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Home My WebLink About218-078DATA SUBMITTAL COMPLIANCE REPORT 1/18/2019 Permit to Drill 2180780 Well Name/No. KUPARUK RIV UNIT 1H-21AL1 Operator CONOCOPHILLIPS ALASKA, INC. API No. 50-029.22355-60-00 MD 11293 TVD 6729 Completion Date 9/14/2018 Completion Status 1.011- Current Status 1 -OIL UIC No REQUIRED INFORMATION Mud Log Mo✓ Samples No Directional Survey Yes DATA INFORMATION List of Logs Obtained: GR/Res (from Master Well Data/Logs) Well Log Information: Log/ Electr Data Digital Dataset Interval Log Log Run OHI Type Med/Frmt Number Name _ Scale Media No Start Stop CH Received Comments ED C 29766 Digital Data 7530 11293 10/8/2018 Electronic Data Set, Filename: 1H-21AL1 GAMMA RES.Ias ED C 29766 Digital Data 10/8/2018 Electronic File: 1H-21AL1 21VID Final Log.cgm ED C 29766 Digital Data 10/8/2018 Electronic File: 11-1-21AL1 5MD Final Log.cgm ED C 29766 Digital Data 10/8/2018 Electronic File: 1H-21AL1 5TVDSS Final ED C 29766 Digital Data 10/8/2018 Electronic File: 1H-21AL1 2MD Final.pdf ED C 29766 Digital Data 10/8/2018 Electronic File: 1H-21AL1 51VID Final.pdf ED C 29766 Digital Data 10/8/2018 Electronic File: 1H-21ALl 5TVDSS Final.pdf ED C 29766 Digital Data 10/8/2018 Electronic File: 11-1-21AL1 EOW - NAD27.pdf ED C 29766 Digital Data 10/8/2018 Electronic File: 1H-21AL1 EOW-NAD27.txt ED C 29766 Digital Data 10/8/2018 Electronic File: 1H-21AL1 Final at TO 11293 ft.csv ED C 29766 Digital Data 10/8/2018 Electronic File: 11-1-21AL1 Final at TO 11293 ft.xlsx ED C 29766 Digital Data 10/8/2018 Electronic File: 1H-21AL1 Survey Listing.td ED C 29766 Digital Data 10/8/2018 Electronic File: 1H-21AL1 Surveys.txt ED C 29766 Digital Data 10/8/2018 Electronic File: 1 H- 21 AL1_25_tapescan_BHl_CTK.txt ED C 29766 Digital Data 10/8/2018 Electronic File: 1H- 21AL1_5_tapescan_BHI _CTK.txt ED C 29766 Digital Data 10/8/2018 Electronic File: 1H-21AL1_output.tap ED C 29766 Digital Data 10/8/2018 Electronic File: 1H-21AL1 21VID Final Log.tif ED C 29766 Digital Data 10/8/2018 Electronic File: 11-1-21AL1 SMD Final Log.tif AOGCC Page 1 of 3 Friday, January 18, 2019 DATA SUBMITTAL COMPLIANCE REPORT 1/18/2019 Permit to Drill 2180780 Well Name/No. KUPARUK RIV UNIT 1H-21AL1 Operator CONOCOPHILLIPS ALASKA, INC. API No. 50.029-22355-60-00 MD 11293 TVD 6729 Completion Date 9/14/2018 ED C 29766 Digital Data Log C 29766 Log Header Scans ED C 29786 Digital Data ED C 29786 Digital Data ED C 29786 Digital Data ED C 29786 Digital Data Log C 29786 Log Header Scans Well Cores/Samples Information: Completion Status 1 -OIL Current Status 1 -OIL UIC No 10/8/2018 Electronic File: 1H-21AL1 5TVDSS Final Log.tif 0 0 2180780 KUPARUK RIV UNIT 1H-21AL1 LOG HEADERS 10/12/2018 Electronic File: 1H-21AL1 EOW - NAD27.pdf 10/12/2018 Electronic File: 1H-21AL1 EOW - NAD27.tM 10/12/2018 Electronic File: 1H-21AL1 EOW -NAD83.pdf 10/12/2018 Electronic File: 1H-21AL1 EOW - NAD83.tM 0 0 2180780 KUPARUK RIV UNIT 1H-21AL1 LOG HEADERS Sample Interval Set Name Start Stop Sent Received Number Comments INFORMATION RECEIVED Completion U Completion Report I Yf 71 Directional / Inclination Data YD Mud Logs, Image Files, Digital Data Y Core Chips Y /&A Production Test Information YY� Mechanical Integrity Test Information /Y / NA Composite Logs, Image, Data Files Core Photographs Y{'�A? Geologic Markers/Tops �Y v Daily Operations Summary /lam Cuttings Samples Y /6 Laboratory Analyses Y( COMPLIANCE HISTORY Completion Date: 9/14/2018 Release Date: Description Date Comments Comments: AOGCC Page 2 of 3 Friday, January 18, 2019 DATA SUBMITTAL COMPLIANCE REPORT 1/18/2019 Permit to Drill 2180780 Well NamelNo. KUPARUK RIV UNIT 1H-21AL1 Operator CONOCOPHILLIPS ALASKA, INC. API No. 50-029.22355-60-00 MD 11293 TVD 6729 C etion to 9/14/2018 Completion Status 1-0I1 Current Status 1 -OIL a UIC No Compliance Reviewed By. Date: / (% AOGCC Page 3 of 3 Friday, January 18, 2019 IBAERC a GE company To: Date: October 11, 2018 Meredith Guhl AOGCC 333 West 711 Ave, Suite 100 Anchorage, Alaska 99501 From: 21 8078 Letter of Transmittal Michael Soper/Yosha Ragbirsingh Baker Hughes, a GE Company 795 East 941" Avenue Anchorage, Alaska 99515 Please find enclosed the directional survey data for the following well(s): KUPARUK RIVER UNIT GREATER MOOSES TOOTH UNIT 3H -31A MT6-03PH 314-31AL1 MT6-03 1H -21A MT6-OSPB1 RECE►vE� 1H-21AL1 MT6-05PB2 1H-21AL2 MT6-05 1H-21AL2-01 MT6-051-1 AOGCG MT6-O8PB1 MT6-O8 (14) Total prints Enclosed for each well(s): 1 hardcopy print of directional survey reports (NAD27) 1 compact disk containing electronic survey files Note: Please feel free to send us an email in place of return mail. Michael Soper, Baker Hughes, Project Engineer Michael.Soper@BHGE.com Yosha Ragbirsingh, Baker Hughes, Survey Manager ConocoPhillips ConocoPhillips (Alaska) Inc. Kuparuk River Unit Kuparuk 1H Pad 1H-21AL1 50-029-22355-60 Baker Hughes INTEQ Definitive Survey Report 02 October, 2018 BA ER I UGHES a GE company 2 180 78 29786 ConocoPhillips BAER ConocoPhilli s p Definitive Survey Report 1Gfies Company: ConocoPhillips (Alaska) Inc. Local Co-ordinate Reference: Well 1 H-21 Project: Kuparuk River Unit TVD Reference: 1H-21 @ 96.O0usft (1 H-21) Site: Kuparuk 1H Pad MD Reference: 1H-21 @ 96.00usft It H-21) Well: 1H-21 North Reference: True Wellbore: 1 H-21 Survey Calculation Method: Minimum Curvature Design: 1 H-21 Database: EDT 14 Alaska Production Project Kuparuk River Unit, North Slope Alaska, United Slates 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 1H-21 _ __,�. __-.....�r-.v.....___._-ds�.._........_.__..., .... e.r ,,......w.-... ,..... Well Position +N/ -S 0.00 usft Northing: 5,980,024.57usft Latitude: 70" 21'22.356 N +E/ -W 0.00 usft Easting: 549,555.22usft Longitude: 149" 35'51.196 W Position Uncertainty 0.00 usft Wellhead Elevation: usft Ground Level: 54.40 usft Wellbore 1H-21AL1 Magnetics Model Name Sample Date Declination Dip Angle Field Strength V) (1) (nT) BGGM2018 9/1/2018 17.01 80.91 57,446 Design 11-1-21 AL1 Audit Notes: Version: 1.0 Phase: ACTUAL Tie On Depth: 8,300.98 Vertical Section: Depth From (TVD) +N/ -S +E! -W Direction (usft) (usft) (usft) (^) 41.60 0.00 0.00 0.00 Survey Program Date From To Survey Survey (usft) (usft) Survey (Wellbore) Tool Name Description Start Date End Date 102.20 7,80230 1 H-21 Srvy 1 - SIB_GCT-MS (1H-21) GCT -MS Schlumberger GCT multishot 4/28/1993 428/1993 7,826.00 7,876.23 1H -21A MWD -INC(/ 1-1-21A) MWD-INC—ONLY MWD-INC—ONLY—FILLER 8/19/2018 8/19/2018 7,907.21 8,300.98 1H -21A MWD(IH-21A)MWD MWD -Standard 8/19/2018 8/21/2018 8,315.00 11,255.34 1H-21ALl MWD(1H-21AL1) MWD MWD - Standard 8/23/2018 8/28/2018 70/2/2018 2:55:40PM Page 2 COMPASS 5000.14 Build 85D 1022018 2:55.40PM Page 3 COMPASS 5000.14 Build 85D �- ConocoPhillips a ER ConocoPhillips tWHFS Definitive Survey Report Company:, _...-._,.__.__...... ... P (Alaska) Inc. ConowPhilli s (Alaska Inc .. `."'_ _. Local Co-ordinate Reference: ce: We- Well 1H2211 �____._„... _._._....__ - _.__ ... .._.._....._.„..... .._........,_ __ _.„_ ..._.._.._ Project: Kuparuk River Unit TVD Reference: 1H-21 @ 96.00usft (11-1-21) Site: Kuparuk 1 H Pad MD Reference: 1H-21 @ 96.00usft (1H-21) Well: 1H-21 North Reference: True Wellbore: 1H-21 Survey Calculation Method: Minimum Curvature Design: 1H-21 Database: EDT 14 Alaska Production Survey ,�-._..__.-.v-.u_.._.. -.��...._..._-�._..�a._...�._..___.-.._. w._'._' .... ..........�-..,_-,._.._.m�...,.. ... Inc ND NDSS +N/ -S +E/ -W Map Map DLS Vertical Net) (°) (1 (°) ) (usft) usft) (usft) (usft) Northing Easting (^/100') Section Survey Tool Name Annotation (ft) UP (ft) 8,300.98 94.98 359.12 6,62349 6,527.49 17805 3,944.99 5,980,228.69 553,498.57 3.83 178.05 MWD (3) TIP 8,315.00 95.05 358.55 6,622.26 6,526.26 192.01 3,944.71 5,980,242.65 553,498.19 4.08 19201 MWD (4) KOP 8,345.32 91.78 357.21 6,620.46 6,524.46 222.25 3,943.59 5,980,2]2.88 553,496.87 11.65 222.25 MWD(4) 8,376.55 90.49 359.09 6,619.84 6,523.84 25346 3,942.58 5,980,304.07 553,495.66 7.30 253.46 MWD (4) 8,404.93 89.63 359.71 6,619.81 6,523.81 281,83 3,942.28 5,980,332.45 553,495.17 3.74 281.83 MM (4) ppp 8,435.70 90.80 2.45 6,61969 6,523.69 312.60 3,942.86 5,980,36321 553,495.55 968 312.60 MWD (4) 8,465.58 88.96 2.96 6,619.76 6,523.76 342.44 3,94427 5,980,393.06 553,496.76 6.39 342.44 MWD(4) 8,496.43 87.82 4.20 6,620.62 6,524.62 373.22 3,946.20 5,980,423.85 553,498.48 5.46 37322 MWD(4) 8526.21 8975 7.58 6,621.25 6,525.25 402.83 3,949.26 5,980,4534] 553,501.34 13.07 402.83 MWD (4) 8,556.21 88.65 8.67 6,621.67 6,52567 432.52 3,953.49 5,980,483.19 553,505.38 5.16 432.52 MM (4) 8,585.74 89.36 8.32 6,622.19 6,526.19 461.72 3,957.86 5,980,512.42 553,509.55 268 461.72 MM (4) 8,616.14 68.53 940 6,622]5 6,526.75 491.76 3,962.54 5,980,54248 553,514.03 448 491.76 MWD (4) 8,645.39 88.31 10.54 6,623.55 6,527.55 520.55 3,96760 5,980,571.30 553,518.90 3.97 520.55 MM (4) 8,676.07 88.34 11.41 6,624.45 6,528.45 550.66 3,973.44 5,980,601,45 553,524.54 2.84 550.66 MWD (4) 8,706.39 88.13 12.24 6,625.38 6,529.38 580.32 3,979.65 5,980,631.14 553,530.56 2.82 58032 MWD(4) 8,735.12 I 88.19 14.96 6,626.34 6,530.34 609.20 3,986.63 5,980,660.07 553,537.35 9.15 609.20 MWD(4) 8,765,31 88.74 1742 6,627.12 6,531.12 637.22 3,994.77 5,980,688.14 553,545.30 8.63 637.22 MWD (4) 8,796.67 89.66 14.38 6,627.56 6,531.56 667.37 4,003.36 5,980,718.34 553,553.69 10.13 667.37 MWD (4) { 8,825.31 90.12 11.39 6627.61 6,531.61 69529 4,009.75 5,980,74630 553,559.89 10.% 695.29 MWD(4) I! 8,855.61 90.77 7.70 6,627.38 6,531.38 72516 4,014.77 5,980,776.20 553,564.71 12.37 725.16 MWD (4) I 8,885.55 91.38 4.34 6,626.81 6,530.81 754.93 4,017,91 5,980,805.98 553,567.66 11.40 54.93 MWD (4) i8,915.04 91.29 0.98 6,626.13 6,530.13 764.37 4,019.28 5,980,835.44 553,566.83 11.39 784.37 MWD (4) 8,945.23 92.55 35773 6,625.12 6,529.12 814.54 4,018.94 5,980,855.60 553,568.29 11.54 814.54 MWD(4) 8,975.12 93.29 354.55 6,623.59 6,527.59 844.32 4,016.93 5,98D,895.36 553,566.08 10.91 844.32 MWD (4) { 9,005.61 92.55 352:41 6,622.04 6,52604 874.57 4,013.47 5,980,925.58 553,55243 742 874.57 MWD(4) E 9,035.48 89.66 352.62 6,62146 6,525.46 904.18 4,009.58 5,980,955.16 553,558.34 9.70 904.18 MWD (4) 9065.68 86.81 352.78 6,622.39 6,526.39 934.12 4,00574 5,980,985.07 553,554.31 9.45 934.12 MWD (4) 9,095.11 84.13 352.91 6,624.72 6,528.72 963.22 4,002.09 5,981,014.15 553,550.46 9.12 963.22 MWD (4) 9,125.89 81.22 353.20 6,628.64 6,532.64 993.52 3,99840 5,981,044.42 553,546.57 9.50 993.52 MM (4) 9,155.86 78.13 353.11 6,634.01 6,538.01 102279 3,994.89 5,981073.67 553,54286 10.31 1022.79 MWD(4) 1022018 2:55.40PM Page 3 COMPASS 5000.14 Build 85D ConocoPhillips ConocoPhillips Definitive Survey Report H WH�ES a Company: 'Project: Site: Well: Wellbore: Design: ConocoPhillips (Alaska) Inc. Kuparuk River Unit Kupamk 1 H Pad 1H-21 1H-21 1 H-21 Local Coordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Database: Well 1H-21 1H-21@96.00usft(1 H-21) 1 H-21 @ 96.00usft (1H-21) True Minimum Curvature EDT 14 Alaska Production -. Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/ -S +E/ -W DLS (usft) (°) (°) (usft) (usft) (usft) (usft) Northing Easting (°/100') Section Survey Tool Name y Annotation (ft) (ft) (ft) 9,184.51 75.35 351.42 6,640.58 6,544.58 1,05042 3,991.14 5,981,101.27 553,538.93 11.27 1,050.42 MWD(4) 9,214.99 74.84 347.99 6,64843 6,55243 1,079.40 3,98587 5,981,13021 553,533.48 11.00 1,079.40 MWD (4) I 9,245.94 r 75.86 344.99 6,65626 6,560.26 1,108.51 3,978.86 5,981,159.26 553,526.28 10.09 1,108.51 MWD(4) 9,275.11 79.10 342.87 6,662.58 6,566.58 1,135.86 3,97097 5,981,186.56 553,518.20 13.09 1,135.86 MWD (4) 9,305.71 79.65 339.87 6,668.17 6,572.17 1,169.37 3,961.36 5,981,215.00 553,508.40 9.95 1,164.37 MM (4) 9,335.53 79.79 336.55 6,673.44 6,577.44 1,191.62 3,950.46 5,981,242.17 553,497.33 10.96 1,191.62 MWD(4) i 9,365.83 80.69 333.05 6,678.58 6,582.58 1,218.63 3,937.75 5,981,269.10 553,484.44 11.76 1,218.63 MWD(4) 1 9,39799 83.08 329.11 6,683.12 6,587.12 1,246.49 3,922.36 5,981,296.85 553,468.86 14.22 1,246.49 MWD (4) 9,42542 84.18 326.36 6,686.16 6,590.16 1,269.54 3,907.80 5,981,319.80 553,454.16 1034 1,269.54 MWD (4) 9,464.57 87.57 322.11 6,688.98 6,592.98 1,301.21 3,869.99 5,981,351.32 553431.14 13.86 1,30121 MWD(4) 1 9,495.94 88.37 321.80 6,690.09 6,594.09 1,325.90 3,865.67 5,981,375.88 553,411.66 2.73 1,325.90 MWD (4) 9,526.99 87.05 320.80 6,691.33 6,595.33 1,350.11 3,846.27 5,981,399.96 553,392.10 5.33 1,350.11 MWD (4) 9,557.41 8662 318.92 6.693.01 6,597.01 1,373.33 3,826.69 5,981,423.05 553,372.37 6,33 1,373.33 MWD(4) 9,588.93 8923 322.78 6,694.15 6,598.15 1,397.75 3,806.81 5,981,447.33 553,352.33 14.78 1,397.75 MWD (4) 9,617.61 87.88 324.55 6,694.88 6,598.88 1,420.84 3,789.82 5,981,470.31 553,335.19 7.76 1,420.84 MWD (4) 9,647.45 89.11 327.00 6,695.66 6,599.66 1,445.51 3,773.05 5,981,494.86 553,318.26 9.18 1,445.51 MWD (4) 9,676.33 89.78 328.71 6,695.94 6,599.94 1,469.96 3,757.68 5,981,519.21 553,302.73 6.36 1,469.96 MWD (4) 9,706.70 89.17 329.85 6,696.22 6,600.22 1,496.06 3,742.17 5,981,545.21 553,287.05 4.26 1,496.06 MWD (4) i 9,737.61 88.74 33023 6,696.78 6,6W.78 1,522.84 3,726.74 5,981,571.88 553,271.44 1.86 1,522.84 MWD (4) j 9,767.15 i 88.68 32988 6,697.45 6,60145 1,548.43 3,711.99 5,981,597.37 553,256.53 1.20 1,548.43 MWD (4) 9,797.53 89.17 330.24 6,698.02 6,602.02 1,57475 3,696.83 5,981,623.58 553,241:20 200 1,574.75 MWD (4) 9,827.21 87.91 33037 6,698.77 6,602.77 1,600.52 3,682.14 5,981,64926 553,226.33 4.27 1,600.52 MWD(4) 9,857.29 88.22 33062 6,699.79 6,603.79 1,626.69 3,687.33 5,981,675.32 553,211.35 1.32 1,626.69 MWD (4) 9,889.44 89.42 333.77 6,700.45 6,60445 1,655.11 3,652.34 5,981,703.65 553,196.18 10.48 1,655.11 MWD (4) i 9,918.77 90.77 33389 6,70040 6,604.40 1,681.44 3,639.40 5,981,72988 553,183.07 4.62 1,681.44 MD (4) I 9,944.17 Y 87.88 33329 6,70070 6,604.70 1,704.18 3,628.11 5,981,752.55 553,171.62 11.62 1,70418 MWD (4) I 9,976.55 8022 333.87 6,701.80 6,605.80 1.733.16 3,613.71 5,981,781.43 553,157.03 2.08 1,733.16 MWD (4) 10,008.81 8948 33320 6,702.45 6,606.45 1,762.04 3,599.34 5,981,810.20 553,142.47 4.42 1,762.04 MWD (4) 10,039.09 90.58 334.18 6,70244 6,606.44 1,789.18 3,585.92 5,981,837.25 553,128.87 4.87 1,789.18 MWD (4) 10,065.86 8942 333.23 6,702.44 6606.44 1,814.07 3,57361 5,981,862.07 553,116.41 540 1,814.07 MWD(4) 10,097.88 89.29 33266 6,70279 6,606.79 184170 3,559.51 5,981,889.59 553,102.12 1.88 1841.70 MWD (4) 10/2/2018 2:55:40PM Page 4 COMPASS 5000.14 Build 850 ConocoPhillips Company: ConocoPhillips (Alaska) Inc. Project: Kuparuk River Unit Site: Kuparuk 1 H Pad Well: 1H-21 Wellbore: 1 H-21 Design: 11-1-21 Survey ConocoPhillips lF l CRHES Definitive Survey Report `""`" Local Co-ordinate Reference: Well 11-1-21 TVD Reference: 1 H-21 @ 96.00usft (1 H-21) MD Reference: 1H-21 @ 96.00usft(I H-21) North Reference: True Survey Calculation Method: Minimum Curvature Database: EDT 14 Alaska Production MD (usft) MD (usft) 10,127.63 10,156.90 10,187.11 10,222.10 Annotation 10/2/2018 2:55:40PM Page 5 COMPASS 5000.14 Build 85D ConocoPhillips Company: ConocoPhillips (Alaska) Inc. ' Protect: Kuparuk River Unit Site: Kuparuk 1 H Pad Well: 1H-21 Wellbore: 1H-21 Design: 1H-21 Survey _.e..,. I MD Inc (usft) Well 1 H-21 11,085.93 90.21 11,117.32 89.W i 11,149.14 89.79 ! 11,177.35 88.96 11,203.50 89.72 3 11,232.33 89.35 11,255.34 90.37 ( 11,293.00 90.37 ConocoPhillipsER H EG Definitive Survey Report +N/ -S Local Co-ordinate Reference: Well 1 H-21 TVD Reference: 1 H-21 (d) 96.00usft (1 H-21) MD Reference: 1 H-21 @ 96.00usft (1 H-21) North Reference: True Survey Calculation Method: Minimum Curvature Database: EDT 14 Alaska Production Azi TVD TVDSS +N/ -S (°) (usft) (usft) (usft) 4153 6,727.88 6,631.88 2,779.06 42.98 6,727.93 6,631.93 2,802.29 4161 6,728.10 6,632.10 2,825.83 39.24 6,728.41 6,632.41 2,847.30 39.03 6,728.71 6,632.71 2,867.58 37.10 6,728.94 6,632.94 2,890.28 38.24 6,728.99 6,632.99 2,908.49 38.24 6,72875 6632.75 2,938.07 1022018 2:55:40PM Page 6 COMPASS 5000.14 Build 85D Map Map Vertical +E/ -W Northing Easting DLS Section (usft) (°rypp•) Survey Tool Name Annotation - (ft) (ft) (ft) 3,524.19 5,982,826.61 553,060.61 6.04 2,779.06 MWD(4) 3,545.30 5,982,849.98 553,081.56 5.01 2,802.29 MWD (4) 3,56671 5,982,873.66 553,102.82 4.35 2,825.83 MWD(4) 3,585.00 5,982,895.25 553,120.96 8.90 2,847.30 MWD (4) 3,601.51 5,982,915.64 553,137.33 3.02 2,867.58 MM (4) 3,619.28 5,982,938.45 553,154.95 6.81 2,890.28 MWD(4) 3,633.34 5,982,956]5 553,168.89 6.62 2,908.49 MWD(4) 3,656.65 5,982,986.48 553;192.00 0.00 2,938.07 PROJECTED to TD - 1022018 2:55:40PM Page 6 COMPASS 5000.14 Build 85D J 1s k a.'t�J' -s � V pt= s ib G STATE OF ALASKA I OCT 09 2013 ALASKA OIL AND GAS CONSFRVATION cnMMISSInN WELL COMPLETION OR RECOMPLETION REPORT ANb "65 o 1a. WeII Status: Oi10 Gas[] SPLUG ❑ Other ❑ Abandoned ❑ Suspended❑ 20AAC 25.105 20AAC 25.110 GINJ ❑ WINJ ❑ WAGE] WDSPL ❑ No. of Completions: - 1b. Well Class: Development ❑� Exploratory El Service ❑ Stratigraphic Test ❑ 2. Operator Name: ConocoPhillips Alaska, Inc. 6. Date Comp., Susp., or Abend.: 9/14/2018 14. Permit to Drill Number/ Sundry: 218-078 3. Address: P.O. Box 100360 Anchorage, AK 99510-0360 7. Date Spudded: .8/23/2018 15, API Number: 50-029-22355-60-00 6 4a. Location of Well (Governmental Section): Surface: 679' FNL, 793' FEL, Sec 33, T12N, R10E, UM Top of Productive Interval: 487' FNL, 2127' FEL, Sec 34, T12N, R10E, UM Total Depth: 3021' FNL, 2409' FEL, Sec 27, T12N, R10E, UM 8. Date TD Reached: 8/28/2018 16. WeII Name and Number: KRU 1H-21AL7 9. Ref Elevations: KB:9( GL:54 BF: 17. Field / Pool(s): Kuparuk River Field/Kuparuk River Oil Pool 10. Plug Back Depth MD/TVD: N/A 18. Property Designation: ADL 25639 4b. Location of Well (State Base Plane Coordinates, NAD 27): Surface: x- 549555 y- 5980024 Zone- 4 TPI: x- 553498 y- 5980243 Zone- 4 Total Depth: x- 553192 y- 5982986 Zone- 4 11. Total Depth MD/TVD: 11293/6729 19. DNR Approval Number: LONS 80-261 12. SSSV Depth MD/TVD: 1789M 783 20. Thickness of Permafrost MD/TVD: 1629/1626 5. Directional or Inclination Survey: Yes 0 (attached) No ❑ Submit electronic and printed information per 20 AAC 25.050 13. Water Depth, if Offshore: N/A (ft MSL) 21. Re-drill/Lateral Top Window MD/TVD: 8316/6622 22. Logs Obtained: List all logs run and, pursuant to AS 31.05.030 and 20 AAC 25.071, submit all electronic data and printed logs within 90 days of completion, suspension, or abandonment, whichever occurs first. Types of logs to be listed include, but are not limited to: mud log, spontaneous potential, gamma ray, caliper, resistivity, porosity, magnetic resonance, dipmeter, formation tester, temperature, cement evaluation, casing collar locator, jewelry, and perforation record. Acronyms may be used. Attach a separate page if necessary GR/Res 23, CASING, LINER AND CEMENTING RECORD CASING' PER GRADE SETTING DEPTH MD SETTING DEPTH TVD HOLE SIZE CEMENTING RECORD AMOUNT FT. TOP BOTTOM TOP BOTTOM PULLED 16 62.5 H-40 41 121 41 121 24 200 sx PF C Cmt 95/8 36 J-55 40 4820 40 4247 121/4 930 sx PERM E, 450 sx Class G 7 26 J-55 39 8296 39 6947 81/2 299 sx Class G 23/8 4.6 L-80 7930 11293 6633 6729 3 Slotted Liner 24. Open to production or injection? Yes 0 No If Yes, list each interval open (MD/TVD of Top and Bottom; Perforation Size and Number; Date Perfd): SLOTTED LINER @: 7943 - 11293 MD and 6635 -6729 TVD... 8/31/2018 COMPLETION r DATE _ q1r 41-113 VF R!P!Er, 25. TUBING RECORD SIZE DEPTH SET (MD) PACKER SET (MD/TVD) 31/2 7693 7664/6453 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. Was hydraulic fracturing used during completion? Yes ❑ No Ej Per 20 AAC 25.283 (i)(2) attach electronic and printed information DEPTH INTERVAL (MD)::]AMOUNT AND KIND OF MATERIAL USED 27. PRODUCTION TEST Date First Production: WAITING FOR HOOKUP Method of Operation (Flowing, gas lift, etc.): Date of Test: Hours Tested: Production for Test Period Oil -Bbl: Gas -MCF: Water -Bbl: Choke Size: Gas -Oil Ratio: Flow Tubing Press. Casino Press: lCalculated 24 -Hour Ra Oil -Bbl: Gas -MCF: Water -Bbl: Oil Gravity - API (corr): Form 10-407 Revised 5/2017 1Ii1- /1/S//V/ CONTINUED ON PAGE 2 REI MS 6 GCT 0 9 2018 Submit ORIGINIAL only✓' � uI8�� e �,$.12�a�i8 1. 28. CORE DATA Conventional Core(s): Yes ❑ No ❑� Sidewall Cores: Yes ❑ No ❑� If Yes, list formations and intervals cored (MD/ VD, From/To), and summarize lithology and presence of oil, gas or water (submit separate pages with this form, if needed). Submit detailed descriptions, core chips, photographs, and all subsequent laboratory analytical results per 20 AAC 25.071. 29. GEOLOGIC MARKERS (List all formations and markers encountered): 30. FORMATION TESTS NAME MD TVD Well tested? Yes ❑ No ❑Q Surface If yes, list intervals and formations tested, briefly summarizing test results. Permafrost - Top Surface Permafrost - Base 1629 1626 Attach separate pages to this form, if needed, and submit detailed test Top of Productive Interval 8315 6622 information, including reports, per 20 AAC 25.071. Formation @ TPI -Kuparuk C3 TD 11293 6729 Formation at total de the I Ku aruk C 31. List of Attachments: Daily Operations Summary, Definitive Survey, Schematics Information to be attached includes, but is not limited to: summary of daily operations, wellbore schematic, directional or inclination survey, core analysis, paleontolooical report. product on or well test results,r 20 AAC 25,070. 32. f hereby certify that the foregoing is true and correct to the best of my knowledge. Authorized Name: James Ohlin er Contact Name: William R. Long 4k/1 Authorized Title: Staff CTD Engineer Contact Email: William.R.Lon co .com Authorized 7 Contact Phone: 263-4372 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 1b: Well Class - Service wells: Gas Injection, Water Injection, Water -Alternating -Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Item 4b: TPI (Top of Producing Interval). Item 9: The Kelly Bushing, Ground Level, and Base Flange elevations in feet above Mean Sea Level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 15: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). Item 19: Report the Division of Oil & Gas / Division of Mining Land and Water: Plan of Operations (LO/Region YY -123), Land Use Permit (LAS 12345), and/or Easement (ADL 123456) number. Item 20: Report measured depth and true vertical thickness of permafrost. Provide MD and TVD for the top and base of permafrost in Box 29. Item 22: Review the reporting requirements of 20 AAC 25.071 and, pursuant to AS 31.05.030, submit all electronic data and printed logs within 90 days of completion, suspension, or abandonment, whichever occurs first. Item 23: Attached supplemental records should show the details of any multiple stage cementing and the location of the cementing tool. Item 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in Rem 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, or Other (explain). Item 28: Provide a listing of intervals cored and the corresponding formations, and a brief description in this box. Pursuant to 20 AAC 25.071, submit detailed descriptions, core chips, photographs, and all subsequent laboratory analytical results, including, but not limited to: porosity, permeability, fluid saturation, fluid composition, fluid fluorescence, vitrinite reflectance, geochemical, or paleontology. Item 30: Provide a listing of intervals tested and the corresponding formation, and a brief summary in this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Item 31: Pursuant to 20 AAC 25.070, attach to this form: well schematic diagram, summary of daily well operations, directional or inclination survey, and other tests as required including, but not limited to: core analysis, paleontological report, production or well test results. Form 10-407 Revised 512017 Submit ORIGINAL Only IH -21 Proposed CTD Schematic - 16'62# H40 shoe 121' MD &SIB" 36# J-55 shoe � 4820' MO KOP�7826'MID i- mg .PTa4-]IDR dcro sxldxaa Mewa768P MDpwm baengi parte squeezed w/wmem 7769' -Mar MD 7918'- 7946 MD T• 2M JL5 ee km shoe®8296 MID >par em eor•MD 312"Camw TRDP= -RO SSSV at 1789 MD (2.812") 3.12" 9.3# J-55 EUE Ord Tubing w surface 8-12" Camw MMG gas lift marginal at 2571', 4355', 5143', 5922', 6719,718T, 7802' Baker 312" PSR at 7859 MD BakerHB packer at 7584' MD (2.99" ID) Daiipple al 76801 MD (Milad out tD 2.8W) 312" Baker SOS @ 7692' MD iH31R .=W45plv'- nllolededive 0 = 8359' MD n�aw�a4 drat=e3ls MD KUP PROD �� r��1� 1. Well Attribut _ <AA 1lJllJr1IIskIpS F.M ware AleSka.IRC. HUPARON RIVER UNIT 1 H-21 AL1 iN-iIK1.1pJlIDIB 1n:103)AM Last Tag Vwhal-'°msec(Z—.) MnaMtlon Last Tag: SLM Entlnare bad trN(BI 6/2812018 8,62.0 Lai By famaj HAxGER', s1a— Last Rev Reason Annolatlen En00ete Laalelor Rev Reason Installed Liner Top Packer 911812018 zembaej Casing Strings Casing Denali 10D (in) I to (in) Tov MEET set Depth MKS) ser 0eoln ITvm-.eaden fl._cewe TOPTnreaa cPVWCTOR, 4L6RLo AL1 Liner 2318 199 71,930.1 112930 671280 460 L-80 STL Liner Details SAFETY VLv: 1..3 TOP Spee TOP(WE, MKS) Top Inc! rl ltam Des Co. N—ard to IIN 0930.1 6633.3 0945 Jur on(Blllet) OH ArcholAluminum Billet (1 1,78 or OHanchor 2250 8 billet) eAS LIFT:2a/os ],9419 6.6309 W61 a yment Shorty Deployment Sleeve 1920. St. 8805) 6,6276 8980 Deployment Shorty Deployment Sleeve 1920, GAS UFT: 4.95¢.9 Sleeve 9,7466 6,6970 8872 Dept oymem Shorty Deployment Sleeve 1920. Sleeve SURFACE, 024,0204— GAS LIFT: 5.143,4 wa JFT: S,P11.9 wa LFT: 6,Tws ws LET', 1.1az.T wS UFT: 7.6022 FSR: 1,6m1 CermT agaeau'. Tress IT MB PACNER', 76fi0e Notlwm atla2ma loran he PoctM T,al00 RUG: 7,.0 CMT SOZ', 1.W561,A/0 NIPPLE: 7.M3 al Tal IPERIF 1,Th" D -7m0— PR0WCT0N', $e mill A1201 Limr', 7.69aa10YA.n EllI .1 Ines: 79]9.1-1T.. IJ KUP PROD COIIOCOPh�� WeII MKWI tr Lm0cf;fb � riseN.- Alaska,InL. KUPARUKRIVER UNIT .at WO: IH -21 1Hs,lnamle lD4]:x AM Last Tag Vwhtl acnes@(tamp Annopnon EM Osie De.gMdlg Last Tag:SLM 61282010 8,062.0 InIMM BY kmai Last Rev Reason ......................................................... ....... MµGFP: 91.8 gnnata0on EM Gate last MOO BY =1a"j Rev Reason: installed Liner Too Packer 9/182018 Casing Strings Laslne Description OD(Inl II iopmne sat ceplh lM1KBI set Oapm lrvO)-wdLm lt_G,de Top Th,eal CONOUCTOR 16 15.06 41.0 121.0 121( 62.50 H-00 WELDED CONDULTCR; x161210 Casing Description ODg,ll ID linl TophtKaI..) SNOapin O".1.sed-.. .ess- SURFACE 9518 892 402 4824 42471 36.00 .. J-55 BoTpM .11M..IDS Casing description ODI., ID (1n) Toptin. set Shad'Inded -..In tI-'e. put -en it Gnae top Tnreetl PRODUCTION ] fi28 38.9 8,2963 6.9470 26.00 J-55 AB -MOD Tubing Stings Tuning Description stung Me... men) roe nine) set Depm las.. set Dapm (rv011-. WIIIIwI) opcon"do casae IT. TUBING 312 2.99 3].6 Ifi929 6,4]52 930 J-55 EVEBRDMOD cqa uFT,2nOs Completion Details ToplrvDl Top Incl xuminal In (a..) mK&I rl Item Des Com ID(inl Gas LIFT; 484.9 37.6 376 0.13 HANGER FMC GEN IV HANGER 3.500 ,]09.3 1,]83.2 14.33 SAFETYVLV CAMCO TRDP-4A-RO SAFETY VALVE 2812 ],85 . 6,4419 39.00 PER BAKERPBR w/ 10' STR K (T P 112" RH 3. 0 SQUARE THREAD FOR PKR RETRIEVAL) 7,863.9 6,452] 39.00 PA KER BAKER HB RETRIEVABLE PACKER 2. 0 ],600.3 64654 39.01 NIPPLE CAMCODNIPPLENOGO(MOEDOWW2. "]/12)2010) 2.00 7,692.0 6,4]4.5 3900 SOS BAKER SHEAR OUT SUB 3015 SURFACE', 40. HJWO 4- Other In Holt (Wireline retrievable plugs, valves, pumps, fish, etc.) hip VD) TOp InU TopIKKB) (flKBI r) DBs Lom Run Oele IO6n1 G48 LIFT: 6.141. ],60.0 6,4496 39.00 PLU Cemem Plug 71122018 0000 ]826.0 6,5]8] 38.66 High Expansion NOPhem SOldtions Hign LxDansionwe0ge 61192018 0. 0 .a LIFT, 5.92t9 Wedge Perforations &Slots CASUFT:aIDgO snoe D ns Dip pae) Bun (TYDI (ant Top IBK81 Bun6770 (S46 llnkM Zane 018 1 Type Com ),6]5.0 ],6]].0 6,461.3 6,461 46.8 ]111201 3.0M SOZ sp,t Gas LIFT;]ao2> phasing tial) phasing 7]68. J, 858.0 6,533.5 .] UNIT D, - 6.061199 8.0 IPERF Enernerjel, tial). 3,1H-21 Phasing ],918.0 ],9480 ---6'6-5O7 74.2 CH. UNIT B, H 628/1993 12.0 IPERF "HJ tlep. 21 phasing Cement Squeezes T` WD) B. D) GK UFT],W23 TOp IXNB) BIm IM1KeI 1K(.p MKe) Oas Sta,l Oah Com ],663.9 8,088.0 6,452.6 6784.1 ement ..142 018 Squeeze Mandrel inserts PBR:7.650.+ at m Camlepwere', 7goosmB PASSER, 7W9 on Top MI) Valw la¢n pwl8lw N Teemel MKBI Make Muted .0 (an) dery Type Type ON TRO Run Deal) Run Oas Com 2,5705 2,4955 CAMCO KBUG 1 GAS UFT- GLV BK5 LASS 1,2710 1811=18 2 4,354.9 3,8906 CAM KBUG i GAS LIFT OV BKS 0,250 0.0 8116NKII xoa,.n sa,mn. ma Top3 PCW W. 5,1434 4495] D 0 CAMCO KBUG 1 GAS DMY BK5 0.0 0.0 &5200] 4 5,9219 5,0899 CAMCO KBUG 1 GAS LIFT DMY BK5 0.000 0.0 8/52007 PLUG,7000 CMi 802: ].SYS6T,&J].0 5 67099 5,]02.6 1 CAMCO KBUG 1 GASLIFT DMY BK5 00 0.0 511311999 6 ],182] 6,0]49 JCAMCO KBUG i GAB LIFT DMY BKS 0000 0.0 5/1311999 ] 7,6022 64007 lGAMC0 MMG-2 11/2 GAS LIFT DMY RK 0000 0.0 7/1011993 NIPPLE. 1.0 Notts: General B Safety End Date gnnWtion 9202010 NOTE: View SChemdtic w/ Alaska SchemaGC9.0 SDS, 1.M20 IPERF',],]89.6],je 0`� ADR ILaw ges".1&SDa0 H'pA FFnnv- I WnIW: ],SRO IPERF:791&D7,918.0� PRODLCTION:W9 aaa Operations Summary (with Timelog Depths) 1 H-21 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log sten Depen SWTnne End Time our (hr) pmeee Op code Ac5Nty Code Th PJA Operedat (MKB) End Depth(Itl(B) 8/17/2018 8/18/2018 12.00 MIRU MOVE MOB P Demob off 3H - Tucks on location @ 0.0 0.0 12:00 0000 16:00. Leave 3H pad 18:30, Arrive 1 H 24:00 8/18/2018 8/18/2018 5.00 MIRU MOVE MOB P On 1H pad, Remove jeeps. Prep cellar 0.0 0.0 00:00 05:00 for spotting rig. Spot dg. Work dg up check list. 8/18/2018 8/18/2018 4.00 MIRU MOVE RURD P Safe out all landings and stairs, call 0.0 0.0 05:00 09:00 out scaffold for wellhead platform, call grease crew, Go stem seal on B1 8/18/2018 8/18/2018 2.00 MIRU MOVE RURD T Operations limited due to dg issues on 0.0 0.0 09:00 11:00 same pad "'Note: Rig Accept time 0900- 8/18/2018 8/18/2018 1.00 MIRU WHDBOP NUND P N/U BOP 0.0 0.0 11:00 12:00 8/18/2018 8/18/2018 2.00 MIRU WHDBOP BOPE P Start BOP test, low 250 psi/high 3000 0.0 0.0 12:00 14:00 psi/annular 2500 psi, test waived by Guy Cook (AOGCC) 8/18/2018 8/18/2018 1.50 MIRU WHDBOP PRTS T Problems with swab valve, call out 0.0 0.0 14:00 15:30 grease crew again 8/18/2018 8/18/2018 5.50 MIRU WHDBOP BOPE P Continue with BOP test, Fail / Pass on 0.0 0.0 15:30 21:00 C2, C1. Fail and replace R1, End of BOPE test 8/18/2018 8/18/2018 2.00 MIRU WHDBOP PRTS P Pressure test PDL's and TT line. 0.0 0.0 21:00 23:00 Install night cap and bleed off WHP. Started at 480 PSI. BIIed down in steps to zero. Observe well. Dead for ten minutes pressure slowly rising. Bleed and watch. Go to pressure deployment ops for Whipstock 8/18/2018 8/19/2018 1.00 PROD1 RPEQPT PULD P PJSM, M/U BHA#1 with high 0.0 0.0 23:00 00:00 expansion whip stock 8/19/2018 8/19/2018 1.00 PROD1 RPEQPT PULD P Continue pressure deployment BHA 0.0 73.5 00:00 01:00 #1 NS HEW Whipstock, Make up to coil and surface test. Inspect pack offs 8/19/2018 8/19/2018 1.50 PROD1 RPEQPT TRIP P RIH BHA #I, EDC open pumping min 73.5 7,565.0 01:00 02:30 rate on seawater. Returns to TT 8/1912018 8/19/2018 0.20 PROD1 RPEQPT DLOG P Log K1 marker for+2.5' 7,565.0 7,595.0 02:30 02:42 8/19/2018 8/19/2018 0.40 PROD1 RPEQPT DLOG P Trip into 7650 run CCL log down to 7,595.0 7,850.0 02:42 03:06 7850 8/19/2018 8/19/2018 0.30 PROD1 RPEQPT TRIP P PUH to whipstock setting depth @ 7,850.0 7,833.7 03:06 03:24 7633.7, TOWS @ 7825. HS Orientation. Set whipstock. See tool shift - 2300PSI. Set down 2.5K - Good 8/19/2018 8/19/2018 1.70 PROD1 RPEQPT TRIP P PUH to 7819. Open EDC Flush well @ 7,833.7 74.0 03:24 0506 2 BPM, Start tripping out 8/19/2018 8/19/2018 0.50 PRODt RPEQPT PULD P Tag up at surface, check well for flow 74.0 74.0 05:06 0536 (no-flow) j 8/19/2018 8/19/2018 1.00 PROD1 RPEQPT PULD P LD setting tools on a dead well 74.0 0.0 05:36 06:36 8/19/2018 8/19/2018 0.30 PROD1 WHPST PULD P PJSM, PD window milling BHA #2 0.0 75.9 06:36 06:54 8/19/2018 8/19/2018 0.20 PROD1 WHPST PULD P Stab INJH, surface test Coiltrak tools, 76.9 76.9 06:54 07:06 (good-test), check pac-offs (good) 8/19/2018 8/19/2018 1.40 PROD1 WHPST TRIP P Tag up, reset counters to zero, RIH 76.9 7,565.0 07:06 08:30 with window milling BHA #2 8/19/2018 8/19/2018 0.20 PROD1 WHPST DLOG P Log the K1 marker correction of plus 7,565.0 7,600.0 08:30 08:42 1.5' 8/19/2018 8/19/2018 0.60 PROD1 WHPST DISP P Finish displacing well to milling fluid 7,600.0 7,600.0 08:42 09:18 Page 1130 Report Printed: 911912018 Operations Summary (with Timelog Depths) 1 H-21 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Stat Time EndTmie Dur(hn Phase Op Code Activity Code Time P.T.X Operation Shin� (flKB) End Depth (PoCB) 8/1912018 8/19/2018 0.20 PROD1 WHPST TRIP P Continue IH, dry tag TOHEW (TOWS), 7,600.0 7,827.7 09:18 09:30 1 HEW 7827.3' 8/19/2018 8/19/2018 0.50 PROD1 WHPST TRIP P PUW 45 it, no pumps, bring pump on- 7,828.7 7,828.7 09:30 10:00 line, RIH 1.0' past TOWS, PUH, shut down pump, RBIH to confirm dry tag HEW pinch point. 7828.7'. 8/19/2018 8/19/2018 2.00 PROD1 WHPST MILL P PUH, and bring pump on line get 7,828.7 7,833.2 10:00 12:00 parameters, begin milling window @ 1 fph, 1.81 bpm at 4,056 psi, BHP=3,629, WHP=419, IA=O, OA=48. "" Note: Center of the mill out of rasing 7,831.2' 8/19/2018 8/19/2018 3.50 PROD1 WHPST MILL P Continue milling window off of 7,833.2 7,846.0 12:00 15:30 Northern Solutions HEW WS, 1.81 bpn at 4,000 psi, WHP=O, BHP=3,610, IA=O, OA=50 "' Note: BOW @ 7,832' 8/19/2018 8/19/2018 0.10 PROD1 WHPST TRIP P TD rat hole 21' from TOWS, pull up 7,846.0 7,829.0 15:30 15:36 hole, PUW 45 k 8/19/2018 8/19/2018 0.80 PROD1 WHPST REAM P Ream window area from 7,844'-7,829' 7,829.0 7,846.0 15:36 16:24 8/19/2018 8/19/2018 0.20 PROD1 WHPST REAM P Dry drift window area 7,814'to TO 7,846.0 7,846.0 16:24 16:36 7,846' 8119/2018 8/19/2018 1.00 PROD1 WHPST TRIP P POOH, pumping 1.81 bpm 7,846.0 75-0- 16:36 17:36 8/19/2018 8/19/2018 1.40 PROD1 WHPST PULD P At surface, Flow check Lay down 83.0 0.0 17:36 19:00 window milling BHA on dead well. Mill out @ 2.79 Go. 2.80" NoGo. 8/19/2018 8/19/2018 0.60 PROD1 DRILL PULD P M/U BHA#3 with RB HCC Bi center, 0.0 72.2 19:00 19:36 2.3+° AKO motor, and USR, M1U to coil and surface test. - Good 8/19/2018 8/19/2018 1.60 PROD1 DRILL TRIP P Trip in well, EDC open pumping min 72.2 7,565.0 19:36 21:12 rate. 8/19/2018 8/19/2018 0.10 PROD1 DRILL DLOG P Log K7 for for +1' 7,565.0 7,586.0 21:12 21:18 8/19/2018 8/19/2018 0.40 PROD1 DRILL TRIP P Continue in well, @ 7810 perform 1 to 7,586.0 7,846.0 21:18 21:42 1 pressure test. Pump 1.78 BPM, BHP=3633, WHP=O with open choke. ECD=10.7 PPG. Shut down pump. Close EDC. Clean pass through window, Tag up and drill from 7846 8/19/2018 8/19/2018 1.60 PRODt DRILL DRLG P 7846', Drill, 1.74 BPM @ 3751 PSI FS, 7,846.0 7,912.0 21:42 23:18 1 1 BHP=3648 8/19/2018 8/19/2018 0.10 PRODi DRILL WPRT P BHA wiper/ weight check, PUW=50K 7,912.0 7,912.0 23:18 23:24 8/19/2018 8/2012018 0.60 PROD1 DRILL DRLG P 7912', Drill, 1.75 BPM @ 3788 PSI 7,912.0 7,930.0 23:24 00:00 FS, BHP=3660 8/20/2018 8/20/2018 3.80 PROD1 DRILL DRLG P 7930', Drill 1.75 BPM @ 3788 PSI FS, 7,930.0 8,T5-4-0- 00:00 03:48 BHP=3660 8/20/2018 8/20/2018 0.20 PROD1 DRILL WPRT P 8054 BHA Wiper trip, PUW=50K, 8,054.0 8,054.0 03:48 04:00 RIW=17.5K 8/20/2018 8/20/2018 3.20 PROD1 DRILL DRLG P 8054', Drill 1.76 BPM @ 3970 PSI FS, 8,054.0 8,150.0 04:00 07:12 BHP=3694 8/20/2018 8/20/2018 1.50 PROD1 DRILL TRIP P TD Build Section, 1 0x1 0 sweep, 8,150.0 73.0 07:12 08:42 POOH 8/20/2018 8/20/2018 0.70 PROD1 DRILL PULD P Tag up, space out, PUD build section 73.0 73.0 08:42 09:24 BHA#3 Page 2/30 Report Printed: 9/1912018 AIML . Operations Summary (with Timelog Depths) 1H-21 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Stan Tune EM Time Our (hr) Phase Op CMe Acdvq CMe Thm P -T -X opaetim Slat Depth (ILKe) EM Depth (IIKe) 8/20/2018 8/20/2018 0.80 PROD1 DRILL PULD T "'BHA hung up in well, trouble pulling 73.0 73.0 09:24 10:12 High Bend motor with SL, line up to pump thru the kill line and tango's, no success, Gose rams, bleed pressure from PDL, unstab, hook up suface power to tools, rotate TF 90° Left. Work tools free 8/20/2018 8/20/2018 0.70 PROD1 DRILL PULD P Continue PUD 73.0 0.0 10:12 10:54 8/20/2018 8/20/2018 1.20 PROD1 DRILL PULD P PJSM, PD lateral drilling BHA #4 0.0 78.2 10:54 12:06 w/0.5°- ako motor/ NOV Agitator 8/20/2018 8/20/2018 1.30 PROD1 DRILL TRIP P RIH, 568'test Agitator (great -test) 78.2 7,565.0 12:06 13:24 8/20/2018 8/20/2018 0.20 PROD1 DRILL DLOG P Log the K1 correction of plus 1.5' 7,565.0 7,593.0 13:24 13:36 8/20/2018 8/20/2018 0.10 PROD1 DRILL TRIP P Continue IH, 7,593.0 7,845.0 13:36 13:42 8/20/2018 8/20/2018 0.10 PROD1 DRILL DLOG P Log the RA @ 7833.5' 7,845.0 8,150.0 13:42 13:48 8/20/2018 8/20/2018 5.30 PROD1 DRILL DRLG P BOBD, 1.79 bpm @ 4,400 psi, 8,150.0 8,577.0 13:48 19:06 Diff -1,250, WHP=open choke, BHP=3,813, IA=O, OA=51 8/20/2018 8/20/2018 0.50 PROD1 DRILL WPRT P Wiper to the window, PUW 51 k 8,577.0 7,900.0 19:06 19:36 8/20/2018 8/20/2018 0.50 PROD1 DRILL WPRT P Wiper back in hole, RIW 17 k 7,900.0 8,577.0 19:36 20:06 8/2012018 8/20/2018 2.70 PROD1 DRILL DRLG P BOBD, 1.80 bpm @ 4,245, Diff=1,230 8,577.0 8,950.0 20:06 22:48 psi, WHP=open choke, BHP=3,780, IA=208, OA=59 8/20/2018 8/20/2018 0.50 PROD1 DRILL WPRT P Wiper up to the window, PUW 60 k 8,950.0 7,565.0 22:48 23:18 8120/2018 8/20/2018 0.20 PROD1 DRILL DLOG P log the K1 marker correc8on of plus 7,565.0 7,589.0 23:18 23:30 5.0' 8/20/2018 8/20/2018 0.30 PROD1 DRILL WPRT P Continue IH, Jog the 7", 7,700'-7,815', 7,589.0 7,815.0 23:30 23:48 closed EDC, 8/20/2018 8/21/2018 0.20 PROD1 DRILL WPRT P Continue wiper back in hole, Tough 7,815.0 7,880.0 23:48 00:00 spot 7880. Multiple setdowns with clean pickups, PUW=62K. Worked through @ .5 BPM 10 FPM. Continue to bottom 8/21/2018 8/21/2018 0.60 PROD1 DRILL WPRT P Continue wiper trip back to bottom 7,880.0 8,951.0 00:00 00:36 8/21/2018 8/21/2018 1.00 PROD1 DRILL DRLG P 8951', Drill, 1.78 BPM @ 4456 PSI 8,951.0 9,119.0 00:36 01:36 FS, BHP=3780PSL RIW=18.5K 8/21/2018 8/21/2018 0.10 PROD1 DRILL WPRT P BHA Wiper, PUW=60K 9,119.0 9,119.0 01:36 01:42 8/21/2018 8/21/2018 1.70 PROD1 DRILL DRLG P 9119', Drill, 1.78 BPM @ 4425 PSI FS, 9,119.0 9,325.0 01:42 03:24 BHP=3838 8/21/2018 8/21/2018 0.70 PROD1 DRILL WPRT P Pull 800' wiper, PUW=70K, 10K 9,325.0 9,325.0 03:24 04:06 overpulls @ 8890, 8690, & 8570. Clean on way in 8/21/2018 8/21/2018 3.80 PROD1 DRILL DRLG P 9325', Drill, 1.79 BPM @ 4480 PSI 9,325.0 9,745.0 04:06 07:54 FS, BHP=3781 8/21/2018 8/2112018 1.10 PROD1 DRILL WPRT P Wiper to window, work through tight 9,745.0 7,050.0 07:54 09:00 area 8088 to 8196 8/21/2018 8121/2018 0.90 PROD1 DRILL WPRT P Pull into 7", recip and jet, pump 7,050.0 7,845.0 09:00 09:54 - sweeps, circ to surface, RBIH, set down at 7828, TOW, PUH spin bit, set down 7786. Go through window 8/21/2018 8/21/2018 0.10 PROD1 DRILL DLOG P Log RA for+7' 7,845.0 7,870.0 09:54 10:00 Page 3130 Report Printed: 911912018 Operations Summary (with Timelog Depths) 1 H-21 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log n De Start Depth St Time End Time Dur (hr) Phase op cWe A CmIe vity Time P -T -X Operation End Depth (N(a) 8/21/2018 8/21/2018 1.10 PROD1 DRILL WPRT P Continue in hole, initial set down Q 7,870.0 7,896.0 10:00 11:06 7871 work down to 7888. multiple setdowns to 7896, Unable to pass 7896 at different speeds and pump rates. Back ream up at 180° still unable to pass. 8/21/2018 8/21/2018 0.60 PROD1 DRILL WPRT P Pull up hole to cased pipe. Circ 7,896.0 7,839.0 11:06 11:42 bottoms up. Check shaker. Nothing there. Discuss plan forward 8/21/2018 8/2112018 1.40 PRODi DRILL TRIP T Trip out for clean out BHA 7,839.0 84.0 11:42 13:06 8/21/2018 8/21/2018 1.40 PROD1 DRILL PULD T PJSM, PUD BHA #4 84.0 0.0 13:06 14:30 8/21/2018 8/21/2018 0.90 PROD1 DRILL PULD T PJSM, PD BHA#5 with 1.5°AKO 0.0 68.3 14:30 15:24 motor, D-331 with rigdge set cutter, and agitator, Make up to coil and surface test. Check packoffs, Tag up 8/21/2018 8/21/2018 1.10 PROD1 DRILL TRIP T RIH BHA#5, Surface test agitator @ 68.3 7,565.0 15:24 16:30 1 500', open EDC and continue in 8/21/2018 8/21/2018 0.50 PRODi DRILL TRIP T Tie in to K1 marker, RIH 7,565.0 7,860.0 16:30 17:00 8/21/2018 8/21/2018 1.60 PROD1 DRILL TRIP T stacked out twice, able to work 7,894.0 8,490.0 17:00 18:36 through, increase pump rate, rih to stall, continue to work area, clean at 7896, rih to 8490 8/21/2018 8/21/2018 1.50 PROD1 DRILL TRIP T pumped bottoms up sweep, puh to 7", 8,490.0 7,858.0 18:36 20:06 taking 3 cleaning passes, attempt to dry drift through trouble area 7840 to 7858, online, continue to tag at different depths each time. 8/21/2018 8/21/2018 2.90 PROD1 DRILL TRIP T pump bottoms up and clean area 7,858.0 7,820.0 20:06 23:00 above problem area, rbih at full pump speed, tagged several times in same area (7840-7950) continue to pump sweeps and try to clean trouble area 8/21/2018 8/22/2018 1.00 PROD1 DRILL TRIP T puh to above window, circ buttoms up, 7,820.0 7,840.0 23:00 00:00 attempt to drift back through window, sveral time tagging at top of window, orient 15 degrees left, now able to drift window, online with pumps at full rate, rih. 8/22/2018 8122/2018 2.00 PROD1 DRILL TRIP T RIH at full pump rate, still tag several 7,820.0 7,820.0 00:00 02:00 time, rih to 8450, pump sweeps, puh into the T'gain, rbih smooth other then one tag at 7858, rih to 8450 again, puh to window. 8/22/2018 8/22/2018 2.00 PROD1 DRILL TRIP T rih and tagged at top of whip stock, 7,820.0 8,450.0 02:00 04:00 puh to tie in, +7,5 ft, rbih, small tag at window, rih with full pump rale, mill through small tag at 7890, rih continue to work area. PUH above window, dry drift to 8000, no tags, online full rate, rih to 8450, start trip run for inflatable. 8/22/2018 8/22/2018 1.30 PROD1 DRILL TRIP T POOH, one overpull at top of window 8,450.0 68.0 04:00 05:18 on bit, fill appears to be cleaned out, POOH 8/22/2018 8/22/2018 1.50 PROD1 DRILL PULD T PJSM, PUD BHA #5 68.0 0.0 05:18 06:48 8/22/2018 8/22/2018 1.20 PROD1 DRILL PULD T PD BHA #6 2 1/8" Inflatable plug, M/U 0.0 68.0 06:48 08:00 to coil and surface lest tool -All good, Check pack offs 8/22/2018 8/22/2018 1.70 PROD1 DRILL TRIP T RIH BHA #6IFC plug 68.0 7,565.0 08:00 09:42 Page 4130 ReportPrinted: 9/1912018 Operations Summary (with Timelog DtNths) 1H-21 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log sten 71MEnd rime Dur(hr) PheSe op code A ity code Time P -T-% operation Depth (11)(B) (Po(B) End Depth(fll(a) 8/22/2018 8/22/2018 0.10 PROD1 DRILL DLOG T Log K1 for +15 7,565.0 7,591.0 09:42 09:48 8/22/2018 8/22/2018 0.50 PROD1 DRILL TRIP T Continue in hole. Slop and shut EDC 7,591.0 8,450.0 09:48 10:18 @ 7771. Clean pass through window. Clean trip down to 8450 8/22/2018 8/22/2018 0.60 PROD1 DRILL OTHR T At septh depth, Pull stretch out of coil. 8,450.0 8,450.0 10:18 10:54 Slowly pressure up inflatable to 1500 PSI. wait ten minutes. Bring pumps online Q 1700 PSI pressure falls off and we are circulating. Packer will not pressure up. able to move packer up and down hole. Attemp pumping Faster. No pressure 8/22/2018 8/22/2018 2.00 PROD1 DRILL TRIP T Trip out with BHA #6 8,450.0 71.0 10:54 12:54 8/22/2018 8/22/2018 1.10 PRODt DRILL PULD T At surface, Tag up and space out, 71.0 0.0 12:54 14:00 PUD BHA #6. Element is damaged on inflatable packer. Pictures on S drive. Lay down packer 8/22/2018 8/22/2018 1.30 PROD1 DRILL OTHR T. Discuss options and alternatives. 0.0 0.0 14:00 15:18 Formulate plan forward 8/22/2018 8/22/2018 1.00 PROD1 DRILL PULD T M/U BHA V. 1° WFT motor and 2.80 0.0 65.3 15:18 16:18 crayola mill to dress window 8/22/2018 8/22/2018 2.00 PROD1 DRILL TRIP T Trip in hole 65.3 7,555.0 16:18 18:18 8/22/2018 8/22/2018 0.10 PROD1 DRILL TRIP T K1 tie, =1 , Close EDC, rih 7,555.0 7,555.0 18:18 18:24 8/22/2018 8/22/2018 1.80 PROD1 DRILL MILL T rih to 7829, dress window several time 7,555.0 7,833.0 18:24 20:12 with 2.79 crayola mill and dry drift per plan forward 8/22/2018 8/22/2018 1.20 PROD1 DRILL TRIP T Trip out of hole for BHA#8 inflatable 7,833.0 71.0 20:12 21:24 plug. 8/22/2018 8/22/2018 1.20 PROD1 DRILL PULD T At surface, Tag up and space out, 71.0 0.0 21:24 22:36 PUD BHA#7. 8/22/2018 8/23/2018 1.40 PROD1 DRILL PULD T PD BHA #82.5" Inflatable plug, M/U to 0.0 71.0 22:36 00:00 coil and surface test tool -All good, Check pack offs 8/23/2018 8/23/2018 1.90 PROD1 DRILL TRIP T trip in hole with BHA #8 71.0 7,555.0 00:00 01:54 8/23/2018 8/23/2018 0.20 PROD1 DRILL DLOG T tie into K1, +1 correction 7,555.0 7,587.0 01:54 02:06 8/23/2018 8/23/2018 1.60 PROD1 DRILL OTHR T tagged up at 8368, 1fl short, Pull 7,587.0 8,368.0 02:06 03:42 stretch out of coil. Slowly pressure up inflatable to 1500 PSI. wait len minutes. Bring pumps online, continue to pressure up to shear at 2300 psi over circ psi, pull 18k over window pu wt, shear off inflatable. 8/2312018 8/23/2018 1.50 PROD1 DRILL TRIP T POOH 8,368.0 68.0 03:42 05:12 8123/2018 8/23/2018 1.50 PROD1 DRILL PULD T Tag up and space out, PJSM PUD 68.0 0.0 05:12 06:42 BHA #8 Packer running tools 8/23/2018 8/23/2018 1.00 PROD1 DRILL PULD T PD BHA#9 OH anchored billit. M/U to 0.0 72.9 06:42 0742 coil track and surface test tool, Check packoffs 8/23/2018 8/23/2018 1.70 PROD1 DRILL TRIP T RIH BHA #9 72.9 7,565.0 07:42 09:24 8/23/2018 8/23/2018 0.20 PRODt DRILL DLOGT Log K1 for +1' correction 7,565.0 7,603.0 09:24 09:36 11 1 Page 5130 ReportPrinted: 9/19/2018 Operations Summary (with Timelog Depths) 1 H-21 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Sten Tuna End Time Dw(hr) Phase Op Cotle ActlNly Cafe Tena P -T-% Operation Stan Depth (fit®) End Depth(ftKB) 8/23/2018 8/23/2018 0.50 PROD1 DRILL TRIP T Continue in hole, Shut EDC @ 7756. 7,603.0 8,327.0 09:36 10:06 Clean pass through window and down to 6327, Set whipstock @ 210` TOWS @ 8315, See tool shift @ 5111, Set down 2K 8/23/2018 8/23/2018 1.70 PROD1 DRILL TRIP T POOH, PUW=53K 8,327.0 74.0 10:06 11:48 8/23/2018 8/23/2018 1.10 PROD? DRILL PULD T At surface, Tag up and space out, 74.0 0.0 11:48 1254 PUD BHA #9 Anchor billet setting tools 8/23/2018 8/23/2018 1.00 PROD2 STK PULD P PD BHA #10 from Pre loaded PDL 0.0 80.5 12:54 13:54 with .5-AKO motor, Strider agitator, and new HCC bi-center bit with Dynamus cutters. 8/23/2018 8/23/2018 1.70 PROD2 STK TRIP P Trip in hole, Shallow test Strider tool 80.5 7,565.0 13:54 15:36 @ 500', Continue in well. 8/23/2018 8/23/2018 0.10 PROD2 STK DLOG P Log K1 for +1' correction 7,565.0 7,594.0 15:36 15:42 8/23/2018 8/23/2018 0.40 PROD2 STK TRIP P Continue in well, Dry tag TOB @ 7,594.0 8,315.0 15:42 16:06 8315', PUH, PUW=54 8/23/2018 8/23/2018 1.90 PROD2 STK KOST P Pumps on 1.83 BPM @ 4286 PSI FS, , 8,315.0 8,318.0 16:06 18:00 BHP=3742. Start milling off billet @ 8315.3. Mill per procedure 8/23/2018 8/23/2018 2.00 PROD2 DRILL DREG P 8318', Drill, 1.70 BPM @ 4145 PSI 8,318.0 8,421.0 18:00 20:00 FS, BHP=3724 6/23/2018 8/23/2018 0.20 PROD2 DRILL DRLG P PU to 8160 and dry drift billet 8,421.0 8,421.0 20:00 20:12 8/23/2018 8/23/2018 2.00 PROD2 DRILL DRLG P 8421', Drill 1.72 BPM @ 4376 PSI FS, 8,421.0 8,546.0 20:12 22:12 1 BHP=3945 8/23/2018 8/23/2018 0.20 PROD2 DRILL WPRT P PU to lower flow and try to get through 8,546.0 8,546.0 22:12 2224 stringer, srart mu swap 8/23/2018 8/24/2018 1.60 PROD2 DRILL DRLG P 8546' Drill 1.60 BPM @ 4368 PSI FS, 8,546.0 8,662.0 22:24 00:00 BHP=4176, trouble getting direction to drop 8/24/2018 8/24/2018 1.50 PROD2 DRILL DRLG P 8662' Drill 1.60 BPM @ 4358 PSI FS, 8,662.0 8,690.0 00:00 01:30 BHP=4192 still having trouble getting direction to drop, consult with town, decission made to trip for BHA. 8/24/2018 8/24/2018 1.90 PROD2 DRILL TRIP T Trip for BHA 8,690.0 69.0 01:30 03:24 8/24/2018 6/24/2018 1.10 PROD2 DRILL PULD T Tag up and space out, PJSM, PUD 69.0 0.0 03:24 04:30 BHA#10 8/24/2018 8/24/2018 1.00 PROD2 DRILL PULD T PD BHA#11 with .7°AKO motor, M/U 0.0 80.5 04:30 05:30 1 1 to coil and surface test 8/24/2018 8/24/2018 1.40 PROD2 DRILL TRIP T Trip in BHA# 11, Test agitator @ 500', 80.5 7,565.0 05:30 06:5, 1 Continue in well 8/24/2018 8/24/2018 0.10 PROD2 DRILL DLOG T Log K1 for+2.5' 7,565.0 7,593.0 06:54 07:00 8/24/2018 8/24/2018 0.70 PROD2 DRILL TRIP T Continue in well, Stop at 7807 for 7,593.0 8,690.0 07:00 07:42 static, Annular pressure = 4200 PSI, 6524.6 TVD, 12.385 EMW. Continue in. Clean pass through window 8/24/2018 8/24/2018 2.50 PROD2 DRILL DRLG P 8690', Drill, 1.81 BPM @4577 PSI FS, 8,690.0 8,863.0 07:42 10:12 BHP=4429 8/24/2018 8/24/2018 0.70 PROD2 DRILL WPRT P 8863, Pull wiper to window with 8,863.0 7,805.0 10:12 10:54 sweeps. Pull up through window and jet 7" 8/24/2018 8/24/2018 1.00 PROM DRILL PRTS P 7805 Obtain static pressure, Bleed 7,805.0 7,805.0 10:54 11:54 down AP to 3800 PSI in three steps. Climbed from 3800 to 3905 in 30 minutes. 6523.1 TVD, 11.51 EMW 8/24/2018 8/24/2078 0.50 PROM DRILL TRIP P Continue wiper trip back to bottom. 7,805.0 8;862.0 1154 12:24 Clean Page 6/30 Report Printed: W-1-912018 . Operations Summary (with Timelog Depths) 111-21 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Stan DepM Start Time End Time Dur (Iv1 Phase Op Code Activity Ccoe Tyne P -T -X OpeMon (BKB) EM DepN (XKB) 8/24/2018 8/24/2018 2.40 PROD2 DRILL DRLG P 8862', Drill, 1.79 BPM @ 4232 PSI 8,862.0 8,985.0 12:24 1448 FS, BHP=4101 8/24/2018 8/24/2018 0.10 PROD2 DRILL WPRT P Pull mini wiper, PUW=55K 8,985.0 8,985.0 14:48 14:54 8/24/2018 8/24/2018 2.90 PROD2 DRILL DRLG P 8985', Drill, 1.79 BPM @ 4254PSI FS, 8,985.0 9,098.0 14:54 17:48 BHP=4084 8/24/2018 8/24/2018 0.20 PROD2 DRILL WPRT P Pull mini wiper, PUW=55K 9,098.0 9,098.0 17:48 18:00 8/24/2018 8/24/2018 4.00 PROD2 DRILL DRLG P 9098', Drill, 1.79 BPM @ 4254PSI FS, 9,098.0 9,260.0 18:00 22:00 BHP=4084 8/24/2018 8/24/2018 0.90 PROD2 DRILL WPRT P wiper trip to 8460, PU wt 55k 9,260.0 9,860.0 22:00 22:54 8/24/2018 8/25/2018 1.10 PROD2 DRILL DRLG P 9260', Drill, 1.80 BPM @ 4480 PSI 9,260.0 9,310.0 22:54 00:00 FS, BHP=4100 8/25/2018 8/25/2018 3.00 PROD2 DRILL DRLG P 9310', Drill, 1.80 BPM @ 4480 PSI 9,310.0 9,414.0 00:00 03:00 FS, BHP=4100 8/25/2018 8/25/2018 0.20 PROD2 DRILL WPRT P Wiper trip to 9314', PU WT 59K 9,414.0 9,414.0 03:00 03:12 8/25/2018 8/25/2018 PROD2 DRILL DRLG P 9414', Drill, 1.80 BPM @ 4430 PSI 9,414.0 9,467.0 03:12 0312 FS, BHP=4138 6/25/2018 8/25/2018 1.50 PROD2 DRILL DRLG P 9467, motor stall, puh, .90 bpm =4356 9,467.0 9,467.0 03:12 04:42 circ psi, unbable to Gear bit, rih to tag 8/25/2018 8125/2018 3.20 PROD2 DRILL TRIP T POOH for motor swap 9,467.0 75.0 04:42 07:54 8/25/2018 8/25/2018 2.10 PROD2 DRILL PULD T Tag up space out, PJSM PUD BHA 75.0 0.0 07:54 10:00 #11. Lay down motor, Stryder agitator, and FVS. Test in mouse hole. All seem normal. Run water through coil track no obstruction 8/25/2018 8/25/2018 1.40 PROD2 DRILL PULD T PJSM, P/U motor, bit, agitator, and 0.0 78.1 10:00 11:24 FVS. PD BHA#12. Pull checks out of UQC and change out. Make up to coil and surface test tool. Pump at surface to ensure BHA functional. Tag up and set counters 8/25/2018 8/25/2018 1.40 PROD2 DRILL TRIP T RIH BHA#12, Shallow test agitator at 78.1 7,565.0 11:24 12:48 500'- Good. Continue in 8/25/2018 8/25/2018 0.10 PROD2 DRILL DLOG T Log K1 for+1.5' 7,565.0 7,592.0 12:48 12:54 8/25/2018 8/25/2018 1.40 PROD2 DRILL TRIP T Continue in well. Wt check @7790 7,592.0 9,469.0 12:54 14:18 49K, Clean pass through window. Stacking @ 8889, 9087, 9117, and 9176. Set down @ 9269 and 9376. reduce rate to .6 to get through 8/25/2018 8/25/2018 6.20 PROD2 DRILL DRLG P 9469, On bottom drilling, 1.78 BPM @ 9,469.0 9,813.0 14:18 20:30 4670 PSi FS, BHP=4165. Ratty with low ROP 8/25/2018 8/25/2018 0.10 PROD2 DRILL WPRT P 100 It wiper, PU WT is 61K 9,813.0 91813.0 20:30 20:36 8/25/2018 8/25/2018 1.00 PROD2 DRILL DRLG P 9813', Drill, 1.78 BPM @ 4694 PSI 9,813.0 9,870.0 20:36 21:36 FS, BHP=4216 8/25/2018 8/26/2018 2.40 PROD2 DRILL WPRT P 9870' wiper, PU 800", 2 overpulls 9,870.0 7,710.0 21:36 00:00 around 9320 of 12k, some trouble getting back to bottom through this area. No WT on bit, Decide to POOH to TTL to clean up 7", PU WT is 58K. 8/26/2018 8/26/2018 1.40 PROD2 DRILL WPRT P Clean out 7" 7,710.0 7,570.0 00:00 01:24 8/26/2018 826/2018 0.10 PROD2 DRILL DLOG P Tie in to K! +6.5 7,570.0 7,570.0 01:24 01:30 8/26/2018 8/26/2018 1.30 PROD2 DRILL TRIP P RIH, Clean through window, set down 7,570.0 9,870.0 01:30 02:48 I at 8755', Clean for remainder to 9870. 1 Page 7/30 Report Printed: 9/1 912 01 8 . Operations Summary (with Timelog Depths) 1 H-21 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Stan Time End Time Dur (hr) Phase Op Code Activity Code Time P -T-% Operation Stan Depth (luta) End Depth (111G) 8/26/2018 8/26/2018 1.20 PROD2 DRILL DRLG P 9870', Drill, 1.78 BPM @ 4622 PSI 9,870.0 10,015.0 02:48 04:00 FS, BHP=4239 8/26/2018 8/26/2018 0.20 PROM DRILL WPRT P 10015 PU for short wiper 100' 10,015.0 10,015.0 0400 0412 8/26/2018 8/26/2018 1.10 PROM DRILL TRIP T Short trip to 9930, survey issues due 10,015.0 10,015.0 04:12 05:18 to magnetic storm. Start obtaining usable surveys. RBIH to drill 8/26/2018 8/26/2018 2.10 PROD2 DRILL DRLG P 10015 Drill, 1.81 BPM @ 4764 PSI 10,015.0 10,172.0 05:18 07:24 1 FS, BHP=4202 8/26/2018 8/26/2018 0.20 PROM DRILL WPRT P 10172 Pull BHA wiper, PUW=61K 10,172.0 10,172.0 07:24 07:36 8/26/2018 8/26/2018 1.00 PROD2 DRILL DRLG P 10172', Drill, 1.77 BPM @ 4747 10,172,0 10,260.0 07:36 08:36 8/26/2018 8/26/2018 2.00 PROD2 DRILL WPRT P Pull 1000' wiper with sweeps, 10,260.0 10,260.0 08:36 10:36 PUW=58K. Hard to get back to bottom 8/26/2018 826/2018 2.00 PROD2 DRILL DRLG P 10260', Drill, 1.79 BPM @ 4737 PSI 10,260.0 10,353.0 10:36 12:36 FS, BHP=4215 8/26/2018 8/26/2018 0.30 PROD2 DRILL WPRT P Stacking, Pull BHA Wiper, PUW=63K 10,353.0 10,353.0 12:36 12:54 8/26/2018 8/26/2018 3.50 PROD2 DRILL DRLG P 10353', Drill, 1.8 BPM @ 4239 PSI 10,353.0 10,488.0 12:54 16:24 FS, BHP=4239 PSI, RIW=-.4, DHWOB=I.6K 8/26/2018 8/26/2018 0.20 PROD2 DRILL WPRT P Pull BHA Wiper, PUW=56K, 10,488.0 10,488.0 16:24 16:36 RIW=6.5K 8/26/2018 8/262018 2.50 PROD2 DRILL DRLG P 10488', Drill, 1.8 BPM @ 4241 PSI 10,488.0 10,573.0 16:36 19:06 FS, BHP=4237 PSI, RIW=-.4, DHWOB=I.6K 8/26/2018 8/27/2018 4.90 PROD2 DRILL WPRT P Wiper, PU WT=70K, PUH to TTL, 10,573.0 10,573.0 19:06 00:00 Time new mud swap for RIH, RBIH several trouble areas going through the C2, new mud at nozzle, big improvment, dh to bottom 8/27/2018 8/27/2018 2.40 PROM DRILL DRLG P 10573', Drill, 1.79 BPM @ 4600 PSI 10,573.0 10,647.0 00:00 02:24 FS, BHP=4225 8/27/2018 827/2018 0.10 PROD2 DRILL WPRT P Pull BHA Wiper, PUW=63K, 10,647.0 10,647.0 02:24 02:30 RIW=6.5K 8/27/2018 8/27/2018 1.30 PROD2 DRILL DRLG P 10647', Drill, 1.79 BPM @ 4600 PSI 10,647.0 10,671.0 02:30 03:48 FS, BHP=4225 8/27/2018 8/27/2018 0.10 PROD2 DRILL WPRT P Pull BHA Wiper, PUW=61 K. 10,671.0 10,671.0 03:48 03:54 RIW=6.5K 8/27/2018 8/27/2018 0.50 PROD2 DRILL DRLG P 10671', Drill, 1.79 BPM @ 4419 PSI 10,671.0 10,676.0 03:54 04:24 FS, BHP=4230 8/27/2018 8/2712018 0.40 PROM DRILL WPRT P PU for GEO Wiper 10,676.0 10,676.0 04:24 04:48 8/27/2018 8/27/2018 2.70 PROM DRILL DRLG P 10676', Drill, 1.79 BPM @ 4412 PSI 10,676.0 10,700.0 04:48 07:30 FS, BHP=4228 8/27/2018 8/2712018 2.90 PROD2 DRILL TRIP P 10,700, Trip for bit, Pump sweeps, jet 10,700.0 -75-0- 5007:30 07:30 10:24 7" chase to surface 8/27/2018 8/27/2018 1.50 PROD2 DRILL PULD P Tag up and space out, PJSM. Run 75.0 0.0 10:24 11:54 blocks to free ice. PUD BHA#12. Lay down FVS, Agitator, motor, and bit. Bit out 3-3 with chipped reamers and nose 8/27/2018 8/27/2018 0.50 PROD2 DRILL BOPE P P/U test joint. Perform Bi weekly 0.0 0.0 11:54 12:24 function test on stack 8/27/2018 8/27/2018 1.30 PROD2 DRILL PULD FVS, Agitiator, motor, and Hyc bi 0.0 78.0 12:24 13:42 bit, PD BHA #13. M/U to coil and surface test tool, Tag up and 4center ounters8/27/2018 8/2712018 1.50 PROM DRILL TRIP in hole, BHA#13, Shallow test 78.0 7,565013:42 15:12 tor - Good. Continue in Page 8/30 Report Printed: 9/1912018 Operations Summary (with Timelog Depths) 1H-21 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log smrc oepm Statl Tire EM Tkre Dur (lit) Phase Op Cotle AdiWty Cafe 7me P -T -X OperaOon (N(B) End Deem (m(B) 8/27/2018 8/272018 0.10 PROD2 DRILL DLOG P Log K1 for+1 foot 7,565.0 7,595.0 15:12 15:18 8127/2018 8/27/2018 1.40 PROD2 DRILL TRIP P . Set down @ 7966 and 8058 requiring 7,595.0 10,700.0 15:18 16:42 pick up. Stacking but no set downs, RIH 8/27/2018 827/2018 1.20 PROD2 DRILL DRLG P 10700', Drill, 1.79 BPM @ 4869 PSI 10,700.0 10,720.0 16:42 17:54 FS, BHP=42236 8/27/2018 8/27/2018 0.10 PROD2 DRILL WPRT P PU for mini wiper, PU WT=65K 10,720.0 10,720.0 17:54 18:00 8/27/2018 8/27/2018 5.20 PROD2 DRILL DRLG P 10720', Drill, 1.79 BPM @ 4776 PSI 10,720.0 10,984.0 16:00 23'.12 FS, BHP=4212 8/27/2018 8/27/2018 0.20 PROD2 DRILL WPRT P 100' Wiper, PU WT is 64K 10,984.0 10,984.0 23:12 23:24 8/27/2018 8/28/2018 0.60 PROD2 DRILL DRLG P 10984', Drill, 1.79 BPM @ 5016 PSI 10,984.0 10,994.0 23:24 00:00 FS, BHP --4253 8/28/2018 8/28/2018 2.00 PROD2 DRILL DRLG P 10984', Drill, 1.79 BPM @ 5016 PSI 10,994.0 11,100.0 00:00 02:00 FS, BHP=4253 8/28/2018 8/28/2018 1.80 PROD2 DRILL WPRT P 850" wiper, PU WT is 65K, pulled 11,100.0 11,100.0 02:00 03:48 heavy at 10980,10425 and 10305 828/2018 828/2018 3.10 PROD2 DRILL DRLG P 11100', Drill, 1.79 BPM @ 5196 PSI 11,100.0 11,216.0 03:48 06:54 FS, BHP=4333 826/2018 8/28/2018 0.20 PROD2 DRILL WPRT P Short wiper, PU WT is 72K 11,216.0 11,216.0 06:54 07:06 8/26/2018 8/28/2018 1.70 PROD2 DRILL DRLG P 11,216', Drill, 1.79 BPM @ 5126 PSI 11,216.0 11,244.0 07:06 08:48 FS, BHP=4310 8/28/2018 8/28/2018 0.20 PROD2 DRILL WPRT P Short wiper, PU WT is 72K, Hard time 11,244.0 11,244.0 08:48 09:00 gelling back down 8/28/2018 8/28/2018 2.50 PROD2 DRILL DRLG P 11,244', Drill, 1.79 BPM @ 5308 PSI 11,244.0 11,293.0 09:00 11:30 FS, BHP=4310 TD uncomfirmed 11,293'. PU Wt, 60 k Ibis 8/28/2018 828/2018 0.90 PROD2 DRILL CIRC P Stage sweeps to bit while RBIH to TD 11,244.0 11,293.0 11:30 12:24 8128/2018 8/28/2018 2.70 PROD2 DRILL WPRT P PUH on swab wiper trip chasing ,11,293.0 7,700.0 12:24 15:06 sweeps to surface. Slight increase in string weght and motor work from 10,400-10,000. RBIH, all clean, continue to POOH. Pull heavy, 68 k lbs, @ 9,917' RBIH, stack out -2, PUH, CT wt to 74 k lbs, RBIH, stack out -5 k, PU to 75 k lbs, RBIH stack out -8 k, PU, clean, PU 75 k, RBIH, all dean, PUH, all clean. Pump additional sweeps, Pull 75 k lbs CT wt, no WOB, @ 8090 in the build, continue out of hole. larg neg WOB @ 7947', 7907', & 7617' with small Ct Wt overpulls, continue up hole, window clean. Make two passes to the tubing tail cleanin up the 7" RBIH 8/28/2018 8/28/2018 0.20 PROD2 DRILL TRIP P RIH to clean up build. 7,700.0 7,840.0 15:06 15:18 Set down in window - 7818', PU 45 k lbs, RBIH 19 ft/min, pumps down while transiting the window, dean. 8/28/2018 8/28/2018 0.20 PROD2 DRILL DLOG P Tie into the RA tag for+13' correction. 7,840.0 7,860.0 15:18 15:30 Page 9130 ReportPrinted: 911 912 01 8 Summary (with Timelog Depths) 1 H-21 lipOperations Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log SMTmo End Time DW(hr) Phase Op Code Ao.q code e Stan Depth (flloil) End Depth (Po(B) 8/28/2018 8/28/2018 0.30 PROD2 DRILL WPRT 15 Continue to RIH in an alempt to clean 7,840.0 8,295.0 15:30 15:48 up the build section. Multiple set downs and WOB spikes with asociated coil wt spikes, 7956', 7960', 7995',8024',8119', 8/28/2018 8/28/2018 1.50 PROD2 DRILL WPRT P Pump 2x 10x10 sweeps, spaced apart 8,295.0 7,751.0 15:48 17:18 and chased up hole while pulling to surface. Slight neg WOB @ 8193', and 8160'. 7899' pulled -18 k WOB, worked pipe. Window clean. 8/28/2018 8/28/2018 1.37 PROD2 DRILL WPRT P Continue POOH (Swab Wiper), 7,751.0 79.0 17:18 1840 pumping 1.71 bpm @ 4,989 psi 8/28/2018 8/28/2018 1.33 PROD2 DRILL TRIP P Tag up, reset counter, set depths. RIH, 79.0 7,560.0 18:40 20:00 pumping 0.43 bpm @ 2,174 psi 8/28/2018 8/28/2018 0.20 PROD2 DRILL DLOG P Log the K1 marker correction of plus 7,560.0 7,594.0 20:00 20:12 1.0', PUW=46 k 8/28/2018 8/28/2018 0.22 PROD2 DRILL TRIP P Continue IH 7,594.0 7,805.0 20:12 20:25 8/28/2018 8/28/2018 0.40 PROD2 DRILL TRIP P Obtain Static Pressure, bleed down to 7,805.0 7,805.0 20:25 20:49 11.6 ppg (3835 psi), 20 min 10.6 (3,601 psi) 6/28/2018 8/28/2018 2.50 PROD2 DRILL TRIP P Continue IH towards bottom, (7,964', 7,805.0 11,293.0 20:49 23:19 7,994', & 8,029'), confirm TO 11,293' 8/28/2018 8/28/2018 0.50 PROD2 DRILL CIRC P PUW=68 k, send liner pill down coil 11,293.0 11,293.0 23:19 23:49 8/28/2018 8/29/2018 0.18 PROD2 DRILL TRIP P POOH, laying in 11.7 ppg beaded liner 11,293.0 10,946.0 23:49 00:00 running pill 8/29/2018 8/29/2018 1.15 PROD2 DRILL TRIP 15 Continue POOH, laying in 11.7 ppg 10,946.0 7,720.0 00:00 01:09 beaded liner running pill up to 7,720' 8/29/2018 829/2018 1.50 PROD2 DRILL TRIP P Continue POOH, displacing well to 7,720.0 79.0 01:09 02:39 11.7 ppg completion fluid 8/29/2018 8/29/2018 0.50 PROD2 DRILL OWFF P At surface, check well for flow, PJSM 79.0 79.0 02:39 03:09 for LD tools. 8/29/2018 8/29/2018 1.25 PROD2 DRILL PULD P LD drilling BHA on a dead well. 79.0 0.0 03:09 04:24 Note: Inspected Coil (0.120') 8/29/2018 8/292018 1.00 COMPZ2 CASING PUTB P Prep RF for liner ops 0.0 0.0 04:24 05:24 8/29/2018 8/29/2018 3.10 COMPZ2 CASING PUTB P Make up lower completion, non ported 0.0 1,545.0 05:24 08:30 bull nose, 50 joints, 4.6 ppf L-80 slotted liner, (1545'), under a shorty deployment sleeve, min ID Crew change w 19 joints in the hole, made up safety joint for hand over. Joint # 48 (31.76') slightly bent, decided to swap out, replaced with joint # 51 ( 31.77'). 8/29/2018 8/29/2018 1.30 COMPZ2 CASING PUTS P PJSM, MU BHA# 14, AL1 lower liner 1,545.0 1,590.0 08:30 09:48 running assembly, skid cart, inspect pack offs - replaced, pull and replace upper checks, stab injector, bump up, reset counters. 8/29/2018 8/29/2018 1.60 COMPZ2 CASING RUNL P RIH pumping min rate, CT Wt 8.63 k 1,545.0 7,954.0 09:48 11:24 lbs at surface. Pu Wt 52 k lbs, Tie into flag for -8.3' correction. Continue to run in hole. Lost 7 bbls on the trip in. Page 10130 ReportPrinted: 9/19/2016 Operations Summary (with Timelog Depths) 1 H-21 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log start Time Pndnine Dur(hr) Phase Op Cade Acw*Coda TMa P -T -X operation Stan Depth (ftKB) End Depth(fiKB) 8/29/2018 8/29/2018 1.10 C0MPZ2 CASING RUNL P Set down, 7954, slid through 1,545.0 8,495.0 11:24 12:30 Set down again 7986', tried multiple attempts and multiple speeds and SID weights, tried rolling the pump. No apparent progress. CT PU Wt 52 k lbs, WOB -13 k lbs until it breaks free and returns to -5.6 k lbs. 17 S/D's Picked up above original SID, RIH, slight bobble and bouced through. SID @ 8355' slowly slid through, 8398', 8460- 8/2912018 8/29/2018 0.60 COMPZ2 CASING RUNL P SD Q 8495', PIU, Pulled -23 k WOB, 8,495.0 8,500.0 12:30 13:06 cycled pipe to 74 K Ct Wt, pulled free, RBIH, selling down and draging heavy when PU to 75 k lbs. PUH to 8325' RBIH, lost ground, SID 8438'. Work pipe, -9 to -20 k WOB, CT Wt 48 - 68 k lbs when POOH. start making hole again slowly 8129/2018 8/29/2018 2.10 COMPZ2 CASING RUNL P Working pipe up to 80 k CT wt, - 24 K 8,500.0 9,432.0 13:06 15:12 1 WOB, on pickups, RIH, SID PU 8/29/2018 8/29/2018 5.00 COMPZ2 CASING RUNL P Continue working pipe towards 9,432.0 9,677.0 15:12 20:12 bottom, PUW 60 k, PUDHWOB=minus 12k 8/29/2018 8/29/2018 0.80 COMPZ2 CASING RUNL P Continue IH @ 30 fpm to bottom 9,677.0 11,293.0 20:12 21:00 11,288' 8/29/2018 8/29/2p18 0.20 COMPZ2 CASING RUNL P PUW=62 k, set back down, minus 2.5 11,293.0 11,293.0 21:00 21:12 k, bring pump up to 1.5 bpm @ 3,900 psi, 0.75 bpm returns, PUW= 48 k, liner is gone, remove liner length from counters, 8/29/2018 8/29/2018 0.75 COMPZ2 CASING CIRC P Finish building and circulate 11.7 ppg 11,293.0 11,293.0 21:12 21:57 beaded liner running pill. 8/29/2018 8/29/2018 1.00 COMPZ2 CASING TRIP P POOH, laying in 11.7 ppg beaded liner 11,293.0 7,545.0 21:57 22:57 running pill to 7,650' 8/29/2018 8/29/2018 0.20 COMPZ2 CASING DLOG P Log K1 marker correction of plus 16.5' 7,545.0 7,563.0 22:57 23:09 8/29/2018 6/30/2018 0.85 COMPZ2 CASING TRIP P POOH to surface 7,563.0 2,465.0 23:09 00:00 8/30/2018 8/30/2018 0.25 COMPZ2 CASING TRIP P Continue POOH 2,465.0 44.2 00:00 00:15 8/30/2018 8/30/2018 0.50 COMPZ2 CASING OWFF P At surface, check well for flow, PJSM 44.2 44.2 00:15 00:45 for liner ops 8/30/2018 8/30/2018 0.25 COMPZ2 CASING PULD P LD setting tools 44.2 0.0 00:45 01:00 8130/2018 8/30/2018 0.25 COMPZ2 CASING PUTS P Prep RF for liner ops 0.0 0.0 01:00 01:15 8/30/2018 8/30/2018 2.00 COMPZ2 CASING PUTB P PU/MU AL1 liner segment #2 w/30 jts 0.0 940.9 01:15 03:15 of slotted liner and ported bullnose 6/3012018 8/30/2018 0.75 COMPZ2 CASING PULD P PU/MU Coiltrak tools and BOT 3" GS, 940.9 985.1 03:15 04:00 stab INJH, surface test CTT (good - test) 8/30/2018 8/30/2018 3.00 COMPZ2 CASING RUNL P Tag up reset counters, RIH 985.1 9,751.0 04:00 07:00 window flag correction -6.43' Wt check above the window - 49 k lbs Tie into the K1 for a +5.5' correction, continue to RIH, tag bottom Q 9751' PU wl 54 k lbs, RBIH, slak 2 k lbs, Release off liner, PU 43 k lbs, TOL 8310' 8/30/2018 8/30/2018 1.10 COMPZ2 CASING CIRC P PUH, correct depths, circulate 18 bbl 9,751.0 8,795.0 07:00 08:06 beaded liner running pill to GS Page 11/30 ReportPrinted: 9/1912018 Operations Summary (with Timelog Depths) 1 H-21 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Steil Time End Time our (hr) Phase Op Coo Activity Cade Time P -T -X Operetlen Start DepM (110) End Deph(flKa) 8/30/2018 8/30/2018 0.50 COMPZ2 CASING DISP P PU 48 k lbs, POOH hole laying in 8,795.0 7,540.0 08:06 08:36 beaded liner running pill to 7,663' 8/30/2018 8/302018 0.20 COMM CASING DLOG P Tie into the Kt for a +2.5' correction 7,540.0 7,565.5 08:36 08:48 8/30/2018 8/30/2018 1.50 COMPZ2 CASING TRIP P Continue to POOH 7,565.5 50.0 08:48 10:18 8/30/2018 8/30/2018 0.70 COMPZ2 CASING PULD P Bump up, space out, Flow check, LD 50.0 0.0 10:18 11:00 1 1 1 BHA# 15 8/30/2018 8/30/2018 0.50 COMPZ2 CASING PUTB P Prep floor to run liner, PJSM 0.0 0.0 11:00 11:30 1 8/30/2018 8/30/2018 1.20 COMPZ2 CASING PUTB P PU AL1 section #3 completion, 3 0.0 863.8 11:30 12:42 pups, 27 joints, ( 863.78'), under shorty with a ported bullnose. Kick drill, AAR, PJSM. clear flow. 8/30/2018 8/3012018 1.20 COMM CASING PULD P PU BHA #15 -AL1 section #3 863.0 908.0 12:42 13:54 completion, check pack offs, skid cart stab on bump up space out. 8/30/2018 8/30/2018 2.20 COMPZ2 CASING RUNL P RIH W BHA#13. Tie into flag for -0.2' 908.0 8,812.0 13:54 16:06 correction, PU 48 k lbs, continue to RIH. drive by the K1 for a +0.5' correction. Continue in hole, tag up, 8812', PU Wt 53 k lbs, RSIH, set down 2 k lbs WOB, online w pump, PU Wt 42 k lbs. "'TOL 7947' 8/30/2018 8/30/2018 1.40 COMPZ2 CASING TRIP P Park, reset counters, POOH. 8,812.0 59.9 16:06 17:30 8/30/2018 8/302018 0.50 COMPZ2 CASING OWFF P At surface, check well for flow, Crew 59.9 59.9 17:30 18:00 change, PJSM 8/302018 8/30/2018 0.50 COMPZ2 CASING PULD P LD setting tools 59.9 0.0 18:00 18:30 8/302018 8/30/2018 0.50 COMPZ2 CASING PULD P PU/MU, Open hole anchored billet w/ 0.0 72.9 18:30 19:00 BOT J -hydraulic setting tool 6/30/2018 8/3012018 0.25 COMM CASING PULD P PU/MU, Coiltrak tools, stab INJH, 72.9 72.9 19:00 19:15 perform surface test (good -test) 8/30/2018 8/30/2018 2.00 COMPZ2 CASING RUNL P RIH, with BHA#17 Open Hole 72.9 7,565.0 19:15 21:15 Anchored Billet, @ 80 fpm/20 fpm jewelry 8/30/2018 8/302018 0.20 COMM CASING OLOG P Log the Ki marker no correction, 7,565.0 7,608.0 21:15 21:27 PUW 50 k 8/30/2018 8/30/2018 0.20 COMM CASING RUNL P Continue IH, tagging TOL @ 7,947 psi 7,608.0 7,947.0 21:27 21:39 8/30/2018 8/30/2018 0.20 COMPZ2 CASING RUNL P Set down 4.5 k DHWOB, PUW 49 k, 7,947.0 7,947.0 21:39 21:51 repeat, PUH to 0.3 k DHWOB, bring pump up 1.4 bpm, seen tool shift 3,077 psi, creep in hole back to 4.5 k, 7,947', PUW 44 k 8/30/2018 8/30/2018 1.20 COMM CASING TRIP P POOH 7,947.0 53.3 21:51 2303 8/30/2018 8/30/2018 0.50 COMPZ2 CASING OWFF P At surface. check well for flow, PJSM 53.3 53.3 23:03 2333 8/30/2018 8/31/2018 0.46 COMPZ2 CASING PULD P LD setting tools 53.3 0.0 23:33 00:00 8/31/2018 8/31/2018 1.00 FROM DRILL CTOP P MU Nozzle, stab INJH, jet surface 0.0 0.0 00:00 01:00 lines and stack, while displacing coil to FW. Sim -ops: grease valves and bop equipment. 8/31/2018 8/31/2018 0.75 FROM DRILL CTOP P Valve shop on location, service tree, 0.0 0.0 01:00 01:45 RD nozzle, remove BHI upper quick, cut/remove CTC, boot a -line Page 12130 Report Printed: 9/1 912 01 8 Operations Summary (with Timelog Depths) 1H-21 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Depth start Time EWTM our (hr) Phase Op Code ActlNly Corte T PTA Operation (flW End Depth(N(e) 8/31/2018 8/31/2018 0.25 FROM DRILL CTOP P Stab INJH, use both pumps, pump 0.0 0.0 01:45 02:00 slack 8/31/2018 8/31/2018 0.25 PRODS DRILL CTOP P Test inner reel valve and pac-off, 0.0 0.0 02:00 02:15 unstab INJH 8/31/2018 8/31/2018 0.50 FROM DRILL CTOP P PJSM, RU coiled tubing cutter 0.0 0.0 02:15 02:45 8/31/2018 8/31/2018 1.00 FROM DRILL CTOP P Cul Coiled tubing back to locate wire 0.0 0.0 02:45 03:45 1 1 (140') 8/31/2018 8/312018 2.45 FROM DRILL CTOP P Install CTC, pull test to 35 k good, 0.0 0.0 03:45 06:12 install UCQ, pressure test good, tested wire 1700Mohms, 69.8 ohms. 8/31/2018 8/3112018 1.30 FROM WHDBOP CTOP P Prep for BOP test, grease and service 0.0 0.0 06:12 07:30 valves, flood up. shell test - 3000 psi. 8/312018 8/31/2018 6.50 FROM WHDBOP BOPE P Prep for BOP test, grease and service 0.0 0.0 07:30 14:00 valves, flood up. shell test - 3000 psi. " Start test 7:30 Tree swab leaking slighlty Annular test took 52 minutes to trouble shoot some issues. 8/31/2018 8/31/2018 1.00 FROM WHDBOP CTOP P Clear floor from BOP testing, Valve 0.0 0.0 14:00 15:00 check list. 8/31/2018 8/31/2018 0.50 FROM DRILL SVRG P Took 30 minutes, dg service timet o 0.0 0.0 15:00 15:30 allow for Washington crane inspector to finish work on injector. 8/31/2018 8/31/2018 1.20 PRODS DRILL CTOP P Skid cart, install nozzle, stab injector, 0.0 0.0 15:30 16:42 turn reel over to kill weight fluid. PJSM, Open up to well, fill 3 bbls, flow check - good, unstab injector, skid cart. 8/312018 8/31/2018 0.70 PRODS STK PULD P PU BHA#18, AL2 lateral drilling 0.0 72.2 16:42 17:24 assembly, Re Run Baker dynamus bit under a 0.4+°AKO motor. 8/31/2018 8/31/2018 0.50 FROM STK TRIP P RIH 72.2 507.0 17:24 17:54 8/31/2018 8/31/2018 0.50 FROM STK TRIP T BHI MWD, check shots reviled 507.0 -7-22- 17:54 18:24 incontinency with the Hydraulic orienting Tool, Pull back to surface 8/31/2018 8/31/2018 0.50 PRODS STK PULD T PJSM, swap out HOT tools 72.2 0.0 18:24 18:54 8/31/2018 8/312018 0.25 FROM STK PULD P MU UQC, surface test tools (good- 0.0 72.2 18:54 19:09 test), stab INJH, tag up reset counters 8/31/2018 8/31/2018 1.50 PRODS STK TRIP P RIH 509.0 7,565.0 19:09 20:39 8/31/2018 8/31/2018 0.20 FROM STK DLOG P Log the K1 marker no correction 7,565.0 7,598.0 20:39 20:51 8/31/2018 8/31/2018 0.65 PRODS STK DISP P Finish displacing well to drilling fluid 7,598.0 7,805.0 20:51 21:30 8/31/2018 8/31/2018 0.20 PRODS STK TRIP P Close EDC, PUW 48 k 7,805.0 7,805.0 21:30 21:42 8/31/2018 8/31/2018 0.30 FROM STK TRIP P Continue IH through window dry tag 7,805.0 7,935.0 21:42 22:00 TOB @ 7,935', PUH, attempt to roll TF 180°, RIH, stack out, PBUH, roll TF as drilled, park 7,932' 8/31/2018 8/31/2018 1.25 FROM STK KOST P Bring pump online 1.75 bpm at 4,195 7,935.0 7,937.0 22:00 23:15 psi, WHP=274, BHP=4074, IA=O, OA=47, kickoff billet as per RP 8/31/2018 8/31/2018 0.25 PRODS DRILL DRLG P Drill Ahead, 1.75 bpm at 4,140 psi, 7,937.0 7,939.3 23:15 23:30 Diff=516 psi, WHP=304, BHP=4,055 psi, IA=O, OA=49 Page 13130 Report Printed: 9119/2018 Operations Summary (with Timelog Depths) 1 H-21 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log sten rime ad Tim Dir (hr) Phase Op Code Activity Code Time P -T -x Operation Stan Depth (MB) End Depth (III(B) 8/31/2018 8/31/2018 0.20 PRODS DRILL DRLG P Stack out weight, shut down pump, 7,939.3 7,939.3 23:30 2342 PUH 56 k to 7,930', RBIH, dry tag 7,939.3- 8/31/2018 9/1/2018 0.30 PRODS DRILL DRLG P PUH 7,930', PUW 52 k, bring pump on 7,939.3 7,939.6 23:42 00:00 -line 1.77 bpm at 4,288 psi, Diff --464 psi, WHP=261, BHP=4,037, IA=O, OA=49 9/1/2018 9/1/2018 1.00 PRODS DRILL DRLG P OBD, 1.77 bpm at 4,177 psi, Diff -467, 7,939.6 7,951.9 00:00 01:00 1 WHP=316, BHP=4,067, IA=O, OA=52 9/1/2018 9/1/2018 2.00 PRODS DRILL DRLG P OBD, 1.79 bpm at 4,154 psi, Diff --467 7,951.9 7,966.0 01:00 03:00 1 psi, WHP=314, BHP=4,054, IA=O, OA=53 9/1/2018 9/1/2018 1.75 PRODS DRILL DRLG P OBD, 1.76 bpm at 4,151 psi, Diff --467 7,966.0 7,972.0 03:00 04:45 psi, WHP=295, BHP=4,076, IA=7, OA=57 — Note: Bit balling PUH creep in hole slowly, continue drilling ahead slowly t@ 20 tph 9/1/2018 911/2018 2.00 PRODS DRILL DRLG P OBD, 1.77 bpm at 4,250 psi, Diff --467 7,972.0 8,028.0 04:45 06:45 psi, WHP=329, BHP=4,039, IA=19, OA=58 Pump 5x5 sweep 9/12018 9/1/2018 1.00 PRODS DRILL DRLG P OBD, CT4403 psi, WH 317 psi, 4145 8,028.0 8,100.0 06:45 07:45 psi annular, IA 54 psi, OA 60 psi Ratty drilling cleaned up, ROP 70 ft/hr, CT Wt 16 k lbs, WOb 1.9 k lbs Some aluminum, clean cuttings, stickier than normal. Pump 5x5 sweep in anticipation of TD. 9/1/2018 9/1/2018 0.30 PRODS DRILL WPRT P TD build early per DO and Geo. 8,100.0 7,957.0 07:45 08:03 PU 52 k lbs, sweeps out the bit, chase up hole to ITT, while slowly PUH. Orient low side for billet, small neg WOB tug while orienting, small neg WOB spike passing the billet at min rate. RBIH, dry drift billet, small WOB spike below the billet, assuming BHA binding up. 9/12018 9/1/2018 1.70 PRODS DRILL TRIP P PU, 50 k IDS, 7,957.0 71.0 08:03 09:45 POOH, billet clean again. Pull through window clean. Slow pass at rate cleaning up 7" to TT, Pull into tubing, Open EDC. POOH for let drilling BHA 9/1/2018 9/1/2018 2.30 PRODS DRILL PULD P PJSM, discussed high bend motor, 71.0 0.0 09:45 12:03 bump up, attempt to pull tool, hung up from the outset, PJSM, pop off, orient tool 180 °, reaftempt with DS PDL winch, its a little faster, tool pulled free with no issue. - 1 hr added time due to hang up. PUD BHA#19. 911/2018 9/112018 1.30 PRODS DRILL PULD P PU BHA#20, AL2 lateral drilling 0.0 80.0 12:03 13:21 assembly, 0.6° AKO, W HYC - SR321 M -Ai 11 mm w 3D nose cutters, test good, skid cart, stab injector, bump up, set counters 9/12018 9/12018 1.40 PRODS DRILL TRIP P RIH, close EDC, Test agitator @ 1.7 80.0 7,565.0 13:21 14:45 bpm and 500'- good, continue in hole. 9!1/2018 9/1/2018 0.20 PRODS DRILL DLOG P Tie into the K1 for a 0.5' correction, 7,565.0 7,590.0 14:45 14:57 9/1/2018 9/1/2018 0.50 PRODS DRILL TRIPP CT PU Wt, 44 k lbs, continue to RIH, 7,590.0 8,101.0 14:57 15:27 window and billet both clean, build clean. Page 14130 Report Printed: 9/1912018 Summary (with Timelog Depths) IH-21 lipOperations Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log rt Start Depth Stan Trine End Tune Dur(hr) Phase op Code Activi Code ry Torre P-T-X operation KS) End Depth (fiKB) 9/1/2018 9/1/2018 1.90 PRODS DRILL DRUG P CT 4176 psi @ 1.77 bpm, annular 8,101.0 8,220.0 15:27 17:21 4124 psi, Free spin diff 960 psi. OBD, CT Wt 15.6 k lbs, WOB 2.0 k Ibs, ROP 70 fUhr. 9/1/2018 9/1/2018 4.50 PRODS DRILL DRLG P OBD, 1.80 bpm at 4,851 psi, 8,220.0 8,505.0 17:21 21:51 Diff--1,100 psi, BHP=4,155, IA=212, OA=57 9/1/2018 9/1/2018 0.25 PRODS DRILL WPRT P Wiper up hole to 8, 100'w/sweeps, 8,505.0 8,100.0 21:51 22:06 1 PUW=53 k 9/1/2018 9/1/2018 0.25 PRODS DRILL WPRT P Wiper back in hole, RIW 8,100.0 8,505.0 22:06 22:21 9/1/2018 9/2/2018 1.65 PRODS DRILL DRLG P BOBD, 1.82 bpm @ 4,707 psi, 8,505.0 8,612.0 22:21 00:00 Diff=1,000 psi, WHP=263, BHP=4,134, IA=213, OA=57, Avg. ROP=60 fph/2.6 it DHWOB 9/2/2018 9/2/2018 1.30 FROM DRILL DRLG P OBD, 1.79 bpm at 4,977 psi, 8,612.0 8,692.0 00:00 01:18 Diff--1,000 psi, WHP=251, BHP=4,170, IA=346, OA=60 9/2/2018 9/2/2018 0.80 PRODS DRILL DRLG P OBD, 1.76 bpm at 5,339 psi, 8,692.0 8,768.0 01:18 02:06 Diff=1,100 psi, WHP=256, BHP=4,156, IA=365, OA=60, Avg.Rop=65 fph/2.4 k DHWOB 9/2/2018 9/2/2018 1.80 FROM DRILL DRUG P OBD, 1.80 bpm @ 5,209 psi, 8,768.0 8,930.0 02:06 03:54 Diff--1,050 psi, WHP=275, BHP=4,221, IA=396, OA=61, Avg. ROP=112 fph 9/2/2018 9/2/2018 1.00 PRODS DRILL WPRT P Wiper up hole to the window, PUW 53 8,930.0 7,840.0 03:54 04:54 k, jog the 7" casing with sweeps up to 7,707'. circulate BU. 9/2/2018 9/2/2018 0.20 PRODS DRILL DLOG P Log the Kt marker correction of plus 7,840.0 7,877.0 04:54 05:06 4,5' 9/2/2018 9/2/2018 0.50 PRODS DRILL WPRT P Wiper back in hole, RIW 14 k 7,877.0 8,930.0 05:06 05:36 Seeing same MWD issues as yesterday, tool is rolling as we near the window and billet. Possibly geometry issues, not electrical. 9/2/2018 9/2/2018 2.40 PRODS DRILL DRLG P Free spin Of 970 psi' , initially 1,100 8,930.0 9,153.0 05:36 08:00 psi dropped once we were on bottom for a bit. IA 470 psi, OA 64 psi, CT 5142 psi, @ 1.78 bpm, Annular 4172 psi CT Wt - 6 k lbs, WOB 1-2 k lbs, ROP 60 - 150 ft/hr' some siderite chips in the cuttings samples Average ROP over section - 93 ft/hr 9/2/2018 9/2/2018 0.20 PRODS DRILL WPRT P PU Wt 54 k lbs, Geo wiper to 9,47', 9,153.0 9,153.0 08:00 08:12 RBIH, RIH Wt 12 k lbs ' - 1,700' on the mud, solids @ 0.7, inlet density up to 8.87 ppg Geo asked for 16' decrease in TVD in the next 100' feel, 9/2/2018 9/2/2018 2.30 FROM DRILL DRLG P CT 4953 psi, @ 1.78 bpm, Annular 9,153.0 9,299.0 08:12 10:30 4195 psi, Free spin diff 950psi OBD, CT Wt 0-2 k lbs, WOB 1.6 k lbs, ROP 100 fUhr BHA wipers, PD's - 50 k lbs, hard stringers. resistivity increasing from 9180' on. Lots of tool face changes, Pick ups climbed from 50 to 68 k. Pump sweeps. Pick ups still climbing,.. Average ROP over section - 63 fUhr Page 15/30 ReportPrinted: 911912018 Operations Summary (with Timelog Depths) 1 H-21 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log SWMDepth Stat Time End Time Dur (hr) Phase Op Code AWhity Code Time P -T -x Operation (We) End Depth (MB) 9/2/2018 9/2/2018 0.50 PRODS DRILL WPRT P PU Wt 71 k lbs, Pull wiper early. #1 9,299.0 8,100.0 10:30 11:00 -1.2 k WOB pull @ 9257', we'd had issues passing this spot earlier on BHAwipers Seeing free spin diff fluctuate from 960 psi to 1200 psi. It doesn't appear to be motor work, agitator kicking in and out?? 9/2/2018 9/2/2018 0.70 PRODS DRILL WPRT P RBIH 8,100.0 9,299.0 11:00 11:42 SD - 8686' PU 52 k, RBIH, 500 Ib WOB spike at 8700, SD,- 8960', PU 50 k, SD,- 9228', PU 50 k, 9/2/2018 9/2/2018 3.40 FROM DRILL DRLG P CT 5121 psi, @ 1.79 bpm, Annular 9,299.0 9,490.0 11:42 15:06 4142 psi, Free spin diff 1140psi OBD, CT Wt -2-2 k lbs, WOB 1.3 k lbs, ROP 100 film Pick ups -52-62 k lbs. Start exporting mud outside - 12:49 - in prep for mud swap. Started new mud @ 14:30 •"New mud at the bit - 9487' Average ROP over section - 76 ff/hr 9/2/2018 9/212018 2.20 FROM DRILL DRLG P PU to get new parameters 9,490.0 9,564.0 15:06 17:18 CT 4744 psi, @ 1.8 bpm, Free spin 940 psi - annular 4190 psi OBD CT -4-0 k lbs, WOB 1.6 to 2 k lbs. ROP 60 - 10 fl/hr On somthing hard starting 9546' 9/2/2018 912/2018 1.50 PRODS DRILL DRLG P BOBD, 1.77 bpm at 4,180 psi, 9,564.0 9,621.0 17:18 18:48 Diff -1,100 psi, WHP=403, BHP=4,165, IA=317, OA=62 9/2/2018 9/2/2018 0.20 FROM DRILL WPRT P Pull Geo Wiper up hole PUW 61 k 9,621.0 9,520.0 18:48 19:00 9/2/2018 9/2/2018 0.20 FROM DRILL WPRT P Wiper back in hole, RIW 12.4 k 9,520.0 9,621.0 19:00 19:12 9/2/2018 9/212018 2.50 FROM DRILL DRLG P BOBD, 1.79 bpm at 4,650 psi, 9,621.0 9,702.0 19:12 21:42 Diff --1,120 psi, WHP=401, BHP=4,167, IA=320, OA=62 9/2/2018 9/2/2018 1.25 FROM DRILL WPRT P Wiper to the window, PUW 55 k, jog 9,702.0 7,840.0 21:42 22:57 the 7" with sweeps 9/2/2018 9/2/2018 0.20 FROM DRILL DLOG P Log the RA marker correction of plus 7,840.0 7,864.0 22:57 23:09 6.0' 9/2/2018 9/2/2018 0.20 FROM DRILL WPRT P Wiper back in hole, RIW 14 k 7,864.0 9,702.0 23:09 2321 9/2/2018 9/3/2018 0.65 PRODS DRILL DRLG P BOBD, 1.77 bpm at 4,583 psi, Diff 9,702.0 9,714.0 23:21 00:00 886, WHP=324, BHP=4,188, IA=292, OA=61 9/3/2018 9/3/2018 1.25 FROM DRILL DRLG P OBD, 1.77 bpm at 4,609 psi, 9,714.0 9,737.0 00:00 01:15 Diff --1,138 psi, WHP=332, BHP=4,197, IA=311, OA=61 9/3/2018 9/3/2018 1.20 PRODS DRILL DRLG P OBD, 1.78 bpm at 4,690 psi, Diff --863, 9,737.0 9,745.0 01:15 02:27 WHP=362, BHP=4,182, IA=374, OA=62 9/3/2018 9/3/2018 2.00 FROM DRILL DRLG P OBD, 1.7 bpm at 4,576 psi, Diff=863 9,745.0 9,789.0 02:27 04:27 psi, WHP=367, BHP=4,190, IA=424, OA=62 9/3/2018 9/3/2018 1.70 FROM DRILL DRLG P OBD, 1.82 bpm at 4,727 psi, Diff --883 9,789.0 9,843.0 04:27 06:09 psi, WHP=346, BHP=4,197, IA=489, OA=63 Page 16/30 ReportPrinted: 911912018 . Operations Summary (with Timelog Depths) 1 H-21 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Lag Start Oeplh Stan Time Erb Time Dir(W) Phase O Code Op v4y Actl' COW Time P -T -X 0 eabon p (MB) EM Depth (flKB) 9/3/2018 9/3/2018 2.50 FROM DRILL DRLG P PU to check parameters, CT Wt 52 k 9,843.0 9,908.0 06:09 08:39 lbs, IA 531 psi, OA 66 psi CT 4780 psi @ 1.80 bpm, Annular 4232 psi, free spin 960 psi OBD, CT Wt -2 k lbs, WOB 1 k lbs, ROP 10-60 9852' on something hard, high vibrations, drilled through 9861'- PU CT 52 k lbs, Choke acting up, swap to choke B, choke B acting up, blow down A. same issues on both, drill ahead 9/3/2018 9/3/2018 0.20 FROM DRILL WPRT P On PU, rebooted the coke controler, 9,908.0 9,908.0 08:39 08:51 same issue, RBIH Running off choke Ain manual mode. 9/3/2018 9/3/2018 2.70 PROD3 DRILL DRLG P OBD, Ratty drilling, hard srtringers 9,908.0 9,987.0 08:51 11:33 with CT Wt -5k and 2 k WOB, ROP 2- 10 ft/hr for 1-2 feet followed by CT Wt -4 K, WOB 0.8 k lbs & 40-100 ft/hr for 10-15'. Average ROP over interval 29 ft/hr 9/3/2018 9/3/2018 2.00 FROM DRILL DRLG P PU WT 57 k lbs, bypass screens, RIH 9,987.0 10,018.0 11:33 13:33 Wt 9 k lbs, CT 4240 psi, 1.71 bpm, Free spin 830 psi. WH 380 psi, annular 4218 psi. OBD, CT Wt -4 k lbs, WOB 1.4 k lbs, ROP9.2 Pump 15 bbls of 1 ppb beads, noticed .5 k lbs increase in WOB when on the hard stuff, no other observable benifits, CT weight, ROP, etc. Tried same pill with 4% lubes, less of a result. Beads in returns are causing annular flucuations that are hard to manage with the choke on manual. 9/3/2018 9/3/2018 4.00 PRODS DRILL DRLG P Drill ahead hard stringers followed by 10,018.0 10,100.0 13:33 17:33 soft. OBD, CT 4900 psi @ 1.78 pbm, Annular 4271 psi. WH 360 psi, IA 638, OA 70 psi CT Wt -4 k lbs, WOB 0.8 k lbs, ROP 8 Average ROP 20 ft/hr over interval. 9/3/2018 9/3/2018 1.80 FROM DRILL WPRT P Wiper to the window, PUW 50 k, jog 10,100.0 7,710.0 17:33 19:21 1 1 the 7" with sweeps, up to 7,710' 9/3/2018 9/3/2018 0.15 FROM DRILL SVRG P Reboot Choke software, (5 min) 7,710.0 7,840.0 19:21 19:30 9/3/2018 9/3/2018 0.20 FROM DRILL DLOG P Log the RA marker correction plus 4.0' 7,840.0 7,868.0 19:30 19:42 9/3/2018 9/3/2018 0.80 FROM DRILL WPRT P Wiper back in hole, RIW 12 k 7,868.0 10,100.0 19:42 20:30 9/3/2018 9/3/2018 1.15 FROM DRILL DRLG P BOBO, 1.78 bpm at 4,837 psi, 10,100.0 10,125.0 20:30 21:39 Diff -863, WHP=308, BHP=4,216, IA=548, OA=68 Average ROP 17 ft/hr over interval. Page 17/30 ReportPrinted: 9/1912018 Summary (with Timelog DtNths) 1 H-21 lipUtierations Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Stars TWO End Time Dor(hr)Phase Op Cods Admly Cole Time P -T -X operation Start Depth (WB) EM DePrh(rtl(9) 9/3/2018 9/3/2018 1.80 PRODS DRILL WPRT P Wiper up hole to the window, PUW 47 10,125.0 7,710.0 21:39 23:27 k — Note: Pull heavy @ 7,896'- 7,906' MD, CTWS=65 k, DHWOB= minus 12 k, RBIH to the EOB, PUH w/sweeps, cleanup area between billet and vdnodw, jog the 7" with sweeps, 9/3/2018 9/4/2018 0.56 PROD3 DRILL TRIP P POOH 7,710.0 5,571.0 23:27 00:00 9/4/2018 9/4/2018 1.25 PROD3 DRILL TRIP P Continue trip to surface 5,571.0 78.2 00:00 01:15 9/4/2018 9/4/2018 1.75 PROD3 DRILL PULD P PUD (ODS -PDL) AL2 drilling BHA#20 78.2 0.0 01:15 03:00 Note: Checks failed, change of scope meeting in the ops cab, continue PUD w/failed checks checklist. 9/4/2018 9/4/2018 1.50 PROD3 DRILL PULD P PD, pre -loaded DS PDL BHA# 21, 0.0 78.1 03:00 04:30 stab INJH, surface test Coiltrak tools (good -test) 9/4/2018 9/4/2018 1.50 PROD3 DRILL TRIP P Tag up reset counters, RIFF_78.1 7,298.0 04:30 06:00 9/4/2018 9/4/2018 0.20 PRODS DRILL DLOG P Tie into the Kt for no correction. 7,298.0 7,585.6- 06:00 06:12 9/4/2018 9/4/2018 1.50 PROD3 DRILL TRIP P PU Wt 43 k lbs, continue in hole, 7,585.0 10,125.0 06:12 07:42 window and billet clean. Still having erratic orienteer issues between the window and the billet. WOB spke @ 8187', 4 k & 8540, 1 k. Had to slow down running speed from 50 to 17 ft/ min - 9100 SD - 9245', 9759110024', 9/4/2018 9/4/2018 2.30 PROD3 DRILL TRIP P IA 152 psi, OA 59 psi, CT 5200 psi @ 10,125.0 10,251.0 07:42 10:00 1.77 bpm, free spin 1100 psi, WH 301 psi, Annular 4282 psi. RIH Wt 8 k lbs OBD, CT Wt 3 k lbs, WOB 2 k lbs, ROP 30-160 ft/hr Average ROP over interval - 54 ft/hr 9/4/2018 9/4/2018 2.80 PROD3 DRILL TRIP P OBD, CT Wt -3 k lbs, WOB 0.6 k lbs, 10,251.0 10,360.0 10:00 12:48 ROP 40 ft/hr Surface and WOB slowly falling off. tried new mud pill, no change in parameters. PU weights - 55-59 k lbs Average ROP over interval - 39 ft/hr 9/4/2018 9/4/2018 1.20 PROD3 DRILL TRIP P start pumping 1 ppb beaded pills built 10,360.0 10,425.0 12:48 14:00 of used mud. beaded pill at the bit @ 10360'. Weights and ROPs improved. PU weights - 50 k lbs Average ROP over interval - 54 ft/hr 9/4/2018 9/4/2018 2.20 PROD3 DRILL TRIP P Managed to break through what ever 10,425.0 10,525.0 14:00 16:12 was below us and get turned down below 92 °. CT Wt -6 to -1 k lbs, WOS 2 to 0.6 k lbs, ROP 20 to 90 ft/hr Settled in at - 86° PU Wt's 50 k lbs Average ROP over interval - 45 ft/hr 9/4/2018 9/4/2018 0.30 PROD3 DRILL TRIP P PU on wiper trip #1 PU Wt 55 k lbs - 10,525.0 9,526.6- 116:12 16:30 1 1 1000' Page 18130 - Report Printed: 9119/2018 Operations Summary (with Timelog Depths) 1 H-21 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Siert Depth Start Time End Tone Dw hr ( ) Phase Op Code Activity Code Time P-T-X Operatlon (flKB) End Depth (fiKB) 9/4/2018 9/4/2018 1.50 PROD3 DRILL TRIP P RBIH 9,526.0 10,522.0 16:30 18:00 SD, 9561', PU, 50 k lbs, slow RIH speed to -25 ft/min, continue in hole Pump beaded sweep. 9/4/2018 9/4/2018 1.00 PROD3 DRILL WPRT P Pull wiper to the casing, PUW 63 k, 10,522.0 7,705.0 18:00 1900 (Town working on well plan changes) 9/4/2018 9/4/2018 0.40 PROD3 DRILL WPRT P Jag the 7" x 2, PUW 42 k 7,705.0 7,840.0 19:00 19:24 9/4/2018 9/4/2018 0.20 PROD3 DRILL DLOG P Log the RA, plus 6', PUW 43 k 7,840.0 7,868.0 19:24 19:36 9/4/2018 9/4/2018 2.50 PROD3 DRILL WPRT P Wiper back in hole, RIW= 0 k, send 5 7,868.0 10,525.0 19:36 22:06 x5 sweep with beads, work pipe back to bottom. 914/2018 9/5/2018 1.90 PROD3 DRILL DRLG P BOBD, 1.79 bpm at 5,262 psi, 10,525.0 10,610.0 22:06 00:00 Diff--1,150 psi, WHP=283, BHP=4,260.IA=575, OA=66 9/5/2018 9/5/2018 1.00 PROD3 DRILL DRLG P OBD, 1.77 bpm at 5,478 psi, 10,610.0 10,630.0 00:00 01:00 Diff--1,200, WHP=298, BHP=4,313, IA=622, OA=67 9/5/2018 9/5/2018 1.00 PROD3 DRILL DRLG P OBD, 1.77 bpm at 5,472 psi, 10,630.0 10,667.0 01:00 02:00 Diff--1,300 psi, WHP=283, BHP=4,302, IA=622, OA=67 9/5/2018 9/5/2018 0.50 PROD3 DRILL WPRT P PUW 80 k, Pull 1,000' wiper up hole to 10,667.0 9,660.0 02:00 02:30 9,660- 9/512018 9/5/2018 1.20 PROD3 DRILL WPRT P Wiper back in hole, RIW 2-6 k CTSW 9,660.0 10,667.0 02:30 03:42 9/5/2018 9/5/2018 2.30 PROD3 DRILL DRLG P BOBO, 1.75 bpm at 5,437 psi, 10,667.0 10,712.0 03:42 06:00 Diff--1,211 psi, WHP=277, BHP=4,419, IA=566, OA=69 9/5/2018 9/5/2018 1.90 PROD3 DRILL DRLG P Drill ahead with poor weight transfer 10,712.0 10,756.0 06:00 07:54 Average over interval 23 ft/hr 9/5/2018 9/5!2018 0.60 PROD3 DRILL WPRT P PU Wt 65 k on BHA wiper - 106' 10,756.0 10,756.0 07:54 08:30 Pull to 10,665' try to RBIH, SID, PU 46 k lbs, to 10,650', RBIH 9/5/2018 9/5/2018 2.00 PROD3 DRILL DRLG P Drilling ahead with poor weight 10,756.0 10,821.0 08:30 10:30 transfer CT Wt -8 k lbs, WOB 2.4 k lbs after a pick up but falls to 200 lbs quickly after a pick up. Having issues turning around after picking up. PU weights climbed to 70 k. Misr and pump 1 ppg beaded pill in new mud w 4% total lubes. ROP increased, RIH ease increased, PU's fell to 55 k lbs. Able to tum up and break through hard layer that we'd been gelling deflected off. Average over interval 32 ft/hr 9/5/2018 9/5/2018 0.60 PROD3 DRILL WPRT P PU Wt 53k on 1000' wiper #2 10,821.0 9,823.0 10:30 11:06 Pull to 10,665' try to RBIH, SID, PU 46 k lbs, to 10,650', RBIH 9/5/2018 9/5/2018 0.60 PROD3 DRILL WPRT P RBIH RIH Wt fell from 13 k lbs at tum 9,823.0 10,821.0 11:06 11:42 around to 6 k lbs by 10,500' and 4 k lbs at 12 ft/min and TD 9/5/2018 9/5/2018 3.30 PROD3 DRILL DRLG P CT 5,420 psi @ 1.72 bpm, annular 10,821.0 10,932.0 11:42 15:00 4370 psi, WH 240 psi, Free spin diff 11,70 psi. WOB -8 to 0 k lbs, WOB 2 to 0.6 k lbs, ROP 80 to Average over interval 33 ft/hr Page 19130 ReportPrinted: 9119/2018 Operations Summary (with Timelog Depths) 1H-21 lip Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Stan TM End rime Ow(hr) Phase OP CDde Ad yCode Time P -T-% Opemtlon Sten Depm (m(a) End Depth(MB) 9/5/2018 9/5/2018 2.50 PRODS DRILL DRLG P OBD, CT 5533 psi, @ 1.73 bpm, WH 10,932.0 11,007.0 15:00 17:30 287 psi, annular 4278 psi. CT Wt -7.5 k lbs, WOB 1.3 k lbs, ROP 35 R/hr. Bleed IA from 745 to 586 psi - diesel. Average over interval 30 ft/hr 9/5/2018 9/5/2018 5.75 PRODS DRILL DRLG P OBD, 1.8 bpm at 5,265 psi, Diff -1.207 11,007.0 11,130.0 17:30 23:15 psi, WHP=246, BHP=4,268, IA=574, OA=74 "" Note: Losses 0.6 bpm slowly healing up to 0.1 bpm loss rate @ 11,110' 9/5/2018 9/5/2018 0.25 PROD3 DRILL DRLG P TDAL2 Lateral, PUH slowly, PUW 55 11,130.0 11,130.0 23:15 23:30 k, circulate beads down coil. 9/5/2018 9/6/2018 0.50 PRODS DRILL WPRT P Perform Swab wiper, laying in beads 11,130.0 9,641.0 23:30 00:00 as we POOH to surface. 9/6/2018 9/6/2018 2.00 PRODS DRILL WPRT P Continue POOH 9,641.0 3,500.0 00:00 02:00 9/6/2018 9/6/2018 1.10 PRODS DRILL WPRT P Perform jog back in hole 500' 3,500.0 78.1 02:00 03:06 9/6/2018 9/6/2018 0.40 PROD3 DRILL SVRG P Tag up, inspect INJH, repair CTES 78.1 78.1 03:06 0330 counter, reset counters 9/6/2018 9/612018 1.25 PRODS DRILL TRIP P RBIH, to confirm TD 78.1 7,570.0 03:30 04:45 9/6/2018 9/6/2018 0.20 PRODS DRILL DLOG P Log the K1 marker correction of plus 7,570.0 7,753.0 04:45 04:57 1,01 9/6/2018 9/612018 0.20 PRODS DRILL CTOP P Obtain Static BHP 11.39 ppg pressure 7,753.0 7,753.0 04:57 05:09 continued to drop, sensor Depth 6,484.67', AP=3,840 9/6/2018 9/6/2018 1.90 PRODS DRILL TRIP P Continue to RIH, Window clean, 705 7,753.0 11,128.0 05:09 07:03 Ib WOB bobble while passing the billet and a nother @ 8519'. Coil weight fell off rapidly from 9700' to 10,213' where we sat down. PU 45 k lbs. continue to RIH reducing tripping speed to - 14 fV.min. WOB climbed stedily from 10,500'to 10,700' then fell off quickly. Tqag bottom at 11128', PU 43 k lbs, SID again with same results. 9/6/2018 9/6/2018 3.10 PRODS DRILL DISP P PU 43 k lbs, Stage beaded liner 11,128.0 70.0 07:03 10:09 running pill to the bit, POOH laying in liner running pill to 7,680' followed by 11.7 ppg KW fluid. Painted yellow TO flag @ 10176' Saw slight neg WOB spikes as we pulled through both the billet and window. Painted white window flag @ 6778' 9/6/2018 9/6/2018 1.30 PRODS DRILL DISP P PJSM, bump up, flow check- good, 70.0 0.0 10:09 1127 PUD BHA#21 Bit came out graded 1-3 LT, lost tooth on gauge reamers. Well tight, no losses. 9/6/2018 9/6/2018 0.30 COMPZ3 DRILL BOPE P Perform BOP function test. 0.0 0.0 11:27 11:45 9/6/2018 9/6/2018 0.50 COMM CASING PUTS P Prep floor for running liner. PJSM. 0.0 0.0 11:45 12:15 9/6/2018 9/6/2018 1.70 COMPZ3 CASING PUTS P Pick up an run 30 joints (937.63') 2-3/8 0.0 938.9 12:15 13:57 ST -L 4.6 lb/fit L-80 slotted liner with a non -ported bullnose under a shorty deployment sleeve. AL2 completion run #1 length over all - 938.87' - kick drill, AAR, clean floor from running liner. Page 20/30 ReportPrinted: 9119/2018 Operations Summary (with Timelog Depths) 1 H-21 li p Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Stert OePU Stat Tim EM Tim Oia(hd phase Cp Code Activ' Cade M Time P -T-% Operation (flKB) End Depth (11103) 9/612018 9/612018 1.00 COMPZ3 CASING PULD P PU / MU BHA# 22, AL2 completion 938.0 983.1 13:57 14:57 run #1, swap checks, skid cart, stab on, test good, bump up, set counters, 9/6/2018 9/6/2018 1.30 COMPZ3 CASING RUNL P RIH w AL2 completion run #1 983.1 7,673.0 14:57 16:15 9/6/2018 9/6/2018 0.20 COMPZ3 CASING DLOG P PU 45 k lbs, tie into window flag for - 7,673.0 7,683.0 16:15 16:27 4.4' correction 9/6/2018 9/6/2018 1.30 COMPZ3 CASING RUNL P Continue to RIH, carried 16 k coil wt 7,683.0 11,128.6 16:27 17:45 all the way to bottom. Tag up, PU 53 k lbs, pumps on PU 43 k lbs. 916/2018 9/6/2018 2.25 COMPZ3 CASING TRIP P Reset counters, POOH painting flags. 11,128.6 44.2 17:45 20:00 9/6/2018 9/6/2018 0.50 COMPZ3 CASING OWFF P Check well for flow, PJSM 44.2 44.2 20:00 20:30 9/612018 9/6/2018 0.25 COMPZ3 CASING PULD P LD setting tools on a dead well 44.2 0.0 20:30 20:45 9/6/2018 9/6/2018 2.25 COMPZ3 CASING PUTB P PJSM, PU/MU AL2 #2 Liner segment 0.0 1,376.4 20:45 23:00 45 its of slotted liner, w/ported bullnose, and shorty deployment sleeve. 9/6/2018. 9/62018 0.75 COMPZ3 CASING PULD P PJSM, PU/MU Coiltrak tools (good- 1,376.4 1,420.6 23:00 23:45 test) 9/6/2018 9/7/2018 0.25 COMPZ3 CASING RUNL P RIH', with BHA#23, AL2 liner segment 1,420.6 23:45 00:00 #2 w/45 its of slotted liner, shorty deployment sleeve, and ported Dullness. 9/7/2018 9/7/2018 1.00 COMM CASING RUNL P Continue IH with BHA#23 2,596.0 7,705.0 00:00 01:00 9/7/2018 9/7/2018 0.15 COMPZ3 CASING RUNL P Weight check PUW 49 It, correct to 7,705.0 7,705.0 01:00 01:09 1 the EOP flag minus 8.0' 9/7/2018 9/7/2018 0.35 COMM CASING RUNL P Continue IH 7,705.0 9,067.0 01:09 01:30 91712018 9/7/2018 0.75 COMM CASING RUNL P Work pipe down hole, PUW 50-58 k 9,067.0 9,343.0 01:30 02:15 9/7/2018 9/7/2018 0.30 COMPZ3 CASING RUNL P Continue RIH 9,343.0 10,189.1 02:15 02:33 9/7/2018 9/72018 1.30 COMPZ3 CASING RUNL P Set down 10,189.13', PUW 58 k, set 10,189.3 8,812.7 02:33 03:51 back down 5.4 k, Bring pump on 1.45 bpm at 3,291 psi, 1.06 bpm returns, PUW 39 k, remove liner length from counters, finish building liner running pill. 9/7/2018 9/7/2018 2.30 COMPZ3 CASING TRIP P POOH, laying in 15 bbl beaded liner 8,812.7 40.0 03:51 06:09 running pill 9/7/2018 9/7/2018 0.60 COMM CASING PULD P Bumped up, flow check good, hole 50.0 0.0 06:09 06:45 static. 9/7/2018 9/7/2018 0.30 COMPZ3 CASING PUTB P Prep floor for liner running, PJSM. 0.0 0.0 06:45 07:03 917/2018 9/7/2018 1.00 COMPZ3 CASING PUTB P Pick up an run 10 joints (312.94') 2-3/8 0.0 324.8 07:03 08:03 ST -L 4.6 Ib/ft L-80 slotted liner with a non -ported bullnose under an anchored liner top billet. AL2 completion run #3 length over all - 324.76' - clean floor from running liner. 9/7/2018 9/7/2018 1.00 COMPZ3 CASING PULD P PU BHA #24, stab on, set counters 324.8 385.7 08:03 09:03 9/7/2018 9/7/2018 1.70 COMPZ3 CASING RUNL P RIH w AL2-01section #3, EDC open, 385.7 7,785.0 09:03 10:45 Page 21130 ReportPrinted: 9119/2018 Operations Summary (with Timelog Depths) IH -21 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Stat Time End Time our(hr) Phase Op Code Activity Code Tore P -T -x opeatlon stag Depth (IIXB) End Depth(fl(a) 9/712018 9/7/2018 0.20 COMPZ3 CASING DLOG P Tie in to window flag, -25' correction, 7,785.0 7,785.0 10:45 10:57 discuss and compare, not making a correction, continue on to the K1. PU Wt 43 k IDS. Park Close EDC. RIH to K1 9/7/2018 9/7/2018 0.10 COMPZ3 CASING RUNL P Continue to RIH w AL2 -01 section#3, 7,785.0 7,885.0 10:57 11:03 EDC open, 9/7/2018 9/72018 0.10 COMPZ3 CASING DLOG P Log K1 + 1' correction. 7,885.0 7,909.0 11:03 11:09 9/7/2018 9/7/2018 0.60 COMPZ3 CASING RUNL P RIH, tag up 8817.5 PU 48 k lbs, RBIH 7,909.0 8,812.0 11:09 11:45 S/D 3.67 K lbs WOB, on line with the pumpPU 42 k Ibs, Set Anchored billet slips oriented LS 9/72018 9/7/2018 1.70 COMPZ3 CASING TRIP P POOH 8,812.0 60.0 11:45 13:27 9/7/2018 9/72018 1.00 COMPZ3 CASING PULD P Flow check, inspected pipe 27' back to 60.0 0.0 13:27 14:27 coil connector wall thickness 1.81". LD BHA #24 over a dead well. -Crew change. 9/7/2018 9/72018 1.00 PROD4 STK PULD P PU BHA#25, AL@ -01 latteml drilling 0.0 80.0 14:27 15:27 assembly, check pack offs, 9/7/2018 9/712018 1.60 PROD4 STK TRIP P RIH, shallow test occilator tool, light 80.0 7,565.0 15:27 17:03 vibration felt on the coil at surface. Monitored frequency on pipe shed computer @ 1.5 bpm - 3500 CT pressure, 875 diff and 1.8 bpm - 5400 CT pressure, 1684 psi diff. Continue to RIH. 917/2018 9/7/2018 0.20 PROD4 STK DLOG P Tie into Kt for zero correction 7,565.0 7,595.0 17:03 17:15 9/7/2018 9/7/2018 1.20 PROD4 STK TRIP P Continue to RIH, displacing well to 7,565.0 7,595.0 17:15 18:27 drilling fluid, 9/7/2018 - 9/7/2018 0.15 PROD4 STK TRIP P Dry tag TOB @ 8,492' 7,595.0 8,492.0 18:27 18:36 9/7/2018 9/7/2018 1.50 PROD4 STK KOST P PUH, and start kicking off billet @ 8,492.0 8,496.6 18:36 20:06 8491.5', 1.75 bpm at 5,172 psi, WHP=181, BHP=4,216, IA=4, OA=54 9/7/2018 9/7/2018 0.15 PROD4 STK KOST P Stall Motor, PUH 57 k, minus 2.3 k 8,496.6 8,473.0 20:06 20:15 DHWOB 9/7/2018 9/7/2018 0.15 PROD4 STK KOST P RBIH, RIW 15 k, 1.81 bpm @ 5,337 8,473.0 8,496.0 20:15 20:24 psi, Diff --1,230 psi, WHP=100, BHP=4,095, IA=5, OA=54 9/7/2018 9/7/2018 0.15 PROD4 STK KOST P Stall Motor, PUW 47 k, PUH to 8,478' 8,496.0 8,478.0 20:24 20:33 9/7/2018 9/712018 0.15 PROD4 STK KOST P RBIH, 1.8 bpm @ 5,387 psi, 8,478.0 8,500.0 20:33 20:42 Diff --1,210, WHP=124, BHP=4,235, IA=8, OA=54 9/7/2018 9/7/2018 0.60 PROD4 STK DRLG P Drill ahead 8,500.0 8,504.0 20:42 21:16 9/7/2018 9/7/2018 0.15 PROD4 STK DRLG P PUH, PUW 51 k, dry drift kickoff point 8,504.0 8,504.0 21:18 21:27 (clean) 9/7/2018 9/7/2018 0.45 PROD4 STK DRLG P BOBD, 1.8 bpm at 5,337 psi, 8,504.0 8,511.1 21:27 21:54 Diff -1,200, WHP=138, BHP=4,124, IA=24, OA=56 9/7/2018 9/8/2018 2.10 PROD4 STK WPRT T Stall motor, PUW=70 k, seems we are 8,511.1 8,511.1 21:54 00:00 detained, unable to tum orienter, work pipe, still stuck, make call to town team, discuss plan forward, bring pump on-line, 1.5 bpm at 4,830 psi, motor no longer stalled, circulate 5x5 around, Page 22/30 Report Printed; 911912018 Operations Summary (with Timelog Depths) 1 H-21 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Stmt Time End Torre Dur (hr) Phase Op cope ArSvpy Dope Tore P -T-% 0 Peradw Start Depth (me) End DepN(flKa) 9/8/2018 9/812018 1.00 PROD4 STK TRIP T Continue working pipe, spot lube pill 8,511.1 8,511.0 00:00 01:00 around BHA, continue working pipe. still detained. 9/8/2018 9/8/2018 1.00 PROD4 STK TRIP T Circulate lube pill up hole, work pipe, 8,511.0 8,511.0 01:00 02:00 still detained. Rotate HOT, torque seen on coil. no movement on motor. 9/8/2018 9/8/2018 0.75 PROD4 STK TRIP T Circulate 2nd 5x5 sweep 8,511.0 8,511.0 02:00 02:45 9/8/2018 9/8/2018 1.10 PROD STK TRIP T Work pipe, Pull 86 k, minus 16.5 k 8,511.0 8,511.0 02:45 03:51 DHWOB 9/8/2018 9/8/2018 0.50 PROD4 STK TRIP T Continue POOH 8,511.0 7,753.0 03:51 04:21 9/8/2018 9/8/2018 1.60 PROD4 STK TRIP T Open EDC, ooutinue POOH 7,753.0 70.0 04:21 05:57 9/8/2018 9/8/2018 1.50 PROD4 STK PULD T Bump up, PUD BHA# 25. Bit had 70.0 0.0 05:57 07:27 chipped reamers but did not have damage indicating we had spun it against liner or slips. 9/8/2018 9/8/2018 1.40 PROD4 STK PULD T LD pre loaded BHA in DS PDL, 0.0 96.1 07:27 08:51 dropped T weight bar and 1.4' knuckle out of PDL. PU BHA# 26 to the HOT. Hung off three pups, LOA 23.66' with a ported bull nose over the hole (9.84', 7.84', 5.66). Picked J setting tool / billet / open hole anchors. PD, BHA, stab on, verify EDC open, bump up set counters. 9/8/2018 9/8/2018 2.60 PROD4 STK TRIP T RIH, 96.1 7,600.0 08:51 11:27 j 9/8/2018 9/8/2018 0.20 PROD4 STK DLOG T Tie into the K1 for no correction. 7,600.0 7,620.0 11:27 11:39 9/8/2018 9/8/2018 0.60 PROD4 STK TRIP T Continue to RIH with anchored billet 7,620.0 8,509.0 11:39 12:15 into 7" @ 7806', PU Wt 45 k lbs, close ECD, RIH to 6504', PU 46 k lbs, RBIH, Bit depth 8502.5', PU to neutral weight, online w pumps, shear - 4300 psi, RIH in attempt to stack weight. Push to bit depth of 8509' with -500 lbs WOB. "' Note TOB @ 8474' 9/8/2018 9/812018 1.50 PROD4 STK TRIP T POOH 8,509.0 71.0 12:15 13:45 9/8/2018 9/8/2018 1.10 PROD4 STK PULD T Bump up space out, PUD BHA # 26 71.0 0.0 13:45 14:51 9/8/2018 9/8/2018 1.10 PROD4 STK SVRG T Wait on arrival of billet w open hole 0.0 0.0 14:51 15:57 anchors. 9/8/2018 9/8/2018 1.60 PR0D4 STK PULD T PU & PD BHA# 27. Open hole 0.0 75.5 15:57 17:33 anchored billet w 2 pups 7.72', & 1.57' with a ported bull nose. check pack offs 9/8/2018 9/8/2018 1.75 PROD4 STK TRIP T RIH, with BHA#27 75.5 7,580.0 17:33 19:18 9/8/2018 9/8/2018 0.20 PROD4 STK DLOG T Log the K1 marker correction of plus 7,580.0 7,605.0 19:18 19:30 0.5', PUW 43 k, close EDC 9/8/2018 9/8/2018 0.50 PROD4 STK TRIP T Continue IH, set down 8,474', 7,605.0 8,473.1 19:30 20:00 9/812018 9/8/2018 0.25 PROD4 STK TRIP T PUW 49 k, set back down 2.2 k, PUH 8,473.1 8,452.3 20:00 20:15 46 k, 0.5 k DHWOB, bring pump up to shear 4,900 psi 9/812018 9/8/2018 1.75 PROD4 STK TRIP T PUH=48 k, POOH 8,452.3 61.2 20:15 22:00 9/8/2018 9/812018 0.92 PROD4 STK PULD T Tag up space out, PUD & LD setting 61.2 0.0 22:00 22:55 tools Page 23130 Report Printed: 9/19/2018 Summary (with Timelog Depths) 1 H-21 lipOperations Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log sternum, End roe Dur (hff Phase Op Code Activity Code Time PJA Ti Operation Stan Depth (RKB) End Depth(BKB) 9/8/2018 9/8/2018 0.30 PROD4 STK PULD T Reconfigure BHA (MU motor and bit) 0.0 0.0 22:55 23:13 9/8/2018 9/9/2018 0.78 PROD4 STK PULD T PD kickoff drilling BHA#28 0.0 0.0 23:13 0000 9/9/2018 9/9/2018 0.50 PROD4 STK PULD T MU Upper Quick, surface test Coiltrak 0.0 78.1 00:00 0030 tools (good -test) 9/9/2018 9/9/2018 1.50 PROD4 STK TRIP T RIH, w/drilling BHA # 28, test agitator 78.1 7,570.0 00:30 02:01 1 @ 500' (good -test) 9/9/2018 9/9/2018 0.15 PROD4 STK DLOG T Log the K1 marker correction of zero 7,570.0 7,590.0 02:00 02:09 919/2018 9/9/2018 0.20 PR0D4 STK TRIP T Continue IH 7,590.0 8,452.5 02:09 02:21 9/9/2018 9/9/2018 0.15 PR0D4 STK TRIP T Dry tag TOB @ 8452.5' 8,452.5 8,436.0 02:21 02:30 9/9/2018 9/9/2018 0.15 PR0D4 STK TRIP T Bring pump on-line @ 1.80 bpm at 8,436.0 8,453.7 02:30 02:39 5,294 psi, Diff -1,360 psi, WHP=336, IA=O, 0A=49 9/9/2016 9/9/2018 0.30 PROD4 STK KOST T Attempt to find billet, 1503 R 0 H S as 8,453.7 8,455.0 02:39 02:57 per RP, chase WOB to 8,455' 9/9/2018 9/9/2018 1.50 PR0D4 STK KOST P Start time milling 1.79 bpm @ 5,475 8,455.0 8,458.0 02:57 04:27 psi, Diif=1344 psi, WHP=149, BHP=4,157, IA=O, OA=53 9/9/2018 9/9/2018 1.60 PR01)4 DRILL DRLG P Start drilling ahead 16 fph 1.79 bpm at 8,458.0 8,565.0 04:27 06:03 5,438 psi, Diff --1,360 psi, WHP=149, BHP=4,173, IA=11, OA=55 9/9/2018 9/9/2018 0.20 PROD4 DRILL WPRT P PU 48 k lbs, PUH, to 8412', billet 8,565.0 8,565.0 06:03 06:15 clean, RBIH dry drift, window clean. 9/9/2018 9/9/2018 1.10 PROD4 DRILL DRLG P CT 4205 psi @ 1.77 bpm, Free spin 8,456.0 8,565.0 06:15 07:21 diff 1348 psi, IA 95 psi, OA 58 psi. OBD, CT wt 15 k lbs, WOB 1.8 k lbs, ROP 40 - 300 ft/ hr. 9/9/2018 9/9/2018 1.40 PROD4 DRILL DRLG P Having difficulty dropping angle. cut 8,458.0 8,720.0 07:21 08:45 rate from 1.8 to 1.5 bpm. Targeting higher WOB. 8688' WOB diming, held WOB - 34 k Ib to 8562'. Allowed to mill off, time drilled to 8720' 919/2018 9/9/2018 1.00 PROD4 DRILL DRLG P PU to acquire new parameters, Ct 8,720.0 8,756.0 08:45 09:45 4558 psi @ 1.5 bpm, annular 4206 psi. OBD, targeting 3-4 k LBS WOB. Drilled ahead with angle slowly dropping. 9/9/2018 9/9/2018 6.10 PROD4 DRILL DRLG P PU and incresae pump rate to 1.78 8,756.0 8,860.0 09:45 15:51 bpm. Ct 5405 psi @ 1.78 bpm, free spin diff 1240 psi, annular 4244 psi. OBD, Ct Wt 15 k Ibs, WOB 3.5 k lbs, ROP 10 ft/hr Drilled through two sections of wrapped gamma @ 8760', and 8810' 9/9/2018 9/9/2018 1.00 PROEM DRILL DRLG P ROP climbed rapidly from 25 to over 8,860.0 8,935.0 15:51 16:51 120 8/hr. CT 5815 psi, @ 1.79 bpm, Annular 4148 psi, IA 457 psi, OA 67 psi CT Wt 1.4 k lbs, WOB 3.4 k lbs, ROP 61 ft/hr Chase sweeps to the bit. bit. 9/9/2018 9/9/201 8 0.35 P ROD4 DRILL WPRT P PUse kIbs, wipe r# (agitator 8,935.0 8,477.0 16:51 17:12 working!, swap computers 9/9/2018 9/9/2016 0.80 PROD4 DRILL WPRT P Wiper back in hole, RIW 15 k 8,477.0 8,935.0 17:12 18:00 1 Page 24130 ReportPrinted: 9/1912018 . Operations Summary (with Timelog Depths) IH -21 W Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Tena End Time Dur (hr) Phase Op Code Activity Code Time P -T -x Operapun Start Depth (ItKB) End Depth (WS) 9/9/2018 9/9/2018 3.75 PROD4 DRILL DRLG P BOBD, 1.76 bpm @ 5,647 psi, 8,935.0 9,436.0 18:00 21:45 Diff=1,390 psi, WHP=181, BHP=4,244, IA=356, OA=67, Avg.ROP=80 fph "' Note: New Mud @ 9,089' 9/9/2018 9/9/2018 0.50 PROD4 DRILL WPRT P Wiper up hole to the window, PUW 53 9,436.0 8,100.0 21:45 22:15 k 9/9/2018 9/9/2018 0.15 PROD4 DRILL WPRT P Perform Jog in hole 100'@ 50 fpm 8,100.0 8,204.0 22:15 22:24 9/9/2018 9/9/2018 0.80 PROD4 DRILL WPRT P Continue wiper up hole, PUW 16 k, 8,204.0 7,845.0 22:24 23:12 —0.20 jog clean 7" with sweeps 9/9/2018 9/9/2018 PROD4 DRILL DLOG P Log the RA marker correction of plus 7,845.0 7,869.0 23:12 23:24 7.0' 9/9/2018 9/10/2018 0.60 PROD4 DRILL WPRT P Continue Wiper back in hole, RIW 15 7,869.0 9,436.0 2324 00:00 —0 k 9/10/2018 9/10/2018 30 PR054 DRILL DRLG P BOBD, 1.79 bpm at 5,160 psi, 9,436.0 9,556.0 00:00 00:18 Di"- 305 psi, WHP=438, BHP=4,338, IA=218, OA=64, "' Note: Needing to get build and turn. 9/10/2018 9/10/2018 —0 15 PR0D4 DRILL WPRT P PUW 52 k. BHAwiper up hole, PUW 9,556.0 9,556.0 00:18 00:27 1 1 52 k 9/10/2018 9/10/2018 0.20 PROD4 DRILL DRLG P BOBD, 1.78 bpm at 5,065 psi, 9,556.0 9,583.0 00:27 00:39 1 Diff -1,365, WHP=357, BHP=4,272, IA=353, OA=66 9/10/2018 9/10/2018 0.15 PROD4 DRILL WPRT P PUW 52 k, work pipe x 3, not able to 9,583.0 9,583.0 00:39 00:48 '611 —0/2018 build angle or tum to the east. 9/10/2018 0.20 PROD4 DRILL DRLG P BOBD, 1.78 bpm at 5,065 psi, 9,583.0 9,614.0 00:48 01:00 Diff -1,365, WHP=357, BHP=4,272, IA=353, OA=66, CTSW - 5 k 9/10/2018 9/10/2018 0.15 PROD4 DRILL WPRT P PUW 52 k, work pipe x 3, not able to 9,614.0 9,614.0 01:00 0109 1 build angle or turn to the east. - 9/10/2018 9/10/2018 0.50 PROD4 DRILL DRLG P BOBD, 1.79 bpm at 5,090 psi, 9,614.0 9,639.0 01:09 01:39 Diff --1,360 psi, WHP=357, —0 BHP=4,257, IA=357, OA=66 9/10/2018 9/10/2018 20 PROD4 DRILL WPRT P PUW 52 k, work pipe x 3. getting turn, 9,639.0 9,725.0 01:39 01:51 still having trouble building angle. 9/10/2018 9/10/2018 0.30 PROD4 DRILL DRLG P BOBD, 1.79 bpm at 5,090 psi, 9,725.0 9,820.0 01:51 02:09 1 Diff=1,360 psi, WHP=357, BHP=4,257, IA=357, OA=66 9/10/2018 9/10/2018 0.15 PROD4 DRILL WPRT P PUW 55 k, work pipe x 3, not able to 9,820.0 9,820.0 02:09 02:18 build, 9/10/2018 9/1012018 0.30 PROD4 DRILL DRLG P BOBD, 1.79 bpm at 5,035 psi, 9,820.0 9,836.0 02:18 02:36 Diff -1,208 psi, WHP=366, —0 BHP=4,337, IA=360, OA=66 9/10/2018 9/10/2018 40 PROD4 DRILL WPRT P 1,000', wiper up hole, PUW 9,836.0 8,841.0 02:36 03:00 9/10/2018 9/10/2018 0.30 PROD4 DRILL WPRT P Wiper back in hole, RIW 14 k, make 8,841.0 9,818.0 03:00 03:18 call to town for plan forward, decision —3 was made to POOH for correction run. 9/10/2018 9/10/2018 00 PROD4 DRILL TRIP T Pump 5x5 sweep, POOH to surface 9,818.0 76.9 03:18 06:16 9/10/2018 9/10/2018 1.20 PROD4 DRILL PULD T Bump Up, PUD following failed EDC 76.9 0.0 06:18 07:30 1 procedure, LDBHA 9/10/2018 9/10/2018 0.70 PROD4 DRILL PULD T PD BHA#290.8°AKOwRRHC 0.0 78.2 07:30 08:12 P104 cutter bit, stab injector, bump up, set counters. 9/10/2018 9/10/2018 1.50 PROD4 DRILL TRIP T Verify SSSV pressure, RIH, close 78.2 7,570.0 08:12 09:42 EDC. shallow test agitator - good. continue in hole. Page 25130 Report Printed: 9/19/2018 y Operations Summary (with Timelog Depths) 1H-21 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Time End Time Our (hd Phase �Cotle Aetivity Code Time P -T -X Operation Sten Depth (MI®) BM Depth (f"(13) 9/10/2018 9/10/2018 0.20 PROD4 DRILL DLOG T Tie into the K1 + 0.5' correction. 7,570.0 7,631.6 09:42 09:54 —0 9!1012018 9/10/2018 80 PROD4 DRILL TRIP T PU Wt, 44 k lbs, RIH, 7,631.6 9,836.0 09:54 10:42 9110/2018 9/10/2018 0.40 PROD4 DRILL DRLG T CT 4750 psi, @ 1.8 bpm, free spin 9,836.0 9,877.0 10:42 11:06 857 psi, annular 4180 psi,WH 255 psi, la 110 psi, OA 60 psi. OBD, CT Wt 9 k lbs, WOB 1.5 k lbs, ROP 50-200 fUhr. Directional driller attempted to steer south, dropped angle rapidly. PU 50 k lbs, reduced rate to 1.50 bpm attempting to target increased WOB, near bit inc continuing to fall rapidly. 9/10/2018 9/10/2018 0.90 PROD4 DRILL WPRT T PU Wt 50 k lbs, Geo wiper. Rig Geo 9,877.0 9,877.0 11:06 12:00 and DD greed to put 90% into turn to the south, RBIH, Drill ahead, PU, 50 k lbs, Geo wiper #2, Last survey to the left. RBIH, PU, to resurvey, RBIH. 9/10/2018 9/10/2018 0.20 PROD4 DRILL DRLG T CT 3967 @ 1.49 bpm, free spin 654 9,877.0 9,962.0 12:00 12:12 psi, WH 276 psi, annular 4198 psi Ct Wt 7 k lbs, WOB .57 k lbs, ROP 200 R/hr. 9/10/2018 9/10/2018 0.30 PROD4 DRILL WPRT T PU 50 k lbs, DD wiper to discuss close 9,962.0 9,962.0 12:12 12:30 approach. Discuss w engineering potential close approach to hard line on the north. Decision made to drill ahead. RBIH 9/10/2018 9/10/2018 2.00 PROD4 DRILL DRLG T OBD, CT 3900 psi @ 1.50 bpm, free 9,877.0 10,195.0 12:30 14:30 spin 580 psi, Annular 4299 psi, WH 364 psi CT 1.8 k lbs, WOB 0.44 k lbs, ROP 115 ft/hr 13:50 and 10,141' increase rate to 1.78 bpm, WH 316, Annular 4307 psi, CT -7 k lbs, WOB 0.34 k lbs, ROP 110 ft/sec. Pump 5 x 5 sweep Average ROP over interval - 160 f/hr 9/10/2018 9/10/2018 0.20 PROD4 DRILL WPRT T PU 53 k lbs, Pull to 9994'- 201' wiper 10,195.0 10,195.0 14:30 14:42 RBIH 9/10/2018 9/10/2018 1.40 PROD4 DRILL DRLG T RBIH Wt 4 k lbs, Ct 4847 psi, @ 1.81 10,195.0 10,270.0 14:42 16:06 bpm, free spin 887 psi, WH 257 psi, Annular 4219 psi. OBD, CT Wt -6.4 k lbs, WOB 0.9 k Ib, ROP 33 ft/hr. 9/1 o/2018 9/10/2018 0.20 PROD4 DRILL WPRT T PU 53 k lbs,- 1000' wiper 10,195.0 8,992.0 16:06 16:18 Pull through low spot @ 9150' Pump 10 bbls 1 ppg beds 9/10/2018 9/10/2018 0.80 PROD4 DRILL WPRT T RBIH, SID 9090' PU 58 lbs, to 9031', 8,992.0 10,195.0 16:18 17:06 RBIH, SD @ 9588' W WOB. SD @ 9679' 9/10/2018 9/10/2018 2.00 PROD4 DRILL DRLG T RBIH Wt 4 k lbs. Ct 4847 psi, @ 1.81 10,195.0 10,404.0 17:06 19:06 bpm, free spin 887 psi, WH 257 psi, Annular 4219 psi. OBD, CT Wt -6.4 k lbs, WOB 0.9 k Ib, ROP 30 - 170 Mr. Still drifting north, tum straight up, reduce pump rate, try sweeps to get more WOB. No sucess, 9/1 o/2018 9/10/2018 3.10 PROD4 DRILL WPRT T PU Wt 53 k IDS, POOH for higher bend 10,404.0 74.4 19:06 22:12 motor. Page 26130 Report Printed: 911912018 Operations Summary (with Timelog Depths) 1 H-21 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log S1arlTme ESM Time Dur (hd Phase OP Cafe ACCvity Cotle TimP-T-X opmaOon aren Depth (Wli) EM Depth (WB) 9/10/2018 9/10/2018 1.30 PROD4 DRILL PULD T PUD BA #29, 74.4 0.0 22:12 23:30 9/10/2018 9111/2018 0.50 PROD4 DRILL PULD T PD BA#30,1.2"AKO 0.0 74.4 23:30 00:00 9/11/2018 9/11/2018 0.50 PROD4 DRILL PULD T Stab INJH, check pac-offs (good) 78.2 78.2 00:00 00:30 9/11/2018 9/1112018 1.25 PROD4 DRILL TRIP T RIH, with BHA# 30 78.2 7,570.0 00:30 01:45 9/11/2018 9/11/2018 0.20 PROD4 DRILL DLOG T Log the Kt marker with no correction, 7,570.0 7,590.0 01:45 01:57 PUW 48 k, close EDC 9/11/2018 9111/2018 1.25 PROD4 DRILL TRIP T Continue IH, steering through 9,090' 7,590.0 10,404.0 01:57 03:12 and 9,590' area. 9/11/2018 9/11/2018 1.00 PROD4 DRILL DRLG T OBD, 1.79 bpm at 5,231 psi, 10,404.0 10,472.0 03:12 04:12 Diff--,1,350 psi, WHP=213, BHP=4,342, IA=36, OA=58 9/11/2018 9/11/2018 0.40 PROD4 DRILL WPRT T Wiper up hole, PUW=53 k 10,472.0 9,925.0 04:12 04:36 9/11/2018 9/11/2018 0.40 PROD4 DRILL WPRT T Wiper back in hole, RIW 5 k 9,925.0 10,472.0 04:36 05:00 9/11/2018 9/11/2018 0.80 PROD4 DRILL DRLG T BOBD, 1.79 bpm at 5,466 psi, 10,472.0 10,491.0 05:00 05:48 Diff--1,244 psi, WHP=221, BHP=4,351, IA=181, OA=58 9/11/2018 9/11/2018 1.50 PROD4 DRILL WPRT T Wiper up hole, PUW=53 k, jet the 7" 10,491.0 7,806.0 05:48 07:18 with sweeps 9/11/2018 9/11/2018 0.15 PROD4 DRILL WPRT T After dicussing with town team, 7,806.0 7,565.0 07:18 0727 decision was made to RBIH to drill ahead 9/11/2018 9/11/2016 0.20 PROD4 DRILL DRLG P Log the K1 correction plus 6.0'7,565.0 7,598.0 07:27 07:39 9/1112018 9/11/2018 1.40 PROD4 DRILL WPRT P Continue RIH 7,598.0 10,491.0 07:39 09:03 9111/2018 9/11/2018 3.80 PROD4 DRILL DRLG P BOBD, 1.78 bpm at 5,293 psi, 10,491.0 10,610.0 09:03 12:51 Diff-1,272 psi, WHP=109, BHP=4,292, IA=263, OA=64 9/11/2018 9/11/2018 1.70 PR0D4 DRILL WPRT P BHA wiper up hole; PUW 58 k 10,610.0 10,510.0 12:51 14:33 9/11/2018 9/11/2018 0.50 PROD4 DRILL DRLG P BOBD. 1.80 bpm at 5,213 psi, 10,510.0 10,666.0 14:33 15:03 Diff-960 psi, WHP=159, BHP=4,316, IA=519, OA=69, trying to hold 85°-87" 9/11/2018 9/11/2018 1.00 PROD4 DRILL DRLG P OBD. 1.80 bpm at 5,213 psi, DiR=960 10,666.0 10,738.0 15:03 16:03 psi, WHP=164, BHP=4,318, IA=520, OA=69 9/11/2018 9/11/2018 1.50 PROD4 DRILL DRLG P OBD. 1.80 bpm at 5,213 psi, D"- 60 10,738.0 10,771.0 16:03 17:33 psi, WHP=167, BHP=4,323, IA=522, OA=69 9/11/2018 9111/2018 0.90 PROD4 DRILL WPRT P 10771. BHA Wiper, PUW=60K, Stack 10,771.0 10,771.0 17:33 18:27 out trying to get to bottom. Continue wiper to 10496. Pump sweeps. Work back to bottom 9/11/2018 9/1112018 2.80 PROD4 DRILL DRLG P 10771', Drill, 1.76 BPM Q 5150 PSI 10,771.0 10,850.0 18:27 21:15 FS, BHP=4415, RIW=-6K, DHW08=2K 9111/2018 9/11/2018 0.10 PROD4 DRILL WPRT P 10850'. BHA wiper, PUW=65K 10,850.0 10,850.0 21:15 21:21 9/11/2018 9/11/2018 1.00 PROD4 DRILL DRLG P 10850', Drill, 1.78 BPM @ 5280PSI 10,850.0 10,881.0 2121 2221 FS, BHP=4400, RIW=4K 9/11/2018 9/11/2018 0.10 PROD4 DRILL WPRT P 10881, P/U and restart, PUW=61K 1o,881.o 10,881.0 22:21 22:27 9/11/2018 911212018 1.55 PROD4 DRILL DRLG P 10881', Drill, 1.78 BPM Q 5210 PSI 10,881.0 10,907.0 22:27 00:00 FS, BHP=4390 Page 27130 Report Printed: 9119/2018 Operations Summary (with Timelog Depths) 1 H-21 lip Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log start Time End Thhe Dur(hr) phase Op Cade Addy Code Time P -T -X Operation short Depth Vto) End Depth ml®) 9/12/2018 9/12/2018 0.20 PROD4 DRILL DRLG P Dilling, 1.78 BPM @ 5210 PSI FS, 10,907.0 10,910.0 00:00 00:12 BHP=4390PSI 9/12/2018 9/12/2018 0.60 PROD4 DRILL WPRT P 10910', Call TD, PUH pumping 10 X 10,910.0 10,910.0 00:12 00:48 10 Sweeps 9/12/2018 9/12/2018 3.10 PROD4 DRILL WPRT P Sweeps out, Chase to swab, 10,910.0 65.0 00:48 03:54 PUW=58K 9/12/2018 9/12/2018 1.50 PROD4 DRILL WPRT P Tag up atsurface, Set counters, RBIH 65.0 7,570.0 03:54 05:24 9/12/2018 9/12/2018 0.15 1 PROD4 DRILL DLOG P Log the K1 correction 0.5' 7,570.0 7,591.0 05:24 05:33 9/12/2018 9/12/2018 0.15 PROD4 DRILL TRIP P Continue IH to above window. 7,591.0 7,800.0 05:33 05:42 9/12/2018 9/12/2018 0.20 PROD4 DRILL CTOP P Obtain pressure survey 6,520.79 7,800.0 7,800.0 05:42 05:54 Sensor/TVD, 11.32 ppg and slowly falling 9/12/2018 9/12/2018 2.50 PROD4 DRILL TRIP P Continue IH confine TD 10,908', (line 7,800.0 10,908.0 05:54 08:24 up liner pill down the coil 9/12/2016 9/12/2018 1.45 PROD4 DRILL TRIP P POOH laying in beaded 11.55 ppg 10,908.0 6,500.0 08:24 09:57 completion fluid, painting EOP flags 9/12/2018 9/12/2018 1.20 PROD4 DRILL TRIP P Continue POOH, displacing well to 6,500.0 78.2 09:51 11:03 11.55 ppg completion fluid to surface 9/12/2018 9/12/2018 0.50 PROD4 DRILL OWFF P Al surface, check well for flow, PJSM 78.2 78.2 11:03 11:33 9/12/2018 9/12/2018 0.50 PROD4 DRILL PULD P LD drilling BHA, flush and blow down 78.2 0.0 11:33 12:03 tools 9/12/2018 9/12/2018 0.25 COMPZ4 CASING PUTB P Prep Rig Floor for Liner Ops 0.0 0.0 12:03 12:18 9/12/2018 9/12/2018 1.30 PROD4 CASING RUNL P PU/MU 30 jts of slotted liner, shorty 0.0 923.0 12:18 13:36 deployment sleeve, and non -ported bullnose. 9/12/2018 9/12/2018 0.50 PROD4 CASING -[TU-LD P PU/MU Coiltrak tools surface test 923.0 967.3 13:36 14:06 (good -test) 9/12/2018 9/12/2018 1.65 PROD4 CASING RUNL P RIH, with AL2 -01 Liner segment #1 w/ 967.3 8,474.0 14:06 15:45 30 jts of slotted liner 9/12/2018 9/12/2018 0.20 PROD4 CASING RUNL P Log the K1 marker correction of plus 8,474.0 8,523.0 15:45 15:57 6.0' (correction at flat minus 4.0') 9/12/2018 9/12/2018 0.60 PROD4 CASING RUNL P Continue IH 8,523.0 10,500.8 15:57 16:33 9/12/2018 9/12/2018 0.20 PROD4 CASING RUNL P PUW 55 k, RBIH to 10,500.8', bring 10,500.8 9,577.8 16:33 16:45 pump online 1.4 bpm, PUW 41 k, remove liner length from counters 9/12/2018 9/12/2018 2.25 PROD4 CASING RUNL P POOH, Paint EDP flag 6600' 9,577.8 55.0 16:45 19:00 9/12/2018 9/12/2018 0.50 PROD4 CASING PULD P At surface, Flow check well, Lay down 55.0 0.0 19:00 19:30 BHA #31 1-2-01 1st liner run setting tools 9/12/2018 9/12/2018 0.50 PROD4 CASING SVRG P Change out mechanical disconnect on 0.0 0.0 19:30 20:00 safety joint 9/12/2018 9/12/2018 2.00 PROD4 CASING PUTB P P/U AL2 -01 intermediate liner run with 0.0 1,112.8 20:00 22:00 ported bull nose, 36 As sloted liner, and shorty deployment sleeve 9/12/2018 9/12/2018 0.60 PROD4 CASING PULD P M/U Coiltrak to liner. M/U coil to tools 1,112.8 1,157.0 22:00 22:36 and surface test. Tag up and set counters 9/12/2018 9/13/2018 1.40 PROD4 CASING RUNL P Trip in hole BHA#32, AL2 -01 1,157.0 7,749.0 22:36 00:00 intermediate compleion, EDC closed pumping 11.4 revised KWF 9/13/2018 9/13/2018 0.70 PROD4 CASING RUNL P Continiue in well BHA#32 7,749.0 8,660.0 00:00 00:42 intermediate liner segment 9/13/2018 9/13/2018 0.10 T5ROD4 CASING DLOG P Log K1 for +3.5' correction 8,660.0 8,680.0 00:42 00:48 Page 28130 ReportPrinted: 911912018 Operations Summary (with Timelog Depths) 1 H-21 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Time End Tene Durthr) phase Op Code Advity CWe Toe P -T-% Operation Start Dept, (fit®) End Depth (W) 9/13/2018 9/13/2018 0.30 PROD4 CASING RUNL P Continue in well. Cean pass through 8,680.0 9,577.0 00:48 01:06 window. tag TOL Q 9577, PUW=53K, DHWOB=-4K 9/13/2018 9/13/2018 0.20 PROD4 CASING RUNL P Set back down, 11.4 PPG New NaBr 9,577.0 8,456.0 01:06 01:18 out of GS. Pump 1.55 BPM @ 4910 PSI. Lift off liner, PUW=43K, DHWOB=-1.2 PUH 10 feet. Subtract liner length left in hole. Circ 10 BBIs in, 9/13/2018 9/13/2018 1.90 PROD4 CASING TRIP P Trip out of well, Paint EDP flag Q 8,456.0 47.1 01:18 03:12 6900' 9/13/2018 9/13/2018 0.70 PROD4 CASING PULD P At surface, Flow check well, PJSM lay 47.1 0.0 03:12 03:54 down tools on dead well 9/13/2018 9/13/2018 2.60 PROD4 CASING PUTS P PJSM, PIU tubing, BHA#33AL2-01 0.0 794.9 03:54 06:30 upper liner segment with ported bull nose, 14 jts slotted liner, HAL Swell Packer, 1 jt solid liner, HAL Swell Packer, 3 jts slotted liner, HAL Swell Packer, 5 jts solid liner, and deployment sleeve w/6' SBR 9/13/2018 9/13/2018 0.70 PROD4 CASING PULL) P M/U Coihrak to liner. M/U coil to tools 794.9 839.1 06:30 07:12 and surface test. Tag up and set counters 9/13/2018 9/13/2018 1.50 PROD4 CASING RUNL P TIH BHA #33 AL2 -01 upper liner 839.1 7,942.0 07:12 08:42 1 segment 9/13/2018 9/13/2018 0.10 PROD4 CASING RUNL P Correct depth at window flag, -2.7' 7,942.0 7,942.0 08:42 08:48 correction, wt check 45k 9/13/2018 9/13/2018 0.10 PROD4 CASING RUNL P Continue TIH, log K1 +3' correction, 7,942.0 8,466.8 08:48 08:54 tag TOL @ 8466.77' 9/13/2018 9/13/2018 0.20 PROD4 CASING RUNL P Pump 1.4 BPM, 1167 psi differential 8,466.8 7,670.5 08:54 09:06 to release off liner, 34k up weight 9/13/2018 9/13/2018 1.80 DEMOB CASING TRIP P Displace well to SW pumping .64 7,670.5 2,700.0 09:06 10:54 BPM/1200 psi, recover 11.4 PPG NaBR and TOOH to 2700' 9/13/2018 9/13/2018 1.00 DEMOB CASING TRIP T Standby for LRS due to poor road 2,700.0 2,700.0 10:54 11:54 conditions 9/13/2018 9/13/2018 0.75 DEMOB WHDBOP FRZP P PJSM w/LRS, PT lines to 4000 psi, 2,700.0 2,700.0 11:54 12:39 line up LRS to pump 35 bbls diesel FP into coil 9/13/2018 9/13/2018 0.75 DEMOB WHDBOP FRZP P TOOH to surface 2,700.0 44.2 12:39 13:24 9/13/2018 9/13/2018 1.50 DEMOB WHDBOP PULD P Close Swap valve, LD, setting tools, 44.2 0.0 13:24 14:54 MU nozzle, *** Note: Final Tubing presure 670 psi 9/13/2018 9/13/2018 2.30 DEMOB WHDBOP CTOP P Stab INJH, PJSM, w/ Haliburton N2, 0.0 0.0 14:54 17:12 PT surface line to 4,000 psi, Blowdown CT strring. Bleed off N2, R/D HES N2 9/13/2018 9/13/2018 0.80 DEMOB WHDBOP CTOP P Unstab injector, remove UOC and cut 0.0 0.0 17:12 18:00 a -line 9/13/2018 9/13/2018 2.00 DEMOB WHDBOP CTOP P PJSM, remove inner reel iron, 0.0 0.0 18:00 20:00 pressure bulkhead, and wash pipe, continue loading out pits 9/13/2018 9/13/2018 2.00 DEMOB WHDBOP CTOP 15 PJSM, R/U CT grapple and 0.0 0.0 20:00 22:00 unstabbing cable. Unstab CT from injector pull back to storage reel and secure to reel 9/13/2018 9/13/2018 1.50 DEMOB WHDBOP CTOP P PJSM, R/U to pick storage reel. Prep 0.0 0.0 22:00 23:30 reel sump. Pull king pin 9/13/2018 9/14/2016 0.50 DEMOB WHDBOP CTOP P PJSM with Peak, Pick reel and plac on 0.0 0.0 23:30 00:00 Peak sow bed truck 9/14/2018 9/14/2018 1.00 DEMOB MOVE CTOP P Continue CT string change 0.0 0.0 00:00 01:00 Page 29130 Report Printed: 9/19/2018 Operations Summary (with Timelog Depths) 1H-21 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Time End Time our (hr) Phase Op Cotle AMivity Cade Time P -T -X Operation Start Depth ptKB) End Depth (flKB) 9/14/2018 9/14/2018 5.00 DEMOB MOVE CTOP P Reel installed, Shim reel to carrier, 0.0 0.0 01:00 0600 Tourque saddle lamps Pull stuffing box for brass change out. Remove pump in sub and quick test sub for tubo inspection. 9/14/2018 9/14/2018 6.00 DEMOB MOVE CTOP P Finish securing reel, stab ,,Into 0.0 0.0 06:00 1200 INJH, Nipple down Stack, Work rig move check list, released 12:00 noon **** Page 30130 Report Printed: 9/19/2018 ConocoPhillips ConocoPhillips (Alaska) Inc. Kuparuk River Unit Kuparuk 1H Pad 1 H-21AL1 50-029-22355-60 Baker Hughes INTEQ Definitive Survey Report 02 October, 2018 BAT(ER UGHES ,,. ConocoPhillips • Cono4hil6ps Definitive Survey Report Campany: Con000PhiOips(Masks) Inc. Local Cmardlmab Reference: Well 1H-21 Project: Kupamk River Unit TVD Reference: 1H21@96.00usfl(1H-21) Sib: Kupamk lH Pad MD Reference. 1H-21 Q95.00usfl(1 H-21) Well: IH41 North Reference: True Wellbore 1H-21 Survey Calculation Method: Minimum Curveture Ossign: IH -21 Database. EDT 14 Alaska Production Prokct Kupamk Real Ni Sbpe Alaska, United5tili , Map System: US State Plane 1927 (Exact solution) System Datum: Mean Sea Level Geo Datum: MAD 1927 (NADCON COMUS) Using Well Reference Point Map Zone: Alaska Zone 04 Using geodetic single factor Well 1H81 Well Position +W45 090 uafl Nerihing: 5,980,024.57usg Latitude: 70°21'22.358N1 .U -W 0.00 ueft Eaadn9: 549,55522usfl Longitude: 149°35'51.196W '. Position Uncertainty O90 ush Wellhead Elevation: usR Ground Level: 54.40 disk Wellbore 1H-21AL1 Magnetics Model Name Sample Dab Declined.. Olp Angle Fleld Strength 19 r) Inn BGGM201B 9/12018 17.01 00.91 57,448 - Design IHZIALt Audit Notes: Version: 1.0 Phase: ACTUAL The On Oepth: 8,30090 Vai Sooner: Depth From (ND) aW8 .ERV Olnctbn (ua") Iw1D (-f" (I 41,60 O.DO D.00 0.00 Survey Program Date � From To Unsay sames, (..ft) (usft) Simi,(WaRon) Toot Na. Description Sued Oaks EIMDete 102.20 7,801 1H-215rvy1-SLBGCT-MS(111-21) GCT -MS Schlumixel GCT muhishol 4/28/1993 4/2811993 7,826.00 ],8]623 1H -21A MWD-lNC(1H-21A) MWD -INC ONLY MWD -INC_ ONLY FILLER 81192018 8119,2018 ],90]21 8,300.90 1H -21A MWD (111-21A) MWD MWD -Standard 811912018 8212018 8,315.00 11,255.34 1H-21 AL1 MiAD U H-21AL1) MWD MWD-Stanhad MMD10 82812018 1022010 2:SS:aOPV( Page 2 COMPASS 5900.149u1M 051) Annotation TIP KOP 10/&2018 255'48926 Papa 3 COMPASS 500014 &W 80 ConocoPhillips ConocoPNlllps Definitive Survey Report campany'. ConocoPhillips(Alaska) Inc. Local Coa781ntle Reference: M111 H-21 Pm)ecL Kuparuk Rivrt Unit TVD RNen:nce: 1H-21@9600usn(1H-21) Sna: Kupamk IM Pad MO Relerenco: 1H-21 Q96.00usn(1 H-21) Well: 188-21 North Reierenu: True Wellhon:: 188-21 Survey Calculation Method: Minimum Curvaelre Des189 18821 Dabhase: EDT 14 Alaska Production Survey Map Map Vertical MD Inc pal TVD TVOSS .1,114 Em No(h) Eastinp DLS Seclian Survey Teal Name (usn) I°I (1 (sat) loan) (us") loan) (111 (.1100') nl 8,30098 90.98 35942 6,623.08 fi527 99 PB.OS 3,944.99 5.98022869 55353 .4985] 383 17005 MND (31 8.315.00 95.05 35055 eamm 6,526,26 19201 3,944.71 59m,242.65 553.498.19 4.00 19201 MJJ1J(4) 0,30.5.32 9178 357,21 6.620.46 6,52446 MM 3943.59 5,90.271,88 553,495,87 11.65 22225 MAD (4) 83]655 9049 359.08 6,619.84 6,523,84 253.0 3,94250 5,980,304.07 563 495M 730 253.48 MAD(4) 0,404,93 6983 359.71 fi l9sl 652381 281.83 394228 5980,33245 553.9517 374 Was MWD(4) 8,48570 .0. 2.45 6,61968 6,521.69 312.60 3,94285 5,98036321 553,495.55 960 312.0 MWD(4) 8,465.58 8696 290 8.81978 8,523.76 3/2.41 3,94437 5.900,393.0 553AR&M 639 342.44 MW➢(4) 6498.43 87.82 420 5621182 6,524.62 373.22 3.946.20 5.90.423.85 553.498.48 5.46 Mn MWO(4) 8,528.21 0,75 TW 6621.25 552535 402M 3949.26 5,90.453.47 553.01.34 1307 40283 MAD(4) 0.556.21 0885 667 6621.67 6,52587 43252 3,953.9 5,90,483.19 553,50538 5,16 43252 MD 0,585.74 09.35 532 6.622.19 655.19 461.72 3,957.86 5,90,512@ 553.0855 2fi0 461.72 MWD (4) 8.616.14 88.53 940 58II.75 6,526.75 49176 396254 5980542.48 553514.03 440 491]6 "D (4) 8.64529 88.31 10.54 6823.55 6,527.55 5211.55 3,96760 5.900.91.30 553,518.90 3.97 520.55 MD (4) 595.07 88]4 11.1 0.824.45 6,520.5 550% 3,973.44 5,900.601.48 553.524.54 2.84 SWIM Mh➢(4) 670.39 8113 1224 6625.38 552631.1 5032 3979.65 5993,631.14 59,5556 2.82 58032 MD (4) 8,736.12 88.18 14.96 SBM.34 6,529.34 0929 3,908.0 5.90.60.07 553,53735 915 6.9.20 Miff) (4) 8,M5.31 8674 17.2 6.627.12 6531.12 637.22 3.999]7 5.90529.14 553.545.93 8.63 63722 MAD (4) 0,790.9 890 1438 6,07.56 653158 667.37 4,003,36 5,9071034 553,5530 10.13 66737 "D (4) a.M 31 9012 11.39 6.07.61 553181 695.29 4.009]5 5900745.30 663 w9 law 05.29 MD (4) 8,85561 907! 770 6,627.38 6,531.38 R5.16 4,014.77 5,980,776.20 553,56471 1237 85.16 hand) (4) 0,88555 9129 4.34 0,626.01 6,530.81 751.83 4.01791 5980805.90 553,071£ 11,440 754,03 MAID (4) 8.915 as 9129 0.90 8,826.13 6,530.13 70437 4,019.28 5,9005.44 553,558.83 1139 78437 MWD (4) 0.945.23 92.55 39.73 6,82512 6.529,12 81/54 4,010.94 5.90,05.60 50,580.29 11.54 81454 MAD(4) 0,975.12 M.29 354.55 A2359 6,527.50 844.m 4016.93 5.90,0536 553,50.08 10.91 84432 MAD(4) 9110581 92.55 35241 6,62204 6,5M.04 874.57 4,01347 590,925.58 553,56243 7.42 874.57 WAR) (4) 9,035.48 061.1 35262 6,621.46 555,46 909.10 40MM 590,95516 55355634 970 MAO MR) (4) 9,26588 wan 39.78 0.62230 6,5539 934.12 4,0574 8,90,98507 553,55431 9.5 90.12 MWD (4) 9095fl 8413 39,91 6,024]2 3.9672 96322 400209 5,981014,15 553.5045 9.12 95322 MWD(4) 912589 01.Y1 353.20 6fi2864 653264 90.52 3998.0 5901.04.2 553.54557 9.50 293.52 MM(41 9.1550 78.13 35311 6,534.01 6538.01 1,02279 3.994.89 59810739 553.54285 10.31 1.13Mn MWD(4) Annotation TIP KOP 10/&2018 255'48926 Papa 3 COMPASS 500014 &W 80 1. ConocoPhillip5 ConocoPhillips Definitive Survey Report Co.,." ConowPhilllps (Alaska) Inc. Local Coortllnate Reference: Well iH-21 Pm1ecC Kupamk River Unit TVD Rehrence: iH-21®96.00ush(M-21) Sita: Kupamk lH Pad MD Reference. 1H-21@95.00uaS(1H-21) Well: 144-21 North Reference True Wellhore: IH -21 Survey Calculation Method: Minimum CurvaWre Design: 1H-21 Database. EDT 14 Alaska Production Survey 1082016 255401724 Annotation COMPASS 500014 SaW e5D Map Was watkad 2411 (.1111°) Ix All ND NDSB +WS +E1AM NorXdng Erin]., DLS Station Sunday Tool Name 11) luaRl (usual (uaNl (Sol In) IDI 1.1160.1 1111 9.184.51 7535 351.42 6640.58 6544.56 1,050.42 3.99114 5,96110127 553,539.93 1127 100042 MWD(4) 9,21499 ]4.84 347,99 6,618.43 6,55243 1,079.40 3,9&5.8] 5.901,130.21 55353,140 11.00 1,0]940 MM (4) 9,245.94 75.88 344.94 6,696.26 6,580.26 1,109.51 3,9M86 5,991,15926 553,52620 1000 1,101151 MM (4) 9,275,11 79.10 ]420] 666250 6.559.58 1,135.99 3,80.87 5,991,185.56 59,51920 1309 1.135.85 MJUD(4) 9,305]1 79-05 33907 666617 6 MAT 1,164.37 3,96136 5,901.215.00 553508.4(1 8.95 1.164.3] MND(4) 9,335.53 79.]9 335.55 667344 657U4 1.19162 3,950,46 5,901,242.17 553,497.33 1095 1,191.62 MND(4) 9,30583 00.68 333.06 6.678.50 6,502.56 1.21863 3.93]]5 5,861,59.10 553,484.44 N]6 121863 MM 1.4) SMITH 83.08 329.11 6.683.12 6,50].12 1245,49 3,M,w 5,981,256.05 55346566 14M 1,246.49 MWD(4) 9,42542 84.18 306.35 6.656.16 6,59016 1,250.54 3,907.80 5981319.83 553454.16 10.74 1,26954 MWD(4) 9,464.57 0757 MAI 6,fi06.99 659298 1,301.21 3,004.99 5,991.35132 553431.14 13.88 1.30131 gave (4) 9,495.94 Seal 321.80 6.6009 6,594.09 1,335.90 3,865.67 5,981.37.80 553,411.66 224 1,335.90 MD (4) 9,526.99 07.05 321.80 6691.33 6,595.33 1,35011 3.840.27 5,901399.96 553392.10 $33 1.350.11 MND(4) 9,557.41 8662 31RW 6.693.01 6,597.01 1,3.33 3,8M.69 5,901 423.05 553.372.7 6.33 1,37.33 MD (4) &580.93 89.23 322.7 6694.15 6,590.15 1,39].]5 3.899.01 5.981 44T33 553.35233 14.78 1,3977 MWD(4) 9,617.61 07.85 30.56 6694.88 8,59&80 142484 3,]89.82 5981.42431 59,MAS ].]6 1.42084 WVD(4) 9,64745 8911 327.00 6,695 ad 6,599.68 1,445.51 3)7.05 5,991494 .80 553,318,26 9.18 1,44651 MWD(4) 9.676.33 8978 32&71 660" 6,59894 1.assam ],]5766 5,901,519.21 553,302.7 6.36 1,46996 MJ4D(4) 0.706.70 89.17 32005 6,6%m 6,6011.23 1,45606 3,]42.1] 5,901,54521 553.287.05 4.26 1,496.99 MNID(4) 9.77,81 88,74 3307 6696.78 6,60.76 1,521114 3.M74 598157186 553.271." 1.80 1.522.04 MND(4) 977.15 88.69 3M.08 6,697,45 6,601.45 1,54843 3.71159 5,981.59].3] 55324653 1.20 1,WAS MWD(n 9.797.53 89.17 33034 669802 6,60202 1,574.75 3fiSM 5,981.82359 551241.20 200 1,5]0]5 Must) (4) 9,82721 8791 330.37 6.159.7] 660277 1,600.52 3,60214 5,981.649.26 553,226.33 4.27 1,60052 MWD(4) B,BS].P SaM 330.62 6,699.79 6,603.79 16M.69 3,667,33 5901,67.32 553311.35 132 1,624.68 MD (4) 9,&90." 0942 33317 6700.45 6,604.45 1,66511 3,652.34 5,gal ]03.65 553,196.18 1048 1.655,11 MND(4) 9,91817 90]7 333.09 670040 6,604.40 1,68144 3,639.40 5,981,mas 553,18307 4.62 1,851." MWD (4) 9,944.17 9788 333.29 6,]00.]0 6.604.70 1799.10 3,Raim 5,981252 .55 553.171.62 1162 1,704.18 MND(4) 9.37&55 8822 333.87 6.701.80 6606.80 1.733.16 3,613.71 5,081.781.43 553,157.03 399 1,7316 MWU(4) 10,00881 89.40 33320 6.702.45 6.69945 1762.04 3599.34 5.99161024 59,14247 4.42 1,76204 MPrD(4) 1010900 90.58 334.10 S.M. 6.699." 1,789.19 3,585.92 5,981637.25 553129.87 4.87 1,789.18 Move) (4) 10.0 .86 Ease 33323 6,702" 6,606." 1,01407 3. MAU 6981,M2.D7 55311641 5,40 1,814.07 MJN(4) 10,097.88 09.29 3MM 67D279 6.601 1,841.70 3,559.51 5,901,689.59 553.102]2 1.80 1.0tl]0 MND(4) 1082016 255401724 Annotation COMPASS 500014 SaW e5D ConocoPhillips 6R 4 ConocoPhilli s W P Definitive Survey Report Company: Canoca ilip5 (Alaska) Inc. Local Coordinate Reference: WON 111-21 Project. Kronor River Una TND Reference: iH-21@ffiMus6(11131) Site: Kup6mk lH Patl MO Reference: 111-21@96,00uart(111-21) Well: 1H-21 North Reference: True Wellbore: 1H-21 Survey Calculation Meri Minimum Commit, Demon. 1H-21 Oatabau: EDT 14 Alaska Production Survey Map Map Vertical MD Im AM TVO l(.R) AWS •ust)ErW DlA IlMrtl 1°7 Ih IMalq lualM loan) luartl Northing Eadl, Section Survry Tool Name AnnotetiDO Irtl I 4*11w,08848 _ t0.t210.127,63fi3 89.05 331.55 6)0333 60]¢2 6.33 1849 ],5 45P5 5,961.916. 03 553W 310 .86 1 "D (4) 10.1569] 08.99 334.04 8,tri 6,60].]2 1,69440 3.53313 5,98194220 553,0]5.39 169 1,894.48 Mliis 10,187,11 09.54 3%.73 6.704]0 6,600,10 1921.94 3,54.55 5,981,960,57 553.02.63 909 1,82194 NAM (4) 10 M.10 8659 337.50 6,704.66 660.00 1,954.9 3,508.94 5,982.00171 55340.02 349 1,954.17 Risen (4) 10251.93 8837 339.83 6,70547 686947 14981,95 320%09 5,9820,2.44 653,011 7.84 1,901.95 "D (4) 10,201.93 Seri M29 6,70.12 6.610.13 2010.31 3,4111 5,902057]0 553,03].84 031 2010.31 Novi t0,311,3', e989 347.39 8,70,62 6.61063 3.08,67 3.478.61 5902,008.01 5530te63 1177 8.00.67 NIM (4) 10,346.20 1111 3. re 8.707.70 6,61170 2,0254 3,47088 5,982119.93 553.01187 sale 2,072.64 VIVID (4) 10,377.3] 0582 2n$8.19 8,70149 6.613.49 2.102.99 3484.19 5,962.15023 553,05.0 689 2,10299 NAND (4) 10,414.46 8582 349.45 6,71220 681820 2,139.26 3,45689 5,983.10844 55290.35 0]0 213926 NAM (4) 10.450,38 86.47 ]4896 6.714CI 6,61681 2,174.48 3,449.99 5,902821.59 `b 190,41 482 2174.48 NAM (4) 10.479.4 07.91 swic, 6.716.05 662005 220,28 3,445.12 5,98225037 552,985.35 5.71 2.203.28 MIND (4) 10.511.31 89,72 350,0 6.718.70 6.00.70 223453 3,44088 5,882281.59 553,993.11 SR 2234,53 NAM (4) 10,539,0 Man 351.59 6.71662 66211.62 2.26276 341 5.98230979 552050 481 2,242]6 MND(4) 10.570.0 91. 352]4 671613 8,820.13 2,29263 3,431.52 5,992,339.0 55297126 4.30 229263 MND(4) 10602.48 93.34 351.40 6.714.02 661682 2,324.85 3,427.99 5,902.9102 553,96242 8.20 2324.05 at (4) 10,629.12 93.0 35291 6,713211 661220 235128 3,425.05 5902,39622 911 5.71 2351.28 MWD(4) 10.0716 93.86 354.8 671141 8,61541 237910 3.422.0 5,902,426,02 5S29l 644 2378.10 MWD(4) 10,685.35 94.27 355.83 6.709.95 6.613.95 240715 3,41971 5,902,454.05 55295860 631 2,40.15 MND(4) 10715.37 85.55 35450 671052 6614.52 2,437.04 3,417.21 5.982,483.93 552,95.90 2277 2,4984 MWD (4) 10748.31 8573 35295 11 6,617,03 2.469.81 341507 5,962.51668 552,953.54 M. 2489.81 NAM (4) 10,774.29 8560 2,42 6,71489 661899 2495.71 3,415.15 590254250 5 .g5346 1716 249571 MOD(4) 10,801 05.49 563 6,71241 6,63141 2526,71 3,417.33 5,96257358 552,955.43 1024 2.DN.71 Mai 10.0886 0358 652 6.72060 6,634.60 255837 3.420.84 5,982,6066 552.958.8 637 2,55977 MND(4) 10,00.18 6514 11.89 6,83.66 6,627.68 2,59052 342503 5.98263].44 55288i.51 1779 2,59052 MNO(4) t09D577 0,11 1529 686.0 66MM 2,625.0 3434.17 5,992.03.0 552,971.62 1102 2fici MID 10,944.29 89.39 22.14 8.87.27 6,63127 2,551.47 3,44652 5,982708w 54,9038 16.73 Z6i NAM (4) 10,973.49 89.75 27.74 68749 6.61 25ari 3.450.83 5962735.0 55299505 19II 264294 MWD(4) 11,0360 69us 3267 68258 6.631.58 $713.95 3.47397 5802761.18 55301082 16.38 2,713.95 Uldi 11.036,117 089 36.55 8)9.74 663174 3.74133 3,491 598278887 553.02953 11.70 2,74133 MNO(4) 1105535 09.72 3975 6,87.05 6brri 2,70..07 3552.28 5,982.80339 553.040.06 17.33 2,755.0 NAND (4) 10(22018 2:55 a0PM Parties COMPASS 5000. 14 Rutld SM ,,. ConocoPhillips ConocoPhlllips Definitive Survey Report Company C.a.lohilllps (Alaska) Inc PmijecL KYpamk River Unit Sea; Kupamk 1H Ped WWI: iH]1 wall 1H-21 Doi 1H-21 Local CocMinate Reremnce: ND Reference: MD Italian, nce: North Relemnce: survey Calculation McNo9: Database: Nall 1H-21 -� 1H-21 @ 96.00use (11-1-21) IH41® 95.00use (114-21) Tine Minimum Curvature EDT 14 Alaska Protluc9on MD Inc AW NDS) +WS +Elie Map Map DL) venal IYael PI PI us l6,n7 (..ft) (u2.7) Iuae) Nonhiny Easting )ectlo^ Survey Tool Name ID) (e) I.1190') (ft) 11085.83 9p.31 4153 6,R].88 6,63188 ]]]906 3,524.19 9,88]82661 553.060.61 604 2]]906 MWD (4) 11,11]32 89.60 4298 6,](1.93 6,631.93 2,802.29 3.545.30 5.%2.849.98 55308L% 5.01 $B0229 MD (4) 11.149.14 89.]9 4161 6,]2810 6.633.10 2,82683 3,566.71 5,802,873% 55310282 4.35 2,82883 MWD(4) ttt]).35 86.% 39.24 6,728.41 6,63241 $847,30 35&9.50 6982.8%5 553.120.96 a.. 2,M7.M MM (4) 11,20350 89R 39.03 6.]3811 6,633]1 2.W7.55 3,601.51 5.982.915.64 553.137.33 302 2,MUM MWD(4) 11,23233 89.36 3110 6]28.94 6633.84 2,89oM 3.619.28 5,L592MAS SM'154.95 6.81 3,89028 Mole) 11,255.34 90.37 38.24 6]28.50 6(S32.88 2,90848 3.633.34 5,882&`6.]5 553.16889 6.62 2506.49 VWV(4) 11=00 80.37 38.24 613615 6,63275 2938.07 36%.65 5,882986.48 553,192.00 O.Oo 2,838.07 PROJECTED to TO Annotation 1NNL018255.40PM Papa6 COMPASS SON) 4l9tok 85D BA ER FUGHES PRINT DISTRIBUTION LIST aGEcompany COMPANY ConocoPhillips Alaska Inc. WELL NAME 1H-21AL1 FIELD Greater Kuparuk Area COUNTY North Slope Borough BHI DISTRICT Alaska AUTHORIZED BY Patrick Rider EMAIL Patri�bakerhuohes com STATUS Final Replacement: COMPANY ADDRESS (FEDEX WILL NOT OUNER TO P.O. WX) PERSON ATTENTION 4 t BP North Slope. EOA, PBOC, PRB.20 (Office 109) D&GWO Wells Admin Brenda Glassmaker& Peggy O'Neill 900 E. Benson Blvd. Anchorage. Alaska 99508 2 .ConocoPhillips Alaska Inc. Attn: Ricky Elgarico ATO 708 700 G Street Anchorage, AK 99510 3 ExxomMobil, Alaska Attn: Lynda M. Yaskell and/or Leonardo Elias 3201 C Street, Suite 505 Anchorage, AK 99503 21 8078 29 76 6 se sign and return one copy of this transmittal form to: ocoPhillips Alaska, Inc. i Osterkamp (WNS Petroleum Technician) G Street. forage, Alaska 99510 :knowledge receipt of this data. LOG TYPE GR - RES LOG DATE September 12, 2018 TODAYS DATE October 4, 2018 Revision No Details: Rev. Requested by: --- FIELD I __ FIELD/ FINAL CD/DVD FINAL PRELIM LOGS (las, cilis, PDF, META, SURVEY REPORT LOGS CGM, Final Surreys) (Compass) # OF PRINTS # OF COPIES 1PUFUCIFILS # OF COPIES jj J; 1i RECEIVED 002 0 0GE1 0 4 fullbp AOGCC 01 01 0 10 0 4, State of Alaska -AOGCC 10 1 1 1 1 0 0 Attn: Natural Resources Technician If .333 W. 7th Ave, Suite 100 1 .Anchorage, Alaska 99501 5 DNR - Division ofOil & Gas *** 0 O 1 O U Attn: Resource Evaluation 550 West 7th Avenue, Suite 1100 Anchorage, Alaska 99501 L_* Stamp "confidential" on all material deliver to DNR 6 BP Exploration (Alaska) Inc. Petrotechnical Data Center, IR2-1 900 E. Benson Blvd Anchorage, Alaska 99508 0 0 1 0 0 TOTALS FOR THIS PAGE: 0 , 3 0 0 PTD �?l8-a7-g Loepp, Victoria T (DOA) From: Loepp, Victoria T (DOA) Sent: Tuesday, July 10, 2018 2:10 PM To: 'Long, William R' Cc: Ohlinger, James J (James.J.Ohlinger@conocophillips.com) Subject: KRU 1H-21AL1(PTD 218-078) PTD Approval Modifications William, Please make the following modifications to the approved PTD 218-078: Annular preventer test pressure is 2500 psig A variance to 20 AAC 25.015(b) is granted to allow the kickoff point to be any point along the parent lateral. Subsequent Form Required: 10-407 Include this approval with the original approved PTD. Thanx, Victoria Victoria Loepp Senior Petroleum Engineer State of Alaska Oil & Gas Conservation Commission 333 W. 7th Ave Anchorage, AK 99501 Work: (907)793-1247 Victoria. Loeoppalaska.aov CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Victoria Loepp at (907)793-1247 or Victoria. Loeoip@alaska.gov THE STATE °fALASKA GOVERNOR BILL WALKER James Ohlinger Staff CTD Engineer ConocoPhillips Alaska, Inc. PO Box 100360 Anchorage, AK 99510-0360 Alaska Oil and Gas Conservation Commission Re: Kuparuk River Field, Kuparuk River Oil Pool, KRU 1H-21AL1 ConocoPhillips Alaska, Inc. Permit to Drill Number: 218-078 Surface Location: 678' FNL, 793' FEL, SEC. 33, T12N, RI OE, UM Bottomhole Location: 2614' FNL, 2579' FEL, SEC. 27, T12N, R10E, UM Dear Mr. Ohlinger: 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 www.aogcc.alasko.gov Enclosed is the approved application for the permit to redrill the above referenced development well. The permit is for a new wellbore segment of existing well Permit No. 218-077, API No. 50-029-22355- 01-00. Production should continue to be reported as a function of the original API number stated above. Per Statute AS 31.05.030(d)(2)(B) and Regulation 20 AAC 25.071, composite curves for well logs run must be submitted to the AOGCC within 90 days after completion, suspension or abandonment of this well. This permit to drill does not exempt you from obtaining additional permits or an approval required by law from other governmental agencies and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the AOGCC reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the AOGCC specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or an AOGCC order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. Sincerely, Hollis S. French Chair DATED this 5 day of July, 2018. STATE OF ALASKA ALF A OIL AND GAS CONSERVATION COMMId )N PERMIT TO DRILL 9n AAc 95 MF RECEIVED 1 a. Type of Work: 1b. Proposed Well Class: Exploratory - Gas ❑ Service - WAG ❑ Service - Disp ❑ 1 c. Specify if well is proposed for: Drill ❑ Lateral Q Stratigraphic Test ❑ Development - Oil Q" Service - Winj ❑ Single Zone Coalbed Gas ❑ Gas Hydrates ❑ Redrill ❑ Reentry Ell Exploratory - Oil ❑ Development - Gas ❑ Service - Supply ❑ Multiple Zone ❑ Geothermal ❑ Shale Gas ❑ 2. Operator Name: 5. Bond: Blanket Q • Single Well ❑ 11. Well Name and Number: Conoco Phillips Alaska, Inc. Bond No. 5952180 Kuparuk Riv Unit 1 H-21AL1 ` 3. Address: 6. Proposed Depth: "-7-- 6., 67 12. Field/Pool(s): PO Box 100360 Anchorage, AK 99510-0360 MD: 11,550' • TVW' 6644' Kuparuk River River Oil 4a. Location of Well (Governmental Section): 7. Property Designation: Z, /FKuparuk Surface: 678' FNL, 793' FEL, Sec 33, T12N, R10E, UM 7 ADL 25639 Top of Productive Horizon: 8. DNR Approval Number: 13. Approximate Spud Date: 609' FNL, 2136' FEL, Sec 34, T12N, R10E, UM LONS 80-261 7/11/2018 Total Depth: 9. Acres in Property: 14. Distance to Nearest Property: 2614' FNL, 2579' FEL, Sec 27, T12N, R10E, UM 2560 5900' 4b. Location of Well (State Base Plane Coordinates - NAD 27): 10. KB Elevation above MSL (ft): 96 • 15. Distance to Nearest Well Open Surface: x- 549555 y- 5980025 Zone- 4 GL / BF Elevation above MSL (ft): 54.4 to Same Pool: 790' to 1H-12 16. Deviated wells: Kickoff depth: 8200 feet ` 17. Maximum Potential Pressures in psig (see 20 AAC 25.035) Maximum Hole Angle: 91.2 degrees Downhole: 3275 • Surface: 2645 ' 18. Casing Program: Specifications Top - Setting Depth - Bottom Cement Quantity, c.f. or sacks Hole Casing Weight Grade Coupling Length MD TVD MD I TVD (including stage data) 3" 2-3/8" 4.6# L-80 ST -L 3625' 7925' - 6536' 11,550'---F--6644—Un-Cemented 19. PRESENT WELL CONDITION SUMMARY (To be completed for Redrill and Re -Entry Operations) Total Depth MD (ft): Total Depth TVD (ft): Plugs (measured): Effect. Depth MD (ft): Effect. Depth TVD (ft): Junk (measured): 8315 6962 N/A 8207 6877 N/A Casing Length Size Cement Volume MD TVD Conductor/Structural 121' 16" 200 SX PF C CMT 121' 121' Surface 4779' 9-5/8" 930 SX PERM E, 450 SX G 4820' 4247' Intermediate Production 8258' 7" 299 SX CLASS G CMT 8295' 6947' Liner Perforation Depth MD (ft): Perforation Depth TVD (ft): 7768-7858, 7918-7948 6534-6604, 6651-6674 Hydraulic Fracture planned? Yes El No Q 20. Attachments: Property Plat ❑ BOP Sketch Diverter Sketch e Drilling Programme Seabed Report Time v. Depth Plot Shallow Hazard Analysis Drilling Fluid Program e 20 AAC 25.050 requirements e 21. Verbal Approval: Commission Representative: Date 22. 1 hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Contact Name: William R. Long Authorized Name: James Ohlinger Contact Email: William.R.Lon COP.com Authorized Title: Staff CTD Engineer Contact Phone: 907-263-4372 // tp• Authorized Signature: Date: `/ipolvs Commission Use Only Permit to Drill �/� ^0,7 Number: API Number: / T _ Permit Approval See cover letter for other 50-�y 2ES� Date: I I 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. Br We.oie,ly $OPB -r ii 3A51 Samples req'd: Yes ❑ No� Mud log req'd: Yes ❑ oL�" r J HzS measures: Yes [v� No❑ Directional svy req'd: Yes VNo❑ Spacing exception req'd: Yes ❑ No�/ Inclination -only svy req'd: Yes ❑ No FV Post initial injection MIT req'd: Yes ❑ No ❑ APPROVED BY Approved by: COMMISSIONER THE COMMISSION Dater �v Form 10-401 Revised 5/2017 This permit is vali f -. 0 [� , r ^ t �� Submit Form and of approval per 20 AAC 25.005(8) Attachments it Duplicate f M.Dr4'..".. �a s/- /, .61 ConocoPhillips Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 June 27, 2018 Commissioner - State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Dear Commissioner: ConocoPhillips Alaska, Inc. hereby submits applications for permits to drill four laterals out of the KRU 1 H-21 (PTD# 193-046) using the coiled tubing drilling rig, Nabors CDR3-AC. CTD operations are scheduled to begin in July 2018. The objective will be to drill four laterals, KRU 1 H -21A, 1 H- 21AL1, 1H-21AL2, and 1H-21AL2-01, targeting the Kuparuk C -sand interval. To account for geological uncertainties, ConocoPhillips requests a variance from the requirements of 20 AAC 25.015 to allow the actual kick-off point to be anywhere along the length of the parent lateral instead of being limited to 500' from the original point. Attached to this application are the following documents: - Permit to Drill Application Forms (10-401) for 11-1-21A, 1H-21AL1, 1H-21AL2, and 1H-21AL2-01 - Detailed Summary of Operations - Directional Plans for 11-1-21A, 1H-21AL1, 1H-21AL2, and 1H-21AL2-01 - Current wellbore schematic - Proposed CTD schematic If you have any questions or require additional information, please contact me at 907-263-4372. Sincerely, William R. Long Coiled Tubing Drilling Engineer ConocoPhillips Alaska Kuparuk CTD Laterals 1H -21A, 1H-21AL1, 1H-21AL2, and 1H-21AL2-01 Application for Permit to Drill Document 1. Well Name and Classification........................................................................................................ 2 (Requirements of 20 AAC 25.005(f) and 20 AAC 25.005(b))...................................................................................................................2 2. Location Summary ..........................................................................................................................2 (Requirements of 20 AAC 25.005(c)(2))..................................................................................................................................................2 3. Blowout Prevention Equipment Information................................................................................. 2 (Requirements of 20 AAC 25.005(c)(3)) .................................................................................................................................................2 4. Drilling Hazards Information and Reservoir Pressure.................................................................. 2 (Requirements of 20 AAC 25.005(c)(4)) .................................................................................................................................................2 5. Procedure for Conducting Formation Integrity tests......................:............................................ 2 (Requirements of 20 AAC 25.005(c)(5))..................................................................................................................................................2 6. Casing and Cementing Program.................................................................................................... 3 (Requirements of 20 AAC 25.005(c)(6)) ..................................................................................................................................................3 7. Diverter System Information ..........................................................................................................3 (Requirements of 20 AAC 25.005(c)(7))..................................................................................................:................................................3 8. Drilling Fluids Program.................................................................................................................. 3 (Requirements of 20 AAC 25.005(c)(6))..................................................................................................................................................3 9. Abnormally Pressured Formation Information............................................................................. 4 (Requirements of 20 AAC 25.005(c)(9))..................................................................................................................................................4 10. Seismic Analysis............................................................................................................................. 4 (Requirements of 20 AAC 25.005(c)(10)) ................................................................................................................................................4 11. Seabed Condition Analysis............................................................................................................ 4 (Requirements of 20 AAC 25.005(c)(11))................................................................................................................................................4 12. Evidence of Bonding...................................................................................................................... 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 ................................................. 14. Disposal of Drilling Mud and Cuttings.......................................................................................... 6 (Requirements of 20 AAC 25.005(c)(14))................................................................................................................................................6 15. Directional Plans for Intentionally Deviated Wells....................................................................... 7 (Requirements of 20 AAC 25.050(b))......................................................................................................................................................7 16. Attachments....................................................................................................................................7 Attachment 1: Directional Plans for 1H -21A, 1H-21AL1, 1H-21AL2, and 1H-21AL2-01 laterals.....................................7 Attachment 2: Current Well Schematic for 1 H-21............................................................................................................7 Attachment 3: Proposed Well Schematic for 1H -21A, 1H-21AL1, 1H-21AL2, and 1H-21AL2-01 laterals .......................7 Page 1 of 7 June 27, 2018 PTD Application: 1H -21A, 1H-41AL1, 1H-21AL2, and 1H-21AL2-01 1. Well Name and Classification (Requirements of 20 AAC 25.005(0 and 20 AAC 25.005(b)) The proposed laterals described in this document are 1H -21A, 1H-21AL1, 1H-21AL2, and 1H-21AL2-01. All laterals will be classified as "Development -Oil' wells. 2. Location Summary (Requirements of 20 AAC 25.005(c)(2)) These laterals will target the C sand package in the Kuparuk reservoir. See attached 10-401 forms for surface and subsurface coordinates of each of the laterals. 3. Blowout Prevention Equipment Information (Requirements of 20 AAC 25.005 (c)(3)) Please reference blowout prevention (BOP) schematics on file with the Commission for Nabors CDR3-AC. BOP equipment is as required per 20 AAC 25.036 for thru-tubing drilling operations. - Pipe rams, blind rams and the CT pack off will be pressure tested to 250 psi and to 3,000 psi. Using the maximum formation pressure in the area of 3,275 psi at the datum in 21-1-12 (i.e. 10 ppg EMW), the maximum potential surface pressure in 1H-21, assuming a gas gradient of 0.1 psi/ft, would be 2,645 psi. Seethe "Drilling Hazards Information and Reservoir Pressure' section for more details. - The annular preventer will be tested to 250 psi and 2,500 psi. 4. Drilling Hazards Information and Reservoir Pressure (Requirements of 20 AAC 25.005 (c)(4)) Reservoir Pressure and Maximum Downhole Pressure (Requirements of 20 AAC 25.005 (c)(4)(a)) The formation pressure in KRU 1 H-21 was measured to be 2,978 psi at the datum (9.1 ppg EMW) on 5/16/2015. The maximum downhole pressure in the 1 H-21 vicinity is the 1 H-12 at 3,275 psi at the datum or 10 ppg EMW. Potential Gas Zones (Requirements of 20 AAC 25.005 (c)(4)(b))% / No specific gas zones will be drilled; gas injection has been performed in this area, so there is a chance of encountering gas while drilling the 1 H-21 laterals. If significant gas is detected in the returns the contaminated mud can be diverted to a storage tank away from the rig. Potential Causes of Hole Problems (Requirements of 20 AAC 25.005 (c)(4)(c)) The major expected risk of hole problems in the 1 H-21 laterals will be shale instability across faults. Managed pressure drilling (MPD) will be used to reduce the risk of shale instability associated with fault crossings. 5. Procedure for Conducting Formation Integrity tests (Requirements of 20 AAC 25.005(c)(5)) The 1 H-21 laterals will be drilled under 20 AAC 25.036 for thru-tubing drilling operations so a formation integrity test is not required. Page 2 of 7 June 27, 2018 PTD Application: 11-1-21A, 11i-21AL1, 1H-21AL2, and 1H-21AL2-01 6. Casing and Cementing Program (Requirements of 20 AAC 25.005(c)(6)) New Completion Details Lateral Name Liner Top Liner Btm Liner TopELinerLiner Connection Top MD Btm MD MD MD TVDSS1H-21A Collapse si Details 16" 8200' 11,500' 6538'2W, Surface 4.7#, L-80, ST -L slotted liner; Surface 121' 1640 670 Surface aluminum billet on to1H-21ALl 36 7925' 11,550' ' 6536' - 4820' 2%", 4.7#, L-80, ST -L slotted liner; 4247' 3520 2020 Production 7" aluminum billet on to 11-1-21AL2 8400' 11,100 6640' 6494' 2%", 4.7#, L-80, ST -L slotted liner; 4980 4320 Tubin 3-1/2" 9.3 aluminum billet on to 1H-21AL2-01 7675' 11,150 6365' 6632' 2W, 4.7#, L-80, ST -L slotted liner; 10,540 deployment sleeve on to Existing Casing/Liner Information Category OD Weigh Grade Connection Top MD Btm MD Top TVD Btm TVD Burst si Collapse si Conductor 16" 62.5 H-40 Welded Surface 121' Surface 121' 1640 670 Surface 9-5/8" 36 J-55 BTC Surface 4820' Surface 4247' 3520 2020 Production 7" 26 J-55 AB -MOD Surface 8296' Surface 6947' 4980 4320 Tubin 3-1/2" 9.3 J-55 EUE8rdMOD Surface 7693' Surface 6475' 10,160 10,540 7. Diverter System Information (Requirements of 20 AAC 25.005(c)(7)) Nabors CDR3-AC will be operating under 20 AAC 25.036, for thru-tubing drilling operations. Therefore, a diverter system is not required. 8. Drilling Fluids Program (Requirements of 20 AAC 25.005(c)(8)) Diagram of Drilling System A diagram of the Nabors CDR3-AC mud system is on file with the Commission. Description of Drilling Fluid System — Window milling operations: Water based Power -Vis milling fluid (8.6 ppg) — Drilling operations: Water based Power -Pro drilling mud (8.6 ppg). This mud weight may not hydrostatically overbalance the reservoir pressure, overbalanced conditions will be maintained using MPD practices described below. — Completion operations: BHA's will be deployed using standard pressure deployments and the well will be loaded with 11.4 ppg NaCl/NaBR completion fluid in order to provide formation over -balance and maintain wellbore stability while running completions. If higher formation pressures are encountered the completion brine will be weighted up with sodium bromide or potassium formate. Managed Pressure Drilling Practice Managed pressure drilling (MPD) techniques will be employed to maintain a constant overbalanced pressure on the open hole formation and promote wellbore stability throughout the coiled tubing drilling (CTD) process. Mud weight is not, in many cases, the primary well control barrier. This is satisfied with the 5000 psi rated coiled tubing pack off and MPD choke. BOPE equipment provides the secondary well control as detailed in section 3 "Blowout Prevention Equipment Information". In the 1 H-21 laterals we will target a constant BHP of 11.4 EMW at the window. The constant BHP target will be adjusted through choke pressure and/or mud weight increases to maintain overbalanced conditions if increased reservoir pressure is encountered. Additional choke pressure or increased mud weight may also be employed Page 3 of 7 June 27. 2018 PTD Application: 1H -21A, 1H-21AL1, 1H-21AL2, and 1H-21AL2-01 for improved borehole stability. Any change of circulating friction pressure due to change in pump rates or change in depth of circulation will be offset with back pressure adjustments. Pressure at the IH -21 Window (7825' MD_ (3578' Tvn) I leinn MPn 9. Abnormally Pressured Formation Information (Requirements of 20 AAC 25.005(c)(9)) N/A - Application is not for an exploratory or stratigraphic test well. 10. Seismic Analysis (Requirements of 20 AAC 25.005(c)(10)) N/A - Application is not for an exploratory or stratigraphic test well. 11. Seabed Condition Analysis (Requirements of 20 AAC 25.005(c)(11)) N/A - Application is for a land based well. 12. Evidence of Bonding (Requirements of 20 AAC 25.005(c)(12)) Evidence of bonding for ConocoPhillips Alaska, Inc. is on file with the Commission. 13. Proposed Drilling Program (Requirements of 20 AAC 25.005(c)(13)) Summary of Operations Background KRU well 1H-21 is a Kuparuk producer equipped with 3-1/2" tubing and 7" production. casing. The CTE sidetrack will utilize laterals to target the Kuparuk sands to the north and east of the existing 1 H-21 wellbore. The laterals will increase throughput and recovery from a potentially sheltered comer of a fault block. Prior to CTD operations, E -Line will punch holes in the 3-1/2" tubing tail below the production packer and the "D" nipple will be milled out to 2.80" ID. The existing perforations will be squeezed with cement and the 3-1/2" tubing tail will be cemented in place to provide a means to kick out of the 7" casing. Following the cement squeeze Nabors CDR3-AC will drill a pilot hole and set a mechanical whipstock in the 2.80" pilot hole. The whipstock will be used to cut a window in the 7" casing and drill CTD laterals. Page 4 of 7 June 27, 2018 Pump; On 1.8 bpm) Pumps Off Formation Pressure 9.1 3113 psi 3113 psi Mud Hydrostatic 8.6 2942 psi 2942 psi Annular friction i.e. ECD, 0.080psi/ft) 626 psi 0 psi Mud + ECD Combined no chokeressure 3568 psi overbalanced -455 psi)underbalanced 2942 psi -171 psi) Target BHP at Window 11.4 3899 psi 3899 psi Choke Pressure Required to Maintain Target BHP 331 psi 957 psi 9. Abnormally Pressured Formation Information (Requirements of 20 AAC 25.005(c)(9)) N/A - Application is not for an exploratory or stratigraphic test well. 10. Seismic Analysis (Requirements of 20 AAC 25.005(c)(10)) N/A - Application is not for an exploratory or stratigraphic test well. 11. Seabed Condition Analysis (Requirements of 20 AAC 25.005(c)(11)) N/A - Application is for a land based well. 12. Evidence of Bonding (Requirements of 20 AAC 25.005(c)(12)) Evidence of bonding for ConocoPhillips Alaska, Inc. is on file with the Commission. 13. Proposed Drilling Program (Requirements of 20 AAC 25.005(c)(13)) Summary of Operations Background KRU well 1H-21 is a Kuparuk producer equipped with 3-1/2" tubing and 7" production. casing. The CTE sidetrack will utilize laterals to target the Kuparuk sands to the north and east of the existing 1 H-21 wellbore. The laterals will increase throughput and recovery from a potentially sheltered comer of a fault block. Prior to CTD operations, E -Line will punch holes in the 3-1/2" tubing tail below the production packer and the "D" nipple will be milled out to 2.80" ID. The existing perforations will be squeezed with cement and the 3-1/2" tubing tail will be cemented in place to provide a means to kick out of the 7" casing. Following the cement squeeze Nabors CDR3-AC will drill a pilot hole and set a mechanical whipstock in the 2.80" pilot hole. The whipstock will be used to cut a window in the 7" casing and drill CTD laterals. Page 4 of 7 June 27, 2018 PTD Application: 1H -21A, 1H-21AL1, 1H-21AL2, and 1H-21AL2-01 Pre -CTD Work 1. RU Slickline: Drift tubing with dummy whipstock. 2. RU E -line: Punch holes in the 3'/z" tubing tail below the production packer. 3. RU Pumping Unit: perform injectivity test down the tubing. 4. RU Service Coil: Mill out "D" nipple and cement squeeze the perforations up to the holes in the tubing tail. 5. RU Slickline: Drift tubing with dummy whipstock. Tag top of cement and pressure test cement. 6. Prep site for Nabors CDR3-AC. Rig Work 1. MIRU Nabors CDR3-AC rig using 2" coil tubing. NU 7-1/16" BOPE, test. 2. Mill 2.80" cement pilot hole. 3. Set monobore whipstock. 4. IH -21A Lateral (C sand -North) a. Mill 2.80" window at 7825' MD. b. Drill 3" bi-center lateral to TD of 11,500' MD. c. Run 2%" slotted liner with an aluminum billet from TD up to 8200' MD. 5. 1 H-21ALI Lateral (C sand -North) a. Kickoff of the aluminum billet at 8200' MD. b. Drill 3" bi-center lateral to TD of 11,550' MD. c. Run 2%" slotted liner with aluminum billet from TD up to 7925' MD. 6. 1H-21AL2 Lateral (C sand -East) a. Kickoff of the aluminum billet at 7925' MD. b. Drill 3" bi-center lateral to TD of 11,100' MD. c. Run 2%" slotted liner with aluminum billet from TD up to 8,400' MD. 7. 1H-21AL2-01 Lateral (C sand -East) a. Kickoff of the aluminum billet at 8400' MD. b. Drill 3" bi-center lateral to TD of 11,150' MD. c. Run 2%" slotted liner with deployment sleeve from TD up to 7675' MD. S. Freeze protect, ND BOPE, and RDMO Nabors CDR3-AC. Post -Rig Work 1. Return to production. Page 5 of 7 June 27. 2018 PTD Application: 1H -21A, 1H-21AL1, 1H-21AL2, and 1H-21AL2-01 Pressure Deployment of BHA The planned bottom hole assemblies (BHAs) are too long to simply isolate by closing the double swab valves on the Christmas tree. MPD operations require the BHA to be lubricated under pressure using a system of double swab valves on the Christmas tree, double deployment rams, double check valves and double ball valves in the BHA, and a slick -line lubricator can be used. This pressure control equipment listed ensures there are always two barriers to reservoir pressure, both internal and external to the BHA, during the deployment process. During BHA deployment, the following steps are observed. — Initially the double swab valves on the tree are closed to isolate reservoir pressure. The lubricator is installed on the BOP riser with the BHA inside the lubricator. — Pressure is applied to the lubricator to equalize across the swab valves. The swab valves are opened and the BHA is lowered in place via slick -line. — When the BHA is spaced out properly, the double deployment rams are closed on the BHA to isolate reservoir pressure via the annulus. A closed set of double ball valves and double check valves isolate reservoir pressure internal to the BHA. Slips on the double deployment rams prevent the BHA from moving when differential pressure is applied. The lubricator is removed once pressure is bled off above the deployment rams. — The coiled tubing is made up to the BHA with the double ball valves plus the double check valves in the closed position. Pressure is applied to the coiled tubing to equalize internal pressure and then the double ball valves are opened. The injector head is made up to the riser, annular pressure is equalized, and the deployment rams are opened. The BHA and coiled tubing are now ready to run in the hole. During BHA undeployment, the steps listed above are observed, only in reverse. Liner Running — 1H-21 CTD laterals will be displaced to an overbalance completion fluid (as detailed in Section 8 "Drilling Fluids Program") prior to running liner. — While running 2%" slotted liner, a joint of 2%" non -slotted tubing will be standing by for emergency deployment. A floor valve is made up onto this joint ahead of time, and the rig crew conducts a deployment drill with this emergency joint on every slotted liner run. The 2%" rams will provide secondary well control while running 2% liner. 14. Disposal of Drilling Mud and Cuttings (Requirements of 20 AAC 25.005(c)(14)) • No annular injection on this well. • All solid waste will be transported to the grind and inject facility at DS4 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). Page 6 of 7 June 27, 2018 PTD Application: 1H -21A, 1H-21AL1, 1H-21AL2, and 1H-21AL2-01 15. Directional Plans for Intentionally Deviated Wells (Requirements of 20 AAC 25.050(b)) - The Applicant is the only affected owner. - Please see Attachment 1: Directional Plans - Magnetic and inclination surveys will be taken every 30 ft. No gyro will be run. - MWD directional, resistivity, and gamma ray will be run over the entire open hole section. - Distance to Nearest Property Line (measured to KPA boundary at closest point) Lateral Name Distance 1H -21A 5,900' 1 H-21AL1 5,900' 1H-21 AL2 7,200' 1 H-21 AL2 -01 7,200' - Distance to Nearest Well within Pool Lateral Name Distance Well 1H -21A 790' 1H-12 1H-21AL1 790' 1H-12 1 H-21AL2 978' 1H-13 1 H-21AL2-01 978' 1 H-13 16. Attachments Attachment 1: Directional Plans for 1H -21A, 1H-21AL1, 1H-21AL2, and 1H-21AL2-01 laterals. Attachment 2: Current Well Schematic for IH -21. Attachment 3: Proposed Well Schematic for 1H -21A, 1H-21AL1, 1H-21AL2, and 1H-21AL2-01 laterals. Page 7 of 7 June 27. 2018 ConocoPhillips Project: Kuparuk River Hnif aNmxn.leni. xo,u MpMk NeM: qAt• WELLBORE DETAILS IH -21A ii/I� i7 REFERIME INFORMATION Sit¢: Well: Kuparuk 1H Pad iH-21 I II xpNlE 9xe Parent Wellbore: iH-21 C -m b(Ni Relueou: wd111+21, T. Nunn Wellbore: iH-21A iii�u,5 61r�pIN'S)e4 a,ni q U, MjW am' Tie on MD: 7807.30 IIFIu]/DHiGL; Veatirgl (P/Of R¢lererce: 11421®96.__it 11-21) 6 inRelent filol-PAON, OmE) Plan: 1H-21A_wp01 (i H•2t/iH-21A) xmi. leeaxml¢ 2 Mree"°1cdiu�m IIII vlllblro 118.19/IFIJ 4900 1 III-Iwlll M H. e1114211 14]-101/IH-101 141-101/gw011.1 Ix-101/ii u1.IDuN{-loud 141-10^JI41-IoiL3 Ix zrvul-2° H1a4/u+-w 1x- ,. 59505 - I - -1 IDI/(t+IOILJ IH 10WH-102L'4.� RATER GI ES GErompany I-19/IH 19ALj1S�iy HMi 'Iln 1-112 n - - - ii/I� i7 .. 11141H/111 IIA I II 5600d y iii�u,5 IIFIu]/DHiGL; 52501 III III um IIII vlllblro 118.19/IFIJ 4900 1 III-Iwlll n II '.V111-�. slNn ' _ 4550- 1111911 p -I• lv 111-1011 H-Irlld � IIIIIUIIII In IH-U'/III-IY 42001 I-01 IIP17/II1.10AITI 1 IIA/III-IH e uSR�I 111 a Nl AID: 1 1 _ .� Ln II I�I;illl l-IGnI .Igen II IA i 1H l7AfII: III J9/If10]A III -11'11 .VIII A III MIII-101 2500, OnOU v FC= I + I-19/IH 19ALj1S�iy HMi ii/I� i7 .. z 00 118.19/IFIJ III-Iwlll n _ 1 lv � IIIIIUIIII In IH-U'/III-IY �I r" 2100 16 N u* OOiI III' U/I -w, + 11IIi/III-n 1 k- _ L' 17501 uF1 nl r w tlNl a -In 1400 1 4 nu''-mlie IIIU3IIIt+,r '1050- '; '- III-III/IIIIII _Y�' 0011 O 700 Izl;ll I-1 l.v' 35D1 s •v II4JII11-91n1.}UI ( 1H -J01 maWpllla(�I - I -3501 1H{INIHL4LL•70p _ � IHLYIH-0iLIDI NI 'I. 'e 3 _Ih.li'11-It 'i -105U- 1050-1400 -14001 d4� Ilb"zrn -1750 suo„ _ -21001 OP -1750 -1400 -1050 -7C0-.- 50 OT 350 700 105U 1400 1750 2100 2450 2800', 3150 15001, 1850 42004550 g9pp 9250 5600 5950 6300 6650 7000 7350 77DO 8050 8400 8950 9100 9450 9800 West( -)/East(+) (350 usft/in) H-bvD+o9 11-1-21@%.00ueft(1 H-21) nILMIHoa u{ -un H -H IIILL14IU2 II{-DI/II{.DI 11418/111 -IB KUP 1H-21 „_ OCO I Ips - '- ' Well Attributes Maz Aa eB MD 721 PlaSKa. Inc. JWMellboreA."e" Fiele Name wall status Incl, MO I.K.) 500292235500 KUPARUK RIVER UNIT PROD 41.59 3,885.60 Act atm(an.) 8,315.0 Comment 143SIPpm) Dab AnnafatlAn Ena Oate KB-Gre (ft) Rig Release Date walco nI.. AgIGaM SSSV: TRDP 100 9262011 Last WO: 3/28/1993 mI AnnmeuonDepm lnKal Ene Daz annotalbn Last mne._ Last Tag: SLM 7,896.0 4/2612012 Rev Reason: WELL REVIEW as Fna Dale 6111)2012 Casin Strin t; xaxGBR. ae csbe DeacrlPxon stone o... sttlnD lD._rov lnnal sM Demn B..set DapinIWD1... Stang Wl.. Otring... slrinP roP Th. CONDUCTOR 16 15.062 41.0 121.0 121.0 62.50 H10 WELDED Caaing peacnptlon StrIn9 O.., atrin9lD _. TOP IXNe) SetDePq IG. Se10ePlM1(rVD)... SVin91VL. 5trin9 -Shing TOPTM1ra SURFACE 9518 8.921 40.2 4,820.4 4,24].1 3600 J-55 BTC lion String 0... a[ring l6 ... iop 10x8) Se8.296M1 IL. Set DepIM1INDL.. String W1.. 54ing... Stang iop TM1rtl PRODUCTION PRODUCTION ] 6.216 38.8 8.296.2 fi,946.9 26.00 J-55 AB -MOD Tubing Strings CONDOCTOR, a-121 Tuhing Description SLIn1 D... Slang lD... Top(nKBl Set Depin ll... Sel DepIM1IND1... elnng W1... 3lring,. Sting TOp Tnra TUBING 312 2992 3].6 ],692.9 6.4]5.2 9.30 J-55 EUEBRDMOD Co letlon Details oP oaob MD) Top Incl Topinna (Ran I PI Hama ... malbn comment IOOnI 9AFEn OLV. 1.AM 37.61 37.6 0.13 HANGER FMC GEN IV HANGER 3.500 1,]89.3 1,783.2 14.35 SAFETY WV CAMCO TRDP4A-R0 SAF -VALVE 2.812 7.650.1 6,441.9 39.00 PER BAKER PER w/10' STROKE (TOP OF PER HAS 412" RH SQUARE 3.000 THREAD FOR PKR RETRIEVAL) GAsuFT. 7,663.9 6,452.7 39.00 PACKER BAKER HE RETRIEVABLE PACKER 2.890 2x1 7,680.3 6.465.4 38.95 NIPPLE CAMCO D NIPPLE NO GO 2.750 7,692.0 6,474.5 38.9]S0S BAKER SHEAR OUT SUB 3.015 Perforations & Slots G SLIF R Shot Top(Tao)Blue To Btm858.0 eK.) Zone One lab... Job Type Comm"' 68. ].]68.0 6.53) ],050.21 6,5335 6, 3 6,fiO3J UNITD, Cd, C-3, 1H-21 811611993 6.0IPEgF 2118'Ene0et, 90 Eeg. phasing 7.918.0 7,948.0 6,00J 6,674.21P1, UNIT B, 612811993 12.0 (PERF SINS 6,5" HJ2, 60 d". phasing H-21 Notes: General $ Safety -aDale Annnmron 912112010 NOTE:Vlew SChem.Ik,w/ Alaska Schemalice0 SUPFPCE,� dad.em GASOFT. Stu OAS OFT. 5,9E GAS un, &]1a .As un. ].10] ws LW7 7.. - pBR.],fiW PACKER.T.YN MPPLE Tfl G SOS, 7,sa Mandrel Details )PERF, ].reSaM Stn Tap Depth Top Part IND) Incl 00 Valvu Lahn Pae TRO Run Tap IAKB) InKel CI MaW Model Ila) Se, Type Type 9n) (PSI) Run One Com.. 1 2,5705 2,495.4 31.02 CAMCO KBUG 1 GAS LIFT GLV BKS 0.155 1,260.0 &5200] )PERF Ta1aT.ade 3,890.4 40.04 CAMCO KBUG 1 GAS LIFT OV BK5 0.250 0.0 86200] 4,495.7 39.97 CAMCO KBUG 1 GAS LIFT D BK5 0.000 0.0 81512007 5,089.9 39.]2 CAMCO KBUG 1 GAS LIFT 0.0 85200] 5.702.6 3.75 CAMCO KBUG 1 GAS LIFT 0.0 5/1311999 V 6,074.9 MAT CAMCO KBUG 1 GAS LIFT 0.0 8113/1999 M 6.404.7 39.04 CAMCO MIA -2 112 GAB LIFT 0.0 7/18/1993 PRDDUCTON. se.2sa rD. e.ms 16" 62# H40 shoe @ 121' MD 9-5/8- 36# J-55 shoe @ 4820' # J @ 7825' C -sand perfs 7768'- 7858' MD 7918'- 7948' MD pilot hole MR 1 H-21 Proposed CTD Schematic Modified by 1JO 6/21/18 3-1/2" Cameo TRDP=4A-RO SSSV at 1789' MD (2.812") 3-1/2" 9.3# J-55 EUE 8rd Tubing to surface 3-1/2" Camco MMG gas lift mandrel at 2571', 4355', 5143', 5922', 6710', 7183', 7602' Baker 3-1/2" PBR at 7650' MD BakerHB packer at 7664' MD (2.89" ID) D -nipple at 7680" MD (2.75" min ID, No -Go) 3-1/2" Baker SOS @ 7692' MD Top of (North) Top of billet ®6200' MD iH-21AL1 (N -M) OH Anchor billet @ 7925' MD iH-21Al2 (EesQ Top of Billet � 8,E00MD r77" 26# J-55 ro, w shoe @ 8296' MD �Ir',-�y 'A 1H-21AL2-01 (East) ='26# �J-55 Tap of Liner @ 7,675 MD ConocoPhillips Mean E c ElArR ES ecEca,wanv Project: Kuparuk River Unit DETAILS: u.a xa%. vnr• WELLBORE DETAILS: 1H.21ALi REFERENCE INFORwHON Site: Kuparuk 1H Pad +N/ -S +E/ -W Northing Easting Well; 1H-21 Latitude woes F.N Parent Wellbore' 1H -21A Cu &nW(NE)Rafe- WeltNatJS Nam 5980024.57 549555.22 sN�am:67usa>n Tie on MD: 8200.00 veum gve) Releerro: ME,5S.arol Wellbore: 1H.21AL7 See ap Aryk mar Inc s.mn(vS) Re(eeme: Sbt-(0MN.0MQ Plan: tX-2tAL1_W02(1H-2111X.21AL1) -S vWN G�w.., Deg uepamm hope R.... t ha1®Sa.aowanx-t0 CdMmon wane: Wmum cumim Mean E c ElArR ES ecEca,wanv WELL DETAILS: 1H-21 +N/ -S +E/ -W Northing Easting Latitude Longitude 0.00 0.00 _- 5980024.57 549555.22 70° 21' 22.356 N 149° 35'51.196 W See MD Inc Azi TV -S +E/ -W Deg TFace VSect Annota on 1 8200.00 91.20 355.98 6537.98 70.48 3936.04 0.00 0.00 70.48 TIP/KOP 2 8400.00 78.05 351.13 6556.69 267.86 3913.83 7.00 200.00 267.86 Start 7 cls 3 8550.00 87.59 346.71 6575.41 413.69 3885.21 7.00 335.00 413.69 3 4 8825.00 87.73 5.97 6566.74 686.61 3867.75 7.00 ROD 686.61 4 5 9000.00 87.78 353.71 6593.62 861.14 3867.27 7.00 270.00 861.14 5 6 9200.00 90.25 339.93 6597.07 1055.35 3821.78 7.00 280.00 1055.35 6 7 9500.00 90.24 0.93 6595.78 1349.52 3772.19 7.00 90.00 1349.52 7 8 9850.00 87.73 336.55 6602.09 1690.13 3704.41 7.00 264.00 1690.13 8 9 9950.00 87.75 329.55 6606.04 1779.14 3659.16 7.00 270.00 1779.14 9 1010400.00 90,17 0.96 6614.44 2208.80 3546.13 7.00 86.00 2208.80 10 11 10550.00 90,16 350.46 6614.01 2358.17 3534.93 7.00 270.00 2358.17 11 1210750.00 86.57 4.00 6619.74 2557.36 3525.27 7.00 105.00 2557.36 12 13 10850.00 86.59 356.99 6625.71 2657.11 3526.13 7.00 270.00 2657.11 13 14 11050.00 87.18 11.00 6636.62 2855.83 3540.01 7.00 88.00 2855.83 14 15 11250.00 89.67 357.21 6642.15 3054.75 3554.27 7.00 280.00 3054.75 15 16 11550.00 89.69 336.21 6643.85 3345.08 3485.71 7.00 270.00 3345.08 Planned TD at 11550.0 Mean E c ElArR ES ecEca,wanv west( -)/East(+) (300 usf /in) 6000 6100 _- 6200 6300 6 2 6400 TIP/K P IX WIN 21AL 6500 I, j ¢1-21/ N-21 6600 ,r 1■■■■\111■■■ ■■■■■■■■I .. 3 1. 5 6 7 IH 21/IH 2IA -01 1. ana-ft ar 115 . 6800 H-21/ H-21 LI -IH-2 /I11-2 6900 7000 ea L 1■■■i��..._�..■j�■i r. MLR�®.�.�■■■■.■I 1�■■■■■■\.iii■■_■■_■■�■' .rr west( -)/East(+) (300 usf /in) 6000 6100 _- 6200 6300 6 2 6400 TIP/K P IX WIN 21AL 6500 I, j ¢1-21/ N-21 6600 6700-.... .. 3 1. 5 6 7 IH 21/IH 2IA -01 1. ana-ft ar 115 . 6800 H-21/ H-21 LI -IH-2 /I11-2 6900 7000 ea L Vertical Section at 0.001 (100 usft/in) ConocoPhillips ConocoPhillips (Alaska) Inc. -Kupl Kuparuk River Unit Kuparuk 1H Pad IH -21 1H-21AL1 Plan: 1H-21AL1_wp02 Standard Planning Report 25 June, 2018 BT�a GHES GE company ConocoPhillips BAKER ConocoPhillips Planning Report TR .GEmmpany Database: EDT Alaska Sandbox Company: ConocoPhillips (Alaska) Inc.-Kupl Project: Kuparuk River Unit Site: Kuparuk 11H Pad Well: 1H-21 Wellbore: 1 H-21AL1 Design: 1 H-21AL7_wp02 Local Coordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Well 1 H-21 Mean Sea Level 1 H-21 Q 96.00usft (1 H-21) True Minimum Curvature Project Kuparuk River Unit, North Slope Alaska, United States Map System: US State Plane 1927 (Exact solution) System Datum: Mean Sea Level Geo Datum: NAD 1927 (NADCON CONUS) Using Well Reference Point Map Zone: Alaska Zone 04 Using geodetic scale factor Site Kuparuk 1 H Pad 1 H-21 Site Position: Northing: 5,979,968.84usft Latitude: 70° 21 21.831 N From: Map Easting: 549,197.16 usft Longitude: 149° 36'1.675 W Position Uncertainty: 0.00 usft Slot Radius: 0.000 in Grid Convergence: 0.38 ° well - 1 H-21 Magnetics Model Name Sample Date Well Position +N/S 0.00 usft Northing: 5,980,024.57 usft Latitude: 70° 211'22.356 N +E/ -W 0.00 usft Easting: 549,555.22 usft Longitude: 149° 35'51.196 W Position Uncertainty Phase: 0.00 usft Wellhead Elevation: usft Ground Level: 54.40 usft Wellbore 1H-21ALl Magnetics Model Name Sample Date BGGM2018 9/l/2018 Design 11-21AL1_wp02 Audit Notes: Build Turn Version: Inclination Phase: PLAN Vertical Section: +E/ -W Depth From (TVD) +N/ -S Rate TFO (usft) (usft) (I (usft) -54.40 0.00 Declination 17.01 625/2018 4:O7., Dip Angle Field Strength K) 80.91 57,446 Tie On Depth: 8,200.00 +E/ -W Direction (usft) (I 0.00 0.00 Plan Sections Measured TVD Below Dogleg Build Turn Depth Inclination Azimuth System +Nl-S +E/ -W Rate Rate Rate TFO (usft) (') (I (usft) (usft) (usft) (°/tooft) (°1100ft) (-1100ft) (1) 8,200.00 91.20 355.98 6,53798 70.48 3,936.04 0.00 0.00 0.00 0.00 8,400.00 78.05 351.13 6,556.69 267.86 3,913.83 7.00 -6.57 -2.43 200.00 8,550.00 87.59 346.71 6,575.41 413.69 3,885.21 7.00 6.36 -2.95 335.00 8,825.00 87.73 5.97 6,586.74 686.61 3,867.75 7.00 0.05 7.01 90.00 9,000.00 87.78 353.71 6,593.62 861.14 3,867.27 7.00 0.03 -7.01 270.00 9,200.00 90.25 339.93 6,597.07 1,055.35 3,821.78 7.00 1.24 -6.89 280.00 9,500.00 90.24 0.93 6,595.78 1,349.52 3,772.19 7.00 -0.01 7.00 90.00 9,850.00 87.73 336.55 6,602.09 1,690.13 3,704.41 7.00 -0.72 -6.96 264.00 9,950.00 87.75 329.55 6,606.04 1,779.14 3,659.16 7.00 0.02 -7.01 270.00 10,400.00 90.17 0.96 6,614.44 2,208.80 3,546.13 7.00 0.54 6.98 86.00 10,550.00 90.16 350.46 6,614.01 2,358.17 3,534.93 7.00 0.00 -7.00 270.00 10,750.00 86.57 4.00 6,619.74 2,557.36 3,525.27 7.00 -1.80 6.77 105.00 10,850.00 86.59 356.99 6,625.71 2,657.11 3,526.13 7.00 0.03 -7.01 270.00 11,050.00 87.18 11.00 6,636.62 2,855.83 3,540.01 7.00 0.29 7.00 88.00 11,250.00 89.67 357.21 6,642.15 3,054.75 3,554.27 7.00 1.24 -6.89 280.00 11,550.00 89.69 336.21 6,643.85 3,345.08 3,485.71 7.00 0.01 -7.00 270.00 Target 57PM page 2 COMPASS 5000.14 Build 85 ConocoPhillips BAR ConocoPhillips Planning Report UGHES a GE.liany Database: EDT Ala Company: Conoco Project: Kuparuk Site: Kuparu Wet]: 1H-21 Wellhore: 1 H-21 AL Design: 1H -21A Planned Survey Measured Depth Inclination (usft) (1) 8,200.00 91.20 TIP/KOP 8,300.00 84.62 8,400.00 78.05 Start 7 dls 8,500.00 84.41 8,550.00 87.59 3 8,600.00 87.60 8,700.00 87.63 8,800.00 87.71 8,825.00 87.73 4 8,900.00 87.74 9,000.00 87.78 5 9,100.00 89.01 9,200.00 90.25 6 9,300.00 90.25 9,400.00 90.24 9,500.00 90.24 7 9,600.00 89.50 9,700.00 88.78 9,800.00 88.07 9,850.00 87.73 a 9,900.00 87.73 9,950.00 87.75 9 10,000.00 88.00 10,100.00 88.51 10,200.00 89.05 10,300.00 89.61 10,400.00 90.17 10 10,500.00 90.16 10,550.00 90.16 11 10,600.00 89.26 10,700.00 87.46 10,750.00 86.57 12 10,800.00 86.58 10,850.00 86.59 13 10,900.00 86.72 11,000.00 87.02 11,050.00 87,18 14 sks Sandbox Phillips (Alaska) Inc. -Kupl River Unit k IH Pad L1_wp02 Local Coordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Well 1 H-21 Mean Sea Level 1H-21 rQ 96.00usft(11-1-21) True Minimum Curvature 350.21 TVD Below 462.63 3,875.21 Vertical Dogleg Toolface Map Map Azimuth System -NIS +Ef-W Section Rate Azimuth Northing Easting (•) (usft) (usft) (usft) (usft) (-/100ft) V) (usft) (usft) 355.98 6,537.98 70.48 3,93604 70.48 0.00 0.00 5,980,121.08 553,490.1 353.58 6,541.63 169.94 3,926.96 169.94 7.00 -160.00 5,980,220.46 553,480.5E 351.13 6,556.69 267.86 3,913.83 267.86 7.00 -159.91 5,980,318.29 553,466.81 348.16 6,571.93 365.01 3,896.06 365.01 7.00 -25.00 5,980,415.31 553,448.4( 346.71 6,575.41 413.69 3,885.21 413.69 7.00 -24.55 5,980,463.91 553,437.2- 350.21 6,577.51 462.63 3,875.21 462.63 7.00 90.00 5,980,512.78 553,426.91 357.22 6,581.67 561.88 3,864.28 561.88 7.00 89.85 5,980,611.94 553,415.32 4.22 6,585.74 661.73 3,865.53 661.73 7.00 89.56 5,980,711.79 553,415.91 5.97 6,586.74 686.61 3,867.75 686.61 7.00 89.28 5,980,736.68 553,417.97 0.72 6,589.71 761.39 3,872.12 761.39 7.00 -90.00 5,980,811.49 553,421.84 353.71 6,593.62 861.14 3,867.27 861.14 7.00 -89.79 51980,911.19 553,416.33 346.82 6,596.43 959.60 3,850.38 959.60 7.00 -80.00 5,981,009.52 553,398.79 339.93 6,597.07 1,055.35 3,821.78 1,055.35 7.00 -79.81 5,981,105.08 553,369.57 346.93 6,596.63 1,151.14 3,793.28 1,151.14 7.00 90.00 5,981,200.67 553,340.44 353.93 6,596.20 1,249.69 3,776.67 1,249.69 7.00 90.03 5,981,299.09 553,323.17 0.93 6,595.78 1,349.52 3,772.19 1,349.52 7.00 90.06 5,981,398.89 553,318.03 353.97 6,596.01 1,449.36 3,767.74 1,449.36 7.00 -96.00 5,981,498.68 553,312.92 347.01 6,597.51 1,547.92 3,751.23 1,547.92 7.00 -95.98 5,981,597.11 553,295.76 340.04 6,600.26 1,643.71 3,722.89 1,643.71 7.00 -95.88 5,981,692.71 553,266.79 336.55 6,602.09 1,690.13 3,704.41 1,690.13 7.00 -95.69 5,981,739.00 553,248.01 333.05 6,604.07 1,735.33 3,683.15 1,735.33 7.00 -90.00 5,981,784.05 553,226.45 329.55 6,606.04 1,779.14 3,659.16 1,779.14 7.00 -89.86 5,981,827.71 553,202.17 333.04 6,607.90 1,822.96 3,635.16 1,822.96 7.00 86.00 5,981,871.36 553,177.89 340.03 6,610.95 1,914.59 3,595.38 1,914.59 7.00 85.87 5,981,962.72 553,137.51 347.01 6,613.07 2,010.40 3,567.03 2,010.40 7.00 85.66 5,982,058.33 553,108.53 353.98 6,614.25 2,108.96 3,550.53 2,108.96 7.00 85.51 5,982,156.76 553,091.38 0.96 6,614.44 2,208.80 3,546.13 2,208.80 7.00 85.43 5,982,256.56 553,086.31 353.96 6,614.16 2,308.64 3,541.70 2,308.64 7.00 -90.00 5,982,356.36 553,081.23 350.46 6,614.01 2,358.17 3,534.93 2,358.17 7.00 -90.02 5,982,405.84 553,074.13 353.84 6,614.26 2,407.69 3,528.10 2,407.69 7.00 105.00 5,982,455.31 553,066.97 0.61 6,617.13 2,507.47 3,523.26 2,507.47 7.00 104.98 5,982,555.05 553,061.48 4.00 6,619.74 2,557.36 3,525.27 2,557.36 7.00 104.79 5,982,604.94 553,063.15 0.49 6,622.73 2,607.22 3,527.23 2,607.22 7.00 -90.00 5,982,654.81 553,064.78 356.99 6,625.71 2,657.11 3,526.13 2,657.11 7.00 -89.79 5,982,704.69 553,063.35 0.49 6,628.62 2,707.01 3,525.03 2,707.01 7.00 88.00 5,982,754.57 553,061.93 7.50 6,634.09 2,806.55 3,531.98 2,806.55 7.00 87.80 5,982,854.15 553,068.22 11.00 6,636.62 2,855.83 3,540.01 2,855.83 7.00 87.41 5,982,903.48 553,075.91 825/2018 4:07:57PM Page 3 COMPASS 5000.14 Build 85 ConocoPhillips BAKER ConocoPhillips Planning Report 1'UGHES a GEwnivany Database: EDT Alaska Sandbox Company: CanocoPhillips (Alaska) Inc. -Kupt Project: Kuparuk River Unit Site: Kuparuk 1H Pad Well: 1H-21 Wellbore: 1H-21AL1 Design: 1 H-21AL1_WP02 Local Coordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Well 1 H-21 Mean Sea Level 1H-21 @96.00usft(I H-21) True Minimum Curvature Planned Survey Measured TVD Below Vertical Dogleg Toolface Map Map Depth Inclination Azimuth System -NIS +E/ -W Section Rate Azimuth Northing Easting (usft) (°) (1 (usft) (usft) (usft) (usft) (°/100ft) (°) (usft) (usft) 11,200.00 89.04 0.66 6,641.59 3,004.77 3,555.20 3,004.77 7.00 -79.85 5,983052.50 553,090.12 11,250.00 89.67 357.21 6,642.15 3,054.75 3,554.27 3,054.75 7.00 -79.66 5,983,102.46 553,088.86 15 11,300.00 89.67 353.71 6,642.44 3,104.58 3,550.31 3,104.58 7.00 -90.00 5,983,152.27 553,084.57 11,400.00 89.67 346.71 6,643.02 3,203.06 3,533.33 3,203.06 7.00 -89.98 5,983,250.62 553,066.94 11,500.00 89.68 339.71 6,643.58 3,298.74 3,504.46 3,298.74 7.00 -89.94 5,983,346.10 553,037.45 11,550.00 89.69 336.21 6,643.85 . 3,345.08 3,485.71 3,345.08 7.00 -89.90 5,983,392.31 553,018.38 Planned TO at 11650.00 8252018 4:07:57PM Page 4 COMPASS 5000.14 Build 85 ConocoPhillips Database: EDT Alaska Sandbox Company: ConocoPhillips (Alaska) Inc. -Kup1 Project: Kuparuk River Unit Site: Kupamk 1 H Pad Well: 1H-21 Wellbore: IH-21AL1 Design: 1 H-21AL7_WP02 ConocoPhillips Planning Report Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: EAIUGHES a GEoxn,xW Well 1H-21 Mean Sea Level iH-21 @ 96.00usft (1 H-21) True Minimum Curvature Targets 1,693,283.00 70" 5'54.714 N 140° 23'41.999 W - plan misses target center by 1139922.26usft at 8200,00usft MD (6537.98 TVD, 70.48 N, 3936.04 E) Target Name - Polygon - hitlmiss target Dip Angle Dip Dir. TVD -N/,S +E/ -W Northing Basting 0.00 -Shape (°j (°) (usft) (usft) (usft) (usft) (usft) Latitude Longitude 1 H-21 AL1_T02 0.00 0.00 6,592.00 -6,931.511,143,993.17 5,980,661.00 1,693,458.00 70° 6'2.125 N 140° 23'33.429 W - plan misses target center by 1140078.63usft at 8200.00usft MD (6537.98 TVD, 70.48 N, 3936.04 E) 397.55 3,275.00 5,960,288.17 - Point Point 0.00 -885.89 3,166.56 IH-21ALi T03 0.00 0.00 6,595.00 -6,448.671,143,875.35 5,981,143.00 1,693,337.00 70'6'6.986N 140`23'34.690W - plan misses target center by 1139957.95usft at 8200.00usft MD (6537.98 TVD, 70.48 N. 3936.04 E) 1,694,728.03 - Point 0.00 -321.02 -2.11 5,979,548.00 1,693,283.01 1H-21AL7 T05 0.00 0.00 6,617.00 -5,479.101,143,655.74 5,982,111.00 1,693,111.00 70° 6'16.723 N 140° 23'36.738 W - plan misses target center by 1139733.21 usft at 8200.00usft MD (6537.98 TVD, 70.48 N, 3936.04 E) 1H-21AL1 T04 0.00 0.00 6,610.00 - Point 5,981,624.00 1,693,207.00 70° 6' 11.852 N 140° 23' 36.212 W - plan misses target center by 1139828.47usft at 8200.00usft MD (6537.98 TVD, 70.48 1 H-21AL1 T06 0.00 0.00 6,638.00 4,981.011,143,651.03 5,982,609.00 1,693,103.00 70'6'21.565 N 140° 23'34.709 W - plan misses target center by 1139726.19usft at 8200.00usft MD (6537.98 TVD, 70.48 N, 3936.04 E) - Point 1H-21AL1_T07 0.00 0.00 6,643.00 -4,487.731,143,618.29 5,983,102.00 IH -21 CTD Polygon Nor 0.00 0.00 0.00 -7,723.091,143,764.91 5,979,868.00 1,693,235.00 70° 5'54,778 N 140° 23'43.370 W - plan misses target center by 1139874.26usft at 8200.00usft MD (6537.98 TVD, 70.48 N, 3936.04 E) - Point - Polygon Point 1 0.00 0.00 0.00 5,979,868.00 1,693,235.00 Point 0.00 9.13 132.08 5,979,878.00 1,693,367.00 Point 0.00 272.48 84.80 5,980,141.01 1,693,317.99 Point 0.00 1,101.34 -31.78 5,980,969.00 1,693,195.94 Point 0.00 2,179.05 -272.73 5,982,044.99 1,692,947.89 Point 0.00 3,319.39 -304.25 5,983,184.98 1,692,908.83 Point 0.00 3,223.79 90.17 5,983,092.00 1,693,303.84 Point 0.00 1,937.50 110.73 5,981,806.00 1,693,332.90 Point 9 0.00 811.57 385.37 5,980,682.02 1,693,614.96 Point 10 0.00 -70.95 447.59 5,979,800.02 1,693,683.01 Point 11 0.00 -231.58 388.53 5,979,639.02 1,693,625.02 Point 12 0.00 -332.56 231.84 5,979,537.01 1,693,469.01 Point 13 0.00 -325.97 -11.14 5,979,542.00 1,693,226.02 Point 14 0.00 0.00 0.00 5,979,868.00 1,693,235.00 1H-21AL1_T01 0.00 0.00 6,583.00 -7,421.641,144,004.93 5,980,171.00 1,693,473.00 70' 5'57.350 N 140° 23'35.222 W - plan misses target center by 1140093.50usft at 8200.00usft MD (6537.98 TVD, 70.48 N, 3936.04 E) - Point 11-1-21 CTD Polygon Eas 0.00 0.00 0.00 -7,722.411,143,812.92 5,979,869.00 1,693,283.00 70" 5'54.714 N 140° 23'41.999 W - plan misses target center by 1139922.26usft at 8200,00usft MD (6537.98 TVD, 70.48 N, 3936.04 E) - Polygon Point 0.00 0.00 0.00 5,979,869.00 1,693,283.00 Point 0.00 25.79 1,403.34 5,979,904.07 1,694,686.00 Point 3 0.00 397.55 3,275.00 5,960,288.17 1,696,554.98 Point 0.00 -885.89 3,166.56 5,979,004.16 1,696,455.04 Point 0.00 -735.54 1,440.34 5,979,143.07 1,694,728.03 Point 0.00 -321.02 -2.11 5,979,548.00 1,693,283.01 Point 0.00 0.00 0.00 5,979,869.00 1,693,283.00 1H-21AL1 T04 0.00 0.00 6,610.00 -5,966.771,143,748.52 5,981,624.00 1,693,207.00 70° 6' 11.852 N 140° 23' 36.212 W - plan misses target center by 1139828.47usft at 8200.00usft MD (6537.98 TVD, 70.48 N, 3936.04 E) - Point 1H-21AL1_T07 0.00 0.00 6,643.00 -4,487.731,143,618.29 5,983,102.00 1,693,067.00 70° 6'26.402 N 140' 23'33.499 W - plan misses target center by 1139691.37usft at 8200.00usft MD (6537.98 TVD, 70.48 N, 3936.04 E) - Point 6252018 4:07:57PM Page 5 COMPASS 5000.14 Build 85 ConocoPhillips Database: EDT Alaska Sandbox Company: ConocaPhillips (Alaska) Inc. -Kupl Project: Kuparuk River Unit Site: Kupawk 1H Pad Well: 1H-21 Wellbore: 1 H-21 AL1 Design: 1H-21AL1_wp02 6,586.74 9,000.00 Casing Points 9,200.00 6,597.07 Measured Vertical 6,595.78 Depth Depth 6,602.09 (usft) (usft) 6,606.04 11.550.00 6,643.85 2 3/8" Plan Annotations I Measured Vertical Depth Depth (usft) (usft) 8,200.00 6,537.98 8,400.00 6,556.69 8,550.00 6,575.41 8,825.00 6,586.74 9,000.00 6,593.62 9,200.00 6,597.07 9,500.00 6,595.78 9,850.00 6,602.09 9,950.00 6,606.04 10,400.00 6,614.44 10,550.00 6,614.01 10,750.00 6,619.74 10,850.00 6,625.71 11,050.00 6,636.62 11,250.00 6,642.15 11,550.00 6,643.85 ConocoPhillips I BAI(ER Planning Report Name (in) TR 2.375 3.000 aGEcompany Local Co-ordinate Reference: Well 1H-21 267.86 TVD Reference: Mean Sea Level 413.69 MD Reference: 1 H-21 @ 96.00usft (I H-21) 686.61 North Reference: True 861.14 Survey Calculation Method: Minimum Curvature 1,055.35 Casing Hole Diameter Diameter Name (in) (in) 2.375 3.000 Local Coordinates +N/S +E/ -W (usft) (usft) Comment 70.48 3,936.04 TIP/KOP 267.86 3,913.83 Stan 7 d1 413.69 3,885.21 3 686.61 3,867.75 4 861.14 3,867.27 5 1,055.35 3,821.78 6 1,349.52 3,772.19 7 1,690.13 3,704.41 8 1,779.14 3,659.16 9 2,208.80 3,546.13 10 2,358.17 3,534.93 11 2,557.36 3,525.27 12 2,657.11 3,526.13 13 2,855.83 3,540.01 14 3,054.75 3,554.27 15 3,345.08 3,485.71 Planned TD at 11550.00 6252018 4:O7:57PM Page 6 COMPASS 5000 14 Build 85 ConocoPhillips Company: ConocoPhillips (Alaska) Inc. -Kupl Project: Kuparuk River Unit Reference Site: Kuparuk 1 H Pad Site Error: 0.00 daft Reference Well: 1 H-21 Well Error: 0.00 usft Reference Wellbore 1H-21 AL1 Reference Design: 1 H-21AL1_wp02 l ConocoPhillips Travelling Cylinder Report Local Co-ordinate Reference: Well 1 H-21 TVD Reference: 1H-21 oQ 96.00usft(1 H-21) MD Reference: IH -21 Q 96.00usft (1 H-21) North Reference: True Survey Calculation Method: Minimum Curvature Output errors are at 1.00 sigma Database: EDT Alaska Prod Offset TVD Reference: Offset Datum a �UGHU Unxrpany Reference 1H-21AL1_wp02 Filter type: GLOBAL FILTER APPLIED: All wellpaths within 200'+ 100/1000 of reference Interpolation Method: MD Interval 25.00usft Error Model: ISCWSA Depth Range: 8,200.00 to 11,550.00usft Scan Method: Tray. Cylinder North Results Limited by: Maximum center -center distance of 1,350.84 usft Error Surface: Pedal Curve Survey Tool Program Date 6/25/2018 Casing From To Depth Reference (usft) (usft) Survey (Wellbore) Tool Name Description 102.20 7,807.301H-21 Srvy1-SLB_GCT-MS(1 H-21) GCT -MS Schlumberger GCT mullishot 7,807.30 8,200.00 1H -21A wp03(1 H -21A) MWD MWD - Standard 8,200.00 11,550.00 1H-21 AL1_wp02(1 H-21 AL1) MWD MWD -Standard Casing Points Measured vertical Casing Hale Depth Depth Reference Diameter Diameter (usft) (usft) Name Measured Measured 121.00 121.00 16" 16 24 4,820.00 4.246.83 95/8" 9-5/8 12-1/4 11,550.00 6,739.85 23/8" 2-3/8 3 Summary Reference Offset Centre to No -Go Allowable Measured Measured Centre Distance Deviation Warning Site Name Depth Depth Distance (usft) from Plan Offset Well - Wellbore - Design (usft) (usft) (usft) (usft) Kuparuk 1H Pad 1 H-05 - 1 H-05 -1 H-05 Out of range 1 H-05 - 1 H-105 - 1 H-105 Out of range 1 H-06 - 1 H-06 - 1 H-06 Out of range 1 H-07 - 1 H-07 - 1 H-07 Out of range 1 H-07 - 1 H -07A - 1 H -07A Out of range 1 H-07 - 1 H-07APB1 - 1 H-07APBI Out of range 1 H-07 - 1 H-07APB2 - 1 H-07APB2 Out of range 1 H-07 - 1 H-07APB3 - 1 H-07APB3 Out of range 1 H-08 - 1 H-08 - 1 H-08 Out of range 1 H-09 - 1 H-09 -1 H-09 Out of range 1 H-10 - 1 H-10 - 1 H-10 Out of range 1 H-10 - 1 H-1 OA - 1 H-1 OA Out of range IH -101 - IH -101 - 11-1-101 Out of range 1 H-101 - 1 H-101 L7 - 1 H-101 -1 Out of range 1 H-101 - 1 H-101 L2 - 1 H-101 L2 Out of range 1 H-101 -1 H-101 L3 - 1 H-101 L3 Out of range 1 H-101 - 1 H-101 L4 - 1 H-101 L4 Out of range 1 H-102 -1 H-102 -1 H-102 Out of range 1 H-102 -1 H-10211 -1 H-10211 Out of range 1 H-102 -1 H-10212 - 1 H-10212 Out of range 1 H-102 - 1 H-10213 - 1 H-10213 Out of range 1 H-102 - 1 H-10214 -1 1-1-10214 Out of range IH -11 - 1H-11 - 1 H-11 Out of range 11-1-12- 1 H-12 - 11-1-12 9,133.52 7,875.00 887.88 245.93 649.24 Pass - Major Risk 1H -13 -1H -13-1H-13 Out of range CC - Min centre to center distance or covergent point SF - min separation factor, ES - min ellipse separation 825/2018 9:51:01AM Page 2 COMPASS 5000.14 Build 85 ConocoPhillips HATER ConocoPhillips Travelling Cylinder Report IGHES HATER Company: ConocoPhillips (Alaska) Inc. -Kupi Local Coordinate Reference: Well 1 H-21 Project: Kupamk River Unit TVD Reference: 1 H-21 @ 91 (11-1-21) Reference Site: Kuparuk 1H Pad MD Reference: 1H-21 @ 96,00usft (1H-21) Site Error, 0.00 usft North Reference: True Reference Well: 1H-21 Survey Calculation Method: Minimum Curvature Well Error: 0.00 usft Output errors are at 1.00 sigma Reference Wellbore 1H-21ALl Database: EDT Alaska Prod Reference Design: 1 H-21AL1_wp02 Offset TVD Reference: Offset Datum Summary Kupawk 1 H Pad - 11 -1 -12 -IH -12-11-1-12 Reference Offset Centre to No -Go Allowable Measured Measured Centre Distance Deviation Warning Site Name Depth Depth Distance (usft) from Pian SemihujorA is Offset Well - Wellbore - Design (usft) (usft) (usft) (usft) Kuparuk 1 H Pad Measured Venial Measured 1 H-14 -1 H-14 - 1 H-14 Reference ofrset Toolface4 onset wellSore Centre Out of range 1 H-15 - 1 H-15 - 1 H-15 No Go A11.1M wamirq oud, Out of range 1 H-18 - 1 H-18 - 1 H-18 Di Aslmuth Out of range 1 H-21 - 1 H-21 -1 H-21 RMe Sou Centre Distance Deviation Out of range 1H -21 -1H -21A -1H-21 A_wp03 8,521.34 8,525.00 64,51 1.04 63.93 Pass -Minor l/10 1 H-21 - 1 H-21 AL2 - 1 H-21AL2_WP02 (Ran) (uaR) 19 (iii Out of range 1 H-21 - 1 H-21 AL2 -01 - 1 H-21 AL2-01_wp02 9,129.90 6.692.85 8,50000 Out of range 1 H-22 - 1 H-22 - 1 H-22 50.03 57.16 128756 4,925.68 Out of range 1 H-401(UGNU) - 1 H-401 - 1 H-401 254.28 93280 Pass Major Risk 9,129.91 Out of range Plan: 1 H-106 - Plan: 1 H-106 - 1 H-106wp22 6.347.10 41.98 50.22 57,97 Out of range Plan: 1 H-107 - Plan: 1 H-107 - 1 H-107wp22 5 1,195.91 254.60 951.93 Out of range Plan: 1H-112- Plan: IH -112- 1 H-112wp22 6,692.85 0.475.00 832805 41.98 Out of range Plan: 1 H-112 - Plan: 1 H-112 - 1 H-112wp23 1,281.92 4,903.77 5 1,160.06 Out of range Rig: 1 H-108 - 1 H-1 08A - 1 H-1 08A wp01 Pau - Major Risk 9.130,04 6.892.05 0,550.00 Out of range Rig: 1 H-108 - 1 H-1088 - 1 H-1 08B wp02 5041 58.73 1,299.52 4.969.60 Out of range Offset Design Kupawk 1 H Pad - 11 -1 -12 -IH -12-11-1-12 offer Sita suor 0.00 usx Surrt'Pro'i io"CT-Ms Run Assgni Major Risk onaet mal Emr. 0.00 usft Reference Mae[ SemihujorA is Measured Venial Measured Venial Reference ofrset Toolface4 onset wellSore Centre Caeing- Centre to No Go A11.1M wamirq oud, Denim depth Di Aslmuth aN145 eEI4M RMe Sou Centre Distance Deviation (saaM ("aft) lusn) (usft) (ean) (usft) (9 (Ran) (uaR) 19 (iii into lose) 9,129.90 6.692.85 8,50000 5,336.67 41.90 50.03 57.16 128756 4,925.68 5 1,178.29 254.28 93280 Pass Major Risk 9,129.91 869285 8525.00 6.347.10 41.98 50.22 57,97 1,293.45 4,W,,Ki 5 1,195.91 254.60 951.93 Pass -Major Risk 9.130.00 6,692.85 0.475.00 832805 41.98 49.64 56.32 1,281.92 4,903.77 5 1,160.06 20.96 914.05 Pau - Major Risk 9.130,04 6.892.05 0,550.00 6.351 41.98 5041 58.73 1,299.52 4.969.60 5 1,215.93 254,93 971.46 Pass - Major Risk 9,130.11 6,692.85 8,45000 6,315.38 41,98 49.65 55.M 1.276.32 4,081,80 5 1,142.12 25383 095.68 Pass - Major Risk 9.130.21 6,592.85 8,425.00 8,304.72 41.98 49.46 54.54 1,270.71 4,859,95 5 1,124.44 253.31 877.57 Pass - Major Risk 9,130.23 6,61 0,575.00 6.367.32 41.90 50,60 5946 1,305.98 4,991.6) 5 1,235.20 255.25 991.33 Pass - Major Risk 9130,35 6,692.05 8,400.00 6,293.94 41.98 49.27 53.61 1.265.17 4,830.09 5 1,107.14 252.98 859.87 Pass - Maim Risk 9.130.43 6,692.85 0.600.00 8377.21 41,98 50]9 50.15 1,312.38 5,013.66 5 1,254.92 255.57 1,011.50 Pass -Malar Risk 9,130.53 6.692.05 5,375.00 8282,97 41.98 49.08 52.63 1,259.74 4,816.29 5 1.09030 252,W 842.67 Pass - Major Risk 9,130.63 6,692.86 8625.40 6,386.78 41.98 50.99 60.82 1,318.04 5,035.83 5 1,274.95 255,09 1,032.07 Pass - Major Risk 9,130]5 6.692.86 8,350.00 6,271.07 41.98 40.89 51,62 1,264.40 4794.54 5 1073.89 252.33 a25.94 Pass - Major Risk 9,130,86 6.692.86 8,650.00 6.395.90 41.98 51,18 61.44 1,325.41 5.050.13 5 1.295.38 256.21 1,053.04 Pass - Major Risk 9,131.01 6.692+86 81 6.260.56 41.98 48.70 50.56 1,249.15 4)72.97 5 1.058.00 252.01 809.73 Pass -Major Risk 9,131.10 6,692.96 0.675.00 6.404.95 41.9s 51.37 02.04 1,332.05 5,080.50 5 1316.11 256.52 1,074.29 Pass -Major Risk 9.131.27 6,692.86 8300.00 8,248.a7 41.98 48.51 49.46 1,243.94 4,751.39 5 1,042.80 251.68 794.21 Pass - Major Risk 9,131.33 6,692.86 8,700.10 6.413.72 41.90 5L57 62.61 1,338,74 5,103.04 5 1,337.21 258.83 1,095.92 Pass - Major Risk 9,131,53 6,692.86 9275.00 6.236.05 41.98 40.32 48.32 1.230]0 4,730.09 5 1,028.29 251.35 779.43 Pass. Major Risk 9,13134 8,69287 8.250.00 6,224.47 41.98 40.13 47.13 1,233.55 4,709.01 5 1,014.54 251.01 765,48 Pass - Major Risk 9,131.88 6,692.07 0,225.00 6,211.73 41.90 47.95 45.91 1,228.21 4.681 5 1,001.57 250,88 752.39 Pau - Major Risk 9,131.94 8892.87 8,200.00 6,198.85 41.98 47.76 44.88 1,222.80 4,667.44 5 909.20 250,34 739.99 Pass -Major Risk 9.132.02 6.892.57 8.175A0 6,105.99 41.98 47.58 43.37 1,217.30 4646,70 5 977.30 250.00 728.15 Pass - Major Risk 9.132.11 6.692.87 8.150.00 6,173.13 41.90 47.39 4205 1,212.00 4,625.94 5 365.89 249.65 716,91 Pass -Major Risk 9,132.22 6,692.97 8,125.00 6.160.20 41.98 47.21 40.70 1.297.62 4,605.19 5 955.00 249.33 706.28 Pass - Major Risk 9,132,35 6,692.87 8.100.00 6.147.45 41.98 47.02 39.32 1,201.27 4,594.41 5 944.52 248.99 896.29 Pass - Major Risk 9,132.47 6.692.87 0.075.00 0,13471 41.98 4681 37.91 1,1111 4.563.58 5 934,70 248.88 655.87 Pau - Major Risk CC - Min centre to center distance or covergent point, SF - min separation factor, ES - min ellipse separation 8252018 9:51:01AM Page 3 COMPASS 5000.14 Build 85 TRANSMITTAL LETTER CHECKLIST WELL NAME: K PTD: Z�o — O742 Development _ Service Exploratory _ Stratigraphic Test _ Non -Conventional FIELD: P`� POOL: Check Box for Appropriate Letter / Paragraphs to be Included in Transmittal Letter CHECK OPTIONS TEXT FOR APPROVAL LETTER MULTI The permit is for a new wellbore segment of existing well Permit LATERAL No. 7-18-0 77 , API No. 50- (If last two digits Production should continue to be reported as a function of the original in API number are API number stated above. between 60-69 In accordance with 20 AAC 25.005(f), all records, data and logs acquired for the pilot hole must be clearly differentiated in both well Pilot Hole name ( PH) and API number (50- from records, data and logs acquired for well name on permit). The permit is approved subject to full compliance with 20 AAC 25.055. Approval to produce/inject is contingent upon issuance of a conservation Spacing Exception order approving a spacing exception. (Comnanv Name) Operator assumes the liability of any protest to the spacing exception that may occur. All dry ditch sample sets submitted to the AOGCC must be in no greater Dry Ditch Sample than 30' sample intervals from below the permafrost or from where samples are first caught and 10' sample intervals through target zones. Please note the following special condition of this permit: production or production testing of coal bed methane is not allowed for Non -Conventional (name of weld 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 (Comnanv Name) in the attached application, the following well logs are also required for this well: Well Logging Requirements Per Statute AS 31.05.030(d)(2)(B) and Regulation 20 AAC 25.071, / composite curves for well logs run must be submitted to the AOGCC within 90 days after completion, suspension or abandonment of this well. Revised 2/2015 WELL PERMIT CHECKLIST Field & Pool KUPARUK RIVER, KUPARUK RIV OIL -490100 Permit can be issued w/o hydrogen_ sulfide measures ...... . . . . . . . ...........No...... Well Name: KUPARUK RIV UNIT 1H-21AL1 _--_.. Program DEV — Well bore seg ❑d PTD#:2180780 Company CONOCOPHILLIPS_ALASKA IN.C__ Initial Class/Type DEV/PEND -_GeoArea 890 Unit 11160 _ _ On/Off Shore On Annular Disposal El Administration 17 _ Nonconven. gas. conforms to AS31.05.0300.1.A),0.2.A-D) NA. _ _ - - _ Weil will be drilled using 8.6 ppg mud,. a coiled -tubing rig, and managed pressure drilling. ------------- '.1 Permit fee attached NA _ technique to control formation pressures and stabilize shale sections. NOTE: Chance of ----------- 39 2 Lease number appropriate .. - - Yes - Entire well -in ADL 025639. 3 Unique well name and number - ........ _ Yes 4 Well located in a defined pool.. - ... - - - - - Yes _ KUPARUK RIVER,. KUPARUK-RIV OIL -490100 - �5 Well located proper distance from drilling unit boundary.. Yes - Kuparuk River Oil Pool, governed by Conservation Order No. 432D - '6 Well located proper distance from other wells - Yes - - Conservation Order No. 432D has no interwell. spacing. restrictions. Wellbore. will be more than 500' - '.7 Sufficient acreage available in drilling unit. - - - Yes - from an external property line. where ownership or landownership. changes. As proposed, well will.... - _ - 18 If deviated, is wellbore plat included - Yes conform to spacing, requirements. 9 Operator only affected party. - - - _ - Yes 10 Operator has. appropriate bond in force ... ...... - - Yes Appr Date 11 Permit can be issued without conservation order- Yes 12 Permit can be issued without administrative. approval Yes SFD 7/2/2018 - - - 13 Can permit be approved before 15 -day weit. - _ - - Yes - . - ..... 14 Well located within area andstrataauthorized 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 18 Conductor string. provided - - - .. - - - - ... _ _ _ _ _ - NA - - - - - _ - Thru tubing CTD Sidetrack from existing wellbore - - - - - - - - - Engineering 19 Surface casing. protects all -known USDWs ... _ - - - _ - - NA - Thru tubing CTD Sidetrack from existing wellbore 20 CMT vol adequate to circulate -on conductor 8 surf csg NA - Thru tubing CTD Sidetrack from existing wellbore - - - - - - -- - - - - - - - 21 CMT vol adequate to tie-in long string to surf csg- - - NA .. - Thru tubing CTD Sidetrack from existing wellbore... 22 CMT will coverall knownproductivehorizons... - .... - - - - NA 23 Casing designs adequate for C, T, B A permafrost_ - - - ..... Yes 24 Adequate tankage. or reserve pit ......... . . . . . . . - _ - - Yes - - - - ......... 25 If.a re -drill, has. a 10-403 for abandonment been approved ........... - Yes 26 Adequate wellbore separation proposed - - - ...... - - - - - Yes I27 If.diverter required, does it meet regulations. - - _ - - _ - - NA_ Appr Date 28 Drilling fluid program schematic 8t equip list adequate- - - ... - - - Yes MGR 7/5/2018 29 BOPEs, do they meet regulation . - -----.............-...--- Yes - ------- ---- -.. -.. 30 BOPE.press rating appropriate; test to (put psig in comments)_ - - - . - ....... Yes - - Test to 3000 psi 31 Choke manifold complies w/API RP -53 (May 84)... - _ - - - ..... _ - Yes - - - - - - - - - - - - - - - - - - - - - - - - - - - - 32 Work will occur without operation shutdown . . . . . . . ........... . Yes 33 Is presence of H2S gas probable - - _ _ - _ _ - _ _ . Yes ...... 34 Mechanicalconditionof wells within AOR verified (For. service wejl only) _ - _ - - - - ....Nq .... . . . . . . . . . . . .............. . . . . . . . . . . . . . . . ..... . . . . . . . . .......... 35 Permit can be issued w/o hydrogen_ sulfide measures ...... . . . . . . . ...........No...... Engineering Commissione : Date - - Wells on 11 -1 -Pad are H2S-bearing. H2S measures required, Geology 36 Data, presented on potential overpressure zones. . . . ... . . . . . . . ........ . . . . . . Yes _ - _ - - - _ Expected reservoir pressure is -9.1 ppg EMW, with a maximum up to -10.0 ppg EMW........ Appr Date 37 Seismic analysis of shallow gas zones .... . . . . . . . ............. . . . . NA _ - - _ - - _ Weil will be drilled using 8.6 ppg mud,. a coiled -tubing rig, and managed pressure drilling. ------------- SFD 7/2/2018 38 Seabed condition survey (if off -shore) . . ......... . . . . . . . . ....... . . . . . NA _ - _ technique to control formation pressures and stabilize shale sections. NOTE: Chance of ----------- 39 Contact name/phone for weeklyProgressreports [exploratory only] ......... . . . . . . NA_ _ - - encountering gas while drilling this wellbore due.to gas. injection performed in this area.... Geologic Commissioner: Date: Engineering Commissione : Date Public CorgilLissioner Date