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DATA SUBMITTAL COMPLIANCE REPORT 7/1/2019 Permit to Drill 2190370 Well Name/No. KUPARUK RIV UNIT 3F-01 Lt -01 Operator ConocoPhillips Alaska, Inc. API No. 50-029-21446-61.00 MD 11401 TVD 5805 Completion Date 3/26/2019 Completion Status 1 -OIL Current Status 1 -OIL UIC No REQUIRED INFORMATION Mud Log No Samples No V111 Directional Survey Yes v DATA INFORMATION List of Logs Obtained: GR / Res (from Master Well Data/Logs) Well Log Information: Log/ Electr Data Digital Dataset Log Log Run Interval OHI Type Med/Frmt Number Name Scale Media No Start Stop CH Received Comments ED C 30659 Digital Data 7929 11401 4/25/2019 Electronic Data Set, Filename: 3F-01L1- 01—GAMMA RES.Ias ED C 30659 Digital Data 4/25/2019 Electronic File: 3F-011-1-01 21VID Final.cgm ED C 30659 Digital Data 4/25/2019 Electronic File: 3F-01 L1-01 51VID Final.cgm ED C 30659 Digital Data 4/25/2019 Electronic File: 3F-011-1-01 5TVDSS Final.cgm ED C 30659 Digital Data 4/25/2019 Electronic File: 3F-011-1-01 2MD Final.pdf ED C 30659 Digital Data 4/25/2019 Electronic File: 3F-011-1-01 5MD Final.pdf ED C 30659 Digital Data 4/25/2019 Electronic File: 3F-01 L1-01 5TVDSS Final.pdf ED C 30659 Digital Data 4/25/2019 Electronic File: 3F-011-1-01 EOW NAD27.pdf ED C 30659 Digital Data 4/25/2019 Electronic File: 3F-011-1-01 EOW NAD27.txt ED C 30659 Digital Data 4/25/2019 Electronic File: 3F-011-1-01 Final Surveys TO 11401.csv ED C 30659 Digital Data 4/25/2019 Electronic File: 317-011-1-01 Final Surveys TO 11401.x1sx ED C 30659 Digital Data 4/25/2019 Electronic File: 3F-01 L1-01 Survey Listing.txt ED C 30659 Digital Data 4/25/2019 Electronic File: 3F-01 L1-01 Surveys.bd ED C 30659 Digital Data 4/25/2019 Electronic File: 317-011-1- 01_25_tapescan_BHI CTK.txt ED C 30659 Digital Data 4/25/2019 Electronic File: 3F-011-1- 01_5_tapescan_BHI_CTK.txl ED C 30659 Digital Data 4/25/2019 Electronic File: 3F-011-1-01_output.tap ED C 30659 Digital Data 4/25/2019 Electronic File: 3F-01 L1-01 2MD Final.tif ED C 30659 Digital Data 4/25/2019 Electronic File: 3F-011-1-01 5MD Final.tif AOG('( Page 1 of 3 Monday, July 1, 2019 DATA SUBMITTAL COMPLIANCE REPORT 7/1/2019 Permit to Drill 2190370 Well Name/No. KUPARUK RIV UNIT 31F-011-1-01 MD 11401 TVD 5805 Completion Date 3/26/2019 ED C 30659 Digital Data Log C 30659 Log Header Scans ED C 30796 Digital Data ED C 30796 Digital Data ED C 30796 Digital Data ED C 30796 Digital Data Log C 30796 Log Header Scans Well Cores/Samples Information: Name INFORMATION RECEIVED Completion Report Production Test Information & NA Geologic Markers/Tops0 COMPLIANCE HISTORY Completion Date: 3/26/2019 Release Date: 3/11/2019 Description Comments: Interval Start Stop Operator ConocoPhillips Alaska, Inc. API No. 50-029-21446-61.00 Completion Status 1 -OIL Current Status 1-0I1 UIC No 4/25/2019 Electronic File: 3F-0111-01 5TVDSS Final.tif 0 0 2190370 KUPARUK RIV UNIT 3F-0111-01 LOG HEADERS 5/17/2019 Electronic File: 3F-01 L1-01 EOW NAD27.pdf 5/17/2019 Electronic File: 3F-011-1-01 EOW NAD27.txt 5/17/2019 Electronic File: 3F -01L1-01 EOW NAD83.pdf 5/17/2019 Electronic File: 3F-01 L1-01 EOW NAD83.txt 0 0 2190370 KUPARUK RIV UNIT 3F-011-1-01 LOG HEADERS Sample Set Sent Received Number Comments Directional / Inclination Data O Mud Logs, Image Files, Digital Data Y / I& Core Chips Y / Ir�4-. Mechanical Integrity Test Information {"!�Y'"/'SNA Composite Logs, Image, Data Files Yr Core Photographs Y / 1 ) Daily Operations Summary 11-/ Cuttings Samples Y / NH/ Laboratory Analyses Y Ai�D Date Comments AOGC(' Page 2 of 3 Monday. July I. 2019 DATA SUBMITTAL COMPLIANCE REPORT 7/112019 Permit to Drill 2190370 Well Name/No. KUPARUK RIV UNIT 3F-011-1-01 Operator ConocoPhillips Alaska, Inc. API No. 50-029-21446-61-00 MD 11401 TVD 5805 pletion Date 3/26/2019 Completion Status 1-0I1- Current Status 1�0 JI1 UIC No Compliance Reviewed By: Date: r I �C) AOG('CPage 3 o(3 Monday- July I, 2019 219037 30795 Letter of Transmittal �— --------------------- BAER — UGHES May 16, 2019 a GEcompany Date: 7 1 Abby Bell AOGCC 333 West 7`^ Ave, Suite 100 Anchorage, Alaska 99501 Harvey Finch Baker Hughes, a GE Company 795 East 94" Avenue Anchorage, Alaska 99515 se find enclosed the directional survey data for the following well(s): 3F -01L1 3F-O1L1-01 RECEIVED MAY 17 2019 AOGcc (1) Total print Enclosed for each well(s): 1 hardcopy print of directional survey reports (NAD27) 1 compact disk containing electronic survey files Note: Please feel free to send us an email in place of return mail. Harvey Finch, Baker Hughes, Wellplanner Harvey.Finch(@BakerHughes.com ConocoPhillips ConocoPhillips Alaska Inc—Kuparuk Kuparuk River Unit Kuparuk 3F Pad 3F-01 L1-01 50-029-21446-61 Baker Hughes INTEQ Definitive Survey Report 22 April, 2019 BA ER F�UGHES a GE company 219037 30 79 6 ConocoPhillips Company: ConocoPhillips Alaska lnc_Kupamk Project: Kupamk River Unit Site: Kupamk 3F Pad Well: 3F-01 Wellbore: 3F -01L1-01 Design: 3F-011.1-01 Project Kupamk River Unit, North Slope Alaska, United States Map System: US State Plane 1927 (Exact solution) System Datum, Geo Datum: NAD 1927 (NADCON CONUS) Map Zone: Alaska Zone 04 Well 3F-01 ConocoPhillips Definitive Survey Report Local Coordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Database: Well Position +Nl-S 0.00 usft Northing: +EI -W 0.00 usft Easting: Position Uncertainty 0.00 usft Wellhead Elevation: Wellbore 3F-011.1-01 Magnetics Model Name Sample Date BGGM2018 4/1/2019 Design 3F-011.1-01 Audit Notes: Version: 1.0 Phase: ACTUAL Vertical Section: Depth From (TVD) (usft) 9300 Well 3F-01 3F-01 @ 93.00usft (3F-01) 3F-01 @ 93.00usft (3F-01) True Minimum Curvature EDT 14 Alaska Production Mean Sea Level Using Well Reference Point Using geodetic scale factor 5,985,734.98usft Latitude: 508,662.35usft Longitude: usft Ground Level: Declination Dip Angle (1) (1) 16.61 8087 Tie On Depth: 9,000.93 +N/ -S +E/ -W Direction (usft) (usft) (•) 000 000 180.00 BAR FIUGHFS 70° 22'20.086 N 149° 55'46.549 W 0.00 usft Field Strength (nT) 57,419 4/22/2079 1:07:OOPM Page 2 COMPASS 5000.14 Build 85O ConocoPhillips a F UER i3 ConocoPhillips Definitive Survey Report GHEF Company: ConocoPhillips Alaska Inc Kuparuk Local Co-ordinate Reference: Well 3F-01 TVDSS Project: Kuparuk River Unit TVD Reference: 3F-01 @ 93.00usft (3F-01) DLS Site: Kuparuk 3F Pad (usft MD Reference: 3F-01 @ 93.00usft (3F-01) (usft) Well: 3F-01 (usft) North Reference: True Wellbore: 31F-011-1-01 Survey Calculation Method: Minimum Curvature Design: 3F-0111-01 Database: EDT 14 Alaska Production ('/100') Survey Program Date 97.79 17573 5,855.28 From To 4,025.88 5,981,24862 512,693.03 8.03 lush) Waft) Survey (Wellbore) Tool Name Description Survey Start Data 100.00 8,200.00 3F-01 (3F-01) GCT -MS Schlumberger GCT multishot 8/18/2000 8,245.50 8,320.79 3F -01L1 MWD INC(3F-01L7) MWD -INC _ONLY MW0.1NC_0NLY_FILLER 3/23/2019 8,352.20 9,000.93 3F-01 L1 MWD (3F-011-7) MWD MWD - Standard 3/24/2018 9,026.00 9,147.37 3F-011-1-01 MWD-INC(31F-011-1-01)MWD-INC_ONLY 100.98 MWD -INC _ONLY -FILLER 3/25/2019 9,178.92 11,355.08 3F-01 L1-01 MWD (3F-O1L1-01) MWD MWD - Standartl 3/25/2019 Survey MD Inc Azl TVD TVDSS +NIS +El -W Map Map DLS Vertical (usft (°) (°) (usft) (usft) (usft) (usft) Northing Easting Section Survey Tool Name (R) (ft) ('/100') (ft) 9,000.93 97.79 17573 5,855.28 5,762.28 -0,491.47 4,025.88 5,981,24862 512,693.03 8.03 4,491.47 MWD (3) 9,02600 98.30 177.56 5,851.77 5,758.77 4,516.25 4,027.34 5,981,223.84 512,694.51 7.51 4,516.25 MWD -INC ONLY (4) 9,057.49 102.41 175.75 5,846.11 5,753.11 -0,547.17 4,029.14 5,981,19293 512,696.35 14.22 4,547.17 MWD -INC ONLY (4) 9,087.48 100.98 174.04 5,840.03 5,747.03 4,57642 4,031.75 5,981,16369 512,696.99 7.34 4,57842 MWD-INC_ONLY(4) 9,117.49 101.19 172.32 5,834.26 5,741.26 4,605.66 4,035.25 5,981,134.45 512,70253 5.67 4,605.66 MWD-INC_ONLY (4) 9,147.37 100.31 170.61 5,828.69 5,73569 4,634.69 4,039.61 5,981,105.43 512,706.92 6.35 4,634.69 MWD -INC -ONLY (4) 9,178.92 98.47 168.81 5,823.54 5,730.54 4,665.31 4,045.17 5,981,074.82 512,712.51 8.11 4,665.31 MWD(5) 9,207.20 96.52 166.13 5,819.85 5,726.85 4.692.68 4,051.25 5,981,04745 512,71863 11.65 4,69268 MWD(5) 9,23761 95.97 165.12 5,816.54 5,723.54 4,721.98 4,058.76 5,981,018.19 512,726.16 376 4,721.96 MWD (5) 9,267.13 95.23 166.73 5,81366 5,72066 4,750.46 4.065.90 5,980,989,71 512,733.34 598 4)50.46 MWO(5) 9,297.15 9464 167.56 5,811.08 5,718.08 4,779.62 4,072.56 5,980,960.56 512,740.03 3.38 4,77962 MWD (5) 9,330.11 95.13 17067 5,808.27 5,715.27 4,811.86 4,078.76 5,9&1,928.32 512,746.27 9.52 4,811.86 MWD (5) 9,360.81 96.06 17332 5,805.28 5,712.28 4,842.11 4,083.01 5,980,898.08 512,750.55 9.11 4,842.11 MWD (5) 9,390.36 9888 174.52 5,802.21 5,709.21 4,871.34 4066.13 5,980,868.66 512,753.70 408 4,871,34 MWD (5) 9,419.89 95.72 176.16 5,79922 5,70622 4,900.62 4,088.51 5,980,839.59 512,756.12 5.55 4,900.62 MM (5) 9,45.03 92.70 176.95 5,797.01 5,704.01 4,930.62 4,090.32 5,980,809.59 512,757.96 10.36 4,930.62 MWD (5) 9,490.49 93.07 17943 5,794.97 5,701.97 4,971.00 4,091.59 5,9W,769 21 512,759.28 6.19 4,971.00 MWD(5) 9,520.62 90.40 180.90 5,794.06 5,701.06 -5,001.12 4,091.51 5,980,739.10 512,75923 10.11 5,001.12 MWD (5) 9,549.89 8828 181.77 5,794.40 5,701.40 -5,030.37 4,090.83 5,980,709.85 512,758.58 7.83 5,030.37 MVM (5) Survey End Date 3/23/2019 3/24/2019 3/25/2019 3/26/2019 Annotation TIP KOP Interpolated Azimuth Interpolated Azimuth Interpolated Azimuth Interpolated Azimuth 41222019 1:07.00PM Page 3 COMPASS 5000.14 Build 85D ConocoPhillips BAER ConocoPhillips Definitive Survey Report ucNEs Company: ConocoPhillips Alaska Inc_Kupamk Local Co-ordinate Reference: Well 3F-01 Project: Kupamk River Unit TVD Reference: 3F-01 @ 93.00usft (31 Site: Kupamk 3F Pad MD Reference: 3F-01 @ 93.00usft (3F-01) Well: 31F-01 North Reference: True Wellbore: 3F-011-1-01 Survey Calculation Method: Minimum Curvature Design: 3F-011-1-01 Database: EDT 14 Alaska Production Survey MD Inc ANTVD TVDSS •N/.4 +E/ -W Map Map DLS Vertical (usft) (°) (°) (usR) (usft) (waft) (usR) Northing Easting (°1100-) Section Survey Tool Name Annotation (ft) (ft) (ft) 9,589.72 WS5 182.89 5,795.47 5,702.47 -5,070.16 4,089.21 5,980,670.07 512,757.01 2% 5,070.16 MWO(5) 9,610.17 88.03 182.70 5,796.06 5,703.05 5,090.57 4,08821 5,980,649.65 512,756.04 3.17 5,090.57 MWD (5) 9,639.97 88.12 182.99 5,79706 5,704.06 -5,12032 4,086.73 5,980,619.90 512,754.60 1.02 5,120.32 MWD (5) 9,67049 88.00 182.53 5,798.09 5,70509 5,150.79 4,08526 5,980,589.44 512,753.16 1.56 5,150.79 MWD (5) 9,70092 87.27 181.16 5,799.35 5,706.35 -5,181.17 4,084.28 5.9B), 559 05 512,752.22 5.10 5,181.17 MWD(5) 9,731.23 85.88 179.91 5,801.16 5,708.16 5,211.43 4,084.00 5,98(1,528.80 512,751.97 6.16 5,211.43 MWD (5) 9,761.10 86.31 179.86 5,803.19 5,710.19 -5,241.23 4,084.06 5,980,49900 512,752.06 1.45 5,241.23 MWD (5) 9,78125 66.87 18049 5,804.39 5,711.39 -5,261.34 4,084.00 5,980,478.89 512,752.03 4.18 5,261.34 MWD (5) 9,81069 8SM 180.04 5,806.13 5.713.13 5290.73 4,083.86 5,980,449.51 512,751.92 2.36 5,290.73 MWO(5) 9,83247 87.14 17975 5,807 37 5,714.37 5,312.47 4,08390 5,980,427.77 512,751.99 391 5,312.47 MWD (5) 9,852.24 8713 179.05 5,808.71 5,715.71 -5,342.21 4,084.21 5,980,398.03 512,752.34 3.07 5,342.21 MWD (5) 9,892.08 86.68 17844 5,810.16 5,71716 -5,372.01 4,084.87 5,980,368.24 512,753.02 4.07 5,372.01 MWD (5) 9,916.82 87.33 17821 5,811,45 5,718.45 5,396.71 4,085.59 5,980,343.55 512,753.77 2.79 5,396.71 MWD (5) 9,945.89 91.84 179.67 5,811.66 5,718.66 5,425.76 4,086.13 5,980,314.49 512,754.34 16.31 5,425.76 MWD (5) 9,975.37 91.47 178.89 5,810.81 5,717.81 5,455.23 4,086.50 5,980,285.03 512,754.75 2.93 5,45523 MWD (5) 10,00524 92.92 178.24 5,8(19.67 5,716.67 -5,485.06 4,087.24 5,980,255.20 512,755.53 5.32 5,485.06 MWD (5) 10,035.72 94.37 17807 5,80713 5,71413 -5,515.47 4,088.22 5,980,224.80 512,756.55 479 5,515.47 MWD (5) 10,065.29 94.24 177.36 5,805.51 5,712.51 -5,544.93 4,089.40 5,980,195.34 512,757.75 2.43 5,544.93 MWD (5) 10,095.17 94.55 177.32 5,803.22 5,710.22 -5,574.69 4,090.78 5,980,165.59 512,759.17 1.05 5,574.69 MWD (5) 10,125.09 94.82 17894 5,800.78 5,707.78 -5,604.47 4,092.28 5.980,135.81 512,760.70 1.65 5,604.47 MWD (6) 10,154.81 94.63 178.17 5,798.33 5,705.33 5,634.06 4,09354 5,980,106.22 512,762.00 4.17 5,634.06 MWD (5) 10,185.26 93.99 178.08 5,796.04 5,703.04 5,664.41 4,094.53 5,980,075.88 512,76303 2.12 5,664.41 MWD (5) 10,215.34 92.33 177.63 5,794.38 5,701.38 -5,694.42 4.095.66 5,980,045.87 512,764.18 572 5,694.42 MWD(5) 10,245.27 92.58 17968 5,793.10 5,700.10 5,724.32 4,096.35 5,980,015.98 512,764.92 6.89 5,724.32 MWD(5) 10,275.31 91.20 179.93 5,792.11 5,699.11 -5,754.34 4,096.46 5,979,985.% 512,765.06 4.67 5,754.34 MWD(5) 10,305.75 91.04 18093 5,791.51 5,698.51 -5,78417 4,096.23 5,979,955.53 512,764.86 3.33 5,784.77 MWD (5) 10,335.80 90M 179.97 5,791.03 5,698.03 -5,814.82 4,096.00 5,979,925.49 512,764.66 3.29 5,814.82 MWD (5) 10,365.67 91.54 178.43 5,790.42 5,697.42 -5,844.68 4,096.41 5,979,89563 512,765,11 5.72 5,84468 MWD (5) 10,395.59 91.53 178.27 5,78962 5,696.62 -5,874.57 4,097,27 5,979,86574 512,766.01 0.54 5,874.57 MWD (5) 10,42059 92.03 177.87 5,788.84 5,695.84 -5,899.55 4,098.12 5,979,840.77 512,768.88 2.56 5,899.55 MWD (5) 10,45027 9000 17822 5,788.32 5,695.32 -5,929.20 4,099.13 5,979,811.12 512,767.93 6.94 5,929.20 MWD (5) 412212019 1:07:OOPM Page 4 COMPASS 5000.14 Build 85D Survey - MD ConocoPhillips Azl ConocoPhillips Definitive Survey Report •N/3 Company: ConocoPhillips Alaska Inc_Kuparuk Local Coordinate Reference: Well 3F-01 Project: Kupamk River Unit TVD Reference: 3F-01 @ 93.00usR (3F-01) Site: Kuparuk 3F Pad MD Reference: 3F-01 @ 93.00usft (3F-01) Well: 3F-01 North Reference: True Wellbore: 3F-01 Ll -01 Survey Calculation Method: Minimum Curvature Design: 3F-01L"I Database: EDT 14 Alaska Production Survey - MD Inc Azl N NDSB DSB •N/3 iE/-W Map Map DLS Vertical Wait) (°) (1) (usR) (weft) (usft) lush) Northing Easting (°1100') Section Survey Tool Name (ft) (ft) ( 10,479.80 8960 1T/.04 5,76842 5,69542 5,958.71 4,100.35 5,979,781.62 512,769.18 4.22 5,9,9 56.71 MWD (5) 10.511.02 91.14 177.50 5,78822 5,69522 -5,989.89 4,101.84 5,979,750.44 512,770.70 5.15 5,989.89 MWD(5) 10,540.10 91.11 177.79 5,787.65 5,694.65 8,018.94 4,103.3 5,979,721.39 512,771.93 1.00 6,018.94 MWD(5) 10,569.70 9209. 17921 5,786.82 5.693,82 8,048.52 4,103.81 5,979,69182 512,772.74 5.83 6,048.52 MWD(5) 10,599.92 91.14 18049 5,785.97 5,692.97 8,078.72 4,103.88 5,979,661.62 512,772.86 5.27 6,07872 MWD (5) 10,630.51 88.68 179.73 5,786.02 5,693.02 8,109.31 4,103.83 5,979,631.03 512,772.83 8.42 6,109.31 MWD (5) 10,660.63 88,46 180.96 5,78617 5,693.77 8,139.42 4,103.64 5,979,600.93 512,772.69 4.15 6,139.42 MWO(5) 10,689.96 88.83 180.03 5,78746 5,694.46 8,168.74 4,103.39 5,979,571.61 512,772.47 3.41 6,168,74 MWD (5) 10,719.68 8288 179.50 5,788.32 5,695.32 8,198.45 4,103.51 5,979,541.90 512,772.62 3.66 6,198.45 MWD (5) 10,750.63 87.33 178,78 5,789.61 5,696.61 8,229.37 4,103.98 5,979,510.99 512,773.12 2.93 6,229.37 MWD (5) 10,780.32 85.97 179.42 5,791.35 5,698,35 8,259.0 4,104.44 5,979,481.36 512,77362 5.06 6.259.00 MWD (5) 10810.17 86.62 180.53 5,793.27 5,700.27 8,288.79 4,104.46 5,979,451.57 512,77367 4.30 6,288.79 MWD (5) 10,840.36 86.65 180.54 5,795.05 5,702.5 8,318.92 4,104.17 5,979,421.44 512,77342 0.10 6,318.92 MWD (5) 10,870.43 66.65 178.95 5,79680 5,70380 8,348.94 4,104.31 5,979,391.43 512,773.59 528 6,348.94 MWD (5) 10,901.83 88.34 17966 5,798.18 5,70.18 8,380.31 4,104.69 5,979,360.06 512,774.01 5.84 6,380.31 MWD (5) 10,930.40 89.69 179,74 5,798.67 5,705.67 8,408.87 4,104.84 5,979,331.50 512,774.19 4.73 6,408.87 MWO(5) 10,960.43 88.99 178.95 5,799.01 5,706.01 8,438.90 4,105.18 5,979,301.48 512,774.57 3.51 6,438.90 MWD (5) 10,990.17 88.62 177.59 5,799.63 5,706.63 8,468.62 4,106.08 5,979,271.76 512,775.0 4.74 6,468.62 MWD (5) 11,01960 88.31 179.18 5,800.42 5,707.42 8,498.02 4,106.91 5,979,242.36 512,776.36 5.50 6,498.02 MWD (5) 11,051.29 88.46 180.36 5,01.31 5,70.31 8,529.70 4,107.03 5,979,210.69 512,776.53 3.75 6,529.70 MWD (5) 11,080.79 89.54 181.76 5,01.83 5,70.83 8,559.19 4,106.49 5,979,181.20 512,776.02 5.99 6,559.19 MWD (5) 11,110.15 88.80 181.74 5,802.25 5,709.26 8,588.53 4,10.59 5,979,151.86 512,775.15 2.52 6,588.53 MWD (5) 11,140.0 89.0 183.29 5,802.81 5,70.81 6,618.43 4,104.28 5,979,12197 512,773.88 5.26 6,618.43 MWD (5) 11,170.13 89.75 184.06 5,803.12 5,710,12 8,64842 4,102.35 5,979,091.98 512,771.98 3.40 6,648.42 MWD (5) 11,20.22 87.70 183.57 5,803.79 5,710.79 8,678.43 4,100.35 5,979,061.97 512,770.02 Too 6,678.43 MWD (5) 11,230.06 87.39 182.96 5,605.0 5,712.0 6,70.19 4,0665 5,979,02.20 512,768.35 2.29 6,70.19 MWD (5) 11,20.79 87.11 183.71 5,06.54 5,713.54 8,738.84 4,096.87 5,979,01,56 512,765.60 2.60 6,738.84 MWD (5) 11,290.15 88.80 1114.3 5,807.59 5,714.59 6,768.11 4,04.87 5,978,972.29 512,764.64 5.90 6,70.11 MWD (5) 11,322.89 90.34 183.90 5,807.83 5,714.83 8,800.77 4,02.59 5,978,939.63 512,762.40 4.74 6,80.77 MWD (5) 11,355.0 92.21 183.42 5,807.11 5,714.11 8,832.88 4,090.54 5,978,907.52 512,70.38 6.0 6,832,88 MWO(5) 11401.0 9221 18342 5,805.34 5,712.34 8,878.69 44087.80 5,978,85172 512,757.70 0.0 6,878.69 PROJECTED to TD Annotation BAER F UGNES 42212019 1:07:OOPM Page 5 COMPASS 5000.14 Build 850 ConocoPhillips DAKK R ConocoPhillipsry, « o Definitive Survey Report Company: ConocoPhillips Alaska lnc_Kupaiuk Project: Kuparuk River Unit Site: Kupamk 3F Pao Well: 3F-01 Wellbore: 3F-0111-01 Design: 3F-011-1-01 Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Database: Well 3F-01 3F-01 @ 93.00usft (3F-01) 3F-01 @ 93.00usft (3F-01) True Minimum Curvature EDT 14 Alaska Production 4/22/2019 1:07:OOPM Page 6 COMPASS 5000.14 Build 85D STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION ECEIVE APR 2 5 2019 WELL COMPLETION OR RECOMPLETION REPORT AN 1a. WeII Status: Oto Gas❑ SPLUG ❑ Other ❑ Abandoned ❑ Suspended❑ 20AAC 25.105 20AAC 25.110 GINJ❑ WINJ❑ WAGE] WDSPL❑ No. of Completions: 1b. Well Class:' Development [D Exploratory❑ Service ❑ Stratigraphic Test El 2. Operator Name: ConocoPhillips Alaska, Inc. 6. Date Comp., Susp., or Aband.: 3/26/2019 14. Permit to Drill Number/ Sundry: 219-037 - 3. Address: P.O. Box 100360 Anchorage, AK 99510-0360 7. Date Spudded: 3/24/2019 15, API Number: 50-029.21446-61-00 4a. Location of Well (Governmental Section): Surface: 89' FNL, 162' FWL, Sec 29, T72N, R9E, UM Top of Productive Interval: 4605' FNL, 4173' FWL, Sec 29, T12N, R9E, UM Total Depth: 1688' FNL, 4226' FWL, Sec 32, T12N, R9E, UM 8. Date TD Reached: 3/25/2019 16. Well Name and Number: KRU 3F -01L7-01 9. Ref Elevations: KB:93 - GL: 52 • BF: 17. Field / Pool(s): Kuparuk River Field/Kuparuk River Oil P 10. Plug Back Depth MD/TVD: N/A 18. Property Designation: ADL 25643, ALK 2574 4b. Location of Well (State Base Plane Coordinates, NAD 27): Surface: x- 508662 • y- 5985735 - Zone- 4 TPI: x- 512694 y- 5981224 Zone- 4 Total Depth: x- 512758 y- 5978862 Zone- 4 11. Total Depth MD/TVD: .11401/5805 ' 19. DNR Approval Number: LONS 83-129 12. SSSV Depth MD/TVD: N/A 20. Thickness of Permafrost MD/TVD: 1593/1523 5. Directional or Inclination Survey: Yes 21 . (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: 9026/5852 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 FT. TOP BOTTOM TOP BOTTOM CEMENTING RECORD AMOUNT PULLED 16 62.5 H-00 37 115 37 115 24 348sx AS II 95/8 36 J-55 37 3971 37 3062 121/4 1020sx PF "E", 400sx PF "C" Top Job Performed w/50sx PF "C" 7 26 J-55 35 8646 35 6187 8112 325sx Class G, 250 sx PF "C 24. Open to production or injection? Yes ❑� No ❑ If Yes, list each interval open (MD/FVD of Top and Bottom; Perforation Size and Number; Date Paddy SLOTTED LINER@ 8236-11401 MD and 5905-5805 ND COMPLETION D TEWas Z b Zol9 EW+ 25. TUBING RECORD SIZE DEPTH SET (MD) PACKER SET (MD/TVD) 31/2 8303 7974/5723, 8280/5936 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. hydraulic fracturing used during completion? Yes ❑ No 2] 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: 4/5/2019 Method of Operation (Flowing, gas lift, etc.): GAS LIFT Date of Test: 4/7/2019 Hours Tested: 19hrs Production for Test Period Oil -Bbl: 26 Gas -MCF: 75 Water -Bbl: 1 2440 Choke Size: 146 Gas -Oil Ratio: 2.8 Mcf/bbl Flow Tubing Press. 152 I Casino Press: 1716 Calculated 24 -Hour Rate Oil -Bbl: 33 Gas -MCF: 96 Water -Bbl: 1 3082 Oil Gravity- API (corr): 1 23.4 Form 10-407 Revised 5/2017 i?L 9 l ply�TINUED ON PAGE 2 p BDIVIS APR 2 B T019 Submit SRIIG NIAL only, 28. CORE DATA Conventional Corals): Yes ❑ No i] • Sidewall Cores: Yes ❑ No ❑� . If Yes, list formations and intervals cored (MD/TVD, From/To), and summarize lithology and presence of oil, gas or water (submit separate pages with this form, if needed). Submit detailed descriptions, core chips, photographs, and all subsequent laboratory analytical results per 20 AAC 25.071. 29. GEOLOGIC MARKERS (List all formations and markers encountered): 30. FORMATION TESTS NAME MD TVD Well tested? Yes ❑ No ❑I If yes, list intervals and formations tested, briefly summarizing test results. Permafrost - Top Surface Surface Permafrost - Base 1593 1523 Attach separate pages to this form, if needed, and submit detailed test Top of Productive Interval 9026 5852 information, including reports, per 20 AAC 25.071. Formation @ TPI -Kuparuk Al TD 11401 5805 Formation at total depth: I Kua ruk A 31. List of Attachments: Daily Operations Summary, Definitive Survey, Schematic Information to be attached includes, but is not limited to: summary of daily operations, wellbore schematic, directional or inclination survey, core analysis, paleontolooical report. oroduction or well test results, r 20 AAC 25,070. 32. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Authorized Name: James Ohlin er Contact Name: Ryan McLaughlin Authorized Title: Staff CTD Engineer Contact Email: ryan.mclaughlinocop.com Authorized Contact Phone: 265-6218 Signature: Date: INSTRUCTIONS General: This form and the required attachments provide a complete and concise record for each well drilled in Alaska. Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed. All laboratory analytical reports regarding samples or tests from a well must be submitted to the AOGCC, no matter when the analyses are conducted. Item 1 a: Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Item lb: Well Class - Service wells: Gas Injection, Water Injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Item 4b: TPI (Top of Producing Interval). Item 9: The Kelly Bushing, Ground Level, and Base Flange elevations in feet above Mean Sea Level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 15: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). Item 19: Report the Division of Oil & Gas / Division of Mining Land and Water: Plan of Operations (LO/Region YY-123), Land Use Permit (LAS 12345), and/or Easement (ADL 123456) number. Item 20: Report measured depth and true vertical thickness of permafrost. Provide MD and TVD for the top and base of permafrost in Box 29. Item 22: Review the reporting requirements of 20 AAC 25.071 and, pursuant to AS 31.05.030, submit all electronic data and printed logs within 90 days of completion, suspension, or abandonment, whichever occurs first. Item 23: Attached supplemental records should show the details of any multiple stage cementing and the location of the cementing tool. Item 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, or Other (explain). Item 28: Provide a listing of intervals cored and the corresponding formations, and a brief description in this box. Pursuant to 20 AAC 25.071, submit detailed descriptions, core chips, photographs, and all subsequent laboratory analytical results, including, but not limited to: porosity, permeability, fluid saturation, fluid composition, fluid fluorescence, vitrinite reflectance, geochemical, or paleontology. Item 30: Provide a listing of intervals tested and the corresponding formation, and a brief summary in this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Item 31: Pursuant to 20 AAC 25.070, attach to this form: well schematic diagram, summary of daily well operations, directional or inclination survey, and other tests as required including, but not limited to: core analysis, paleontological report, production or well test results. Form 10-407 Revised 512017 Submit ORIGINAL Only DI. KUP PROD WELLNAME 3F•01 WELLBORE 3F-01 ConocoPh)Ihps Will Attribute Max Anglei 1 T13 FMM Nanta WeI11wrtAPW WI Wall0e,e5tatus ncl(•) Mo IT q[f Blm (XKef Alaska. Inc. KOPARIMWVFRIIrv1T 5110J9J1aafi0A PRlllt JAS i100 nn 3Fm,arzaa,e,v3, e9AM Last Tag Vn4al�AenaEc(appe Annotabon Depth mKB) End ONe WNluo,e Last MM By _ Lag Tag'SLM 6,486.0 ]192 I, 3F-01 zembeej nArvGEs'. xa Last Rev Reason Annotation EnE WeIIWre last Mad By REV REASON: POST RIG GLV INSTALL Data 4112019 3F-01 aapplah Casing Strings Casing 0eecnp,mn oo ON D(m) Top (XKO SH Oepm MKB) set oepin(rvq... wuLen p._Graae Tnprnrcad CONDUCTOR 16 1506 3)0 115.0 115.0 62.50 HAO WELDED I CONWCTOfl', T.61150 Casino 0ezcription OD (in) ID llnl I Top IXKBI Set Depth (NIB) $N CepiM1INOj... IML B...Geade TopThre� SURFACE 9518 8.92 37.0 3,9706 3.061.6 36.00 J-55 BTC Crimp Des[aption Do (in) tulip Top IXKB) $N Depth (.a) set.01 lrv0l... WULen II Tov Tll,xe MWLEam1 Inual PRODUCTION ] 6.28 35.0 86461 6,1871 26.00 J-55 BTC I I Strings sess,Tubing Tobin g 0es[eipticn Shing Ma... IG(In) Top (IIHB) BBI DepIM1 (M.. SM OepM jN01 (... WIIIAYtI Grede icpCm„xlon TUBING -WO 31/2 2.99 33.0 ],968.5 5,]19.1 930 L-80 EUEBrnd axa Gas uFT l 3, Ina- Completion Details Top RV.) Top Incl Nominal Top dnun IXKBI •) Item Des Co. to pp 330 33.0 0.03 IHANGER FMC TUBING HANGER 2.992 518.1 518.0 3.9 NIPPLE CAMCO 2.8]5"'W NIPPLE 2.875 suSEACE, a,.'On - 7,9558 5,710. 45.83 LOCATOR BAKER LOCATOR 3-90 3 7,9588 5710.8 45.82 SEAL ASSY BAKER SEAL ASSY the PER, VSfiek-Dp" 2.990 GAS LIFT a.aWd Tubina DBwnO- Ma... ID pp Tap Ma, Stl Depth (X_Sel Depth"Di I. -Jo HIMq G,Ma TOPCenn.-.n losing TUBING-Onginal 3112 2.99 7,960.2 8,3034 5,9516 9.20 J-55 EUE BCD 35"x2.8]5" @8279' Completion Details Gib LIF.. agai Top (TVD) TOP Intl Nominal Topmost notle (•1 Ikm Des Com to(in) ],960.2 5,713.3 46.81 PER BAKER PER 3,000 ],9]3.9 5,]229 45.75 PACKER BAKER FHL PACKER 3.000 Onsun:9..1 8,2659 5,925.7 46.32 NIPPLE AVA BPL PORTED 05B NIPPLE 2,300 82682 5,92].3 4833 XO -Reducing CROSSOVER 35 - TO 2.075" 2,441 8,2784 5,934.3 48.34 LOCATOR BAKER LOCATOR 3.000 ----9--9,35.6 Gas LIFT; T,4Ta3 8,280.2 4 M PACKER BAKER FB -1 PACKER 4.000 8,283.4 5,937.8 46.35 SBE BAKER SEAL BORE EXTENSION 4.000 6,2952 5,945.9 48:8A NIPPLE CAMCO LV PPLE NO GO 2.250 GAS LIFT; 7.8933 8.3027 5,951.1 46.38 SOS CAMCO HE Do T SUB 2.441 Omer In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top GV In Top Incl LOCATOR', Laseel To, mem IXKBI I') Des Con Run Data ID (in) SEA-ASay.Tasae PW , 79e1 8,2430 5,909.9 4629 1WHIPSHLOCK- Set 3.5'monobore XLtop @ 8243'bottom @ 8253T5 N1912019 1.000 IMONOBORE PACKER T.ane 8265.0 5,925.1 46.32 Sand Plug Dump bail sandon pli,g wl-5' of safe Caro 3142019 0000 on lop. P1e°uc°reC BpW 8,295.0 5,9458 46.36 Plug 517225"CA2PIug 32/2019 1 0.000 PRODUCTION.S.011,7 Perforations 8 Slots Shot nen TOpi ¢(Set :Nobm Top(nKe) abn (nKe) MKe) (XKa) unkm una Date ) Type Can caurep"et2ao. (PERF: eCRSOd2180� 81M6. 8.219.0 5.]8].1 5,8933 C-3, -2,C-, UNIT B, 3F-01 1127/1985 120 IPERF 120 deg. phasing 5" HJ G$g GOn 8A1]0 8423.0 6,029.8 8,0339 A-0, 3F -T 112]11985 40 (PERF 90 deg. pnasinB, a"RJ II -F428 Csg Gun 8428.0 0.468.0 6,03)4 6,084.8 A-3, 3F-01 1112L1985 4.0 PDT- 90 deg. ph g -4F7,7 Csg Gun 8,498.0 8,5280 6,0654 6,104) 72, 3F-01 1119/1985 4.0 IPERF 90 deg. pnasing, "HJI WNIPSTCCKON.DORE: CSg GTe agaao Cement Squeezes Top RVD) etm(rvol NIwUe 52059 TopdWEp St. pKED (XK0) IXKB) Des atan- Com 8,0000 8265.0 5,741.0 5,925.1 Pe.d3Cuon31812019 sSOUP 15.8 PPG CLASS G CEMENT PUMPED And Nug'112es3 PACKER: 8.2832 Casing Cement INTO FORMATION 8123.0 8.265.0 5,826.8 8925.1 Cement Plug 31812019 OSLO 15. "ta CLASS D letal. I I 'D.. .E:a.i09.a 11 TUBING Mandrel Inserts al NIPPLE', 9,Rv.2 84 Paq', x285.0an N Tep(aKBI TopMot ) MMVotes _ake odel OD(in) Sam TOP" Typo Bid Ranges, TRnto flan Dab Can 162.8 2,5]1.1 CAMCO MMG 1112 G45 LIFT GLV K 0.1 1,204.0 41112019 2 4,850.5 3,6248 CAMCO MMG 1112 GAS LIFT OV RK 025 0.0 41112019 SOS: 83g2 5,996.9 4,370.4 CAMCO MM 1112 GAS LIFT DMY RK 00 41112019 4 8840.4 4.940.4 TANGO MMG 112 GAS LIFT DMY RK oBU 00 4/12019 5 ],4]4.3 53]6.5 CAMCO MMG 1 17 GAS LIFT DMY RK 0.000 0.0 4N2019 6 7,896 3 5,668.8 CAMCO MMG -71-72 GAS LIFT DMV RK 0,W0 0) 4112019 ] 8.011.) 5,]49.3 CAMCO KBUG 1 PROD DMY BK 0.000 0.0 5118/1988 IPop, 8417 D-Sapsn- Notes: General B Safety End DaRAnnobtion Sl4/2003 NOTE; WAIVERED WELL IA xOA COMMUNICATION IPERF: a.... a� IPERF:9,428i FRODWTapa5.0eead1 KUP PROD WELLNAME 3F-01 WELLBORE 3F-010-01 ConocoPhillips Naska.l ha. 3F -0111-01,M 1911:31:WM1 Casing Strings .1 x1ena added) Casln00esn Id... OD(n) Ll -01 LINER 23/8 10 (n1 1.99 iap lflNBl Sel OeplM1 (OMB) $e1 8$35.5 tlppl.0 DepIM1 INDI.. W0-(I..Groe d)6 Top Thread L-80 ST -L Liner Details .......... MAwGER >To... .. _-._...._ wominal ID TopINMR) Top (NO)(MILB) Top Incl') Hep pBs Com Nn) 8,2355 5.964.8 46.28 00e1 ShOM1y DeDlDyment Sleeve 1.920 Perforations & Slots sem Top IND) Mr. (7v ISh. Tap IMMe) B1m(., me) va" I Lmo.Z—e 0. ) Type Com 8,2360 i14WU 5,9051 5,8056 3Y232619 SLOTS CONDUCTM 3L0.H50 HIPPIE: 5181 GPB LIFT. 3,1 B28 SURFACE; 3].03B]08� GAS 117 a,e.Bs .LIFT: ".0 c LIFT, dead GCS LIFT: ]a]! 3 ..LIFT ]S%.3 WO R', ],BB.B BFAL, ],8398 PBR; 1.2 PACMER; 7M9 .erten Laalg Lenaq 8.M0h,<d PRODUCTION: 0,0117 Camem Plq: 81.. MB (PERF: 808. 0-0.219 0� PRODU 014. 15.08,BK1 ..T.; ak. D11,4W.O— 11. UNER; 826.11'.4010 3F-01 Final CTD Schematic 16" 62# H40 shoe 9-6/8.'4 0# J55shoe 03971 3971' MD C -sand pe rfs 8066' 8219' MD KOP @ 8243' MD - A -sand parts 8417'- 8423' MD 8428'- 8468' MD 8498'- 8526' MD 7" 26# J-55 shoe @ 8646' MD 3-1/2" Cameo DS nipple @ 518' MD (2.875" min ID) 3-1/2" 9.3# L-80 EUE 8rd Tubing to surface 3-1/2" Cameo gas lift mandrels @ 3163', 4851', 5997', 6841', 7474', 7896' MD Baker 3-1/2" PBR @ 7960' MD (3" ID) Baker FHL packer @ 7974' MD (4.0" ID) 3-1/2" Cameo MMG production mandrels @ 8012' MD AVA BP Ported Nipple @ 8266' MD (2.3" min ID) XO 3.5" to 2.875" Baker FBA packer @ 8280' MD (4.0" ID) Baker SBE @ 8283' MD 3-1/2" Cameo D landing nipple @ 8295' MD (2.25" min ID, No -Go) w12.25" CA -2 Plug, 30' of sand on top of plug to 8265', cement from 8265'to KOP (8243') Cameo SOS @ 8303' MD 3F-011-1-01 TD: 11,401' MD TOL: 8,236' MO Jj BOL: 11,401' MD 2-3/8" slotted liner w/deployment sleeve 3F-011_1 TD: 11,463' MD TOL: 9028' MD BOL: 11,448' MD 2-3/8" slotted liner w/liner top billet Operations Summary (with Timelog Depths) We 3F-01 Lonoc<3ph,11,15 611 -A Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log start Time End Time ow" Phase op code I ActMty code Tane P -T-% Operetlon M Dep S (N(B) m EM Depth (IIKB) 3/15/2019 3/15/2019 2.00 MIRU MOVE RURD P Continue RD checklist, move shop & 0.0 0.0 15:00 1700 112 -Way house from 2G-Pag to 3F - Pad, secure stairs & landings, secure BOP's 3/15/2019 3/15/2019 3.00 MIRU MOVE RURD P Complete RD checklist, RU to NES 0.0 0.0 17:00 20:00 trucks, pull modules off well, jeep -up modules, ready to move 3/15/2019 3/16/2019 4.00 MIRU MOVE MOB P Begin move from 2G -Pad to 3F -Pad 0.0 0.0 20:00 00:00 3/16/2019 3/16/2019 3.50 MIRU MOVE MOB P Arrive at 3F -Pad 0.0 0.0 00:00 03:30 3/16/2019 3/16/2019 4.50 MIRU MOVE MOB P Spot sub & pits over well, lay mats, 0.0 0.0 03:30 08:00 drop stairs 3/16/2019 3/16/2019 1.50 MIRU MOVE RURD P Begin RU checklist, get COMMS up, 0.0 0.0 08:00 09:30 set -down shop & lay mats, install scaffolding & plafform around well 3/16/2019 3116/2019 2.50 MIRU MOVE NUND P Continue RU checklist, spot tiger -tank 0.0 0.0 09:30 12:00 & MU hard-line, begin NU BOPE, MU PUTZ, grease tree valves & Tangos, complete NU BOP •• Rig Accept: 3/16/19 @ 1200 ms 3/76/2019 3/16/2019 2.10 MIRU WHDBOP OTHR P Complete RU checklist, grease Bravo 0.0 0.0 12:00 14:06 1 & Romeo valves, fluid pack lines 3/16/2019 3/16/2019 0.40 MIRU WHDBOP PRTS P Perform shell test 5000 psi 0.0 0.0 14:06 14:30 3/16/2019 3/16/2019 7.00 MIRU WHDBOP BOPE P Begin BOP test (250 low / 3500 high) 0.0 0.0 14:30 21:30 F/P Lower 2", cycled once and passed. •• Witnessed by Matt Herrera of the AOGCC 3/16/2019 3/16/2019 1.00 MIRU WHDBOP RURD P PT tiger tank lin and PDL to 250/ 0.0 0.0 21:30 22:30 1 3500 psi - good, checked pack offs 3/16/2019 3/16/2019 1.00 MIRU WHDBOP RURD P Blow down post BOP test, open well 0.0 0.0 22:30 23:30 and confirm zero pressure. Pick up elevators, prep floor for picking up tools. 3/16/2019 3/17/2019 0.50 SLOT WELLPR PULD P PJSM, PU BHA#1 and load into a 0.0 63.0 23:30 00:00 dead well. 3/17/2019 3/17/2019 0.80 SLOT WELLPR PULD P Compete BHA#1 and load into a dead 0.0 63.0 00:00 00:48 well, Bump up, set counters. 3/17/2019 3/17/2019 1.20 SLOT WELLPR TRIP P RIH W BHA#1. 63.0 7,960.0 00:48 02:00 3/1712019 3/17/2019 0.30 SLOT WELLPR DLOG P Tie into K1 for -4.6' correction Note 7,960.0 8,011.0 02:00 02:18 Kt is 7963' 3/17/2019 3117/2019 1.00 SLOT WELLPR DISP P Pump seawater flush, CT 6100 psi, @ 8,011.0 8,027.0 02:18 03:18 2.4 bpm, - 220 bbls total 3/17/2019 3/17/2019 0.50 SLOT WELLPR DISP P Start pumping cement milling fluid, 1 8,027.0 8,032.0 03:18 03:48 ppb Power Pro with 0.5% lubes 776 / low torque. 3/17/2019 3/17/2019 0.20 SLOT WELLPR TRIP P After 15 bbls drilling fluid out the bit, 8,032.0 8,119.0 03:48 04:00 park,close EDC, RIH, tag bottom 8119' Page 1/16 ReportPrinted: 4/812019 . Operations Summary (with Timelog Depths) 3F-01 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Stall Time End Time Dw(hn Phase Op Code Ach4 Code Time P -T -X Operation Sten Depth (ftKB) End Depth (fil(B) 3/17/2019 3/17/2019 1.00 SLOT WELLPR DRLG P PU Wt 29 k lbs, Set rate, CT 3512 psi 8,119.0 8,129.0 04:00 05:00 @ 1.89 bpm, diif 454, BHP 3121 psi - 10.37 EMW @ sensor. WH 73 psi, RIH Wt 13 k lbs OBD, CT Wt 10.7 k lbs, WOB 0.8 klbs, 40 fl/hr w 100 lbs of motor work. Stall 8124' PU 30 k lbs Stall 8124' PU 34 k lbs Set ROP to 20 Po hr, drill ahead Stall 8130' PU 32 k lbs 3/17/2019 3/17/2019 1.70 SLOT WELLPR DRLG P Continue milling, pumping 1.87 bpm, 8,129.0 8,151.9 05:00 06:42 CWT =11.2K, WOB=.5K, pump= 3562 ps, Stalls at: 8129', 8132', 8137', PUW = 26K from 8151', wiper to 8076' 3/17/2019 3/17/2019 1.50 SLOT WELLPR DRLG P Drilling, FS = 440 psi @ 1.87 bpm, 8,151.9 8,172.0 06:42 08:12 stall getting started, PUW = 26K, annular = 3173 psi, bleed down IA from 1077 (1 hr, drops to 350 psi, shut-in & climbs back to 1050 ps). Stalls at: 8161', 8166' (PUW = 29K) 3/17/2019 3/17/2019 0.40 SLOT WELLPR WPRT P Wiper(300'while circulating bottoms 8,172.0 8,172.0 08:12 08:36 1 up), PUW = 28K 3/17/2019 3/17/2019 0.90 SLOT WELLPR DRLG P Drilling cement, FS = 448 psi @ 1.9 8,172.0 8,190.0 08:36 09:30 bpm, CWT = 8.9K, WOB = O.5K, annular = attempt more WOB to increase ROP, 0.8K WOB @ 36 fph, pump sweeps 3/17/2019 3/17/2019 0.60 SLOT WELLPR WPRT P Wiper, PUW = 28K, losing milling fluid 8,190.0 8,190.0 09:30 10:06 over shakers, circulate bottoms up, losing prime on MP, resolve, swap shaker screens, reslove issue 3/17/2019 3/17/2019 1.60 SLOT WELLPR DRLG P Drilling, FS = 458 psi @ 1.93 bpm, 8,190.0 8,230.0 10:06 11:42 CWT = 8.3K, WOB = 0.9K, stall @ 8196', PUW = 31 K, bleed down OA Stall at 8196', 8197.5', 8199', 8204', 8217', 3117/2019 3/17/2019 0.30 SLOT WELLPR WPRT P Wiper, PUW = 28K, circulate bottoms 8,230.0 8,230.0 11:42 12:00 up, set-downlOK WOB at 8000' (No loorected Jewelry at that depth. Update: GLM at depth of 8000) 3/17/2019 3/17/2019 1.20 SLOT WELLPR DRLG T Difficulty getting started @ 8230' (7 8,230.0 8,230.0 12:00 13:12 stalls —8230', various speeds), attempt getting started at 1 fph 8229.8', stall, confer w/ town 3/17/2019 3/172019 0.10 SLOT WELLPR WPRT T PUH to log K1, PUW = 29K 8,230.0 7,969.0 13:12 13:18 3/17/2019 3/17/2019 0.10 SLOT WELLPR DLOG T Log K1 for+1' correction 7,969.0 7,997.0 13:18 13:24 3/17/2019 3/172019 0.30 SLOT WELLPR DRLG T Attempt to get started at 8230', stall, 7,997.0 8,230.0 13:24 13:42 confer w/ town, decision made to POOH & inspect tools 3/17/2019 3/172019 2.10 SLOT WELLPR TRIP T Pumps sweeps, POOH, PJSM, flow- 8,230.0 62.0 13:42 15:48 check 3/1712019 31172019 0.50 SLOT WELLPR PULD T LD BHA#1 62.0 0.0 15:48 16:18 3/17/2019 3/172019 0.5o SLOT WELLPR -Tu-LD T PU BHA#2 (new motor & D331 w/ 0.0 82.0 16:18 16:48 ridge -set mill), bit come out a 2-2 (broken & chipped cutters), slide in cart, MU to coil, tag up, set counters Page 2116 Report Printed: 418/2019 * Operations Summary (with Timelog Depths) 3F-01 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Time EM Time Dur(hd Phase Op (nCe Activity DOtlO Tme P -T -X Operation Start Depth (111®) EM Depth (nxeJ 3/17/2019 3/17/2019 1.40 SLOT WELLPR TRIP T RIH w/BHA#2 62.0 7,970.0 16:48 18:12 2019 019 0.20 SLOT WELLPR DLOG T Log K1 for -6' correction 7,970.0 7,998.0 18:1 18:12 18:24 18:24 T17/2019 3/17/2019 1.90 SLOT WELLPR TRIP T Continue in hole w D331 ridge set, 7,998.0 8,231.5 18:24 20:18 SO 8032', 3.5 k WOB, and again at 8040'7.5k WOB -PU wt 34klbs. On bottom, 5 stalls 8231.4 to 8231.9. No hole made, variability in tag depth simply CT stack. PU and restart @ 8231.4' auto drill at 1 ft/ hr - stall 8231.6', PU and attempt tp auto drill Q 0.5' per hr, stall Q -5 8231.6', clean pick ups - 29 k lbs. 3/17/2019 3/17/2019 30 SLOT WELLPR DLOG T PU hole, 29 k lbs, Log K1 for zero 8,231.5 7,996.0 20:18 20:36 correction 3/17/2019 3/17/2019 1.20 SLOT WELLPR DLOG T Swap MWD over to CCL mode, log 7,996.0 8,230.0 20:36 21:48 CCL from 7848'- 8179'@ 16 ft/min CCL on with the July 2019 caliper and the tubing detail. Consult with town engineering. 3/17/2019 3/17/2019 1.40 SLOT WELLPR TRIP T POOH for ventun basket. 8,230.0 75.0 21:48 23:12 3/17/2019 3/18/2019 0.80 SLOT WELLPR PULD T LD BHA#2 over dead well. D331 0.0 0.0 23:12 00:00 starting to ring out just past the tip. Agressive damage to that area only,diamond cutters missing in a ring and matrix removed. 2.79 NO, 2.80 go. 3/18/2019 3/18/2019 0.60 SLOT WELLPR PULD T Stand by for BOT hand bringing 0.0 0.0 00:00 00:36 venturi out -Hold Sunday Safety -1 meetng in dog house. 3/18/2019 3/18/2019 00 SLOT WELLPR 'PULD T Pick BHA #3, Venturi with 1 ° bent sub 0.0 64.9 00:36 01:36 and 3/4 mule shoe under a HOT. Bent sub high sided. Note mule shoe scoop -180 ° out from bent sub. Skid cart, inspect pack offs - good, bump up,set counters. 3/18/2019 3/18/2019 1.60 SLOT WELLPR TRIP T RIH. 64.9 7,970.0 01:36 03:12 3/18/2019 3/18/2019 0.20 SLOT WELLPR DLOG T Tie into the Kt for a -7' correction. 7,970.0 7,997.3 03:12 03:24 3/18/2019 3/1812019 0.20 SLOT WELLPR TRIP T continue to RIH, park, Gose EDC. 7,997.3 8,095.9 03:24 03:36 3/18/2019 3/18/2019 0.90 SLOT WELLPR WASH T Run into 8200' - 8230' HS, 90,180, 8,095.9 8,231.6 03:36 04:30 270, then worked from 8220' to bottom at HS, 90, 180, 270 while pumping 2 -1 bpm. 3/18/2019 3/18/2019 70 SLOT WELLPR TRIP T Down on the pump, PU above TOC, 8,231.6 65.0 04:30 06:12 open EDC, POOH 3/18/2019 3/18/2019 0.50 SLOT WELLPR PULD T LD BHA#2, 3 fish in basket, upload 65.0 0.0 06:12 06:42 pictures &confer with town 3/18/2019 31182019 0.70 SLOT WELLPR WAIT T Determine path forward, decision 0.0 0.0 06:42 07:24 1 1made to make additional Venturi run 3/18/2019 3/1812019 0.40 SLOT WELLPR PULD T PU BHA #4 Venturi with 1 ° bent sub 0.0 65.6- 07:24 07:48 and 3/4 mule shoe under a HOT 3/18/2019 3/18/2019 1.50 SLOT WELLPR TRIP T RIH w/ BHA #4 65.0 7,970.0 07:48 09:16 -0 019 31182019 20 SLOT WELLPR DLOG T Log K1 for -6.5' correction, Gose EDC, 7,970.0 8,200.0 09:18 09:18 09:30 PUW = 30K, RIH to 8200' Page 3116 ReportPrinted: 41812019 Operations Summary (with Timelog Depths) 3F-01 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Time End Time EX, thr) phase Op Code A fty Code Time P -T -X SW DepthOparation W11) Ertl Depth (flKB) 3/18/2019 3/18/2019 1.00 SLOT WELLPR WASH T Perform Venturi passes from 8200' to 8,200.0 8,230.0 09:30 10:30 8230' @ HS, 90',180'. & 270°, 5 fpm, PUH to 8000', wash past GLM, wash down to TD twice work just off bottom, PUH & wash past 8000' one additional time 3/18/2019 3/18/2o19 1.20 SLOT WELLPR TRIP T POOH, open EDC, PJSM 8,230.0 65.0 10:30 11:42 3/18/2019 3/18/2019 0.50 SLOT WELLPR PULD T Flow check, LD BHA #4, cement 65.0 0.0 11:42 12:12 pieces in basket, no metal, decison made to PU bi-center bit 3/18/2019 3/18/2019 0.90 SLOT WELLPR PULD T PJSM, PU BHA #5 Cement Drilling (0° 0.0 62.0 12:12 13:06 AKO motor, RR HYC 2.98" bi-center), slide in cart, MU to coil, tag up, set counters 3/16/2019 3/18/2019 1.50 SLOT WELLPR TRIP T RIH w/ BHA#5 62.0 7,960.0 13:06 14:36 3/18/2019 3/18/2019 0.20 SLOT WELLPR DLOG T Log K1 for -7' correction, close EDC, 7,960.0 7,998.0 14:36 14:48 1 PUW = 29K 3/18/2019 3/18/2019 0.10 SLOT WELLPR TRIP T Continue RIH 7,998.0 8,231.0 14:48 14:54 3/18/2019 3/18/2019 1.10 SLOT WELLPR DRLG P Drilling, FS = 331 psi, @ 1.9 bpm, 8,231.0 8,258.0 14:54 16:00 CWT = 11.8K, WOB = 0.7K, pump = 3462 psi, PUW = 27K from, pump 5x5 sweeps, recip from 8100' to TD, PUW = 27K 3/18/2019 3/18/2019 1.70 SLOT WELLPR TRIP P POOH, flow -check, PJSM 8,258.0 65.0 16:00 17:42 3/18/2019 3/18/2019 0.70 SLOT WELLPR PULD P LD BHA#5 65.0 0.0 17:42 18:24 3/18/2019 3/18/2019 1.30 SLOT WELLPR WAIT P Discuss caliper plan forward, agree on 0.0 0.0 18:24 19:42 190 min activation time for caliper, hand returns to truck to program tool SIMOPS: inspect & torque storage reel bolts 3/18/2019 3/18/2019 0.60 SLOT WELLPR PULD P PJSM, PU BHA #6 PDS 24 Arm 0.0 56.6- 19:42 20:18 Memory Caliper, slide in cart, MU to coil, tag up, set counters 3/18/2019 3/18/2019 1.50 SLOT WELLPR TRIP P RIH w/ BHA #6 56.0 7,970.0 20:18 21:48 3/18/2019 3/18/2019 0.10 SLOT WELLPR DLOG P Log K1 for -7' correction 7,970.0 7,993.0 21:48 21:54 3/18/2019 3/18/2019 0.60 SLOT WELLPR TRIP P Continue RIH, PUW = 28K, RIH to 7,993.0 8,256.8 21:54 2230 3/18/2019 3/18/2019 0.70 SLOT WELLPR WAIT P Wait on caliper activation 8,256.8 8,256.8 22:30 23:12 3/18/2019 3/18/2019 0.20 SLOT WELLPR DLOG P Log 8256.IT Coto 78OU 8,256.8 7,705.0 23:12 23:24 3/18/2019 3/18/2019 0.30 SLOT WELLPR DLOG 5 Stop, allow arms to close, RIH & log 7,705.0 7,705.0 23:24 23:42 K1 for+1.5' correction (up -hole per PDS rep) 3/18/2019 3/19/2019 0.30 SLOT WELLPR TRIP P Begin POOH w/ BHA #6 7,705.0 6,476.0 23:42 00:00 3/19/2019 3/19/2019 1.10 SLOT WELLPR TRIP P Complete POOH, flow -check, PJSM 6,476.0 75.0 00:00 01:06 3/19/2019 3119/2019 0.60 SLOT WELLPR PULD P LD BHA#6 memory caliper, good 75.0 0.0 0106 01:42 data. Page 4116 ReportPrinted: 418/2019 Operations Summary (with Timelog Depths) 3F-01 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Time EMTYne our (hr) Phase Dp Code ActlWry CMe Time P-T-% Operation Start Depth Mal EM Depth(flKB) 3/19/2019 3/1972019 0.60 SLOT WELLPR PULD P PJSM, PU BHA#7, dummy WS drift, 0.0 49.0 01:42 02:18 17.85' long 2.64" OD barbell shaped to mimic setting tool and WS. .. Inspected coil 20' back from CTC, tested wall thickness@ 12' back from CTC, ODS 1.76", Reel 1.78", DW 1.79", DS 1.88" slight gouges, from down hole - 9' back. 3/19/2019 3/19/2019 1.50 PROM WHPST TRIPP RIH w/BHA #7 49.0 7,966.0 02:18 03:48 3/19/2019 3/19/2019 0.20 PROM WHPST DLOG P Log K1 for-6' correction 7,966.0 8,003.0 03:48 04:00 3/19/2019 3/19/2019 0.20 PROM WHPST TRIP P Continue in hole with dummy 8,003.0 8,258.6 04:00 04:12 whipstock. tag depth of 8258.55'& 1.16 k Itis WOB, PU Wt 27 k - clean. 3/19/2019 3/1912019 1.40 PROD1 WHPST TRIP P POOH w dummy WS drift 8,258.6 50.0 04:12 05:36 3/19/2019 3/19/2019 0.90 PROD1 WHPST PULD P Bump up, crew change, LD BHA#7 50.0 0.0 05:36 06:30 3/19/2019 3/19/2019 1.20 PR051 WHPST PULD P PU BHA #8, BOT 3.5 "whipstock. 0.0 70.0 06:30 07:42 3/19/2019 3/19/2019 1.80 PROM WHPST TRIP P RIH w3.5"BOT whipstock 70.0 7,180.0 07:42 09:30 3/192019 3/19/2019 0.10 PROM WHPST CLOG P Tie into the K1 for a -7' correction. 7,180.0 8,000.0 09:30 09:36 3/19/2019 3/19/2019 0.20 PROD1 WHPST WPST P RIH to 8200', PU Wt 29 k lbs. Close 8,000.0 8,254.0 09:36 09:48 EDC, orient HS, RIH to bit depth 8253.4' Online w the pump @ 0.50 bpm, WOB built from 64 Itis to 4.6 k lbs, sheared at 3,700 psi, WOB fell to 1.9 k lbs, SO to 3.5 k lbs. "Top of WS 8243' 0°ROHS 3119/2019 3/1912019 1.20 TRODI TRIP P PU 37 k lbs, POOH 8,254.0 70.0 09:48 11:00 3/19/2019 3/192019 0.80 PR0D1 WHPST PULD P LD BHA#8, WS setting assembly 70.0 0.0 11:00 11:48 3/19/2019 3/19/2019 0.70 PROD1 WHPST PULD P PU BHA#9, l st window milling 0.0 70.0 11:48 12:30 assembly, bump up, set depths, 3119/2019 3/19/2019 1.20 PROD1 WHPST TRIP P RIH, swapping coil over to milling fluid 70.0 7,985.0 12:30 13:42 3/19/2019 3/192019 0.20 PRODi WHPST TRIP P Tie into the K1 for a -7' correction. 7,985.0 8,005.0 13:42 13:54 3/192019 3/192019 0.80 PR0D1 WHPST DISP P Open EDC, circulate milling fluid to 7,985.0 8,092.0 13:54 14:42 surface, close EDC. 3/19/2019 3/19/2019 0.10 PROM WHPST TRIP P RIH, dry tag TOWS 8245.2, PO Wt 29 8,092.0 8,245.2 14:42 14:48 klbs 3/19/2019 3/192019 0.20 PROM WHPST WPST P PU, set rate, RBIH 8,245.2 8,245.2 14:48 15:00 CT 4249 psi, Q 1.90 bpm, diff 481 psi, BHP 3434 psi, 11.25 ppg EMW at the Window, Open choke, WH 18 psi, IA 941, OA 567. Stall 3 times, Get started on 8245.19' 3/19/2019 3/192019 2.20 PROD1 WHPST WPST P OBD, CT Wt 11 k lbs, WOB 0.48 k lbs, 8,245.2 8,247.0 15:00 17:12 50 Itis of motor work. 1 Increase ROP to 0.8 ft/ hr, CT 11 k lbs, WOB 2.53 k lbs Page 5116 Report Printed: 4/8/2019 Operations Summary (with Timelog Depths) 3F-01 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Statrme End tore Dw ( Phew Op coos Activly Cosa rnra P -T -X operaliw, Stat � (WS) End Depth (MG) 3/19/2019 3/1912019 4.8.8 0 PROD1 WHPST WPST P Continue milling window exit as per 8,247.0 8,251.2 17:12 22:00 RP and BOT rep. 1.9 bpm at 4,100 psi, Diff -489 psi,WHP=-16, BHP=3418, IA=956, OA=617 - Note: Increased motor work @ 8,248.7', 8,249.2', and 8,249.4', motor work milled off nomally. 3/19/2019 3/19/2019 0.15 PROD1 WHPST TRIP P TDfirstwindow run, PUH to ream 8,251.2 8,243.0 22:00 22:09 window area, PUW=30 k •" Note: No indication of 7" contact 3/19/2019 3/19/2019 0.60 PROD1 WHPST REAM P Make reaming passes @ 60 fph x 3 8,243.0 8,251.2 22:09 22:45 3/19/2019 3/20/2019 1.25 PROM WHPST TRIP P POOH, with closed EDC, pumping 1.9 8,251.2 1,255.0 22:45 00:00 bpm at 4,010 psi 3/20/2019 3/20/2019 0.25 PROD1 WHPST TRIP P Continue POOH w/window milling 1,255.0 74.7 00:00 00:15 BHA#9 3/20/2019 3/20/2019 0.75 PROD1 WHPST PULD P PU/MU BHI X-Treme 1.25° bend 74.7 0.0 00:15 o100 motor and FAT Radius mill 3/20/2019 3/20/2019 0.50 1 PROD1 WHPST PULD P PU/MU Window Milling section#2 0.0 78.7 01:00 01:30 BHA#10 3/20/2019 3/20/2019 0.25 PROD1 WHPST PULD P Stab onto well, perform surface test 78.7 78.7 01:30 01:45 (good -test) 3/20/2019 3/20/2019 1.40 PROD1 WHPST TRIP P RIH, w/BHA#10 78.7 7,980.0 01:45 03:09 3/20/2019 3/20/2019 o.20 PROD1 WHPST DLOG P Log formation (K1 marker) correction 7,980.0 8,252.0 03:09 03:21 of minus 7.0' 3/20/2019 3/20/2019 0.20 PR0D1 WHPST TRIP P Continue IH, drytag @ 8,252.05' 8,252.0 8,252.0 03:21 03:33 19 019 0.20 PROD1 WHPST TRIP P PUH, obtain pump parameters 8,252.0 8,251.9 03:33 03:33 03:45 03:45 3/20/2019 3/20/2019 2.20 PROD1 WHPST MILL P OBM, 1.86 bpm at 3,955 psi, Diff --464. 8,251.9 8,253.3 03:45 05:57 WHP=14. BHP=3,413, IA=950, OA=600 3/20/2019 3/20/2019 1.30 PR0D1 WHPST MILL P Engage auto drill 8,253.3 8,254.9 05:57 07:15 OBM, CT 4253 psi @ 1.85 bpm in and 1.85 bpm out, BHP 3490 psi. WH 117 psi, IA 961, OA 636 psi. CT 10.4 k lbs, WOB 2.1 - 2.99 k lbs 3/20/2019 3/20/2019 0.80 PROD1 WHPST MILL P Drill off, out of 7" @ 8254.9' 8,254.9 8,255.9 07:15 08:03 Reamer out @ 8255.5' 320/2019 3/20/2o19 1.90 PROD1 DRILL DRLG P Drilling ahead 8,255.9 8,270.0 08:03 09:57 CT 4261 psi @ 1.85 bpm in and 1.85 bpm out, 666 psi diff, BHP 3498 psi, CT 9.2 k lbs, WOB 2.5 k lbs, ROP 8 fthr. Geologist confirms formation in sample. "TD Build @ 8270' 3/20/2019 3/20/2019 1.60 PROD1 DRILL REAM P Perform Reamming up passes at 330, 8,270.0 8,243.0 09:57 11:33 30, and 180°, down passes @ 0° ROHS. Launch TO sweeps. 3/20/2019 320/2019 0.40 PROD1 DRILL CIRC P Dry drift clean, PUH, open EDC, 8,243.0 8,123.0 11:33 11:57 chase sweeps out of coil. 3/202019 3/20/2019 1.40 PROD1 DRILL TRIP P POOH. 8,123.0 68.0 11:57 13:21 3/20/2019 3202019 1.10 PRODt DRILL PULD P PUD BHA#10, WH 640 psi. 68.0 0.0 13:21 14:27 3/202019 3/20/2019 0.60 PROD1 DRILL CIRC P Pull checks, stab injector, jet stack 0.0 0.0 14:27 15:03 Page 6116 Report Printed: 4/812019 Operations Summary (with Timelog Depths) 3F-01 li p Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Starl7me FiW Titre Dir (lin Phase 2LCode Acbrity Cotle Tune P-T-x opemlim Smit Depth End DepN (RKB) 3/202019 3/20/2019 0.40 PROUl DRILL CTOP P Reverse circulate, unstab, replace 0.0 0.0 15:03 15:27 upper quick connect. 3/20/2019 3/202019 1.00 PROD1 DRILL PULD P PU & PD BHA#11, L1 build drilling 0.0 72.0 15:27 16:27 assembly. 3/202019 3/202019 1.80 PROD1 DRILL TRIP P RIH, 72.0 7,975.0 16:27 18:15 3/20/2019 3/20/2019 0.20 PROD1 DRILL DLOG P Tie into the K1 for -6' correction. 7,975.0 7,996.0 18:15 18:27 3/202019 3/20/2019 0.40 PROD1 DRILL TRIP P Continue RIH, tag bottom 8,270' 7,996.0 8,270.0 18:27 18:51 3202019 3/20/2019 0.60 PROD1 DRILL DRLG P OBD, 1.86 bpm at 4,244 psi, Diff- 8,270.0 8,295.0 18:51 19:27 464, WHP=120, BHP=3538, IA=962, OA=638 320/2019 3/202019 0.15 PROD1 DRILL WPRT P Tools hung up in window area, PUH, 8,295.0 8,295.0 1927 19:36 PUW 33 k, Restart 320/2019 3/20/2019 0.25 PROD1 DRILL DRLG P OBD, 1.66 bpm at 4,244 psi, Diff-- 8,295.0 8,303.0 19:36 19:51 464, WHP=120, BHP=3538, IA=962, —0 OA=638 3/20/2019 320/2019 15 PROM DRILL WPRT P PUH, PUW 33 k, restart 8,303.0 8,303.0 19:51 20:00 320/2019 3/20/2019 1.60 PROD1 DRILL DRLG P OBD, 1.86 bpm at 4,244 psi, Diff-- 8,303.0 8,340.0 20:00 21:36 464, WHP=120, BHP=3538, IA=962, OA=638 3/202019 3/202019 0.15 PROM DRILL WPRT P PUH, PUW 33 k, restart 8,340.0 8,340.0 21:36 21:45 3/20/2019 3/20/2019 0.35 PROD1 DRILL DRLG P OBD, 1.86 bpm at 4,244 psi, Diff= 8,340.0 8,357.5 21:45 22:06 464, WHP=120, BHP=3538, IA=962, OA=638 3/20/2019 320/2019 0.25 PROD1 DRILL WPRT P TD build section (Avg. DLGS 49.26° 8,357.5 8,245.0 22:06 22:21 1 DLGS), PUW 33 k, pull wiper to the window, chasing 5x5 sweep 3/20/2019 3/202019 1.50 PROD1 DRILL WPRT P POOH 8,245.0 78.0 22:21 23:51 —0 3/202019 3/21/2019 16 PR0D1 DRILL PULD P Tag up, spaceout, PJSM for PUD build 78.0 78.8 23:51 00:00 —0 assembly 3/21/2019 3/212019 60 PROM DRILL PULD P PUD, build assembly 78.8 0.0 00:00 00:36 3/21/2019 3/21/2019 1.20 PROD1 DRILL PULD P PD, Lt Lateral section assembly 0.0 78.3 00:36 01:48 321/2019 3/212019 1.55 PROM DRILL TRIP P RIH, w/Lateral Drilling BHA#12, 0.5" 78.3 7,975.0 01:48 03:21 1 ako motor, agitator, bi-center bit. 3212019 321/2019 0.20 PROD1 DRILL DLOG P Log the K1 for depth control (minus 7,975.0 8,000.0 03:21 03:33 —0 6.0'), PUW 30 k 3/212019 3/21/2019 20 PROM DRILL TRIP P Continue IH 8,000.0 8,265.0 03:33 03:45 3/21/2019 3/21/2019 0.20 PROD1 DRILL DLOG P Log the RA marker 8,265.0 8,265.0 03:45 03:57 Note: Offical Window Depths TOWS=8245.5' RA Marker-8251.5' BOW=8252.5' EOB=8357.5' 3/212019 3/21/2019 0.20 PR0D1 DRILL TRIP P Continue IH 8,265.0 8,357.5 03:57 04:09 3/21/2019 3/212019 2.50 PROD1 DRILL DRLG P OBD, 1.87 bpm at 5,150 psi, 8,357.5 8,616.0 04:09 06:39 Diff-1,375, WHP=53, BHP=3533, IA=958, OA=618 PU 30 k lbs - 8588' Page 7116 Report Printed: 4/8/2019 Operations Summary (with Timelog Depths) 3F-01 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log start Time End Time Dur(m) Phase Op codeActivity Cade Time P -T -X O Sh(KKBpth EM Depth (WB) 3/21/2019 3/21/2019 1.30 FROM DRILL DRLG P OBD,CT 5386 psi, 1.89 by min 1.83 8,616.0 8,760.0 06:39 07:57 bpm out, WHP=44, BHP=3538, IA=970, OA=641 pump 5x5 sweep 3/21/2019 3/21/2019 0.20 PROD1 DRILL WPRT P PU 30 k Ib, wiper trip #1 - 460' 8,760.0 8,300.0 07:57 08:09 3121/2019 3/21/2019 0.10 PRODt DRILL WPRT P RBIH, RIH Wt 8.7 k lbs 8,300.0 8,760.0 08:09 08:15 .• bleed IA for 1 hr 3/21/2019 3/21/2019 1.20 PROD1 DRILL DRLG P CT 5265 psi @ 1.90 bpm in and 1.89 8,760.0 8,903.0 08:15 09:27 bpm out, BHP 3569 psi, 11.45 EMW the window. WH 49 psi, IA 806 psi, OA 643 psi. OBD, CT Wt 6 k lbs, WOB 1.6 k lbs Average ROP while on bottom - 119 ft/hr 3/21/2019 3/21/2019 0.90 PROM DRILL DRLG P 1.87 bpm in, returns fell to 1.35 bpm. 8,903.0 8,954.0 09:27 10:21 P. 34 k lbs, RBIH, loses increased, returns fell to 1 bpm. Drill ahead, high WOB with low diff, PU, 35 k lbs, restart drill ahead, ratty drilling, High ROP low WOB, then stack out. PU, 35 it lbs. Losses healing as we drill ahead, 1.88 bpm in, 1.75 bpm out. Average ROP while on bottom - 56 fl/hr 3/21/2019 3/21/2019 0.70 PROD1 DRILL DRLG P CT 525 psi, 1.88 bpm in and 1.82 bpm 8,954.0 9,070.0 10:21 11:03 out, free spin diff 1399 psi, BHP 3562 psi, CT Wt 6 k lbs, WOB 0.8 k ibs, Launch 5x5 in anticipation of wiper trip. Average ROP while on bottom - 166 ft/hr 3/21/2019 3/21/2019 0.20 PROM DRILL WPRT P PU Wt 33 k lbs, 9,070.0 8,850.0 11:03 11:15 Pull wiper chasing 5x5 sweep. Wipe above original loss zone -8905' 3/21/2019 3/21/2019 0.10 PROM DRILL WPRT P RBIH 8,850.0 9,070.0 11:15 11:21 3/21/2019 3/21/2019 3.00 PROD1 DRILL DRLG P Initiate Continuous rotation of the 9,070.0 9,543.0 11:21 14:21 HOT, new stearable script, Limit ROP to 160 ft/hr or less. CT 5230 psi 1.87 bpm in and 1.82 bpm out. Free spin diff 1360 psi, BHP 3625, Ct Wt 5.5 it lbs, Had to slide and increase WOB to arrest from 9463'- 9476' Pump 5x5 sweep and chase with new mud. Average ROP while on bottom - 157 ft/hr 3/21/2019 3/21/2019 0.30 PROM DRILL WPRT P PU Wt 32 k ibs - Wiper#2, - 1145' 9,543.0 8,400.0 14:21 14:39 PUH chasing sweeps new mud at the bit - 9543' 3/21/2019 3/21/2019 0.60 PROD1 DRILL WPRT P RBIH, RIH Wt 7.9 k lbs 8,400.0 9,543.0 14:39 15:15 3/21/2019 3/21/2019 2.75 PR0D1 DRILL DRLG P CT 4995 psi @ 1.89 bpm in and 1.96 9,070.0 9,543.0 15:15 18:00 bpm out. Free spin diff 1327 psi, BHP 3552, Ct Wt 4.7 k lbs, Average ROP while on bottom - ft/hr 3/21/2019 3/21/2019 0.65 PROD1 DRILL WPRT P Wiper up hole, PUW 32 k 9,543.0 8,270.0 18:00 18:39 3/21/2019 3/21/2019 0.20 PROM DRILL DLO G P Log the RA marker correction 0f plus 8,270.0 8,287.2 18:39 18:51 3.01ft 3/21/2019 3/21/2019 0.60 PRODt DRILL WPRT P Wiper back in hole, RIW 9 k 8,287.2 9,973.0 18:51 19:27 Page 8116 Report Printed: 4/8/2019 a , Operations Summary (with Timelog Depths) rte;, 3F-01 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Time Entl Txne D.(hr) Phase Op Code I Activity Cotle Time P -T-% Operation Start Depth (RKB) End Depth (WB) 3/21/2019 3/21/2019 0.25 PROD? DRILL DRLG P BOBD, 1.89 bpm at 5,000 psi, 9,973.0 10,023.0 19:27 1942 Diff -1,190, WHP=138, BHP=3,606, IA=911, OA=599 3/21/2019 3/21/2019 2.20 PROD? DRILL DRLG P Geo steer from 86° NBI to 97°, 10,023.0 10,270.0 19:42 27:54 discontinue continous rotation drilling (test interval 9,070'-10,023'), continue drilling ahead @ 345° TF, 1.89 bpm at 5,277 psi, R0P=165 fph, off bottom Diff=1,190, WHP=97, BHP=3,631, IA=610, OA=588 019 3/21/2019 0.25 PROD1 DRILL WPRT P Wiper up hole PUW 33 k 10,270.0 9,570.0 21:54 21:54 22:09 3/21/2019 3/21!2019 0.30 PROD1 DRILL WPRT P Wiper back in hole, RIW 8 k 9,570.0 10,270.0 22:09 22:27 -1.30 3/21/2019 019 PROD1 DRILL DRLG P 6- BID, 1.89 bpm at 4.987 psi, 10,270.0 10,398.0 22:27 2345 2345 Diff=1,102, WHP=69, BHP=3,631, IA=611, OA=605 3/21/2019 3/21/2019 0.15 PROD1 DRILL WPRT P PUH, and restart, BHA wiper 10,398.0 10,398.0 23:45 2354 3/21/2019 3/22/2019 0.10 PROD? DRILL DRLG P BOBD, 1.89 bpm at 4.987 psi, 10,398.0 10,470.0 23:54 00:00 Diff=1,102, WHP=69, BHP=3,631, IA=611, OA=605 3/22/2019 3/22/2019 2.00 PROD1 DRILL DRLG P 01 1.89 bpm at 5,125 psi, 10,410.0 10,551.0 00:00 02:00 Diff=1,264, WHP=90. BHP=3,633, IA=616, OA=624 3/22/2019 3/22/2079 0.15 PROD? DRILL WPRT P PUH, restart, BHA wiper PUW -30k 10,551.0 70,551.0 02:00 02:09 3/22/2019 3/22/2019 1.60 PROD1 DRILL DRLG P BOBD, 1.89 bpm at 5,008 psi, 10,551.0 10,673.0 02:09 03:45 Diff=1,089, WHP=106, BHP=3,693, IA=616, OA=624 3/22/2079 2/2019 0.30 PROD1 DRILL WPRT P Wiper up hole, PUW 32 k 10,673.0 9,473.0 03:45 :03 F3122/2019 3/22/2019 0.40 PROD1 DRILLWPRT P Wiper back in hole, RIW 8 k 9,473.0 10,673.0 04:03 27 3/22/2019 3/22/2079 0.90 PR0D1 DRILL DRLG P CT 4973 psi, @ 7.89 bpm in, 1.89 10,673.0 10,754.0 04:27 05:21 bpm, free spin 1025 psi, BHP 3623 psi. OBD, CT Wt 2.9 k lbs, WOB 1.3 k lbs, ROP -130 @10754 sudden loss in returns, 1.89 bpm in, returns fell to -0.45 bpm PU Wt 31 k lbs, PU slowly, returns not healing, 3/22/2019 3/22/2019 1.70 PROD? DRILL WPRT P PUH to the window, adjust choke to 10,754.0 8,077.0 05:21 07:03 11.1 ppg EMW at the window to manage losses while pulling to the window. 3/22/2019 3/22/2019 0.20 PROD1 DRILL DLOG P Tie int othe RA tag for a +4.5 8,077.0 8,291.0 07:03 07:15 correction 3/22/2019 3/22/2019 0.90 PROD' DRILL TRIP P RBIH, 8,291.0 10,754.0 07:15 08:09 S/D @ 8769' Higher gamma area, 1.8 k WOB, bounced through. 1.85 bpm in and 1.73 bpm out fell to 1.14 bpm out at bottom 3/22/2019 3/22/2019 1.40 PROD1 DRILL DRLG P CT 4790 psi, at 1.86 bpm in and 1.14 10,754.0 10,888.0 08:09 09:33 bpm out, free spin diff 978 psi, WH 109 psi holding 11.1 ppg. Drill ahead, returns heal to 1.4 bpm whie holding 11.1 EMW Page 9116 ReportPrinted: 4/8/2019 Summary (with Timelog Depths) 3F-01 lipOperations Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Time EM 11MOur (hd Phase Op Coda Ao Qy Cade Time P -T -X Opmation Start Depth (M(B) End Depth(M(B) 3/22/2019 3/22/2019 2.40 PROD1 DRILL DRLG P Ecountered additional losses, returns 10,888.0 11,109.0 09:33 11:57 fell to 0.25 bpm. PU, 33 k lbs, RBIH, drill ahead with multiple pick ups, CT PU WT 35-33 k lbs. targeting 11.0 ppg EMW @ the window, returns healing CT 4962 psi, 1.86 bpm in and 1.51 bpm out. BHP 3593 psi 3/2212019 3/22/2019 0.40 PROD1 DRILL WPRT P PU Wt 34 k lbs - #1 - 1000' 11,109.0 10,009.0 11:57 12:21 1.88 bpm in, 1.48 bpm out while pulling 50 ftlmin losses -0.25 bpm 3/22/2019 3/22/2019 0.30 PROD1 DRILL WPRT P RBIH 10,009.0 11,109.0 1221 12:39 WellWorc shows .5 bbl solids returned. 3/22/2019 3/2212019 4.40 PROD1 DRILL DRLG P CT 4625 psi, @ 1.88 bpm in and 1.60 11,109.0 11,401.0 12:39 17:03 bpm out, free spin diff 980 psi, BHP 3506 psi, holding 11.0 ppg @ the window. 11190' PU 35 k lbs 11414'PU 40 k lbs 3/22/2019 3/22/2019 0.50 PROD1 DRILL DRLG P OBD, 1.88 bpm at 4,800 psi, 11,401.0 11,462.0 17:03 17:33 Diff --1,190, WHP=132, BHP=3,565, IA=595, OA=588 3/22/2019 3/22/2019 2.50 PROD1 DRILL WPRT P Encountered 100% losses, PUH, 11,462.0 8,240.0 17:33 20:03 PUW 36 k, pull slow wiper up hole, circulate 1 0x1 0 sweep, confer with town team, called TD early 11,462', continue wiper up hole, returns slow to return. pull slow wiper to the window chasing sweep. 3/22/2019 3/22/2019 2.00 PROD1 DRILL WPRT P Pull through the window, bring pump 8,240.0 2,400.0 20:03 22:03 back up to full rate, continue pulling swab wiper @ 25 fpm, maintaining 0.75 bpm returns. @ 6,500', WHP steadiy climbing, increase pulling speed to 80 fpm, maintaining 0.85 bpm returns, 31222019 31222019 0.70 PROW DRILL WPRT P Increase pulling speed to 90 fpm 2,400.0 78.2 22:03 22:45 maintaining 0.9 bpm returns. 3/22/2019 3/22/2019 0.20 PROM DRILL TRIP P Tag up, reset counter depths, RIH 78.2 1,529.0 22:45 22:57 3/2212019 31222019 0.45 PROD1 DRILL TRIP P Set down, PUH clean, inspect INJH, 1,529.2 1,529.2 22:57 23:24 seems to be pac-off lube, continue RIH 3/22/2019 3/232619 0.60 PROD1 DRILL TRIP P RBIH, pumping 0.62 bpm/0.20 bpm 1,529.2 3,195.0 23:24 00:00 returns, w/ Lateral drilling BHA#12 3/23/2019 3/23/2019 0.80 PROD1 DRILL TRIP P Continue RlHw/BHA#12toconfirm 3,195.0 7,980.0 00:00 00:48 TD 3/23/2019 3123/2019 0.20 PROD1 DRILL DLOG P Log the Kt (minus 6.0) PUW 30 k 7,980.0 8,000.7 00:48 01:00 3/23/2019 3/23/2019 0.20 PROD1 DRILL TRIP P Continue IH 8,000.7 8,215.0 01:00 01:12 323/2019 3/23/2019 0.15 PROD1 DR ILL TRIP P Perform Pressure Survey -3 min- 8,215.0 8,215.0 01:12 01:21 Failing quickly, come back online with pump. Press Sesor @ 5,856.9 TVD AP=3,012 9.899 ppg 3/23/2019 3/232019 1.35 PROD1 DRILL TRIP P Continue IH, holding 11.0 ppg at the 8,215.0 11,463.0 01:21 02:42 window, pumping 1.7 bpm at 4,014 psi, 0.50 bpm returns, WHP=328, Page 10116 Report Printed: 418/2019 Operations Summary (with Timelog Depths) 3F-01 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Time End Time Dw inn PhamOp Cod. Activity Code P--Tx TimeLL Cpe thon SM4 Depth (e(a) End Depth (Wit)3/23/2019 3/23/2019 1.80 PRO D1 DRI TRIP P Tag bottom 11,463', PUW 35 k, 11,463.0 5,778.0 02:42 04:30 painting EDP flags TD flag (Yellow 15778.25') 9073.25'), Window flag (White 3/23/2019 3/2312019 1.00 PROM DRILL TRIP P Continue to POOH. while tuning coil 5,778.0 93.0 04:30 05:30 over to 10.5 pgg KWF. 3123/2019 3/23/2019 2.00 PROD1 DRILL DISP P Park and pump 50 bbls, of viscosified 93.0 93.0 05:30 07:30 (100k Cp LSRu) 10.5 ppb liner running pill down the kill line /back side, followed by 50 additional bbls of 10.5 ppb normal vise liner running pill. 3/23/2019 3/23/2019 0.90 PROD1 DRILL PULD T7 PJSM, Flow check, initial losses -12 93.0 0.0 07:30 08:24 bbVhr. LD BHA#12 over a dead well. 3/23/2019 3/23/2019 0.40 COMPZI CASING PUTB P Pre floor for running liner 0.0 0.0 08:24 08:48 3/23/2019 3/23/2019 0.40 COMPZ1 CASING 'BOPE BOP function test 0.0 0.0 08:48 09:12 3/23/2019 3/23/2019 3.40 COMPZI CASING PUTB P PU 2-318 " 4.6 # STL slotted liner, 81 0.0 2,410.8 09:12 12:36 joints over a non ported bull nose ( LOA 2410.84), clean floor of liner running equipment. 3/23/2019 3/23/2019 1.10 COMPZI CASING PULD P PU L1 liner running BHA ( GS stabbed 2,410.8 2,464.1 12:36 13:42 into an aluminum liner top billet), skid cart, stab injector, inspect pack offs, bump up, set counters. ""118 bbls KWlost while picking up liner and BHA 3/232019 3/2312019 2.50 COMPZI CASING RUNL P RIH W L1 completion, lined up across 2,464.1 11,456.0 13:42 16:12 the top, pumping KW away with just the charge pump pressure, lined up down the coil @ 0.5 bpm, caught returns @ 4065', 0.6 bpm losses. Tie into white window flag for -10.78' correction. Pu wt 32 k bs, RIH WOB - 5.39 k lbs SID shallow @ 11,456', PU and RBIH, SID 11,452', PU 44 k and SID 11448' Consult town, Pump of linerl.5 bpm, 800 psi diff, PU 30k bs. TOL @ 9028' bottom of liner 11448' 3/23/2019 3/23/2019 1.50 COMPZI CASING TRIP P PUH after dropping off L1 completion, 11,456.0 8,218.0 16:12 17:42 park, reset counters. 312312019 3/23/2019 0.90 COMPZI CASING DISP P Turn well over to mud 8,218.0 8,218.0 17:42 18:36 3/23/2019 3/23/2019 1.30 COMPZI CASING TRIP P POOH 8,218.0 44.2 18:36 19:54 3/23/2019 3/23/2019 0.80 COMPZI CASING PULD P At surface, spaceout, PUD/LD setting 44.2 0.0 19:54 20:42 tools 3/23/2019 3/23/2019 1.00 PROD2 STK PULD PU/PD, L1-01Lateral Drilling 0.0 78.3 20:42 21:42 Assembly, BHA#14 3/23/2019 3/23/2019 0.30 PROD2 STK TRIPTag FP up, reset counters, close EDC, 78.3 486.0 21:42 22:00 RIH @ 486' surface test mud motor/agitator (good -test) 3/232019 3/23/2019 1.40 PROD2 STK TRIP P Continue RIH 486.0 7,980.0 22:00 23:24 3/23/2019 3/23/2019 D2 STK DLOG P Log the K1 marker (minus 6.5') 7,980.0 8,000.8 23:24 23:36 3/232019 3/24/2019 J0.60 D2 STK TRIP P Continue IH 8,000.8 8,618.0 23:36 00:00 19 3/24/2019 D2 STK TRIP P Continue IH, dry tag TOB 8,618.0 9,026.0 00:00 00:00 00:36 Page 11116 Report Printed: 418/2019 z-, Operations Summary (with Timelog Depths) 3F-01 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Time End Tme Ow (hr) Phase DP Code Activity code, Tim P -T-% Operatlon Start Depth (ftKe) End Depth (W8) 3/24/2019 3/24/2019 0.20 PROD2 STK TRIP P PUH PUW 30 k, obtain pump 9,026.0 9,026.0 00:36 00:48 parameters 3/24/2019 3/24/2019 0.60 PROD2 STK KOST P Kickoff Billet, 1.88 bpm at 4,272 psi, 9,026.0 9,027.0 00:48 01:24 Diff=903, WHP=155, BHP=3,405, IA=603, OA=584, Time mill 2 tenths @ 6 min 3/24/2019 3/24/2019 0.70 PROD2 STK KOST P Increase ROP to 2 fph, 1.88 bpm at 9,027.0 9,028.0 01:24 02:06 4,287 psi, Diff=935, WHP=149, BHP=3,408, IA=605, OA=593, 0.7 k=DHWOB, CTSW= 12 k 3/24/2019 3/24/2019 0.60 PROD2 STK KOST P Increase ROP to 3 fph, 1.88 bpm at 9,028.0 9,029.0 02:06 0242 4,376 psi, Diff=1,008, WHP=147, BHP=3,399, IA=607, OA=599, 0.74 k=DHWOB, CTSW=11.1 k 3/24/2019 3/24/2019 0.30 PROD2 STK KOST P Increase ROP to 10 fph, 1.88 bpm at 9,029.0 9,036.5- 02:42 03:00 4,376 psi, Diff=1,008, WHP=147, BHP=3,399, IA=607, OA=599, 0.74 k=DHWOB, CTSW=11.1 k 3/24/2019 3/24/2019 0.90 PROD2 DRILL DRLG P Drill ahead 1.88 bpm @ 4,325 psi, 9,036.0 9,142.0 03:00 03:54 Diff=990, WHP=118, BHP=3,402, IA=609, OA=604, 3/24/2019 3/24/2019 0.30 PROD2 DRILL WPRT P PU Wt 39 k lbs, PUH to dry drift billet. 9,142.0 9,142.0 03:54 04:12 9070'Pull-1k WOB RBIH See WOB spike @ 9075'to 1.3 k lbs, same area we started the continuous rotation lest during the L1 lateral drilling Billet drifted clean 3/24/2019 3/24/2019 2.40 PROD2 DRILL DRLG P CT 4310 psi @ 1.9 bpm in and 1.9 9,142.0 9,426.0 04:12 0636 bpm out. BH 3374 psi, holding 11.0 EMW @ the window. OBD, CT 6.3 k Is, WOB 2.1 0500 - increase choke to target 11.2 ppg EMW @ the window, BHP 3477 psi Average ROP over section = 118 ft/hr 3/24/2019 3/24/2019 0.40 PROD2 DRILL WPRT P PUWt 33 k Its, - Wiper#1 - short 9,426.0 9,426.0 06:36 07:00 wiper to just below the billet - 379' Turn around @ 6:48 and 9047' RBIH, No evidence of issues at 9070' - clean 3/24/2019 3/24/2019 0.90 PROD2 DRILL DRLG P CT 4629 psi @ 1.9 bpm in and 1.9 9,426.0 9,552.0 07:00 07:54 bpm out. free spin diff 948 psi, BH 3475 psi, holding 11.2 EMW @ the window. OBD, CT 9 k lbs, WOB 2.8 Average ROP over section = 140 ft/hr 3/24/2019 3/24/2019 2.50 PROD2 DRILL DRLG P Initiate continuous rotation of the HOT 9,552.0 9,826.0 07:54 10:24 -AKA and from here forward - RotoTrak CT 5016 psi @ 1.89 bpm in and 1.89 bpm out, 3461 psi BHP, 11.2 ppg EMW @ the windowCT Wt 0.2 k lbs, 2.4 k lbs WOB. Average ROP over section = 110 ft/hr 3/24/2019 3/24/2019 0.30 PROD2 DRILL WPRT P PU Wt 32 k lbs, Wiper trip #2-778' 9,826.0 9,048.0 10:24 10:42 3/24/2019 3/24/2019 0.20 PROD DRILL WPRT P RBIH 9,048.0 9,826.0 10:42 10:54 WellWorc indicates 0.27 bbls cutting returned on the trip. Page 12116 Report Printed: 4/8/2019 Operations Summary (with Timelog Depths) 3F-01 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Time Emirates Write) Phase Op Code Activity Code Time P -T -X Operstlon stat (NCB) End Depth (fIKB) 3/24/2019 3/24/2019 0.40 PROD2 DRILL DRLG P RotoTrak 9,826.0 9,875.0 10:54 11:18 CT psi 5128 psi @ 1.89 bpm in and 1.89 bpm out, free spin 886 psi, 3492 psi BHP, 11.2 ppg EMW @ the window CT Wt -0.2 k lbs, 3.1 k lbs WOB. Average ROP over interval 122 ft/hr 3/24/2019 3/24/2019 3.50 PROD2 DRILL DRLG P Roto Trak 9,875.0 10,226.0 11:18 14:48 " Losses, returns fell to 0.2 bpm, PU Wt 33 k lbs, Reduced choke to hole 11.0 ppg EMW at the window. Losses slowly healed returns climbed tol.6 bpm RBIH and drill ahead. CT psi 5064 psi @ 1.89 bpm in and 1.60 bpm out, free spin 885 psi, 3439 psi BHP, 11.0 ppg EMW @ the window CT Wt -3 k lbs, 2.2 k lbs WOB. 3/242019 3/24/2019 0.60 PROD2 DRILL WPRT P PU W132 k lbs, Wiper trip #3, long 10,226.0 6,270.0 14:48 15:24 wier to the window for lie in. Saw negative WOB tug @ 9066'- 1 k lbs 324/2019 324/2019 0.20 PROD2 DRILL DLOG P Tie into the RA tag for a +3.5 8,270.0 8,302.0 15:24 15:36 correction. 3/24/2019 3/242019 0.60 PROD2 DRILL WPRT P RBIH, Window clean 8,302.0 10,226.0 15:36 16:12 Saw WOB bobble @ 9072'0.4 k lbs Billet clean 3/24/2019 3/24/2019 0.80 PROD2 DRILL DRLG P RotoTrak 10,226.0 10,335.0 16:12 17:00 CT 4693 psi, @ 1.89 bpm in and 1.73 bpm out, free spin 931 psi, BHP 3438 psi, 11.0 ppg EMW @ the window. CT Wt -1.9 k lbs, 2.5 k WOB. 324/2019 324/2019 0.20 PROM DRILL WPRT P PUH, PUW 33 k, restart 10,335.0 10,335.0 17:00 17:12 3/242019 3/24/2019 1.50 PROD2 DRILL DRLG P BOBD, 1.87 bpm at 4,800 psi, 10,335.0 10,501.0 17:12 18:42 Diff=941 psi, WHP=108, BHP=3,471, IA=623, OA=654, RotoTrak Drilling 10,335'-10341' (6) 10,357'-10,398'(4l') 10,407'-10,428'(21) 10,448'-10,501' (53) 3/24/2019 324/2019 0.20 PROD2 DRILL WPRT P PUH, PUW 32 k, restart 10,501.0 10,501.0 18:42 18:54 324/2019 3/24/2019 2.00 PROD2 DRILL DRLG P BOBD, 1.88 bpm at 4,900 psi, 10,501.0 10,653.0 18:54 20:54 Diff -940 psi, WHP=94, BHP=3,481, IA=623, OA=655 RotoTrak 10,501'-10,567'(66') 10,633'-10.663'(20) 324/2019 3/242019 0.30 PROD2 DRILL WPRT P Wiper up hole to 9,653', PUW 33 k 10,653.0 9,653.0 20:54 21:12 3/242019 3/24/2019 0.30 PROD2 DRILL WPRT P Wiper back in hole, RIW 7 k 9,653.0 10,653.0 21:12 21:30 3/24/20193/24/2019 0.50 PROD2 DRILL DRLG P BOBD, 1.88 bpm at 4,238 psi, 10,653.0 10,705.0 21:30 22:00 Diff -940 psi, WHP=94, BHP=3,481, IA=623, OA=655 3/242019 3/24/2019 0.20 PROD2 DRILL WPRT P Losses increased from 0.15 bpm - 10,705.0 10,705.0 22:00 22:12 I 0.65 bpm @ 10,694', PUW 35 k, restart Page 13/16 Report Printed: 418/2019 Summary (with Timelog Depths) 3F-01 lipOperations Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log S Ertl Toe Dur (hr) Phew Op Cafe Ad"Oade rimP-T-X Operation Start Depth MKB) End Depth (1") 3/24/2019/2019 3!25/2019 1.80 PROD2 DRILL DRLG P BOBD, 1.88 bpm at 4„922 psi, 10,705.0 10,901.0 22:12 00:00 Di"- 40 psi, WHP=153, BHP=3,474, IA=622, OA=656, encounter another loss zone @ 10,726', MM IN=1.87 bpm, MM OUT=1.53 (losses 0.35 bpm) RotoTrak 10,705'-10,750'(45') 10,765'-10,830'(65') 10,850'-10,901' (51) 3/25/2019 3/25/2019 0.30 PROD2 DRILL DRLG P OBD, 1.88 bpm at 4„922 psi, Diff --940 10,901.0 10,922.0 00:00 00:18 psi, WHP=153, BHP=3,474, IA=622, OA=656, encounterd drop in return rate @ 10,913'and 10,922' 3/25/2019 3/25/2019 0.30 PROD2 DRILL DRLG P BOBD, 1.88 bpm at 4„922 psi, 10,922.0 10,971.5 00:18 00:36 Diff --940 psi, WHP=153, BHP=3,474, IA=622, OA=656 3/25/2019 3/25/2019 0.20 PROD2 DRILL WPRT P 100% losses, PUH, PUW 35 k 10,971.5 10,505.0 00:36 00:48 3/25/2019 3/25/2019 0.30 7ROD2 DRILL WPRT P RBIH, circ 5x5 sweep, down the coil 10,505.0 10,900.0 00:48 01:06 3/25/2019 3/25/2019 0.50 PROD2 DRILL WPRT P Pull wiper up hole to 9,900', 10,900.0 9,900.0 01:06 01:36 3/25/2019 3/25/2019 0.50 PROD2 DRILL WPRT P Wiper back in hole, RIW 10 k 9,900.0 10,971.0 01:36 02:06 3/25/2019 3/25/2019 0.50 PROD2 DR ILL DRLG P BOBD, 1.77 bpm at 4,460 psi, 10,971.0 11,019.0 02:06 02:36 Diff -829, WHP=273, BHP=3,456, IA=608, OA=638 3/25/2019 3/25/2019 0.20 PROD2 DRILL WPRT P Wiper up hole 250', PUW 40 k 11,019.0 11,019.0 02:36 02:48 3/25/2019 3!25/2019 0.55 PROD2 DRILL DRLG P BOBD, 1.77 bpm at 4,460 psi, 11,019.0 11,058.0 02:48 03:21 Diff -829, WHP=273, BHP=3,456, IA=608, OA=638 3!25/2019 3/25/2019 0.35 7052 5 -RI FLL WPRT P ROP increased >180 fph, PUW -32k, 11,058.0 10,837.0 03:21 03:42 pull short wiper up hole Note: Choke Fully closed 10,610'- 10,810', WHP=850 psi, open choke, maintaining 11.0 ppg at the window 3/25/2019 3/25!2019 0.25 PROD2 DRILL WPRT P Wiper back in hole, set down @ 10,837.0 11,058.0 03:42 03:57 1 1 10,929' and 10,960', PUH clean 3/25/2019 3/25/2019 0.60 PROD2 DRILL DRLG P BOBD, 1.78 bpm at 4,500 psi, 11,058.0 11,123.6 03:57 04:33 1 Diff --880, WHP=230, BHP=3475, IA=607, OA=632, 3/25/2019 3/25/2019 1.30 PROD2 DRILL WPRT P Wiper trip to the window, PUW33k 11,123.6 8,266.0 04:33 05:51 WellWorc shows 0.68 bbls of cuttings removed. 3!25/2019 3/25/2019 0.20 PROD2 DRILL DLOG P Tie into the 12Atag for a + 5.5' 8,266.0 8,299.0 05:51 06:03 correction. 3/25/2019 3/25/2019 1.00 PROD2 DRILL TRIP P RBIH to drill marginal returns 1.4 to 8,299.0 11,123.6 06:03 07:03 0.6 bpm returns whie holding 1.9 bpm in. 3/252019 3/25/2019 2.70 PROM DRILL DRLG P RotoTrak 11,123.6 11,400.0 07:03 09:45 CT 4806 psi @ 1.9 bpm in and 1 bpm out. Reduce choke setting to hold 10.9+ EMW Q the window. Retuns fluctuated from 1.4 to 1.5 bpm. CT Wt 8 klbs, WOB 1.2 klbs 11193' PU 38 k IDS, 11253' PU 36 k lbs, 11381 PU 37 k lbs. launch 5x5 sweep in anticipation of TD. ROP over interval = 103 ft(hr Page 14116 Report Printed: 4/8/2019 Operations Summary (with Timelog Depths) 3F-01 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Sint Tme EndT,. Our (h0 Phew Op Coda Activity Cotle Time P -T -X Operation Start Depth (Me) End Dep1h(ryXa) 3/25/2019 3/25/2019 1.20 PROD2 DRILL WPRT P Wiper trip to the window, PUW 33 k 11,400.0 8,015.0 09:45 10:57 PUH chasing sweeps to surface 3/25/2019 3/25/2019 1:90 PROD2 DRILL WPRT P Continue out of hole on wiper tdp. 8,015.0 78.0 10:57 12:51 3/25/2019 3/25/2019 1.40 PROD2 DRILL TRIP P Bump u, set counters, RBIH to 78.0 7,985.0 12:51 1415 measure BHP and confirm TD 3/25/2019 3/25/2019 0.20 PR0D2 DRILL DLOG P Tie into the Kl for a -6' correction 7,985.0 8,006.0 14:15 14:27 3/25/2019 3/25/2019 0.30 PROD2 DRILL DLOG P Park at 8236.05 CTMD and 5871.85 8,006.0 8,236.0 14:27 14:45 TVD, trap 3312 psi, observe pressure. initial 3312 psi 10.84 ppg 1 min 3293 psi 10.78 ppg 2 min 3287 psi 10.76 ppg 5 min 3239 psi 10.61 ppg 10 min 3185 psi 10.43 ppg Bled off fluid to 70 psi well head 13 min 3155 psi 10.33 ppg - BHP did not appear to break trend Bled WH to 371 psi, BHP did break trend 15 min 3126 psi 10.24 ppg 20 min 3083 psi 10.1 ppg 3/25/2019 3/25/2019 120 PROD2 DRILL TRIP P PU Wt 30 k lbs, continue to RIM 8,236.0 11,401.0 14:45 15:57 "` Confirm TD @ 11,401' 3/25/2019 3/25/2019 2.00 PROD2 DRILL DISP P PU Wt 34 k lbs, Complete building 11,401.0 11,395.0 15:57 17:57 weighted lier running pit I(LRP) and pump to bit. 3/25/2019 3/25/2019 1.10 PR0D2 DRILL DISP P PUH laying in 10.5 ppg LRP while 11,395.0 8,178.3 17:57 19:03 painting flags Yellow flag 8178.29' 3/25/2019 3/25/2019 1.80 PROD2 DRILL TRIP P Continue to POOH displacing the well 8,178.3 73.0 19:03 20:51 to 10.5 KW Paint whit flag @ 3/25/2019 3/25/2019 0.80 PR0D2 DRILL PULD P LD BHA #14 over a Used well. 73.0 0.0 20:51 21:39 3/25/2019 3/25/2019 0.40 COMPZ2 DRILL PUTS P Prep floor for running liner 0.0 0.0 21:39 22:03 3/25/2019 3/26/2019 1.95 COMPZ2 DRILL P U T B P PU AL1-0111ner-107 joints of 2- 0.0 1,028.8 22:03 00:00 3/8"4.6 # STL slotted liner under a shorty deployment sieve with a non poised bull nose 3/26/2019 3/26/2019 3.75 COMPZ2 CASING PUTB P PUAL1-011iner-107 joints of 2- 1,028.8 3,164.0 00:00 03:45 3/8"4.6 # STL slotted liner under a shorty deployment sleve with a non ported bull nose - Note: Lost 28 bbl while PU liner 3/26/2019 3/26/2019 0.75 COMPZ2 CASING PULD P PU CoilTrak tools, change out upper 3,164.0 3,209.4 03:45 04:30 checks, change out pac-offs, surface lest tools (good -test) 3/26/2019 3/26/2019 1.00 COMPZ2 CASING RUNL P RIM, with Lt -01 liner, 107 jts of slotted_ 3,209.4 8,100.0 04:30 05:30 liner, shorty deployment p yment sleeve, and non -ported bullnose. 3126/2019 3/2612019 0.15 COMPZ2 CASING RUNL P Correct to the EOP flag, minus 10.0' 8,100.0 8,100.0 05:30 05:39 3/26/2019 3/26/2619 1.50 COMPZ2 CASING RUNL P Continue IH with liner assembly 8,100.0 10,876.0 05:39 07:09 3/26/2019 3/26/2019 1.15 COMPZ2 CASING RUNL P Work liner to bottom, PUW 41-44k, tag 10,876.0 11,401.0 07:09 08:18 bottom, PUH, tag bottom again Page 15116 Report Printed: 4/8/2019 a . Operations Summary (with Timelog Depths) 3F-01 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Tme End Time our (hr) Phase Op Code Activly Code TNne P -T-% Operation Stan Depth (ORB) End Depth (WB) 3!26/2019 3/26/2019 0.30 COMPZ2 CASING RUNL P Bring pump online 1.6 bpm, 990 psi 11,401.0 8,214.7 08:18 08:36 diff, PUW 30 k, remove liner length from counters, PUH for static. 3/26/2019 3126/2019 0.50 COMPZ2 WHDBOP USPP "' Note: SBP @ 8,214.7', Sensor 8,214.7 8,185.2 08:36 09:06 depth 8,200.3' CTMD, 5880.43' TVD, 10.41 ppg, 3179 psi, " LRS on location, PJSM, rig up air and confirm line is free, rig up to customer line and PT to 4,500 psi 3/26/2019 3/26/2019 1.10 DEMOB WHDBOP DISP P Line up to circulate SW down the coil 8,185.2 8,185.0 09:06 -3/-26/201 10:12 9 3/26/2019 1.00 DEMOB WHDBOP TRIP P POOH, ,while displacing well 8,185.0 44.2 10:12 11:12 3/26/2019 3/26/2019 1.45 DEMOB WHDBOP FRZP P At surface, spaceout, PUD & LD 44.2 0.0 11.12 12:39 setting tools. Note: Final Tubing Pressure 372 psi, SW 8,185'-2,500', Deisel 2,500'-0' 3/26/2019 3/2612019 1.50 DEMOB WHDBOP RURD P Install Nozzle, stab back on with INJH, 0.0 0.0 12:39 14:09 jet stack 3/26/2019 3/26/2019 0.75 DEMOB WHDBOP RURD P "' Note: Wellhead bolts loose torque —C) 0 0.0 14:09 14:54 up tree bolts 3/26/2019 3/26/2019 3.10 DEMOB WHDBOP RURD p7— RDMO, work the rig move checklist 0.0 0.0 14:54 18:00 3/26/2019 3/26/2019 DEMOB WHDBOP RURD P Crew change, Comtme working Rid —0 0 18:00 18:00 down chaeck list, Nipple down stack and secure for transport, Pits offloaded, Putz rig down. Blow down steam. RIG RELESE 20:00 Page 16116 Report Printed: 4/3/2019 r r' APR 2 9 2019 ConocoPhillips AOGCC ConocoPhillips Alaska Inc_Kuparuk Kuparuk River Unit Kuparuk 3F Pad 3F -01L1-01 50-029-21446-61 Baker Hughes INTEQ BATER GE company UGHES a Definitive Survey Report 22 April, 2019 ` ConocoPhillips RA(ER ConocoPhilli s p Definitive Survey Report {OGRE$ Company: ConocoPhillips Alaska Inc_Kuparuk Local Co-ordinate Reference: Well 3F-01 Project: Kuparuk River Unit TVD Reference: 3F-01 @ 93.00usft (3F-01) Site: Kuparuk 3F Pad MD Reference: 3F-01 @ 93.00usft (3F-01) Well: 3F-01 North Reference: True Wellbore: 3F-01 L1-01 Survey Calculation Method: Minimum Curvature Design: 3F-0111-01 Database: EDT 14 Alaska Production Project Kuparuk River Unit, North Slope Alaska, United States Map System: US State Plane 1927 (Exact solution) System Datum: Mean Sea Level Geo Datum: NAD 1927 (NADCON CONUS) Using Well Reference Point Map Zone: Alaska Zone 04 - Using geodetic scale factor Well 3F-01 Well Position +N/ -S 0.00 usft Northing: 5,985,734.98usft Latitude: 70° 22'20,086 N +EI -W 0.00 usft Easting: 508,662.35usft Longitude: 149° 55'46.549 W Position Uncertainty 0.00 usft Wellhead Elevation: usft Ground Level: 0.00 usft Wellbore 3F-01 L1-01 Magnetics Model Name Sample Date Declination Dip Angle Field Strength (') (1) (nT) BGGM2018 4/1/2019 16.61 80.87 57,419 Design 3F-01 1-1-01 Audit Notes: Version: 1.0 Phase: ACTUAL Tie On Depth: 9,000.93 Vertical Section: Depth From (TVD) +N/.S +E/ -W Direction (usft) (usft) (usft) V) 93.00 0.00 0.00 180.00 4/222019 1:07:OOPM Page 2 COMPASS 5000.14 Build 85D ConocoPhillips aA FJ2 ConocoPhillips Definitive Survey Report t�ixS Company: ConocoPhillips Alaska Inc_Kuparuk Local Co-ordinate Reference: Well 3F-01 1 Project: Kupamk River Unit ND Reference: 3F-01 @ 93.00usft (3F-01) Site: Kuparuk 3F Pad MD Reference: 3F-01 @ 93.00usft (3F-01) Well: 3F-01 North Reference: True 9 Wellbore: 3F-0111-01 Survey Calculation Method: Minimum Curvature Design: 31F-011-1-01 Database: EDT 14 Alaska Production Survey Program Date From i To Survey Survey, (usft) (usft) Survey (Wellbore) Tool Name Description Start Date End Date 100.00 8,200.00 3F-01 (3F-01) GCT -MS Schlumberger GCT mullishot 8/18/2000 - 8,245.50 8,320.79 3F -01L7 MWD INC (3F-01L7) MWD-INC_ONLY MWD -INC _ONLY -FILLER 3/23/2019 3/23/2019 8,352.20 9,000.93 3F -01L1 MWD(3F-01L1) MWD MWD - Standard 3/24/2019 3/24/2019 j 9,026.00 9,147.37 3F-0111-01 MWD -INC (3F-0117-01) MWD -INC ONLY MWD-INC_ONLY-FILLER 3/25/2019 3/25/2019 it 9,178.92 11,355.08 3F-0111-01 MWD (3F-0111-01) MWD MWD - Standard 3/25/2019 3/2612019 Survey MD Inc AN ND NDSB +NIS +FJ4N Map Map DES Vertical i (usft) (°) (°) (usft) (usft) (usft) (usft) Northing Eaaftng (•)100') Section Survey Tool Name Annotation 01) (ft) (ft) 9,000.93 97.79 175.73 5,855.28 5,762.28 4,491.47 4,025.88 5,981,248.62 512,693.03 8.03 4,491.47 MWD (3) TIP 9,026.00 98.30 177.56 5,851.77 5,758.77 -4,516.25 4,027.34 5,981,223.84 512,694.51 7.51 4,516.25 MWD-INC_ONLY(4) KOP 9,057.49 102.41 175.75 5,846.11 5,753.11 4,547.17 4,029.14 5,981,192.93 512,696.35 14.22 4.547.17 MWD -INC _ ONLY (4) Interpolated Azimuth 9,087.48 100.98 174.04 5,840.03 5,747.03 -0,576.42 4,031.75 5,981,163.69 512,698.99 7.34 4,576.42 MWD -INC _ONLY(4) Interpolated Azimuth 9,117.49 101.19 172.32 5,834.26 5,741.26 4,605.66 4,035.25 5,981,134.45 512,702.53 5.67 4.605.66 MWD -INC -ONLY (4) Interpolated Azimuth 9,147.37 100.31 170.61 5,828.69 5,735.69 -4,634.69 4,039.61 5,981,105.43 512,706.92 6.35 4,634.69 MWD -INC ONLY(4) Interpolated Azimuth 9,178.92 98.47 168.81 5,823.54 5,730.54 -4,665.31 4,045.17 5,981,074.82 512,712.51 8.11 4,665.31 MWD (5) 9,207.20 96.52 166.13 5,819.85 5,726.85 -4,692.68 4,051.25 5,981,047.46 512,718.63 11.65 4,692.68 MWD (5) 9,237.61 95.97 165.12 5,816.54 5,723.54 4,721.96 4,058.76 5,981,018.19 512,726.16 3.76 4,721.96 MWD (5) 9,267.13 95.23 166.73 5,813.66 5,720.66 4,750.46 4,065.90 5,980,989.71 512,733.34 5.98 4,750.46 MWD (5) 9,297.15 94.64 167.56 5,811.08 5,718.08 4,779.62 4,072.56 5,980,960.56 512,740.03 3.38 4,779.62 MWD (5) 9,330.11 95.13 170.67 5,808.27 5,715.27 -0,811.86 4,078.76 5,980,928.32 512,746.27 9.52 4,811.86 MWD (5) 9,360.81 96.06 173.32 5,805.28 5,712.28 1,842.11 4,083.01 5,980,898.08 512,750.55 9.11 4,842.11 MM (5) 9,390.36 95.88 174.52 5,802.21 5,709.21 -4,871.34 4,086.13 5,980,868.86 512,753.70 4.06 4,871.34 MM (5) 9,419.89 95.72 176.16 5,799.22 5,706.22 -4,900.62 4,088.51 5,980,839.59 512,756.12 5.55 4,900.62 MIND (5) 9,450.03 92.70 176.95 5,797.01 5,704.01 -4,930.62 4,090.32 5,980,809.59 512,757.96 10.36 4,930.62 MWD (5) 9,490.49 93.07 179.43 5,794.97 5,701.97 1,971.00 4,091.59 5,980,769.21 512,759.28 6.19 4,971.00 MWD (5) 9,52062 90.40 180.90 5,794.06 5,701.06 -5.001.12 4,091.51 5,98D,739.10 512,759.23 10.11 5,001.12 MWD (5) 9,549.89 88.28 18177 5,794.40 5,70140 -5,03037 4090.83 5,980,709.85 512,758.58 7.83 5,030.37 MWD (5) 4222019 1:07:OOPM Page 3 COMPASS 5000.14 Build 85D ConocoPhillips BAER}t kIUGHE9 ConocoPhillips Definitive Survey Report Company: ConocoPhillips Alaska Inc_Kuparuk Local Co-ordinate Reference: Well 3F-01 Project: Kuparuk River Unit TVD Reference: 31F-01 @ 93.00usft (31F-01) Site: Kuparuk 3F Pad MD Reference: 3F-01 @ 93.00usft (3F-01) Well: 3F-01 North Reference: True Wellbore: 3F-0111-01 Survey Calculation Method: Minimum Curvature Design: 3F-01 L1-01 Database: EDT 14 Alaska Production Survey MD Inc Azi TVD NDSS +N13 +E/-WNorthing Map Map DES Vertical (usft) (1) V) (usft) (usft) (usR) Neff) Casting (°/too,) Section Survey Tool Name (ft) (ft) (ft) 9,589.72 88.65 182.89 5,795.47 5,702.47 -5,070.16 4,089.21 5,980,670.07 512,757.01 2.96 5,070.16 MWD (5) 9,610.17 88.03 182.70 5,796.06 5,703.06 -5,090.57 4,088.21 5,980,649.65 512,756.04 3.17 5,090.57 MWD (5) 9,639.97 88.12 182.99 5,797.06 5,704.8 -5,120.32 4,086.73 5,980,619.90 512,754.60 1.02 5,120.32 MWD (5) 9,670.49 88.00 182.53 5,798.09 5,705.09 -5,150.79 4,085.26 5,980,589.44 512,753.16 1.56 5,150.79 MWD (5) 9,700.92 87.27 181.16 5,799.35 5,706.35 -5,181.17 4,084.28 5,980,559.05 512,752.22 5.10 5,181.17 MWD (5) 9,731.23 85.88 179.91 5,801.16 5,708.16 -5,211.43 4,084.00 5,980,528.80 512,751.97 6,16 5,211.43 MWD (5) 9,761.10 86.31 179.86 5,803.19 5,710.19 -5,241.23 4,084.06 5,980,499.00 512,752.06 1.45 5,241.23 MWD (5) 9,781.25 86,87 180.49 5,804.39 5,711.39 -5,261.34 4,084.00 5,980,478.89 512,752.03 4.18 5,261.34 MWD(5) 9,810.69 86.34 180.04 5,806.13 5,713.13 -5,290.73 4,083.86 5,980,449.51 512,751.92 2.36 5,290.73 MWD (5) 9,832.47 87.14 179.75 5,807.37 5,714.37 -5,312.47 4,083.90 5,980,427.77 512,751.99 3.91 5,312.47 MWD (5) 9,862.24 87.73 179.05 5,808.71 5,715.71 -5,342.21 4,084.21 5,980,398.03 512,752.34 3.07 5,342.21 MWD (5) 9,892.08 86.66 178.44 5,810.16 5,717.16 -5,372.01 4,084.87 5,980,368.24 512,753.02 4.07 5,372.01 MWD (5) 9,916.82 87.33 178.21 5,811.45 5,718.45 5,396.71 4,085.59 5,980,343.55 512,753.77 2.79 5,396.71 MWD (5) 9,945.89 91.84 179.67 5,811.66 5,718.66 5,425.76 4,086.13 5,980,314.49 512,754.34 16.31 5,425.76 MWD (5) 9,975.37 91.47 178.89 5,810.81 5,717.81 -5,455.23 4,086.50 5,980,285.03 512,754.75 2.93 5,455.23 MWD (5) 10,005.24 92.92 178.24 5,809.67 5,716.67 -5,485.06 4,087.24 5,980,255.20 512,755.53 5.32 5,485.06 MWD (5) 10,035.72 94.37 178.07 5,807.73 5,714.73 -5,515.47 4,088.22 5,980,224.80 512,75655 4,79 5,515.47 MWD (5) 10,065.29 94.24 177.36 5,805.51 5,712.51 -5,544.93 4,089.40 5,980,195.34 512,757,75 2.43 5,544.93 MWD (5) 10,095.17 94.55 177.32 5,803.22 5,710.22 -5,574.69 4,090.78 5,980,165.59 512,759.17 1.05 5,574.69 MWD (5) 10,125.09 94.82 176.94 5,800.78 5,707.78 -5,604.47 4,092.28 5,960,135.81 512,760.70 1.55 5,604.47 MWD (5) 10,154.81 94.63 178.17 5,798.33 5,705,33 -5,634.06 4,093.54 5,980,106.22 512,762.00 4.17 5,634.06 MWD (5) 10,185.26 93.99 178.08 5,796.04 5,703.04 -5,664.41 4,094.53 5,980,075.88 512,763.03 2.12 5,664.41 MWD (5) 10,215.34 92.33 177.63 5,794.38 5,701.38 5,694.42 4,095.66 5,980,045.87 512,764.18 5.72 5,694.42 MWD(5) 10,245.27 92.58 179.66 5,793.10 5,700.10 -5,724.32 4,096.36 5,96D,015.98 512,764.92 6.89 5,724.32 MWD(5) 10,275.31 91.20 179.93 5,792.11 5,699.11 -5,754.34 4,096.46 5,979,9a5.95 512,765.06 4.67 5,754.34 MWD (5) 10,305.75 91.04 180.93 5,791.51 5,698.51 -5,784.77 4,096.23 5,979,955.53 512,764.86 3.33 5,784.77 MWD (5) 10,335.80 90.80 179.97 5,791.03 5,698.03 -5,814.82 4,096.00 5,979,925.49 512,764.66 3.29 5,814.82 MWD (5) 10,365.67 91.54 178.43 5,790.42 5,697.42 -5,844.68 4,096.41 5,979,895.63 512,765.11 5.72 5,844.68 MWD (5) 10,395.59 91.53 178.27 5,789.62 5,696.62 -5,874.57 4,097.27 5,979,865.74 512,766.01 0.54 5,874.57 MWD (5) 10,420.59 92.03 177.87 5,788.84 5,695.84 -5,899.55 4,098.12 5,979,840.77 512,766.88 2.56 5,899.55 MWD (5) 10,450.27 90.00 178.22 5,788.32 5,695.32 -5,929.20 4,099.13 5.979.811.12 512.767.93 6.94 5,929.20 MWD (5) Annotation 422/2019 1:07.00PM Page 4 COMPASS 5000.14 Build 850 ConocoPhillips ConocoPhillips eEjGRHES. a Definitive Survey Report Company: ConocoPhillips Alaska lnc_Kuparuk Local Co-ordinate Reference: Well 3F-01 Project: Kuparuk River Unit ND Reference: 3F-01 @ 93.00usfl (3F-01) Site: Kuparuk 3F Pad MD Reference: 3F-01 @ 93.00usi1 (3F-01) Well: 3F-01 North Reference: Two Wellbore: 3F-011.1-01 Survey Calculation Method: Minimum Curvature Design: 31F-01 Li -01 Database: EDT 14 Alaska Production Survey MD Inc Azl ND NDSS +WS +iJ-W Map Map DLS Vertical (usft) (°) V) (usft) (usft) (usft) (usft) Northing Easting ("1100.) Section Survey Tool Name Annotation Ift) (ft)(ft) 10,479.80 89.60 177.04 5,788.42 5,695.42 -5,958.71 4,100.35 5,979,781.62 512,769.18 4.22 5,958.71 MWD (5) 10,511.02 91.14 177.50 5,788.22 5,695.22 -5,989.89 4,101.84 5,979,750.44 512,770.70 5.15 5,989.89 MWD (5) 10,540.10 91.11 177.79 5,787.65 5,694.65 -0,018.94 4,103.03 5,979,721.39 512,771.93 1.00 6,018.94 MWD (5) 10,569.70 92.09 179.21 5,786.82 5,693.82 -6,048.52 4,103.81 5,979,691.82 512,772.74 5.83 6,048.52 MWO(5) 10,599.92 91.14 180.49 5,785.97 5,692.97 -6,078.72 4,103.88 5,979,661.62 512,772.86 5.27 6,078.72 MWD (5) 10,630.51 88.68 179.73 5,786.02 5,693.02 -6,109.31 4,103.83 5,979,631.03 512,772.83 8.42 6,109.31 MWD (5) i 10,660.63 88.48 180.98 5,786.77 5,693.77 -6,139.42 4,103.64 5,979,600.93 512,772.69 4.15 6,139.42 MWD (5) 10.689.98 88.83 180.133 5,787.48 5,894.48 -6,168.74 4,103.39 5,979,571.61 512,772.47 3.41 6,168.74 MVD(5) 10,719.68 87.88 179.50 5,788.32 5,695.32 -6,198.45 4,103.51 5,979,541.90 512,772.82 3.66 6,198.45 MWD (5) 10,750.63 87.33 178.78 5,789.61 5,696.61 -6,229.37 4,103.98 5,979,510.99 512,773.12 2.93 6,229.37 MWD (5) 10,780.32 85.97 179.42 5,791.35 5,698.35 -6,259.00 4,104.44 5,979,481.36 512,773.62 5.06 6,259.00 MWD (5) 10,810.17 86.62 180.53 5,793.27 5,700.27 -6,288.79 4,104.46 5,979,451.57 512,773.67 4.30 6,288.79 MWD (5) 10,840.36 86.65 180.54 5,795.05 5,702.05 -6,318.92 4,104.17 5,979,421.44 512,773.42 0.10 6,318.92 MWD (5) 10,870.43 86.65 178.95 5,796.80 5,703.80 -6,348.94 4,104.31 5,979,391.43 512,773.59 5.28 6,348.94 MWD (5) 10,901.83 88.34 179.66 5,798.18 5,705.18 -6,380.31 4,104.69 5,979,360.06 512,774.01 5.84 6,380.31 MWD (5) 10,930.40 89.69 179.74 5,798.67 5,705.67 -6,408.87 4,104.84 5,979,331.50 512,774.19 4.73 6,408.87 MWD (5) 10,960.43 88.99 178.95 5,799.01 5,706.01 -6,438.90 4,105.18 5,979,301.48 512,774.57 3.51 6,438.90 MWD (5) 10,990.17 88.62 177.59 5,799.63 5,706.63 -6,488.62 4,106.08 5,979,271.76 512,775.50 4.74 6,468.62 MWD (5) 11,019.60 88.31 179.16 5,800.42 5,707.42 -6,498.02 4,106.91 5,979,242.36 512,776.36 5.50 6,498.02 MWD (5) 11,051.29 88.46 180.36 5,801.31 5,708.31 -6,529.70 4,107.03 5,979,210.69 512,776.53 3.75 6,529.70 MWD (5) 11,080.79 89.54 181.76 5,801.83 5,708.83 -6,559.19 4,106.49 5,979,181.20 512,776.02 5.99 6,559.19 MWD (5) 11,110.15 88.80 181.74 5,802.25 5,709.26 41,588.53 4,105.59 5,979,151.86 512,775.15 2.52 6,588.53 MWD (5) 11,140.08 89.08 183.29 5,802.81 5,709.81 8,618.43 4,104.28 5,979,121.97 512,773.88 5.26 6,618.43 MWD (5) 11,170.13 89.75 184.06 5,8D3.12 5,710.12 $,648.42 4,102.35 5,979,091.98 512,771.98 3.40 6,648.42 MWD (5) 11,200.22 87.70 183.57 5,8133.79 5,710.79 -6,678.43 4,100.35 5,979,061.97 512,770.02 7.00 8,678.43 MWD (5) 11230.06 87.39 182.96 5,805.06 5,712.06 -6,708.19 4,098.65 5,979,032.20 512,768.35 2.29 6,708.19 MWO(5) 11,260.79 87.11 183.71 5,806.54 5,713.54 -6,738.84 4,096.87 5,979,001.56 512,766.60 2.60 6,738.84 MWO(5) 11,290.15 88.80 184.09 5,807.59 5,714.59 -6,766.11 4,094.87 5,978,972.29 512,764.64 5.90 6,768.11 MWD (5) 11,322.89 90.34 183.90 5,607.83 5,714.83 -6,800.77 4,092.59 5,978,939.63 512,762.40 4.74 6,800.77 MND (5) 11355.08 92.21 183.42 5,807.11 5,714.11 -6,832.88 4,090.54 5,978,907.52 512,760.38 6.00 6,832.88 MWD (5) 11,401.00 • 92.21 183.42 5,805.34 5,712.34 -6878.69 4,087.80 5,978,861.72 512,757.70 0.00 6,878.69 PROJECTEDIOTD 41222019 1:07:OOPM Page 5 COMPASS 5000.14 Build 85D ConocoPhillips BA ER,,, s ConocoPhilli -� .,- ConocoPhillips Definitive Survey Report Company: ConocoPhillips Alaska Inc_ Kuparuk Project: Kuparuk River Unit Site: Kuparuk 3F Pad Well: 3F-01 Wellbore: 3F-01 L1-01 Design: 3F-0111-01 Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Database: Well 3F-01 3F-01 @ 93.00usft(3F-01) 3F-01 @ 93.00usft (3F-01) True Minimum Curvature EDT 14 Alaska Production 4222019 1: 07: OOPM Page 6 COMPASS 5000.14 Build 85D BAN(ER UGHES PRINT DISTRIBUTION LIST a GE company COMPANY ConocoPhillips Alaska, Inc. WELL NAME 317-010-01 FIELD Greater Kuparuk Area COUNTY North Slope Borough BHI DISTRICT Alaska AUTHORIZED BY Patrick Rider EMAIL Patrick.RiderCo�bakerhuohes.com X1903' 30 65 9 sign and return one copy of this transmittal form to: coPhillips Alaska, Inc. Osterkamp (WNS Petroleum Technician) 3 Street. orage, Alaska 99510 LOG TYPE GR - RES LOG DATE March 25, 2019 TODAYS DATE April 23, 2019 Revision STATUS Final Replacement: No Details: COMPANY ADDRESS (FEDEX WILL NOT DELIVER TO P.O. BOX) PERSON ATTENTION V 1 BP North Slope. EOA, PBOC, PRB-20 (Office 109) D&G WO Wells Admin Brenda Glassmaker & Peggy O'Neill 900 E. Benson Blvd. Anchorage, Alaska 99508 2 ConocoPhillips Alaska Inc. Attn: Ricky Elgarico ATO 708 700 G Street Anchorage, AK 99510 3 Exxon Mobil, Alaska Attn: Lynda M. Vaskell and/or Leonardo Elias 3201 C Street, Suite 505 Anchorage, AK 99503 4 State of Alaska -AOGCC Attn: Natural Resources Technician 11 333 W. 7th Ave, Suite 100 Anchorage, Alaska 99501 5 DNR - Division ofOil & Gas ... Attn: Resource Evaluation 550 West 7th Avenue, Suite 1100 IA-_nchorage, Alaska 99501 L` Stamp "confidential" on all material deliver to DNR 6 BP Exploration (Alaska) Inc. Petrotechnical Data Center, IR24 900 E. Benson Blvd. Anchorage, Alaska 99508 TOTALS FOR THIS PAGE: Requested by: -- FIELD I FINAL CD/DVDFINAL PRELIM LOGS (las, dlis, PDF, META, I SURVEY REPORT LOGS CGM, Final Surveys) (Compass) # OF PRINTSour PRIN # OF COPIES I#OFCOPIES # OF COPIES 4 4 !1 4 4 8 RECEIVED 0 1 2 0 0 THE STATE ALASKA GOVERNOR MIKE DUNLEAVY James Ohlinger Staff CTD Engineer ConocoPhillips Alaska, Inc. PO Box 100360 Anchorage, AK 99510-0360 r Alaska Oil and Gas Conservation Commission Re: Kuparuk River Field, Kuparuk River Oil Pool, KRU 317-01L1-01 ConocoPhillips Alaska, Inc. Permit to Drill Number: 219-037 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 v .00gcc.alaska.gov Surface Location: 89' FNL, 162' FWL, SEC. 29, T12N, R9E, UM Bottomhole Location: 1793' FNL, 4130' FWL, SEC. 32, TI 2N, R9E, UM Dear Mr. Ohlinger: Enclosed is the approved application for the permit to drill the above referenced development well. The permit is for a new wellbore segment of existing well Permit 185-225, API 50-029-21446-00- 00. Production should continue to be reported as a function of the original API number stated above. Per Statute AS 31.05.030(d)(2)(B) and Regulation 20 AAC 25.071, composite curves for well logs run must be submitted to the AOGCC within 90 days after completion, suspension or abandonment of this well. This permit to drill does not exempt you from obtaining additional permits or an approval required by law from other governmental agencies and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the AOGCC reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the AOGCC specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or an AOGCC order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. Sincerely, Jessie L. Chmielowski Commissioner DATED this )I day of March, 2019. STATE OF ALASKA / aSKA OIL AND GAS CONSERVATION COIL SSION NAR J 6 2019 PERMIT TO DRILL 20 AAC 25.005 1 a. Type of Work: - 1 1b. Proposed Well Class: Exploratory - Gas ❑ Service - WAG ❑ Service - Disp ❑ 1c. Specilpi OMI d s for: Drill ❑ Lateral ❑Q Stratigraphic Test ❑ Development - Oil ❑� - Service - Winj ❑ Single Zone ❑' - Coalbed Gas ❑ Gas Hydrates ❑ Redrill ❑ Reentry ❑ I Exploratory -Oil ❑ Development - Gas ❑ Service - Supply ❑ Multiple Zone ❑ Geothermal ❑ Shale Gas ❑ 2. Operator Name: 5. Bond: Blanket Q . Single Well ❑ 11. Well Name and Number: ConocoPhillips Alaska, Inc. Bond No. 5952180 KRU 3F -01L1-01 3. Address: 6. Proposed Depth: 12. Field/Pool(s): P.O. Box 100360 Anchorage, AK 99510-0360 MD: 11520' TVD: 5752' Kuparuk River Field / Kuparuk River Oil Pool 4a. Location of Well (Governmental Section): 7. Property Designation: Surface: 89' FNL, 162' FWL, Sec 29, T12N, R9E, UM ADL 25643 ALK 2574 Top of Productive Horizon: 8. DNR Approval Number: 13. Approximate Spud Date: 4681' FNL, 4174' FWL, Sec 29, T12N, R9E, UM LONS 83-129 3/19/2019 9. Acres in Property: 14. Distance to Nearest Property: Total Depth: 1793' FNL, 4130' FWL, Sec 32, T12N, R9E, UM 2560 23,400' 4b. Location of Well (State Base Plane Coordinates - NAD 27): 10. KB Elevation above MSL (ft): 93' • 15. Distance to Nearest Well Open Surface: x- 508662 ` y- 5985735 ` Zone- 4 GL / BF Elevation above MSL (ft): 52' to Same Pool: 283',2U-13 16. Deviated wells: Kickoff depth: 9100 • feet 17. Maximum Potential Pressures in psig (see 20 AAC 25.035) Maximum Hole Angle: 107 degrees Downhole: 3302 • Surface: 2722 - 18. Casing Program: Specifications Top - Setting Depth - Bottom Cement Quantity, c.f. or sacks Hole Casing Weight Grade Coupling Length MD TVD MD TVD (including stage data) 3" 2-3/8" 4.7# L-80 ST -L 2420' 8243' 5910' 11520' 5752' Slotted Liner 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): 8730' 6245' N/A 8646' 6187' N/A Casing Length Size Cement Volume MD TVD Conductor/Structural 80' 16" 348 sx AS II 115' 115' Surface 3873' 9-5/8" 1020 sx PF "E", 400 sx PF "C" 3908' 3068' Top Job performed w/50 sx PF "C" Production 8750' 7" 325 sx G 8784' 6259' Perforation Depth MD (ft): 8066'-8219', 8417'-8423', 8428'-8468', Perforation Depth TVD (ft): 5787'-5893', 6030'-6034', 6037'-6065', 6085'-6105' 8498'-8526' Hydraulic Fracture planned? Yes ❑ No ❑Q Sketch 20. Attachments: Property Plat ❑ B Drillingv. Depth lot B Shallow Hazard Analysi's e✓ B DiveBOP rter Sketch Report Drilling Fluid Program 20 AAC 25.050 requirements 21. Verbal Approval: Commission Representative: Date 22. 1 hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Contact Name: Ryan McLaughl' Authorized Name: James Ohlinger Contact Email: an.rinclaU hlin CO .Cool Authorized Title: Staff CTD Engineer Contact Phone: 907-265-6218 �• Authorized Signature: Date: 365/-_/9P Commission Use Only Permit to Drill zz API Number: Permit Approval See cover letter for other Number: =J 7 50-r) — Z� Y' fp —(, (--UU I 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: • Samples req'd: Yes ❑ No[v� Mud log req'd: Yes E] No R/ Yes [Y No El Directional Yes Fit No El ���!/ ' �! ✓! fi r �- z cJ jy�'Sg measures: svy req'd: Sing Yes ❑ NoL Inclination -only svy req'd: Yes ❑ No[r e- xcerpOn req'd: C f b Ofi� C 2S. D l5 C e Post initial injection MIT req'd: Yes ❑ No["� IS 9rgv trd fo a/!or 1 tG1t k/`ckC,FF point i1r, be aP,v )POir) t alv-7.77i the P a Y-?" f i��rQ,1 - APPROVED BY 3/ It 1� I Approved by: COMMISSIONER THE COMMISSION Date: (11 L. / /''� n �1 Submit Form and Form 10-401 Revised 5/2017 Th s permit is valid f{r a4�g6n�h� ip d approval per 20 AAC 25.005(8) / Attachments in Duplicate 1i %9'!Y ConocoPhillips Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 March 5, 2019 Commissioner - State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Dear Commissioner: ConocoPhillips Alaska, Inc. hereby submits applications for permits to drill two laterals out of the KRU 3F-01 (PTD# 185-225) using the coiled tubing drilling rig, Nabors CDR3-AC. CTD operations are scheduled to begin on March 19th, 2019. The objective will be to drill two laterals, KRU 3F- 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 3F-01 L1 & 3F-01 L1-01 - Detailed Summary of Operations - Directional Plans for 3F-01 L1 & 3F-01 L1-01 - Current wellbore schematic - Proposed CTD schematic If you have any questions or require additional information, please contact me at 907-265-6218. Sincerely, Ryan McLaughlin Coiled Tubing Drilling Engineer ConocoPhillips Alaska Kuparuk CTD Lateral 3F-011-1, 3F-011-1-01 Application for Permit to Drill Document 1. Well Name and Classification........................................................................................................ 2 (Requirements of 20 AAC 25.005(0 and 20 AAC 25.005(b))........................................................................................................................2 2. Location Summary .......................................................................................................................... 2 (Requirements of 20 AAC 25.005(c)(2)).................................................................................................................................................. 2 3. Blowout Prevention Equipment Information................................................................................. 2 (Requirements of 20 AAC 25.005(c)(3)).................................................................................................................................................2 4. Drilling Hazards Information and Reservoir Pressure.................................................................. 2 (Requirements of 20 AAC 25.005(c)(4))..................................................................................................................................................2 5. Procedure for Conducting Formation Integrity tests................................................................... 2 (Requirements of 20 AAC 25.005(c)(5))..................................................................................................................................................2 6. Casing and Cementing Program.................................................................................................... 3 (Requirements of 20 AAC 25.005(c)(5))...................................................................................................................................................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)(5))..................................................................................................................................................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 ...................... (Requirements of 20 AAC 25.005(c)(11)). ........................ .............................................................. 4 ...................................................................................... 4 12. Evidence of Bonding...................................................................................................................... 4 (Requirements of 20 AAC 25.005(c)(12))................................................................................................................................................4 13. Proposed Drilling Program.............................................................................................................4 (Requirements of 20 AAC 25.005(c)(13))................................................................................................................................................4 Summaryof Operations...................................................................................................................................................4 LinerRunning...................................................................................................................................................................5 14. Disposal of Drilling Mud and Cuttings.......................................................................................... 5 (Requirements of 20 AAC 25.005(c)(14))................................................................................................................................................ 5 15. Directional Plans for Intentionally Deviated Wells....................................................................... 5 (Requirements of 20 AAC 25.050(b))......................................................................................................................................................5 16. Attachments....................................................................................................................................6 Attachment 1: Directional Plans for 3F-011-1, 3F-0111-01..............................................................................................6 Attachment 2: Current Well Schematic for 3F-01 L1, 3F-01 L1-01....................................................................................6 Attachment 3: Proposed Well Schematic for 3F-011-1, 3F-011-1-01................................................................................6 Page 1 of 6 March 5, 2019 PTD Application: 3F-011-1, 3F-011-1-01 1. Well Name and Classification (Requirements of 20 AAC 25.005(1) and 20 AAC 25.005(b)) The proposed laterals described in this document are 3F-011-1 & 3F-011-1-01. The 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 form for surface and subsurface coordinates of 3F-01 L1 & 3F-01 L1-01. . 3. Blowout Prevention Equipment Information (Requirements of 20 AAC 25.005 (c)(3)) Please reference blowout prevention (BOP) schematics on file with the Commission for Nabors CDR3-AC. BOP equipment is as required per 20 AAC 25.036 for thru-tubing drilling operations. - Pipe rams, blind rams and the CT pack off will be pressure tested to 250 psi and to 3,500 psi. Using the maximum formation pressure in the area of 3,302 psi in 3F-04 (i.e. 10.6 ppg EMW), the maximum potential surface pressure in 3F-01, assuming a gas gradient of 0.1 psi/ft, would be 2722 psi. See the "Drilling Hazards Information and Reservoir Pressure" section for more details. - The annular preventer will be tested to 250 psi and 2,500 psi. 4. Drilling Hazards Information and Reservoir Pressure (Requirements of 20 AAC 25.005 (c)(4)) Reservoir Pressure and Maximum Downhole Pressure (Requirements of 20 AAC 25.005 (c)(4)(a)) The formation pressure in KRU 3F-01 was measured to be 2596 psi (8.5 ppg EMW) on 10/7/2018. The maximum downhole pressure in the 3F-01 vicinity is the 3F-04 at 3302 psi (10.6 ppg EMW) measured on 11/17/2014. --- Potential Gas Zones (Requirements of 20 AAC 25.005 (c)(4)(b)) The offset injection wells to 3F-01 have injected gas, so there is a possibility of encountering free gas while drilling the 3F-01 L1 and 3F-01 L1-01 laterals. If gas is detected in the returns the contaminated mud can be diverted to a storage tank away from the rig. Potential Causes of Hole Problems (Requirements of 20 AAC 25.005 (c)(4)(c)) The major expected risk of hole problems in the 3F-01 L1 and 3F-01 L1-01 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 3F-01 L1 & 3F-01 L1-01 laterals will be drilled under 20 AAC 25.036 for thru-tubing drilling operations so a formation integrity test is not required. Page 2 of 6 March 5, 2019 PTD Application: 3F-011-1, 3F-011-1-01 6. Casing and Cementing Program (Requirements of 20 AAC 25.005(c)(6)) New Completion Details Lateral Name Liner Top Liner Btm Liner Top Liner Btm Liner Details Btm MD MD MD TVDSS TVDSS Conductor 3F-01LI 9100' 11,500' 5744' 5698' 2-3/8", 4.7#, L-80, ST -L slotted liner; 0' 115' 1640 670 Surface aluminum billet on to 3F -01L1-01 8243' • 11,520' 5817' 5659' 2-3/8"1 4.7#, L-80, ST -L slotted liner; 3062' 3520 2020 Production 7" shorty deployment sleeve on to Existing Casing/Liner Information Category OD Weight f Grade Connection Top MD Btm MD Top TVD Btm TVD Burst psi Collapse psi Conductor 16" 62.5 H-40 Welded 0' 115' 0' 115' 1640 670 Surface 9-5/8" 36.0 J-55 BTC 0' 3971' 0' 3062' 3520 2020 Production 7" 26.0 J-55 BTC 0' 8646' 0' 3187' 4980 4320 Tubing 3-1/2" 9.3 L-80 EUE 8rd 0' 7969' 0' 5719' 10160 10540 Tubing 3.5" x 2.875"6980 8279' J-55 EUE 8rd 7960' 8303' 5713' 5952' 6980 7400 7. Diverter System Information (Requirements of 20 AAC 25.005(c)(7)) Nabors CDR3-AC will be operating under 20 AAC 25.036, for thru-tubing drilling operations. Therefore, a diverter system is not required. 8. Drilling Fluids Program (Requirements of 20 AAC 25.005(c)(8)) Diagram of Drilling System A diagram of the Nabors CDR3-AC mud system is on file with the Commission. Description of Drilling Fluid System — Window milling operations: Chloride -based PowerVis mud (8.6 ppg) — Drilling operations: Chloride -based PowerVis 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: The well will be loaded with 11.4 ppg NaBr completion fluid in order to provide formation over -balance and shale stability while running completions. Managed Pressure Drilling Practice Managed pressure drilling (MPD) techniques will be employed to maintain a constant overbalanced pressure on the open hole formation throughout the coiled tubing drilling (CTD) process. Mud weight is not, in many cases, the primary well control barrier. This is satisfied with the 5,000 psi rated coiled tubing pack off and MPD choke. BOPE equipment provides the secondary well control as detailed in section 3 "Blowout Prevention Equipment Information". In the 3F-01 L1 &3F-011-1-01 laterals we will target a constant BHP of 11.4ppg EMW at the window. The constant BHP target will be adjusted through choke pressure and/or mud weight increases to maintain overbalanced conditions if increased reservoir pressure is encountered. Additional choke pressure or increased mud weight may also be employed for improved borehole stability. Any change of circulating friction pressure due to change in pump rates or change in depth of circulation will be offset with back pressure adjustments. Page 3 of 6 March 5, 2019 PTD Application: 3F-01 L1, 3F-01 L1-01 Vii,` Pressure at the 3F-01 Window 18243' MD.M0V TVDI Usina MPD 9. Abnormally Pressured Formation Information (Requirements of 20 AAC 25.005(c)(9)) N/A - Application is not for an exploratory or stratigraphic test well. 10. Seismic Analysis (Requirements of 20 AAC 25.005(c)(10)) N/A - Application is not for an exploratory or stratigraphic test well. 11. Seabed Condition Analysis (Requirements of 20 AAC 25.005(c)(11)) N/A - Application is for a land based well. 12. Evidence of Bonding (Requirements of 20 AAC 25.005(c)(12)) Evidence of bonding for ConocoPhillips Alaska, Inc. is on file with the Commission. 13. Proposed Drilling Program (Requirements of 20 AAC 25.005(c)(13)) Summary of Operations Background Well KRU 3F-01 is a Kuparuk A/C -sand producer equipped with 3-1/2" tubing. The CTD sidetrack will utilize two lateral to target the C -sand to south of the 3F-01 parent wellbore. The laterals will increase recovery and add additional resources. Pre -CTD Work 1. RU Slickline: Pull TPC, MIT -T, set plug at 8295', bail sand on top of plug 2. RU Coil: Pump Cement, mill/underream cement in 3-1/2" tubing 3. RU Slickline: Dummy whipstock Drift 4. RU E -Line: Caliper, set whipstock @ 8243' MD 5. Prep site for Nabors CDR3-AC rig. Ria Work 1. MIRU Nabors CDR3-AC rig using 2" coil tubing. NU 7-1/16" ROPE, test. 2. 3F-01 L1 Lateral (C sand -south) a. Mill 2.80" window at 8243' MD b. Drill 3" bi-center lateral to TD of 11,500' MD. Page 4 of 6 March 5, 2019 Pumps On 1.8 bpm) Pumps Off C -sand Formation Pressure 8.5 2565 psi 2565 psi Mud Hydrostatic 8.6 2596 psi 2596 psi Annular friction i.e. ECD, 0.08 psi/ft 659 psi 0 psi Mud + ECD Combined no chokepressure) 3252 psi Overbalanced -687psi) 2596 psi Overbalanced -31psi) Target BHP at Window 11.4 3441 psi 3441 psi Choke Pressure Required to Maintain Target BHP 189 psi 845 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 Well KRU 3F-01 is a Kuparuk A/C -sand producer equipped with 3-1/2" tubing. The CTD sidetrack will utilize two lateral to target the C -sand to south of the 3F-01 parent wellbore. The laterals will increase recovery and add additional resources. Pre -CTD Work 1. RU Slickline: Pull TPC, MIT -T, set plug at 8295', bail sand on top of plug 2. RU Coil: Pump Cement, mill/underream cement in 3-1/2" tubing 3. RU Slickline: Dummy whipstock Drift 4. RU E -Line: Caliper, set whipstock @ 8243' MD 5. Prep site for Nabors CDR3-AC rig. Ria Work 1. MIRU Nabors CDR3-AC rig using 2" coil tubing. NU 7-1/16" ROPE, test. 2. 3F-01 L1 Lateral (C sand -south) a. Mill 2.80" window at 8243' MD b. Drill 3" bi-center lateral to TD of 11,500' MD. Page 4 of 6 March 5, 2019 PTD Application: 31F -01L1, 3F -01L1-01 c. Run 2-3/8" slotted liner with aluminum billet from TD up to 9,100' MD. 3. 3F-01 L1-01 Lateral (C sand -south) a. Kickoff of the aluminum billet at 9,100' MD. b. Drill 3" bi-center lateral to TD of 11,520' MD. c. Run 2-3/8" slotted liner with deployment sleeve from TD up to 8,243' MD. 4. Freeze protect, ND BOPE, and RDMO Nabors CDR3-AC rig. Post -Rip Work 5. Return well to production. Pressure Deployment of BHA The planned bottom hole assemblies (BHAs) are too long to simply isolate by closing the double swab valves on the Christmas tree. MPD operations require the BHA to be lubricated under pressure using a system of double swab valves on the Christmas tree, double deployment rams, double check valves and double ball valves in the BHA, and a slick -line lubricator can be used. This pressure control equipment listed ensures there are always two barriers to reservoir pressure, both internal and external to the BHA, during the deployment process. During BHA deployment, the following steps are observed. - Initially the double swab valves on the tree are closed to isolate reservoir pressure. The lubricator is installed on the BOP riser with the BHA inside the lubricator. - Pressure is applied to the lubricator to equalize across the swab valves. The swab valves are opened and the BHA is lowered in place via slickline. - 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 un -deployment, the steps listed above are observed, only in reverse. Liner Running - The 3F-01 L1 & 3F-01 L1-01 laterals will be displaced to an overbalancing fluid prior to running liner. See "Drilling Fluids" section for more details. - While running 2-3/8" slotted liner, a joint of 2-3/8" non -slotted tubing will be standing by for emergency deployment. A floor valve is made up onto this joint ahead of time, and the rig crew conducts a deployment drill with this emergency joint on every slotted liner run. The 2-3/8" rams will provide secondary well control while running 2-3/8" liner. 14. Disposal of Drilling Mud and Cuttings (Requirements of 20 AAC 25.005(c)(14)) • No annular injection on this well. • All solid waste will be transported to the grind and inject facility at DS -4 Prudhoe Bay for disposal. • Incidental fluids generated from drilling operations will be injected in a Kuparuk Class II disposal well (1 R-18 or 1 B disposal facilities) or Prudhoe DS -4 if a Kuparuk facility is unavailable. • All wastes and waste fluids hauled from the pad must be properly documented and manifested. • Contact Kuparuk Environmental Coordinator for questions regarding waste classification. (670-4200). 15. Directional Plans for Intentionally Deviated Wells (Requirements of 20 AAC 25.050(b)) Page 5 of 6 March 5, 2019 PTD Application: 3F -01L1, 3F-011-1-01 - 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 istnc 3F -01L1 2400 3F -01L1-01 23,400'• Distance to Nearest Well within Pool Lateral NameDistance Well 3F-011-1 284' 2U-13 3F -01L1-01 283' 2U-13 16. Attachments Attachment 1: Directional Plans forthe 3F -01L1 & 3F -01L1-01 laterals Attachment 2: Current Well Schematic for 3F-01 Attachment 3: Proposed CTD Well Schematic for the 3F -01L1 & 3F -01L1-01 laterals Page 6 of 6 March 5, 2019 ConocoPhillips _ConocoPhillips Export Company Kuparuk River Unit Kuparuk 3F Pad 3F-01 3F-01 L1-01 Plan: 3F-01 L1-01_wp06 Standard Planning Report 27 February, 2019 BER GHES TGE company ConocoPhillips BITER ConocoPhillips Planning Report F U6HES a GEmmparry Database: EDT 14 Alaska Production Company: _ConocoPhillips Export Company Project: Kupamk River Unit Site: Kupamk 3F Pad Well: 3F-01 Wellbore: 3F-01 L1-01 Design: 3F-01 L1-01_wp06 Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Well 31`-01 Mean Sea Level 3F-01 Qa 93.00usft (3F-01) ' True Minimum Curvature - 'roject Kupamk River Unit, North Slope Alaska, United States lap System: US State Plane 1927 (Exact solution) System Datum: Mean Sea Level leo Datum: NAD 1927 (NADCON CONUS) Using Well Reference Point lap Zone: Alaska Zone 04 Using geodetic scale factor its Kuparuk 3F Pad Plan Sections Its, Position: Northing: 5,985,734.46usft Latitude: 70' 22'20.081 t mm: Map Easting: 508,662.33usft Longitude: 149° 55'46.550 V osition Uncertainty: 0.00 usft Slot Radius: 0.000in Grid Convergence: 0.07 ' Well Well Position Pos.Wn Uncertainty Wellbore Magnetics Design Audit Notes: Version: Vertical Section: 3F-01 +N/S 0.00 usft +E/ -W 0.00 usft 0.00 usft 3F.01L1-01 Model Name BGGM2018 3F -07L1-01 wp06 Northing: Beating: Wellhead Elevation Sample Date 4/1/2019 5,985,734.98 usft - Latitude: 508,662.35 usft . Longitude: usft Ground Level: Declination Dip Angle 16.61 80.87 Phase: PLAN Depth From (TVD) +NI -S (usft) (usft) 0.00 0.00 Te On Depth: +EI -W (usft) 0.00 70° 22'20.086 N 149° 55'46.549 W 0.00 usft Field Strength (nT) 57,419 9,100.00 Direction (°) 180.00 TVD Below Plan Sections Build Turn Measured System +N/ -S Depth Inclination Azimuth (usft) (°I (°) 9,100.00 95.20 176.19 9,275.00 107.45 176.19 9,475.00 94.25 180.95 9,600.00 86.32 177.26 9,800.00 85.22 191.25 9,950.00 87.11 180.90 10,100.00 92.37 171.81 10,370.00 99.23 189.53 10,580.00 91.28 177.10 10,760.00 85.00 188.03 11,020.00 62.13 169.94 11,220.00 93.91 177.53 11,370.00 99.09 186.72 11, 520.00 100.75 197.25 Northing: Beating: Wellhead Elevation Sample Date 4/1/2019 5,985,734.98 usft - Latitude: 508,662.35 usft . Longitude: usft Ground Level: Declination Dip Angle 16.61 80.87 Phase: PLAN Depth From (TVD) +NI -S (usft) (usft) 0.00 0.00 Te On Depth: +EI -W (usft) 0.00 70° 22'20.086 N 149° 55'46.549 W 0.00 usft Field Strength (nT) 57,419 9,100.00 Direction (°) 180.00 TVD Below Dogleg Build Turn System +N/ -S +EAW Rate Rate Rate TFO (usft) (usft) (usft) ('/100usft) (°1100usft) (°/100usft) (°) 5,752.99 -4,591.64 4,02808 0.00 0.00 0.00 0.00 5,718.69 -4,762.53 4,039.45 7.00 7.00 0.00 0.00 5,681.11 -4,958.40 4,044.16 7.00 -6.60 2.38 160.00 5,680.49 -5,083.26 4,046.11 7.00 -6.35 -2.95 205.00 5,695.33 -5,281.67 4,031.37 7.00 -0.55 7.00 95.00 5,705.40 -5,430.28 4,015.56 7.00 1.26 -6.90 280.00 5,706.09 -5,579.76 4,025.08 7.00 3.51 -6.06 300.00 5,678.60 -5,847.12 4,022.21 7.00 2.54 6.56 68.00 5,659.30 -6,055.31 4,010.31 7.00 -3.78 -5.92 238.00 5,665.15 -6,234.68 4,002.32 7.00 -3.49 6.07 120.00 5,694.52 -6,491.87 4,006.77 7.00 -1.10 -6.96 260.00 5,701.42 -6,690.07 4,028.49 7.00 5.89 3.79 33.00 5,684.41 -6,838.79 4,023.03 7.00 3.45 6.13 60.00 5,658.50 -6,983.11 3,992.42 7.00 1.11 7.02 80.00 Target 227/2019 11'46.51AM Page 2 COMPASS 5000 14 Build 85D I ConocoPhillips BAj(ER ConocoPhillips Planning Report UG, ES a GErampny Database: EDT 14 Alaska Production Local Co-ordinate Reference: Well 3F-01 Company: _ConocoPhillips Export Company TVD Reference: Mean Sea Level Project: Kupamk River Unit MD Reference: 3F-01 Qc 93.00usft (3F-01) Site. Kuparuk 3F Pad North Reference: True Well: 3F-01 Survey Calculation Method: Minimum Curvature Wellbore: 3F-01 L1-01 Measured Design: 3F-01 L1-01_Wp06 TV�r�) BBe16dr jam' ` Planned Survey /�'7�C;77 (� Measured TV�r�) BBe16dr jam' ` VerBwl Dogleg Toolface Map Map Depth Inclination Azimuth siem +NIS +E/ -W Section Rate Azimuth Northing Easdng (usft) (1) (1) (usft) (usft) (usft) (usft) (11100usft) (1) (usft) (usft) 9,100.00 95.20 176.19 5,752.99 4,591.64 4,028.08 4,591.64 0.00 0.00 5,981,148.46 512,695.34 TIP/Start 7 DLS 9,200.00 102.20 176.19 5,737.87 -4,690.21 4,034.64 4,690.21 7.00 0.00 5,981,049.91 512,702.01 9,275.00 107.45 176.19 5,716.69 -4,762.53 4,039.45 4,762.53 7.00 0.00 5,980,977.61 512,706.91 2 9,300.00 105.80 176.81 5,711.54 -4,786.44 4,040.91 4,786.44 7.00 160.00 5,980,953.70 512,708.40 9,400.00 99.21 179.21 5,689.89 -4,883.94 4,044.27 4,883.94 7.00 160.18 5,980,856.21 512,711.86 9,475.00 94.25 180.95 5,681.11 4,956.40 4,044.16 4,958.40 7.00 160.70 5,980,781.76 512,711.54 3 9,500.00 92.66 180.21 5,679.60 4,983.35 4,043.90 4,983.35 7.00 -155.00 5,980,756.81 512,711.61 9,600.00 86.32 177.26 5,680.49 -5,083.26 4,046.11 5,083.26 7.00 -155.04 5,980,656.91 512,713.94 4 9,700.00 85.73 184.25 5,687.43 -5,182.95 4,044.80 5,182.95 7.00 95.00 5,980,557.23 512,712.74 9,800.00 85.22 191.25 5,695.33 5,281.67 4,031.37 5,281.67 7.00 94.51 5,980,458.51 512,699.42 5 9,900.00 86.46 184.35 5,702.60 -5,380.42 4,017.85 5,380.42 7.00 -80.00 5,980,359.75 512,686.02 9,950.00 87.11 180.90 5,705.40 -5,430.28 4,015.56 5,430.28 7.00 -79.50 5,980,309.89 512,683.79 6 10,000.00 88.86 177.87 5,707.16 -5,480.24 4,016.10 5,480.24 7.00 -60.00 5,980,259.94 512,684.39 10,100.00 92.37 171.81 5,706.09 -5,579.76 4,025.08 5,579.76 7.00 -59.89 5,980,160.43 512,693.48 7 10,200.00 94.97 178.33 5,699.67 -5,679.13 4,033.66 5,679.13 7.00 68.00 5,980,061.09 512,702.18 10,300.00 97.51 184.89 5,688.79 -5,778.43 4,030.89 5,778.43 7.00 68.42 5,979,961.79 512,699.52 10,370.00 99.23 189.53 5,678.60 -5,847.12 4,022.21 5,847.12 7.00 69.13 5,979,893.11 512,690.92 8 10,400.00 98.11 487.73 5,674.07 -5,876.44 4,017.76 5,876.44 7.00 -122.00 5,979,863.78 512,686.51 10,500.00 94.34 181.80 5,663.22 -5,975.44 4,009.53 5,975.44 7.00 -122.27 5,979,764.78 512,678.40 10,580.00 91.28 177.10 5,659.30 -6,055.31 4,010.31 6,055.31 7.00 -122.92 5,979,684.92 512,679.26 9 10,600.00 90.58 178.31 5,658.97 -6,075.29 4,011.11 6,075.29 7.00 120.00 5,979,664.94 512,680.09 10,700.00 87.08 184.37 5,661.01 -6,175.18 4,008.78 6,175.18 7.00 120.02 5,979,565.06 512,677.87 10,760.00 85.00 188.03 5,665.15 -6,234.68 4,002.32 6,234.68 7.00 119.90 5,979,505.56 512,671.48 10 10,800.00 84.52 185.26 5,668.81 -6,274.24 3,997.71 6,274.24 7.00 -100.00 5,979,466.00 512,666.92 10,900.00 83.38 178.31 5,679.36 -6,373.57 3,994.61 6,373.57 7.00 -99.75 5,979,366.68 512,663.93 11,000.00 82.33 171.34 5,691.82 -6,472.32 4,003.54 6,472.32 7.00 -99.01 5,979,267.94 512,672.98 11,020.00 82.13 169.94 5,694.52 -6,491.87 4,006.77 6,491.87 7.00 -98.14 5,979,248.40 512,676.23 11 11,100.00 86.84 172.99 5,702.21 -6,570.59 4,018.57 6,570.59 7.00 33.00 5,979,169.70 512,688.12 11,200.00 92.73 176.77 5,702.58 -6,670.13 4,027.49 6,670.13 7.00 32.71 5,979,070.18 512,697.16 11,220.00 93.91 177.53 5,701.42 -6,690.07 4,028.49 6,690.07 7.00 32.69 5,979,050.24 512,698.17 12 11,300.00 96.69 182.41 5,694.02 5,769.70 4,028.54 6,769.70 7.00 60.00 5,978,970.63 512,698.32 11,370.00 99.09 186.72 5,684.41 -6,838.79 4,023.03 6,838.79 7.00 60.45 5,978,901.53 512,692.89 13 11,400.00 99.45 188.82 5,679.58 -6,868.13 4,019.02 6,868.13 7.00 80.00 5,978,872.20 512,686.92 11,500.00 100.55 195.84 5,662.19 -6,964.27 3,996.02 6,964.27 7.00 80.34 5,978,776.03 512,668.03 11,520.00 100.75 197.25 5,658.50 -6,983.11 3,992.42 6,983.11 7.00 81.56 5,978,757.19 512,662.45 Planned TO at 11520.00 2272019 11:46:51AM Page 3 COMPASS 5000.14 Build 85D ConocoPhillips ConocoPhillips Planning Report �F�UGHES a 6E company Database: Company: Project: Site: Well: Wellbore: Design: Casing Points Plan Annotations EDT 14 Alaska Produclion _ConocoPhillips Export Company Kupamk River Unit Kupaluk 3F Pad 3F-01 31F-011-1-01 31F-0111-01_wp06 Local Coordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Well 3F-01 Mean Sea Level 3F-01 @ 93.00usft (3F-01) True Minimum Curvature Measured Vertical Casing Hole Depth Depth Diameter Diameter (usft) (usft) Name (in) (in) 11 520.00 5,658.50 2 3/8" 2.375 3.000 Measured Vertical Local Coordinates Depth Depth +N/ -S +E/ -W (usft) (usft) (usft) (usft) Comment 9,100.00 5,752.99 -4,591.64 4,028.08 TIP/Start 7 DLS 9,275.00 5,718.69 4,762.53 4,039.45 2 9,475.00 5,681.11 4,958.40 4,044.16 3 9,600.00 5,680.49 -5,083.26 4,046.11 4 9,800.00 5,695.33 -5,281.67 4,031.37 5 9,950.00 5,705.40 -5,430.28 4,015.56 6 10,100.00 5,706.09 -5,579.76 4,025.08 7 10,370.00 5,678.60 -5,847.12 4,022.21 8 10,580.00 5,659.30 -6,055.31 4,010.31 9 10,760.00 5,665.15 -6,234.68 4,002.32 10 11,020.00 5,694.52 -6,491.87 4,006.77 11 11,220.00 5,701.42 -6,690.07 4,028.49 12 11,370.00 5,664.41 -6,838.79 4,023.03 13 11,520.00 5,658.50 -6,983.11 3,992.42 Planned TD at 11520.00 2272019 11'46.51AM Page 4 COMPASS 5000.14 Build 85D ConocoPhillips BAER ConocoPhillips Anticollision Report UGHES aGEcompany Company: ConocoPhillips Alaska lnc Kupamk Project: Kuparuk River Unit -2 Reference Site: Kuparuk 3F Pad Site Error: 0.00 usft Reference Well: 3F-01 Well Error: 0.00 usft Reference Wellbore 3F-01 L7-07 Reference Design: 3F-01 1-1-01_wp06 Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Output errors are at Database: Offset TVD Reference: Well 3F-01 3F-01 @ 93.00usft (3F-01) 3F-01 @ 93.00usft (3F-01) True Minimum Curvature 2.00 sigma EDT 14 Alaska Production Offset Datum Reference 3F-01 Lt-01_wp06 Filter type: NO GLOBAL FILTER: Using user defined selection & filtering critena Interpolation Method: MD Interval 25.00usft Error Model: ISCWSA Depth Range: 9,100.00 to 11,520.00usft Scan Method: Tray. Cylinder North Results Limited by: Maximum centercenter distance of 1,342.70 usft Error Surface: Combined Pedal Curve Warning Levels Evaluated at: 2.79 Sigma Casing Method: Added to Error Values Survey ToolProgram Date 2/27/2019 283.43 110.23 From To 7,500.00 285.01 (usft) (usft) Survey (Wellbore) Tool Name Description 100.00 8,200.00 3F-01 (3F-01) GCT -MS Schlumberger GCT muitishot 8,200.00 9,100.00 3F-01L7_wp06(3F-011-1) GCT -MS Schlumberger GCT muftishot 9,100.00 11,520.00 3F-01L7-01_wP06(3F-0111-01) MWD MWD -Standard Site Name Offset Well - Wellbore - Design Kuparuk 21.1 Pad 21.1-13 - 2U-13 - 2U-13 2U-13 - 21.1-13 - 2U-13 Kuparuk 3F Pad 3F-01 - 3F-01 L1 - 3F-01 L1_wp06 3F -01-3F-01 L1 -3F-011-7 wp06 3F-01 - 3F-01 L1 - 3F-01 L7_Wp06 3F-18 - 3F-18AL2 - 3F-18AL2 3F-18 - 3F-18AL2 - 3F-1 BAL2 Reference Offset Distance Measured Measured Between Between Separation Warning Depth Depth Centres Ellipses Factor (usft) itself) (usft) (usft) 11,008.83 7,525.00 283.43 110.23 1.636 Caution Monitor Closely, CC 11,016.33 7,500.00 285.01 109.52 1.624 Caution Monitor Closely, ES 11,083.44 11,075.00 19.19 4.55 1.311 Take Immediate Action, ES 11,107.71 11,100.00 18.42 4.73 1.345 Take Immediate Action, CC 11,204.77 11,200.00 23.86 4.98 1.264 Take Immediate Action, SF Out of range Measured vesical Out of range Offset Design Kuparuk 21J Pad -2U -13 -2U -13-2U-13 araatatte Error: o6ousft survey Program; 200ACT-MS Oetttwell Error 0.00 usft saltines. Oriel Semi MajorAgs Distance Measured vesical Measured vanical Rehrence Off. NImNft West Wellbore CemM aetnaen Between Minimum 6epenllon Warning Depth Depth Depth Depth from Nonni -11I4 aEAW Centres Ellipses separation Factor (ware) hism (wart) (ass) (usft) (tun) PI lusrt) (wall (unto loan) )usft 10.850.30 5,768.87 7.95200 6,271.89 10663 85.07 -3.84 4.270.20 3.907.54 499.19 385.70 11349 4,399 10.853.56 5,767.21 7.950A0 6,266.61 106.65 ease -4.41 -6,273.83 3.94.72 493.85 379.87 113.98 4.333 10.864.95 5,768.44 7,925.00 6,247.76 106.74 84.85 -6.55 -6,286.80 3.934.66 474.95 359.10 115.85 4.100 10.875.97 5,769.65 7,900.00 6.228.90 106.82 84.33 -8.79 -6,299.77 3.924.59 456.38 338,45 117.93 3.870 1088884 5,770.84 7,875.00 6,210,05 Ideas 84.01 -11.17 4,312.74 3,914.53 438.17 317.95 120,22 3.646 10,896.98 5.772.01 7,050.00 6,191.20 106.97 83.68 -13.68 4.325.71 3.904.46 420.40 297.60 122.76 3.425 10,905.99 5,773.17 7,825.00 6,172.31 107,04 83.36 -16.38 4,338.68 3,09140 403,13 27.57 125.56 3.211 10,916.68 5.74.31 7.800.00 6.153.49 107.12 83.04 -19.21 4.351.65 3,884.33 308.4 257.82 128.63 3.004 10.926.12 5.75.44 7.775,00 6,134.67 10720 82.71 -22.27 41380.66 3.87434 370.47 23849 131.98 2.807 Normal Operations 10.935.33 5,778.55 7,750.00 6,115.94 107.27 82,39 -25.56 -6,377.74 3,864.10 365.37 219.75 135.62 2.620 Normal O,esolois 10,944,34 5,77.86 7,725.00 6.097.28 107.34 02.05 -29,08 4,390.90 3,853.92 341.25 201.72 13453 2.446 Caution Monitor Closely 10,95113 5,778,75 7,700.00 6.078.70 107.41 81.74 -32.86 4,404.13 31843.68 328,25 184.52 143.73 2,284 Caution Monitor Closely 10,961.72 5,779.84 7,675.00 6.060.22 107.49 81.41 -36.91 -6,41242 3,833,34 316.M 168.24 148.33 2.134 Caution Monitor Closely 10,970.10 5,780.90 7,650.00 6,041.87 107.56 81.08 .41.22 4,430.77 3,822.85 306.40 153,36 153.04 2.002 Caution Monitor Closely 10,978.25 5,781.96 7,625.00 8023.68 107,83 80.76 -45.79 4,444.18 3,012.20 297.92 140.17 157.74 less Caution Monitor Closely 10.986.22 5.783.00 7.600.0 6,005.57 107,70 80.43 -50.59 4,457.64 8a01.40 291.28 129.00 162.28 1.795 Caution Monitor Closely CC - Min centre to center distance or covergent point. SF - min separation factor, ES - min ellipse separation 2/272019 6: 06 57A Page 2 COMPASS 5000 14 Build 85D ConocoPhillips ProSM: Ruparuk Rb.r UnM_2 WON: k]FPatl uymex... feel yge.kF.e VVELLBORE DETAILS: 3F -01L1-01 RIWERNCE WFORWTM Parent MINN..: 3F-011.1 C.WWMlN[IRelxmxa We1Ndl, T.~ 3F-01 WO: 3F-01 s.m�a.sTun' The On MD: 8100.00 Vakaa"%Ru..iW. W.�seelew WHIEon: JF -011.1-01 oaeea.eon 5752.99 -4591.64 swvonryRlRdrmor. a 0WN,ewE) Pan:3F-01L1-01_Rap06(3F-0V3F-01L1-0n y�gRpyml 4591.64 WwyMOgnRRaWW. ]Fd1®03wMOFdq 2 9275.00 107.45 176.19 CyvsbnNHat NmumCw.4e WELLDETAILS: 3F-01 +NIS +E/ -W Northing Easting Latitude Longitude 0.00 0.00 5985734.98 508662.35 70'2Z 20.086 N 149° 56'55.644 W sec MU Inc AZI TVDSS -NI-5 +FJ -W Dleg TFace VSed n ron 1 9100.00 95.20 176.19 5752.99 -4591.64 4028.08 0.00 0.D0 4591.64 TIRlSIan7DLS 2 9275.00 107.45 176.19 5718.69 -0762.53 4039.45 7.00 0.00 4762.53 2 3 9475.00 94.25 180.95 5681.11 4958.40 4044.16 7.00 160.00 4958.40 3 4 9600.00 86.32 177.26 5680.49 -5083.26 4046.11 7.00 205.00 5083.26 4 5 9800.00 85.22 191.25 5695.33 -5281.67 4031.37 7.00 95.00 5281.67 5 6 9950.00 87.11 180.90 5705.40 -5430.28 4015.56 7.00 280.00 5430.28 6 7 10100.00 92.37 171.81 5706.09 5579.76 4025.08 7.00 300.00 5579.76 7 8 10370.00 99.23 189.53 5678.60 5847.12 4022.21 7.00 68.00 5847.12 8 9 10580.00 91.28 177.10 5659.30 -6055.31 4010.31 7.00 238.00 6055.31 9 10 10760.00 85.00 188.03 5665.15 -6234.68 4002.32 7.00 120.00 6234.68 10 11 11020.00 82.13 169.94 5694.52 5491.87 4006.77 7.00 260.00 6491.87 11 12 11220.00 93.91 177.53 5701.42 -6690.07 4028.49 7.00 33.00 6690.07 12 13 11370.00 99.09 186.72 5684.41 -6638.79 4023.03 7.00 60.00 6838.79 13 14 11520.00 100.75 197.25 5656.50 -6983.11 3992.42 7.00 80.00 6983.11 Planned TD at 11520.00 Men Saa 1 JER HES GF .npary West(-)1East(+) (250 usftlin) Vertical section at 1su-DU" (95 usH/in) 1 ■■■■■■■■■■■■■ ■■■■■■■■■■■■■■■■■■■so vi■■ I ■■■■■■■■■■■■■■■■■■■■■■■■■■■■■■■■■,II■■■■� ■■■■■■■■■■■■■■■■■■■■■■■■■■■■■■■■�■■■■■N 11 ON MOM ■■■■■■■ISO■■■■ MEMO ■■■■■■■®■ ®■�■ Vertical section at 1su-DU" (95 usH/in) 1 1b, KUP PROD 3F-01 ConomPFI(llips Well Attributes _-_ Maz.Angle&M TD Naska.lnc. Field Name wenWre 44600 WtllOartsmNs ncl l'1 MDlnl(91 Act Blm (nKBI KUPARUK RIVER UNIT 500292144600 PROD .85 3,100.00 B,YJ0.0 LanmeM --I[::,. (ppmj EM Date KBGrd MI Rlp ReleaeDam SSSV: NIPPLE /4/2015 WO: 4242014 41.00 9/25/1985 R1 3Fp1na1am1eea9s, AN Last Tag Ven'ya,Aemnel+ctuFll Annotation E"d Date DepM IRKS) last MW By Last Tag-RKB(es119'AFill, lesving441'or Openperla) 512/2018 8,507.0 9embaej 330- Last Rev Reason Annsupbou Fip DMe taseMW By Rev Reason: Open C Sands. Swapped ON TPI for TPC 1052018 fergDsp Casing Strings Lazing Description OD lin ID (nl Top lkKBl $el OeplM1 lkKBj $el OeptM1 jND1... WnLen (I... Grade Top TM1reatl CONDUCTOR i6 15.06 370 115.0 115.0 62.50 H<0 WELDED fANDUCrOR: n.o-ttaD Casim Ces<riptbn BDlinl IDpn) Top MKBI 5&DeNigne!1 .DeptM1jNDL_ WdLen11...GMa Top Threw SURFACE 9518 8.92 37.0 3,970.6 3,061.6 36.00 7-55 BTC Caslrp ..vain GD pnl 10 (In) TOP(ken, Set..n,AG, Bet DepM j1Y➢L�� wuten lL.. Grade Top TM1rtW PRODUCTION 7 6.28 350 8.646.1 &1371 2600 J-55 eTC "IPPLEam' Tubing Strings - Tubing Desaipnon 3mng Ma... lD lint rop d1Ku set novae X_set Dept"(VG)L.. VA(.) Grade ropeonnedon TUBING -WO 31/2 2.99 334 ],968.5 5]19.1 9.30 L-80 EUEBrnd Completion. Details GAS D1;3,1a3.a Top (1p) TapIncl Nominal I.IkKBI @KB) 1•I Item Gov com 10 (in) 33.0 33.0 0. HANGER EMC TUBING HANGER 2.992 51&1 518.0 3.99 NIPPLE CAMCO 2.8750 -DS' NIPPLE 2.875 7,9558 5,710.2 45.83 LOCATOR BAKER LOCATOR 3.830 SDRFAOE,S1Tn,97p.S- 7,956.6 5,710.8 45.82 EAL BY BAKER SEALASSY the PBR, 3-X "Slick -up' 2.990 GAS u6T: 1,ss°5 TuMrp Deeer,,Nn Spin M. In 'in' TUBING -Original 31/2 2.99 3.5'x2.875' @82]9' Top(XKBI 7,960.2 Set Odom IS 8,303.4 OgM(IWII... 5951.6 Wr11WX1 9.20 15"a J-55 Top tmnectbn EUE BRO Completion Derails I -p (WIN Top Incl Novenel GAS DFT; 5,596.9 TOP IXK81 (GREG PI Item Des can ID (in) 7,960.2 5,713.3 45. PBR BAKER PBR 3,000 7,973.9 57229 45.75 PACKER BAKER THE PACKER 3.000 8,2659 5,925.7 /8.32 NIPPLE AVA BPL PORTED 05B NIPPLE 2.300 GK UFT'. B.BpA 6.2 5,927.3 46.33 XO-Reduting CROSSOVER 3. "TO 2.875- 2.441 &278.4 5,934.3 46.34 fACATOR BAKER LOCATOR 3.000 $280.2 5,935.6 46.34 PACKER BAKER F&1 PACKER 4.000 -8-.2M OAS UFT; LOa3 5,=7.8 46.35 SBE BAKER SEAL BORE EXTENSION 4.000 5295.2 5945.9 4636 NIPPLE CAMCO D NIPPLE NO GO 2.250 &302] 5951.1 46.38 SOS I CAMCO SHEAROUT SUB 2,441 GAS UFT; 7.bK3 Other In Hole (Wireline reVievable plugs, valves, pumps, fish, eec.j T.p ITVDI Tnpmn T.".., (xufi) (') Des eom Run Dam III pn 8.265.3 5925.3 46.32275"NEW 2]5'NEW STYLE TPC Q. DAL12.31)"10)C Sands 1019/2018 2300 LOe.B.7,.. STYLE TPC SLEEVE 0,Qn 9EALASSY', 7.958 P8R.75s2 Perforations& Slots $hw PKKER, ]9]3.9 Gens Top ITAA Btm (NO) (shou. PROOMTI0N;B.0I11 TOP IRKS) BIMMKIN (XKBI (SLB) LinkWZone Da. I Type Con &066.0 8.219.0 5,787.1 5,893.3 G3, 2,C-1, UNIT B. 3F41 1127/1985 12.0 (PERF 120deg. phasing. 5"HJ 1 Ong Gun 8,417.0 8,423.0 6.675.8 6,033.9 AA, 3F-01 1127/1985 4.0 (PERE 9D deg. phasing, 4" HJ II CSg Gun IFERF', aeIS6&2I9.p- ,4 .0 B,d68.0 6.037.4 6.064.8 TFY-01 112711 4.01PERE Dag Wdeg. phasing, 4' HJ 11 Gun 8 526.0 6 M5- 6 1047 1 4,0 IPER8&498.0 0de.ph.br,g.4'HJ Cm Gun Mandrel Inserts st MI 3.1BSNEW &TYLE TPC Sibee'S 8,263.3 on Tap ISIR VNve Rjunin'N PM) INQ N Top,,Bl gIKB) Make MWN DO (In) Sery Type Type (in) IWII Run Date Wm NIPLL98.NSG 3,162.8 2,571.1 CAMCO MMG 112 GASLIFT GLV RK 0.188 1,248.0 5212018 2 4.850.5 3.624.8 CAMC MMG 112 GASLIFT GLV RK 0.188 1.2/0.0 9212018 3 5,996.9 4.370.4 CAMCO DISC; GAS LIFT GLV RK 0.188 1,234.0 5/2/2018 4 6,8404 4,940.4 CAMCO MMG 1112 GASLIFT GLV RK 0.188 1,227.0 SI22018 PACKER/B.ID11.2 5 7,043 5,376.5 CANOU DID 1112 GASLIFT GLV RK 0.188 1.220- 5112018 seE. 826x1 6 7896.3 5.668.8 CAMCO MMG 11/2 GAS LIFT OV RK 0.188 0.0 5112018 7 8,0117 5,749.3 CAMCO KBUG 1 PROD DMY BK 0.000 0.0 5/1&1988 NIPPLE: e,aa2 Notes: General& Safety Fee Dae. appop im 51412(103 NOTE: WAIVERED WELL: IA x OA COMMUNICATION SOSe3oi> IPERF;811 ].0$1]3.0 IPERF, &<39.08.Ifiae- IPERF; 8.1�.G8,SM0� 1p.G-GION:L,0,nn PSA 3F-01 Proposed CTD Schematic 16" 62# H-40 shoe 9-5/8" 40# J-55 shoe @ 3971' MD C -sand perfs 8066' 8219' MD KOP @ 8243' MD A -sand perfs 8417'- 8423' MD a428'- 8468' MD 8498'- 8526' MD 7" 26# J-55 shoe @ 8646' MD 3-1/7' Camco DS nipple @ 518' MD (2.875" min ID) 3-1/2" 9.3# L-80 EUE 8rd Tubing to surface 3-1/2" Cameo gas lift mandrels @ 3163', 4851', 5997', 68411, 74741, 7896' MD Baker 3-1/2" PBR @ 7960' MD (3" ID) Baker FHL packer @ 7974' MD (4.0" ID) 3-1/2" Cameo MMG production mandrels @ 8012' MD AVA SP Ported Nipple @ 8266' MD (2.3" min ID) XO 3.5" to 2.875" Baker FB -1 packer @ 8280' MD (4.0" ID) Baker SBE @ 8283' MD 3-1/7' Camco D landing nipple @ 8295' MD (2.25" min ID, No -Go) Cameo SOS @ 8303' MD 3F -01L1-01 wp06 TO @ 11,520' MD Top of Liner @ 8,243' MD 3F -01L1 wp06 TD@ 11,500' MD Billet @ 9,100' MD TRANSMITTAL LETTER CHECKLIST WELL NAME: l,K%(, �3r &IL-I(f� 1 PTD: _Z/2-037 Development _ Service _ Exploratory _ Stratigraphic Test _ Non -Conventional FIELD: eGy/ _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 (If last two digits No. /vim 1 �� API No. 50-6 - Production should continue to be reported as a function of the original in API number are API number stated above. between 60-69 In accordance with 20 AAC 25.005(f), all records, data and logs acquired for the pilot hole must be clearly differentiated in both well Pilot Hole name ( PH) and API number (50-_- _-_) from records, data and logs acquired for well name on permit). The permit is approved subject to full compliance with 20 AAC 25.055. Approval to produce/inject is contingent upon issuance of a conservation Spacing Exception order approving a spacing exception. (Company Name) Operator assumes the liability of any protest to the spacing exception that may occur. All dry ditch sample sets submitted to the AOGCC must be in no greater Dry Ditch Sample than 30' sample intervals from below the permafrost or from where samples are fust caught and 10' sample intervals through target zones. Please note the following special condition of this permit: production or production testing of coal bed methane is not allowed for Non -Conventional (name of well) until after (Company Name) has designed and Well implemented a water well testing program to provide baseline data on water quality and quantity. (Company Name) must contact the AOGCC to obtain advance approval of such water well testing program. Regulation 20 AAC 25.071(a) authorizes the AOGCC to specify types of well logs to be run. In addition to the well logging program proposed by (Company Name) in the attached application, the following well logs are also required for this well: Well Logging Requirements Per Statute AS 31.05.030(d)(2)(B) and Regulation 20 AAC 25.071, composite curves for well logs run must be submitted to the AOGCC within 90 days after com letion, sus ension or abandonment of this well. Revised 2/2015 WELL PERMIT CHECKLIST Field & Pool KUPARUK RIVER, KUPARUK RIV OIL - 490100 PTD#:2190370 Company CONOCO PHILLIPS ALASKA INC Initial Class/Type Well Name: KUPARUK RIV UNIT 3F-0111-01 Program DEV Well bore seg DEV/PEND GeoArea 890 Unit 11160 On/Off Shore On Annular Disposa Administration '17 Nonconven, gas conforms to AS31.05.030(L 1.A).0,2.A-D) _____ _ _ _ _ _ _ _ _ _ _ _ ______ NA 1 Permit fee attached- _ - - _ . .INA 2 Lease number appropriate- - - _ _ _ _ _ _ - Yes Entire well in ADL 25643... 3 Unique well -name and number _ _ _ _ _ _ _ _ _ _ _ _ _ ............ Yes 4 Well located in a_defined pool ....... - - - - - - - - - - - - ---- - - - - - - - Yes _ 5 Well located proper distance fromdrillingunit_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 orlandownership changes. As proposed,well will. 8 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 SFD 3/6/2019 12 Permit can be issued without administrative approval - - - _ _ _ _ _ Yes 13 Can permit be approved before 15 -day wait.. ....... _ _ _ _ _ _ _ _ _ Yes 14 .Well located within area and strata authorized by Injection Order # (put 10# in commeats).(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 produgtien less than 3 months -(For service well only) - . NA- - - - - - - - - - - - - - - - ----- - - - - - - - - - 18 Conductor stringprovided. ...... . . . . . . . . . . . . . . .............. . NA- . - - , _ - - Conductor set in KRU 3F-01 Engineering 19 Surface casing_ protects all known USDWs . - _ - - NA. _ _ ..... Surface casing set in KRU 3F-01,.... 20 CMT vol adequate. to circulate on conductor & sLuf-csg ......... _ _ NA.. _ _ _ _ _ _ Surface casing set and fully cemented 21 CMT vol adequate to tie-in long string to surf csg_ _ _ _ _ _ _ _ _ _ _ _ _ NA 22 CMT -will cover all known productive horizons _ _ _ _ _ . - - No... . Productiveintervalwill be completed withuncementedslotted liner 23 Casing designs adequate for C, T, B &-permafrost_ __ _ _ _ _ _ _ _ _ Yes 24 Adequate tankage or reserve pit _ ... .. . . . . . . .......... Yes _ Rig has steel tanks; all waste to approved disposal wells 25 If a -re -drill, has -a 10-403 for abandonment been approved _ _ _ _ _ .. - - - - - - - - NA - - - - - ---- - - - - - - - - - - - - - - ---- - - - - - - - - - 26 Adequate wellbore separation proposed _ _ _ _ ... _ _ _ _ _ Yes Anti -collision analysis complete; no major risk failures _ 27 If diverter required, does it meet regulations. - - _ - NA Appr Date 28 Drilling fluid. program schematic & equip list adequate_ _ _ _ _ _ Yes .. Max formation pressure is. 3302 psig(10.6 ppg EMW); will drill -w/ 8,6-ppg EMW andmaintain overbal w/ MPD - - VTL 3/7/2019 ,29 BOPEs,. do they meet regulation - - - - - _ _ _ _ _ . Yes...... 30 ROPE -press rating appropriate; test to (put psig in comments). _ _ _ _ _ ....... Yes MPSP is 2722 paig; will test BOPS to 3500 psig 31 Chokemanifoldcomplies w/API-RP-53 (May 84).. - - - Yes 32 Work will occur without operation shutdown_ _ _ _ _ ______ _ _ _ _ _ _ _ _ _ _ _ ____ Yes .......... 33 Is presence of 1-128 gas probable ... .......... . . .. . . . . . . . . . . . . ..... . . Yes - - - - - - - H2S measures required.. 34 Mechanical condition of wells within AOR yerifed (For service well only) . . . ..... . ..... NA_ _ . _ .. _ _ .. _ - - - - 35 Permitcan be issued w/o hydrogen sulfide measures _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ No........ 3F-Pad.wells are H28-bearing..112S measures are required.. Geology 36 Data.presented on potential overpressure zones _ _ _ _ ...... Yes . - _ _ _ _ - Max. potenfial.res. pressure is 10.6 ppg EMW; expected -res. pressure is 6.5 ppg EMW. Well will be _ Appr Date 37 Seismic analysis of shallow gas. zones.. - - - - - _ _ _ _ _ .. NA- - - - - - - - drilled using 8,6ppg mud,_a coiled -tubing rig, and managedpressuredrilling technique to control SFD 3/6/2019 38 Seabed condition survey (if off -shore) ........ . . . . . . . - - - - _ _ _ _ _ N k _ _ _ formation pressures and stabilize shale sections with constant BHP of about 11.4 ppg EMW. I39 Contact name/phone for weekly progress reports [exploratory only] .. _ _ . _ NA _ _ NOTE: Chance of encountering free. gas while driUing due to gas injection performed in -this area.. . Geologic Engineering Public Commissioner: Date: Commissioner: Date Commissioner Date 311114 � yl 1//1 v`
