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Home My WebLink About216-118DATA SUBMITTAL COMPLIANCE REPORT 3/30/2017 Permit to Drill 2161180 Well Name/No. KUPARUK RIV UNIT 2X-131-1-03 Operator CONOCOPHILLIPS ALASKA INC API No. 50-029-21197-64-00 MD 10952 TVD 5952 Completion Date 12/16/2016 Completion Status 1 -OIL Current Status 1-0I1- UIC No REQUIRED INFORMATION Mud Log No Samples t No Z,— Directional Survey Yes DATA INFORMATION Types Electric or Other Logs Run: GR/Res Well Log Information: Log/ Electr Data Digital Dataset Type Med/Frmt Number Name ED C 27861 Digital Data ED C 27861 Digital Data Log C 27861 Log Header Scans ED C 27934 Digital Data ED C 27934 Digital Data ED C 27934 Digital Data ED C 27934 Digital Data ED C 27934 Digital Data ED C 27934 Digital Data ED C 27934 Digital Data ED C 27934 Digital Data ED C 27934 Digital Data ED C 27934 Digital Data ED C 27934 Digital Data ED C 27934 Digital Data ED C 27934 Digital Data ED C 27934 Digital Data (data taken from Logs Portion of Master Well Data Maint) Log Log Run Interval OH/ Scale Media No Start Stop CH Received Comments 1/6/2017 Electronic File: 2X-131-1-03 EOW - NAD27.pdf 1/6/2017 Electronic File: 2X-131-1-03 EOW - NAD27.txt 0 0 2161180 KUPARUK RIV UNIT 2X-131-1-03 LOG HEADERS 1/30/2017 Electronic File: 2X-131-1-03 2MD Final Log.cgm 1/30/2017 Electronic File: 2X-131-1-03 51VID Final Log.cgm - 1/30/2017 Electronic File: 2X-131-1-03 5TVDSS Final- Log.cgm !P 1/30/2017 Electronic File: 2X-131-1-03 2MD Final Log.PDF+ Jc'tP� 91/30/2017 Electronic File: 2X-131-1-03 5MD Final Log.PDF , 01/30/2017 Electronic File: 2X -13L1-03 5TVDSS Final Y Log.PDF 1/30/2017 Electronic File: 2X-131-1-03 EOW - NAD27.pdf - 1/30/2017 Electronic File: 2X-131-1-03 EOW - NAD27.txt - 1/30/2017 Electronic File: 2X -13L1-03 Final Surveys 10952 TD.csv 1/30/2017 Electronic File: 2X-131-1-03 Survey Listing.txt 1/30/2017 Electronic File: 2X-131-1-03 Surveys.txt 1/30/2017 Electronic File: 2X-131-1- 03_25_tapescan_BHI_CTK.txt 1/30/2017 Electronic File: 2X-131-1- 03_5_tapescan_BHI_CTK.txt - 1/30/2017 Electronic File: 2X-131-1-03_output.tap AOGCC Page I of 2 Thursday, March 30, 2017 DATA SUBMITTAL COMPLIANCE REPORT 3/30/2017 Permit to Drill 2161180 Well Name/No. KUPARUK RIV UNIT 2X-131-1-03 Operator CONOCOPHILLIPS ALASKA INC API No. 50-029-21197-64-00 MD 10952 TVD 5952 Completion Date 12/16/2016 Completion Status 1 -OIL Current Status 1 -OIL UIC No ED C 27934 Digital Data 1/30/2017 Electronic File: 2X-131-1-03 2MD Final Log..tif , ED C 27934 Digital Data 1/30/2017 Electronic File: 2X-131-1-03 5MD Final Log..tif ED C 27934 Digital Data 1/30/2017 Electronic File: 2X-131-1-03 5TVDSS Final Log..tif Log C 27934 Log Header Scans 0 0 2161180 KUPARUK RIV UNIT 2X -13L1-03 LOG HEADERS Well Cores/Samples Information: Name INFORMATION RECEIVED Completion Report I I Y / Production Test Informatio Y NA Geologic Markers/Tops Y COMPLIANCE HISTORY Completion Date: 12/16/2016 Release Date: 9/23/2016 Description Comments: Compliance Interval Start Stop Directional / Inclination Data y Mechanical Integrity Test Information Y �N Daily Operations Summary Date Comments Sample Set Sent Received Number Comments Mud Logs, Image Files, Digital Data Y,{/ Nq Core Chips Y/ A Composite Logs, Image, Data Files Core Photographs Y/ A Cuttings Samples Y / Laboratory Analyses Y / A Date: AOGC'C Page 2 of 2 Thursday, March 30, 2017 //.liv BAKER HUGHES RECEIVr CD in 216-114 27931 21 6' 18 27 93 4 JAN 3 0 2017 PRINT DISTRIBUTION LIST AV l: G , COMPANY ConocoPhillips Alaska, Inc. WELL NAME 2X -13L1-03 FIELD Prudhoe Bay Unit COUNTY North Slope Borough BHI DISTRICT Alaska Please sign and return one copy of this transmittal form to: ConocoPhillips Alaska, Inc. Tom Osterkamp DATA LOGGED - / 2/201 Z 700 GStreet. iai K. BENDER Anchorage, Alaska 99510 to acknowledge receipt of this data. LOG TYPE GR - RES LOG DATE December 15, 2016 AUTHORIZED BY Patrick Rider EMAIL Patrick. RiderCa)bakerhughes.com TODAYS DATE January 26, 2017 Revision STATUS Final Replacement: No Details: Requested by: --- COMPANY ADDRESS (FEDEX WILL NOT DELIVER TO P.O. BO* PERSON ATTENTION N FIELD FINAL CD CD LOGS LOGS (digital/image) Surveys (Final surveys) # OF PRINTS # OF HKIN 16 # OF COPIES # OF COPIES # OF COPIE 1 BP North Slope 0 0 0 EOA, PBOC, PRB-20 (Office 109) D&C Wells Project Aids Agatha Rutka & Barbara Glassmaker 900 E. Benson Blvd. Anchorage, Alaska 99508 r - 2 ConocoPhillips Alaska Inc. 0 0 0 Attn: Ricky Elgaricio ATO 3-344 700 G Street Anchorage, AK 99510 3 ExxonMobil, Alaska Attn: Lynda M. Vaskell and/or Leonardo Elias 3201 C Street, Suite 505 Anchorage, AK 99503 4 State of Alaska - AOGCC Attn: Makana Bender 333 W. 7th Ave, Suite 100 Anchorage, Alaska 99501 5 [DNR - Division of Oil & Gas *** Attn: Resource Evaluation I 1550 West 7th Avenue, Suite 1100 Anchorage, Alaska 99501 *** Stamp "confidential' on all material deliver to DNR 6 BP Exploration (Alaska) Inc. Petrotechnical Data Center, LR2-1 1900 E. Benson Blvd. Anchorage, Alaska 99508 TOTALS FOR THIS PAGE: TOTALS FOR ALL PAGES: 1 1 1 0 2 3 3 0 0 0 2 3 3 0 0 ConocoPh i l l i s p ConocoPhillips (Alaska) Inc. -Kup2 Kuparuk River Unit Kuparuk 2X Pad 2X-1 X1-03 60-029-21197-64 Baker Hughes INTEQ Definitive Survey Report 21 December, 2016 1 61 1 27 93 4 Few a I BAKER HUGHES ConocoPhillips F&Aas �, ConocoPhillips Definitive Survey Report HIUGHES Company: ConocoPhillips (Alaska) Inc. -Kup2 Local Co-ordinate Reference: Well 2X-13 Project: Kuparuk River Unit TVD Reference: 2X-13 @ 112.00usft (2X-13) Site: Kuparuk 2X Pad MD Reference: 2X-13 @ 112.00usft (2X-13) Well: 2X-13 North Reference: True Wellbore: 2X-131-1-03 Survey Calculation Method: Minimum Curvature Design: 2X-131-1-03 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 2X-13 Well Position +N/-S 0.00 usft Northing: 5,971,233.11 usft Latitude: 70° 19' 57.263 N +E/-W 0.00 usft Easting: 518,889.15usft Longitude: 149° 50'48.394 W Position Uncertainty 0.00 usft Wellhead Elevation: usft Ground Level: 0.00 usft Wellbore 2X-13L1-03 Magnetics Model Name Sample Date Declination Dip Angle Field Strength (I (I (nT) BGG M2016 12/1/2016 17.84 80.94 57,544 Design 2X-131-1-03 Audit Notes: Version: 1.0 Phase: ACTUAL Tie On Depth: 8,640.80 Vertical Section: Depth From (TVD) +N/-S +E/-W Direction (usft) (usft) (usft) (I 112.00 0.00 0.00 135.00 Survey Program Date 12116/2016 From To Survey Survey (usft) (usft) Survey (Wellbore) Tool Name Description Start Date End Date 200.00 8,100.00 2X-13 (2X-13) GCT-MS Schlumberger GCT multishot 1/16/2001 8,159.00 8,640.80 2X-131-1 (2X-131-1) MWD MWD - Standard 11/25/2016 11/29/2016 8,670.00 10,900.76 2X-131-1-03 (2X-131-1-03) MWD MWD - Standard 12/11/2016 12/15/2016 12121/2016 5.3244PM Page 2 COMPASS 5000.1 Build 74 *I' ConocoPhillips RUN ConocoPhillips Definitive Survey Report HUGHES Company: ConocoPhillips (Alaska) Inc. -Kup2 Project: Kuparuk River Unit Site: Kuparuk 2X Pad Well: 2X-13 Wellbore: 2X-131-1-03 Design: 2X-131-1-03 Survey Local Co-ordinate Reference: Well 2X-13 TVD Reference: 2X-13 @ 112.00usft (2X-13) MD Reference: 2X-13 @ 112.00usft (2X-13) North Reference: True Survey Calculation Method: Minimum Curvature Database: EDM Alaska NSK Sandbox MD Inc AN TVD TVDSS +N1 -S +E1 -W Map (usft) (' 0 (usft) (usft) (usft) (usft) Northing 18.06 1,343.38 MWD (3) 523,337.46 16.15 1,359.02 MWD (3) 523,332.97 12.19 (ft) 8,640.80 92.46 191.57 5,991.49 5,879.49 2,619.47 4,475.67 5,973,863.58 8,670.00 93.25 194.34 5,990.04 5,878.04 2,591.05 4,469.14 5,973,835.15 8,700.42 98.74 194.54 5,986.86 5,874.86 2,561.77 4,461.60 5,973,805.85 8,730.20 101.93 190.88 5,981.52 5,869.52 2,533.20 4,455.15 5,973,777.26 8,759.97 102.19 187.18 5,975.29 5,863.29 2,504.45 4,450.58 5,973,748.51 8,790.03 101.65 182.08 5,969.08 5,857.08 2,475.14 4,448.21 5,973,719.20 - 8,819.38 98.84 179.20 5,963.86 5,851.86 2,446.27 4,447.89 5,973,690.33 8,850.38 94.70 177.20 5,960.21 5,848.21 2,415.51 4,448.86 5,973,659.57 8,880.41 89.69 173.91 5,959.06 5,847.06 2,385.61 4,451.18 5,973,629.68 8,909.95 89.82 169.30 5,959.18 5,847.18 2,356.39 4,455.49 5,973,600.48 8,940.63 90.61 165.77 5,959.07 5,847.07 2,326.44 4,462.12 5,973,570.55 8,972.29 90.18 161.39 5,958.85 5,846.85 2,296.08 4,471.06 5,973,540.21 8,999.92 88.59 157.80 5,959.15 5,847.15 2,270.19 4,480.69 5,973,514.35 9,030.03 88.37. 159.97 5,959.94 5,847.94 2,242.11 4,491.54 5,973,486.30 9,060.04 91.07 162.63 5,960.09 5,848.09 2,213.69 4,501.16 -5,973,457.91 9,090.50 90.12 166.08 5,959.77 5,847.77 2,184.37 4,509.37 5,973,428.61 9,120.32 88.10 169.33 5,960.24 5,848.24 2,155.24 4,515.72 5,973,399.50 9,145.34 88.99 172.31 5,960.87 5,848.87 2,130.55 4,519.71 5,973,374.82 9,174.82 88.96 175.24 5,961.40 5,849.40 2,101.25 4,522.90 5,973,345.54 9,205.25 90.46 179.22 5,961.55 5,849.56 2,070.87 4,524.37 5,973,315.16 9,235.04 90.61 181.53 5,961.28 5,849.28 2,041.08 4,524.18 - 5,973,285.37 9,265.16 90.18 184.87 5,961.07 5,849.07 2,011.01 4,522.50 5,973,255.30 9,296.76 90.21 188.65 5,960.96 5,848.96 1,979.64 4,518.78 5,973,223.92 9,326.50 92.67. 192.42 5,960.21 5,848.21 1,950.42 4,513.34 5,973,194.69 9,358.28 95.14 190.85 5,958.05 5,846.05 1,919.36 4,506.95 5,973,163.63 9,394.52 95.51 188.37 5,954.69 5,842.69 1,883.79 4,500.93 5,973,128.04 9,420.05 92.77 187.16 5,952.84 5,840.84 1,858.56 4,497.49 5,973,102.81 9,446.20 90.03 185.24 5,952.20 5,840.20 1,832.58 4,494.66 5,973,076.82 9,478.16 87.48 185.08 5,952.90 5,840.90 1,800.76 4,491.79 5,973,044.99 9,507.89 85.21 180.56 5,954.79 5,842.79 1,771.13 4,490.33 5,973,015.37 Map Vertical Easting DLS (°1100') Section Survey Tool Name (ft) (ft) 523,357.77 9.63 1,312.53 MWD (2) 523,351.30 9.85 1,328.01 MWD (3) 523,343.84 18.06 1,343.38 MWD (3) 523,337.46 16.15 1,359.02 MWD (3) 523,332.97 12.19 1,376.12 MWD (3) 523,330.67 16.70 1,395.17 MWD (3) 523,330.42 13.60 1,415.36 MWD (3) 523,331.47 14.81 1,437.79 MWD (3) 523,333.87 19.95 1,460.58 MWD (3) 523,338.25 15.61 1,484.29 MWD (3) 523,344.95 11.79 1,510.15 MWD (3) 523,353.97 13.90 1,537.95 MWD (3) 523,363.67 14.21 1,563.06 MWD (3) 523,374.58 7.24 1,590.58 MWD (3) 523,384.27 12.63 1,617.48 MWD (3) 523,392.55 11.75 1,644.02 MWD (3) 523,398.98 12.83 1,669.11 MWD (3) 523,403.03 12.43 1,689.39 MWD (3) 523,406.30 9.94 1,712.36 MWD (3) 523,407.84 13.98 1,734.89 MWD (3)- 523,407.72 7.77 1,755.81 MWD (3) 523,406.12 11.18 1,775.89 MWD (3) 523,402.48 11.96 1,795.44 MWD (3) 523,397.12 15.13 1,812.26 MWD (3) 523,390.80 9.20 1,829.70 MWD (3) 523,384.87 6.89 1,850.59 MWD (3) - 523,381.49 11.73 1,866.00 MWD (3) 523,378.74 12.79 1,882.38 MWD (3) 523,375.94 7.99 1,902.85 MWD (3) 523,374.56 16.98 1,922.76 MWD (3) Annotation TIP KOP 12/21/2016 5:32:44PM Page 3 COMPASS 5000.1 Build 74 ConocoPhillips Has ConocC -Phillips Definitive Survey Report HUGHES Company: ConocoPhillips (Alaska) Inc. -Kup2 Local Co-ordinate Reference: Well 2X-13 Project: Kuparuk River Unit TVD Reference: 2X-13 @ 112.00usft (2X-13) Site: Kuparuk 2X Pad MD Reference: 2X-13 @ 112.00usft (2X-13) Well: 2X-13 North Reference° True Wellbore: 2X-131-1-03 Survey Calculation Method: Minimum Curvature Design: 2X-131-1-03 Database: EDM Alaska NSK Sandbox Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/ S +E/ -W Northing Eastin9 DLS Section Survey Tool Name Annotation (usft) (°) C) (rift) (-ft) (usft) (usft) (ft) (ft) (°1100') (ft) . 9,535.94 84.16 176.95 5,957.39 5,845.39 1,743.22 4,490.93 5,972,987.45 523,375.23 13.35 1,942.93 MWD (3) 9,565.00 84.07 173.03 5,960.37 5,848.37 1,714.42 4,493.46 5,972,958.67 523,377.83 13.42 1,965.07 MWD (3) 9,595.05 85.05 169.88 5,963.22 5,851.22 1,684.85 4,497.90 5,972,929.11 523,382.35 10.93 1,989.13 MWD (3) 9,624.70 84.56 167.21 5,965.91 5,853.91 1,655.91 4,503.77 5,972,900.19 523,388.28 9.12 2,013.74 MWD (3) 9,656.52 85.85 164.48 5,968.57 5,856.57 1,625.17 4,511.52 5,972,869.47 523,396.12 9.46 2,040.96 MWD (3) 9,681.48 87.39 161.75 5,970.04 5,858.04 1,601.33 4,518.76 5,972,845.65 523,403.41 12.54 2,062.93 MWD (3) 9,710.99 88.53 158.70 5,971.09 5,859.09 1,573.58 4,528.73 5,972.817.93 523,413.46 11.03 2,089.61 MWD (3) 9,743.90 86.53 155.98 5,972.51 5,860.51 1,543.24 4,541.40 5,972,787.63 523,426.20 10.25 2,120.02 MWD (3) 9,770.44 87.24 152.98 5,973.95 5,861.95 1,519.33 4,552.82 5,972,763.75 523,437.67 11.60 2,145.00 MWD (3) 9,795.92 87.39 150.69 5,975.15 5,863.15 1,496.89 4,564.83 5,972,741.34 523,449.74 9.00 2,169.36 MWD (3) 9,825.20 87.45 146.31 5,976.47 - 5,864.47 1,471.96 4,580.11 5,972,716.45 523,465.08 14.95 2,197.79 MWD (3) 9,854.97 88.07 144.22 5,977.63 5,865.63 1,447.51 4,597.06 5,972,692.05 523,482.09 7.32 2,227.06 MWD (3) 9,885.56 89.60 142.12 5,978.25 5,866.25 1,423.04 4,615.39 5,972,667.62 523,500.48 8.49 2,257.33 MWD (3) 9,920.43 91.26 139.19 5,977.99 5,865.99 1,396.08 4,637.49 5,972,640.72 523,522.65 9.66 2,292.03 MWD (3) 9,950.72 91.38 136.02 5,977.29 5,865.29 1,373.71 4,657.91 5,972,618.41 523,543.12 10.47 2,322.27 MWD (3) 9,981.22 89.60 133.95 5,977.03 5,865.03 1,352.16 4,679.48 5,972,596.91 523,564.74 8.95 2,352.77 MWD (3) 10,010.26 92.85 132.18 5,976.41 5,864.41 1,332.33 4,700.68 5,972,577.14 523,585.99 12.74 2,381.78 MWD (3) 10,035.52 95.41 130.74 5,974.59 5,862.59 1,315.65 4,719.56 5,972,560.51 523,604.91 11.62 2,406.93 MWD (3) 10,065.39 93.56 128.27 5,972.25 5,860.25 1,296.71 4,742.54 5,972,541.63 523,627.93 10.31 2,436.56 MWD (3) 10,090.66 93.31 125.93 5,970.74 5,858.74 1,281.50 4,762.65 5,972,526.47 523,648.09 9.30 2,461.55 MWD (3) 10,120.54 94.97 122.44 5,968.58 5,856.58 1,264.76 4,787.30 5,972,509.79 523,672.77 12.91 2,490.81 MWD (3) 10,145.05 94.45 119.84 5,966.57 5,854.57 1,252.13 4,808.21 5,972,497.22 523,693.71 10.78 2,514.53 MWD (3) 10,176.90 92.39 118.04 5,964.67 5,852.67 1,236.74 4,836.03 5,972,481.90 523,721.57 8.58 2,545.08 MWD (3) 10,208.99 88.56 116.73 5,964.40 5,852.40 1,221.99 4,864.51 5,972,467.22 523,750.09 12.61 2,575.66 MWD (3) 10,236.08 84.90 116.07 5,965.95 5,853.95 1,209.96 4,888.73 5,972,455.26 523,774.34 13.73 2,601.28 MWD (3) 10,267.32 85.30 112.79 5,968.62 5,856.62 . 1,197.09 4,917.07 5,972,442.46 523,802.70 10.54 2,630.42 MWD (3) 10,296.30 - 84.63 109.79 5,971.16 5,859.16 1,186.61 4,943.96 5,972,432.05 523,829.62 10.57 2,656.85 MWD (3) 10,330.66 86.13 106.49 5,973.93 5,861.93 1,175.95 4,976.51 5,972,421.47 523,862.18 10.52 2,687.40 MWD (3) 10,356.24 86.59 103.10 5,975.55 5;863.55 1,169.43 5,001.18 5,972,415.02 523,886.88 13.35 2,709.46 MWD (3) 10,386.16 86.90 100.30 5,977.25 5,865.25 1,163.38 5,030.43 5,972,409.03 523,916.14 9.40 2,734.42 MWD (3) 10,420.45 87.39 97.79 5,978.96 5,866.96 1,157.99 5,064.25 5,972,403.74 523,949.96 7.45 2,762.14 MWD (3) 1212112016 5:32:44PM Page 4 COMPASS 5000.1 Build 74 12/21/2016 5:32:44PM Page 5 COMPASS 5000.1 Build 74 ConocoPhillips //j, ConocoPhillips BAKER Definitive Survey Report HUGHES Company: ConocoPhillips (Alaska) Inc. -Kup2 Local Co-ordinate Reference: Well 2X-13 Project: Kuparuk River Unit TVD Reference: 2X-13 @ 112.00usft (2X-13) Site: Kuparuk 2X Pad MD Reference: 2X-13 @ 112.00usft (2X-13) Well: 2X-13 North Reference: True Wellbore: 2X-131-1-03 Survey Calculation Method: Minimum Curvature Design: 2X-131-1-03 Database: EDM Alaska NSK Sandbox Survey Map Map Vertical MD Inc Azi .TVD TVDSS +N/ -S +E/ -W Northin g Eastin g DLS Section (usft) (°) (I (usft) (usft) (usft) (usft) (°/100') Survey Tool Name Annotation (ft) (ft) (ft) 10,450.22 89.48 95.97 5,979.77 5,867.77 1,154.43 5,093.79 5,972,400.25 523,979.51 9.31 2,785.55 MWD (3) 10,480.48 89.85 94.29 5,979.95 5,867.95 1,151.72 5,123.93 5,972,397.62 524,009.65 5.68 2,808.77 MWD (3) 10,510.48 91.56 96.70 5,979.58 5,867.58 1,148.85 5,153.79 5,972,394.82 524,039.51 9.85 2,831.92 MWD (3) 10,540.69 93.84 98.79 5,978.16 5,866.16 1,144.79 5,183.68 5,972,390.83 524,069.42 10.23 2,855.93 MWD (3) 10,571.76 96.76 99.05 5,975.29 5,863.29 1,139.99 5,214.24 5,972,386.11 524,099.99 9.43 2,880.93 MWD (3) 10,602.20 96.21 102.04 5,971.85 5,859.85 1,134.45 5,243.97 5,972,380.65 524,129.73 9.93. 2,905.87 MWD (3) 10,632.61 94.23 104.05 5,969.08 5,857.08 1,127.62 5,273.47 5,972,373.89 524,159.24 9.26 2,931.56 MWD (3) ` 10,662.97 91.93 105.30 5,967.45 5,855.45 1,119.94 5,302.80 5,972,366.29 524,188.58 8.62 2,957.73 MWD (3) 10,691.74 90.92 107.49 5,966.74 5,854.74 1,111.82 5,330.39 5,972,358.24 524,216.19 8.38 2,982.98 MWD (3) 10,722.41 90.95 110.67 5,966.24 5,854.24 1,101.80 5,359.37 5,972,348.29 524,245.19 10.37 3,010.55 MWD (3) 10,752.76 91.50 113.14 5,965.59 5,853.59 1,090.48 5,387.52 5,972,337.04 524,273.37 8.34 3,038.46 MWD (3) 10,783.22 91.20 116.22 5,964.87 5,852.87 1,077.77 5,415.18 5,972,324.40 524,301.06 10.16 3,067.02 MWD (3) 10,816.75 92.28 119.39 5,963.85 5,851.85 1,062.14 5,444.82 5,972,308.85 524,330.74 9.98 3,099.03 MWD (3) 10,842.36 i 93.60 121.09 5,962.54 5,850.54 1,049.26 5,466.92 5,972,296.02 524,352.86 8.40 3,123.76 MWD (3) 10,871.76 94.86 123.68 5,960.37 5,848.37 1,033.55 5,491.67 5,972,280.39 524,377.66 9.77 3,152.37 MWD (3) 10,900.76 95.81 126.77 5,957.67 5,845.67 1,016.90 5,515.26 5,972,263.79 524,401.28 11.10 3,180.82 MWD (3) 10,952.00 95.81 126.77 5,952.49 5,840.49 986.39 5,556.09 5,972,233.39 524,442.19 0.00 3,231.27 PROJECTED to TD 12/21/2016 5:32:44PM Page 5 COMPASS 5000.1 Build 74 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION RECEIVED JAN 13 2017 WELL COMPLETION OR RECOMPLETION REPORT A 1a. Well Status: Oil R] . Gas❑ SPLUG ❑ Other ❑ Abandoned ❑ Suspended ❑ 20AAC 25.105 20AAC 25.110 GINJ ❑ WINJ ❑ WAG❑ WDSPL ❑ No. of Completions: 1b. Well Class: Development I] ' Exploratory ❑ Service ❑ Stratigraphic Test ❑ 2. Operator Name: ConocoPhillips Alaska, Inc. 6. Date Comp., Susp., oryf t Aband.: 12A�6 / 14. Permit to Drill Number/ Sundry: 216-118/ ' , 3. Address: P.O. Box 100360 Anchorage, AK 99510-0360 7. Date Spudded: 12/11/2016 15. API Number: 50-029-21197-64-00 4a. Location of Well (Governmental Section): Surface: 1229' FSL, 238' FEL, Sec 4, T11N, R9E, UM Top of Productive Interval: 3819' FSL, 1043' FEL, Sec 3, T11 N, R9E, UM Total Depth: 2213' FSL, 5240' FEL, Sec 2, T11 N, R9E, UM 8. Date TD Reached: 12,114;12016- lz f �5%llQ " 16. Well Name and Number: KRU 2X-131-1-03, 9. Ref Elevations: KB: 112 GL: 77 BF:76 17. Field / Pool(s): Kuparuk River Field/Kuparuk Oil Pool 10. Plug Back Depth MD/TVD: 10952/5952 , 18. Property Designation: ADL 25645, ADL 25646 4b. Location of Well (State Base Plane Coordinates, NAD 27): Surface: x- 518889 y- 5971233 Zone- 4 TPI: x- 523351 y- 5973835 Zone- 4 Total Depth: x- 524442 y- 5972233 Zone- 4 11. Total Depth MD/TVD: 10952/5952 ' 19. Land Use Permit: ALK 2576 12. SSSV Depth MD/TVD: N/A 20. Thickness of Permafrost MD/TVD: 1561/1512 5. Directional or Inclination Survey: Yes , E] (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 MD/TVD: 8670/5990 22. Logs Obtained: List all logs run and, pursuant to AS 31.05.030 and 20 AAC 25.071, submit all electronic data and printed logs within 90 days of completion, suspension, or abandonment, whichever occurs first. Types of logs to be listed include, but are not limited to: mud log, spontaneous potential, gamma ray, caliper, resistivity, porosity, magnetic resonance, dipmeter, formation tester, temperature, cement evaluation, casing collar locator, jewelry, and perforation record. Acronyms may be used. Attach a separate page if necessary GR/Res 23. CASING, LINER AND CEMENTING RECORD WT. PER GRADE SETTING DEPTH MD HOLE SIZE CEMENTING RECORD SETTING DEPTH TVD AMOUNT CASING FT TOP BOTTOM TOP BOTTOM PULLED 16 62.5 H-40 37 103 37 103 24 260 sx Cold Set II 95/8 36 J-55 36 3747 36 3030 121/4 900 sx CS III, 650 sx CSII 7 26 J-55 34 8510 34 6163 81/2 315 sx Class G 23/8 4.6 L-80 8161 10952 5918 5952 3 Slotted Liner 24. Open to production or injection? Yes 2 No ❑ If Yes, list each interval open (MD/TVD of Top and Bottom; Perforation Size and Number): Slotted Liner @ 8161 - 10952 MD and 5918 - 5952 TVD t2 I lte t Le 25. TUBING RECORD SIZE DEPTH SET (MD) PACKER SET (MD/TVD) 3 1/2 8181 7778/5638 8121/5889 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. Was hydraulic fracturing used during completion? Yes ❑ No 2 Per 20 AAC 25.283 (i)(2) attach electronic and printed information DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED 27. PRODUCTION TEST Date First Production: 12/26/2016 Method of Operation (Flowing, gas lift, etc.): GAS LIFT Date of Test: 12/27/16 Hours Tested: 12 hrs Production for Test Period Oil -Bbl: 241 Gas -MCF: 491 Water -Bbl: 1876 Choke Size: 176/176 Gas -Oil Ratio: 2040 Flow Tubing Press. 157 Casinq Press: 1245 Calculated 24 -Hour Rate Oil -Bbl: 482 Gas -MCF: 983 Water -Bbl: 3752 Oil Gravity - API (corr): Forrrl 10 403Fiel%ed,11/2015/ �7 VTL ZL 6 _fQ tNUED 0N PAGE 2 ti s,l 7 yr^ Submit ORIGINIAL only 28. CORE DATA Conventional Core(s): Yes ❑ No D Sidewall Cores: Yes ❑ No 0 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 0 If yes, list intervals and formations tested, briefly summarizing test results. Permafrost - Top Surface Surface Permafrost - Base 1561 1512 Attach separate pages to this form, if needed, and submit detailed test Top of Productive Interval 8670 5990 information, including reports, per 20 AAC 25.071. TD 'uv��Lv`L A N 10952 5951 ,r Formation at total depth: Ku aruk A 31. List of Attachments: Daily Operations Summary, Definitive Survey, Schematic Information to be attached includes, but is not limited to: summary of daily operations, wellbore schematic, directional or inclination survey, core analysis, paleontoloaical reoort, voduction or well test results, r 20 AAC 25.070. 32. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Ron Phillips Ca-) 265-6312 Email: ron.l. hilli s co .com Printed Name: K. Starck Title: CTD Director Signature: Phone: 263-4093 Date: 1-13-17 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 1 b: 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 2X-13 Final CTD Schematic MD 9-5/8" 36# J-55 shoe @ 3,747' MD C -sand parts 7,970 - 8,014' MD KOP at 8159' 2X -13L1-03 34 ROHS TD at 10,952 MD Liner top 8161' MD Eaarem Later I Lat a4 -------------------------------- Lat x7 2X-131-1-02 TD at 10,929' MD 7" 26# J-55 shoe Dner billet at 8670' MO @ 8,510' MD Baker Orbit Valve at 3498' MD (2.835" minimum ID) 3-1/2" 9.3# L-80 EUE 8rd Tubing to surface 3-1/2" Camco gas lift mandrels @ 2932', 4782', 6228', 7140', 7706' MD. Baker FHL Packer w/PBR @ 7779' MD 3-1/2" X -nipple 7832' MD (2.813" min ID) Production mandrels @ 7886', 8073' MD. Baker F Packer w/SBR @ 81 21'MD Northern Solutions Back up WEDGE (KOP -8145') 3-1/2" X -nipple 8157' MD Northern Solutions WEDGE (KOP -8165') 3-1/2" X -nipple 8177' MD 131-1-01 Dat 11,169' MD ty t Late I Liner billet at 8715 MD PF --'- _-- - -- -- 2X-131-1� Let Mi TDat 11,100'MDe Liner billet at 9097' MD nd perts 4-8240 ,' 8 - 8,288' Operations Summary (with Timelog Depths) 2X-13 Aw Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Time End Time our (hr) Phase Op Code Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 11/24/2016 11/24/2016 3.50 MIRU MOVE MOB P Prep to move rig to 2X-13. Peak 00:00 03:30 trucks on location 11:30 pm. 11/24/2016 11/24/2016 2.50 MIRU MOVE MOB P Move rig from 2K-11 to 2X-13 03:30 06:00 11/24/2016 11/24/2016 1.00 MIRU MOVE MOB P Hold rig @ CPF2 for field crew 06:00 07:00 change. ( 7 miles traveled) 11/24/2016 11/24/2016 1.50 MIRU MOVE MOB P On site, 10.5 miles total trip. 4 hrs 07:00 08:30 travel time, 2.62 mph average speed while moving. 11/24/2016 11/24/2016 2.00 MIRU MOVE MOB P Spot and set down sub 08:30 10:30 11/24/2016 11/24/2016 1.50 MIRU MOVE MOB P Spot and set down service 10:30 12:00 11/24/2016 11/24/2016 6.00 MIRU MOVE MOB P Rig up, spot shop, thaw cellar stab 12:00 18:00 BOP. 11/24/2016 11/24/2016 5.00 MIRU WHDBOP NUND P Bolt up BOP stack, RU managed 18:00 23:00 pressure line. Valve crew serviced tree valves. Check all tree flange bolts ok. Accept rig 23:00 11/24/2016 11/25/2016 1.00 MIRU WHDBOP RURD P Flush lines and grease. 23:00 00:00 11/25/2016 11/25/2016 1.50 MIRU WHDBOP RURD P C/O, Prep rig floor for BOP test. 0.0 0.0 00:00 01:30 Dress threads on SSV, damaged, install fusable cap. Flood lines & stack. Shell test to 3000 psi good. 11/25/2016 11/25/2016 7.00 MIRU WHDBOP BOPE P PJSM, BOPE test (3000/250 psi, 2500 0.0 0.0 01:30 08:30 psi annular). UQC changed out on previous tower, double check no checks installed. Begin fluid packing coil @ 0700. Finish IRV and packoff test. "AOGCC inspector, Lou Grimaldi, waived witness via e-mail @ 2138 on 11/24/2016.** 11/25/2016 11/25/2016 2.00 MIRU WHDBOP PRTS P PT PDLs and TT line. 0.0 0.0 08:30 10:30 11/25/2016 11/25/2016 2.75 MIRU WHDBOP MPSP P PJSM, retrieve BPV. Make two 0.0 0.0 10:30 13:15 attempts, no BPV. Wrong retrieval tool rigged up. Swapped retrieval tools and pulled BPV. WHP=475 psi. 11/25/2016 11/25/2016 1.25 SLOT WELLPR DHEQ P Function Orbit valve, had to replace 0.0 0.0 13:15 14:30 gauge with leaking threads on control line. Attempt to bleed IA. Could not get below 1200 psi. Will rig up to TT after swapping well over to FloPro for milling and bleed down. 11/25/2016 11/25/2016 2.20 PROD1 RPEQPT PULD P PJSM, PD BHA #1 (2.8" no-go mill, 0.0 74.0 14:30 16:42 2.79" no-go string mill, 0.6° AKO X- treme motor). 11/25/2016 11/25/2016 1.80 PROD1 RPEQPT TRIP P RIH, PU Wt 38k lbs. Tie into the K1 74.0 7,925.0 16:42 18:30 for a +9.5' correction. 11/25/2016 11/25/2016 2.00 PROD1 RPEQPT` TRIP P Close EDC, RIH, dry tag WS @ 7,925.0 8,160.5 18:30 20:30 8160.5', PUH while start C9, RBIH, pumping 1.7 bpm, CT 4186 psi, CT RIH Wt 27.9k lbs, HW 122 psi, Diff 476 no load. 11/25/2016 11/25/2016 1.00 PROD1 RPEQPT RGRP T Generator issues, PUH, pumps to min 8,160.0 8,160.0 20:30 21:30 rate. Experiencing losses, order truck of Seawater to build powervis milling fluid. Estimate - 7 b/hr Page 1/24 Report Printed: 12/30/2016 Operations Summary Timelog Depths) (with 2X-13 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time Dur (hr) Phase Op Code Activity Code Time P -T -X Operation (ftKB) End Depth (WB) 11/25/2016 11/25/2016 2.40 PROD1 RPEQPT CIRC P RIH, 34 deg ROHS, 1.73 bpm, CT 8,160.0 8,161.7 21:30 23:54 426 psi, diff 494 psi off bottom, well head 57 psi. Tag up 8160' Zero G/L, RIH 1/10' per 6 min, WOB - 1 k lbs. 650 psi diff. Increase WOB to 3.3 k lbs after 1 foot milled, set auto driller. Pump 20 bbls High Vis pill and squeeze away. 11/25/2016 11/26/2016 0.10 PROD1 RPEQPT RGRP T Discovered weep from pulsation 8,161.7 8,161.7 23:54 00:00 dampner, PUH, swap pumps, discover leaking butterfly vallve on suction side of pump #2. 11/26/2016 11/26/2016 0.20 PROD1 RPEQPT RGRP T Isolate pump #2, swap back to pump 8,161.7 8,161.4 00:00 00:12 #1. 11/26/2016 11/26/2016 2.80 PROD1 WHPST WPST P Time milling exit window. 1.71 bpm, 8,161.4 8,163.0 00:12 03:00 CT 4246 psi, WH 86 psi, WOB 2.59 k lbs, Diff 700 psi, WOB fell off from 3.5k lbs to 3.0 k lbs @ 8162.9' then built back up to 3.8k lbs @ 8163.6 total losses midnight till 0300 26 bbls. 11/26/2016 11/26/2016 3.00 PROD1 WHPST WPST P Time milling exit window. Estimate 8,161.4 8,165.0 03:00 06:00 mill approx at top of 7" window and bottom of 3.5 window. total losses since midnight 34.3 bbls Time milling window exit, 1.7 bpm, CT 4200 psi, WH 95 psi, WOB 3.5k lbs, diff 736 psi. 11/26/2016 11/26/2016 5.90 PROD1 WHPST WPST P Time milling window exit off of 8,165.0 8,172.0 06:00 11:54 Northern Solutions Tandom Wedge WS, 1.7 BPM @ 4122 psi FS, WOB 3.5 - 3.8, CTSW 11.5k - 14.6k, ROP 1 FPH. Saw WOB, motor work drop off @ 8,166.5'(6.5' passed TOWS). Cont time milling until 12' passed TOWS per program. 11/26/2016 11/26/2016 2.30 PROD1 WHPST WPST P Mill rathole, 1.7 BPM @ 3861 psi FS, 8,172.0 8,184.7 11:54 14:12 WOB 2.6k, CTSW 12k, ROP 5 FPH. 11/26/2016 11/26/2016 1.40 PROD1 WHPST REAM P PUW=31 k. Perform 4 backreaming 8,184.7 8,137.0 14:12 15:36 passes @ 1 FPM w specified tool faces per program. Losses since 0600: 13 bbls (-40.5 bbls lost since midnight). 11/26/2016 11/26/2016 0.10 PROD1 WHPST REAM P Dry drift window, small (200-300 Ib) 8,135.0 8,179.0 15:36 15:42 WOB bobbles. Looks good. 11/26/2016 11/26/2016 1.40 PROD1 WHPST TRIP P PUH, PUW=30k, open EDC, POOH 8,179.0 3,498.0 15:42 17:06 slow until 5x5 sweeps reach bit. Cont POOH. 11/26/2016 11/26/2016 1.40 PROD1 WHPST TRIP P Jet Orbit valve area, POOH, jog near 3,498.0 77.0 17:06 18:30 surface, 11/26/2016 11/26/2016 1.00 PROD1 WHPST PRTS P Tag up and space out, close 77.0 77.0 18:30 19:30 deployment valve, PT orbit valve to 3000 psi. Initial, 3084 psi, 5 min 3071 psi, 10min 3054 psi, 15 min 3039 psi. lost 45 psi in 15 min 1.4%, lost 13, 17 and 15 psi per 5 min interval respectively. Page 2/24 Report Printed: 12/30/2016 Operations Summary (with Timelog Depths) 2X-13 Wiw Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time our (hr) Phase Op Code Activity Code Time P -T -X Operation (W) End Depth (ftKB) 11/26/2016 11/26/2016 1.50 PROM WHPST PULD P Bleed system, Fow check, PJSM, lay 77.0 0.0 19:30 21:00 down BHA #1. String mill & window mill both 2.79" no-go. 11/26/2016 11/26/2016 0.30 PROM WHPST PULD P MU nozzle, shut swab, stab on, 0.0 0.0 21:00 21:18 jet/flush stack. 11/26/2016 11/26/2016 0.20 PROM WHPST PULD P Pop off, inspect / replace stripper 0.0 0.0 21:18 21:30 elements. Normal wear near the top. 11/26/2016 11/26/2016 1.30 PROM DRILL PULD P PJSM, PU BHA#2, Build BHA. Stab 0.0 72.0 21:30 22:48 on. Open deployment valve. 11/26/2016 11/27/2016 1.20 PROM DRILL TRIP P RIH 72.0 6,236.0 22:48 00:00 11/27/2016 11/27/2016 0.50 PROM DRILL TRIP P RIH 6,236.0 7,880.0 00:00 00:30 11/27/2016 11/27/2016 0.40 PROD1 DRILL DLOG P Tie into K1 for +4' correction, log rat 7,880.0 8,183.0 00:30 00:54 hole. 34.5k lbs PU Wt, 11/27/2016 11/27/2016 1.70 PROM DRILL DRLG P Bring pump to 1.80 bpm, CT 12k lbs, 8,183.0 8,310.0 00:54 02:36 CT 4250 psi, Off bottom diff 600 psi. Drilling ahead at 80-110 f/hr. WOB .8 -1.5k lbs. Some initial losses, minimal now, -2 bbls since starting build section. 11/27/2016 11/27/2016 1.00 PROD1 DRILL DLOG P PU to Log K1, PU wt 33.5k lbs, PUH, 8,310.0 8,310.0 02:36 03:36 min rate through window, Tie into K1 for +1 correction, log RA tag in whipstock, corrected TOW 8159', BOW 8167'. RBIH 11/27/2016 11/27/2016 1.00 PROM DRILL DRLG P BOBD 1.8 bpm RIH wt 12k lbs, CT 8,310.0 8,387.0 03:36 04:36 14400 psi, WOB 1 k lbs, ROP 115 ft/hr 11/27/2016 11/27/2016 0.30 PROM DRILL WPRT P Geo wiper trip, evaluating 8,387.0 8,387.0 04:36 04:54 11/27/2016 11/27/2016 1.25 PROM DRILL DRLG P BOBD 1.8 bpm, CT 4400 psi, Ct Wt 8,387.0 8,490.0 04:54 06:09 11.3, WOB 1.4k lbs, ROP 75 ft/hr. Losses of 5 bbls since midnight. 11/27/2016 11/27/2016 2.00 PROM DRILL TRIP P POOH, PUW=33k, following MP 8,490.0 75.0 06:09 08:09 schedule. Open EDC, chase 5x5 sweeps POOH. Jog back in @ 300'. POOH, Tag -up. Space -out. 11/27/2016 11/27/2016 1.15 PROM DRILL PULD P PJSM, PUD BHA#2. 75.0 0.0 08:09 09:18 11/27/2016 11/27/2016 0.60 PROM DRILL PULD P LD BHA #2. 0.0 0.0 09:18 09:54 11/27/2016 11/27/2016 0.35 PROM DRILL PULD P PU BHA#3 (Weatherford 0.76° bend 0.0 0.0 09:54 10:15 motor + rebuild HCC bi-center bit) 11/27/2016 11/27/2016 1.15 PROM DRILL PULD P PJSM, PD BHA #3. Test MWD. Strip 0.0 78.0 10:15 11:24 on WH, equalize, open BOP, tag stripper, set depth. 11/27/2016 11/27/2016 1.50 PROM DRILL TRIP P RIH BHA #3. Tag on X -nipple. Try 78.0 7,832.0 11:24 12:54 different tool faces, close EDC, RIH, tag, roll pump rate on. Temporarily detained. Pulled free. 11/27/2016 11/27/2016 2.30 PROM DRILL TRIP T Open EDC, continue swapping to 7,832.0 78.0 12:54 15:12 fresh drilling mud system (only 5 bbls volume below current depth). POOH BHA #3. 11/27/2016 11/27/2016 2.40 PROM DRILL PULD T PJSM, PUD BHA#3, PD BHA #4, 78.0 78.0 15:12 17:36 baker motor. 11/27/2016 11/27/2016 1.60 PROM DRILL TRIP T RIH, wt chk 7890, 32.5k lbs, 78.0 7,890.0 17:36 19:12 I Page 3124 Report Printed: 12/3012016 Operations Summary (with Timelog Depths) r r" 2X-13 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time our (hr) Phase Op Code Activity Code Time P -T -X Operation (ftKB) End Depth (ftK8) 11/27/2016 11/27/2016 0.60 PROM DRILL DLOG P Close EDC, Log to 8480' Tie into K1 7,890.0 8,493.0 19:12 19:48 for a +4 foot correction. Close EDC, RIH. 11/27/2016 11/27/2016 1.00 PROM DRILL DRLG P 1.77 bpm, off bottom, CT 3500 psi, 8,480.0 8,668.0 19:48 20:48 diff, 480 psi. OBD CT 3800 psi, WOB 1.7 k lbs, ROP 150 ft/hr. Not making turn dog legs, PU, wt 34k lbs RBIH. Zero Pit G/L once on bottom drilling, quite a few fish eyes in the new flow pro, spilling a decent amount of mud off the shaker, start gun lines to help shear down polymer clumps. 11/27/2016 11/27/2016 2.30 PROM DRILL DRLG P Concerned about not making sufficient 8,668.0 8,990.0 20:48 23:06 dog legs to complete turn on plan, reduce rate and increase WOB. 1.6 bpm, off bottom, CT 3500 psi, diff, 386 psi. OBD CT 4000 psi, Ct Wt 6.9k lbs, WOB 2.3 k lbs, ROP 180-240fUhr. 11/27/2016 11/27/2016 0.20 PROM DRILL WPRT P Wiper trip #1, PU Wt 33.4 k lbs, 8,990.0 8,500.0 23:06 23:18 11/27/2016 11/27/2016 0.20 PROM DRILL WPRT P RBIH, RIH Wt 10.2k lbs 8,950.0 8,990.0 23:18 23:30 11/27/2016 11/27/2016 0.30 PROM DRILL DRLG P BOBD, Still concerned about not 8,990.0 9,042.0 23:30 23:48 making high enough dog legs to complete the turn on plan. Reduce rate 1.5 bpm, off bottom, CT 3450 psi, diff, 367 psi. OBD CT 3984 psi, Ct Wt 6.3k lbs, WOB 3.13 k lbs, ROP 190 ft/hr. 11/27/2016 11/28/2016 0.20 PROM DRILL WPRT T Geo wiper to consult W town re. 8,925.0 8,970.0 23:48 00:00 adherence to plan. 11/28/2016 11/28/2016 0.60 PROM DRILL WPRT T Geo wiper to consult W town re 8,925.0 8,635.0 00:00 00:36 adherence to plan. 11/28/2016 11/28/2016 0.20 PROM DRILL WPRT T RBIH 8,635.0 9,042.0 00:36 00:48 11/28/2016 11/28/2016 0.30 PROM DRILL DRLG T Off bottom, 1.4 bpm, 10.76k lbs RIH 9,042.0 9,092.0 00:48 01:06 Wt, CT 3154 psi, Diff 325 psi. OBD, CT Wt 4.8 k lbs, CT 3814 psi, WOB 3.0 k lbs, ROP 139 ft/hr. 11/28/2016 11/28/2016 1.00 PROD1 DRILL TRIP T Town Geo's requesting a trip for a 9,092.0 9,092.0 01:06 02:06 higher bend motor. Belay that decision, going to drill min 4 surveys and reevaluate. RBIH. 11/28/2016 11/28/2016 1.00 PROM DRILL DRLG P Off bottom, 1.4 bpm, 9.2k lbs RIH Wt, 9,042.0 9,220.0 02:06 03:06 CT 3142 psi, Diff 317 psi. OBD, CT Wt 6.4 k lbs, CT 3708 psi, WOB 3.24 k lbs, ROP 150 ft/hr. 12, 10, 11/28/2016 11/28/2016 0.40 PROD1 DRILL TRIP P Averaged 11.2 DL in last 4 surveys, 9,220.0 9,220.0 03:06 03:30 9.75, 10,10.5, 14.5. Consulting geo's. OK to drill ahead, RBIH from 9080. 11/28/2016 11/28/2016 2.00 PROD1 DRILL DRLG P BOBD, CT Wt 4.6 k lbs, CT 3809 psi, 9,220.0 9,388.0 03:30 05:30 WOB 3.6 k lbs, ROP 240 - 60 ft/hr. 11/28/2016 11/28/2016 0.10 PROM DRILL WPRT P BHA wiper, PUW=38k. 9,388.0 9,388.0 05:30 05:36 11/28/2016 11/28/2016 0.70 PROM DRILL DRLG P BOBD, 1.38 BPM @ 3300 psi FS, 9,388.0 9,441.0 05:36 06:18 WOB 3.5k, CTSW -1.5k, ROP 100 - 60 FPH. Page 4/24 Report Printed: 1 213 0/2 01 6 Operations Summary (with Timelog Depths) 2X-13 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time our (hr) Phase Op Code Activity Code Time P -T -X Operation (ftKB) End Depth (ftKB) 11/28/2016 11/28/2016 0.70 PROD1 DRILL WPRT P Wiper trip #2, to 8,522', PUW=35k. 9,441.0 9,441.0 06:18 07:00 11/28/2016 11/28/2016 1.00 PROD1 DRILL DRLG P BOBD, 1.38 BPM @ 3212 psi FS, 9,441.0 9,483.0 07:00 08:00 WOB 3.5k - 3.2k, CTSW -0.8k to - 3.5k, ROP 50 FPH. 11/28/2016 11/28/2016 0.10 PROD1 DRILL WPRT P BHA wiper, PUW=36k. 9,483.0 9,483.0 08:00 08:06 11/28/2016 11/28/2016 2.50 PROD1 DRILL DRLG P BOBD, 1.38 BPM @ 3212 psi FS, 9,483.0 9,690.0 08:06 10:36 WOB 1.7k - 2k, CTSW -3.2k to -0.5k, ROP 75 - 110 11/28/2016 11/28/2016 0.60 PROD1 DRILL WPRT P Window wiper trip, PUW=34k. 9,690.0 8,185.0 10:36 11:12 11/28/2016 11/28/2016 0.10 PROD1 DRILL DLOG P Tie-in to RA marker for+3' correction. 8,185.0 8,203.0 11:12 11:18 11/28/2016 11/28/2016 0.60 PROD1 DRILL WPRT P Wiper back in hole. 8,203.0 9,690.0 11:18 11:54 11/28/2016 11/28/2016 2.00 PROD1 DRILL DRLG P BOBD, 1.34 BPM @ 3242 psi FS, 9,690.0 9,888.0 11:54 13:54 WOB 2.9k - 1.2k, CTSW 0.8k to -5.7k, ROP 85 - 115 FPH. 11/28/2016 11/28/2016 0.20 PROD1 DRILL WPRT P BHA wiper, PUW=37k. 9,888.0 9,888.0 13:54 14:06 11/28/2016 11/28/2016 1.60 PROD1 DRILL DRLG P BOBD, bump rate from 1.33 to 1.5 9,888.0 10,090.0 14:06 15:42 BPM, helped weight transfer. 1.5 BPM @ 36029 psi FS. 11/28/2016 11/28/2016 0.80 PROD1 DRILL WPRT P 1 000'wiper trip (#1 since window 10,090.0 10,090.0 15:42 16:30 wiper), PUW=34k. 11/28/2016 11/28/2016 2.10 PROD1 DRILL DRLG P BOBD, 1.53 BPM @ 3620 psi FS, 10,090.0 10,376.0 16:30 18:36 WOB 1.1 k - 2k, CTSW 4k to -6k, ROP 160 - 240 FPH. 11/28/2016 11/28/2016 0.60 PROD1 DRILL WPRT T Pull short BHA wiper. Temporarily 10,376.0 10,370.0 18:36 19:12 detained above DPS (WOB sensor), work pipe in tension and compression. Varied pumping rates. Tried pipe relaxation, bled off pump at surface. No luck. No indicators of differential sticking prior to being stuck. Could "move" pipe -15 ft while working pipe (pipe stretch). 11/28/2016 11/28/2016 2.40 PROD1 DRILL WPRT T Pumped to -vis pill, worked pipe. No 10,370.0 10,370.0 19:12 21:36 luck. Pumped 22 bbls LVT mineral oil. Circulated 11 bbls out of the bit with CTSW=40k. Pumps off, 4 minutes into soak, pipe came free. 11/28/2016 11/28/2016 1.70 PROD1 DRILL WPRT P Wiper to 8,100'. Motor work seen in 10,370.0 8,175.0 21:36 23:18 build section, come up above WS, jet bottoms up w EDC open. Metal shavings across shaker. Close EDC. RIH. 11/28/2016 11/28/2016 0.10 PROD1 DRILL DLOG P RA tie-in for+8' correction. 8,175.0 8,205.0 23:18 23:24 11/28/2016 11/29/2016 0.60 PROD1 DRILL WPRT P Wiper in hole. Slow to 5 FPM for mad 8,205.0 9,074.0 23:24 00:00 pass from 9,000'- 9,100'. Cont RIH. 11/29/2016 11/29/2016 0.20 PROD1 DRILL WPRT P Cont. MAD pass. 9,074.0 9,135.0 00:00 00:12 11/29/2016 11/29/2016 0.50 PROD1 DRILL TRIP P RIH 9,135.0 10,377.0 00:12 00:42 I Page 5124 Report Printed: 12130/2016 Operations Summary (with Timelog Depths) �a 2X-13 MW Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time our (hr) Phase Op Code Activity Code Time P -T -X Operation (ftKB) End Depth (ftKB) 11/29/2016 11/29/2016 0.20 PROD1 DRILL DRLG P BOBD, WOB 1.85k lbs, CT Wt 4.5k 10,377.0 10,402.0 00:42 00:54 lbs, CT 4162 psi, WH 170 psi. ROP 170 Ft/hr. 11/29/2016 11/29/2016 0.50 PROM DRILL TRIP T PUH to troubleshoot. Packing off at 10,402.0 10,402.0 00:54 01:24 surface, swap chokes, issue in the micromotion. bypass micromotion. 11/29/2016 11/29/2016 0.40 PROM DRILL DRLG P BOBD, WOB 1.85k lbs, CT Wt 4.5k 10,402.0 10,457.0 01:24 01:48 lbs, CT 4162 psi, WH 170 psi. ROP 170 Ft/hr. 11/29/2016 11/29/2016 0.20 PROM DRILL TRIP T PUH to troubleshoot surface issues 10,457.0 10,457.0 01:48 02:00 again. Zero pit G/L. RBIH 11/29/2016 11/29/2016 0.40 PROM DRILL DRLG P BOBD, 1.5 bpm, WOB 1.8k lbs, CT Wt 10,457.0 10,526.0 02:00 02:24 5.8 k lbs, CT 4270 psi, ROP 170 Ft/hr. 11/29/2016 11/29/2016 0.20 PROM DRILL WPRT P BHA wiper. 10,526.0 10,526.0 02:24 02:36 11/29/2016 11/29/2016 1.50 PROM DRILL DRLG P BOBD, 1.5 bpm, WOB 1.58k lbs, CT 10,526.0 10,724.0 02:36 04:06 Wt -1.0k lbs, CT 3979 psi, ROP 143 Ft/hr. 11/29/2016 11/29/2016 0.20 PROM DRILL WPRT P BHA wiper.100'RBIH. 10,724.0 10,724.0 04:06 04:18 11/29/2016 11/29/2016 0.20 PROD1 DRILL DRLG P BOBD, 1.54 bpm, WOB 1.49k lbs, CT 10,724.0 10,741.0 04:18 04:30 Wt 0.5k lbs, CT 4107 psi, ROP 140 Ft/hr. Diff 434 psi. 11/29/2016 11/29/2016 0.30 PROD1 DRILL WPRT P Poor weight transfer, Call for a returns 10,741.0 9,741.0 04:30 04:48 truck to swap out mud, pull wiper trip 29 feet short of planned 400'. PU wt, 39 k lbs. 11/29/2016 11/29/2016 0.20 PROD1 DRILL WPRT P RBIH 9,741.0 10,741.0 04:48 05:00 11/29/2016 11/29/2016 2.20 PROM DRILL DRLG P Took a couple pickups to get drilling, 10,741.0 10,833.0 05:00 07:12 1.54 bpm CT 3697 psi, CT Wt -4k lbs, WOB 2.3k lbs, ROP 75 Ft/hr. New mud at bit @ 0700. 11/29/2016 11/29/2016 0.90 PROM DRILL WPRT P PUH for a wiper trip PU Wt 37 k lbs. 10,833.0 8,500.0 07:12 08:06 11/29/2016 11/29/2016 0.30 PROD1 DRILL WPRT P PUH for a wiper trip PU Wt 37 k lbs. 8,500.0 10,833.0 08:06 08:24 11/29/2016 11/29/2016 2.60 PROM DRILL DRLG P Took a couple pickups to get drilling, 10,833.0 10,949.0 08:24 11:00 1.54 bpm CT 4132 psi, CT Wt -1 k lbs, WOB 1.8 k lbs, ROP 185 Ft/hr. Lost weight transfer. Unable to regain WOB. 11/29/2016 11/29/2016 0.50 PROM DRILL WPRT P PUH for a wiper trip PU Wt 38 k lbs. 10,949.0 10,420.0 11:00 11:30 Build lube pill 2.5/ 2.5% PUH on short wiper 11/29/2016 11/29/2016 0.50 PROD1 DRILL WPRT P RBIH, pump 15 bbls lube pill. 10,420.0 10,949.0 11:30 12:00 11/29/2016 11/29/2016 0.70 PROM DRILL DRLG P Let 5 bbls around the nozzle. Off 10,949.0 11,018.0 12:00 12:42 bottom 1.53 bpm, CT 3817 psi, 440 diff, Struggled to get moving, BOBD at reduced rate, 1.46 bpm, CT 3917 psi, Ct Wt -1.16 k lbs, WOB 1.76 k lbs, ROP 150 fph. 11/29/2016 11/29/2016 0.90 PROM DRILL DRLG P Pumped 16.5 bbls 2.5/2.5 % 11,018.0 11,019.0 12:42 13:36 remaining lube pill, Struggled again to get moving. 11/29/2016 11/29/2016 1.00 PROD1 DRILL WPRT P PUH while building and pumping 24 11,019.0 11,019.0 13:36 14:36 bbl beaded pill. Page 6/24 Report Printed: 12/30/2016 ' Operations Summary (with Timelog Depths) 2X-13 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time Dur (hr) Phase Op Code Activity Code Time P -T -X Operation (ftK8) End Depth (ftKB) 11/29/2016 11/29/2016 1.00 PROM DRILL DRLG P BOBD, 12 bbls out, BOBD, CT wt -1.3 11,019.0 11,074.0 14:36 15:36 k lbs, WOB 2.3 k Lbs, ROP 161 ft/hr, Weight transfer declined as pill circulated up hole. Started second 20 bbl beaded pill down hole. 11/29/2016 11/29/2016 0.50 PROM DRILL DRLG P 2nd bead pill exiting the nozzle. Geo's 11,074.0 11,084.0 15:36 16:06 called TD @ 11084. 11/29/2016 11/29/2016 1.00 PROD1 DRILL WPRT P PUH while building Hi -vis pill. RBIH, 11,084.0 11,084.0 16:06 17:06 Pump 1 0x1 0 to hi sweep 11/29/2016 11/29/2016 1.00 PROD1 DRILL WPRT P Sweeps out the nozzle, POOH, 11,084.0 8,134.0 17:06 18:06 11/29/2016 11/29/2016 0.20 FROM DRILL DLOG P Perform pressure check at window, 8,134.0 8,134.0 18:06 18:18 down on pumps, closed choke with 700 WHP, 3468 psi BHP, after 10 min, 3228 psi BHP and falling, calculated 10.7 ppg based on annular pressure. 11/29/2016 11/29/2016 2.10 FROM DRILL TRIP P Open EDC, POOH follow trip schedule 8,134.0 72.0 18:18 20:24 for 8.6 ppg MW, pumpingl.9 bpm, jog near surface. "' start seeing minor scratches on coil at 2800 ft from surface, long continuous linear scratches from 6 to 8 O'clock looking downhole "' 11/29/2016 11/29/2016 1.60 PROM DRILL TRIP P RBIH, follow trip schedule for 8.6 ppg 72.0 7,880.0 20:24 22:00 MW 11/29/2016 11/29/2016 0.20 PROM DRILL DLOG P Log K1,+ 2 ft correction, close EDC 7,880.0 8,135.0 22:00 22:12 11/29/2016 11/29/2016 1.20 PROM DRILL TRIP P Trip thru build at min pump rate .24 8,135.0 11,100.0 22:12 23:24 bpm, 50 FPM, RI, tag TD at 11100' 11/29/2016 11/29/2016 0.50 FROM DRILL CIRC P Pump 50 bbl liner running pill with 11,100.0 11,090.0 23:24 23:54 alpine beads followed by 11.5 ppg K - Formate, pick up 10' while circulating pill 11/29/2016 11/30/2016 0.10 PROM DRILL DISP P POOH with 5 MIS out, lay in liner 11,090.0 11,090.0 23:54 00:00 running pill. 11/30/2016 11/30/2016 3.50 FROM DRILL DISP P POOH while displacing hole over to 11,084.0 72.0 00:00 03:30 11.5 ppg K -Formate, follow tripping schedule for 11.5 ppg KWF, Stop at 9122' to paint yellow TD flag, Stop at 6072', paint white window flag, continue POOH, tag up, estimated 8 bbl loss. 11/30/2016 11/30/2016 0.50 PROM DRILL OWFF P Flow check for 30 min. No flow 72.0 72.0 03:30 04:00 observed, Hold PJSM for next operation 11/30/2016 11/30/2016 1.00 PROM DRILL PULD P UT inspect on coil, approx 3 ft above 72.0 0.0 04:00 05:00 CTC, minimum wall thickness reading was 0.129". LD BHA #4 over dead well. 11/30/2016 11/30/2016 4.10 COMPZ1 CASING PUTB P PJSM, pick up BHA # 5, L1 Latteral 0.0 1,980.0 05:00 09:06 slotted line, (65 joints plus 10' pup&BHA). 11/30/2016 11/30/2016 0.30 COMPZ1 CASING PUTB P Safety joint drill, 4 min, AAR in dog 1,980.0 1,980.0 09:06 09:24 house, discuss safety joint hanger, pros cons. 11/30/2016 11/30/2016 1.20 COMPZ1 CASING PULD P LD safety joint and MU BHA # 5, 1,980.0 2,043.0 09:24 10:36 deploy same 11/30/2016 11/30/2016 1.60 COMPZ1 CASING RUNL P RIH w/ BHA #5, Pits ,G/L 0,0, 47.5 2,043.0 8,043.0 10:36 12:12 bbls, rolling min rate, CT Wt 6.55 k lbs, CT 473 psi. Page 7124 Report Printed: 1 213 0/201 6 Operations Summary (with Timelog Depths) 2X-13 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time Dur (hr) Phase Op Code Activity Code Time P -T -X Operation (ftKB) End Depth (ftKB) 11/30/2016 11/30/2016 3.30 COMPZI CASING RUNL P Tie into pipe flag @ 8043' for -1.5' 8,043.0 10,158.0 12:12 15:30 correction. PU Wt 36 k LBS, WOB - 3.45k lbs. Nothing notable while running through window. SD @ 9358' @ 12:40 PU 44 k lbs RBIH, work liner slowly to 10158' over next 2.8 hrs, lost ground to 10020'. 11/30/2016 11/30/2016 2.30 COMPZ1 CASING PULL T POOH 43k lbs, WOB -7.5k lbs in open 10,158.0 2,043.0 15:30 17:48 hole, 11/30/2016 11/30/2016 0.50 COMPZ1 CASING OWFF T Perform 30 min no flow check 2,043.0 72.0 17:48 18:18 11/30/2016 11/30/2016 1.00 COMPZ1 CASING PULD T LD BHA#5, CoilTrak and BOT liner 72.0 0.0 18:18 19:18 running tools, inspect Baker G -spear, no issues, inspect FN on aluminum billet, FN slightly rolled, not bad. 11/30/2016 11/30/2016 0.50 COMPZ1 CASING PUTB T Clean rig floor prep to LD liner, PJSM 0.0 0.0 19:18 19:48 11/30/2016 11/30/2016 3.90 COMPZ1 CASING PUTB T LD 2-3/8" liner; 10 ft pup, 65 ints, non 0.0 0.0 19:48 23:42 ported BN. 11/30/2016 12/1/2016 0.30 COMPZ1 CASING PUTB T Clean and clear floors, monitor hole, 0.0 0.0 23:42 00:00 PJSM for picking up cleanout BHA 12/1/2016 12/1/2016 1.00 COMPZ1 CASING PULD T MU BHA #6 with BHI motor, 0.7° AKO, 0.0 62.4 00:00 01:00 D-331 mill w/ ridge set, 12/1/2016 12/1/2016 1.60 COMPZ1 CASING TRIP T Trip in with cleanout BHA, pump 13 62.4 7,850.0 01:00 02:36 bbl spacer (interface) followed by 11.5 ppg K -Formate at min rate, 12/1/2016 12/1/2016 0.30 COMPZ1 CASING DLOG T Log K1 marker, +4' correction 7,850.0 7,908.0 02:36 02:54 12/1/2016 12/1/2016 1.10 COMPZ1 CASING DISP T Displace hole over to 8.6 ppg FloPro 7,908.0 8,145.0 02:54 04:00 at window, FloPro at bit at 03:15, close EDC 12/1/2016 12/1/2016 0.30 COMPZ1 CASING REAM T RIH to EOB at 40 FPM, 0.31 bpm, 8,145.0 8,500.0 04:00 04:18 2350 psi CP, 383 psi WHP 12/1/2016 12/1/2016 0.80 COMPZ1 CASING REAM T Attempt to make backream pass at 1.6 8,500.0 8,130.0 04:18 05:06 bpm, 4576 psi CP, 70 psi WH P, 31K up wt, had to bring pump rate down due to high dP, pull into window to troubleshoot high dP, (1133 psi at 1.3 bpm). Open EDC and circulate at 1.4 bpm, dp at 35 psi. Close EDC and attempt to clear obstruction, no success, open EDC 12/1/2016 12/1/2016 1.70 COMPZ1 CASING TRIP T Trip out to troubleshoot for plugged 8,130.0 62.0 05:06 06:48 nozzle/plugged motor. 12/1/2016 12/1/2016 2.00 COMPZ1 CASING PULD T Bump up, PJSM, PUD BHA #6. 62.0 0.0 06:48 08:48 Inspect bit, clean, blow air and water through motor, no obvious issues. 12/1/2016 12/1/2016 1.00 COMPZ1 CASING PULD T Lay down old motor and tools. Pick 62.0 0.0 08:48 09:48 up BHA#7, replace, DPS, DGS,HOT, FVS, & Motor, ( all below EDC ), PD BHA #7 12/1/2016 12/1/2016 1.30 COMPZ1 CASING PULD T PD BHA#7 0.0 62.0 09:48 11:06 12/1/2016 12/1/2016 1.80 COMPZ1 CASING TRIP T RIH, @ 210', down on the pumps, 62.0 7,909.0 11:06 12:54 close EDC, RIH 57 min, pump 1.5 bpm, diff 350 psi, Down on the pumps, Open EDC, continue RIH. Page 8/24 Report Printed: 12/30/2016 Operations Summary (with Timelog Depths) 2X-13 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time Dur (hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth (ftKB) 12/1/2016 12/1/2016 1.20 COMPZ1 CASING TRIP T Tie into the K1 for+4' correction, Wt 7,909.0 11,094.0 12:54 14:06 Ck, 30k lbs, close EDC, zero WOB. min rate, I bpm after build, RIH to bottom, slight CT weight bobble @ 10930 & 10943'. No WOB bobbles until TD @ 11,094'. Ct Wt fell offfrom 11 k lbs to 8 k lbs from window to TD. PU Wt 31 k lbs. Consult w town engineering. 12/1/2016 12/1/2016 0.20 COMPZI CASING TRIP T PUH while wait on plan forward. 11,094.0 10,947.0 14:06 14:18 Cleared to add 2% Low Torque and 1 % 776 in the liner running pill and 1 % 776 in the kill weight fluid. 12/1/2016 12/1/2016 2.50 COMPZ1 CASING CIRC T Build add lubes to liner running pill 10,947.0 10,288.0 14:18 16:48 and kill weight fluid. 12/1/2016 12/1/2016 0.50 COMPZ1 CASING DISP T Lay in liner running pill, 48 bbls, 0.65 10,288.0 7,650.0 16:48 17:18 bpm, stop at 9112', paint yellow TD flag, liner pill all out of coil at 7650'. 12/1/2016 12/1/2016 2.80 COMPZ1 CASING TRIP T Trip out at 100 FPM, 1 bpm, 1975 psi 7,650.0 62.0 17:18 20:06 CP, 201 psi WHIP, follow 11.5 ppg trip schedule. 12/1/2016 12/1/2016 0.50 COMPZ1 CASING OWFF T Perform 30 min no-flow check, well on 62.0 0.0 20:06 20:36 vac, hold PJSM for LD BHA over dead well 12/1/2016 12/1/2016 0.70 COMPZI CASING PULD T LD BHA #7 over dead well. 0.0 0.0 20:36 21:18 12/1/2016 12/1/2016 0.20 COMPZ1 CASING PUTB T Prep rig floor for running liner, PJSM 0.0 0.0 21:18 21:30 12/1/2016 12/2/2016 2.50 COMPZI CASING PUTB T MU slotted liner, as of midnight, 59 0.0 1,827.0 21:30 00:00 jnts run as of midnight 12/2/2016 12/2/2016 0.60 C0MPZ1 CASING PUTB T Midnight Crew change, PJSM, 1,827.0 1,989.6 00:00 00:36 continue to MU last 6 jnts of slotted and a 10' PUP. 12/2/2016 12/2/2016 0.30 COMPZ1 CASING PUTB T Clear rig floor, hold PJSM 1,989.6 1,989.6 00:36 00:54 12/2/2016 12/2/2016 1.10 COMPZI CASING PULD T MU BHA #8, liner running tool and 1,989.6 2,043.3 00:54 02:00 aluminum billet to slotted liner, surface check tools, bump up and set depth 12/2/2016 12/2/2016 2.00 COMPZI CASING RUNL T RIH w/ liner, -5' correction at Window 2,043.3 8,159.0 02:00 04:00 flag, set WOB to -8K, 12/2/2016 12/2/2016 1.50 COMPZ1 CASING RUNL T RIH through window, sat down at 8,159.0 11,090.0 04:00 05:30 10110', PU and worked past, continue RIH, SD at 11090', 41 K PUW, pick-up 3X and tag up at 11090',pull up to neutral, online at 1.1 bpm, free from liner, 28K CW 12/2/2016 12/2/2016 2.20 COMPZI CASING TRIP P POOH 11,090.0 48.0 05:30 07:42 12/2/2016 12/2/2016 1.00 COMPZI CASING PULD P Bump up, flow check, PJSM, Lay 48.0 0.0 07:42 08:42 down BHA #8 liner running BHA, measured flat spot - 5' up from the coil connector, 0.145". Verify hole full, fluid at the rams, shut in swabs 1 & 2. 12/2/2016 12/2/2016 0.20 PROD2 WHDBOP PULD P Clean rig floor, pick up test joint, 0.0 0.0 08:42 08:54 space out. 12/2/2016 12/2/2016 0.20 PROD2 WHDBOP BOPE P BOP function test - good 0.0 0.0 08:54 09:06 12/2/2016 12/2/2016 0.30 PROD2 WHDBOP PULD P Lay down test joint, inspect reel, 0.0 0.0 09:06 09:24 Page 9/24 Report Printed: 12/30/2016 Uperations Summary (with Timelog Depths) 2X-13 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time Dur (hr) Phase Op Code Activity Code Time P -T -X Operation (WB) End Depth (ftKB) 12/2/2016 12/2/2016 1.40 PROD2 STK PULD P PJSM, PU BHA#9, L1-01, check 0.0 78.0 09:24 10:48 pressure via tango valves, open swab 1 and 2. Replace checks, inspect/replace stripper, old set new 11/26. Stab on, PT, Tag up. set depth. 12/2/2016 12/2/2016 1.90 PROD2 STK TRIP P RIH, perform shallow hole test, 891 78.0 7,895.0 10:48 12:42 psi diff @ 1.5 bpm, comparable to past WTF motors - 1.7 bpm and 934 psi on 1H-07. open EDC, RIH. displacing coil w/ system #2, flow pro. 12/2/2016 12/2/2016 0.20 PROD2 STK DLOG P Tie into the K1 for + 13.5' 7,895.0 7,925.0 12:42 12:54 12/2/2016 12/2/2016 1.30 PROD2 STK TRIP P RIH, park above window, bring rate up 7,924.0 8,124.0 12:54 14:12 to 1.53 bpm, swap out coil depth counter, new mud at the bit, 13:00, roll hole to flow pro. 12/2/2016 12/2/2016 0.20 PROD2 STK DLOG P Close EDC, RIH, log whipstock RA 7,924.0 8,124.0 14:12 14:24 tag, for no correction. 12/2/2016 12/2/2016 2.60 PROD2 STK DLOG P RIH, min rate, down on the pumps, 7,924.0 9,097.0 14:24 17:00 zero WOB, dry tag top of billet @ 9097, PU Wt 33 k lbs, RBIH, CT Wt, 10.37k lbs, 1.5 bpm, diff off bottom, 614 psi, CT 3910 psi, Multiple stalls - 10, PU weights 34 -36k lbs 12/2/2016 12/2/2016 4.50 PROD2 STK KOST P Time mill on billet, difficulty getting 9,097.0 9,103.0 17:00 21:30 kicked off, 13 stalls, varied pump rates, pumped 5 bbl lube pill 12/2/2016 12/2/2016 0.30 PROD2 DRILL DRLG P Kicked off billet at 9103', drilling per 9,103.0 9,134.0 21:30 21:48 DD; 9K CW, 1.62 bpm, 4343 psi CP, 950 psi OB diff pressure, 1 K WOB, 90 ft/hr ROP 12/2/2016 12/2/2016 0.20 PROD2 DRILL WPRT P 34K PUW, dry drift billet, saw 2K 9,134.0 9,134.0 21:48 22:00 bobble whille pulling up, billet drifted clean while RIH. Repeat drift with same result, RIH to drill 12/2/2016 12/2/2016 0.90 PROD2 DRILL DRLG P OBD, 1.74 bpm, 4522 psi CP, 830 psi 9,134.0 9,269.0 22:00 22:54 dif OB. Drill ahead with ROP's 150 to 250 ft/hr, getting 8°/100' DLS, less than desired. PU, lower pump rate to 1.4 bpm, 3730 psi CP, 668 psi diff OB, try increasing WOB to 2.3 to 3K, lowered pump rate to 1.3 bpm, turned tool face to 90 ROHS, getting less than 8° DL. 12/2/2016 12/3/2016 1.10 PROD2 DRILL WPRT P Wiper up slowly while consulting town 9,269.0 9,269.0 22:54 00:00 Geo and Engineer, at 9120' as of midnight 12/3/2016 12/3/2016 0.30 PROD2 DRILL WPRT P Continue wiper, consult town, decision 9,269.0 9,043.0 00:00 00:18 to POOH 12/3/2016 12/3/2016 2.00 PROD2 DRILL TRIP T Trip out for higher bend motor, follow 9,043.0 78.0 00:18 02:18 8.6 ppg trip schedule, MP choke B packed off, switched chokes 12/3/2016 12/3/2016 2.70 PROD2 DRILL PULD T Bumped up, space out, hold PJSM, 78.0 0.0 02:18 05:00 flush choke B, PUD, dual checks not holding, PUD w/ EDC closed. LD BHA #9 12/3/2016 12/3/2016 1.00 PROD2 DRILL PULD T PU BHA# 10 0.0 0.0 05:00 06:00 Page 10124 Report Printed: 12/3012016, -� Uperations Summary (with Timelog Depths) t' 2X-13 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time Dur (hr) Phase Op Code Activity Code Time P -T -X Operation (ftKB) End Depth (MB) 12/3/2016 12/3/2016 1.50 PROD2 DRILL PULD T Change out, PD BHA # 10, valve 0.0 72.5- 06:00 07:30 check, PJSM, C/O upper quick floats, test MWD, inspect stripper, ok, stab on.equilize, tag up, 12/3/2016 12/3/2016 1.00 PROD2 DRILL TRIP T RIH, tie into the K1 for a +9', Slight 72.0 9,288.0 07:30 08:30 WOB, bobble @ 8200' no motor work. 12/3/2016 12/3/2016 4.80 PROD2 DRILL DRLG P 1.39 bpm, 350 psi diff, Off bottom Ct 9,288.0 9,439.0 08:30 13:18 3156 psi, RIH Wt 9.5k lbs, BOBD, CT Wt 7.46k lbs, CT 3551 psi, Wh 84 psi, WOB 2.6 k lbs, ROP 80 Ft/hr Zero pit G/L, 292, bbls 12/3/2016 12/3/2016 0.20 PROD2 DRILL WPRT P Short wiper over drilled interval to 9,439.0 9,439.0 13:18 13:30 9284' to regain WOB. 12/3/2016 12/3/2016 0.20 PROD2 DRILL DRLG P BOBO, CT Wt 5.5 k lbs, CT 3994 psi, 9,439.0 9,561.0 13:30 13:42 Wh 166 psi, WOB 2.54 k lbs, ROP 114 Ft/hr. Pit G/L, 284, bbls - 7.2 bbls. Spill drill, 3 minute response time, A few non essentials did not call in to report to the muster area. 12/3/2016 12/3/2016 1.00 PROD2 DRILL DRLG P Pick up drilling rate from 1.4 to 1.5 9,561.0 9,690.0 13:42 14:42 bpm PU Wt 33.8 k lbs, RIH Wt 8.7k lbs. CT 3660 psi, off bottom diff 430 psi, BOBD, CT Wt 6.3 k lbs, WOB 2.0 k lbs, ROP 160 FPH. 12/3/2016 12/3/2016 2.80 PROD2 DRILL TRIP T Reach end of turn, POOH to swap to 9,690.0 72.0 14:42 17:30 lower bend motor. PU Wt, 36k lbs, Increase rate to 1.8 bpm, pull through window, open EDC, POOH. Multiple choke pack offs, jog near surface. 12/3/2016 12/3/2016 2.00 PROD2 DRILL PULD T Bump up, PJSM, PUD BHA#10, Crew 72.0 0.0 17:30 19:30 change, continue PUD, w/ EDC closed, checks not holding. LD BHA #10 12/3/2016 12/3/2016 0.50 PROD2 DRILL PULD T Set-up new AKO on BHI motor, one 0.0 0.0 19:30 20:00 back-up is houred out and the other is suspect from high diff pressure from the other day. Inspect suction strainer upstream of Out Micromotion, strainer was clean. 12/3/2016 12/3/2016 1.00 PROD2 DRILL RGRP T Break off and inspect MP return hose 0.0 0.0 20:00 21:00 in cellar for solids or blockage, hose is clear, attempt to install whipsocks on both ends of MP return line, wouldn't fit over hammer unions, hammer up line. install night cap on QT sub, PT to 2500 psi 12/3/2016 12/3/2016 1.30 PROD2 DRILL PULD T PJSM, PU BHA #11 w/ Baker 0.7° 0.0 72.0 21:00 22:18 AKO motor, RR HCC 3.0 bi-center bit, PD 12/3/2016 12/4/2016 1.70 PROD2 DRILL TRIP T Trip in w/ EDC open, pump min rate, 72.0 7,880.0 22:18 00:00 8.8 ppg FloPro. 12/4/2016 12/4/2016 0.20 PROD2 DRILL DLOG T Log K1 marker, +7' correction, close 7,880.0 7,910.0 00:00 00:12 EDC 12/4/2016 12/4/2016 0.70 PROD2 DRILL TRIP T Dry drift past billet clean, RIH Wt 11 k 7,910.0 9,691.0 00:12 00:54 lbs, bring rate up to 1.72 bpm, CT 4175 psi, WH 164 psi, off bottom dif 465 psi, Page 11/24 Report Printed: 12/30/2016 =' Operations Summary (with Timelog Depths) 2X-13 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time our (hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth (ftKB) 12/4/2016 12/4/2016 1.60 PROD2 DRILL DRLG P OBD, CT Wt 2k lbs, 1.72 bpm, CT 9,691.0 9,930.0 00:54 02:30 4398 psi, WH 166 psi, 874 psi diff, WOB 1.5k lbs, ROP 160, Pits 267 bbl, G/L = +11. multiple PU's and BHA wipers to get WOB, 41 k lbs, may at the bottom of the A4, cutting the A4 silts, Spill dril, 3 minute response time, all non essentials called in this time to report to the muster area, spill conex has a combo lock and no one knew the combo. 12/4/2016 12/4/2016 0.50 PROD2 DRILL WPRT P PU for Geo wiper, 35k lbs clean, pull 9,930.0 9,930.0 02:30 03:00 up to 9780', RIH to drill 12/4/2016 12/4/2016 1.00 PROD2 DRILL DRLG P OBD, CT Wt 3.8k lbs, 1.74 bpm CP 9,930.0 10,062.0 03:00 04:00 4293 psi, WH 44 psi, on bottm dif 874 psi, WOB 1.5k, ROP 200, PT 268 bbls, G/L= -1.2 bbl, trouble getting WOB at 10061', pumped 5x5 sweep, tried multiple PU's and BHA wipers 12/4/2016 12/4/2016 0.90 PROD2 DRILL WPRT P First wiper trip, PU Wt 37k lbs, at 10,062.0 10,062.0 04:00 04:54 9660' saw slight bobble, 850 ft wiper 12/4/2016 12/4/2016 0.70 PROD2 DRILL DRLG P 1.60 bpm, CT 4150 psi, CT Wt 3.6 10,062.0 10,142.0 04:54 05:36 klbs, WOB 2k lbs, ROP 200-70 fragile weight transfer 12/4/2016 12/4/2016 0.70 PROD2 DRILL WPRT P BHA wiper 10,142.0 10,142.0 05:36 06:18 12/4/2016 12/4/2016 0.70 PROD2 DRILL DRLG P 1.48 bpm, CT 3938 psi, CT Wt 1 to -1 10,142.0 10,280.0 06:18 07:00 klbs, WOB 1.5 - 2.7k lbs, ROP 120 12/4/2016 12/4/2016 3.00 PROD2 DRILL DRLG P 1.48 bpm, CT 3934 psi, CT Wt -1 10,280.0 10,493.0 07:00 10:00 klbs, WOB 2.29 k lbs, ROP 130. 12/4/2016 12/4/2016 0.40 PROD2 DRILL WPRT P Wiiper trip #2, PU Wt 36k lbs. 893 ft 10,439.0 9,600.0 10:00 10:24 wiper 12/4/2016 12/4/2016 0.20 PROD2 DRILL WPRT P RBIH 9,600.0 10,439.0 10:24 10:36 12/4/2016 12/4/2016 2.00 PROD2 DRILL DRLG P 1.5 bpm, off bottom CT 3612 psi, diff 10,280.0 10,555.0 10:36 12:36 422 CT RIH Wt 7.9k lbs OBD CT Wt -1.5k lbs, CT 3815 psi, WOB k lbs, ROP 130. 12/4/2016 12/4/2016 2.50 PROD2 DRILL TRIP P POOH for an agitator. Open EDC 10,555.0 67.0 12:36 15:06 above the window, POOH. Still getting some aluminum ribbons at the shaker as coil passed 12/4/2016 12/4/2016 2.20 PROD2 DRILL PULD P Bump up, Space out, PJSM, checks 67.0 0.0 15:06 17:18 did not hold. LD BHA #11 12/4/2016 12/4/2016 2.20 PROD2 DRILL PULD P PU BHA #12, L1-01 lateral drilling 0.0 78.2 17:18 19:30 assembly w agitator. Change pack- offs 12/4/2016 12/4/2016 1.50 PROD2 DRILL TRIP P RIH w/ EDC open, follow 8.6 ppg trip 78.2 7,825.0 19:30 21:00 schedule 12/4/2016 12/4/2016 0.30 PROD2 DRILL DLOG P Log K1, +5.5' correction, close EDC 7,825.0 8,145.0 21:00 21:18 12/4/2016 12/4/2016 0.90 PROD2 DRILL TRIP P Trip in, dry drift clean past billet at 8,145.0 10,555.0 21:18 22:12 9097', bring pumps back on to 1.2 bpm, RIH to 10525', CT Wt 7.6K lbs, bring rate up to 1.5 bpm, CT 4430 psi, WH 53 psi, 1026 psi diff off bottom Page 12/24 Report Printed: 12130/2016 Not Operations Summary Timelog Depths) (with ZX -13 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time our (hr) Phase Op Code Activity Code Time P -T -X Operation (ftKB) End Depth (ftKB) 12/4/2016 12/5/2016 1.80 PROD2 DRILL DRLG P 1.48 bpm, CT 4643 psi, CT Wt 5.5K 10,555.0 10,667.0 22:12 00:00 lbs, 1376 psi diff, WOB 2K, ROP 88 ft/min 12/5/2016 12/5/2016 0.20 PROD2 DRILL WPRT P BHA wiper up to 10550', PU Wt 46K 10,667.0 10,667.0 00:00 00:12 lbs, RIH Wt 5.5K lbs, 1.5 bpm, CT 4354 psi, 1036 psi dif off bot. 12/5/2016 12/5/2016 0.50 PROD2 DRILL DRLG P 1.5 bpm, CT Wt 1.4K lbs, CT 4800 psi, 10,667.0 10,707.0 00:12 00:42 1456 psi diff, WOB 1.7K lbs, ROP 115 ft/hr 12/5/2016 12/5/2016 2.10 PROD2 DRILL DRLG P Snubbing, CT Wt -1 k to -5k lbs, WOB 10,707.0 10,856.0 00:42 02:48 1.7k, ROP 85 to100 ft/hr, pump 5x5 sweep w/ 5% Lubes at 10707'. Saw improvement in CT Wt and ROP, +2.2k lbs, ROP over 200 ft/hr when lubes were around BHA, Continue drilling with PU's and BHA wipers to get CT Wt back. Pumped 2nd 5x5 sweep. At the bit at 10785', 12/5/2016 12/5/2016 0.80 PROD2 DRILL WPRT P Wiper trip #1 at 10856', PU Wt 45k lbs 10,856.0 8,700.0 02:48 03:36 12/5/2016 12/5/2016 0.70 PROD2 DRILL TRIP P RIH Wt 7k lbs, 2 bpm, CT 3504 psi, 8,700.0 10,856.0 03:36 04:18 WH 112 psi. Bring rate up to 1.5 bpm, CT 4487 psi, WH 114 psi, 1058 psi diff off bottom. 12/5/2016 12/5/2016 1.70 PROD2 DRILL DRLG P 1.5 bpm, CT Wt 2 to 4k lbs, CT 4980 10,856.0 10,976.0 04:18 06:00 psi, 1530 diff, WOB 1.8k, ROP 150 to 200. Continue to have weight transfer issues, multiple short pickups and one 5X5 lube pill, little effect seen by lube pill. 12/5/2016 12/5/2016 3.80 PROD2 DRILL DRLG P 1.68 bpm, CT Wt 0- 4k lbs, CT 5156 10,976.0 11,165.0 06:00 09:48 psi, 1538 diff, WOB 1.7-1 k, ROP 50 to 180. Geo's called TD 12/5/2016 12/5/2016 3.40 PROD2 DRILL TRIP P Pump 10 X 10 low x hi vis sweeps, 11,165.0 69.7 09:48 13:12 Chase out of hole. Nothing remarkable at the shaker as the high vis sweep landed. Jog near surface, a few pieces of wire and aluminum ribbon returned. 12/5/2016 12/5/2016 1.50 PROD2 DRILL TRIP P Tagged up, RBIH. 69.0 7,874.0 13:12 14:42 12/5/2016 12/5/2016 0.20 PROD2 DRILL DLOG P Tie into K1 for + 6.5' correction 7,874.0 7,910.0 14:42 14:54 12/5/2016 12/5/2016 1.00 PROD2 DRILL TRIP P RIH, Close EDC. Observed 1.1k lbs 7,910.0 11,169.0 14:54 15:54 WOB bobble running past 8200' no motor work, observed this trend while tripping in hole w BHA #10 on 12-3- 16, Slight coil weight stack out again at 10930 and 10970'. PU to 11025 @ 25 fpm RBIH, saw slight stack again @ 10972' continue in hole, tag bottom @ 11169. 12/5/2016 12/5/2016 3.30 PROD2 DRILL DISP P PU slowly while pumping 50 bbl 11.5 11,169.0 96.0 15:54 19:12 ppg liner running pill w/ 2 ppb alpine beads + 2% Low Torque , 1 % 776, and 11.5 KW fluid W 1% 776, painting TD flag at 8788.22' Yellow, and Window flag at 5778.22 White Page 13/24 Report Printed: 12/30/2016 Operations Summary (with Timelog Depths) 2X-13 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time Dur (hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth (ftKB) 12/5/2016 12/5/2016 2.20 PROD2 DRILL PULD P Bump up and flow check 30 min, 78.0 0.0 19:12 21:24 PJSM. LD BHA # 12 over a dead well. Found 3 gouges in the pipe — 13 ' back from the coil connecter, measured wall thickness @ 0.104". Clean / Clear the rig floor. PJSM. 12/5/2016 12/6/2016 2.60 COMPZ2 DRILL PUTB P Prepare liner running 0.0 2,297.9 21:24 00:00 equipment.PJSM, Run 75 joints, 2297.92' of 2 3/8" 4.7# L80 ST-L slotted liner. 12 jnts run as of midnight 12/6/2016 12/6/2016 0.30 COMPZ2 CASING PUTB P Continue running lower liner assembly 2,297.0 2,297.0 00:00 00:18 12/6/2016 12/6/2016 0.20 COMPZ2 CASING SFTY P Well Control Drill - Kick while running 2,297.0 2,297.0 00:18 00:30 liner, response time was 3 min to space out safety joint and simulate close U/L 2-3/8" pipe rams. Drill complete, safety joint laid down. 12/6/2016 12/6/2016 2.10 COMPZ2 CASING PUTB P Resume running liner. Finished 2,297.0 2,297.0 00:30 02:36 running 75 jnts total. 12/6/2016 12/6/2016 0.20 COMPZ2 CASING PUTB P Clear rig floor, PJSM 2,297.0 2,297.0 02:36 02:48 12/6/2016 12/6/2016 0.90 COMPZ2 CASING PULD P MU Baker BHA #13 wl liner running 2,297.0 2,343.0 02:48 03:42 tool, Pull and inspect checks in UQC, both had broken springs and stuck open, replaced checks. Surface check MWD, strip on with coil. 12/6/2016 12/6/2016 1.40 COMPZ2 CASING TRIP P RIH, EDC closed, 80 FPM, pump min 2,343.0 8,042.9 03:42 05:06 rate 0.3 bpm. Stop at white window flag (8044.16'), -1.3' correction, PU CT wt w/ pumps off 33K 12/6/2016 12/6/2016 5.00 COMPZ2 CASING TRIP P Trip in, sat down at 9277', begin 8,042.9 10,164.0 05:06 10:06 working liner 05:40 hrs, worked liner for 5 hours to 10164', decision by engineer to POOH and shorten liner section. 12/6/2016 12/6/2016 2.30 COMPZ2 CASING TRIP T POOH, pump across the top to keep 10,164.0 2,343.0 10:06 12:24 hole full and not displace liner pill. Bump up w/ 15k CT Wt. 12/6/2016 12/6/2016 0.50 COMPZ2 CASING OWFF T Perform 30 min no flow check. Hold 2,343.0 2,343.0 12:24 12:54 PJSM 12/6/2016 12/6/2016 1.00 COMPZ2 CASING PULD T Inspect flat spot on coil, LD BHA #13 2,343.0 2,298.0 12:54 13:54 liner running tool. 12/6/2016 12/6/2016 3.10 COMPZ2 CASING PUTB T PJSM, laydown 42 jnts of 2-3/8" 2,298.0 1,014.6 13:54 17:00 slotted liner 12/6/2016 12/6/2016 1.20 COMPZ2 CASING PULD T PJSM, MU Baker BHA #14 w/ agitator 1,014.6 1,065.7 17:00 18:12 and liner running tool. Surface test MWD, 12/6/2016 12/6/2016 1.70 COMPZ2 CASING TRIP T Trip in hole, BHA 14 with non ported 1,065.7 6,762.0 18:12 19:54 bullnose, 33 Jts slotted liner, and shorty deployment sleeve 12/6/2016 12/6/2016 0.10 COMPZ2 CASING DLOG T Tie into 5700' EOP flag for +3.4' 6,762.0 6,765.0 19:54 20:00 12/6/2016 12/6/2016 0.50 COMPZ2 CASING TRIP T Continue in well 6,765.0 8,695.0 20:00 20:30 12/6/2016 12/6/2016 0.30 COMPZ2 CASING DLOG T Log HRZ for tie in for +7' correction 8,695.0 8,744.0 20:30 20:48 12/6/2016 12/6/2016 1.10 COMPZ2 CASING TRIP T Continue in well, clean trip to 11040'. 8,744.0 11,063.0 20:48 21:54 Work pipe down to 11063, release liner, TOL=10048 Page 14/24 Report Printed: 12/30/2016 . Operations Summary (with Timelog Depths) w 2X-13 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time Dur (hr) Phase Op Code Activity Code Time P -T -X Operation (ftK8) End Depth (ftKB) 12/6/2016 12/7/2016 2.10 COMPZ2 CASING TRIP T PUH to 10004', remove liner length left 11,063.0 990.0 21:54 00:00 in hole, corrected depth 6750, paint window EOP flag @ 6700 12/7/2016 12/7/2016 0.20 COMPZ2 CASING TRIP T Continue trip out of well 990.0 55.8 00:00 00:12 12/7/2016 12/7/2016 0.50 COMPZ2 CASING OWFF T At surface, perform 30 min no flow test 55.8 55.8 00:12 00:42 good 12/7/2016 12/7/2016 0.50 COMPZ2 CASING PULD T PJSM, Lay down lower liner segment 55.8 0.0 00:42 01:12 running tools, R/U floor to run liner 12/7/2016 12/7/2016 3.00 COMPZ2 CASING PUTB T PJSM, M/U L1-01 upper liner segment 0.0 1,335.3 01:12 04:12 with ported bullnose, 42 Jts slotted liner and shorty deployment sleeve, M/U to coil trak BHA and set in rams. M/U to coil and surface test tools 12/7/2016 12/7/2016 1.80 COMPZ2 CASING TRIP T Trip in hole w/ BHA#15 upper liner 1,335.3 8,031.0 04:12 06:00 assembly 12/7/2016 12/7/2016 0.10 COMPZ2 CASING DLOG T Tie-in to flag, +4.5' correction 8,031.0 8,140.0 06:00 06:06 12/7/2016 12/7/2016 0.70 COMPZ2 CASING TRIP T RIH, satdown with Baker BHA near 8,140.0 10,048.0 06:06 06:48 window 9522', PU and RIH to 10048', tag, PU 4K, and tag same place, release from liner (TOL at 8763'). 12/7/2016 12/7/2016 1.90 COMPZ2 CASING TRIP P POOH 10,048.0 70.4 06:48 08:42 12/7/2016 12/7/2016 0.60 COMPZ2 CASING OWFF P At surface, 30 min flow check - good 70.4 70.4 08:42 09:18 12/7/2016 12/7/2016 0.50 COMPZ2 CASING PULD P PJSM, Lay down upper liner section 70.4 0.0 09:18 09:48 running tools. 12/7/2016 12/7/2016 1.50 PRODS STK PULD P PJSM, M/U L1-01 aluminum billet w/ 0.0 104.0 09:48 11:18 anchor, 1 jnt slotted liner, ported bull nose, M/U to coil trak BHA, M/U to coil and surface check tools. Injector maintenance, oil planitary. 12/7/2016 12/7/2016 2.70 PRODS STK TRIP P Trip in hole w/ BHA #16 anchor billet 104.0 7,910.0 11:18 14:00 12/7/2016 12/7/2016 0.30 PRODS STK DLOG P Log K1 marker, +7' correction 7,910.0 7,950.0 14:00 14:18 12/7/2016 12/7/2016 0.70 PRODS STK TRIP P Run down to 8140', close EDC, get 7,950.0 8,762.0 14:18 15:00 pick up CT Wt 32k lbs, RIH saw 1k bobble at 8220', orient upper anchor to 170 ROHS, tag top of liner at 8762'w/ 4k WOB, pick up to 1 k WOB, roll pumps, anchor set at 4600 psi, SO to 5k pick up off billet. 12/7/2016 12/7/2016 0.70 PRODS STK TRIP P POOH, stop reset depth at 8084' (- 8,762.0 7,603.0 15:00 15:42 42.8'), open EDC, continue POOH 12/7/2016 12/7/2016 0.50 PRODS STK TRIP P Started seeing gouges on coil back at 7,603.0 7,603.0 15:42 16:12 the reel -7800', stopped at 7603' to inspect and take photos, can't RBIH because of rod on Baker #10 setting tool. 12/7/2016 12/7/2016 1.50 PRODS STK TRIP P Contuue POOH 7,603.0 79.0 16:12 17:42 12/7/2016 12/7/2016 0.90 PRODS STK OWFF P At surface, perform 30 minute no flow 79.0 79.0 17:42 18:36 test, crew change out 12/7/2016 12/7/2016 0.70 PRODS STK PULD P PJSM, Lay down BHA # 16. Anchor 79.0 0.0 18:36 19:18 billet running BHA Page 15/24 Report Printed: 12/30/2016 e Operations Summary (with Timelog Depths) F 2X-13 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time Dur (hr) Phase Op Code Activity Code Time P -T -X Operation (ftKB) End Depth (ftKB) 12/7/2016 12/7/2016 1.30 PROD3 STK CTOP P Stab back on well with nozzle, Jet 0.0 0.5- 19:18 20:36 stack while rolling coil to water in prep for slack mgmt / Full BOPE test 12/7/2016 12/8/2016 3.40 PROD3 STK CTOP P Remove CTC, Boot end of wire to seal 0.0 0.0 20:36 00:00 for slack mgmt, Stab on and pump slack, Cut 11 8'of pipe, Found wire @ 110' 12/8/2016 12/8/2016 0.30 PROD3 STK CTOP P Continue coil trim of 118', Test E -Line 0.0 0.0 00:00 00:18 12/8/2016 12/8/2016 0.90 PROD3 STK CTOP P Prep coil and install Coil Connector, 0.0 0.0 00:18 01:12 Pull test 35K 12/8/2016 12/8/2016 1.30 PROD3 STK CTOP P Head up BHI upper quick connect, PT 0.0 0.0 01:12 02:30 to 4500 PSI 12/8/2016 12/8/2016 1.50 PROD3 STK CTOP P Prep for full BOPE test, Test to be 0.0 0.0 02:30 04:00 witnessed/by Brian Bixby, AOGCC 12/8/2016 12/8/2016 8.30 PROD3 STK BOPE P Start full Bi weekly BOPE test. Test 0.0 0.0 04:00 12:18 witnessed by Bill Bixby, AOGCC. Complete BOP test 250 psi / 3000 psi, including the Inner Reel Valve and PO's, no test failures. 12/8/2016 12/8/2016 1.40 PROD3 STK CIRC P Swap reel back to KWF and fill hole 0.0 0.0 12:18 13:42 with 3.5 bbls 12/8/2016 12/8/2016 0.50 PROD3 STK OWFF P Perform 30 min no -flow test 0.0 0.0 13:42 14:12 12/8/2016 12/8/2016 1.80 PROD3 STK PULD P P/U BHA *17, Weatherford motor w/ 0.0 78.0 14:12 16:00 0.95° AKO (2.684" @ the wear band), Hycolag 2.74" x 3-1/4" bi-center bit. Make up to coil and surface test 12/8/2016 12/8/2016 1.70 PRODS STK TRIP P Trip in hole, EDC open, pumping 1 78.0 7,598.0 16:00 17:42 BPM 12/8/2016 12/8/2016 0.50 PROD3 STK TRIP P Continue in well checking marks on 7,598.0 7,900.0 17:42 18:12 pipe, Unable to get clear wall thickness in gouge, Take photos 12/8/2016 12/8/2016 0.50 PROD3 STK DLOG P Log K1 for+ 17', Check counters and 7,900.0 7,948.0 18:12 18:42 clean, reset depth and trip in 12/8/2016 12/8/2016 0.40 PROD3 STK TRIP P Continue in well 7,948.0 8,131.0 18:42 19:06 12/8/2016 12/8/2016 0.60 PROD3 STK CIRC P Displace well to Flo Pro, Close EDC 8,131.0 8,131.0 19:06 19:42 12/8/2016 12/8/2016 0.50 PROD3 STK TRIP P Trip in to 8190 and log RA for -2' 8,131.0 8,715.0 19:42 20:12 correction, Clean pass through window, dry tag billet @ 8715' 12/8/2016 12/9/2016 3.80 PROD3 STK KOST P Bring on pumps 1.5 BPM @ 4222 PSI 8,715.0 8,715.0 20:12 00:00 FS. Encounter multiple stalls, attempt differnet rates / speeds and stick drilling. Prep for mud swap. Stick slipping stalling 12/9/2016 12/9/2016 1.50 PRODS STK KOST P Continue working to get on billet. 1.6 8,715.0 8,731.0 00:00 01:30 BPM @ 4300 PSI FS, BHP=3687, New mud going down @ 1:05, New mud @ bit 8720'. 12/9/2016 12/9/2016 0.20 PROD3 DRILL DRLG P Kicked off @ 8715', Drill ahead, 1.7 8,731.0 8,750.0 01:30 01:42 BPM @ 4095 (New Mud) PSI FS, BHP=3595, ROP= -160 FPH, Not much aluminium across shaker 12/9/2016 12/9/2016 0.20 PROD3 DRILL WPRT P Dry drift billet area, Clean up and 8,750.0 8,750.0 01:42 01:54 down, PUW=33K 12/9/2016 12/9/2016 2.20 PROD3 DRILL DRLG P 8750', Drill ahead, 1.71 BPM @ 4095 8,750.0 9,155.0 . 01:54 04:06 PSI FS, BHP=3595 Page 16/24 Report Printed: 12/30/2016 Operations Summary (with Timelog Depths) T 2X-13 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time Dur (hr) Phase Op Code Activity Code Time P-T-X Operation (WB) End Depth (ftKB) 12/9/2016 12/9/2016 0.50 PROD3 DRILL WPRT P Wiper trip to 8500', PUW=32K, Clean 9,155.0 9,155.0 04:06 04:36 trip up and down. Clean past billet 12/9/2016 12/9/2016 2.50 PRODS DRILL DRLG P 9155', Drill 1.65 BPM @ 4020 PSI FS, 9,155.0 9,550.0 04:36 07:06 BHP=3645, RIW=10.7K, WHP=213 12/9/2016 12/9/2016 0.60 PROD3 DRILL WPRT P 9550', 2nd wiper trip to 8750', PUW= 9,550.0 9,550.0 07:06 07:42 38k, clean trip 12/9/2016 12/9/2016 0.80 PRODS DRILL DRLG P Drill 1.65 BPM, CT 4220 psi on 9,550.0 9,712.0 07:42 08:30 bottom, BHP=3600 psi, CT Wt = 5 to 10k, WOB 1 to 2K, ROP 180 to 200 ft/hr. Began seeing losses of 56 bbls / hour, at 9710' 12/9/2016 12/9/2016 0.20 PRODS DRILL WPRT P 9712', pull up to 9650', observe 9,712.0 9,712.0 08:30 08:42 losses, consult town engineer, drill ahead 50 to 100' and monitor losses 12/9/2016 12/9/2016 2.20 PROD3 DRILL DRLG P Drilling ahead, BHA wiper at 9829', PU 9,712.0 9,950.0 08:42 10:54 Wt 48k, losses improved to 26 bbl / hr, 12/9/2016 12/9/2016 0.70 PROD3 DRILL WPRT P 9950', 3rd wiper trip, PU Wt= 38k, 9,950.0 8,160.0 10:54 11:36 12/9/2016 12/9/2016 0.30 PROD3 DRILL DLOG P Log RA tag, +7.5' correction. 8,160.0 8,210.0 11:36 11:54 12/9/2016 12/9/2016 0.70 PROD3 DRILL TRIP P Trip in to drill, RIH Wt 8.6k, 1.64 bpm, 8,210.0 9,950.0 11:54 12:36 CT 3976 psi FS, WH 278 psi, 738 psi diff off bottom 12/9/2016 12/9/2016 2.80 PROD3 DRILL DRLG P Drilling 1.63 bpm, CT 4400 psi, 1110 9,950.0 10,355.0 12:36 15:24 psi diff, WOB 2.3k, ROP 115 ft/hr, pumped 5x5 sweep before upcoming wiper. 12/9/2016 12/9/2016 0.80 PROD3 DRILL WPRT P 10355', 4th wiper trip, PUW 38k, up to 10,355.0 10,355.0 15:24 16:12 9350', RIH to drill 12/9/2016 12/9/2016 2.00 PRODS DRILL DRLG P Drilling, multiple pick ups and BHA 10,355.0 10,492.0 16:12 18:12 wipers at 10432 to get WOB, start 5x5 sweep 12/9/2016 12/9/2016 1.80 PROD3 DRILL WPRT P Perform 300 'wiper for weight 10,492.0 10,492.0 18:12 20:00 transfer, Hard to get drilling, try lowering rate to get going - No Go Pull wiper to billet, PUW=41 K 12/9/2016 12/9/2016 1.20 PRODS DRILL DRLG P 10492', Drill ahead, 1.58 BPM @ 4035 10,492.0 10,640.0 20:00 21:12 PSI FS, BHP=3710, RIW=-lKwith 1.4K DHWOB 12/9/2016 12/9/2016 0.30 PROD3 DRILL WPRT P Pull 100 foot BHA wiper for weight 10,640.0 10,640.0 21:12 21:30 transfer, PUW=40K 12/9/2016 12/9/2016 0.80 PROD3 DRILL DRLG P 10640', Drill, 1.58 BPM @ 4115 PSI 10,640.0 10,805.0 21:30 22:18 FS, BHP=3825 12/9/2016 12/9/2016 0.80 PROD3 DRILL WPRT P Pull 1000' wiper, PUW=39K 10,805.0 10,805.0 22:18 23:06 12/9/2016 12/10/2016 0.90 PROD3 DRILL DRLG P 10805 Drill, 1.58 BPM @ 4085 PSi 10,805.0 10,881.0 23:06 00:00 FS, BHP=3790 12/10/2016 12/10/2016 1.90 PROD3 DRILL DRLG P Continue drilling, 10895 hard spot, 10,881.0 10,895.0 00:00 01:54 Tough to get through, P/U many times loosing any differential. Most likely bottom of A4 lower silt 12/10/2016 12/10/2016 0.30 PROD3 DRILL DRLG P Drilling break, Drill ahead 1.55 BPM @ 10,895.0 10,920.0 01:54 02:12 4029 PSI FS, BHP=3747, Call TD @ 10920, Confirmed top of pay zone 12/10/2016 12/10/2016 3.00 PROD3 DRILL WPRT P Pump 10 X 10 Sweeps, chase to 10,920.0 69.5 02:12 05:12 swab, Open EDC @ 8144 Page 17124 Report Printed: 12/30/2016 -- Operations Summary (with Timelog Depths) �r- 'f 2X-13 AJ. ,. Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time our (hr) Phase Op Code Activity Code Time P -T -X Operation (WB) End Depth (ftKB) 12/10/2016 12/10/2016 0.10 PROD3 DRILL WPRT P Tag up. Reset counters. Inspect/ 78.1 78.1 05:12 05:18 clean injector counter 12/10/2016 12/10/2016 1.50 PROD3 DRILL TRIP P Trip in to confirm TD 78.1 7,890.0 05:18 06:48 12/10/2016 12/10/2016 0.20 PRODS DRILL DLOG P Log K1 marker, +5' correction 7,890.0 7,929.0 06:48 07:00 12/10/2016 12/10/2016 1.30 PROD3 DRILL TRIP P Trip in, close EDC at window, SD at 7,929.0 10,929.0 07:00 08:18 10800', wiped clean 3X, tagged TD at 10928.84', beads at the bit at 08:20 am 12/10/2016 12/10/2016 2.70 PROD3 DRILL TRIP P Lay in 11.5 ppg liner pill w/lubes and 10,929.0 78.1 08:18 11:00 beads, pulled thru 10800' clean, continue trip out, stop at 8708' paint yellow flag, stop at 5878' paint white flag, POOH, 16 bbl loss during trip in and out. 12/10/2016 12/10/2016 0.50 PROD3 DRILL OWFF P At surface, 30 min flow check 78.1 78.1 11:00 11:30 12/10/2016 12/10/2016 0.80 PROD3 DRILL PULD P Lay down BHA #17, fill hole with 2 78.1 0.0 11:30 12:18 bbls 12/10/2016 12/10/2016 3.70 COMPZ3 CASING PUTB P Clear rig floor, PJSM, M/U solid BN 0.0 2,247.0 12:18 16:00 and 73 joints of 2-3/8" slotted liner 12/10/2016 12/10/2016 1.30 COMPZ3 CASING PULD P PJSM, M/U BHA # 18, aluminum billet, 2,247.0 2,299.9 16:00 17:18 GS and Baker Inteq tools. Change pack -offs, EDC is closed, surface test MWD. 12/10/2016 12/10/2016 1.40 COMPZ3 CASING TRIP P Trip in hole with BHA #18 2,299.0 8,100.0 17:18 18:42 12/10/2016 12/10/2016 0.10 COMPZ3 CASING DLOG P Tie into EOP flag for no correction 8,100.0 8,100.0 18:42 18:48 12/10/2016 12/10/2016 0.40 COMPZ3 CASING TRIP P Continue in with liner 8,100.0 9,337.0 18:48 19:12 12/10/2016 12/11/2016 4.80 COMPZ3 CASING TRIP P Initial setdown @ 9337, Multiple 9,337.0 10,688.0 19:12 00:00 setdowns to midnight depth of 10688. Made steady but slow progress 12/11/2016 12/11/2016 2.70 COMPZ3 CASING TRIP P Continue working liner to bottom, Hard 10,688.0 10,920.0 00:00 02:42 bottom Unable to pass, Bring on pumps 1.5 BPM @ 4K PSI, PUW=30K, DHWOB=3K, stop at 10,904 and subtrack liner length from counters, TOL=8670 12/11/2016 12/11/2016 0.40 COMPZ3 CASING TRIP P Trip out after running liner, 8648 8,648.0 8,148.0 02:42 03:06 12/11/2016 12/11/2016 0.20 COMPZ3 CASING DLOG P Log RA for+7.5' 8,148.0 8,164.0 03:06 03:18 12/11/2016 12/11/2016 2.40 COMPZ3 CASING TRIP P Trip out for L1-03 Kick off BHA 8,164.0 43.3 03:18 05:42 12/11/2016 12/11/2016 0.50 COMPZ3 CASING OWFF P At surface, 30 min flow check 43.3 43.3 05:42 06:12 12/11/2016 12/11/2016 1.00 COMPZ3 CASING PULD P PJSM, LID BHA#18. 43.3 0.0 06:12 07:12 12/11/2016 12/11/2016 2.50 PROD4 STK RGRP T Pull guards on injector, pressure 0.0 0.0 07:12 09:42 wash, clean and inspect chains and gripper blocks, replaced chain tension pressure switch, did not find any damage or foreign debris 12/11/2016 12/11/2016 1.30 PROD4 STK PULD P M/U BHA#19 w/ 1° AKO Weatherford 0.0 78.1 09:42 11:00 motor, 3.25" HYC bi center bit Page 18/24 Report Printed: 12/30/2016 Operations Summary (with Timelog Depths) 2X-13 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time Dur (hr) Phase Op Code Activity Code Time P -T -X Operation (ftKB) End Depth (ftKB) 12/11/2016 12/11/2016 1.80 PROD4 STK TRIP P Trip in, 78.1 7,885.0 11:00 12:48 12/11/2016 12/11/2016 0.30 PROD4 STK DLOG P Log K1 marker, +8.5' correction 7,885.0 8,162.0 12:48 13:06 12/11/2016 12/11/2016 1.60 PROD4 STK CIRC P Circulate well to FloPro with 0.2 bpm 8,162.0 8,162.0 13:06 14:42 loss rate. 12/11/2016 12/11/2016 0.30 PROD4 STK TRIP P Dry tag billet at 8670', PUW 36k, 8,162.0 8,670.0 14:42 15:00 12/11/2016 12/11/2016 2.70 PROD4 STK KOST P Bring pumps to 1.6 bpm, CT 4056 psi, 8,670.0 8,672.0 15:00 17:42 WH 153 psi, 730 psi FS. Engage top of billet at 8670.1, high side exit, stalled 4x, weight transfer, make 200' back ream pass, Auto drill at 1 fph, trouble getting weight transfer. 12/11/2016 12/11/2016 1.30 PROD4 DRILL DRLG P Estabished WOB and ROP, 1.6 BPM 8,672.0 8,700.0 17:42 19:00 @ 3980 PSI FS, BHP=3550 12/11/2016 12/11/2016 0.30 PROD4 DRILL WPRT P 8700', drift billet area, Saw billet area 8,700.0 8,700.0 19:00 19:18 up and down. Made three clean up passes, Looks good 12/11/2016 12/11/2016 1.60 PROD4 DRILL DRLG P 8700', Drill ahead, 1.6 BPM @ 3900 8,700.0 8,768.0 19:18 20:54 PSI FS, BHP=3595, ROP 25 - 60 FPH 12/11/2016 12/11/2016 0.10 PROD4 DRILL WPRT P Short pick up / stacking - PUW=45K 8,768.0 8,768.0 20:54 21:00 12/11/2016 12/11/2016 2.00 PROD4 DRILL DRLG P 8768', Drill 1.6 BPM @ 3875 PSI FS, 8,768.0 8,862.0 21:00 23:00 BHP=3590, RIW=11K, DHWOB=2.5K, ROP 40 to 60 FPH 12/11/2016 12/11/2016 0.20 PROD4 DRILL WPRT P BHA Wiper, PUW=45K, stall twice in 8,862.0 8,862.0 23:00 23:12 this area getting back to drilling, RIW=10K 12/11/2016 12/12/2016 0.80 PROD4 DRILL DRLG P 8862, Drilling break ROP over 100 8,862.0 8,933.0 23:12 00:00 FPH, 1.6 BPM @ 3898 PSI FS, BHP=3600 12/12/2016 12/12/2016 1.70 PROD4 DRILL DRLG P Continue drilling ahead L1-03 lateral, 8,933.0 9,010.0 00:00 01:42 1.6 BPM @ 3900 PSI FS, BHP=3600, WHP=197 12/12/2016 12/12/2016 0.70 PROD4 DRILL WPRT P Wiper trip to 8200', PUW=44K, with 9,010.0 9,010.0 01:42 02:24 sweeps, RIW=9K, Overpull at billet area, 2K 12/12/2016 12/12/2016 1.20 PROD4 DRILL DRLG P 9100', Drill, 1.6 BPM @ 3935 PSI FS, 9,010.0 9,050.0 02:24 03:36 BHP=3565, Hard to maintain drilling Stacking 9026 to 9050 12/12/2016 12/12/2016 0.30 PROD4 DRILL WPRT P BHA Wiper, 41 K 9,050.0 9,050.0 03:36 03:54 12/12/2016 12/12/2016 1.00 PROD4 DRILL DRLG P 9050', Drill, 1.66 BPM @ 3970 PSI 9,050.0 9,061.0 03:54 04:54 FS, BHP = 3600, Poor drilling with stacking 12/12/2016 12/12/2016 0.30 PROD4 DRILL WPRT P Wiper to 8600. Geo reporting more 9,061.0 9,061.0 04:54 05:12 aluminum in samples. Going past billet - Reset out total and watch for bottoms up from billet area, PUW=44K 12/12/2016 12/12/2016 5.40 PROD4 DRILL DRLG P Continue drilling, stacking,lots of 9,061.0 9,220.0 05:12 10:36 motor stalls, small drilling breaks 150 ft/hr, back to 30 -60 ft/hr, pumped (2) 5x5 sweeps, helped weight transfer but short lived. Consult town engineer on adding lubes, add 1 % Lo Torq to active system Page 19/24 Report Printed: 12/30/2016 Operations Summary with Timelo Depths) ) 0.11 s. 2X-13 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time Dur (hr) Phase Op Code Activity Code Time P -T -X Operation (ftKB) End Depth (ftKB) 12/12/2016 12/12/2016 0.40 PROD4 DRILL WPRT P Wiper trip back to the window, to clean 9,220.0 6,650.0 10:36 11:00 the hole while waiting for 1 % Lo Torq , saw small overpull at the billet, open EDC. circulate 2 bpm„ got 1 BU. 12/12/2016 12/12/2016 0.80 PROD4 DRILL TRIP P Trip in 6,650.0 7,885.0 11:00 11:48 12/12/2016 12/12/2016 0.40 PROD4 DRILL DLOG P Tie in at K1 marker, +6.5', close EDC 7,885.0 7,925.0 11:48 12:12 12/12/2016 12/12/2016 0.30 PROD4 DRILL TRIP P Trip in to drill, drift clean past billet, 7,925.0 9,220.0 12:12 12:30 12/12/2016 12/12/2016 1.80 PROD4 DRILL DRLG P Drilling, 1.68 bpm, CT 4433 psi, WH 9,220.0 9,331.0 12:30 14:18 70 psi, 885 psi diff FS, weight transfer is improved. 12/12/2016 12/12/2016 1.20 PROD4 DRILL DRLG P 9331', no ROP, unable to get motor 9,331.0 9,331.0 14:18 15:30 work or stalls, picked multiple times and spud in at 25 fpm, set 5K WOB, tried different tool face and pump rates. Consult town 12/12/2016 12/12/2016 2.50 PROD4 DRILL TRIP T Trip for new motor and inspect bit, 9,331.0 78.1 15:30 18:00 open EDC above window, trip out following 11.4 ppg trip schedule, jog in hole at 500' 12/12/2016 12/12/2016 2.00 PROD4 DRILL PULD T At surface, bump, space out, crew 78.1 0.0 18:00 20:00 change, PJSM, PUD BHA#19, inspect Weatherford motor, suspect output shaft on power end broke, bit grade 1-1, laydown motor 12/12/2016 12/12/2016 1.40 PROD4 DRILL PULD T PJSM, PD BHA #20 0.92° AKO 0.0 83.7 20:00 21:24 Weatherford motor, NOV agitator, and RR HYC 3.25" bit 12/12/2016 12/12/2016 1.40 PROD4 DRILL TRIP T Trip in 83.7 7,885.0 21:24 22:48 12/12/2016 12/12/2016 0.30 PROD4 DRILL DLOG T Tie in at K1 marker, +3' correction 7,885.0 7,930.0 22:48 23:06 12/12/2016 12/12/2016 0.60 PROD4 DRILL TRIP T Trip in to drill, close EDC, 7,930.0 9,331.0 23:06 23:42 12/12/2016 12/13/2016 0.30 PROD4 DRILL DRLG P 1.60 bpm, 4818 psi FS, 1335 psi diff. 9,331.0 9,345.0 23:42 00:00 12/13/2016 12/13/2016 2.90 PROD4 DRILL DRLG P 9345', Drill ahead, 1.6 BPM @ 4760 9,345.0 9,459.0 00:00 02:54 PSI FS, BHP=3665 12/13/2016 12/13/2016 0.20 PROD4 DRILL WPRT T Pull Geo wiper, discuss DLS situation. 9,459.0 9,459.0 02:54 03:06 Avg 9.9° needing 12's to stay in polygon. Discuss with town geo. Polygon is hard line, PUW=42K 12/13/2016 12/13/2016 2.40 PROD4 DRILL DRLG P 9459', Drill, 1.6 BPM @ 4825 PSI FS, 9,459.0 9,605.0 03:06 05:30 BHP=3700, RIW=11K 12/13/2016 12/13/2016 1.70 PROD4 DRILL DRLG P 9605, Drilling break - start taking 9,605.0 9,750.0 05:30 07:12 losses. Inititialy 1 BPM, started healing while drilling ahead, 1.7 BPM @ 5169 PSI FS, BHP=3689 12/13/2016 12/13/2016 0.60 PROD4 DRILL WPRT P 9750 Wiper to 8900', PUW=39K 9,750.0 9,750.0 07:12 07:48 12/13/2016 12/13/2016 1.30 PROD4 DRILL DRLG P 9750', Drill Ahead, 1.6 BPM @ 4700 9,750.0 9,826.0 07:48 09:06 PSi FS, BHP=3580 12/13/2016 12/13/2016 0.30 PROD4 DRILL WPRT P 9826 pull 300' wiper, weight transfer, 9,826.0 9,826.0 09:06 09:24 PUW=60K 12/13/2016 12/13/2016 0.60 PROD4 DRILL DRLG P 9826', Drill ahead, 1.6 BPM @ 4800 9,826.0 9,914.0 09:24 10:00 PSI FS, BHP=3675 Page 20/24 Report Printed: 12/30/2016 '. Operations Summary (with Timelog Depths) 2X-13 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time Dur (hr) Phase Op Code Activity Code Time P -T -X Operation (ftKB) End Depth (ftKB) 12/13/2016 12/13/2016 1.60 PROD4 DRILL DRLG T Attempt to come off bottom - stuck - 9,914.0 9,914.0 10:00 11:36 circulate bottoms up - trap pressure and relax pipe, ECD down to 10.8. Work pipe two cycles -5K to 75K 12/13/2016 12/13/2016 0.50 PROD4 DRILL CIRC T Load pits with LVT and circulate down 9,914.0 9,914.0 11:36 12:06 hole, 7.2 BBIs, Pipe in tension 66K 12/13/2016 12/13/2016 0.70 PROD4 DRILL WPRT P LVT reached BHA, popped free, 9,914.0 8,183.0 12:06 12:48 Perform wiper to window with tie in 12/13/2016 12/13/2016 0.20 PROD4 DRILL DLOG P Log RA for+7' correction 8,183.0 8,215.0 12:48 13:00 12/13/2016 12/13/2016 0.60 PROD4 DRILL WPRT P RBIH to drill, RIW=9K Clean trip up 8,215.0 9,914.0 13:00 13:36 and down 12/13/2016 12/13/2016 3.00 PROD4 DRILL DRLG P 9914', Drill, 1.61 BPM @ 4665 PSI 9,914.0 10,160.0 13:36 16:36 FS, BHP=3625 12/13/2016 12/13/2016 0.10 PROD4 DRILL WPRT P BHA Wiper, PUW=52K 10,160.0 10,160.0 16:36 16:42 12/13/2016 12/13/2016 3.70 PROD4 DRILL DRLG P 10160', Drill, 1.7 BPM @ 5125 PSI 10,160.0 10,311.0 16:42 20:24 FS, BHP=3783. Several PUS for weight transfer. PUW = 40k - 46k. 12/13/2016 12/13/2016 0.30 PROD4 DRILL WPRT P 150'Wiper for weight transfer. 10,311.0 10,311.0 20:24 20:42 PUW=45k. 12/13/2016 12/13/2016 1.60 PROD4 DRILL DRLG P BOBD, 1.66 BPM @ 5165 psi FS, 10,311.0 10,370.0 20:42 22:18 WOB 1.8k, ROP 60. New mud system #4 at the bit @ 10,330'. Steady axial vibration of 1, affecting surveys. 12/13/2016 12/13/2016 0.70 PROD4 DRILL WPRT P 850' Wiper (#1). PUW=45k. 10,370.0 10,370.0 22:18 23:00 12/13/2016 12/13/2016 0.50 PROD4 DRILL DRLG P BOBD, 1.6 BPM @ 4815 psi FS, WOB 10,370.0 10,442.0 23:00 23:30 1.9k, CTSW 4k, ROP 130. Back in the A4 sand after cresting into the A6. 12/13/2016 12/13/2016 0.20 PROD4 DRILL WPRT P PUH to obtain missed surveys. 10,442.0 10,442.0 23:30 23:42 PUW=42k. 12/13/2016 12/14/2016 0.30 PROD4 DRILL DRLG P BOBD, 1.56 BPM @ 4486 psi FS, 10,442.0 10,454.0 23:42 00:00 WOB 1.3k, CTSW 1k, ROP 40. 12/14/2016 12/14/2016 0.30 PROD4 DRILL DRLG P Drill ahead, 1.56 BPM @ 4486 psi 10,454.0 10,475.0 00:00 00:18 FS, WOB 1.6k, CTSW 1k, ROP 79. 12/14/2016 12/14/2016 0.90 PROD4 DRILL DRLG T Bore pressure dropped, attempt to 10,475.0 10,475.0 00:18 01:12 PUH 50 FPM (65k) - stuck. Work pipe 75k to -4k pumping 1.56 BPM. 12/14/2016 12/14/2016 2.30 PROD4 DRILL CIRC T Pump sweep all the way around. 10,475.0 10,475.0 01:12 03:30 Pump 1 tote (7 bbls) LVT. 5 bbls out of bit and let soak couple minutes, work pipe not pumping. Pump out last 2 bbls, let soak, work pipe (80k to -8k) while waiting on truck w/ LVT from KIC. 12/14/2016 12/14/2016 0.70 PROD4 DRILL CIRC T Pump 25 bbls LVT, 20 bbls out of bit, 10,475.0 10,475.0 03:30 04:12 let soak 4 mins w CTSW=65k, pop free. 12/14/2016 12/14/2016 1.10 PROD4 DRILL WPRT P PUH for window wiper & tie-in. Heavy 10,475.0 8,450.0 04:12 05:18 overpulls (62k) through high gamma ray section (10,230' - 10,155'). 12/14/2016 12/14/2016 0.70 PROD4 DRILL WPRT T 8450 Pull heavy, Lost returns, Packed 8,450.0 8,450.0 05:18 06:00 off. Unable to go down work up, Unable to circulate or orient Page 21/24 Report Printed: 12/30/2016 Y Operations Summary (with Timelog Depths) } 3.r 2X-13 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time Dur (hr) Phase Op Code Activity Code Time P -T -X Operation (ftKB) End Depth (ftKB) 12/14/2016 12/14/2016 3.20 PROD4 DRILL WPRT T Attempt to work pipe down, Set CT in 8,450.0 8,450.0 06:00 09:12 compression, -3K, Attempt to regain circulation while working agitator, Start getting returns @ 1 BPM. Work up to 1.49 getting back 1 BPM. Pump bottoms up. Pump sweeps. Able to orient. 12/14/2016 12/14/2016 0.70 PROD4 DRILL WPRT T Pump 10 BBI LVT pill and circulate 8,450.0 8,640.0 09:12 09:54 down. Get 5 BBIs out of coil. Pipe free moving down hole. RIH until all LVT out of coil 12/14/2016 12/14/2016 0.80 PROD4 DRILL WPRT P Start PUH, Overpulls at 8450. Work 8,640.0 8,122.0 09:54 10:42 pipe down after overpulls. Jog pipe below window. Jog pipe above window before opening EDC 12/14/2016 12/14/2016 0.70 PROD4 DRILL WPRT P Open EDC and circ sweeps out, 2 8,122.0 7,772.0 10:42 11:24 BPM @ 4000PSI 12/14/2016 12/14/2016 0.30 PROD4 DRILL WPRT P RBIH, Shut EDC @ 8100, Clean pass 7,772.0 8,175.0 11:24 11:42 throught window 12/14/2016 12/14/2016 0.20 PROD4 DRILL DLOG P Log RA for tie in, +8' correction 8,175.0 8,213.8 11:42 11:54 12/14/2016 12/14/2016 0.70 PROD4 DRILL WPRT P Continue in well 8,213.8 9,710.0 11:54 12:36 12/14/2016 12/14/2016 0.20 PROD4 DRILL WPRT P Return path plugged, Micro motion or 9,710.0 9,535.0 12:36 12:48 MP chokes 12/14/2016 12/14/2016 0.50 PROD4 DRILL WPRT P Continue back in hole 9,535.0 10,148.0 12:48 13:18 12/14/2016 12/14/2016 1.10 PROD4 DRILL WPRT P Plugged up again, PUH Clear Micro 10,148.0 7,810.0 13:18 14:24 motion still plugged, Pull down MP chokes 12/14/2016 12/14/2016 0.10 PROD4 DRILL DLOG P Log RA for +6 foot correction, Inspect 7,845.0 7,910.0 14:24 14:30 counters 12/14/2016 12/14/2016 1.30 PROD4 DRILL WPRT P Continue in hole, Work pipe 10,150 to 7,910.0 10,405.0 14:30 15:48 10,350'. Reduce pump rate to get through 12/14/2016 12/14/2016 0.60 PROD4 DRILL WPRT P Pull up hole through high gamma 10,405.0 10,096.0 15:48 16:24 zone, 1.82 BPM @ 5470 PSI FS, BHP=3734, PUW=39K 12/14/2016 12/14/2016 0.40 PROD4 DRILL WPRT P RBIH, Able to go through area @ 1 10,096.0 10,475.0 16:24 16:48 BPM, RIH to Drill 12/14/2016 12/14/2016 2.70 PROD4 DRILL DRLG P 10475', Drill 1.58 BPM @ 4770 PSI 10,475.0 10,758.0 16:48 19:30 FS, BHP=3812. Several PUS for weight transfer. PUW=48k - 55k. 12/14/2016 12/14/2016 0.20 PROD4 DRILL WPRT P 100' Wiper trip, PUW = 55k. 10,758.0 10,758.0 19:30 19:42 12/14/2016 12/14/2016 1.00 PROD4 DRILL DRLG P BOBD, 1.51 BPM @ 4595 psi FS, 10,758.0 10,880.0 19:42 20:42 WOB 1.61k, CTSW= -6k, ROP 190. At 10,820', increasing inclination to 94° pointing TF HS. 12/14/2016 12/14/2016 0.80 PROD4 DRILL WPRT P 1 000'Wiper trip, PUW=40k. 10,880.0 10,880.0 20:42 21:30 12/14/2016 12/15/2016 2.50 PROD4 DRILL DRLG P BOBD, 1.51 BPM @ 5050 psi FS, 10,880.0 10,950.0 21:30 00:00 WOB 1.5k, CTSW -6k to -10k. Numerous PUS for weight transfer, inclination to 95°+ not helping. 12/15/2016 12/15/2016 1.40 PROD4 DRILL WPRT P Perform swab wiper - clean open hole. 10,950.0 8,130.0 00:00 01:24 Jog above window prior to opening the EDC. Open EDC. 12/15/2016 12/15/2016 1.70 PROD4 DRILL WPRT P Cont POOH pumping 1.7 BPM. Tag- 8,130.0 84.0 01:24 03:06 up, set depths. Page 22/24 Report Printed: 12/30/2016 y Operations Summary (with Timelog Depths) 2X-13 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time Dur (hr) Phase Op Code Activity Code Time P -T -X Operation (ftKB) End Depth (ftKB) 12/15/2016 12/15/2016 1.50 PROD4 DRILL WPRT P RBIH 84.0 7,910.0 03:06 04:36 12/15/2016 12/15/2016 0.20 PROD4 DRILL DLOG P Tie-in to K1 for +6' correction 7,910.0 7,940.0 04:36 04:48 12/15/2016 12/15/2016 1.20 PROD4 DRILL WPRT P Cont RIH. Close EDC above window. 7,940.0 10,952.0 04:48 06:00 Cont RIH to confirm TD. Set down @ 10045'. P/U and run through 12/15/2016 12/15/2016 3.20 PROD4 DRILL TRIP P Trip out of hole pumping 11.5 PPG 10,952.0 96.0 06:00 09:12 beaded liner running pill followed by 11.5 PPG Beaded liner running pill. Paint 9500' and 9800' EOP flag. Had over pull @ 9070 12/15/2016 12/15/2016 0.50 PROD4 DRILL OWFF P Perform 30 Min No Flow - good test 96.0 96.0 09:12 09:42 12/15/2016 12/15/2016 1.00 PROD4 DRILL PULD P PJSM Pull injector and lay down 96.0 0.0 09:42 10:42 drilling BHA #20 12/15/2016 12/15/2016 2.80 COMPZ4 CASING PUTB P Prep floor to run liner, P/U L1-03 lower 0.0 1,245.2 10:42 13:30 liner segment. Non Ported bullnose, 41 Jts slotted liner and shorty deployment sleeve 12/15/2016 12/15/2016 1.30 COMPZ4 CASING PULD P Skid Injector, Change float valves, 1,245.2 1,305.1 13:30 14:48 Inspect counters, M/U injector to coiltrak and surface test 12/15/2016 12/15/2016 1.90 COMPZ4 CASING RUNL P Trip in hole with BHA #21. L1-03 lower 1,305.1 8,104.0 14:48 16:42 liner segment 12/15/2016 12/15/2016 0.10 COMPZ4 CASING DLOG P Tie into 5100' EOP flag for+.8. 8,104.0 8,104.0 16:42 16:48 12/15/2016 12/15/2016 0.40 COMPZ4 CASING RUNL P Trip in to hole, Set down at 8840 8,104.0 9,122.0 16:48 17:12 12/15/2016 12/15/2016 0.20 COMPZ4 CASING DLOG P Log K1 set down first pass. PUH and 9,122.0 9,157.1 17:12 17:24 start again Correct +1.5' 12/15/2016 12/15/2016 3.50 COMPZ4 CASING RUNL P Continue in well. Work liner through 9,157.1 10,952.0 17:24 20:54 hotter GR sections (9,300' - 9,575' and 9,880'- 10,810'). Set top of lower liner section @ 9,697'. 12/15/2016 12/15/2016 0.70 COMPZ4 CASING TRIP P POOH 10,952.0 7,875.0 20:54 21:36 12/15/2016 12/15/2016 0.20 COMPZ4 CASING DLOG P Tie-in to K1 for a +5' correction. 7,875.0 7,898.0 21:36 21:48 12/15/2016 12/15/2016 1.80 COMPZ4 CASING TRIP P RIH to paint YELLOW EOP flag @ 7,898.0 69.0 21:48 23:36 8,010'. POOH. Paint WHITE EOP flag @ 6,500'. Cont POOH to surface. Tag -up, space out. 12/15/2016 12/16/2016 0.40 COMPZ4 CASING OWFF P Flow check. 69.0 69.0 23:36 00:00 12/16/2016 12/16/2016 0.40 COMPZ4 CASING OWFF P Flow check - good. Crew change. 69.0 69.0 00:00 00:24 12/16/2016 12/16/2016 0.80 COMPZ4 CASING PULD P PJSM - LD liner running BHA #21. 69.0 0.0 00:24 01:12 Noticed damaged coil -11' from coil connector. Similar to damage seen earlier on this well. 12/16/2016 12/16/2016 1.00 COMPZ4 WHDBOP BOPE P Function test BOP 0.0 0.0 01:12 02:12 12/16/2016 12/16/2016 3.90 COMPZ4 CASING PUTB P PJSM - Run upper liner section 0.0 1,536.0 02:12 06:06 consisting of ported bullnose, 50 slotted liner joints, 2 pup joints, and shorty deployment sleeve. Performed kick drill during liner running. Filled pipe every 5 joints. Page 23124 Report Printed: 12/30/2016 s { Operations Summary (with Timelog Depths) 2X-13 .. Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time our (hr) Phase Op Code Activity Code Time P-T-X Operation (W) End Depth (WEI) 12/16/2016 12/16/2016 1.00 COMPZ4 CASING PULD P Make up coil trac to liner, M/U to coil 1,536.0 1,586.3 06:06 07:06 and surface test 12/16/2016 12/16/2016 1.70 COMPZ4 CASING TRIP P RIH with L1-03 Upper liner segment, 1,586.3 8,083.0 07:06 08:48 EDC closed, Pumping min rate 12/16/2016 12/16/2016 0.10 COMPZ4 CASING DLOG P Tie into flag for +3.6' correction, 8,083.0 8,087.0 08:48 08:54 PUW=39K 12/16/2016 12/16/2016 0.40 COMPZ4 CASING TRIP P Continue in with liner, Stack out @ 8,087.0 9,420.0 08:54 09:18 9147, work past 12/16/2016 12/16/2016 0.50 COMPZ4 CASING DLOG P Attempt to tie into K1, make two 9,420.0 9,420.0 09:18 09:48 passes, stacking out at low speed 12/16/2016 12/16/2016 0.50 COMPZ4 CASING TRIP P Continue in with liner, work to bottom 9,420.0 9,697.0 09:48 10:18 @ 9697, PUW=45K, DHWOB=-6.8. Set back down 12/16/2016 12/16/2016 0.10 COMPZ4 CASING TRIP P Bring pumps online @ 1.5 BPM, PUH 9,697.0 8,149.0 10:18 10:24 and release from liner remove liner length left in hole from counters 12/16/2016 12/16/2016 2.00 COMPZ4 CASING DISP P Pump spacer pill followed by 8,149.0 8,149.0 10:24 12:24 seawater, recover 11.5 K-formate 12/16/2016 12/16/2016 2.50 COMPZ4 CASING TRIP P Start trip out of well. NOV injector tech 8,149.0 1,000.0 12:24 14:54 and ARP tech here to analyze injector for CT damages. 12/16/2016 12/16/2016 1.30 COMPZ4 CASING TRIP P RBIH to 2500 for freeze protect. LRS 1,000.0 2,500.0 14:54 16:12 online with 25 BBIs diesel, Tech still on injector 12/16/2016 12/16/2016 0.60 COMPZ4 CASING DISP P Trip out laying in FP from 2500' 2,500.0 50.0 16:12 16:48 12/16/2016 12/16/2016 1.70 COMPZ4 CASING PULD P At surface, PJSM, PUD BHA#22, L1- 50.0 50.0 16:48 18:30 03 upper liner running tools 12/16/2016 12/16/2016 1.00 COMPZ4 CASING PULD T DS PDL slickline parted when sucking 50.0 50.0 18:30 19:30 up the BHA, BHA fell to NoGo ring, slickline pulled out of the top of the pressurized lubricator allowing a small release of diesel (1/2 gal into secondary containment, 1/2 gal onto pad). Secured well, unstabbed DS PDL and swapped to ODS PDL. 12/16/2016 12/16/2016 1.50 COMPZ4 CASING PULD P Cont PUD BHA #22. 50.0 0.0 19:30 21:00 12/16/2016 12/16/2016 1.75 DEMOB WHDBOP CIRC P Flush BOP stack and chokes 0.0 0.0 21:00 22:45 thoroughly. Remove UQC checks. 12/16/2016 12/17/2016 1.25 DEMOB WHDBOP MPSP P RU lubricator, set BPV w SITP=550 0.0 0.0 22:45 00:00 psi below, RD lubricator. 12/17/2016 12/17/2016 3.00 DEMOB WHDBOP RURD P Rig down checklist. Blow down TT 0.0 0.0 00:00 03:00 line. Clean pits, remove remaining SW. SIMOPS: Clean up diesel on pad. 12/17/2016 12/17/2016 3.00 DEMOB WHDBOP NUND P Targeted T installation on BOP choke 0.0 0.0 03:00 06:00 line. ND BOP. 12/17/2016 12/17/2016 6.00 DEMOB MOVE MOB P Complete RD. Pull off well and Jeep 0.0 06:00 12:00 1 up - RIG RELEASE 12:00 Page 24/24 Report Printed: 12/30/2016 ,r ConocoPhillips ConocoPhillips (Alaska) Inc. -Kup2 Kuparuk River Unit Kuparuk 2X Pad 2X -13L1-03 50-029-21197-64 Baker Hughes INTEQ Definitive Survey Report 21 December, 2016 rIAbI BAKER HUGHES ConocoPhillips HIM ConocoPhillips HUGHES Definitive Survey Report Company: ConocoPhillips (Alaska) Inc. -Kup2 Local Co-ordinate Reference: Well 2X-13 Project: Kuparuk River Unit TVD Reference: 2X-13 @ 112.00usft (2X-13) Site: Kuparuk 2X Pad MD Reference: 2X-13 @ 112.00usft (2X-13) Well: 2X-13 North Reference: True Wellbore: 2X-1311-03 Survey Calculation Method: Minimum Curvature Design: 2X-1311-03 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 2X-13 Well Position -NI-S 0.00 usft Northing: 5,971,233.11 usft Latitude: 70° 19'57.263 N +E/ -W 0.00 usft Easting: 518,889.15usft Longitude: 1490 50'48.394 W Position Uncertainty 0.00 usft Wellhead Elevation: usft Ground Level: 0.00 usft Wellbore 2X-131-1-03 Magnetics Model Name Sample Date Declination Dip Angle Field Strength (nT) BGGM2016 12/112016 17.84 80.94 57,544 Design 2X-1311-03 " Audit Notes: Version: 1.0 Phase: ACTUAL Tie On Depth: 8,640.80 Vertical Section: Depth From (TVD) -NI-S +EI -W Direction (usft) (usft) (usft) n 112.00 0.00 0.00 135.00 Survey Program Date 12116/2016 From To Survey Survey (usft) (usft) Survey (Wellbore) Tool Name Description Start Date End Date 200.00 8,100.00 2X-13 (2X-13) GCT -MS Schlumberger GCT multishot 1/16/2001 8,159.00 8,640.80 2X-1311 (2X-131-1) MWD MWD - Standard 11/25/2016 11/29/2016 8,670.00 10,900.76 2X-1311-03(2X-1311-03)MWD MWD - Standard 12/11/2016 12/15/2016 1221!2016 5:32:44PM Page 2 COMPASS 5000.1 Build 74 ConocoPhillips ConocoPhillips Definitive Survey Report MAP kI KER HUGHES Company: ConocoPhillips (Alaska) Inc. -Kup2 Local Co-ordinate Reference: Well 2X-13 Map ProjectKuparuk River Unit ND Reference: 2X-13 @ 112.00usft (2X-13) Site: Kuparuk 2X Pad MD Reference: 2X-13 @ 112.00usft (2X-13) 7VD Well: 2X-13 North Reference: True Northing Wellbore: 2X-131-1-03 Survey Calculation Method: Minimum Curvature Annotation Design: 2X-131-1-03 Database: EDM Alaska NSK Sandbox Well) Survey Map Map Vertical MD Inc AxI 7VD TVDSS +N!-9 +El -W Northing Ea DLS Section Survey Tool Name Annotation (lastt) C) (°] Well) (t,srt) Writ)Writ)(usn) (n) ni Oil ("Mwi ltti 8,640.80 92.46 191.57 5,991.49 5,879.49 2,61947 4,475.67 5,973,863.58 523,357.77 9.63 1,312.53 MWD (2) TIP 8,670.00 93.25 194.34 5,990.04 5,878.04 2,591.05 4,469.14 5,973,835.15 523,351.30 9.85 1,328.01 MWD (3) KOP 8,700.42 98.74 194.54 5,986.86 5,874.86 2,561.77 4,461.60 5,973,805.85 523,343.84 18.06 1,343.38 MWD (3) 8,730.20 101.93 190.88 5,981.52 5,869.52 2,533.20 4,455.15 5,973,777.26 523,337.46 16.15 1,359.02 MWD (3) 8,759.97 102.19 187.18 5,975.29 5,863.29 2,504.45 4,450.58 5,973,748.51 523,332.97 12.19 1,376.12 MWD (3) 8,790.03 101.65 182.08 5,969.08 5,857.08 2,475.14 4,448.21 5,973,719.20 523,330.67 16.70 1,395.17 MWD (3) 81819.38 98.84 179.20 5,963.86 5,851.86 2,446.27 4,447.89 5,973,690.33 523,330.42 13.60 1,415.36 WD (3) 8,850.38 94.70 177.20 5,960.21 5,848.21 2,415.51 4,448.86 5,973,659.57 523,331.47 14.81 1,437.79 MWD (3) 8,880.41 89.69 173.91 5,959.06 5,847.06 2,385.61 4,451.18 5,973,629.68 523,333.87 19.95 1,460.58 MWD (3) I 8,909.95 89.82 169.30 5,959.18 5,847.18 2,356.39 4,45549 5,973,600.48 523,338.25 15.61 1,484.29 MWD (3) 8,940.63 90.61 165.77 5,959.07 5,847.07 2,326.44 4,462.12 5,973,570.55 523,344.95 11.79 1,510.15 MWD (3) 8,972.29 90.18 161.39 5,958.85 5,846.85 2,296.08 4,471.06 5,973,540.21 523,353.97 13.90 1,537.95 MWD (3) 8,999.92 88.59 157.80 5,959.15 5,847.15 2,270.19 4,480.69 5,973,514.35 523,363.67 14.21 1,563.06 MWD (3) - 9,030.03 88.37 159.97 5,959.94 5,847.94 2,242.11 4,491.54 5,973,486.30 523,374.58 7.24 1,590.58 MWD (3) 9,060.04 91.07 162.63 5,960.09 5,848.09 2,213.69 4,501.16 5,973,457.91 523,384.27 12.63 1,617.48 MWD (3) 9,090.50 90.12 166.08 5,959.77 5,847.77 2,184.37 4,509.37 5,973,428.61 523,392.55 11.75 1,644.02 MWD (3) 9,120.32 88.10 169.33 5,960.24 5,848.24 2,155.24 4,515.72 5,973,399.50 523,398.98 12.83 1,669.11 MWD (3) 9,145.34 88.99 172.31 5,960.87 5,848.87 2,130.55 4,519.71 5,973,374.82 523,403.03 12.43 1,689.39 MWD (3) 9,174.82 88.96 175.24 5,961.40 5,849.40 2,101.25 4,522.90 5,973,345.54 523,406.30 9.94 1,712.36 MWD (3) 9,205.25 90.46 179.22 5,961.55 5,849.56 2,070.87 4,524.37 5,973,315.16 523,407.84 13.98 1,734.89 MWD (3) 9,235.04 90.61 181.53 5,961.26 5,849.28 2,041.08 4,524.18 5,973,285.37 - 523,407.72 7.77 1,755.81 MWD (3) 9,265.16 90.18 184.87 5,961.07 5,849.07 2,011.01 4,522.50 5,973,255.30 523,406.12 11.18 1,775.89 MWD (3) 9,296.76 90.21 188.65 5,960.96 5,848.96 1,979.64 4,518.78 5,973,223.92 523,402.48 11.96 1,795.44 MWD (3) 9,326.50 92.67 192.42 5,960.21 5,848.21 1,950.42 4,513.34 5,973,194.69 523,397.12 15.13 1,812.26 MWD (3) 9,358.28 95.14 190.85 5,958.05 5,846.05 1,919.36 4,506.95 5,973,163.63 523,390.80 9.20 1,829.70 MWD (3) 9,394.52 95.51 188.37 5,954.69 5,842.69 1,883.79 4,500.93 5,973,128.04 523,384.87 6.89 1,650.59 MWD (3) 9,420.05 92.77 187.16 5,952.84 5,840.84 1,858.56 4,497.49 5,973,102.81 523,38149 11.73 1,866.00 MWD (3) 9,446.20 90.03 185.24 5,952.20 5,840.20 1,832.58 4,494.66 5,973,076.82 523,378.74 12.79 1,882.38 MWD (3) 9,478.16 87.48 185.08 5,952.90 5,84090 1,800.76 4,491.79 5,973,044.99 523,375.94 7.99 1,902.85 MWD(3) 9,507.89 85.21 180.56 5,954.79 5,842.79 1,771.13 4,490.33 5,973,015.37 523,374.56 16.98 1,922.76 MWD (3) 12/212016 5:32:44PM Page 3 COMPASS 5000.1 Build 74 ConocoPhillips r?,isI ConocoPhillipsDefinitive HUGHES Survey Report Company: ConocoPhillips (Alaska) Inc. -Kup2 Local Co-ordinate Reference: Well 2X-13 Project: Kuparuk River Unit TVD Reference: 2X-13 @ 112.00usft (2X-13) Site: Kuparuk 2X Pad MD Reference: 2X-13 @ 112.00usft (2X-13) Well: 2X-13 North Reference: True Wellbore: 2X-131-1-03 Survey Calculation Method: Minimum Curvature Design: 2X-131-1-03 Database: EDM Alaska NSK Sandbox Survey Map Map Vertical MD Inc Azi TVD TVDSS +W3 +El•W Northing Earth g DLS Section Survey Tool Name Annotation ( (haft) (:1) (°) (usft) (usft) (usft) (usft) (n) (n) V1100') (ft) 9,535.94 84.16 176.95 5,957.39 5,845.39 1,743.22 4,490.93 5,972,98745 523,375.23 13.35 1,942.93 MWD (3) 9,565.00 84.07 173.03 5,960.37 5,848.37 1,714.42 4,493.46 5,972,958.67 523,377.83 13.42 1,965.07 MWD(3) 9,595.05 85.05 169.88 5,963.22 5,851.22 1,684.85 4,497.90 5,972,929.11 523,382.35 10.93 1,989.13 MWD (3) ' 9,624.70 84.56 167.21 5,965.91 5,853.91 1,655.91 4,503.77 5,972,900.19 523,388.28 9.12 2,013.74 MWD (3) ' 9,656.52 85.85 164.48 5,968.57 5,856.57 1,625.17 4,511.52 5,972,869.47 523,396.12 9.46 2,040.96 MWD (3) 9,681.48 87.39 161.75 5,970.04 5,858.04 1,601.33 4,518.76 5,972,845.65 523,403.41 12.54 2,062.93 MWD (3) 9,710.99 88.53 158.70 5,971.09 5,859.09 1,573.58 4,528.73 5,972,817.93 - 523,413.46 11.03 2,089.61 MWD (3) 9,743.90 86.53 155.98 5,972.51 5,860.51 1,543.24 4,541.40 5,972,787.63 523,426.20 1025 2,120.02 MWD (3) 9,770.44 87.24 152.98 5,973.95 5,861.95 1,519.33 4,552.82 5,972,763.75 523,437.67 11.60 2,145.00 MWD (3) 9,795.92 87.39 150.69 5,975.15 5,863.15 1496,89 4,564.83 5,972,741.34 523,449.74 9.00 2,169.36 MWD (3) 9,825.20 87.45 146.31 5,976.47 5,864.47 1,471.96 4,580.11 5,972,716.45 523,465.08 14.95 2,197.79 MWD (3) 9,854.97 88.07 144.22 5,977.63 5,865.63 1,447.51 4,597.06 5,972,692.05 523,482.09 7.32 2,227.06 MWD (3) 9,885.56 89.60 142.12 5,978.25 5,866.25 1,423.04 4,615.39 5,972,667.62 523,500.48 8.49 2,257.33 MWD (3) 9,920.43 91.26 139.19 5,977.99 5,865.99 1,396.08 4,637.49 5,972,640.72 523,522.65 9,66 2,292.03 MWD (3) 9,950.72 91.38 136.02 5,977.29 5,865.29 1,373.71 4,657.91 5,972,618.41 523,543.12 10.47 2,322.27 MWD (3) 9,981.22 89.60 133.95 5,977.03 5,865.03 1,352.16 4,679.48 5,972,596.91 523564.74 8.95 2,352.77 MWD (3) ' 10,010.26 92.85 132.18 5,976.41 5,864.41 1,332.33 4,700.68 5,972,577.14 523,585.99 12.74 2,381.78 MWD (3) 10,035.52 95.41 130.74 5,974.59 5,862.59 1,315.65 4,719.56 5,972,560.51 523,604.91 11.62 2,406.93 MWD (3) 10,065.39 93.56 128.27 5,972.25 5,860.25 1,296.71 4,742.54 5,972,541.63 523,627.93 10.31 2,436.56 MWD (3) 10,090.66 93.31 125.93 5,970.74 5,858.74 1,281.50 4,762.65 5,972,526.47 523,648.09 9.30 2,461.55 MWD (3) 10,120.54 94.97 122.44 5,968.58 5,856.58 1,264.76 4,787.30 5,972,509.79 523,672.77 12.91 2,490.81 MWD(3) d, 10,145.05 94.45 119.84 5,966.57 5,854.57 1,252.13 4,808.21 5,972,497.22 523,693.71 10.78 2,514.53 MWD (3) Yt 10,176.90 92.39 118.04 5,964.67 5,852.67 1,236.74 4,636.03 5,972,481.90 523,721.57 8.58 2,545.08 MWD (3) 10,208.99 88.56 116.73 5,964.40 5,85240 1,221.99 4,864.51 5,972,467.22 523,750.09 12.61 2,575.66 MWD (3) 10,236.08 84.90 116.07 5,965.95 5,853.95 1,209.96 4,888.73 5,972,455.26 523,774.34 13.73 2,601.28 MWD (3) 10,267.32 85.30 112.79 5,968.62 5,856.62 1,197.09 4,917.07 5,972,442.46 523,802.70 10.54 2,630.42 MWD (3) 10,296,30 84.63 109.79 5,971.16 5,859.16 1,186.61 4,943.96 5,972,432.05 523,829.62 10.57 2,656.85 MWD (3) 10,330.66 86.13 106.49 5,973.93 5,861.93 1,175.95 4,976.51 5,972,421.47 523,862.18 10.52 2,687.40 MWD (3) 10,356.24 86.59 103.10 5,975.55 5,863.55 1,169.43 5,001.18 5,972,415.02 523,886.88 13.35 2,709.46 MWD (3) 10,386.16 86.90 100.30 5,977.25 5,865.25 1,163.38 5,030.43 5,972,409.03 523,916.14 9.40 2,734.42 MWD (3) 10,420.45 87.39 97.79 5,978.96 5,866.96 1,15799 5,064.25 5,972,403.74 523,949.96 7.45 2,762.14 MWD (3) 1221/2016 6:32:44PM Page 4 COMPASS 5000.1 Build 74 Survey ConocoPhillips /GGA ConocoPhillips Definitive Survey Report HUGHES Company: ConocoPhillips (Alaska) Inc. -Kup2 Local Co-ordinate Reference: Well 2X-13 MD Project. Kuparuk River Unit TVD Reference: 2X-13 @ 112.00usft (2X-13) TVDSS Site: Kuparuk 2X Pad MD Reference 2X-13 @ 112.00usft (2X-13) East) Well: 2X-13 North Reference. True (1 Wellbore: 2X-131-1-03 Survey Calculation Method: Minimum Curvature (usft) Design: 2X-131-1-03 Database. EDM Alaska NSK Sandbox (on00.) Survey 12212016 5.32:44PM Page 5 COMPASS 5000.1 Build 74 Map Map Vertical MD Inc Axi TVD TVDSS +NlS +E/ -W Northing East) DLS Section n gutveyToolName Annotation. (ustt) (1 (°) (usft) (usft) (usft) (usft) (on00.) 10,450.22 89.48 95.97 5,979.77 5,867.77 1,154.43 5,093.79 5,972,400.25 523,979.51 9.31 2,785.55 MWD(3) 10,480.48 89.85 94.29 5,979.95 5,867.95 1,151.72 5,123.93 5,972,397.62 524,009.65 5.68 2,808.77 MWD (3) 10,510.48 91.56 96.70 5,979.58 5,867.58 1,148.85 5,153.79 5,972,394.82 524,039.51 9.85 2,831.92 MWD (3) i 10,540.69 93.84 98.79 5,978.16 5,866.16 1,144.79 5,183.68 5,972,390.83 524,06942 10.23 2,855.93 MWD (3) 10,571.76 96.76 99.05 5,975.29 5,863.29 1,139.99 5,214.24 5,972,386.11 524,099.99 9.43 2,880.93 MWD (3) 10,602,20 96.21 102.04 5,971.85 5,859.85 1,134.45 5,243.97 5,972,380.65 524,129.73 9.93 2,905.87 MWD (3) ( 10,632.61 94.23 104.05 5,969.08 5,857.08 1,127.62 5,273.47 5,972,373.89 524,159.24 9.26 2,931.56 MWD (3) Y 10,662.97 91.93 105.30 5,967.45 5,855.45 1,119.94 5,302.80 5,972,366.29 524,188.58 8.62 2,957.73 MWD (3) 10,691.74 90.92 10249 5,966.74 5,854.74 1,111.82 5,330.39 5,972,358.24 524,216.19 8.38 2,982.98 MWD (3) 10,722.41 90.95 110.67 5,966.24 5,854.24 1,101.80 5,359.37 5,972,348.29 524,245.19 10.37 3,010.55 M.(3) $ 10,752.76 91.50 113.14 5,965.59 5,853.59 1,090.48 5,387.52 5,972,337.04 524,273.37 8.34 3,038.46 MWD (3) 10,783.22 91.20 116.22 5,964.87 5,852.87 1,077.77 5,415.18 5,972,324.40 524,301.06 10.16 3,067.02 MWD (3) 10,816.75 92.28 119.39 5,963.85 5,851.85 1,062.14 5,444.82 5,972,308.85 524,330.74 9.98 3,099.03 MWD (3) 10,842.36 93.60 121.09 5,962.54 5,850.54 1,049.26 5,466.92 5,972,296.02 524,352.86 8.40 3,123.76 MWD (3) 10,871.76 94.86 123.68 5,960.37 5,848.37 1,033.55 5,491.67 5,972,280.39 524,377.66 9.77 3,152.37 MWD(3) 10,900.76 95.81 126.77 5,957.67 5,845.67 1,016.90 5,515.26 5,972,263.79 524,401.28 11.10 3,180.82 MWD (3) 10,952.00 95.81 126.77 5,952.49 5,84049 986.39 5,556.09 5,972,233.39 524,442.19 0.00 3,231.27 PROJECTED to TO 12212016 5.32:44PM Page 5 COMPASS 5000.1 Build 74 ",1ECIE JAN 0 6 2017 Fe FIG --AO%..� (3A Ce Cf -- BAKER Date: December 22, 2016 HUGHES To Makana Bender AOGCC 333 West 7" Ave, Suite 100 Anchorage, Alaska 99501 Letter of Transmittal DATA LOGGED V/R.Q/201 -j M K. BENDER 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): 2X -13L1 2 1 61 14 27 85 8 2X -13L1-01 2X -13L1-02 2 1 6 1 1 55 27 85 9 2X -13L1-03 21 61 16 27 86 0 j 21 61 18 2786 1 (4) Total prints I Enclosed for each well(s): 1 hardcopy print of directional survey reports (NAD27) 1 compact disk containing electronic survey files Note: Please feel free to send us an email in place of return mail. Michael Soper, Baker Hughes, Project Engineer Michael.Soper@BakerHughes.com Yosha Ragbirsingh, Baker Hughes, Survey Manager Yosha.Ragbirsingh@BakerHughes.com ConocoPhilli s p OGC' P ConocoPhillips (Alaska) Inc. -Kup2 Kuparuk River Unit Kuparuk 2X Pad 2X -13L1-03 50-029-21197-64 Baker Hughes I NTEQ Definitive Survey Report 21 December, 2016 21 61 18 27 86 1 WE FA I BAKER HUGHES - ConocoPhillips M/kv ConocoPhillips Definitive Survey Report HUGHES Company: ConocoPhillips (Alaska) Inc. -Kup2 Local Co-ordinate Reference: Well 2X-13. Project: Kuparuk River Unit TVD Reference: 2X-13 @ 112.00usft (2X-13) Site: Kuparuk 2X Pad MD Reference: 2X-13 @ 112,00usft (2X-13) Well: 2X-13 North Reference: True Wellbore: 2X-131-1-03 Survey Calculation Method: Minimum Curvature Design: 2X-131-1-03 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 2X-13 Well Position +N/ -S 0.00 usft Northing: 5,971,233.11 usft Latitude: 700 19' 57.263 N +E/ -W 0.00 usft Easting: 518,889.15 usft Longitude: 1490 50'48.394 W Position Uncertainty 0.00 usft Wellhead Elevation: usft Ground Level: 0.00 usft ) Wellbore 2X-131-1-03 Magnetics Model Name Sample Date Declination Dip Angle Field Strength (°) (°) (nT) BG G M 2016 12/1/2016 17.84 80.94 57,544 Design 2X-1311-03 Audit Notes: Version: 1.0 Phase: ACTUAL Tie On Depth: 8,640.80 Vertical Section: Depth From (TVD) +N/ -S +E/ -W Direction (usft) (usft) (usft) (I 112.00 0.00 0.00 135.00 Survey Program Date 12/16/2016 From To Survey Survey (usft) (usft) Survey (Wellbore) Tool Name Description Start Date End Date 200.00 8,100.00 2X-13 (2X-13) GCT -MS Schlumberger GCT multishot 1/16/2001 8,159.00 8,640.80 2X-1311 (2X-131-1) MWD MWD - Standard 11/25/2016 11/29/2016 8,670.00 10,900.76 2X-131-1-03 (2X-1311-03) MWD MWD - Standard 12/11/2016 12/15/2016 COMPASS 5000.1 Build 74 12/21/2016 5:32:44PM Page 2 ConocoPhillips Raw ConocoPhillips Definitive Survey Report HUGHES Company: ConocoPhillips (Alaska) Inc. -Kup2 Local Co-ordinate Reference: Well 2X-13 Project: Kuparuk River Unit TVD Reference: 2X-13 @ 112.00usft (2X-13) Site: Kuparuk 2X Pad MD Reference: 2X-13 @ 112.00usft (2X-13) Well: 2X-13 North Reference: True Wellbore: 2X-131-1-03 Survey Calculation Method: Minimum Curvature Design: 2X-131-1-03 Database: EDM Alaska NSK Sandbox Survey MD Inc Azi TVD TVDSS +N/ -S +E/ -W Map Map DLS Vertical (usft) (1 (1) (usft) (usft) (usft) (usft) Northing Easting (%100') Section Survey Tool Name Annotation Y (ft) (ft) (ft) 8,640.80 92.46 191.57 5,991.49 5,879.49 2,619.47 4,475.67 5,973,863.58 523,357.77 9.63 1,312.53 MWD (2) TIP 18,670.00 93.25 194.34 5,990.04 5,878.04 2,591.05 4,469.14 5,973,835.15 523,351.30 9.85 1,328.01 MWD (3) KOP 1 8,700.42 i 98.74 194.54 5,986.86 5,874.86 2,561.77 4,461.60 5,973,805.85 523,343.84 18.06 1,343.38 MWD (3) 8,730.20 101.93 190.88 5,981.52 5,869.52 2,533.20 4,455.15 5,973,777.26 523,337.46 16.15 1,359.02 MWD (3) 8,759.97 102.19 187.18 5,975.29 5,863.29 2,504.45 4,450.58 5,973,748.51 523,332.97 12.19 1,376.12 MWD (3) 8,790.03 101.65 18208 5,969.08 5,857.08 2,475.14 4,448.21 5,973,719.20 523,330.67 16.70 1,395.17 MWD (3) 8,819.38 98.84 179.20 5,963.86 5,851.86 2,446.27 4,447.89 5,973,690.33 523,330.42 13.60 1,415.36 MWD (3) i 8,850.38 94.70 177.20 5,960.21 5,848.21 2,415.51 4,448.86 5,973,659.57 523,331.47 14.81 1,437.79 MWD (3) ". 8,880.41 89.69 173.91 5,959.06 5,847.06 2,385.61 4,451.18 5,973,629.68 523,333.87 19.95 1,460.58 MWD (3) 8,909.95 89.82 169.30 5,959.18 5,847.18 2,356.39 4,455.49 5,973,600.48 523,338.25 15.61 1,484.29 MWD (3) s 8,940.63 S 90.61 165.77 5,959.07 5,847.07 2,326.44 4,462.12 5,973,570.55 523,344.95 11.79 1,510.15 MWD (3) 8,972.29 90.18 161.39 5,958.85 5,846.85 2,296.08 4,471.06 5,973,540.21 523,353.97 13.90 1,537.95 MWD (3) 8,999.92 88.59 157.80 5,959.15 5,847.15 2,270.19 4,480.69 5,973,514.35 523,363.67 14.21 1,563.06 MWD (3) x 9,030.03 88.37 159.97 5,959.94 5,847.94 2,242.11 4,491.54 5,973,486.30 523,374.58 7.24 1,590.58 MWD (3) 9,060.04 91.07 162.63 5,960.09 5,848.09 2,213.69 4,501.16 5,973,457.91 523,384.27 12.63 1,617.48 MWD (3) k 9,090.50 90.12 166.08 5,959.77 5,847.77 2,184.37 4,509.37 5,973,428.61 523,392.55 11.75 1,644.02 MWD (3) 1 9,120.32 88.10 169.33 5,960.24 5,848.24 2,155.24 4,515.72 5,973,399.50 523,398.98 12.83 1,669.11 MWD (3) 9,145.34 i 88.99 172.31 5,960.87 5,848.87 2,130.55 4,519.71 5,973,374.82 523,403.03 12.43 1,689.39 MWD (3) 9,174.82 88.96 175.24 5,961.40 5,849.40 2,101.25 4,522.90 5,973,345.54 523,406.30 9.94 1,712.36 MWD (3) 9,205.25 90.46 179.22 5,961.55 5,849.56 2,070.87 4,524.37 5,973,315.16 523,407.84 13.98 1,734.89 MWD (3) 9,235.04 90.61 181.53 5,961.28 5,849.28 2,041.08 4,524.18 5,973,285.37 523,407.72 7.77 1,755.81 MWD (3) 9,265.16 90.18 184.87 5,961.07 5,849.07 2,011.01 4,522.50 5,973,255.30 523,406.12 11.18 1,775.89 MWD (3) 9,296.76 90.21 188.65 5,960.96 5,848.96 1,979.64 4,518.78 5,973,223.92 523,402.48 11.96 1,795.44 MWD (3) s ) 9,326.50 92.67 192.42 5,960.21 5,848.21 1,950.42 4,513.34 5,973,194.69 523,397.12 15.13 1,812.26 MWD (3) 9,358.28 95.14 190.85 5,958.05 5,846.05 1,919.36 4,506.95 5,973,163.63 523,390.80 9.20 1,829.70 MWD (3) 9,394.52 95.51 188.37 5,954.69 5,842.69 1,883.79 4,500.93 5,973,128.04 523,384.87 6.89 1,850.59 MWD (3) 9,420.05 92.77 187.16 5,952.84 5,840.84 1,858.56 4,497.49 5,973,102.81 523,381.49 11.73 1,866.00 MWD (3) 9,446.20 90.03 185.24 5,952.20 5,840.20 1,832.58 4,494.66 5,973,076.82 523,378.74 12.79 1,882.38 MWD (3) 9,478.16 8248 185.08 5,952.90 5,840.90 1,800.76 4,491.79 5,973,044.99 523,375.94 7.99 1,902.85 MWD (3) 9,507.89 85.21 16056 5,954.79 5,84279 1,771.13 4490.33 5,973,015.37 523,374.56 16.98 1,922.76 MWD (3) ; 1212112016 5:32:44PM Page 3 COMPASS 5000.1 Build 74 ConocoPhillips Company: Project: Site: Well: Wellbore: Design: Survey ConocoPhillips (Alaska) Inc. -Kup2 Kuparuk River Unit Kuparuk 2X Pad 2X-13 2X-131-1-03 2X-131-1-03 MD Inc Azi TVD TVDSS +Nl-S (usft) (1 (1) (usft) (usft) (usft) 9,535.94 84.16 176.95 5,957.39 5,845.39 1,743.22 9,565.00 84.07 173.03 5,960.37 5,848.37 1,714.42 9,595.05 85.05 169.88 5,963.22 5,851.22 1,684.85 9,624.70 84.56 167.21 5,965.91 5,853.91 1,655.91 9,656.52 85.85 164.48 5,968.57 5,856.57 1,625.17 9,681.48 87.39 161.75 5,970.04 5,858.04 1,601.33 9,710.99 88.53 158.70 5,971.09 5,859.09 1,573.58 9,743.90 86.53 155.98 5,972.51 5,860.51 1,543.24 9,770.44 87.24 152.98 5,973.95 5,861.95 1,519.33 9,795.92 87.39 150.69 5,975.15 5,863.15 1,496.89 9,825.20 87.45 146.31 5,976.47 5,864.47 1,471.96 9,854.97 88.07 144.22 5,977.63 5,865.63 1,447.51 9,885.56 89.60 142.12 5,978.25 5,866.25 1,423.04 9,920.43 91.26 139.19 5,977.99 5,865.99 1,396.08 9,950.72 91.38 136.02 5,977.29 5,865.29 1,373.71 9,981.22 89.60 133.95 5,977.03 5,865.03 1,352.16 10,010.26 92.85 132.18 5,976.41 5,864.41 1,332.33 10,035.52 95.41 130.74 5,974.59 5,862.59 1,315.65 10,065.39 93.56 128.27 5,972.25 5,860.25 1,296.71 10,090.66 93.31 125.93 5,970.74 5,858.74 1,281.50 10,120.54 94.97 122.44 5,968.58 5,856.58 1,264.76 10,145.05 94.45 119.84 5,966.57 5,854.57 1,252.13 10,176.90 92.39 118.04 5,964.67 5,852.67 1,236.74 10,208.99 88.56 116.73 5,964.40 5,852.40 1,221.99 10,236.08 84.90 116.07 5,965.95 5,853.95 1,209.96 10,267.32 85.30 112.79 5,968.62 5,856.62 1,197.09 10,296.30 84.63 109.79 5,971.16 5,859.16 1,186.61 10,330.66 86.13 106.49 5,973.93 5,861.93 1,175.95 10,356.24 86.59 103.10 5,975.55 5,863.55 1,169.43 10,386.16 86.90 100.30 5,977.25 5,865.25 1,163.38 10,420.45 87.39 97.79 5,978.96 5,866.96 1,157.99 12/21/2016 5:32:44PM ConocoPhillips Definitive Survey Report Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Database: ®lily BAKER HUGHES Well 2X-13 2X-13 @ 112.00usft (2X-13) 2X-13 @ 112.00usft (2X-13) True Minimum Curvature EDM Alaska NSK Sandbox Page 4 Annotation COMPASS 5000.1 Build 74 Map Map Vertical +E/ -W (usft) Northing Easting DLS Section Survey Tool Name y (ft) (ft) (°/100') (ft)_ 4,490.93 5,972,987.45 523,375.23 13.35 1,942.93 MWD (3) 4,493.46 5,972,958.67 523,377.83 13.42 1,965.07 MWD (3) 4,497.90 5,972,929.11 523,382.35 10.93 1,989.13 MWD (3) 4,503.77 5,972,900.19 523,388.28 9.12 2,013.74 MWD (3) 4,511.52 5,972,869.47 523,396.12 9.46 2,040.96 MWD (3) 4,518.76 5,972,845.65 523,403.41 12.54 2,062.93 MWD (3) 4,528.73 5,972,817.93 523,413.46 11.03 2,089.61 MWD (3) 4,541.40 5,972,787.63 523,426.20 10.25 2,120.02 MWD (3) 4,552.82 5,972,763.75 523,437.67 11.60 2,145.00 MWD (3) 4,564.83 5,972,741.34 523,449.74 9.00 2,169.36 MWD (3) 4,580.11 5,972,716.45 523,465.08 14.95 2,197.79 MWD (3) 4,597.06 5,972,692.05 523,482.09 7.32 2,227.06 MWD (3) 4,615.39 5,972,667.62 523,500.48 8.49 2,257.33 MWD (3) 4,637.49 5,972,640.72 523,522.65 9.66 2,292.03 MWD (3) 4,657.91 5,972,618.41 523,543.12 10.47 2,322.27 MWD (3) 4,679.48 5,972,596.91 523,564.74 8.95 2,352.77 MWD (3) 4,700.68 5,972,577.14 523,585.99 12.74 2,381.78 MWD (3) 4,719.56 5,972,560.51 523,604.91 11.62 2,406.93 MWD (3) 4,742.54 5,972,541.63 523,627.93 10.31 2,436.56 MWD (3) 4,762.65 5,972,526.47 523,648.09 9.30 2,461.55 MWD (3) 4,787.30 5,972,509.79 523,672.77 12.91 2,490.81 MWD (3) 4,808.21 5,972,497.22 523,693.71 10.78 2,514.53 MWD (3) 4,836.03 5,972,481.90 523,721.57 8.58 2,545.08 MWD (3) 4,864.51 5,972,467.22 523,750.09 12.61 2,575.66 MWD (3) 4,888.73 5,972,455.26 523,774.34 13.73 2,601.28 MWD (3) 4,917.07 5,972,442.46 523,802.70 10.54 2,630.42 MWD (3) 4,943.96 5,972,432.05 523,829.62 10.57 2,656.85 MWD (3) 4,976.51 5,972,421.47 523,862.18 10.52 2,687.40 MWD (3) 5,001.18 5,972,415.02 523,886.88 13.35 2,709.46 MWD (3) 5,030.43 5,972,409.03 523,916.14 9.40 2,734.42 MWD (3) 5,064.25 5,972,403.74 523,949.96 7.45 2,762.14 MWD (3) Page 4 Annotation COMPASS 5000.1 Build 74 ConocoPhillips .fAke ConocoPhillips Definitive Survey Report BAKER Company: ConocoPhillips (Alaska) Inc. -Kup2 Local Co-ordinate Reference: Well 2X-13 i b Project: Kuparuk River Unit TVD Reference: 2X-13 @ 112.00usft (2X-13) Site: Kuparuk 2X Pad MD Reference: 2X-13 @ 112.00usft (2X-13) Well: 2X-13 North Reference: True Wellbore: 2X-131-1-03 Survey Calculation Method: Minimum Curvature Design: 2X-131-1-03 Database: EDM Alaska NSK Sandbox 1 Survey MD Inc Azi TVD TVDSS +N/ -S +E/ -W Map Map Vertical (usft) V) (1) (usft) (usft) (usft) (usft) Northing East) (o�00) Section Survey Tool Name Annotation 10;450.22 89.48 95.97 5,979.77 5,867.77 1,154.43 5,093.79 5,972,400.25 523,979.51 9.31 2,785.55 MWD (3) 10,480.48 89.85 94.29 5,979.95 5,867.95 1,151.72 5,123.93 5,972,397.62 524,009.65 5.68 2,808.77 MWD (3) 10,510.48 91.56 96.70 5,979.58 5,867.58 1,148.85 5,153.79 5,972,394.82 524,039.51 9.85 2,831.92 MWD (3) 10,540.69 93.84 98.79 5,978.16 5,866.16. 1,144.79 5,183.68 5,972,390.83 524,069.42 10.23 2,855.93 MWD (3) 10,571.76 96.76 99.05 5,975.29 5,863.29 1,139.99 5,214.24 5,972,386.11 524,099.99 9.43 2,880.93 MWD (3) 10,602.20 96.21 102.04 5,971.85 5,859.85 1,134.45 5,243.97 5,972,380.65 524,129.73 9.93. 2,905.87 MWD (3) 10,632.61 94.23 104.05 5,969.08 5,857.08 1,127.62 5,273.47 5,972,373.89 524,159.24 9.26 2,931.56 MWD (3) 10,662.97 91.93 105.30 5,967.45 5,855.45 1,119.94 5,302.80 5,972,366.29 524,188.58 8.62 2,957.73 MWD (3) 10,691.74 90.92 107.49 5,966.74 5,854.74 1,111.82 5,330.39 5,972,358.24 524,216.19 8.38 2,982.98 MWD (3) 10,722.41 90.95 110.67 5,966.24 5,854.24 1,101.80 5,359.37 5,972,348.29 524,245.19 10.37 3,010.55 MWD (3) 10,752.76 91.50 113.14 5,965.59 5,853.59 1,090.48 5,387.52 5,972,337.04 524,273.37 8.34 3,038.46 MWD (3) i 10,783.22 91.20 116.22 5,964.87 5,852.87 1,077.77 5,415.18 5,972,324.40 524,301.06 10.16 3,067.02 MWD (3) p 10,816.75 92.28 119.39 5,963.85 5,851.85 1,062.14 5,444.82 5,972,308.85 524,330.74 9.98 3,099.03 MWD (3) 10,842.36 93.60 121.09 5,962.54 5,850.54 1,049.26 5,466.92 5,972,296.02 524,352.86 8.40 3,123.76 MWD (3) 10,871.76 94.86 123.68 5,960.37 5,848.37 1,033.55 5,491.67 5,972,280.39 524,377.66 9.77 3,152.37 MWD (3) 10,900.76 95.81 126.77 5,957.67 5,845.67 1,016.90 5,515.26 5,972,263.79 524,401.28 11.10 3,180.82 MWD (3) 10,952.00 95.81 126.77 5,952.49 5,840.49 986.39 5,556.09 5,972,233.39 524,442.19 0.00 3,231.27 PROJECTED to TD 12/21/2016 5.,32:44PM Page 5 COMPASS 5000.1 Build 74 THE NATE oz-,LASKAf GOVERNOR BILL WALKER J. Ohlinger CTD Engineering Supervisor ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510-0360 Alaska Oil and Gas Conservation 1 Re: Kuparuk River Field, Kuparuk River Oil Pool, KRU 2X-13 L 1-03 ConocoPhillips Alaska, Inc. Permit to Drill Number: 216-118 Surface Location: 1229' FSL, 238' FEL, Sec. 4, TI IN, R9E, UM Bottomhole Location: 2131' FSL, 5258' FEL, Sec. 2, TI IN, R9E, UM Dear Mr. Ohlinger: 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 www.aogcc.alaska.gov Enclosed is the approved application for permit to drill the above referenced development well. The permit is for a new wellbore segment of existing well Permit No. 184-174, API No. 50-029- 21197-00-00. 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, Cathy P. Foerster Chair DATED this Y day of September, 2016. STATE OF ALASKA AL .A OIL AND GAS CONSERVATION COMMI, JN PERMIT TO DRILL 20 AAC 25.005 Hk:k;taYGLJ SEP 082016 0G Cf 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 ❑✓ , Coalbed Gas ❑ Gas Hydrates ❑ Redrill ❑ Reentry ❑ Exploratory - Oil ❑ Development - Gas ❑ Service - Supply ❑ Multiple Zone ❑ Geothermal ❑ Shale Gas ❑ 2. Operator Name: 5. Bond: Blanket ❑ Single Well ❑ 11. Well Name and Number: ConocoPhillips Alaska Inc Bond No. 59-52-180 KRU 2X-131_1-03 3. Address: 6. Proposed Depth: 12. Field/Pool(s): P.O. Box 100360 Anchorage, AK 99510-0360 MD: 11,050' 1 TVD: 5,970' Kuparuk River Field Kuparuk Oil Pool 4a. Location of Well (Governmental Section): 7. Property Designation (Lease Number): Surface: 1229' FSL, 238' FEL, Sec. 4, T11 N, R9E, UM ADL 25645 X4 (o Top of Productive Horizon: 8. Land Use Permit: 13. Approximate Spud Date: 3782' FSL, 1055' FEL, Sec. 3, T11 N, R9E, UM ALK 2576 11/1/2016 9. Acres in Property: 14. Distance to Nearest Property: Total Depth: 2131' FSL, 5258' FEL, Sec. 2, T11N, R9E, UM 2560 as(� 35,376' 4b. Location of Well (State Base Plane Coordinates - NAD 27): 10. KB Elevation above MSL (ft): 112 15. Distance to Nearest Well Open Surface: x- 518889 y- 5,971,233 Zone- 4 GL Elevation above MSL (ft): 77 to Same Pool: 2X-14, 1290' 16. Deviated wells: Kickoff depth: 8,800 feet 17. Maximum Potential Pressures in psig (see 20 AAC 25.035) Maximum Hole Angle: 102° degrees Downhole: 2,670 psig , Surface: 2,066 psig 18. Casing Program: Specifications Top - Setting Depth - Bottom Cement Quantity, c.f. or sacks Hole Casing Weight Grade Coupling Length MD TVD MD TVD (including stage data) 3" 2.375" 4.7# L-80 ST -L 2,300' 8,750' 5,999' 11,050' 5,970' 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): 8,539' 6,187' none 8,428' 6,108' 8,428' Casing Length Size Cement Volume MD TVD Conductor/Structural 66' 16" 260 sx Cold set II 103' 103' Surface 3,711' 9-5/8" 900 sx CS III & 650 sx CS II 3,747' 3,030' Production 8,476' 7" 315 sx Class G 8,510' 6,163' Perforation Depth MD (ft): 7970'-8060', 8214'-8240', 8248'-8288' Perforation Depth TVD (ft): 5779'-5845', 5956'-5975', 5981'-6009' 7719'-7729' 20. Attachments: Property Plat ❑ BOP Sketch ❑ Drilling Program ❑✓ Time v. Depth Plot ❑ Shallow Hazard Analysis❑ Diverter Sketch ❑ Seabed Report ❑ Drilling Fluid Program ❑� 20 AAC 25.050 requirements 21. Verbal Approval: Commission Representative: Date 9/1 1 b 22. 1 hereby certify that the foregoing is true and the procedure approved herein will not R. Phillips @265-6312 Contact be deviated from without prior written approval. Email ron.l.phillipspcop.com Printed Name J.Ohlinger Title CTD Engineering Supervisor Signature Phone 265-1102 Date Commission Use Only Permit to Drill API Number: I Permit Approval See cover letter for other Number: ` — 1 50-Q I-- —6{ 00 Date: q _2_?>—' 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: O bh frs f O 30 C 0 9 Samples req'd: YesE] No4 Mud log req'd: Yes❑/ NoZ HzS measures: Yes No ❑ Directional svy req'd: Yes [ti/I No ❑ U Yes ❑ No Spacing exception req'd: Yes ❑ Nod Inclination -only svy req'd: 5 Post initial injection MIT req'd: Yes ❑ No 1 l�LCICo rjOLYy� to be Q12� 1Jbi`Hf a�JrviC� tL1L /�4✓tv�� ZR/�a�C / V APPROVED BY Date: Approved by:41 COMMISSIONER THE COMMISSION _23 J �� 9R d 1 /2 15) Pi+t5v1liNrArrLnths Submit Form and Form 10,401 (�vys� I �p15) from the date of approval (20 AAC 25.005(8)) Attachments in Duplicate ConocoPhillips p Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 September 7, 2016 Commissioner - State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Dear Commissioner: SEP 082016 AOGCC ConocoPhillips Alaska, Inc. hereby submits applications for permits to drill six laterals out of the newly worked over Kuparuk well 2X-13 well using the coiled tubing drilling rig, Nabors CDR2-AC or Nabors CDR3-AC. 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 November 3, 2016. The objective will be to drill laterals KRU 2X-131-1, 2X-131-1- 01, 2X-131-1-02, 2X-131-1-03, 2X-131-1-04 and 2X-131-1-05 targeting the Kuparuk A -sands. Attached to this application are the following documents: — 10-401 Applications for 2X-131-1, 2X-131-1-01, 2X-131-1-02, 2X-131-1-03, 2X-131-1-04 and 2X-131-1-05 — Detailed Summary of Operations — Directional Plans for 2X-131-1, 2X-131-1-01, 2X-131-1-02, 2X-131-1-03, 2X-131-1-04 and 2X-131-1-05 — Proposed CTD Schematic If you have any questions or require additional information, please contact me at 907-265-6312. Sincerely, Ron Phillips ConocoPhillips Alaska Coiled Tubing Drilling Engineer Kuparuk CT® Laterals NA BO r%" 2X-131-1, 2X-131-1-01, 2X -13L1-02, 2X -13L1-03, 2X -13L1-04 & 2X -13L1-05 CIJi9 Application for Permit to Drill Document 2RC 1. Well Name and Classification........................................................................................................ 2 (Requirements of 20 AAC 25.005(1) and 20 AA C 25.005(b))................................................................................................................... 2 2. Location Summary.......................................................................................................................... 2 (Requirements of 20 AAC 25.005(c)(2)).................................................................................................................................................. 2 3. Blowout Prevention Equipment Information................................................................................. 2 (Requirements of 20 AAC 25.005 (c)(3)) ........... --..................................................................................................................................2 4. Drilling Hazards Information and Reservoir Pressure.................................................................. 2 (Requirements of 20 AAC 25.005(c)(4))................................................................................................................................................. 2 5. Procedure for Conducting Formation Integrity tests................................................................... 2 (Requirements of 20 AAC 25.005(c)(5)) ................................... -...... .............................................................................. ....... .................. 2 6. Casing and Cementing Program.................................................................................................... 3 (Requirements of 20 AAC 25.005(c)(6)).................................................................................................................................................. 3 7. Diverter System Information.......................................................................................................... 3 (Requirements of 20 AAC 25.005(c)(7)).................................................................................................................................................. 3 8. Drilling Fluids Program.................................................................................................................. 3 (Requirements of 20 AAC 25.005(c)(8)).................................................................................................................................................. 3 9. Abnormally Pressured Formation Information............................................................................. 4 (Requirements of 20 AAC 25.005(c)(9))..................................................................................................................................................4 10. Seismic Analysis............................................................................................................................. 4 (Requirements of 20 AAC 25.005(c)(10))................................................................................................................................................4 11. Seabed Condition Analysis............................................................................................................ 4 (Requirements of 20 AAC 25.005(c)(11))................................................................................................................................................ 4 12. Evidence of Bonding...................................................................................................................... 4 (Requirements of 20 AAC 25.005(c)(12))................................................................................................................................................ 4 13. Proposed Drilling Program.............................................................................................................4 (Requirements of 20 AAC 25.005(c)(13)).....................................................................-......................................................................... 4 Summaryof Operations...................................................................................................................................................4 LinerRunning...................................................................................................................................................................6 14. Disposal of Drilling Mud and Cuttings.......................................................................................... 6 (Requirements of 20 AAC 25.005(c)(14))................................................................................................................................................ 6 15. Directional Plans for Intentionally Deviated Wells....................................................................... 7 (Requirements of 20 AAC 25.050(b))...................................................................................................................................................... 7 16. Attachments....................................................................................................................................7 Attachment 1: Directional Plans for 2X-131-1, 2X -13L1-01, 2X-131-1-02, 2X-131-1-03, 2X-131-1-04 and.........................7 2X-131-1-05 laterals..........................................................................................................................................................7 Attachment 2: Current Well Schematic for 1 L-13............................................................................................................7 Attachment 3: Proposed Well Schematic for 2X-131-1, 2X-131-1-01, 2X-131-1-02, 2X-131-1-03, 2X-131-1-04 ..................7 & 2X-131-1-05 laterals......................................................................................................................................................7 Page 1 of 7 March 8, 2016 PTD Application: 2X -13L1, 2X-131-1-01, 2X-131-1-02, 2X-131-1-03, 2X -13L1-04 & 2X -13L1-05 1. Well Name and Classification (Requirements of 20 AAC 25.005(1) and 20 AAC 25.005(b)) The proposed laterals described in this document are 2X-131-1, 2X-131-1-01, 2X-131-1-02, 2X-131-1-03, 2X - 13L1 -04 and 2X-131-1-05. All laterals will be classified as "Development -Oil' wells. 2. Location Summary (Requirements of 20 AAC 25,0057c)(2)) These laterals will target the A sand package in the Kuparuk reservoir. See attached 10-401 forms for surface and subsurface coordinates of the 2X-131-1, 2X-131-1-01, 2X-131-1-02, 2X-131-1-03, 2X-131-1-04 and 2X-131-1- 05 laterals. 3. Blowout Prevention Equipment Information (Requirements of 20 AAC 25.005 (c)(3)) Please reference blowout prevention (BOP) schematics on file with the Commission for Nabors CDR2-AC and CDR3-AC. BOP equipment is as required per 20 AAC 25.036 for thru-tubing drilling operations. — Pipe rams, blind rams and the CT pack off will be pressure tested to 250 psi and to 3,000 psi. Using the maximum formation pressure in the area of 2,670 psi in 1Y-13 (i.e. 8.5 ppg EMW), the maximum potential surface pressure in 2X-13, assuming a gas gradient of 0.1 psi/ft, would be 2,066 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 2X-13 was measured to be 2,136 psi (6.9 ppg EMW) on 2/2/2016. All of the wells in the 2X-13 vicinity are between 6.9 ppg and 8.6 ppg. The combined A and C sand SBHP readings suggest pressures will be close to 7.5 ppg. The maximum downhole pressure in the 2X-13 vicinity, is the 1Y-13 at 2,670 psi or 8.5 ppg EMW. Potential Gas Zones (Requirements of 20 AAC 25.005 (c)(4)(b)) The offset injection wells to 2X-13 have injected gas, so there is a chance of encountering free gas while drilling the 2X-13 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 2X-13 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 2X-13 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 September 7, 2016 PTD Application: 2X -13L1, 2X -13L1-01, 2X -13L1-02, 2X -13L1-03, 2X -13L1-04 & 2X -13L1-05 6. Casing and Cementing Program (Requirements of 20 AA 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 2X-131_1 9,200' 11,250' 5,898' 5,949' 23/", 4.7#, L-80, ST -L slotted liner; 37' 103' 1,640 670 Surface aluminum billet on top 2X -13L1-01 9,150' 11,300' 5,894' 5,912' 23/", 4.7#, L-80, ST -L slotted liner; 3,030' 3,520 2,020 Production 7" aluminum billet on top 2X-131_1-02 8,800' 11,080' 5,885' 5,903' 23/", 4.7#, L-80, ST -L slotted liner; 4,980 4,320 Tubing 3-1/2" 9.3 aluminum billet on to 2X -13L1-03 8,750' 11,050' 5,887' 5,858' 23/" 4.7#, L-80, ST -L slotted liner; 10,540 alum,inum billet on top 2X-131_1-04 8,900' 11,300' 5,885' 5,906' 23/", 4.7#, L-80, ST -L slotted liner; aluminum billet on top 2X -13L1-05 8,160' 11,050' 5,805' 5,847' 2%", 4.7#, L-80, ST -L slotted liner; 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 37' 103' 37' 103' 1,640 670 Surface 9-5/8" 36 J-55 BTC 36' 3,747' 36' 3,030' 3,520 2,020 Production 7" 26 J-55 BTC 34' 8,510' 34' 6,167' 4,980 4,320 Tubing 3-1/2" 9.3 L-80 EUE 31' 8,181' 31' 5,933' 10,160 10,540 7. Diverter System Information (Requirements of 20 AA 25.005(c)(7)) Nabors CDR2-AC or CDR3-AC will be operating under 20 AAC 25.036, for thru-tubing drilling operations. Therefore, a diverter system is not required. 8. Drilling Fluids Program (Requirements of 20 AA 25.005(c)(8)) Diagram of Drilling System A diagram of the Nabors CDR2-AC or CDR3-AC mud system is on file with the Commission. Description of Drilling Fluid System - Window milling operations: Chloride -based FloVis mud (8.6 ppg) - Drilling operations: Chloride -based FloVis mud (8.6 ppg)./ While this mud weight will hydrostatically overbalance the reservoir pressure, overbalanced conditions will also 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 11.4ppg NaBr completion fluid will be utilized to provide formation over- balance and well bore stability while running completions. Managed Pressure Drilling Practice Managed pressure drilling (MPD) techniques will be employed to maintain a constant overbalanced pressure on the open hole formation and promote wellbore stability throughout the coiled tubing drilling (CTD) process. Mud weight is not, in many cases, the primary well control barrier. This is satisfied with the 5,000 psi rated coiled tubing pack off and MPD choke. BOPE equipment provides the secondary well control as detailed in section 3 "Blowout Prevention Equipment Information". Page 3 of 7 September 7, 2016 PTD Application: 2X -13L1, 2X -13L1-01, 2X -13L1-02, 2X -13L1-03, 2X -13L1-04 & 2X -13L1-05 In the 2X-13 laterals we will target a constant BHP of 11.4 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. Pressure at the 2X-13 Window (8165' MD, 5921' 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 2X-13 was originally drilled and completed in 1984 as a Kuparuk A -sand producer. The A -sand was stimulated with a fracture treatment in September 1988. In October 1990, the upper completion was pulled and replaced to perforated the Kuparuk C -sand. A Rig Work Over was performed in September 2016 to fix these issues: January 2016 the IC Packoffs failed, a known tubing leak at 8059'and subsidence related helically buckled tubing found in June of 2016. The 3-1/2" selective completion was replaced, the permanent tubing patch removed, IC packoffs replaced and the 7" casing was allowed to grow. Prior to CTD operations, a whipstock will be set with E -line. Nabors CDR2-AC will mill a 2.80" window off the whipstock at 8165'. Six laterals will be drilled: three to the west and three to the east of the parent well with the laterals targeting the Kuparuk A4 and A3 sands. All laterals will be completed with 2-3/8" slotted liner from TD with the last lateral liner top located inside the 3-1/2" tubing tail. Page 4 of 7 September 7, 2016 Pumps On (1.5 bpm) Pumps Off A -sand Formation Pressure 6.9 2124 psi 2124 psi Mud Hydrostatic 8.6 2648 psi 2648 psi Annular friction i.e. ECD, 0.080psi/ft) 653 psi 0 psi Mud + ECD Combined (no choke pressure) 3301 psi overbalanced 1177psi) 2648 psi (overbalanced —524psi) Tar etBHP at Window (11.4 pg) 3510 psi 3510 psi FChoke Pressure Required to Maintain Target BHP 209 psi 862 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 2X-13 was originally drilled and completed in 1984 as a Kuparuk A -sand producer. The A -sand was stimulated with a fracture treatment in September 1988. In October 1990, the upper completion was pulled and replaced to perforated the Kuparuk C -sand. A Rig Work Over was performed in September 2016 to fix these issues: January 2016 the IC Packoffs failed, a known tubing leak at 8059'and subsidence related helically buckled tubing found in June of 2016. The 3-1/2" selective completion was replaced, the permanent tubing patch removed, IC packoffs replaced and the 7" casing was allowed to grow. Prior to CTD operations, a whipstock will be set with E -line. Nabors CDR2-AC will mill a 2.80" window off the whipstock at 8165'. Six laterals will be drilled: three to the west and three to the east of the parent well with the laterals targeting the Kuparuk A4 and A3 sands. All laterals will be completed with 2-3/8" slotted liner from TD with the last lateral liner top located inside the 3-1/2" tubing tail. Page 4 of 7 September 7, 2016 PT® Application: 2X -13L1, 2X -13L1-01, 2X -13L1-02, 2X -13L1-03, 2X -13L1-04 & 2X -13L1-05 Pre -CTD Work 1. Perform RWO to install new 3-1/2" tubing, Orbit valve and packers. 2. RU Slickline: Pull sheared out SOV. Perform a dummy whipstock drift. Set a tubing tail plug. 3. RU E -line: Set 3-1/2" Northern Solutions Whipstock in tubing tail at 8165'. 4. Prep site for Nabors CDR2-AC or CDR3-AC and set BPV. Ria Work 1. MIRU Nabors CDR2-AC or CDR3-AC rig using 2" coil tubing. NU 7-1/16" BOPE, test. 2. 2X -13L1 Lateral (A3 sand - West) a. Mill 2.80" window at 8165' MD. b. Drill 3" bi-center lateral to TD of 11,250' MD. c. Run 2%" slotted liner with an aluminum billet from TD up to 9200' MD. 2X -13L1-01 Lateral (A4 sand - West) a. Kick off of the aluminum billet at 9200' MD. b. Drill 3" bi-center lateral to TD of 11,300' MD. c. Run 2%" slotted liner with an aluminum billet from TD up to 9150' MD. 4. 2X -13L1-04 Lateral (A4 sand - West) a. Kick off of the aluminum billet at 9150' MD. b. Drill 3" bi-center lateral to TD of 11,300' MD. c. Run 2%" slotted liner with an aluminum billet from TD up to 8900' MD. 5. 2X-13 L 1-02 Lateral (A3 sand - East) a. Kick off of the aluminum billet at 8900' MD. b. Drill 3" bi-center lateral to TD of 11,080' MD. c. Run 2%" slotted liner with an aluminum billet from TD up to 8800' MD. 6. 2X -13L1-03 Lateral (A4 sand - East) a. Kickoff of the aluminum billet at 8800' MD. b. Drill 3" bi-center lateral to TD of 11,050' MD. c. Run 2%" slotted liner with an aluminum billet from TD up to 8750' MD. 7. 2X -13L1-05 Lateral (A4 sand - East) a. Kick off of the aluminum billet at 8750' MD. b. Drill 3" bi-center lateral to TD of 11,050' MD. c. Run 2%" slotted liner from TD up into the tubing at 8160' NO. 8. Freeze protect, set BPV, ND BOPE, and RDMO Nabors CRD2-AC or CDR3-AC. Post -Rig Work 1. Pull BPV. 2. Obtain SBFT. 3. Install GLV's . 4. Return to production. Page 5 of 7 September 7, 2016 PTD Application: 2X-1311-1, 2X-1311-1-01, 2X -13L1-02, 2X -13L1-03, 2X -13L1-04 & 2X -13L1-05 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 2X-13 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 2%" slotted liner, a joint of 2%" non -slotted tubing will be standing by for emergency deployment. A floor valve is made up onto this joint ahead of time, and the rig crew conducts a deployment drill with this emergency joint on every slotted liner run. The 2%" rams will provide secondary well control while running 23/" 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 September 7, 2016 PTD Application: 2X-131-1, 2X-131-1-01, 2X -13L1-02, 2X -13L1-03, 2X -13L1-04 & 2X -13L1-05 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 2X-131-1 36,960' 2X -13L1-01 36,960' 2X-131-1-02 35,376' 2X-131-1-03 35,376' 2X-131-1-04 36,960' 2X-131-1-05 35,376' — Distance to Nearest Well within Pool Lateral Name Distance Well 2X-131-1 870' 2X-17 2X-131-1-01 870' 2X-17 2X-131-1-02 1290' 2X-14 2X-131-1-03 1290' 2X-14 2X-131-1-04 870' 2X-17 2X-131-1-05 1290' 2X-14 16. Attachments Attachment 1: Directional Plans for2X-13L1, 2X -13L1-01, 2X -13L1-02, 2X -13L1-03, 2X -13L1-04 and 2X -13L 1-05 laterals. Attachment 2: Current Well Schematic for IL-13 Attachment 3. Proposed Well Schematic for 2X -13L1, 2X -13L1-01, 2X -13L1-02, 2X -13L1-03, 2X -13L1-04 & 2X -13L1-05 laterals. Page 7 of 7 September 7, 2016 ConocoPhillips (Alaska) Inc. -Kup2 Kuparuk River Unit Kuparuk 2X Pad 2X-13 2X-131-1-03 Plan: 2X-13L1-03_wp02 Standard Planning Report 07 September, 2016 Ft fAd &I BAKER HUGHES Baker Hughes INTEQ Has ConocoPhillips Planning Report BAKER HUGHES Database: OAKEDMP2 Company: ConocoPhillips (Alaska) Inc. -Kup2 Project: Kuparuk River Unit Site: Kuparuk 2X Pad Well: 2X-13 Wellbore: 2X-131-1-03 Design: 2X-13L1-03_wp02 Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Well 2X-13 Mean Sea Level 2X-13 @ 112.00usft (2X-13) Grid Minimum Curvature Project Kuparuk River Unit, North Slope Alaska, United States Map System: US State Plane 1927 (Exact solution) System Datum: Mean Sea Level Geo Datum: NAD 1927 (NADCON CONUS) Using Well Reference Point Map Zone: Alaska Zone 04 Using geodetic scale factor Site Kuparuk 2X Pad Site Position: Northing: 5,970,513.01 usft Latitude: 70° 19'50.180 N From: Map Easting: 518,889.00usft Longitude: 149° 50'48.451 W Position Uncertainty: 0.00 usft Slot Radius: 13-3/16" Grid Convergence: 0.14 ° Well 2X-13 Well Position +N/ -S 0.00 usft Northing: 5,971,233.11 usft Latitude: 70° 19'57.263 N +E/ -W 0.00 usft Easting: 518,889.15 usft Longitude: 149° 50'48.394 W Position Uncertainty 0.00 usft Wellhead Elevation: usft Ground Level: 0.00 usft Wellbore 2X-1311-03 Magnetics Model Name Sample Date Declination BGGM2016 12/1/2016 17.84 Design 2X-131-1-03_wp02 Audit Notes: Dip Angle Field Strength (°) (nT) 80.94 57,544 Version: Phase: PLAN Tie On Depth: 8,800.00 Vertical Section: Depth From (TVD) +N/ -S +E/ -W Direction (usft) (usft) (usft) (°) 0.00 0.00 0.00 134.86 Plan Sections Measured TVD Below Dogleg Build Turn Depth Inclination Azimuth System +N/ -S +E/ -W Rate Rate Rate TFO (usft) (°) (°) (usft) (usft) (usft) (°/10ousft) (°/100usft) (°/100usft) (°) 8,800.00 90.89 194.47 5,885.45 2,517.09 4,436.13 0.00 0.00 0.00 0.00 8,900.00 102.15 190.30 5,874.11 2,420.23 4,414.82 12.00 11.26 -4.17 -20.00 9,000.00 94.31 181.11 5,859.78 2,321.93 4,405.08 12.00 -7.84 -9.19 -130.00 9,100.00 83.04 177.00 5,862.09 2,222.15 4,406.72 12.00 -11.28 -4.11 -160.00 9,200.00 75.45 167.53 5,880.78 2,124.98 4,419.82 12.00 -7.59 -9.47 -130.00 9,350.00 89.44 178.99 5,900.53 1,977.90 4,436.96 12.00 9.33 7.64 40.00 9,450.00 89.45 190.99 5,901.50 1,878.47 4,428.29 12.00 0.01 12.00 90.00 9,550.00 89.46 178.99 5,902.46 1,779.03 4,419.61 12.00 0.01 -12.00 -90.00 9,750.00 87.48 155.06 5,907.88 1,585.63 4,464.16 12.00 -0.99 -11.96 -95.00 9,950.00 90.53 131.25 5,911.41 1,426.79 4,583.22 12.00 1.53 -11.91 -83.00 10,200.00 91.46 101.26 5,906.96 1,317.48 4,804.84 12.00 0.37 -12.00 -88.00 10,350.00 91.70 119.26 5,902.79 1,265.77 4,944.93 12.00 0.16 12.00 89.00 10,500.00 93.16 101.30 5,896.38 1,214.02 5,084.92 12.00 0.97 -11.97 -85.00 10,700.00 94.92 125.30 5,882.09 1,135.72 5,266.81 12.00 0.88 12.00 85.00 10,825.00 94.75 140.35 5,871.49 1,051.29 5,357.89 12.00 -0.13 12.04 90.00 11,050.00 91.97 113.45 5,858.06 917.74 5,535.87 12.00 -1.24 -11.96 -95.00 Target 9/7/2016 9:45:22AM Page 2 COMPASS 5000.1 Build 74 1 Baker Hughes INTEQ ��.. ConocoPhillIpS Planning Report RAKER HUGHES Database: OAKEDMP2 Local Co-ordinate Reference: Well 2X-13 Company: ConocoPhillips (Alaska) Inc. -Kup2 TVD Reference: Mean Sea Level Project: Kuparuk River Unit MD Reference: 2X-13 @ 112.00usft (2X-13) Site: Kuparuk 2X Pad North Reference: Grid Well: 2X-13 Survey Calculation Method: Minimum Curvature Wellbore: 2X-131-1-03 Depth Inclination Azimuth Design: 2X-13 L 1-03_wp 02 +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 tasting (usft) (°) (°) (usft) (usft) (usft) (usft) (°/100usft) (°) (usft) (usft) 8,800.00 90.89 194.47 5,885.45 2,517.09 4,436.13 1,369.09 0.00 0.00 5,973,749.95 523,324.84 TIP/KOP 8,900.00 102.15 190.30 5,874.11 2,420.23 4,414.82 1,422.31 12.00 -20.00 5,973,653.10 523,303.53 Start 12 dls 9,000.00 94.31 181.11 5,859.78 2,321.93 4,405.08 1,484.74 12.00 -130.00 5,973,554.81 523,293.79 3 9,100.00 83.04 177.00 5,862.09 2,222.15 4,406.72 1,556.28 12.00 -160.00 5,973,455.04 523,295.43 4 9,200.00 75.45 167.53 5,880.78 2,124.98 4,419.82 1,634.11 12.00 -130.00 5,973,357.88 523,308.53 5 9,300.00 84.74 175.24 5,897.99 2,027.75 4,434.45 1,713.06 12.00 40.00 5,973,260.66 523,323.16 9,350.00 89.44 178.99 5,900.53 1,977.90 4,436.96 1,750.00 12.00 38.67 5,973,210.82 523,325.67 6 9,400.00 89.44 184.99 5,901.02 1,927.96 4,435.23 1,784.00 12.00 90.00 5,973,160.88 523,323.94 9,450.00 89.45 190.99 5,901.50 1,878.47 4,428.29 1,813.99 12.00 89.94 5,973,111.39 523,317.00 7 9,500.00 89.45 184.99 5,901.98 1,828.98 4,421.34 1,843.98 12.00 -90.00 5,973,061.91 523,310.05 9,550.00 89.46 178.99 5,902.46 1,779.03 4,419.61 1,877.98 12.00 -89.94 5,973,011.97 523,308.32 8 9,600.00 88.94 173.01 5,903.15 1,729.18 4,423.10 1,915.61 12.00 -95.00 5,972,962.12 523,311.81 9,700.00 87.94 161.05 5,905.88 1,631.95 4,445.50 2,000.08 12.00 -94.92 5,972,864.90 523,334.21 9,750.00 87.48 155.06 5,907.88 1,585.63 4,464.16 2,045.98 12.00 -94.59 5,972,818.58 523,352.87 9 9,800.00 88.22 149.10 5,909.76 1,541.50 4,487.55 2,093.68 12.00 -83.00 5,972,774.46 523,376.25 9,900.00 89.76 137.20 5,911.53 1,461.64 4,547.40 2,192.44 12.00 -82.78 5,972,694.61 523,436.10 9,950.00 90.53 131.25 5,911.41 1,426.79 4,583.22 2,242.41 12.00 -82.56 5,972,659.76 523,471.91 10 10,000.00 90.74 125.25 5,910.85 1,395.85 4,622.47 2,292.05 12.00 -88.00 5,972,628.82 523,511.16 10,100.00 91.12 113.26 5,909.22 1,347.08 4,709.54 2,388.18 12.00 -88.07 5,972,580.05 523,598.22 10,200.00 91.46 101.26 5,906.96 1,317.48 4,804.84 2,476.61 12.00 -88.26 5,972,550.45 523,693.51 11 10,300.00 91.64 113.26 5,904.25 1,287.87 4,900.13 2,565.04 12.00 89.00 5,972,520.85 523,788.79 10,350.00 91.70 119.26 5,902.79 1,265.77 4,944.93 2,612.39 12.00 89.33 5,972,498.75 523,833.59 12 10,400.00 92.21 113.28 5,901.08 1,243.66 4,989.72 2,659.73 12.00 -85.00 5,972,476.65 523,878.37 10,500.00 93.16 101.30 5,896.38 1,214.02 5,084.92 2,748.12 12.00 -85.20 5,972,447.01 523,973.56 13 10,600.00 94.13 113.29 5,890.00 1,184.41 5,180.03 2,836.42 12.00 85.00 5,972,417.40 524,068.66 10,700.00 94.92 125.30 5,882.09 1,135.72 5,266.81 2,932.28 12.00 85.76 5,972,368.72 524,155.43 14 10,800.00 94.81 137.34 5,873.58 1,070.05 5,341.49 3,031.54 12.00 90.00 5,972,303.05 524,230.11 10,825.00 94.75 140.35 5,871.49 1,051.29 5,357.89 3,056.39 12.00 91.03 5,972,284.30 524,246.50 15 10,900.00 93.91 131.37 5,865.82 997.68 5,409.91 3,131.09 12.00 -95.00 5,972,230.69 524,298.53 11,000.00 92.65 119.41 5,860.08 939.97 5,491.16 3,229.38 12.00 -95.68 5,972,172.99 524,379.76 11,050.00 91.97 113.45 5,858.06 917.74 5,535.87 3,276.76 12.00 -96.37 5,972,150.76 524,424.47 Planned TD at 11050.00 9/7/2016 9:45:22AM Page 3 COMPASS 5000.1 Build 74 Baker Hughes INTEQ Planning Report Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Well 2X-13 Mean Sea Level 2X-13 @ 112 00usft (2X-13) Grid Minimum Curvature ri.I BAKER HUGHES Casing Points ConocoPhillips Database: OAKEDMP2 Company: ConocoPhillips (Alaska) Inc. -Kup2 Project: Kuparuk River Unit Site: Kuparuk 2X Pad Well: 2X-13 Wellbore: 2X-131-1-03 Design: 2X-13 L 1-03_wp02 Baker Hughes INTEQ Planning Report Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Well 2X-13 Mean Sea Level 2X-13 @ 112 00usft (2X-13) Grid Minimum Curvature ri.I BAKER HUGHES Casing Points Measured Vertical Casing Hole Vertical Depth Depth Diameter Diameter Depth (usft) (usft) Name +E/ -W 11,050.00 5,858.06 2 3/8" 2-3/8 3 Plan Annotations Measured Vertical Local Coordinates Depth Depth +N/ -S +E/ -W (usft) (usft) (usft) (usft) Comment 8,800.00 5,885.45 2,517.09 4,436.13 TIP/KOP 8,900.00 5,874.11 2,420.23 4,414.82 Start 12 dls 9,000.00 5,859.78 2,321.93 4,405.08 3 9,100.00 5,862.09 2,222.15 4,406.72 4 9,200.00 5,880.78 2,124.98 4,419.82 5 9,350.00 5,900.53 1,977.90 4,436.96 6 9,450.00 5,901.50 1,878.47 4,428.29 7 9,550.00 5,902.46 1,779.03 4,419.61 8 9,750.00 5,907.88 1,585.63 4,464.16 9 9,950.00 5,911.41 1,426.79 4,583.22 10 10,200.00 5,906.96 1,317.48 4,804.84 11 10,350.00 5,902.79 1,265.77 4,944.93 12 10,500.00 5,896.38 1,214.02 5,084.92 13 10,700.00 5,882.09 1,135.72 5,266.81 14 10,825.00 5,871.49 1,051.29 5,357.89 15 11,050.00 5,858.06 917.74 5,535.87 Planned TD at 11050.00 Survey Tool Program Date 8/31/2016 From To (usft) (usft) Survey (Wellbore) Tool Name 200.00 8,100.00 2X-13 (2X-13) GCT -MS 8,100.00 8,800.00 2X-13L1_wp03 (2X-1311) MWD 8,800.00 11,050.00 2X-13L1-03_wp02 (2X-1311-03) MWD Description Schlumberger GCT multishot MWD - Standard MWD - Standard 9/7/2016 9:45:22AM Page 4 COMPASS 5000.1 Build 74 ConocoPhillips ConocoPhillips (Alaska) Inc. -Ku p2 Kuparuk River Unit Kuparuk 2X Pad 2X-13 2X -13L1-03 2X-13L1-03_wp02 Travelling Cylinder Report 01 September, 2016 WeAd a I BAKER HUGHES ConocoPhillips Company: ConocoPhillips (Alaska) Inc. -Kup2 Project: Kuparuk River Unit Reference Site: Kuparuk 2X Pad Site Error: 0.00 usft Reference Well: 2X-13 Well Error: 0.00 usft Reference Wellbore 2X-131-1-03 Reference Design: 2X-13L1-03_wp02 Baker Hughes INTEQ Travelling Cylinder Report Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Output errors are at Database: Offset TVD Reference: Well 2X-13 2X-13 @ 112.00usft (2X-13) 2X-13 @ 112.00usft (2X-13) True Minimum Curvature 1.00 sigma OAKEDMP2 Offset Datum Reference 2X-13L1-03_wp02 Filter type: GLOBAL FILTER APPLIED: All wellpaths within 200'+ 100/1000 of reference Interpolation Method: MD Interval 25.00usft Error Model: ISCWSA Depth Range: 8,800.00 to 11,050.00usft Scan Method: Tray. Cylinder North Results Limited by: Maximum center -center distance of 1,293.80 usft Error Surface: Elliptical Conic F%/LI BAKER HUGHES Casing Points Measured Vertical Casing Hole Depth Depth Diameter Diameter (usft) (usft) Name 11,050.00 5,970.06 2 3/8" 2-3/8 3 Summary Date 8/31/2.016 Survey Tool Program From To Reference (usft) (usft) Survey (Wellbore) Tool Name Description 200.00 8,100.00 2X-13 (2X-13) GCT -MS Schlumberger GCT multishot 8,100.00 8,800.00 2X-13L1_wp03 (2X-131-1) MWD MWD - Standard 8,800.00 11,050.00 2X-13L1-03_wp02 (2X-131-1-03) MWD MWD - Standard Casing Points Measured Vertical Casing Hole Depth Depth Diameter Diameter (usft) (usft) Name 11,050.00 5,970.06 2 3/8" 2-3/8 3 Summary Kuparuk 2X Pad - 2X -13 -2X -13-2X-13 Reference Offset Centre to No -Go Allowable Measured Measured Centre Distance Deviation Warning Site Name Depth Depth Distance (usft) from Plan Offset Well - Wellbore - Design (usft) (usft) (usft) Vertical (usft) Vertical Kuparuk 2X Pad Offset Toolface + Offset Wellbore Centre Casing - Centre to 2X-13 - 2X-13 - 2X-13 8,816.98 7,475.00 842.16 13.91 833.69 Pass - Major Risk 2X-13 - 2X-131_1 - 2X-13L1_wp03 8,824.97 8,825.00 0.83 0.44 0.39 Pass - Minor 1/10 2X -13-2X-131-1-01 - 2X-13L1-01_wp03 8,824.97 8,825.00 0.83 0.44 0.39 Pass - Minor 1/10 2X-13 - 2X-131-1-02 - 2X-131_1-02_wp03 8,824.97 8,825.00 0.83 0.44 0.39 Pass - Minor 1/10 2X-13 - 2X-131-1-04 - 2X-13L1-04_wp01 8,824.97 8,825.00 0.83 0.44 0.39 Pass - Minor 1/10 2X-13 - 2X-131_1-05 - 2X-131-1-05_wp01 9,201.52 9,200.00 3.71 1.44 2.43 Pass - Minor 1/10 2X-14 - 2X-14 - 2X-14 7,450.00 5,397.47 0.68 0.00 -122.20 Out of range 2X-15 - 2X-15 - 2X-15 2-11/16 853.08 14.41 854.01 Pass - Major Risk 8,900.00 Out of range 2X-16 - 2X-16 - 2X-16 5,361.59 0.74 0.00 -124.17 2,638.14 Out of range Plan: 2X -A - 2X -A - 2X -A (wp01) 903.85 14.81 894.33 Pass - Major Risk 8,900.00 5,986.11 Out of range Offset Design Kuparuk 2X Pad - 2X -13 -2X -13-2X-13 offset site Error: 0 00 usft Survey Program: 200 -GCT -MS Rule Assigned: Major Risk Offset Well Error: 0.00 usft Reference Offset Semi Major Axis Measured Vertical Measured Vertical Reference Offset Toolface + Offset Wellbore Centre Casing - Centre to No Go Allowable Warning Depth Depth Depth Depth Azimuth +N/ -S +E/ -W Hole Size Centre Distance Deviation (usft) (usft) (usft) (usft) (usft) (usft) (") (usft) (usft) (") (usft) (usft) (usft) 8,816.98 5,996.91 7,475.00 5,415.53 0.60 0.00 -119.81 2,663.64 3,854.22 2-11/16 842.16 13.91 833.69 Pass - Major Risk, CC, ES, SF 8,864.66 5,992.35 7,450.00 5,397.47 0.68 0.00 -122.20 2,655.17 3,839.14 2-11/16 853.08 14.41 854.01 Pass - Major Risk 8,900.00 5,986.11 7,400.00 5,361.59 0.74 0.00 -124.17 2,638.14 3,808.77 2-11/16 903.85 14.81 894.33 Pass - Major Risk 8,900.00 5,986.11 7,425.00 5,379.49 0.74 0.00 -124.08 2,646.67 3,823.99 2-11/16 883.44 14.81 873.93 Pass - Major Risk 8,911.83 5,983.72 7,375.00 5,343.85 0.76 0.00 -125.57 2,629.50 3,793.41 2-11/16 924.20 15.01 914.53 Pass - Major Risk 8,916.67 5,982.79 7,350.00 5,326.36 0.77 0.00 -126.15 2,620.68 3,777.88 2-11/16 944.69 15.10 934.95 Pass - Major Risk 8,925.00 5,981.27 7,275.00 5,275.34 0.78 0.00 -127.10 2,593.27 3,730.23 2-11/16 1,006.51 15.24 996.66 Pass - Major Risk 8,925.00 5,981.27 7,300.00 5,292.15 0.78 0.00 -127.10 2,602.52 3,746.26 2-11/16 985.80 15.24 975.94 Pass - Major Risk 8,925.00 5,981.27 7,325.00 5,309.13 0.78 0.00 -127.10 2,611.69 3,762.16 2-11/16 965.24 15.24 955.39 Pass - Major Risk CC - Min centre to center distance or covergent point, SF - min separation factor, ES - min ellipse separation 9/1/2016 11:31:40AM Page 2 COMPASS 5000.1 Build 74 ConocoPhillips Azimuths. to True North WELLBORE DETAILS: 2X-1311-03 REFERENCE INFORMATION Project: Kuparuk River Unit Magnetic North: 17.84• Site: Kuparuk 2X Pad Magnetto Feld Parent Wellbore: 2X -13L1 Coordinate (NIE) Reference: Well 2X-13, True North Well: 2X-13 Sirengtn: 67543.9sni Vertical (TVD) Reference Mean Sea Leel Wellbore: 2X -13L1-03 Dip Angte 80.94 Tie on MD: 6600.00 Section (VS) Reference: Slot -(O.00N, O.00E) Plan: 2X-131-1-03 w 02 2X -13/2X -13L1-03 Date:12A/2016 Measured Depth Reference: 2X-13@112.00usft (2X-13) P ( j Model: BGGM2016 Calculation Method: Minimum Curvature 558 564 570 576 O 582 C. Q588 Cd 594 600 d) 606 612 618 Mean Sea 2700 2550 240C 225C 2100 G 950 1800 O 1650 J500 1350 200 J)1050 900 750 600 ri.I BA HUGHES 2x 13/2x WELL DETAILS: ---- KOP Ll 2X-13 _•_` +N/ -S +E/ -W Northing Easting F Latitude Longitude 0.00 0.00 5971233.11 518889.15 70° 19'57.263 N 149° 50'48.394 W Sec MD Inc Azi TVDSS +N/ -S +E/ -W Dleg TFace VSect 2X -13/2X-1 Annotation 1 8800.00 90.89 194.61 5885.45 2506.14 4442.33 0.00 0.00 1369.09 Ll -03 1105 TIP/KOP 2 8900.00 102.15 190.44 5874.11 2409.33 4420.78 12.00 -20.00 1422.31 Start 12 dls 3 9000.00 94.31 181.25 5859.78 2311.06 4410.80 12.00 -130.00 1484.74 2X-131.1 Fau t1A 3 4 9100.00 83.04 177.14 5862.09 2211.28 4412.19 12.00 -160.00 1556.28 4 5 9200.00 75.45 167.67 5880.78 2114.07 4425.05 12.00 -130.001634.11 5 6 9350.00 89.44 179.13 5900.53 1966.95 4441.83 12.00 40.00 1750.00 6 7 9450.00 89.45 191.13 5901.50 1867.54 4432.91 12.00 90.00 1813.99 -13L1 7 8 9550.00 89.46 179.13 5902.46 1768.13 4423.99 12.00 -90.001877.98 8 9 9750.00 87.48 155.20 5907.88 1574.61 4468.06 12.00 -95.00 2045.98 9 10 9950.00 90.53 131.39 5911.41 1415.48 4586.73 12.00 -83.00 2242.41 10 11 10200.00 91.46 101.40 5906.96 1305.62 4808.08 12.00 -88.00 2476.61 11 12 10350.00 91.70 119.40 5902.79 1253.57 4948.04 12.00 89.00 2612.39 12 13 10500.00 93.16 101.45 5896.38 1201.47 5087.90 12.00 -85.00 2748.12 13 14 10700.00 94.92 125.44 5882.09 1122.72 5269.59 12.00 85.00 2932.28 14 15 10825.00 94.75 140.50 5871.49 1038.07 5360.46 12.00 90.00 3056.39 15 16 11050.00 91.97 113.59 5858.06 904.08 5538.12 12.00 -95.00 3276.76 Planned TD at 11050.00 558 564 570 576 O 582 C. Q588 Cd 594 600 d) 606 612 618 Mean Sea 2700 2550 240C 225C 2100 G 950 1800 O 1650 J500 1350 200 J)1050 900 750 600 ri.I BA HUGHES 2x 13/2x West( -)/East(+) (150 usft/in) ---- KOP Ll --_- _•_` 1 <2X 13/2X 13L1 F 3 0 X-13 1-02 aultl t X-13/ -131 -04 l 2 X-1 V2 -13L -01 4 X 2X -13/2X-1 Ll -0 5 TIP/ OP2X-1 6- -.._-- /2X-13 2X-13 Planned TD a 1-02 Ll -03 1105 00 7 - '•, 5 6 7 8 9 10 2X-1 11 12 13 14 15 2X-1 LI_F ultlA 8 •• 2X- 3Ll ult1B 2X-131.1 Fau t1A 2X -i3 ]-02 Faultl 2X-13 2X-13 1-01 9' 1260 1370 1IRn I 44. 19nn 1Vrn Iron ,run tonn__-- 2X -13,2X.131,1.04 10 l l 12 2X-13 X-13 I-02 13 15" 2 -13/2 -13L1 3 Plann ad TD it 1105 .00 2X-13 2X-13 1 -OS 2X -13L1 03_TO1 1 West( -)/East(+) (150 usft/in) ---- --- --- --_- _•_` 1 F 0 t X-13/ -131 -04 l 2 X-1 V2 -13L -01 X 2X -13/2X-1 Ll -0 TIP/ OP2X-1 -.._-- /2X-13 2X-13 Planned TD a 1-02 Ll -03 1105 00 S art 12 Its 3 '•, 5 6 7 8 9 10 2X-1 11 12 13 14 15 X -13/'X-131 1 4 i i i 2X-131.1 Fau t1A 2X -i3 ]-02 Faultl 1260 1370 1IRn I 44. 19nn 1Vrn Iron ,run tonn__-- ---- ,,,,, �„�� oo� c.>-.� �v�� wu �,�� siaU 11- 1 33VU SSbV 3420 3480 3540 Vertical Section at 135.00° (60 usft/in) 2X-13 Proposed CTD Schematic 6" 62.5# H-40 shoe 03' MD 9-5/8" 36# J-55 shoe @ 3,747' MD C -sand perfs 7,970 - 8,014' MD 2X-1311-05 wp01 (A4) TO at 11,050' MD EWE Liner billet 8155' MD ------------------------------ ------ 2X-1 31-1 -03 wp02 (A4) Lat #5 TO at 11,050' MD Liner top 8750' MD Eastern Laterals - Lat#4 --- 2X -13L1-02 wp03 (A3) TD at 11,080' MD Liner billet at 8800' MD 7" 26# J-55 shoe @ 8,510' MD Modified by RLP 9-8-16 Baker Orbit Valve at 3498' MD (2.835" minimum ID) 3-1/2" 9.3# L-80 EUE 8rd Tubing to surface 3-1/2" Camco gas lift mandrels @ 2932', 4782', 6227', 7140', 7706' MD. Baker FHL Packer w/PBR @ 7778' MD 3-1/2" X -nipple 7832' MD (2.812" min ID) Production mandrels @ 7886', 8073' MD Baker F Packer w/SBE @ 8121' MD Northern Solutions Back up WEDGE (KOP @ 8145') 3-1/2" X -nipple @ 8157' MD Northern Solutions WEDGE (KOP @ 8165') 3-1/2" X -nipple @ 8177' MD 3-1/2" TBG Tail 8185' 2X-131-1-04 wp01(A4) TO at 11,300' MD Liner billet at 8900' MD KOP at 8165' 2X -13L1-01 wp03 (A4) NOTE: WS needs to beWestern Laterals TD at 11,300' MD set 30 -deg ROHS A",Liner billet at 9150' MD ------------------- 2X-131-1 wp03 (A3) Lat#1 TD at 11,250' Nt Liner billet at 9200' MD A -sand perfs 8,214 - 8,240' 8,248 - 8,288' TRANSMITTAL LETTER CHECKLIST WELL NAME: 1K pu, PTD: J N — 11� ✓ Development _ Service Exploratory Stratigraphic Test Non -Conventional FIELD: \ 6r POOL:/&JOJVJl AVVIJ- �'W 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 V/ LATERAL No. � , API No. 50-�_- i r - 64 - 0C� . (If last two digits Production should continue to be reported as a function of the original in API number are API number stated above. between 60-69) In accordance with 20 AAC 25.005(f), all records, data and logs acquired for the pilot hole must be clearly differentiated in both well Pilot Hole name ( PH) and API number (50- - - -� from records, data and logs acquired for well (name onpermit). The permit is approved subject to full compliance with 20 AAC 25.055. Approval to produce/inject is contingent upon issuance of a conservation Spacing Exception order approving a spacing exception. (Company Name) Operator assumes the liability of any protest to the spacing exception that may occur. All dry ditch sample sets submitted to the AOGCC must be in no greater Dry Ditch Sample than 30' sample intervals from below the permafrost or from where samples are first caught and 10' sample intervals through target zones. Please note the following special condition of this permit: production or production testing of coal bed methane is not allowed for Non -Conventional ,(name of well) until after (Company Name) has designed and Well implemented a water well testing program to provide baseline data on water quality and quantity. (Company Name) must contact the AOGCC to obtain advance approval of such water well testing program. Regulation 20 AAC 25.071(a) authorizes the AOGCC to specify types of well logs to be run. In addition to the well logging program proposed by (Company Name) in the attached application, the following well logs are also required for this well: Well Logging Requirements Per Statute AS 31.05.030(d)(2)(B) and Regulation 20 AAC 25.071, composite curves for well logs run must be submitted to the AOGCC within 90 days after completion, suspension or abandonment of this well. Revised 2/2015 WELL PERMIT CHECKLIST Field & Pool KUPARUK RIVER, KUPARUK RIV OIL -490100 11 _ Well Name: KUPARUK RIV UNIT 2X -13L1-03 Program DEV _ - Well bore seg PTD#:2161180 Company CONOCOPHILLIPS ALASKA INC_ _ Initial Class/Type DEV / PEND- 890 Unit 11160On/Off Shore On Annular Disposal ❑ Administration 17 Nonconven. gas conforms to AS31.05.030(j.1.A),(j.2.A-D) NA 1 Permit fee attached NA Yes 2 Lease number appropriate Yes ADL0025645, Surf Loc & Top Prod Interv; ADL0025646, TD. 3 Unique well name and number Yes KRU 2X -13L1-03 4 Well located in a defined pool Yes KUPARUK RIVER, KUPARUK RIV OIL - 490100, governed by Conservation Order No 432D. 5 Well located proper distance from drilling unit boundary Yes CO 432D contains no spacing restrictions with respect to drilling unit boundaries. 6 Well located proper distance from other wells- Yes CO 432D has no interwell spacing -restrictions. Conductor set in KRU _2X-13 Sufficient acreage available in drilling unit Yes Surface casing protects all known USDWs 8 If deviated, is wellbore plat included Yes 20 9 Operator only affected party Yes Wellbore will be more than 500' from an external property line where ownership or landownership changes. 10 Operator has appropriate bond in force Yes Appr Date 11 Permit can be issued without conservation order Yes 12 Permit can be issued without administrative approval Yes PKB 9/12/2016 13 Can permit be approved before 15 -day wait - Yes 14 Well located within area andstrataauthorized by Injection Order # (put IO# in comments) (For NA 15 All wells within 1/4 mile area of review identified (For service well only) NA 16 Pre -produced injector: duration of pre -production less than 3 months (For service well only) NA 18 Conductor string provided NA Conductor set in KRU _2X-13 Engineering 19 Surface casing protects all known USDWs NA Surface casing set in KRU 2X-13 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 uncemented slotted liner 23 Casing designs adequate for C, T, B & permafrost Yes 24 Adequate tankage or reserve pit Yes Rig has steel tanks; all waste to approved disposal wells 25 If_a re -drill, has a 10-403 for abandonment been approved NA 26 Adequate wellbore separation proposed Yes Anti -collision analysis complete; no major risk failures 27 If diverter required, does it meet regulations NA Appr Date 28 Drilling fluid program schematic & equip list adequate Yes Max formation pressure is 2670 psig(8.5 ppg EMW); will drill w/ 8.6 ppg and maintain over bal w/ MPD VTL 9/22/2016 29 BOPEs, do they meet regulation Yes 30 BOPE press rating appropriate; test to (put psig in comments) Yes MPSP is 2066 psig; will test BOPs to 3000 psig 31 Choke manifold complies w/API_ RP -53 (May 84) Yes 32 Work will occur without operation _shutdown Yes 33 Is presence of 1-12S gas probable Yes 1-12S measures required 34 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 2X -Pad are_H2S-bearing. 1-12S measures required. Geology 36 Data presented on potential overpressure zones Yes Max. potential reservoir pressure is 8.5 ppg EMW; will be drilled using 8.6 ppg mud and MPD technique. Appr Date 37 Seismic analysis of shallow gas zones NA PKB 9/12/2016 38 Seabed condition survey (if off -shore) NA 39 Contact name/phone for weekly progress reports [exploratory only] NA Onshore development lateral to be drilled. Geologic Engineering Public Commissioner: Date: C mmissioner: Date Commis ioner Date