00 9,200.00 1,540.78 1,357.43 8.403 SF 2A -20 -2A -20-2A-20 12,977.01 8,700.00 1,459.19 1,298.18 9.062 ES 2A -20 -2A -20-2A-20 13,016.29 8,600.00 1,456.88 1,300.21 9.299 CC 2A-24 - 2A-24 - 2A-24 612.39 229.54 3.668 Out of range 2A -27 -2A -27A -2A -27A 14,300.00 8,028.00 1,522.59 1,273.81 6.120 CC, ES, SF Kuparuk 2M Pad 822.21 591.47 230.75 3.563 2M-21 - 2M-21 - 2M-21 10,402.21 10,475.00 183.81 178.05 31.895 CC, ES 2M-21 - 2M-21 - 2M-21 10,498.70 10,575.00 248.14 240.27 31.535 SF 2M-21 - 2M-21 11 - 2M-21L1_wp05 (Draft A) 12,200.00 5,916.05 9,60D.00 6,037.73 149.02 Out of range Offset Design Kuparuk 2A Pad - 2A -19 -2A -19-2A-19 Offset Site Error. 0.00 Usti Survey Program: 141 -GCT -MS Offset Well Error: 0.00 usft Reference Offset Semi Major Axis Distance Measured Vertical Measured Vertical Reference Offset Azimuth Offset Wellbore Centre Between Between Minimum Separation Warning Depth Depth Depth Depth from North +N/S +E/ -W Centres Ellipses Separation Factor (usft) (usft) (usft) (usft) (usft) (usft) (°) (usft) (usft) (usft) (usft) (usft) 12,172.62 5,915.67 9,785.00 6,179.03 148.70 128.22 -87.27 9,024.32 3,204.87 849.89 620.82 229.07 3.710 12,174.29 5,915.70 9,775.00 6,171.40 148.72 128.09 -86.84 9,024.76 3,211.31 841.93 612.39 229.54 3.668 12,178.49 5,915.76 9,750.00 6,152.31 148.77 127.76 -85.72 9,025.86 3,227.42 822.21 591.47 230.75 3.563 12,200.00 5,916.05 9,575.00 6,016.64 149.02 125.48 -76.68 9,035.13 3,339.96 693.49 453.22 240.28 2.886 Normal Operations 12,200.00 5,916.05 9,60D.00 6,037.73 149.02 125.81 -78.04 9,033.19 3,323.95 710.46 471.77 238.68 2.977 Normal Operations 12,200.00 5,916.05 9,625.00 6,056.84 149.02 126.13 -79.33 9,031.53 3,307.91 728.01 490.90 237.11 3.070 12,200.00 5,916.05 9,650.10 6,076.02 149.02 126.46 -80.55 9,030.25 3,291.78 746.22 510.66 235.56 3.168 12,200.00 5,916.05 9,675.00 6,095.04 149.02 126.79 -81.71 9,029.16 3,275.74 764.77 530.71 234.05 3.267 12,200.00 5,916.05 9,700.00 6,114.13 149.02 127.11 -82.82 9,028.06 3,259.63 783.74 551.17 232.57 3.370 CC - Min Centre to center distance or covergent point, SF - min separation factor, ES - min ellipse separation 10/7/2019 9:55:19AM Page 2 COMPASS 5000.14 Build 85H ConocoPhillips Project: Kuparuk River Unit_2 Site: Kuparuk 2M Pad Well: 2M-21 Wellbore: 2M-211-1-01 Plan: 2M 211-1-01 w 05 Draft A 2M -21/2M -211-1A1 _ P ( j t t �M� bo N Ak 1sd i M,e;, Field Stier Me 57_._n on'Mpie: 80.77° Dare: 1.,_, Model: BGGM201 WELLBORE DETAILS: 2M-211-1-01 REFERENCE INFORMATION Parent Wellbore: 2M-211-7 Tie on MD: 10300.00 Coordinate (WE) Reference: Wei M-21, True North Vertical (TVD) Reference. 2M-21 @ 140.00usft Section (VS) Reference Sbt-(O.00N, O.00E) Measured Depth Reference: 2M.21 @ 140.00usft Calculation Method: Minimum Curvatura WELL DETAILS: +N/ -S +E/ -W Northir@ Easti ng 0.00 0.00 5948985.88 488319.18 1 10300.00 89.25 49.04 5909.20 7154.62 3037.66 2 10370.00 93.49 51.49 5907.53 7199.34 3091.46 3 10500.00 90.35 42.95 5903.17 7287.50 3186.72 4 10800.00 90.34 30.95 5901.34 7526.81 3366.71 5 11150.00 90.33 44.95 5899.26 7802.12 3581.40 6 11375.00 89.78 29.21 5899.05 7981.07 3716.62 7 11875.00 88.08 9.27 5908.47 8450.65 3880.55 8 12275.00 89.53 25.21 5916.85 8831.34 3998.73 9 12675.00 91.75 9.37 5912.34 9212.00 4117.22 10 13125.00 91.66 27.37 5898.83 9637.13 4258.39 11 13525.00 91.60 11.37 5887.36 10013.11 4390.57 12 14025.00 91.50 31.37 5873.69 10476.19 4571.78 13 14500.00 83.11 359.13 5896.59 10927.39 4695.30 2M-2 2M-21 i 1 Latitude Longitude 70° 16' 18.585 N 150' 5' 40.098 W Annotation 1 0.00 0.00 7762. 9 TIPIKOP 7.00 30.00 7822. 1 Start DLS 7.00 TFO -110.00 7.00 -110.00 7937. 3 Start DLS 4.00 TFO -90.00 4.00 -90.00 8224. 7 Start DLS 4.00 TFO 90.00 4.00 90.00 8556. 1 Start DLS 7.00 TFO -92.00 - 7.00 -92.00 8770. 1 Start DLS 4.00 TFO 4.00 -95.00 -95.00 9268. 4 Start DLS 4.00 TFO 85.00 4.00 85.00 9666. 9 Start DLS 4.00 TFO ' 4.00 -82.00 -82.00 10064. 3 Start DLS 4.00 TFO 90.00 4.00 90.00 10512. 9 Start DLS 4.00 TFO -90.00 4.00 -90.00 10910. 0 Start DLS 4.00 TFO 90.00 + 4,00 90.00 11408.4 Start DLS 7.00 TFO -105.00 t 7.00 -105.00 11 87C 8 Planned TD at 14500.0 0 0 UGHES a GE company West( -)/East(+) (650 usft/in) Vertical Section at 20.00° (250 usft/in) Anneths to To-North WELLBORE DETAILS: 2M-2111 REFERENCE INFORMATION Project: Kuparuk River Unit_2 Magnetic Norm 16.17° Site: Kuparuk 2M Pad Magrretk Reid Parent Wellbore: 2M-21 Co-ordinate (N/E) Reference. Well 2M-21, True North CC[p7r Well: 2M-21 Strength 57382.6snT Vertical IND) Reference: 2M-21 @ 140.00us Gt1 v �.� plFMgte: STT, Tie on MD: 10100.00 Section (VS) Reference: Slot -(o.oaN, o.ODE) UGHES Wellbore: 2M-21 L1 1/201Mon —ed sured Depth Reference2M-21 @ 140.00us : f1 a GE company ConocoPhillips Plan: 2M-21 L1 wp05 (Draft A) (2M-21/2M-2111) Mopate. 12/del BGGM2018 Calculation Method Minimum Curvature ,,f' KUP PROD WELLNAME 2M-21 ' LLBIDRE 2M-21 Conornhhillips Well Attributes Max Angle & MD TD Alaska, Inc. Field Name Wellbore API/UWI Wellbore Status I cl (°) MD (ftKB) Act Btm (ftKB) K PAR K RIVER NIT 1 2 15 PR D 4.31 9,100.00 10,599.0 Comment H2S (ppm) Date Annotation End Date KB-Grtl (ft) Rig Release Date 40 12/5/2016 Last WO: 3/19/2019 43.00 11/14/1991 2M-21, 10!//20194.54.06AM Last Tag Vertical schematic (actual) Annotation Depth (ftKB) End DateWellbore Last Mod By Last Tag: RKB 10,382.0 10/6/2019 2M-21 fergusp Last Rev Reason HANGER-, 36.8 Annotation End Date Wellbore i Last Mod By Rev Reason: Tag 8 whipstock drift 10/6/2019 2M-21 fergusp Casing Strings Casing Description OD (in) ID (in) Top (ftKB) Set Depth (ftKB) Set Depth (TVD)... Wt/Len (L.. Grade Top Thread CONDUCTOR 16 15.06 39.0 123.0 1 23 .0 62.58 H-40 WELDED Casing Description OD (in) ID (in) Top (ftKB) Set Depth (ftKB) Set Depth (TVD)... Wt/Len (I... Grade Top Thread SURFACE 95/8 8.92 48.8 3,926.0 2,824.6 36.00 J-55 BTC Casing Description OD (in) ID (in) Top (ftKB) Set Depth (ftKB) Set Depth (TVD)... Wt/Len (I... Grade Top Thread TIE BACK STRING 7 6.28 44.0 1,797.3 1,702.8 26.00 L-80 Hyd563 Casing Description OD (in) ID (in) Top (ftKB) Set Depth(ftKB) Set Depth (TVD) Wt/Len (I.., Grade Top Thread CONDUCTOR, 39.0.123.0 PRODUCTION 7 6.28 1,795.0 10,599.0 6,119.0 26.00 J-55 BTC LEAK: 708.0 Annular Fluid - Diesel; 45.0. 2,n5.0;3n8=19 Tubing. Strings Tubing Description S[ring Ma... ID (in) Top (ftKB) Set Depth (ft.. Set Depth (TV (... Wt (lb/ t) Gratle Top Connection TUBING 2019 31/2 2.99 38.8 9,968.7 5,837.5 9.30 L80 EUE ', ', Completion Details Top (TVD) Top Incl Nominal Top(ftKB) (ftKB) (°) Item Des Co. to (in) 38.8 38.8 0.07 HANGER FMC Gen V, 3 /12" Tubing Hanger w/ dbl pin pup 3 -1/2" EUE land 2.992 the TIE BACK STRING; 44.0. 9,902.3 5,797.9 62.90 SEAL ASSY Baker 3 1/2" PBR EUE 3.000 1,797.3 9,916.0 5,804.2 62.85 PACKER Baker 7" x 3 1/2" FHL Packer EUE 2.992 9,937.8 5,814.1 62.77 NIPPLE HES 3 1/2"x 2.813" X Nipple with RHC -M Plug installed (SN 5894- 2.813 6) GAS LIFT; 3,330.1 9,987.7 5.837.01 62.58 1 LOCATOR OTIS Locator spaced out 1/2' above PBR 3.000 Tubing Description String Ma... ID (in) lop (ftKB) Set Depth (ft.. Set Depth (TVD) (... Wt (IWtt) Grade lop Connection TUBING ORIGINAL 5.41 2.97 9,988.6 10,029.7 5,856.4 Completion Details Top (TVD) Top Incl Nominal Top (ftKB) (ftKB) (') Item Des Co. ID (in) SURFACE; 48.8-3,926.0 9,988.6 5,837.5 62.58 PBR OTIS 10' STROKE PBR w/4" SEAL BORE 2.970 10,004.3 5,844.7 62.54 PACKER OTIS HVT RETRIEVABLE PACKER 3.250 10,019.7 5,851.8 62.55 NIPPLE - D CAMCO D NIPPLE 2.750 GAS LIFT; 6,007.8 10,029.1 5,856.1 62.56 WLEG OTIS RH BALL SEAT SUB/WL GUIDE (SHEARED), ELMD TTL @ 2.875 Annular Fluid - S,imatedadne, 10021' PER SWS PERF (10/11/99) 2,775.0-9,986.: 3/1x/2019 Other In Hole (Wirefine retrievable plugs, valves, Pumps, fish, etc.) GAS LIFT, 7,862.8 Top (TVD) Top Incl Top (ftKB) (ftKB) (°) Des Com Run Date ID (in) 708.0 705.6 9.23 LEAK SURFACE CASING LEAK. REMEDIATED WITH 11/24/201 1 1 CEMENT 3/14/19 7 GAS LIFT; 9,041.8 Perforations & Slots Shot Dens Top (TVD) Btm (ND) (shots/tt GAS LIFT; 9,873.9 Top (ftKB) Bt. (ftKB) (ftKB) (ftKB) Linked Zone Date ) Type Co. 10,109.0 10,124.0 5,892.9 5,899.8 C-1, 2M-21 10/11/1999 4.0 APERF 2.5" HSD, 60 deg. ph, non - oriented SEALASSY; 9,902.3 10,135.0 10,150.0 5,904.9 5,911.8 C-4, 210-21 3/11/2000 4.0 APERF 2.5" HSI) PJ 60 deg ph PACKER; 9,916.0 10,170.0 10,179.0 5,921.0 5,925.1 A-3, 2M-21 7/9/2013 6.0 APERF 2.5" HSC GUN LOADED, PHASED 60 DEGREES NIPPLE; 9,937.8 10,195.0 10,212.0 5,932.5 5,940.3 A -3,2M-21 6/28/2013 6.0 APERF 21/2"HSCGUN,60DEG PHASING, 102 SHOT TOTAL 10,232.0 10,252.0 5,949.5 5,958.7 A-3, 2M-21 10/29/1992 4.0 IPERF 4.5" Csg Gun, 180 deg. ph; LOCATOR; 9,987.7 Oriented 179 deg. ph PBR: 9,986.6 10,252.0 10,272.0 5,958.7 5,967.9 A-3, 2M-21 10/29/1992 4.0 IPERF 4.5" Csg Gun, 180 deg. ph; Oriented 169 deg. ph PACKER; 1:004.3 10,272.0 10,292.0 5,967.9 5,977.1 A-3, 2M-21 10/29/1992 4.0 IPERF 4.5" Csg Gun, 180 deg. ph; Oriented 176 deg. ph NIPPLE - D; 10,019.7 Frac Summary Start Date Proppant Designed (lb) Proppant In Formation (lb) 8/1/2001 WLEG; 10,029.1 Stg N Start Date Top Depth (ftKB) Bt. (ftKB) Link to Fluid System Vol Clean (bbl) Vol Slurry (bbi) 1 8/1/2001 10,109.0 10,150.0 Mandrel Inserts st APERF; 10,109.0.1 0,124.0 o i FRAC, 10,109.0 N Top (TVD) Valve Latch Port size TRO Run Top (ftKB) (ftKB) Make Model OD (In) Be, Type Type (in) (psi) Run Date Co. APERF; 10,135.0-10,150.0 3,330.1 2,493.3 Carrico MMG 1 1/2 GAS LIFT GLV RK 0.188 1,211.0 3/28/2019 2 6,007.8 3,899.3 Carrico MMG 1 1/2 GAS LIFT GLV RK 0.188 1,211.0 3/28/2019 3 7,862.8 4,843.9 Carrico MMG 1 1/2 GAS LIFT OV RK 0.250 0.0 3/28/2019 4 9,041.8 5,405.3 Carrico MMG 1 1/2 GAS LIFT DMY RK 3/18/2019 5 9,873.9 5,785.0 Camco MMG 11/2 GAS LIFT DMY RK 3/18/2019 APERF; 10,170.0.10,179.0 Notes: General & Safety End Date Annotation APERF; 10,195.0.10,212.0 11/24/2017 NOTE: SCLD (FAILED- SC LEAK @ 708'). 12/20/2017 NOTE: LEAK FOUND @ 7505' - Eline 4/1112019 NOTE: View Schematic w/ Alaska Schematic10.0 (PERF; 10,232.0.10,252.0 (PERF; 10,252.0.10,272.0 IPERF; 1:272.0.10,29? 0 PRODUCTION; 1,795.0- 10.599.0- 2M-21 Proposed CTD Schematic 16" 62# H-40 shoe C� 123' MD 9-5/8" 36# J-55 shoe @ 3926' MD C -sand perfs 10,109'-10,124' MD 10,135'-10,150' MD IPr000sed KOP 5- 10.120' MD I A -sand perfs 10,170'-10,179' MD 10,195'-10,212' MD 10,232'-10,292' MD 7" 26# J-55 shoe @ 10,599' MD 3-1/2" 9.3# L-80 EUE 8rd Tubing to surface 3-1/2" Camco MMG gas lift mandrels @ 3330', 6008', 7863', 9042', & 9874' MD Baker 3-1/2" PBR 9902' MD (3" ID) Baker FHL Packer @ 9916' MD (4" ID) 3-'/z' X landing nipple at 9938' MD w/ RHC Plug (2.813" min ID) Otis 3-1/2" PBR 9989' MD (2.97" ID) Otis HVT Packer @ 10,004' MD (3.25" ID) 3-1/2' Camco D -nipple at 10,020' MD Otis WLEG @ 10,029' MD 2M -21L1-01 Northwp04 TO 14,500' MD ✓ Top of Liner @ 10,010' MD 2M-21 L1 Southwp04 TD 15,500' MD Top of Billet @ 10,300' MD TRANSMITTAL LETTER CHECKLIST WELL NAME:Z PTD: Development _ Service _ Exploratory Stratigraphic Test Non -Conventional FIELD:1:s1jti4�� Check Box for Appropriate Letter / Paragraphs to be Included in Transmittal Letter CHECK OPTIONS TEXT FOR APPROVAL LETTER / / MULTI LATERAL The permit is fo a new wellbore segment of ex�is`tinng/ well Permit No. LZ API No.-�C'�- (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 gg� g 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 Well Name: _KUPARUK RIV UNIT 2M-211-1-01 Program DEV Well bore seg k PTD#:2191390 Company ConocoPhillips Alaska, Inc. Initial Class/Type DEV/PEND GeoArea 890 Unit 11160 On/Off Shore On Annular Disposal ❑ Administration 1 Permit -fee attache d---------------------------------------------NA- €z )0W 2 Lease number appropriate_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes - - - - - - - Surface Location lies within ADL0025586; Top Prod Int & TD lie ----------- - - - - - - - - 3within 3 Unique well name and number - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - Yes - 4 Well located in -a- defined pool _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes - - - - - - - Kuparuk River Oil_ Pool, governed by Conservation Order No. 432D 5 Well located proper distance from_ drilling unit_boundary_ Yes - - - - CO 432D Rule 3: There shall be no restrictions as to well spacing except that no pay shall be opened ---- 6 6 Well located proper distance from other wells- - - - - - - - - - - - - - - - - - - - - - - - - - - - - - Yes -- - - - - - a well closer_than_500 feet to an external property -line where ownership or landownership changes._ 7 Sufficient acreage available in_drilling. unit- - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - Yes - - - - - - _ As planned, well conforms with_spacing_requirements - _ _ _ - - 8 If_ deviated, is wellbore plat _included - - - ------------------------------- Yes___ ____________ 9 Operator only affected party - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - Yes - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - 10 Operator has appropriate bond in force - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - Yes - - 11 Permitcan be issued without conservation order- - - - - - - - - - - - - - - _ _ _ _ _ _ - ----- Yes - - - - - - - - - - - - - - - ------------------------------------------------------------ Appr Date 12 Permitcan be issued without administrative -approval - - - - - - - - - - - - - - _ _ _ _ _ - - - - Yes - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - 13 Can permit be approved before 15 -day wait_ - - - - - - - - - - Yes SFD 10/11/2019 - - - _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ - _ 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- - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - 16 Pre -produced injector: duration of pre production less than_ 3 months_ (For service well only) _ _ NA- - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - 17 Nonconven. gas conforms to AS31.05.030Q.1_.A),(j,2.A-D) - - - - - - - - - - - - - - - - - - - - - - NA- - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - 18 or Conductor string_provided - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - NA_ _ _ - _ _ - _ Conductor set_for_KRU_ 2M-21 _ _ _ _ _ _ _ _ _ _ _ _ _ _ - - - - - Engineering 19 Surface protects all -known USDWs - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - NA_ _ - - - - - Surface casing set for KRU 2M-21_ 20 CMT-voladequate _to circulate on conductor & surlcsg - - - - - - - - - - - - - - - - - - - - - - - - NA_ --- - - - - Surface casing set and fully cemented - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - 21 CMT_voladequatetotie-inlongstringtosurf-csg---------------------------- NA - - - - - - - - - - - - - - - ------------ - - - ----- - - - - -- 22 CMT -will coverall known productive horizons - - - - - - - - - - - - - - - No. _ _ _ _ _ _ _ Productiv_e_interval will be completed with -uncemented slotted liner_ _ _ _ _ _ _ _ 23 Casing designs adequate for C,_T, B &_ permafrost - - - - - - - - - - - - - - - - - - - - - - - - - - Yes - _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ 24 Adequate tankage or reserve pit - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - Yes - - - - - - - Rig has steel tanks; all_waste_to approved disposal wells_ - - - - - - - - - - - - - - - - - - - - - - - - - - 25 If a_re-drill, has_a 10-403 for abandonment been approved - - - - - - - - - - - - - - - - - - - - - - NA_ - _ - - _ - - - - - - - - - - _ - - _ _ - _ _ - - - - - - - - - _ _ _ _ _ - - - 26 Adequate wellbore separation -proposed - _ - Yes - - - - - - - Anti,collision analysis complete; no major risk failures 27 If diverter required, does it meet regulations- - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - NA_ _ _ _ _ _---------------------------------------------------------------------- Appr Date 28 Drilling fluid- program schematic & equip list adequate_ Yes - _ - _ _ _ _ Max format ion_ pressure is 4113 psig(12.6 ppg EMW); will drill_w/ 8.6 maintain EMW and maintain ov_erbal_w/ MPD VTL10/15/2019 29 BOPEs,-do they meet regulation - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - Yes - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - 30 BOPE-press rating appropriate; test to _(put psig in comments)- - - - - - - - - - - - - - - - - - - - Yes - - - - - - - MPSP is 3523 psig; will test BOPs_to 4000-psig - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - 31 Choke_manifoldcomplies w/API_RP-53(May 84)---------------------------- Yes - - - - --- -- - - - - - - - -- - - ----- -- -- - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - -- - - 32 Work will occur without operation shutdown- - - - - - - - - - - - - - - - - - - - - - - - - - - - - - Yes - _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ - 33 Is presence of H2S gas probable - - - - - - - - - - - - - - - - - - - - - - - - - Yes 1-12S measures required 34 Mechanical condition of wells within AOR verified (For service well only_) _ _ _ _ _ _ _ _ _ _ _ _ _ _ NA_ _ - _ _ - _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ - - _ - - _ - - _ _ - - _ _ _ _ _ _ _ - - _ - - - - _ _ _ _ _ - _ _ - - - - - - - - - - - - - _ - 35 Permitcan be issued w/o hydrogen_ sulfide measures - - - - - - - - - - No_ - - - _ - _ Wells -on 2M -Pad are 1-12S -bearing, H2$ measures required- - - - - - - - - - - - - - - - - - - - - - - - - - - - - Geology 36 Data_presented on_ potential overpressure zones - - - - - - - - - - - - - - - - - - - - - - - - - - - Yes - - - _ _ - - Max. potential -res. pressure is 12.6 ppg EMW; expected pressure is 8.8 ppg EMW. Well will be - - - - - Appr Date 37 Seismic analysis -shallow gas zones _ - - - - - - - - - - - - - - - - - - - - - - - - - - NA_ - - - - _ - _drilled using 8.6_ppg mud,_a coiled -tubing rig, an_d_managed_pressure drilling technique t -control _ _ _ SFD 10/11/2019 38 Seabed condition survey (if off -shore) - - - - - - - - - - - - - - - _ _ _ - NA_ _ _ _ _ _ _ _formation pressures and_stabilize shale_sections with -constant BHP of about 11.8 ppg EMW. - - - - - - 39 Contact-name/phone for weekly -progress reports [exploratory only] - - - - - - - - - - - - - - - - NA_ - - _ _ _ _ _ NOTE: Chance of encountering free -gas while -drilling due to gas injection_ performed in -this area. Geologic Engineering Public Commissioner: Date: Commissioner: Date Commissioner Date €z )0W
