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216-095
DATA SUBMITTAL COMPLIANCE REPORT 2/17/2017 Permit to Drill 2160950 Well Name/No. KUPARUK RIV UNIT 2M-081-1 Operator CONOCOPHILLIPS ALASKA INC API No. 50-103-20184-63-00 MD 15650 TVD 6227 Completion Date 10/7/2016 Completion Status 1 -OIL Current Status 1 -OIL UIC No REQUIRED INFORMATION Mud Log No ✓ Samples No ✓ 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 OHI Type Med/Frmt Number Name Scale Media No Start Stop CH Received Comments ED C 27649 Digital DataElectronicFile: 2 - ED C 27649 Digital Data T12072016 El ED C 27649 Digital Data 10/20/2016 Electronic File: 2M-081-1 EOW - NAD27.pdf ED C 27649 Digital Data 10/20/2016 Electronic File: 2M-081-1 EOW - NAD27.txt Log C 27649 Log Header Scans 0 0 2160950 KUPARUK RIV UNIT 2M-081-1 LOG HEADERS ED C 27735 Digital Data 11/11/2016 Electronic File: 2M-081-1 21VID Final Log.cgm r S ED C 27735 Digital Data 11/11/2016 Electronic File: 2M-081-1 51VID Final Log.cgm ' ED C 27735 Digital Data 11/11/2016 Electronic File: 2M-081-1 5TVDSS Final Log.cgm ED C 27735 Digital Data 1 11/11/2016 Electronic File: 2M-081-1 21VID Final.pdf• ED C 27735 Digital Data 11/11/2016 Electronic File: 21VI-081-1 51VID Final.pdf' ED C 27735 Digital Data vo11/11/2016 Electronic File: 2M-081-1 5TVDSS Final.pdf ED C 27735 Digital Data 11/11/2016 Electronic File: 2M-081-1 EOW - NAD27.pdf• ED C 27735 Digital Data 11/11/2016 Electronic File: 2M-081-1 EOW - NAD27.txt ED C 27735 Digital Data 11/11/2016 Electronic File: 2M-081-1 Survey listing.txt ED C 27735 Digital Data 11/11/2016 Electronic File: 2M-081-1 Surveys.txt ED C 27735 Digital Data 11/11/2016 Electronic File: 2M-08L1_Final_Surveys.csv ED C 27735 Digital Data 11/11/2016 Electronic File: 2M- 08L1_252apescan_BH I_CTK.txt - ED C 27735 Digital Data 11/11/2016 Electronic File: 2M- 08L 1 _5_tapescan_B H I_CTK.txt - ED C 27735 Digital Data 11/11/2016 Electronic File: 2M-081-1_output.tap , AOGCC Page I of2 Friday, February 17, 2017 DATA SUBMITTAL COMPLIANCE REPORT 2/17/2017 Permit to Drill 2160950 Well Name/No. KUPARUK RIV UNIT 2M-081-1 Operator CONOCOPHILLIPS ALASKA INC API No. 50-103-20184-63-00 MD 15650 TVD 6227 Completion Date 10/7/2016 Completion Status 1 -OIL Current Status 1 -OIL UIC No ED C 27735 Digital Data 11/11/2016 Electronic File: 2M-081-1 2MD Final Log.tif ED C 27735 Digital Data 11/11/2016 Electronic File: 2M-081-1 5MD Final Log.tif ED C 27735 Digital Data 11/11/2016 Electronic File: 2M-081-1 5TVDSS Final Log.tif ' Log C 27735 Log Header Scans 0 0 2160950 KUPARUK RIV UNIT 2M-081-1 LOG HEADERS Well Cores/Samples Information: Sample Interval Set Name Start Stop Sent Received Number Comments INFORMATION RECEIVED Completion Report Directional / Inclination Data /^ r Y 1 /� Mud Logs, Image Files, Digital Data Core Chips Y (hVAi Production Test Informatior�Y NA Mechanical Integrity Test Information Y 0 --\ Composite Logs, Image, Data Files Core Photographs Y �J Geologic Markers/Tops Daily Operations Summary Cuttings Samples Y / jVA) Laboratory Analyses Y / N COMPLIANCE HISTORY Completion Date: 10/7/2016 Release Date: 8/10/2016 Description Date Comments Comments: Compliance Reviewed By: Date:( 0 l t AOGCC Page 2 of 2 Friday, February 17, 2017 ECEIVE0 VA liv BAKER NOV 11 2uR0' PRINT DISTRIBUTION LIST HUGHES G(hhp" 11 COMPANY ConocoPhillips Alaska, Inc. WELL NAME 2M -08L1 FIELD Prudhoe Bay Unit COUNTY North Slope Borough BHI DISTRICT Alaska AUTHORIZED BY Patrick Rider EMAIL Patrick.Rider6c bakerhughes.com STATUS Final Replacement: COMPANY ADDRESS (FEDEX WILL NOT DELIVER TO P.O. BO$ PERSON ATTENTION 21 6095 27 73 5 Please sign and return one copy of this transmittal form to: ConocoPhillips Alaska, Inc. Tom Osterkamp DATA LOGGED 700 G Street. 1k /2l/201(° M.K.BENDEP Anchorage, Alaska 99510 to acknowledge receipt of this data. LOG TYPE GR - RES LOG DATE October 6, 2016 TODAYS DATE November 7, 2016 Revision No Details: Requested by: FIELD FINAL CD CD LOGS LOGS(digital/image) Surveys (Final Surveys) # OF PRINTS 4 OF PRIN I S # OF COPIES # OF COPIES # OF COPIE 4 4 4 JJ 1 BP North Slope C 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 ExxonMobil, Alaska 0 0 0 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: Sean Clifton 550 West 7th Avenue, Suite 802 Anchorage, Alaska 99501 *** Stamp "confidential' on all material deliver to DNR 6 BP Exploration (Alaska) Inc. 1 1 1 Petrotechnical Data Center, 1,112-1 900 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 ConocoPhillips qECEIVED 1 LUij a,OGCC ConocoPhillips (Alaska) Inc. -Kup2 Kuparuk River Unit Kuparuk 2M Pad 2M -08L1 50-103-20184-63 Baker Hughes INTEQ Definitive Survey Report 14 October, 2016 BAKER HUGHES W' ConocoPhillips ConocoPhillips FGas BAKER Definitive Survey Report HUGHES Company: ConocoPhillips (Alaska) Inc. -Kup2 Local Coordinate Reference: Well 2M-08 Project: Kuparuk River Unit TVD Reference: 2M-08 @ 147.00usft (P245) Site: Kuparuk 2M Pad MD Reference: 2M-08 @ 147.00usft (P245) Well: 2M-08 North Reference: True Wellbore: 2M-081-1 Survey Calculation Method: Minimum Curvature Design: 2M-081-1 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 2M-08 Well Position +N/ -S 0.00 usft Northing: 5,948,985.84 usft Latitude: 70° 16' 18.579 N +E/ -W 0.00 usft Easting: 487,949.23usft Longitude: 150° 5'50.870 W Position Uncertainty 0.00 usft Wellhead Elevation: usft Ground Level: 105.50 usft Wellbore 2M-081-1 Magnetics Model Name Sample Date Declination Dip Angle Field Strength (I V) (nT) BGG M2016 10/1/2016 17.84 80.88 57,537 Design 2M-081-1 Audit Notes: Version: 1.0 Phase: ACTUAL Tie On Depth: 11,740.69 Vertical Section: Depth From (TVD) +N/ -S +E/ -W Direction (usft) (usft) (usft) (I 41.50 0.00 0.00 180.00 Survey Program Date 10/12/2016 Survey Survey From (usft) To (usft) Survey (Wellbore) Tool Name Description Start Date End Date 151.90 11,740.89 2M-08 Srvy 1 -GCT-MS (2M-08) GCT -MS Schlumberger GCT multishot 11/16/1992 11/16/1992 11,745.00 15,616.13 2M-081-1 (2M-081-1) MWD MWD - Standard 9/24/2016 9/30/2016 Page 2 COMPASS 5000.1 Build 74 10/14/2016 10:03:38AM ConocoPhillips ConocoPhillips M/ j9 BAKER Definitive Survey Report HUGHES Company: ConocoPhillips (Alaska) Inc. -Kup2 Local Coordinate Reference: Well 2M-08 Project: Kuparuk River Unit TVD Reference: 2M-08 @ 147.00usft (P245) Site: Kuparuk 2M Pad MD Reference: 2M-08 @ 147.00usft (P245) Well: 2M-08 North Reference: True Wellbore: 2M-081-1 Survey Calculation Method: Minimum Curvature Design: 2M-081-1 Database: EDM Alaska NSK Sandbox Survey MD Inc Azl TVD TVDSS +N/ -S +E/ -W Map Map Map DLS Vertical (usft) (°) (°) (usft) (-ft) (usft) (usft) Easting (°/100') Section Survey Tool Name Annotation (ft) (k) (ft) 11,740.89 41.11 185.37 6,167.94 6,020.94 -9,313.44 -855.55 5,939,674.71 487,078.85 1.16 9,313.44 MWD (2) TIP 11,745.00 41.17 185.38 6,171.03 6,024.03 -9,316.13 -855.80 5,939,672.02 487,078.60 1.47 9,316.13 MWD (2) KOP 11,777.60 51.35 185.38 6,193.54 6,046.54 -9,339.55 -858.01 5,939,648.61 487,076.35 31.23 9,339.55 MWD (2) 11,807.27 64.16 183.00 6,209.34 6,062.34 -9,364.53 -859.80 5,939,623.64 487,074.52 43.70 9,364.53 MWD (2) 11,837.51 72.71 172.07 6,220.47 6,073.47 -9,392.54 -858.52 5,939,595.63 487,075.76 43.88 9,392.54 MWD (2) 11,871.02 87.73 171.93 6,226.15 6,079.15 -9,425.15 -853.93 5,939,563.01 487,080.29 44.82 9,425.15 MWD (2) 11,901.05 95.78 165.96 6,225.23 6,078.23 -9,454.57 -848.19 5,939,533.59 487,085.99 33.36 9,454.57 MWD (2) 11,930.14 99.75 153.89 6,221.28 6,074.29 -9,481.59 -838.33 5,939,506.55 487,095.80 43.31 9,481.59 MWD (2) 11,960.18 101.43 140.04 6,215.74 6,068.74 -9,506.29 -822.28 5,939,481.83 487,111.81 45.66 9,506.29 MWD (2) 11,990.25 96.30 128.14 6,211.09 6,064.09 -9,526.90 -800.97 5,939,461.19 487,133.08 42.65 9,526.90 MWD (2) 12,020.39 96.14 122.81 6,207.82 6,060.82 -9,544.28 -776.58 5,939,443.77 487,157.44 17.59 9,544.28 MWD (2) 12,050.35 95.28 120.61 6,204.84 6,057.84 -9,559.95 -751.22 5,939,428.06 487,182.78 7.85 9,559.95 MWD (2) 12,080.37 95.38 121.54 6,202.05 6,055.05 -9,575.38 -725.62 5,939,412.60 487,208.35 3.10 9,575.38 MWD (2) 12,110.43 95.44 122.88 6,199.22 6,052.22 -9,591.33 -700.30 5,939,396.61 487,233.64 4.44 9,591.33 MWD (2) 12,140.45 95.54 124.42 6,196.35 6,049.35 -9,607.88 575.43 5,939,380.01 487,258.49 5.12 9,607.88 MWD (2) 12,170.46 95.53 126.00 6,193.45 6,046.45 -9,625.11 551.02 5,939,362.75 487,282.86 5.24 9,625.11 MWD (2) 12,200.48 96.52 125.94 6,190.30 6,043.30 -9,642.64 526.86 5,939,345.18 487,306.99 3.30 9,642.64 MWD (2) 12,230.32 97.54 127.20 6,186.65 6,039.65 -9,660.28 503.08 5,939,327.50 487,330.75 5.41 9,660.28 MWD (2) 12,260.47 97.08 127.94 6,182.81 6,035.81 -9,678.52 579.38 5,939,309.23 487,354.42 2.87 9,678.52 MWD (2) 12,290.37 96.59 129.38 6,179.25 6,032.25 -9,697.06 -556.19 5,939,290.65 487,377.57 5.05 9,697.06 MWD (2) 12,320.56 94.77 130.58 6,176.26 6,029.26 -9,716.37 -533.18 5,939,271.31 487,400.55 7.21 9,716.37 MWD (2) 12,352.51 92.67 132.29 6,174.19 6,027.19 -9,737.46 -509.28 5,939,250.18 487,424.41 8.47 9,737.46 MWD (2) 12,380.59 91.54 133.20 6,173.16 6,026.16 -9,756.51 1388.67 5,939,231.10 487,444.99 5.17 9,756.51 MWD (2) 12,410.25 90.15 135.15 6,172.72 6,025.72 -9,777.17 -467.40 5,939,210.41 487,466.22 8.07 9,777.17 MWD (2) 12,440.27 88.43 135.99 6,173.09 6,026.09 -9,798.61 -446.39 5,939,188.94 487,487.20 6.38 9,798.61 MWD (2) 12,470.56 88.10 135.82 6,174.01 6,027.01 -9,820.35 -425.32 5,939,167.16 487,508.23 1.23 9,820.35 MWD (2) 12,501.33 87.76 139.10 6,175.12 6,028.12 -9,843.01 404.53 5,939,144.48 487,528.98 10.71 9,843.01 MWD (2) 12,530.58 87.91 140.62 6,176.23 6,029.23 -9,865.35 -385.69 5,939,122.11 487,547.78 5.22 9,865.35 MWD (2) 12,560.51 88.10 141.45 6,177.27 6,030.27 -9,888.61 -366.88 5,939,098.82 487,566.55 2.84 9,888.61 MWD (2) 12,590.39 88.86 142.07 6,178.06 6,031.06 -9,912.07 -348.39 5,939,075.34 487,585.00 3.28 9,912.07 MWD (2) 10/14/2016 10:03:38AM Page 3 COMPASS 5000.1 Build 74 ConocoPhillips FeAkS ConocoPhillips BAKER Definitive Survey Report HUGHES Company: ConocoPhillips (Alaska) Inc. -Kup2 Local Coordinate Reference: Well 2M-08 Project: Kuparuk River Unit TVD Reference: 2M-08 @ 147.00usft (P245) Site: Kuparuk 2M Pad MD Reference: 2M-08 @ 147.00usft (P245) Well: 2M-08 North Reference: True Wellbore: 2M-081-1 Survey Calculation Method: Minimum Curvature Design: 2M-081-1 Database: EDM Alaska NSK Sandbox Survey Annotation 10/14/2016 10:03:38AM Page 4 COMPASS 5000.1 Build 74 Map Map Vertical MD Inc Azi TVD TVDSS +Nl-S +E1 -W Northing Easting DLS Section Survey Tool Name (usft) (I (°) (usft) (usft) (usft) (usft) (ft) (ft) (°1100') (ft) 12,620.39 89.82 143.23 6,178.41 6,031.41 -9,935.91 -330.19 5,939,051.46 487,603.16 5.02 9,935.91 MWD (2) 12,650.47 90.49 143.95 6,178.33 6,031.33 -9,960.12 -312.34 5,939,027.23 487,620.97 3.27 9,960.12 MWD (2) 12,680.21 90.86 144.83 6,177.98 6,030.98 -9,984.30 -295.03 5,939,003.03 487,638.25 3.21 9,984.30 MWD (2) 12,710.31 91.54 146.29 6,177.35 6,030.35 -10,009.12 -278.01 5,938.978.18 487,655.23 5.35 10,009.12 MWD (2) 12,740.42 92.21 147.37 6,176.36 6,029.36 -10,034.31 -261.54 5,938.952.97 487,671.65 4.22 10,034.31 MWD (2) 12,771.55 91.69 148.64 6,175.30 6,028.30 -10,060.69 -245.06 5,938,926.56 487,688.09 4.41 10,060.69 MWD (2) 12,800.47 91.84 149.70 6,174.41 6,027.41 -10,085.51 -230.24 5,938,901.72 487,702.86 3.70 10,085.51 MWD (2) 12,830.65 92.33 149.34 6,173.31 6,026.31 -10,111.50 -214.95 5,938,875.71 487,718.12 2.01 10,111.50 MWD (2) 12,860.75 91.75 149.16 6,172.24 6,025.24 -10,137.36 -199.57 5,938.849.83 487,733.45 2.02 10,137.36 MWD (2) 12,890.25 91.96 148.89 6,171.29 6,024.29 -10,162.63 -184.39 5,938,824.53 487,748.59 1.16 10,162.63 MWD (2) 12,920.67 91.35 150.85 6.170.41 6,023.41 -10,188.93 -169.13 5,938.798.21 487,763.81 6.75 10,168.93 MWD (2) 12,950.58 92.33 150.66 6,169.45 6,022.45 -10,215.02 -154.52 5,938,772.11 487,778.37 3.34 10,215.02 MWD (2) 12,980.67 91.60 150.72 6,168.42 6,021.42 -10,241.24 -139.80 5,938.745.86 487,793.04 2.43 10,241.24 MWD (2) 13,010.23 91.14 152.10 6,167.71 6,020.71 -10,267.19 -125.66 5,938,719.90 487,807.14 4.92 10,267.19 MWD (2) 13,040.28 91.14 153.59 6,167.11 6,020.11 -10,293.92 -111.95 5,938,693.15 487,820.81 4.96 10,293.92 MWD (2) 13,070.13 90.28 154.99 6,166.74 6,019.74 -10,320.81 -99.00 5,938,666.24 487,833.71 5.50 10,320.81 MWD (2) 13,100.76 87.67 155.89 6,167.29 6,020.29 -10,348.66 -86.27 5,938,638.37 487,846.40 9.01 10,348.66 MWD (2) 13,130.75 87.54 156.23 6,168.54 6,021.54 -10,376.05 -74.12 51938,610.96 487,858.51 1.21 10,376.05 MWD (2) 13,160.41 88.07 157.34 6,169.68 6,022.68 -10,403.29 -62.43 5,938,583.71 487,870.15 4.14 10,403.29 MWD (2) 13,190.40 88.31 159.25 6,170.63 6,023.63 -10,431.13 -51.35 5,938,555.85 487,881.19 6.42 10,431.13 MWD (2) 13,220.44 88.74 161.82 6,171.40 6,024.40 -10,459.45 -41.34 5,938,527.52 487,891.15 8.67 10,459.45 MWD (2) 13,250.35 89.48 162.53 6,171.86 6,024.86 -10,487.92 -32.19 5,938,499.04 487,900.25 3.43 10,487.92 MWD (2) 13,280.33 89.69 160.48 6,172.08 6,025.08 -10,516.34 -22.68 5,938,470.60 487,909.72 6.87 10,516.34 MWD (2) 13,310.53 91.07 160.87 6,171.88 6,024.88 -10,544.84 -12.68 5,938,442.09 487,919.66 4.75 10,544.84 MWD (2) 13,340.62 91.32 162.49 6,171.25 6,024.25 -10,573.40 -3.23 5,938,413.52 487,929.07 5.45 10,573.40 MWD (2) 13,370.75 90.92 163.43 6,170.66 6,023.66 -10,602.20 5.60 5,938.384.70 487,937.85 3.39 10,602.20 MWD (2) 13,400.82 90.86 163.92 6,170.20 6,023.20 -10,631.06 14.05 5,938.355.84 487,946.26 1.64 10,631.06 MWD (2) 13,430.92 91.08 165.71 6,169.69 6,022.69 -10,660.10 21.93 5,938,326.79 487,954.09 5.99 10,660.10 MWD (2) 13,460.71 91.17 165.47 6,169.10 6,022.10 -10,688.95 29.35 5,938,297.93 487,961.46 0.86 10,688.95 MWD (2) 13,490.31 91.54 165.52 6,168.40 6,021.40 -10,717.59 36.76 5,938,269.27 487,968.82 1.26 10,717.59 MWD (2) 13,520.26 90.21 166.61 6,167.95 6,020.95 -10,746.66 43.97 5,938,240.20 487,975.99 5.74 10,746.66 MWD (2) Annotation 10/14/2016 10:03:38AM Page 4 COMPASS 5000.1 Build 74 ConocoPhillips ConocoPhillips Azi TVD Definitive Survey Report +N/ -S Company: ConocoPhillips (Alaska) Inc. -Kup2 Local Co-ordinate Reference: Well 2M-08 Project: Kuparuk River Unit TVD Reference: 2M-08 @ 147.00usft (P245) Site: Kuparuk 2M Pad MD Reference: 2M-08 @ 147.00usft (P245) Well: 2M-08 North Reference: True Wellbore: 2M-081-1 Survey Calculation Method: Minimum Curvature Design: 2M-081-1 Database: EDM Alaska NSK Sandbox Survey MD Inc Azi TVD TVDSS +N/ -S +E/ -W Map Map DLS Vertical (waft) r) O Neft) Naft) (wait) (usft) Northing Northing Easting sti (°/100') Section SectionSurvey Tool Name 13,550.41 89.26 166.74 6,168.08 6,021.09 -10,776.00 50.92 5,938,210.85 487,982.89 3.18 10,776.00 MWD (2) 13,580.41 89.08 166.85 6,168.52 6,021.52 -10,805.20 57.77 5,938,181.64 487,989.69 0.70 10,805.20 MWD (2) 13,610.31 88.10 169.52 6,169.26 6,022.26 -10,834.45 63.89 5,938,152.38 487,995.77 9.51 10,834.45 MWD (2) 13,641.55 88.34 172.30 6,170.23 6,023.23 -10,865.28 68.82 5,938,121.55 488,000.65 8.93 10,865.28 MWD (2) 13,670.67 88.77 173.76 6,170.96 6,023.96 -10,894.18 72.35 5,938,092.65 488,004.13 5.23 10,894.18 MWD (2) 13,700.63 89.51 173.36 6,171.41 6,024.41 -10,923.95 75.71 5,938,062.88 488,007.45 2.81 10,923.95 MWD (2) 13,730.42 89.36 172.49 6,171.70 6,024.70 -10,953.51 79.38 5,936,033.32 488,011.07 2.96 10,953.51 MWD (2) 13,760.53 89.60 173.18 6,171.98 6,024.98 -10,983.38 83.14 5,938,003.44 488,014.77 2.43 10,983.38 MWD (2) 13,790.67 88.96 173.33 6,172.36 6,025.36 -11,013.31 86.68 5,937,973.51 488,018.27 2.18 11,013.31 MWD (2) 13,820.39 89.11 173.45 6,172.86 6,025.86 -11,042.83 90.10 5,937,943.99 488,021.64 0.65 11,042.83 MWD (2) 13,850.41 88.59 174.20 6,173.46 6,026.46 -11,072.67 93.33 5,937,914.15 488,024.82 3.04 11,072.67 MWD (2) 13,880.35 88.34 174.24 6,174.26 6,027.26 -11,102.45 96.34 5,937,884.37 488,027.79 0.85 11,102.45 MWD (2) 13,910.43 88.65 175.70 6,175.05 6,028.05 -11,132.40 98.98 5,937,854.41 488,030.37 4.96 11,132.40 MWD (2) 13,940.59 88.80 177.11 6,175.72 6,028.72 -11,162.49 100.87 5,937,824.32 488,032.22 4.70 11,162.49 MWD (2) 13,970.59 88.89 178.19 6,176.33 6,029.33 -11,192.46 102.10 5,937,794.35 488,033.40 3.61 11,192.46 MWD (2) 14,000.36 88.34 179.16 6,177.05 6,030.05 -11,222.21 102.79 5,937,764.60 488,034.04 3.74 11,222.21 MWD (2) 14,030.45 89.48 179.76 6,177.62 6,030.62 -11,252.29 103.07 5,937,734.52 488,034.27 4.28 11,252.29 MWD (2) 14,062.56 90.34 178.76 6,177.67 6,030.67 -11,284.40 103.48 5,937,702.42 488,034.64 4.11 11,284.40 MWD (2) 14,090.28 91.47 179.38 6,177.23 6,030.23 -11,312.11 103.93 5,937,674.71 488,035.04 4.65 11,312.11 MWD (2) 14,120.33 93.53 179.22 6,175.92 6,028.92 -11,342.13 104.30 5,937,644.69 488,035.36 6.88 11,342.13 MWD (2) 14,150.31 92.40 179.79 6,174.37 6,027.37 -11,372.07 104.56 5,937,614.76 488,035.57 4.22 11,372.07 MWD (2) 14,180.23 90.86 180.75 6,173.52 6,026.52 -11,401.97 104.42 5,937,584.85 488,035.38 6.06 11,401.97 MWD (2) 14,210.65 88.40 181.41 6,173.72 6,026.72 -11,432.39 103.85 5,937,554.45 488,034.76 8.37 11,432.39 MWD (2) 14,240.56 87.21 182.62 6,174.86 6,027.86 -11,462.25 102.79 5,937,524.58 488,033.66 5.67 11,462.25 MWD (2) 14,270.15 86.84 183.41 6,176.40 6,029.40 -11,491.76 101.24 5,937,495.08 488,032.06 2.94 11,491.76 MWD (2) 14,300.33 84.77 184.40 6,178.60 6,031.60 -11,521.79 99.19 5,937,465.06 488,029.96 7.60 11,521.79 MWD (2) 14,330.52 84.80 184.72 6,181.35 6,034.35 -11,551.76 96.80 5,937,435.09 488,027.53 1.06 11,551.76 MWD (2) 14,361.55 84.44 186.13 6,184.26 6,037.26 -11,582.52 93.88 5,937,404.35 488,024.56 4.67 11,582.52 MWD (2) 14,390.86 84.93 188.76 6,186.97 6,039.97 -11,611.45 90.10 5,937,375.42 488,020.73 9.09 11,611.45 MWD (2) 14,420.92 86.16 184.02 6,189.31 6,042.31 -11,641.22 86.77 5,937,345.66 488,017.35 16.24 11,641.22 MWD (2) 14,450.73 86.10 182.56 6,191.32 6,044.32 -11,670.92 85.06 5,937,315.97 488,015.59 4.89 11,670.92 MWD (2) Annotation BAKrER:• HUGHES 10/14/2016 10:03:38AM Page 5 COMPASS 5000.1 Build 74 Survey ConocoPhillips ConocoPhillips Definitive Survey Report Map Company: ConocoPhillips (Alaska) Inc. -Kup2 Local Co-ordinate Reference: Well 2M-08 Project: Kuparuk River Unit TVD Reference: 2M-08 @ 147.00usft (P245) Site: Kuparuk 2M Pad MD Reference: 2M-08 @ 147.00usft (P245) Well: 2M-08 North Reference: True Wellbore: 21\11-081-1 Survey Calculation Method: Minimum Curvature Design: 2M-081-1 Database: EDM Alaska NSK Sandbox Survey Annotation Phil BAKER HUGHES 10/14/2016 10:03:38AM Page 6 COMPASS 5000.1 Build 74 Map Map Vertical MD Inc Azi TVD TVDSS +N/ -S +E/ -W Northing Easting DLS Section Survey Too[ Name (usft) V) V) (usft) (usft) (usft) (usft) (ft) (ft) V/100') (ft) 14,480.55 87.36 182.37 6,193.02 6,046.02 -11,700.66 83.78 5.937,286.23 488,014.27 4.27 11,700.66 MWD (2) 14,510.27 86.71 183.43 6,194.56 6,047.56 -11,730.30 82.28 5,937,256.60 488.012.72 4.18 11,730.30 MWD (2) 14,540.53 87.21 185.57 6,196.16 6,049.16 -11,760.42 79.91 5.937,226.48 488,010.30 7.25 11,760.42 MWD (2) 14,570.66 88.46 185.50 6,197.30 6,050.30 -11,790.39 77.00 5,937,196.52 488,007.35 4.16 11,790.39 MWD (2) 14,600.51 89.05 185.19 6,197.95 6,050.95 -11,820.10 74.22 5,937,166.81 488,004.52 2.23 11,820.10 MWD (2) 14,630.35 88.28 184.22 6,198.65 6,051.65 -11,849.84 71.78 5,937,137.09 488,002.03 4.15 11,849.84 MWD (2) 14660.55 88.59 182.86 6,199.47 6,052.47 -11,879.97 69.91 5,937.106.97 488,000.11 4.62 11,879.97 MWD (2) 14,690.57 90.00 182.00 6,199.84 6,052.84 -11,909.96 68.64 5,937.076.98 487,998.79 5.50 11,909.96 MWD (2) 14,721.13 90.77 182.66 6,199.64 6.052.64 -11,940.49 67.40 5,937,046.45 487,997.50 3.32 11,940.49 MWD (2) 14,750.29 90.64 184.26 6,199.28 6,052.28 -11,969.59 65.64 5,937.017.36 487,995.70 5.50 11,969.59 MWD (2) 14,770.29 91.04 184.39 6,198.98 6,051.98 -11,989.53 64.13 5,936,997.42 487,994.16 2.10 11,989.53 MWD (2) 14,780.36 91.14 184.58 6,198.79 6,051.79 -11,999.57 63.34 5,936.987.38 487,993.35 2.13 11,999.57 MWD (2) 14,810.53 90.12 184.91 6,198.46 6,051.46 -12,029.64 60.85 5,936,957.33 487,990.81 3.55 12,029.64 MWD (2) 14,840.43 89.82 184.64 6,198.48 6,051.48 -12,059.43 58.36 5,936,927.54 487,988.27 1.35 12,059.43 MWD (2) 14,870.55 89.42 186.34 6,198.68 6,051.68 -12,089.41 55.48 5,936,897.57 487,985.34 5.80 12,089.41 MWD (2) 14,900.37 90.92 188.32 6,198.59 6,051.59 -12,118.99 51.67 5,936,868.00 487,981.49 8.33 12,118.99 MWD (2) 14,930.37 90.03 190.60 6,198.34 6,051.34 -12,148.57 46.74 5,936,838.42 487,976.51 8.16 12,148.57 MWD (2) 14,960.35 90.68 194.08 6,198.15 6,051.15 -12,177.86 40.33 5,936,809.15 487,970.06 11.81 12,177.86 MWD (2) 14,990.32 89.72 196.34 6,198.05 6,051.05 -12,206.77 32.47 5,936,780.25 487,962.16 8.19 12,206.77 MWD (2) 15,024.17 90.46 196.97 61197.99 6,051.00 -12,239.20 22.77 5,936,747.84 487,952.40 2.87 12,239.20 MWD (2) 15.055.34 91.96 194.72 6,197.34 6,050.34 -12,269.18 14.26 5,936,717.88 487,943.85 8.67 12,269.18 MWD (2) 15,080.25 92.09 193.22 6,196.46 6,049.46 -12,293.34 8.25 5,936,693.74 487,937.80 6.04 12,293.34 MWD (2) 15,110.21 90.58 191.29 6,195.76 6,048.76 -12,322.60 1.90 5,936,664.48 487,931.40 8.18 12,322.60 MWD (2) 15,140.30 88.34 190.61 6,196.04 6,049.04 -12,352.14 -3.82 5.936,634.96 487,925.63 7.78 12,352.14 MWD (2) 15,170.31 85.11 188.88 6,197.76 6,050.76 -12,381.67 -8.89 5,936,605.44 487.920.52 12.20 12,381.67 MWD (2) 15,200.17 84.06 186.49 6,200.57 6,053.57 -12,411.12 -12.87 5,936,576.00 487,916.49 8.71 12,411.12 MWD (2) 15,230.29 84.34 184.75 6,203.62 6,056.62 -12,440.94 -15.80 5,936,546.18 487,913.51 5.82 12,440.94 MWD (2) 15,260.31 85.51 183.27 6,206.27 6,059.27 -12,470.77 -17.89 5,936,516.36 487,911.37 6.27 12.470.77 MWD (2) 15,290.27 87.30 181.81 6,208.15 6,061.15 -12,500.64 -19.22 5,936,486.50 487,910.00 7.70 12,500.64 MWD (2) 15,320.41 88.46 179.41 6,209.27 6,062.27 -12,530.76 -19.54 5,936,456.38 487,909.63 8.84 12,530.76 MWD (2) 15,350.13 89.75 177.00 6,209.73 6,062.73 -12,560.46 -18.60 5,936,426.69 487,910.52 9.20 12,560.46 MWD (2) Annotation Phil BAKER HUGHES 10/14/2016 10:03:38AM Page 6 COMPASS 5000.1 Build 74 ConocoPhillips ConocoPhillips BAKER" Definitive Survey Report HUGHES Company: ConocoPhillips (Alaska) Inc. -Kup2 TVD Reference: 2M-08 @ 147.00usft (P245) Project: Kuparuk River Unit True Survey Calculation Method: Minimum Curvature Site: Kuparuk 2M Pad (ft) (ft) Well: 2M-08 -16.36 5,936,396.57 487,912.71 Wellbore: 2M -08L1 MWD (2) -12.99 5,936,366.91 487,916.04 Design: 2M-0811 MWD (2) -8.34 5,936,334.91 487,920.64 Survey 12,652.23 MWD (2) -3.57 5,936,307.75 487,925.36 MD Inc Azi TVD TVDSS +NIS (usft) (I V) (usft) (usft) (usft) 15,380.33 90.03 174.47 6,209.79 6,062.79 -12,590.57 15,410.19 88.07 172.57 6,210.29 6,063.29 -12,620.23 15,442.56 86.62 170.88 6,211.78 6,064.78 -12,652.23 15,470.17 87.42 169.20 6,213.22 6,066.22 -12,679.38 15,500.29 87.48 167.70 6,214.56 6,067.56 -12,708.86 15,530.18 88.22 166.24 6,215.68 6,068.68 -12,737.96 15,560.20 86.62 167.23 6,217.03 6,070.03 -12,767.15 15,592.02 83.69 169.20 6,219.72 6,072.72 -12,798.18 15,616.13 82.66 170.53 6,222.59 6,075.59 -12,821.75 15,650.00 82.66 170.53 6,226.91 6,079.91 -12,854.88 Local Co-ordinate Reference: Well 2M-08 TVD Reference: 2M-08 @ 147.00usft (P245) MD Reference: 2M-08 @ 147.00usft (P245) North Reference: True Survey Calculation Method: Minimum Curvature Database: EDM Alaska NSK Sandbox Annotation 1011412016 10.03:38AM Page 7 COMPASS 5000.1 Build 74 Map Map Vertical (ustW Northing Easting S Section Survey Tool Name (ft) (ft) (OD (ft) -16.36 5,936,396.57 487,912.71 8.43 12,590.57 MWD (2) -12.99 5,936,366.91 487,916.04 9.14 12,620.23 MWD (2) -8.34 5,936,334.91 487,920.64 6.87 12,652.23 MWD (2) -3.57 5,936,307.75 487,925.36 6.73 12,679.38 MWD (2) 2.46 5,936,278.26 487,931.34 4.98 12,708.86 MWD (2) 9.19 5,936,249.15 487,938.03 5.47 12,737.96 MWD (2) 16.07 5,936,219.96 487,944.86 6.27 12,767.15 MWD (2) 22.55 5,936,188.92 487,951.28 11.08 12,798.18 MWD (2) 26.76 5,936,165.35 487,955.46 6.95 12,821.75 MWD (2) 32.29 5,936,132.21 487,960.93 0.00 12,854.88 PROJECTED to TD Annotation 1011412016 10.03:38AM Page 7 COMPASS 5000.1 Build 74 upC#rB,-b STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1a. Well Status: 011 21 , Gas❑ SPLUG ❑ Other ❑ Abandoned ❑ Suspended ❑ 20aoc 25.105 20AAC 25.110 GINJ ❑ WINJ ❑ WAG❑ WDSPL ❑ No. of Completions: 1b. Well Class: Development 21 k Exploratory ❑ Service ❑ Stratigraphic Test ❑ 2. Operator Name: ConocoPhillips Alaska, Inc. 6. Date Comp., Susp., or Aband.: 10/7/2016 14. Permit to Drill Number/ Sundry: 216-0951 , 3. Address, P.O. Box 100360 Anchorage, AK 99510-0360 7. Date Spudded: 9125/2016 15. API Number: 50-103-20184-63-00 4a. Location of Well (Governmental Section): Surface: 114' FSL, 109' FWL, Sec 27, T11 N, RSE, UM Top of Productive Interval: 1165' FSL, 4548' FWL, Sec 4, T1 ON, R8E, UM Total Depth: 2181' FNL, 5166' FEL, Sec 10, T10N, R8E, UM 8. Date TD Reached: 9/30/2016 16. Well Name and Number: KRU 2M-081-1 . 9. Ref Elevations: KBA47 GL:105.5 BF: 17. Field / Pool(s): Kuparuk River Field/Kuparuk Oil Pool 10. Plug Back Depth MD)TVD: WA 18. Property Designation: ADL 25589, ADL 25586 4b. Location of Well (State Base Plane Coordinates, NAD 27): Surface: x- 487949 y- 5948986 Zone- 4 TPI: x- 487113 y- 5939480 Zone- 4 Total Depth: x- 487961 y- 5936132 Zone- 4 11. Total Depth MD/TVD: 15650/6227 - 19. Land Use Permit: ALK 2675 12. SSSV Depth MDJTVD: N/A 20. Thickness of Permafrost MDITVD: 1495/1480 5. Diirectional or Inclination Survey: Yes • M (attached) No ❑ Submit electronic and printed Information per 20 AAC 25.050 13. Water Depth, if Offshore: N/A (ft MSL) 1 21. Re-drill/Lateral Top Window MDITVD: 11745/6171 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, dipmetet, formation tester, temperature, cement evaluation, casing collar locator, jewelry, and perforation record. Acronyms may be used. Attach a separate page if necessary GR/Res 23. CASING, LINER AND CEMENTING RECORD WT. PER GRADE SETTING DEPTH MD SETTING DEPTH TVD AMOUNT CASING FT TOP BOTTOM TOP BOTTOM HOLE SIZE CEMENTING RECORD PULLED 16 62.5 H-40 42 121 43 121 24 250 sx AS 11 9 518 47 L-80 42 4253 42 2744 121/4 660 sx PF E & 760 sx Class G 7 26 J-55 39 12138 39 6466 81/2 198 sx Class G 2 318 4.6 L-80 1 11962 115650 6216 6227 3 Slotted Liner 24, Open to production or injection? Yes 2 No ❑ If Yes, list each interval open (MDITVD of Top and Bottom; Perforation Size and Number): Slotted Liner @ 11962 - 15650 MD and 6215-6227 TVD 25. TUBING RECORD SIZE DEPTH SET (MD) PACKER SET (MD/TVD) 31/2 11676 11538/6016 4 1/2 BTP 11759 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. Was hydraulic fracturing used during completion? Yes ❑ No I] Per 20 AAC 25.283 (i)(2) attach electronic and printed information DEPTH INTERVAL (MD) JAMOUNT AND KIND OF MATERIAL USED 27. PRODUCTION TEST Date First Production: 10/21/2016 Method of Operation (Flowing, gas lift, etc.): GAS LIFT Date of Test: 10/20/2016 Hours Tested: 17.7 Production for Test Period Oil -Bbl: 535.88 Gas -MCF: 772.81 Water -Bbl: 956.94 Choke Size: 176 Gas -Oil Ratio: 1665 scflstb Flow Tubing Press. 238.44 Casing Press: 1268 sl Calculated 24 -Hour Rate Oil -Bbl: 727 Gas -MCF: 10491299 Water -Bbl: Oil Gravlty - API (corr): Form 10-40���'sed 1112Q15� �T/' Z1/ 6��C/ONTINUED ON PAGE 2 RB�MS �� NOV � s �Q�G Submit ORIGINiAL only�� STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION RECEIVE=D NOV 0 4 2016 WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1 a. Well Status: Oil 0 Gas❑ SPLUG ❑ Other ❑ Abandoned ❑ Suspended ❑ 20AAC 25.105 20AAC 25.110 GINJ ❑ WINJ ❑ WAG❑ WDSPL ❑ No. of Completions: 1 b. Well Class: Development Q Exploratory ❑ Service ❑ Stratigraphic Test ❑ 2. Operator Name: ConocoPhillips Alaska, Inc. 6. Date Comp., Susp., or Aband.: 10/7/2016 14. Permit to Drill Number / Sundry: 216-095/ 3. Address: P.O. Box 100360 Anchorage, AK 99510-0360 7. Date Spudded: 9/25/2016 15. API Number: 50-103-20184-63-00 4a. Location of Well (Governmental Section): Surface: 114' FSL, 109' FWL, Sec 27, T11 N, R8E, UM Top of Productive Interval: 1165' FSL, 4548' FWL, Sec 4, TION, R8E, UM Total Depth: 2181' FNL, 5166' FEL, Sec 10, T10N, R8E, UM 8. Date TD Reached: 9/30/2016 16. Well Name and Number: KRU 2M-081_1 9. Ref Elevations: K13:147 GL: 105.5 BF: 17. Field / Pool(s): Kuparuk River Field/Kuparuk Oil Pool 10. Plug Back Depth MD/TVD: N/A 18. Property Designation: ADL 25589, ADL 25586 4b. Location of Well (State Base Plane Coordinates, NAD 27): Surface: x--xA644+- y- -& 8 (6 (>kA Zone- 4 TPI: x- 487113 y- 5939480 1 Zone- 4 Total Depth: x- 487961 y- 5936132 Zone- 4 11. Total Depth MD/TVD: 15650/6227 19. Land Use Permit: ALK 2675 12. SSSV Depth MD/TVD: N/A 20. Thickness of Permafrost MD/TVD: 1495/1480 5. Directional or Inclination Survey: Yes [2] (attached) No ❑ Submit electronic and printed information per 20 AAC 25.050 13. Water Depth, if Offshore: N/A (ft MSL) 1 1 21. Re-drill/Lateral Top Window MD/TVD: 11745/6171 22. Logs Obtained: List all logs run and, pursuant to AS 31.05.030 and 20 AAC 25.071, submit all electronic data and printed logs within 90 days of completion, suspension, or abandonment, whichever occurs first. Types of logs to be listed include, but are not limited to: mud log, spontaneous potential, gamma ray, caliper, resistivity, porosity, magnetic resonance, dipmeter, formation tester, temperature, cement evaluation, casing collar locator, jewelry, and perforation record. Acronyms may be used. Attach a separate page if necessary GR/Res 23. CASING, LINER AND CEMENTING RECORD WT. PER GRADE SETTING DEPTH MD SETTING DEPTH TVD HOLE SIZE CEMENTING RECORD AMOUNT CASING FT TOP BOTTOM TOP BOTTOM PULLED 16 62.5 H-40 42 121 43 121 24 250 sx AS II 9518 47 L-80 42 4253 42 2744 121/4 660 sx PF E & 760 sx Class G 7 26 J-55 39 12138 39 6466 81/2 198 sx Class G 23/8 4.6 L-80 11962 15650 6216 6227 3 Slotted Liner 24. Open to production or injection? Yes 0 No ❑ If Yes, list each interval open (MD/TVD of Top and Bottom; Perforation Size and Number): Slotted Liner @ 11962 -15650 MD and 6215-6227 TVD 66 • -!' L�- 25. TUBING RECORD SIZE DEPTH SET (MD) PACKER SET (MD/TVD) 3 1/2 11676 11538/6016 4 1/2 BTP 11759 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. Was hydraulic fracturing used during completion? Yes ❑ No EJ Per 20 AAC 25.283 (i)(2) attach electronic and printed information DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED 27. PRODUCTION TEST Date First Production: 10/21/2016 Method of Operation (Flowing, gas lift, etc.): GAS LIFT Date of Test: 10/20/2016 Hours Tested: 17.7 Production for Test Period -11111. Oil -Bbl: 535.88 Gas -MCF: 772.81 Water -Bbl: 956.94 Choke Size: 176 Gas -Oil Ratio: 1665 scf/stb Flow Tubing Press. 238.44 Casinq Press: 1268psi Calculated 24 -Hour Rate Oil -Bbl: 727 Gas -MCF: 1049 Water -Bbl: 1299 Oil Gravity - API (corr): 24 Form 10-407 Revised 11/2015 CONTINUED ON PAGE 2RBDMS L V NOV - 7 2016 Submit ORIGINIAL on( Ir 28. CORE DATA Conventional Core(s): Yes ❑ No E Sidewall Cores: Yes ❑ No R] 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 [21 If yes, list intervals and formations tested, briefly summarizing test results. Permafrost - Top Surface Surface Permafrost - Base 1495 1480 Attach separate pages to this form, if needed, and submit detailed test Top of Productive Interval 11962 6215 information, including reports, per 20 AAC 25.071. A3 11782 6196 A4 12101 6200 TD 15650 6227 Formation at total depth: A4 31. List of Attachments: Daily Operations Summary, Definitive Survey, Schematic Information to be attached includes, but is not limited to: summary of daily operations, wellbore schematic, directional or inclination survey, core analysis, r)aleontoloaical report, r)roduction or well test results, oer 20 AAC 25.070. 32. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Jeff Connelly Ccs 263-4112 Email: eff.s.connell co .com Printed Name: K. Starck Title: CTD Supervisor & Superintendent Si nature: Phone: 263-4172 Date: INSTRUCTIONS General: This form and the required attachments provide a complete and concise record for each well drilled in Alaska. Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed. All laboratory analytical reports regarding samples or tests from a well must be submitted to the AOGCC, no matter when the analyses are conducted. Item 1 a: Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Item 1b: Well Class - Service wells: Gas Injection, Water Injection, Water -Alternating -Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Item 4b: TPI (Top of Producing Interval). Item 9: The Kelly Bushing, Ground Level, and Base Flange elevations in feet above Mean Sea Level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 15: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). Item 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 2M-08 Proposed CTD Schematic Baker Orbit Valve at 4485' MD (RKB) (2.835" minimum ID) 3-1/2" 9.3# L-80 ELIE 8rd Tubing to surface 3-1/2" Camco KBMG gas lift mandrels @ 3648', 6335', 8411', 9918', 10923', 11453' (RKB) Baker PBR @ 11,516' MD Baker FHL packer @ 11539' MD (RKB) 3-1/2" X Nipple 11,592' MD (2.812" min ID) (RKB) 2M-081-1 (A4 South) TD @ 15,650' MD Liner Bottom @ 15,650' MD Billet @ 11,962' MD ---------------------------------------- 2M-081-1-01 (A3 South West) TD @ 14,503' MD Bottom of Liner @ 14,498' Top of Liner @ 11,745' MD `s Operations Summary (with Timelog Depths) sf .;* 2M-08 AW 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 (ftK6) 9/20/2016 9/20/2016 1.50 MIRU WHDBOP NUND P RU MP lines and upper swab valve. 0.0 0.0 18:00 19:30 Finish cellar work. 9/20/2016 9/20/2016 1.50 SLOT WELLPR CTOP P PJSM, RU SLB N2 and blow down 0.0 0.0 19:30 21:00 reel. 9/20/2016 9/21/2016 3.00 SLOT WELLPR CTOP P Pull coil through injector and secure 0.0 0.0 21:00 00:00 to reel. 9/21/2016 9/21/2016 2.00 SLOT WELLPR CTOP P Pull back coil and secure it to the reel. 0.0 0.0 00:00 02:00 Lower coil tubing reel off rig. 9/21/2016 9/21/2016 2.85 SLOT WELLPR SLKL P RU Slickline to RIH, set catcher and 0.0 0.0 02:00 04:51 pull SOV. Dummy GLM #3. Pull catcher and plug in tailpipe. Slickline pulled SOV and is now heading back in hole to set DV. 9/21/2016 9/21/2016 6.00 SLOT WELLPR SVRG T Replaced pillar blocks, reel drive and 0.0 0.0 04:51 10:51 bull gear. 9/21/2016 9/21/2016 1.25 SLOT WELLPR CTOP P New coil spool #50044 has arrived on 0.0 0.0 10:51 12:06 site. Peform PJSM with Nabors and Peak hands.............install new spool.................Slickline has installed DV and successfully pressure tested tubing ............. 9/21/2016 9/21/2016 2.00 SLOT WELLPR CTOP P Begin securing and prepping new coil 0.0 0.0 12:06 14:06 reel...............Slickline RBIH to pull prong......... 9/21/2016 9/21/2016 2.25 SLOT WELLPR CTOP P Prong on surface. RBIH and retrieve 0.0 0.0 14:06 16:21 plug..................POOH with plug ........... Plug at surface. 9/21/2016 9/21/2016 0.45 SLOT WELLPR SLKL P Close Orbit Valve. 0.0 0.0 16:21 16:48 9/21/2016 9/21/2016 2.00 SLOT WELLPR SLKL P RD slickline and clear rig floor. 0.0 0.0 16:48 18:48 9/21/2016 9/22/2016 5.20 SLOT WELLPR CTOP P Install inner reel iron and terminate 0.0 18:48 00:00 bulkhead. 9/22/2016 9/22/2016 3.00 SLOT WELLPR CTOP P Installed inner reel iron. Terminated 0.0 0.0 00:00 03:00 the bulkhead. Changed BOP packoffs. 9/22/2016 9/22/2016 5.88 SLOT WELLPR CTOP P Pull testing injector to 100K. Chains 0.0 0.0 03:00 08:52 slipping at 75K. Changed the stripper brass. Having issues with removing the stripper brass......... having to beat it out ............... 9/22/2016 9/22/2016 0.38 SLOT WELLPR CTOP P Stripper brass has been changed, 0.0 0.0 08:52 09:15 start pull testing again to 100k 9/22/2016 9/22/2016 0.43 SLOT WELLPR CTOP P Pull test to 105k successful. Remove 0.0 0.0 09:15 09:41 test joint. 9/22/2016 9/22/2016 0.42 SLOT WELLPR CTOP P PJSM for stabbing coil. 09:41 10:06 Page 1/13 ReportPrinted: 10/10/2016 `p Operations Summary (with Timelog Depths) 2M-08 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) 9/22/2016 9/22/2016 7.10 SLOT WELLPR CTOP P Begin stabbing coil operations and 0.0 0.0 10:06 17:12 then install coil connector ............ pull test to 50k .... install UQC, etc. .......fluid pack coil tubing and pressure test ........... coil connector and reel iron all good ........... depressure and install nozzle on BHA ................. ****Note = Contacted AOGCC Inspector Guy Cook at 16:20 hrs to inform him we were ready for the BOPE test and he waived witness on this test due to a rig move blocking the spine road from Deadhorse. **** 9/22/2016 9/23/2016 6.79 MIRU WHDBOP BOPE P BOPE test. New swab valve failed and 0.0 0.0 17:12 00:00 called grease crew. Continued on with the test. Greased tree valves and swab valve passed. 9/23/2016 9/23/2016 2.75 MIRU WHDBOP BOPE P Tested BOPE. 0.0 0.0 00:00 02:45 9/23/2016 9/23/2016 1.00 MIRU WHDBOP RURD P RD BOPE test equipment 0.0 0.0 02:45 03:45 9/23/2016 9/23/2016 0.50 SLOT WELLPR CTOP P Pump a -line slack forward. 0.0 0.0 03:45 04:15 9/23/2016 9/23/2016 0.25 SLOT WELLPR OWFF P Open Master Valve and flow check 0.0 0.0 04:15 04:30 against closed Orbit Valve. 9/23/2016 9/23/2016 0.45 PROD1 RPEQPT PULD P Baker hand on site. Initiate PJSM prior 0.0 0.0 04:30 04:57 to making up Whipstock setting BHA. 9/23/2016 9/23/2016 2.65 PROD1 RPEQPT PULD P Pick up Whipstock setting 0.0 0.0 04:57 07:36 BHA ................. 9/23/2016 9/23/2016 0.35 PROD1 RPEQPT PULD P Open Orbit Vlave...... 0.0 0.0 07:36 07:57 9/23/2016 9/23/2016 0.58 PROD1 RPEQPT PRTS P Go to well with BHA and pressure test. 0.0 0.0 07:57 08:31 9/23/2016 9/23/2016 2.80 PROD1 RPEQPT WPST P Open well and RIH with EDC open 0.0 0.0 08:31 11:19 pumping at minimum rate 9/23/2016 9/23/2016 0.45 PROD1 RPEQPT EQRP T Stop RIH to work on reel...........tighten 11,000.0 11,000.0 11:19 11:46 saddle bolts ................. 9/23/2016 9/23/2016 0.12 PROD1 RPEQPT WPST P Continue RIH............. 11,580.0 11,580.0 11:46 11:54 9/23/2016 9/23/2016 0.76 PROD1 RPEQPT DLOG P Tie into K1 Marker..............RIH speed 11,580.0 11,650.0 11:54 12:39 at 3 fpm 9/23/2016 9/23/2016 0.14 PROD1 RPEQPT DLOG P Missed K1 Marker................PUH and 11,650.0 0.0 12:39 12:48 Log again.......... 9/23/2016 9/23/2016 0.20 PROD1 RPEQPT DLOG P @11,571 ............... RBIH at 3 fpm 11,571.0 11,643.0 12:48 13:00 logging again......... 9/23/2016 9/23/2016 0.04 PROD1 RPEQPT DLOG P @ 11,643' ........Finished 11,643.0 11,643.0 13:00 13:02 logging ....make correction of + 37.5'............ 9/23/2016 9/23/2016 0.14 PROD1 RPEQPT DLOG P PUH to 11,490'to ruin CCL ............... 11,643.0 11,490.0 13:02 13:10 9/23/2016 9/23/2016EO.31PROD1 RPEQPT DLOG PLog CCL........ 11,490.013:10 13:29 9/23/2016 9/23/2016 PROD1 RPEQPT WPST P PUH to 11,600', check CCL Log, looks 11,831.0 11,600.0 13:29 13:50 good, RBIH to set Whipstock Page 2113 Report Printed: 10/10/2016 711 Operations Summary (with Timelog Depths) 2M-08 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 (ftK6) 9/23/2016 9/23/2016 0.08 PROD1 RPEQPT WPST P On set depth, P/U weight, close EDC. 11,758.0 11,758.0 13:50 13:55 Bring pump online and set Whipstock. Top of whipstock is at 11,745'..0 degrees / High side..... set down 3k over to verify set ..... good set....... 9/23/2016 9/23/2016 0.90 PROD1 RPEQPT DISP P Open EDC and begin poumping 8.6 11,730.0 11,730.0 13:55 14:49 ppg used flow -Pro to displace coil and wellbore ................ 9/23/2016 9/23/2016 2.00 PROD1 RPEQPT TRIP P POOH pumping Flo -Pro and 11,730.0 0.0 14:49 16:49 maintaining 1:1's .............. 9/23/2016 9/23/2016 0.90 PROD1 RPEQPT OWFF P At surface. Close Orbit Valve. Check 0.0 0.0 16:49 17:43 for flow.............no flow ............ 9/23/2016 9/23/2016 0.53 PROD1 RPEQPT PULD P L/D BHA #1, whipstock setting BHA. 0.0 0.0 17:43 18:15 Lost 7 bbls of used 8.6ppg FloPro on TOOK 9/23/2016 9/23/2016 1.75 PROD1 WHPST PULD P P/U BHA #2, Window milling BHA. 0.0 0.0 18:15 20:00 9/23/2016 9/23/2016 2.50 PROD1 WHPST TRIP P Open Orbit valve and RIH. 0.0 11,600.0 20:00 22:30 9/23/2016 9/23/2016 0.50 PROD1 WHPST DLOG P Tie-in to the K1 marker. Plus 18' 11,600.0 11,747.0 22:30 23:00 correction. Close EDC and get PU wt 38K. 9/23/2016 9/24/2016 1.00 PROD1 WHPST WPST P Tag WS pinch point at 11,747' (TOWS 11,747.0 11,748.0 23:00 00:00 at 11,746). Start milling window. Losses 2.5 bbl/hr. 9/24/2016 9/24/2016 5.00 PROD1 WHPST WPST P Milling window at 11,748'. Losses 2.5 11,748.0 11,754.0 00:00 05:00 bbl/hr. 9/24/2016 9/24/2016 3.68 PROD1 WHPST WPST P Continue milling window from 11,748' 11,754.4 11,755.3 05:00 08:40 per recommended practice and Baker Rep. 1.5 bpm at 3,708 psi, IA 838, OA 184, CWT 7.06, WOB 2.18 9/24/2016 9/24/2016 4.89 PROD1 WHPST WPST P Stall..............PUH and bring pump 11,755.3 11,758.6 08:40 13:34 back online.............RBIH to 11,755.3' and continue milling window per recommended practice and Baker Rep. 1.5 bpm at 3,728 psi, IA 857, OA 200, CWT 7.06, WOB 2.18 9/24/2016 9/24/2016 2.25 PROD1 WHPST WPST P @ 11,758.6' and bit and string reamer 11,758.6 11,770.0 13:34 15:49 should now be out the 7" window ( big drop in WOB) ............ continue drilling into formation 25' past TOWS per recommended practice and Baker Rep......... 1.5 bpm at 3,745, IA 890, OA 245, CWT 9.31, WOB 2.04 9/24/2016 9/24/2016 1.35 PROD1 WHPST REAM P @ 11,770.0' TO Rathole............ PUH 11,770.0 11,745.0 15:49 17:10 to backream window area @ 1 fpm with 3 up and down passes .......... dry drift window with no issues........... 9/24/2016 9/24/2016 3.00 PROD1 WHPST TRIP P POOH with BHA#2 (window milling 11,745.0 0.0 17:10 20:10 assembly). Open EDC. Close Orbit Valve. Close EDC. Flow check well. 9/24/2016 9/24/2016 1.25 PROD1 WHPST PULD P LD BHA #2 (window milling 0.0 0.0 20:10 21:25 assembly). 9/24/2016 9/24/2016 1.80 PROD1 DRILL PULD P PU BHA #3 (Build drilling BHA 0.0 0.0 21:25 23:13 w/2.20bend motor). Open EDC. Open Orbit valve. Page 3113 Report Printed: 10/10/2016 Operations Summary (with Timelog Depths) 3 ``a 2M-08 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) 9/24/2016 9/25/2016 0.78 PROD1 DRILL TRIP P RIH with BHA #3 (Build drilling BHA 0.0 3,800.0 23:13 00:00 w/2.20bend motor). 9/25/2016 9/25/2016 1.75 PROD1 DRILL TRIP P RIH to drill the build section. 3,800.0 11,770.0 00:00 01:45 9/25/2016 9/25/2016 2.75 PROD1 DRILL DRLG P Drilling Build section. ROP 46 fph, 11,700.0 11,845.0 01:45 04:30 losses 2.5 bph. PU WT 35K, FS 3800 psi. 9/25/2016 9/25/2016 3.88 PROD1 DRILL DRLG P @ 12,000'....... End of build section. 11,845.0 12,000.0 04:30 08:22 DLS avg. - 42.5°, max - 45.7°, min - 33° Pump 5 bbl hi/lo sweep and chased up hole to 3.5 x 4.5 crossover..............RBIH and PUH again to thoroughly clean area ............ pretty consistant solids amounts coming across shaker while drilling build section ............... Following information recorded at window as requested: Density Out: 8.78 BHP: 3,700 Choke Press: 550 9/25/2016 9/25/2016 2.10 PROD1 DRILL TRIP P POOH chasing returns to surface...... 12,000.0 87.7 08:22 10:28 9/25/2016 9/25/2016 0.47 PROD1 DRILL OWFF P At surface. Close Orbit Valve and 87.7 0.0 10:28 10:57 check for flow..............no flow........... 9/25/2016 9/25/2016 0.78 PROD1 DRILL PULD P L/D Build Section BHA (#3) 0.0 0.0 10:57 11:43 9/25/2016 9/25/2016 1.10 PROD1 DRILL PRTS P Pressure test PDL which was just put 0.0 0.0 11:43 12:49 back together yesterday after the workover operation................remove PDL after pressure test............ 9/25/2016 9/25/2016 0.91 PROD1 DRILL PULD P P/U BHA #4, 2M-08 L1 Lateral Drilling 0.0 69.2 12:49 13:44 BHA w/RSM ............ stab onto well .... test MWD..... replace packoffs........... Open Orbit Valve ........... 9/25/2016 9/25/2016 2.40 PROD1 DRILL TRIP P RBIH with 2M-08 L1 Lateral drilling 69.2 11,550.0 13:44 16:08 BHA ............. 9/25/2016 9/25/2016 0.62 PROD1 DRILL DLOG P Tie in to K1 Marker and make 11,550.0 11,780.0 16:08 16:45 correction of +14.5................continue RIH and log RA...............RA @ 11,752.5............ ***Note: Small weight bobble entering window with RSM............ 9/25/2016 9/25/2016 0.12 PROD1 DRILL TRIP P Continue RIH to drill L1 11,780.0 12,000.0 16:45 16:52 Lateral .................. 9/25/2016 9/25/2016 0.63 PROD1 DRILL DRLG P at 12,000' BOBD..............swapping to 12,000.0 12,023.0 16:52 17:30 new 8.6 ppg Flo -Pro mud system .......... 9/25/2016 9/26/2016 6.49 PROD1 DRILL DRLG P Drilling L1 Lateral section. ROP 56 12,023.0 12,365.0 17:30 00:00 fph, losses 2 bph. PU WT 36K, FS 4141 psi . 9/26/2016 9/26/2016 2.00 PROD1 DRILL DRLG P Drilling L1 lateral section. ROP 46 fph, 12,365.0 12,505.0 00:00 02:00 losses 1.5 bph. PU WT 35K, FS 3800 psi . Page 4/13 Report Printed: 10/10/2016 Operations Summary (with Timelog Depths) 2M-08 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 (MB) End Depth (WB) 9/26/2016 9/26/2016 1.20 PROD1 DRILL WPRT P Wiper trip to window. 12,505.0 12,505.0 02:00 03:12 Mud wt IN &71ppg/ OUT 8.75ppg. Flow rate IN 1.5gpm/OUT 1.48 gpm. BHP 3803. Choke 250 psi. ECD 12.24 ppg- 9/26/2016 9/26/2016 1.80 PROD1 DRILL DRLG P BOBD drilling at 70 fph, 12,505.0 12,755.0 03:12 05:00 9/26/2016 9/26/2016 2.50 PROD1 DRILL DRLG P Drilling ahead in L1 Lateral @ 60 fpm, 12,755.0 12,905.0 05:00 07:30 Circ Press - 4,014, WHP - 214, Pump Rate 1.5 bpm, BHP = 3,893, IA - 394, OA - 327 9/26/2016 9/26/2016 2.33 PROD1 DRILL DRLG P @ 12,905' ...........PUH to check 12,905.0 12,955.0 07:30 09:49 weights as per CTD Engineer ......... PUW = 38K ............ RBIH and continue drilling ahead......... at 89 fph, WOB - 1.73, Circ Press - 4,051, WHP - 218, BHP - 3,924, IA - 435, OA - 383, CTW - 8.97 9/26/2016 9/26/2016 0.80 PROD1 DRILL DRLG P @ 12,955' ...........PUH to check 12,955.0 13,005.0 09:49 10:37 weights again as per CTD Engineer ......... PUW = 38K again with an occasional 39k seen ............ RBIH and continue drilling ahead......... at 89 fph, WOB - 1.73, Circ Press - 4,051, WHP - 218, BHP - 3,924, IA - 435, OA - 383, CTW - 8.97 9/26/2016 9/26/2016 0.51 PROD1 DRILL WPRT P @ 13,005 ............ Stop here and 13,005.0 11,680.0 10:37 11:08 perform a wiper trip up to the 3.5 x 4.5 XO ........... only a slight weight bobble coming through window......... 9/26/2016 9/26/2016 0.78 PROD1 DRILL WPRT P @ 11,678.............RBIH to 11,680.0 13,005.0 11:08 11:55 bottom.............Tie in to RA marker make a +3' correction............ 9/26/2016 9/26/2016 0.70 PROD1 DRILL DRLG P @ 13,005 ............ BOBD ......... 1.5 bpm, 13,005.0 13,072.0 11:55 12:37 Circ Press = 4,259, WHP = 151, BHP = 3,883, IA = 456, OA = 385, 9.6 fph. WOB = 2.09 After drilling about 40' ahead hit something hard and ROP as slowed way down........... 9/26/2016 9/26/2016 4.38 PROD1 DRILL DRLG P Drilling withl.59 bpm, Circ Press = 13,072.0 13,072.0 12:37 17:00 4,381, BHP = 3,904, 4 fph. WOB = 1.9K 9/26/2016 9/26/2016 2.00 PROD1 DRILL DRLG P Drilling withl.56 bpm, Circ Press = 13,072.0 13,085.0 17:00 19:00 4,264, BHP = 3,958, 7 fph. WOB = 1.7K 9/26/2016 9/27/2016 5.00 PROD1 DRILL DRLG P Drilling withl.56 bpm, Circ Press = 13,085.0 13;222.0 19:00 00:00 4,211, BHP = 3,980, 57 fph. WOB = 1.7K 9/27/2016 9/27/2016 3.00 PROD1 DRILL DRLG P Drilling withl.54 bpm, Circ Press = 13,222.0 13,380.0 00:00 03:00 4,400, BHP = 3,954, 89 fph. WOB = 1.8K 9/27/2016 9/27/2016 0.75 PROD1 DRILL WPRT P Pulling a 1 000'wiper trip after drilling 13,380.0 13,380.0 03:00 03:45 L 1 380'. 9/27/2016 9/27/2016 6.85 PROD1 DRILL DRLG P BOBD with 1.53 bpm, Circ Press = 13,380.0 13,780.0 03:45 10:36 4,164, BHP = 3,946, 40 fph. WOB = 1.4K 9/27/2016 9/27/2016 0.55 PROD1 DRILL WPRT P Wiper trip up hole to 12,250 ft., PUW 13,780.0 12,250.0 10:36 11:09 39k. Page 5113 Report Printed: 10/10/2016 Operations Summary (with Timelog Depths) b 2M-08 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 (MB) End Depth (ftKB) 9/27/2016 9/27/2016 0.65 PROD1 DRILL WPRT P Wiper back in hole, RIW 1 O 12,250.0 13,780.0 11:09 11:48 9/27/2016 9/27/2016 8.20 PROD1 DRILL DRLG P BOBD- 1.5 bpm at 3,910 psi FS, BHP 13,780.0 14,180.0 11:48 20:00 3,932 psi, CWT 8.7k, WOB 1.4k, ROP 80, WHP 9, IA 550, OA 455. Note: Mud swap with new mud out bit at 13,925 ft. 9/27/2016 9/27/2016 1.25 PROD1 DRILL WPRT P 14,180 ft, Wiper up hole PUW 40k, 14,180.0 11,760.0 20:00 21:15 perform jog below EOB 12,000 ft - 12,100 ft, continue wiper up hole, pull up thru window, jog the 4.5" 11,690 ft - 11,730 ft 9/27/2016 9/27/2016 0.25 PROD1 DRILL DLOG P 11,760 ft, log RA correction of plus 7 ft 11,760.0 11,771.0 21:15 21:30 9/27/2016 9/27/2016 0.25 PROD1 DRILL WPRT P Perform Choke Calibration, holding 11,771.0 11,800.0 21:30 21:45 11.8 ppg at the window sensor depth (40' from bit) CP= 200 psi MWO= 8.66 ppg FO= 1.59 bpm BHP= 3689 psi 9/27/2016 9/27/2016 0.75 PROD1 DRILL WPRT P 11,800 ft, Wiper back in hole RIW 13k 11,800.0 14,180.0 21:45 22:30 9/27/2016 9/28/2016 1.50 PROD1 DRILL DRLG P 14,180 ft, BOBD 1.6 bpm at 3764 psi, 14,180.0 14,264.0 22:30 00:00 BHP 3968, IA 531, OA 434 9/28/2016 9/28/2016 4.00 PROD1 DRILL DRLG P 14,264 ft, OBD 1.54 bpm at 3890 psi, 14,264.0 14,433.0 00:00 04:00 BHP 3989, WHP 274, IA 572, OA 448 9/28/2016 9/28/2016 0.50 PROD1 DRILL WPRT P 14,433 ft, Wiper up hole to 13,430 ft. 14,433.0 13,430.0 04:00 04:30 PUW 41k 9/28/2016 9/28/2016 0.50 PROD1 DRILL WPRT P 13,430 ft, wiper back in hole RIW 1 O 13,430.0 14,433.0 04:30 05:00 9/28/2016 9/28/2016 3.65 PROD1 DRILL DRLG P 14,433 ft, BOBD 1.55 bpm at 3900 psi 14,433.0 14,681.0 05:00 08:39 FS, BHP 3945, WHP 56, IA 615, OA 475, pump 5x5 sweep 9/28/2016 9/28/2016 0.45 PROD1 DRILL WPRT P 14,681 ft. Wiper up hole, PUW 40k 14,681.0 13,481.0 0839 09:06 9/28/2016 9/28/2016 0.45 PROD1 DRILL WPRT P 13,480 ft. Wiper back in hole, RIW 13,481.0 14,681.0 09:06 09:33 8.Ok 9/28/2016 9/28/2016 3.75 PROD1 DRILL DRLG P 14,681 ft. BOBD 1.55 bpm at 3,960 14,681.0 14,822.0 09:33 13:18 FS, BHP 4,018, CWT 6k, WOB 1.4k, ROP84, WHP 54, IA 640, OA 514. weight issue, pump 5x5, pull 500 ft wiper at 14,775 ft., RBIH, ROP 75 for a short period, surface weight issues, pump 5x5. 9/28/2016 9/28/2016 4.75 PROD1 DRILL TRIP P 14,822 ft. POOH for Agitator and 14,822.0 69.2 13:18 18:03 motor, PUW 42k, perform jog below EOB 12,000 ft. -12,300 ft. continue POOH, pull up thru window, jet/jog the 4.5" 11,690 ft. -11,730 ft. continue POOH, open EDC at —4,600 ft. jet past Orbit Valve at 5 ft/hr, POOH. 9/28/2016 9/28/2016 1.50 PROD1 DRILL PULD P At surface, Close Orbit valve, monitor, 69.2 0.0 18:03 19:33 LD BHA #4, bit condition 1 -2 -BT -A -X-1 -PN-BHA 9/28/2016 9/28/2016 0.25 PROD1 DRILL PULD P PJSM, function test BOPE 0.0 0.0 19:33 19:48 Page 6113 Report Printed: 10/10/2016 a. Operations Summary (with Timelog Depths) 4 d t 2M-08 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) 9/28/2016 9/28/2016 2.00 PROM DRILL PULD P PJSM, MU L1 drilling assembly BHA# 0.0 78.3 19:48 21:48 5, with agitator 9/28/2016 9/29/2016 2.20 PROD1 DRILL TRIP P RIH, with drilling BHA# 5 78.3 9,948.0 21:48 00:00 9/29/2016 9/29/2016 0.25 PROM DRILL TRIP P 9,948 ft, continue RIH to tie in depth. 9,948.0 11,575.0 00:00 00:15 9/29/2016 9/29/2016 0.25 PROM DRILL DLOG P 11,575 ft, log the K1 correction of plus 11,575.0 11,639.0 00:15 00:30 10.0 ft, PUW 36k 9/29/2016 9/29/2016 1.40 PROD1 DRILL TRIP P 11,639 ft, continue trip in hole, RM 11,639.0 14,822.0 00:30 01:54 14k 9/29/2016 9/29/2016 7.80 PROD1 DRILL DRLG P 14,822 ft, OBD 1.4 bpm at 3985 psi, 14,822.0 15,111.0 01:54 09:42 BHP 4016, WHP 92, IA 450, OA 331, several BHA wipers, pump 5x5. 9/29/2016 9/29/2016 0.45 PROD1 DRILL WPRT P 15,111 ft. Wiper up hole, PUW 41 k, 15,111.0 14,000.0 09:42 10:09 2k overpull at 14,689 ft. no problem up thru 14,100 ft to 14,340 ft, no problem at 14,689 ft. 9/29/2016 9/29/2016 0.45 PROD1 DRILL WPRT P 14,000 ft, Wiper back in hole, RIW 5k, 14,000.0 15,111.0 10:09 10:36 no problems RBIH. 9/29/2016 9/29/2016 6.50 PROD1 DRILL DRLG P 15,111 ft, BOBD 1.5 bpm at 4,268 15,111.0 15,390.0 10:36 17:06 FS, BHP 4,080 psi, CWT 4.6k, WOB 1.5k, ROP 38, WHP 6, IA 600, OA 448, pump 5x5 for wiper trip. 9/29/2016 9/29/2016 2.00 PROD1 DRILL WPRT P 15,390 ft, wiper up hole PUW 40k, 15,390.0 15,390.0 17:06 19:06 RBIH stacked out at -15,120 ft, PUH, lower pump rate to 1.0 bpm, RBIH to 15,255 ft, wiper up hole at 25 fpm up to 14,950 ft, continue wiper back in hole 9/29/2016 9/29/2016 3.25 PROM DRILL DRLG P 15,390 ft, BOBD 1.5 bpm at 4189 psi, 15,390.0 15,512.0 19:06 22:21 BHP 4609, WHP 0, IA 637, OA 463 9/29/2016 9/30/2016 1.66 PROM DRILL WPRT P 15512 ft, wiper up hole performing jog 15,512.0 11,940.0 22:21 00:00 12,000 ft -12,200 ft, PUW 49 k 9/30/2016 9/30/2016 0.25 PROD1 DRILL WPRT P Continue wiper up hole thru window, 11,940.0 11,690.0 00:00 00:15 jet 4.5" up to 11,690 ft 9/30/2016 9/30/2016 0.15 PROD1 DRILL WPRT P RBIH, to tie in depth 11,690.0 11,758.0 00:15 00:24 9/30/2016 9/30/2016 0.25 PROM DRILL DLOG P 11,758 ft, log RA marker correction of 11,758.0 11,808.0 00:24 00:39 plus 5.0 ft 9/30/2016 9/30/2016 1.20 PROM DRILL WPRT P 11808 ft, continue wiper in hole, RIW 11,808.0 15,512.0 00:39 01:51 10k 9/30/2016 9/30/2016 2.90 PROM DRILL DRLG P 15,512 ft, BOBD 1.5 bpm at 4000 psi, 15,512.0 15,603.0 01:51 04:45 BHP 4031, WHP 0, IA 609, OA 423 9/30/2016 9/30/2016 0.20 PROD1 DRILL WPRT P 15,603 ft, short BHA wiper up hole to 15,603.0 15,603.0 04:45 04:57 15,250 ft. PUW 41k 9/30/2016 9/30/2016 2.50 PROM DRILL DRLG P 15,603 ft, BOBD 1.51 bpm @ 4,465 15,603.0 15,650.0 04:57 07:27 psi FS, BHP 4,170 psi, CWT -4.0k, WOB 1.2k, ROP 21, IA 618, OA 418 9/30/2016 9/30/2016 1.90 PROM DRILL WPRT P 15,650 ft. TD called. Wiper to window, 15,650.0 11,690.0 07:27 09:21 PUW 39k, 1 k over pull at 15,548 ft, pulled 2k heavy 15,000 ft to 14,930 ft at 25 fpm, nothing noticable thru upper high Gama area, Jog EOB 12,00 ft to 12,200 ft, pull up into and jog 4.5" BTP 11,690 ft to 11,735 ft. 9/30/2016 9/30/2016 0.25 PROD1 DRILL DLOG P RBIH, tie in to RA marker for a plus 11,690.0 11,791.0 09:21 09:36 4.5 ft correction. Page 7113 ReportPrinted: 10/10/2016 Operations Summary (with Timelog Depths) 2M-08 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) 9/30/2016 9/30/2016 1.55 PROM DRILL WPRT P RIH to confirm TD, stack at 15,455 ft, 11,791.0 15,650.0 09:36 11:09 RIH 30 fpm at .85 bpm, no WOB increase, PU 37k, stack and fell thru, TF transition L90 to R90 when drilling, confirm TD at 15,650 ft. 9/30/2016 9/30/2016 0.95 PROD1 DRILL CIRC P PUH circulating beaded liner running 15,650.0 15,650.0 11:09 12:06 pill to bottom, RBIH. 9/30/2016 9/30/2016 3.75 PROM DRILL TRIP P POOH laying in 45 bbl beaded liner 15,650.0 78.0 12:06 15:51 running pill / 8.6 ppg completion fluid to surface. paint flags at 13,630 ft and 7,900 ft. 9/30/2016 9/30/2016 1.75 PROD1 DRILL PULD P At surface, Close Orbit valve, monitor, 78.0 0.0 15:51 17:36 LD drilling BHA #5, bit condition: 9/30/2016 9/30/2016 1.00 COMPZ1 CASING PUTB P Prep rig floor for MU liner, crew 0.0 0.0 17:36 18:36 change, perform valve check list. 9/30/2016 9/30/2016 4.50 COMPZ1 CASING PUTB P PJSM, MU first L1 liner section with 63 0.0 1,874.8 18:36 23:06 jts of slotted liner 9/30/2016 10/1/2016 0.90 COMPZ1 CASING PULD P PJSM, MU Coiltrak tools, swap out 1,874.8 1,874.8 23:06 00:00 checks 10/1/2016 10/1/2016 0.25 COMPZ1 CASING PUTB P Continue MU Coiltrak tools, swap out 1,874.8 1,919.0 00:00 00:15 checks in upper quick ( both checks jammed open w/beads) 10/1/2016 10/1/2016 2.80 COMPZN CASING RUNL P 1919 ft, RIH with lower L1 liner section 1,919.0 11,616.0 00:15 03:03 with 63 jts of slotted liner and shorty deployment sleeve. 10/1/2016 10/1/2016 1.00 COMPZ1 CASING RUNL P 11,616 ft, corrected to the EOP flag 11,616.0 13,460.0 03:03 04:03 9700 ft. minus 2.6 ft PUW 35 k 10/1/2016 10/1/2016 0.25 COMPZ1 CASING DLOG P 13,460 ft, log the K1 correction of plus 13,460.0 13,484.0 04:03 04:18 5.5 ft, no correction made to counters. 10/1/2016 10/1/2016 0.65 COMPZ1 CASING RUNL P 13,484 ft, continue RIH to bottom 13,484.0 15,650.0 04:18 04:57 10/1/2016 10/1/2016 0.60 COMPZ1 CASING RUNL T L1 lower liner section on bottom 15,650.0 13,776.0 04:57 05:33 15,650 ft, PUW 39k,WOB -3.3k, Bring pump up to 1.5 bpm, PUW 34k, WOB -3.4k, loss of surface weight looks good but WOB did not change, 6 more various attempts with same results, confer with Prudhoe Baker rep., liner gone. reset counters to GS. 10/1/2016 10/1/2016 1.75 COMPZ1 CASING RUNL T 13,776 ft. POOH, PUW 40k, WOB- 13,776.0 12,538.6 05:33 07:18 3.3k, clean thru window but PUW 40k & WOB increasing to -6.2k at 10,671 ft. Confer with town. reset counters to liner shoe. 10/1/2016 10/1/2016 0.25 COMPZ1 CASING RUNL T 12,538 ft. RBIH, RIW 12k, WOB 1.6k 12,538.6 13,465.0 07:18 07:33 10/1/2016 10/1/2016 0.15 COMPZ1 CASING DLOG T Log K1 for a plus 7.5 ft correction, no 13,465.0 13,485.0 07:33 07:42 correction made to counters. 10/1/2016 10/1/2016 0.80 COMPZ1 CASING RUNL T Continue RIH to bottom. 13,485.0 15,650.0 07:42 08:30 10/1/2016 10/1/2016 0.45 COMPZ1 CASING RUNL T 15,650 ft. On bottom, PUW 37k, WOB 15,650.0 15,650.0 08:30 08:57 -3.3k, sat back down with Ok CWT, WOB +4.45k pump 1.6 bpm at 4,300 psi, PUW 34k, WOB -3.1k, 3 more attempts to release off liner appears to be unsuccessful. Page 8113 Report Printed: 10110/2016 ` Operations Summary (with Timelog Depths) 2M-08 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 (WS) 10/1/2016 10/1/2016 3.60 COMPZ1 CASING TRIP T POOH for liner, running tool check. 15,650.0 1,919.0 08:57 12:33 Stop and reset counters to GS, POOH paint flag at 9,700'. Continue POOH. 10/1/2016 10/1/2016 2.20 COMPZ1 CASING PULD T Tag up, space out, function closed 1,919.0 1,874.0 12:33 14:45 Orbit valve, monitor, PJSM- strip off wellhead, PU BHA to GS, no indication of why tool would not release, Shorty in new shape, inspect coil above CTC, pressure test coil to CTC to 800 psi, no leaks, BHA components appear competent. 10/1/2016 10/1/2016 1.25 COMPZ1 CASING PULD T PJSM- MU 2.63 OD Hyd GS and add 1,874.0 1,919.8 14:45 16:00 knuckle joint to BHA) make up to CoilTrak, lower QC neck un -torqued, changed out, surface test, strip on well, Open Orbit valve. 10/1/2016 10/1/2016 2.00 COMPZ1 CASING RUNL T RIH with lower L1 liner assembly on 1,919.8 11,521.0 16:00 18:00 BHA #7. 10/1/2016 10/1/2016 0.25 COMPZ1 CASING RUNL T Correct to the EOP flag (9,700 ft), 11,521.0 11,619.8 18:00 18:15 correction of plus 98.6 ft, realign INJH counter assembly PUW 33 k 10/1/2016 10/1/2016 1.50 COMPZ1 CASING RUNL T 11,620 ft, continue RIH 11,619.8 13,450.0 18:15 19:45 10/1/2016 10/1/2016 0.25 COMPZi CASING DLOG T 13,450 ft, Log the K1 correction of 13,450.0 13,491.0 19:45 20:00 plus 10.0 ft, 10/1/2016 10/1/2016 0.38 COMPZ1 CASING RUNL T 13,491 ft, continue RIH 13,491.0 15,550.0 20:00 20:22 10/1/2016 10/1/2016 0.25 COMPZ1 CASING RUNL T 15,550 ft, PUW 39.5 k, continued RIH, 15,550.0 15,650.0 20:22 20:37 brought pump up to 1.44 bpm, set down - 2 k CTSW, PUW 31 k, remove liner length from BHA 10/1/2016 10/1/2016 2.82 COMPZ1 CASING TRIP P 15,650 ft, POOH 15,650.0 45.0 20:37 23:27 10/1/2016 10/2/2016 0.55 COMPZ1 CASING PULD P At surface, function closed Orbit valve 45.0 45.0 23:27 00:00 (975 psi), PJSM, for LD liner running BHA 10/2/2016 10/2/2016 0.35 COMPZ1 CASING PULD P LD lower liner running BHA# 6 45.0 0.0 00:00 00:21 10/2/2016 10/2/2016 0.50 COMPZ1 CASINC, PUTB P Prep rig floor for MU upper liner 0.0 0.0 00:21 00:51 section, PJSM 10/2/2016 10/2/2016 3.15 COMPZ1 CASING PUTB P MU L1 upper liner section 0.0 1,798.5 00:51 04:00 10/2/2016 10/2/2016 1.60 COMPZ1 CASING PULD P PU/MU Coiltrak tools with OH 1,798.5 1,872.0 04:00 05:36 Anchored Billet 10/2/2016 10/2/2016 2.70 COMPZ1 CASING RUNL P RIH with L1-01 upper liner section and 1,872.0 11,668.5 05:36 08:18 OH Anchored Billet, EDC open, Open Orbit valve. 10/2/2016 10/2/2016 0.20 COMPZ1 CASING RUNL P Plus 4.3 ft correction at 9,800 ft EOP 11,668.5 11,672.8 08:18 08:30 flag, close EDC, PUW 38k, WOB -6.4k above window. 10/2/2016 10/2/2016 0.80 COMPZ1 CASING RUNL P 11,672.8 ft. Continue RIH. 11,672.8 13,400.0 08:30 09:18 10/2/2016 10/2/2016 0.20 COMPZ1 CASING DLOG P Log K1 5 fpm for plus 4 ft correction, 13,400.0 13,440.0 09:18 09:30 did not reset counters. 10/2/2016 10/2/2016 0.20 COMPZ1 CASING RUNL P Continue in hole to bottom, slight 13,440.0 13,772.0 09:30 09:42 I bobble thru window. Page 9/13 Report Printed: 1 011 012 01 6 Operations Summary (with Timelog Depths) a 2M-08 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 (MB) 10/2/2016 10/2/2016 0.25 COMPZ1 CASING RUNL P 13,772 ft. on bottom with upper liner 13,772.0 11,962.0 09:42 09:57 assembly, HOT issue, PUW 41 k, reorientate single slip to 157° ROHS, release off liner at 4,400 psi, PUW 35k, reset counters to setting tool, top of liner at 11,962 ft. 10/2/2016 10/2/2016 3.05 COMPZI CASING TRIP P 11,962 ft, POOH, at 2,300 ft choke not 11,962.0 1,044.0 09:57 13:00 responding, 1,044 ft stop, closed Orbit valve, no flow good, troubleshoot choke issue, POOH, functioning choke, all good. NOTE: Nabors down 30 minutes servicing choke. 10/2/2016 10/2/2016 1.00 COMPZI CASING PULD P On surface, PJSM- no flow good, LD 62.6 0.0 13:00 14:00 BHA #8, off load Baker tools. 10/2/2016 10/2/2016 4.00 PROD2 DRILL CTOP P PJSM- Cut 23 ft coil, flat spot 3-6 ft 0.0 0.0 14:00 18:00 above CTC .086", gouge in coil 13-14 ft up. prep coil and re -head CTC, pull test 50k, rehead and test, PIT 4,500 psi. 10/2/2016 10/2/2016 1.50 PROD2 STK PULD P Crew change, perform valve check 0.0 72.2 18:00 19:30 list, PU/MU L1-01 kickoff/drilling BHA with 0.5° bend motor and RB RWD bi- center bit. 10/2/2016 10/2/2016 2.75 PROD2 STK TRIP P Function open the Orbit valve, RIH L1- 72.2 11,595.0 19:30 22:15 01 kickoff/drilling BHA# 9 10/2/2016 10/2/2016 0.25 PROD2 STK DLOG P 11,595 ft, Log K1 correction plus 15.5 11,595.0 11,631.0 22:15 22:30 ft. PUW 34 k 10/2/2016 10/2/2016 0.75 PROD2 STK TRIP P 11,631 ft, continue RIH dry tag TOB at 11,631.0 11,962.0 22:30 23:15 11,962 ft. 10/2/2016 10/3/2016 0.75 PROD2 STK KOST P Back ream 11,961 ft up to 11,938 ft, 11,962.0 23:15 00:00 Start time milling as per procedure, Stalled motor, PUH, start again, 1.38 bpm at 3740 psi, BHP 3853, WHP 56, IA 166, OA 73 10/3/2016 10/3/2016 1.20 PROD2 STK KOST P Continue to kickoff billet 11,963.0 11,972.0 00:00 01:12 10/3/2016 10/3/2016 0.85 PROD2 DRILL DRLG P 11,972 ft, drill build section, 1.4 bpm at 11,972.0 12,000.0 01:12 02:03 3883 psi, BHP 3865, WHIP 56, IA 215, OA 104 10/3/2016 10/3/2016 0.25 PROD2 DRILL WPRT P 12,000 ft, wiper above billet (clean), 12,000.0 11,940.0 02:03 02:18 PUW 34 k, RBIH 10/3/2016 10/3/2016 0.25 PROD2 DRILL WPRT P 11,940 ft, dry drift billet area, (clean), 11,940.0 12,000.0 02:18 02:33 wiper back in hole, RIW 9 k 10/3/2016 10/3/2016 1.25 PROD2 DRILL DRLG P 12,000 ft, BOBD 1.41 bpm at 3883 12,000.0 12,084.0 02:33 03:48 psi, BHP 3868, WHIP 57, IA 215, OA 107 10/3/2016 10/3/2016 0.50 PROD2 DRILL WPRT P 12,084 ft, TD build section, PUH, 12,084.0 12,084.0 03:48 04:18 PUW 35 k, pump 5x5 sweep 10/3/2016 10/3/2016 2.65 PROD2 DRILL TRIP P POOH, with Build Section BHA# 9, 12,084.0 72.2 04:18 06:57 performing jog in the 4.5" to clean BTP 10/3/2016 10/3/2016 1.65 PROD2 DRILL PULD P On surface, close Orbit valve, flow 72.2 0.0 06:57 08:36 check, PJSM- found two 2" gouges in pipe 16 & 17 ft above CTC, LD BHA #9, bit condition: 1 -1 -NO-X-I-NO-BHA Page 10113 Report Printed: 10/10/2016 "- Operations Summary (with Timelog Depths) 2M-08 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) 10/3/2016 10/3/2016 1.50 PROD2 DRILL PULD P PJSM- MU BHA #10 a Weatherford 0.0 74.7 08:36 10:06 0.5° motor with RB HYC B7 Durafource Edge (4-9's) Bi-center bit, changed out both lower floats, MU to Coiltrak, change out pack-offs, surface test, open Orbit valve. 10/3/2016 10/3/2016 2.35 PROD2 DRILL TRIP P RIH with BHA #10 74.7 11,580.0 10:06 12:27 10/3/2016 10/3/2016 0.20 PROD2 DRILL DLOG P Tie in at K1 for plus 15.5 ft correction, 11,580.0 11,620.0 12:27 12:39 Close EDC, PUW 35k 10/3/2016 10/3/2016 0.20 PROD2 DRILL TRIP P RBIH with BHA #10, SO 2k passing 11,620.0 12,084.0 12:39 12:51 billet at 11,962 ft. 10/3/2016 10/3/2016 5.20 PROD2 DRILL DRLG P 12,084 ft. OBD 1.5 bpm at 4,200 psi 12,084.0 12,580.0 12:51 18:03 FS, BHP 3,833 psi, CWT 3.0k, WOB 1.8k, ROP 80, WHP 6, IA 182, OA 90. New mud around OBD 1.5 bpm at 3,848 FS, BHP 3,835 psi, CWT -2k, WOB 3.26k, ROP 155, WHP 195, IA 360, OA 200 NOTE: Mud swap, mud system #3 out bit at 12,314 ft. 10/3/2016 10/3/2016 0.30 PROD2 DRILL WPRT P Wiper up hole 500 ft, PUW 34k 12,580.0 12,080.0 18:03 18:21 10/3/2016 10/3/2016 0.25 PROD2 DRILL WPRT P Wiper in hole, RIW 7.5k 12,080.0 12,580.0 18:21 18:36 10/3/2016 10/3/2016 4.10 PROD2 DRILL DRLG P 12,580 ft. BOBD 1.50 bpm at 3,853 12,580.0 12,980.0 18:36 22:42 psi FS, BHP 3,835 psi, CWT 3.0k, WOB 1.8k, ROP 80, WHP 192, IA 410, OA 240, pump 5x5 sweep. 10/3/2016 10/3/2016 1.10 PROD2 DRILL WPRT P Wiper to 12,100 ft. PUW 32k, Jog at 12,980.0 11,690.0 22:42 23:48 EOB 12,100 to 12,300 ft, PU into tail pipe, Jog 4.5" BTP from 11,690 ft. 10/3/2016 10/4/2016 0.20 PROD2 DRILL DLOG P Log RA for plus 1.5 ft correction. 11,690.0 11,780.0 23:48 00:00 10/4/2016 10/4/2016 0.75 PROD2 DRILL WPRT P Wiper trip back in hole 11,780.0 12,980.0 00:00 00:45 10/4/2016 10/4/2016 4.75 PROD2 DRILL DRLG P 12,980 ft, BOBD 1.5 bpm at 4092 psi, 12,980.0 13,380.0 00:45 05:30 BHP 3897, WHP 149, IA 502, OA 323 10/4/2016 10/4/2016 0.65 PROD2 DRILL WPRT P 13,380 ft, wiper up hole, PUW 32 k 13,380.0 12,300.0 05:30 06:09 10/4/2016 10/4/2016 0.50 PROD2 DRILL WPRT P 12,300 ft, wiper back in hole, RIW 8 k 12,300.0 13,380.0 06:09 06:39 10/4/2016 10/4/2016 5.50 PROD2 DRILL DRLG P 13,380 ft, BOBD 1.5 bpm at 4064 psi, 13,380.0 13,780.0 06:39 12:09 BHP 3927, WHP 97, IA 565, OA 383 10/4/2016 10/4/2016 0.50 PROD2 DRILL WPRT P 13,780 ft, wiper up hole PUW 33 k 13,780.0 12,680.0 12:09 12:39 10/4/2016 10/4/2016 0.50 PROD2 DRILL WPRT P 12,680 ft, wiper back in hole, RIW 5 k 12,680.0 13,780.0 12:39 13:09 10/4/2016 10/4/2016 3.85 PROD2 DRILL DRLG P 13,780 ft, BOBD 1.5 bpm at 4080 psi, 13,780.0 13,990.0 13:09 17:00 BHP 3908, WHP 0, IA 613, OA 415 10/4/2016 10/4/2016 0.50 PROD2 DRILL WPRT P 13,990 ft. Wiper trip up to RA. PUW 13,990.0 11,700.0 17:00 17:30 34 Klbs. 10/4/2016 10/4/2016 2.00 PROD2 DRILL WPRT P 11,700 ft. Wiper back in hole. RIW = 5 11,700.0 13,990.0 17:30 19:30 Klbs. Jog across 4-1/2" BTP. Tie into RA for +4.5 ft correction. Bleed OA to 0 psi and IA to 200 psi. Page 11/13 Report Printed: 10/10/2016 Operations Summary (with Timelog Depths) 2M-08 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 (WEI) End Depth (W13) 10/4/2016 10/5/2016 4.50 PROD2 DRILL DRLG P 13,990 ft, BOBD 1.5 bpm at 4150 psi, 13,990.0 14,158.0 19:30 00:00 BHP 3900, WHP 0, IA=210, OA=O. Mud swap, new mud at bit at 14,040 ft. 10/5/2016 10/5/2016 0.25 PROD2 DRILL WPRT P BHA Wiper. PUW = 32 Klbs 14,158.0 13,650.0 00:00 00:15 10/5/2016 10/5/2016 0.25 PROD2 DRILL WPRT P Wiper back in the hole. RIW=5KIbs. 13,650.0 14,158.0 00:15 00:30 10/5/2016 10/5/2016 2.00 PROD2 DRILL DRLG P Continue drilling ahead. 14,158.0 14,290.0 00:30 02:30 10/5/2016 10/5/2016 0.50 PROD2 DRILL WPRT P Short wiper to try and maintain weight 14,290.0 13,300.0 02:30 03:00 transfer. PUW = 33KIbs While pulling up at 13660 ft, observed increase in PUW to 39KIbs. 10/5/2016 10/5/2016 0.50 PROD2 DRILL WPRT P Wiper back in the hole. RIW = 5.51<Ibs 13,000.0 14,290.0 03:00 03:30 10/5/2016 10/5/2016 3.25 PROD2 DRILL DRLG P BOBD 1.55 bpm at 4250 psi, BHP 14,290.0 14,360.0 03:30 06:45 3995, WHP 190, IA 270, OA 70 ROP 50-60 fph. WOB 1 Klbs. CTW between 0 and-4.5KIbs. 10/5/2016 10/5/2016 0.25 PROD2 DRILL WPRT P 500 wiper up hole PUW 32 k 14,360.0 13,860.0 06:45 07:00 10/5/2016 10/5/2016 0.25 PROD2 DRILL WPRT P Wiper back in hole, RIW 5 k 13,860.0 14,360.0 07:00 07:15 10/5/2016 10/5/2016 2.75 PROD2 DRILL DRLG P BOBD 1.31 bpm at 3869 psi, BHP 14,360.0 14,360.0 07:15 10:00 4455, WHP 226, IA 270, OA 67 Difficult drilling pump 25 bbl beaded pill, still no help on cosistant WOB. discuss with town plan forward. 10/5/2016 10/5/2016 3.50 PROD2 DRILL TRIP P Decision was made to POOH, to PU 14,360.0 74.7 10:00 13:30 agitator and new motor, perform jog below EOB, pull up thru widnow, perform jog in 4.5", open EDC, POOH, jetting Orbit valve. 10/5/2016 10/5/2016 1.00 PROD2 DRILL PULD P At surface, monitor well for flow (15 74.7 0.0 13:30 14:30 min), LD drilling BHA# 10 10/5/2016 10/5/2016 1.25 PROD2 DRILL PULD P PU/MU L1-01 drilling BHA# 11 0.0 78.3 14:30 15:45 10/5/2016 10/5/2016 4.00 PROD2 DRILL TRIP P RIH, L1-01 drilling BHA# 11 w/ 78.3 14,360.0 15:45 19:45 agitator and RB bi-center bit. Tie-in to the K1 for a +1 Oft correction. Taking weight at 11,962 ft. PU and run back through with slight weight bobble. 10/5/2016 10/5/2016 3.75 PROD2 DRILL DRLG P BOBD. 1.45 bpm at 4200 psi, BHP 14,360.0 14,440.0 19:45 23:30 3980, WHP 120, IA 131, OA 23 CTW = (-)5KIbs. WOB = 1-1.5KIbs. 10/5/2016 10/5/2016 0.25 PROD2 DRILL WPRT P BHA wiper to help improve weight 14,440.0 14,440.0 23:30 23:45 transfer. PUW = 36KIbs. 10/5/2016 10/6/2016 0.25 PROD2 DRILL DRLG P BOBD 1.45 bpm at 4230 psi, BHP 14,440.0 14,447.0 23:45 00:00 4000, WHP 120, IA 130, OA 23 CTW = (-)5KIbs. WOB = 1-1.5KIbs. Add 60bbls of new 8.5ppg flo-pro to active. Page 12/13 Report Printed: 10/10/2016 Operations Summary (with Timelog Depths) 2M-08 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) 10/6/2016 10/6/2016 9.00 PROD2 DRILL DRLG P BOBD 1.40 bpm at 4300 psi, BHP 14,447.0 14,509.0 00:00 09:00 4000, WHP 120, IA 130, OA 23 CTW = (-)5 to (-)5.5KIbs. WOB = 1-2.5KIbs. Begin pumping 20bbl pills of 1 ppb beads followed by 20 bbls mud from active. Some improvement observed in weight transfer. 10/6/2016 10/6/2016 1.75 PROD2 DRILL WPRT P 14,509 ft, TD L1-01 lateral, pump 14,509.0 11,692.0 09:00 10:45 1 0x1 0 sweep, IA 149, OA 34, pull wiper up hole, jet 4.5", RBIH to logging depth 10/6/2016 10/6/2016 0.25 PROD2 DRILL DLOG P Log RA marker correction of plus 1.0 11,692.0 11,796.0 10:45 11:00 ft. 10/6/2016 10/6/2016 1.50 PROD2 DRILL WPRT P Wiper back in hole RIW 8 k confirmed 11,796.0 14,503.0 11:00 12:30 TD 14,503 ft, 10/6/2016 10/6/2016 1.00 PROD2 DRILL DISP P Lay in liner running pill 14,503.0 11,450.0 12:30 13:30 10/6/2016 10/6/2016 2.25 PROD2 DRILL TRIP P Continue POOH 11,450.0 78.3 13:30 15:45 10/6/2016 10/6/2016 0.50 PROD2 DRILL OWFF P At surface, function closed orbit valve, 78.3 78.3 15:45 16:15 check well for flow. Static. 10/6/2016 10/6/2016 1.00 PROD2 DRILL PULD P LD BHA #11. Bit grade 2 -1 -BT -N -X-1- 78.3 0.0 16:15 17:15 WT -TD. 10/6/2016 10/6/2016 5.50 COMPZ2 CASING PULD P Prep rig floor. PU 94 joints of 2-3/8" 0.0 2,796.6 17:15 22:45 slotted liner. MU CoilTrak BHA. Surface test. Good. Strip injector over stump. 10/6/2016 10/7/2016 1.25 COMPZ2 CASING RUNL P RIH with liner. 2,796.6 6,995.0 22:45 00:00 10/7/2016 10/7/2016 2.50 COMPZ2 CASING RUNL P Continue running in the hole with 2- 6,995.0 14,498.0 00:00 02:30 3/8" slotted liner. Tie-in to window flag for +8.5 ft correction. Tie-in to TD flag for no correction. Tie-in to K1 for no correction. Weight check at 14,466 ft. PUW = 35KIbs. Position liner on depth at 14,498 ft. TOL at 11,745 ft. Release from liner per Baker rep. PUW after release = 29KIbs. 10/7/2016 10/7/2016 3.00 DEMOB WHDBOP DISP P Reset depth. Open EDC, displace well 14,498.0 11,724.0 02:30 05:30 over to seawater. 10/7/2016 10/7/2016 1.75 DEMOB WHDBOP FRZP P Freeze protect well from 2500', POOH 11,724.0 45.0 05:30 07:15 10/7/2016 10/7/2016 1.00 DEMOB WHDBOP PULD P LD Liner running BHA 45.0 0.0 07:15 08:15 10/7/2016 10/7/2016 1.50 DEMOB WHDBOP RURD P Blow reel and surface lines down, 0.0 0.0 08:15 09:45 unload fluids from the pits. 10/7/2016 10/7/2016 5.00 DEMOB WHDBOP RURD P Work on rig move checklist 0.0 0.0 09:45 14:45 10/7/2016 10/7/2016 2.75 DEMOB WHDBOP RURD P Trucks on location, PJSM for loading 0.0 0.0 14:45 17:30 and moving shop to 213 -pad 10/7/2016 10/8/2016 6.50 DEMOB WHDBOP RURD P PJSM, Move Sub and pits off of well 0.0 0.0 17:30 00:00 and stage modules in the center of pad for post workover work. 10/8/2016 10/8/2016 6.00 MIRU WHDBOP RURD P RDMO well, perform post workover 0.0 0.0 00:00 06:00 work in cellar, remove flow -box, swap out annular, pull AC unit from dog house wall, install window back in dog house, remove BOPE pedistal from cellar, and re -install gang box . Page 13/13 Report Printed: 1 011 0/2 01 6 ConocoPhillips ConocoPhillips (Alaska) Inc. -Kup2 Kuparuk River Unit Kuparuk 2M Pad 2M -08L1 50-103-20184-63 Baker Hughes INTEQ NFAI BAKER Definitive Survey Report HUGHES 14 October, 2016 ✓hillps Conoco ConocoPhillips WON BAKER Definitive Survey Report HUGHES Company: ConocoPhillips (Alaska) Inc. -Kup2 Local Coordinate Reference: Well 2M-08 Project: Kuparuk River Unit TVD Reference: 2M-08 @ 147,00usft (P245) Site: Kuparuk 2M Pad MO Reference: 2M-08 @ 147.00usft (P245) Well: 2M-08 North Reference: True Wellbore: 2M-0811 Survey Calculation Method: Minimum Curvature Design: 2M-0811 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 2M-08 Well Position +N/ -S 0.00 usft Northing: 5,948,985.84usft Latitude: 70° 16' 18.579 N +E/ -W 0.00 usft Easting: 487,949.23usft Longitude: 150° 5'50.870 W Position Uncertainty 0.00 usft Wellhead Elevation: usft Ground Level: 105.50 usft Wellbore 2M -08L1 Magnetics Model Name Sample Date Declination Dip Angie Field Strength (°) (1) W) BGGM2016 1011/2016 17.84 80.88 57,537 Design 2M-0811 Audit Notes: Version: 1.0 Phase: ACTUAL Tie On Depth: 11,740.89 Vertical Section: Depth From (TVD) +WS +E/.W Direction (usft) {usft) (usft) (1) 41.50 0.00 0.00 180.00 Survey Program Date 10/12/2016 From To Survey Survey (usft) (usft) Survey (Wellbore) Tool Name Description Start Date End Date 151.90 11,740.89 2M-08 Srvy 1 - GCT -MS (2M-08) GCT -MS Schlumberger GCT multishot 11/16/1992 11/16/1992 11,745.00 15,616.13 2M-0811 (2M-081-1) MWD MWD - Standard 9/24/2016 9/30/2016 1011412016 10 03:38AM Page 2 COMPASS 5000.1 Build 74 it I ConocoPhillips ConocoPhillips BAKER R Definitive Survey Report HUGHES Company: ConocoPhillips (Alaska) Inc. -Kup2 Local Co-ordinate Reference: Well 2M-08 Project: Kupamk River Unit TVD Reference: 2M-08 @ 147.00ustt (P245) Site: Kupamk 2M Pad MD Reference: 2M-08 @ 147.00usn (P245) Well: 2M-08 North Reference: True Wellbore: 2M-081-1 Survey Calculation Method: Minimum Curvature Design: 2M -08L1 Database: EDM Alaska NSK Sandbox Survey Annotation TIP KOP 10/142016 10: 03: 38AM Page 3 COMPASS 5000.1 Build 74 map Map Vertical MD Inc Azi TND TNDSS +N/ -S +E1 -W NOipling Fasting DLS Section Survey Too] Name (.usn) l°t E°l iu�tj (��) Min) tusttf iftJ (hi 1°1100) thl 11,140.89 41.11 185.37 6,167.94 6,020.94 -9,313.44 -855.55 5,939,674.71 487,078.85 1.16 9,313.44 MWD (2) 11,745.00 41.17 185.38 6,171.03 6,024.03 -9,316.13 -855.80 „-5,939,672.02 X487,078.60 1.47 9,316.13 MWD (2) 11,777.60 51.35 185.38 6,193.54 6,046.54 -9,339.55 -858.01 5,939,648.61 487,076.35 31.23 9,339.55 MWD (2) 11,807.27 64.16 183.00 6,209.34 6,062.34 -9,364.53 -859.80 5,939,623.64 487,074.52 43.70 9,364.53 MWD (2) 11,837.51 72.71 172.07 6,220.47 6,073.47 -9,392.54 -858.52 5,939,595.63 487,075.76 43.88 9,392.54 MAID (2) 11,871.02 87.73 171.93 6,226.15 6,079.15 -9,425.15 -853.93 5,939,563.01 487,080.29 44.82 9,425.15 MWD (2) 11,901.05 95.78 165.96 6,225.23 6,078.23 -9,454.57 -848.19 5,939,533.59 487,085.99 33.36 9,454.57 MWD (2) 11,930.14 99.75 153.89 6,221.28 6,074.29 -9,481.59 -838.33 5,939,506.55 487,095.80 43.31 9,481.59 MWD (2) 11,960.18 101.43 140.04 6,215.74 6,068.74 -9,506.29 -822.28 5,939,481.83 487,111.81 45.66 9,506.29 MWD (2) 11,990.25 96.30 128.14 6,211.09 6,064.09 -9,526.90 -800.97 5,939,461.19 487,133.08 42.65 9,526.90 MWD (2) 12,020.39 96.14 122.81 6,207.82 6,060.82 -9,544.28 -776.58 5,939,443.77 487,157.44 17.59 9,544.28 MWD (2) 12,050.35 95.28 120.61 6,204.84 6,057.84 -9,559.95 -751.22 5,939,428.06 487,182.78 7.85 9,559.95 MWD (2) 12,080.37 95.38 121.54 6,202.05 6,055.05 -9,575.38 -725.62 5,939,412.60 487,208.35 3.10 9,575.38 MWD (2) 12,110.43 95.44 122.88 6,199.22 6,052.22 -9,591.33 -700.30 5,939,396.61 487,233.64 4.44 9,591.33 MWD (2) 12,140.45 95.54 124.42 6,196.35 6,049.35 -9,607.88 £75.43 5,939,380.01 487,258.49 5.12 9,607.88 MWD (2) 12,170.46 95.53 126.00 6,193.45 6,046.45 -9,625.11 -651.02 5,939,362.75 487,282.86 5.24 9,625.11 MWD (2) 12,200.48 96.52 125.94 6,190.30 6,043.30 -9,642.64 -626.86 5,939,345.18 487,306.99 3.30 9,642.64 MWD (2) 12,230.32 97.54 127.20 6,186.65 6,039.65 -9,660.28 -603.08 5,939,327.50 487,330.75 5.41 9,660.28 MWD (2) 12,260.47 97.08 127.94 6,182.81 6,035.81 -9,678.52 -579.38 5,939,309.23 487,354.42 2.87 9,678.52 MWD (2) 12,290.37 96.59 129.38 6,179.25 6,032.25 -9,697.06 -556.19 5,939,290.65 487,37257 5.05 9,697.06 MWD (2) 12,320.56 94.77 130.58 6,176.26 6,029.26 -9,716.37 -533.18 5,939,27131 487,400.55 7.21 9,716.37 MWD (2) 12,352.51 92.67 132.29 6,174.19 6,027.19 -9,73246 509.28 5,939,250.18 487,424.41 8.47 9,737.46 MWD (2) 12,380.59 91.54 133.20 6,173.16 6,026.16 -9,756.51 488.67 5,939,231.10 487,444.99 5.17 9,756.51 MWD (2) 12,410.25 90.15 135.15 6,172.72 6,025.72 -9,777.17 -467.40 5,939,210.41 487,466.22 8.07 9,777.17 MWD (2) 12,440.27 88.43 135.99 6,173.09 6,026.09 -9,798.61 -446.39 5,939,188.94 487,487.20 6.38 9,798.61 MWD (2) 12,470.56 88.10 135.82 6,174.01 6,027.01 -9,820.35 425.32 5,939,167.16 487,508.23 1.23 9,820.35 MWD (2) 12,501.33 87.76 139.10 6,175.12 6,028.12 -9,843.01 404.53 5,939,144.48 487,528.98 10.71 9,843.01 MWD (2) 12,530.58 87.91 140.62 6,176.23 6,029.23 -9,865.35 -385.69 5,939,122.11 487,547.78 5.22 9,865.35 MWD (2) 12,560.51 88.10 141.45 6,177.27 6,030.27 -9,888.61 -366.88 5,939,098.82 487,566.55 2.84 9,888.61 MWD (2) 12,590.39 88.86 142.07 6,178.06 6,031.06 -9,912.07 -348.39 5,939,075.34 487,585.00 3.28 9,912.07 MWD (2) Annotation TIP KOP 10/142016 10: 03: 38AM Page 3 COMPASS 5000.1 Build 74 ConocoPhillips Ilf�l11 ConocoPhillips BAKER Definitive Survey Report HUGHES Company: ConocoPhillips (Alaska) Inc. -Kup2 Local Coordinate Reference: Well 2M-08 protect: Kuparuk River Unit TVD Reference: 2M-08 @ 147.00usft (P245) Site: Kuparuk 2M Pad MD Reference: 2M-08 @ 147.00usft (P245) Well: 2M-08 North Reference: True Wellbore: 2M -08L1 Survey Calculation Method: Minimum Curvature Design: 2M -08L1 Database: EDM Alaska NSK Sandbox Survey 10/142016 10:03: 38AM Page 4 COMPASS 5000.1 Build 74 MAP Map Vertical MD Inc Azt TVD TVDSS +N/ -S +Ef-W Northing Fasting DLS Section survey Tool Name Annotation NIM (`j (") (usftj (usft) (usft) (u�) (►tl (it) (°YI00') (ft) 12,620.39 89.82 143.23 6,178.41 6,031.41 -9,935.91 -330.19 5,939,05146 487,603.16 5.02 9,935.91 MWD (2) 12,65047 90.49 143.95 6,178.33 6,031.33 -9,960.12 -312.34 5,939,027.23 487,620.97 3.27 9,960.12 MWD (2) 12,680.21 90.86 144.83 6,177.98 6,030.98 -9,984.30 -295.03 5,939,003.03 487,638.25 3.21 9,984.30 MWD (2) 12,710.31 91.54 146.29 6,177.35 6,030.35 -10,009.12 -278.01 5,938,978.18 487,655.23 5.35 10,009.12 MWD(2) 12,740.42 92.21 147.37 6,176.36 6,029.36 -10,034.31 -261.54 5,938,952.97 487,671.65 4.22 10,034.31 MWD (2) 12,771.55 91.69 148.64 6,175.30 6,028.30 -10,060.69 -245.06 5,938,926.56 487,688.09 4.41 10,060.69 MWD (2) 12,800.47 91.84 149.70 6,174.41 6,027.41 -10,085.51 -230.24 5,938,901.72 487,702.86 3.70 10,085.51 MWD (2) 12,830.65 92.33 149.34 6,173.31 61026.31 -10,111.50 -214.95 5,938,875.71 487,718.12 2.01 10,111.50 ID (2) 12,860.75 91.75 149.16 6,172.24 6,025.24 -10,137.36 -199.57 5,938,849.83 487,733.45 2.02 10,137.36 MWD (2) 12,890.25 91.96 148.89 6,171.29 6,024.29 -10,162.63 -184.39 5,938,824.53 487,748.59 1.16 10,162.63 MWD (2) 12,920.67 91.35 150.85 6,170.41 6,023.41 -10,188.93 -169.13 5,938,798.21 487,763.81 6.75 10,188.93 MWD (2) 12,950.58 92.33 150.66 6,169.45 6,022.45 -10,215.02 -154.52 5,938,772.11 487,778.37 3.34 10,215.02 MWD (2) 12,980.67 91.60 150.72 6,168.42 6,021.42 -10,241.24 -139.80 5,938,745.86 487,793.04 2.43 10,241.24 MWD (2) 13,010.23 91.14 152.10 6,167.71 6,020.71 -10,267.19 -125.66 5,938,719.90 487,807.14 4.92 10,267.19 MWD (2) 13,040.28 91.14 153.59 6,167.11 6,020.11 -10,293.92 -111.95 5,938,693.15 487,820.81 4.96 10,293.92 MWD (2) 13,070.13 90.28 154.99 6,166.74 6,019.74 -10,320.81 -99.00 5,938,666.24 487,833.71 5.50 10,320.81 MWD (2) 13,100.76 87.67 155.89 6,167.29 6,020.29 -10,348.66 -86.27 5,938,638.37 487,846.40 9.01 10,348.66 MWD (2) 13,130.75 87.54 156.23 6,168.54 6,021.54 -10,376.05 -74.12 5,938,610.96 487,858.51 1.21 10,376.05 MWD (2) 13,160.41 88.07 157.34 6,169.68 6,022.68 -10,403.29 -62.43 5,938,583.71 487,870.15 4.14 10,403.29 MWD(2) 13,190.40 88.31 159.25 6,170.63 6,023.63 -10,431.13 -51.35 5,938,555.85 487,881.19 6.42 10,431.13 MWD (2) 13,220.44 88.74 161.82 6,171.40 6,024.40 -10,459.45 -41.34 5,938,527.52 487,891.15 8.67 10,459.45 MWD (2) 13,250.35 89.48 162.53 6,171.86 6,024.86 -10,487.92 -32.19 5,938,499.04 487,900.25 3.43 10,487.92 MWD (2) 13,280.33 89.69 160.48 6,172.08 6,025.08 -10,516.34 -22.68 5,938,470.60 487,909.72 6.87 10,516.34 MWD (2) 13,310.53 91.07 160.87 6,171.88 6,02488 -10,544.84 -12.68 5,938,442.09 487,919.66 4.75 10,544.84 MWD (2) 13,340.62 91.32 162.49 6,171.25 6,024.25 -10,573.40 -3.23 5,938,413.52 487,929.07 5.45 10,573.40 MWD (2) 13,370.75 90.92 163.43 6,170.66 6,023.66 -10,602.20 5.60 5,938,384.70 487,937.85 3.39 10,602.20 MWD (2) 13,400.82 90.86 163.92 6,170.20 6,023.20 -10,631.06 14.05 5,938,355.84 487,946.26 1.64 10,631.06 MWD (2) 13,430.92 91.08 165.71 6,169.69 6,022.69 -10,660.10 21.93 5,938,326.79 487,954.09 5.99 10,660.10 MWD (2) 13,460.71 91.17 165.47 6,169.10 6,022.10 -10,688.95 29.35 5,938,297.93 487,961.46 0.86 10,688.95 MWD (2) 13,490.31 91.54 165.52 6,168.40 6,021.40 -10,717.59 36.76 5,938,269.27 487,968.82 1.26 10,717.59 MWD (2) 13,520.26 90.21 166.61 6,167.95 6,020.95 -10,746.66 43.97 5,938,240.20 487,975.99 5.74 10,746.66 MWD (2) 10/142016 10:03: 38AM Page 4 COMPASS 5000.1 Build 74 ConocoPhillips ConocoPhillips Definitive Survey Report Company: ConocoPhillips (Alaska) Inc. -Kup2 Local Coordinate Reference: Well 2M-08 Project: Kuparuk River Unit TVD Reference: 2M-08 @ 147.00usft (P245) Site: Kuparuk 2M Pad MD Reference: 2M-08 @ 147.O0usft (P245) Well: 2M-08 North Reference: True Wellbore: 2M-081-1 Survey Calculation Method: Minimum Curvature Design: 2M-081-1 Database: EDM Alaska NSK Sandbox Survey Annotation IGiI BAKER HUGHES 10/142016 10:03: 38AM Page 5 COMPASS 5000.1 Build 74 Map Map Vertical MD Inc Azi TVD TVDSS +NIS +E/ -W Northing Easting DLS Section Survey Tool Name (uom) 41i ("i (usft) (usft) (usft) (usft) I>€t) (ft) (°rtoo•) tel 13,550.41 89.26 166.74 6,168.08 6,021.09 -10,776.00 50.92 5,938,210.95 487,982.89 3.18 10,776.00 MWD (2) 13,580.41 89.08 166.85 6,168.52 6,021.52 -10,805.20 57.77 5,938,181.64 487,989.69 0.70 10,805.20 MWD (2) 13,610.31 88.10 169.52 6,169.26 6,022.26 -10,834.45 63.89 5,938,152.38 487,995.77 9.51 10,834.45 MWD (2) 13,641.55 88.34 172.30 6,170.23 6,023.23 -10,865.28 68.82 5,938,121.55 488,000.65 8.93 10,865.28 MWD (2) 13,670.67 88.77 173.76 6,170.96 6,023.96 -10,894.18 72.35 5,938,092.65 488,004.13 5.23 10,894.18 MWD (2) 13,700.63 89.51 173.36 6,171.41 6,024.41 -10,923.95 75.71 5,938,062.88 488,007.45 2.81 10,923.95 MWD (2) 13,730.42 89.36 172.49 6,171.70 6,024.70 -10,953.51 79.38 5,938,033.32 488,011.07 2.96 10,953.51 MWD (2) 13,760.53 89.60 173.18 6,171.98 6,024.98 -10,983.38 83.14 5,938,003.44 488,014.77 2.43 10,983.38 MWD (2) 13,790.67 88.96 173.33 6,172.36 6,025.36 -11,013.31 86.68 5,937,973.51 488,018.27 2.18 11,013.31 MWD(2) 13,820.39 89.11 173.45 6,172.86 6,025.86 -11,042.83 90.10 5,937,943.99 488,021.64 0.65 11,042.83 MWD (2) 13.850.41 88.59 174.20 6,173.46 6,026.46 -11,072.67 93.33 5,937,914.15 488,024.82 3.04 11,072.67 MWD (2) 13,880.35 88.34 174.24 6,174.26 6,027.26 -11,102.45 96.34 5,937,884.37 488,027.79 0.85 11,102.45 MWD (2) 13,910.43 88.65 175.70 6,175.05 6,028.05 -11,132.40 98.98 5,937,854.41 488,030.37 4.96 11,132.40 MWD (2) 13,940.59 88.80 177.11 6,175.72 6,028.72 -11,162.49 100.87 5,937,824.32 488,032.22 4.70 11,162.49 MWD (2) 13,970.59 88.89 178.19 6,176.33 6,029.33 -11,192.46 102.10 5,937,794.35 488,033.40 3.61 11,192.46 MWD (2) 14,000.36 88.34 179.16 6,177.05 6,030.05 -11,222.21 102.79 5,937,764.60 488,034.04 3.74 11,222.21 MWD (2) 14,030.45 89.48 179.76 6,177.62 6,030.62 -11,252.29 103.07 5,937,734.52 488,034.27 4.28 11,252.29 MWD (2) 14,062.56 90.34 178.76 6,177.67 6,030.67 -11,284.40 103.48 5,937,702.42 488,034.64 4.11 11,284.40 MWD (2) 14,090.28 91.47 179.38 6,177.23 6,030.23 -11,312.11 103.93 5,937,674.71 488,035.04 4.65 11,312.11 MWD (2) 14,120.33 93.53 179.22 6,175.92 6,028.92 -11,342.13 104.30 5,937,644.69 488,035.36 6.88 11,342.13 MWD (2) 14,150.31 92.40 179.79 6,174.37 6,027.37 -11,372.07 104.56 5,937,614.76 488,035.57 4.22 11,372.07 MWD (2) 14,180.23 90.86 180.75 6,173.52 6,026.52 -11,401.97 104.42 5,937,584.85 488,035.38 6.06 11,401.97 MWD (2) 14,210.65 88.40 181.41 6,173.72 6,026.72 -11,432.39 103.85 5,937,554.45 488,034.76 8.37 11,432.39 MWD (2) 14,240.56 87.21 182.62 6,174.86 6,027.86 -11,462.25 102.79 5,937,524.58 488,033.66 5.67 11,462.25 MWD (2) 14,270.15 86.84 183.41 6,176.40 6,029.40 -11,491.76 101.24 5,937,495.08 488,032.06 2.94 11,491.76 MWD (2) 14,300.33 84.77 184.40 6,178.60 6,031.60 -11,521.79 99.19 5,937,465.06 488,029.96 7.60 11,521.79 MWD (2) 14,330.52 84.80 184.72 6,181.35 6,034.35 -11,551.76 96.80 5,937,43509 488,027.53 1.06 11,551.76 MWD (2) 14,361.55 84.44 186.13 6,184.26 6,037.26 -11,582.52 93.88 5,937,404.35 488,024.56 4.67 11,582.52 MWD (2) 14,390.86 84.93 188.76 6,186.97 6,039.97 -11,611.45 90.10 5,937,375.42 488,020.73 9.09 11,611.45 MWD (2) 14,420.92 86.16 184.02 6,189.31 6,042.31 -11,641.22 86.77 5,937,345.66 488,017.35 16.24 11,641.22 MWD (2) 14,450.73 86.10 182.56 6,191.32 6,044.32 -11,670.92 85.06 5,937,315.97 488,015.59 4.89 11,670.92 MWD (2) Annotation IGiI BAKER HUGHES 10/142016 10:03: 38AM Page 5 COMPASS 5000.1 Build 74 Survey ConocoPhillips e N ConocoPhillips Definitive Survey Report s HUGHES Company: ConocoPhillips (Alaska) Inc. -Kup2 Local Co-ordinate Reference: Well 2M-08 MD Project: Kuparuk River Unit TVD Reference:. 2M-08 @ 147.00usft (P245) TVDSS Site: Kuparuk 2M Pad MD Reference: 2M-08 @ 147.00usft (P245) Eastin g Well: 2M-08 North Reference, True (1) Wellbore: 2M-081-1 Survey Calculation Method: Minimum Curvature (usft) Design: 2M-081-1 Database. EDM Alaska NSK Sandbox (-tioo-) Survey Map Map Vertical MD Inc AZI TVD. TVDSS +N/ -S -ll Northing Eastin g DLS Section Survey Tool Name Annotation Nam (1) (°), (eett) (usft) (usft) (usft) Pill (ft) (-tioo-) (ft) 14,480.55 87.36 182.37 6,193.02 6,046.02 -11,700.66 83.78 5,937,286.23 488,014.27 4.27 11,700.66 MWD(2) 14,510.27 86.71 183.43 6,194.56 6,047.56 -11,730.30 82.28 5,937,256.60 488,012.72 4.18 11,730.30 MWD (2) 14,540.53 8221 185.57 6,196.16 6,049.16 -11,760.42 79.91 5,937,226.48 488,010.30 7.25 11,760.42 MWD (2) 14,570.66 88.46 185.50 6,197.30 6,050.30 -11,790.39 77.00 5,937,196.52 488,007.35 4.16 11,790.39 MWD (2) 14,600.51 89.05 185.19 6,197.95 6,050.95 -11,820.10 74.22 5,937,166.81 488,004.52 2.23 11,820.10 MWD (2) P 14,630.35 88.28 184.22 6,198.65 6,051.65 -11,849.84 71.78 5,937,137.09 488,002.03 4.15 11,849.84 MWD (2) 14,660.55 88.59 182.86 6,199.47 6,052.47 -11,879.97 69.91 5,937,106.97 488,000.11 4.62 11,879.97 MWD (2) 14,690.57 90.00 182.00 6,199.84 6,052.84 -11,909.96 68.64 5,937,076.98 487,998.79 5.50 11,909.96 MWD (2) 14,721.13 90.77 182.66 6,199.64 6,052.64 -11,940.49 67.40 5,937,046.45 487,997.50 3.32 11,940.49 MWD (2) 14,750.29 90.64 184.26 6,199.28 6,052.28 -11,969.59 65.64 5,937,017.36 487,995.70 5.50 11,969.59 MWD (2) 14,770.29 91.04 184.39 6,198.98 6,051.98 -11,989.53 64.13 5,936,997.42 487,994.16 2.10 11,989.53 MWD (2) 14,780.36 91.14 184.58 6,198.79 6,051.79 -11,999.57 63.34 5,936,987.38 487,993.35 2.13 11,999.57 MWD (2) 14,810.53 90.12 184.91 6,198.46 6,051.46 -12,029.64 60.85 5,936,957.33 487,990.81 3.55 12,029.64 MWD (2) 14,840.43 89.82 184.64 6,198.48 6,051.48 -12,059.43 58.36 5,936,927.54 487,988.27 1.35 12,059.43 MWD (2) 14,870.55 89.42 186.34 6,198.68 6,051.68 -12,089.41 55.48 5,936,897.57 487,985.34 5.80 12,089.41 MWD (2) 14,900.37 90.92 188.32 6,198.59 6,051.59 -12,118.99 51.67 5,936,868.00 487,981.49 8.33 12,118.99 MWD (2) 14,930.37 90.03 190.60 6,198.34 6,051.34 -12,148.57 46.74 5,936,838.42 487,976.51 8.16 12,148.57 MWD (2) 14,960.35 90.68 194.08 6,198.15 6,051.15 -12,177.86 40.33 5,936,809.15 487,970.06 11.81 12,177.86 MWD (2) 14,990.32 89.72 196.34 6,198.05 6,051.05 -12,206.77 32.47 5,936,780.25 487,962.16 8.19 12,206.77 MWD(2) 15,024.17 90.46 196.97 6,197.99 6,051.00 -12,239.20 22.77 5,936,747.84 487,952.40 2.87 12,239.20 MWD(2) 15,055.34 91.96 194.72 6,197.34 6,050.34 -12,269.18 14.26 5,936,717.88 487,943.85 8.67 12,269.18 MWD(2) 15,080.25 92.09 193.22 6,196.46 6,049.46 -12,293.34 8.25 5,936,693.74 487,937.80 6.04 12,293.34 MWD (2) ' 15,110.21 90.58 191.29 6,195.76 6,048.76 -12,322.60 1.90 5,936,664.48 487,931.40 8.18 12,322.60 MWD (2) 15,140.30 88.34 190.61 6,196.04 6,049.04 -12,352.14 -3.82 5,936,634.96 487,925.63 7.78 12,352.14 MWD (2) , 15,170.31 85.11 188.88 6,197.76 6,050.76 -12,381.67 -8.89 5,936,605.44 487,920.52 12.20 12,381.67 MWD (2) 15,200.17 84.06 186.49 6,200.57 6,053.57 -12,411.12 -12.87 5,936,576.00 487,916.49 8.71 12,411.12 MWD (2) 15,230.29 84.34 184.75 6,203.62 6,056.62 -12,440.94 -15.80 5,936,546.18 487,913.51 5.82 12,440.94 MWD (2) 15,260.31 85.51 183.27 6,206.27 6,059.27 -12,470.77 -1289 5,936,516.36 487,911.37 6.27 12,470.77 MWD (2) 15,290.27 87.30 181.81 6,208.15 6,061.15 -12,500.64 -19.22 5,936,486.50 487,910.00 7.70 12,500.64 MWD(2) 15,320.41 88.46 179.41 6,209.27 6,062.27 -12,530.76 -19.54 5,936,456.38 487,909.63 8.84 12,530.76 MWD (2) 15,350.13 89.75 177.00 6,209.73 6,062.73 -12,560.46 -18.60 5,936,426.69 487,910.52 9.20 12,560.46 MWD (2) 10/1412016 10:03:38AM Page 6 COMPASS 5000.1 Build 74 ConocoPhillips ConocoPhillips � = rks Definitive Survey Report NYGM Company: ConocoPhillips (Alaska) Inc. -Kup2 Local Co-ordinate Reference: Well 2M-08 Project: Kuparuk River Unit TVD Reference: 2M-08 @ 147.00usft (P245) Site: Kuparuk 2M Pad MD Reference: 2M-08 @ 147.00usft (P245) Well: 2M-08 North Reference: True Wellbore: 2M-081-1 Survey Calculation Method: Minimum Curvature Design: 2M-081-1 Database: EDM Alaska NSK Sandbox Survey Annotation 10/142016 10:03.38AM Page 7 COMPASS 5000.1 Build 74 Map Map cal MD Inc Rzl TVD TVDSS +N/ -S +Ef-Wy NOtIft) Fasting OLS Sectio Section purvey Tool Name (usft) (1) M (usft) (usft) (usft) (usft) Et1) (ft) (-M00') (ft) 15,380.33 90.03 174.47 6,209.79 6,062.79 -12,590.57 -16.36 5,936,396.57 487,912.71 8.43 12,590.57 MWD (2) 15,410.19 88.07 172.57 6,210.29 6,063.29 -12,620.23 -12.99 5,936,366.91 487,916.04 9.14 12,620.23 MWD (2) 15,442.56 86.62 170.88 6,211.78 6,064.78 -12,652.23 -8.34 5,936,334.91 487,920.64 6.87 12,652.23 MWD(2) 15,470.17 87.42 169.20 6,213.22 6,066.22 -12,679.38 -3.57 5,936,307.75 487,925.36 6.73 12,679.38 MWD (2) 15,500.29 87.48 167.70 6,214.56 6,067.56 -12,708.86 2.46 5,936,278.26 487,931.34 4.98 12,708.86 MWD (2) 15,530.18 88.22 166.24 6,215.68 6,068.68 -12,737.96 9.19 5,936,249.15 487,938.03 5.47 12,737.96 MWD (2) 15,560.20 86.62 167.23 6,217.03 6,070.03 -12,767.15 16.07 5,936,219.96 487,944.86 6.27 12,767.15 MWD (2) 15,592.02 83.69 169.20 6,219.72 6,072.72 -12,798.18 22.55 5,936,188.92 487,951.28 11.08 12,798.18 MWD (2) 15,616.13 82.66 170.53 6,222.59 6,075.59 -12,821.75 26.76 5,936,165.35 487,955.46 6.95 12,821.75 MWD (2) 15,650.00 82.66 170.53 6,226.91 6,079.91 -12,854.88 32.29 5,936,132.21 487,960.93 0.00 12,854.88 PROJECTED to TO Annotation 10/142016 10:03.38AM Page 7 COMPASS 5000.1 Build 74 WE FA 2 BAKER HUGHES To OCT 2 ° 201u Letter of Transmittal Date: DATA LOGGED October 14, 2016 Nu �ENo(a 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): 2M -08L1 2 1 60 95 27 64 9 2M -08L1-01 2 1 60 96 27 65 0 (4) 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 s Conoco hillip REG 1, OCT 2 0 2016 ConocoPhillips (Alaska) Inc. -Kup2 Kuparuk River Unit Kuparuk 2M Pad 2M -08L1 50-103-20184-63 Baker Hughes INTEQ Definitive Survey Report 14 October, 2016 21 6095 Few FA I BAKER HUGHES 'w ' ConocoPhillips ConocoPhillips FrA Fag Definitive Survey Report BAKER HUGHES Company: ConocoPhillips (Alaska) Inc. -Kup2 Local Co-ordinate Reference: Well 2M-08 Latitude: Project; Kuparuk River Unit TVD Reference: 2M-08 @ 147.00usft (P245) 0.00 usft Site: Kuparuk 2M Pad MID Reference: 2M-08 @ 147.00usft (P245) 150' 5'50.870 W Well: 2M-08 North Reference: True usft Wellbore: 2M-0811 Survey Calculation Method: Minimum Curvature Design: 2M-081-1 Database: EDM Alaska NSK Sandbox Project Kuparuk River Unit, North Slope Alaska, United States Sample Date Declination 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 10/1/2016 i Well 2M-08 Well Position +N/ -S 0.00 usft Northing: 5,948,985.84usft Latitude: 70' 16' 18.579 N +E/ -W 0.00 usft Easting: 487,949.23 usft Longitude: 150' 5'50.870 W Position Uncertainty 0.00 usft Wellhead Elevation: usft Ground Level: 105.50 usft Wellbore 2M-081-1 Magnetics Model Name Sample Date Declination Dip Angle Field Strength (I (°) (nT) BGGM2016 10/1/2016 17.84 80.88 57,537 Design 2M-0811 Audit Notes: Version: 1.0 Phase: ACTUAL Tie On Depth: 11,740.89 Vertical Section: Depth From (TVD) +N/ -S +E/ -W Direction (usft) (usft) (usft) 41.50 0.00 0.00 180.00 Survey Program Date 10/12/2016 From TO Survey Survey (usft) (usft) Survey (Wellbore) Tool Name Description Start Date End Date 151.90 11,740.89 2M-08 Srvy 1 - GCT -MS (2M-08) GCT -MS Schlumberger GCT multishot 11/16/1992 11/16/1992 11,745.00 15,616.13 2M-0811 (2M-081-1) MWD MWD -Standard 9/24/2016 9/30/2016 1011412016 10:03:38AM Page 2 COMPASS 5000.1 Build 74 ConocoPhillips ConocoPhillips Definitive Survey Report Company: ConocoPhillips (Alaska) Inc. -Kup2 Local Co-ordinate Reference: Project: Kuparuk River Unit TVD Reference: Site: Kuparuk 2M Pad MD Reference: Well: 21\11-08 North Reference: Wellbore: 2M-081-1 Survey Calculation Method: Design: 2M-081-1 Database: Survey rfA.s BAKER HUGHES Well 2M-08 2M-08 @ 147.00usft (P245) a, 2M-08 @ 147.00usft (P245) True Minimum Curvature EDM Alaska NSK Sandbox 10/14/2016 10:03:38AM Page 3 COMPASS 5000.1 Build 74 Map Map Vertical MD Inc Azi TVD TVDSS +N/ -S +E/ -W Northing Easting DLS Section (usft) (1 (1) (usft) (usft) (usft) (usft) (°1100') Survey Tool Name Annotation (ft) (ft) (ft) 11,740.89 41.11 185.37 6,167.94 6,020.94 -9,313.44 -855.55 5,939,674.71 487,078.85 1.16 9,313.44 MWD (2) TIP 11,745.00 41.17 185.38 6,171.03 6,024.03 -9,316.13 -855.80 5,939,672.02 487,078.60 1.47 9,316.13 MWD (2) KOP 11,777.60 51.35 185.36 6,193.54 6,046.54 -9,339.55 -858.01 5,939,648.61 487,076.35 31.23 9,339.55 MWD (2) 11,807.27 64.16 183.00 6,209.34 6,062.34 -9,364.53 -859.80 5,939,623.64 487,074.52 43.70 9,364.53 MWD (2) 11,837.51 72.71 172.07 6,220.47 6,073.47 -9,392.54 -858.52 5,939,595.63 487,075.76 43.88 9,392.54 MWD (2) 11,871.02 87.73 171.93 6,226.15 6,079.15 -9,425.15 -853.93 5,939,563.01 487,080.29 44.82 9,425.15 MWD (2) 11,901.05 95.78 165.96 6,225.23 6,078.23 -9,454.57 -848.19 5,939,533.59 487,085.99 33.36 9,454.57 MWD (2) 11,930.14 99.75 153.89 6,221.28 6,074.29 -9,481.59 -838.33 5,939,506.55 487,095.80 43.31 9,481.59 MWD (2) 11,960.18 101.43 140.04 6,215.74 6,068.74 -9,506.29 -822.28 5,939,481.83 487,111.81 45.66 9,506.29 MWD (2) 11,990.25 96.30 128.14 6,211.09 6,064.09 -9,526.90 -800.97 5,939,461.19 487,133.08 42.65. 9,526.90 MWD (2) 12,020.39 96.14 122.81 6,207.82 6,060.82 -9,544.28 -776.58 5,939,443.77 487,157.44 17.59 9,544.28 MWD (2) 12,050.35 95.28 120.61 6,204.84 6,057.84 -9,559.95 -751.22 5,939,428.06 487,182.78 7.85 9,559.95 MWD (2) 12,080.37 95.38 121.54 6,202.05 6,055.05 -9,575.38 -725.62 5,939,412.60 487,208.35 3.10 9,575.38 MWD (2) 12,110.43 95.44 122.88 6,199.22 6,052.22 -9,591.33 -700.30 5,939,396.61 487,233.64 4.44 9,591.33 MWD (2) 12,140.45 95.54 124.42 6,196.35 6,049.35 -9,607.88 -675.43 5,939,380.01 487,258.49 5.12 9,607.88 MWD (2) 12,170.46 95.53 126.00 6,193.45 6,046.45 -9,625.11 -651.02 5,939,362.75 487,282.86 5.24 9,625.11 MWD (2) 12,200.48 96.52 125.94 6,190.30 6,043.30 -9,642.64 -626.86 5,939,345.18 487,306.99 3.30 9,642.64 MWD (2) 12,230.32 97.54 127.20 6,186.65 6,039.65 -9,660.28 -603.08 5,939,327.50 487,330.75 5.41 9,660.28 MWD (2) 12,260.47 97.08 127.94 6,182.81 6,035.81 -9,678.52 -579.38 5,939,309.23 487,354.42 2.87 9,678.52 MWD (2) 12,290.37 96.59 129.38 6,179.25 6,032.25 -9,697.06 -556.19 5,939,290.65 487,377.57 5.05 9,697.06 MWD (2) 12,320.56 94.77 130.58 6,176.26 6,029.26 -9,716.37 -533.18 5,939,271.31 487,400.55 7.21 9,716.37 MWD (2) 12,352.51 92.67 132.29 6,174.19 6,027.19 -9,737.46 -509.28 5,939,250.18 487,424.41 8.47 9,737.46 MWD (2) 12,380.59 91.54 133.20 6,173.16 6,026.16 -9,756.51 -488.67 5,939,231.10 487,444.99 5.17 9,756.51 MWD (2) 12,410.25 90.15 135.15 6,172.72 6,025.72 -9,777.17 -467.40 5,939,210.41 487,466.22 8.07 9,777.17 MWD (2) 12,440.27 88.43 135.99 6,173.09 6,026.09 -9,798.61 -446.39 5,939,188.94 487,487.20 6.38 9,798.61 MWD (2) 12,470.56 88.10 135.82 6,174.01 6,027.01 -9,820.35 -425.32 5,939,167.16 487,508.23 1.23 9,820.35 MWD (2) 12,501.33 87.76 139.10 6,175.12 6,028.12 -9,843.01 -404.53 5,939,144.48 487,528.98 10.71 9,843.01 MWD (2) 12,530.58 87.91 140.62 6,176.23 6,029.23 -9,865.35 -385.69 5,939,122.11 487,547.78 5.22 9,865.35 MWD (2) 12,560.51 88.10 141.45 6,177.27 6,030.27 -9,888.61 -366.88 5,939,098.82 487,566.55 2.84 9,888.61 MWD (2) 12,590.39 88.86 142.07 6,178.06 6,031.06 -9,912.07 -348.39 5,939,075.34 487,585.00 3.28 9,912.07 MWD (2) 10/14/2016 10:03:38AM Page 3 COMPASS 5000.1 Build 74 ConocoPhillips ConocoPhillips BAKER Definitive Survey Report HUGHES Company Project: Site: Well: Wellbore: Design: Survey ConocoPhillips (Alaska) Inc. -Kup2 Kuparuk River Unit Kuparuk 2M Pad 2M-08 2M-081_1 2M -08L1 Local Co-ordinate Reference: ND Reference: MD Reference: North Reference: Survey Calculation Method: Database: Well 2M-08 a 2M-08 @ 147.00usft (P245) 2M-08 @ 147.00usft (P245) True Minimum Curvature EDM Alaska NSK Sandbox Annotation 10/14/2016 10:03:38AM Page 4 COMPASS 5000.1 Build 74 Map Map Vertical MD Inc Azi ND NDSS +N/ -S +E/ -W Northing Easting OLS Section (usft) C) (1) (usft) (usft) (usft) (usft) (oi1oo.) Survey Tool Name (ft) (ft) (ft) 12,620.39 89.82 143.23 6,178.41 6,031.41 -9,935.91 -330.19 5,939,051.46 487,603.16 5.02 9,935.91 MWD (2) 12,650.47 90.49 143.95 6,178.33 6,031.33 -9,960.12 -312.34 5,939,027.23 487,620.97 3.27 9,960.12 MWD (2) 12,680.21 90.86 144.83 6,177.98 6,030.98 -9,984.30 -295.03 5,939,003.03 487,638.25 3.21 9,984.30 MWD (2) 12,710.31 91 54 146.29 6,177.35 6,030.35 -10,009.12 -278.01 5,938,978.18 487,655.23 5.35 10,009.12 MWD (2) 12,740.42 92.21 147.37 6,176.36 6,029.36 -10,034.31 -261.54 5,938,952.97 487,671.65 4.22 10,034.31 MWD (2) 12,771.55 91.69 148.64 6,175.30 6,028.30 -10,060.69 -245.06 5,938,926.56 487,688.09 4.41 10,060.69 MWD (2) 12,800.47 91.84 149.70 6,174.41 6,027.41 -10,085.51 -230.24 5,938,901.72 487,702.86 3.70 10,085.51 MWD (2) 12,830.65 92.33 149.34 6,173.31 6,026.31 -10,111.50 -214.95 5,938,875.71 487,718.12 2.01 10,111.50 MWD (2) 12,860.75 91.75 149.16 6,172.24 6,025.24 -10,137.36 -199.57 5,938,849.83 487,733.45 2.02 10,137.36 MWD (2) 12,890.25 91.96 148.89 6,171.29 6,024.29 -10,162.63 -184.39 5,938,824.53 487,748.59 1.16 10,162.63 MWD (2) 12,920.67 91.35 150.85 6,170.41 6,023.41 -10,188.93 -169.13 5,938,798.21 487,763.81 6.75 10,188.93 MWD (2) 12,950.58 92.33 150.66 6,169.45 6,022.45 -10,215.02 -154.52 5,938,772.11 487,778.37 3.34 10,215.02 MWD (2) 12,980.67 91.60 150.72 6,168.42 6,021.42 -10,241.24 -139.80 5,938,745.86 487,793.04 2.43 10,241.24 MWD (2) 13,010.23 91.14 152.10 6,167.71 6,020.71 -10,267.19 -125.66 5,938,719.90 487,807.14 4.92 10,267.19 MWD (2) 13,040.28 91.14 153.59 6,167.11 6,020.11 -10,293.92 -111.95 5,938,693.15 487,820.81 4.96 10,293.92 MWD (2) 13,070.13 90.28 154.99 6,166.74 6,019.74 -10,320.81 -99.00 5,938,666.24 487,833.71 5.50 10,320.81 MWD (2) 13,100.76 87.67 155.89 6,167.29 6,020.29 -10,348.66 -86.27 5,938,638.37 487,846.40 9.01 10,348.66 MWD (2) 13,130.75 87.54 156.23 6,168.54 6,021.54 -10,376.05 -74.12 5,938,610.96 487,858.51 1.21 10,376.05 MWD (2) 13,160.41 88.07 157.34 6,169.68 6,022.68 -10,403.29 -62.43 5,938,583.71 487,870.15 4.14 10,403.29 MWD (2) 13,190.40 88.31 159.25 6,170.63 6,023.63 -10,431.13 -51.35 5,938,555.85 487,881.19 6.42 10,431.13 MWD (2) 13,220.44 88.74 161.82 6,171.40 6,024.40 -10,459.45 -41.34 5,938,527.52 487,891.15 8.67 10,459.45 MWD (2) 13,250.35 89.48 162.53 6,171.86 6,024.86 -10,487.92 -32.19 5,938,499.04 487,900.25 3.43 10,487.92 MWD (2) 13,280.33 89.69 160.48 6,172.08 6,025.08 -10,516.34 -22.68 5,938,470.60 487,909.72 6.87 10,516.34 MWD (2) 13,310.53 91.07 160.87 6,171.88 6,024.88 -10,544.84 -12.68 5,938,442.09 487,919.66 4.75 10,544.84 MWD (2) 13,340.62 91.32 162.49 6,171.25 6,024.25 -10,573.40 -3.23 5,938,413.52 487,929.07 5.45 10,573.40 MWD (2) 13,370.75 90.92 163.43 6,170.66 6,023.66 -10,602.20 5.60 5,938,384.70 487,937.85 3.39 10,602.20 MWD (2) 13,400.82 90.86 163.92 6,170.20 6,023.20 -10,631.06 14.05 5,938,355.84 487,946.26 1.64 10,631.06 MWD (2) 13,430.92 91.08 165.71 6,169.69 6,022.69 -10,660.10 21.93 5,938,326.79 487,954.09 5.99 10,660.10 MWD (2) 13,460.71 91.17 165.47 6,169.10 6,022.10 -10,688.95 29.35 5,938,297.93 487,961.46 0.86 10,688.95 MWD (2) 13,490.31 91.54 165.52 6,168.40 6,021.40 -10,717.59 36.76 5,938,269.27 487,968.82 1.26 10,717.59 MWD (2) 13,520.26 90.21 166.61 6,167.95 6,020.95 -10,746.66 43.97 5,938,240.20 487,975.99 5.74 10,746.66 MWD (2) Annotation 10/14/2016 10:03:38AM Page 4 COMPASS 5000.1 Build 74 ConocoPhillips ConocoPhillips BAKER•• Definitive Survey Report HUGHES Company: Project: Site: Well: Wellbore: Design: Survey MD (usft) 13,550.41 13,580.41 13,610.31 13,641.55 13,670.67 13,700.63 13,730.42 13,760.53 13,790.67 13,820.39 13, 850.41 13, 880.35 13,910.43 13, 940.59 13, 970.59 14, 000.36 14, 030.45 14,062.56 14, 090.28 14,120.33 14,150.31 14,180.23 14,210.65 14,240.56 14,270.15 14,300.33 14,330.52 14, 361.55 14,390.86 14,420.92 14,450.73 ConocoPhillips (Alaska) Inc. -Kup2 Local Co-ordinate Reference: Well 2M-08 Kuparuk River Unit TVD Reference: 2M-08 @ 147.00usft (P245) Kuparuk 2M Pad MD Reference: 2M-08 @ 147.00usft (P245) 2M-08 North Reference: True 2M-081-1 Survey Calculation Method: Minimum Curvature 2M-081-1 Database: EDM Alaska NSK Sandbox Map Map Vertical Inc Azi TVD TVDSS +N/ -S +E/-WDLS Northing Easting Section 10/14/2016 10:03:38AM Page 5 COMPASS 5000.1 Build 74 (usft) (usft) (usft) (usft) (°l100') Survey Tool Name Annotation (ft) (ft) (ft) 89.26 166.74 6,168.08 6,021.09 -10,776.00 50.92 5,938,210.85 487,982.89 3.18 10,776.00 MWD (2) 89.08 166.85 6,168.52 6,021.52 -10,805.20 57.77 5,938,181.64 487,989.69 0.70 10,805.20 MWD (2) 88.10 169.52 6,169.26 6,022.26 -10,834.45 63.89 5,938,152.38 487,995.77 9.51 10,834.45 MWD (2) 88.34 172.30 6,170.23 6,023.23 -10,865.28 68.82 5,938,121.55 488,000.65 8.93 10,865.28 MWD (2) 88.77 173.76 6,170.96 6,023.96 -10,894.18 72.35 5,938,092.65 488,004.13 5.23 10,894.18 MWD (2) 89.51 173.36 6,171.41 6,024.41 -10,923.95 75.71 5,938,062.88 488,007.45 2.81 10,923.95 MWD (2) 89.36 172.49 6,171.70 6,024.70 -10,953.51 79.38 5,938,033.32 488,011.07 2.96 10,953.51 MWD (2) 89.60 173.18 6,171.98 6,024.98 -10,983.38 83.14 5,938,003.44 488,014.77 2.43 10,983.38 MWD (2) 88.96 173.33 6,172.36 6,025.36 -11,013.31 86.68 5,937,973.51 488,018.27 2.18 11,013.31 MWD (2) 89.11 173.45 6,172.86 6,025.86 -11,042.83 90.10 5,937,943.99 488,021.64 0.65 11,042.83 MWD (2) 88.59 174.20 6,173.46 6,026.46 -11,072.67 93.33 5,937,914.15 488,024.82 3.04 11,072.67 MWD (2) 88.34 174.24 6,174.26 6,027.26 -11,102.45 96.34 5,937,884.37 488,027.79 0.85 11,102.45 MWD (2) 88.65 175.70 6,175.05 6,028.05 -11,132.40 98.98 5,937,854.41 488,030.37 4.96 11,132.40 MWD (2) 88.80 177.11 6,175.72 6,028.72 -11,162.49 100.87 5,937,824.32 488,032.22 4.70 11,162.49 MWD (2) 88.89 178.19 6,176.33 6,029.33 -11,192.46 102.10 5,937,794.35 488,033.40 3.61 11,192.46 MWD (2) 88.34 179.16 6,177.05 6,030.05 -11,222.21 102.79 5,937,764.60 488,034.04 3.74 11,222.21 MWD (2) 89.48 179.76 6,177.62 6,030.62 -11,252.29 103.07 5,937,734.52 488,034.27 4.28 11,252.29 MWD (2) 90.34 178.76 6,177.67 6,030.67 -11,284.40 103.48 5,937,702.42 488,034.64 4.11 11,284.40 MWD (2) 91.47 179.38 6,177.23 6,030.23 -11,312.11 103.93 5,937,674.71 488,035.04 4.65 11,312.11 MWD (2) 93.53 179.22 6,175.92 6,028.92 -11,342.13 104.30 5,937,644.69 488,035.36 6.88 11,342.13 MWD (2) 92.40 179.79 6,174.37 6,027.37 -11,372.07 104.56 5,937,614.76 488,035.57 4.22 11,372.07 MWD (2) 90.86 180.75 6,173.52 6,026.52 -11,401.97 104.42 5,937,584.85 488,035.38 6.06 11,401.97 MWD (2) 88.40 181.41 6,173.72 6,026.72 -11,432.39 103.85 5,937,554.45 488,034.76 8.37 11,432.39 MWD (2) 87.21 182.62 6,174.86 6,027.86 -11,462.25 102.79 5,937,524.58 488,033.66 5.67 11,462.25 MWD (2) 86.84 183.41 6,176.40 6,029.40 -11,491.76 101.24 5,937,495.08 488,032.06 2.94 11,491.76 MWD (2) 84.77 184.40 6,178.60 6,031.60 -11,521.79 99.19 5,937,465.06 488,029.96 7.60 11,521.79 MWD (2) 84.80 184.72 6,181.35 6,034.35 -11,551.76 96.80 5,937,435.09 488,027.53 1.06 11,551.76 MWD (2) 84.44 186.13 6,184.26 6,037.26 -11,582.52 93.88 5,937,404.35 488,024.56 4.67 11,582.52 MWD (2) 84.93 188.76 6,186.97 6,039.97 -11,611.45 90.10 5,937,375.42 488,020.73 9.09 11,611.45 MWD (2) 86.16 184.02 6,189.31 6,042.31 -11,641.22 86.77 5,937,345.66 488,017.35 16.24 11,641.22 MWD (2) 86.10 182.56 6,191.32 6,044.32 -11,670.92 85.06 5,937,315.97 488,015.59 4.89 11,670.92 MWD (2) 10/14/2016 10:03:38AM Page 5 COMPASS 5000.1 Build 74 T ConocoPhillips Company: ConocoPhillips (Alaska) Inc. -Kup2 Project: Kuparuk River Unit Site: Kuparuk 2M Pad Well: 2M-08 Wellbore: 2M-081-1 Design: 2M-081-1 Survey MD Inc (usft) (I 14,480.55 87.36 14,510.27 86.71 14,540.53 87.21 14,570.66 88.46 14,600.51 89.05 14,630.35 88.28 14,660.55 88.59 I 14,690.57 90.00 14,721.13 90.77 14,750.29 90.64 14,770.29 91.04 14,780.36 91.14 14,810.53 90.12 I 14,840.43 89.82 1 14,870.55 89.42 j 14,900.37 90.92 14,930.37 90.03 14,960.35 90.68 14,990.32 89.72 15,024.17 90.46 15,055.34 91.96 15,080.25 92.09 15,110.21 90.58 15,140.30 88.34 15,170.31 85.11 15,200.17 84.06 I 15,230.29 84.34 15,260.31 85.51 15,290.27 87.30 15, 320.41 88.46 15,350.13 8975 rL7fLfLs WIF11X"l--IF-Mli Azi TVD TVDSS +N/ -S (1) (usft) (usft) (usft) 182.37 6,193.02 6,046.02 -11,700.66 183.43 6,194.56 6,047.56 -11,730.30 185.57 6,196.16 6,049.16 -11,760.42 185.50 6,197.30 6,050.30 -11,790.39 185.19 6,197.95 6,050.95 -11,820.10 184.22 6,198.65 6,051.65 -11,849.84 182.86 6,199.47 6,052.47 -11,879.97 182.00 6,199.84 6,052.84 -11,909.96 182.66 6,199.64 6,052.64 -11,940.49 184.26 6,199.28 6,052.28 -11,969.59 184.39 6,198.98 6,051.98 -11,989.53 184.58 6,198.79 6,051.79 -11,999.57 184.91 6,198.46 6,051.46 -12,029.64 184.64 6,198.48 6,051.48 -12,059.43 186.34 6,198.68 6,051.68 -12,089.41 188.32 6,198.59 6,051.59 -12,118.99 190.60 6,198.34 6,051.34 -12,148.57 194.08 6,198.15 6,051.15 -12,177.86 196.34 6,198.05 6,051.05 -12,206.77 196.97 6,197.99 6,051.00 -12,239.20 194.72 6,197.34 6,050.34 -12,269.18 193.22 6,196.46 6,049.46 -12,293.34 191.29 6,195.76 6,048.76 -12,322.60 190.61 6,196.04 6,049.04 -12,352.14 188.88 6,197.76 6,050.76 -12,381.67 186.49 6,200.57 6,053.57 -12,411.12 184.75 6,203.62 6,056.62 -12,440.94 183.27 6,206.27 6,059.27 -12,470.77 181.81 6,208.15 6,061.15 -12,500.64 179.41 6,209.27 6,062.27 -12,530.76 177.00 6,209.73 6,062.73 -12,560.46 ConocoPhillips Definitive Survey Report Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Database: Page 6 Map +E/ -W Northing (usft) (ft) 83.78 5,937,286.23 82.28 5,937,256.60 79.91 5,937,226.48 77.00 5,937,196.52 74.22 5,937,166.81 71.78 5,937,137.09 69.91 5,937,106.97 68.64 5,937,076.98 67.40 5,937,046.45 65.64 5,937,017.36 64.13 5,936,997.42 63.34 5,936,987.38 60.85 5,936,957.33 58.36 5,936,927.54 55.48 5,936,897.57 51.67 5,936,868.00 46.74 5,936,838.42 40.33 5,936,809.15 32.47 5,936,780.25 22.77 5,936,747.84 14.26 5,936,717.88 8.25 5,936,693.74 1.90 5,936,664.48 -3.82 5,936,634.96 -8.89 5,936,605.44 -12.87 5,936,576.00 -15.80 5,936,546.18 -17.89 5,936,516.36 -19.22 5,936,486.50 -19.54 5,936,456.38 -18.60 5,936,426.69 Page 6 Map rib2 Vertical BAKER Fasting HUGHES Well 2M-08 Survey Tool Name 2M-08 @ 147.00usft (P245) (low) 2M-08 @ 147.00usft (P245) True 4.27 Minimum Curvature MWD (2) EDM Alaska NSK Sandbox a Map Vertical Fasting DLS Section Survey Tool Name (ft) (low) (ft) 488,014.27 4.27 11,700.66 MWD (2) 488,012.72 4.18 11,730.30 MWD (2) 488,010.30 7.25 11,760.42 MWD (2) 488,007.35 4.16 11,790.39 MWD (2) 488,004.52 2.23 11,820.10 MWD (2) 488,002.03 4.15 11,849.84 MWD (2) 488,000.11 4.62 11,879.97 MWD (2) 487,998.79 5.50 11,909.96 MWD (2) 487,997.50 3.32 11,940.49 MWD (2) 487,995.70 5.50 11,969.59 MWD (2) 487,994.16 2.10 11,989.53 MWD (2) 487,993.35 2.13 11,999.57 MWD (2) 487,990.81 3.55 12,029.64 MWD (2) 487,988.27 1.35 12,059.43 MWD (2) 487,985.34 5.80 12,089.41 MWD (2) 487,981.49 8.33 12,118.99 MWD (2) 487,976.51 8.16 12,148.57 MWD (2) 487,970.06 11.81 12,177.86 MWD (2) 487,962.16 8.19 12,206.77 MWD (2) 487,952.40 2.87 12,239.20 MWD (2) 487,943.85 8.67 12,269.18 MWD (2) 487,937.80 6.04 12,293.34 MWD (2) 487,931.40 8.18 12,322.60 MWD (2) 487,925.63 7.78 12,352.14 MWD (2) 487,920.52 12.20 12,381.67 MWD (2) 487,916.49 8.71 12,411.12 MWD (2) 487,913.51 5.82 12,440.94 MWD (2) 487,911.37 6.27 12,470.77 MWD (2) 487,910.00 7.70 12,500.64 MWD (2) 487,909.63 8.84 12,530.76 MWD (2) 487,910.52 9.20 12,560.46 MWD (2) Annotation COMPASS 5000.1 Build 74 ConocoPhillips Company: ConocoPhillips (Alaska) Inc. -Kup2 Project: Kuparuk River Unit Site: Kuparuk 2M Pad Well: 2M-08 Wellbore: 2M-081-1 Design: 2M-081-1 Survey ConocoPhillips Definitive Survey Report Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Database: Well 2M-08 2M-08 @ 147.00usft (P245) 2M-08 @ 147,00usft (P245) True Minimum Curvature EDM Alaska NSK Sandbox BAKER HUGHES 10/14/2016 10:03:38AM Page 7 COMPASS 5000.1 Build 74 Map Map Vertical MD Inc Azi TVD TVDSS +N/ -S +E/ -W DLS (usft) V) (1) (usft) (usft) (usft) (usft) Northing Easting (°/100') Section SurveyTool Name Annotation (ft) (ft) (ft) 15,380.33 90.03 174.47 6,209.79 6,062.79 -12,590.57 -16.36 5,936,396,57 487,912.71 8.43 12,590.57 MWD (2) 15,410.19 88.07 172.57 6,210.29 6,063.29 -12,620.23 -12.99 5,936,366.91 487,916.04 9.14 12,620.23 MWD (2) 15,442.56 86.62 170.88 6,211.78 6,064.78 -12,652.23 -8.34 5,936,334.91 487,920.64 6.87 12,652.23 MWD (2) 15,470.17 87.42 169.20 6,213.22 61066.22 -12,679.36 -3.57 5,936,307.75 487,925.36 6.73 12,679.38 MWD (2) 15,500.29 87.48 167.70 6,214.56 6,067.56 -12,708,86 2.46 5,936,278.26 487,931.34 4.98 12,708.86 MWD (2) 15,530.18 88.22 166.24 6,215.68 6,068.68 -12,737.96 9.19 5,936,249.15 487,938.03 5.47 12,737.96 MWD (2) 15,560.20 86.62 167.23 6,217.03 6,070.03 -12,767.15 16.07 51936,219.96 487,944.86 6.27 12,767.15 MWD (2) 15,592.02 83.69 169.20 6,219.72 6,072.72 -12,798.18 22.55 5,936,188.92 487,951.28 11.06 12,798.18 MWD (2) 15,616.13 82.66 170.53 6,222.59 6,075.59 -12,821.75 26.76 5,936,165.35 487,955.46 6.95 12,821.75 MWD (2) 15,650.00 82.66 170.53 6,226.91 6,079.91 -12,854.88 32.29 5,936,132.21 487,960.93 0.00 12,854.88 PROJECTED to TD 10/14/2016 10:03:38AM Page 7 COMPASS 5000.1 Build 74 THE STATE 'A L As"' K A GOVERNOR BILL WALKER G. Eller CTD Engineering Supervisor ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510-0360 Alaska Oil and Gas CGnservati®n Commission Re: Kuparuk River Field, Kuparuk River Oil Pool, KRU 2M -08L1 ConocoPhillips Alaska, Inc. Permit to Drill Number: 216-095 Surface Location: 114' FSL, 109' FWL, SEC. 27, TI IN, R8E, UM Bottomhole Location: 2801' FSL, 90' FWL, SEC. 10, TION, R8E, UM Dear Mr. Eller: 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 www.aogcc.alaska.gov Enclosed is the approved application for permit to re -drill the above referenced development well. The permit is for a new wellbore segment of existing well Permit No. 192-101, API No. 50-103- 20184-00-00. 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, Cathyl. Foerster Chair DATED this AO�Jay of August, 2016. RE('r-,IVED 2016 STATE OF ALASKA :A OIL AND GAS CONSERVATION COMM PERMIT TO DRILL 20 AAC 25.005 ON 1 a. Type of Work: 1 b. Proposed Well Class: Exploratory - Gas ❑ Service - WAG ❑ Service - Disp ❑ 1 c. Specify if well is proposed for: Drill ❑ -Lateral ❑✓ Stratigraphic Test ❑ Development - Oil ❑✓ - Service - Winj ❑ Single Zone Q t 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 Bond No. 59-52-180 KRU 2M -08L1 3. Address: 6. Proposed Depth: 12. Field/Pool(s): P.O. Box 100360 Anchorage, AK 99510-0360 MD: 16,000' TVD: 6,047' Kuparuk River Field Kuparuk Oil Pool 4a. Location of Well (Governmental Section): 7. Property Designation (Lease Number): Surface: 114' FSL, 109' FWL, Sec. 27, T11N, R8E, UM ADL 25589 asses Top of Productive Horizon: 8. Land Use Permit: 13. Approximate Spud Date: 1083' FSL, 4630' FWL, Sec. 4, T10N, R8E, UM 2675 9/7/2016 9. Acres in Property: 2,0 14. Distance to Nearest Property: Total Depth: 2801' FSL, 90' FWL, Sec. 10, T10N, R8E, UM - 2�e 14,294' 4b. Location of Well (State Base Plane Coordinates - NAD 27): 10. KB Elevation above MSL (ft): 147 f 15. Distance to Nearest Well Open Surface: x- 487949 y- 5,948,986 Zone- 4- GL Elevation above MSL (ft): 106 Ito Same Pool: 2K-27, 240' 16. Deviated wells: Kickoff depth: 11,745' feet , 17. Maximum Potential Pressures in psig (see 20 AAC 25.035) Maximum Hole Angle: 100° degrees . Downhole: 4,547 psig , Surface: 3,930 psig 18. Casing Program: Specifications Top - Setting Depth - Bottom Cement Quantity, c.f. or sacks Hole Casing Weight Grade Coupling I Length MD TVD MD TVD (including stage data) 3" 2.375" 4.7# L-80 ST -L 3,900' 12,100' 6,197' 16,000' 6,194' slotted liner 19. PRESENT WELL CONDITION SUMMARY (To be completed for Redrill and Re -Entry Operations) Total Depth MD (ft): Total Depth TVD (ft): Plugs (measured): Effect. Depth MD (ft): Effect. Depth TVD (ft): Junk (measured): 12,151' 6,476' none 12,046' 6,397' none Casing Length Size Cement Volume MD TVD Conductor/Structural 79' 16" 250 sx AS II 121' 121' Surface 4,211' 9-5/8" 660 sx PF E & 760 sx Class G 4253' 2744' Production 12,099' 7" 198 sx Class G 12138' 6466' Perforation Depth MD (ft): 11,721'-11,750' Perforation Depth TVD (ft): 6,153'-6,175' 11,784'-11,807' 6,200'-6,218' 20. Attachments: Property Plat ❑ BOP Sketch ❑ Drilling Program Time v. Depth Plot ❑ Shallow Hazard Analysis❑ Diverter Sketch ❑ Seabed Report ❑ Drilling Fluid Program Q 20 AAC 25.050 requirements 21. Verbal Approval: Commission Representative: Date VZ ZGI6 22. 1 hereby certify that the foregoing is true and the procedure approved herein will not J. Connelly @ 263-4112 be deviated from without prior wri approval. Contact v . Email ieff.s.COnnelly(p—p .com Z-tompp� Printed Name G. Eller Tifle CTD Engineering Supervisor S� Signature Phone 263-4172 Date Commission Use Only Permit to Drill API Number: Permit Approval See cover letter for other Number: kl — �QS' 50- 1o3—,2ooi—(.3--Q() Date: �01)�p I requirements. Conditions of approval : If box is checked, well may not be used to explore for, test, or produce coalbed methane, gas hydrates, or gas contained in shales: Other: '0 0 A to 5 f fi-o -4 5-t) d /� S�� �0 Z-5-00Samples req'd: Yes ❑,{' No [if Mud log req'd: Yes ❑ No [� f`-h✓ttllo r� prr-vevv��� f<Z-5-00 P 5 r J HzS measures: Yes ["1 No El Directional svy req'd: Yes[ No❑ Spacing exception req'd: Yes ❑ Nov Inclination -only svy req'd: Yes ❑ No[� Post initial injection MIT req'd: Yes ❑ No Eg--. APPROVED BY Q Approved by: �fi-- COMMISSIONER THE COMMISSION Date:CJ —1/ 6 ��(e ft V I'T ,oe U! �1'� -rL g/B/ 1�O n � IrC-71 N "val Submit Form and Form 10-401 (Revised 11/2015) This permit is valid for 2 S (20 AAC 25.005(g)) Attachments in Duplicate ConocoPhilli s p Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 July 26, 2016 Commissioner - State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Dear Commissioner: ConocoPhillips Alaska, Inc. hereby submits applications for permits to drill a dual -lateral out of the KRU 2M-08 (PTD 192-101) using the coiled tubing drilling rig, Nabors CDR2-AC or Nabors CDR3-AC. The scope of work and window exit type for KRU 2M-08 have been modified from a cement pilot -hole casing exit to a big tail -pipe casing exit. For this reason, please cancel the previously issued sundry (316-116) and permits to drill 216-032, 216-033, 216-034, and 216 -035 for 2M-08. ,/ To account for geological uncertainties, ConocoPhillips requests a variance from the requirements of 20 AAC 25.015 to allow the actual kick-off point to be anywhere along the length of the parent lateral instead of being limited to 500' from the original point. The work is scheduled to begin September 11, 2016. The objective will be to drill laterals KRU 2M-081_1 and 2M- 081_1-01 targeting the Kuparuk A -sands. Attached to this application are the following documents: — 10-401 Applications for 2M-081_1 and 2M-081_1-01 — Detailed Summary of Operations — Directional Plans for 2M-081_1 and 2M-081_1-01 — Proposed CTD Schematic If you have any questions or require additional information, please contact me at 907-263-4112. Sincerely, Jeff Connel y ConocoPhillips Alaska Coiled Tubing Drilling Engineer Kuparuk CTD Laterals NABOAS ALASKA 2M-081-1, 2M-081-1-01 CDk Application for Permit to Drill Document 2AC 1. Well Name and Classification........................................................................................................ 2 Directional Plans for 2M-081-1 laterals.....................................................................................................7 (Requirements of 20 AAC 25.005(0 and 20 AAC 25.005(b))................................................................................................................... 2 2. Location Summary.......................................................................................................................... 2 Planned rig workover schematic..............................................................................................................7 (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....................................................................... 7 (Requirements of 20 AAC 25.050(b))...................................................................................................................................................... 7 16. Attachments.................................................................................................................................... 7 Attachment 1: Directional Plans for 2M-081-1 laterals.....................................................................................................7 Attachment 2: Current Well Schematic for 2M-08...........................................................................................................7 Attachment 3: Planned rig workover schematic..............................................................................................................7 Attachment 4: Proposed Well Schematic for 2M-081-1 and 2M -08L1-01 laterals............................................................7 Page 1 of 7 July 26, 2016 PTD Application: 2M -08L1, 2M-081_1-01 1. Well Name and Classification (Requirements of 20 AAC 25.005(f) and 20 AAC 25.005(b)) The proposed laterals described in this document are 2M -08L1, 2M-08AL1-01. All laterals will be classified as "Development -Oil" wells. 2. Location Summary (Requirements of 20 AAC 25.005(c)(2)) These laterals will target the A sand package in the Kuparuk reservoir. See attached 10-401 form for surface and subsurface coordinates of the 2M -08L1, 2M-081-1-01. 3. Blowout Prevention Equipment Information (Requirements of 20 AAC 25.005 (c)(3)) Please reference blowout prevention (BOP) schematics on file with the Commission for Nabors 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 4,500 psi. Using the maximum formation pressure in the area of 4,547'psi in 2M-35 (i.e. 14.1 ppg EMW)'the maximum potential surface pressure in 2M-08, assuming a gas gradient of 0.1 psi/ft, would be 3,927 psi` See the "Drilling Hazards Information and Reservoir Pressure" section for more details. — The annular preventer will be tested to 250 psi and 2,500 psi. 4. Drilling Hazards Information and Reservoir Pressure (Requirements of 20 AAC 25.005 (c)(4)) Reservoir Pressure and Maximum Downhole Pressure (Requirements of 20 AAC 25.005 (c)(4)(a)) The formation pressure in KRU 2M-08 was measured to be 3,403 psi (10.8 ppg EMW) on 5/2/2016. All of the wells in the 2M-08 vicinity are SI except the 2M-14 producer. The maximum downhole pressure in the 2M-08 vicinity, but isolated by a sealing fault is the shut in 2M-35 injector at 4,547 psi (14.1 ppg EMW) from April 2016. Potential Gas Zones (Requirements of 20 AAC 25.005 (c)(4)(b)) Wells on 2M pad have injected gas, so there is a chance of encountering free gas while drilling the 2M-08 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 2M-08 laterals will be shale instability across faults. Managed pressure drilling (MPD) will be used to reduce the risk of shale instability associated with fault crossings. 5. Procedure for Conducting Formation Integrity tests (Requirements of 20 AAC 25.005(c)(5)) The 2M-08 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 July 26, 2016 PTD Application: 21VI-081-1, 21VI-081-1-01 6. Casing and Cementing Program (Requirements of 20 AAC 25.005(c)(6)) New Completion Details Lateral Name Liner Top Liner Btm Liner Top Liner Btm Liner Details Btm MD MD MD TVDSS TVDSS Conductor 21VI-081_1 12,100' 16,000' 6,050' 6,047' 2%", 4.7#, L-80, ST -L slotted liner; 0' 121' 1,640 670 Surface aluminum billet on top 2M -08L1-01 11,676' 14,150' 5,972' 6,060' 2'/", 4.7#, L-80, ST -L slotted liner; 2,744' 6,870 4,760 Production 7" deployment sleeve on top Existing Casing/Liner Information Category OD Weight (ppf) Grade Connection Top MD Btm MD Top TVD Btm TVD Burst psi Collapse psi Conductor 16" 62.5 H-40 Welded 0' 121' 0' 121' 1,640 670 Surface 9-5/8" 47 L-80 AB -MOD 0' 4,253' 0' 2,744' 6,870 4,760 Production 7" 26 J-55 BTC 0' 12,138' 0' 6,466' 4,980 4,320 Tubing 3-1/2" 9.3 J-55 EUE 0 11,610' 0 6,069' 10,160 10,540 Tubing Tail 4-1/2" 12.6 L-80 STC 11,681 11,765 6,123 6,186 NA NA 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 RoVis mud (8.6 ppg) — Drilling operations: Chloride -based RoVis mud (8.6 ppg).✓While this mud weight will not hydrostatically overbalance the reservoir pressure, overbalanced conditions will be maintained using MPD practices described below. — Completion operations: CTD will utilize an Orbit valve for formation isolation while running liner. In the event of an Orbit valve failure 11.8ppg NaBr completion fluid will be utilized to provide formation over- balance and well bore stability while running completions. Managed Pressure Drilling Practice J Managed pressure drilling (MPD) techniques will be employed to maintain a constant overbalanced pressure on the open hole formation and promote wellbore stability throughout the coiled tubing drilling (CTD) process. Mud weight is not, in many cases, the primary well control barrier. This is satisfied with the 5,000 psi rated coiled tubing pack off and MPD choke. BOPE equipment provides the secondary well control as detailed in section 3 "Blowout Prevention Equipment Information". In the 2M-08 laterals we will target a constant BHP of 11.8 ppg EMW at the window. The constant BHP target will be adjusted through choke pressure and/or mud weight increases to maintain overbalanced conditions if increased reservoir pressure is encountered. Additional choke pressure or increased mud weight may also be employed for improved borehole stability. Any change of circulating friction pressure due to change in pump rates or change in depth of circulation will be offset with back pressure adjustments. Page 3 of 7 July 26, 2016 PTD Application: 21VI-08L1, 21VI-081_1-01 Pressure at the 2M-08 Window (11,745' MD, 6171' 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 Well 2M-08 was originally drilled and completed in 1992 with 3'/z" tubing and 7" production casing as an A5 -sand, gas lifted producer in Kuparuk. Well 2M-08 has been on production since 1993. In 2013 the A3 - sand was perforated. Prior to CTD operations, a workover will replace the existing completion with 4-1/2" big tail pipe to facilitate the CTD window exit. An Orbit valve will also be installed. Post CTD workover, a mechanical whip -stock will be set inside the 4 ''/2" big tail pipe at the planned kick off point of 11,745' MD. The 2M -08L1 lateral will exit through the big tail pipe at 11,745' MD and TD at 16,000 MD. Ll lateral will be completed with 2 3/8" slotted liner from TD up to 12,100' MD with an aluminum billet for kicking off the 2M -08L1-01 lateral. The 2M -08L1-01 will drill to a TD of 14,150' MD, with the liner top at 11,676' MD; just above the whipstock. Page 4 of 7 July 26, 2016 Pumps On 1.5 bpm) Pumps Off A -sand Formation Pressure (10.8 p 3466 psi 3466 psi Mud Hydrostatic (8.6 p) 2760 psi 2760 psi Annular friction i.e. ECD, 0.080 psi/ft) 940 psi 0 psi Mud + ECD Combined no chokepressure) 3700 psi overbalanced —234psi) 2760 psi underbalanced —706psi) Target BHP at Window (11.8 pp) 3787 psi 3787 psi Choke Pressure Required to Maintain Target BHP 87 psi 1027 psi 9. Abnormally Pressured Formation Information (Requirements of 20 AAC 25.005(c)(9)) N/A - Application is not for an exploratory or stratigraphic test well. 10. Seismic Analysis (Requirements of 20 AAC 25.005(c)(10)) N/A - Application is not for an exploratory or stratigraphic test well. 11. Seabed Condition Analysis (Requirements of 20 AAC 25.005(c)(11)) N/A - Application is for a land based well. 12. Evidence of Bonding (Requirements of 20 AAC 25.005(c)(12)) Evidence of bonding for ConocoPhillips Alaska, Inc. is on file with the Commission. 13. Proposed Drilling Program (Requirements of 20 AAC 25.005(c)(13)) Summary of Operations Background Well 2M-08 was originally drilled and completed in 1992 with 3'/z" tubing and 7" production casing as an A5 -sand, gas lifted producer in Kuparuk. Well 2M-08 has been on production since 1993. In 2013 the A3 - sand was perforated. Prior to CTD operations, a workover will replace the existing completion with 4-1/2" big tail pipe to facilitate the CTD window exit. An Orbit valve will also be installed. Post CTD workover, a mechanical whip -stock will be set inside the 4 ''/2" big tail pipe at the planned kick off point of 11,745' MD. The 2M -08L1 lateral will exit through the big tail pipe at 11,745' MD and TD at 16,000 MD. Ll lateral will be completed with 2 3/8" slotted liner from TD up to 12,100' MD with an aluminum billet for kicking off the 2M -08L1-01 lateral. The 2M -08L1-01 will drill to a TD of 14,150' MD, with the liner top at 11,676' MD; just above the whipstock. Page 4 of 7 July 26, 2016 PTD Application: 2M-081_1, 2M-081_1-01 Pre -CTD Work 1. Perform RWO to install 3-1/2" tubing, Orbit valve, packer, and 4-1/2" big tail pipe. Rid Work 1. MIRU Nabors CDR2-AC or CDR3-AC rig using 2" coil tubing. NU 7-1/16" BOPE, test. 2. 2M -08L1 Lateral (A4 sand to south) a. Set whip -stock at 11,745' MD b. Mill 2.80" window at 11,745' MD. c. Drill 3" bi-center lateral to TD of 16,000' MD. d. Run 23/8" slotted liner with an aluminum billet from TD up to 12,100' MD. 3. 2M -08L1-01 Lateral (A3 sand to south) a. Kickoff of the aluminum billet at 12,100' MD. b. Drill 3" bi-center lateral to TD of 14,150' MD. c. Run 23/8" slotted liner from TD up into 31/2" tubing at 11,676' MD 4. Freeze protect. Set BPV, ND BOPE. RDMO Nabors CDR2-AC or Nabors CDR3-AC. Post -Rig Work 1. Pull BPV. 2. Obtain SBHP. 3. Install GLV's . 4. Return to production. Page 5 of 7 July 26, 2016 PTD Application: 2M -08L1, 2M-081_1-01 Pressure Deployment of BHA The planned bottom hole assemblies (BHAs) are too long to simply isolate by closing the double swab valves on the Christmas tree. MPD operations require the BHA to be lubricated under pressure, so installed in this well is a deployment valve. This valve, when closed using hydraulic control lines from surface, isolates the well pressure and allows long BHA's to be deployed/un-deployed without killing the well. If the deployment valve fails, operations will continue using the standard pressure deployment process. A system of double swab valves on the Christmas tree, double deployment rams, double check valves and double ball valves in the BHA, and a slick -line lubricator can be used. This pressure control equipment listed ensures there are always two barriers to reservoir pressure, both internal and external to the BHA, during the deployment process. During BHA deployment, the following steps are observed. — Initially the double swab valves on the tree are closed to isolate reservoir pressure. The lubricator is installed on the BOP riser with the BHA inside the lubricator. — Pressure is applied to the lubricator to equalize across the swab valves. The swab valves are opened and the BHA is lowered in place via slickline. — When the BHA is spaced out properly, the double deployment rams are closed on the BHA to isolate reservoir pressure via the annulus. A closed set of double ball valves and double check valves isolate reservoir pressure internal to the BHA. Slips on the double deployment rams prevent the BHA from moving when differential pressure is applied. The lubricator is removed once pressure is bled off above the deployment rams. — The coiled tubing is made up to the BHA with the double ball valves plus the double check valves in the closed position. Pressure is applied to the coiled tubing to equalize internal pressure and then the double ball valves are opened. The injector head is made up to the riser, annular pressure is equalized, and the deployment rams are opened. The BHA and coiled tubing are now ready to run in the hole. During BHA undeployment, the steps listed above are observed, only in reverse. Liner Running — The 2M-08 well has a deployment valve installed. It will serve to deploy liners into the newly drilled laterals. If the valve fails, the laterals will be displaced to an overbalance completion fluid (as detailed in Section 8 "Drilling Fluids Program") prior to running liner. — While running 23/" slotted liner, a joint of 2%" non -slotted tubing will be standing by for emergency deployment. A floor valve is made up onto this joint ahead of time, and the rig crew conducts a deployment drill with this emergency joint on every slotted liner run. The 2%" rams will provide secondary well control while running 2%" liner. 14. Disposal of Drilling Mud and Cuttings (Requirements of 20 AAC 25.005(c)(14)) • No annular injection on this well. • All solid waste will be transported to the grind and inject facility at DS -4 Prudhoe Bay for disposal. • Incidental fluids generated from drilling operations will be injected in a Kuparuk Class II disposal well (1 R-18 or 1 B disposal facilities) or Prudhoe DS -4 if a Kuparuk facility is unavailable. • All wastes and waste fluids hauled from the pad must be properly documented and manifested. • Contact Kuparuk Environmental Coordinator for questions regarding waste classification. (670-4200). Page 6 of 7 July 26, 2016 PTD Application: 21VI-081-1, 21VI-081-1-01 15. Directional Plans for Intentionally Deviated Wells (Requirements of 20 AAC 25.050(b)) - The Applicant is the only affected owner. - Please see Attachment 1: Directional Plans - Magnetic and inclination surveys will be taken every 30 ft. No gyro will be run. - MWD directional, resistivity, and gamma ray will be run over the entire open hole section. Distance to Nearest Property Line (measured to KPA boundary at closest point) Lateral Name Distance 2M -08L1 14,294 2M -08L1-01 14,300' Distance to Nearest Well within Pool Lateral Name Distance Well 2M -08L1 240' 2K-27 2M-08AL1-01 1,700' 2K-27 16. Attachments Attachment 1: Directional Plans for 2M -08L1 laterals Attachment 2: Current Well Schematic for 2M-08 Attachment 3: Planned rig workover schematic Attachment 4: Proposed Well Schematic for 2M -08L1 and 2M -08L1-01 laterals Page 7 of 7 July 26, 2016 Loepp, Victoria T (DOA) From: Connelly, Jeff <Jeff.S.Connelly@conocophillips.com> Sent: Monday, August 08, 2016 12:37 PM To: Loepp, Victoria T (DOA) Subject: RE: KRU 2M-08L1(PTD 216-095) Anti -collision Hello Victoria, 2K-27 has been shut-in since October of 2014 and will remain shut-in during the duration of the drilling of 2M-081_1 and 2M-081-1-01. Please let me know if you have any additional questions. Thank you, Jeff Connelly Associate CTD Engineer 907-263-4112 (Office) 907-328-8854 (Mobile) 700 G Street, ATO 662 Jeff.S.Connelly@conocophillips.com r ConocoPhillips Ajay From: Loepp, Victoria T (DOA)[mailto:victoria.loepp@alaska.gov] Sent: Monday, August 08, 201611:08 AM To: Connelly, Jeff <Jeff.S.Connelly@conocophilIips.com> Subject: [EXTERNAL]KRU 2M-08L1(PTD 216-095) Anti -collision Jeff, KRU 2M-081_1 fails major risk with 2K-27. What mitigation measures will be in place? Will a deep plug be set or will 2K- 27 be SI during drilling? Thanx, Victoria Victoria Loepp Senior Petroleum Engineer State of Alaska Oil & Gas Conservation Commission 333 W. 7th Ave Anchorage, AK 99501 Work: (907)793-1247 Victoria. Loepp(a)alaska.gov CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Victoria Loepp at (907)793-1247 or Victoria. Loepp@alaska.aov AdMilit KUP PROD 2M-08 Arm COnocoPhillips Well Attributes Max Angle & MD TD Alaska, Inc. Wellbore API/UWI Field Name Wellbore Status 501032018400 KUPARUK RIVER UNIT PROD ncl (°) MD (ftKB) Act Don (ftKB) 68.171 7,756.40 12,151.0 • Comment M25 (ppm) Dala SSSV: TRDP 55 11/21/2015 Annotation End Date Last WO: KB-Grd (ft) Rig Release Date 46.21 11/9/1992 2M-08, 016 5:57:24 PM Va..] cherretic actual Annotation Depth (ftKB)End Dale Annotation Lasl Mod ey End Date Last Tag: SLM 11,842.0 3/2/3016 Rev Reason: GLV C/O, CUT TUBING, SET 2.80 pproven 6/8/2016 .........__... _.. _. ..__..,.._. ISO SLEEVE HANGER', 392 asing r—in g$ I Casing Description00 (in) ID (in) Top (ftKB) Set Depth (ftKB) Set Depth (TVD)... Wt/Len (I... Grade Top Thread CONDUCTOR 16 15.062 42.0 121.0 121.0 62.58 H-40 WELDED 1 Casing Description OD (in) ID (in) Top (ftKB) Set Depth (ftKB) Set Depth (TVD)... WULen (I... Grade Top Thread (. SURFACE 95/8 8.921 41.8 4,252.8 2,743.9 47.00 L-80 AB -MOD Casing Description OD (in) ID (in) Top (ftKB) Set Depth (ftKB) Set Depth (TVD)... INV en (I... Grade Top Thread PRODUCTION 7 6.276 39.2 12,138.0 6,466.1 26.00 J-55 JBTC Tubing Strings Tubing Description Slnng Ma... ID (in) Top (ftKB) Set Depth (ft.. Sei Depth (TVD) (... Wl (11,/11) Grade Top Connection cONDUCTOR;42.0-121.0 TUBING 31/2 2.992 39.2 11,610.5 6,069.4 9.30 J-55 ABM-EUE Completion Details Nominal ID Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des Com (in) 39.2 39.2 0.24 HANGER FMC GEN IV TUBING HANGER 3.500 SAFETY VLV', 1,806.9 1,806.9 1,655.5 46.56 SAFETY VLV CAMCO TRDP-4A-RO SAFETY VALVE 2.812 (SET 2.80" ISO SLEEVE IN TRSV ON 6/6/2016) 11,568.1 6,037.7 41.88 PER BAKER PER 3.000 11,581.9 6,047.9 41.50 PACKER BAKER HB RETRIEVABLE PACKER 2.870 11,598.0 6,060.1 41.14 NIPPLE CAMCO D NIPPLE 2.750 11,609.6 6,068.8 40.94 SOS BAKER SHEAR OUT SUB, TTL ELMD @ 11605' SWS 3.015 PPROF 6/3/2007 1 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top (TVD) Top Incl Top (ftKB) (ftKB) (°) Des Com Run DateF.1m, 11,548.0 6,022.7 42.35 CUT TUBING CUT TUBING 512/2016 SURFACE; 41.83,252.8 Perforations & Slots GAS LIFT; 4,384.9 Shot Dens Top (TVD) Btm (TVD) (shoal( Top (ftKB) Bim (ftKe) (ftKB) (ftKB) Zone Date t) Type Co. 11,721.0 11,750.0 6,152.9 6,174.8 A-5, A-4, 210- 12/26/1992 4.0 IPERF 180 deg. phasing; 41/2" 08 Csg Gun 11,784.0 11,807.0 6,200.3 6,217.5 A-3, 2M -O8 4/6/2013 6.0 APERF 2.5" HSD Gun, 60 degree phase Mandrel Inserts St GAS LIFT; 8,855.3 all on Top (TVD) Valve Latch Port Size TRO Run N Top (ftKB) (ftKB) Make Model OD (in) S., Type Type (in) (psi) Run Dale Com 1 4,384.9 2,800.6 CAMCO KBUG 1 GAS LIFT GLV INT 0.188 1,344.0 1/25/2015 2 81855.3 4,627.8 CAMCO KBUG 1 GAS LIFT GLV INT 0.188 1,323.0 1/28/2015 GAS LIFT; 11,039.0 3 11,039.0 5,669.0 CAMCO KBUG 1 GAS LIFT GLV INT 0.188 1,303.0 5/2/2016 4 11,520.6 6,002.5 CAMCO MMG 1 1/2 GAS LIFT OPEN 6/5/2016 Notes: General & Safety End Dale Annotation 11/11/2010 NOTE: View Schematicw/ Alaska Schematic9.0 GAS LIFT; 11,520.6- 1,520.fiCIIT CUTTUBING, 11,548.0 PBR; 11,568.1 PACKER; 11,581.9 NIPPLE; 11,598.0 SOS: 11,609.5 IPERF; 11,721.0-11,750.0 APERF; 11,784 0-11,807.0 PRODUCTION; 39.2-12,138.0 16" 62# H - shoe @ 12 MD 9-5/8" 47A shoe @ 4: CTD K( @ 11,7 A5 -sand pe 11721' - 11' A3 -sand per 11784'-11E 2M-08 Proposed RWO Schematic Baker Orbit Valve at 4500' MD (2.835" minimum ID) 3-1/2" 9.3# L-80 ELIE 8rd Tubing to surface 3-1/2" Camco gas lift mandrels @ TBD Baker PBR @ XXXX' MD Baker FHL packer @ xxxx' MD 3-1/2" HES landing nipple - xxxx' MD (2.812" min ID) 4-1/2" Big Tail Pipe (see details below) I'-11765' MD CRITICAL DEPTH!! t-1/2", 12.6#, J-55, STC Range 3 (assume jnts 42' ea) :s ported between each wearsox so old perfs not restricted :h correlated via drill pipe irsox 6" OD, every 2.5-3.0' along the pipe )I/shoe on bottom onnections Baker -Locked 2M-08 Proposed CTD Schematic 16" 62# H-40 shoe @ 121' MD 9-5/8" 47# L-80 shoe @ 4253' MD IKOP @ 11,745' MD A5 -sand perfs 11721'- 11750' MD A3 -sand perfs 11784'- 11807' MD 7" 26# J-55 shoe @ 12138' MD Baker Orbit Valve at —4500' MD (2.835" minimum ID) 3-1/2" 9.3# L-80 ELIE 8rd Tubing to surface 3-1/2" Camco gas lift mandrels @ TBD Baker PBR @ XXXX' MD Baker FHL packer @ xxxx' MD 3-1/2" HES landing nipple — xxxx' MD (2.812" min ID) 4-1/2" Big Tail Pipe planned at 11,681'-11765' MD 2M-081-1 WP05 (A4 South) TD @ 16,000' MD Billet @ 12,100' MD 2M -08L1-01 WP04 (A3 South West) TD @ 14,150' MD Top of Liner@ 11,600' MD ConocoPh i I I i ps ConocoPhillips (Alaska) Inc. -Kup2 Kuparuk River Unit Kuparuk 2M Pad 2M-08 501032018400 2M-081-1 Plan: 2M-08L1_wp06 Standard Planning Report 22 July, 2016 WO Papps BAKER HUGHES ConocoPhillips 2M -08L1 ConocoPhillips Database: EDM Alaska NSK Sandbox Company: ConocoPhillips (Alaska) Inc. -Kup2 Project: Kuparuk River Unit Site: Kuparuk 2M Pad Well: 2M-08 Wellbore: 2M-081-1 Design: 2M-08 L 1 _wp06 ConocoPhillips 2M -08L1 Planning Report Local Co-ordinate Reference: Well 2M-08 TVD Reference: Mean Sea Level MD Reference: 2M-08 @ 147.00usft (P245) 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 rel .I BAKER HUGHES Site Kuparuk 2M Pad Site Position: Northing: 5,948,985.89 usft Latitude: 70° 16' 18.578 N From: Map Easting: 487,859.45 usft Longitude: 150° 5'53.484 W Position Uncertainty: 0.00 usft Slot Radius: 0.000 in Grid Convergence: -0.09 ° Well 2M-08 2M -08L1 Well Position +N/ -S 0.00 usft Northing: 5,948,985.84 usft Latitude: 70° 16' 18.579 N +E/ -W 0.00 usft Easting: 487,949.23 usft Longitude: 150° 5'50.870 W Position Uncertainty 0.00 usft Wellhead Elevation: usft Ground Level: 105.50 usft Wellbore 2M -08L1 Magnetics Model Name Sample Date Declination Dip Angle Field Strength (nT) BGGM2015 5/1/2016 _18.26 80.90 57,48_ I Design 2M-081-1_wp06 Audit Notes: Version: Phase: PLAN Tie On Depth: 11,740.89 Vertical Section: Depth From (TVD) +N/ -S +E/ -W Direction (usft) (usft) (usft) (°) -105.50 0.00 0.00 180.00 7/22/2016 4:23:01PM Page 2 COMPASS 5000.1 Build 74 r ConocoPhillips NM ConocoPhillips Planning Report BAKER HUGHES Database: EDM Alaska NSK Sandbox Local Co-ordinate Reference: Well 2M-08 Company: ConocoPhillips (Alaska) Inc. -Kup2 TVD Reference: Mean Sea Level Project: Kuparuk River Unit MD Reference: 2M-08 @ 147.00usft (P245) Site: Kuparuk 2M Pad North Reference: True Well: 2M-08 Survey Calculation Method: Minimum Curvature Wellbore: 2M-081-1 Azimuth System Design: 2M-08L1_wp06 Rate Rate Plan Sections Measured TVD Below Dogleg Build Turn Depth Inclination Azimuth System +N/ -S +E/ -W Rate Rate Rate TFO (usft) (°) (°) (usft) (usft) (usft) (°/100ft) (°/100ft) (°1100ft) (°) 11,740.89 41.11 185.37 6,020.94 -9,313.44 -855.55 0.00 0.00 0.00 0.00 11,745.00 41.17 185.38 6,024.03 -9,316.13 -855.80 1.47 1.46 0.24 6.26 11,766.00 45.37 185.38 6,039.32 -9,330.46 -857.15 20.00 20.00 0.00 0.00 11,878.51 96.00 185.38 6,075.33 -9,432.77 -866.79 45.00 45.00 0.00 0.00 11,948.51 100.33 153.84 6,065.14 -9,500.03 -854.56 45.00 6.19 -45.05 280.00 12,018.51 94.67 122.57 6,055.78 -9,551.01 -808.83 45.00 -8.09 -44.68 262.00 12,058.51 94.16 119.40 6,052.70 -9,571.53 -774.64 8.00 -1.27 -7.92 261.00 12,128.51 93.72 116.63 6,047.89 -9,604.33 -713.00 4.00 -0.63 -3.96 261.00 12,675.00 90.12 138.21 6,029.38 -9,934.27 -281.90 4.00 -0.66 3.95 99.00 13,125.00 90.11 156.21 6,028.46 -10,311.00 -39.17 4.00 0.00 4.00 90.00 13,550.00 90.11 173.21 6,027.64 -10,719.44 72.52 4.00 0.00 4.00 90.00 14,000.00 90.41 191.20 6,025.58 -11,167.26 55.28 4.00 0.07 4.00 89.00 14,500.00 89.02 171.25 6,028.09 -11,664.60 44.62 4.00 -0.28 -3.99 266.00 15,000.00 89.08 191.25 6,036.47 -12,161.88 33.75 4.00 0.01 4.00 90.00 15,250.00 89.42 173.76 6,039.77 -12,410.65 22.86 7.00 0.14 -7.00 271.00 15,550.00 89.46 194.76 6,042.73 -12,708.14 0.72 7.00 0.01 7.00 90.00 16,000.00 89.54 163.26 6,046.76 -13,152.40 8.43 7.00 0.02 -7.00 270.00 Target 7/22/2016 4:23:01PM Page 3 COMPASS 5000.1 Build 74 i ConocoPhillips EkI ConocoPhillips Planning Report BAKER HUGHES Database: EDM Alaska NSK Sandbox Local Co-ordinate Reference: Well 2M-08 Company: ConocoPhillips (Alaska) Inc. -Kup2 TVD Reference: Mean Sea Level Project: Kuparuk River Unit MD Reference: 2M-08 @ 147.00usft (P245) Site: Kuparuk 2M Pad North Reference: True Well: 2M-08 Survey Calculation Method: Minimum Curvature Wellbore: 2M-081-1 Depth Inclination Azimuth Design: 2M-08L1_wp06 +E/ -W Section Planned Survey Measured TVD Below Vertical Dogleg Toolface Map Map Depth Inclination Azimuth System +N/ -S +E/ -W Section Rate Azimuth Northing Easting (usft) (o) (o) (usft) (usft) (usft) (usft) (°/100ft) (°) (usft) (usft) 11,740.89 41.11 185.37 6,020.94 -9,313.44 -855.55 9,313.44 0.00 0.00 5,939,674.71 487,078.85 TIP 11,745.00 41.17 185.38 6,024.03 -9,316.13 -855.80 9,316.13 1.47 6.26 5,939,672.02 487,078.60 KOP 11,766.00 45.37 185.38 6,039.32 -9,330.46 -857.15 9,330.46 20.00 0.00 5,939,657.70 487,077.22 End 20 dls, Start 46 dls 11,800.00 60.67 185.38 6,059.71 -9,357.42 -859.69 9,357.42 45.00 0.00 5,939,630.74 487,074.64 11,878.51 96.00 185.38 6,075.33 -9,432.77 -866.79 9,432.77 45.00 0.00 5,939,555.42 487,067.43 4 11,900.00 97.59 175.77 6,072.79 -9,454.08 -867.01 9,454.08 45.00 -80.00 5,939,534.11 487,067.18 11,948.51 100.33. 153.84 6,065.14 -9,500.03 -854.56 9,500.03 45.00 -81.14 5,939,488.14 487,079.54 5 12,000.00 96.37 130.76 6,057.56 -9,540.02 -823.60 9,540.02 45.00 -98.00 5,939,448.11 487,110.44 12,018.51 94.67 122.57 6,055.78 -9,551.01 -808.83 9,551.01 45.00 -101.40 5,939,437.10 487,125.19 End 45 dls, Start RSM 12,058.51 94.16 119.40 6,052.70 -9,571.53 -774.64 9,571.53 8.00 -99.00 5,939,416.52 487,159.34 7 12,100.00 93.90 117.76 6,049.78 -9,591.33 -738.30 9,591.33 4.00 -99.00 5,939,396.66 487,195.65 12,128.51 93.72 116.63 6,047.89 -9,604.33 -713.00 9,604.33 4.00 -99.12 5,939,383.62 487,220.93 8 12,200.00 93.27 119.46 6,043.53 -9,637.88 -650.03 9,637.88 4.00 99.00 5,939,349.98 487,283.84 12,300.00 92.62 123.41 6,038.39 -9,689.95 -564.83 9,689.95 4.00 99.17 5,939,297.78 487,368.94 12,400.00 91.96 127.36 6,034.39 -9,747.80 -483.39 9,747.80 4.00 99.38 5,939,239.80 487,450.29 12,500.00 91.30 131.31 6,031.54 -9,811.14 -406.09 9,811.14 4.00 99.53 5,939,176.34 487,527.48 12,600.00 90.63 135.25 6,029.86 -9,879.67 -333.31 9,879.67 4.00 99.65 5,939,107.70 487,600.14 12,675.00 90.12 138.21 6,029.38 -9,934.27 -281.90 9,934.27 4.00 99.71 5,939,053.03 487,651.45 9 12,700.00 90.12 139.21 6,029.32 -9,953.05 -265.40 9,953.05 4.00 90.00 5,939,034.22 487,667.92 12,800.00 90.12 143.21 6,029.12 -10,030.98 -202.76 10,030.98 4.00 90.00 5,938,956.20 487,730.43 12,900.00 90.12 147.21 6,028.91 -10,113.08 -145.71 10,113.08 4.00 90.01 5,938,874.02 487,787.34 13,000.00 90.12 151.21 6,028.71 -10,198.97 -94.53 10,198.97 4.00 90.02 5,938,788.06 487,838.38 13,100.00 90.11 155.21 6,028.51 -10,288.21 -49.46 10,288.21 4.00 90.03 5,938,698.75 487,883.30 13,125.00 90.11 156.21 6,028.46 -10,311.00 -39.17 10,311.00 4.00 90.03 5,938,675.95 487,893.55 10 13,200.00 90.11 159.21 6,028.31 -10,380.38 -10.72 10,380.38 4.00 90.00 5,938,606.53 487,921.89 13,300.00 90.11 163.21 6,028.12 -10,475.03 21.49 10,475.03 4.00 90.01 5,938,511.84 487,953.94 13,400.00 90.11 167.21 6,027.92 -10,571.70 47.02 10,571.70 4.00 90.01 5,938,415.14 487,979.31 13,500.00 90.11 171.21 6,027.73 -10,669.91 65.74 10,669.91 4.00 90.02 5,938,316.91 487,997.88 13,550.00 90.11 173.21 6,027.64 -10,719.44 72.52 10,719.44 4.00 90.03 5,938,267.37 488,004.58 11 13,600.00 90.14 175.21 6,027.53 -10,769.18 77.57 10,769.18 4.00 89.00 5,938,217.62 488,009.55 13,700.00 90.21 179.20 6,027.22 -10,869.04 82.44 10,869.04 4.00 89.00 5,938,117.77 488,014.26 13,800.00 90.28 183.20 6,026.79 -10,969.00 80.34 10,969.00 4.00 89.02 5,938,017.82 488,012.00 13,900.00 90.35 187.20 6,026.25 -11,068.57 71.27 11,068.57 4.00 89.03 5,937,918.28 488,002.77 14,000.00 90.41 191.20 6,025.58 -11,167.26 55.28 11,167.26 4.00 89.06 5,937,819.62 487,986.63 12 14,100.00 90.13 187.21 6,025.11 -11,265.95 39.28 11,265.95 4.00 -94.00 5,937,720.97 487,970.47 14,200.00 89.85 183.22 6,025.12 -11,365.51 30.19 11,365.51 4.00 -94.02 5,937,621.43 487,961.22 14,300.00 89.57 179.23 6,025.63 -11,465.47 28.05 11,465.47 4.00 -94.02 5,937,521.49 487,958.92 14,400.00 89.29 175.24 6,026.62 -11,565.33 32.86 11,565.33 4.00 -94.00 5,937,421.63 487,963.57 14,500.00 89.02 171.25 6,028.09 -11,664.60 44.62 11,664.60 4.00 -93.96 5,937,322.35 487,975.17 13 7/22/2016 4: 23 01P Page 4 COMPASS 5000.1 Build 74 ConocoPhillips I r��! Planning Report Database: EDM Alaska NSK Sandbox +E/ -W Company: ConocoPhillips (Alaska) Inc. -Kup2 Easting Project: Kuparuk River Unit (°/100ft) MD Reference: Site: Kuparuk 2M Pad North Reference: True 4.00 Well: 2M-08 487,986.76 61.16 11,863.73 Wellbore: 2M-081-1 5,937,123.22 487,991.39 58.97 Design: 2M-08L1_wp06 89.86 5,937,023.29 487,989.04 Planned Survey 12,063.21 4.00 89.80 5,936,923.77 Measured 33.75 12,161.88 TVD Below 89.73 Depth Inclination Azimuth System +N/ -S (usft) (1 (1) (usft) (usft) 14,600.00 89.02 175.25 6,029.80 -11,763.87 14,700.00 89.03 179.25 6,031.50 -11,863.73 14,800.00 89.04 183.25 6,033.19 -11,963.67 14,900.00 89.06 187.25 6,034.85 -12,063.21 15,000.00 89.08 191.25 6,036.47 -12,161.88 End RSM, Start 7 ells 89.89 5,936,327.68 487,940.94 15,100.00 89.21 184.25 6,037.97 -12,260.89 15,200.00 89.35 177.26 6,039.23 -12,360.81 15,250.00 89.42 173.76 6,039.77 -12,410.65 15 5,936,131.32 487,904.64 -25.33 12,955.79 15,300.00 89.42 177.26 6,040.28 -12,460.48 15,400.00 89.43 184.26 6,041.28 -12,560.41 15,500.00 89.45 191.26 6,042.25 -12,659.43 15,550.00 89.46 194.76 6,042.73 -12,708.14 16 15,600.00 89.46 191.26 6,043.20 -12,756.84 15,700.00 89.47 184.26 6,044.13 -12,855.86 15,800.00 89.49 177.26 6,045.05 -12,955.79 15,900.00 89.51 170.26 6,045.93 -13,055.13 16,000.00 89.54 163.26 6,046.76 -13,152.40 Planned TD at 16000.00 ConocoPhillips I r��! Planning Report Map BAKER +E/ -W Section HUGHES Local Co-ordinate Reference: Well 2M-08 Easting TVD Reference: Mean Sea Level (°/100ft) MD Reference: 2M-08 @ 147.00usft (P245) (usft) North Reference: True 4.00 Survey Calculation Method: Minimum Curvature 487,986.76 712212016 4:23:01PM Page 5 COMPASS 5000.1 Build 74 Vertical Dogleg Toolface Map Map +E/ -W Section Rate Azimuth Northing Easting (usft) (usft) (°/100ft) (°) (usft) (usft) 56.37 11,763.87 4.00 90.00 5,937,223.07 487,986.76 61.16 11,863.73 4.00 89.93 5,937,123.22 487,991.39 58.97 11,963.67 4.00 89.86 5,937,023.29 487,989.04 49.82 12,063.21 4.00 89.80 5,936,923.77 487,979.73 33.75 12,161.88 4.00 89.73 5,936,825.14 487,963.50 20.26 12,260.89 7.00 -89.00 5,936,726.16 487,949.86 18.95 12,360.81 7.00 -88.90 5,936,626.25 487,948.38 22.86 12,410.65 7.00 -88.81 5,936,576.41 487,952.22 26.78 12,460.48 7.00 90.00 5,936,526.58 487,956.06 25.46 12,560.41 7.00 89.96 5,936,426.66 487,954.58 11.98 12,659.43 7.00 89.89 5,936,327.68 487,940.94 0.72 12,708.14 7.00 89.83 5,936,278.99 487,929.61 -10.53 12,756.84 7.00 -90.00 5,936,230.31 487,918.28 -24.01 12,855.86 7.00 -89.97 5,936,131.32 487,904.64 -25.33 12,955.79 7.00 -89.90 5,936,031.41 487,903.16 -14.46 13,055.13 7.00 -89.84 5,935,932.06 487,913.87 8.43 13,152.40 7.00 -89.78 5,935,834.76 487,936.60 712212016 4:23:01PM Page 5 COMPASS 5000.1 Build 74 ConocoPh i I I i ps ConocoPhillips (Alaska) Inc. -Kup2 Kuparuk River Unit Kuparuk 2M Pad 2M-08 501032018400 2M -08L1 2M-08L1_wp06 Travelling Cylinder Report 12 July, 2016 WCA a I BAKER HUGHES Baker Hughes INTEQ rias ConocoPhillips Travelling Cylinder Report BAKER HUGHES Company: ConocoPhillips (Alaska) Inc. -Kup2 Project: Kuparuk River Unit Reference Site: Kuparuk 2M Pad Site Error: 0.00 usft Reference Well: 2M-08 Well Error: 0.00 usft Reference Wellbore 2M-081_1 Reference Design: 2M-08L1_wp06 Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Output errors are at Database: Offset TVD Reference: Well 2M -O8 2M-08 @ 147 00usft (P245) 2M-08 @ 147.00usft (P245) True Minimum Curvature 1.00 sigma OAKEDMP2 Offset Datum Reference 2M-08L1_wp06 Filter type: GLOBAL FILTER APPLIED: All wellpaths within 200'+ 100/1000 of reference Interpolation Method: MD Interval 25.00usft Error Model: ISCWSA Depth Range: 11,740.89 to 16,000.00usft Scan Method: Tray. Cylinder North Results Limited by: Maximum center -center distance of 1,795.85 usft Error Surface: Elliptical Conic Survey Tool Program Date 7/12/2016 From To (usft) (usft) Survey (Wellbore) Tool Name Description 151.90 11,740.89 2M-08 Srvy 1 - GCT -MS (2M-08) GCT -MS Schlumberger GCT multishot 11,740.89 16,000.00 2M-08L1_wp06 (2M -08L1) MWD MWD - Standard Casing Points Offset Centre to Measured Vertical Casing Hole Depth Depth Diameter Diameter (usft) (usft) Name Warning 121.00 121.00 16" 16 24 4,253.00 2,743.97 9 5/8" 9-5/8 12-1/4 16,000.00 6,193.76 2 3/8" 2-3/8 3 tmmary ite Name Offset Well - Wellbore - Design Cuparuk 2K Pad 2K-13 - 2K -13A - 2K -13A 2K-27 - 2K-27 - 2K-27 2K-34 - 2K -34L1 - 2K -34L1 :uparuk 2M Pad 2M-04 - 2M-04 - 2M-04 2M-08 - 2M-08 - 2M-08 2M-08 - 2M-0811-01 - 2M-08L1-01_wp05 2M-09 - 2M-09 - 2M-09 2M-32 - 2M-32 - 2M-32 2M-32 - 2M -32L1 - 2M-321_1 2M-32 - 2M -32L1-01 - 2M-321_1-01 2M-32 - 2M-321_1 PB1 - 2M-321_1 PB1 2M-32 - 2M -32L1 P132 - 2M -32L1 PB2 2M-33 - 2M-33 - 2M-33 2M-35 - 2M-35 - 2M-35 Reference Offset Centre to No -Go Allowable Measured Measured Centre Distance Deviation Warning Depth Depth Distance (usft) from Plan (usft) (usft) (usft) (usft) 14,800.00 11,691.00 1,632.71 326.06 1,307.75 Pass- Major Risk 15,292.62 12,950.00 256.03 2.36 254.56 Pass - Minor 1/10 13,236.72 12,397.00 961.98 338.17 625.25 Pass - Major Risk Out of range 11,774.84 11,775.00 1.63 2.64 -1.03 FAIL - Major Risk 11,924.65 11,925.00 2.65 0.49 2.28 Pass- Minor 1/10 Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Offset Design Kuparuk 2K Pad - 2K-13 - 2K -13A - 2K -13A offset site Error: 0 00 usft Survey Program: 40 -Copy of GYD-CT-CMS, 9258 -MWD Rule Assigned: Major Risk Offset Well Error: 0.00 usft Reference Offset Semi Major Axis Measured vertical Depth Depth Measured Vertical Reference Offset Depth Depth Toolface + Azimuth Offset Wellbore +N/ -S Centre +E/ -W Casing - Hole Size Centre to Centre No Go Distance Allowable Warning Deviation (usft) (usft) (usft) (usft) (usft) (usft) (°) (usft) (usft) (") (usft) (usft) (usft) 14,800.00 6,180.19 11,550.00 6,223.57 90.66 56.25 92.05 -12,014.52 1,830.49 2-11/16 1,772.62 325.62 1,448.20 Pass - Major Risk 14,800.00 6,180.19 11,575.00 6,225.25 9066 56.52 91.98 -12,015.53 1,805.57 2-11/16 1,747.78 325.64 1423.32 Pass - Major Risk 14,800.00 6,180.19 11,600.00 6,226.82 9066 56.79 91.91 -12,016.62 1,780.64 2-11/16 1,722.94 325.66 1,398.43 Pass - Major Risk CC - Min Centre to center distance or covergent point, SF - min separation factor, ES - min ellipse separation 7/1212016 4:06:46PM Page 2 COMPASS 5000.1 Build 74 Project: Kuparuk River Unit Site: Kuparuk 2M Pad Well: 2M-08 Well 2M-081-1 ConocoPhillips Plan: 2M -08L1 wp06 (2M -08/2M -08L1) REFERENCE INFORMATION Co-ordinate (NIE) Reference: We112M-08, True North Vertical (TVD) Reference: 2M-08 @ 147.00usft (2M-08) Section (VS) Reference: Slot-(O.00N, O.00E) Measured Depth Reference: 2M-08 @ 147.00usft (2M-08) ri.9 BAKER HUGHES AximuBms to True North Magnetic North'. 18.28' WELLBORE DETAILS: 21VI-081-1 Magnetic Fieid Parent Wellbore: 210-08 Strength: 57483.3snT Dip Male: 80.90' Tie on MD: 11740.89 Gate' 5/1/2016 Model: BGGM2015 REFERENCE INFORMATION Co-ordinate (NIE) Reference: We112M-08, True North Vertical (TVD) Reference: 2M-08 @ 147.00usft (2M-08) Section (VS) Reference: Slot-(O.00N, O.00E) Measured Depth Reference: 2M-08 @ 147.00usft (2M-08) ri.9 BAKER HUGHES West( -)/East(+) (350 usft/in) I/ r I -5950 -6300 -6650 6000: -. -7000 —_.. I 4/.A7 -:f -. r.... _. -7350 S p p p I o 7700 t '. I 0(10- -8050 -8400- 8400 -9750 -8750 /H(/. ..1 K-0er2K� & - - -9100 �_ 2f. G /2K -0R K-0 K U8�1 13' "T 0 2K -M 12K 09NI'FS3 —� 2K-08/2K K-08/ K r84i13t -9450: '_A Oa/2tv1 UJ ', G 2N,i OK/ 6 - 1,A�921-fry _h �fU2}K 41ti Ti V R � _M= J M:321 PRI 190800 � K IJ/21k-Innl 4 7- IK _ i t -losoo 6 -x4/31- _ '-341- 1 _. 2K -34/2K 31 ---- I C 10850 M 12)2M- 21JP13-- :.j•_ _ I. '�.. _ ', , -I 1200 .•. Oti � :M-3:18 T 12t 1 -11550 — •. M +2B f-321-1 L .__ I I _. i 62G� — � _T _ _ -11900 2K 13 K-IbA 9T1 35/ M -3y 1 - -�- �` g -12250 F T_— T -12600 — -_ ,... _. -12950 - — — 2 -13/2K 3e11.2 :. I -13300 -13650�---- -14000 _. - _,- 2S-07 2.5;07 ..;. -14.350 G -14700 f 2K 112K 19P 1.1 `-' 2K-20/ K-2tl -7000 -6650 -6300 -5950 -5600 -5250 -4900 -4550 -4200 -3850 -3500 -3150 -2800 -2450 -2100 -1750 -1400 -1050 -700 -350 0 350 700 1050 1400 1750 2100 2450 2800 3150 3500 3850 4200 4550 4900 5250 5600 5950 West( -)/East(+) (350 usft/in) ConocoPhillips Project: Kuparuk River Unit Site: Kuparuk 2M Pad Azimuths to True North Magnetic North: 18.26' Magnetic Field WELLBORE DETAILS: 2M-081_1 REFERENCE INFORMATION Parent Wellbore: 210-08 Co-ordinate (NIE) Reference: Well 2M-08, True Nollh Well: 210-08 Strength: 57480.3-T Tie on MD: 11740.89 Vertical (TVD) Reference: 2M -0B @ 147.00usit (2M-08) Wellbore: 2M-081-1 Dip Angle: 80.90• -----.- Section [VS) Reference: Slot -(O.00N, O.DOE) Plan: 210-081-1 W O6 210-08/210-081-1 _ P ( j Date: 5/12016 Madel: BGGM2015 4p Or Measured Depth Reference: 210-08 @ 147.00usf1(210-08) -- llt jjM-21)fw f (r Calculation Method: Minimum Curvature rel 04- BAKER HUGHES 2100 -- -----.- Lbl O /210-(,j = 2 tl 4p Or T •� -- llt jjM-21)fw f (r -- - _ - 21 (19/211-f9 101) 211{i>/ - N{ - 1400 M(I j 1(/210 .1210 19/ M-19 214- 7/211-1-, •5 p 21IIH/T (h :. 1 rnH-12 210{, /"It M-( .. 3 00 'O 1 0M1/ til -1 700 l �0000 �q© '(70 Kt _j ..M 03/ V4.•1 n 700 - Ifs -I o 101_0 ( �0� 21k 3/'II 4117/2 -1400 }� :. 6 -- 1.14/21, ?NJ -21!21,16 6 ,µ19 2100 -,-�- 210 7'210 _^ _ 4r '1110 !p 11N101). .P H-I412I 1 A 211 f1I P o y O I -.- I.. 0 ;r?rM1Frl( Irlll .. 5 lW 5 0 t/ �li•uR/2:Yu, -3500 G 3_.. J016 G d °sAYi 40 0 b� I- 60p0a -4200 - - 6600 a� 4 _ �2M-17/2M-E; 211-22/2V 22 �•�� -I Il2f Cllf/ -4900 X00211_ -141X114 j -5600 - I. —, r :. -0 J '5t00 41 ZK 7 T. 4f p0 ... - 21024/ W.2921 l - 2 •o4/2K W 2K-03 2K-03 2 4l99tt2K 02 -6300 -- - Rj 00 { ','_ ,§/ M _9&()o ...—fi b'\' 9, `^ 41 0 k.o. G 6400 c -7000 — _- ... 1-07 .. _ 9RK-2 n0 - p v -7700 Op .z1J r1l . " 2K.09 2K{}41_ rdl I . Sn0 S O soy t I. • a a ^ 0 00.. z8400 o`�Oo - 50[101 2 41812 ' : 16A 2K-08/" Kfl$721 K-08 ' qh -401!0 0 -0$API3 4)8A1'f3 -$ o CQ `i -9100' .. 2 -331210 32 IMaMI^_ ,,14 00 _..662 - - o A -1j9 .. p 2 -1012 `lo C/7)-9800 - — 34 — r _ _M 19¢10-11 n - o ro d2K-07(i b 2 092' .. .. •; v 0 -10500 2enM-3 U.1 P132 - -- >d R/2K- 41_ 1 - 21t 8Y2K RRl Q3 '+'x34/2K 341k3 I 0� o °. 1200 v7ZK 12K1 -] T rK- k 128 267 M , /210-3 14t2M-12/'M,;2[2K -0 6z�- 13/" Kj 13 \ 2K'. -0 ! 3a v 0 1,'yo Ii , b -11900' ^i;^vg - .151_ -12600 .. o - : 2K -2:'2f✓ -26A -, .• a •Ia2 I L. 'K.2 712K-27` T nK li'2K-.13 3 K -13300 � i. I _ -. -- 6 94 - 2K -1.12K-13 1.1 2K -13/2K -' 11A1.2 " _ - p�j s M/ � 0 312-2 14000 25.0.1 "4 z .n7/2.k 7 2M-0 /2M -08I I r YL/8 n / / 5 9 JO 0 5000 - K -14700 -�--- —.. �- . 2 ;a1i/2K 19ALI:. UA+ / G al -� SR5 8/2K.] I;.. 15400 _ .. ° ' 2 -2S/ 2K-iq1_. 1w'K ' _ __ a� �. 5 UO -K Al; -16100 _ -_- —t- -._ _ / _y,- r , •' p 2 22A .,:5/2K- _ _ 2KK-2?-2Zi Y 2M-�88S >A, 66 `7.00u1ft-(21008) — _. �S _ _ S01^ti-nl _ 3zK 'aT �" 6 0—r to/r min, - � 'M2�z/27C 2ALI{r K241 K a4 -13300-12600-11900-11200-10500-9800 -9100 -8400 -7700 -7000 -6300 -5600 -4900 -4200 -3500 -2800 -2100 -1400 -700 0 700 1400 2100 2800 3500 4200 4900 5600 6"3081/9 (t 7700 8400 9100 9800 10500 11200 11900 12600 West( -)/East(+) (700 usft/in) 525 540 C 555 � 570 585 600 Q R 615 U 630 N �3 645 H 660 675 Mean Sea L a Project: Kuparuk River Unit Site: Kuparuk 2M Pad Azimuths to True North Magnetic North: 18.26' Magnetic WELLBORE DETAILS: 2M -08A REFERENCE INFORMATION Parent Wellbore: 21-08 Coordinate (NIE) Reference. Well 2M-08, True North _ Well: 2M-08 2M-081_1 Strength: 57483.3snT .3- Dip Argle: 80.90• Tie on MD: 11740.89 Vertical (ND) Reference: Mean See Level Section (VS) Reference: Slot - (O.00N, O.00E) BAKER BAKER ConocoPhillips Wellbore: Plan:2M-08L1 O6 2M-08/21-081_1 .WP t 1 Date 5112016 Model: BGGM2015 Measured Depth Reference 2M-08@147.00usf1(2M-08) Calculation Method: Minimum Curvature 11 70' 16' 18.579 N 150' 5'50.870 W Sec MD Inc Azi 525 540 C 555 � 570 585 600 Q R 615 U 630 N �3 645 H 660 675 Mean Sea L a WELL DETAILS: West( -)/East(+) (5 00 usft/in) 2M-08 +N/ -S +E/ -W Northing Easting Latitude Longitude 0.00 0.00 5948985.84 487949.23 70' 16' 18.579 N 150' 5'50.870 W Sec MD Inc Azi TVDSS +N/ -S +E/ -W Meg TFace VSect Annotation 1 11740.89 41.11 185.37 6020.94 -9313.15 -855.87 0.00 0.00 9313.15 TIP 2 11745.00 41.17 185.38 6024.03 -9315.85 -856.13 1.47 6.26 9315.85 KOP 3 11766.00 45.37 185.38 6039.32 -9330.17 -857.48 20.00 0.00 9330.17 End 20 d1s, Start 45 dls 4 11878.51 96.00 185.38 6075.33 -9432.48 -867.11 45.00 0.00 9432.48 4 5 11948.51 100.33 153.84 F 6065.14 -9499.74 -854.89 45.00 280.00 9499.74 5 6 12018.51 94.67 122.57 End 2 6055.78 -9550.72 -809.15 45.00 262.00 9550.72 End 45 d1s, Start RSM 7 12058.51 94.16 119.40 6052.70 -9571.25 -774.96 8.00 261.00 9571.25 7 8 12128.51 93.72 116.63 6047.89 -9604.04 -713.32 4.00 261.00 9604.04 8 9 12675.00 90.12 138.21 {78 91 End S s, tart R. M 6029.38 -9933.98 -282.22 4.00 99.00 9933.98 9 10 13125.00 90.11 156.21 6028.46-10310.71 -39.50 4.00 90.0010310.71 10 11 13550.00 90.11 173.21 6027.64-10719.15 72.20 4.00 90.0010719.15 11 12 14000.00 90.41 191.20 6025.58 -11166.97 54.96 4.00 89.0011166.97 12 13 14500.00 89.02 171.25 6028.09-11664.31 44.30 4.00 266.0011664.31 13 14 15000.00 89.08 191.25 6036.48-12161.59 33.42 4.00 90.0012161.59 End RSM, Start 7 dls 1515250.00 89.42 173.76 6039.77-12410.36 22.54 7.00 271.0012410.36 15 16 15550.00 89.46 194.76 6042.73 -12707.85 0.40 7.00 90.0012707.85 16 17 16000.00 89.54 163.26 6046.76-13152.12 8.11 7.00 270.0013152.12 Planned TD at 16000.00 525 540 C 555 � 570 585 600 Q R 615 U 630 N �3 645 H 660 675 Mean Sea L a 50 9300 9450 9600 9750 9900 10050 10200 10350 10500 10650 10800 10950 11100 11250 11400 11550 11700 11850 12000 12150 12300 12450 12600 12750 12900 130501320013350 13500 13650 13800 13950 14i0l) 14250 Vertical Section at 180.00° (150 usft/in) West( -)/East(+) (5 00 usft/in) � a F. F I I IKop End 2 TIP „ dls, Start 45 t `. PI nned =0 D at 1 /2M-0 000.0 LI Is {78 91 End S s, tart R. M 1 1 12 ! I 2M 08/2X1 081,1-01 1 nd S , Stan7 I dls I I 2M -0812M -OE 1 I 2M-0 Ll Fauld 2M- 8L1 lault2 2 -27/2 -27 50 9300 9450 9600 9750 9900 10050 10200 10350 10500 10650 10800 10950 11100 11250 11400 11550 11700 11850 12000 12150 12300 12450 12600 12750 12900 130501320013350 13500 13650 13800 13950 14i0l) 14250 Vertical Section at 180.00° (150 usft/in) Loepp. Victoria T (DOA) From: Connelly, Jeff <Jeff.S.Connelly@conocophillips.com> Sent: Monday, August 08, 201612:37 PM To: Loepp, Victoria T (DOA) Subject: RE: KRU 2M-08L1(PTD 216-095) Anti -collision Hello Victoria, 2K-27 has been shut-in since October of 2014 and will remain shut-in during the duration of the drilling of 2M -08L1 and 2M -08L1-01. Please let me know if you have any additional questions. Thank you, Jeff Connelly Associate CTD Engineer 907-263-4112 (Office) ) 907-328-8854 (Mobile) 700 G Street, ATO 662 Jeff.S.Connelly@conocophillips.com CC)1' ocoPiiilips Alaska From: Loepp, Victoria T (DOA) [mailto:victoria.loepp@alaska.gov] Sent: Monday, August 08, 201611:08 AM To: Connelly, Jeff <Jeff.S.Connelly@conocophillips.com> Subject: [EXTERNAL]KRU 2M-08L1(PTD 216-095) Anti -collision Jeff, KRU 2M -08L1 fails major risk with 2K-27. What mitigation measures will be in place? Will a deep plug be set or will 2K- 27 be SI during drilling? Thanx, Victoria Victoria Loepp Senior Petroleum Engineer State of Alaska Oil & Gas Conservation Commission 333 W. 7th Ave Anchorage, AK 99501 Work: (907)793-1247 Victoria. Loepp(a)alaska.gov CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Victoria Loepp at (907)793-1247 or Victoria.Loepp@a1aska.gov TRANSMITTAL LETTER CHECKLIST WELL NAME: PTD: QI � /Development _ Service _ Exploratory _ Stratigraphic Test Non -Conventional FIELD: 2�UE,� 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. 19a- O1 , API No. 50-1D�- 0/9 - 00 - OD. e/ (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 PTD#: 2160950 Company CONOCOPHILLIPS ALASKA INC_ _ Initial Class/Type Well Name: KUPARUK RIV UNIT 2M-081_1 Program DEV Well bore seg ❑d DEV/PEND GeoArea 890 _ Unit 11160 On/Off Shore On Annular Disposal ❑ Administration 17 Nonconven. gas conforms to AS31.05.0300.1_.A),(j.2_.A-D) - - - - - - - - - - - - - - - - - NA- . . - - - - - - - - - - _ _ - - - - - _ - - - - - - - - _ . Surface casing -protects all -known USDWs 1 Permit fee attached- 20 CMT _vol _adequate -to circulate -on conductor surf_csg 2 Lease number appropriate_ - - - Yes ADL0025589, Top Prod Interv. &.TD; AD1_00.25586, Surf- Loc ---------- CMT vol adequate_ to tie-in long string to -surf csg - 3 Unique well name and number - Yes _ KRU 2M-081_1_ - - - - - - - - - - - - - - --- - - CMT - will coverall known -productive horizons- - - . 4 Well located in_a_defined_pool_ - ---- -. Yes KUPARUK RIVER,_KUPARUK_RIV OIL_- 4901.00,_governed_by Conservation -Order No. 432D Casing designs adequate for C,_T, B &_ permafrost_ 5 Well located proper distance from drilling unit -boundary -- - - - - - - - - - - - - - - - - Yes CO 432D contains no spacing restrictions with respect to drilling unit boundaries. - Adequate tankage_ or reserve pit 6 Well located proper distance from other wells_ - - - - Yes - - - CO 432D has no interwell spacing -restrictions._ - - - Ifa re -drill, has_a 1.0-403 for abandonment been approved 7 Sufficient acreage available in -drilling unit - - - - - - - - - - - - - - - - - - - Yes 26 Adequate wellbore separation_proposed 8 If -deviated, is -wellbore plat included Yes _ _ _ _ _ _ _ _ _ - - - - - - - - - - - - - - - - - - - - - - - If_diverter required, does it meet regulations_ - - - - - - - - - 9 Operator only affected party - - Yes _ _ . _ . Wellbore -will be more than 500' from an external property line -where -ownership or landownership -changes.. . Drilling fluid_ program schematic-& equip -list adequate- 10 Operator has -appropriate bond in force - - - - - - - - - Yes - - - - - - - - - - - - - - - - - - - - - - - - - Appr Date 11 Permit can be issued without conservation order_ - - - - Yes _ - - - -- -- - - - - -- - - BOPE_press rating appropriate; test to -(put psig in comments)_ 12 Permit_can be issued without administrativ_e_appr_oval - - - - - - - - - - - Yes - - - - - - - - - - - - - _ _ - - - PKB 8/1/2016 Yes �31 32 Work will occur without operation shutdown_ - - - 13 Can permit be approved before 15 -day wait_ Yes - - - - - - - Is presence of H2S gas probable - 14 Well located within area and strata authorized by Injection Order # (put_ 10# in -comments) (For- NA_ _ _ - .. .. _ _ _ _ - _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Mechanical_ condition of wells within AOR verified (For service well only) 15 _All wells -within -1/4 mile area.of review identified (For service well only). NA_ - - - - - - - - - - - - - - - Permit can be issued w/o hydrogen sulfide measures 16 Pre -produced injector; duration of pre -production fess than 3 months. (For -service well only) _NA_ - - - - - - - - - Geologic Engineering Public Commissioner: Date: mmission r: Date Commissioner Date � l�-,/i6 18 Conductor string provided - - - _ NA - - - - - Conductor set-in 2M-08 - - - - - - - Engineering 19 Surface casing -protects all -known USDWs NA_ - - - - - Surface casing set in_2M-O8 20 CMT _vol _adequate -to circulate -on conductor surf_csg NA_ _ - _ _ _ _ _ Surface casing set and fully cemented - 21 CMT vol adequate_ to tie-in long string to -surf csg - NA 22 CMT - will coverall known -productive horizons- - - . No Productive_ interval will -be completed with_s_lotted liner . 23 Casing designs adequate for C,_T, B &_ permafrost_ Yes 24 Adequate tankage_ or reserve pit Yes Rig has steel tanks; all_ waste_to approved disposal wells 25 Ifa re -drill, has_a 1.0-403 for abandonment been approved NA_ _ _ - _ _ _ . - - - 26 Adequate wellbore separation_proposed Yes Anti -collision analysis complete; major risk failure; 2K-27: $I 27 If_diverter required, does it meet regulations_ - - - - - - - - - NA - - - - - - - - . _ - --- Appr Date 28 Drilling fluid_ program schematic-& equip -list adequate- Yes Max formation_ pres is 4547psig(14.1 ppg EMW); Will -drill w/ 8.6 ppg_ EMW and maintain overbal w/ MPD VTL 8/4/2016 29 BOPEs,_do they meet regulation - Yes 30 BOPE_press rating appropriate; test to -(put psig in comments)_ Yes . - - - - - is 3930 psig; will test BOPS -to 4500_psig Choke -manifold complies w/API_ RP -53 (May 84) Yes �31 32 Work will occur without operation shutdown_ - - - Yes 33 Is presence of H2S gas probable - Yes H2S measures required_ i34 Mechanical_ condition of wells within AOR verified (For service well only) NA - - - - - - - - - 35 Permit can be issued w/o hydrogen sulfide measures No - - - Wells -on 2M -Pad are H2S-bearing, H2Smeasures_required. - . Geology 36 Data -presented on potential overpressure zones. Yes Expected r_eservoirpressure is 14.1 ppg EMW; will be drilled using -8.6 ppg-mud and MPD technique. Appr Date 37 _Seismicanalysisofshallow gas_zones--- - _N_A_ - - - - - - -- - - - - - - - - - - - - - - - - - - - - - - - - - -- - _ _ - . _ - - PKB 8/1/2016 38 Seabed condition survey_(if off_ -shore) NA_ 39 Contact name/phone for weekly -progress reports [exploratory only] . - - - - - - _Onshore development lateral to be drilled. Geologic Engineering Public Commissioner: Date: mmission r: Date Commissioner Date � l�-,/i6
