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Home My WebLink About216-144DATA SUBMITTAL COMPLIANCE REPORT 3/13/2017 Permit to Drill 2161440 Well Name/No. KUPARUK RIV UNIT 113-18AL3 4 �3v Operator CONOCOPHILLIPS ALASKA INC API No. 50-029-22472-62-00 MD 9788 TVD 6619 Completion Date 12/14/2016 Completion Status 1 -OIL Current Status 1 -OIL UIC No REQUIRED INFORMATION Mud Log No✓ Samples `No V Directional Survey Yes DATA INFORMATION Types Electric or Other Logs Run: GR/Res (data taken from Logs Portion of Master Well Data Maint) Well Log Information: Log/ Electr Data Digital Dataset Log Log Run Interval OH/ Type Med/Frmt Number Name Scale Media No Start Stop CH Received Comments Log C 27865 Log Header Scans 0 0 2161440 KUPARUK RIV UNIT 1 B-18AL3 LOG HEADERS ED C 27865 Digital Data 1/6/2017 Electronic File: 113-18AL3 EOW - NAD27.pdf ED C 27865 Digital Data 1/6/2017 Electronic File: 1B-18AL3 EOW - NAD27.txt - ED C 27866 Digital Data 1/6/2017 Electronic File: 1B-18AL3PB1 EOW - NAD27.pdf ED C 27866 Digital Data 1/6/2017 Electronic File: 1B-18AL3PB1 EOW - NAD27.txt Log C 27866 Log Header Scans 0 0 2161440 KUPARUK RIV UNIT 1B-18AL3PB1 LOG HEADERS ED C 27926 Digital Data 6920 9788 1/18/2017 Electronic Data Set, Filename: 16-18AL3 GAMMA RES.Ias ED C 27926 Digital Data 1/18/2017 Electronic File: 113-18AL3 2MD Final Logs.cgm ° ED C 27926 Digital Data 1/18/2017 Electronic File: 1B-18AL3 5MD Final Logs.cgm " ED C 27926 Digital Data 1/18/2017 Electronic File: 1B-18AL3 5TVDSS Final Logs.cgm ED C 27926 Digital Data 1/18/2017 Electronic File: 1B-18AL3 2MD Final Logs.pdf* ED C 27926 Digital Data Q 1/18/2017 Electronic File: 1B-18AL3 5MD Final Logs.pdf ED C 27926 Digital Data 1/18/2017 Electronic File: 1B-18AL3 5TVDSS Final Logs.pdf " ED C 27926 Digital Data 1/18/2017 Electronic File: 1B-18AL3 EOW - NAD27.pdf . ED C 27926 Digital Data 1/18/2017 Electronic File: 1B-18AL3 EOW - NAD27.txt ' ED C 27926 Digital Data 1/18/2017 Electronic File: 113-18AL3 Final Surveys TD 9788 Confirmed.csv ED C 27926 Digital Data 1/18/2017 Electronic File: 1 B-18AL3 Survey Listing.txt ED C 27926 Digital Data 1/18/2017 Electronic File: 16-18AL3 Surveys.txt AOGCC Pagel of 3 Monday, March 13, 2017 DATA SUBMITTAL COMPLIANCE REPORT 3/13/2017 Permit to Drill 2161440 Well Name/No. KUPARUK RIV UNIT 1 B-18AL3 Operator CONOCOPHILLIPS ALASKA INC API No. 50-029-22472-62-00 MD 9788 TVD 6619 Completion Date 12/14/2016 ED C 27926 Digital Data ED C 27926 Digital Data ED C 27926 Digital Data ED C 27926 Digital Data ED C 27926 Digital Data ED C 27926 Digital Data Log C 27926 Log Header Scans Log C 27927 Log Header Scans ED C 27927 Digital Data ED C 27927 Digital Data ED C 27927 Digital Data ED C 27927 Digital Data ED C 27927 Digital Data ED C 27927 Digital Data ED C 27927 Digital Data ED C 27927 Digital Data ED C 27927 Digital Data ED C 27927 Digital Data ED C 27927 Digital Data ED C 27927 Digital Data ED C 27927 Digital Data ED C 27927 Digital Data AOGCC Completion Status 1 -OIL Page 2 of 3 0 0 0 0 6920 9098 Current Status 1 -OIL UIC No 1/18/2017 Electronic File: 113- 18AL3_25_tapescan_BHI_CTK.txt -- 1/18/2017 Electronic File: 1B- 18AL3_5_tapescan_B H I_CTK.txt 1/18/2017 Electronic File: 1B-18AL3_output.tap 1/18/2017 Electronic File: 1B-18AL3 2MD Final Logs.tif- 1/18/2017 Electronic File: 1B-18AL3 5MD Final Logs.tif 1/18/2017 Electronic File: 1B-18AL3 5TVDSS Final Logs.tif 2161440 KUPARUK RIV UNIT 113-18AL3 LOG HEADERS 2161440 KUPARUK RIV UNIT 1B-18AL3PB1 LOG HEADERS 1/18/2017 Electronic Data Set, Filename: 1B-18AL3P61 GAMMA RES.las 1/18/2017 Electronic File: 1B-18AL3PB1 21VID Final Logs.cgm 1/18/2017 Electronic File: 1B-18AL3PB1 5MD Final Logs.cgm 1/18/2017 Electronic File: 16-18AL31D61 5TVDSS Final ' Logs.cgm 1/18/2017 Electronic File: 1B-18AL3PB1 2MD Final.pdf ' P 1/18/2017 Electronic File: 1B-18AL3PB1 5MD Final.pdf 1/18/2017 Electronic File: 113-18AL3PB1 5TVDSS Final.pdf 1/18/2017 Electronic File: 1B-18AL3PB1 EOW - NAD27.pdf 1/18/2017 Electronic File: 1B-18AL3PB1 EOW - NAD27.txt- 1/18/2017 Electronic File: 1B-18AL3PB1 Final Surveys TD 9098.csv 1/18/2017 Electronic File: 1B-18AL3PB1 Survey Listing.txt 1/18/2017 Electronic File: 1B-18AL3P61 Surveys.txt . 1/18/2017 Electronic File: 113- 18AL3PB1_25_tapescan_BHI_CTK.txt , 1/18/2017 Electronic File: 16- 18AL3PB 1 _5_tapescan_B H I_CTK.txt Monday, March 13, 2017 DATA SUBMITTAL COMPLIANCE REPORT 3/13/2017 Permit to Drill 2161440 Well Name/No. KUPARUK RIV UNIT 1 B-18AL3 Operator CONOCOPHILLIPS ALASKA INC API No. 50-029-22472-62-00 MD 9788 TVD 6619 Completion Date 12/14/2016 Completion Status 1 -OIL Current Status 1 -OIL UIC No ED C 27927 Digital Data 1/18/2017 Electronic File: 1B-18AL3PB1_output.tap " ED C 27927 Digital Data 1/18/2017 Electronic File: 1B-18AL3PB1 2MD Final Logs.tif ED C 27927 Digital Data 1/18/2017 Electronic File: 1B-18AL3PB1 5MD Final Logs.tif , ED C 27927 Digital Data 1/18/2017 Electronic File: 1B-18AL3PB1 5TVDSS Final Logs.tif Well Cores/Samples Information: Sample Interval Set Name Start Stop Sent Received Number Comments INFORMATION RECEIVED Completion Report c10 - Production Test InformatioNA Geologic Markers/Tops cy COMPLIANCE HISTORY Completion Date: 12/14/2016 Release Date: 11/10/2016 Description Directional / Inclination Data/ �Y) Mud Logs, Image Files, Digital Data Y NA Core Chips Y 6 Mechanical Integrity Test Information Y N Composite Logs, Image, Data Files�� Core Photographs Y Daily Operations Summary Y / Cuttings Samples Y /�lA / Laboratory Analyses Y / A Date Comments Comments: Compliance Reviewed By: Date: t -� AOGCC Page 3 of 3 Monday, March 13, 2017 REC E N 911 F r) c -O t r1 2c6 —�O ", 27,1 %73 x'90 JAN $ 2017 BAKER PRINT DISTRIBUTION LIST HUGHES AO G C C COMPANY ConocoPhillips Alaska, Inc. WELL NAME 1B-18AL3 FIELD Prudhoe Bay Unit COUNTY North Slope Borough BHI DISTRICT Alaska AUTHORIZED BY Patrick Rider EMAIL Patrick. Rider(obakerhughes.com STATUS Final Replacement: COMPANY ADDRESS (FEDEX WILL NOT DELIVER TO P.O. BO)J PERSON ATTENTION 4 21 6144 2792 6 Please sign and return one copy of this transmittal form to: ConocoPhillips Alaska, Inc. Tom Osterkamp DATA LOGGED 2 n \ I2011 700 G Street. M K. SENDEP Anchorage, Alaska 99510 to acknowledge receipt of this data. LOG TYPE GR - RES LOG DATE December 7, 2016 TODAYS DATE January 16, 2017 Revision No Details: Requested by: FIELD FINAL CD 1 CD LOGS LOGS I (digital/image) Surveys (Final Surveys) # OF PRINTS # OF PKIN 1 S # OF COPIES # OF COPIES # OF COPIE V � V 1 BP North Slope 0 0 0 EOA, PBOC, PRB-20 (Office 109) D&C Wells Project Aids Agatha Rutka & Barbara Glassmaker 900 E. Benson Blvd. Anchorage, Alaska 99508 2 (ConocoPhillips Alaska Inc. 0 0 0 Attn: Ricky Elgaricio TATO 3-344 700 G Street Anchorage, AK 99510 3,ExxonMobil,Alaska Attn: Lynda M. Yaskell and/or Leonardo Elias 3201 C Street, Suite 505 Anchorage, AK 99503 4 State of Alaska - AOGCC 1 1 1 Attn: Makana Bender 333 W. 7th Ave, Suite 100 Anchorage, Alaska 99501 5' DNR - Division of Oil & Gas *** 0 1 1 Attn: Resource Evaluation 1550 West7th Avenue, Suite 1100 Anchorage, Alaska 99501 ** Stamp "confidential' on all material deliver to DNR 6 BP Exploration (Alaska) Inc. 1 1 1 Petrotechnical Data Center, LR2-1 '900 E. Benson Blvd. Anchorage, Alaska 99508 TOTALS FOR THIS PAGE: 0 2 3 3 0 0 TOTALS FOR ALL PAGES: 0 2 3 3 0 0 ConocoPs philli RECEIVED JAN 18 2017 ADCCC ConocoPhillips (Alaska) Inc. -Kup1 Kuparuk River Unit Kuparuk 1B Pad 1 B-18AL3 50-029-22472-62 Baker Hughes INTEQ Definitive Survey Report 20 December, 2016 MA as BAKER HUGHES 216144 27 92 6 ConocoPhillips W/aI BAKER ConocoPhillips Definitive Survey Report HUGHES Company: ConocoPhillips (Alaska) Inc. -Kupl Local Co-ordinate Reference: Well 1 B-18 Project: Kuparuk River Unit TVD Reference: 1 B-18 @ 102.00usft Site: Kuparuk 1 B Pad MD Reference: 1 B-18 @ 102.00usft Well: 113-18 North Reference: True Wellbore: 1 B-18AL3 Survey Calculation Method: Minimum Curvature Design: 1 B-18AL3 Database: EDM Alaska NSK Sandbox 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 16-18 Well Position +N/ -S 0.00 usft Northing: 5,969,647.06 usft Latitude: 700 19'40.248 N +E/ -W 0.00 usft Easting: 550,148.90 usft Longitude: 149° 35'35.868 W Position Uncertainty 0.00 usft Wellhead Elevation: usft Ground Level: 61.20 usft Wellbore 1 B-18AL3 Magnetics Model Name Sample Date Declination Dip Angie Field Strength V) (�) (nT) BGG M2016 10/1/2016 18.01 80.96 57,551 Design 1B-18AL3 Audit Notes: Version: 1.0 Phase: ACTUAL Tie On Depth: 8,080.19 Vertical Section: Depth From (TVD) +N/ -S +E/ -W Direction (usft) (usft) (usft) (I 40.80 0.00 0.00 45.00 Survey Program Date 12/16/2016 From To Survey Survey (usft) (usft) Survey (Wellbore) Tool Name Description Start Date End Date 469.67 6,897.50 1 B-18 (1B-18) MWD MWD - Standard 4/28/1994 4/28/1994 7,392.00 8,080.19 1B-18AL3PB1 (1B-18AL3PB1) MWD MWD - Standard 11/5/2016 11/11/2016 8,094.00 9,750.37 1 B-1 8AL3 (1 B-1 8AL3) MWD MWD - Standard 11/26/2016 12/6/2016 12/20/2016 9:03:16AM Page 2 COMPASS 5000.1 Build 74 12/20/2016 9:03:16AM Page 3 COMPASS 5000.1 Build 74 ,�- ConocoPhillips //as ConocoPhillips HUGHES Definitive Survey Report Company: ConocoPhillips (Alaska) Inc. -Kupl Local Co-ordinate Reference: Well 1 B-18 Project: Kuparuk River Unit TVD Reference: 1 B-18 @ 102.00usft Site: Kuparuk 1 B Pad MD Reference: 1 B-18 @ 102.00usft Well: 1B-18 North Reference: True Wellbore: 1B-18AL3 Survey Calculation Method: Minimum Curvature Design: 1B-18AL3 Database: EDM Alaska NSK Sandbox Survey Map Map Vertical MD Inc Azi TVD TVDSS +Nl-S +E/ -W Northing Easting DLS Section (usft) (°) (°) (usft) (usft) (usft) (usft) (°1100') Survey Tool Name Annotation (ft) (ft) (ft) 8,080.19 93.41 60.46 6,705.33 6,603.34 -2,562.46 198.59 5,967,08623 550,364.59 7.32 -1,671.51 MWD (2) TIP 8,094.00 93.41 59.44 6,704.51 6,602.51 -2,555.56 210.52 5,967,093.21 550,376.47 7.37 -1,658.19 MWD (3) KOP 8,124.97 87.63 61.00 6,704.23 6,602.23 -2,540.18 237.38 5,967,108.76 550,403.23 19.33 -1,628.33 MWD (3) 8,160.07 87.15 67.21 6,705.83 6,603.83 -2,524.88 268.91 5,967,124.28 550,434.65 17.73 -1,595.21 MWD (3) 8,184.96 86.59 63.49 6,707.19 6,605.19 -2,514.52 291.50 5,967,134.79 550,457.17 15.09 -1,571.91 MWD (3) 8,215.15 88.40 58.79 6,708.51 6,606.51 -2,499.96 317.90 5,967,149.52 550,483.47 16.67 -1,542.95 MWD (3) 8,245.05 89.75 53.30 6,709.00 6,607.00 -2,483.27 342.69 5,967,166.38 550,508.15 18.91 -1,513.62 MWD (3) 8,275.11 90.71 47.17 6,708.87 6,606.87 -2,464.05 365.78 5,967,185.75 550,531.11 20.64 -1,483.70 MWD (3) 8,305.21 90.06 43.36 6,708.67 6,606.67 -2,442.87 387.16 5,967,207.07 550,552.34 12.84 -1,453.61 MWD (3) 8,335.33 91.78 38.58 6,708.19 6,606.19 -2,420.14 406.90 5,967,229.93 550,571.93 16.86 -1,423.57 MWD (3) 8,365.26 90.61 33.09 6,707.56 6,605.56 -2,395.89 424.41 5,967,254.29 550,589.28 18.75 -1,394.04 MWD (3) 8,395.00 90.33 27.13 6,707.32 6,605.32 -2,370.18 439.33 5,967,280.10 550,604.01 20.06 -1,365.32 MWD (3) 8,425.10 89.36 23.25 6,707.40 6,605.40 -2,342.94 452.13 5,967,307.42 550,616.64 13.29 -1,337.00 MWD (3) 8,454.98 89.45 18.45 6,707.71 6,605.71 -2,315.03 462.77 5,967,335.40 550,627.08 16.07 -1,309.75 MWD (3) 8,485.19 90.37 13.44 6,707.76 6,605.76 -2,285.99 471.06 5,967,364.49 550,635.18 16.86 -1,283.35 MWD (3) 8,515.33 90.92 8.94 6,707.42 6,605.42 -2,256.43 476.91 5,967,394.08 550,640.83 15.04 -1,258.31 MWD (3) 8,545.24 90.52 3.74 6,707.04 6,605.04 -2,226.72 480.21 5,967,423.82 550,643.94 17.44 -1,234.97 MWD (3) 8,575.22 91.44 3.09 6,706.53 6,604.53 -2,196.80 482.00 5,967,453.75 550,645.52 3.76 -1,212.55 MWD (3) 8,605.25 91.29 7.89 6,705.81 6,603.81 -2,166.92 484.87 5,967,483.64 550,648.19 15.99 -1,189.39 MWD (3) 8,635.13 91.35 12.12 6,705.12 6,603.12 -2,137.51 490.06 5,967,513.08 550,653.18 14.15 -1,164.93 MWD (3) 8,665.25 91.66 17.04 6,704.33 6,602.33 -2,108.38 497.63 5,967,542.26 550,660.57 16.36 -1,138.97 MWD (3) 8,695.68 92.00 21.51 6,703.36 6,601.36 -2,079.68 507.67 5,967,571.02 550,670.41 14.72 -1,111.58 MWD (3) 8,725.12 92.70 25.92 6,702.15 6,600.15 -2,052.75 519.50 5,967,598.02 550,682.06 15.15 -1,084.18 MWD (3) 8,755.27 92.64 31.07 6,700.75 6,598.75 -2,026.29 533.86 5,967,624.58 550,696.24 17.06 -1,055.31 MWD (3) 8,782.53 92.73 33.86 6,699.47 6,597.47 -2,003.32 548.48 5,967,647.64 550,710.70 10.23 -1,028.73 MWD (3) 8,814.77 90.18 37.40 6,698.65 6,596.65 -1,977.13 567.25 5,967,673.95 550,729.29 13.53 -996.94 MWD (3) 8,846.88 84.46 36.57 6,700.15 6,598.15 -1,951.52 586.54 5,967,699.69 550,748.41 18.00 -965.19 MWD (3) 8,877.61 83.91 31.86 6,703.27 6,601.27 -1,926.25 603.72 5,967,725.08 550,765.42 15.35 -935.17 MWD (3) 8,905.05 85.85 27.13 6,705.72 6,603.72 -1,902.47 617.17 5,967,748.94 550,778.71 18.57 -908.84 MWD (3) 8,935.29 86.77 21.91 6,707.66 6,605.66 -1,875.02 629.69 5,967,776.47 550,791.05 17.49 -880.58 MWD (3) 12/20/2016 9:03:16AM Page 3 COMPASS 5000.1 Build 74 ConocoPhillips ConocoPhillips Definitive Survey Report Company: ConocoPhillips (Alaska) Inc. -Kup1 Local Co-ordinate Reference: Project: Kuparuk River Unit TVD Reference: Site: Kuparuk 1 B Pad MD Reference: Well: 113-18 North Reference: Wellbore: 1 B-18AL3 Survey Calculation Method: Design: 1 B-18AL3 Database: Survey Well 1 B-18 1 B-18 @ 102.00usft 1 B-18 @ 102.00usft True Minimum Curvature EDM Alaska NSK Sandbox Annotation BAKER HUGHES 12120/2016 9103116AM Page 4 COMPASS 5000.1 Build 74 Vertical DLS Section Survey Tool Name (°1100') Map Map MD Inc Azi TVD TVDSS +N/ -S +E/ -W Northing Easting (usft) (°) (°) (usft) (usft) (usft) (usft) (ft) (ft) 8,965.00 88.87 17.56 6,708.80 6,606.80 -1,847.08 639.71 5,967,804.47 550,800.88 } 9,001.87 90.92 12.04 6,708.86 6,606.86 -1,811.45 649.13 5,967,840.16 550,810.06 9,030.21 93.19 8.32 6,707.85 6,605.85 -1,783.58 654.13 5,967,868.06 550,814.87 9,060.33 95.62 3.65 6,705.53 6,603.53 -1,753.73 657.26 5,967,897.93 550,817.81 9,090.23 98.88 359.57 6,701.76 6,599.76 -1,724.09 658.10 5,967,927.57 550,818.45 9,119.97 100.47 354.66 6,696.76 6,594.76 -1,694.82 656.63 5,967,956.83 550,816.78 9,152.89 102.17 352.23 6,690.29 6,588.29 -1,662.76 652.95 5,967,988.87 550,812.88 9,180.01 102.03 356.95 6,684.61 6,582.61 -1,636.36 650.45 5,968,015.24 550,810.21 9,209.88 101.27 1.24 6,678.57 6,576.57 -1,607.12 649.99 5,968,044.48 550,809.55 9,239.85 101.13 5.14 6,672.75 6,570.75 -1,577.77 651.62 5,968,073.83 550,810.99 9,269.80 100.28 9.75 6,667.18 6,565.18 -1,548.60 655.44 5,968,103.02 550,814.61 9,299.80 99.39 14.15 6,662.06 6,560.06 -1,519.69 661.56 5,968,131.97 550,820.53 9,329.81 98.82 18.54 6,657.30 6,555.30 -1,491.26 669.89 5,968,160.45 550,828.68 9,359.83 98.20 23.33 6,652.86 6,550.86 -1,463.54 680.50 5,968,188.24 550,839.10 9,389.82 96.78 27.79 6,648.95 6,546.95 -1,436.73 693.33 5,968,215.14 550,851.75 9,419.83 96.70 30.76 6,645.43 6,543.43 -1,410.73 707.90 5,968,241.22 550,866.14 9,449.80 96.56 30.23 6,641.96 6,539.97 -1,385.08 723.01 5,968,266.97 550,881.08 i 9,479.87 96.15 26.86 6,638.64 6,536.64 -1,358.83 737.28 5,968,293.32 550,895.18 -- 9,509.83 95.78 22.83 6,635.52 6,533.52 -1,331.80 749.80 5,968,320.43 550,907.51 9,539.90 93.38 24.08 6,633.12 6,531.12 -1,304.31 761.73 5,968,348.00 550,919.26 9,570.05 92.00 27.43 6,631.70 6,529.70 -1,277.19 774.82 5,968,375.21 550,932.16 ' 9,600.05 92.61 30.90 6,630.50 6,528.50 -1,251.01 789.42 5,968,401.47 550,946.59 9,630.10 92.76 34.07 6,629.09 6,527.09 -1,225.70 805.54 5,968,426.89 550,962.54 9,660.05 91.44 36.89 6,627.99 61525.99 -1,201.33 822.91 5,968,451.38 550,979.74 9,690.16 91.69 41.40 6,627.17 6,525.17 -1,177.99 841.91 5,968,474.84 550,998.58 9,720.10 94.58 41.53 6,625.53 6,523.53 -1,155.59 861.70 5,968,497.37 551,018.22 9,750.37 95.44 45.15 6,622.89 6,520.89 -1,133.66 882.39 5,968,519.43 551,038.76 9,788.00 95.44 45.15 6,619.32 6,517.32 -1,107.24 908.95 5,968,546.02 551,065.14 Annotation BAKER HUGHES 12120/2016 9103116AM Page 4 COMPASS 5000.1 Build 74 Vertical DLS Section Survey Tool Name (°1100') (ft) 16.25 -853.74 MWD (3) 15.97 -821.89 MWD (3) 15.37 -798.64 MWD (3) 17.44 -775.32 MWD (3) 17.38 -753.77 MWD (3) 17.13 -734.11 MWD (3) 8.89 -714.04 MWD (3) 17.03 -697.15 MWD (3) 14.29 -676.80 MWD (3) 12.77 -654.89 MWD (3) 15.39 531.56 MWD (3) 14.75 -606.79 MWD (3) 14.57 -580.80 MWD (3) 15.91 553.69 MWD (3) 15.49 -525.66 MWD (3) 9.83 -496.98 MWD (3) 1.82 -468.16 MWD (3) 11.22 -439.50 MWD (3) 13.44 -411.53 MWD (3) 8.99 -383.66 MWD (3) 12.01 -355.23 MWD (3) 11.73 -326.39 MWD (3) 10.55 -297.09 MWD (3) 10.39 -267.58 MWD (3) 15.00 -237.65 MWD (3) 9.66 -207.81 MWD (3) 12.25 -177.68 MWD (3) 0.00 -140.22 PROJECTED to TD Annotation BAKER HUGHES 12120/2016 9103116AM Page 4 COMPASS 5000.1 Build 74 EEI V Er) WIN "a ■ BAKER JAN 10 2017 PRINT DISTRIBUTION LIST HUGHES nn OGCC COMPANY ConocoPhillips Alaska, Inc. WELL NAME 1B-18AL3PB1 FIELD Prudhoe Bay Unit COUNTY North Slope Borough BHI DISTRICT Alaska AUTHORIZED BY Patrick Rider EMAIL Patrick. Rider(a)bakerhughes.com STATUS Final Replacement: 21 6144 2%92'7 Please sign and return one copy of this transmittal form to: ConocoPhillips Alaska, Inc. Tom Osterkamp DATA LOGGED700 G Street. 2-1 � /2011M.K.6ENDEP Anchorage, Alaska 99510 to acknowledge receipt of this data. LOG TYPE GR - RES LOG DATE December 7, 2016 TODAYS DATE January 16, 2017 Revision No Details: Requested by: COMPANY FIELD FINAL CD LOGS LOGS(digital/image)#Surveys ADDRESS (FEDEX WILL NOT DELIVER TO P.O. BOJj Surveys) # OF 1'KIN I S 1#(Final COMPANY FIELD FINAL CD CD ADDRESS (FEDEX WILL NOT DELIVER TO P.O. BOJj 1#(Final PERSON ATTENTION # OF PRINTS OF COPIE1 # OF COPIES OFCOPIES 'BP North Slope 0 0 0 EOA, PBOC, PRB-20 (Office 109) D&C Wells Project Aids Agatha Rutka & Barbara Glassmaker 900 E. Benson Blvd. Anchorage, Alaska 99508 2 ConocoPhillips Alaska Inc. 0 0 0 Attn: Ricky Elgaricio ATO 3-344 700 G Street Anchorage, AK 99510 3 IExxonMobil,Alaska 0 0 0 Attn: Lynda M. Yaskell and/or Leonardo Elias 3201 C Street,Suite 505 Anchorage, AK 99503 4I State ofAlaska -AOGCC Attn: Makana Bender 1333 W. 7th Ave, Suite 100 (Anchorage, Alaska 99501 51 DNR - Division of Oil & GasAttn: Resource Evaluation 550 West 7th Avenue, Suite 1100 Anchorage, Alaska 99501 *** Stamp "confidential' on allmaterial deli, 6 BP Exploration (Alaska) Inc. Petrotechnical Data Center, LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 TOTALS FOR THIS PAGE: 0 2 3 3 0 0 TOTALS FOR ALL PAGES: 0 2 3 3 0 0 21 6144 27 92 7 ConocoPhillips RECEIVE® JAN 18 2017 AOGCC ConocoPhillips (Alaska) Inc. -Kup1 Kuparuk River Unit Kuparuk 1 B Pad 1 B-18AL3PB1 50-029-22472-70 Baker Hughes INTEQ //a I BAKER Definitive Survey Report HUGHES 20 December, 2016 ConocoPhillips MAP aI BHUGHES ConocoPhillips Definitive Survey Report Company: ConocoPhillips (Alaska) Inc. -Kupl Local Co-ordinate Reference: Well 1B-18 Project: Kuparuk River Unit TVD Reference: 113-18 @ 102.O0usft Site: Kuparuk 1B Pad MD Reference: 1B-18 @ 102.00usft Well: 113-18 North Reference: True Wellbore: 1B-18AL3PB1 Survey Calculation Method: Minimum Curvature Design: 1B-18AL3PB1 Database: EDM Alaska NSK Sandbox 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 1B-18 Well Position +N/ -S 0.00 usft Northing: 5,969,647.06 usft Latitude: 700 19'40.248 N +E/ -W 0.00 usft Easting: 550,148.90usft Longitude: 149° 35'35.868 W Position Uncertainty 0.00 usft Wellhead Elevation: usft Ground Level: 61.20 usft Wellbore 1B-18AL3PB1 Magnetics Model Name Sample Date Declination Dip Angle Field Strength (I (°) ("T) BGG M2016 10/1/2016 18.01 80.96 57,551 Design 1B-18AL3PB1 Audit Notes: Version: 1.0 Phase: ACTUAL Tie On Depth: 6,897.50 Vertical Section: Depth From (TVD) +N/ -S +E/ -W Direction (usft) (usft) (usft) (°) 40.80 0.00 0.00 45.00 Survey Program Date 11/11/2016 From To Survey Survey (usft) (usft) Survey (Wellbore) Tool Name Description Start Date End Date 469.67 6,897.50 1 B-18 (16-18) MWD MWD - Standard 4/28/1994 4/28/1994 7,392.00 9,056.07 1B-18AL3PB1 (16-18AL3PB1) MWD MWD - Standard 11/5/2016 11/11/2016 12/20/2016 8:58:06AM Page 2 COMPASS 5000.1 Build 74 ConocoPhillips ConocoPhillips Definitive Survey Report RUN BHUGHES Company: ConocoPhillips (Alaska) Inc. -Kupl Local Co-ordinate Reference: Well 1 B-18 Map Project: Kuparuk River Unit TVD Reference: 1 B-18 @ 102.00usft Site: Kuparuk 1 B Pad MD Reference: 1 B-18 @ 102.00usft TVD Well: 113-18 North Reference: True Northing Wellbore: 1B-18AL3PB1 Survey Calculation Method: Minimum Curvature Annotation Design: 1 B-18AL3PB1 Database: EDM Alaska NSK Sandbox usft ( ) Survey Map Map Vertical MD Inc Azi TVD TVDSS +W -S +E/ -W Northing Eating DLS Section Survey Tool Name Annotation usft ( ) (°) (°) usft ( ) usft ( ) us ( ft) (usft) {ft) (ft) (°1100') (ft) 6,897.50 43.20 180.80 6,227.45 6,125.45 -2,108.07 -221.61 5,967,537.76 549,941.40 0.50 -1,647.33 MWD (2) TIP 7,392.00 39.69 191.22 6,598.51 6,496.51 -2,432.69 -254.75 5,967,212.96 549,910.44 1.56 -1,900.30 MWD (2) KOP 7,420.23 45.15 186.48 6,619.35 6,517.35 -2,451.49 -257.64 5,967,194.14 549,907.68 22.40 -1,915.64 MWD (2) 7,452.15 52.87 182.05 6,640.28 6,538.28 -2,475.49 -259.37 5,967,170.13 549,906.10 26.35 -1,933.84 MWD (2) 7,482.15 60.01 178.52 6,656.85 6,554.85 -2,500.47 -259.47 5,967,145.16 549,906.18 25.73 -1,951.57 MWD (2) 7,512.62 61.84 175.39 6,671.66 6,569.66 -2,527.05 -258.05 5,967,118.58 549,907.77 10.81 -1,969.36 MWD (2) 7,542.18 63.42 166.73 6,685.27 6,583.27 -2,552.95 -253.96 5,967,092.72 549,912.03 26.55 -1,984.78 MWD (2) 7,562.49 64.58 161.21 6,694.18 6,592.18 -2,570.48 -248.92 5,967,075.22 549,917.19 25.08 -1,993.62 MWD (2) 7,590.41 67.65 148.25 6,705.52 6,603.52 -2,593.48 -238.02 5,967,052.29 549,928.24 43.82 -2,002.18 MWD (2) 7,620.38 71.93 135.09 6,715.92 6,613.92 -2,615.45 -220.59 5,967,030.44 549,945.81 43.59 -2,005.39 MWD (2) 7,650.21 83.51 129.03 6,722.25 6,620.26 -2,634.91 -198.98 5,967,011.13 549,967.56 43.58 -2,003.86 MWD (2) 7,670.45 91.23 124.90 6,723.18 6,621.18 -2,647.06 -182.84 5,966,999.10 549,983.77 43.24 -2,001.04 MWD (2) 7,690.50 97.73 118.72 6,721.62 6,619.62 -2,657.59 -165.87 5,966,988.68 550,000.81 44.66 -1,996.49 MWD (2) 7,720.45 95.81 105.56 6,718.07 6,616.07 -2,668.76 -138.38 5,966,977.69 550,028.37 44.10 -1,984.95 MWD (2) 7,750.39 93.75 93.61 6,715.57 6,613.57 -2,673.72 -109.02 5,966,972.93 550,057.76 40.36 -1,967.69 MWD (2) 7,780.21 91.75 80.84 6,714.13 6,612.13 -2,672.27 -79.33 5,966,974.57 550,087.44 43.29 -1,945.68 MWD (2) 7,810.27 90.58 73.25 6,713.52 6,611.52 -2,665.54 -50.07 5,966,981.50 550,116.65 25.54 -1,920.22 MWD (2) 7,840.09 89.94 71.88 6,713.38 6,611.38 -2,656.61 -21.62 5,966,990.63 550,145.04 5.07 -1,893.79 MWD (2) 7,870.45 90.28 71.01 6,713.32 6,611.32 -2,646.95 7.16 5,967,000.48 550,173.75 3.08 -1,866.61 MWD (2) 7,900.35 91.53 70.60 6,712.85 6,610.85 -2,637.12 35.40 5,967,010.49 550,201.92 4.40 -1,839.69 MWD (2) 7,930.48 91.53 68.60 6,712.05 6,610.05 -2,626.62 63.63 5,967,021.18 550,230.07 6.64 -1,812.31 MWD (2) 7,960.57 91.47 66.69 6,711.26 6,609.26 -2,615.18 91.44 5,967,032.80 550,257.81 6.35 -1,784.55 MWD (2) 7,990.31 92.12 65.43 6,710.33 6,608.33 -2,603.12 118.61 5,967,045.05 550,284.90 4.77 -1,756.81 MWD (2) 8,020.23 92.98 63.60 6,709.00 6,607.00 -2,590.26 145.59 5,967,058.08 550,311.79 6.75 -1,728.64 MWD (2) 8,050.50 93.81 62.60 6,707.20 6,605.20 -2,576.59 172.54 5,967,071.93 550,338.64 4.29 -1,699.92 MWD (2) 8,080.19 93.41 60.46 6,705.33 6,603.34 -2,562.46 198.59 5,967,086.23 550,364.59 7.32 -1,671.51 MWD (2) 8,110.58 93.41 58.21 6,703.53 6,601.53 -2,546.99 224.68 5,967,101.87 550,390.57 7.39 -1,642.12 MWD (2) 8,140.61 93.93 56.27 6,701.60 6,599.60 -2,530.78 249.88 5,967,118.26 550,415.66 6.68 -1,612.84 MWD (2) 8,170.22 93.81 55.51 6,699.61 6,597.61 -2,514.21 274.34 5,967,134.98 550,440.01 2.59 -1,583.83 MWD (2) 8,200.23 93.47 53.52 6,697.70 6,595.70 -2,496.82 298.72 5,967,152.53 550,464.28 6.71 -1,554.29 MWD (2) 12120/2016 &58:06AM Page 3 COMPASS 5000.1 Build 74 ConocoPhillips ®/as BAKERER ConocoPhilli s Definitive Survey RepoHUGHES Company: ConocoPhillips (Alaska) Inc. -Kupl Local Co-ordinate Reference: Well 1 B-18 Project: Kuparuk River Unit TVD Reference: 1 B-18 @ 102.00usft Site: Kuparuk 1 B Pad MD Reference: 1 B-18 @ 102.00usft Well: 113-18 North Reference: True Wellbore: 1 B-18AL3PB1 Survey Calculation Method: Minimum Curvature Design: 1B-18AL3PB1 Database: EDM Alaska NSK Sandbox Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/ -S *E1 -W Northing Easting DLS Section Survey Tool Name Annotation (usft) (°) (I (usft) (usft) (usft) (usft) (ft) (ft) (°/100') (ft) 8,230.35 92.21 54.14 6,696.21 6,594.21 -2,479.07 323.01 5,967,170.44 550,488.44 4.66 -1,524.57 MWD (2) 8,260.36 90.52 54.54 6,695.49 6,593.49 -2,461.58 347.38 5,967,188.09 550,512.69 5.79 -1,494.96 MWD (2) 8,291.67 88.34 56.39 6,695.81 6,593.81 -2,443.83 373.17 5,967,206.01 550,538.36 9.13 -1,464.18 MWD (2) 8,320.25 89.82 57.60 6,696.26 6,594.26 -2,428.27 397.14 5,967,221.74 550,562.22 6.69 -1,436.23 MWD (2) 8,350.60 89.39 57.58 6,696.47 6,594.47 -2,412.00 422.76 5,967,238.17 550,587.73 1.42 -1,406.61 MWD (2) 8,380.23 86.41 56.31 6,697.56 6,595.56 -2,395.85 447.57 5,967,254.48 550,612.43 10.93 -1,377.64 MWD (2) 8,410.27 85.36 55.21 6,699.71 6,597.71 -2,379.00 472.34 5,967,271.51 550,637.08 5.06 -1,348.21 MWD (2) 8,440.32 87.27 55.19 6,701.65 6,599.65 -2,361.88 496.96 5,967,288.78 550,661.59 6.36 -1,318.70 MWD (2) 8,470.14 85.76 54.61 6,703.46 6,601.46 -2,344.77 521.32 5,967,306.06 550,685.82 5.42 -1,289.38 MWD (2) 8,500.21 85.02 53.03 6,705.88 6,603.88 -2,327.07 545.51 5,967,323.91 550,709.90 5.79 -1,259.76 MWD (2) 8,530.19 85.39 53.34 6,708.38 6,606.38 -2,309.17 569.42 5,967,341.97 550,733.69 1.61 -1,230.19 MWD (2) 8,560.07 86.28 53.61 6,710.55 6,608.55 -2,291.44 593.37 5,967,359.86 550,757.52 3.11 -1,200.71 MWD (2) 8,590.19 85.94 54.23 6,712.60 6,610.60 -2,273.74 617.66 5,967,377.72 550,781.68 2.34 -1,171.03 MWD (2) 8,619.30 85.54 54.47 6,714.76 6,612.76 -2,256.82 641.25 5,967,394.80 550,805.16 1.60 -1,142.38 MWD (2) 8,650.11 85.52 56.55 6,717.16 6,615.16 -2,239.43 666.56 5,967,412.35 550,830.35 6.73 -1,112.18 MWD (2) 8,680.29 85.24 56.39 6,719.59 6,617.59 -2,222.81 691.64 5,967,429.14 550,855.31 1.07 -1,082.70 MWD (2) 8,710.37 85.79 57.52 6,721.94 6,619.94 -2,206.46 716.78 5,967,445.65 550,880.34 4.17 -1,053.36 MWD (2) 8,740.26 84.03 58.69 6,724.59 6,622.59 -2,190.73 742.05 5,967,461.55 550,905.51 7.06 -1,024.37 MWD (2) 8,770.31 82.74 60.36 6,728.06 6,626.06 -2,175.59 767.78 5,967,476.86 550,931.13 6.99 -995.47 MWD (2) 8,800.41 81.42 62.46 6,732.20 6,630.20 -2,161.32 793.95 5,967,491.30 550,957.20 8.18 -966.88 MWD (2) 8,830.47 81.87 64.30 6,736.57 6,634.57 -2,148.00 820.54 5,967,504.80 550,983.70 6.24 -938.66 MWD (2) 8,860.54 83.63 65.09 6,740.37 6,638.37 -2,135.25 847.51 5,967,517.73 551,010.58 6.41 -910.57 MWD (2) 8,890.56 84.90 66.11 6,743.37 6,641.37 -2,122.91 874.71 5,967,530.25 551,037.69 5.42 -882.61 MWD (2) 8,920.12 86.74 66.10 6,745.52 6,643.52 -2,110.97 901.66 5,967,542.37 551,064.56 6.22 -855.11 MWD (2) 8,950.34 88.25 66.78 6,746.84 6,644.84 -2,098.90 929.33 5,967,554.62 551,092.15 5.48 -827.01 MWD (2) 8,980.26 90.28 66.59 6,747.23 6,645.23 -2,087.06 956.81 5,967,566.64 551,119.54 6.81 -799.21 MWD (2) 9,010.34 92.73 66.92 6,746.44 6,644.44 -2,075.20 984.43 5,967,578.69 551,147.08 8.22 -771.29 MWD (2) 9,040.30 92.71 68.37 6,745.01 6,643.01 -2,063.81 1,012.11 5,967,590.26 551,174.68 4.83 -743.67 MWD (2) 9,056.07 93.81 67.33 6,744.12 6,642.12 -2,057.88 1,026.69 5,967,596.29 551,189.22 9.59 -729.16 MWD (2) 9,098.00 93.81 67.33 6,741.33 6,639.33 -2,041.75 1,065.30 5,967,612.67 551,227.72 0.00 -690.46 PROJECTED to TD 12/20/2016 8:58:06AM Page 4 COMPASS 5000.1 Build 74 FeAlik- 2 BAKERDate: HUGHES To: JAN 0 6 2017 Letter of Transmittal DATA LOGGED December 22, 2016 �� BENDER Makana Bender AOGCC 333 West 7th Ave, Suite 100 Anchorage, Alaska 99501 From: Yosha Ragbirsingh / Michael Soper Baker Hughes INTEQ 795 East 94th Avenue Anchorage, Alaska 99515 Please find enclosed the directional survey data for the following well(s): 1B -18A 2 1 6108 27 86 2 1B-18AL1 2 1 6 1 0 9 27 86 3 1 B-18AL2 1B-18AL3PB1 1 61 10 27 86 4 1B-18AL3 .4 6 1 4 4 27 86 5 1B-18AL3-01 2 1 6 1 4 4 27 86 6 21 61 56 27867 (6) Total prints Enclosed for each well(s): 1 hardcopy print of directional survey reports (NAD27) 1 compact disk containing electronic survey files Note: Please feel free to send us an email in place of return mail. Michael Soper, Baker Hughes, Project Engineer Michael.Soper@BakerHughes.com Yosha Ragbirsingh, Baker Hughes, Survey Manager Yosha.Ragbirsingh@BakerHughes.com ConocoPh i l l ips RECEIVED JAN 0 6 2017 ConocoPhillips (Alaska) Inc. -Kup1 Kuparuk River Unit Kuparuk 1 B Pad 1 B-18AL3PB1 50-029-22472-70 Baker Hughes INTEQ Definitive Survey Report 20 December, 2016 21 61 4 f FeA FA I BAKER HUGHES 'V" ConocoPhillips ConocoPhillips Definitive Survey Report Company: ConocoPhillips (Alaska) Inc. -Kupl Local Co-ordinate Reference: Well 1 B-18 Project: Kuparuk River Unit TVD Reference: 1 B-18 @ 102.00usft Site: Kuparuk 1B Pad MD Reference: 1 B-18 @ 102.00usft Well: 1 B-18 North Reference: True Wellbore: 1 B-18AL3PB1 Survey Calculation Method: Minimum Curvature Design: 1B-18AL3PB1 Database: EDM Alaska NSK Sandbox 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 1B-18 Well Position +N/ -S 0.00 usft Northing: 5,969,647.06 usft Latitude: +E/ -W 0.00 usft Easting: 550,148.90usft Longitude: Position Uncertainty 0.00 usft Wellhead Elevation: usft Ground Level: Wellbore 1B-18AL3PB1 Magnetics Model Name Sample Date Declination (°) Dip Angle (1) BGGM2016 10/1/2016 18.01 80.96 Design 1B-18AL3PB1 Audit Notes: Version: 1.0 Phase: ACTUAL Tie On Depth: 61897.50 Vertical Section: Depth From (TVD) +N/ -S +E/ -W Direction (usft) (usft) (usft) (1) 40.80 0.00 0.00 45.00 Survey Program Date 11/11/2016 From To Survey (usft) (usft) Survey (Wellbore) Tool Name Description Start Date 469.67 6,897.50 1 B-18 (1 B-18) MWD MWD - Standard 4/28/1994 7,392.00 9,056.07 1B-18AL3PB1 (1B-18AL3PB1) MWD MWD - Standard 11/5/2016 rias BAKER HUGHES 70° 19'40.248 N 149° 35'35.868 W 61.20 usft Field Strength (nT) 57,551 Survey End Date 4/28/1994 11/11/2016 12120/2016 8:58:06AM Page 2 COMPASS 5000.1 Build 74 Survey ConocoPhillips F/RS ConocoPhillips Definitive Survey Report BHUGHES Company: ConocoPhillips (Alaska) Inc. -Kupl Local Co-ordinate Reference: Well 1 B-18 Project: Kuparuk River Unit TVD Reference: 1 B-18 @ 102.00usft Azi Site: Kuparuk 1B Pad MD Reference: 1 B-18 @ 102.00usft +E/ -W Well: 1 B-18 North Reference: True Section Wellbore: 1B-18AL3PB1 Survey Calculation Method: Minimum Curvature (1) Design: 1 B-18AL3PB1 Database: EDM Alaska NSK Sandbox (usft) Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/ -S +E/ -W Northing Easting DLS Section (usft) (1) (1) (usft) (usft) (usft) (usft) (°/100') Survey Tool Name Annotation (ft) (ft) (ft) 6,897.50 43.20 180.80 6,227.45 6,125.45 -2,108.07 -221.61 5,967,537.76 549,941.40 0.50 -1,647.33 MWD (2) TIP , 7,392.00 39.69 191.22 6,598.51 6,496.51 -2,432.69 -254.75 5,967,212.96 549,910.44 1.56 -1,900.30 MWD (2) KOP 7,420.23 45.15 186.48 6,619.35 6,517.35 -2,451.49 -257.64 5,967,194.14 549,907.68 22.40 -1,915.64 MWD (2) 7,452.15 52.87 182.05 6,640.28 6,538.28 -2,475.49 -259.37 5,967,170.13 549,906.10 26.35 -1,933.84 MWD (2) ,. 7,482.15 60.01 178.52 6,656.85 6,554.85 -2,500.47 -259.47 5,967,145.16 549,906.18 25.73 -1,951.57 MWD (2) 7,512.62 61.84 175.39 6,671.66 6,569.66 -2,527.05 -258.05 5,967,118.58 549,907.77 10.81 -1,969.36 MWD (2) 7,542.18 63.42 166.73 6,685.27 6,583.27 -2,552.95 -253.96 5,967,092.72 549,912.03 26.55 -1,984.78 MWD (2) 7,562.49 64.58 161.21 6,694.18 6,592.18 -2,570.48 -248.92 5,967,075.22 549,917.19 25.08 -1,993.62 MWD (2) 7,590.41 67.65 146.25 6,705.52 6,603.52 -2,593.48 -238.02 5,967,052.29 549,928.24 43.82 -2,002.18 MWD (2) 7,620.38 71.93 135.09 6,715.92 6,613.92 -2,615.45 -220.59 5,967,030.44 549,945.81 43.59 -2,005.39 MWD (2) 7,650.21 83.51 129.03 6,722.25 6,620.26 -2,634.91 -198.98 5,967,011.13 549,967.56 43.58 -2,003.86 MWD (2) 7,670.45 91.23 124.90 6,723.18 6,621.18 -2,647.06 -182.84 5,966,999.10 549,983.77 43.24 -2,001.04 MWD (2) 7,690.50 97.73 118.72 6,721.62 6,619.62 -2,657.59 -165.87 5,966,988.68 550,000.81 44.66 -1,996.49 MWD (2) 7,720.45 95.81 105.56 6,718.07 6,616.07 -2,668.76 -138.38 5,966,977.69 550,028.37 44.10 -1,984.95 MWD (2) - 7,750.39 93.75 93.61 6,715.57 6,613.57 -2,673.72 -109.02 5,966,972.93 550,057.76 40.36 -1,967.69 MWD (2) 7,780.21 91.75 80.84 6,714.13 6,612.13 -2,672.27 -79.33 5,966,974.57 550,087.44 43.29 -1,945.68 MWD (2) 7,810.27 90.58 73.25 6,713.52 6,611.52 -2,665.54 -50.07 5,966,981.50 550,116.65 25.54 -1,920.22 MWD (2) - - 7,840.09 89.94 71.88 6,713.38 6,611.38 -2,656.61 -21.62 5,966,990.63 550,145.04 5.D7 -1,893.79 MWD (2) 7,870.45 90.28 71.01 6,713.32 6,611.32 -2,646.95 7.16 5,967,000.48 550,173.75 3.08 -1,866.61 MWD (2) 7,900.35 91.53 70.60 6,712.85 6,610.85 -2,637.12 35.40 5,967,010.49 550,201.92 4.40 -1,839.69 MWD (2) 7,930.48 91.53 68.60 6,712.05 6,610.05 -2,626.62 63.63. 5,967,021.18 550,230.07 6.64 -1,812.31 MWD (2) 7,960.57 91.47 66.69 6,711.26 6,609.26 -2,615.18 91.44 5,967,032.80 550,257.81 6.35 -1,784.55 MWD (2) 7,99D.31 92.12 65.43 6,710.33 6,608.33 -2,603.12 118.61 5,967,045.05 550,284.90 4.77 -1,756.81 MWD (2) 8,020.23 92.98 63.60 6,709.00 6,6D7.00 -2,59D.26 145.59 5,967,058.08 550,311.79 6.75 -1,728.64 MWD (2) 8,050.50 93.81 62.60 6,707.20 6,605.20 -2,576.59 172.54 5,967,071.93 550,338.64 4.29 -1,699.92 MWD (2) 8,080.19 93.41 60.46 6,705.33 6,603.34 -2,562.46 198.59 5,967,086.23 550,364.59 7.32 -1,671.51 MWD (2) 8,110.58 93.41 58.21 6,703.53 6,601.53 -2,546.99 224.68 5,967,101.87 550,390.57 7.39 -1,642.12 MWD (2) 8,140.61 93.93 56.27 6,701.60 6,599.60 -2,530.78 249.88 5,967,118.26 550,415.66 6.68 -1,612.84 MWD (2) ` 8,170.22 93.81 55.51 6,699.61 6,597.61 -2,514.21 274.34 5,967,134.98 550,440.01 2.59 -1,583.83 MWD (2) 8,200.23 93.47 53.52 6,697.70 61595.70 -21496.82 298.72 5,967,152.53 550,464.28 6.71 -1,554.29 MWD (2) 12/20/2016 8:58:06AM Page 3 COMPASS 5000.1 Build 74 ConocoPhillips /I*ks ConocoPhillips HUGHES Definitive Survey Report Company: ConocoPhillips (Alaska) Inc. -Kup1 Local Co-ordinate Reference: Well 1 B-18 Project: Kuparuk River Unit ND Reference: 1 B-18 @ 102.00usft Site: Kuparuk 1 B Pad MD Reference: 1 B-18 @ 102.00usft Well: 113-18 North Reference: True Wellbore: 1B-18AL3PB1 Survey Calculation Method: Minimum Curvature Design: 1 B-18AL3PB1 Database: EDM Alaska NSK Sandbox Survey Map Vertical MD Inc Azi TVD TVDSS +N/-S +E/-W DLS (usft) (') (1 (usft) (usft) (usft) (usft) Northing Northing East) (o/1000 Section Survey Tool Name Annotation (ft) (ft) (ft) 8,230.35 92.21 54.14 6,696.21 6,594.21 -2,479.07 323.01 5,967,170.44 550,488.44 4.66 -1,524.57 MWD (2) 8,260.36 90.52 54.54 6,695.49 6,593.49 -2,461.58 347.38 5,967,188.09 550,512.69 5.79 -1,494.96 MWD (2) 8,291.67 88.34 56.39 6,695.81 6,593.81 -2,443.83 373.17 5,967,206.01 550,538.36 9.13 -1,464.18 MWD (2) 8,320.25 89.82 57.60 6,696.26 6,594.26 -2,428.27 397.14 5,967,221.74 550,562.22 6.69 -1,436.23 MWD (2) 8,350.60 89.39 57.58 6,696.47 6,594.47 -2,412.00 422.76 5,967,238.17 550,587.73 1.42 -1,406.61 MWD (2) 8,380.23 86.41 56.31 6,697.56 6,595.56 -2,395.85 447.57 5,967,254.48 550,612.43 10.93 -1,377.64 MWD (2) I 8,410.27 85.36 55.21 6,699.71 6,597.71 -2,379.00 472.34 5,967,271.51 550,637.08 5.06 -1,348.21 MWD (2) 8,440.32 87.27 55.19 6,701.65 6,599.65 -2,361.88 496.96 5,967,288.78 550,661.59 6.36 -1,318.70 MWD (2) 8,470.14 85.76 54.61 6,703.46 6,6D1.46 -2,344.77 521.32 5,967,3D6.06 550,685.82 5.42 -1,289.38 MWD (2) 8,500.21 85.02 53.03 6,705.88 6,603.88 -2,327.07 545.51 5,967,323.91 550,709.90 5.79 -1,259.76 MWD (2) 8,530.19 85.39 53.34 6,708.38 6,606.38 -2,309.17 569.42 5,967,341.97 550,733.69 1.61 -1,230.19 MWD (2) 8,560.07 86.28 53.61 6,710.55 6,608.55 -2,291.44 593.37 5,967,359.86 550,757.52 3.11 -1,200.71 MWD (2) 8,590.19 85.94 54.23 6,712.60 6,610.60 -2,273.74 617.66 5,967,377.72 550,781.68 2.34 -1,171.03 MWD (2) 8,619.30 85.54 54.47 6,714.76 6,612.76 -2,256.82 641.25 5,967,394.80 550,8D5.16 1.60 -1,142.38 MWD (2) 8,650.11 85.52 56.55 6,717.16 6,615.16 -2,239.43 666.56 5,967,412.35 550,830.35 6.73 -1,112.18 MWD (2) 8,680.29 85.24 56.39 6,719.59 6,617.59 -2,222.81 691.64 5,967,429.14 550,655.31 1.D7 -1,082.70 MWD (2) 8,710.37 85.79 57.52 6,721.94 6,619.94 -2,206.46 716.78 5,967,445.65 550,880.34 4.17 -1,053.36 MWD (2) 8,740.26 84.03 58.69 6,724.59 6,622.59 -2,190.73 742.05 5,967,461.55 550,905.51 7.06 -1,024.37 MWD (2) 8,770.31 82.74 60.36 6,728.06 6,626.06 -2,175.59 767.78 5,967,476.86 550,931.13 6.99 -995.47 MWD (2) 8,800.41 81.42 62.46 6,732.20 6,630.20 -2,161.32 793.95 5,967,491.30 550,957.20 8.18 -966.88 MWD (2) 8,830.47 81.87 64.30 6,736.57 6,634.57 -2,148.00 820.54 5,967,504.80 550,983.70 6.24 -938.66 MWD (2) 8,860.54 83.63 65.09 6,740.37 6,638.37 -2,135.25 847.51 5,967,517.73 551,010.58 6.41 -910.57 MWD (2) 8,890.56 84.90 66.11 6,743.37 6,641.37 -2,122.91 874.71 5,967,530.25 551,037.69 5.42 -882.61 MWD (2) 8,920.12 86.74 66.10 6,745.52 6,643.52 -2,11D.97 901.66 5,967,542.37 551,064.56 6.22 -855.11 MWD (2) 8,950.34 88.25 66.78 6,746.84 6,644.84 -2,098.90 929.33 5,967,554.62 551,092.15 5.48 -827.01 MWD (2) 8,980.26 90.28 66.59 6,747.23 6,645.23 -2,087.06 956.81 5,967,566.64 551,119.54 6.81 -799.21 MWD (2) 9,010.34 92.73 66.92 6,746.44 6,644.44 -2,075.20 984.43 5,967,578.69 551,147.08 8.22 -771.29 MWD (2) 9,040.30 92.71 68.37 6,745.01 6,643.01 -2,063.81 1,012.11 5,967,590.26 551,174.68 4.83 -743.67 MWD (2) 9,056.07 93.81 67.33 6,744.12 6,642.12 -2,057.88 1,026.69 5,967,596.29 551,189.22 9.59 -729.16 MWD (2) 9,098.00 93.81 67.33 6,741.33 6,639.33 -2,041.75 1,065.30 5,967,612.67 551,227.72 0.00 -690.46 PROJECTED to TO 12120/2016 8:58:06AM Page 4 COMPASS 5000.1 Build 74 WE FA2 BAKERDate: HUGHES IA RECEIVED IV i JAN 0 6 2017 December 22, 2016 Makana Bender AOGCC 333 West 7th Ave, Suite 100 Anchorage, Alaska 99501 From: Letter of Transmittal DATA LOGGED t 1W1201 -C K. BENDER Yosha Ragbirsingh / Michael Soper Baker Hughes INTEQ 795 East 94th Avenue Anchorage, Alaska 99515 Please find enclosed the directional survey data for the following well(s): 1B -18A 21 6108 27 86 2 IB-18AL1 2 1 9 1 0 9 27 86 3 IB-18AL2 1B-18AL3PB1 2 1 61 10 27 86 4 I B-18AL3 2 1 61 4 4 27 86 5 1B-18AL3-01 21 6 1 4 4 27 86 6 2 1 61 56 27867 (6) Total prints Enclosed for each well(s): 1 hardcopy print of directional survey reports (NAD27) 1 compact disk containing electronic survey files Note: Please feel free to send us an email in place of return mail. Michael Soper, Baker Hughes, Project Engineer Michael. Soper@BakerHughes.com Yosha Ragbirsingh, Baker Hughes, Survey Manager Yosha.Ragbirsingh@BakerHughes.com ConocoPhilli s p RECEIVED JAN 0 6 2017 A®CCC ConocoPhillips (Alaska) Inc. -Kup1 Kuparuk River Unit Kuparuk 1 B Pad 1 B-18AL3 50-029-22472-62 Baker Hughes INTEQ Definitive Survey Report 20 December, 2016 21 6144 27 86 5 FeA R I BAKER NIlGIIES ConocoPhillips Company: ConocoPhillips (Alaska) Inc. -Kupl Project: Kuparuk River Unit Site: Kuparuk 1 B Pad Well: 113-18 Wellbore: 1 B-1 SAI -3 Design: 1 B-18AL3 Project Kuparuk 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 1 B-18 ConocoPhillips Definitive Survey Report Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Database: Well Position +N/ -S 0.00 usft Northing: Tie On Depth: 8,080.19 +E/ -W 0.00 usft Easting: Position Uncertainty 0.00 usft Wellhead Elevation: Wellbore 1 B-18AL3 +E/ -W Magnetics Model Name Sample Date BGGM2016 10/1/2016 Design 1 B-18AL3 Audit Notes: 40.80 Well 1 B-18 1 B-18 @ 102.00usft 1 B-18 @ 102.00usft True Minimum Curvature EDM Alaska NSK Sandbox Mean Sea Level Using Well Reference Point Using geodetic scale factor 5,969,647.06 usft Latitude: 550,148.90 usft Longitude: usft Ground Level: Declination (1) 18.01 Dip Angle (1) 80.96 ri.V BAKER HUGHES 70° 19'40.248 N 149° 35'35.868 W 61.20 usft Field Strength (nT) 57,551 Version: 1.0 Phase: ACTUAL Tie On Depth: 8,080.19 Vertical Section: Depth From (TVD) +N/ -S +E/ -W Direction (usft) (usft) (usft) (I 40.80 0.00 0.00 45.00 Survey Program Date 12/16/2016 From To Survey Survey (usft) (usft) Survey (Wellbore) Tool Name Description Start Date End Date 469.67 6,897.50 1 B-18 (1 B-18) MWD MWD - Standard 4/28/1994 4/28/1994 7,392.00 87080.19 1B-18AL3PB1 (113-18AL3PB1) MWD MWD - Standard 11/5/2016 11/11/2016 8,094.00 9,750.37 1B-18AL3(1B-18AL3) MWD MWD - Standard 11/26/2016 12/6/2016 12120/2016 9:03:16AM Page 2 COMPASS 5000.1 Build 74 ConocoPhillips Mks ConocoPhillips Definitive Survey Report HUGHES Company: ConocoPhillips (Alaska) Inc. -Kupl Local Co-ordinate Reference: Well 1 B-18 Project: Kuparuk River Unit TVD Reference: 1 B-18 @ 102.00usft Site: Kuparuk 1 B Pad MD Reference: 1 B-18 @ 102.00usft Well: 1 B-18 North Reference: True Wellbore: 18-18AL3 Survey Calculation Method: Minimum Curvature Design: 1 B-18AL3 Database: EDM Alaska NSK Sandbox Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/ -S +E/ -W DLS (usft) (°) (°) (usft) (usft (usft) (usft) Northing Eating (°/100') Section SurveyTool Name Annotation (ft) (ft) ( (ft) 8,080.19 93.41 60.46 6,705.33 6,603.34 -2,562.46 198.59 5,967,086.23 550,364.59 7.32 -1,671.51 MWD (2) TIP 8,094.00 93.41 59.44 6,704.51 6,602.51 -2,555.56 210.52 5,967,093.21 550,376.47 7.37 -1,658.19 MWD (3) KOP 8,124.97 87.63 61.00 6,704.23 6,602.23 -2,540.18 237.38 5,967,108.76 550,403.23 19.33 -1,628.33 MWD (3) 8,160.07 87.15 67.21 6,705.83 8,603.83 -2,524.88 268.91 5,967,124.28 550,434.65 17.73 -1,595.21 MWD (3) 8,184.96 86.59 63.49 6,707.19 6,605.19 -2,514.52 291.50 5,967,134.79 55Q457.17 15.09 -1,571.91 MWD (3) 8,215.15 86.40 58.79 6,708.51 6,606.51 -2,499.96 317.90 5,967,149.52 550,483.47 16.67 -1,542.95 MWD (3) � 8,245.05 89.75 53.30 6,709.00 6,607.00 -2,483.27 342.69 5,967,166.38 550,508.15 18.91 -1,513.62 MWD (3) 8,275.11 90.71 47.17 6,708.87 6,606.87 -2,464.05 365.78 5,967,185.75 550,531.11 20.64 -1,483.70 MWD (3) 8,305.21 E 90.06 43.36 6,708.67 6,606.67 -2,442.87 387.16 5,967,207.07 550,552.34 12.84 -1,453.61 MWD (3) 8,335.33 91.78 38.58 6,708.19 6,606.19 -2,420.14 406.90 5,967,229.93 550,571.93 16.86 -1,423.57 MWD (3) i 8,365.26 90.61 33.09 6,707.56 6,605.56 -2,395.89 424.41 5,967,254.29 550,589.28 18.75 -1,394.04 MWD (3) 8,395.00 90.33 27.13 6,707.32 6,605.32 -2,370.18 439.33 5,967,280.10 550,604.01 20.06 -1,365.32 MWD (3) k 8,425.10 89.36 23.25 6,707.40 6,605.40 -2,342.94 452.13 5,967,307.42 550,616.64 13.29 -1,337.00 MWD (3) 8,454.98 89.45 18.45 6,707.71 6,605.71 -2,315.03 462.77 5,967,335.40 550,627.08 16.07 -1,309.75 MWD (3) 8,485.19 ( 90.37 13.44 6,707.76 6,605.76 -2,285.99 471.06 5,967,364.49 550,635.18 16.86 -1,283.35 MWD (3) 8,515.33 90.92 8.94 6,707.42 6,605.42 -2,256.43 476.91 5,967,394.08 550,640.83 15.04 -1,258.31 MWD (3) M 8,545.24 90.52 3.74 6,707.04 6,605.04 -2,226.72 480.21 5,967,423.82 550,643.94 17.44 -1,234.97 MWD (3) 8,575.22 91.44 3.09 6,706.53 6,6D4.53 -2,196.80 482.00 5,967,453.75 550,645.52 3.76 -1,212.55 MWD (3) 8,605.25 91.29 7.89 6,705.81 6,603.81 -2,166.92 484.87 5,967,483.64 550,648.19 15.99 -1,189.39 MWD (3) 8,635.13 91.35 12.12 6,705.12 6,603.12 -2,137.51 490.06 5,967,513.08 550,653.18 14.15 -1,164.93 MWD (3) ' 8,665.25 91.66 17.04 6,704.33 6,602.33 -2,108.38 497.63 5,967,542.26 550,660.57 16.36 -1,138.97 MWD (3) 8,695.68 92.00 21.51 6,703.36 6,601.36 -2,079.68 507.67 5,967,571.02 550,670.41 14.72 -1,111.58 MWD (3) 8,725.12 92.70 25.92 6,702.15 6,600.15 -2,052.75 519.50 5,967,598.02 550,682.06 15.15 -1,084.18 MWD (3) 8,755.27 92.64 31.07 6,700.75 6,598.75 -2,026.29 533.86 5,967,624.58 550,696.24 17.06 -1,055.31 MWD (3) 8,782.53 92.73 33.86 6,699.47 6,597.47 -2,003.32 548.48 5,967,647.64 550,710.70 10.23 -1,028.73 MWD (3) 8,814.77 90.18 37.40 6,698.65 6,596.65 -1,977.13 567.25 5,967,673.95 550,729.29 13.53 -996.94 MWD (3) 8,846.88 8,877.61 84.46 36.57 6,700.15 6,598.15 -1,951.52 586.54 5,967,699.69 550,748.41 18.00 -965.19 MWD (3) 83.91 31.86 6,703.27 6,601.27 -1,926.25 603.72 5,967,725.08 550,765.42 15.35 -935.17 MWD (3) 8,905.05 85.85 27.13 6,705.72 6,603.72 -1,902.47 617.17 5,967,748.94 550,778.71 18.57 -908.84 MWD (3) 81935.29 86.77 21.91 6,707.66 6,605.66 -1,875.02 629.69 5,967,776.47 550,791.05 17.49 -880.58 MWD (3) 12/20/2016 9:03:16AM Page 3 COMPASS 5000.1 Build 74 12/20/2016 9:03:16AM Page 4 COMPASS 5000.1 Build 74 ConocoPhillips FIFAtI ConocoPhillips Definitive Survey Report HUGHES Company: ConocoPhillips (Alaska) Inc. -Kupl Local Co-ordinate Reference: Well 1 B-18 _ Project: Kuparuk River Unit TVD Reference: 1 B-18 @ 102.00usft Site: Kuparuk 1 B Pad MD Reference: 1 B-18 @ 102.00usft Well: 1 B-18 North Reference: True Wellbore: 1 B-18AL3 Survey Calculation Method: Minimum Curvature Design: 1 B-18AL3 Database: EDM Alaska NSK Sandbox Survey MD Inc Azi TVD TVDSS +N/ -S +E/ -W Map Map DLS Vertical (usft) (°) (°) (usft (usft) (usft) Northing (usft) Easting (°l100') Section Survey Tool Name Annotation (ft) (ft) (ft) 8,965.00 88.87 17.56 6,708.80 6,606.80 -1,847.08 639.71 5,967,804.47 550,800.88 16.25 -853.74 MWD (3) 9,001.87 90.92 12.04 6,708.86 6,606.86 -1,811.45 649.13 5,967,840.16 550,810.06 15.97 -821.89 MWD (3) 9,030.21 93.19 8.32 6,707.85 6,605.85 -1,783.58 654.13 5,967,868.06 550,814.87 15.37 -798.64 MWD (3) 9,060.33 95.62 3.65 6,705.53 6,603.53 -1,753.73 657.26 5,967,897.93 550,817.81 17.44 -775.32 MWD (3) 9,090.23 98.88 359.57 6,701.76 6,599.76 -1,724.09 658.10 5,967,927.57 550,818.45 17.38 -753.77 MWD (3) 9,119.97 100.47 354.66 6,696.76 6,594.76 -1,694.82 656.63 5,967,956.83 550,816.78 17.13 -734.11 MWD (3) _. 9,152.89 102.17 352.23 6,690.29 6,588.29 -1,662.76 652.95 5,967,988.87 550,812.88 8.89 -714.04 MWD (3) 9,180.01 102.03 356.95 6,684.61 6,582.61 -1,636.36 650.45 5,968,015.24 550,810.21 17.03 -697.15 MWD (3) 9,209.66 101.27 1.24 6,678.57 6,576.57 -1,607.12 649.99 5,968,044.48 550,809.55 14.29 -676.80 MWD (3) 9,239.85 101.13 5.14 6,672.75 6,570.75 -1,577.77 651.62 5,968,073.83 550,810.99 12.77 -654.89 MWD (3) 9,269.80 100.28 9.75 6,667.18 6,565.18 -1,548.60 655.44 5,968,103.02 550,814.61 15.39 -631.56 MWD (3) 9,299.80 99.39 14.15 6,662.06 6,560.06 -1,519.69 661.56 5,968,131.97 550,820.53 14.75 -606.79 MWD (3) 9,329.81 98.82 18.54 6,657.30 6,555.30 -1,491.26 669.89 5,968,160.45 550,828.68 14.57 -580.80 MWD (3) ! 9,359.83 9B.20 23.33 6,652.86 6,550.86 -1,463.54 680.50 5,968,188.24 550,839.10 15.91 -553.69 MWD (3) i 9,389.82 96.78 27.79 6,648.95 6,546.95 -1,436.73 693.33 5,968,215:14 550,851.75 15.49 -525.66 MWD (3) 9,419.83 96.70 30.76 6,645.43 6,543.43 -1,410.73 707.90 5,968,241.22 550,866.14 9.83 -496.98 MWD (3) j 9,449.80 96.56 30.23 6,641.96 6,539.97 -1,385.08 723.01 5,968,266.97 550,881.08 1.82 -468.16 MWD (3) 9,479.87 96.15 26.86 6,638.64 6,536.64 -1,358.83 737.28 5,968,293.32 550,895.18 11.22 -439.50 MWD (3) y 9,509.83 1 95.78 22.83 6,635.52 6,533.52 -1,331.80 749.80 5,968,320.43 550,907.51 13.44 -411.53 MWD (3) 9,539.90 93.38 24.08 6,633.12 6,531.12 -1,304.31 761.73 5,968,348.00 550,919.26 8.99 -383.66 MWD (3) 9,570.05 92.00 27.43 6,631.70 6,529.70 -1,277.19 774.82 5,968,375.21 550,932.16 12.01 -355.23 MWD (3) ` c 9,600.05 92.61 30.90 6,630.50 6,528.50 -1,251.01 789.42 5,968,401.47 550,946.59 11.73 -326.39 MWD (3) 9,630.10 92.76 34.07 6,629.09 6,527.09 -1,225.70 805.54 5,968,426.89 550,962.54 10.55 -297.09 MWD (3) 9,660.05 91.44 36.89 6,627.99 6,525.99 -1,201.33 822.91 5,968,451.38. 550,979.74 10.39 -267.58 MWD (3) ' 9,690.16 91.69 41.40 6,627.17 6,525.17 -1,177.99 841.91 5,968,474.84 550,998.58 15.00 -237.65 MWD (3) 9,720.10 94.58 41.53 6,625.53 6,523.53 -1,155.59 861.70 5,968,497.37 551,018.22 9.66 -207.81 MWD (3) 9,750.37 95.44 45.15 6,622.89 6,520.89 -1,133.66 882.39 5,968,519.43 551,038.76 12.25 -177.68 MWD (3) 9,788.00 95.44 45.15 6,619.32 6,517.32 -1,107.24 908.95 5,968,546.02 551,065.14 0.00 -140.22 PROJECTED to TD 12/20/2016 9:03:16AM Page 4 COMPASS 5000.1 Build 74 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION %EC 3 0 7016 WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1a. Well Status: Oil Gas[-] SPLUG ❑ Other ❑ Abandoned ❑ Suspende❑ 20AAC 25.105 20AAC 25.110 GINJ ❑ WINJ ❑ WAG[:] WDSPL ❑ No. of Completions: 1b. Well Class: Development Exploratory ❑ Service ❑ Stratigraphic Test ❑ 2. Operator Name: ConocoPhillips Alaska, Inc. 6. Date Comp., Susp., or u Ili �Z ly Aband.: 14. Permit to Drill Number/ Sundry: 216-144 . 3. Address: P.O. Box 100360 Anchorage, AK 99510-0360 7. Date Spudded: 11/30/2016 15. API Number: 50-029-22472-62-00 ° 4a. Location of Well (Governmental Section): Surface: 500' FNL, 292' FEL, Sec. 9, T11 N, R10E, UM Top of Productive Interval: 3056' FNL, 85 FEL, Sec. 9, T11 N, R10E, UM Total Depth: 1608' FNL, 4664' FEL, Sec. 10, T11 N, R10E, UM 8. Date TD Reached: 2,17,,1291 1Z MILO 16. Well Name and Number: KRU 1 B-18AL3 9. Ref Elevations: KB: Io'L GL 61 BF: 41 17. Field / Pool(s): Kuparuk River Field/ Oil Pool ° 10. Plug Back Depth MD/TVD: NA 18. Property Designation: ADL 25648 4b. Location of Well (State Base Plane Coordinates, NAD 27): Surface: x- 550147 y- 5969648 Zone- 4 TPI: x- 550376 y- 5967093 Zone- 4 Total Depth: x- 551065 y- 5968546 Zone- 4 11. Total Depth MD/TVD: 9788' MD/6619" TVD 19. Land Use Permit: ALK 466 12. SSSV Depth MD/TVD: N/A 20. Thickness of Permafrost MD/TVD: 160271602' 5. Directional or Inclination Survey: e Yes ❑(attached) No ❑ Submit electronic and printed information per 20 AAC 25.050 13. Water Depth, if Offshore: N/A (ft MSL) 21. Re-drill/Lateral Top Window MD/TVD: 8094' MD/ 6705' TVD 22. Logs Obtained: List all logs run and, pursuant to AS 31.05.030 and 20 AAC 25.071, submit all electronic data and printed logs within 90 days of completion, suspension, or abandonment, whichever occurs first. Types of logs to be listed include, but are not limited to: mud log, spontaneous potential, gamma ray, caliper, resistivity, porosity, magnetic resonance, dipmeter, formation tester, temperature, cement evaluation, casing collar locator, jewelry, and perforation record. Acronyms may be used. Attach a separate page if necessary GR/RES 23. CASING, LINER AND CEMENTING RECORD WT. PER GRADE SETTING DEPTH MD HOLE SIZE CEMENTING RECORD SETTING DEPTH TVD AMOUNT CASING FT TOP BOTTOM TOP BOTTOM PULLED 16" 62.5 H-40 43 121 43 121 24" 200 sx ASI 7-5/8" 29.7 L-80 41 4256 41 4148 9.875" 650 ASIII, 300 sx G 5"x5.5" 17/18 L-80 26 7809 26 6930 6.75" 210 sx G 2-3/8" 4.6 L-80 7609 9785 6710 6619 3 Slotted Liner 24. Open to production or injection? Yes ❑ No ❑ If Yes, list each interval open (MD/TVD of Top and Bottom; Perforation Size and Number): Perfs cement squeezed prior to CTD operations Slotted Liner from 8387'-10092' MD /6698'-6654' TVD cOMPLETIOIN DATE IZ�14 ��(v VERIFIED 25. TUBING RECORD SIZE DEPTH SET (MD) PACKER SET (MD/TVD) 3-1/2" 7061 6934' MD /6244' TVD 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. Was hydraulic fracturing used during completion? Yes ❑ No 0 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: 12/22/2016 Method of Operation (Flowing, gas lift, etc.): Gas Lift Date of Test: 12/25/2016 Hours Tested: 18 Production for Test Period --♦ Oil -Bbl: 476 Gas -MCF: 915 Water -Bbl: 55 Choke Size: 176 bean Gas -Oil Ratio: 2107 scf/stb Flow Tubing Press. 140 Casinq Press: 1042 Calculated 24 -Hour Rate Oil -Bbl: 590 Gas -MCF: 1244 Water -Bbl: 73 Oil Gravity - API (corr): 21 Form 10-407 Revised 11/2015 V77-� CONTINUED ON PAGE 2 RE®MS LL JAN 1 8 2014- 01} Submit ORIGINIAL only, 28. CORE DATA Conventional Com. _,$): Yes ❑ No Q Sidewall Cores: � es ❑ No ❑J If Yes, list formations and intervals cored (MD/TVD, From/To), and summarize lithology and presence of oil, gas or water (submit separate pages with this form, if needed). Submit detailed descriptions, core chips, photographs, and all subsequent laboratory analytical results per 20 AAC 25.071. 29. GEOLOGIC MARKERS (List all formations and markers encountered): 30. FORMATION TESTS NAME MD TVD Well tested? Yes ❑ No ❑✓ If yes, list intervals and formations tested, briefly summarizing test results. Base PERMAFROST 1602 1602 KOP (Kuparuk A4) 8094 6705 Attach separate pages to this form, if needed, and submit detailed test TPI (Kuparuk A Sand) 8094 6705 information, including reports, per 20 AAC 25.071. TD (Kuparuk A4) 9788 6619 31. List of Attachments: Summary of daily operations, well schematics and final directional surveys. Information to be attached includes, but is not limited to: summary of daily operations, wellbore schematic, directional or inclination survey, core analysis, paleontological report, production or well test results, per 20 AAC 25.070. 32. 1 hereby certify that the foregoing is ue and correct to the best of my knowledge. Contact: Jeff Co nelly Email: jeff.S.connell conocO hllll S.cOm Printed Name: G. EII Title: Principal CTD Engineer 1 Signature: Phone: (907)-263-4172 Date: wZ \ko INSTRUCTIONS General: This form and th uire attachments provide a complete and concise record for each well drilled in Alaska. Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed. All laboratory analytical reports regarding samples or tests from a well must be submitted to the AOGCC, no matter when the analyses are conducted. Item 1 a: Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Item 1b: Well Class - Service wells: Gas Injection, Water Injection, Water -Alternating -Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Item 4b: TPI (Top of Producing Interval). Item 9: The Kelly Bushing, Ground Level, and Base Flange elevations in feet above Mean Sea Level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 15: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). Item 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 11/2015 Submit ORIGINAL Only I B-18 CTD Working Schematic 16" 62# H-40 shoe @ 121' MD 7-5/8" 29.7# L-80 shoe @ 4147' MD 5.5" 17# L-80 shoe @ 6997' MD C -sand perfs (sqz'd) 7131'- 7273' MD KOP @ 7392' MD 31i" x 5" TTWS set at 0° toolface KOP @ 7502' MD 3'/2" x 5" TTWS set at 330° toolface A -sand perfs (sqz'd) 7256'- 7575' MD Tapered Prod Csq 5'h, 17#, L-80, 0'-7044' MD 5", 18#, L-80, 7044'-7809' MD Camco BP -6 injection nipple @ 1951' MD ID = 2.813" 3-1/2" 9.3# L-80 ELIE 8rd Tubing to surface 3-1/2" Camco gas lift mandrels @ 2629', 4223', 5498', 6335'& 6862' X -nipple @ 6895' MD ID = 2.812"ID Baker GBH -22 Loactor & Seal assembly at 6918 Baker 3-1/2" PBR @ 6920' MD (3" ID) Baker KBH-22 anchor seal assembly at 6933' MD Baker FA -1 packer @ 6934' MD 5" casing sealbore extension @ 7044' (4.0" ID) Liner -top packer set post -rig at 6994' MD & swell packer at 7535' MD (in A5 sand) to ensure no C - sand production 1 B-1 SA TD @ 9500' MD Liner Bottom at 8315' MD Liner Top at 7412' MD (in 5") 1B-18AL2 (West) KO billet at 7610' MD TD at 8,568' MD Liner from 8196'- 6994' MD 1B-18AL3 (Northeast) KO billet at 8094' MD TD at 9788' MD Liner from 9785'- 7609' MD 1B-18AL3PB1 (Northeast) TD @ 9098' MD 1B-18AL1 (East) KO billet at 8449' MD TD at 10,200' MD Liner from 10,092'- 8387' MD 1B-18AL3-01 (East) KO billet at 8387' MD TD at 10,900' MD Liner from 10,900'- 8094' MD Operations Summary (with Timelog Depths) 1B-18 Rig: NABORS CDR2-AC Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time Dur (hr) Phase Op Code Activity Code Time P -T -X Operation (ftKB) End Depth (ftKB) 10/28/2016 10/28/2016 1.00 MIRU MOVE RURD P Complete pre move check list. 0.0 0.0 12:00 13:00 10/28/2016 10/28/2016 4.00 MIRU MOVE MOB P Trucks on location, PJSM, stage pits 0.0 0.0 13:00 17:00 on pad, pull sub off 2B-02, hook up jeeps, move rig to 2C pad access road. 10/28/2016 10/28/2016 1.00 MIRU MOVE WAIT T Wait at 2C pad access for CPF2 crew 0.0 0.0 17:00 18:00 change out. 10/28/2016 10/28/2016 3.00 MIRU MOVE MOB P Move rig from 2C pad to 1B -pad. 0.0 0.0 18:00 21:00 10/28/2016 10/28/2016 0.50 MIRU MOVE MOB P Remove jeeps, prep 1B-18, set 0.0 0.0 21:00 21:30 herculite and mat. 10/28/2016 10/28/2016 1.25 MIRU MOVE MOB P Spot sub over 1B-18, lay mats and set 0.0 0.0 21:30 22:45 down. 10/28/2016 10/29/2016 1.25 MIRU MOVE MOB P Spot pits, lay mays and set down 0.0 0.0 22:45 00:00 10/29/2016 10/29/2016 1.00 MIRU MOVE RURD P Release trucks, lower BOPE's, work 0.0 0.0 00:00 01:00 on post rig move check list. 10/29/2016 10/29/2016 3.00 MIRU MOVE RURD P Start rig up checklist. Hook up steam. 0.0 0.0 01:00 04:00 berm celler. Hook up PUTZ interconnect. RU flowline. 10/29/2016 10/29/2016 2.00 MIRU WHDBOP NUND P NU BOPE. Install choke hose and 0.0 0.0 04:00 06:00 annular hydraulics. Check tree bolts, all tight (40 minutes). Grease choke valves and BOP valves. 10/29/2016 10/29/2016 3.00 MIRU WHDBOP CTOP P Perform Slack Management, trim 105 0.0 0.0 06:00 09:00 ft of coil to find wire, install CTC, pull tested to 52 k, re -headed BHI upper quick (sim-ops), 10/29/2016 10/29/2016 8.00 MIRU WHDBOP BOPE P Start BOP testing, test witness waived 0.0 0.0 09:00 17:00 per state tester Jeff Jones, 3,500 psi high/250 psi low/2,500 annular preventor. Stab INJH test inner reel valve, stripper, and tiger tank line. 10/29/2016 10/29/2016 2.50 MIRU WHDBOP PRTS P Pressure test CTC 4,000 psi, good. 0.0 0.0 17:00 19:30 Post BOPE grease choke and BOPE valves. RD testing equipment, freeze protect test pump, store test joint back onto rack in pipe shed. SimOps- Calibrate MM with Dave Smith. 10/29/2016 10/29/2016 2.50 MIRU WHDBOP MPSP P PJSM, Load BPV equipment, MU and 0.0 0.0 19:30 22:00 lubricate out BPV, tubing 230 psi, bleed tubing to zero, still flowing, RD BPV equipment, off load same while performing valve alignment check list, blow down TT line. 10/29/2016 10/30/2016 2.00 PROD1 WHPST PULD P PJSM- Install checks, MU milling BHA 0.0 74.3 22:00 00:00 #1, 0.6° motor with 2.79" string reamer and 2.79" no-go window mill, MU to CoilTrak, surface test 10/30/2016 10/30/2016 1.85 PROD1 W HPST TRIP P RIH with window milling BHA #1 74.3 6,930.0 00:00 01:51 10/30/2016 10/30/2016 0.45 PROD1 W HPST DLOG P Tie in to K1 for minus 4.0 ft correction, 6,930.0 6,995.0 01:51 02:18 continue to log HRZ 10/30/2016 10/30/2016 0.70 PROD1 WHPST TRIP P RIH, dry tag pinch point at 7,506 ft, 6,995.0 7,506.0 02:18 03:00 PUW 34k, set milling parameters. Page 1/37 Report Printed: 12/27/2016 °av . E - Operations Summary (with Timelog Depths) r 1B-18 Rig: NABORS CDR2-AC Job: DRILLING SIDETRACK Time Log Start Time End Time our (hr) Phase Op Code Activity Code Time P -T -X Operation Start Depth (WB) End Depth (ftKB) 10/30/2016 10/30/2016 1.10 PROD1 WHPST WPST P 7505.3 ft. Milling 1.53 bpm at 3,769 7,506.0 7,506.7 03:00 04:06 psi FS per recomended practice, WHP 0, IA 400, OA 3, getting crude stringers back, take 5 bbls out, adjust WHP to 200 psi, pumping 7 bph away 10/30/2016 10/30/2016 0.60 PROD1 WHPST WPST T 7,506.7 ft. Stall motor, PU, set 7,506.7 7,506.7 04:06 04:42 parameters, free spin higher, attempt to restart milling and stalled, chunked motor suspect, unable to pump through bit, Open EDC. 10/30/2016 10/30/2016 2.00 PROD1 WHPST TRIP T POOH for new motor 7,506.7 74.3 04:42 06:42 10/30/2016 10/30/2016 1.50 PROD1 WHPST PULD T PJSM, undeploy failed milling BHA# 1, 74.3 0.0 06:42 08:12 WHP dropped to zero, check well for flow (no -flow) LD motor 10/30/2016 10/30/2016 1.25 PROD1 WHPST PULD T PU/MU BHA# 2 with new motor and 0.0 74.3 08:12 09:27 mills. 10/30/2016 10/30/2016 1.75 PROD1 WHPST TRIP T Tag up set counters, RIH 74.3 6,960.0 09:27 11:12 10/30/2016 10/30/2016 0.50 PROD1 WHPST DLOG T Log the K1 correction of minus 4.5', 6,960.0 7,506.0 11:12 11:42 continue RIH to pinch point. *'* Note: NPT 7.0 hrs Baker Hughes. 10/30/2016 10/30/2016 8.60 PROD1 WHPST MILL P Dry tag pinch point at 7,506', PUW 32 7,506.0 7,527.0 11:42 20:18 k, 1.45 bpm at 3735 psi FS, BHP 3,597, open choke, IA 357, OA 3, holding 1:1 returns. Once bit outside casing, slowly bring ECD up to 11.8 at window, 1.44 bpm at 4,120 psi, BHP 4,025 psi, WHP 433, 1.30 bpm rate out, -8 bph losses, 10/30/2016 10/30/2016 2.30 PROD1 WHPST REAM P 7,527 ft. TD rathole. back ream 7,527.0 7,527.0 20:18 22:36 window area, 330R, 30OR and HS, dry drift window, clean, open EDC 10/30/2016 10/31/2016 1.40 PROD1 WHPST TRIP P POOH for drilling BHA maintaining 7,527.0 2,000.0 22:36 00:00 11.8 tripping schedule. 10/31/2016 10/31/2016 0.75 PROD1 WHPST TRIP P POOH for drilling BHA maintaining 2,000.0 74.3 00:00 00:45 11.8 tripping schedule. 10/31/2016 10/31/2016 1.35 PROD1 WHPST PULD P PUD / LD BHA #2 74.3 0.0 00:45 02:06 10/31/2016 10/31/2016 1.60 PROD1 DRILL PULD P PJSM- MU/PD drilling BHA #3, MU to 0.0 72.2 02:06 03:42 CoilTrak, surface test. 10/31/2016 10/31/2016 1.65 PROD1 DRILL TRIP P RIH with BHA #3, 2.3-° AKO motor 72.2 6,950.0 03:42 05:21 and HCC RR 1-1 Bi -center bit, sat down at 4,239 ft (GLM #2 at 4,223 ft) PUW 24k, orientate TF 180°, RIH clean past suspect GLM. 10/31/2016 10/31/2016 0.30 PROD1 DRILL DLOG P Tie in at K1 for minus 4.5 ft correction 6,950.0 6,976-70- 05:21 05:39 10/31/2016 10/31/2016 1.00 PROD1 DRILL TRIP P RIH, displacing well to new mud, close 6,976.0 7,527.0 05:39 06:39 EDC, PUW 29 k, continue RIHTB 10/31/2016 10/31/2016 0.85 PROD1 DRILL DRLG P OBD 1.43 bpm at 4,200 psi, BHP 7,527.0 7,533.0 06:39 07:30 4,344, WHP 530, IA 0, OA 6 10/31/2016 10/31/2016 1.75 PROD1 DRILL TRIP TLPUH,HI tools lost power, 7,533.0 743 07:30 09:15 hoot from surface, (issue down hole via troubleshooting rt. Page 2137 Report Printed: 12/27/2016 - Operations Summary (with Timelog Depths) 1B-18 ire Rig: NABORS CDR2-AC Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time Dur (hr) Phase Op Cade Activity Code Time P -T -X Operation (ftKB) End Depth (ftKB) 10/31/2016 10/31/2016 2.00 PROM DRILL PULD T PJSM, PUD build section BHA with a 74.3 0.0 09:15 11:15 2.3° bend motor successfully, inspect upper quick and flowsub, 10/31/2016 10/31/2016 1.75 PROM DRILL PULD T PD, build section BHA# 4 (pre -loaded) 0.0 72.2 11:15 13:00 Stab INJH, surface test tools (good test) 10/3112016 10/31/2016 1.55 PROD1 DRILL TRIP T RIH with build section BHA# 4 72.2 6,950.0 13:00 14:33 10/31/2016 10/31/2016 0.25 PROM DRILL DLOG T Log the K1 correction of minus 3.0' 6,950.0 6,972.0 14:33 14:48 "* Note: NPT for failed drilling tools 7.0 hrs. 10/31/2016 10/31/2016 0.50 PROM DRILL TRIP T RIH, PUW above window 29k, Close 6,972.0 7,533.0 14:48 15:18 EDC 10/31/2016 10/31/2016 6.65 PROD1 DRILL DRLG P OBD 1.45 bpm at 4093 psi, BHP 7,533.0 7,664.0 15:18 21:57 4101, WHP 594, IA 353, OA 7, slow drilling thru Anchorite, getting dirty surveys, not solar or environmental disruption, troubleshoot, suspect DGS. 10/31/2016 11/1/2016 2.05 PROD1 DRILL TRIP T POOH for new BHA 7,664.0 72.2 21:57 00:00 "'Note: NPT for failed drilling tools 2.0 hrs. 11/1/2016 11/1/2016 1.35 PROD1 DRILL PULD T PJSM- PUD BHA#4, bit condition 2-2- 72.2 0.0 00:00 01:21 BT-A-X-1-NO-DTF 11/1/2016 11/1/2016 1.55 PROM DRILL PULD T PJSM- MU/PD 3rd build BHA #5, 2.32 0.0 72.2 01:21 02:54 AKO motor and RR HCC bit, MU to Coil Trak, surface test. (Sim -Ops) 11/1/2016 11/1/2016 1.55 PROM DRILL TRIP T RIH with 3rd build BHA #5 72.2 6,950.0 02:54 04:27 11/1/2016 11/1/2016 0.25 PROM DRILL DLOG T Tie in to K1 for a minus 3.5 ft 6,950.0 6,973.0 04:27 04:42 correction 11/1/2016 11/1/2016 0.30 PROD1 DRILL TRIP T RIH, PUW above window 29k, close 6,973.0 7,520.0 04:42 05:00 EDC, clean thru window. 11/1/2016 11/1/2016 0.25 PROD1 DRILL DLOG T Log RA at 7,509.5 ft, TOWS at 7,502 7,520.0 7,657.0 05:00 05:15 ft. Continue RIH. "`Note: NPT for failed drilling tools 5 hrs. 11/1/2016 11/1/2016 1.50 PROD1 DRILL DRLG P Stack weight, PUH, dragging minus 7,657.0 7,664.0 05:15 06:45 3.0 k to minus 5.0 k DHWOB, lower pump rate work pipe to bottom, back reaming area from 7,657' up to 7,520' 11/1/2016 11/1/2016 8.25 PROD1 DRILL DRLG P 7,664 ft. OBD 1.40 bpm at 4,100 psi, 7,664.0 7,855.0 06:45 15:00 BHP 4,138, WHP 539, IA 533, OA 11 11/1/2016 11/1/2016 0.50 PROD1 DRILL TRIP P TD build section (EOB), wiper up hole, 7,855.0 7,816.0 15:00 15:30 seems to be dragging 7,816' 11/1/2016 11/1/2016 2.00 PROD1 DRILL TRIP P Continue wiper up hole, cleaning open 7,816.0 7,060.0 15:30 17:30 hole. Jog tubing tail area. Significant cuttings observed over the shaker at bottoms up. 11/1/2016 11/1/2016 2.50 PROM DRILL TRIP P Open EDC, continue POOH. Tag up 7,060.0 66.0 17:30 20:00 1 and space out at surface. Page 3/37 Report Printed: 12/27/2016 J1 Operations Summary (with Timelog Depths) 4, 1B-18 Rig: NABORS CDR2-AC Job: DRILLING SIDETRACK Time Log Start Time End Time our (hr) Phase Op Code Activity Code Time P -T -X Operation Start Depth (ftKB) End Depth (ftKB) 11/1/2016 11/1/2016 1.00 PROD1 DRILL PULD P PJSM. PUD build BHA #5. Bit graded 66.0 0.0 20:00 21:00 1-1. 11/1/2016 11/1/2016 1.25 PROD1 DRILL PULD P PJSM, PD lateral BHA #6 with 0.5° 0.0 74.0 21:00 22:15 Weatherford motor and RB HYC bit. 11/1/2016 11/2/2016 1.75 PROD1 DRILL TRIP P RIH with BHA #6. Tie in to K1 for a - 74.0 6,984.0 22:15 00:00 3.5 ft correction. 11/2/2016 11/2/2016 0.75 PROD1 DRILL TRIP P Continue running in the hole. Tie in to 6,984.0 7,855.0 00:00 00:45 the K1 for a -3.5 ft correction. Close EDC at the window. PUW = 29KIbs. Continue in the hole to bottom. No issues. 11/2/2016 11/2/2016 3.00 PROD1 DRILL DRLG P BOBD. 1.40 bpm at 4,500 psi, BHP 7,855.0 8,104.0 00:45 03:45 4,145 psi, ROP 20-120 fph. 11/2/2016 11/2/2016 1.75 PROD1 DRILL DRLG P Motor stall at 8104 ft. PU and restart. 8,104.0 8,255.0 03:45 05:30 Stall a second time. PU and restart, continue drilling ahead. PUW 31 Klbs. 11/2/2016 11/2/2016 1.00 PROD1 DRILL WPRT P PUH for wiper trip. PUW = 32, pulled 8,255.0 7,080.0 05:30 06:30 heavy negative DHWOB, CTSW = 35 k, work area (clean), continue wiper up hole. 11/2/2016 11/2/2016 0.75 PROD1 DRILL WPRT P Jog/clean the 5" 7,080.0 7,500.0 06:30 07:15 11/2/2016 11/2/2016 0.85 PROD1 DRILL WPRT P Wiper back in hole RIW 10 k 7,500.0 8,255.0 07:15 08:06 11/2/2016 11/2/2016 3.50 PROD1 DRILL DRLG P BOBD 1.5 bpm at 4,397 psi, BHP 8,255.0 8,543.0 08:06 11:36 4125, WHP 352, IA 238, OA 6 11/2/2016 11/2/2016 2.25 PROD1 DRILL WPRT T Unable to retrieve clean survey, 8,543.0 8,543.0 11:36 13:51 Perform DD wiper up hole to 7,997', perform 6 check shots up hole, PUW 32 k, RBIH to bottom, approved to drill another 30' per TE 11/2/2016 11/2/2016 1.00 PROD1 DRILL DRLG P BOBD 1.5 bpm at 4,130 psi, BHP 8,543.0 8,655.0 13:51 14:51 4,142, WHP 352, IA 279, OA 6 11/2/2016 11/2/2016 0.75 PROD1 DRILL WPRT P Wiper up hole 7,550' for a tie in. PUW 8,655.0 7,550.0 14:51 15:36 32 k 11/2/2016 11/2/2016 0.25 PROD1 DRILL DLOG P Log the RA marker correction of plus 7,550.0 7,615.0 15:36 15:51 3.0' 11/2/2016 11/2/2016 0.50 PROD1 DRILL WPRT P Wiper back in hole 7,615.0 8,655.0 15:51 16:21 11/2/2016 11/2/2016 1.00 PROD1 DRILL DRLG P BOBD 1.5 bpm at 4330 psi, BHP 8,655.0 8,667.0 16:21 17:21 4125, WHP 217, IA 219, OA 7 11/2/2016 11/2/2016 1.40 PROD1 DRILL WPRT T DD wiper up hole, PUW 29 k unable to 8,667.0 8,667.0 17:21 18:45 get a clean survey, discuss with town team, approved to drill to 8725 ft (95 ft past last clean survey at 8630 ft.) 11/2/2016 11/2/2016 0.50 PROD1 DRILL DRLG P BOBD 1.5 bpm at 4530 psi, BHP 8,667.0 8,725.0 18:45 19:15 4125, WOB 1.7 Klbs, ROP 90-120 fph. Unable to obtain clean survey. Discuss with town. POOH to reconfigure BHA. 11/2/2016 11/2/2016 1.25 PROD1 DRILL TRIP T POOH with BHA #6. PUW = 30 Kibs. 8,725.0 7,500.0 19:15 20:30 Pulled heavy at 7672 ft, 7665 ft, 7660 ft, 7643 ft and 7611 ft. (-)7KIbs WOB. Worked BHA up into 5" casing. 11/2/2016 11/2/2016 0.75 PROD1 DRILL CIRC P Jog 5" casing. 7,500.0 7,060.0 20:30 21:15 Page 4137 Report Printed: 12/27/2016 Operations Summary (with Timelog Depths) IB -18 X:' NO Rig: NABORS CDR2-AC Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time our (hr) Phase Op Code Activity Code Time P -T -X Operation (ftK8) End Depth (ftKB) 11/2/2016 11/3/2016 2.75 PROD1 DRILL TRIP P Continue POOH with BHA#6. Bump 7,060.0 74.0 21:15 00:00 up at surface and space out. Begin PUD BHA #6. 11/3/2016 11/3/2016 0.75 PROD1 DRILL PULD T Finish PUD BHA#6. Bit grade 3-3 74.0 0.0 00:00 00:45 11/3/2016 11/3/2016 0.75 PROD1 DRILL PULD T PD BHA#7 with a 0.5-° AKO motor 0.0 72--0- 00:45 01:30 and RR BCC bit. 11/3/2016 11/3/2016 2.00 PROD1 DRILL TRIP T RBIH with BHA #7. Tie in to the K1 for 72.0 7,554.0 01:30 03:30 a -2.5 ft correction. 11/3/2016 11/3/2016 0.50 PROD1 DRILL TRIP T Stacked out at 7554 ft while RIH. 7,554.0 7,554.0 03:30 04:00 PUH. PUW=30 Klbs. Attempt to RBIH. Stack out at 7562 ft. Vary parameters to try and work through build section. 11/3/2016 11/3/2016 1.75 PROD1 DRILL TRIP T Continue RIH, obtaining check shot 7,554.0 8,725.0 04:00 05:45 surveys and resurvey 11/3/2016 11/3/2016 7.75 PROD1 DRILL DRLG T OBD 1.5 bpm at 4,080 psi, BHP 4276, 8,725.0 9,125.0 05:45 13:30 IA 155, OA 7 Mud swap, with new 8.6 ppg flopro mud at the bit at 9067 ft. 11/3/2016 11/3/2016 0.50 PROD1 DRILL WPRT T Wiper up hole PUW 27 k 9,125.0 8,125.0 13:30 14:00 11/3/2016 11/3/2016 0.50 PROD1 DRILL WPRT T Wiper back in hole. RIW 8 k 8,125.0 9,125.0 14:00 14:30 11/3/2016 11/3/2016 5.25 PROD1 DRILL DRLG T BOBD 1.5 bpm at 3,913 psi, BHP 9,125.0 9,254.0 14:30 19:45 4,233, WHP 623, IA 7, OA 10 11/3/2016 11/3/2016 0.25 PROD1 DRILL WPRT T BHA wiper. PUW = 28 Klbs, SOW = 9,254.0 9,254.0 19:45 20:00 11.8 Klbs. 11/3/2016 11/4/2016 4.00 PROD1 DRILL DRLG T BOBD 1.5 bpm at 4100 psi, BHP 9,254.0 9,453.0 20:00 00:00 4,250, W H P 615, IA 7, OA 10 11/4/2016 11/4/2016 2.50 PROD1 DRILL DRLG T Continue crosscutting down through 9,453.0 9,500.0 00:00 02:30 section. 1.5 bpm at 4200 psi, BHP 4,200 Geologist called TD at 9500 feet. Pump TD sweeps. 11/4/2016 11/4/2016 2.75 PROD1 DRILL TRIP T POOH with BHA #7. PUW 29KIbs. 9,500.0 7,070.0 02:30 05:15 11/4/2016 11/4/2016 0.25 PROD1 DRILL WPRT T Jog the 5", pull tight at the tubing tail, 7,070.0 7,215.0 05:15 05:30 RBIH stacked out and stalled motor, jog again 11/4/2016 11/4/2016 2.25 PROD1 DRILL WPRT T Continue wiper to the swab valves. 7,215.0 72.0 05:30 07:45 11/4/2016 11/4/2016 1.75 PROD1 DRILL TRIP T Tag up at surface, reset counters, RIH 72.0 6,950.0 07:45 09:30 11/4/2016 11/4/2016 0.25 PROD1 DRILL DLOG T Log the K1 correction of minus 2.5' 6,950.0 6,975.0 09:30 09:45 11/4/2016 11/4/2016 1.00 PROD1 DRILL WPRT T Continue RIH to the EOB, POOH 6,975.0 7,855.0 09:45 10:45 11/4/2016 11/4/2016 1.25 PROD1 DRILL WPRT T PUH, cleaning build section, perform 7,855.0 7,070.0 10:45 12:00 jog above window, open EDC, jetting the 5" 11/4/2016 11/4/2016 0.25 PROD1 DRILL TRIP T Close EDC, wiper back in hole RIW 15 7,070.0 7,655.0 12:00 12:15 k, pull back up hole log RA. 11/4/2016 11/4/2016 0.25 PROD1 DRILL DLOG T Log the RA for no correction. 7,655.0 7,679.0 12:15 12:30 11/4/2016 11/4/2016 4.00 PROD1 DRILL TRIP T RBIH. Tag up at 9210 ft. Multiple 7,679.0 9,252.0 12:30 16:30 stalls. Work BHA down. Could not get deeper than 9252 ft. Page 5/37 Report Printed: 12/27/2016 Operations Summary (with Timelog Depths) IB -18 Rig: NABORS CDR2-AC Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time our (hr) Phase Op Code Activity Code Time P -T -X Operation (ftK8) End Depth (ftKB) 11/4/2016 11/4/2016 1.50 PROD1 DRILL TRIP T PUH to the window. Pulling heavy in 9,252.0 7,515.0 16:30 18:00 the build section. Work BHA up towards window. Tie in to the RA for a +5 ft correction. 11/4/2016 11/4/2016 0.75 PROD1 DRILL TRIP T RBIH. Could not work past 9269 ft. 7,515.0 9,269.0 18:00 18:45 11/4/2016 11/4/2016 3.75 PROD1 DRILL DISP T POOH pumping liner running pill. 9,269.0 72.0 18:45 22:30 Clean trip through build section. Paint window flag at 6472 ft. 11/4/2016 11/4/2016 0.50 PROD1 DRILL OWFF T Flow check at surface. Static. 72.0 72.0 22:30 23:00 11/4/2016 11/5/2016 1.00 PROD1 DRILL PULD T PJSM. LD BHA #7. 72.0 0.0 23:00 00:00 11/5/2016 11/5/2016 0.25 FROM DRILL DRLG T Finish LD BHA#7. Bit grade 1-2. 0.0 0.0 00:00 00:15 11/5/2016 11/5/2016 0.75 FROM DRILL BOPE T Function test BOPE. 0.0 0.0 00:15 01:00 11/5/2016 11/5/2016 4.50 COMPZI CASING PUTB T Prep floor to run liner. PU 29 joints 2- 0.0 0.0 01:00 05:30 3/8" slotted liner. PU/MU anchored billet assembly. MU CoilTrak tools. Stab injector. 11/5/2016 11/5/2016 1.50 COMPZ1 CASING RUNL T Bump up and reset counters. RIH with 0.0 7,369.0 05:30 07:00 liner on CT. 11/5/2016 11/5/2016 0.25 COMPZI CASING RUNL T Correct to the EOP flag at 6,400', 7,369.0 7,369.0 07:00 07:15 minus 5.2' 11/5/2016 11/5/2016 1.00 COMPZI CASING RUNL T Close EDC, PUW 29 k, continue RIH 7,369.0 8,315.0 07:15 08:15 to bottom 11/5/2016 11/5/2016 1.50 COMPZI CASING RUNL T Set down plus 7 k, DHWOB, PUH 8,315.0 8,315.0 08:15 09:45 minus 8 k, discuss with town, pull up to maxwith out initiating further setting, or damage to tools string. CTSW-45 k, DHWOB-minus 18 k, RBIH to neutral wieght 11/5/2016 11/5/2016 1.00 COMPZI CASING RUNL T WOO 8,315.0 8,315.0 09:45 10:45 11/5/2016 11/5/2016 2.00 COMPZI CASING TRIP T Bring pump up to shear 3,600 psi, 8,315.0 72.5 10:45 12:45 1 PUW 28 k, TOB at 7,412'. POOH 11/5/2016 11/5/2016 0.50 COMPZI CASING SFTY T Check well for flow, PJSM 72.5 0.0 12:45 13:15 11/5/2016 11/5/2016 0.75 COMPZI CASING PULD T LD, liner setting tools, 0.0 0.0 13:15 14:00 11/5/2016 11/5/2016 1.00 PROD1 RPEQPT PULD T Load WS into pipe shed, MU and 0.0 0.0 14:00 15:00 scibe tools, inspect Top Drive 11/5/2016 11/5/2016 1.00 PRODI RPEQPT PULD T PU/MU/WS BHA# 9 0.0 75.3 15:00 16:00 11/5/2016 11/5/2016 1.50 PROM RPEQPT TRIP T RIH, with WS, pumping min rate 0.3 75.3 6,950.0 16:00 17:30 bpm 11/5/2016 11/5/2016 0.25 PROD1 RPEQPT DLOG T log the K1 correction of -2.5 ft. 6,950.0 6,983.0 17:30 17:45 11/5/2016 11/5/2016 0.25 PROD1 RPEQPT TRIP T Position WS on depth. PUW = 28 6,983.0 9,405.0 17:45 18:00 Klbs. 11/5/2016 11/5/2016 0.25 PROM RPEQPT WPST T Close EDC. Bring up pumps and set 9,405.0 9,405.0 18:00 18:15 anchors. Set down 5KIbs WOB to confirm set. Top of WS set at 7392 ft, oriented HS. 11/5/2016 11/5/2016 1.25 PROM RPEQPT TRIP T POOH with WS running tools. 9,405.0 73.0 18:15 19:30 11/5/2016 11/5/2016 0.50 PROD1 RPEQPT OWFF T Flow check at surface. Static. 73.0 73.0 19:30 20:00 Page 6/37 Report Printed: 12127/2016 Operations Summary (with Timelog Depths) 1B-18 Rig: NABORS CDR2-AC Job: DRILLING SIDETRACK Time Log Start Time End Time 11/5/2016 our (hr) 0.75 Phase PROD1 Op Code RPEOPT Activity Code Time P -T -X Operation P Start Depth (ftKB) End Depth (ft KB)11/5/2016 20:00 20:45 PULD T PJSM, LD BHA #9. 73.0 0.0.0 11/5/2016 11/5/2016 1.25 PROD' WHPST PULD T PJSM. PU BHA#10 with 0.6° AKO 0.0 75.0 20:45 22:00 motor and HCC DSM. 11/5/2016 11/5/2016 1.50 PROD' WHPST TRIP T RIH with BHA#10. 75.0 6,950.0 22:00 23:30 11/5/2016 11/5/2016 0.25 PR0D1 WHPST DLOG T Tie in to the K1 for -a4 correction 6,950.0 7,000.0 23:30 23:45 11/5/201611/6/2016 23:45 0.25 PROD1 WHPST TRIP T Continue to RIH with BHA #10. Begin 7,000.0 7,371.0 00:00 displacing well to drilling fluid. 11/6/2016 11/6/2016 1.25 PROD1 WHPST CIRC T Displace well from completion fluid to 7,371.0 7,371.0 00:00 01:15 FloPro drilling fluid. **Adjust for daylight savings time*** 11/6/2016 11/6/2016 0.25 PROD1 WHPST WPST T RIH and dry tag WS at 7395 ft (TOWS 7,371.0 7,392.0 01:15 01:30 7392 ft). Begin milling window per procedure. 11/6/2016 11/6/2016 7.00 7ROD1 WHPST WPST T Begin milling window per procedure. 7,392.0 7,401.0 01:30 08:30 11/6/2016 08:30 11/6/2016 1.50 PROD1 WHPST WPST T Continue milling with string reamer @ 7,401.0 7,403.0 10:00 1.4 fph, 11/6/2016 10:00 11/6/2016 4.00 PROD1 WHPST WPST T Drill rathoie towards TD 741 T, 1.45 7,403.0 7,417.0 14:00 bpm at 3840 psi, BHP 4023, WHP 403, IA 61, OA 9 11/6/2016 14:00 11/6/2016 1.50 PR0D1 WHPST WPST T Back Ream window 0°, 30° ROHS, 7,417.0 7,292.0 15:30 30° LOHS, and 0° 11/6/2016 11/6/2016 0.25 PR0D1 WHPST WPST T PUH, and dry drift window area. 7,292.0 7,417.0 15:30 15:45 11/6/2016 11/6/2016 2.00 PROD1 WHPST WPST T POOH, pumping 1.45 bpm at 3,900 7,417.0 70.0 15:45 17:45 psi, BHP 4,029, WHP 417, IA 97, OA 0 11/6/2016 11!6/2016 1.50 PROD1 WHPST PULD T PJSM. PUD BHA#10. Crewchange. 70.0 0.0 17:45 19:15 Finish PUD. Mill gauge 2.79" no-go. 11/6/2016 11/6/2016 2.00 PROD1 DRILL PULD T PJSM, PD Build BHA#11 with 1.7° 0.0 74.0 19:15 21:15 AKO motor and HCC bit. 11/6/2016 11/7/2016 2.75 PROD1 DRILL TRIP T Bump up and reset counters. RIH with 74.0 7,437.0 21:15 00:00 BHA #11. Log the K1 for a -3 ft correction. Close EDC. PUW at the window = 37 Klbs. 11/7/2016 11/7/2016 6.75 PROD1 DRILL DRLG T BOBD. Pumping 1.45 bpm at 4200 7,437.0 7,562.0 00:00 06:45 psi. WOB = 2-3 Klbs. CTW = 12.5 Klbs, BHP = 4140 psi. ROP = 5-80 fph. Some stalls observed while drilling this interval. 11/7/2016 11/7/2016 2.75 FROD1 DRILL TRIP T POOH, perform jog in the 5" with open 7,562.0 72.2 06:45 09:30 EDC 11/7/2016 11/7/2016 1.25 PROD1 DRILL PULD T OOH, PJSM, PUD and LD build 72.2 0.0 09:30 10:45 section BHA# 11 11/7/2016 11/7/2016 1.00 PROD1 DRILL SVRG T Service INJH, change oil in TOP 0.0 0.0 10:45 11:45 Drive, 11/7/2016 11/7/2016 1.25 PROD1 DRILL PULD T PJSM, PD second build section BHA# 0.0 72.2 11:45 13:00 12 with 2.3° motor and RR HCC bi- center bit. 11/7/201611/7/2016 2.00 TROD' DRILL TRIP T RIH, slowing down 20 fpm pass _72.J2-6,9 50.0 13:00 15:00 jewlery. Page 7137 Report Printed: 12/27/2016 .-, Operations Summary (with Timelog Depths) 1B-18 Rig: NABORS CDR2-AC Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time our (hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth (MB) 11 /7/20 16 11/7/2016 0.45 PROM DRILL DLOG T Log the K1 marker correction of minus 6,950.0 6,977.0 15:00 15:27 3.0', continue RIH to log RA marker. 11/7/2016 11/7/2016 0.30 PROD1 DRILL DLOG T Log the RA no correction 6,977.0 7,432.0 15:27 15:45 TO W S=7,392.15' BOW= 7,401' RA= 7399.5' 11/7/2016 11/7/2016 0.30 PROM DRILL TRIP T Continue RIH to bottom 7,432.0 7,562.0 15:45 16:03 11/7/2016 11/7/2016 5.25 PROM DRILL DRLG T OBD 1.45 bpm at 4035 psi FS, BHP 7,562.0 7,599.0 16:03 21:18 4108, WHP 380, IA 0, CA 11/7/2016 11/7/2016 0.25 PROM DRILL WPRT T Wiper up hole PUW 29 k 7,599.0 7,476.0 21:18 21:33 11/7/2016 11/7/2016 0.25 PROD1 DRILL WPRT T Wiper back in hole, RIW 15 k 7,476.0 7,599.0 21:33 21:48 11/7/2016 11/8/2016 2.20 PROD1 DRILL DRLG T BOBD 1.45 bpm at 3950 psi, BHP 7,599.0 7,693.0 21:48 00:00 4141, WHIP 437, IA 220, OA 10 11/8/2016 11/8/2016 2.00 PROM DRILL DRLG T BOBD 1.45 bpm at 3950 psi, BHP 7,693.0 7,800.0 00:00 02:00 4150, WHP 437, IA 220, OA 10 End of build at 7800 ft. 11/8/2016 11/8/2016 2.00 PROM DRILL TRIP T POOH with BHA#12. PUW = 30Kibs. 7,800.0 70.0 02:00 04:00 11/8/2016 11/8/2016 1.50 PROD DRILL PULD T PUD and LD BHA#12. 70.0 0.0 04:00 05:30 11/8/2016 11/8/2016 1.50 PROM DRILL PULD T PD BHA #13 with 0.46° AKO motor 0.0 72.0 05:30 07:00 and new HYC bit. 11/8/2016 11/8/2016 2.75 PROD1 DRILL TRIP T RIH with BHA #13. 72.0 6,950.0 07:00 09:45 11/8/2016 11/8/2016 0.25 PROD1 DRILL DLOG T Log K1 for a -2.5 ft correction. 6,950.0 7,000.0 09:45 10:00 11/8/2016 11/8/2016 0.75 PROD1 DRILL TRIP T Continue running in the hole to 7,000.0 7,800.0 10:00 10:45 bottom. PUW at the window = 27KIbs, Close EDC. Clean trip through window and open hole. 11/8/2016 11/8/2016 10.14 --P-ROD1 DRILL DRLG T BOBD. Pumping 1.4 bpm at 4230 psi. 7,800.0 8,210.0 10:45 20:53 WOB = 1.5KIbs. CTW = 13.5KIbs. BHP = 4190 psi. 11/8/2016 11/8/2016 0.55 PROD1 DRILL WPRT T Wiper Trip Uphole. PUW = 25k 8,210.0 7,000.0 20:53 21:26 Pumped a 5/5 pill sweep before PUH.................made several jogs in 5" casing.......... 11/8/2016 11/8/2016 0.27 PROD1 DRILL TRIP T Trip back in hole 7,000.0 7,385.0 21:26 21:42 11/8/2016 11/8/2016 0.30 PROM DRILL DLOG T Log the RA Tag at 7,400' and make a 7,420.0 7,420.0 21:42 22:00 correction of +2' 11/8/2016 11/8/2016 0.45 PROM DRILL TRIP T Trip back in hole 7,420.0 8,210.0 22:00 22:27 11/8/2016 11/9/2016 1.54 PROM DRILL DRLG T BOBD. Pumping 1.4 bpm at 4251 psi. 8,210.0 8,218.0 22:27 00:00 WOB = 2.25KIbs. CTW = 10.5KIbs. BHP = 4210 psi. ROP = 4.7 to 6.5 fph 11/9/2016 11/9/2016 2.00 PROM DRILL DRLG T OBD. Pumping 1.4 bpm at 4321 psi. 8,218.0 8,236.0 00:00 02:00 WOB = 2.32KIbs. CTW = 11.4KIbs. BHP = 4220 psi. ROP = 4.0 FPH 11/9/2016 11/9/2016 6.50 PROD1 DRILL DRLG T OBD. Pumping 1.4 bpm at 4379 psi. 8,236.0 8,323.0 02:00 08:30 WOB = 1.32KIbs. CTW = 10.8 Klbs. BHP = 4230 psi. ROP = 7.5 to 30 FPH Page 8137 Report Printed: 12/27/2016 o - Operations Summary (with Timelog Depths) 1B-18 Rig: NABORS CDR2-AC Job: DRILLING SIDETRACK Time Log Start Time End Time Dur (hr) Phase Op Code Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 11/9/2016 11/9/2016 0.25 PROD1 DRILL WPRT T Short wiper. PUW =28k 81323.0 8,200.0 08:30 08:45 11/9/2016 11/9/2016 0.25 PROD1 DRILL WPRT T RBIH. SOW = 12k 8,200.0 8,323.0 08:45 09:00 Clean trip in and out. 11/9/2016 11/9/2016 9.00 PROD1 DRILL DRLG T OBD. Pumping 1.4 bpm at 4379 psi. 8,323.0 8,426.0 09:00 18:00 WOB = 1.32KIbs. CTW = 10.8 Klbs. BHP = 4230 psi. ROP = 7.5 to 30 FPH 11/9/2016 11/9/2016 3.00 PROD1 DRILL DRLG T OBD. Pumping 1.4 bpm at 4364 psi. 8,426.0 8,503.0 18:00 21:00 WOB = 1.39KIbs. CTW = 13.5 Klbs. BHP = 4254 psi. ROP = 20 to 30 FPH 11/9/2016 11/10/2016 3.00 PROD1 DRILL DRLG T OBD. Pumping 1.4 bpm at 4457 psi. 8,503.0 8,574.0 21:00 00:00 WOB = 2.10KIbs. CTW = 10.5 Klbs. BHP = 4260 psi. ROP = 20 to 44 FPH 11/10/2016 11/10/2016 1.19 PROD1 DRILL DRLG T OBD. Pumping 1.4 bpm at 4257 psi. 8,574.0 8,590.0 00:00 01:11 WOB = 1.63KIbs. CTW = 8.8 Klbs. BHP = 4320 psi. ROP = 07 to 18 FPH Pump a 5 x 5 Hi/Lo Vis Pill prior to beginning wiper trip....... 11/10/2016 11/10/2016 0.38 PROD1 DRILL DRLG T Wiper trip up hole. Initiate a 1,000 ft 8,590.0 7,598.0 01:11 01:34 wiper trip 20 ft earlier than planned due to verylow ROP (<10 fph) PUW = 25K 11/10/2016 11/10/2016 0.48 PROD1 DRILL DRLG T Trip back in hole. RW = 9.3K 7,598.0 8,590.0 01:34 02:03 11/10/2016 11/10/2016 4.45 PROD1 DRILL DRLG T BOBD. Pumping 1.4 bpm at 4209 psi. 8,590.0 8,630.0 02:03 06:30 WOB = 2.03KIbs. CTW = 9.3 Klbs. BHP = 4282 psi. ROP = 6 to 16 FPH Initiate swapping to a new mud system.... switching from FlowVis to 8.7 ppbPowerPro w/3% KlaStop and 6% KCL New mud at the bit at 8,596' @ 0242 hrs 11/10/2016 11/10/2016 0.25 PROD1 DRILL WPRT T BHA Wiper. PUW = 27 Klbs 8,630.0 8,467.0 06:30 06:45 11/10/2016 11/10/2016 0.25 PROD1 DRILL WPRT T RBIH. SOW 13 Klbs. 8,467.0 8,630.0 06:45 07:00 11/10/2016 11/10/2016 2.25 PROD1 DRILL DRLG T BOBD. Pumping 1.67 bpm at 4300 8,630.0 8,685.0 07:00 09:15 psi. WOB = 1.7KIbs. CTW = 13 Klbs. BHP = 4280 psi. ROP = 10 to 25 FPH 11/10/2016 11/10/2016 2.75 PROD1 DRILL TRIP T Discuss with town. Made decision to 8,685.0 7-2-.0- 09:15 12:00 POOH and c/o bit and BHA. POOH. PUW = 26 Klbs. Clean trip out of the hole. 11/10/2016 11/10/2016 1.75 PROD1 DRILL PULD T PJSM. PUD BHA#13. Bit grade 2-2. 72.0 0.0 12:00 13:45 11/10/2016 11/10/2016 1.50 PROD1 DRILL CTOP T Change out UQC. Test e-line. 0.0 0.0 13:45 15:15 11/10/2016 11/10/2016 0.25 PROD1 DRILL CTOP T Change out stripper pack off. 0.0 0.0 15:15 15:30 11/10/2016 11/10/2016 1.68 PROD1 DRILL PULD T PD BHA #14 with 0.5° AJO 0.0 72.0 15:30 17:10 Weatehrford motor and new HYC bit. Resistivity moved below the DGS. Page 9/37 Report Printed: 12/27/2016 Operations Summary (with Timelog Depths) 113-18 Rig: NABORS CDR2-AC Job: DRILLING SIDETRACK Time Log Start Time End Time Dur (hr) Phase Op Code Activity Code Time P -T -X Operation Start Depth (WEI) End Depth (ftKB) 11/10/2016 11/10/2016 1.88 PROD1 DRILL TRIP T RBIH with open EDC pumping at 72.0 6,959.0 17:10 19:03 minimum rate. SOW = 7.9 K 11/10/2016 11/10/2016 0.36 PROD1 DRILL DLOG T Log for K1 Marker and make 6,959.0 7,000.0 19:03 19:25 correction of + 6.5 FT. Close EDC 11/10/2016 11/10/2016 0.87 PROD1 DRILL TRIP T Resume RIH............. 7,000.0 8,685.0 19:25 20:17 WT CK @ 7,350'= 25K Slow down to 28 fpm while in build section........ 11/10/2016 11/11/2016 3.71 PROD1 DRILL DRLG T BOBD. Pumping 1.28 bpm at 4272 8,685.0 8,853.0 20:17 00:00 psi. WOB = 1.2KIbs. CTW = 12.4 Klbs. BHP = 4180 psi. ROP = 40 to 51 FPH `*Perform a BHA wiper trip right before midnight to help clean out hole........ having difficulty getting the bit to turn. 11/11/2016 11/11/2016 1.00 PROD1 DRILL DRLG T BOBD. Pumping 1.28 bpm at 4272 8,853.0 8,886.6 00:00 01:00 psi. WOB = 2.2KIbs. CTW = 12.4 Klbs. BHP = 4180 psi. ROP = 40 to 51 FPH "Perform a BHA wiper trip right before midnight to help clean out hole........ having difficulty getting the bit to turn. Now having to stack considerable WOB to help facilitate turning.............Geo's can work with what we're getting........... 1. 11/11/2016 11/11/2016 0.94 PROD1 DRILL WPRT T PUH slowly and confer with town 8,886.6 8,540.0 01:00 01:56 engineer and town GEO ........... having difficulty getting the bit to turn up with trying numerous options ......... not getting sufficent enough turn to facilitate making our next target which is critical. Waiting for town to decide on course of action, so still PUH slowly............ PUW = 27.31K 11/11/2016 11/11/2016 0.20 PROD1 DRILL TRIP T Recieved word from town engineer to 8,540.0 8,886.0 01:56 02:08 proceed forward and "aggressively try and make next target at 6,645". Start RBI SOW= 11.5 11/11/2016 11/11/2016 2.86 PROD1 DRILL DRLG T BOBD. Pumping 1.18 bpm at 4072 8,886.0 8,986.0 02:08 05:00 psi. WOB = 3.1 Klbs. CTW = -1.2 Klbs. BHP = 4140 psi. ROP = 40 to 54 FPH 11/11/2016 11/11/2016 4.00 PROD1 DRILL DRLG T OBD. Pumping 1.14 bpm at 3962 psi. 8,986.0 9,080,j- 05:00 09:00 WOB = 2.3KIbs. CTW = -3.5 Klbs. BHP = 4299 psi. ROP = 40 fph 11/11/2016 11/11/2016 1.50 PROD1 DRILL DRLG T OBD. Pumping 1.14 bpm at 3962 psi. 9,080.0 9,098.0 09:00 10:30 WOB = 2.3KIbs. CTW = -3.5 Kibs. BHP = 4300 psi. ROP decreasing to <5fph. Multiple pick ups and restarts to try and improve ROP. Page 10137 Report Printed: 12/27/2016 Operations Summary (with Timelog Depths) 1B-18 Rig: NABORS CDR2-AC Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time our (hr) Phase Op Code Activity Code Time P -T -X Operation (ftKB) End Depth (ftKB) 11/11/2016 11/11/2016 3.00 PROD1 DRILL TRIP T After discussion with town. Decision 9,098.0 68.0 10:30 13:30 made to POOH. PUW = 29 Klbs. Jog 5" window area. Open EDC. Continue out of the hole. 11/11/2016 11/11/2016 2.00 PROD1 DRILL PULD T PJSM. PUD BHA#14. 68.0 0.0 13:30 15:30 11/11/2016 11/11/2016 2.25 PROD1 STK PULD T PJSM. PD BHA #15, Anchored billet 0.0 72.0 15:30 17:45 assembly. 11/11/2016 11/11/2016 1.82 PROD1 STK TRIP T RIH with Anchored Billet 72.0 6,959.0 17:45 19:34 Assembly............ 11/11/2016 11/11/2016 0.22 PROD1 STK DLOG T Logging for K1 Marker and make 6,959.0 7,086.0 19:34 19:47 correction of - 3 ft correction. 11/11/2016 11/11/2016 0.17 PROD1 STK TRIP T Continue RIH with Anchored Billett 7,086.0 7,350.0 19:47 19:57 11/11/2016 11/11/2016 0.06 PROD1 STK TRIP T Stop here. Offline with pump. Close 7,350.0 7,350.0 19:57 20:01 EDC. WT CK = 27k 11/11/2016 11/11/2016 0.20 PROD1 STK TRIP T Continue RIH with Anchored Billett 7,350.0 7,480.0 20:01 20:13 11/11/2016 11/11/2016 0.68 PROD1 STK TRIP T Starting to get some noticable weight 7,480.0 7,480.0 20:13 20:54 bobbles after 7,456 ft. and eventually setting down too much weight at 7,480 ft. Tried jogging through area and other different options, but ultimately could not get past 7,480 ft. Did not want to get western with the billet due to proximity to the window and distance from target set depth. Confer with town engineer and he agreed we should POOH and do a clean up run. Once OOH, we will do the BOP Test before the clean up run. 11/11/2016 11/11/2016 0.90 PROD1 STK TRIP T Start to POOH and dragging too much 7,480.0 7,383.0 20:54 21:48 weight ......... hopefully the dogs are not sticking out........... work the billet up and down slowly and are eventually able to start POOH albeit slowly....... 11/11/2016 11/11/2016 0.12 PROD1 STK TRIP T Stop here to open EDC and bring 7,383.0 7,383.0 21:48 21:55 pump online at .75 bpm......... 11/11/2016 11/12/2016 2.09 PROD1 STK TRIP T Resume POOH pumping at .75 bpm, 7,383.0 72.3 21:55 00:00 CP = 2,442 PUW = 28k WHP = 841 BHP = 3,805 11/12/2016 11/12/2016 1.75 PROD1 STK PULD T At surface. PUD and LD BHA #15. 68.2 0.0 00:00 01:45 11/12/2016 11/12/2016 1.50 PROD1 STK PULD T Pull floats, MU no=le. Stab on 0.0 0.0 01:45 03:15 lubricator. Flush stack. 11/12/2016 11/12/2016 0.75 PROD1 STK BOPE T Pressure test inner reel valve and 0.0 0.0 03:15 04:00 pack off. 11/12/2016 11/12/2016 2.00 PROD1 STK SVRG T Change out bales on TD. Grease 0.0 0.0 04:00 06:00 stack and choke manifold. Change out 4 foot riser. 11/12/2016 11/12/2016 10.50 PROD1 STK BOPE T Perform BOP Test after PJSM and 0.0 06:00 16:30 after tree is serviced, stack flushed out, coil displaced with water. Restest master after greasing. 11/12/2016 11/12/2016 2.27 PROD1 STK BOPE T BOP Test complete. P/U BHA #16 0.0 62.3 16:30 18:46 w/2.80" Ridge Set Mill 11/12/2016 11/12/2016 2.00 PROD1 STK PULD T Pressure Deploy BHA#16 62.3 62.3 18:46 20:46 Page 11/37 Report Printed: 1212712016 tee i=.. Operations Summary (with Timelog Depths) P j i t 1B-18 �v Rig: NABORS CDR2-AC Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time Dur (hr) Phase Op Code Activity Code Time P -T -X Operation (ftKB) End Depth (WEI) 11/12/2016 11/12/2016 1.93 PROD1 STK TRIP T RIH pumping at .5 bpm with open 62.3 6,943.0 20:46 22:42 EDC First 5 x 5 Gel sweep pumped...... 11/12/2016 11/12/2016 0.40 PROD1 STK DLOG T Log for K1 Marker and make 6,943.0 6,974.0 22:42 23:06 correction of -2 ft 11/12/2016 11/12/2016 0.08 PROD1 STK TRIP T Continue RIH for clean out run 6,972.0 7,522.0 23:06 23:10 Second 5 x 5 gel pill launched Close EDC at 7,380 ft............ Reciprocate pipe through 5" to clean area while first pill is exiting coil...... First sweep back to shakers brought cuttings to surface. 11/12/2016 11/13/2016 0.82 PROD1 STK REAM T Hit hard tag at 7,522 ft. Reciprocate 7,522.0 7,546.0 23:10 00:00 pipe through this area trying to break through ... ...pass 7,522 ft only to tag up at 7,533 ft...............PUH and RBIH...............pump third sweep ............ getting about 2 feet deeper with each bite ............ very slow going ............. PUWs are between 25 and 35k 11/13/2016 11/13/2016 1.82 PROD1 STK REAM T Still cleaning cuttings out of build 7,546.0 8,561.0 00:00 01:49 section by taking 50' bites after breaking through last fill tag at 7,548 ft. 11/13/2016 11/13/2016 1.13 PROD1 STK REAM T Tag something at 8,565.0 ft. 8,561.0 8,589.0 01:49 02:57 Slowly work past this depth and continue RIH to 8,589 ft and unable to go any further. PUW exceeded 50k and - 15k on WOB............ ID of hole seems to have swollen...... doesn't act like fill. Confer with town engineer or setting billet higher than 8,650 ft. Waiting on return call with plan forward. 11/13/2016 11/13/2016 3.05 PROD1 STK TRIP T Engineer called back and said billet 8,589.0 62.0 02:57 06:00 would be set higher, but currently has not decided on a depth yet. Continue POOH chasing returns to surface as planned (pumping sweeps, jogging through 5" and again at surface). Begin POOH. PUW = 27K Make several jogs through 5............. 11/13/2016 11/13/2016 1.75 PROD1 STK PULD T PUD and LD BHA#16. Packed clay 62.0 0.0 06:00 07:45 and cuttings observed in the mill junk slot area. 11/13/2016 11/13/2016 1.75 PROD1 STK PULD T PJSM. PD BHA#17, anchored billet 0.0 72.0 07:45 09:30 assembly. 11/13/2016 11/13/2016 1.75 PROD1 STK TRIP T RIH with BHA #17. 72.0 6,960.0 09:30 11:15 11/13/2016 11/13/2016 0.25 PROD1 STK DLOG T Log K1 for a -1.5 ft correction. 6,960.0 6,985.0 11:15 11:30 11/13/2016 11/13/2016 1.00 PROD1 STK TRIP T Continue RIH with anchored billet. 6,985.0 8,462.0 11:30 12:30 Weight check at the window = 28KIbs PUW. Page 12137 Report Printed: 12/27/2016 Operations Summary (with Timelog Depths) 1B-18 Rig: NABORS CDR2-AC Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time our (hr) Phase Op Code Activity Code Time P -T -X Operation (ftKB) End Depth (ftIB) 11/13/2016 11/13/2016 0.25 PROD1 STK WPST T Position billet on depth (TOB = 8450 8,462.0 8,462.0 12:30 12:45 ft, oriented 25° LOHS). Bring pump up. Setting tool sheared at 4600 psi. Set 5klbs down and confirmed set. 11/13/2016 11/13/2016 1.25 PROD1 STK TRIP T POOH with BHA#17. 8,462.0 72.0 12:45 14:00 11/13/2016 11/13/2016 1.80 PROD1 STK PULD T PJSM. PUD BHA #17. 72.0 0.0 14:00 15:48 11/13/2016 11/13/2016 1.35 PROD1 DRILL PULD T PJSM, PD BHA #18 with 0.85° AKO 0.0 72.0 15:48 17:09 motor and RB HCC bit. 11/13/2016 11/13/2016 1.68 PROD1 DRILL TRIP T RIH with EDC open pumping minimum 72.0 6,952.0 17:09 18:49 rate 11/13/2016 11/13/2016 0.21 PROD1 DRILL DLOG T Log for K1 Marker and make 6,952.0 6,980.0 18:49 19:02 correction of -2 ft 11/13/2016 11/13/2016 0.88 PROD1 DRILL TRIP T Resume RIH pumping at minimum 6,980.0 8,450.2 19:02 19:55 rate ....... RIW = 14.5K 11/13/2016 11/13/2016 1.97 PROD1 DRILL KOST T Tag top of billet ........... PUH and 8,450.2 8,450.2 19:55 21:53 perform a 1 00'wiper trip to ensure clean BHA ......... RBIH and lightly set down on top of billet to begin milling ........... having major wieght transfer issues ........... 7 stalls so far........... still trying different tactics ........... too much friction and too many stalls.......... 11/13/2016 11/13/2016 0.35 PROD1 DRILL WPRT T Perform a wiper trip to the window and 8,450.2 7,444.0 21:53 22:14 mix a lube pill to pump so as to be back on bottom when pill comes out 11/13/2016 11/13/2016 0.40 PROD1 DRILL TRIP T RBIH 7,444.0 8,449.2 22:14 22:38 11/13/2016 11/14/2016 1.36 PROD1 STK KOST T BOBM. Still having weight transfer 8,449.2 8,449.2 22:38 00:00 issues and trying different tactics such as different pump rates, backreaming passes, wiper trips, different speeds, changing tool face, etc. with no luck. Still getting stalls. Have tried pumping a 20 bbI lube pill which seems to be helping somewhat....... 11/14/2016 11/14/2016 3.58 PROD1 STK KOST T Continuing to try and kick off billet at 8,449.2 8,449.2 00:00 03:34 8,450 ft. Still working with lube pill and trying different tactics. Have tried backreaming, moving the tool face orietation, different pump rates, speeds and tried 3 different drillers. Having weight transfer issues. Have now pumped beads to help with weight transfer ................. Page 13/37 Report Printed: 12/2712016 i1 rf � a Operations Summary (with Timelog Depths) 1B-18 Rig: NABORS CDR2-AC Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time our (hr) Phase Op Code Activity Code Time P -T -X Operation (ftKB) End Depth (ftKB) 11/14/2016 11/14/2016 3.92 PROD1 STK KOST T After the first 7 bbls of beads are out, 8,449.2 8,457.0 03:34 07:30 we start to get some weight transfer.............able to gently tag billet and start milling.............starting to lose weight again.............PUH for a short wiper and RBI and try again ........... impossible to get weight transfer without beads .......... continue drilling, but periodically lose WOB ....... Multiple pick ups and restarts. Rate = 1.41 bpm, Circ Press = 3,541, W HP = 608, IA = 38, OA = 07, CTW = 13.9K, WOB = .08 to.46 k 11/14/2016 11/14/2016 2.50 PROD1 DRILL DRLG T Continue drilling ahead. Pumping 1.5 8,457.0 8,508.0 07:30 10:00 bpm at 4000 psi. BHP = 4280 psi, WOB = 0.5-0.8KIbs ROP 10-30 fph. 11/14/2016 11/14/2016 0.25 PROD1 DRILL WPRT T PUH and dry drift kick off area. PUW = 8,508.0 8,450.0 10:00 10:15 26KIbs. Dry drift clean. 11/14/2016 11/14/2016 3.25 PROD1 DRILL WPRT T Continue to PUH into 5" casing and 8,450.0 7,050.0 10:15 13:30 jog area. Choke B plugging up with cuttings and aluminum. Clean and clear both Choke B and choke A. Significant amount of aluminum observed over the shakers. 11/14/2016 11/14/2016 1.00 PROD1 DRILL WPRT T RBIH. Clean trip through window and 7,050.0 8,508.0 13:30 14:30 open hole. 11/14/2016 11/14/2016 1.00 PROD1 DRILL DRLG T Continue drilling ahead. Pumping 1.45 8,508.0 8,574.0 14:30 15:30 bpm at 4300 psi. BHP = 4290 psi, WOB = 1.0KIbs ROP 50-80 fph. 11/14/2016 11/14/2016 0.25 PROD1 DRILL WPRT T PUH for short wiper to 8500, PUW = 8,574.0 8,574.0 15:30 15:45 271<Ibs. 11/14/2016 11/14/2016 2.00 PROD1 DRILL DRLG T Continue drilling ahead. Pumping 1.6 8,574.0 8,810.0 15:45 17:45 bpm at 4300 psi. BHP = 4290 psi, WOB = 1.9KIbs ROP 20-50 fph. 11/14/2016 11/14/2016 2.75 PROD1 DRILL WPRT T PUH for planned wiper trip. PUW = 8,810.0 7,808.0 17:45 20:30 27KIbs 11/14/2016 11/14/2016 0.50 PROD1 DRILL WPRT T RBI H. SOW 11 Klbs. 7,808.0 8,809.0 20:30 21:00 11/14/2016 11/15/2016 3.00 PROD1 DRILL DRLG T Continue drilling ahead. Pumping 1.6 8,809.0 8,910.0 21:00 00:00 bpm at 4300 psi. BHP = 4290 psi, WOB = 1.9KIbs ROP 20-50 fph. 11/15/2016 11/15/2016 5.10 PROD1 DRILL DRLG T Continue drilling ahead. Pumping 1.6 8,910.0 9,110.0 00:00 05.06 bpm at 4289 psi. BHP = 4320 psi, WOB = 1.8KIbs ROP 20-80 fph. Launch 5 x 5 Sweep pill prior to PUH for wiper trip 11/15/2016 11/15/2016 1.77 PROD1 DRILL WPRT T Perform wiper trip to 5" TT and 9,110.0 7,069.0 05:06 06:52 perform several jogs in 5 " casing 11/15/2016 11/15/2016 1.22 PROD1 DRILL TRIP T Trip back in hole 7,069.0 9,110.0 06:52 08:05 11/15/2016 11/15/2016 5.98 PROD1 DRILL DRLG T BOB drilling ahead. Pumping 1.5 bpm 9,110.0 9,374.8 08:05 14:04 at 4272 psi. BHP = 4294 psi, WOB = 1.2KIbs ROP 20-80 fph. Page 14137 Report Printed: 12/27/2016 Operations Summary (with Timelog Depths) 1B-18 Rig: NABORS CDR2-AC Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time Dur (hr) Phase Op Code Activity Code Time P -T -X Operation (W13) End Depth (RKB) 11/15/2016 11/15/2016 0.65 PROD1 DRILL WPRT T Perform 1,000 ft wiper trip a little 9,374.8 8,360.0 14:04 14:43 earlier than planned due to losing push ability..............pumped a sweep pill..................pill brought back sticky clay and some shale ............... 11/15/2016 11/15/2016 0.66 PROD1 DRILL WPRT T Trip back in hole 8,360.0 9,374.8 14:43 15:22 **Note: Town engineer called and would like us to keep an eye on two hot spots and make note in WSR if any issue noticed ........ 8,950 ft and 9,163 ft. Notified the day driller Greg also. 11/15/2016 11/15/2016 5.62 PROD1 DRILL DRLG T BOB drilling ahead. Pumping 1.65 9,374.9 9,469.0 15:22 21:00 bpm at 4172 psi. BHP = 4344 psi, WOB = 1.0Klbs ROP 20-30 fph. Swapping to new mud system (#4) at 9,389 ft. Around 1,500 ft an System #3 with .8% DS. 11/15/2016 11/15/2016 2.00 PROD1 DRILL DRLG T OBD 1.65 bpm at 3,993 psi FS, BHP 9,469.0 9,500.0 21:00 23:00 4,355 psi, CWT -7k, WOB .9k, ROP 7, weight transfer issue, high gama sinse 9,340 ft, confer with town, pumped 25 bbl Drill Zone pill, little help, make up and pump staggered beaded pills. 11/15/2016 11/16/2016 1.00 PROD1 DRILL DRLG P 9,500 ft OBD 1.65 bpm at 3,993 psi 91500.0 9,516.0 23:00 00:00 FS, BHP 4,367 psi, WOB .8, ROP 20- 30 ** Note: off trouble time 11/16/2016 11/16/2016 4.60 PROD1 DRILL DRLG P OBD 1.65 bpm at 3,993 psi FS, BHP 9,516.0 9,582.0 00:00 04:36 4,368 psi, CWT -4.5k, WOB .8k, continue staggered beaded pill sweeps, several restarts, BHA wipers, PUW's consistent 28k to 29k, pump 5x5 sweep 11/16/2016 11/16/2016 1.25 PROD1 DRILL WPRT P Early wiper to window, PUW 29k, 9,582.0 7,069.0 04:36 05:51 Make several jogs in 5" ......... 11/16/2016 11/16/2016 0.25 PROD1 DRILL WPRT P Wiper back in hole 7,069.0 7,410.0 05:51 06:06 11/16/2016 11/16/2016 0.20 PROD1 DRILL DLOG P Log for RA Tag and make correction 7,410.0 7,428.0 06:06 06:18 of + 5 ft. 11/16/2016 11/16/2016 1.20 PROD1 DRILL WPRT P Continue RBIH 7,428.0 8,889.0 06:18 07:30 11/16/2016 11/16/2016 1.30 PROD1 DRILL WPRT P Having to work through tight spot from 8,889.0 8,956.0 07:30 08:48 8,889 to 8,946 ft..............changing tool face and pump rates seemed to help. Appeared to be more hole geometry and swollen clays than cuttings until we hit 8,946 ft where it looks like we have a bed of cuttings ............ had a 12k overpull here....... town called and said to work down throough area and work back up cleaning up this tight spot Page 15137 Report Printed: 12/27/2016 Operations Summary (with Timelog Depths) ) 1B-18 Rig: NABORS CDR2-AC Job: DRILLING SIDETRACK Time Log StartTime End Time our (hr) Phase Op Code Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 11/16/2016 11/16/2016 0.70 PROM DRILL WPRT P Town called back and said since we 8,956.0 9,582.0 08:48 09:30 made it through this tight area to head to bottom and continue drilling until they call back ............ heading to bottom 11/16/2016 11/16/2016 8.50 PROM DRILL DRLG P BOBD 1.60 bpm at 4,027 psi FS, BHP 9,582.0 9,701.0 09:30 18:00 4,325 psi, CWT-3.5k, WOB .5k, continue staggered beaded pill sweeps, several restarts, BHA wipers, PUW's consistant 29k to 30k. Avg ROP = 14 fph 11/16/2016 11/17/2016 6.00 PROD1 DRILL DRLG P OBD 1.6 bpm at 4,190 psi FS, BHP 9,701.0 9,819.0 18:00 00:00 4,268 psi, CWT-9.8k, WOB .5k, ROP 18, continue beaded pills, PUW's 26k to 28k, added 1% LoTorc lube to system, seeing better CWT .0k, WOB 1.1k to 1.5k, ROP 19 11/17/2016 11/17/2016 4.00 PROD1 DRILL DRLG P Continue drilling ahead 1.6 bpm at 9,819.0 9,980.0 00:00 04:00 4,450 psi FS, BHP 4,370 psi, CWT .0k, WOB 1.1k 11/17/2016 11/17/2016 0.40 PROM DRILL WPRT P Wiper trip up hole 900 ft, PUW 26k 9,982.0 9,082.0 04:00 04:24 11/17/2016 11/17/2016 0.55 PROD1 DRILL WPRT P Wiper trip back in hole, slow speed to 9,082.0 9,982.0 04:24 04:57 30 fpm at .8 bpm to work past 9,465 ft to 9,485 ft, continue in hole. 11/17/2016 11/17/2016 14.95 PROM DRILL DRLG P BOBD 1.61 bpm at 4,417 psi FS, BHP 9,982.0 10,200.0 04:57 19:54 4,306 psi, CWT 3k, WOB .7k, ROP 10 to 30 11/17/2016 11/17/2016 1.20 PROD1 DRILL CIRC P 10,200 ft. TD called, reciprocate pipe, 10,200.0 10,200.0 19:54 21:06 PUW 26k while pumping last of beaded pill, build Hi/Lo vis sweeps, pump 1 0x1 0 Lo/Hi sweep. 11/17/2016 11/17/2016 1.80 PROD1 DRILL WPRT P Chase sweeps to window, PUW 25k, 10,200.0 7,070.0 21:06 22:54 slow thru window 6 fpm at ,5 bpm. 11/17/2016 11/17/2016 0.95 PROM DRILL WPRT P Jet/jog 5" 7,370 ft to 7,070 ft 2 times, 7,070.0 7,370.0 22:54 23:51 wait for heavy returns to clean up over shaker, pump 10x10. 11/17/2016 11/18/2016 0.15 PROD1 DRILL WPRT P RBIH to 7,575 ft. 7,370.0 7,575.0 23:51 00:00 11/18/2016 11/18/2016 2.85 PROD1 DRILL WPRT P Continue RIH from 7,575 ft to 8,005 ft, 7,575.0 72.2 00:00 02:51 chase 1 0x1 0 sweeps to 5" and Jet/jog 5" 7,370 ft to 7,070 ft 2 times, wait for returns to clean up, continue wiper to swab, 200 ft jog at surface. 11/18/2016 11/18/2016 1.90 PROM DRILL TRIP P Bump up, reset counters, RBIH to 72.2 6,940.0 02:51 04:45 confirm TD, DS pillow block overheating, slow RIH speed to troubleshoot. 11/18/2016 11/18/2016 0.20 PROD1 DRILL DLOG P Tie in to K1 for minus 1.5 ft correction. 6,940.0 6,978.0 04:45 04:57 Pump 1 0x1 0 sweep 11/18/2016 11/18/2016 0.72 PROM DRILL TRIP P Continue RIH to EOB 6,978.0 7,896.0 04:57 05:40 11/18/2016 11/18/2016 0.92 PROM DRILL WPRT P At EOB.chase sweep to window and 7,896.0 7,086.0 05:40 06:35 1 make several jogs in 5" Page 16137 Report Printed: 12/27/2016 Operations Summary (with Timelog Depths) 1B-18 Rig: NABORS CDR2-AC Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time Dur (hr) Phase Op Code Activity Code Time P -T -X Operation (ftKB) End Depth (WB) 11/18/2016 11/18/2016 1.33 PROD1 DRILL TRIP P RBIH to confirm TD 7,086.0 10,200.0 06:35 07:55 At 9,009' we tagged up, PUH reduce pump rate to .5 and went through area without a weight bobble................no other issues seen to TD depth. PUWs were are all in normal range .....26k until we got to 10,180' and then we had a 12k overpull....... ..... looks like TD is at 10,200.0 11/18/2016 11/18/2016 0.35 PROM DRILL TRIP P On bottom and just started pumping 10,200.0 10,130.0 07:55 08:16 the liner running pill and waiting for pill to reach bit ............... 11/18/2016 11/18/2016 2.97 PROD1 DRILL TRIP P POOH laying in beaded liner pill to 10,130.0 92.0 08:16 11:14 surface and completion fluid (11.8 ppg). 50 fpm and PUW = 25K Paint flags at 8,372 ft and at 5,572 ft. 11/18/2016 11/18/2016 0.64 PROD1 DRILL OWFF P At surface. Perform Flow Check. 92.0 92.0 11:14 11:52 Hold PJSM for laying down BHA #18. Passing Flow Check 11/18/2016 11/18/2016 0.85 FROM DRILL PULD P L/DBHA #18 92.0 0.0 11:52 12:43 11/18/2016 11/18/2016 1.45 COMPZ1 CASING EQRP P Swap out bails after PJSM. 0.0 0.0 12:43 14:10 11/18/2016 11/18/2016 2.60 COMPZ1 CASING PUTB P Start making up 55 joints 2 3/8" 0.0 1,694.0 14:10 16:46 Slotted Liner Note: Well Flowing BOP Drill performed. 11/18/2016 11/18/2016 1.45 COMPZ1 CASING PULD P MUAL1liner assembly toBHA #19, 1,694.0 1,738.2 16:46 18:13 MU to CoilTrak, surface test 11/18/2016 11/18/2016 2.00 COMPZ1 CASING RUNL P RIH with BHA #19, Tie in at flag for 1,738.2 8,519.0 18:13 20:13 minus 7 ft correction, PUW 28k, RBIH, clean thru window and build section. 11/18/2016 11/19/2016 3.77 COMPZ1 CASING RUNL P Start stacking, begin working liner 8,519.0 10,092.0 20:13 00:00 assembly down, breakover 35k, broke free from 9,450 fit to 10,020 ft, work liner hard, confer with town. 11/19/2016 11/19/2016 0.25 COMPZ1 CASING RUNL P Continue working liner, unable to get 10,092.0 8,398.0 00:00 00:15 deeper than 10,092 ft, confer with town, PUW 38k, WOB -4.8k. Release off liner assembly at 1.2 bpm, PUW 32k, WOB -0.5k. reset counters. TOL 8,398 ft. 11/19/2016 11/19/2016 1.95 COMPZ1 CASING TRIP P POOH pumping across the top. 8,398.0 44.2 00:15 02:12 11/19/2016 11/19/2016 0.55 COMPZ1 CASING OWFF P On surface, flow check, good. PJSM- 44.2 44.2 02:12 02:45 LD BHA over dead well. 11/19/2016 11/19/2016 0.75 COMPZ1 CASING PULD P LD BHA#19. 44.2 0.0 02:45 03:30 11/19/2016 11/19/2016 0.50 COMPZ1 CASING BOPE P PJSM- Function test BOPE. 0.0 0.0 03:30 04:00 11/19/2016 11/19/2016 1.00 COMPZ1 CASING PULD P PJSM- MU OH Anchored billet to BHA 0.0 73.0 04:00 05:00 #20, MU to CoilTrak, surface test, DPS malfuntioning, unstab to change out CoilTrak tools. Page 17/37 Report Printed: 12/27/2016 Operations Summary (with Timelog Depths) ) 1 B-18 Rig: NABORS CDR2-AC Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time Dur (hr) Phase Op Code Activity Code Time P -T -X Operation (ftKB) End Depth (ftKB) 11/19/2016 11/19/2016 0.93 COMPZI CASING PULD T Swap CoilTrak tools. 73.0 73.0 05:00 05:55 11/19/2016 11/19/2016 2.50 COMPZI CASING RUNL P RIH with BHA #20, EDC open. 73.0 6,956.0 05:55 08:25 11/19/2016 11/19/2016 0.29 COMPZI CASING DLOG P Log for K1 Marker and make 6,956.0 6,982.0 08:25 08:43 correction of minus 1.5 ft 11/19/2016 11/19/2016 0.16 COMPZI CASING RUNL P Continue RIH with anchored billet 6,982.0 7,374.0 08:43 08:52 11/19/2016 11/19/2016 0.15 COMPZI CASING RUNL P Stop here and close EDC and perform 7,374.0 7,374.0 08:52 09:01 a weight check.............WT CK = 26k 11/19/2016 11/19/2016 0.50 COMPZI CASING RUNL P Continue RIH with anchored billet 7,374.0 7,418.0 09:01 09:31 11/19/2016 11/19/2016 0.64 COMPZI CASING RUNL T Tag hard at 7,918 ft with 7,918.0 7,918.0 09:31 10:10 billet .......... set down 3k and could not get string weight back. Tried PUH 50 ft and RBIH with no luck...............tried several other options to no avail. Last PUW was at 32k ......... Confer with town engineer and decision made to POOH and put on a 1.5 degree motor and 2.80" Ridge Set Mill and clean out the hole and tag TOL to determine exact depth. 11/19/2016 11/19/2016 1.84 COMPZI CASING TRIP T POOH with anchored billet after 7,918.0 80.6 10:10 12:00 opening EDC and bringing pumps online at .7 bpm 11/19/2016 11/19/2016 0.68 COMPZI CASING OWFF T At surface. Perform flow check. 80.6 80.6 12:00 12:41 11/19/2016 11/19/2016 0.40 COMPZI CASING PULD T LID BHA #20 BHA came back with 80.6 0.0 12:41 13:05 some sticky clay -like substance on it.............. 11/19/2016 11/19/2016 0.50 COMPZ1 CASING PULD T P/U BHA #21w/1.5 degree motor and 0.0 67.3 13:05 13:35 2.80" Ridge Set Mill 11/19/2016 11/19/2016 1.20 COMPZI CASING TRIP T RIH with EDC open pumping at .5 67.3 6,953.0 13:35 14:47 bpm 11/19/2016 11/19/2016 0.26 COMPZ1 CASING DLOG T Log for K1 Marker and make 6,953.0 6,972.0 14:47 15:03 correction of minus 1.5 ft 11/19/2016 11/19/2016 0.12 COMPZI CASING TRIP T Continue RIH 6,792.0 7,297.0 15:03 15:10 11/19/2016 11/19/2016 0.09 COMPZI CASING TRIP T Stop here and close EDC and perform 7,297.0 7,297.0 15:10 15:15 a weight check.............WT CK = 28k 11/19/2016 11/19/2016 0.31 COMPZ1 CASING TRIP T Continue RIH 7,297.0 7,918.0 15:15 15:34 11/19/2016 11/19/2016 0.43 COMPZI CASING REAM T Have passed where we were hung up 7,918.0 8,399.0 15:34 16:00 with the billet earlier ........... saw only the slightest weight bobble..............continuing creeping in hole at 20 fpm..... offline with pump and continue RIH to dry tag TOL at 8,399 ft .................... 11/19/2016 11/19/2016 0.85 COMPZI CASING DIS P T PUH slowly and bring pump online to 8,399.0 8,380.0 16:00 16:51 displace KW F with 8.8 Power -Pro before pumping sweeps and cleaning hole........... Page 18/37 Report Printed: 12/27/2016 _s- Operations Summary (with Timelog Depths) w 1B-18 Rig: NABORS CDR2-AC Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time Dur (hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth (ftKB) 11/19/2016 11/19/2016 2.65 COMPZ1 CASING REAM T Start PUH now that KWF has been 8,380.0 7,370.0 16:51 19:30 displace and begin hole cleaning operations, work area 7,955 ft to 7,840 ft, pump 5x5, RBIH, chase sweep to window, pump 2nd 5x5, jet/jog 5"- 7,370 ft to 7,070 ft, wait for sweeps to come over shaker. 11/19/2016 11/19/2016 1.60 COMPZ1 CASING TRIP T POOH, 200 ft jog at surface. PJSM- 7,370.0 62.3 19:30 21:06 PUD BHA 11/19/2016 11/19/2016 1.85 COMPZ1 CASING PULD T On surafce, Attempt to PUD, unable to 62.3 62.3 21:06 22:57 bleed down, lower checks not holding, PJSM- scope change, close Annular and EDC, open bleed to pump, WHP drops 1,170 psi to 800 psi, troubleshoot, upper checks not holding also, confer with town, PD BHA #21 and RIH to kill well. 11/19/2016 11/19/2016 0.65 COMPZ1 CASING TRIP T RBIH with BHA#21, EDC open, 62.3 62.3 22:57 23:36 attempt flush upper floats 1.7 bpm while RIH, decided to stop at 350 ft, shut in well, bleed off to pumps, upper QC's holding, POOH 11/19/2016 11/20/2016 0.40 COMPZ1 CASING PULD T Bump up, space out, bleed back 62.3 62.3 23:36 00:00 pump, upper checks holding, PJSM- PUD BHA #21 under 1st contingency, close Annular, EDC closed. Note: BHI 3.5 hrs down time. 11/20/2016 11/20/2016 3.35 COMPZ1 CASING PULD T PUD BHA#21, close Annular, EDC 62.3 0.0 00:00 03:21 closed. LD mill and motor, LD upper half, check connection torques, open EDC, load PDL and MU anchored billet. 11/20/2016 11/20/2016 1.50 COMPZ1 CASING PULD T PJSM- PD OH Anchored billet BHA 0.0 72.9 03:21 04:51 #22, replace UQC floats, MU to CoilTrak, surface test. 11/20/2016 11/20/2016 1.66 COMPZ1 CASING TRIP T RIH with OH Anchored Billet (Shears 72.9 6,954.0 04:51 06:30 screws checked, pinned heavy, 16,960#, 23-28k shear) 11/20/2016 11/20/2016 0.20 COMPZ1 CASING DLOG T Log for K1 Marker and make 6,954.0 6,980.0 06:30 06:42 correction of minus 1.0 ft. 11/20/2016 11/20/2016 0.15 COMPZ1 CASING TRIP T Continue RIH with Anchored Billet with 6,980.0 7,372.0 06:42 06:51 open EDC pumping at minimum rate 11/20/2016 11/20/2016 0.55 COMPZ1 CASING TRIP T Continue RIH with anchored 7,372.0 8,399.0 06:51 07:24 billet ....................... Note; Passed the problem area around 7,918 ft with only a slight weight bobble.................smooth sailing down to TOL....... 11/20/2016 11/20/2016 0.28 COMPZ1 CASING TRIP P Tag TOL with billet at 8,399 ft ...... set 8,399.0 8,387.2 07:24 07:41 down 3k............ PUH to 24 k........ bring pump online and pump off of billet ........... TOB at 8,387.25 ft, 150 degrees ROHS 11/20/2016 11/20/2016 1.80 COMPZ1 CASING TRIP P POOH pumping at 1.2 bpm............. 8,387.2 67.8 07:41 09:29 11/20/2016 11/20/2016 0.80 COMPZ1 CASING PULD P At surface. Pressure Undeploy BHA 67.8 67.8 09:29 10:17 #22 after PJSM. Page 19137 Report Printed: 12/27/2016 Operations Summary (with Timelog Depths) 1B-18 Rig: NABORS CDR2-AC Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time Dur (hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth (WB) 11/20/2016 11/20/2016 0.40 COMPZ1 CASING PULD P Lay down BHA#22 67.8 0.0 10:17 10:41 11/20/2016 11/20/2016 0.55 PROD2 STK PULD P P/U BHA #23 w/ AKO .8° motor and 0.0 72.1 10:41 11:14 HCC 2.7 X 3.0" bit 11/20/2016 11/20/2016 0.85 PROD2 STK PULD P Pressure Deploy BHA #23 72.1 72.1 11:14 12:05 11/20/2016 11/20/2016 1.10 PROD2 RIGMNT SVRG P Service Rig------- Service Choke B, 72.1 72.1 12:05 13:11 Rotate Top Drive, Change out Locking Pin hose on ram. 11/20/2016 11/20/2016 1.33 PROD2 STK TRIP P RIH with open EDC pumping at .5 72.1 6,954.0 13:11 14:31 bpm 11/20/2016 11/20/2016 0.18 PROD2 STK DLOG P Log for K1 Marker and make 6,954.0 6,997.0 14:31 14:42 correction of minus 1.5 ft 11/20/2016 11/20/2016 0.14 PROD2 STK TRIP P Continue RIH 6,997.0 7,381.0 14:42 14:50 11/20/2016 11/20/2016 0.15 PROD2 STK TRIP P Stop here and close EDC and perform 7,381.0 7,381.0 14:50 14:59 a weight check..WT CK = 26k 11/20/2016 11/20/2016 0.30 PROD2 STK TRIP P Continue RIH to billet 7,381.0 8,387.6 14:59 15:17 11/20/2016 11/20/2016 1.50 PROD2 STK KOST P Tag TOB at 8,387.64 ft ......... PUH and 8,387.6 8,387.0 15:17 16:47 start creeping back in hole.............1.5 bpm CP = 3,797 WHP = 510 BHP =4,272 CTW = 13.87 K WOB = .34 K 11/20/2016 11/21/2016 7.21 PROD2 STK KOST P OBD ...... 1.59 bpm Circ Press = 8,387.0 8,387.0 16:47 00:00 4,084 WHP = 510 BHP = 4,252 CTW = 24K W OB = .54 K Having some weight transfer issues...... have pumped a Hi-Lo Vis pill and a beaded pill to help........ BHA wipers, beads, varying speeds, rates and trenching, engauged at 8,386.6 ft, aluminum across shaker. 11/21/2016 11/21/2016 3.15 PROD2 STK KOST P Kick off billet using beads, frequent 8,387.0 8,395.0 00:00 03:09 stalls due to stick slipping after starting, 1.53 bpm at 3,800 psi FS, BHP 4,250 psi, WHP 495, IA 134, OA 0 11/21/2016 11/21/2016 0.50 PROD2 DRILL DRLG P OBD 1.55 bpm at 3,800 psi FS, BHP 8,395.0 8,430.0 03:09 03:39 4,257 psi, CWT 13.8k, W0130.81k, ROP 53 11/21/2016 11/21/2016 0.25 PROD2 DRILL WPRT P Wiper up hole above billet to 8,300 ft, 8,430.0 8,430.0 03:39 03:54 PUW 26k, RBIH, dry drift billet area clean. 11/21/2016 11/21/2016 6.80 PROD2 DRILL DRLG P BOBD 1.61 bpm at 3,998 psi FS, BHP 8,430.0 8,750.0 03:54 10:42 4,268 psi, CWT 11.8k, WOB 1.0k, ROP 40 to 80 fph Page 20/37 Report Printed: 12/27/2016 6 Operations Summary (with Timelog Depths) 1B-18 Rig: NABORS CDR2-AC Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time Dur (hr) Phase Op Code Activity Code Time P -T -X Operation (ftKB) End Depth (ftKB) 11/21/2016 11/21/2016 1.45 PROD2 DRILL WPRT P Once 5 x 5 sweep is out of bit, PUH 8,750.0 8,750.0 10:42 12:09 for a wiper trip to the 5".............make several jogs in 5".......... Town is also looking at the DLS data to determine if we need to POOH and change to a lesser degree motor.............doglegs are coming in at 16 degrees instead of 12 degrees ............... Jeff calls back and town has decided to keep what we have on for now.................DLS is trending downward .............. 11/21/2016 11/21/2016 7.53 PROD2 DRILL DRLG P BOBD 1.63 bpm at 4,359 psi FS, BHP 8,750-0 9,008.0 12:09 19:40 4,323 psi, CWT 10.8k, WOB 1.0k, ROP 20 to 40 fph Note: The two dog legs right before 1730hrs were both 16.4 and 18 degrees.......... 11/21/2016 11/21/2016 2.00 PROD2 DRILL WPRT P At 9,008 ft and having weight transfer 9,008.0 9,008.0 19:40 21:40 issues ...... ...... current mud system has around 1,400 ft and .8 DS ...... will try and do a 1,000 ft wiper trip to see if that helps before doing a mud swap......... wiper trip did not help......... start pumping a beaded pill .... 11/21/2016 11/22/2016 2.32 PROD2 DRILL DRLG P BOBD 1.53 bpm at 4,357 psi FS, BHP 9,008.0 9,101.0 21:40 00:00 4,337 psi, CWT 6.3k, WOB 1.4k, ROP 20 to 50 fph Note: We got weight transfer back before the beaded pill exited the nozzle..............still on System #4 11/22/2016 11/22/2016 8.50 PROD2 DRILL DRLG P OBD 1.5 bpm at 3,981 psi FS, BHP 9,101.0 9,410.0 00:00 08:30 4,292 psi, CWT -0.7k, WOB 2.0k, ROP 30, W HP 478, IA 440, OA 0 Note: Mud swap with new mud out bit at 9,242 ft. 11/22/2016 11/22/2016 2.00 PROD2 DRILL WPRT P Wiper trip to window, PUW 25k, hole 9,410.0 7,070.0 08:30 10:30 loading up, 200 ft jog at EOB, Pulling heavy thru build from 7,820 ft, clean thru window, Jet/Jog 5", wait for shaker to clean up, RBI 11/22/2016 11/22/2016 0.15 PROD2 DRILL DLOG P Log RA for a plus 4.0 ft correction. 7,070.0 7,429.0 10:30 10:39 11/22/2016 11/22/2016 0.75 PROD2 DRILL WPRT P Wiper back in hole, clean thru build 7,429.0 9,410.0 10:39 11:24 and hole appears clean. 11/22/2016 11/22/2016 1.30 PROD2 DRILL DRLG P BOBD 1.52 bpm at 4,055 psi FS, BHP 9,410.0 9,432.0 11:24 12:42 4,348 psi, CWT 6k, WOB 1.1 k, ROP 80. Lost all returns at 9,424 ft, PUW 28k, RBIH, restart 1.52 bpm at 4,055 FS, BHP 4,338 psi, CWT 6k, WOB 1.1 k, ROP 99, healing starting at 9,445 ft. Page 21/37 Report Printed: 12/27/2016 Operations Summary (with Timelog Depths) ) 1 B-18 N Rig: NABORS CDR2-AC Job: DRILLING SIDETRACK Time Log Start Time End Time Dur (hr) Phase Op Code Activity Code Time P-T-x Operation Start Depth (ftKB) End Depth (RKB) 11/22/2016 11/22/2016 5.50 PROD2 DRILL DRLG P OBD 1.52 bpm at 4,055 psi FS, BHP 9,432.0 9,561.0 12:42 18:12 4,338 psi, CWT-8k, WOB 1.4k, ROP 3, hit Anchorite, slow drilling 11/22/2016 11/22/2016 1.30 PROD2 DRILL DRLG P OBD 1.52 bpm at 4055 psi FS, BHP 9,561.0 9,629.0 18:12 19:30 4331, WHP 375, IA 367, OA 0 11/22/2016 11/22/2016 0.25 PROD2 DRILL WPRT P 200'w per up hole, PUW 9,629.0 9,429.0 19:30 19:45 11/22/2016 11/22/2016 0.25 PROD2 DRILL WPRT P Wiper back in hole, RIW 5 k 9,429.0 9,629.0 19:45 20:00 11/22/2016 11/23/2016 4.00 PROD2 DRILL DRLG P BOBD 1.52 bpm at 4055 psi FS, BHP 9,629.0 9,779.0 20:00 00:00 4350, WHP 373, IA 368, OA 6 11/23/2016 11/23/2016 0.75 PROD2 DRILL DRLG P OBD 1.52 bpm at 4055 psi FS, BHP 9,779.0 9,810.0 00:00 00:45 4431, WHP 375, IA 368, OA 6 11/23/2016 11/23/2016 0.35 PROD2 DRILL WPRT P Wiper up hole 1000', PUW 28 k 9,810.0 8,800.0 00:45 01:06 11/23/2016 11/23/2016 0.50 PROD2 DRILL WPRT P Wiper back in hole, RIW 9 k 8,800.0 9,810.0 01:06 01:36 11/23/2016 11/23/2016 7.95 PROD2 DRILL DRLG P BOBD 1.52 bpm at 3860 psi FS, BHP 9,810.0 9,989.0 01:36 09:33 4326, WHP 359, IA 375, OA 0 11/23/2016 11/23/2016 2.00 PROD2 DRILL WPRT P Wiper trip to window, PUW 27k, hole 9,989.0 7,070.0 09:33 11:33 loading up, 200 ft jog at EOB, Pulling heavy 31 k thru build from 7,820 ft, clean thru window, Jet/Jog 5", wait for shaker to clean up, RBIH 11/23/2016 11/23/2016 0.25 PROD2 DRILL DLOG P Log RA for a plus 4.5 ft correction. 7,070.0 7,430.0 11:33 11:48 11/23/2016 11/23/2016 0.95 PROD2 DRILL WPRT P Wiper back in hole, clean thru build, 7,430.0 9,989.0 11:48 12:45 past billet and hole appears clean RIW . 11/23/2016 11/23/2016 5.25 PROD2 DRILL DRLG P BOBD 1.55 bpm at 4,100 psi FS, BHP 9,989.0 10,106.0 12:45 18:00 4,366 psi, CWT-3.7k, WOB, 1.2k, WHP 373, IA 400, OA 0, BHA wiper at 9,949' 11/23/2016 11/24/2016 6.00 PROD2 DRILL DRLG P Continue drilling ahead 1.52 bpm at 10,106.0 10,246.0 18:00 00:00 4,100 FS, BHP 4384, WHP 344, IA 461, OA 0, BHA wiper at 10,120', 10,165', 10,192', pumping beaded pills 11/24/2016 11/24/2016 3.25 PROD2 DRILL DRLG P Continue drilling ahead on bottom, 1.4 10,246.0 10,299.0 00:00 03:15 bpm at 4200 psi, BHP 4371, WHP 366, IA 466, OA 0 11/24/2016 11/24/2016 0.50 PROD2 DRILL WPRT P 1000' Wiper up hole PUW 25 k 10,299.0 9,300.0 03:15 03:45 11/24/2016 11/24/2016 0.35 PROD2 DRILL WPRT P Wiper back in hole. RIW 2 k 9,300.0 10,299.0 03:45 04:06 11/24/2016 11/24/2016 12.25 PROD2 DRILL DRLG P BOBD 1.4 bpm at 3921 psi FS, BHP 10,299.0 10,688.0 04:06 16:21 4374, WHP 370, IA 436, OA 0, lots of pick ups and beads, PUW's 25k to 27k and clean. pump 10x10 11/24/2016 11/24/2016 2.50 PROD2 DRILL WPRT P Wiper trip to window, PUW 25k, pull 10,688.0 7,410.0 16:21 18:51 up thru window jog the 5 inch up to 7,410- 11/24/2016 11/24/2016 0.25 PROD2 DRILL DLOG P RIH , log the RA marker correction of 7,410.0 7,430.0 18:51 19:06 plus 5.5' 11/24/2016 11/24/2016 1.25 PROD2 DRILL WPRT P Wiper back in hole RIW 1.5 k 7,430.0 10,688.0 19:06 20:21 11/24/2016 11/25/2016 3.65 PROD2 DRILL DRLG P BOBD 1.35 bpm at 4060 psi FS, BHP 10,688.0 10,770.0 20:21 00:00 4470, WHP 408, IA 372, OA 0 Page 22137 Report Printed: 12/27/2016 i E Operations Summary (with Timelog Depths) IB -18 Rig: NABORS CDR2-AC Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time Dur (hr) Phase Op Code Activity Code Time P -T -X Operation (RKB) End Depth (RKB) 11/25/2016 11/25/2016 9.95 PROD2 DRILL DRLG P OBD 1.35 bpm at 4,060 psi FS, BHP 10,770.0 10,900.0 00:00 09:57 4395, WHP 363, IA 367, OA 0, Lo -vis sweeps folowed by lots of beads and numerous pick ups, PUW's 28k to 31 k, pumped last of beaded pill, MU Hi -vis sweep 11/25/2016 11/25/2016 0.75 PROD2 DRILL CIRC P TD called, reciprocate pipe, PUW 28k 10,900.0 10,900.0 09:57 10:42 while pumping last of beaded pill, build Hi/Lo vis sweeps, pump 1 0x1 0 Lo/Hi sweep. 11/25/2016 11/25/2016 2.10 PROD2 DRILL WPRT P Chase sweeps to window, PUW 28k, 10,900.0 7,070.0 10:42 12:48 Jog at EOB, slow thru window 6 fpm at 0.5 bpm. 11/25/2016 11/25/2016 1.15 PROD2 DRILL WPRT P Jet/jog 5" from 7,370 ft to 7,070 ft 2 7,070.0 7,370.0 12:48 13:57 times, wait for returns to clean up over shaker, pump 10x10. 11/25/2016 11/25/2016 0.55 PROD2 DRILL WPRT P RBIH to 8,250 ft. 7,370.0 8,250.0 13:57 14:30 11/25/2016 11/25/2016 2.40 PROD2 DRILL WPRT P Chase 1 0x1 0 sweeps to 5" and Jet/jog 8,250.0 72.2 14:30 16:54 5" Fromm 7,370 ft to 7,070 ft, wait for returns to clean up, continue wiper to swab, 250 ft jog at surface. 11/25/2016 11/25/2016 1.60 PROD2 DRILL TRIP P Bump up, reset counters, RBIH to 72.2 6,940.0 16:54 18:30 confirm TD 11/25/2016 11/25/2016 0.25 PROD2 DRILL DLOG P Tie in to K1 for minus 1.0 ft correction. 6,940.0 6,980.0 18:30 18:45 Pump 10x10 sweep, jogged the build section, jetted the 5 inch, 11/25/2016 11/25/2016 2.50 PROD2 DRILL TRIP P Continue RIH, bobble at 10299', TF 6,980.0 10,900.0 18:45 21:15 stops rotated, PUH, RBIH clean with drilled TF, confirmed TD 10,900'. 11/25/2016 11/26/2016 2.75 PROD2 DRILL DISP P POOH laying in 12.0 ppg liner running 10,900.0 4,167.0 21:15 00:00 pill with beads, painting EOP flags at 9,800' and 6,200' 11/26/2016 11/26/2016 1.00 PROD2 DRILL TRIP P Continue POOH 4,167.0 72.1 00:00 01:00 11/26/2016 11/26/2016 0.75 PROD2 DRILL OW FF P PJSM, check well for flow 72.1 72.1 01:00 01:45 11/26/2016 11/26/2016 1.00 PROD2 DRILL PULD P LD drilling BHA# 23 72.1 0.0 01:45 02:45 11/26/2016 11/26/2016 0.30 COMPZ2 CASING PUTB P Prep rig floor to run liner. 0.0 0.0 02:45 03:03 11/26/2016 11/26/2016 0.25 COMPZ2 CASING SFTY P PJSM, to MU lower AL3 -01 liner 0.0 0.0 03:03 03:18 section ** Note: Bit grade 8 -6 -LM -NX -1 -BT - TD, pictures are on the s:drive 11/26/2016 11/26/2016 2.95 COMPZ2 CASING PUTB P MU Ported bullnose, 32 jts of slotted 0.0 1,044.7 03:18 06:15 liner and shorty to BHA #24, change out checks, surface test. 11/26/2016 11/26/2016 2.00 COMPZ2 CASING RUNL P RIH with AL3 -01 lower liner assembly, 1,044.7 8,450.0 06:15 08:15 minus 6.0 ft at flag, continue RIH. Page 23/37 Report Printed: 12/27/2016 Operations Summary (with Timelog Depths) IB -18 a. Rig: NABORS CDR2-AC Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time Dur (hr) Phase Op Code Activity Code Time P -T -X Operation (RKB) End Depth (MB) 11/26/2016 11/26/2016 3.00 COMPZ2 CASING RUNL T Stacking 8,450 ft to 8,500 ft, PUW 8,450.0 9,910.0 08:15 11:15 30k, continue RIH, stacking at 9,800 ft, attempt to work down, loosing ground to 9,669 ft, pump .4 bpm, work to 9,775 ft, PU 225 ft, RIH 55 fpm to 9,910 ft, PUW 35k, loosing ground getting back to 9,900 ft, PUH, RBIH to 9,906 ft, unable to work deeper, loosing ground to 9,880 ft, confer with town. 11/26/2016 11/26/2016 2.50 COMPZ2 CASING TRIP T POOH for BOPE test and plan 9,910.0 1,044.7 11:15 13:45 forward, PUW 36k. 11/26/2016 11/26/2016 0.50 COMPZ2 CASING OWFF T On surface, monitor well for flow, 1,044.7 1,044.7 13:45 14:15 PJSM- LD BHA over dead well. 11/26/2016 11/26/2016 0.75 COMPZ2 CASING PULD T LD BHA #24, prep floors. 1,044.7 1,000.2 14:15 15:00 11/26/2016 11/26/2016 3.00 COMPZ2 CASING PULL T PJSM- LD shorty, 32 its slotted and 1,000.2 0.0 15:00 18:00 bullnose. 11/26/2016 11/26/2016 2.00 COMPZ2 CASING CTOP T Flush surface lines and displace coil to 0.0 0.0 18:00 20:00 fresh water, grease choke manifold 11/26/2016 11/26/2016 3.25 COMPZ2 WHDBOP BOPE P Start BOP testing, test witness waived 0.0 0.0 20:00 23:15 per state tester Lou Grimadli, 3,500 psi high/250 psi low/2,500 annular preventor. Stab INJH test inner reel valve, stripper 11/27/2016 11/27/2016 5.00 COMPZ2 WHDBOP BOPE T Continue BOP testing, test witness 0.0 0.0 00:00 05:00 waived per state tester Lou Grimaldi, 3,500 psi high/250 psi low/2,500 annular preventor flowing BOP check list. 11/27/2016 11/27/2016 3.00 COMPZ2 CASING CTOP T RD test equipment, flush surface lines 0.0 0.0 05:00 08:00 and displace coil to 12.0 ppg completion fluid, grease choke manifold and stack 11/27/2016 11/27/2016 1.35 COMPZ2 CASING PULD T PJSM, MU Cleanout BHA #25 with a 0.0 62.4 08:00 09:21 0.8° ako motor and D331 GEB, 2.79" no/go, MU to CoilTrak, surface test. 11/27/2016 11/27/2016 1.40 COMPZ2 CASING TRIP T RIH with clean out BHA #25 62.4 6,940.0 09:21 10:45 11/27/2016 11/27/2016 0.20 COMPZ2 CASING DLOG T Tie in to K1 for minus 1.5 ft correction. 6,940.0 6,973.0 10:45 10:57 11/27/2016 11/27/2016 1.65 COMPZ2 CASING TRIP T Continue RIH, close EDC, PUW 6,973.0 10,900.0 10:57 12:36 above window 27k, clean thru build, some drag just past billet, clean past 9,910 ft, (15k CWT) confirm TD again at 10,900 ft (10k CWT) 11/27/2016 11/27/2016 0.25 COMPZ2 CASING SFTY T Confirm TD again at 10,900 ft (101k 10,900.0 10,900.0 12:36 12:51 CWT) confer with town, change of scope, will not clean out, pump new bedaded completion fluid to surface. PJSM- change of scope. 11/27/2016 11/27/2016 5.50 COMPZ2 CASING CIRC T Reciprocate pipe, PUW 29k, while 10,900.0 10,900.0 12:51 18:21 making up 100 bbl of 12.0 ppg beaded liner pill, 2ppb beads, 3% Safe Lube, and pumping to mill, pulled 34.5k at 9,905 11/27/2016 11/27/2016 3.00 COMPZ2 CASING TRIP T Discuss plan forward, POOH from 10,900.0 62.4 18:21 21:21 10,570' displacing wellbore to beads, beads to surface, continue POOH pumping pipe displacement. Page 24137 Report Printed: 12/27/2016 i F Operations Summary (with Timelog Depths) IB -18 Rig: NABORS CDR2-AC Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time Dur (hr) Phase Op Code Activity Code Time P -T -X Operation (ftKB) End Depth (ftKB) 11/27/2016 11/27/2016 0.50 COMPZ2 CASING OWFF T Tag up at surface, PJSM, check well 62.4 62.4 21:21 21:51 for flow 11/27/2016 11/27/2016 0.65 COMPZ2 CASING PULD T LD Cleanout BHA 62.4 0.0 21:51 22:30 11/27/2016 11/27/2016 0.50 COMPZ2 CASING SFTY T Tools OOH, Prep to MU liner 0.0 0.0 22:30 23:00 assembly 11/27/2016 11/27/2016 0.75 COMPZ2 CASING PUTB T MU 16 joints of slotted liner 0.0 505.6 23:00 23:45 11/27/2016 11/28/2016 0.25 COMPZ2 CASING PULD T PU/MU BHI Coiltrak tools, w/ agitator 505.6 505.6 23:45 00:00 11/28/2016 11/28/2016 1.00 COMPZ2 CASING PULD T Continue MU Coiltrak tools, surface 505.6 557.1 00:00 01:00 test 11/28/2016 11/28/2016 1.50 COMPZ2 CASING RUNL T RIH, with AL3 -01 liner running BHA# 557.1 7,364.0 01:00 02:30 26 with agitator 11/28/2016 11/28/2016 0.25 COMPZ2 CASING RUNL T Correct to the 6,700' EOP flag, 7,364.0 7,450.0 02:30 02:45 continue IH 11/28/2016 11/28/2016 0.25 COMPZ2 CASING DLOG T Log the K1 correction of plus 5.0' 7,450.0 7,450.0 02:45 03:00 11/28/2016 11/28/2016 0.55 COMPZ2 CASING RUNL T Continue RIH to bottom, no pumps, 35 7,450.0 9,110.0 03:00 03:33 fpm, BHP 4 450 psi, annular increasing 11/28/2016 11/28/2016 1.30 COMPZ2 CASING RUNL P Continue RIH to bottom (off trouble 9,110.0 10,900.0 03:33 04:51 time) on depth at 10,900 ft, release off liner at 1.1 bpm at 5,000 psi BHA, PUW 25k, liner appears to be off, reset depths. 11/28/2016 11/28/2016 3.65 COMPZ2 CASING TRIP P POOH, paint flags at 8,000 ft and 10,393.0 50.3 04:51 08:30 5,000 ft 11/28/2016 11/28/2016 0.50 COMPZ2 CASING OWFF P On surface, monitor well for flow. 50.3 50.3 08:30 09:00 PJSM- LD BHA over dead well 11/28/2016 11/28/2016 0.75 COMPZ2 CASING PULD P LD BHA#26, remove agitator from 50.3 0.0 09:00 09:45 BHA, lower liner in hole. 11/28/2016 11/28/2016 0.50 COMPZ2 CASING RURD P Prep floors for liner run. 0.0 0.0 09:45 10:15 11/28/2016 11/28/2016 1.40 COMPZ2 CASING PUTB P PJSM- MU ported bullnose, 38 jts 0.0 1,191.9 10:15 11:39 slotted, Shorty. 11/28/2016 11/28/2016 0.85 COMPZ2 CASING PULD P PJSM-MU lower liner assembly to 1,191.9 1,236.1 11:39 12:30 CoilTrak tools, surface test. 11/28/2016 11/28/2016 3.10 COMPZ2 CASING RUNL P RIH with 1,192 ft AL3 -01 lower middle 1,236.1 8,130.0 12:30 15:36 liner BHA #27, correct to flag minus 3.5 ft, continue RIH, PUW 25k at 7,000 ft. continue RIH 11/28/2016 11/2812016 0.15 COMPZ2 CASING DLOG P Log K1 for plus 1.5 ft, 8,130.0 8,160.0 15:36 15:45 11/28/2016 11/28/2016 0.95 COMPZ2 CASING RUNL P Continue RIH, 35 fpm at -350 psi over 8,160.0 10,145.0 15:45 16:42 BHP, pumps off. 11/28/2016 11/28/2016 0.65 COMPZ2 CASING RUNL P Stacking at 10,145 ft, PUW 30k, work 10,145.0 10,392.0 16:42 17:21 liner to 10,392 ft, PUW 30k, release off liner at 1.1 bpm at 4,711 psi, BHP 4,882 psi, 775 psi Diff. PUW 22k. reset counters. 11/28/2016 11/28/2016 3.15 COMPZ2 CASING TRIP P POOH pumping beaded completion 9,200.0 44.2 17:21 20:30 fluid paint EOP flags at 8,000 ft and 6,200 ft. 11/28/2016 11/28/2016 0.50 COMPZ2 CASING OWFF P On surface, monitor well for flow. 44.2 44.2 20:30 21:00 PJSM- LD BHA over dead well 11/28/2016 11/28/2016 0.50 COMPZ2 CASING PULD P LD BHA#27 44.2 0.0 21:00 21:30 Page 25/37 Report Printed: 12/27/2016 Operations Summary (with Timelog Depths) Rig: NABORS CDR2-AC Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time our (hr) Phase Op Code Activity Code Time P -T -X Operation (ftKB) End Depth (ftKB) 11/28/2016 11/28/2016 0.25 COMPZ2 CASING RURD P Prep floors for liner run 0.0 0.0 21:30 21:45 11/28/2016 11/28/2016 1.50 COMPZ2 CASING PUTB P PJSM- MU ported bullnose, 35 jts 0.0 1,090.3 21:45 23:15 slotted, 10 ft solid pup jt and Shorty. 11/28/2016 11/29/2016 0.75 COMPZ2 CASING PULD P PJSM- MU number 3 liner assembly to 1,090.3 1,134.5 23:15 00:00 BHA #28, MU to CoilTrak tools 11/29/2016 11/29/2016 0.25 COMPZ2 CASING PULD P continue to MU number 3 liner 1,134.5 1,134.5 00:00 00:15 assembly to CoilTrak tools, surface test. 11/29/2016 11/29/2016 2.00 COMPZ2 CASING RUNL P RIH with 1,092 ft AL3 -01 middle liner 1,134.5 7,334.5 00:15 02:15 BHA #27 11/29/2016 11/29/2016 0.25 COMPZ2 CASING RUNL P Correct to the EOP flag, continue IH 7,334.5 8,762.0 02:15 02:30 11/29/2016 11/29/2016 1.00 COMPZ2 CASING RUNL P Set down minus 10 k CTSW, minus 8,762.0 9,201.0 02:30 03:30 1.9 k DHWOB, PUW 28 k, RBIH, at 45 fpm, 11/29/2016 11/29/2016 2.00 COMPZ2 CASING TRIP P Remove liner length from BHA, POOH 9,201.0 55.1 03:30 05:30 11/29/2016 11/29/2016 0.50 COMPZ2 CASING PULD P Check well for flow, PJSM for laying 55.1 55.1 05:30 06:00 down setting BHA 11/29/2016 11/29/2016 1.00 COMPZ2 CASING PULD P LD BHA# 28, liner setting tools 55.1 0.0 06:00 07:00 11/29/2016 11/29/2016 0.75 COMPZ2 CASING PULD P PU/MU OH anchored billet 0.0 0.0 07:00 07:45 11/29/2016 11/29/2016 0.50 COMPZ2 CASING PULD P Discuss with town team concerns of 0.0 0.0 07:45 08:15 current fluid in hole, w/ running an OH Anchored Billet. 11/29/2016 11/29/2016 1.25 COMPZ2 CASING PULD P PJSM, LD billet, MU cleanout BHA 0.0 62.4 08:15 09:30 with a D331. 11/29/2016 11/29/2016 3.00 COMPZ2 CASING TRIP P Tag up, reset counters, surface test 62.4 6,947.0 09:30 12:30 BHI Coiltrak tools. RIH, slowly keeping annular below 350 psi over pressure schedule, switching to 8.8 ppg drilling fluid, at .15 bpm, BHP 4,600 psi 11/29/2016 11/29/2016 0.25 COMPZ2 CASING DLOG P log the K1 correction of minus 2.0' 6,947.0 6,970.0 12:30 12:45 11/29/2016 11/29/2016 1.25 COMPZ2 CASING TRIP P Continue RIH 6,970.0 8,090.0 12:45 14:00 11/29/2016 11/29/2016 5.50 COMPZ2 CASING DISP P Jog from 8,090'to 7,150', increasing 8,090.0 8,090.0 14:00 19:30 pump rate to 0.4 bpm, BHP 4,590 psi displacing well to 8.8 ppg used flopro. 11/29/2016 11/29/2016 2.00 COMPZ2 CASING TRIP P POOH, jogging before build and inside 8,090.0 500.0 19:30 21:30 5". Chase sweep out of the hole. 11/29/2016 11/29/2016 0.50 COMPZ2 CASING TRIP P Open EDC, continue POOH. Tag up 500.0 56.0 21:30 22:00 and space out. 11/29/2016 11/29/2016 1.25 COMPZ2 CASING PULD P PUD BHA#29. 56.0 0.0 22:00 23:15 11/29/2016 11/29/2016 0.25 COMPZ2 CASING PULD P PU and PD BHA #30, anchored billet 0.0 0.0 23:15 23:30 assembly. 11/30/2016 11/30/2016 1.00 COMPZ2 CASING PULD P Continue to PD BHA #30. Anchored 0.0 72.0 00:00 01:00 billet assembly. 11/30/2016 11/30/2016 1.75 COMPZ2 CASING TRIP P RIH with anchored billet. SOW = 72.0 6,950.0 01:00 02:45 15Klbs 11/30/2016 11/30/2016 0.25 COMPZ2 CASING DLOG P Log the K1 for a -2 ft correction. 6,950.0 6,982.0 02:45 03:00 j Page 26/37 Report Printed: 12/27/2016 Operations Summary (with Timelog Depths) 1B-18 Rig: NABORS CDR2-AC Job: DRILLING SIDETRACK Time Log Start Time End Time Dur (hr) Phase Op Code Activity Code Time P -T -X Operation Start Depth (ftKB) End Depth (MB) 11 /30/201 6 11/30/2016 0.75 COMPZ2 CASING TRIP P Close EDC at the window. Continue 6,982.0 8,105.0 03:00 03:45 running in the hole with BHA #30. Tag up at 8105 ft. PU and repeat tag at 8105 ft. Bring up pump and set billet at 4700 psi, anchor oriented low side. Top of billet at 8,094 ft. 11/30/2016 11/30/2016 2.25 COMPZ2 CASING TRIP P POOH with BHA #30. 8,105.0 61.0 03:45 06:00 11/30/2016 11/30/2016 2.00 COMPZ2 CASING PULD P PJSM, PUD, BHA# 30 61.0 0.0 06:00 08:00 11/30/2016 11/30/2016 3.00 PRODS DRILL SVRG P Install MM parts, simops repair 0.0 0.0 08:00 11:00 hydraulic seal in cellar. 11/30/2016 11/30/2016 1.50 PRODS DRILL PULD P PJSM, PD kickoff/drilling BHA 0.0 72.1 11:00 12:30 11/30/2016 11/30/2016 1.50 PRODS DRILL TRIP P RIH w/ AL3 kickoff/drilling BHA# 31, 72.1 6,947.0 12:30 14:00 0.8 ako motor and RB HYC bi-center bit 11/30/2016 11/30/2016 0.25 PROD3 DRILL DLOG P Log the K1 marker correction minus 6,947.0 6,957.0 14:00 14:15 1.5' 11/30/2016 11/30/2016 0.25 PRODS DRILL TRIP P Continue RIH to bottom 6,957.0 8,094.0 14:15 14:30 11/30/2016 11/30/2016 5.50 PRODS STK KOST P Dry tag TOB at 8093.8', PUW 28 k 8,094.0 8,115.0 14:30 20:00 Begin milling billet. Stacking CT weight. Pump beads to assist kicking off. Drill off billet to 8115ft PUH, clean dry drift through billet area. 11/30/2016 12/1/2016 4.00 PRODS DRILL DRLG P Continue drilling ahead, pumping 1.5 8,115.0 8,320.0 20:00 00:00 BPM, at 3860 psi. BHP = 4200 psi, WHP = 498 psi. WOB 1.5-2 Klbs, ROP = 20-70 FPH. 12/1/2016 12/1/2016 3.25 PRODS DRILL DRLG P Continue drilling ahead, pumping 1.5 8,320.0 8,490.0 00:00 03:15 BPM, at 3900 psi. BHP = 4200 psi, WHP =498 psi. WOB 1.5-2 Klbs, ROP = 20-70 FPH. 12/1/2016 12/1/2016 0.25 PRODS DRILL WPRT P PUH for planned wiper trip. PUW = 8,490.0 8,110.0 03:15 03:30 26KIbs. 12/1/2016 12/1/2016 0.25 PRODS DRILL WPRT P RBIH. SOW = 13.5 Klbs 8,110.0 8,490.0 03:30 03:45 12/1/2016 12/1/2016 5.00 PRODS DRILL DRLG P BOBD, 1.4 bpm at 3,598 psi, BHP 8,490.0 8,805.0 03:45 08:45 4283, WHP 644 12/1/2016 12/1/2016 1.50 PRODS DRILL WPRT P Wiper up hole, PUW 25 k, jog the 5 8,805.0 7,393.0 08:45 10:15 inch 12/1/2016 12/1/2016 0.25 PRODS DRILL DLOG P RBIH, log the RA marker correction of 7,393.0 7,431.0 10:15 10:30 plus 3.0'. 12/1/2016 12/1/2016 0.75 PRODS DRILL WPRT P Wiper back in hole, RIW 11 k 7,431.0 8,805.0 10:30 11:15 12/1/2016 12/1/2016 6.75 PRODS DRILL DRLG P BOBD, 1.53 bpm at 3,712 psi, BHP 8,805.0 9,045.0 11:15 18:00 4,396, WHP 663, IA 200, OA 0 12/1/2016 12/2/2016 6.00 PRODS DRILL DRLG P Continue drilling ahead pumping 1.55 9,045.0 9,164.0 18:00 00:00 BPM at 4250 psi. BHP 4310 psi. IA 252, OA 0. Beginning to have weight transfer issues. Prepare pill pit for beaded pills. Page 27137 Report Printed: 12127f2-016 Operations Summary (with Timelog Depths) .; Rig: NABORS CDR2-AC Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time our (hr) Phase Op Code Activity Code Time P -T -X Operation (ftKB) End Depth (MB) 12/2/2016 12/2/2016 5.00 PROD3 DRILL DRLG P Continue drilling ahead pumping 1.55 9,164.0 9,245.0 00:00 05:00 BPM at 4150 psi. BHP 4430 psi. IA 265, OA 0. Beginning to have weight transfer issues. Begin pumping alternating 20bb1 beaded pills, followed by 20bb1 mud from the active. BHA wipers as required to maintain weight transfer. 12/2/2016 12/2/2016 1.25 PROD3 DRILL WPRT P Wiper up hole into the 5 inch. PUW 25 9,245.0 7,393.0 05:00 06:15 12/2/2016 12/2/2016 0.25 PROD3 DRILL WPRT P RIH, to log RA 7,393.0 7,404.0 06:15 06:30 12/2/2016 12/2/2016 0.25 PROD3 DRILL DLOG P Log the RA marker correction of plus 7,404.0 7,431.0 06:30 06:45 3.5' 12/2/2016 12/2/2016 0.75 PROD3 DRILL WPRT P Wiper back in hole, RN 14 k 7,431.0 9,245.0 06:45 07:30 12/2/2016 12/2/2016 6.00 PRODS DRILL DRLG P BOBD 1.4 bpm at 4,029 psi FS, BHP 9,245.0 9,322.0 07:30 13:30 4272, WHP 405, IA 289, OA 0, pumping beads, mix up 45 bbl of lubed pill (2% of each) no advantage seen, continue pumping beaded pills, 12/2/2016 12/2/2016 3.00 PROD3 DRILL DRLG P OBD 1.4 bpm at 4,025psi, BHP 4,284, 9,322.0 9,358-0- 13:30 16:30 WHP 465, IA 357, OA 0 12/2/2016 12/2/2016 2.00 PROD3 DRILL DRLG P OBD with beaded pills, 40/20 beads, 9,358.0 9,384.0 16:30 18:30 22 fph, 1 k- DHWOB, 0 k- CTSW 1.4 bpm at 4,313 psi, BHP 385, WHP 414, IA 358, OA 0 12/2/2016 12/2/2016 4.25 PROD3 DRILL DRLG P Continue drilling pumping 40bb1 9,384.0 9,437.0 18:30 22:45 beaded pills followed by 20 bbls of mud from the active. CTW =-5KIbs, WOB = 0.8 - 1.0KIbs BHP 4350 psi. Multiple BHA wipers required to maintain weight transfer. 12/2/2016 12/3/2016 1.25 PROD3 DRILL WPRT P PUH for early wiper trip. Troubleshoot 9,437.0 9,223.0 22:45 00:00 mud pump #2. 12/3/2016 12/3/2016 1.50 PROD3 DRILL WPRT P Continue wiper trip to the window. 9,223.0 7,220.0 00:00 01:30 Troubleshoot MP#1 and MP#2 while pulling to the window. 12/3/2016 12/3/2016 1.50 PROD3 DRILL WPRT P Jog the 5 inch, while troubleshooting 7,220.0 7,380.0 01:30 03:00 pump issues. 12/3/2016 12/3/2016 4.00 PRODS DRILL SVRG T PJSM, fill out proper permits, Tear 7,380.0 7,380.0 03:00 07:00 down pump # 2 and replace failed seal, clear suction screen on pump # 1, and clear suction line, 12/3/2016 12/3/2016 0.25 PROD3 DRILL DLOG P RIH, Log the RA marker correction of 7,380.0 7,430.0 07:00 07:15 plus 4.0', 7,410'-7,430' 12/3/2016 12/3/2016 1.25 PROD3 DRILL TRIP P Wiper back in hole, RIW 14 k 7,430.0 9,430.0 07:15 08:30 12/3/2016 12/3/2016 2.00 PROD3 DRILL WPRT P Clean hole from 9,420' up to 9,210', 9,430.0 9,437.0 08:30 10:30 lowering pump rate to 0.3 bpm to RIH, up to 1.3 bpm PUH, RIH to drill ahead. 12/3/2016 12/3/2016 5.00 PROD3 DRILL DRLG P OBD, 1.3 bpm at 3,558 psi, BHP 9,437.0 9,440.0 10:30 15:30 4245, WHP 355, IA 229, OA 0, pumping beaded pills, pumping new mud pills, Multiple BHA wipers and PU's to help improve weight transfer. Page 28/37 Report Printed: 12/27/2016 Operations Summary (with Timelog Depths) 1B-18 .110 Rig: NABORS CDR2-AC Job: DRILLING SIDETRACK Time Log Start Time End Time Dur (hr) Phase Op Code Activity Code Time. P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 12/3/2016 12/3/2016 4.00 PROD3 DRILL DRLG P OBD, 1.3 bpm at 4,100 psi, BHP 9,440.0 9,461.0 15:30 19:30 4300, WHP 500, IA 195, OA 0, continue to pump beaded pills, Multiple BHA wipers and PU's to help improve weight transfer. 12/3/2016 12/3/2016 0.75 PROD3 DRILL WPRT P PUH for BHA wiper to try and improve 9,461.0 9,461.0 19:30 20:15 weight transfer. Slight overpull at 9210 ft. 12/3/2016 12/4/2016 3.75 PROD3 DRILL DRLG P OBD, 1.3 bpm at 4,100 psi, BHP 9,461.0 9,495.0 20:15 00:00 4310, WHP 570, IA 195, OA 0, Multiple BHA wipers and PU's to help improve weight transfer. Swap mud. New mud at the bit at 9470 ft. New mud at surface at 9478 ft. 12/4/2016 12/4/2016 7.75 PRODS DRILL DRLG P OBD, 1.3 bpm at 4, 100 psi, BHP 9,495.0 9,555.0 00:00 07:45 4340, WHP 550, IA 227, OA 0, Multiple BHA wipers and PU's to help improve weight transfer. 12/4/2016 12/4/2016 0.25 PROD3 DRILL WPRT P Short wiper up hole, PUW 30 k 9,555.0 9,300.0 07:45 08:00 12/4/2016 12/4/2016 0.25 PROD3 DRILL WPRT P Wiper back in hole RIW 8 k 9,300.0 9,555.0 08:00 08:15 12/4/2016 12/4/2016 2.00 PROD3 DRILL DRLG P BOBD 1.3 bpm at 4,100 psi, BHP 9,555.0 9,565.0 08:15 10:15 4,334, WHP 589, IA 278, OA 0 12/4/2016 12/4/2016 2.00 PROD3 DRILL DRLG P OBD 1.3 bpm at 4,092 psi, BHP 9,565.0 9,577.0 10:15 12:15 4,366, WHP 611, IA 286, OA 0, pumping beaded pills again to assist with weight transfer. 12/4/2016 12/4/2016 1.00 PROD3 DRILL DRLG P OBD, 1.3 bpm at 4,113 psi, BHP 9,577.0 9,581.0 12:15 13:15 4379, WHP 608, IA 290, OA 0, pumping 40 bbl beaded pill followed by 20 bead-free mud. 12/4/2016 12/4/2016 1.10 PRODS DRILL WPRT P Wiper up hole, PUW 30 k, jog the 5 9,581.0 7,050.0 13:15 14:21 inch, 7,050'- 7390'. 12/4/2016 12/4/2016 1.75 PROD3 DRILL TRIP P Discuss with town plan forward, due to 7,050.0 72.1 14:21 16:06 slow ROP, and weight transfer, POOH for agitator. 12/4/2016 12/4/2016 2.40 PROD3 DRILL PULD P Tag surface, PJSM, PUD drilling 72.1 0.0 16:06 18:30 BHA# 31. Crew change. Prepare to function test BOPE. Bit grade 1-1-BU-A-X-I-BHA 12/4/2016 12/4/2016 1.00 PROD3 DRILL BOPE P Function test BOPE. Perform post test 0.0 0.0 18:30 19:30 greasing on stack and choke valves. 12/4/2016 12/4/2016 0.75 PRODS DRILL SVRG P Service reel and injector. 0.0 0.0 19:30 20:15 12/4/2016 12/4/2016 2.25 PRODS DRILL PULD P PJSM. PU and PD BHA #32 with 0.7° 0.0 0.0 20:15 22:30 AKO motor, agitator and RB HYC bit. 12/4/2016 12/5/2016 1.50 PROD3 DRILL TRIP P Bump up, reset counters, RIH. Close 0.0 4,827.0 22:30 00:00 EDC and shallow test agitator. Good test. Continue in the hole. 12/5/2016 12/5/2016 0.50 PROD3 DRILL TRIP P Continue to RIH with BHA #32. 4,827.0 6,955.0 00:00 00:30 12/5/2016 12/5/2016 0.25 PROD3 DRILL DLOG P Tie-in to the K1 for no correction. 6,955.0 7,000.0 00:30 00:45 12/5/2016 12/5/2016 1.00 PRODS DRILL WPRT P Continue to RIH to bottom with BHA 7,000.0 9,581.0 00:45 01:45 1 #32. Page 29/37 Report Printed: 12/2712016 ririri 9 E Operations Summary (with Timelog Depths) 1B-18 Rig: NABORS CDR2-AC Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time Dur (hr) Phase Op Code Activity Code Time P -T -X Operation (ftKB) End Depth (ftKB) 12/5/2016 12/5/2016 2.75 PRODS DRILL DRLG P BOBD. Pumping 1.3 bpm at 4400 psi. 9,581.0 9,600.0 01:45 04:30 BHP = 4320 psi. WOB = 0.6 Klbs. ROP 5-8 fph. 12/5/2016 12/5/2016 8.25 PROD3 DRILL DRLG P OBD, 1.3 bpm at 4,254 psi, BHP 9,600.0 9,653.0 04:30 12:45 4,382, WHP 573, IA 355, OA 0 12/5/2016 12/5/2016 0.25 PROD3 DRILL WPRT P Short 100' BHA wiper up hole, PUW 9,653.0 9,653.0 12:45 13:00 25 k 12/5/2016 12/5/2016 2.50 PRODS DRILL DRLG P BOBD, 1.3 bpm at 4,370 psi, BHP 9,653.0 9,680.0 13:00 15:30 4,379, WHP 583, IA 334, OA 0 12/5/2016 12/5/2016 0.25 PROD3 DRILL WPRT P Wiper up hole to 8,700', PUW 26 k 9,680.0 8,700.0 15:30 15:45 12/5/2016 12/5/2016 0.50 PROD3 DRILL WPRT P Wiper back in hole RIW 12 k 8,700.0 9,680.0 15:45 16:15 12/5/2016 12/5/2016 1.75 PROD3 DRILL DRLG P BOBD 1.3 bpm at 4,330 psi, BHP 9,680.0 9,687.0 16:15 18:00 4,390, WHP 587, IA 323, OA 0 12/5/2016 12/5/2016 0.50 PROD3 DRILL WPRT P BHA Wiper. Difficulty getting back to 9,687.0 9,687.0 18:00 18:30 bottom. 12/5/2016 12/5/2016 2.00 PRODS DRILL DRLG P BOBD. 1.3 bpm at 4285 psi. BHP = 9,687.0 9,702.0 18:30 20:30 4360 psi. WOB 0-1.4 Klbs. ROP <10fph. IA 348 psi OA = 0. 12/5/2016 12/5/2016 1.75 PROD3 DRILL WPRT P PUH for wiper to the window. Pulled 9,702.0 7,400.0 20:30 22:15 heavy at 9367 ft and 9220 ft. Jog 5" casing 2x. 12/5/2016 12/5/2016 0.25 PROD3 DRILL DLOG P RBIH. Log RA for a +4 ft correction. 7,400.0 7,420.0 22:15 22:30 12/5/2016 12/5/2016 1.00 PROD3 DRILL WPRT P Continue RIH. Took weight at 9207 ft, 7,420.0 9,702.0 22:30 23:30 9226 ft and 9406 ft. 12/5/2016 12/6/2016 0.50 PROD3 DRILL DRLG P BOBD. 1.25 bpm at 4350 psi. BHP = 9,702.0 9,708.0 23:30 00:00 4360 psi. WOB 1.2 Klbs. ROP 15fph. IA 348 psi OA = 0. 12/6/2016 12/6/2016 9.75 PRODS DRILL DRLG P Continue drilling ahead pumping 1.25 9,708.0 9,790.0 00:00 09:45 bpm at 4280 psi. BHP = 4340. IA 346psi, OA Opsi. Begin pumping 20bbls beaded pills followed by 20bbls mud from the active. BHA wipers as required to help maintain weight transfer. 12/6/2016 12/6/2016 2.50 PROD3 DRILL CIRC P TD called at 9790'. Wiper up hole and 9,790.0 8,870.0 09:45 12:15 circulate beaded pill out. Clean hole. Build Hi/Lo vis sweeps. 12/6/2016 12/6/2016 1.00 PROD3 DRILL WPRT P RBIH to TD at 9790'. Pump 10x10 8,870.0 9,790.0 12:15 13:15 Hi/Lo sweeps at 1.2 BPM and 4300 psi. IA 371 psi, OA 0 psi. 12/6/2016 12/6/2016 0.75 PRODS DRILL WPRT P Chase 1 0x1 0 sweep to 7060'. 9,790.0 7,060.0 13:15 14:00 Decrease rate to .5BPM through window at 7400'. Increase rate back to 1.3 BPM up to 7060'. 12/6/2016 12/6/2016 0.75 PRODS DRILL WPRT P RBIH past EOB to 7970'. Pump 7,060.0 7,970.0 14:00 14:45 10x10 sweep at 1.3 BPM and 4300 psi. 12/6/2016 12/6/2016 2.37 PROD3 DRILL WPRT P PUH and chase sweep to window. 7,970.0 69.4 14:45 17:07 Decrease rate to .5BPM through window at 7400'. Continue wiper to swab. 12/6/2016 12/6/2016 1.64 PROD3 DRILL TRIP P RBIH to confirm TD. 69.4 6,944.0 17:07 18:45 12/6/2016 12/6/2016 0.24 PRODS DRILL DLOGP Log for K1 Marker and make 6,944.0 6,980.2 18:45 19:00 correction of + .5 ft. Page 30137 Report Printed: 12/27/2016 Operations Summary (with Timelog Depths) IB -18 Rig: NABORS CDR2-AC Job: DRILLING SIDETRACK Time Log Start Depth StartTime End Time Dur (hr) Phase Op Code Activity Code Time P -T -X Operation (WB) End Depth (ftKB) 12/6/2016 12/6/2016 1.22 PRODS DRILL TRIP P Continue RIH to confirm 6,980.2 9,788.0 19:00 20:13 TD.............Slight tag at 9,226 ft and 9,476 ft ..... confirmed TD is at 9,788 ft. 12/6/2016 12/7/2016 3.78 PRODS DRILL DISP P Start PUH and laying in liner running 9,788.0 78.1 20:13 00:00 pill which is 12 ppg Potassium Formate with 2 ppg beads after pill reaches the bit......... Paint flags .......... at window and KWF with beads is being laid in while POOH........... 12/7/2016 12/7/2016 1.20 PRODS DRILL OW FF P At surface. Prep for flow check and 78.1 78.1 00:00 01:12 then perform a 30 minute flow check. 12/7/2016 12/7/2016 0.64 PRODS DRILL PULD P L/D BHA # 32. 78.1 0.0 01:12 01:50 Note: Bit Graded Out at 1 - 1 - bu - a - x - i -ct - td 12/7/2016 12/7/2016 3.83 COMPZ3 CASING PULD P PJSM and begin M/U 49 jts of liner. 0.0 1,545.6 01:50 05:40 P/U BHA #33 w/liner running assembly. 12/7/2016 12/7/2016 2.00 COMPZ3 CASING RUNL P RIH with BHA #33 and 49 jts of slotted 1,545.6 8,100.0 05:40 07:40 liner w/ non=ported bullnose. Tie in to at flag for -5' correction. PUW 26K. Continue RIH clean through window and build section. 12/7/2016 12/7/2016 2.00 COMPZ3 CASING RUNL P Start stacking weight at 8410', begin 8,100.0 9,787.0 07:40 09:40 working liner assembly down. Work liner by varying speeds and pump rates through tight spots at 8410', 8456', 8704', 8798', 8934', & 8976'. Heavy PU weights throughout. Work liner down to TD at 9787.4' pumping min rate. PUW 30K. Stack down WOB -8.5K. Release lower liner assembly at 9785' pumping 1.2 BPM, PUW 25K. Reset counter. TOL at 8284'. 12/7/2016 12/7/2016 2.90 COMPZ3 CASING TRIP P POOH and paint window flag at 6644'. 9,787.0 43.9 09:40 12:34 Continue POOH pumping across top. 12/7/2016 12/7/2016 0.60 COMPZ3 CASING OWFF P At surface. Prep for flow check and 43.9 0.0 12:34 13:10 then perform a 30 minute flow check. Good. 12/7/2016 12/7/2016 2.50 COMPZ3 CASING PULD P L/D BHA#33 over dead well. PJSM 0.0 705.8 13:10 15:40 and begin M/U 21 jts of liner. P/U BHA #34 w/liner running assembly. 12/7/2016 12/7/2016 1.88 COMPZ3 CASING RUNL P RIH w/ BHA#34 and 21 jts slotted liner 705.8 8,284.0 15:40 17:33 w/ ported bullnose. 12/7/2016 12/7/2016 0.33 COMPZ3 CASING RUNL P Tag top of liner at 8,284 ft. PUH for a 8,284.0 7,620.0 17:33 17:52 weight check and then tag again. Bring pump online and release off of upper liner assembly. Top of liner now at 7,620 ft. 12/7/2016 12/7/2016 5.70 COMPZ3 CASING TRIP P PUH slowly and start to displace well 7,620.0 33.5 17:52 23:34 with 8.7 drilling fluid through the GS...............pumping slow due to annular pressure ....................after well has been swapped over to drilling fluid, pump a Hi / Lo sweep and chase up to the 5" and make several jogs and then chase sweep to surface....... Page 31/37 Report Printed: 12/27/2016 -4 Operations Summary (with Timelog Depths) 1B-18 Rig: NABORS CDR2-AC Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time our (hr) Phase op Code Activity Code Time P-T-X Operation (MB) End Depth (WB) 12/7/2016 12/8/2016 0.43 COMPZ3 CASING TRIP P At surface. PJSM and then begin 33.5 33.5 23:34 00:00 Pressure Undeploy Operations. 12/8/2016 12/8/2016 0.80 COMPZ3 CASING PULD P Pressure undeploy BHA # 34. 33.5 33.5 00:00 00:48 12/8/2016 12/8/2016 0.19 COMPZ3 CASING PULD P L/D BHA #34. 33.5 0.0 00:48 00:59 12/8/2016 12/8/2016 0.30 COMPZ3 CASING PULD P P/U BHA #35 w/Anchored Billet 0.0 72.9 00:59 01:17 12/8/2016 12/8/2016 1.35 COMPZ3 CASING PULD P Pressure deploy BHA #35. 72.9 72.9 01:17 02:38 12/8/2016 12/8/2016 1.70 COMPZ3 CASING TRIP P RIH w/anchored billet 72.9 6,950.0 02:38 04:20 12/8/2016 12/8/2016 0.19 COMPZ3 CASING DLOG P Log K1 Marker and make a correction 6,950.0 6,980.0 04:20 04:31 of -1 ft 12/8/2016 12/8/2016 0.20 COMPZ3 CASING TRIP P Continue RIH w/Anchored Billet 6,980.0 7,620.6 04:31 04:43 12/8/2016 12/8/2016 0.39 COMPZ3 CASING TRIP P Tag top of liner at 7,620.6 6,620.6 6,609.6 04:43 05:07 ft .......... ..release off of billet with no issues..............TOB is at 7,608.6 ft. 12/8/2016 12/8/2016 1.50 COMPZ3 CASING TRIP P POOH 6,609.6 72.9 05:07 06:37 12/8/2016 12/8/2016 1.00 COMPZ3 CASING PULD P PJSM and PUD BHA# 35. 72.9 72.9 06:37 07:37 12/8/2016 12/8/2016 0.75 COMPZ3 CASING PULD P L/D BHA#35 72.9 0.0 07:37 08:22 12/8/2016 12/8/2016 0.75 COMPZ3 CASING PULD P P/U BHA#36 0.0 0.0 08:22 09:07 12/8/2016 12/8/2016 1.00 PROD4 DRILL PULD P PJSM, PD kickoff/drilling BHA #36 0.0 72.2 09:07 10:07 12/8/2016 12/8/2016 1.55 PROD4 DRILL TRIP P RIH w/ AL2 kickoff/drilling BHA# 36, 72.2 6,949.0 10:07 11:40 2.0 AKO motor and RB HCC bi-center bit 12/8/2016 12/8/2016 0.23 PROD4 DRILL DLOG P Log K1 marker for -1 ft. correction. 6,949.0 6,976.0 11:40 11:54 12/8/2016 12/8/2016 0.50 PROD4 DRILL TRIP P Continue RIH. 6,976.0 7,610.0 11:54 12:24 12/8/2016 12/8/2016 1.10 PROD4 STK KOST P Dry tag TOB at 7610% PUW 27K. 7,610.0 7,640.0 12:24 13:30 Begin milling billet, drill off billet to 7640'. PUH to 7582'. Dry drift clean past billet area. No issues. 12/8/2016 12/8/2016 5.83 PROD4 DRILL DRLG P Continue drilling ahead, pumping 1.3 7,640.0 7,981.0 13:30 19:19 BPM, at 3900 psi. BHP = 4200 psi, WHP = 430 psi. WOB -1-1.5 Klbs, ROP -50-80 FPH 12/8/2016 12/8/2016 1.59 PROD4 DRILL WPRT P Having weight transfer 7,981.6 7,981.6 19:19 20:55 issues.............pump a 5 x 5 sweep and chase up hole to 5".....jog this area several times to clean up and then RBIH Note: Increased amount of cuttings seen across shaker after wiper 12/8/2016 12/9/2016 3.08 PROD DRILL DRLG P BOBD, pumping 1.4 BPM, at 4036 psi. 7,981.6 7,999.0 20:55 00:00 BHP = 4100 psi, WHP = 366 psi. WOB -1-2.4 Klbs, ROP -8 to 10 FPH Page 32/37 Report Printed: 12/27/2016 } Operations Summary (with Timelog Depths) 1B-18 Rig: NABORS CDR2-AC Job: DRILLING SIDETRACK Time Log Start Time End Time Dur (hr) Phase Op Code Activity Code Time P -T -X Operation Start Depth(ftKB) End Depth (ftKB) 12/9/2016 12/9/2016 8.30 PROD4 DRILL DRLG P Drilling ahead in 1 B-18 AL2 Build 7,999.0 8,054.0 00:00 08:18 section, pumping 1.4 BPM, at 4142 psi. BHP = 4100 psi, WHP = 500 psi. WOB -2 - 2.9 Klbs, ROP -8 to 10 FPH Note: Got back confirmed samples of Ankorite at 01:15hrs 12/9/2016 12/9/2016 3.40 PROD4 DRILL DRLG P Pump 5x5 sweep. PUW 26K. 8,054.0 8,085.0 08:18 11:42 Continue drilling ahead in build section. ROP picking up to -10- 20FPH, 1.3 BPM, at 4000 psi, BHP 4200, WHP 415, WOB 2.5 Klbs. 12/9/2016 12/9/2016 0.10 PROD4 DRILL SRVY P PU for geo survey. PUW 26K. Lower 8,085.0 8,068.0 11:42 11:48 pump rate to 1 BPM. Obtain clean geo survey. 12/9/2016 12/9/2016 3.50 PROD4 DRILL DRLG P BOBD, 1.3 BPM, 4100 psi, WHP 420, 8,068.0 8,090.0 11:48 15:18 BHP 4200, WOB 1.2KIbs, ROP -10 FPH, IA 383, OA 0. Pumping 5x5 sweeps and pick ups as needed. 12/9/2016 12/9/2016 0.50 PROD4 DRILL DRLG P Drilled ahead to EOB at 8102.58 ft. 8,090.0 8,102.6 15:18 15:48 12/9/2016 12/9/2016 1.50 PROD4 DRILL WPRT P Pumped final 10x10 sweep. Chased 8,102.6 72.9 15:48 17:18 to 7060. Decrease rate to .3 BPM through window. RBIH and jog 5" casing from 7040'-8090'. Continue chase sweep out of hole. 12/9/2016 12/9/2016 1.68 PROD4 DRILL PULD P PJSM and begin pressure undeploy 72.9 72.9 17:18 18:58 BHA #36 12/9/2016 12/9/2016 1.00 PROD4 DRILL PULD P L/D BHA #36 72.9 0.0 18:58 19:58 12/9/2016 12/9/2016 2.02 PROD4 WHDBOP BOPE P Prep (Stab back on well with nozzle 0.0 0.0 19:58 22:00 and jet on stack several times, grease -2 stack, etc.) for BOPE test. 12/9/2016 12/10/2016 o0 PROD4 WHDBOP BOPE P Start full bi-weekly BOPE test. Test 0.0 -0 0 22:00 00:00 wiitness waived by Jeff Jones, AOGCC. 12/10/2016 12/10/2016 5.00 PROD4 WHDBOP BOPE P Complete full bi-weekly BOPE test 0.0 0.0 00:00 05:00 250 psi/3500 psi including inner reel valve (6 hour test). No test failures. 12/10!2016 12/10/2016 1.12 PROD4 DRILL CTOP P PJSM and prep to cut coil and perform 0.0 0.0 05:00 06:07 slack management. Remove CTC, boot end of wire to seal for slack management. 12/10/2016 12/10/2016 6.78 PROD4 DRILL CTOP P Cut 1,600' of coil and 1,612' of eline. 0.0 0.0 06:07 12:54 Install boot end of wire and heat shrink wrap. Perform slack management. Cut an additional 100' of coil (Cut 1,700'total of coil and 1,612'total of eline). 12/10/2016 12/10/2016 4.50 PROD4 DRILL CTOP P Prep coil and re -head CTC, pull test 0.0 0.0 12:54 17:24 50k, re -head, install UQC, PIT 4,500 psi, displace coil to drilling fluid. 12/10/2016 12/10/2016 2.60 PROD4 DRILL PULD P P/U BHA #37 ( AL2 Lateral Drilling 0.0 72.8 17:24 20:00 BHA) and presure deploy Page 33/37 Report Printed: 12/27/2016 Y At h,u Operations Summary (with Timelog Depths) 1B-18 Rig: NABORS CDR2-AC Job: DRILLING SIDETRACK Time Log Start Time End Time our (hr) Phase Op Code Activity Code Time P -T -X Operation Start Depth (ftKB) End Depth (WB) 12/10/2016 12/10/2016 1.00 PROD4 DRILL EQRP T After pressure deploying and ready to 72.8 72.8 20:00 21:00 RIH, lost power to tools ........... pressure undeploy, troubleshoot, repair and pressure deploy again. Note: Problem was 1/4" of the eline at the UQC was found to have been scrapped bare and was shorting out. Wire cut and reheaded. 12/10/2016 12/10/2016 1.40 PROD4 DRILL TRIP P RIH with EDC open pumping at 1 bpm 72.8 6,950.0 21:00 22:24 to facilitate pushing slack forward. 12/10/2016 12/10/2016 0.22 PROD4 DRILL DLOG P Log for K1 Marker and make 6,950.0 6,973.0 22:24 22:37 correction of minus 2 ft. 12/10/2016 12/10/2016 0.61 PROD4 DRILL TRIP P Continue RIH (closed the EDC at 6,973.0 8,102.0 22:37 23:13 7,350 ft) 12/10/2016 12/11/2016 0.78 PROD4 DRILL DRLG P BOBD. Pumping at 1.4 bpm Circ 8,102.0 8,172.0 23:13 00:00 Press 4,077 WHIP 379 BHP 4,223 WOB 1.6 klb ROP 64 to 88 fph 12/11/2016 12/11/2016 4.00 PROD4 DRILL DRLG P BOBD. Pumping at 1.4 bpm Circ 8,172.0 8,326.7 00:00 04:00 Press 4,077 WHIP 379 BHP 4,223 WOB 1.6 klb ROP 64 to 88 fph Note: Around 8,320 ft ROP slowed drastically .......... Geo thinks it's the fault........... 12/11/2016 12/11/2016 0.38 PROD4 DRILL WPRT P Perform a 300 ft wiper trip to help 8,326.7 8,326.7 04:00 04:22 alliviate weight transfer issues..............we are either in ankorite or at the fault or both..............we have pumped several sweeps prior to PUH 12/11/2016 12/11/2016 4.41 PROD4 DRILL DRLG P BOBD. Pumping at 1.5 bpm Circ 8,326.7 8,332.0 04:22 08:47 Press 4,215 WHIP 437 BHP 4,259 WOB 1.0 klb ROP 1 to 2 FPH. PU's as needed. 12/11/2016 12/11/2016 5.39 PROD4 DRILL DRLG P ROP averaging 2-4 FPH. Drilling 8,332.0 8,347.1 08:47 14:10 ahead, 1.5 BPM, Circ 4100 psi, WHP 342 psi, BHP 4210 psi, WOB 1.5-2 klbs. 12/11/2016 12/12/2016 9.83 PROD4 DRILL DRLG P Continue drilling ahead at 3-5 FPH, 8,347.1 8,378.4 14:10 00:00 1.4 BPM, Circ 4115 PSI, WHP 250 psi, BHP 4149 psi, WOB 1-3 klbs. 12/12/2016 12/12/2016 8.00 PROD4 DRILL DRLG P Continue drilling ahead at 3-5 FPH, 8,378.4 8,400.0 00:00 08:00 1.4 BPM, Circ 4115 PSI, WHP 250 psi, BHP 4149 psi, WOB 1-3 klbs. PU's and restarts as needed. 12/12/2016 12/12/2016 0.90 PROD4 DRILL DRLG P Swap to mud system #8 (8.65 ppg 8,400.0 8,400.0 08:00 08:54 Power -Pro SF) with new mud at the bit at 8,400 ft and continue drilling ahead. 12/12/2016 12/12/2016 6.30 PROD4 DRILL DRLG P Continue drilling ahead 3-5 FPH, 1.5 8,400.0 8,414.0 08:54 15:12 BPM, Circ 3950 psi, WHP 505, BHP 4140 psi, WOB 2-3 Klbs. PU's and restarts as needed. Adjust trip schedule holding 11.8 ppg at window to help with losses Geo samples continue to show —15% ankorite. Page 34137 Report Printed: 12/27/2016 Operations Summary (with Timelog Depths) IB -18 Rig: NABORS CDR2-AC Job: DRILLING SIDETRACK Start Depth Start Time End Time Dur (hr) Phase Op Code I Activity Code I Time P -T -x Operation (WB) End Depth (ftKB; 12/12(2016 12/12/2016 4.28 PROD4 DRILL DRLG P Continue drilling ahead -2-4 FPH, 1.5 8,414.0 8,421.2 15:12 19:28 BPM, Circ 4000 psi, WHP 500, BHP 4140 psi, WOB 2-3 Klbs. PU's and restarts as needed. 12/12/2016 12/12/2016 0.40 PROD4 DRILL TRIP 5 Discuss with town and decision made 8,421.2 8,200.0 19:28 19:52 to POOH for new motor and bit. PUW 26K. 12/12/2016 12/12/2016 2.00 PROD4 DRILL TRIP P Pump 5x5 sweep and chase to 8,200.0 71.6 19:52 21:52 window at 7,393', Jog 5" casing from 7,060' to 7,373'. POOH w/ open EDC. 12/12/2016 12/12/2016 1.00 PROD4 DRILL PULD P PJSM, PUD BHA#37. 71.6 71.6 21:52 22:52 Bit grade 7-5-bt-a-x-i-ct-pr 12/12/2016 12/12/2016 0.60 PROD4 DRILL PULD P M/U BHA# 38 w/ Weatherford .5° AKO 71.6 71.6 22:52 23:28 motor and a SRFE3408MB7 HYC bit. 12/12/2016 12/13/2016 0.52 PROD4 DRILL PULD P PJSM and start PD BHA#38. 71.6 71.6 23:28 00:00 12/13/2016 12/13/2016 0.40 PROD4 DRILL PULD P Completed pressure deploying 71.6 71.6 00:00 00:24 BHA#38 w/.5° AKO Weathford motor and a SRFE3408MB7 HYC bit. 12/13/2016 12/13/2016 1.40 PROD4 DRILL TRIP P RIH with open EDC pumping at 71.6 6,945.0 00:24 01:48 minimum rate 12/13/2016 12/13/2016 0.27 PROD4 DRILL DLOG P Log K1 Marker and make correction of 6,945.0 6,973.0 01:48 02:04 minus 2 ft 12/13/2016 12/13/2016 0.49 PROD4 DRILL TRIP P Continue RIH with now closed EDC 6,973.0 8,422.0 02:04 02:33 pumping minimum rate. 12/13/2016 12/13/2016 1.55 PROD4 DRILL DRLG 5 BOBD. Pumping at 1.41 bpm Circ = 8,422.0 8,446.0 02:33 04:06 4,248 WHP = 562 CTW = 13.66 ROP = 7 fph WOB = 2.24 klb Note: Experiencing some severe vibration issues once on bottom drilling ......... Note: Aftyer 10 minutes on bottom drilling, computer screens for DD goes pink,,,,,,,,,, PUH and re -boot computers ......... RBIH and continue drilling. ... 5 minute delay. 12/13/2016 12/13/2016 3.27 PROD4 DRILL DRLG P Pumping at 1.39 bpm Circ = 4,078 8,446.0 8,510.0 04:06 07:22 WHP = 560 CTW = 6.30 ROP = 24 to 75 fph WOB = 2.24 klb Note: We seemed to have broke through after 8,440 ft. This is wher we had our last stall and now the ROP is increasing 12/13/2016 12/13/2016 1.80 PROD4 DRILL WPRT P After 0700 hr morning meeting 8,568.0 7,080.0 07:22 09:10 engineer called and due to faulting into the Miluveach Formation, pump a 10 x 10 sweep and chase up hole ( jog 5" several times ) and hopefully by that time twon will have a decision on a way forward (plug back or run liner). PUH and pump a 10 x 10 sweep and chase up hole once out of bit. PUW = 27 k.............Having issue with choke periodically clogging ........... more clay coming across shaker now. ...... make several jogs in 5" Page 35/37 Report Printed: 12/27/2016 Operations Summary (with Timelog Depths) 1B-18 Rig: NABORS CDR2-AC Time Log Start Time End Time our (hr) Phase Op Code 12/13/2016 12/13/2016 1 1.10 1 PROD4 DRILL 09:10 10:16 12/13/2016 112/13/2016 10:16 13:37 13:37 115:00 12/13/2016 12/13/2016 15:00 15:13 12/13/2016 12/13/2016 15:13 16:09 12/13/2016 12/13/2016 16:09 18:30 12/13/2016 12/13/2016 18:30 19:00 12/13/2016 12/13/2016 19:00 19:51 12/13/2016 12/13/2016 19:51 20:30 12/13/2016 12/1312016 20:30 22:27 12/13/2016 12/13/2016 22:27 23:21 12/13/2016 12/14/2016 23:21 00:00 12/14/2016 12/14/2016 00:00 01:24 12/14/2016 12/14/2016 01:24 01:36 12/14/2016 12/14/2016 01:36 03:48 12/14/2016 12/14/2016 03:48 04:48 12/14/2016 12/14/2016 04:48 06:00 12/14/2016 12/14/2016 06:00 06:15 12/14/2016 12/14/2016 06:15 07:39 12/14/2016 12/14/2016 07:39 08:00 3.341PROD4 IDRILL 0.23 PROD4 DRILL 0.92 PROD4 DRILL 2.35 PROD4 IDRILL 0.50 PROD4 DRILL 0.85 PROD4 DRILL 0.65 COMPZ4 CASIN 0 2.20 1 COM PZ4 TRIP TRIP DISP PULD PUTS CASING ITRIP 1.40 1 COMPZ4 CASING 0.35 ICOMPZ4 ICASING Job: DRILLING SIDETRACK Start Depth (WB) End Depth (ftKB) Code Time P -T -X I Operation running liner P Another call from town and instructed jts slotted, Halliburton swell packer, 17 once completing jogs in 5", RBIH and jts solids, 6 ft SBR deployment sleeve. pump another sweep and chase up P PJSM- MU AL2 liner assembly to BHA hole again as above whilst meetings #39, MU to CoilTrac tools, surface are being held on AL2 Lateral's P RIH with AL2 liner assembly status....... Continue RIH, tie in at flag for minus P BOB. After 5 x 5 exits bit plus a few at 8,058 ft, work liner down to 8,196 ft, bbls, chase up hole, jog through 5" PUW 28k, WOB -2.7k, P again and chase to surface. 23k, WOB 2.6k, reset counters to bit Note: Town called again and decision depth. Mid element of swell packer at made to run liner. P P At surface, RBIH to called TD to start site, PJSM with LRS P laying in liner running pill and then LRS P/T lines and equipment. KW F............ 2,500 ft. LRS pump 30 bbls diesel, P Log the K1 Marker and make a P Continue POOH correction of minus 2 ft At surface, tagged up. Pressure P Continue RIH to 8,230 ft .............. P After liner running pill gets to the bit and above, start PUH and laying in pill and then KW F. Paint flags at 6,900 ft and 6,000 ft, continue laying in beaded liner pill to surface. P On surface, monitor well for flow, PJSM- LD BHA over open hole. P Prep floors for liner run. PJSM- running liner P MU AL2 liner assembly- bullnose, 21 jts slotted, Halliburton swell packer, 17 jts solids, 6 ft SBR deployment sleeve. BOP drill. Clean floors. P PJSM- MU AL2 liner assembly to BHA #39, MU to CoilTrac tools, surface test. P RIH with AL2 liner assembly P Continue RIH, tie in at flag for minus 3.04 ft, PUW 26k, continue RIH, stack at 8,058 ft, work liner down to 8,196 ft, PUW 28k, WOB -2.7k, P Release off liner at 1.3 bpm, PUW 23k, WOB 2.6k, reset counters to bit depth. Mid element of swell packer at 7,535 ft, TOP of SBR at 6,994 ft. P Displace well to seawater, LRS on site, PJSM with LRS P POOH pumping seawater to 2,500 ft. LRS P/T lines and equipment. P 2,500 ft. LRS pump 30 bbls diesel, RDMO LRS. Open EDC at 500 ft P Continue POOH P At surface, tagged up. Pressure Undeploy after PJSM. 72.81 6,948.01 6,948.0 6,992.0 8,230.0 72.8 0.0 0.0 0.0 0.0 1,202.2 3,990.01 6,994.0 2,500.0 2,500.0 500.0 Page 36137 Report Printed: 12/27/2016 �x Operations Summary (with Timelog Depths) 4A 1B-18 Rig: NABORS CDR2-AC Job: DRILLING SIDETRACK Time Log Start Time End Time Dur (hr) Phase Op Cade Activity Code Time P -T -X Operation Start Depth (ftKB) End Depth (ftKB) 12/14/2016 12/14/2016 1.00 DEMOB WHDBOP MPSP P Prep for BPV installment. 0.0 0.0 08:00 09:00 12/14/2016 12/14/2016 2.00 DEMOB WHDBOP MPSP P Valve Crew shows up and installs 0.0 0.0 09:00 11:00 BPV 12/14/2016 12/14/2016 5.00 DEMOB WHDBOP DISP P Pump corrosion Inhibitor through coil 0.0 0.0 11:00 16:00 and then blow down coil. 12/14/2016 12/14/2016 2.00 DEMOB WHDBOP RURD P Start rig move check list, blow down 0.0 0.0 16:00 18:00 steam lines, disconnect PUTZ, remove mouse holes, etc.... 12/14/2016 12/14/2016 2.00 DEMOB WHDBOP NUND P ND BOPE, torque checked, remove 0.0 0.0 18:00 20:00 kill and deployment lines. ***Rig released at 20:00 on 12/14/2016. Page 37137 Report Printed: 12/27/2016 ConocoPs philli ConocoPhillips (Alaska) Inc. -Kup1 Kuparuk River Unit Kuparuk 1B Pad 1 B-18AL3 50-029-22472-62 Baker Hughes INTEQ Definitive Survey Report 20 December, 2016 Few FA I BAKER HUGHES "w, ConocoPhillips /GF9I ConocoPhillips Definitive Survey Report NUEER ES Company: ConocoPhillips (Alaska) Inc. -Kupl Local Co-ordinate Reference: Well 1 B-18 Project: Kuparuk River Unit TVD Reference: 1 B-18 @ 102,00usft Site: Kuparuk 1 B Pad MD Reference: 1 B-18 @ 102.00usft Well: IB -18 North Reference: True Wellbore: 1B-18AL3 Survey Calculation Method: Minimum Curvature Design: 1B-18AL3 Database: EDM Alaska NSK Sandbox 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 E Map Zone: Alaska Zone 04 Using geodetic scale factor I Well IB -18 Well Position +N/ -S 0.00 usft Northing: 5,969,647.06 usft Latitude: 70° 19'40.248 N +E/ -W 0.00 usft Easting: 550,148.90 usft Longitude: 149° 35'35.868 W Position Uncertainty 0.00 usft Wellhead Elevation: usft Ground Level: 61.20 usft Wellbore 113-18AL3 Magnetics Model Name Sample Date Declination Dip Angle Field Strength (nT) BGGM2016 10/1/2016 18.01 80.96 57,551 Design 113-18AL3 Audit Notes: Version: 1.0 Phase: ACTUAL Tie On Depth: 8,080.19 ) Vertical Section: Depth From (TVD) +NI -S +E/ -W Direction 1 (usft) (usft) (usft) (°) 40.80 0.00 0.00 45.00 Survey Program Date 12/16/2016 From To Survey Survey (usft) (usft) Survey (Wellbore) Tool Name Description Start Date End Date 469.67 6,897.50 1 B-18 (1 B-18) MWD MWD - Standard 4/28/1994 4/28/1994 7,392.00 8,080.19 1B-18AL3PB1 (1B-18AL3PB1) MWD MWD - Standard 11/5/2016 11/11/2016 8,094.00 9,750.37 1B-18AL3(1B-18AL3) MWD MWD - Standard 11/26/2016 12/6/2016 COMPASS 5000.1 Build 74 12/20/2016 9:03:16AM Page 2 - ConocoPhillips IGkI ConocoPhillips Definitive Survey Report BAKER HUGHES Company: ConocoPhillips (Alaska) Inc. -Kupl Local Co-ordinate Reference: Well 1 B-18 Project: Kuparuk River Unit TVD Reference: 1 B-18 @ 102.00usft Site: Kuparuk 1 B Pad MD Reference: 1 B-18 @ 102.00usft 3 Well: 113-18 North Reference: True Wellbore: 1 B-18AL3 Survey Calculation Method: Minimum Curvature Design: 1 B-1 BAL3 Database: EDM Alaska NSK Sandbox Survey MD Inc Azi TVD TVDSS +N/ -S +E/ -W Map Map DLS Vertical (usft) (1) (°) (usft) (usft) (usft) (usft) North rth Northing East (°l100') Section Section Survey Tool Name Annotation (ft) 8,080.19 93.41 60.46 6,705.33 6,603.34 -2,562.46 198.59 5,967,086.23 550,364.59 7.32 -1,671.51 MWD (2) TIP E 8,094.00 93.41 59.44 6,704.51 6,602.51 -2,555.56 210.52 5,967,093.21 550,376.47 7.37 -1,658.19 MWD (3) KOP 8,124.97 87.63 61.00 6,704.23 6,602.23 -2,540.18 237.38 5,967,108.76 550,403.23 19.33 -1,628.33 MWD (3) d 8,160.07 87.15 67.21 6,705.83 6,603.83 -2,524.88 268.91 5,967,124.28 550,434.65 17.73 -1,595.21 MWD (3) 8,184.96 86.59 63.49 6,707.19 6,605.19 -2,514.52 291.50 5,967,134.79 550,457.17 15.09 -1,571.91 MWD (3) 8,215.15 88.40 58.79 6,708.51 6,606.51 -2,499.96 317.90 5,967,149.52 550,483.47 16.67 -1,542.95 MWD (3) 8,245.05 89.75 53.30 6,709.00 6,607.00 -2,483.27 342.69 5,967,166.38 550,508.15 18.91 -1,513.62 MWD (3) 8,275.11 90.71 47.17 6,706.67 6,606.87 -2,464.05 365.78 5,967,185.75 550,531.11 20.64 -1,483.70 MWD (3) 8,305.21 90.06 43.36 6,708.67 6,606.67 -2,442.87 387.16 5,967,207.07 550,552.34 12.84 -1,453.61 MWD (3) 8,335.33 91.78 38.58 6,708.19 6,606.19 -2,420.14 406.90 5,967,229.93 550,571.93 16.86 -1,423.57 MWD (3) a 8,365.26 90.61 33.09 6,707.56 6,605.56 -2,395.89 424.41 5,967,254.29 550,589.28 18.75 1,394.04 MWD (3) 8,395.00 90.33 27.13 6,707.32 6,605.32 -2,370.18 439.33 5,967,280.10 550,604.01 20.06 -1,365.32 MWD (3) { 8,425.10 89.36 23.25 6,707.40 6,605.40 -2,342.94 452.13 5,967,307.42 550,616.64 13.29 -1,337.00 MWD (3) 4 8,454.98 89.45 18.45 6,707.71 6,605.71 -2,315.03 462.77 5,967,335.40 550,627.08 16.07 -1,309.75 MWD (3) 1 8,485.19 90.37 13.44 6,707.76 6,605.76 -2,285.99 471.06 5,967,364.49 550,635.18 16.86 -1,283.35 MWD (3) 8,515.33 90.92 8.94 6,707.42 6,605.42 -2,256.43 476.91 5,967,394.08 550,640.83 15.04 -1,258.31 MWD (3) 8,545.24 90.52 3.74 6,707.04 6,605.04 -2,226.72 480.21 5,967,423.82 550,643.94 17.44 -1,234.97 MWD (3) 8,575.22 91.44 3.09 6,706.53 6,604.53 -2,196.80 482.00 5,967,453.75 550,645.52 3.76 -1,212.55 MWD (3) 8,605.25 91.29 7.89 6,705.81 6,603.81 -2,166.92 484.87 5,967,483.64 550,648.19 15.99 -1,189.39 MWD (3) 8,635.13 91.35 12.12 6,705.12 6,603.12 -2,137.51 490.06 5,967,513.08 550,653.18 14.15 -1,164.93 MWD (3) 8,665.25 91.66 17.04 6,704.33 6,602.33 -2,108.38 497.63 5,967,542.26 550,660.57 16.36 -1,138.97 MWD (3) 8,695,68 92.00 21.51 6,703.36 6,601.36 -2,079.68 507.67 5,967,571.02 550,670.41 14.72 -1,111.58 MWD (3) b p 8,725.12 92.70 25.92 6,702.15 6,600.15 -2,052.75 519.50 5,967,598.02 550,682.06 15.15 -1,084.18 MWD (3) 8,755.27 92.64 31.07 6,700.75 6,598.75 -2,026.29 533.86 5,967,624.58 550,696.24 17.06 -1,055.31 MWD (3) 8,782.53 92.73 33.86 6,699.47 6,597.47 -2,003.32 548.48 5,967,647.64 550,710.70 10.23 -1,028.73 MWD (3) 8,814.77 90.18 37.40 6,698.65 6,596.65 -1,977.13 567.25 5,967,673.95 550,729.29 13.53 -996.94 MWD (3) 8,846.88 84.46 36.57 6,700.15 6,598.15 -1,951.52 586.54 5,967,699.69 550,748.41 18.00 -965.19 MWD (3) s 8,877.61 83.91 31.86 6,703.27 6,601.27 -1,926.25 603.72 5,967,725.08 550,765.42 15.35 -935.17 MWD (3) 8,905.05 85.85 27.13 6,705.72 6,603.72 -1,902.47 617.17 5,967,748.94 550,778.71 18.57 -908.84 MWD (3) 8,935.29 86.77 21.91 6,707.66 6,605.66 -1,875.02 629.69 5.967,776.47 550,791.05 17.49 -880.58 MWD (3) 12120/2016 9:03:16AM Page 3 COMPASS 5000.1 Build 74 ConocoPhillips ConocoPhillips Definitive Survey Report MA R1 HUGHES Company: ConocoPhillips (Alaska) Inc. -Kupl Local Co-ordinate Reference: Well 1 B-18 Map Project: Kuparuk River Unit TVD Reference: 1 B-18 @ 102.00usft Site: Kuparuk 1 B Pad MD Reference: 1 B-18 @ 102.00usft TVD Well: 1 B-18 North Reference: True Wellbore: 1 B-18AL3 Survey Calculation Method: Minimum Curvature Design: 1 B-18AL3 Database: EDM Alaska NSK Sandbox (usft) Survey 12120/2016 9:03:16AM Page 4 COMPASS 5000.1 Build 74 Map Map Vertical MD Inc Azi TVD TVDSS +N/ -S +E/ -W DLS (usft) (°) (°) (usft) (usft) (usft) (usft) Northing Easting (°/100') Section Survey Tool Name Annotation (ft) (ft) (ft) 8,965.00 88.87 17.56 6,708.80 6,606.80 -1,847.08 639.71 5,967,804.47 550,800.88 16.25 -853.74 MWD (3) 9,001.87 90.92 12.04 6,708.86 6,606.86 -1,811.45 649.13 5,967,840.16 550,810.06 15.97 -821.89 MWD (3) 9,030.21 93.19 8.32 6,707.85 6,605.85 -1,783.58 654.13 5,967,868.06 550,814.87 15.37 -798.64 MWD (3) 9,060.33 95.62 3.65 6,705.53 6,603.53 -1,753.73 657.26 5,967,897.93 550,817.81 17.44 -775.32 MWD (3) 9,090.23 98.88 359.57 6,701.76 6,599.76 -1,724.09 658.10 5,967,927.57 550,818.45 17.38 -753.77 MWD (3) 9,119.97 100.47 354.66 6,696.76 6,594.76 -1,694.82 656.63 5,967,956.83 550,816.78 17.13 -734.11 MWD (3) 9,152.89 102.17 352.23 6,690.29 6,588.29 -1,662.76 652.95 5,967,988.87 550,812.88 8.89 -714.04 MWD (3) rt 9,180.01 102.03 356.95 6,684.61 6,582.61 -1,636.36 650.45 5,968,015.24 550,810.21 17.03 -697.15 MWD (3) 9,209.88 101.27 1.24 6,678.57 6,576.57 -1,607.12 649.99 5,968,044.48 550,809.55 14.29 -676.80 MWD (3) 9,239.85 101.13 5.14 6,672.75 6,570.75 -1,577.77 651.62 5,968,073.83 550,810.99 12.77 -654.89 MWD (3) 9,269.80 10D.28 9.75 6,667.18 6,565.18 -1,546.60 655.44 5,968,103.02 550,814.61 15.39 -631.56 MWD (3) 9,299.80 99.39 14.15 6,662.06 6,560.06 -1,519.69 661.56 5,968,131.97 550,820.53 14.75 -606.79 MWD (3) 9,329.81 98.82 18.54 6,657.30 6,555.30 -1,491.26 669.89 5,968,16D.45 550,828.68 14.57 -580.80 MWD (3) 9,359.83 98.20 23.33 6,652.86 6,550.86 -1,463.54 680.50 5,968,188.24 550,839.10 15.91 -553.69 MWD (3) 9,389.82 96.78 27.79 6,648.95 6,546.95 -1,436.73 693.33 5,968,215.14 550,851.75 15.49 -525.66 MWD (3) 9,419.83 96.70 30.76 6,645.43 6,543.43 -1,410.73 707.90 5,968,241.22 550,866.14 9.83 -496.98 MWD (3) 9,449.80 96.56 30.23 6,641.96 6,539.97 -1,385.08 723.01 5,968,266.97 550,881.08 1.82 -468.16 MWD (3) 9,479.87 96.15 26.86 6,638.64 6,536.64 -1,358.83 737.28 5,968,293.32 550,895.18 11.22 -439.50 MWD (3) 9,509.83 95.78 22.83 6,635.52 6,533.52 -1,331.80 749.80 5,968,320.43 550,907.51 13.44 -411.53 MWD (3) 9,539.90 93.38 24.08 6,633.12 6,531.12 -1,304.31 761.73 5,968,348.00 550,919.26 8.99 -383.66 MWD (3) 9,570.05 92. D0 27.43 6,631.70 6,529.70 -1,277.19 774.82 5,968,375.21 550,932.16 12.01 -355.23 MWD (3) 9,600.05 92.61 30.90 6,630.5D 6,528.50 -1,251.01 789.42 5,968,401.47 550,946.59 11.73 -326.39 MWD (3) 9,630.10 92.76 34.07 6,629.D9 6,527.09 -1,225.70 805.54 5,968,426.89 550,962.54 10.55 -297.09 MWD (3) 9,660.05 91.44 36.89 6,627.99 6,525.99 -1,201.33 822.91 5,968,451.38 550,979.74 10.39 -267.58 MWD (3) 9,690.16 91.69 41.40 6,627.17 6,525.17 -1,177.99 841.91 5,968,474.84 550,998.58 15.00 -237.65 MWD (3) 1 9,720.10 94.58 41.53 6,625.53 6,523.53 -1,155.59 861.70 5,968,497.37 551,018.22 9.66 -207.81 MWD (3) e 9,750.37 95.44 45.15 6,622.89 6,520.89 -1,133.66 882.39 5,968,519.43 551,038.76 12.25 -177.68 MWD (3) 9,788.00 n 95.44 45.15 6,619.32 6,517.32 -1,107.24 908.95 5,968,546.02 551,065.14 0.00 -140.22 PROJECTED to TD 12120/2016 9:03:16AM Page 4 COMPASS 5000.1 Build 74 ConocoPhilli s p ConocoPhillips (Alaska) Inc. -Kup1 Kuparuk River Unit Kuparuk 1 B Pad 1 B-18AL3PB1 50-029-22472-70 Baker Hughes INTEQ Definitive Survey Report 20 December, 2016 WE a I BAKER N116NES ConocoPhillips d Company: ConocoPhillips (Alaska) Inc. -Kup1 Project: Kuparuk River Unit Site: Kuparuk 1 B Pad Well: 113-18 Wellbore: 1 B-18AL3PB1 Design: 1 B-18AL3PB1 Project Kuparuk 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 113-18 ConocoPhillips Definitive Survey Report Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Database: Well 1B-18 1 B-18 @ 102.00usft 16-18 @ 102.00usft True Minimum Curvature EDM Alaska NSK Sandbox Mean Sea Level Using Well Reference Point Using geodetic scale factor BAR • HILMHES Well Position +N/ -S 0.00 usft Northing: 5,969,647.06usft Latitude: 70° 19'40.248 N +E/ -W 0.00 usft Easting: 550,148.90 usft Longitude: 149° 35'35.868 W 4Position Uncertainty 0.00 usft Wellhead Elevation: usft Ground Level: 61.20 usft Wellbore 16-18AL3P61 45.00 Survey Magnetics Model Name Sample Date 4/28/1994 Declination Dip Angle LBGGM2016 11/11/2016 1011/2016 18.01 80.96 Design 1 B-18AL3PB1 Audit Notes: Version: 1.0 Phase: ACTUAL Tie On Depth: 6,897.50 Vertical Section: Depth From (TVD) +N/ -S +E/ -W (usft) (usft) (usft) 40.80 0.00 0.00 Survey Program Date 11/11/2016 From To (usft) (usft) Survey (Wellbore) Tool Name Description 469.67 6,897.50 1B -18(1B-18) MWD MWD - Standard 7,392.00 9,056.07 1B-18AL3PB1 (1B-18AL3PB1) MWD MWD - Standard Field Strength (nT) 57.551 Direction (°) 45.00 Survey Survey Start Date End Date 4/28/1994 4/28/1994 11/5/2016 11/11/2016 12/20/2016 8:58:06AM Page 2 COMPASS 5000.1 Build 74 V-' ConocoPhillips WEkv ConocoPhillips Definitive Survey Report HUGHES Company: ConocoPhillips (Alaska) Inc. -Kup1 Local Co-ordinate Reference: Well 113-18 Project: Kuparuk River Unit TVD Reference: 1 B-18 @ 102.00usft Site: Kuparuk 1 B Pad MD Reference: 113-18 @ 102.00usft Well: 113-18 North Reference: True Wellbore: 1B-18AL3PB1 Survey Calculation Method: Minimum Curvature Design: 1 B-18AL3PB1 Database: EDM Alaska NSK Sandbox Survey MD Inc Azi TVD TVDSS +N/ -S +E/ -W Map Map Map Vertical (usft) (°) (°) (usft) (usft) (usft) (usft) Northing Easting (° /100' ) Section Survey Tool Name (ft) (ft) (ft) 6,897.50 43.20 180.80 6,227.45 6,125.45 -2,108.07 -221.61 5,967,537.76 549,941.40 0.50 -1,647.33 MWD (2) 7,392.00 39.69 191.22 6,598.51 6,496.51 -2,432.69 -254.75 5,967,212.96 549,910.44 1.56 -1,900.30 MWD (2) 7,420.23 45.15 186.48 6,619.35 6,517.35 -2,451.49 -257.64 5,967,194.14 549,907.68 22.40 -1,915.64 MWD (2) 7,452.15 52.87 182.05 6,640.28 6,538.28 -2,475.49 -259.37 5,967,170.13 549,906.10 26.35 -1,933.84 MWD (2) 7,482.15 60.01 178.52 6,656.85 6,554.85 -2,500.47 -259.47 5,967,145.16 549,906.18 25.73 -1,951.57 MWD (2) 7,512.62 61.84 175.39 6,671.66 6,569.66 -2,527.05 -258.05 5,967,118.58 549,907.77 10.81 -1,969.36 MWD (2) 7,542.18 63.42 166.73 6,685.27 6,583.27 -2,552.95 -253.96 5,967,092.72 549,912.03 26.55 -1,984.78 MWD (2) 7,562.49 64.58 161.21 6,694.18 6,592.18 -2,570.48 -248.92 5,967,075.22 549,917.19 25.08 -1,993.62 MWD (2) 7,590.41 67.65 148.25 6,705.52 6,603.52 -2,593.48 -238.02 5,967,052.29 549,928.24 43.82 -2,002.18 MWD (2) 7,620.38 71.93 135.09 6,715.92 6,613.92 -2,615.45 -220.59 5,967,030.44 549,945.81 43.59 -2,005.39 MWD (2) 7,650.21 83.51 129.03 6,722.25 6,620.26 -2,634.91 -198.98 5,967,011.13 549,967.56 43.58 -2,003.86 MWD (2) 7,670.45 91.23 124.90 6,723.18 6,621.18 -2,647.06 -182.84 5,966,999.10 549,983.77 43.24 -2,001.04 MWD (2) 7,690.50 97.73 118.72 6,721.62 6,619.62 -2,657.59 -165.87 5,966,988.68 550,000.81 44.66 -1,996.49 MWD (2) 7,720.45 95.81 105.56 6,718.07 6,616.07 -2,668.76 -138.38 5,966,977.69 550,028.37 44.10 -1,984.95 MWD (2) 7,750.39 93.75 93.61 6,715.57 6,613.57 -2,673.72 -109.02 5,966,972.93 550,057.76 40.36 -1,967.69 MWD (2) 7,780.21 91.75 80.84 6,714.13 6,612.13 -2,672.27 -79.33 5,966,974.57 550,087.44 43.29 -1,945.68 MWD (2) 7,810.27 90.58 73.25 6,713.52 6,611.52 -2,665.54 -50.07 5,966,981.50 550,116.65 25.54 -1,920.22 MWD (2) 7,840.09 89.94 71.88 6,713.38 6,611.38 -2,656.61 -21.62 5,966,990.63 550,145.04 5.07 -1,893.79 MWD (2) 7,870.45 90.28 71.01 6,713.32 6,611.32 -2,646.95 7.16 5,967,000.48 550,173.75 3.08 -1,866.61 MWD (2) 7,900.35 91.53 70.60 6,712.85 6,610.85 -2,637.12 35.40 5,967,010.49 550,201.92 4.40 -1,839.69 MWD (2) 7,930.48 91.53 68.60 6,712.05 6,610.05 -2,626.62 63.63 5,967,021.18 550,230.07 6.64 -1,812.31 MWD (2) 7,960.57 91.47 66.69 6,711.26 6,609.26 -2,615.18 91.44 5,967,032.80 550,257.81 6.35 -1,784.55 MWD (2) 7,990.31 92.12 65.43 6,710.33 6,608.33 -2,603.12 118.61 5,967,045.05 550,284.90 4.77 -1,756.81 MWD (2) 8,020.23 92.98 63.60 6,709.00 6,607.00 -2,590.26 145.59 5,967,058.08 550,311.79 6.75 -1,728.64 MWD (2) 8,050.50 93.81 62.60 6,707.20 6,605.20 -2,576.59 172.54 5,967,071.93 550,338.64 4.29 -1,699.92 MWD (2) 8,080.19 93.41 60.46 6,705.33 6,603.34 -2,562.46 198.59 5,967,086.23 550,364.59 7.32 -1,671.51 MWD (2) 8,110.58 93.41 58.21 6,703.53 6,601.53 -2,546.99 224.68 5,967,101.87 550,390.57 7.39 -1,642.12 MWD (2) 8,140.61 93.93 56.27 6,701.60 6,599.60 -2,530.78 249.88 5,967,118.26 550,415.66 6.68 -1,612.84 MWD (2) 8,170.22 93.81 55.51 6,699.61 6,597.61 -2,514.21 274.34 5,967,134.98 550,440.01 2.59 -1,583.83 MWD (2) 8,200.23 93.47 53.52 6,697.70 6,595.70 -2,496.82 298.72 5,967,152.53 550,464.28 6.71 -1,554.29 MWD (2) Annotation TIP KOP 12/20/2016 8:58 06AM Page 3 COMPASS 5000.1 Build 74 10-1 ConocoPhillips FORS ConocoPhillips Definitive Survey Report HUGHES Company: ConocoPhillips (Alaska) Inc. -Kup1 Local Co-ordinate Reference: Well 1 B-18 Project: Kuparuk River Unit TVD Reference: 1 B-18 @ 102.00usft Site: Kuparuk 1 B Pad MD Reference: 113-18 @ 102.00usft Well: 113-18 North Reference: True Wellbore: 1 B-18AL3PB1 Survey Calculation Method: Minimum Curvature Design: 1 B-18AL31`131 Database: EDM Alaska NSK Sandbox Survey MD Inc Azi TVD TVDSS +N/ -S +E/ -W Map Map DLS Vertical (usft) (°) (°) (usft (usft) (usft ) usft ( ) Northing Easting (°1100') Section Survey Tool Name Annotation (ft) (ft) (ft) 8,230.35 92.21 54.14 6,696.21 6,594.21 -2,479.07 323.01 5,967,170.44 550,488.44 4.66 -1,524.57 MWD (2) 8,260.36 90.52 54.54 6,695.49 6,593.49 -2,461.58 347.38 5,967,188.09 550,512.69 5.79 -1,494.96 MWD (2) 8,291.67 88.34 56.39 6,695.81 6,593.81 -2,443.83 373.17 5,967,206.01 550,538.36 9.13 -1,464.18 MWD (2) 8,320.25 89.82 57.60 6,696.26 6,594.26 -2,428.27 397.14 5,967,221.74 550,562.22 6.69 -1,436.23 MWD (2) 8,350.60 89.39 57.58 6,696.47 6,594.47 -2,412.00 422.76 5,967,238.17 550,587.73 1.42 -1,406.61 MWD (2) 8,380.23 86.41 56.31 6,697.56 6,595.56 -2,395.85 447.57 5,967,254.48 550,612.43 10.93 -1,377.64 MWD (2) 8,410.27 85.36 55.21 6,699.71 6,597.71 -2,379.00 472.34 5,967,271.51 550,637.08 5.06 -1,348.21 MWD (2) 8,440.32 87.27 55.19 6,701.65 6,599.65 -2,361.88 496.96 5,967,288.78 550,661.59 6.36 -1,318.70 MWD (2) 8,470.14 85.76 54.61 6,703.46 6,601.46 -2,344.77 521.32 5,967,306.06 550,685.82 5.42 -1,289.38 MWD (2) 8,500.21 85.02 53.03 6,705.88 6,603.88 -2,327.07 545.51 5,967,323.91 550,709.90 5.79 -1,259.76 MWD (2) 8,530.19 85.39 53.34 6,708.38 6,606.38 -2,309.17 569.42 5,967,341.97 550,733.69 1.61 -1,230.19 MWD (2) 8,560.07 86.28 53.61 6,710.55 6,608.55 -2,291.44 593.37 5,967,359.86 550,757.52 3.11 -1,200.71 MWD (2) 8,590.19 85.94 54.23 6,712.60 6,610.60 -2,273.74 617.66 5,967,377.72 550,781.68 2.34 -1,171.03 MWD (2) 8,619.30 85.54 54.47 6,714.76 6,612.76 -2,256.82 641.25 5,967,394.80 550,805.16 1.60 -1,142.38 MWD (2) 8,650.11 85.52 56.55 6,717.16 6,615.16 -2,239.43 666.56 5,967,412.35 550,830.35 6.73 -1,112.18 MWD (2) 8,680.29 85.24 56.39 6,719.59 6,617.59 -2,222.81 691.64 5,967,429.14 550,855.31 1.07 -1,082.70 MWD (2) 8,710.37 85.79 57.52 6,721.94 6,619.94 -2,206.46 716.78 5,967,445.65 550,880.34 4.17 -1,053.36 MWD (2) 8,740.26 84.03 58.69 6,724.59 6,622.59 -2,190.73 742.05 5,967,461.55 550,905.51 7.06 -1,024.37 MWD (2) 8,770.31 82.74 60.36 6,728.06 6,626.06 -2,175.59 767.78 5,967,476.86 550,931.13 6.99 -995.47 MWD (2) 8,800.41 81.42 62.46 6,732.20 6,630.20 -2,161.32 793.95 5,967,491.30 550,957.20 8.18 -966.88 MWD (2) 8,830.47 81.87 64.30 6,736.57 6,634.57 -2,148.00 820.54 5,967,504.80 550,983.70 6.24 -938.66 MWD (2) 8,860.54 83.63 65.09 6,740.37 6,638.37 -2,135.25 847.51 5,967,517.73 551,010.58 6.41 -910.57 MWD (2) 8,890.56 84.90 66.11 6,743.37 6,641.37 -2,122.91 874.71 5,967,530.25 551,037.69 5.42 -882.61 MWD (2) 8,920.12 86.74 66.10 6,745.52 6,643.52 -2,110.97 901.66 5,967,542.37 551,064.56 6.22 -855.11 MWD (2) 8,950.34 88.25 66.78 6,746.84 6,644.84 -2,098.90 929.33 5,967,554.62 551,092.15 5.48 -827.01 MWD (2) ! 8,980.26 90.28 66.59 6,747.23 6,645.23 -2,087.06 956.81 5,967,566.64 551,119.54 6.81 -799.21 MWD (2) E 9,010.34 92.73 66.92 6,746.44 6,644.44 -2,075.20 984.43 5,967,578.69 551,147.08 8.22 -771.29 MWD (2) 9,040.30 92.71 68.37 6,745.01 6,643.01 -2,063.81 1,012.11 5,967,590.26 551,174.68 4.83 -743.67 MWD (2) 9,056.07 93.81 67.33 6,744.12 6,642.12 -2,057.88 1,026.69 5,967,596.29 551,189.22 9.59 -729.16 MWD (2) E 9,098.00 93.81 67.33 6,741.33 6,639.33 -2,041.75 1,065.30 5,967,612.67 551,227.72 0.00 -690.46 PROJECTED to TD 12/20/2016 8:58:06AM Page 4 COMPASS 5000.1 Build 74 THE STATE Alaska , � 1' a-L-C (-3- a s OfALASKA CGnservafiGn GOVERNOR BILL WALKER Gary Eller CTD Team Lead ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510-0360 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 www,aogcc.claska.gov Re: Kuparuk River Field, Kuparuk River Oil Pool, KRU 113-18AL3 ConocoPhillips Alaska, Inc. Permit to Drill Number: 216-144 (revised) Surface Location: 500' FNL, 262' FEL, SEC. 9, TI IN, RI OE, UM Bottomhole Location: 1146' FNL, 2665' FEL, SEC. 10, Tl 1N, RI OE, UM Dear Mr. Eller: Enclosed is the approved application for permit to re -drill the above referenced development well. The permit is for a new wellbore segment of existing well Permit No. 216-108, API No. 50-029- 22472-01-00. Production should continue to be reported as a function of the original API number stated above. 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, 40'1� Daniel T. Seamount, Jr. Commissioner DATED this /7 day of November, 2016. STATE OF ALASKA AL _A OIL AND GAS CONSERVATION COMM ON PERMIT TO DRILL 20 AAC 25 nn5 1 a. Type of Work: 1b.. Proposed Well Class: Exploratory - Gas ❑ Service - WAG ❑ Service - Disp ❑ 1 c. Specify if well is proposed for: Drill ❑ Lateral ❑✓ °Stratigraphic Test ❑ Development - Oil 0 • Service - Winj ❑ Single Zone E/1 .I� Coalbed Gas ❑ Gas Hydrates ❑ Redrill ❑ Reentry ❑ Exploratory - Oil ❑ Development - Gas ❑ Service - Supply ❑ Multiple Zone Geothermal ❑ Shale Gas ❑ 2. Operator Name: 5. Bond: Blanket 0 Single Well ❑ 11. Well Name and Number: ConocoPhillips Alaska Inc a Bond No. 5952180 1 B-18AL3 ° 3. Address: 6. Proposed Depth: 12. Field/Pool(s): P.O. Box 100360 Anchorage, AK 99510-0360 MD: 11600' ' TVD: 6644'- 644' -4a. Kuparuk River Field / Kuparuk Oil Pool 4a.Location of Well (Governmental Section): 7. Property Designation (Lease Number): Surface: 500' FNL, 292' FEL, Sec 9, T11 N, R10E, UM . ADL 25648 Top of Productive Horizon: 8. Land Use Permit: 13. Approximate Spud Date: 3136' FNL, 495' FEL, Sec. 10, T11 N, R1 OE, UM ALK 466 11/18/2016 Total Depth: 9. Acres in Property: 14. Distance to Nearest Property: 1146' FNL, 2665' FEL, Sec. 10, T11 N, R1 OE, UM 2560 a 17730' 4b. Location of Well (State Base Plane Coordinates - NAD 27): 10. KB Elevation above MSL (ft): 102 15. Distance to Nearest Well Open Surface: x- 550147 y- 5969648 Zone -4 GL Elevation above MSL (ft): 61.2 to Same Pool: 237' (113- 17) 16. Deviated wells: Kickoff depth: 7392 feet 17. Maximum Potential Pressures in psig (see 20 AAC 25.035) Maximum Hole Angle: 116 , degrees Downhole: 3005 • Surface: 2347 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 2800' 7640' 6719' 11600' 6644' N/A 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): 7824' 6941' 7809' 6929' Casing Length Size Cement Volume MD TVD Conductor/Structural 78' 16" 200 sx ASI 121' 121' Surface 4215' 7-5/8" 650 sx ASIII, 300 sx G 4256' 4148' Intermediate Production 7783' 5"x5.5" 210 sx G 7809' 6929' Liner Perforation Depth MD (ft): Perforation Depth TVD (ft): 7131'- 7194', 7246'-7575' 6400'-6448', 6507'-6741' 20. Attachments: Property Plat ❑ BOP Sketch ❑ Drilling Program 0 Time v. Depth Plot Shallow Hazard Analysis Diverter Sketch ❑ Seabed Report ❑ Drilling Fluid Program 0 20 AAC 25.050 requirements 0 21. Verbal Approval: Commission Representative: Guy Schwartz (11/6/2016) 11/15/2016 Date 22. 1 hereby certify that the foregoing is true and the procedure approved herein will not Jeff Connelly- 263-4112 be deviated from without prior written approval. Contact Email Ieff.s.connelly(c�cop.com Printed Name Gary Eller Title CTD Team Lead Signature Phone 263-4172 Date Commission Use Only t Permit to Drill API Number: Permit Approval See cover letter for other Number:2t _� rQV1 5o -a 29 - 22'{2-Ca2- OCA Date: (1 — requirements. Conditions of approval : If box is checked, well may not be used to explore for, test, or produce coalbed methan , gas hydrates, or gas contained in shales: Other: Samples req'd: Yes a No[] Mud log req'd: Yes❑ No[7� H2S measures: Yes rLJ{ No El Directional svy req'd: Yes No❑ Spacing exception req'd: Yes ❑ No[?Inclination-only svy req'd: Yes El [ Post initial injection MIT req'd: Yes ❑ No ❑ APPROVED BY Approved 1, r� !��A�p�CC�r�I �L? Submit Form and pp Oil, 10-401 Revised 11/2015 i r i i Ii r 4 me n@W'iTb117IW slate of a Wbi��.005 a e: 11 /16/!G U R I U I I V H L. "0" _9" l /'. ConocoPs philli Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 November 15, 2016 Commissioner - State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Dear Commissioner: RECEIVED NOV 15 2016 Due to difficult faulting encountered in the drilling of the KRU 1 B-18AL3 lateral (Verbal approval given 11/6/16 by Guy Schwartz) a revised well -plan will be required in order to achieve the original goals of the project. AOGCC approval is needed for this revision as portions of the revised directional plan are more than 500' away from the approved plan. The revised plan will target the same A4 fault block to the northeast, though will stay to the west of an unforeseen North-South fault not anticipated in the original planning. A revised 10-401 PTD and well -plan are attached for your review. If you have any questions or require additional information, please contact me at 907-263-4112. Sincerely, v Jeff Connelly ConocoPhillips Alaska Coiled Tubing Drilling Engineer ConocoPhillips ConocoPhillips (Alaska) Inc. -Kup1 Kuparuk River Unit Kuparuk 1 B Pad 113-18 1 B-18AL3 Plan: 1 B-18AL3_wp05 Standard Planning Report 15 November, 2016 WE a I BAKER HUGHES It. ConocoPhillips MCA.. ConocoPhillips Planning Report BAKER HUGHES Database: EDM Alaska NSK Sandbox Company: ConocoPhillips (Alaska) Inc. -Kup1 Project: Kuparuk River Unit Site: Kuparuk 1 B Pad Well: 1B-18 Wellbore: 1 B-18AL3 Design: 1 B-18AL3_wp05 Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Well 1B-18 Mean Sea Level 1 B-18 @ 102.00usft True Minimum Curvature Project Kuparuk River Unit, North Slope Alaska, United States Map System: US State Plane 1927 (Exact solution) System Datum: Mean Sea Level Geo Datum: NAD 1927 (NADCON CONUS) Using Well Reference Point Map Zone: Alaska Zone 04 Using geodetic scale factor 11/15/2016 9:17.25AM Page 2 COMPASS 5000.1 Build 74 Site Kuparuk 1 B Pad Site Position: Northing: 5,969,646.72 usft Latitude: 70° 19'40.290 N From: Map Easting: 549,457.40 usft Longitude: 1490 35' 56.056 W Position Uncertainty: 0.00 usft Slot Radius: 0.000 in Grid Convergence: 0.38 ° Well 18-18 Well Position +N/ -S 0.00 usft Northing: 5,969,647.06 usft Latitude: 70° 19'40.248 N +E/ -W 0.00 usft Easting: 550,148.90 usft Longitude: 149° 35'35.868 W Position Uncertainty 0.00 usft Wellhead Elevation: usft Ground Level: 61.20 usft Wellbore 1 B-18AL3 Magnetics Model Name Sample Date Declination Dip Angle Field Strength (nT) BGGM2016 10/1/2016 18.01 80.96 57,551 Design 1 B-18AL3_wp05 Audit Notes: Version: Phase: PLAN Tie On Depth: 7,870.45 Vertical Section: Depth From (TVD) +N/ -S +E/ -W Direction (usft) (usft) (usft) (°) -61.20 0.00 0.00 45.00 11/15/2016 9:17.25AM Page 2 COMPASS 5000.1 Build 74 ConocoPhillips WGaI ConocoPhillips Planning Report BAKER HUGHES Database: EDM Alaska NSK Sandbox Build Turn Company: ConocoPhillips (Alaska) Inc. -Kupl Rate Project: Kuparuk River Unit (usft) (°/10oft) Site: Kuparuk 1 B Pad (°) 7.16 0.00 Well: 1B-18 0.00 35.07 4.42 Wellbore: 1 B-18AL3 -18.29 100.71 12.00 Design: 1 B-18AL3_wp05 0.00 303.40 12.00 Plan Sections -11.83 260.00 376.26 12.00 Measured 11.82 TVD Below 455.69 Depth Inclination Azimuth -11.82 System +N/ -S (usft) (°) (°) 11.60 (usft) (usft) 7,870.45 90.28 71.01 6,611.32 -2,646.95 7,900.00 91.52 70.60 6,610.86 -2,637.23 7,970.00 99.92 70.60 6,603.89 -2,614.12 8,220.00 93.65 41.04 6,573.71 -2,475.95 8,320.00 91.50 52.85 6,569.19 -2,407.88 8,430.00 89.19 39.86 6,568.52 -2,332.13 8,500.00 87.03 47.98 6,570.83 -2,281.78 8,810.00 87.64 10.74 6,585.77 -2,016.63 8,970.00 88.43 29.94 6,591.31 -1,867.40 9,095.00 88.48 14.93 6,594.70 -1,752.23 9,595.00 90.11 74.92 6,601.50 -1,414.24 9,870.00 90.09 41.92 6,601.02 -1,272.20 10,170.00 90.07 77.92 6,600.59 -1,124.29 10,350.00 90.07 56.32 6,600.37 -1,054.72 10,575.00 90.06 83.32 6,600.11 -977.81 10,770.00 90.05 59.92 6,599.92 -916.74 10,945.00 90.05 80.92 6,599.75 -858.42 11,145.00 90.05 56.92 6,599.58 -787.00 11,345.00 90.04 80.92 6,599.42 -715.59 11,600.00 116.20 64.44 6,541.66 -644.40 Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Well 1 B-18 Mean Sea Level 1 B-18 @ 102.00usft True Minimum Curvature Target 11/15/2016 9:17:25AM Page 3 COMPASS 5000.1 Build 74 Dogleg Build Turn +E/ -W Rate Rate Rate TFO (usft) (°/10oft) (°/100ft) (°/100ft) (°) 7.16 0.00 0.00 0.00 0.00 35.07 4.42 4.20 -1.39 -18.29 100.71 12.00 12.00 0.00 0.00 303.40 12.00 -2.51 -11.83 260.00 376.26 12.00 -2.15 11.82 100.00 455.69 12.00 -2.10 -11.82 260.00 504.17 12.00 -3.08 11.60 105.00 653.31 12.00 0.19 -12.01 270.00 708.64 12.00 0.49 12.00 88.00 756.19 12.00 0.04 -12.00 270.00 1,093.37 12.00 0.33 12.00 89.00 1,324.42 12.00 -0.01 -12.00 270.00 1,579.76 12.00 -0.01 12.00 90.00 1,744.62 12.00 0.00 -12.00 270.00 1,953.85 12.00 0.00 12.00 90.00 2,137.62 12.00 0.00 -12.00 270.00 2,301.58 12.00 0.00 12.00 90.00 2,486.83 12.00 0.00 -12.00 270.00 2,672.08 12.00 0.00 12.00 90.00 2,906.79 12.00 10.26 -6.46 330.00 Target 11/15/2016 9:17:25AM Page 3 COMPASS 5000.1 Build 74 Ir-11, ConocoPh i I I i ps ConocoPhillips (Alaska) Inc. -Kup1 Kuparuk River Unit Kuparuk 1B Pad 1B-18 1 B-18AL3 1 B-18AL3_wp05 Travelling Cylinder Report 15 November, 2016 FSAA &I BAKER HUGHES IV-, Baker Hughes INTEQ .E.. ConocoPhillips Travelling Cylinder Report BAKER HUGHES Company: ConocoPhillips (Alaska) Inc. -Kup1 Project: Kuparuk River Unit Reference Site: Kuparuk 1 B Pad Site Error: 0.00 usft Reference Well: 1 B-18 Well Error: 0.00 usft Reference Wellbore 1 B-18AL3 Reference Design: 1 B-18AL3_wp05 Local Co-ordinate Reference: Well 1 B-18 TVD Reference: 1 B-18 @ 102 00usft MD Reference: 1 B-18 @ 102.00usft North Reference: True Survey Calculation Method: Minimum Curvature Output errors are at 1.00 sigma Database: OAKE DM P2 Offset TVD Reference: Offset Datum teference 1 B-18AL3_wp05 'iltertype: GLOBAL FILTER APPLIED: All wellpaths within 200'+ 100/1000 of reference nterpolation Method: MD Interval 25.00usft Error Model: ISCWSA )epth Range: 7,870.45 to 11,600.00usft Scan Method: Tray. Cylinder North tesults Limited by: Maximum center -center distance of 1,355.92 usft Error Surface: Elliptical Conic Survey Tool Program Date 11/15/2016 From To (usft) (usft) Survey (Wellbore) Tool Name Description 469.67 6,897.50 1 B-18 (1 B-18) MWD MWD - Standard 7,392.00 7,870.45 1 B-18AL3PB1 (1 B-18AL3PB1) MWD MWD - Standard 7,870.45 11,600.00 1 B-18AL3_wp05 (1 B-18AL3) MWD MWD - Standard Casing Points Measured Vertical Casing Hole Depth Depth Diameter Diameter (usft) (usft) Name 4,256.00 4,147.97 7.625" 7-5/8 8-1/2 11,600.00 6,643.66 23/8" 2-3/8 3 Summary Site Name Offset Well - Wellbore - Design Kuparuk 1 B Pad 1 B-04 - 1 B-04 - 1 B-04 1 B-05 - 1 B-05 - 1 B-05 18-06 - 1 B-06 - 1 B-06 1 B-07 - 1 B-07 - 1 B-07 1 B-08 - 1 B-08 - 1 B-08 1 B-08 - 1 B -08A - 1 B -08A 1 B-08 - 1 B-08AL1 - 1 B-08ALl 1 B-08 - 1 B -08A L 1-01 - 1 B -08A L 1-01 1 B-08 - 1 B-08ALl-01 - 1 B-08ALl-01 wp07 1 B-08 - 1 B-08ALl PB 1- 1 B-08ALl PB1 1 B-101 - 1 B-101 - 1 B-101 113-101 - 113-10111 - 113-1011-1 1 B-101 - 1 B-101 PB1 - 1 B-101 PB1 18-102 - 1 B-102 - 1 B-102 1 B-12 - 1 B-12 - 1 B-12 1 B-12 - Plan: 1 B-1 2A - 1 B-1 2A (wp01) 1B -13 -1B -13-1B-13 1 B-13 - 1 B-131_1 - 1 B-131_1 1 B-13 - 1 B-131_2 - 1 B-131_2 1B -14 -1B -14-1B-14 1B -15 -1B -15-1B-15 1 B-15 - 1 B-1 5A - 1 B -1 5A 1 B-15 - 1 B-15AL1 - 1 B-15AL1 1 B-15 - 1 B-15AL2 - 1 B-15AL2 1 B-15 - 1 B-15AL2PB1 - 1 B-15AL2PB1 1 B-15 - 1 B-15AL2PB2 - 1 B-15AL2PB2 Reference Offset Centre to No -Go Allowable Measured Measured Centre Distance Deviation Warning Depth Depth Distance (usft) from Plan (usft) (usft) (usft) (usft) Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range CC - Min centre to center distance or covergent point, SF - min separation factor, ES - min ellipse separation 11/15/2016 8:04:20AM Page 2 COMPASS 5000.1 Build 74 Baker Hughes INTEQ Fara. ConocoPhillips Travelling Cylinder Report BAKER HUGHES Company: ConocoPhillips (Alaska) Inc. -Kupl Project: Kuparuk River Unit Reference Site: Kuparuk 113 Pad Site Error: 0.00 usft Reference Well: 1 B-18 Well Error: 0.00 usft Reference Wellbore 1 B-18AL3 Reference Design: 1B-18AL3_wp05 Local Co-ordinate Reference: Well 1B-18 TVD Reference: 1 B-18 @ 102.00usft MD Reference: 1 B-18 @ 102.00usft North Reference: True Survey Calculation Method: Minimum Curvature Output errors are at 1.00 sigma Database: OAKEDMP2 Offset TVD Reference: Offset Datum Summary Kuparuk 1 B Pad - 1B -17 -IB -17-1B-17 Reference Offset Centre to No -Go Allowable Measured Measured Centre Distance Deviation Warning Site Name Depth Depth Distance (usft) from Plan Offset Well - Wellbore - Design (usft) (usft) (usft) Measured (usft) Measured Kuparuk 1B Pad Reference Offset Toolface+ Offset Wellbore Centre Casing- 1B-15 - 1 B-15AL3 - 1 B-15AL3 No Go Allowable Warning Depth Depth Depth Out of range 1 B-15 - 1 B-15AL3PB1 - 1 B-15AL3PB1 Azimuth +N/ -S +E/ -W Hole Size Out of range 1 B-16 - 1 B-16 - 1 B-16 Deviation (usft) (usft) (usft) (usft) Out of range 1 B-17 - 1 B-17 - 1 B-17 9,486.89 7,100.00 236.93 8.18 234.24 Pass - Minor 1/10 1 B-17 - 1 B-1711 - 1 B-171_1 9,483.80 7,025.00 251.96 2.74 250.14 Pass - Minor 1/10 1 B-17 - 1 B-171-2 - 1 B-171-2 9,488.67 6,975.00 281.09 2.78 279.69 Pass - Minor 1/10 1 B-17 - 1 B-171-2-01 - 1 B-171-2-01 9,488.67 6,975.00 281.09 2.78 279.69 Pass - Minor 1 /10 1 B-17 - 1 B-171-2-01 PB1 - 1 B-171-2-01 PB1 10,802.86 8,525.00 263.69 4.66 262.79 Pass - Minor 1/10 1 B-18 - 1 B-18 - 1 B-18 8,225.00 6,775.00 875.72 62.66 826.13 Pass - Major Risk 1 B-18 - 1 B -18A - 1 B-1 8A 7,985.06 8,075.00 21.08 0.30 20.86 Pass - Minor 1 /10 1 B-18 - 1 B-18AL1 - 1 B-18AL1_wp05 7,875.00 7,875.00 0.00 1.30 -1.21 FAIL - Minor 1/10 1 B-18 - 1 B-18AL2 - 1 B-18AL2_wp02 8,225.00 6,775.00 875.72 2.58 875.49 Pass - Minor 1/10 1 B-18 - 1 B-18AL3PB1 - 1 B-18AL3PB1 7,875.00 7,875.00 0.00 1.30 -1.21 FAIL - Minor 1/10 1 B-19 - 1 B-19 - 1 B-19 7.97 1,249.01 Pass - Minor 1/10 9,450.00 6,703.08 5,875.00 Out of range 1 B-19 - 1 B-191_1 - 113-191-1 26.38 36.21 -1,092.23 729.37 5 Out of range 1 B-19 - 16-191-1-01 - 1 B-191-1-01 1,224.55 Pass- Minor 1/10 9,450.00 6,703.08 5,900.00 5,582.81 Out of range 1 B-19 - 16-191-1-02 - 1 B-1911-02 36.46 -1,103.79 736.79 5 1,200.53 Out of range WSW -01 - WSW -01 - WSW -01 9,450.00 6,703.08 5,925.00 5,603.71 25.36 Out of range WSW -02 - WSW -02 - WSW -02 -1,115.32 744.23 5 1,176.11 7.97 Out of range WSW -03 - WSW -03 - WSW -03 6,703.08 5,950.00 5,624.63 25.36 26.77 Out of range WSW -04 - WSW -04 - WSW -04 751.68 5 1,151.71 7.97 1,151.29 Pass - Minor 1/10 Out of range WSW -05 - WSW -05 - WSW -05 5,975.00 5,645.56 25.36 26.90 37.26 Out of range Offset Design Kuparuk 1 B Pad - 1B -17 -IB -17-1B-17 Offset Site Error: 0 00 usft Survey Program: 60 -GCT -MS, 7427 -CB -GYRO -SS Rule Assigned: Minor 1/10 Offset Well Error: 0.00 usft Reference Offset Semi Major Axis Measured Vertical Measured Vertical Reference Offset Toolface+ Offset Wellbore Centre Casing- Centre to No Go Allowable Warning Depth Depth Depth Depth Azimuth +N/ -S +E/ -W Hole Size Centre Distance Deviation (usft) (usft) (usft) (usft) (usft) (usft)(°) usft ( ) (usft) () (usft) (usft) (usft) 9,450.00 6,703.08 5,750.00 5,457.28 25.36 25.74 35.12 -1,034.37 692.96 5 1,347.55 7.97 1,347.14 Pass - Minor 1110 9,450.00 6,703.08 5,775.00 5,478.24 25.36 25.87 35.32 -1,045.97 700.10 5 1,322.99 7.97 1,322.57 Pass- Minor 1/10 9,450.00 6,703.08 5,800.00 5,499.21 25.36 25.99 35.53 -1,057.53 707.29 5 1,298.44 7.97 1,298.02 Pass- Minor 1/10 9,450.00 6,703.08 5,825.00 5,520.15 25.36 26.12 35.74 -1,069.07 714.57 5 1,273.92 7.97 1,273.50 Pass - Minor 1/10 9,450.00 6,703.08 5,850.00 5,541.05 25.36 26.25 35.97 -1,080.65 721.95 5 1,249.43 7.97 1,249.01 Pass - Minor 1/10 9,450.00 6,703.08 5,875.00 5,561.92 25.36 26.38 36.21 -1,092.23 729.37 5 1,224.97 7.97 1,224.55 Pass- Minor 1/10 9,450.00 6,703.08 5,900.00 5,582.81 25.36 26.51 36.46 -1,103.79 736.79 5 1,200.53 7.97 1,200.12 Pass - Minor 1/10 9,450.00 6,703.08 5,925.00 5,603.71 25.36 26.64 36.72 -1,115.32 744.23 5 1,176.11 7.97 1,175.69 Pass - Minor 1/10 9,450.00 6,703.08 5,950.00 5,624.63 25.36 26.77 36.99 -1,126.81 751.68 5 1,151.71 7.97 1,151.29 Pass - Minor 1/10 9,450.00 6,703.08 5,975.00 5,645.56 25.36 26.90 37.26 -1,138.27 759.13 5 1,127.33 7.97 1,126.91 Pass - Minor 1/10 9,450.00 6,703.08 6,000.00 5,666.49 25.36 27.03 37.55 -1,149.73 766.60 5 1,102.97 7.97 1,102.56 Pass - Minor 1110 9,450.00 6,703.08 6,025.00 5,687.43 25.36 27.16 37.85 -1,161.16 774.07 5 1,078.65 7.97 1,078.23 Pass - Minor 1/10 9,450.00 6,703.08 6,050.00 5,708.38 25.36 27.29 38.17 -1,172.55 781.56 5 1.,054.34 7.97 1,053.93 Pass - Minor 1/10 9,450.00 6,703.08 6,075.00 5,729.35 25.36 27.42 38.50 -1,183.92 789.04 5 1,030.07 7.97 1,029.65 Pass - Minor 1110 9,450.00 6,703.08 6,100.00 5,750.33 25.36 27.55 38.84 -1,195.28 796.53 5 1,005.83 7.97 1,005.41 Pass - Minor 1/10 9,450.00 6,703.08 6,125.00 5,771.25 25.36 27.69 39.20 -1,206.67 804.10 5 981.64 7.97 981.23 Pass - Minor 1/10 9,450.00 6,703.08 6,150.00 5,792.09 25.36 27.82 39.60 -1,218.14 811.79 5 957.55 7.97 957.13 Pass - Minor 1/10 9,450.00 6,703.08 6,175.00 5,812.85 25.36 27.95 40.02 -1,229.68 819.59 5 933.54 7.97 933.12 Pass - Minor 1/10 9,450.00 6,703.08 6,200.00 5,833.60 25.36 28.08 40.46 -1,241.20 827.44 5 909.59 7.97 909.18 Pass- Minor 1/10 9,450.00 6,703.08 6,225.00 5,854.39 25.36 28.21 40.93 -1,252.67 835.28 5 885.69 7.97 885.27 Pass - Minor 1/10 CC - Min centre to center distance or covergent point, SF - min separation factor, ES - min ellipse separation 11/1512016 8:04:20AM Page 3 COMPASS 5000.1 Build 74 ConocoPhillips Project: Kuparuk River Unit Azimuths to True North Magnetic Nonh: 18.01° WELLBORE DETAILS: 1B-18AL3 REFERENCE INFORMATION Site: Kuparuk 1B Pad 1B 18AL T03 1B-18 Well: 113.18 +N/ -S +E/ -W Magnehc Field Parent Wellbore: 1 B-18AL3PB1 Coordinate (NIE) Reference: Well 113-18, True North Wellbore: 1B-18AL3 Longitude Strength: 57550.7snT Dip Angle:BO.e6° Te on MD: 7870.45 Vertical (TVD) Reference: Mean See Ll eveSection(VS)Reference: Plan: 1 B-16AL3 wp05 (16-18/16-18AL3) 550148.90 Da eBGGM2016 70° Slot - (0.00N, O.00E) Measured Depth Reference: 1B-18 @ 10200usfl -17t 64RB Sec Model Inc Calculation Method: Minimum Curvature 6100 ,r. 6200 1 18 L2_F ultl O 6300 O 6400 O Q6500 P U 6600 6700 Start 12 di, 4 5 6 7 8 B- 18/1 B- AL2 y� 6800 F' B - -300C -325C 7/I$ -17 WE I BAKER HUGHES WELL DETAILS: 1B 18AL T03 1B-18 25( +N/ -S +E/ -W Northing Easting Latitude Longitude 1600.0 0.00 0.00 5969647.06 550148.90 B-18 L3_T 1 X 70° 19'40.248 N 149° 35' 35.868 W -17t 64RB Sec MD Inc Azi TVDSS +N/ -S +E/ -W Dleg TFace VSect Annotation -251 1 7870.45 90.28 71.01 6611.32 -2646.95 7.16 0.00 0.00-1866.61 TIP 2 7900.00 91.52 70.60 6610.86 -2637.23 35.07 4.42 -18.29-1840.01 KOP -50c 3 7970.00 99.92 70.60 6603.89 -2614.12 100.71 12.00 0.00 -1777.25 Start 12 dls 4 8220.00 93.65 41.04 6573.71 -2475.95 303.40 12.00 260.00 -1536.23 4 7sc 5 8320.00 91.50 52.85 6569.19 -2407.88 376.26 12.00 100.00 -1436.57 5 6 8430.00 89.19 39.86 6568.52 -2332.13 455.69 12.00 260.00 -1326.85 6 loot 7 8500.00 87.03 47.98 6570.83 -2281.78 504.17 12.00 105.00 -1256.96 7 8 8810:00 87.64 10.74 6585.77 -2016.63 653.31 12.00 270.00 -964.01 8 -l2sc 9 8970.00 88.43 29.94 6591.31 -1867.40 708.64 12.00 88.00 -819.37 9-150t 10 9095.00 88.48 14.93 6594.70 -1752.23 756.19 12.00 270.00 -704.31 10 11 9595.00 90.11 74.92 6601.50 -1414.24 1093.37 12.00 89.00 -226.89 11 �nsc 12 9870.00 90.09 41.92 6601.02 -1272.20 1324.42 12.00 270.00 36.92 12 13 14 10170.00 10350.00 90.07 90.07 77.92 56.32 6600.59 6600.37 -1124.29 -1054.72 1579.76 1744.62 12.00 12.00 90.00 322.06 270.00 487.83 13 14 -200( 1510575.00 90.06 83.32 6600.11 -977.81 1953.85 12.00 90.00 690.17 15_2zsc 16 10770.00 90.05 59.92 6599.92 -916.74 2137.62 12.00 270.00 863.29 16 1710945.00 90.05 80.92 6599.75 -858.422301.58 12.00 90.00 1020.47 17 0-zsoc 1811145.00 90.05 56.92 6599.58 -787.00 2486.83 12.00 270.00 1201.96 18 1911345.00 90.04 80.92 6599.42 -715.59 2672.08 12.00 90.00 1383.45 19 20 11600.00 116.20 64.44 6541.66 -644.40 2906.79 12.00 330.00 1599.75 Planned TD at 11600.00 -2750 6100 ,r. 6200 1 18 L2_F ultl O 6300 O 6400 O Q6500 P U 6600 6700 Start 12 di, 4 5 6 7 8 B- 18/1 B- AL2 y� 6800 F' B - -300C -325C 7/I$ -17 WE I BAKER HUGHES •�� - <w wu r�u Iuuu IZDU I>DD 1/50 2000 2250 2500 2750 3000 3250 3500 3750 West( -)/East(+) (250 usft/in) 8A IB -17/111-171,2 -- 1-17/IB -171,2-011`11 18-1 nB=t z-ol Pla tined T at 11 500.0b Mean Sea L - -- -2200 -2100 -2000 -1900 -1800 -1700 -1600 -1500 -1400 -1300 -1200 -1100 -1000 -960 -800 -760 -600 -500 -400 -300 -200 -100 0 100 200 300 400 500 600 700 800 900 1000 1100 1200 1300 1400 1500 1600 Vertical Section at 45.00° (100 usft/in) 1B 18AL T03 art IB- 8AL3 TO2 is IaN1@d Dat IB -11 CTD of or North Revise 1600.0 l 1 B-18 L3_T 1 X -17t 64RB 1B- 7/1 B'., 7L2 1 -17/1 -17L -Ol 1 -18/113 18AL --------- - 113.1 16- I -9 8 1-1-7r] I Frx TIP KOP IB -1 8/1 B-1 I AL3PI I 1 a 113-18/113-11 ALI Sta t 12 dl 113-I LI Fa,,Itl 1B 18/111 18 111-I A Fatltl •�� - <w wu r�u Iuuu IZDU I>DD 1/50 2000 2250 2500 2750 3000 3250 3500 3750 West( -)/East(+) (250 usft/in) 8A IB -17/111-171,2 -- 1-17/IB -171,2-011`11 18-1 nB=t z-ol Pla tined T at 11 500.0b Mean Sea L - -- -2200 -2100 -2000 -1900 -1800 -1700 -1600 -1500 -1400 -1300 -1200 -1100 -1000 -960 -800 -760 -600 -500 -400 -300 -200 -100 0 100 200 300 400 500 600 700 800 900 1000 1100 1200 1300 1400 1500 1600 Vertical Section at 45.00° (100 usft/in) ConocoPhillips 36( 32( 28( 24( 20( 16C 12C 8( 4C -4C S". -8C O -12C O -16C + -20C O 7 -24C -280 C/ -320 -360 -400 -440 -480 -520 560 -600 -640 -680 qao Project: Kuparuk River Unit Site: Kuparuk 113 Pad Well: 13-18 Azimulns to TrueNorth Magnetic North'. 18.01° Magnetic Field WELLBORE DETAILS: 113-18AL3 REFERENCE INFORMATION Parent Wellbore: 1 B-18AL3PB1 Co-ordinate (N/E) Reference'. Well iB-18, True North Wellbore: 113-18AL3 strengin: 57550.7enT Dip Angle: 80.56• Tie on MD: 7870.45 Vertical (TVD) Reference: 113-18 @ 102.00usft Plan: 113A8AL3_wp05 (113-18/113-18AL3) Date: 1011QD16 _ II-0�t/113-93-1.u.1 Section [VS) Reference: Slot -(O.00N, 0.00E) Measured Depth Reference: 18-18 102.00usft Model: BGGM2016 Calculation Method: Minimum Curvature WE '&'-- BAKER HUGHES ) — I3-14 - _ II-0�t/113-93-1.u.1 [;-111115-LI Ili-7[�(IF3-ir. p� -SO({0 7��41 0 1Fi T �Illli II II 6 6\ A IC'{WIC 17 I.II N ` ' <k'1 IU /II IO21 131 113- UI 1 t3 I( 1 ;' h4C4i yI Ica/I : Ift31.1 IC Ir IC OXI, I -i �� tC.-I7R11C 17h * IA -30/ A->1, : •. d�` 'VA( IC t,PI('-(II ,�h IC -74/17 I-7,Irri711 Cali r ik Ii •t f'F}k--- T lh 1611 H.1" \_ WSW 9 S. -119 H Oi'Il -01 „ 113-12/ R 12 'IC•I /1 C'-1'. ?W! IC -(i /lC r1K WSW-] /'WSW -II S�0 9 Gp W 011V SIA 03 ^dy I!A- 411 MI 1, (i1'1,� ,4A pC dtib ,b 77 IC 102/ 11 IU2P 32- IC 17'/IC17RUP31 h ; IDN03 ID! 103 o �.- �� j 1 11 1271E -173 4 ;.OKI S •OK Sw-01 WS�4-.dl I(�-uX Ili-lrK� I-ul I `q� g sw.oz sw-o �. � •- N 1 vu-Izl It I^3 I1 _ :I - - f�3-tIK/J 1p-uKAI. f,lt � 1 0 0 B-I8/1I IKAI.3 II 121/IF 121':1:1 " 37v6 4 1 -itil l B (18AI 111318 Ili -I"1 RqA WSW- 6/WSW IO � r"�^ :�� I;L-II)/1C-1:1 ID- /IJI_ I.y 4Nkj 7t I SII 7[< t _. - ' cG 113 17 X13 1'I' 11'1 I -c� q: II 12;,FI:12,11 I by ,34 ,3 o0 09M 3-U dp F1 1S SW -US S - F3 -15/11 -1>.V!1 _ c -n 4upp 60 0 -1R 1 i 16-17 _ 1-17C1 I -172/10-I77AI. I�f31 .? ita= In; 0 1 yr ;1 snr 1/41 a 713-I8113.1KAL 061104/A _1041'13 It3 1 .IH IjA Q� 41 IB -IRA 5"", 113- 8l113-) AlB-18 f 8.��0 Clio I, 211IC_ _ IR/I[3-IS 1 p� 1F3-1 '1 Fi:!> 13P731 - - IR I,/ Ii 16AL CP132 �1p 113-1 1314:15 L2P131 (r _ +. '6110i IC -24/1C.24 �. b`` �1 3-I 173`til II3-t�4/1 3 -CI 010 0 1 1 b c IF, (12/1 s-1 V131 I'-03 COI 1a/Ic-In- ' - .( .- 3s �s II:- u>/ I: -.112L IP13 I I(3/IC I(r31 1 - 1'13-uo Ilt IiA 6076 I il,7,11 07 Il.r^ H::4U7A ^_ 01 1C 17 rIC-17-A}r2VIi 73,1 n Lr:-oK/ r-osAL -ol ?I C7/ILI7ALZ� ('-104 IC- ! Ito IC -17 /IC 17- 39 113 -IH,' 6-141.1 c H19 '. II A. IC -10411['-I •11.1 I(.4/I li_f(i A 40(1 _..n IR -U113 -1911-i' %'414. 56 3p7KF 111-12/P-12.1 --.1R-I9iIY,-IPC f9t Ir UK/1G08A I1�t1K/II-o8 .Lot 'IC -17 1 Ih ilia I s-iK/fli-0 Alll-03 tl TTJ-II_ 1412 :-17 /1 09 Al l 11-10/1 �, 1(� €r -b IE -08 a roh/n- 104 DoT 660j J17/II;-17 A D- 471D-1- .66� oI1 •• 6 5'" ]F 1 /IL 121. PI31 .n 0a o Ip �0 00 ll u8/I I, I1.- K/111 -I -0411 F. (iKAI 1 sp t :-16 !IF fi F131 . b�o IF -1 / f,; 121.2 1 k11 Pitt IF -I 9/11 1"12 ID -1131D-113 --- - I: LI2/11-12 1P31 o 1 isK — 1t I, n Ikn bigc 0p0 d /I(7s - 1 In a @1D2000sft IS _-I IE -12/1 / c1 19 _ IIE-) (7 ID --1 1 - 11( I - it cryr -Cn00-S((0 -57(1(1 _4R(1n _dd()n _dnnn _'tAnn nn ?ann _7nnn - ---- ---- ---- - -- ---- ---- ---- I— /DUU SUVU 841JU West( -)Bast(+) (400 usft/in) TRANSMITTAL LETTER CHECKLIST WELL NAME: M Lc Z /3 - / g A o PTD: Development _ Service _ Exploratory _ Stratigraphic Test _ Non -Conventional FIELD: POOL: Check Box for Appropriate Letter / Paragraphs to be Included in Transmittal Letter CHECK OPTIONS TEXT FOR APPROVAL LETTER MULTI The permit is for a new wellbore segment of existing well Permit / LATERAL No. a f �, -% API No. 50-0�-�-- 0c. (If last two digits Production should continue to be reported as a function of the original in API number are API number stated above. between 60-69) In accordance with 20 AAC 25.005(f), all records, data and logs acquired for the pilot hole must be clearly differentiated in both well Pilot Hole name ( PH) and API number (50- - - -) from records, data and logs acquired for well (name on permit). The permit is approved subject to full compliance with 20 AAC 25.055. Approval to produce/inject is contingent upon issuance of a conservation Spacing Exception order approving a spacing exception. (Company Name) Operator assumes the liability of any protest to the spacing exception that may occur. All dry ditch sample sets submitted to the AOGCC must be in no greater Dry Ditch Sample than 30' sample intervals from below the permafrost or from where samples are first caught and 10' sample intervals through target zones. Please note the following special condition of this permit: production or production testing of coal bed methane is not allowed for Non -Conventional (name of well) until after (Company Name) has designed and Well implemented a water well testing program to provide baseline data on water quality and quantity. (Company Name) must contact the AOGCC to obtain advance approval of such water well testing program. Regulation 20 AAC 25.071(a) authorizes the AOGCC to specify types of well logs to be run. In addition to the well logging program proposed by (Company Name) in the attached application, the following well logs are also required for this well: Well Logging Requirements Per Statute AS 31.05.030(d)(2)(B) and Regulation 20 AAC 25.071, composite curves for well logs run must be submitted to the AOGCC within 90 days after completion, suspension or abandonment of this well. Revised 2/2015 WELL PERMIT CHECKLIST Field & Pool KUPARUK RIVER, KUPARUK RIV OIL - 490100 Well Name: KUPARUK RIV UNIT 1B-18AL3 Program DEV Well bore seg ❑d PTD#:2161440 Company CONOCOPHILLIPS ALASKA INC Initial Class/Type DEV/1-OIL GeoArea 890 Unit 11160 On/Off Shore On Annular Disposal ❑ Administration 17 _N_onconven. gas conforms to AS31.05.0300.1.A),(,j.2.A-D) - - - - - - -- NA_ - - - - - - - - - - - - - - - - - - - - - - 1 Permit fee attached_ - - - - - N_A 2 Lease number appropriate_ - - - Yes - . - - -- ADL0025648, entire wellbore. - - - - - 3 Unique well _name -and number - - - - - - - _ _ - Yes KRU 1B-18AL3_ 14 Well -located in_a_ deiined_pool - ----------- - - --- Yes - KUPARUK RIVER, KUPARUK RIV OIL - 490100, governed by Order No. 432D. - - - - govery C '5 Well located proper distance from dri_Iling unit -boundary- - - - - - - Yes _ CO 432D contains no spacing restrictions with respect to drilling unit boundaries. 6 Well located proper distance_ from other wells_ - Yes - CO 432D has no interwell spacing restrictions. 7 Sufficient acreage _available in_dril_ling unit Yes 8 If.deviated, -is-wellbore plat_inc_luded - - - - Yes - - - - I9 Operator only affected party_ - - - - - - - - - - - Yes Wellbore_will be than 500' from an external property line where- ownership or landownership_ changes._ - 10 Operator has appropriate_ bond in force _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes _ _ _ _ _ _ _ _ _ _ _ _ - Appr Date 11 Permit. can be issued without conservation order_ Yes _ - . - - - - - - - - - - - - _ - - - - - - - - - - - 112 Permit -can be issued -without administrativ_e_appr_oval Yes PKB 11/16/2016 _ - - - - - 113 -Can permit be approved before 15 -day wait- - - - - - - - - - - - - Yes ------------------------- 14 Well located within area and -strata authorized by Injection Order # (put 10# in_comments)_ (For_ NA_ - - - 15 All wells_within_1/4_mile_area-of review identified (For service well only) - - - - - - NA. - .. . --------------------------------------------------------------- 16 Pre -produced injector; -duration-of pre production less_ than 3 months_ (For service well only) - _ NA - 18 Conductor string -provided - - - - - - - - _ N_A_ - - - - - Con_ductor set_in 13-18 Engineering 19 Surface casing_ Protects all -known- USDWs NA_ - - - _ Surface casing set and ful_ly_cemented in motherbore_1.13-18- - - - - - - - - - - - - - - - - - - - - - - - 20 CMT_vol adequate_to circul_ate_o_n conductor & surf csg _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ NA - 21 CMT -vol adequate -to tie-in_long string to_surf csg- - - -- - NA - 22 CMT -will cover -all known -productive horizons- - - - - - - - - - - - _Yes - - - - Lateral_w_ill _u_se slotted liner. 2 3/8" OD. - Window at 7392 -ft and - 23 _C_asing designs adequate for CJ, B-&- permafrost_ - - - - Yes 24 Adequate_tankage-or reserve pit - - - - - - - - - - - - - - - - - - - - - Yes - - - - Rig has steel pits.. All waste to -approved disposal well, - 25 If-a_re-drill_, has -a 10-403 for abandonment been approved _ _ _ _ _ _ _ _ _ _ _ _ _ - _ _ NA_ _ _ _ _ _ _ _ sundry 316-416_ _ _ _ _ _ _ _ _ _ 26 Adequate wellbore separation_proposed- Yes 1B-17 will be shut in during drilling_. Close approach._ 27 If_diverter required, does it meet regulations_ - - - - - - - NA - - - _ Wellhead in place.. BOPE will be used. - - - Appr Date 128 Drilling fluid- program schematic _& equip list adequate_ - - - - - _ Yes - - - - -Max formation_ press =_3005 psi (9.0 ppg_ EMW) will drill with 8.6_ppg and_ MPD equip. - - - - - - - - - - GLS 11/16/2016 I29 BOPEs,_do they meet regulation - - - - - - - - - Yes - - _ - - CDR2 has 5000 psi BOPE - - - - - 30 BOPE_press rating appropriate; test to -(put psig in comments)_ - Yes . - - - - MPSP = 2347 -psi Will test BOPE to 3500 psi - - - - ----------------- 31 Choke_manifold complies w/API-RP-53 (May 84)_ - - - - Yes - - - - - - - - - - - - - - - - 32 Work will occur without operation shutdown_ - - - - - - -Yes ------ -- ---- ----- - - - - - - - - - - _ _ 133 Is presence of 1-12S gas -probable - - - - - - - - - - Yes - H2S on pad- Rig_has sensors and alarms._ 34 Mechanical -condition of wells within AOR verified (For service well only) - - NA_ - - - - - - - _ - - 35 Permit can be issued w/o hydrogen_ sulfide measures - - - - - - - - - - - - - - - - - No. . .... Wel-Is-on 1B -Pad are-H2S-bearing. H2S measures_ required. - - - - - - - - - - - - - - - - - Geology 36 _D_ata_p_resented on Potential overpressure zones - Yes . Estimated _rese_rvoir pressure is 9.0 ppg EMW; will be drilled using &.6 ppg_mu_d and MPD technique. - - - - Appr Date 37 Seismic _analys_is_ofshallow gas -zones - - - - - - - - - - - - - - - - - - - - - - - - - - NA _ - - - - - - - - _ - - - - _ - _ _ _ PKB 11/16/2016 38 dition survey -(if off -shore) - - - - - _ _ - - - Seabed con ---- -- --------- --------- NA_ _ _ _ - _ - Revised wellbore trajectory due to unforeseen fault._ 39 Contact name/phone for weekly -progress reports- [exploratory only] - - - - - - - - _ - - - - _ NA_ - - - - - - - Onshore development -lateral -to be drilled. - - - - - _ - _ Geologic Engineering Public Added additional lateral L3 due to drilling faults and geologic uncertainty in first Lateral (113-18A) Will capture same target as first Commissioner: Date: Commissioner: Date C ssioner Date lateral with L3 lateral. GIs DTS l k ` ((416L THE STATE N O's' 11, � � � "44116C N GOVERNOR BILL WALKER Gary Eller CTD Team Lead ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510-0360 Conservati®n Commission 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 www.cogcc.alaska.gov Re: Kuparuk River Field, Kuparuk River Oil Pool, KRU 1B-18AL3 ConocoPhillips Alaska, Inc. Permit to Drill Number: 216-144 Surface Location: 500' FNL, 262' FEL, SEC. 9, TI IN, R10E, UM Bottomhole Location: 1168' FNL, 2706' FEL, SEC. 10, TI IN, R10E, UM Dear Mr. Eller: Enclosed is the approved application for permit to re -drill the above referenced development well. The permit is for a new wellbore segment of existing well Permit No. 216-144, API No. 50-029- 22472-62-00. Production should continue to be reported as a function of the original API number stated above. 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, Daniel T. Seamount, Jr. Commissioner -16 DATED this /0 day of November, 2016. STATE OF ALASKA AL. OIL AND GAS CONSERVATION COMM PERMIT TO DRILL (� 20 AAC 25.005 REG .a.. ; �N NOV 0 7 2016 1 a. Type of Work: 1 b. Proposed Well Class: Exploratory - Gas F1 Service - WAG ❑ Service - Disp 0,01 c. Specify if well is proposed for: r�I Drill El L! 1 Stratigraphic Test ElDevelopment - Oil ❑✓ Service - Winj El Single Zone � Coalbed Gas ❑ Gas Hydrates ❑ Redrill [ Reentry ❑ Exploratory - Oil ❑ Development - Gas ❑ Service - Supply ❑ Multiple Zone ❑ Geothermal ❑ Shale Gas ❑ 2. Operator Name: 5. Bond: Blanket ❑ • Single Well E] 11. Well Name and Number: ConocoPhillips Alaska Inc Bond No�Sz 595 2180 1B-18AL3 ' 3. Address: 6. Proposed Depth:?r,' 12. Field/Pool(s): P.O. Box 100360 Anchorage, AK 99510-0360 MD 11400' • TVD: 6 6' Kuparuk River Field / Kuparuk Oil Pool 4a. Location of Well (Governmental Section): 7. Property Designation (Lease Number): Surface: 500' FNL, 292' FEL, Sec 9, T11 N, R10E, UM ADL 25648 Top of Productive Horizon: 8. Land Use Permit: 13. Approximate Spud Date: 2933' FNL, 550' FEL, Sec. 9, T11 N, R10E, UM ALK 466 11/6/2016 Total Depth: 9. Acres in Property: 14. Distance to Nearest Property: 1168' FNL, 2706' FEL, Sec. 10, T11 N, R10E, UM 2560 17730' 4b. Location of Well (State Base Plane Coordinates - NAD 27): 10. KB Elevation above MSL (ft): 102 15. Distance to Nearest Well Open Surface: x- 550147 y- 5969648 Zone -4 GL Elevation above MSL (ft): 61.2 to Same Pool: 145' (1 13-171_1) 16. Deviated wells: Kickoff depth: 7392' feet + 17. Maximum Potential Pressures in psig (see 20 AAC 25.035) Maximum Hole Angle: tOi 40" degrees Downhole: 3005 • Surface: 2347, 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 2800' 8900' 6677" 11400' 6616' N/A 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): 7824' 6941' 7809' 6929' Casing Length Size Cement Volume MD TVD Conductor/Structural 78' 16" 200 sx ASI 121' 121' Surface 4215' 7-5/8" 650 sx AS] 11, 300 sx G 4256' 4148' Intermediate Production 7783' 5"x5.5" 210 sx G 7809' 6929' Liner Perforation Depth MD (ft): Perforation Depth TVD (ft): 7131'- 7194', 7246'-7575' 6400'-6448', 6507'-6741' 20. Attachments: Property Plat ❑ BOP Sketch ❑ Drilling Program 0 Time v. Depth Plot ❑ Shallow Hazard Analysis ❑ Diverter Sketch ❑ Seabed Report ❑ Drilling Fluid Program 20 AAC 25.050 requirements❑✓ 21. Verbal Approval: Commission Representative: �Ati¢ 1^ V�'� •� ��, ip \� 11/7/2016 W�� Date 22. 1 hereby certify that the foregoing is true and the procedure approved herein will not Jeff Connelly- 263-4112 be deviated from without prior written approval. Contact Email Ieff.s.connelly a)cop.com Printed Name `. Gary Eller Title CTD Team Lead Signature Phone 263-4172 Date Commission Use Only Permit to Drill PI Number: Permit Approval See cover letter for other Number: I 50- Date: _ ( b -( Le requirements. Conditions of approval : If box is checked, well may not be used to explore for, test, or produce coalbed meth an ,gas hydrates, or gas contained in shales: Other: �� /�� /� Samples req'd: Yes E]No Mud log req'd: Yes ❑ No x PSS i� f S HzS measures: Yes [Z' No�❑f Directional svy req'd: Yes[. No El /�5�, ,/ , Q j� n,� �S�Spacing exception req'd: Yes ❑ Nou Inclination -only svy req'd: Yes ❑ Nov i'� Post initial injection MIT req'd: Yes ❑ No ❑ APPROVED BY Approved by: COMMISSIONER THE COMMISSION Date: O I 1 \ Lmonths (Tnt FForm 10-401 (Revised 11/2015) t s d from th,2,date of approval (20 AAC 25.005(g)) i/ Attachments in Duplicate 140" ConocoPs philli Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 November 7, 2016 Commissioner - State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Dear Commissioner: N O V 1 17 ? ConocoPhillips Alaska, Inc. hereby submits applications for permits to drill 4 laterals out of the Kuparuk Well 113- 18 using the coiled tubing drilling rig, Nabors CDR2-AC. Attached to this application are the following documents: — 10-401 Applications for 1 B -18A, 1 B-18AL1,1 B-18AL2, and 1 B-18AL3 — Detailed Summary of Operations --- - 1 B-18 Schematic — Proposed CTD Schematic If you have any questions or require additional information, please contact me at 907-263-4180. Sincerely, l� Jeff Connelly ConocoPhillips Alaska Coiled Tubing Drilling Engineer All N Kuparuk CTD Laterals NABOAS ALASKA 1 B-1 8A9 1 B-18AL13 1 B-18AL27 & 1 B-18AL3 Application for Permit to Drill Document 2RC 1. Well Name and Classification........................................................................................................ 2 (Requirements of 20 AAC 25.005(0 and 20 AAC 25.005(b))................................................................................................................... 2 2. Location Summary.......................................................................................................................... 2 (Requirements of 20 AAC 25.005(c)(2)).................................................................................................................................................. 2 3. Blowout Prevention Equipment Information................................................................................. 2 (Requirements of 20 AAC 25.005(c)(3))................................................................................................................................................. 2 4. Drilling Hazards Information and Reservoir Pressure.................................................................. 2 (Requirements of 20 AAC 25.005(c)(4)).................................................................................................................................................2 5. Procedure for Conducting Formation Integrity tests................................................................... 2 (Requirements of 20 AAC 25.005(c)(5)).................................................................................................................................................. 2 6. Casing and Cementing Program.................................................................................................... 3 (Requirements of 20 AAC 25.005(c)(6)).................................................................................................................................................. 3 7. Diverter System Information.......................................................................................................... 3 (Requirements of 20 AAC 25.005(c)(7)).................................................................................................................................................. 3 8. Drilling Fluids Program.................................................................................................................. 3 (Requirements of 20 AAC 25.005(c)(8)).................................................................................................................................................. 3 9. Abnormally Pressured Formation Information............................................................................. 4 (Requirements of 20 AAC 25.005(c)(9)).................................................................................................................................................. 4 10. Seismic Analysis............................................................................................................................. 4 (Requirements of 20 AAC 25.005(c)(10))................................................................................................................................................4 11. Seabed Condition Analysis............................................................................................................ 4 (Requirements of 20 AAC 25.005(c)(11))................................................................................................................................................ 4 12. Evidence of Bonding...................................................................................................................... 4 (Requirements of 20 AAC 25.005(c)(12))................................................................................................................................................ 4 13. Proposed Drilling Program.............................................................................................................4 (Requirements of 20 AAC 25.005(c)(13))................................................................................................................................................ 4 Summaryof Operations...................................................................................................................................................4 LinerRunning...................................................................................................................................................................6 14. Disposal of Drilling Mud and Cuttings.......................................................................................... 6 (Requirements of 20 AAC 25.005(c)(14))................................................................................................................................................ 6 15. Directional Plans for Intentionally Deviated Wells....................................................................... 6 (Requirements of 20 AAC 25.050(b))...................................................................................................................................................... 6 16. Attachments....................................................................................................................................7 Attachment 1: Directional Plans for 113-18A, 1 B-18AL1, 1 B-18AL2, and 1 B-18AL3 laterals...........................................7 Attachment 2: Current Well Schematic for 1 B-18............................................................................................................7 Attachment 3: Proposed Well Schematic for 113-18A, 1 B-18AL1, 1 B-18AL2, and 1 13-18AL3 laterals .............................7 Page 1 of 7 November 7, 2016 PTD Application: 1 B-1 8A, 1 B-18AL1, 1 B-18AL2, and 1 B-18AL3 1. Well Name and Classification (Requirements of 20 AAC 25.005(f) and 20 AAC 25.005(b)) The proposed laterals described in this document are 113-18A, 1 B-18AL1, 1 B-18AL2, and 1 B-18AL3. All laterals will be classified as production wells. 2. Location Summary (Requirements of 20 AAC 25.005(c)(2)) These laterals will target the A sand package in the Kuparuk reservoir. See attached 10-401 form for surface and subsurface coordinates of the 1 B-1 8A, 1 B-18AL1, 1 B-18AL2, and 1 B-18AL3. 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 CDR2-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 3005 psi in 1 B-04 (i.e. 9.0 ppg EMW), the maximum potential surface pressure in 1 B-18, assuming a gas gradient of 0.1 psi/ft, would be 2347 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 1 B-18 was measured to be 2640 psi (7.7 ppg EMW) on 9/3/2012. The maximum downhole pressure in the 1 B-18 vicinity is to the south in the 1 B-04 injector at 3005 psi (9.0 ppg EMW) from November of 2014. The 1 B-18AL2 sidetrack will be drilled to the west and could encounter formation pressure from 1 B-04. Potential Gas Zones (Requirements of 20 AAC 25.005 (c)(4)(b)) Wells on 1 B pad have injected gas, so there is a chance of encountering free gas while drilling the 1 B-18 laterals. If significant gas is detected in the returns the contaminated mud can be diverted to a storage tank ✓ ' away from the rig. Potential Causes of Hole Problems (Requirements of 20 AAC 25.005 (c)(4)(c)) The major expected risk of hole problems in the 1 B-18 laterals will be shale instability across faults and at zonal interfaces. Managed pressure drilling (MPD) will be used to reduce the risk of shale instability associated with fault crossings and interfaces. 5. Procedure for Conducting Formation Integrity tests (Requirements of 20 AAC 25.005(c)(5)) The 1 B-18 laterals will be drilled under 20 AAC 25.036 for thru-tubing drilling operations so a formation integrity test is not required. Page 2 of 7 November 7, 2016 PTD Application: 1 B-1 8A, 1 B-18AL1, 1 B-18AL2, and 1 B-18AL3 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 1 B-1 8A 8900' 11,400' 6513' 6458' 2-3/8", 4.7#, L-80, ST -L slotted liner,- iner;aluminum TVD TVD psi psi Conductor aluminumbillet on top 1 B-18AL1 7500' 11300' 6480' 6477`2-3/8", 4.7#, L-80, ST -L slotted liner; 121' 1640 670 Surface 7-5/8" deployment sleeve on top 1 B-18AL2 7040' 9575' 6229' 6453' 2-3/8", 4.7#, L-80, ST -L slotted liner; 6890 4790 Production deployment sleeve on to 1 B-18AL3 7392' 11,400' 6497' 6575' 2-3/8", 4.7#, L-80, ST -L slotted liner; 6290 Tie -Back 5-1/2" 17.0 L-80 aluminum billet on to Existing Casing/Liner Information i Category OD Weight Grade Connection Top MD Btm MD Top Btm Burst Collapse (ppf) TVD TVD psi psi Conductor 16" 62.5 H-40 Welded 0' 121' 0' 121' 1640 670 Surface 7-5/8" 29.7 L-80 LTC 0' 4256' 0' 4148' 6890 4790 Production 7960 6290 Tie -Back 5-1/2" 17.0 L-80 TC -II 0' 7030' 0' 6325' Production 5" 18.0 L-80 LTC MOD 7030' 7809' 6325' 6929' 10140 10500 Tubing 3-1/2" 9.2 L-80 IBTM 0' 6930' 0' 6251' 10160 10530 7. Diverter System Information (Requirements of 20 AAC 25.005(c)(7)) Nabors CDR2-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 CDR2-AC mud system is on file with the Commission. Description of Drilling Fluid System — Window milling operations: Chloride -based FloVis mud (8.6 ppg) — Drilling operations: Chloride -based FloVis 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 11.8 ppg NaBr completion fluid in order to provide formation over -balance and well bore stability while running completions. Managed Pressure Drilling Practice Managed pressure drilling (MPD) techniques will be employed to maintain a constant overbalanced pressure on the open hole formation and promote wellbore stability throughout the coiled tubing drilling (CTD) process. Mud weight is not, in many cases, the primary well control barrier. This is satisfied with the 5,000 psi rated coiled tubing pack off and MPD choke. BOPE equipment provides the secondary well control as detailed in section 3 "Blowout Prevention Equipment Information". In the 1B-18 laterals we will target a constant BHP of 11.8 ppg EMW at the window. The constant BHP target will be adjusted through choke pressure and/or mud weight increases to maintain overbalanced conditions if increased reservoir pressure is encountered. Additional choke pressure or increased mud weight may also be Page 3 of 7 November 7, 2016 PTD Application: 1 B-1 8A, 1 B-18AL1, 1 B-18AL2, and 1 B-18AL3 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. Pressure at the 1B-18 Window (7505' MD, 6584' TVD) Using MPD 9. Abnormally Pressured Formation Information (Requirements of 20 AAC 25.005(c)(9)) N/A - Application is not for an exploratory or stratigraphic test well. 10. Seismic Analysis (Requirements of 20 AAC 25.005(c)(10)) N/A - Application is not for an exploratory or stratigraphic test well. 11. Seabed Condition Analysis (Requirements of 20 AAC 25.005(c)(11)) N/A - Application is for a land based well. 12. Evidence of Bonding (Requirements of 20 AAC 25.005(c)(12)) Evidence of bonding for ConocoPhillips Alaska, Inc. is on file with the Commission. 13. Proposed Drilling Program (Requirements of 20 AAC 25.005(c)(13)) Summary of Operations Background KRU well 1 B-18 is a Kuparuk A/C -sand producer equipped with 3-1/2" tubing and 5-1/2" production casing. The CTD sidetrack will utilize three laterals to target the A4 sand to the north, south, and west of 1B-18. Prior to CTD operations, the existing A -sand and C -sand perforations will be squeezed with cement and a whip -stock will be set to kickoff out of the 5" casing. Following the pre -rig work, Nabors CDR2-AC will move in and drill Four laterals targeting the A4 Sand. The first lateral will be drilled from one window, and the following 3 laterals from a second window just above the first. All four laterals will be completed with 2-3/8" slotted liner from TD with the first and fourth lateral liner tops located inside the mother bore. The 1B -18A northeastern lateral will exit the 5" casing at 7505' MD and TD at 11,400' MD (Note: liner for I B-1 8A lateral became stuck with bottom of liner at 8314' MD and top of liner at 7412' MD), targeting the A4 sand. Page 4 of 7 November 7, 2016 Pumps On (1.5 bpm) Pumps Off A -sand Formation Pressure 7.7 2640 psi 2640 psi Mud Hydrostatic 8.6 2945 psi 2945 psi Annular friction i.e. ECD, 0.090psi/ft) 675 psi 0 psi Mud + ECD Combined no choke pressure) 3620 psi 2945 psi Target BHP at Window (11.8 pp) 4040 psi 4040 psi Choke Pressure Required to Maintain Target BHP 420 psi 1095 psi 9. Abnormally Pressured Formation Information (Requirements of 20 AAC 25.005(c)(9)) N/A - Application is not for an exploratory or stratigraphic test well. 10. Seismic Analysis (Requirements of 20 AAC 25.005(c)(10)) N/A - Application is not for an exploratory or stratigraphic test well. 11. Seabed Condition Analysis (Requirements of 20 AAC 25.005(c)(11)) N/A - Application is for a land based well. 12. Evidence of Bonding (Requirements of 20 AAC 25.005(c)(12)) Evidence of bonding for ConocoPhillips Alaska, Inc. is on file with the Commission. 13. Proposed Drilling Program (Requirements of 20 AAC 25.005(c)(13)) Summary of Operations Background KRU well 1 B-18 is a Kuparuk A/C -sand producer equipped with 3-1/2" tubing and 5-1/2" production casing. The CTD sidetrack will utilize three laterals to target the A4 sand to the north, south, and west of 1B-18. Prior to CTD operations, the existing A -sand and C -sand perforations will be squeezed with cement and a whip -stock will be set to kickoff out of the 5" casing. Following the pre -rig work, Nabors CDR2-AC will move in and drill Four laterals targeting the A4 Sand. The first lateral will be drilled from one window, and the following 3 laterals from a second window just above the first. All four laterals will be completed with 2-3/8" slotted liner from TD with the first and fourth lateral liner tops located inside the mother bore. The 1B -18A northeastern lateral will exit the 5" casing at 7505' MD and TD at 11,400' MD (Note: liner for I B-1 8A lateral became stuck with bottom of liner at 8314' MD and top of liner at 7412' MD), targeting the A4 sand. Page 4 of 7 November 7, 2016 PTD Application: 1 B -1 8A, 1 B-1 BALI, 1 B-18AL2, and 1 B-18AL3 The 113-18AL1 lateral will kick off the billet at 8900' and drill to the east to a TD of 11300' MD targeting the A4 sand. It will be completed with 2-3/8" slotted liner from TD up to 7640' MD for kicking off of the 1 13-18AL2 lateral. The 113- 1 8AL2 western lateral will kick off of an aluminum billet at 7640' MD and TD at 9575' MD, targeting the A4 sand. It will be completed with 2-3/8" slotted liner from TD back into the tubing tail at 7392'MD with a deployment sleeve. The 113- 1 8AL3 Northern lateral will kick off out of a window in the 5" casing at 7392' MD and TD at 11,400' MD, targeting the A4 sand. It will be completed with 2-3/8" slotted liner from TD back to 8900' with an aluminum billet for kicking off of the AL1 lateral. Pre -CTD Work 1. RU Slickline: Dummy off gas lift mandrels, tag PBTD, obtain SBHP 2. RU Pumping: Swap hole over to diesel and perform injectivity test 3. RU Service Coil: Lay in cement plug and squeeze off the A/C -sand perforations. Let cement harden, pressure test cement and under -ream cement down to 7525' MD. 4. RU E -line: Set whip -stock at 7505' MD 5. Prep site for Nabors CDR2-AC and set BPV. Rib Work 1. MIRU Nabors CDR2-AC rig using 2" coil tubing. NU 7-1/16" BOPE, test. 2. 1B -18A Sidetrack (A4 sand -Northeast) i. Mill 2.80" window at 7505' MD ii. Drill 3" bi-center lateral to TD of 11,400 MD. iii. Run 2%" slotted liner with an aluminum billet from TD up to 8900' MD. (Note: liner for 1 B-1 8A lateral became stuck with bottom of liner at 8314' MD and top of liner at 7412' MD), 3. 113- 1 8AL 1 Lateral (A4 sand - East) i. Kick off of the aluminum billet at 8900' MD. ii. Drill 3" bi-center lateral to TD of 11300' MD. iii. Run 2%" slotted with aluminum billet up to 7460' MD 4. 113-18AL2 Lateral (A4 sand -West) i. Kick off of the aluminum billet at 7460' MD. ii. Drill 3" bi-center lateral to TD of 9575' MD. iii. Run 2%" slotted liner with deployment sleeve from TD back into 5" casing. 5. 113-18AL3 Lateral (A4 sand - Northeast) i. Mill 2.80" window at 7392' MD. ii. Drill 3" bi-center lateral to TD of 11,400' MD. iii. Run 2%" slotted liner with aluminum billet up to 8900' MD. Page 5 of 7 November 7, 2016 PTD Application: 1 B-1 8A, 1 B-18AL1, 1 B-18AL2, and 1 B-18AL3 6. Freeze protect, set BPV, ND BOPS, and RDMO Nabors CRD2-AC. Post -Rig Work 1. Pull BPV 2. Obtain SBHP 3. Install gas lift design 4. Return to production Pressure Deployment of BHA The planned bottom hole assemblies (BHAs) are too long to simply isolate by closing the double swab valves on the Christmas tree. MPD operations require the BHA to be lubricated under pressure using a system of double swab valves on the Christmas tree, double deployment rams, double check valves and double ball valves in the BHA, and a slick -line lubricator can be used. This pressure control equipment listed ensures there are always two barriers to reservoir pressure, both internal and external to the BHA, during the deployment process. During BHA deployment, the following steps are observed. — Initially the double swab valves on the tree are closed to isolate reservoir pressure. The lubricator is installed on the BOP riser with the BHA inside the lubricator. — Pressure is applied to the lubricator to equalize across the swab valves. The swab valves are opened and the BHA is lowered in place via slick -line. — When the BHA is spaced out properly, the double deployment rams are closed on the BHA to isolate reservoir pressure via the annulus. A closed set of double ball valves and double check valves isolate reservoir pressure internal to the BHA. Slips on the double deployment rams prevent the BHA from moving when differential pressure is applied. The lubricator is removed once pressure is bled off above the deployment rams. — The coiled tubing is made up to the BHA with the double ball valves plus the double check valves in the closed position. Pressure is applied to the coiled tubing to equalize internal pressure and then the double ball valves are opened. The injector head is made up to the riser, annular pressure is equalized, and the deployment rams are opened. The BHA and coiled tubing are now ready to run in the hole. During BHA undeployment, the steps listed above are observed, only in reverse. Liner Running — The 1 B-18 laterals will be displaced to an overbalanced fluid (11.8 ppg NaBr) prior to running liner. See "Drilling Fluids" section for more details. — While running 2-3/8" slotted liner, a joint of 2-3/8" non -slotted tubing will be standing by for emergency deployment. A floor valve is made up onto this joint ahead of time, and the rig crew conducts a deployment drill with this emergency joint on every slotted liner run. The 2-3/8" rams will provide secondary well control while running 2-3/8" liner. 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. r' • Incidental fluids generated from drilling operations will be injected in a Kuparuk Class II disposal well (1 R-18 or 1 B disposal facilities) or Prudhoe DS -4 if a Kuparuk facility is unavailable. • All wastes and waste fluids hauled from the pad must be properly documented and manifested. • Contact Kuparuk Environmental Coordinator for questions regarding waste classification. (670-4200). 15. Directional Plans for Intentionally Deviated Wells (Requirements of 20 AAC 25.050(b)) — The Applicant is the only affected owner. — Please see Attachment 1: Directional Plans — Magnetic and inclination surveys will be taken every 30 ft. No gyro will be run. Page 6 of 7 November 7, 2016 PTD Application: 1 B-1 8A, 1 B-18AL1, 1 B-18AL2, and 1 B-18AL3 — MWD directional, resistivity, and gamma ray will be run over the entire open hole section. — Distance to Nearest Property Line (measured to KPA boundary at closest point) Lateral Name Distance 1 B-1 8A 17730' 1 B-18AL1 18680' 1 B-18AL2 21220' 1 B-12AL3 17730' — Distance to Nearest Well within Pool Lateral Name Distance Well 1 B-1 8A 155' 1B-171-1 1 B-18AL1 315' 1B-17 1 B-18AL2 285' 1 B-15AL3 1 B-18AL3 145' 1B -17L1 16.Attachments Attachment 1: Directional Plans for 1B -18A, 1B-18AL1, 1B-18AL2, and 1B-18AL3laterals Attachment 2: Current Well Schematic for 1B-18 Attachment 3: Proposed Well Schematic for 1B -18A, 1B-18AL1, 1B-18AL2, and 1B-18AL3laterals Page 7 of 7 November 7, 2016 1 B-18 Proposed CTD Schematic 6" 62# H-40 hoe @ 121' M 7-5/8" 29.7# L-80 shoe @ 4147' MD Modified by JSC 11-4-16 Camco BP -6 injection nipple @ 1951' MD ID = 2.813" 3-1/2" 9.3# L-80 EUE 8rd Tubing to surface 3-1/2" Camco gas lift mandrels @ 2629', 4223', 5498', 6335' & 6862' X -nipple @ 6895' MD ID = 2.812"ID Baker GBH -22 Loactor & Seal assembly at 6918 Baker 3-1/2" PBR @ 6920' MD (3" ID) Baker KBH-22 anchor seal assembly at 6933' MD Baker FA -1 packer @ 6934' MD 5" casing sealbore extension @ 7044' (4.0" ID) 3-1/2" tubing tail @ 7047' MD 5.5" 17# L-80 shoe @ 6997' MD 1 B-18AL2 TD @ 9,575' MD (West) TOL @ —7392' MD KOP @ 7392' MD �a ------ --- 3Y2' x 5" TTWS set at 0' toolface-- 6v 505' KID 1 B-18AL3 TD @ 11400' MD (Northeast) 3�1' x 5" TTWS Billet at 8900' MD end pens _ 7575' MD ;__ 1B-18AL1 TD @ 11,300 MD (East) Tapered Prod Csq Billet @ 7460' MD 5'/2, 17#, L-80, 0'-7044' MD 5", 18#, L-80, 7044'-7809' MD ----------------- 1B-i8A TD @ 9500' MD Liner Bottom at 8314' MQ Liner Top at 7412 MD Ajjj KUP PROD 1B-18 LonoeornnnpsWell Attributes ax Ang Mle S MD TD Aiaska.Inc,VICarminorn WellboreAP6UWI Field Name Wellbore Status ncl{•J MD(ftKB) Ae Bim (kK8) 500292247200 KUPARUK RIVER UNIT PROD 43.20 8,897.51 7,824.0 ••• H2S (ppm) Date SSSV: WRDP 160 11/8/2014 Annotation End Data Last WO: 8/21M12 KEIGrd (ft) Rlg Release Dale 40.81 4/30/1994 16-1 S. 12162015459:13 PM vera<el zenem.6c (.dve6 Annotation Depth (ftKB) Eno Date Annotation Last Mod By End' - LPI WilDate .._. ..__..._ _ _.._ 770 Last Tag: LM 7,477.0 127172014 Rev Reason: REPLACE WRDP/SLIPSTOP 12/6/2015 HANGER: 25.3 _ as ng Strings Casing Description OD (In) ID (In) Top (ftKB) Set Depth (ftKB) Set Depth (TVD)... WVLen (1... Grade Top Thread CONDUCTOR 16 15.063 43.0 121.0 121.0 62.50 H-40 WELDED Casing Description OD (in) ID (In) Top (ftKB) Set Depth (ftKB) Set Depth (TVD)._ WVLen (I... Grade Top Thread SURFACE 75/8 6-875 41.3 4,255.6 4,147.7 29.70 L-80 LTC Casing Deaerlptlan OD (In) ID (In) Top (ftKB) Set Depth (ftKB) Set Depth (TVD)... W61 -en (I... Grade Top Thread PRODUCTION TIE- 5112 4.892 26.3 1.771.5 1,771.4 17.00 L-80 TC -11 BACK CONDUCTOR: 43.0-121 D Casing Description OD (In) 10 (In) Top (ftKB) Set Depth INKS) Set Depth (TVD)... WNLen (I... Grade Top Thread PRODUCTION 5.5"x5" @ 51/2 4.766 1,771.5 7,809.4 6,929.5 17.00 L-80 LTC MOD 7044' "- Tubing Strings Tubing Description String Ma... ID (In) Top (ftKB) 5et Depth (R. Set Depth (TVD) (... Wt (IbHt) Grade Top Con -ton PRODUCTION TIE-BACK26.3- TUBING WO 3112 2.992 25.3 6,930.3 6,251.4 9.20 L-80 IBT-M 17715 Completion Details Nominal 10 TSG STOP; 1,949 7 WRDP; Is 0.7 - Top (ftKB) Top (TVD) (ftKB) Top Incl (') Item Des Co. (in) NIPPLE. 1,950.7 25.3 25.3 0.01 HANGER FMC GEN IV TUBING HANGER 3.500 1,950.7 1,950.7 0.79 NIPPLE CAMCO BP -6I LANDING NIPPLE 2.812 6,894.9 6,225.5 43.19 NIPPLE HESX NIPPLE 2.812 6,918.1 6,242.5 43.06 LOCATOR BAKER LOCATOR SUB 3.000 GAS LIFT; 2.829.7 6,919.0 6,243.2 43.05 SEAL ASSY BAKER GBH -22 SEAL ASSEMBLY 3.000 Tubing Description 51111g Ma... ID (In) Top (kK8) Set Depth (ft.. Set Depth (TVD) ( Wt (lb"T Glade Top Connedtlon SEAL ASSY 3112 2992 6,920.0 7.046.6 6.337.2 9.30 L-80 EUE8RD Completion Details Nominal ID Top (ftKB) Top (TVD) (ftKB) Top Incl 11 Item Des Co. pn) 6,920.0 6,243.9 43.04 PBR BAKER POLISHED BORE RECEPTACLE 3.000 GAS LIFT; 4.223.6 6,933.3 6,253.6 42.95 SEAL ABBY KSH-22 ANCHOR SEAL ASSEMBLY 3.000 6,933.7 6,253.9 42.95 PACKER BAKER FA -145A36 PACKER 3.020 7,034.0 6,327.8 42.24 LOCATOR BAKER LOCATOR 2.990 7,034.8 6,328.4 42.23 1 SEAL ASSY BAKER GBH -22 SEAL ASSEMBLY W/O SEALS 2.990 SURFACE; 41.3-4.255.6- Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top (TVD) Top Incl Top (ftKB) (ftKB) (') Des Co. Run Date ID (In) GAS LIFT; 5,496.0 1,949.7 1,949.61 0.79 TBG STOP 3.5" TUBING STOP 12/5/2015 1,950.7 1,950.6 0.79 WRDP 3.5" WRDP (S/N: C25-0318)ON 2.81'13-7 LOCK 12/512015 1.520 (OAL=65' 1 Perforations & Slots GAS LIFT', 6335.6 Shot Dans Top (TVD) etm (TVD) (shaW Top (ftKB) Stm (ftKB) (ftKB) (ft)(B) Zone Date 0 Type Co. 7,131.0 7,161.0 6,400.2 6,422.7 C-4, C-3,18- 11/5/1994 6.0 RPERF 21/8"Eneriet 90 deg 18 phase, 45 deg GAS LIFT; 6,862.3 odentation 7.166.0 7,176.0 6,426.5 6,434.0 C -2,1B-18 11/5/1994 6.0 RPERF 21/8' Eneriet 90 deg phase, 45 deg orientation NIPPLE;6,894.9 7,182.0 7,194.0 6,438.5 6,447-6 C-2, IB -18 11/5/1994 6.0 RPERF 21/8"Eneriet 90 deg phase, 45 deg orientation LOCATOR: 6.918.1 7.246.0 7.273.0 6,486.9 6,507.4 C-1, IB -18 2/4/1995 6.0 RPERF 21/8"Eneriet, 90 deg SEAL ASSY; 6.919.0 PBR; 6.920.0 phase, orientation 45 deg 7,256.0 7.539.0 6.494.5 6,712.8 Ad, 1B-18 6/9/1994 4.0 IPERF 33/8'HSD CSG guns, SEAL ASSY; 8,9331 _- Oriented - PACKER; 6.933.6 7,548.0 7.575.0 6.719.9 6,7412 Ad, 1B-18 6/9/1994 4.0 IPERF 3 Oriented 318" HSD CSG guns, Cement Squeezes Top (TVD) Btm (TVD) Top (ftKB) Btm (11K.){ftKB) (ftKB) Des Start Dara Com 26.3 1,771.5 26.3 1,771.4 CSG CMT B/W2012 PRODUCTION TIEBACK CEMENT LOCATOR; 7,034.0 Mandrel Inserts SEAL ASSY; 7,034.8 g1 a8 N Top (TVD) Top (ftKB) (ftKB) Make Model OD (In) S., Valve Type Latch Port Size TRO Run Type (In) (pet) Run Date Co. 1 2,629.7 2,629.6 CAMCO KBG-2- i GAS LIFT GLV INT 0.166 1,246.0 9/3/2012 9 2 4,223.6 4,120.9 CAMCO KBG-2- 1 GAS LIFT GLV INT 0.156 1,249.0 9/22012 RPERF; 7,131.0.7,161.0 9 3 5,498.0 5,120.9 CAMCO KBG-2- 1 GAS LIFT GLV INT 0.188 1,283.0 9)2/2012 9 RPERF: 7.166.0.7.176.0 q 6,335.6 5,805.5 CAMCO KBG-2- 1 GAS LIFT GLV INT 0.188 1,278.0 9/2/2012 1 9 I 1 RPERF; 7,182.&7,1940 5 6,862.3 6,201.8 CAMCO KBG-2- 1 GAS LIFT OV INT 0.250 0.0 92/2012 9 Notes: General & Safety _ RPERF; 7,z4s.&7,z73.o End Owe Annotation 8/92010 NOTE: View Schematic w/ Alaska Schematic9.0 IPERF: 7,256.0.7,539.0 IPERF; 7,548.0-7.575.0 PRODUCTION 5.5Y5" (9 7044'; -] 1,752.&7,809.4 ConocoPhillips ConocoPhillips (Alaska) Inc. -Kup1 Kuparuk River Unit Kuparuk 1 B Pad IB -18 1 B-18AL3 Plan: 1 B-18AL3_wp03 Standard Planning Report 06 November, 2016 a pw--- BAKER HUGHES ConocoPhillips ConocoPhillips Database: EDM Alaska NSK Sandbox Company: ConocoPhillips (Alaska) Inc. -Kup1 Project: Kuparuk River Unit Site: Kuparuk 1 B Pad Well: 1B-18 Wellbore: 1 B-18AL3 Design: 1 B-18AL3_wp03 ConocoPhillips Nal Planning Report BAKER HUGHES Local Co-ordinate Reference: Well 1 B-18 TVD Reference: Mean Sea Level MD Reference: 1 B-18 @ 102.00usft North Reference: True Survey Calculation Method: Minimum Curvature Project Kuparuk River Unit, North Slope Alaska, United States Map System: US State Plane 1927 (Exact solution) System Datum: Mean Sea Level Geo Datum: NAD 1927 (NADCON CONUS) Using Well Reference Point Map Zone: Alaska Zone 04 Using geodetic scale factor Site Kuparuk 1 B Pad Site Position: Northing: 5,969,646.72 usft Latitude: 70° 19'40.290 N From: Map Easting: 549,457.40 usft Longitude: 149° 35'56.056 W Position Uncertainty: 0.00 usft Slot Radius: 0.000 in Grid Convergence: 0.38 ° Well 113-18 Well Position +N/ -S 0.00 usft Northing: 5,969,647.06 usft Latitude: 70° 19'40.248 N +E/ -W 0.00 usft Easting: 550,148.90 usft Longitude: 149° 35' 35.868 W Position Uncertainty 0.00 usft Wellhead Elevation: usft Ground Level: 61.20 usft Wellbore 1 B-18AL3 Magnetics Model Name Sample Date Declination Dip Angle Field Strength (°) (°) (nT) BG G M 2016 10/1/2016 18.01 80.96 57,551 Design 1 B-18AL3_wp03 Audit Notes: Version: Phase: PLAN Tie On Depth: 6,897.50 Vertical Section: Depth From (TVD) +N/ -S +E/ -W Direction (usft) (usft) (usft) (1) -61.20 0.00 0.00 45.00 11/6/2016 12:12:25AM Page 2 COMPASS 5000.1 Build 74 ConocoPhillips rel.. ConocoPhillips Planning Report BAKER HUGHES Database: EDM Alaska NSK Sandbox Company: ConocoPhillips (Alaska) Inc. -Kupl Project: Kuparuk River Unit Site: Kuparuk 1B Pad Well: 1B-18 Wellbore: 1 B-1 SAL3 Design: 1 B-18AL3_wp03 Plan Sections Measured Depth (usft) 6,897.50 7,392.00 7,417.00 7,487.00 7,562.00 7,632.00 7,707.98 7,795.00 7,835.00 7,915.00 8,035.00 8,235.00 8,410.00 8,690.00 8,805.00 8,925.00 9,105.00 9,355.00 9,455.00 9,555.00 9,660.00 10, 010.00 10,210.00 10,310.00 10, 505.00 10, 590.00 10, 690.00 10, 790.00 10, 960.00 11,400.00 Inclination Azimuth 43.20 180.80 39.69 191.22 43.19 191.22 62.57 187.46 64.52 164.07 71.00 130.67 101.00 114.03 92.31 75.54 91.75 72.39 90.92 69.30 93.32 65.13 91.63 57.31 89.46 50.65 83.07 59.87 83.09 55.24 86.50 58.64 94.61 68.29 94.39 50.74 97.86 44.62 101.83 50.47 100.46 43.11 93.42 66.77 89.74 53.26 89.74 60.26 89.75 46.61 89.75 52.56 89.75 45.56 89.75 52.56 87.50 64.25 80.22 34.12 Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Well 1 B-18 Mean Sea Level 1 B-18 @ 102.00usft True Minimum Curvature TVD Below Dogleg Build Turn System +N/ -S +E/ -W Rate Rate Rate TFO (usft) (usft) (usft) (°/100ft) (°/100ft) (°1100ft) V) 6,125.45 -2,108.07 -221.61 0.00 0.00 0.00 0.00 6,496.51 -2,432.69 -254.75 1.56 -0.71 2.11 120.82 6,515.25 -2,448.91 -257.97 14.00 14.00 0.00 0.00 6,557.30 -2,503.75 -266.75 28.00 27.68 -5.38 350.00 6,591.09 -2,570.04 -261.72 28.00 2.61 -31.18 270.00 6,618.23 -2,623.34 -227.07 45.00 9.25 -47.72 275.00 6,623.51 -2,663.12 -163.87 45.00 39.49 -21.89 330.00 6,613.04 -2,669.93 -79.45 45.00 -9.99 -44.23 260.00 6,611.63 -2,658.89 -41.04 8.00 -1.40 -7.88 260.00 6,609.76 -2,632.65 34.50 4.00 -1.04 -3.86 255.00 6,605.32 -2,586.22 145.03 4.00 2.00 -3.47 300.00 6,596.68 -2,490.10 320.02 4.00 -0.84 -3.91 258.00 6,595.02 -2,387.25 461.46 4.00 -1.24 -3.80 252.00 6,613.30 -2,228.23 690.65 4.00 -2.28 3.29 125.00 6,627.16 -2,167.00 786.97 4.00 0.02 -4.03 270.00 6,638.05 -2,101.84 887,11 4.00 2.84 2.83 45.00 6,636.32 -2,021.58 1,047.81 7.00 4.51 5.36 50.00 6,616.55 -1,895.63 1,261.73 7.00 -0.09 -7.02 270.00 6,605.87 -1,828.74 1,335.21 7.00 3.47 -6.12 300.00 6,588.76 -1,762.26 1,407.84 7.00 3.97 5.85 55.00 6,568.44 -1,691.78 1,482.86 7.00 -1.30 -7.01 260.00 6,525.57 -1,494.24 1,765.32 7.00 -2.01 6.76 105.00 6,520.03 -1,394.55 1,938.05 7.00 -1.84 -6.76 255.00 6,520.49 -1,339.77 2,021.63 7.00 0.00 7.00 90.00 6,521.37 -1,223.87 2,177.88 7.00 0.00 -7.00 270.00 6,521.75 -1,168.79 2,242.56 7.00 0.00 7.00 90.00 6,522.19 -1,103.30 2,318.05 7.00 0.00 -7.00 270.00 6,522.63 -1,037.81 2,393.54 7.00 0.00 7.00 90.00 6,526.72 -948.92 2,538.03 7.00 -1.32 6.88 101.00 6,574.84 -667.13 2,865.54 7.00 -1.65 -6.85 255.00 Target 11/6/2016 12: 12 25A Page 3 COMPASS 5000.1 Build 74 ConocoPhillips ConocoPhillips (Alaska) Inc. -Kup1 Kuparuk River Unit Kuparuk 1 B Pad 1B-18 1 B-18AL3 1 B-18AL3_wp03 Travelling Cylinder Report 06 November, 2016 WAI a I BAKER HUGHES `- ConocoPhillips MAP FAI ConocoPhillips Travelling Cylinder Report BAKER HUGHES Company: ConocoPhillips (Alaska) Inc. -Kupl Project: Kuparuk River Unit Reference Site: Kuparuk 1B Pad Site Error: 0.00 usft Reference Well: 1 B-18 Well Error: 0.00 usft Reference Wellbore 1 B-18AL3 Reference Design: 1 B-18AL3_wp03 Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Output errors are at Database: Offset TVD Reference: Well 1 B-18 1 B-18 @ 102.O0usft 113-18 @ 102.00usft True Minimum Curvature 1.00 sigma EDM Alaska ANC Prod Offset Datum Reference 1 B-18AL3_wp03 Filter type: GLOBAL FILTER APPLIED: All wellpaths within 200'+ 100/1000 of reference Interpolation Method: MD Interval 25.00usft Error Model: ISCWSA Depth Range: 6,897.50 to 11,400.00usft Scan Method: Tray. Cylinder North Results Limited by: Maximum center -center distance of 1,335.92 usft Error Surface: Elliptical Conic Survey Tool Program Date 11/6/2016 From To (usft) (usft) Survey (Wellbore) Tool Name Description 469.67 6,897.50 1 B-18 (1 B-18) MWD MWD - Standard 6,897.50 11,400.00 1 B-18AL3_wp03 (1 B-18AL3) MWD MWD - Standard Casing Points Measured Vertical Casing Hole Depth Depth Diameter Diameter (usft) (usft) Name 4,256.00 4,147.97 7.625" 7-5/8 8-1/2 11,400.00 6,676.84 2 3/8" 2-3/8 3 Summary Site Name Offset Well - Wellbore - Design Kuparuk 1 B Pad 1 B-04 - 1 B-04 - 1 B-04 1 B-06 - 1 B-06 - 1 B-06 1 B-07 - 1 B-07 - 1 B-07 1 B-08 - 1 B-08 - 1 B-08 1 B-08 - 1 B -08A - 1 B -08A 1 B-08 - 1 B-08ALl - 1 B-08ALl 1 B-08 - 1 B-08ALl-01 - 1 B-08ALl-01 1 B-08 - 1 B-08AL1-01 - 1 B-08ALl-01 wp07 1 B-08 - 1 B-08AL1 P131 - 1 B-08AL1 PB1 1 B-101 - 1 B-101 - 1 B-101 1 B-101 - 1 B-101 1-1 - 1 B-101 1-1 1 B-101 - 1 B-101 PB1 - 1 B-101 PB1 1 B-102 - 1 B-102 - 1 B-102 1B -12 -1B -12-1B-12 1 B-12 - Plan: 1 B-1 2A - 1 B-1 2A (wp01) 1 B-15 - 1 B-15 - 1 B-15 1 B-15 - 1 B-1 5A - 1 B-1 5A 1 B-15 - 1 B-15AL1 - 1 B-15AL1 1 B-15 - 1 B-15AL2 - 1 B-15AL2 1 B-15 - 1 B-15AL2PB1 - 1 B-15A1_2PB1 1 B-15 - 1 B-15AL2PB2 - 1 B-15AL2PB2 18-15 - 1 B-15AL3 - 1 B-15AL3 1 B-15 - 1 B-15AL3PB1 - 1 B-15AL3PB1 1 B-17 - 1 B-17 - 1 B-17 18-17 - 1 B-1711 - 1 B-171-1 1 B-17 - 1 B-1712 - 1 B-171_2 1 B-17 - 1 B-171-2-01 - 1 B-171-2-01 1 B-17 - 1 B-1712-01 PB1 - 1 B-171-2-01 PBI Reference Offset Centre to Measured Measured Centre Depth Depth Distance (usft) (usft) (usft) 11,400.00 7,125.00 1,307.09 7,636.49 10, 992.00 1,085.45 6,911.27 10, 500.00 1,151.20 9,362.65 7,325.00 220.73 9,854.42 7,675.00 145.01 9,888.88 7,675.00 233.41 11,028.40 9,000.00 221.54 10,913.88 8,825.00 215.76 No -Go Allowable Distance Deviation Warning (usft) from Plan (usft) CC - Min centre to center distance or covergent point, SF - min separation factor, ES - min ellipse separation 111612016 12:11:37AM Page 2 COMPASS 5000.1 Build 74 Out of range Out of range Out of range 198.69 1,153.54 Pass - Major Risk Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range 193.60 912.96 Pass - Major Risk Out of range Out of range 210.61 943.00 Pass - Major Risk Out of range 9.66 220.31 Pass - Minor 1/10 4.30 143.61 Pass - Minor 1/10 4.65 232.92 Pass - Minor 1/10 5.38 221.10 Pass - Minor 1/10 5.54 215.54 Pass - Minor 1/10 CC - Min centre to center distance or covergent point, SF - min separation factor, ES - min ellipse separation 111612016 12:11:37AM Page 2 COMPASS 5000.1 Build 74 y - ConocoPhillips WAPA.. ConocoPhillips Travelling Cylinder Report BAKER HUGHES Company: ConocoPhillips (Alaska) Inc. -Kupl Project: Kuparuk River Unit Reference Site: Kuparuk 1 B Pad Site Error: 0.00 usft Reference Well: 1 B-18 Well Error: 0.00 usft Reference Wellbore 1 B-18AL3 Reference Design: 1 B-18AL3_wp03 Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Output errors are at Database: Offset TVD Reference: Well 1 B-18 1 B-18 @ 102.00usft 1 B-18 @ 102.00usft True Minimum Curvature 1.00 sigma EDM Alaska ANC Prod Offset Datum Summary Kuparuk 1 B Pad - 1 B-08 - 1 B-08 - 1 B-08 Reference Offset Centre to No -Go Allowable Measured Measured Centre Distance Deviation Warning Site Name Depth Depth Distance (usft) from Plan Offset Well - Wellbore - Design (usft) (usft) (usft) Vertical (usft) Offset Kuparuk 1B Pad Offset Wellbore Centre Casing - Centre to No Go Allowable Warning 1 B-18 - 1 B-18 - 1 B-18 7,150.00 7,150.00 0.34 3.00 -2.50 FAIL - Minor 1/10 1B -18 -1B -18A -1B -18A 7,125.00 7,125.00 0.00 1.34 -1.32 FAIL - Minor 1/10 1 B-18 - 1 B-18AL1 - 1 B-18AL1_wp03 7,125.00 7,125.00 0.00 1.34 -1.32 FAIL- Minor 1/10 1 B-18 - 1 B-18AL2 - 1 B-18AL2_wp02 7,125.00 7,125.00 0.00 1.34 -1.32 FAIL - Minor 1/10 1 B-19 - 1 B-19 - 1 B-19 72.04 -997.63 3,631.16 2-11/16 1,333.21 Out of range 1 B-19 - 1 B-1911 - i B-191-1 11,400.00 6,676.64 7,075.00 5,650.36 4425 48.50 Out of range 1 B-19 - 1 B-191-1-01 - 1 B-1911-01 3,642.55 2-11/16 1,324.18 198.42 1,173.44 Pass -Major Risk Out of range 18-19 - 1 B-1911-02 - 1 B-191-1-02 5,672.14 44.25 48.64 74.00 -1.007.15 Out of range WSW -02 - WSW -02 - WSW -02 1,315.47 198.56 1,163.34 Pass -Major Risk 11,400.00 6,676.84 7,125.00 Out of range WSW -03 - WSW -03 - WSW -03 48.77 74.99 -1,011.91 3,665.07 2-11/16 Out of range WSW -04 - WSW -04 - WSW -04 1,153.54 Pass - Major Risk, CC, ES, SF Out of range Offset Design Kuparuk 1 B Pad - 1 B-08 - 1 B-08 - 1 B-08 Offset Site Error: 0 00 usft Survey Program: 100 -BOSS -GYRO Rule Assigned: Major Risk Offset Well Error: 0.00 usft Reference Offset Semi Major Axis Measured Vertical Measured Vertical Reference Offset Toolface+ Offset Wellbore Centre Casing - Centre to No Go Allowable Warning Depth Depth Depth Depth Azimuth +N/S +E/ -W Hole Size Centre Distance Deviation (usft) (usft) (usft) (usft) (usft) (usft) (1 lush) (usft) C) (usft) (usft) (usft) 11,400.00 6,676.84 7,050.00 5,628.62 44.25 48.36 72.04 -997.63 3,631.16 2-11/16 1,333.21 198.28 1,183.85 Pass - Major Risk 11,400.00 6,676.64 7,075.00 5,650.36 4425 48.50 73.01 -1,002.39 3,642.55 2-11/16 1,324.18 198.42 1,173.44 Pass -Major Risk 11,400.00 6,676.84 7,100.00 5,672.14 44.25 48.64 74.00 -1.007.15 3,653.86 2-11/16 1,315.47 198.56 1,163.34 Pass -Major Risk 11,400.00 6,676.84 7,125.00 5,693.97 44.25 48.77 74.99 -1,011.91 3,665.07 2-11/16 1,307.09 198.69 1,153.54 Pass - Major Risk, CC, ES, SF CC - Min centre to center distance or covergent point, SF - min separation factor, ES - min ellipse separation 111612016 12:11:37AM Page 3 COMPASS 5000.1 Build 74 ConocoPhillips Project: Kuparuk River Unit Aximutnato True North Magnetic North: 18.01' WELLBORE DETAILS: 1 B-18AL3 REFERENCE INFORMATION Site: Kuparuk 1B Pad 1B-18 Magnetic Field Parent Wellbore: 1B-18 Coerdinate(NIE) Reference: Well 113-i6,True North Well: IB-18 Easting strength: 57550.7enT Tie on MD: 6897.50 Verbal (TVD) Reference. Mean Sea Level Wellbore: 1 B-18AL3 5969647.06 550148.90 Dip Angle: 80.96 N 149° 35'35.868 W Section (VS) Reference: Sled -(O.00N, O.00E) Plan: 1B-18AL3 wp03 (16-18/1 B-18AL3) Azi Date: 10112016 Model: BGGM2016 +E/ -W Measured Depth Refere: iB-18 102.00ueft nce TFace VSect Annotation 1 6897.50 43.20 Calculation Method Minimum Curvature Mean S 25C a -25C -50C -75C G toot Id M@o}251 0 N -I SOC ,175C 0-2000 .`-',-2250 Vn 2500 -2750 -3000 -3250 ONNPRO BAKER HUGHES WELL DETAILS: 1B-18 11400 +N/ -S +E/ -W Northing Easting Latitude Longitude 0.00 0.00 5969647.06 550148.90 70e 19'40.248 N 149° 35'35.868 W Sec MD Inc Azi TVDSS +N/ -S +E/ -W Dleg TFace VSect Annotation 1 6897.50 43.20 180.80 6125.45 -2108.07 -221.61 0.00 0.00 -1647.33 TIP 2 7392.00 39.69 191.22 6496.51 -2432.69 -254.75 1.56 120.82 -1900.30 KOP 3 7417.00 43.19 191.22 6515.25 -2448.91 -257.97 14.00 0.00 -1914.05 End 14 d1s, Start 28 dls 4 7487.00 62.57 187.46 6557.30 -2503.75 -266.75 28.00 350.00 -1959.03 4 5 7562.00 64.52 164.07 6591.09 -2570.04 -261.72 28.00 270.00 -2002.36 End 28 dls, Start 45 dls 6 7632.00 71.00 130.67 6618.23 -2623.34 -227.07 45.00 275.00 -2015.54 6 7 7707.98 101.00 114.03 6623.51 -2663.12 -163.87 45.00 330.00 -1998.99 7 8 7795.00 92.31 75.54 6613.04 -2669.93 -79.45 45.00 260.00 -1944.11 End 45 d1s, Start Low Be 9 7835.00 91.75 72.39 6611.63 -2658.89 -41.04 8.00 260.00 -1909.14 9 10 7915.00 90.92 69.30 6609.76 -2632.65 34.50 4.00 255.00 -1837.17 10 11 8035.00 93.32 65.13 6605.32 -2586.22 145.03 4.00 300.00 -1726.18 11 12 8235.00 91.63 57.31 6596.68 -2490.10 320.02 4.00 258.00 -1534.48 12 13 8410.00 89.46 50.65 6595.02 -2387.25 461.46 4.00 252.00 -1361.74 13 14 8690.00 83.07 59.87 6613.30 -2228.23 690.65 4.00 125.00 -1087.23 14 15 8805.00 83.09 55.24 6627.16 -2167,00 786.97 4.00 270.00 -975.83 15 16 8925.00 86.50 58.64 6638.05 -2101.84 887.11 4.00 45.00 -858.95 16 17 9105.00 94.61 68.29 6636.32 -2021.58 1047.81 7.00 50.00 -688.56 17 18 9355.00 94.39 50.74 6616.55 -1895.63 1261.73 7.00 270.00 -448.24 18 19 9455.00 97.86 44.62 6605.87 -1828.74 1335.21 7.00 300.00 -348.98 19 20 9555.00 101.83 50.47 6588.76 -1762.26 1407.84 7.00 55.00 -250.62 20 21 9660.00 100.46 43.11 6568.44 -1691.78 1482.86 7.00 260.00 -147.72 21 22 10010.00 93.42 66.77 6525.57 -1494.24 1765.32 7.00 105.00 191.69 22 23 10210.00 89.74 53.26 6520.03 -1394.55 1938.05 7.00 255.00 384.31 23 24 10310.00 89.74 60.26 6520.49 -1339.77 2021.63 7.00 90.00 482.15 24 25 10505.00 89.75 46.61 6521.37 -1223.87 2177.88 7.00 270.00 674.58 25 26 10590.00 89.75 52.56 6521.75 -1168.79 2242.56 7.00 90.00 759.27 26 27 10690.00 89.75 45.56 6522.19 -1103.30 2318.05 7.00 270.00 858.96 27 28 10790.00 89.75 52.56 6522.63 -1037.81 2393.54 7.00 90.00 958.64 28 2910960.00 87.50 64.25 6526.72 -948.92 2538.03 7.00 101.00 1123.67 29 30 11400.00 80.22 34.12 6574.84 -667.13 2865.54 7.00 255.00 1554.51 Planned TD at 11400.00 Mean S 25C a -25C -50C -75C G toot Id M@o}251 0 N -I SOC ,175C 0-2000 .`-',-2250 Vn 2500 -2750 -3000 -3250 ONNPRO BAKER HUGHES - -1- -tw u /5u 5uu 750 1000 1250 1500 1750 2000 2250 2500 2750 3000 3250 3500 3750 Vertical Section at 45.00° (100 usft/in) Planne I To al 11400 - 1B,48/IB- 8AL3 1R-1 1 A u t2 ISA IM - VIR.11 > Pr 1B-1 AL3 13 B-18 `;TII 2 2 `'.1B 18AL `• Q I-1, AL3_, 09 1 -17/1 -17L �IFB 1 -18 3, `TO8•.,'• } IB- 7/113, 7L2 B -]M 3 TO'; 1 -17/1 -17L -Ol I E -18/IB 18AL IB -1 (I11-1 ` B- I SA UTC6\ TIP IB -18 L3 05 1B- 8AL3 T03 B-19 L . 15 LP-T' i14i31B-1 *dlSta ALl ultl IB-IIB-18 LI -En dls nd 28 dK S d,45 s End 4 dls, S n Lo Bend Motor IB -1 A Fa ItI - -1- -tw u /5u 5uu 750 1000 1250 1500 1750 2000 2250 2500 2750 3000 3250 3500 3750 Vertical Section at 45.00° (100 usft/in) ConocoPhillips 360 320 280 240 200 160 120 80 40 -40 -80 O -120 O -160 ,5-200 7 -240 -280 0 V) -320 -360 -400 -440 -4801 -5201 -5601 -6001 -6401 -6801 -p Project: Kuparuk River Unit Site: Kuparuk 1B Pad AzlrrumstoTrue North Marantic North: 18.01' Magnetic Field WELLBORE DETAILS: IB-18AL3 REFERENCE INFORMATION Parent Wellbore: IB -18A Coordinate (N/E) Reference: Well 1B-18, True North Well: 1 B-18 strength: 57560.7enT Tie on MD: 8680,00 Vertical (ND) Reference: 1B-18 @ 102.00usft Wellbore: 1B-18AL3 Dip Angle: 80.96• l,t Section (VS) Reference: Slot -(O.00N, O.00E) Plan: 1 B-18AL3_wp01 (1 B-1811 B.18AL3) Data: 10/12016 Madel: BGGM2016 IB-tp/1 Measured Depth Reference: 1 B-18 102.00usft P @ IE will •I'J Calculation Method: Minimum Curvature .el.■ BAKER HUGHES _ --- ---- ,--- ,.--- ---- ---- ---- ---- -r--- YY-- -- �tuu "n" o u ngvv 0 6UU /LUU /buo 8000 M400 West( -)/East(+) (400 usft/in) a 19-14/ L#-14 l,t -U'1/IB-1V IB-tp/1 1-10 IE will •I'J IB -1 �l tll;-If ,. _,,_ 0l0 1R=t IIIIB-11111 668 • .\;, .. 6p c1wI1.17iBI3 LI102/11' I0V[3l Iii#- 01/113-101 ': 65 IC 78,/1 C.17(iC I C.74 l IC . )'�4a 9 I It(2!I .:III�I.I IL' -O8 IC -681 I.rl IC -179/112 178 V IA -16/[A-20 , '7711.. / IC u811 Ct[SLI 5� y IC- 74'I'1en 1' 74, LI flu; Ol '. i _ eP 40TI) 36 i"; .a 'I llA. ;Un 3 57'', —Ic "ITT / C--fl- .6 WS 9 S. La '&W -06 "5W- H t,'Il Ot 19-121ID '.I C. 11 tic -I.. 1 \ a rICWSW I/WSW-03 5W-07 to 4/IA-I 1/ 01/IA l -A o ..3A15 y, IE -102/ 0 102P 32`r 1"781 1PIDLI07 I -127/1 -08 8 .081 •61 SW SW I : 'if IB-ObA 1-0I SW+O SW -0 ' II 121/I 121 1E 121 1L ' .1 -S1$/1 IMAL Qtr V1-13;16- X1.2 1 -121/) .,'121 1iTq 1 709 s, I IB.18d13 IR)\L IL t21/IG-121! 1 IB IH- 4 0IU 121/IP.-1217 I 37y6 4A I I h� WSW-0/WS 10- J'�'2^'S6 s4 -1)6/18 )AAI Dl� :IC-Ill/IC-17 77 ., 113-) B I,^L2 IP131 .OA I1, k291,1 :12311 I, `. lir. 'y ' 1H 0R'I i 1 18 IR/113-I AL n d'' ' , F41i� BW -lb SW- '.. - - I R-15/11 1SAL I - `t0 0 60 ��1 0 e _ - 11 1711-1' _ -16:17 1.1711 Ir -77>/I C -0U1 172Al. 04A PRIAT 3. I lit 47� I 94 13 -IR :. r :.. IU -ISA .' "'---� .1114/3 ':104PB Ill 3 !IB -ISA � 800 A EB -18/ 13-18A{ I 1 21/IC 121 Ire), IB 8/IB:-1 0� 1R-1 !{B,IS I iI'L30 1H I+/ $-15A7 21'6; \ )0 IBI /111-1 S 1,21'8.1 & - - 411A4 I— L<^ ''.I kill IlR 01 113-u4/1 .0.1 r I -03 C 03 _ "3 IC- 0271 . 1 J^_PBL. I 02/1'; _302 DRi 1'_I 2L IPl3 102/10 I(12L1 1 {3.0('1Ii-UN fi47G! IB-i,7/I 07 IL,a7IF-074 ^01 I[ 17 /IC.I$ AL, 1 78. i 113-0R/ E -0i -01 n f7n1, �ncz r -Enna -1 _TC 1-7 /IC -n - sg -Tit! 13-141,1 r .I+ i`J 767 11;•1 8/IT,.I6 .A A 1( -1()4/I .tpr 1.. -lis I //IB-lY G cw r fi I1 IP 108(1 1118 `- 38 ID 12/ 23211 - 1Ii-t9/IB-79L 01 11-09111,08.4'.. I U I?8/ C -()R -. -- 11 to if 9�1P]sl - I : I8/1 0 ALI.19 q u,=114, q w z - _ dr .0 IE -.11 /Iti-I 4.I J-1721 It 1:4nf I IF -1 /IG II 01 IF --10/7 •10 IP1-0 iL 08 6¢07 IF I(A/W 104 - . d/ID-1 b 6'S .% all 67/1F-7 '4 iT [I 1�-I 11tie�D• 12/II.-127. BI 600 IF O8l1fA ryU;T-O IL' ©moo ,l k: 1 .08/Ih (38flL.1 8/IE-I' �0 tF I6 Il -1,9/ 6 IF 681 Pk31 r GI 1/2-121-2 1PR1 IE.,18/I1181.2 ID -113111.113 to IE 1511E-1 A 358 q"+ '5000All t 61 a II 1211 _ 121 2 - 1F 011/11'-0`/ ?-1'J -19 -Fnnn _—A _conn nnnn nnnn nnnn Dann _ --- ---- ,--- ,.--- ---- ---- ---- ---- -r--- YY-- -- �tuu "n" o u ngvv 0 6UU /LUU /buo 8000 M400 West( -)/East(+) (400 usft/in) a Schwartz, Guy L (DOA) From: Connelly, Jeff <Jeff.S.Connelly@conocophillips.com> Sent: Sunday, November 06,2016 10:48 AM To: Schwartz, Guy L (DOA) Cc: Loepp, Victoria T (DOA); Bettis, Patricia K (DOA); Nabors CDR2 Company Man; Starck, Kai; Eller, J Gary; Ohlinger, James J; Burke, Jason; Phillips, Ron L; Callahan, Mike S; Herring, Keith E; Long, William R; Bettis, Patricia K (DOA); Soper, Michael K (Baker HughesINTEQ) Subject: RE: Request to mill window Guy, Thank you again for your consideration in this matter. Regards, Jeff From: Schwartz, Guy L (DOA) [mailto:guy.schwartz@alaska.gov] Sent: Sunday, November 06, 2016 10:46 AM To: Connelly, Jeff <Jeff.S.Connelly@conocophillips.com> Cc: Loepp, Victoria T (DOA) <victoria.loepp@alaska.gov>; Bettis, Patricia K (DOA) <patricia.bettis@alaska.gov>; Nabors CDR2 Company Man <NaborsCDR2CompanyMan@conocophillips.com>; Starck, Kai <Kai.Starck@conocophillips.com>; Eller, J Gary <J.Gary.Eller@conocophillips.com>; Ohlinger, James J <James.J.Ohlinger@conocophillips.com>; Burke, Jason <Jason.Burke @conocophillips.com>; Phillips, Ron L <Ron.L.Phillips@conocophillips.com>; Callahan, Mike S <Mike.Callahan@conocophillips.com>; Herring, Keith E <Keith. E. Herring@conocophillips.com>; Long, William R <William.R.Long@conocophillips.com>; Bettis, Patricia K (DOA) <patricia.bettis@alaska.gov>; Soper, Michael K (Baker Hughes INTEQ) <Michael.K.Soper@contractor.conocophillips.com> Subject: [EXTERNAL]RE: Request to mill window Jeff, I have reviewed the new updated well plan for 1B-18AL3 with the kickoff point at 7392' (milled window). You have verbal approval to proceed with drilling the lateral as proposed in your directional plan. A formal PTD application for 1B- 18AL3 must be submitted on Monday as we discussed. Regards, Guy Schwartz Sr. Petroleum Engineer AOGCC 907-301-4533 cell 907-793-1226 office CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Guy Schwartz at (907-793-1226 ) or (Guy.schwartz@alaska.gov). From: Connelly, Jeff [mailto:Jeff.S.Connelly@conocophillips.com] Sent: Sunday, November 06, 201610:21 AM To: Schwartz, Guy L (DOA) <guy.schwartz@alaska.gov> Cc: Loepp, Victoria T (DOA) <victoria.loepp@alaska.gov>; Bettis, Patricia K (DOA) <patricia.bettis@alaska.gov>; Nabors CDR2 Company Man <NaborsCDR2CompanyMan@conocophillips.com>; Starck, Kai <Kai.Starck@conocophillips.com>; Eller, J Gary <J.Gary.Eller@conocophillips.com>; Ohlinger, James J <James.J.Ohlinger@conocophillips.com>; Burke, Jason <Jason.Burke@conocophillips.com>; Phillips, Ron L <Ron.L.Phil lips@conocophillips.com>; Callahan, Mike S <Mike.Callahan@conocophillips.com>; Herring, Keith E <Keith.E.Herring@conocophillips.com>; Long, William R <William.R.Long@conocophillips.com>; Soper, Michael K (Baker Hughes INTEQ) <Michael.K.Soper@contractor.conocophiIli ps.com> Subject: RE: Request to mill window Guy, As per our conversation moments ago, I am resending the email from last night. If you have any issues give me a call. Attached, please find the requested revised documents for the 113-18AL3 lateral. As discussed in our phone conversation Saturday morning, liner became stuck inside our 5" casing which required that the kick-off point be moved up. We are currently milling the window of this lateral. Please let me know if you require anything further. Regards, Jeff Connelly From: Schwartz, Guy L (DOA) [ma ilto:guy.schwa rtz@alaska.gov] Sent: Saturday, November 05, 20161:54 PM To: Connelly, Jeff <Jeff.S.Connelly@conocophillips.com> Cc: Loepp, Victoria T (DOA) <victoria.loepp@alaska.gov>; Bettis, Patricia K (DOA) <patricia.bettis@alaska.gov>; Nabors CDR2 Company Man <NaborsCDR2CompanyMan@conocophillips.com>; Starck, Kai <Kai.Starck@conocophillips.com>; Eller, J Gary <J.Gary.Eller@conocophillips.com>; Ohlinger, James J <James.J.Ohlinger@conocophillips.com>; Burke, Jason <Jason.Burke@conocophillips.com>; Phillips, Ron L <Ron.L.Phil lips@conocophillips.com>; Callahan, Mike S <Mike.Callahan@conocophillips.com>; Herring, Keith E <Keith.E.Herring@conocophillips.com>; Long, William R <William.R.Long@conocophillips.com>; Soper, Michael K (Baker Hughes INTEQ) <Michael.K.Soper@contractor.conocophilIips.com> Subject: [EXTERNAL]Re: Request to mill window Jeff , You have approval to mill window as proposed below. Additional approval to proceed with drilling the lateral will be needed after AOGCC reviews the directional plan. Regards, Guy Schwartz AOGCC 907-301-4533 Sent from my iPhone On Nov 5, 2016, at 1:26 PM, Connelly, Jeff <Jeff.S.Connelly@conocophillips.com> wrote: Guy, Guy, et all- ConocoPhillips requests written authorization via email from the Commission to proceed with drilling operations without interruption as per 20 AAC 25.015(b)(2). As per our conversation over the phone, ConocoPhillips requests written approval to mill a window at 7392' MD. Once a directional plan has been created I will provide you with the same documentation requested yesterday to modify our planned KO point of the "AL3" lateral. Regards, Jeff Connelly Associate CTD Engineer 907-263-4112 (Office) 1907-328-8854 (Mobile) 700 G Street, ATO 662 Jeff.S.Connelly@conocophillips.com <image001.jpg> ConocoPhillips Project: Kuparuk River Unit Site: Kuparuk 18 Pad .h rk wm : ie th Meprc9c Field WELLBORE DETAILS: 1 B-18AL3 REFERENCE INFORMATION Parent Wellbore: IB -18 Coadinste (N/E) Reference: Web 113-18, True North Well: IB -18 Strenpth: 5755D.7enTie on MD: 6897 Vertical (TVD) Reference: Meeh Sea level Wellbore: 1B-18AL3 Dip AVla: 80.96' .50 Sectlon(VS) Reference. Slot-(O.00N, 0.00E) Plan: 1 B-1eAL3_wp03 (113-18H B-18AL3) M.D�w: 1011=16 del: BGGM2CCdculation 0.00 Meaeu atl Dep h Reference: 1&18 102.00uefl Method. Minimum Curvahae 6100- a WELL DETAILS: Q 1B-18 +N/ -S +E/ -W Northing Easting Latitude Longitude 0.00 0.00 5969647.06 550148.90 70e 19'40.248 N 149' 35'35.868 W Sec MD Inc Azi TVDSS +N/ -S +E/ -W Dleg TFace VSect y Annotation 1 6897.50 43.20 180.80 6125.45 -2108.07 -221.61 0.00 0.00 -1647.33 TIP 2 7392.00 39.69 191.22 6496.51 -2432.69 -254.75 1.56 120.82 -1900.30 KOP 3 7417,00 43.19 191.22 6515.25 -2448.91 -257.97 14.00 0.00 -1914.05 End 14 dis, Start 28 dis 4 7487.00 62.57 187.46 6557.30 -2503.75 -266.75 28.00 350.00 -1959.03 B.!8/]B-1 4 5 7562,00 64.52 164.07 6591.09 -2570.04 -261.72 28.00 270.00 -2002.36 End 28 d1s, Start 45 dis 6 7632.00 71.00 130.67 6618.23 -2623.34 -227.07 45.00 275.00 -2015.54 I 6 7 7707.98 101.00 114.03 6623.51 -2663.12 -163.87 45.00 330.00 -1998.99 7 8 7795.00 92.31 75.54 6613.04 -2669.93 -79.45 45.00 260.00-1944.11 End 45 d1s, Start Low Bel 9 7835.00 91.75 72.39 6611.63 -2658.89 -41.04 8.00 260.00 -1909.14 9 10 7915.00 90.92 69.30 6609.76 -2632.65 34.50 4.00 255.00 -1837.17 10 11 8035,00 93.32 65,13 6605.32 -2586.22 145.03 4.00 300.00 -1726.18 11 12 8235.00 91.63 57.31 6596.68 -2490.10 320.02 4.00 258.00 -1534.48 12 13 8410.00 89.46 50.65 6595.02 -2387.25 461.46 4.00 252.00 -1361.74 13 14 8690.00 83.07 59.87 6613.30 -2228.23 690.65 4.00 125.00 -1087.23 14 15 8805.00 83.09 55.24 6627.16 -2167.00 786.97 4.00 270.00 -975.83 15 16 8925.00 86.50 58.64 6638.05 -2101.84 887.11 4.00 45.00 -858.95 16 17 9105.00 94.61 68.29 6636.32 -2021.58 1047.81 7.00 50.00 -688.56 17 18 9355.00 94.39 50.74 6616.55 -1895.63 1261.73 7.00 270,00 -448.24 18 19 9455.00 97.86 44,62 6605.87 -1828.74 1335.21 7.00 300.00 -348.98 19 20 9555.00 101.83 50.47 6588.76 -1762.26 1407.84 7.00 55.00 -250.62 20 21 9660.00 100.46 43.11 6568.44 -1691.78 1482.86 7.00 260.00 -147.72 21 22 10010.00 93.42 66.77 6525.57 -1494.24 1765.32 7.00 105.00 191,69 22 23 10210.00 89.74 53.26 6520.03 -1394.55 1938.05 7.00 255.00 384.31 23 24 10310.00 89.74 60.26 6520.49 -1339.77 2021.63 7.00 90.00 482.15 24 25 10505.00 89.75 46.61 6521.37 -1223.87 2177.88 7.00 270.00 674.58 25 26 10590.00 89.75 52.56 6521.75 -1168.79 2242.56 7.00 90.00 759.27 26 27 10690.00 89.75 45.56 6522.19 -1103.30 2318.05 7.00 270.00 858.96 27 28 10790.00 89.75 52.56 6522.63 -1037.81 2393.54 7.00 90.00 958.64 28 29 10960.00 87.50 64.25 6526.72 -948.92 2538.03 7.00 101.00 1123.67 29 30 11400.00 80.22 34.12 6574.84 -667,13 2865.54 7.00 255.00 1554.51 Planned TD at 11400.00] 6100- a �� N H Q F I j 6200 -1--- 1-- 8AL2 F 1 I I p 6300 .. - Wi 1• ` O 6400 P OP y 13 d 14 dis, Start'28 dks - - - - Q6500> k! 28 dis, Start 45 dis: � 6600----- --+- ,V.45' 6700 ---6 '9 - -ri- 12 I3-. 7 .10 B.!8/]B-1 AL2',., 1 6800 - Bend M � tOr (-� rid 451Is, Start L - S/113-18 I I I d Kill BAKER HUGHES 1B- est( -)/East(+) (250 usft/in) - HI _ IB -17 113 7L2 t0 -on 1B-17/IB-17L _0IPB 113-17/1S=M1-01 26'.. 27',li 28 29 11, 8A ___ F_ 1B-18AAA _Flt - Mean Sea L -2200 -2100 -2000 -1900 -1800 -1700 -1600 -1500 -1400 -1300 -1200 -1100 -1000 -900 -800 -700 -600 -500 -400 -300 200 100 0 100 200 300 400 500 600 700 800 900 1000 1100 1200 1300 1400 1500 1600 Vertical Section at 45.00° (100 usft/in) 0 9 1 B-18 Proposed CTD Schematic 6" 62# H-40 hoe @ 121' 7-5/8" 29.7# L-80 shoe @ 4147' MD 5.5" 17# L-80 shoe @ 6997' MD C -sand perfs sgz'd) 7131'- 7273' MD KOP @ 7392' MD 3%" x 5" TTWS t at 0' toolface KOP @ 7505' MD 3'/2' x 5" TTWS '130' toolface A -sand perfs sgz'd) C 7256'- 7575' MD C Tapered Prod Csp 5%, 17#, L-80, 0'-7044' MD 5", 18#, L-80, 7044'-7809' MD Camco BP -6 injection nipple @ 1951' MD ID = 2.813" 3-1/2" 9.3# L-80 EUE 8rd Tubing to surface 3-1/2" Camco gas lift mandrels @ 2629', 4223', 5498', 6335'& 6862' X -nipple @ 6895' MD ID = 2.812"ID Baker GBH -22 Loactor & Seal assembly at 6918 Baker 3-1/2" PBR @ 6920' MD (3" ID) Baker KBH-22 anchor seal assembly at 6933' MD Baker FA -1 packer @ 6934' MD 5" casing sealbore extension @ 7044' (4.0" ID) 3-1/2" tubing tail @ 7047' MD 1 B-18AL2 TD @ 9,575' MD (West) TOL @ —7392' MD ---------- 00, ,'; ✓, 1 B-18AL3 TD @ 11400' MD (Northeast) 4 Billet at 8900' MD 1B-18AL1 TD @ 11,300' MD (East) Billet @ 7460' MD 1B -18A TD @ 9500' MD Liner Bottom at 8314' MD Liner Top at 7412' MD TRANSMITTAL LETTER CHECKLIST WELL NAME: I< /A (,_ /3— /� 1AL 3 PTD: Development _ Service _ Exploratory _ Stratigraphic Test _ Non -Conventional FIELD: Ci l't �, 1/i POOL: 4tnk ►Vr �1/E� �; , Check Box for Appropriate Letter / Paragraphs to be Included in Transmittal Letter CHECK OPTIONS TEXT FOR APPROVAL LETTER ULTI The permit is for a new wellbore segment of existing well Permit LATERAL No. J10_& API No. 50 -CQ - )_ () I - O Q (If last two digits Production should continue to be reported as a function of the original in API number are API number stated above. between 60-69) In accordance with 20 AAC 25.005(f), all records, data and logs acquired for the pilot hole must be clearly differentiated in both well Pilot Hole name ( PH) and API number (50- - - -� from records, data and logs acquired for well (name onpermit). The permit is approved subject to full compliance with 20 AAC 25.055. Approval to produce/inject is contingent upon issuance of a conservation Spacing Exception order approving a spacing exception. (Company Name) Operator assumes the liability of any protest to the spacing exception that may occur. All dry ditch sample sets submitted to the AOGCC must be in no greater Dry Ditch Sample than 30' sample intervals from below the permafrost or from where samples are first caught and 10' sample intervals through target zones. Please note the following special condition of this permit: production or production testing of coal bed methane is not allowed for Non -Conventional (name of well) until after (Company Name) has designed and Well implemented a water well testing program to provide baseline data on water quality and quantity. (Company Name) must contact the AOGCC to obtain advance approval of such water well testing program. Regulation 20 AAC 25.071(a) authorizes the AOGCC to specify types of well logs to be run. In addition to the well logging program proposed by (Company Name) in the attached application, the following well logs are also required for this well: Well Logging Requirements Per Statute AS 31.05.030(d)(2)(B) and Regulation 20 AAC 25.071, composite curves for well logs run must be submitted to the AOGCC within 90 days after completion, suspension or abandonment of this well. Revised 2/2015 WELL PERMIT CHECKLIST Field & Pool KUPARUK RIVER, KUPARUK RIV OIL - 490100 NA_ Conductor set_ in 1 B-18 PTD#:2161440 Company CONOCOPHILLIPS ALASKA INC Initial Class/Type -- -_ Well Name: KUPARUK RIV UNIT 1 B-18AL3 _ - Program DEV - Well bore seg DEV/PEND GeoArea Administration 17 . Nonconven. gas conforms to AS31.05.030G.1_.A),tj.2.A-D) - NA 890_ _ _ Unit 11160 __ On/Off Shore On _ Annular Disposal CMT vol_ adequate to tie-in long string to -surf csg_ 1 - - _ Permit_fee attached_ _ --.- NA ----------------- -- - - _ Lateral Will_use slotted -liner. 2 3/8" -OD. - Window at 7392 ft and ---------------- -T, Adequ- an_ age or reserve pit - - - a_re-drill, has -a_ 10-403 for abandonment been approved -------------------- Lease number appropriate_ Yes _________ __ ____________ ___ _______ ADL0025648, entire wellbore. NA_ Yes sundry 316-41.6_ _A _ -- -- -- --- - 16-17 will be shut in during drilling.. Close approach._ niquewell_name and number Yes ------------- KRU 1B-18AL3_ Drilling fluid_ program schematic_$ equip -list _adequat_e_ 4 5 Well _located prop defined pool. - - - - - - - - - - - -- - Well located proper distance from drilling unit boundary_ Yes _ _ - - - _ KUPARUK RIVER, KUPARUK RIV OIL 7490100, governed by Conservation Order No. 432D. _ - - - CDR2 has 5000 psi BOPE 6 Well proper distance_ from other wells- Yes CO 432D contains no spacing p g restrictions with respect to drilling unit boundaries_. Yes 7 - - - - - Sufficient acreage available in drilling unit_ Yes _ CO 432D has no interwell spacing restrictions._ --- 8 ---- - - - - _deviated, -is. wellbore plat_inc_luded _ _ Yes Yes - 9 10 Operator only affected party _ - - - - - - - - - - -------- ---- Operator has -appropriate in force Yes - - - - - - - - - - - - - - - - - - - - Wellbore_will be_ more than 500' from an external property _line_ where_ ownership or landownership changes.- Appr Date 11 -bond -Permit can be issued without conservation order_ - - -Yes Yes -------- - - - - - - - - - - - - - - - - - - - - - PKB 11/8/2016 11 Permit_can be issued without administrative -approval ---- Yes --- ------------ ---------- ------------ _ _ _ - - - - - - - NA_ - - - - 113 -C------ an permit be approved before 15 -day wait_ - - - - _ - _ - Yes ------------- 114 e _ ocat_ed within area and -strata authorized by Injection Order # (put_ 10# in_comments)_(For. NA - wells- within _1/4_mile-area_of review identified (For service well only)_ NA ----------------------- - -------------- -------------------- jJ6 . re -pro u_ced injector. -duration of pre -production Less than 3 months_ (For_servi_ce well only) NA_ ----- ------------------------- ----------------- ---- 18 Engineering 19 21 22 23 24 125 26 27 Appr Date 28 GLS 11/9/2016 129 30 31 32 33 34 35 Geology 36 Appr Date 37 PKB 11/8/2016 38 Geologic Rolnmissioner -Conductor string _provided _ -------------- NA_ Conductor set_ in 1 B-18 ng Surface casiquateprotects all -known n USDWs - _ ------- - NA_ _ Surface casing set and fully cemented in adequate to circulate -on conductor & su_rf_csg------ --- - ----- NA -1_B-18_ CMT vol_ adequate to tie-in long string to -surf csg_ NA --------------- --------------- -- ---------- willcover-all known_ productive horizons_ _ - - - ------------- -- Casing designs adequate for C, B &_permafrost_ ------------------------------------ Yes - -- - - _ Lateral Will_use slotted -liner. 2 3/8" -OD. - Window at 7392 ft and ---------------- -T, Adequ- an_ age or reserve pit - - - a_re-drill, has -a_ 10-403 for abandonment been approved Yes - - - Yes -- ---- ------- - - - - -- ----------- ______________ - _ - - Rig has steel pits,. All waste to -approved disposal - - _ we - ll._ -d equa a -we_ _-------- ore separation _ ---- NA_ Yes sundry 316-41.6_ _A _ -- -- -- --- - 16-17 will be shut in during drilling.. Close approach._ _ _diverter required, does it meet regulations_ - NA_ - _ --------------------------- Wellhead in place.. BOPE will be used. Drilling fluid_ program schematic_$ equip -list _adequat_e_ Yes - _ _ _ Pres Max formation _s =_3005 _si p ( 9.0 ppg_ EMW) will drill with 8,6_ppg and MPD equip, BOPEs,-do they meet regulation _ -- -- - -- --- ---------- - - - Yes - _ - - - CDR2 has 5000 psi BOPE _press rating appropriate; test to_(put psig in comments) _ Yes - -- - -- - -- - - - - - - - - - -- MPSP = 2347 -psi BOPE to 3500 psi hoke_manifold complies w/API_RP-5$ May 84) _ Yes -- --------------------- Work- will occur without operation shutdown_ - _ -- Yes -- ------------------ Js presence o gas_ probable- - _ - Yes - _ - _ _ H2S onig_h _ pad.. Ras sensors and alarms._ Mechanical_condition of wells within AOR verified (For service well only) - - - - - - - -NA --------------------------------------------- _ Permit_can be issued w/o hydrogen_ sulfide measures.. - - - - - - - ata presented on potential overpressure zones No_ --------- -------------------- _ - Wells_o_n_lB-Pad are_H2S-bearin H2S measures required.. 9� --- -- - - -- --- _ - - - - - Seismic analysis_ of shallow gas_zones_ - Yes _ Estimated reservoir pressure is 9.0- P ppg EMW,- will be drilled using 8.6 ppg_mucland MPD technique. _ -Seabed__condition survey -(if off -shore) _ _ _ _ _ _ _ - _ _ _ _ ------- NA_ ---- NA_ ----------------------------------------------- on ac -name/phone for weekly reports_ [exploratory only] - - - - - - - - - - _ _ _ - - - - - - - NA_ - - - - _ ------------------------------------------ - - - Onshore development -lateral -to be drilled. Date: Engineering Public Commissioner: Date (�nmmieci Date Added additional lateral L3 due to drilling faults and geologic uncertainty in first Lateral (1 B-1 8A) Will capture same target as first lateral with L3 lateral. GIs -N-- I ) n