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Home My WebLink About216-096DATA SUBMITTAL COMPLIANCE REPORT 2/17/2017 Permit to Drill 2160960 Well Name/No. KUPARUK RIV UNIT 2M-081-1-01 Operator CONOCOPHILLIPS ALASKA INC API No. 50-103-20184-64-00 MD 14503 TVD 6204 Completion Date 10/7/2016 Completion Status 1 -OIL Current Status 1 -OIL UIC No REQUIRED INFORMATION / Mud Log No Samples No ✓ Directional Survey Yes DATA INFORMATION Types Electric or Other Logs Run: GR/Res (data taken from Logs Portion of Master Well Data Maint) Well Log Information: Log/ Electr Data Digital Dataset Log Log Run Interval OH I Type Med/Frmt Number Name Scale Media No Start Stop CH Received Comments_ ED C 27650 Digital Data 10/20/2016 D27 ED C 27650 Digital Data 10/20/2016 ED C 27650 Digital Data 10/20/2016 Electronic File: 2M-081-1-01 EOW - NAD27.pdf . ED C 27650 Digital Data 10/20/2016 Electronic File: 2M-081-1-01 EOW - NAD27.txt Log C 27650 Log Header Scans 0 0 2160960 KUPARUK RIV UNIT 2M-081-1-01 LOG HEADERS Log C 27736 Log Header Scans 0 0 2160960 KUPARUK RIV UNIT 2M-081-1-01 LOG HEADERS ED C 27736 Digital Data 11/11/2016 Electronic File: 2M-081-1-01 2MD Final Log.cgm ED C 27736 Digital Data 11/11/2016 Electronic File: 2M-081-1-01 51VID Final Log.cgm ED C 27736 Digital Data 11/11/2016 Electronic File: 2M-081-1-01 5TVDSS Final Log.cgm ED C 27736 Digital Data 11/11/2016 Electronic File: 2M-081-1-01 21VID Final.pdf ' ED C 27736 Digital Data 1911/11/2016 Electronic File: 2M-081-1-01 5MD Final.pdf ED C 27736 Digital Data 1P11/11/2016 Electronic File: 2M-081-1-01 5TVDSS Final.pdf ED C 27736 Digital Data 11/11/2016 Electronic File: 2M-081-1-01 EOW - NAD27.pdf' ED C 27736 Digital Data 11/11/2016 Electronic File: 2M-081-1-01 EOW - NAD27.txt ' ED C 27736 Digital Data 11/11/2016 Electronic File: 2M-081-1-01 Final Surveys.csv' ED C 27736 Digital Data 11/11/2016 Electronic File: 2M-081-1-01 Survey listing.txt . ED C 27736 Digital Data 11/11/2016 Electronic File: 2M-081-1-01 Surveys.txt ED C 27736 Digital Data 11/11/2016 Electronic File: 2M-081-1- 01_25_tapescan_BHI_CTK.txt AOGCC Page I of 2 Friday, February 17, 2017 INFORMATION RECEIVED Completion Report D Production Test Information! A Geologic Markers/Tops 10 COMPLIANCE HISTORY Completion Date: 10/7/2016 Release Date: 8/10/2016 Description Comments: Directional / Inclination Data YD Mechanical Integrity Test Information Y Daily Operations Summary v Date Comments Mud Logs, Image Files, Digital Data Y & Composite Logs, Image, Data Files 0 Cuttings Samples Y & Core Chips Y /6 Core Photographs Y / 5 Laboratory Analyses Y / CP Compliance Reviewed By: Date: ` 1 AO(;('(' Page 2 ol'2 Friday, February 17, 2017 DATA SUBMITTAL COMPLIANCE REPORT 2/17/2017 Permit to Drill 2160960 Well Name/No. KUPARUK RIV UNIT 2M-081-1-01 Operator CONOCOPHILLIPS ALASKA INC API No. 50-103-20184-64-00 MD 14503 TVD 6204 Completion Date 10/7/2016 Completion Status 1 -OIL Current Status 1 -OIL UIC No ED C 27736 Digital Data 11/11/2016 Electronic File: 2M-081-1- 01 _5_tapescan_B H I_CTK.txt ED C 27736 Digital Data 11/11/2016 Electronic File: 2M-081-1-01output.tap ' ED C 27736 Digital Data 11/11/2016 Electronic File: 2M-081-1-01 2MD Final Log.tif ' ED C 27736 Digital Data 11/11/2016 Electronic File: 2M-081-1-01 5MD Final Log.tif ` ED C 27736 Digital Data 11/11/2016 Electronic File: 2M-081-1-01 5TVDSS Final Log.tif Well Cores/Samples Information: Sample Interval Set Name Start Stop Sent Received Number Comments INFORMATION RECEIVED Completion Report D Production Test Information! A Geologic Markers/Tops 10 COMPLIANCE HISTORY Completion Date: 10/7/2016 Release Date: 8/10/2016 Description Comments: Directional / Inclination Data YD Mechanical Integrity Test Information Y Daily Operations Summary v Date Comments Mud Logs, Image Files, Digital Data Y & Composite Logs, Image, Data Files 0 Cuttings Samples Y & Core Chips Y /6 Core Photographs Y / 5 Laboratory Analyses Y / CP Compliance Reviewed By: Date: ` 1 AO(;('(' Page 2 ol'2 Friday, February 17, 2017 RECEIVEL MARY BAKER NOV 11 2016 HUGHES PRINT DISTRIBUTION LIST �0103�� COMPANY ConocoPhillips Alaska, Inc. WELL NAME 2M -08L1-01 FIELD Prudhoe Bay Unit COUNTY North Slope Borough BHI DISTRICT Alaska AUTHORIZED BY Patrick Rider EMAIL Patrick. RiderCo)bakerhughes.com STATUS Final Replacement: COMPANY ADDRESS (FEDEX WILL NOT DELIVER TO P.O. BO$ PERSON ATTENTION 21 6096 27736 Please sign and return one copy of this transmittal form to: ConocoPhillips Alaska, Inc. Tom Osterkamp DATA LUGGED 700 G Street. kk Ll,/201 K. BENDER Anchorage, Alaska 99510 to acknowledge receipt of this data. LOG TYPE GR - RES LOG DATE October 6, 2016 TODAYS DATE November 7, 2016 Revision No Details: Requested by: FIELD FINAL CD 4 CD 0 LOGS LOGS (digital/image) Surveys I# (Final Surveys) I# # OF PRINTS # OF HRIN 16 # OF COPIES OF COPIES OF CORE 1R 4 4 4 4 1 BP North Slope 0 0 0 �EOA, PBOC, PRB-20 (Office 109) D&C Wells Project Aids Agatha Rutka & Barbara Glassmaker 900 E. Benson Blvd. Anchorage, Alaska 99508 2 ConocoPhillips Alaska Inc. 0 0 0 :Attn: Ricky Elgaricio ATO 3-344 700 G Street 'Anchorage, AK 99510 3 ExxonMobil, Alaska 0 0 0 Attn: Lvnda M. Yaskell and/or Leonardo Elias 3201 C Street, Suite 505 iAnchorage, AK 99503 4 State of Alaska - AOGCC 1 1 1 Attn::Makana Bender 333 W. 7th Ave, Suite 100 Anchorage, Alaska 99501 51 DNR - Division of Oil & Gas *** 0 1 1 Attn: Sean Clifton 550 West 7th Avenue, Suite 802 Anchorage, Alaska 99501 ***Stamp "confidential' on all material deliver to DNR 6 BP Exploration (Alaska) Inc. 1 1 1 Petrotechnical Data Center, LR2-1 900 E. Benson Blvd. ;Anchorage, Alaska 99508 TOTALS FOR THIS PAGE: 0 2 3 3 0 0 TOTALS FOR ALL PAGES: 0 2 3 3 0 0 ConocoPs philli ConocoPhillips (Alaska) Inc. -Kup2 Kuparuk River Unit Kuparuk 2M Pad 2M -08L1-01 50-103-20184-64 Baker Hughes INTEQ V/& I BAKER Definitive Survey Report HUGHES 14 October, 2016 10/14/2016 10:05:43AM Page 2 COMPASS 5000.1 Build 74 WIPARI 10-1 ConocoPhillips ConocoPhillips BAKER Definitive Survey Report HUGHES Company: ConocoPhillips (Alaska) Inc. -Kup2 Local Coordinate Reference: Well 2M-08 Project: Kuparuk River Unit TVD Reference: 2M-08 @ 147.00usft (P245) Site: Kuparuk 2M Pad MD Reference: 2M-08 @ 147.00usft (P245) Well: 2M-08 North Reference: True Wellbore: 2M-081-1-01 Survey Calculation Method: Minimum Curvature Design: 2M-081-1-01 Database: EDM Alaska NSK Sandbox Project Kuparuk River Unit, North Slope Alaska, United States Map System: US State Plane 1927 (Exact solution) System Datum: Mean Sea Level Geo Datum: NAD 1927 (NADCON CONUS) Using Well Reference Point Map Zone: Alaska Zone 04 Using geodetic scale factor Well 2M-08 Well Position +N/ -S 0.00 usft Northing: 5,948,985.84usft Latitude: 70° 16' 18.579 N +E/ -W 0.00 usft Easting: 487,949.23 usft Longitude: 150° 5'50.870 W Position Uncertainty 0.00 usft Wellhead Elevation: usft Ground Level: 105.50 usft Wellbore 2M-081-1-01 Magnetics Model Name Sample Date Declination Dip Angle Field Strength (1) (1 (nT) BGG M2016 10/1/2016 17.84 80.88 57,537 Design 2M-081-1-01 Audit Notes: Version: 1.0 Phase: ACTUAL Tie On Depth: 11,960.18 Vertical Section: Depth From (TVD) +NI -S +E/ -W Direction (usft) (usft) (usft) (I 41.50 0.00 0.00 180.00 Survey Program Date 10/13/2016 Survey Survey From (usft) To (usft) Survey (Wellbore) Tool Name Description Start Date End Date 151.90 11,740.89 2M-08 Srvy 1 - GCT -MS (2M-08) GCT -MS Schlumberger GCT multishot 11/16/1992 11/16/1992 11,745.00 11,960.18 2M-081-1 (2M-081-1) MWD MWD - Standard 9/24/2016 9/30/2016 11,962.00 14,462.79 210-081-1-01 (2M -08L1-01) MWD MWD - Standard 10/1/2016 10/6/2016 10/14/2016 10:05:43AM Page 2 COMPASS 5000.1 Build 74 ConocoPhillips ConocoPhillips BAKER fAbI Definitive Survey Report HUGHES Company: ConocoPhillips (Alaska) Inc. -Kup2 Local Co-ordinate Reference: Well 2M-08 Project: Kuparuk River Unit TVD Reference: 2M-08 @ 147.00usft (P245) Site: Kuparuk 2M Pad MD Reference: 2M-08 @ 147.00usft (P245) Well: 2M-08 North Reference: True Wellbore: 2M-081-1-01 Survey Calculation Method: Minimum Curvature Design: 2M -08L1-01 Database: EDM Alaska NSK Sandbox Survey MD Inc Azi TVD TVDSS +N/ -S +E1 -W Map Map Vertical (usft) (°) (°) (usft) (usft) (usft) (usft) Northing Easting °OLS (1100') Section Survey Tool Name (ft) (ft) (ft) 11,960.18 101.43 140.04 6,215.74 6,068.74 -9,506.29 -822.28 5,939,481.83 487,111.81 45.66 9,506.29 MWD (2) 11,962.00 101.13 139.31 6,215.38 6,068.38 -9,507.65 -821.13 5,939,480.47 487,112.96 42.65 9,507.65 MWD (3) 11,990.33 93.75 152.74 6,211.70 6,064.70 -9,530.89 -805.50 5,939,457.21 487,128.55 53.71 9,530.89 MWD (3) 12,020.18 86.50 166.65 6,211.63 6,064.63 -9,558.79 -795.17 5,939,429.29 487,138.83 52.52 9,558.79 MWD (3) 12,041.77 82.49 175.07 6,213.71 6,066.71 -9,579.99 -791.76 5,939,408.09 487,142.21 43.03 9,579.99 MWD (3) 12,070.61 87.36 186.19 6,216.27 6,069.27 -9,608.66 -792.08 5,939,379.42 487,141.84 41.94 9,608.66 MWD (3) 12,100.57 90.40 190.57 6,216.85 6,069.85 -9,638.28 -796.45 5,939,349.81 487,137.43 17.79 9,638.28 MWD (3) 12,128.99 89.48 193.35 6,216.88 6,069.88 -9,666.08 -802.34 5,939,322.02 487,131.50 10.30 9,666.08 MWD (3) 12,160.98 88.65 195.87 6,217.40 6,070.41 -9,697.03 -810.41 5,939,291.09 487,123.38 8.29 9,697.03 MWD (3) 12,189.90 88.34 197.80 6,218.16 6,071.16 -9,724.70 -818.78 5,939,263.44 487,114.97 6.76 9,724.70 MWD (3) 12,220.61 88.62 200.20 6,218.98 6,071.98 -9,753.73 -828.77 5,939,234.43 487,104.93 7.87 9,753.73 MWD (3) 12,250.56 87.79 202.49 6,219.92 6,072.92 -9,781.61 -839.67 5,939,206.57 487,093.99 8.13 9,781.61 MWD (3) 12,280.79 87.36 203.36 6,221.20 6,074.20 -9,809.42 -851.43 5,939,178.78 487,082.18 3.21 9,809.42 MWD (3) 12,310.88 86.77 204.71 6,222.74 6,075.74 -9,836.87 -863.67 5,939,151.35 487,069.90 4.89 9,836.87 MWD (3) 12,340.75 86.80 203.09 6,224.41 6,077.41 -9,864.13 -875.75 5,939,124.11 487,057.77 5.42 9,864.13 MWD (3) 12,371.06 87.27 200.38 6,225.98 6,078.98 -9,892.25 -886.96 5,939,096.02 487,046.52 9.06 9,892.25 MWD (3) 12,400.94 87.73 198.77 6,227.28 6,080.28 -9,920.37 -896.96 5,939,067.91 487,036.48 5.60 9,920.37 MWD (3) 12,430.98 89.17 197.85 6,228.10 6,081.10 -9,948.88 -906.39 5,939,039.42 487,027.00 5.69 9,948.88 MWD (3) 12,460.94 90.00 195.79 6,228.31 6,081.31 -9,977.55 -915.06 5,939,010.76 487,018.28 7.41 9,977.55 MWD (3) 12,490.72 89.75 193.30 6,228.38 6,081.38 -10,006.38 -922.54 5,938,981.95 487,010.76 8.40 10,006.38 MWD (3) 12,520.76 89.79 191.05 6,228.50 6,081.50 -10,035.74 -928.88 5,938,952.60 487,004.38 7.49 10,035.74 MWD (3) 12,550.50 90.40 189.39 6,228.45 6,081.45 -10,065.01 -934.15 5,938,923.35 486,999.06 5.95 10,065.01 MWD (3) 12,580.94 90.61 188.32 6,228.18 6,081.18 -10,095.08 -938.84 5,938,893.28 486,994.32 3.58 10,095.08 MWD (3) 12,610.57 91.07 189.60 6,227.75 6,080.75 -10,124.35 -943.45 5,938,864.03 486,989.66 4.59 10,124.35 MWD (3) 12,642.38 91.01 190.31 6,227.17 6,080.17 -10,155.67 -948.95 5,938,832.72 486,984.11 2.24 10,155.67 MWD (3) 12,671.20 89.69 190.99 6,226.99 6,079.99 -10,184.00 -954.28 5,938,804.41 486,978.74 5.15 10,184.00 MWD (3) 12,700.66 90.34 192.71 6,226.99 6,079.99 -10,212.83 -960.33 5,938,775.59 486,972.65 6.24 10,212.83 MWD (3) 12,730.77 89.69 194.28 6,226.98 6,079.98 -10,242.10 -967.35 5,938,746.32 486,965.58 5.64 10,242.10 MWD (3) 12,760.70 89.63 196.32 6,227.16 6,080.16 -10,270.97 -975.25 5,938,717.47 486,957.63 6.82 10,270.97 MWD (3) 12,790.57 89.85 198.06 6,227.29 6,080.29 -10,299.51 -984.08 5,938,688.95 486,948.76 5.87 10,299.51 MWD (3) Annotation TIP KOP 10/14/2016 10.,05:43AM Page 3 COMPASS 5000 1 Build 74 V-` ConocoPhillips ConocoPhillips Definitive Survey Report Map Company: ConocoPhillips (Alaska) Inc. -Kup2 Local Coordinate Reference: Well 2M-08 Project: Kuparuk River Unit TVD Reference: 2M-08 @ 147.00usft (P245) Site: Kuparuk 2M Pad MD Reference: 2M-08 @ 147.00usft (P245) Well: 2M-08 North Reference: True Wellbore: 2M-081-1-01 Survey Calculation Method: Minimum Curvature Design: 2M-081-1-01 Database: EDM Alaska NSK Sandbox Survey HE lis BAKER HUGHES 10/14/2016 10:05:43AM Page 4 COMPASS 5000.1 Build 74 Map Map Vertical MD Inc Azi TVD TVDSS +N/ -S +E/ -W Northing Easting DLS Section Survey Tool Name Annotation (usft) (°) (°) (usft) (usft) (usft) (usft) (ft) (ft) (°/100') (ft) 12,820.56 88.71 200.22 6,227.67 6,08067 -10,327.83 -993.91 5,938,660.65 486,938.89 8.14 10,327.83 MWD (3) 12,850.49 90.25 200.01 6,227.94 6,080.94 -10,355.94 -1,004.20 5,938,632.56 486,928.55 5.19 10,355.94 MWD (3) 12,880.61 91.87 197.71 6,227.38 6,080.38 -10,384.43 -1,013.93 5,938,604.09 486,918.77 9.34 10,384.43 MWD (3) 12,910.52 90.86 194.66 6,226.67 6,079.67 -10,413.14 -1,022.27 5,938,575.39 486.910.39 10.74 10,413.14 MWD (3) 12,945.48 90.31 193.75 6,226.31 6,079.31 -10,447.03 -1,030.85 5,938.541.52 486,901.76 3.04 10,447.03 MWD (3) 12,970.42 88.56 190.45 6,226.56 6,079.56 -10,471.41 -1,036.07 5,938,517.15 486,896.50 14.98 10,471.41 MWD (3) 13,000.42 87.42 189.57 6,227.61 6,080.61 -10,500.94 -1,041.28 5,938.487.64 486,891.24 4.80 10,500.94 MWD (3) 13,030.45 86.72 189.89 6,229.15 6,082.15 -10,530.50 -1,046.35 5,938,458.09 486,886.12 2.56 10,530.50 MWD (3) 13,061.92 87.42 188.39 6,230.75 6,083.76 -10,561.52 -1,051.35 5,938,427.07 486,881.08 5.25 10,561.52 MWD (3) 13,090.58 86.78 185.19 6,232.21 6,085.21 -10,589.94 -1,054.73 5,938,398.66 486,877.65 11.37 10,589.94 MWD (3) 13,120.72 86.28 184.37 6,234.03 6,087.03 -10,619.92 -1,057.24 5,938,368.69 486,875.10 3.18 10,619.92 MWD (3) 13,150.40 85.55 181.97 6,236.14 6,089.14 -10,649.48 -1,058.87 5,938,339.14 486,873.41 8.43 10,649.48 MWD (3) 13,180.40 85.52 183.33 6,238.48 6,091.48 -10,679.36 -1,060.26 5.938,309.26 486,871.98 4.52 10,679.36 MWD (3) 13,210.76 85.21 185.29 6,240.93 6,093.93 -10,709.53 -1,062.53 5,938,279.10 486,869.66 6.52 10,709.53 MWD (3) 13,240.74 86.44 186.36 6,243.12 6,096.12 -10,739.27 -1,065.57 5,938,249.36 486,866.58 5.43 10,739.27 MWD (3) 13,270.64 87.94 186.74 6,244.58 61097.58 -10,768.94 -1,068.97 5,938,219.70 486,863.12 5.17 10,768.94 MWD (3) 13,302.51 89.85 187.69 6,245.20 6.098.20 -10,800.55 -1,072.97 5,938.188.10 486,859.07 6.69 10.800.55 MWD (3) 13,331.30 90.83 188.33 6,245.03 6,098.03 -10,829.06 -1,076.99 5,938,159.60 486,855.02 4.07 10,829.06 MWD (3) 13,361.80 90.06 189.71 6,244.79 6.097.79 -10,859.18 -1,081.77 5,938,129.49 486,850.19 5.18 10,859.18 MWD (3) 13,390.72 88.74 188.51 6,245.09 6,098.09 -10,887.73 -1,086.35 5,938,100.95 486,845.56 6.17 10,887.73 MWD (3) 13,421.92 88.31 185.96 6,245.89 6,098.90 -10,918.67 -1,090.27 5,938.070.02 486,841.59 8.29 10,918.67 MWD (3) 13,450.86 88.16 184.83 6,246.79 6,099.79 -10,947.47 -1,092.99 5,938,041.23 486,838.82 3.94 10,947.47 MWD (3) 13,480.59 90.18 184.30 6,247.22 6,100.22 -10,977.10 -1,095.36 5,938.011.60 486,836.41 7.02 10,977.10 MWD (3) 13,510.47 89.91 182.97 6,247.19 6,100.19 -11,006.92 -1,097.25 5.937.981.79 486,834.47 4.54 11,006.92 MWD (3) 13,540.32 88.47 183.86 6,247.62 6,100.62 -11,036.71 -1,099.03 5,937,952.00 486,832.64 5.67 11,036.71 MWD (3) 13,570.55 87.54 185.55 6,248.67 6,101.67 -11,066.82 -1,101.51 5,937,921.90 486,830.11 6.38 11,066.82 MWD (3) 13,600.58 86.47 186.97 6,250.24 6,103.24 -11,096.63 -1,104.78 5,937,892.10 486,826.80 5.92 11,096.63 MWD (3) 13,630.32 85.85 188.81 6,252.23 6,105.23 -11,126.02 -1,108.85 5,937.862.72 486,822.68 6.52 11,126.02 MWD (3) 13,660.54 85.23 190.31 6,254.58 6,107.58 -11,155.73 -1,113.85 5,937,833.02 486,817.63 5.36 11,155.73 MWD (3) 13,690.42 85.33 192.41 6,257.04 6,110.04 -11,184.93 -1,119.72 5,937.803.84 486,811.72 7.01 11,184.93 MWD (3) 13,720.31 86.31 192.77 6,259.22 6,112.22 -11,214.02 -1,126.22 5,937.774.76 486,805.17 3.49 11,214.02 MWD (3) HE lis BAKER HUGHES 10/14/2016 10:05:43AM Page 4 COMPASS 5000.1 Build 74 ConocoPhillips hillips ConocoPhillips Definitive Survey Report Company: ConocoPhillips (Alaska) Inc. -Kup2 Local Co-ordinate Reference: Well 2M-08 Project: Kuparuk River Unit TVD Reference: 2M-08 @ 147.00usft (P245) Site: Kuparuk 2M Pad MD Reference: 2M-08 @ 147.00usft (P245) Well: 2M-08 North Reference: True Wellbore: 2M-081-1-01 Survey Calculation Method: Minimum Curvature Design: 2M-081-1-01 Database: EDM Alaska NSK Sandbox Survey Annotation F&AkI BAKER HUGHES 10/14/2016 10:05:43AM Page 5 COMPASS 5000.1 Build 74 Map Map Vertical i MD Ince ° Azl TVD TVDSS +NlS +E/ -W Northing Easting DLS ° Section Survey Tool Name (u tft) O (°) (usft) (usft) (usft) (usft) (ft) (ft) (ft) 13,750.44 87.27 192.83 6,260.90 6,113.90 -11,243.35 -1,132.88 5,937,745.44 486,798.46 3.19 11,243.35 MWD (3) 13,780.47 88.71 193.57 6,261.96 6,114.96 -11,272.57 -1,139.74 5,937,716.24 486,791.56 5.39 11,272.57 MWD (3) 13,810.18 89.60 193.89 6,262.39 6,115.40 -11,301.43 -1,146.79 5,937,687.39 486,784.47 3.18 11,301.43 MWD (3) 13,841.32 90.68 194.77 6,262.32 6,115.32 -11,331.60 -1,154.49 5,937,657.24 486,776.71 4.47 11,331.60 MWD (3) 13,870.32 90.80 197.90 6,261.94 6,114.94 -11,359.42 -1,162.65 5,937,629.43 486,768.51 10.80 11,359.42 MWD (3) 13,900.43 91.26 197.16 6,261.40 6,114.40 -11,388.13 -1,171.72 5,937,600.74 486,759.40 2.89 11,388.13 MWD (3) 13,930.21 91.93 197.53 6,260.57 6,113.57 -11,416.54 -1,180.59 5,937,572.34 486,750.48 2.57 11,416.54 MWD (3) 13,960.34 92.64 197.20 6,259.37 6,112.37 -11,445.28 -1,189.58 5,937,543.63 486,741.45 2.60 11,445.28 MWD (3) 13,990.16 92.98 194.98 6,257.91 6,110.91 -11,473.89 -1,197.83 5,937,515.03 486,733.15 7.52 11,473.89 MWD (3) 14,020.26 95.47 195.37 6,255.69 6,108.69 -11,502.86 -1,205.69 5,937,486.07 486,725.25 8.37 11,502.86 MWD (3) 14,050.17 98.00 195.51 6,252.19 6,105.19 -11,531.49 -1,213.59 5,937,457.46 486,717.30 8.47 11,531.49 MWD (3) 14,080.22 99.63 193.04 6,247.58 6,100.58 -11,560.27 -1,220.92 5,937,428.70 486,709.93 9.77 11,560.27 MWD (3) 14,108.23 99.78 193.08 6,242.86 6,095.86 -11,587.16 -1,227.16 5,937,401.82 486,703.65 0.55 11,587.16 MWD (3) 14,140.42 99.72 191.33 6,237.41 6,090.41 -11,618.17 -1,233.86 5,937,370.83 486,696.89 5.36 11,618.17 MWD (3) 14,173.14 99.18 191.15 6,232.03 6,085.03 -11,649.82 -1,240.15 5,937,339.18 486,690.55 1.74 11,649.82 MWD (3) 14,205.00 98.01 190.55 6,227.27 6,080.27 -11,680.76 -1,246.08 5,937,308.26 486,684.57 4.12 11,680.76 MWD (3) 14,229.70 96.74 189.34 6,224.10 6,077.10 -11,704.89 -1,250.31 5,937,284.14 486,680.30 7.07 11,704.89 MWD (3) 14,260.07 95.26 188.38 6,220.93 6,073.93 -11,734.73 -1,254.96 5,937,254.31 486,675.60 5.80 11,734.73 MWD (3) 14,290.62 93.90 187.40 6,218.49 6,071.49 -11,764.89 -1,259.14 5,937,224.15 486,671.38 5.48 11,764.89 MWD (3) 14,320.00 93.87 185.92 6,216.50 6,069.50 -11,794.01 -1,262.54 5,937,195.05 486,667.93 5.03 11,794.01 MWD (3) 14,350.21 93.94 185.19 6,214.44 6,067.44 -11,824.01 -1,265.46 5,937,165.06 486,664.97 2.42 11,824.01 MWD (3) 14,380.10 92.46 182.50 6,212.77 6,065.77 -11,853.78 -1,267.46 5,937,135.29 486,662.92 10.26 11,853.78 MWD (3) 14,410.13 91.69 179.58 6,211.68 6,064.68 -11,883.78 -1,268.01 5,937,105.29 486,662.33 10.05 11,883.78 MWD (3) 14,442.08 94.77 179.56 6,209.88 6,062.88 -11,915.68 -1,267.77 5,937,073.40 486,662.51 9.64 11,915.68 MWD (3) 14,462.79 96.09 177.53 6,207.92 6,060.92 -11,936.28 -1,267.24 5,937,052.79 486,663.00 11.65 11,936.28 MWD (3) 14,503.00 96.09 177.53 6,203.66 6,056.66 -11,976.23 -1,265.52 5,937,012.85 486,664.66 0.00 11,976.23 PROJECTED to TD Annotation F&AkI BAKER HUGHES 10/14/2016 10:05:43AM Page 5 COMPASS 5000.1 Build 74 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION NOV 0 4 2016 , 01 GC WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1a. Well Status: Oil Q ' Gas❑ SPLUG ❑ Other ❑ Abandoned ❑ Suspended ❑ 20AAC 25.105 20AAC 25.110 GINJ ❑ WINJ ❑ WAG❑ WDSPL ❑ No. of Completions: 1b. Well Class: Development 0 i Exploratory ❑ Service ❑ Stratigraphic Test ❑ 2. Operator Name: ConocoPhillips Alaska, Inc. 6. Date Comp., Susp., or Aband.: 10/7/2016 14. Permit to Drill Number/ Sundry: 216-096/ 3. Address: P.O. Box 100360 Anchorage, AK 99510-0360 7. Date Spudded: 10/2/2016 15. API Number: 50-103-20184-64-00 ' 4a. Location of Well (Governmental Section): Surface: 114' FSL, 109' FWL, Sec 27, T11N, R8E, UM Top of Productive Interval: 1357' FSL, 4514' FWL, Sec 4, T1 ON, R8E, UM Total Depth: 1303' FNL, 1181' FEL, Sec 9, T10N, R8E, UM 8. Date TD Reached: 10/6/2016 16. Well Name and Number: KRU 2M -08L1-01 9. Ref Elevations: KB:147 GL: 105.5 BF: 17. Field / Pool(s): Kuparuk River Field/Kuparuk Oil Pool 10. Plug Back Depth MD/TVD: 14498/6203 18. Property Designation: r�S ADL 25589, ADL 25 6 4b. Location of Well (State Base Plane Coordinates, NAD 27): Surface: x- 487949 y- 5948986 Zone -4 TPI: x- 487079 y- 5939672 Zone -4 Total Depth: x- 486665 y- 5937013 Zone -4 11. Total Depth MD/TVD: 14503/6204 19. Land Use Permit: ALK 2675 12. SSSV Depth MD/TVD: N/A 20. Thickness of Permafrost MD/TVD: 1495/1480 5. Directional or Inclination Survey: Yes 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: 11962/6215 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 42 121 43 121 24 250 sx AS II 95/8 47 L-80 42 4253 42 2744 121/4 660 sx PF E & 760 sx Class G 7 26 J-55 39 12138 39 6466 8 1/2 198 sx Class G 2 3/8 4.6 1 L-80 1 11745 114498 16171 6203 13 ISlotted Liner 24. Open to production or injection? Yes Ei No ❑ If Yes, list each interval open (MD/TVD of Top and Bottom; Perforation Size and Number): Slotted Liner @ 11745 - 14498 MD and 6171 - 6203 TVD COMPLET!ON neT�7 - / 25. TUBING RECORD SIZE DEPTH SET (MD) PACKER SET (MD/TVD) 3 1/2 11676 11538/6016 4 1/2 BTP 11759 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. Was hydraulic fracturing used during completion? Yes ❑ No 0 Per 20 AAC 25.283 (i)(2) attach electronic and printed information DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED 27. PRODUCTION TEST Date First Production: 10/21/2016 Method of Operation (Flowing, gas lift, etc.): GAS LIFT Date of Test: Hours Tested: Production for Oil -Bbl: Gas -MCF: Water -Bbl: Choke Size: Gas -Oil Ratio: Date of Test: 10/20/2016 Hours Tested: 17.7 Production for Test Period Oil -Bbl: 535.88 Gas -MCF: 772.81 Water -Bbl: 956.94 Choke Size: 176 Gas -Oil Ratio: 1665 scf/stb Flow Tubing Press. 238.4 Casinq Press: 1268psi Calculated -Jo. 24 -Hour Rate Oil -Bbl: 727 Gas -MCF: 1049 Water -Bbl: 1299 Oil Gravity - API (corr): 24 J aN11;L- Form 10-407 Revised 11/2015 'A. 4 �r CONTINUED ON PAGE 2 RB�M `J C `' NO jl� % 2016 Submit ORIGINIAL only. 28. CORE DATA Conventional Core(s): Yes ❑ No 0 Sidewall Cores: Yes ❑ No E 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 Fz] If yes, list intervals and formations tested, briefly summarizing test results. Permafrost - Top Surface Surface Permafrost - Base 1495 1480 Attach separate pages to this form, if needed, and submit detailed test Top of Productive Interval 11745 6171 information, including reports, per 20 AAC 25.071. A4 14046 6253 A5 14320 6217 C4 14344 6215 TD(Kuparuk A4) 14503 6204 Formation at total depth: C4 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, paleontological reoort, i)roduction or well test results, 1)er 20 AAC 25.070. 32. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Jeff Connelly (aD 263-4112 Email: eff.s.connell co .com Printed Name: K. Starck Title: CTD Supervisor & Superintendent Si nature:4�S&5� Phone: 263-4172 Date: INSTRUCTIONS General: This form and the required attachments provide a complete and concise record for each well drilled in Alaska. Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed. All laboratory analytical reports regarding samples or tests from a well must be submitted to the AOGCC, no matter when the analyses are conducted. Item 1 a: Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Item 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 2M-08 Proposed CTD Schematic 16"62# H-40 shoe @ 121' MD 9-5/8" 47# L-80 shoe @ 4253' MD KOP @ 11,745- MD 6171' TVD A5 -sand perfs 11721'- 11750' MD A3 -sand perfs 11784' - 11807' MD E # J-55 shoe @ 8' MD Baker Orbit Valve at 4485' MD (RKB) (2.835" minimum ID) 3-1/2" 9.3# L-80 ELIE 8rd Tubing to surface 3-1/2" Camco KBMG gas lift mandrels @ 3648', 6335', 8411', 9918', 10923', 11453' (RKB) Baker PBR @ 11,516' MD Baker FHL packer @ 11539' MD (RKB) 3-1/2" X Nipple 11,592' MD (2.812" min ID) (RKB) 2M-081-1 (A4 South) TD @ 15,650' MD Liner Bottom @ 15,650' MD Billet @ 11,962' MD 2M-081-1-01 (A3 South West) TD @ 14,503' MD Bottom of Liner @ 14,498' Top of Liner @ 11,745' MD Operations Summary (with Timelog Depths) 2M-08 Rig: NABORS CDR2-AC Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time Dur (fir) Phase Op Code Activity Code Time P -T -X Operation (ftKB) :End Depth (ftKB) 9/20/2016 9/20/2016 1.50 MIRU WHDBOP NUND P RU MP lines and upper swab valve. 0.0 0.0 18:00 19:30 Finish cellar work. 9/20/2016 9/20/2016 1.50 SLOT WELLPR CTOP P PJSM, RU SLB N2 and blow down 0.0 0.0 19:30 21:00 reel. 9/20/2016 9/21/2016 3.00 SLOT WELLPR CTOP P Pull coil through injector and secure 0.0 0.0 21:00 00:00 to reel. 9/21/2016 9/21/2016 2.00 SLOT WELLPR CTOP P Pull back coil and secure it to the reel. 0.0 0.0 00:00 02:00 Lower coil tubing reel off rig. 9/21/2016 9/21/2016 2.85 SLOT WELLPR SLKL P RU Slickline to RIH, set catcher and 0.0 0.0 02:00 04:51 pull SOV. Dummy GLM #3. Pull catcher and plug in tailpipe. Slickline pulled SOV and is now heading back in hole to set DV. 9/21/2016 9/21/2016 6.00 SLOT WELLPR SVRG T Replaced pillar blocks, reel drive and 0.0 0.0 04:51 10:51 bull gear. 9/21/2016 9/21/2016 1.25 SLOT WELLPR CTOP P New coil spool #50044 has arrived on 0.0 0.0 10:51 12:06 site. Peform PJSM with Nabors and Peak hands.............install new spool.................Slickline has installed DV and successfully pressure tested tubing ............. 9/21/2016 9/21/2016 2.00 SLOT WELLPR CTOP P Begin securing and prepping new coil 0.0 0.0 12:06 14:06 reel...............Slickline RBIH to pull prong......... 9/21/2016 9/21/2016 2.25 SLOT WELLPR CTOP P Prong on surface. RBIH and retrieve 0.0 0.0 14:06 16:21 plug..................POOH with plug ........... Plug at surface. 9/21/2016 9/21/2016 0.45 SLOT WELLPR SLKL P Close Orbit Valve. 0.0 0.0 16:21 16:48 9/21/2016 9/21/2016 2.00 SLOT WELLPR SLKL P RD slickline and clear rig floor. 0.0 0.0 16:48 18:48 9/21/2016 9/22/2016 5.20 SLOT WELLPR CTOP P Install inner reel iron and terminate 0.0 18:48 00:00 bulkhead. 9/22/2016 9/22/2016 3.00 SLOT WELLPR CTOP P Installed inner reel iron. Terminated 0.0 0.0 00:00 03:00 the bulkhead. Changed BOP packoffs. 9/22/2016 9/22/2016 5.88 SLOT WELLPR CTOP P Pull testing injector to 100K. Chains 0.0 0.0 03:00 08:52 slipping at 75K. Changed the stripper brass. Having issues with removing the stripper brass......... having to beat it out ............... 9/22/2016 9/22/2016 0.38 SLOT WELLPR CTOP P Stripper brass has been changed, 0.0 0.0 08:52 09:15 start pull testing again to 100k 9/22/2016 9/22/2016 0.43 SLOT WELLPR CTOP P Pull test to 105k successful. Remove 0.0 0.0 09:15 09:41 test joint. 9/22/2016 9/22/2016 0.42 SLOT WELLPR CTOP P PJSM for stabbing coil. 0.0 0.0 09:41 10:06 Page 1/13 Report Printed: 10/10/2016 Operations Summary (with Timelog Depths) m 2M-08 K1 F Rig: NABORS CDR2-AC Job: DRILLING SIDETRACK Time Log Start Depth:... Start Time End Time Dur (hr) Phase Op Code Activity Code Time P -T -X Operation (ftK6) End Depth (ftKB) 9/22/2016 9/22/2016 7.10 SLOT WELLPR CTOP P Begin stabbing coil operations and 0.0 0.0 10:06 17:12 then install coil connector ............ pull test to 50k .... install UQC, etc. .......fluid pack coil tubing and pressure test ........... coil connector and reel iron all good ........... depressure and install nozzle on BHA ................. ****Note = Contacted AOGCC Inspector Guy Cook at 16:20 hrs to inform him we were ready for the BOPE test and he waived witness on this test due to a rig move blocking the spine road from Deadhorse. **** 9/22/2016 9/23/2016 6.79 MIRU WHDBOP BOPE P BOPE test. New swab valve failed and 0.0 0.0 17:12 00:00 called grease crew. Continued on with the test. Greased tree valves and swab valve passed. 9/23/2016 9/23/2016 2.75 MIRU WHDBOP BOPE P Tested BOPE. 0.0 0.0 00:00 02:45 9/23/2016 9/23/2016 1.00 MIRU WHDBOP RURD P RD BOPE test equipment 0.0 0.0 02:45 03:45 9/23/2016 9/23/2016 0.50 SLOT WELLPR CTOP P Pump a -line slack forward. 0.0 0.0 03:45 04:15 9/23/2016 9/23/2016 0.25 SLOT WELLPR OWFF P Open Master Valve and flow check 0.0 0.0 04:15 04:30 against closed Orbit Valve. 9/23/2016 9/23/2016 0.45 PROD1 RPEQPT PULD P Baker hand on site. Initiate PJSM prior 0.0 0.0 04:30 04:57 to making up Whipstock setting BHA. 9/23/2016 9/23/2016 2.65 PROD1 RPEQPT PULD P Pick up Whipstock setting 0.0 0.0 04:57 07:36 BHA ................. 9/23/2016 9/23/2016 0.35 PROD1 RPEQPT PULD P Open Orbit Vlave...... 0.0 0.0 07:36 07:57 9/23/2016 9/23/2016 0.58 PROD1 RPEQPT PRTS P Go to well with BHA and pressure test. 0.0 0.0 07:57 08:31 9/23/2016 9/23/2016 2.80 PROD1 RPEQPT WPST P Open well and RIH with EDC open 0.0 0.0 08:31 11:19 pumping at minimum rate 9/23/2016 9/23/2016 0.45 PROD1 RPEQPT EQRP T Stop RIH to work on reel ........... tighten 11,000.0 11,000.0 11:19 11:46 saddle bolts ................. 9/23/2016 9/23/2016 0.12 PROD1 RPEQPT WPST P Continue RIH............. 11,580.0 11,580.0 11:46 11:54 9/23/2016 9/23/2016 0.76 PROD1 RPEQPT DLOG P Tie into K1 Marker..............RIH speed 11,580.0 11,650.0 11:54 12:39 at 3 fpm 9/23/2016 9/23/2016 0.14 PROD1 RPEQPT DLOG P Missed K1 Marker................PUH and 11,650.0 0.0 12:39 12:48 Log again.......... 9/23/2016 9/23/2016 0.20 PROD1 RPEQPT DLOG P @ 11,571...............RBIH at 3 fpm 11,571.0 11,643.0 12:48 13:00 logging again......... 9/23/2016 9/23/2016 0.04 PROD1 RPEQPT DLOG P @ 11,643' ........Finished 11,643.0 11,643.0 13:00 13:02 logging ....make correction of + 37.5'............ 9/23/2016 9/23/2016 0.14 PROD1 RPEQPT DLOG P PUH to 11,490'to ruin CCL ............... 11,643.0 11,490.0 13:02 13:10 9/23/2016 9/23/2016 0.31 PR RPEQPT DLOG P Log CCL........ 11,490.0 11,831.0 13:10 13:29 11 9/23/2016 9/23/2016 0.35 PROD1 RPEQPT WPST P PUH to 11,600', check CCL Log, looks 11,831.0 11,600.0 13:29 13:50 good, RBIH to set Whipstock Page 2113 Report Printed: 10 0/2 01 6 Operations Summary (with Timelog Depths) 2M-08 Rig: NABORS CDR2-AC Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time Dur (hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth (ftKB) 9/23/2016 9/23/2016 0.08 PROD1 RPEQPT WPST P On set depth, P/U weight, close EDC. 11,758.0 11,758.0 13:50 13:55 Bring pump online and set Whipstock. Top of whipstock is at 11,745'..0 degrees / High side..... set down 3k over to verify set ..... good set....... 9/23/2016 9/23/2016 0.90 PROD1 RPEQPT DISP P Open EDC and begin poumping 8.6 11,730.0 11,730.0 13:55 14:49 ppg used flow-Pro to displace coil and wellbore................ 9/23/2016 9/23/2016 2.00 PROD1 RPEQPT TRIP P POOH pumping Flo-Pro and 11,730.0 0.0 14:49 16:49 maintaining 1:1's.............. 9/23/2016 9/23/2016 0.90 PROD1 RPEQPT OWFF P At surface. Close Orbit Valve. Check 0.0 0.0 16:49 17:43 for flow.............no flow ............ 9/23/2016 9/23/2016 0.53 PROD1 RPEQPT PULD P L/D BHA #1, whipstock setting BHA. 0.0 0.0 17:43 18:15 Lost 7 bbls of used 8.6ppg FloPro on TOOK 9/23/2016 9/23/2016 1.75 PROD1 WHPST PULD P P/U BHA #2, Window milling BHA. 0.0 0.0 18:15 20:00 9/23/2016 9/23/2016 2.50 PROD1 WHPST TRIP P Open Orbit valve and RIH. 0.0 11,600.0 20:00 22:30 9/23/2016 9/23/2016 0.50 PROD1 WHPST DLOG P Tie-in to the K1 marker. Plus 18' 11,600.0 11,747.0 22:30 23:00 correction. Close EDC and get PU wt 38K. 9/23/2016 9/24/2016 1.00 PROD1 WHPST WPST P Tag WS pinch point at 11,747' (TOWS 11,747.0 11,748.0 23:00 00:00 at 11,745'). Start milling window. Losses 2.5 bbl/hr. 9/24/2016 9/24/2016 5.00 PROD1 WHPST WPST P Milling window at 11,748'. Losses 2.5 11,748.0 11,754.0 00:00 05:00 bbl/hr. 9/24/2016 9/24/2016 3.68 PROD1 WHPST WPST P Continue milling window from 11,748' 11,754.4 11,755.3 05:00 08:40 per recommended practice and Baker Rep. 1.5 bpm at 3,708 psi, IA 838, OA 184, CWT 7.06, WOB 2.18 9/24/2016 9/24/2016 4.89 PROD1 WHPST WPST P Stall..............PUH and bring pump 11,755.3 11,758.6 08:40 13:34 back online.............RBIH to 11,755.3' and continue milling window per recommended practice and Baker Rep. 1.5 bpm at 3,728 psi, IA 857, OA 200, CWT 7.06, WOB 2.18 9/24/2016 9/24/2016 2.25 PROD1 WHPST WPST P @ 11,758.6' and bit and string reamer 11,758.6 11,770.0 13:34 15:49 should now be out the 7" window ( big drop in WOB) ............ continue drilling into formation 25' past TOWS per recommended practice and Baker Rep......... 1.5 bpm at 3,745, IA 890, OA 245, CWT 9.31, WOB 2.04 9/24/2016 9/24/2016 1.35 PROD1 WHPST REAM P @ 11,770.0' TD Rathole............ PUH 11,770.0 11,745.0 15:49 17:10 to backream window area @ 1 fpm with 3 up and down passes .......... dry drift window with no issues........... 9/24/2016 9/24/2016 3.00 PROD1 WHPST TRIP P POOH with BHA #2 (window milling 11,745.0 0.0 17:10 20:10 assembly). Open EDC. Close Orbit Valve. Close EDC. Flow check well. 9/24/2016 9/24/2016 1.25 PROD1 WHPST PULD P LD BHA #2 (window milling 0.0 0.0 20:10 21:25 assembly). 9/24/2016 9/24/2016 1.80 PROD1 DRILL PULD P PU BHA #3 (Build drilling BHA 0.0 0.0 21:25 23:13 w/2.2°bend motor). Open EDC. Open Orbit valve. Page 3/13 Report Printed: 10/10/2016 Operations Summary (with Timelog Depths) 2M-08 Rig: NABORS CDR2-AC Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time Dur (hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth (ftKB) 9/24/2016 9/25/2016 0.78 PROD1 DRILL TRIP P RIH with BHA #3 (Build drilling BHA 0.0 3,800.0 23:13 00:00 w/2.21bend motor). 9/25/2016 9/25/2016 1.75 PROD1 DRILL TRIP P RIH to drill the build section. 3,800.0 11,770.0 00:00 01:45 9/25/2016 9/25/2016 2.75 PROD1 DRILL DRLG P Drilling Build section. ROP 46 fph, 11,700.0 11,845.0 01:45 04:30 losses 2.5 bph. PU WT 35K, FS 3800 psi . 9/25/2016 9/25/2016 3.88 PROD1 DRILL DRLG P @ 12,000....... End of build section. 11,845.0 12,000.0 04:30 08:22 DLS avg. - 42.5°, max - 45.7°, min - 33° Pump 5 bbl hi/lo sweep and chased up hole to 3.5 x 4.5 crossover..............RBIH and PUH again to thoroughly clean area ............ pretty consistant solids amounts coming across shaker while drilling build section............... Following information recorded at window as requested: Density Out: 8.78 BHP: 3,700 Choke Press: 550 9/25/2016 9/25/2016 2.10 PROD1 DRILL TRIP P POOH chasing returns to surface...... 12,000.0 87.7 08:22 10:28 9/25/2016 9/25/2016 0.47 PROD1 DRILL OWFF P At surface. Close Orbit Valve and 87.7 0.0 10:28 10:57 check for flow..............no flow........... 9/25/2016 9/25/2016 0.78 PROD1 DRILL PULD P UD Build Section BHA (#3) 0.0 0.0 10:57 11:43 9/25/2016 9/25/2016 1.10 PROD1 DRILL PRTS P Pressure test PDL which was just put 0.0 0.0 11:43 12:49 back together yesterday after the workover operation................remove PDL after pressure test............ 9/25/2016 9/25/2016 0.91 PROD1 DRILL PULD P P/U BHA #4, 2M-08 L1 Lateral Drilling 0.0 69.2 12:49 13:44 BHA w/RSM ............ stab onto well .... test MWD..... replace packoffs........... Open Orbit Valve........... 9/25/2016 9/25/2016 2.40 PROD1 DRILL TRIP P RBIH with 2M-08 L1 Lateral drilling 69.2 11,550.0 13:44 16:08 BHA............. 9/25/2016 9/25/2016 0.62 PROD1 DRILL DLOG P Tie in to K1 Marker and make 11,550.0 11,780.0 16:08 16:45 correction of +14.5................continue RIH and log RA...............RA @ 11,752.5............ '*'Note: Small weight bobble entering window with RSM............ 9/25/2016 9/25/2016 0.12 PROD1 DRILL TRIP P Continue RIH to drill L1 11,780.0 12,000.0 16:45 16:52 Lateral.................. 9/25/2016 9/25/2016 0.63 PROD1 DRILL DRLG P at 12,000' BOBD..............swapping to 12,000.0 12,023.0 16:52 17:30 new 8.6 ppg Flo-Pro mud system ......... 9/25/2016 9/26/2016 6.49 PROD1 DRILL DRLG P Drilling L1 Lateral section. ROP 56 12,023.0 12,365.0 17:30 00:00 fph, losses 2 bph. PU WT 36K, FS 4141 psi . 9/26/2016 9/26/2016 2.00 PROD1 DRILL DRLG P Drilling L1 lateral section. ROP 46 fph, 12,365.0 12,505.0 00:00 02:00 losses 1.5 bph. PU WT 35K, FS 3800 psi . Page 4/13 ReportPrinted: 10/10/2016 Operations Summary (with Timelog Depths) a. 2M-08 Rig: NABORS CDR2-AC Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time Our (hr) Phase Op Code Activity Code Time P -T -X Operation (W) End Depth (ftKB) 9/26/2016 9/26/2016 1.20 PROD1 DRILL WPRT P Wiper trip to window. 12,505.0 12,505.0 02:00 03:12 Mud wt IN 8.71 ppg/ OUT 8.75ppg. Flow rate IN 1.5gpm/OUT 1.48 gpm. BHP 3803. Choke 250 psi. ECD 12.24 ppg- 9/26/2016 9/26/2016 1.80 PROD1 DRILL DRLG P BOBD drilling at 70 fph, 12,505.0 12,755.0 03:12 05:00 9/26/2016 9/26/2016 2.50 PROD1 DRILL DRLG P Drilling ahead in L1 Lateral @ 60 fpm, 12,755.0 12,905.0 05:00 07:30 Circ Press - 4,014, WHP - 214, Pump Rate 1.5 bpm, BHP = 3,893, IA - 394, OA - 327 9/26/2016 9/26/2016 2.33 PROD1 DRILL DRLG P @ 12,905' ...........PUH to check 12,905.0 12,955.0 07:30 09:49 weights as per CTD Engineer ......... PUW = 38K ............ RBIH and continue drilling ahead......... at 89 fph, WOB - 1.73, Circ Press - 4,051, WHP - 218, BHP - 3,924, IA - 435, OA - 383, CTW - 8.97 9/26/2016 9/26/2016 0.80 PROD1 DRILL DRLG P @ 12,955' ...........PUH to check 12,955.0 13,005.0 09:49 10:37 weights again as per CTD Engineer ......... PUW = 38K again with an occasional 39k seen ............ RBIH and continue drilling ahead......... at 89 fph, WOB - 1.73, Circ Press - 4,051, WHP - 218, BHP - 3,924, IA - 435, OA 383, CTW - 8.97 9/26/2016 9/26/2016 0.51 PROD1 DRILL WPRT P @ 13,005 ............ Stop here and 13,005.0 11,680.0 10:37 11:08 perform a wiper trip up to the 3.5 x 4.5 XO ..... ...... only a slight weight bobble coming through window......... 9/26/2016 9/26/2016 0.78 PROD1 DRILL WPRT P @ 11,678.............RBIH to 11,680.0 13,005.0 11:08 11:55 bottom.............Tie in to RA marker make a +3' correction............ 9/26/2016 9/26/2016 0.70 PROD1 DRILL DRLG P @ 13,005 ......... ...BOBD......... 1.5 bpm, 13,005.0 13,072.0 11:55 12:37 Circ Press = 4,259, WHP = 151, BHP = 3,883, IA = 456, OA = 385, 9.6 fph. WOB = 2.09 After drilling about 40' ahead hit something hard and ROP as slowed way down........... 9/26/2016 9/26/2016 4.38 PROD1 DRILL DRLG P Drilling with1.59 bpm, Circ Press = 13,072.0 13,072.0 12:37 17:00 4,381, BHP = 3,904, 4 fph. WOB = 1.9K 9/26/2016 9/26/2016 2.00 PROD1 DRILL DRLG P Drilling with1.56 bpm, Circ Press = 13,072.0 13,085.0 17:00 19:00 4,264, BHP = 3,958, 7 fph. WOB = 1.7K 9/26/2016 9/27/2016 5.00 PROD1 DRILL DRLG P Drilling with1.56 bpm, Circ Press = 13,085.0 13,222.0 19:00 00:00 4,211, BHP = 3,980, 57 fph. WOB = 1.7K 9/27/2016 9/27/2016 3.00 PROD1 DRILL DRLG P Drilling with1.54 bpm, Circ Press = 13,222.0 13,380.0 00:00 03:00 4,400, BHP = 3,954, 89 fph. WOB = 1.8K 9/27/2016 9/27/2016 0.75 PROD1 DRILL WPRT P Pulling a 1 000'wiper trip after drilling 13,380.0 13,380.0 03:00 03:45 380'. 9/27/2016 9/27/2016 6.85 PROD1 DRILL DRLG P BOBD with 1.53 bpm, Circ Press = 13,380.0 13,780.0 03:45 10:36 4,164, BHP = 3,946, 40 fph. WOB = 1.4K 9/27/2016 9/27/2016 0.55 PROD1 DRILL WPRT P Wiper trip up hole to 12,250 ft., PUW 13,780.0 12,250.0 10:36 11:09 39k. Page 5/13 Report Printed: 10/10/2016 Operations Summary (with Timelog Depths) 2M-08 Rig: NABORS CDR2-AC Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time our (hr) Phase Op Code Activity Code Time P -T -X Operation (ftKB) End Depth (ftKB) 9/27/2016 9/27/2016 0.65 PROD1 DRILL WPRT P Wiper back in hole, RIW 10k 12,250.0 13,780.0 11:09 11:48 9/27/2016 9/27/2016 8.20 PROD1 DRILL DRLG P BOBD- 1.5 bpm at 3,910 psi FS, BHP 13,780.0 14,180.0 11:48 20:00 3,932 psi, CWT 8.7k, WOB 1.4k, ROP 80, WHP 9, IA 550, OA 455. Note: Mud swap with new mud out bit at 13,925 ft. 9/27/2016 9/27/2016 1.25 PROD1 DRILL WPRT P 14,180 ft, Wiper up hole PUW 40k, 14,180.0 11,760.0 20:00 21:15 perform jog below EOB 12,000 ft - 12,100 ft, continue wiper up hole, pull up thru window, jog the 4.5" 11,690 ft - 11,730 ft 9/27/2016 9/27/2016 0.25 PROD1 DRILL DLOG P 11,760 ft, log RA correction of plus 7 ft 11,760.0 11,771.0 21:15 21:30 9/27/2016 9/27/2016 0.25 PROD1 DRILL WPRT P Perform Choke Calibration, holding 11,771.0 11,800.0 21:30 21:45 11.8 ppg at the window sensor depth (40' from bit) CP= 200 psi MWO= 8.66 ppg FO= 1.59 bpm BHP= 3689 psi 9/27/2016 9/27/2016 0.75 PROD1 DRILL WPRT P 11,800 ft, Wiper back in hole RIW 13k 11,800.0 14,180.0 21:45 22:30 9/27/2016 9/28/2016 1.50 PROD1 DRILL DRLG P 14,180 ft, BOBD 1.6 bpm at 3764 psi, 14,180.0 14,264.0 22:30 00:00 BHP 3968, IA 531, OA 434 9/28/2016 9/28/2016 4.00 PROD1 DRILL DRLG P 14,264 ft, OBD 1.54 bpm at 3890 psi, 14,264.0 14,433.0 00:00 04:00 BHP 3989, WHP 274, IA 572, OA 448 9/28/2016 9/28/2016 0.50 PROD1 DRILL WPRT P 14,433 ft, Wiper up hole to 13,430 ft. 14,433.0 13,430.0 04:00 04:30 PUW 41k 9/28/2016 9/28/2016 0.50 PROD1 DRILL WPRT P 13,430 ft, wiper back in hole RIW 10k 13,430.0 14,433.0 04:30 05:00 9/28/2016 9/28/2016 3.65 PROD1 DRILL DRLG P 14,433 ft, BOBD 1.55 bpm at 3900 psi 14,433.0 14,681.0 05:00 08:39 FS, BHP 3945, WHP 56, IA 615, OA 475, pump 5x5 sweep 9/28/2016 9/28/2016 0.45 PROD1 DRILL WPRT P 14,681 ft. Wiper up hole, PUW 40k 14,681.0 13,481.0 08:39 09:06 9/28/2016 9/28/2016 0.45 PROD1 DRILL WPRT P 13,480 ft. Wiper back in hole, RIW 13,481.0 14,681.0 09:06 09:33 8.Ok 9/28/2016 9/28/2016 3.75 PROD1 DRILL DRLG P 14,681 ft. BOBD 1.55 bpm at 3,960 14,681.0 14,822.0 09:33 13:18 FS, BHP 4,018, CWT 6k, WOB 1.4k, ROP84, WHP 54, IA 640, OA 514. weight issue, pump 5x5, pull 500 ft wiper at 14,775 ft., RBIH, ROP 75 for a short period, surface weight issues, pump 5x5. 9/28/2016 9/28/2016 4.75 PROD1 DRILL TRIP P 14,822 ft. POOH for Agitator and 14,822.0 69.2 13:18 18:03 motor, PUW 42k, perform jog below EOB 12,000 ft. -12,300 ft. continue POOH, pull up thru window, jet/jog the 4.5" 11,690 ft. -11,730 ft. continue POOH, open EDC at —4,600 ft. jet past Orbit Valve at 5 ft/hr, POOH. 9/28/2016 9/28/2016 1.50 PROD1 DRILL PULD P At surface, Close Orbit valve, monitor, 69.2 0.0 18:03 19:33 LD BHA #4, bit condition 1 -2 -BT -A -X-1 -PN-BHA 9/28/2016 9/28/2016 0.25 PROD1 DRILL PULD P PJSM, function test BOPE 0.0 0.0 19:33 19:48 Page 6/13 Report Printed: 10/10/2016 Operations Summary (with Timelog Depths) -' 2M-08 Rig: NABORS CDR2-AC Job: DRILLING SIDETRACK Time Log Start Depth Start Time End'. Time Dur (hr) Phase Op Code Activity Code Time P -T -X Operation (ftKB) End Depth.(ftKB) 9/28/2016 9/28/2016 2.00 PROD1 DRILL PULD P PJSM, MU L1 drilling assembly BHA# 0.0 78.3 19:48 21:48 5, with agitator 9/28/2016 9/29/2016 2.20 PROM DRILL TRIP P RIH, with drilling BHA# 5 78.3 9,948.0 21:48 00:00 9/29/2016 9/29/2016 0.25 PROM DRILL TRIP P 9,948 ft, continue RIH to tie in depth. 9,948.0 11,575.0 00:00 00:15 9/29/2016 9/29/2016 0.25 PROD1 DRILL DLOG P 11,575 ft, log the K1 correction of plus 11,575.0 11,639.0 00:15 00:30 10.0 ft, PUW 36k 9/29/2016 9/29/2016 1.40 PROD1 DRILL TRIP P 11,639 ft, continue trip in hole, RIW 11,639.0 14,822.0 00:30 01:54 14k 9/29/2016 9/29/2016 7.80 PROD1 DRILL DRLG P 14,822 ft, OBD 1.4 bpm at 3985 psi, 14,822.0 15,111.0 01:54 09:42 BHP 4016, WHP 92, IA 450, OA 331, several BHA wipers, pump 5x5. 9/29/2016 9/29/2016 0.45 PROM DRILL WPRT P 15,111 ft. Wiper up hole, PUW 41 k, 15,111.0 14,000.0 09:42 10:09 2k overpull at 14,689 ft. no problem up thru 14,100 ft to 14,340 ft, no problem at 14,689 ft. 9/29/2016 9/29/2016 0.45 PROD1 DRILL WPRT P 14,000 ft, Wiper back in hole, RIW 5k, 14,000.0 15,111.0 10:09 10:36 no problems RBIH. 9/29/2016 9/29/2016 6.50 PROM DRILL DRLG P 15,111 ft, BOBD 1.5 bpm at 4,268 15,111.0 15,390.0 10:36 17:06 FS, BHP 4,080 psi, CWT 4.6k, WOB 1.5k, ROP 38, WHP 6, IA 600, OA 448, pump 5x5 for wiper trip. 9/29/2016 9/29/2016 2.00 PROD1 DRILL WPRT P 15,390 ft, wiper up hole PUW 40k, 15,390.0 15,390.0 17:06 19:06 RBIH stacked out at -15,120 ft, PUH, lower pump rate to 1.0 bpm, RBIH to 15,255 ft, wiper up hole at 25 fpm up to 14,950 ft, continue wiper back in hole 9/29/2016 9/29/2016 3.25 PROM DRILL DRLG P 15,390 ft, BOBD 1.5 bpm at 4189 psi, 15,390.0 15,512.0 19:06 22:21 BHP 4609, WHP 0, IA 637, OA 463 9/29/2016 9/30/2016 1.66 PROM DRILL WPRT P 15512 ft, wiper up hole performing jog 15,512.0 11,940.0 22:21 00:00 12,000 ft -12,200 ft, PUW 49 k 9/30/2016 9/30/2016 0.25 PROM DRILL WPRT P Continue wiper up hole thru window, 11,940.0 11,690.0 00:00 00:15 jet 4.5" up to 11,690 ft 9/30/2016 9/30/2016 0.15 PROM DRILL WPRT P RBIH, to tie in depth 11,690.0 11,758.0 00:15 00:24 9/30/2016 9/30/2016 0.25 PROM DRILL DLOG P 11,758 ft, log RA marker correction of 11,758.0 11,808.0 00:24 00:39 plus 5.0 ft 9/30/2016 9/30/2016 1.20 PROM DRILL WPRT P 11808 ft, continue wiper in hole, RIW 11,808.0 15,512.0 00:39 01:51 10k 9/30/2016 9/30/2016 2.90 PROM DRILL DRLG P 15,512 ft, BOBD 1.5 bpm at 4000 psi, 15,512.0 15,603.0 01:51 04:45 BHP 4031, WHP 0, IA 609, OA 423 9/30/2016 9/30/2016 0.20 PROD1 DRILL WPRT P 15,603 ft, short BHA wiper up hole to 15,603.0 15,603.0 04:45 04:57 15,250 ft. PUW 41k 9/30/2016 9/30/2016 2.50 PROM DRILL DRLG P 15,603 ft, BOBD 1.51 bpm @ 4,465 15,603.0 15,650.0 04:57 07:27 psi FS, BHP 4,170 psi, CWT -4.0k, WOB 1.2k, ROP 21, IA 618, OA 418 9/30/2016 9/30/2016 1.90 PROD1 DRILL WPRT P 15,650 ft. TD called. Wiper to window, 15,650.0 11,690.0 07:27 09:21 PUW 39k, 1 k over pull at 15,548 ft, pulled 2k heavy 15,000 ft to 14,930 ft at 25 fpm, nothing noticable thru upper high Gama area, Jog EOB 12,00 ft to 12,200 ft, pull up into and jog 4.5" BTP 11,690 ft to 11,735 ft. 9/30/2016 9/30/2016 0.25 PROM DRILL DLOG P RBIH, tie in to RA marker for a plus 11,690.0 11,791.0 09:21 09:36 1 4.5 ft correction. Page 7/13 Report Printed: 10/10/2016 Operations Summary (with Timelog Depths) 2M-08 Rig: NABORS CDR2-AC Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time Dur (hr) Phase Op Code Activity Code Time P -T -X Operation (ftKB) End Depth (ftKB) 9/30/2016 9/30/2016 1.55 PROM DRILL WPRT P RIH to confirm TD, stack at 15,455 ft, 11,791.0 15,650.0 09:36 11:09 RIH 30 fpm at .85 bpm, no WOB increase, PU 37k, stack and fell thru, TF transition L90 to R90 when drilling, confirm TD at 15,650 ft. 9/30/2016 9/30/2016 0.95 PROM DRILL CIRC P PUH circulating beaded liner running 15,650.0 15,650.0 11:09 12:06 pill to bottom, RBIH. 9/30/2016 9/30/2016 3.75 PROM DRILL TRIP P POOH laying in 45 bbl beaded liner 15,650.0 78.0 12:06 15:51 running pill / 8.6 ppg completion fluid to surface. paint flags at 13,630 ft and 7,900 ft. 9/30/2016 9/30/2016 1.75 PROM DRILL PULD P At surface, Close Orbit valve, monitor, 78.0 0.0 15:51 17:36 LD drilling BHA #5, bit condition: 9/30/2016 9/30/2016 1.00 COMPZ1 CASING PUTB P Prep rig floor for MU liner, crew 0.0 0.0 17:36 18:36 change, perform valve check list. 9/30/2016 9/30/2016 4.50 COMPZ1 CASING PUTB P PJSM, MU first L1 liner section with 63 0.0 1,874.8 18:36 23:06 jts of slotted liner 9/30/2016 10/1/2016 0.90 COMPZ1 CASING PULD P PJSM, MU Coiltrak tools, swap out 1,874.8 1,874.8 23:06 00:00 checks 10/1/2016 10/1/2016 0.25 COMPZ1 CASING PUTB P Continue MU Coiltrak tools, swap out 1,874.8 1,919.0 00:00 00:15 checks in upper quick ( both checks jammed open w/beads) 10/1/2016 10/1/2016 2.80 COMPZN CASING RUNL P 1919 ft, RIH with lower L1 liner section 1,919.0 11,616.0 00:15 03:03 with 63 jts of slotted liner and shorty deployment sleeve. 10/1/2016 10/1/2016 1.00 COMPZ1 CASING RUNL P 11,616 ft, corrected to the EOP flag 11,616.0 13,460.0 03:03 04:03 9700 ft. minus 2.6 ft PUW 35 k 10/1/2016 10/1/2016 0.25 COMPZ1 CASING DLOG P 13,460 ft, log the K1 correction of plus 13,460.0 13,484.0 04:03 04:18 5.5 ft, no correction made to counters. 10/1/2016 10/1/2016 0.65 COMPZ1 CASING RUNL P 13,484 ft, continue RIH to bottom 13,484.0 15,650.0 04:18 04:57 10/1/2016 10/1/2016 0.60 COMPZ1 CASING RUNL T L1 lower liner section on bottom 15,650.0 13,776.0 04:57 05:33 15,650 ft, PUW 39k,WOB -3.3k, Bring pump up to 1.5 bpm, PUW 34k, WOB -3.4k, loss of surface weight looks good but WOB did not change, 6 more various attempts with same results, confer with Prudhoe Baker rep., liner gone. reset counters to GS. 10/1/2016 10/1/2016 1.75 COMPZ1 CASING RUNL T 13,776 ft. POOH, PUW 40k, WOB- 13,776.0 12,538.6 05:33 07:18 3.3k, clean thru window but PUW 40k & WOB increasing to -6.2k at 10,671 ft. Confer with town. reset counters to liner shoe. 10/1/2016 10/1/2016 0.25 COMPZ1 CASING RUNL T 12,538 ft. RBIH, RIW 12k, WOB 1.6k 12,538.6 13,465.0 07:18 07:33 10/1/2016 10/1/2016 0.15 COMPZ1 CASING DLOG T Log K1 for a plus 7.5 ft correction, no 13,465.0 13,485.0 07:33 07:42 correction made to counters. 10/1/2016 10/1/2016 0.80 COMPZ1 CASING RUNL T Continue RIH to bottom. 13,485.0 15,650.0 07:42 08:30 10/1/2016 10/1/2016 0.45 COMPZ1 CASING RUNL T 15,650 ft. On bottom, PUW 37k, WOB 15,650.0 15,650.0 08:30 08:57 -3.3k, sat back down with Ok CWT, WOB +4.45k pump 1.6 bpm at 4,300 psi, PUW 34k, WOB -3.1k, 3 more attempts to release off liner appears to be unsuccessful. Page 8113 Report Printed: 1 0/1 012 01 6 Operations Summary (with Timelog Depths) C c+a`a 2M-08 Rig: NABORS CDR2-AC Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time Dur (hr) Phase Op Code Activity Code Time P -T -X Operation (ftKB) End Depth (WB). 10/1/2016 10/1/2016 3.60 COMPZ1 CASING TRIP T POOH for liner, running tool check. 15,650.0 1,919.0 08:57 12:33 Stop and reset counters to GS, POOH paint flag at 9,700'. Continue POOH. 10/1/2016 10/1/2016 2.20 COMPZ1 CASING PULD T Tag up, space out, function closed 1,919.0 1,874.0 12:33 14:45 Orbit valve, monitor, PJSM- strip off wellhead, PU BHA to GS, no indication of why tool would not release, Shorty in new shape, inspect coil above CTC, pressure test coil to CTC to 800 psi, no leaks, BHA components appear competent. 10/1/2016 10/1/2016 1.25 COMPZ1 CASING PULD T PJSM- MU 2.63 OD Hyd GS and add 1,874.0 1,919.8 14:45 16:00 knuckle joint to BHA) make up to CoilTrak, lower QC neck un -torqued, changed out, surface test, strip on well, Open Orbit valve. 10/1/2016 10/1/2016 2.00 COMPZ1 CASING RUNL T RIH with lower L1 liner assembly on 1,919.8 11,521.0 16:00 18:00 BHA #7. 10/1/2016 10/1/2016 0.25 COMPZ1 CASING RUNL T Correct to the EOP flag (9,700 ft), 11,521.0 11,619.8 18:00 18:15 correction of plus 98.6 ft, realign INJH counter assembly PUW 33 k 10/1/2016 10/1/2016 1.50 COMPZ1 CASING RUNL T 11,620 ft, continue RIH 11,619.8 13,450.0 18:15 19:45 10/1/2016 10/1/2016 0.25 COMPZI CASING DLOG T 13,450 ft, Log the K1 correction of 13,450.0 13,491.0 19:45 20:00 plus 10.0 ft, 10/1/2016 10/1/2016 0.38 COMPZ1 CASING RUNL T 13,491 ft, continue RIH 13,491.0 15,550.0 20:00 20:22 10/1/2016 10/1/2016 0.25 COMPZ1 CASING RUNL T 15,550 ft, PUW 39.5 k, continued RIH, 15,550.0 15,650.0 20:22 20:37 brought pump up to 1.44 bpm, set down - 2 k CTSW, PUW 31 k, remove liner length from BHA 10/1/2016 10/1/2016 2.82 COMPZ1 CASING TRIP P 15,650 ft, POOH 15,650.0 45.0 20:37 23:27 10/1/2016 10/2/2016 0.55 COMPZ1 CASING PULD P At surface, function closed Orbit valve 45.0 45.0 23:27 00:00 (975 psi), PJSM, for LD liner running BHA 10/2/2016 10/2/2016 0.35 COMPZ1 CASING PULD P LD lower liner running BHA# 6 45.0 0.0 00:00 00:21 10/2/2016 10/2/2016 0.50 COMPZ1 CASING PUTB P Prep rig floor for MU upper liner 0.0 0.0 00:21 00:51 section, PJSM 10/2/2016 10/2/2016 3.15 COMPZ1 CASING PUTB P MU L1 upper liner section 0.0 1,798.5 00:51 04:00 10/2/2016 10/2/2016 1.60 COMPZ1 CASING PULD P PU/MU Coiltrak tools with OH 1,798.5 1,872.0 04:00 05:36 Anchored Billet 10/2/2016 10/2/2016 2.70 COMPZ1 CASING RUNL P RIH with L1-01 upper liner section and 1,872.0 11,668.5 05:36 08:18 OH Anchored Billet, EDC open, Open Orbit valve. 10/2/2016 10/2/2016 0.20 COMPZ1 CASING RUNL P Plus 4.3 ft correction at 9,800 ft EOP 11,668.5 11,672.8 08:18 08:30 flag, close EDC, PUW 38k, WOB -6.4k above window. 10/2/2016 10/2/2016 0.80 COMPZ1 CASING RUNL P 11,672.8 ft. Continue RIH. 11,672.8 13,400.0 08:30 09:18 10/2/2016 10/2/2016 0.20 COMPZ1 CASING DLOG P Log K1 5 fpm for plus 4 ft correction, 13,400.0 13,440.0 09:18 09:30 did not reset counters. 10/2/2016 10/2/2016 0.20 COMPZ1 CASING RUNL P Continue in hole to bottom, slight 13,440.0 13,772.0 09:30 09:42 I bobble thru window. Page 9/13 ReportPrinted: 10/10/2016 Operations Summary (with Timelog Depths) 2M-08 Rig: NABORS CDR2-AC Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time Dur (fir) Phase Op Code Activity Code Time P -T -X Operation (MB) End Depth (ftKB) 10/2/2016 10/2/2016 0.25 COMPZ1 CASING RUNL P 13,772 ft. on bottom with upper liner 13,772.0 11,962.0 09:42 09:57 assembly, HOT issue, PUW 41 k, reorientate single slip to 157° ROHS, release off liner at 4,400 psi, PUW 35k, reset counters to setting tool, top of liner at 11,962 ft. 10/2/2016 10/2/2016 3.05 COMPZ1 CASING TRIP P 11,962 ft, POOH, at 2,300 ft choke not 11,962.0 1,044.0 09:57 13:00 responding, 1,044 ft stop, closed Orbit valve, no flow good, troubleshoot choke issue, POOH, functioning choke, all good. NOTE: Nabors down 30 minutes servicing choke. 10/2/2016 10/2/2016 1.00 COMPZ1 CASING PULD P On surface, PJSM- no flow good, LD 62.6 0.0 13:00 14:00 BHA #8, off load Baker tools. 10/2/2016 10/2/2016 4.00 PROD2 DRILL CTOP P PJSM- Cut 23 ft coil, flat spot 3-6 ft 0.0 0.0 14:00 18:00 above CTC .086", gouge in coil 13-14 ft up. prep coil and re -head CTC, pull test 50k, rehead and test, PIT 4,500 psi. 10/2/2016 10/2/2016 1.50 PROD2 STK PULD P Crew change, perform valve check 0.0 72.2 18:00 19:30 list, PU/MU L1-01 kickoff/drilling BHA with 0.5° bend motor and RB RWD bi- center bit. 10/2/2016 10/2/2016 2.75 PROD2 STK TRIP P Function open the Orbit valve, RIH L1- 72.2 11,595.0 19:30 22:15 01 kickoff/drilling BHA# 9 10/2/2016 10/2/2016 0.25 PROD2 STK DLOG P 11,595 ft, Log K1 correction plus 15.5 11,595.0 11,631.0 22:15 22:30 ft. PUW 34 k 10/2/2016 10/2/2016 0.75 PROD2 STK TRIP P 11,631 ft, continue RIH dry tag TOB at 11,631.0 11,962.0 22:30 23:15 11,962 ft. 10/2/2016 10/3/2016 0.75 PROD2 STK KOST P Back ream 11,961 ft up to 11,938 ft, 11,962.0 23:15 00:00 Start time milling as per procedure, Stalled motor, PUH, start again, 1.38 bpm at 3740 psi, BHP 3853, WHP 56, IA 166, OA 73 10/3/2016 10/3/2016 1.20 PROD2 STK KOST P Continue to kickoff billet 11,963.0 11,972.0 00:00 01:12 10/3/2016 10/3/2016 0.85 PROD2 DRILL DRLG P 11,972 ft, drill build section, 1.4 bpm at 11,972.0 12,000.0 01:12 02:03 3883 psi, BHP 3865, WHP 56, IA 215, OA 104 10/3/2016 10/3/2016 0.25 PROD2 DRILL WPRT P 12,000 ft, wiper above billet (clean), 12,000.0 11,940.0 02:03 02:18 PUW 34 k, RBIH 10/3/2016 10/3/2016 0.25 PROD2 DRILL WPRT P 11,940 ft, dry drift billet area, (clean), 11,940.0 12,000.0 02:18 02:33 wiper back in hole, RIW 9 k 10/3/2016 10/3/2016 1.25 PROD2 DRILL DRLG P 12,000 ft, BOBD 1.41 bpm at 3883 12,000.0 12,084.0 02:33 03:48 psi, BHP 3868, WHP 57, IA 215, OA 107 10/3/2016 10/3/2016 0.50 PROD2 DRILL WPRT P 12,084 ft, TD build section, PUH, 12,084.0 12,084.0 03:48 04:18 PUW 35 k, pump 5x5 sweep 10/3/2016 10/3/2016 2.65 PROD2 DRILL TRIP P POOH, with Build Section BHA# 9, 12,084.0 72.2 04:18 06:57 performing jog in the 4.5" to clean BTP 10/3/2016 10/3/2016 1.65 PROD2 DRILL PULD P On surface, close Orbit valve, flow 72.2 0.0 06:57 08:36 check, PJSM- found two 2" gouges in pipe 16 & 17 ft above CTC, LD BHA #9, bit condition: 1 -1 -NO -X -I -NO -BHA Page 10/13 Report Printed: 10/10/2016 Operations Summary (with Timelog Depths) s 2M-08 Rig: NABORS CDR2-AC Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time Dur (hr) Phase Op Code Activity Code Time P -T -X Operation (ftKB) End Depth (ftKB) 10/3/2016 10/3/2016 1.50 PROD2 DRILL PULD P PJSM- MU BHA #10 a Weatherford 0.0 74.7 08:36 10:06 0.5° motor with RB HYC B7 Durafource Edge (4-9's) Bi -center bit, changed out both lower floats, MU to Coiltrak, change out pack -offs, surface test, open Orbit valve. 10/3/2016 10/3/2016 2.35 PROD2 DRILL TRIP P RIH with BHA #10 74.7 11,580.0 10:06 12:27 10/3/2016 10/3/2016 0.20 PROD2 DRILL DLOG P Tie in at K1 for plus 15.5 ft correction, 11,580.0 11,620.0 12:27 12:39 Close EDC, PUW 35k 10/3/2016 10/3/2016 0.20 PROD2 DRILL TRIP P RBIH with BHA #10, SO 2k passing 11,620.0 12,084.0 12:39 12:51 billet at 11,962 ft. 10/3/2016 10/3/2016 5.20 PROD2 DRILL DRLG P 12,084 ft. OBD 1.5 bpm at 4,200 psi 12,084.0 12,580.0 12:51 18:03 FS, BHP 3,833 psi, CWT 3.0k, WOB 1.8k, ROP 80, WHP 6, IA 182, OA 90. New mud around OBD 1.5 bpm at 3,848 FS, BHP 3,835 psi, CWT -2k, WOB 3.26k, ROP 155, WHP 195, IA 360, OA 200 NOTE: Mud swap, mud system #3 out bit at 12,314 ft. 10/3/2016 10/3/2016 0.30 PROD2 DRILL WPRT P Wiper up hole 500 ft, PUW 34k 12,580.0 12,080.0 18:03 18:21 10/3/2016 10/3/2016 0.25 PROD2 DRILL WPRT P Wiper in hole, RIW 7.5k 12,080.0 12,580.0 18:21 18:36 10/3/2016 10/3/2016 4.10 PROD2 DRILL DRLG P 12,580 ft. BOBD 1.50 bpm at 3,853 12,580.0 12,980.0 18:36 22:42 psi FS, BHP 3,835 psi, CWT 3.0k, WOB 1.8k, ROP 80, WHP 192, IA 410, OA 240, pump 5x5 sweep. 10/3/2016 10/3/2016 1.10 PROD2 DRILL WPRT P Wiper to 12,100 ft. PUW 32k, Jog at 12,980.0 11,690.0 22:42 23:48 EOB 12,100 to 12,300 ft, PU into tail pipe, Jog 4.5" BTP from 11,690 ft. 10/3/2016 10/4/2016 0.20 PROD2 DRILL DLOG P Log RA for plus 1.5 ft correction. 11,690.0 11,780.0 23:48 00:00 10/4/2016 10/4/2016 0.75 PROD2 DRILL WPRT P Wiper trip back in hole 11,780.0 12,980.0 00:00 00:45 10/4/2016 10/4/2016 4.75 PROD2 DRILL DRLG P 12,980 ft, BOBD 1.5 bpm at 4092 psi, 12,980.0 13,380.0 00:45 05:30 BHP 3897, WHP 149, IA 502, OA 323 10/4/2016 10/4/2016 0.65 PROD2 DRILL WPRT P 13,380 ft, wiper up hole, PUW 32 k 13,380.0 12,300.0 05:30 06:09 10/4/2016 10/4/2016 0.50 PROD2 DRILL WPRT P 12,300 ft, wiper back in hole, RIW 8 k 12,300.0 13,380.0 06:09 06:39 10/4/2016 10/4/2016 5.50 PROD2 DRILL DRLG P 13,380 ft, BOBD 1.5 bpm at 4064 psi, 13,380.0 13,780.0 06:39 12:09 BHP 3927, WHP 97, IA 565, OA 383 10/4/2016 10/4/2016 0.50 PROD2 DRILL WPRT P 13,780 ft, wiper up hole PUW 33 k 13,780.0 12,680.0 12:09 12:39 10/4/2016 10/4/2016 0.50 PROD2 DRILL WPRT P 12,680 ft, wiper back in hole, RIW 5 k 12,680.0 13,780.0 12:39 13:09 10/4/2016 10/4/2016 3.85 PROD2 DRILL DRLG P 13,780 ft, BOBD 1.5 bpm at 4080 psi, 13,780.0 13,990.0 13:09 17:00 BHP 3908, WHP 0, IA 613, OA 415 10/4/2016 10/4/2016 0.50 PROD2 DRILL WPRT P 13,990 ft. Wiper trip up to RA. PUW 13,990.0 11,700.0 17:00 17:30 34 Klbs. 10/4/2016 10/4/2016 2.00 PROD2 DRILL WPRT P 11,700 ft. Wiper back in hole. RIW = 5 11,700.0 13,990.0 17:30 19:30 Klbs. Jog across 4-1/2" BTP. Tie into RA for +4.5 ft correction. Bleed OA to 0 psi and IA to 200 psi. Page 11/13 Report Printed: 10/70/2016 Operations Summary (with Timelog Depths) k 2M-08 Rig: NABORS CDR2-AC Job: DRILLING SIDETRACK Time Log Start Depth StartTime End Time Dur (hr) Phase Op Code Activity Code Time P-T-X Operation (W) End Depth (WB) 10/4/2016 10/5/2016 4.50 PROD2 DRILL DRLG P 13,990 ft, BOBD 1.5 bpm at 4150 psi, 13,990.0 14,158.0 19:30 00:00 BHP 3900, WHP 0, IA=210, OA=O. Mud swap, new mud at bit at 14,040 ft. 10/5/2016 10/5/2016 0.25 PROD2 DRILL WPRT P BHA Wiper. PUW = 32 Klbs 14,158.0 13,650.0 00:00 00:15 10/5/2016 10/5/2016 0.25 PROD2 DRILL WPRT P Wiper back in the hole. RIW=5KIbs. 13,650.0 14,158.0 00:15 00:30 10/5/2016 10/5/2016 2.00 PROD2 DRILL DRLG P Continue drilling ahead. 14,158.0 14,290.0 00:30 02:30 10/5/2016 10/5/2016 0.50 PROD2 DRILL WPRT P Short wiper to try and maintain weight 14,290.0 13,300.0 02:30 03:00 transfer. PUW = 33KIbs While pulling up at 13660 ft, observed increase in PUW to 39KIbs. 10/5/2016 10/5/2016 0.50 PROD2 DRILL WPRT P Wiper back in the hole. RIW = 5.5KIbs 13,000.0 14,290.0 03:00 03:30 10/5/2016 10/5/2016 3.25 PROD2 DRILL DRLG P BOBD 1.55 bpm at 4250 psi, BHP 14,290.0 14,360.0 03:30 06:45 3995, WHP 190, IA 270, OA 70 ROP 50-60 fph. WOB 1 Klbs. CTW between 0 and-4.5KIbs. 10/5/2016 10/5/2016 0.25 PROD2 DRILL WPRT P 500 wiper up hole PUW 32 k 14,360.0 13,860.0 06:45 07:00 10/5/2016 10/5/2016 0.25 PROD2 DRILL WPRT P Wiper back in hole, RIW 5 k 13,860.0 14,360.0 07:00 07:15 10/5/2016 10/5/2016 2.75 PROD2 DRILL DRLG P BOBD 1.31 bpm at 3869 psi, BHP 14,360.0 14,360.0 07:15 10:00 4455, WHP 226, IA 270, OA 67 Difficult drilling pump 25 bbl beaded pill, still no help on cosistant WOB. discuss with town plan forward. 10/5/2016 10/5/2016 3.50 PROD2 DRILL TRIP P Decision was made to POOH, to PU 14,360.0 74.7 10:00 13:30 agitator and new motor, perform jog below EOB, pull up thru widnow, perform jog in 4.5", open EDC, POOH, jetting Orbit valve. 10/5/2016 10/5/2016 1.00 PROD2 DRILL PULD P At surface, monitor well for flow (15 74.7 0.0 13:30 14:30 min), LD drilling BHA# 10 10/5/2016 10/5/2016 1.25 PROD2 DRILL PULD P PU/MU L1-01 drilling BHA# 11 0.0 78.3 14:30 15:45 10/5/2016 10/5/2016 4.00 PROD2 DRILL TRIP P RIH, L1-01 drilling BHA# 11 w/ 78.3 14,360.0 15:45 19:45 agitator and RB bi-center bit. Tie-in to the K1 for a +1 Oft correction. Taking weight at 11,962 ft. PU and run back through with slight weight bobble. 10/5/2016 10/5/2016 3.75 PROD2 DRILL DRLG P BOBD. 1.45 bpm at 4200 psi, BHP 14,360.0 14,440.0 19:45 23:30 3980, WHP 120, IA 131, OA 23 CTW = (-)5KIbs. WOB = 1-1.5KIbs. 10/5/2016 10/5/2016 0.25 PROD2 DRILL WPRT P BHA wiper to help improve weight 14,440.0 14,440.0 23:30 23:45 transfer. PUW = 36KIbs. 10/5/2016 10/6/2016 0.25 PROD2 DRILL DRLG P BOBD 1.45 bpm at 4230 psi, BHP 14,440.0 14,447.0 23:45 00:00 4000, WHP 120, IA 130, OA 23 CTW = (-)5KIbs. WOB = 1-1.5KIbs. Add 60bbls of new 8.5ppg flo-pro to active. Page 12/13 Report Printed: 10/10/2016 Operations Summary (with Timelog Depths) 2M-08 Rig: NABORS CDR2-AC Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time Our (hr) Phase Op Code Activity Code Time P-T-X Operation ^B) End Depth (ftKB) 10/6/2016 10/6/2016 9.00 PROD2 DRILL DRLG P BOBD 1.40 bpm at 4300 psi, BHP 14,447.0 14,509.0 00:00 09:00 4000, WHP 120, IA 130, OA 23 CTW = (-)5 to (-)5.5KIbs. WOB = 1-2.5KIbs. Begin pumping 20bbl pills of /ppb beads followed by 20 bbls mud from active. Some improvement observed in weight transfer. 10/6/2016 10/6/2016 1.75 PROD2 DRILL WPRT P 14,509 ft, TO L1-01 lateral, pump 14,509.0 11,692.0 09:00 10:45 1 0x1 0 sweep, IA 149, OA 34, pull wiper up hole, jet 4.5", RBIH to logging depth 10/6/2016 10/6/2016 0.25 PROD2 DRILL DLOG P Log RA marker correction of plus 1.0 11,692.0 11,796.0 10:45 11:00 ft. 10/6/2016 10/6/2016 1.50 PROD2 DRILL WPRT P Wiper back in hole RIW 8 k confirmed 11,796.0 14,503.0 11:00 12:30 TD 14,503 ft, 10/6/2016 10/6/2016 1.00 PROD2 DRILL DISP P Lay in liner running pill 14,503.0 11,450.0 12:30 13:30 10/6/2016 10/6/2016 2.25 PROD2 DRILL TRIP P Continue POOH 11,450.0 78.3 13:30 15:45 10/6/2016 10/6/2016 0.50 PROD2 DRILL OWFF P At surface, function closed orbit valve, 78.3 78.3 15:45 16:15 check well for flow. Static. 10/6/2016 10/6/2016 1.00 PROD2 DRILL PULD P LD BHA #11. Bit grade 2-1-BT-N-X-I- 78.3 0.0 16:15 17:15 WT-TD. 10/6/2016 10/6/2016 5.50 COMPZ2 CASING PULD P Prep rig floor. PU 94 joints of 2-3/8" 0.0 2,796.6 17:15 22:45 slotted liner. MU CoilTrak BHA. Surface test. Good. Strip injector over stump. 10/6/2016 10/7/2016 1.25 COMPZ2 CASING RUNL P RIH with liner. 2,796.6 6,995.0 22:45 00:00 10/7/2016 10/7/2016 2.50 COMPZ2 CASING RUNL P Continue running in the hole with 2- 6,995.0 14,498.0 00:00 02:30 3/8" slotted liner. Tie-in to window flag for +8.5 ft correction. Tie-in to TD flag for no correction. Tie-in to K1 for no correction. Weight check at 14,466 ft. PUW = 35KIbs. Position liner on depth at 14,498 ft. TOL at 11,745 ft. Release from liner per Baker rep. PUW after release = 29KIbs. 10/7/2016 10/7/2016 3.00 DEMOB WHDBOP DISP P Reset depth. Open EDC, displace well 14,498.0 11,724.0 02:30 05:30 over to seawater. 10/7/2016 10/7/2016 1.75 DEMOB WHDBOP FRZP P Freeze protect well from 2500', POOH 11,724.0 45.0 05:30 07:15 10/7/2016 10/7/2016 1.00 DEMOB WHDBOP PULD P LD Liner running BHA 45.0 0.0 07:15 08:15 10/7/2016 10/7/2016 1.50 DEMOB WHDBOP RURD P Blow reel and surface lines down, 0.0 0.0 08:15 09:45 unload fluids from the pits. 10/7/2016 10/7/2016 5.00 DEMOB WHDBOP RURD P Work on rig move checklist 0.0 0.0 09:45 14:45 10/7/2016 10/7/2016 2.75 DEMOB WHDBOP RURD P Trucks on location, PJSM for loading 0.0 0.0 14:45 17:30 and moving shop to 2B-pad 10/7/2016 10/8/2016 6.50 DEMOB WHDBOP RURD P PJSM, Move Sub and pits off of well 0.0 0.0 17:30 00:00 and stage modules in the center of pad for post workover work. 10/8/2016 10/8/2016 6.00 MIRU WHDBOP RURD P RDMO well, perform post workover 0.0 0.0 00:00 06:00 work in cellar, remove flow-box, swap out annular, pull AC unit from dog house wall, install window back in dog house, remove BOPE pedistal from cellar, and re-install gang box . Page 13/13 ReportPrinted: 10/10/2016 ConocoPhillips ConocoPhillips (Alaska) Inc. -Kup2 Kuparuk River Unit Kuparuk 2M Pad 2M -08L1-01 50-103-20184-64 Baker Hughes INTEQ WMA aI BAKER Definitive Survey Report HUGHES 14 October, 2016 ConocoPhillips ConocoPhillips BAKER Definitive Survey Report HUGHES Company: ConocoPhillips (Alaska) Inc. -Kup2 Local Co-ordinate Reference: Well 2M-08 Project: Kuparuk River Unit TVD Reference: 2M-08 @ 147.00usft (P245) Site: Kuparuk 2M Pad MD Reference: 2M-08 @ 147.00usft (P245) Well: 2M-08 North Reference: True Wellbore: 2M-0811-01 Survey Calculation Method: Minimum Curvature Design: 2M-0811-01 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) Magnetics Using Well Reference Point Map Zone: Alaska Zone 04 Declination (°) Using geodetic scale factor Well 2M-08 10/1/2016 11,962.00 Well Position -NI-S 0.00 usft Northing: 5,948,985.84usft +EI -W 0.00 usft Easting: 487,949.23usft Position Uncertainty 0.00 usft Wellhead Elevation: usft Latitude: 70° 16' 18.579 N Longitude: 150° 5'50,870 W Ground Level: 105.50 usft Wellbore 21M-0811-01 Date 10/13/2016 From To MWD - Standard Magnetics Model Name Sample Date 151.90 Declination (°) Dip Angle (°) 11,745.00 BGGM2016 10/1/2016 11,962.00 17.84 80.88 Design 2M-0811-01 Audit Notes: Version: 1.0 Phase: ACTUAL Tie On Depth: 11,960.18 Vertical Section: Depth From (TVD) +Nl-S +E/ -W (usft) (usft) (usft) 41.50 0.00 0.00 Survey Program Description Date 10/13/2016 From To MWD - Standard (usft) (usft) Survey (Wellbore) 151.90 11,740.89 210-08 Srvy 1 - GCT -MS (2M-08) 11,745.00 11,960.18 2M-0811 (210-0811) 11,962.00 14,462.79 210-0811-01 (2M-0811-01) Tool Name Description GCT -MS Schlumberger GCT multishot MWD MWD - Standard MWD MWD - Standard Direction (°) 180.00 Survey Stan Date 11/16/1992 9/24/2016 10/1/2016 Field Strength (nT) 57,537 Survey End Date 11/16/1992 9/30/2016 10/6/2016 1011412016 10:05 43AM Page 2 COMPASS 5000.1 Build 74 ConocoPhillips ConocoPhillips Definitive Survey Report Company: ConocoPhillips (Alaska) Inc. -Kup2 Local Co-ordinate Reference: Well 2M-08 Project: Kuparuk River Unit TVD Reference: 2M-08 @ 147.O0usft (P245) Site: Kuparuk 2M Pad MD Reference: 2M-08 @ 147.O0usft (P245) Well: 2M-08 North Reference: True Wellbore: 21M-081-1-01 Survey Calculation Method: Minimum Curvature Design: 2M-081-1-01 Database: EDM Alaska NSK Sandbox Survey Annotation TIP KOP WIN BAM E "MIS 101142016 10:05.43AM Page 3 COMPASS 5000.1 Build 74 Map Map Vertical MD Inc AN TVD TVDSS +Nfs +El•W Northing Easting OLS Section Survey Tool Name (usft) (°) (°) (usft) (11sft) (usRj justt► (ft) IH) (.110w) (ft) 11,960.18 10143 140.04 6,215.74 6,068.74 -9,506.29 -822.28 5,939,481.83 487,111.81 45.66 9,506.29 MWD (2) 111,962.00 101.13 139.31 6,215.38 6,068.38 -9,507.65 -821.13 5,939,480.47 487,112.96 42.65 9,507.65 MWD (3) 11,990.33 93.75 152.74 6,211.70 6,064.70 -9,530.89 -805.50 5,939,457.21 487,128.55 53.71 9,530.89 MWD (3) 12,020.18 86.50 166.65 6,211.63 6,064.63 -9,558.79 -795.17 5,939,429.29 487,138.83 52.52 9,558.79 MWD(3) 12,041.77 82.49 175.07 6,213.71 6,066.71 -9,579.99 -791.76 5,939,408.09 487,142.21 43.03 9,579.99 MWD(3) 12,070.61 87.36 186.19 6,216.27 6,069.27 -9,608.66 -792.08 5,939,379.42 487,141.84 41.94 9,608.66 MWD (3) g 12,100.57 90.40 190.57 6,216.85 6,069.85 -9,63828 -796.45 5,939,349.81 487,137.43 17.79 9,638.28 MWD (3) # 12,128.99 89.48 193.35 6,216.88 6,069.88 -9,666.08 -802.34 5,939,322.02 487,131.50 10.30 9,666.08 MWD(3) y 12,160.98 88.65 195.87 6,217.40 6,070.41 -9,697.03 -810.41 5,939,291.09 487,123.38 8.29 9,697.03 MWD (3) 12,189.90 88.34 197.80 6,218.16 6,071.16 -9,724.70 -818.78 5,939,263.44 487,114.97 6.76 9,724.70 MWD (3) 12,220.61 88.62 200.20 6,218.98 6,071.98 -9,753.73 -828.77 5,939,234.43 487,104.93 7.87 9,753.73 MWD (3) 12,250.56 87.79 202.49 6,219.92 6,072.92 -9,781.61 -839.67 5,939,206.57 487,093.99 8.13 9,781.61 MWD (3) 12,280.79 87.36 203.36 6,221.20 6,074.20 -9,809.42 -851.43 5,939,178.78 487,082.18 3.21 9,809.42 MWD (3) 12,310.88 86.77 204.71 6,222.74 6,075.74 -9,836.87 -863.67 5,939,151.35 487,069.90 4.89 9,836.87 MWD (3) 12,340.75 86.80 203.09 6,224.41 6,077.41 -9,864.13 -875.75 5,939,124.11 487,057.77 5.42 9,864.13 MWD(3) 12,371.06 87.27 200.38 6,225.98 6,078.98 -9,892.25 -886.96 5,939,096.02 487,046.52 9.06 9,892.25 MWD (3) 12,400.94 87.73 198.77 6,227.28 6,080.28 -9,920.37 -896.96 5,939,067.91 487,036.48 5.60 9,920.37 WD (3) 12,430.98 89.17 197.85 6,228.10 6,081.10 -9,948.88 -906.39 5,939,039.42 487,027.00 5.69 9,948.88 MWD(3) 12,460.94 90.00 195.79 6,228.31 6,081.31 -9,977.55 -915.06 5,939,010.76 487,018.28 7.41 9,977.55 MWD (3) 12,490.72 89.75 193.30 6,228.38 6,081.38 -10,006.38 -922.54 5,938,981.95 487,010.76 8.40 10,006.38 MWD (3) i 12,520.76 89.79 191.05 6,228.50 6,081.50 -10,035.74 -928.88 5,938,952.60 487,004.38 7.49 10,035.74 MWD (3) 12,550.50 90.40 189.39 6,228.45 6,081.45 -10,065.01 -934.15 5,938,923.35 486,999.06 5.95 10,065.01 MWD (3) ( 12,580.94 90.61 188.32 6,228.18 6,081.18 -10,095.08 -938.84 5,938,893.28 486,994.32 3.58 10,095.08 MWD(3) 12,610.57 91.07 189.60 6,227.75 6,080.75 -10,124.35 -943.45 5,938,864.03 486,98966 4.59 10,124.35 MWD(3) 12,642.38 91.01 190.31 6,227.17 6,080.17 -10,155.67 -948.95 5,938,832.72 486,984.11 2.24 10,155.67 MWD (3) 12,671.20 89.69 190.99 6,226.99 6,079.99 -10,184.00 -954.28 5,938,804.41 486,978.74 5.15 10,184.00 MWD (3) 12,700.66 90.34 192.71 6,226.99 6,079.99 -10,212.83 -960.33 5,938,775.59 486,972.65 6.24 10,212.63 MWD (3) 12,730.77 89.69 194.28 6,226.98 6,079.98 -10,242.10 -967.35 5,938,746.32 486,965.58 5.64 10,242.10 MWD (3) 12,760.70 89.63 196.32 6,227.16 6,080.16 -10,270.97 -97525 5,938,717.47 486,957.63 6.82 10,270.97 MWD(3) 12,790.57 89.85 198.06 6,227.29 6,080.29 -10,299.51 -984.08 5,938,688.95 486,948.76 5.87 10,299.51 MWD(3) Annotation TIP KOP WIN BAM E "MIS 101142016 10:05.43AM Page 3 COMPASS 5000.1 Build 74 ConocoPhillips ConocoPhillips BAKER Definitive Definitive Survey Report HUGHES Company: ConocoPhillips (Alaska) Inc. -Kup2 Local Co-ordinate Reference: Well 2M-08 Project: Kuparuk River Unit TVD Reference: 2M-08 @ 147.00usft (P245) Site: Kuparuk 2M Pad MD Reference: 2M-08 @ 147.00usft (P245) Well: 2M-08 North Reference: True Wellbore: 2M-081-1-01 Survey Calculation Method: Minimum Curvature Design: 2M -08L1-01 Database. EDM Alaska NSK Sandbox Survey 10/142016 10:05: 43AM Page 4 COMPASS 5000. 1 Build 74 Map Map vertical MD Inc Azi TVD TVDSS +NTS +Et -W Northing EastIng. DLS Section Survey Tool Name Annotation (usft) (I (I (4811t) (usft) (ustt) (usft) (ft) VQ (-M 00.) (ft) 12,820.56 88.71 200.22 6,227.67 6,080.67 -10,327.83 -993.91 5,938,660.65 486,938.89 8.14 10,327.83 MWD (3) 12,850.49 90.25 200.01 6,227.94 6,080.94 -10,355.94 -1,004.20 5,938,632.56 486,928.55 5.19 10,355.94 MWD (3) 12,880.61 91.87 197.71 6,227.38 6,080.38 -10,384.43 -1,013.93 5,938,604.09 486,918.77 9.34 10,384.43 MWD (3) 12,910.52 90.86 194.66 6,226.67 6,079.67 -10,413.14 -1,022.27 5,938,575.39 486,910.39 10.74 10,413.14 MWD (3) 12,945.48 90.31 193.75 6,226.31 6,079.31 -10,447.03 -1,030.85 5,938,541.52 486,901.76 3.04 10,447.03 MWD(3) 12,970.42 88.56 190.45 6,226.56 6,079.56 -10,471.41 -1,036.07 5,938,517.15 486,896.50 14.98 10,471.41 MWD (3) € 13,000.42 87.42 189.57 6,227.61 6,080.61 -10,500.94 -1,041.28. 5,938,487.64 486,89124 4.80 10,500.94 MWD (3) 13,030.45 86.72 189.89 6,229.15 6,082.15 -10,530.50 -1,046.35 5,938,458.09 486,886.12 2.56 10,530.50 MWD (3) 13,061.92 87.42 188.39 6,230.75 6,083.76 -10,561.52 -1,051.35 5,938,427.07 486,881.08 5.25 10,561.52 MWD(3) 13,090.58 86.78 185.19 6,232.21 6,085.21 -10,589.94 -1,054.73 5,938,398.66 486,877.65 11.37 10,589.94 MWD (3) 13,120.72 86.28 184.37 6,234.03 6,087.03 -10,619.92 -1,057.24 5,938,368.69 486,875.10 3.18 10,619.92 MWD (3) 13,150.40 85.55 181.97 6,236.14 6,089.14 -10,649.48 -1,058.87 5,938,339.14 486,873.41 8.43 10,649.48 MWD (3) 13,180.40 85.52 183.33 6,238.48 6,09148 -10,679.36 -1,060.26 5,938,309.26 486,871.98 4.52 10,679.36 MWD (3) € 13,210.76 85.21 185.29 6,240.93 6,093.93 -10,709.53 -1,062.53 5,938,279.10 486,869.66 6.52 10,709.53 MWD (3) i 13,240.74 86.44 186.36 6,243.12 6,096.12 -10,739.27 -1,065.57 5,938,249.36 486,866.58 5.43 10,739.27 MWD (3) { 13,270.64 87.94 186.74 6,244.58 6,097.58 -10,768.94 -1,068.97 5,938,219.70 486,863.12 5.17 10,768.94 MWD (3) (( 13,302.51 89.85 187.69 6,245.20 6,098.20 -10,800.55 -1,072.97 5,938,188.10 486,859.07 6.69 10,800.55 MWD (3) 13,331.30 90.83 188.33 6,245.03 6,098.03 -10,829.06 -1,076.99 5,938,159.60 486,855.02 4.07 10,829.06 MWD (3) 13,361.80 90.06 189.71 6,244.79 6,097.79 -10,859.18 -1,081.77 5,938,129.49 486,850.19 5.18 10,859.18 MWD (3) 13,390.72 88.74 188.51 6,245.09 6,098.09 -10,887.73 -1,086.35 5,938,100.95 486,845.56 6.17 10,887.73 MWD (3) 13,421.92 88.31 185.96 6,245.89 6,098.90 -10,918.67 -1,090.27 5,938,070.02 486,841.59 8.29 10,918.67 MWD (3) 13,450.86 88.16 184.83 6,246.79 6,099.79 -10,947.47 -1,092.99 5,938,041.23 486,838.82 3.94 10,947.47 MWD (3) 13,480.59 90.18 184.30 6,247.22 6,100.22 -10,977.10 -105.36 5,938,011.60 486,836.41 7.02 10,977.10 MWD (3) 13,510.47 89.91 182.97 6,247.19 6,100.19 -11,006.92 -1,097.25 5,937,981.79 486,834.47 4.54 11,006.92 MWD(3) 13,540.32 88.47 183.86 6,247.62 6,100.62 -11,036.71 -1,099.03 5,937,952.00 486,832.64 5.67 11,036.71 MWD (3) 13,570.55 87.54 185.55 6,248.67 6,101.67 -11,066.82 -1,101.51 5,937,921.90 486,830.11 6.38 11,066.82 MWD (3) j 13,600.58 86.47 186.97 6,250.24 6,103.24 -11,096.63 -1,104.78 5,937,892.10 486,826.80 5.92 11,096.63 MWD (3) 13,630.32 85.85 188.81 6,252.23 6,105.23 -11,126.02 -1,108.85 5,937,862.72 486,822.68 6.52 11,126.02 MWD (3) 13,660.54 85.23 190.31 6,254.58 6,107.58 -11,155.73 -1,113.85 5,937,833.02 486,817.63 5.36 11,155.73 MWD (3) 13,690.42 85.33 192.41 6,257.04 6,110.04 -11,184.93 -1,119.72 5,937,803.84 486,811.72 7.01 11,184.93 MWD (3) 13,720.31 86.31 192.77 6,259.22 6,112.22 -11,214.02 -1,126.22 5,937,774.76 486,805.17 3.49 11,214.02 MWD (3) 10/142016 10:05: 43AM Page 4 COMPASS 5000. 1 Build 74 4 ConocoPhillips ConocoPhillips F/ks BAKER Definitive Survey Report HUGHES Company: ConocoPhillips (Alaska) Inc. -Kup2 Local Coordinate Reference: Well 2M-08 Project: Kuparuk River Unit TVD Reference: 2M-08 @ 147,00usft (P245) Site: Kuparuk 2M Pad MD Reference: 2M-08 @ 147.00usft (P245) W011: 2M-08 North Reference: True Wellbore: 2M -08L7-01 Survey Calculation Method: Minimum Curvature Design: 2M -08L1-01 Database: EDM Alaska NSK Sandbox Survey Map Map Vertical MD Me AZ1 TVD TVDSS +N/ -S +El -W Northing Ea DLS Section Survey Tool Name i1Dn028(IOn Nam £'! t7 (use) (use) ) (usn) (usn) lel (ft) (°nop-) (e) 13,750.44 87.27 192.83 6,260.90 6,113.90 -11,243.35 -1,132.88 5,937,745.44 486,798.46 3.19 11,243.35 MWD (3) 13,780.47 88.71 193.57 6,261.96 6,114.96 -11,272.57 -1,139.74 5,937,716.24 486,791.56 5.39 11,272.57 MWD (3) 13,810.18 89.60 193.89 6,262.39 6,115.40 -11,301.43 -1,146.79 5,937,687.39 486,784.47 3.18 11,301.43 MWD (3) 13,841.32 90.68 194.77 6,262.32 6,115.32 -11,331.60 415449 5,937,657.24 486,776.71 4.47 11,331.60 MWD (3) E E 13,870.32 90.80 197.90 6,261.94 6,114.94 -11,359.42 -1,162.65 5,937,629.43 486,768.51 10.80 11,359.42 MWD (3) 13,900.43 91.26 197.16 6,261.40 6,11440 -11,388.13 -1,171.72 5,937,600.74 486,759.40 2.89 11,388.13 MWD (3) 13,930.21 91.93 197.53 6,260.57 6,113.57 -11,416.54 -1,160.59 5,937,572.34 486,750.48 2.57 11,416.54 MWD (3) ' 13,960.34 92.64 19220 6,259.37 6,112.37 -11,445.28 -1,189.58 5,937,543.63 486,741.45 2.60 11,445.28 MWD (3) 13,990.16 92.98 194.98 6,257.91 6,110.91 -11,473.89 -1,197.83 5,937,515.03 486,733.15 7.52 11,473.89 MWD (3) 14,020.25 95.47 195.37 6,255.69 6,108.69 -11,502.86 -1,205.69 5,937,486.07 486,725.25 8.37 11,502.86 MWD(3) 14,050.17 98.00 195.51 6,252.19 6,105.19 -11,53149 -1,213.59 5,937,457.46 486,717.30 8.47 11,531.49 MWD (3) 14,080.22 99.63 193.04 6,247.58 6,100.58 -11,560.27 -1,220.92 5,937,428.70 486,709.93 9.77 11,560.27 MWD (3) 14,108.23 99.78 193.08 6,242.86 6,095.86 -11,587.16 -1,227.16 5,937,401.82 486,703.65 0.55 11,587.16 MWD (3) 14,140.42 99.72 191.33 6,237.41 6,090.41 -11,618.17 -1,233.86 5,937,370.83 486,696.89 5.36 11,618.17 MWD (3) 14,173.14 99.18 191.15 6,232.03 6,085.03 -11,649.82 -1,240.15 5,937,339.18 486,690.55 1.74 11,649.82 MWD (3) ' 14,205.00 98.01 190.55 6,227.27 6,080.27 -11,680.76 -1,246.08 5,937,308.26 486,684.57 4.12 11,680.76 MWD (3) 14,229.70 96.74 189.34 6,224.10 6,077.10 -11,704.89 -1,250.31 5,937,284.14 486,680.30 7.07 11,704.89 MWD (3) 14,260.07 95.26 188.38 6,220.93 6,073.93 -11,734.73 -1,254.96 5,937,254.31 486,675.60 5.80 11,734.73 MWD (3) 14,290.62 93.90 187.40 6,218.49 6,071.49 -11,764.89 -1,259.14 5,937,224.15 486,671.38 5.48 11,764.89 MWD (3) 14,320.00 93.87 185.92 6,216.50 6,069.50 -11,794.01 -1,262.54 5,937,195.05 486,667.93 5.03 11,794.01 MWD (3) 14,350.21 93.94 185.19 6,214.44 6,067.44 -11,824.01 -1,265.46 5,937,165.06 486,664.97 2.42 11,824.01 MWD (3) 14,380.10 92.46 182.50 6,212.77 6,065.77 -11,853.78 -1,267.46 5,937,135.29 486,662.92 10.26 11,853.78 MWD (3) 14,410.13 91.69 179.58 6,211.68 6,064.68 -11,883.78 -1,26801 5,937,105.29 486,662.33 10.05 11,883.78 MWD (3) 14,442.08 94.77 179.56 6,209.88 6,062.88 -11,915.68 -1,267.77 5,937,073.40 486,662.51 9.64 11,915.68 MWD (3) _ 14,462.79 96.09 177.53 6,207.92 6,060.92 -11,936.28 -1,26724 5,937,052.79 486,663.00 11.65 11,936.28 MWD (3) 14,503.00 96.09 177.53 6,203.66 6,056.66 -11,976.23 -1,265.52 5,937,012.85 486,664.66 0.00 11,976.23 PROJECTEDto TD 10/1412016 10:05: 43AM page 5 COMPASS 5000.1 Build 74 FrA a a BAKER HUGHES To OCT 20201u Letter of Transmittal Date: DATA LOGGED October 14, 2016 11 BENDE10 1201 R Makana Bender AOGCC 333 West 7th Ave, Suite 100 Anchorage, Alaska 99501 From: Yosha Ragbirsingh /Michael Soper Baker Hughes INTEQ 795 East 94th Avenue Anchorage, Alaska 99515 Please find enclosed the directional survey data for the following well(s): 2M -08L 1 2 1 60 95 . 27 64 9 2M -08L1-01 2 60 96 27 65 0 (4) Total prints Enclosed for each well(s): 1 hardcopy print of directional survey reports (NAD27) 1 compact disk containing electronic survey files Note: Please feel free to send us an email in place of return mail. Michael Soper, Baker Hughes, Project Engineer Michael. Soper@BakerHughes.com Yosha Ragbirsingh, Baker Hughes, Survey Manager Yosha.Ragbirsingh@BakerHughes.com 21 6096 27650 r s ConocoPhilli OCT 20' p ONI: ConocoPhillips (Alaska) Inc. -Kup2 Kuparuk River Unit Kuparuk 2M Pad 2M -08L1-01 50-103-20184-64 Baker Hughes INTEQ BpKER�• Definitive Survey Report HUGHES 14 October, 2016 ConocoPhillips ConocoPhillips Definitive Survey Report BAKER•• HUGHES Company: ConocoPhillips (Alaska) Inc. -Kup2 Local Co-ordinate Reference: Well 2M-08 Project: Kuparuk River Unit TVD Reference: 2M-08 @ 147.00usft (P245) Site: Kuparuk 2M Pad MD Reference: 2M-08 @ 147.00usft (P245) Well: 2M-08 North Reference: True Wellbore: 2M-0811-01 Survey Calculation Method: Minimum Curvature Design: 2M-0811-01 Database: EDM Alaska NSK Sandbox Project Kuparuk River Unit, North Slope Alaska, United States i Map System: US State Plane 1927 (Exact solution) System Datum: Mean Sea Level 1 Geo Datum: NAD 1927 (NADCON CONUS) Using Well Reference Point Map Zone: Alaska Zone 04 Using geodetic scale factor Well 2M-08 Well Position +N/ -S 0.00 usft Northing: 5,948,985.84 usft Latitude: 70° 16' 18.579 N +E/ -W 0.00 usft Easting: 487,949.23 usft Longitude: 150° 650.870 W Position Uncertainty 0.00 usft Wellhead Elevation: usft Ground Level: 105.50 usft Wellbore 2M-031-1-01 Magnetics Model Name Sample Date Declination Dip Angle Field Strength (I (I (nT) B G G M2016 10/1/2016 F 17.84 80.88 57,537 Design 2M-0811-01 Audit Notes: Version: 1.0 Phase: ACTUAL Tie On Depth: 11,960.18 Vertical Section: Depth From (TVD) +N/ -S +E/ -W Direction (usft) (usft) (usft) (°) 41.50 0.00 0.00 180.00 Survey Program Date 10/13/2016 From To Survey Survey (usft) (usft) Survey (Wellbore) Tool Name Description Start Date End Date 151.90 11,740.89 2M-08 Srvy 1 - GCT -MS (2M-08) GCT -MS Schlumberger GCT multishot 11/16/1992 11/16/1992 11,745.00 11,960.18 2M-0811 (2M-081-1) MWD MWD - Standard 9/24/2016 9/30/2016 11,962.00 14,462.79 2M-0811-01 (2M-0811-01) MWD MWD - Standard 10/1/2016 10/6/2016 10114/2016 10.05:43AM Page 2 COMPASS 5000.1 Build 74 ConocoPhillips ConocoPhillips //FIS IRAKE Definitive Survey Report HUGHES Vertical Section Survey Tool Name (ft) 9,506.29 MWD (2) 9,507.65 MWD (3) 9,530.89 MWD (3) 9,558.79 MWD (3) 9,579.99 MWD (3) 9,608.66 MWD (3) 9,638.28 MWD (3) 9,666.08 MWD (3) 9,697.03 MWD (3) 9,724.70 MWD (3) 9,753.73 MWD (3) 9,781.61 MWD (3) 9,809.42 MWD (3) 9,836.87 MWD (3) 9,864.13 MWD (3) 9,892.25 MWD (3) 9,920.37 MWD (3) 9,948.88 MWD (3) 9,977.55 MWD (3) 10,006.38 MWD (3) 10,035.74 MWD (3) 10,065.01 MWD (3) 10,095.08 MWD (3) 10,124.35 MWD (3) 10,155.67 MWD (3) 10,184.00 MWD (3) 10,212.83 MWD (3) 10,242.10 MWD (3) 10,270.97 MWD (3) 10,299.51 MWD (3) Annotation TIP KOP 10/14/2016 10:05:43AM Page 3 COMPASS 5000.1 Build 74 Company: ConocoPhillips (Alaska) Inc. -Kup2 Local Co-ordinate Reference: Well 2M-08 Project: Kuparuk River Unit TVD Reference: 2M-08 @ 147.00usft (P245) 3 Site: Kuparuk 2M Pad MD Reference: 2M-08 @ 147.00usft (P245) Well: 2M-08 North Reference: True Wellbore: 2M-081-1-01 Survey Calculation Method: Minimum Curvature Design: 2M -08L1-01 Database: EDM Alaska NSK Sandbox Survey (usft) (°) Vertical Section Survey Tool Name (ft) 9,506.29 MWD (2) 9,507.65 MWD (3) 9,530.89 MWD (3) 9,558.79 MWD (3) 9,579.99 MWD (3) 9,608.66 MWD (3) 9,638.28 MWD (3) 9,666.08 MWD (3) 9,697.03 MWD (3) 9,724.70 MWD (3) 9,753.73 MWD (3) 9,781.61 MWD (3) 9,809.42 MWD (3) 9,836.87 MWD (3) 9,864.13 MWD (3) 9,892.25 MWD (3) 9,920.37 MWD (3) 9,948.88 MWD (3) 9,977.55 MWD (3) 10,006.38 MWD (3) 10,035.74 MWD (3) 10,065.01 MWD (3) 10,095.08 MWD (3) 10,124.35 MWD (3) 10,155.67 MWD (3) 10,184.00 MWD (3) 10,212.83 MWD (3) 10,242.10 MWD (3) 10,270.97 MWD (3) 10,299.51 MWD (3) Annotation TIP KOP 10/14/2016 10:05:43AM Page 3 COMPASS 5000.1 Build 74 Map MD Inc Azi TVD TVDSS +N/ -S +E/ -W DLS NMap orthing East ng (usft) (°) (I (usft) (usft) (usft) (usft) (°/100') (ft) (ft) 11,960.18 101.43 140.04 6,215.74 6,068.74 -9,506.29 -822.28 5,939,481.83 487,111.81 45.66 4 11,962.00 ri 101.13 139.31 6,215.38 6,068.38 -9;507.65 -821.13 5,939,480.47 487,112.96 42.65 11,990.33 93.75 152.74 6,211.70 6,064.70 -9,530.89 -805.50 5,939,457.21 487,128.55 53.71 12,020.18 86.50 166.65 6,211.63 6,064.63 -9,558.79 -795.17 5,939,429.29 487,138.83 52.52 12,041.77 82.49 175.07 6,213.71 6,066.71 -9,579.99 -791.76 5,939,408.09 487,142.21 43.03 12,070.61 87.36 186.19 6,216.27 6,069.27 -9,608.66 -792.08 5,939,379.42 487,141.84 41.94 12,100.57 90.40 190.57 6,216.85 6,069.85 -9,638.28 -796.45 5,939,349.81 487,137.43 17.79 12,128.99 x 89.48 193.35 6,216.88 6,069.88 -9,666.08 -802.34 5,939,322.02 487,131.50 10.30 j 12,160.98 88.65 195.87 6,217.40 6,070.41 -9,697.03 -810.41 5,939,291.09 487,123.38 8.29 y 12,189.90 88.34 197.80 6,218.16 6,071.16 -9,724.70 -818.78 5,939,263.44 487,114.97 6.76 12,220.61 88.62 200.20 6,218.98 6,071.98 -9,753.73 -828.77 5,939,234.43 487,104.93 7.87 12,250.56 87.79 202.49 6,219.92 6,072.92 -9,781.61 -839.67 5,939,206.57 487,093.99 8.13 12,280.79 87.36 203.36 6,221.20 6,074.20 -9,809.42 -851.43 5,939,178.78 487,082.18 3.21 12,310.88 86.77 204.71 6,222.74 6,075.74 -9,836.87 -863.67 5,939,151.35 487,069.90 4.89 s' 12,340.75 A 86.80 203.09 6,224.41 6,077.41 -9,864.13 -875.75 5,939,124.11 487,057.77 5.42 a 12,371.06 87.27 200.38 6,225.98 6,078.98 -9,892.25 -886.96 5,939,096.02 487,046.52 9.06 12,400.94 87.73 198.77 6,227.28 6,080.28 -9,920.37 -896.96 5,939,067.91 487,036.48 5.60 12,430.98 89.17 197.85 6,228.10 6,081.10 -9,948.88 -906.39 5,939,039.42 487,027.00 5.69 12,460.94 90.00 195.79 6,228.31 6,081.31 -9,977.55 -915.06 5,939,010.76 487,018.28 7.41 12,490.72 89.75 193.30 6,228.38 6,081.38 -10,006.38 -922.54 5,938,981.95 487,010.76 8.40 12,520.76 89.79 191.05 6,228.50 6,081.50 -10,035.74 -928.88 5,938,952.60 487,004.38 7.49 12,550.50 i 90.40 189.39 6,228.45 6,081.45 -10,065.01 -934.15 5,938,923.35 486,999.06 5.95 12,580.94 90.61 188.32 6,228.18 6,081.18 -10,095.08 -938.84 5,938,893.28 486,994.32 3.58 12,610.57 91.07 189.60 6,227.75 6,080.75 -10,124.35 -943.45 5,938,864.03 486,989.66 4.59 12,642.38 91.01 190.31 6,227.17 6,080.17 -10,155.67 -948.95 5,938,832.72 486,984.11 2.24 12,671.20 89.69 190.99 6,226.99 6,079.99 -10,184.00 -954.28 5,938,804.41 486,978.74 5.15 12,700.66 90.34 192.71 6,226.99 6,079.99 -10,212.83 -960.33 5,938,775.59 486,972.65 6.24 12,730.77 89.69 194.28 6,226.98 6,079.98 -10,242.10 -967.35 5,938,746.32 486,965.58 5.64 12,760.70 89.63 196.32 6,227.16 6,080.16 -10,270.97 -975.25 5,938,717.47 486,957.63 6.82 12,790.57 89.85 198.06 6,227.29 6,080.29 -10,299.51 -984.08 5,938,688.95 486,948.76 5.87 Vertical Section Survey Tool Name (ft) 9,506.29 MWD (2) 9,507.65 MWD (3) 9,530.89 MWD (3) 9,558.79 MWD (3) 9,579.99 MWD (3) 9,608.66 MWD (3) 9,638.28 MWD (3) 9,666.08 MWD (3) 9,697.03 MWD (3) 9,724.70 MWD (3) 9,753.73 MWD (3) 9,781.61 MWD (3) 9,809.42 MWD (3) 9,836.87 MWD (3) 9,864.13 MWD (3) 9,892.25 MWD (3) 9,920.37 MWD (3) 9,948.88 MWD (3) 9,977.55 MWD (3) 10,006.38 MWD (3) 10,035.74 MWD (3) 10,065.01 MWD (3) 10,095.08 MWD (3) 10,124.35 MWD (3) 10,155.67 MWD (3) 10,184.00 MWD (3) 10,212.83 MWD (3) 10,242.10 MWD (3) 10,270.97 MWD (3) 10,299.51 MWD (3) Annotation TIP KOP 10/14/2016 10:05:43AM Page 3 COMPASS 5000.1 Build 74 ConocoPhillips ConocoPhillips //%I p Definitive Survey Report BHUGHES Company: ConocoPhillips (Alaska) Inc. -Kup2 Project: Kuparuk River Unit Site: Kuparuk 2M Pad Well: 2M-08 Wellbore: 2M -08L1-01 Design: 2M -08L1 -D1 Survey Local Co-ordinate Reference: Well 2M-08 TVD Reference: 2M-08 @ 147.00usft (P245) MD Reference: 2M-08 @ 147.00usft (P245) j North Reference: True I Survey Calculation Method: Minimum Curvature i Database: EDM Alaska NSK Sandbox 4 Annotation 10/1412016 10:05:43AM Page 4 COMPASS 5000.1 Build 74 Map Map Vertical MD Inc Azi TVD TVDSS +Nl-S +E/ -W Northing Easting DLS Section (usft) (I (I (usft) (usft) (usft) usft (usft) (°1100') Survey Tool Name (ft) (ft) (ft) 12,820.56 88.71 200.22 6,227.67 6,080.67 -10,327.83 -993.91 5,938,660.65 486,938.89 8.14 10,327.83 MWD (3) 12,850.49 90.25 200.01 6,227.94 6,080.94 -10,355.94 -1,004.20 5,938,632.56 486,928.55 5.19 10,355.94 MWD (3) 12,880.61 91.87 197.71 6,227.38 6,080.38 -10,384.43 -1,013.93 5,938,604.09 486,918.77 9.34 10,384.43 MWD (3) 12,910.52 90.86 194.66 6,226.67 6,079.67 -10,413.14 -1,022.27 5,938,575.39 486,910.39 10.74 10,413.14 MWD (3) 12,945.48 90.31 193.75 6,226.31 6,079.31 -10,447.03 -1,030.85 5,938,541.52 486,901.76 3.04 10,447.03 MWD (3) 12,970.42 88.56 190.45 6,226.56 6,079.56 -10,471.41 -1,036.07 5,938,517.15 486,896.50 14.98 10,471.41 MWD (3) 13,000.42 87.42 189.57 6,227.61 6,080.61 -10,500.94 -1,041.28 5,938,487.64 486,891.24 4.80 10,500.94 MWD (3) 13,030.45 86.72 189.89 6,229.15 6,082.15 -10,530.50 -1,046.35 5,938,458.09 486,886.12 2.56 10,530.50 MWD (3) 13,061.92 87.42 188.39 6,230.75 6,083.76 -10,561.52 -1,051.35 5,938,427.07 486,881.08 5.25 10,561.52 MWD (3) 13,090.58 86.78 185.19 6,232.21 6,085.21 -10,589.94 -1,054.73 5,938,398.66 486,877.65 11.37 10,589.94 MWD (3) 13,120.72 86.28 184.37 6,234.03 6,087.03 -10,619.92 -1,057.24 5,938,368.69 486,875.10 3.18 10,619.92 MWD (3) 13,150.40 85.55 181.97 6,236.14 6,089.14 -10,649.48 -1,058.87 5,938,339.14 486,873.41 8.43 10,649.48 MWD (3) 13,180.40 85.52 183.33 6,238.48 6,091.48 -10,679.36 -1,060.26 5,938,309.26 486,871.98 4.52 10,679.36 MWD (3) 13,210.76 85.21 185.29 6,240.93 6,093.93 -10,709.53 -1,062.53 5,938,279.10 486,869.66 6.52 10,709.53 MWD (3) 13,240.74 86.44 186.36 6,243.12 6,096.12 -10,739.27 -1,065.57 5,938,249.36 486,866.58 5.43 10,739.27 MWD (3) 13,270.64 87.94 186.74 6,244.58 6,097.58 -10,768.94 -1,068.97 5,938,219.70 486,863.12 5.17 10,768.94 MWD (3) 13,302.51 89.85 187.69 6,245.20 6,098.20 -10,800.55 -1,072.97 5,938,188.10 486,859.07 6.69 10,800.55 MWD (3) 13,331.30 90.83 188.33 6,245.03 6,098.03 -10,829.06 -1,076.99 5,938,159.60 486,855.02 4.07 10,829.06 MWD (3) 13,361.80 90.06 189.71 6,244.79 6,097.79 -10,859.18 -1,081.77 5,938,129.49 486,850.19 5.18 10,859.18 MWD (3) 13,390.72 88.74 188.51 6,245.09 6,098.09 -10,887.73 -1,086.35 5,938,100.95 486,845.56 6.17 10,887.73 MWD (3) 13,421.92 88.31 185.96 6,245.89 6,098.90 -10,918.67 -1,090.27 5,938,070.02 486,841.59 8.29 10,918.67 MWD (3) 13,450.86 88.16 184.83 6,246.79 6,099.79 -10,947.47 -1,092.99 5,938,041.23 486,838.82 3.94 10,947.47 MWD (3) 13,480.59 90.18 184.30 6,247.22 6,100.22 -10,977.10 -1,095.36 5,938,011.60 486,836.41 7.02 10,977.10 MWD (3) 13,510.47 89.91 182.97 6,247.19 6,100.19 -11,006.92 -1,097.25 5,937,981.79 486,834.47 4.54 11,006.92 MWD (3) 13,540.32 88.47 183.86 6,247.62 6,100.62 -11,036.71 -1,099.03 5,937,952.00 486,832.64 5.67 11,036.71 MWD (3) 13,570.55 87.54 185.55 6,248.67 6,101.67 -11,066.82 -1,101.51 5,937,921.90 486,830.11 6.38 11,066.82 MWD (3) 13,600.58 86.47 186.97 6,250.24 6,103.24 -11,096.63 -1,104.78 5,937,892.10 486,826.80 5.92 11,096.63 MWD (3) 13,630.32 85.85 188.81 6,252.23 6,105.23 -11,126.02 -1,108.85 5,937,862.72 486,822.68 6.52 11,126.02 MWD (3) 13,660.54 85.23 190.31 6,254.58 6,107.58 -11,155.73 -1,113.85 5,937,833.02 486,817.63 5.36 11,155.73 MWD (3) 13,690.42 85.33 192.41 6,257.04 6,110.04 -11,184.93 -1,119.72 5,937,803..84 486,811.72 7.01 11,184.93 MWD (3) 13,720.31 86.31 192.77 6,259.22 6,112.22 -11,214.02 -1,126.22 5,937,774.76 486,805.17 3.49 11,214.02 MWD (3) Annotation 10/1412016 10:05:43AM Page 4 COMPASS 5000.1 Build 74 ConocoPhillips F/kI ConocoPhillips BAKER Definitive Survey Report HUGHES Company: ConocoPhillips (Alaska) Inc. -Kup2 Local Co-ordinate Reference: Well 2M-08 Project: Kuparuk River Unit TVD Reference: 2M-08 @ 147.00usft (P245) Site: Kuparuk 2M Pad MD Reference: 2M-08 @ 147.00usft (P245) Well: 2M-08 North Reference: True Wellbore: 2M -08L1-01 Survey Calculation Method: Minimum Curvature Design: 2M -08L1-01 Database: EDM Alaska NSK Sandbox .. , . ,.. .. Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/ -S +E/ -W Northing Easting DLS Section (usft) (I (I (usft) (usft) (usft) (usft) (°1100') Survey Tool Name Annotation (ft) (ft) (ft) 13,750.44 87.27 192.83 6,260.90 6,113.90 -11,243.35 -1,132.88 5,937,745.44 486,798.46 3.19 11,243.35 MWD (3) 13,780.47 88.71 193.57 6,261.96 6,114.96 -11,272.57 -1,139.74 5,937,716.24 486,791.56 5.39 11,272.57 MWD (3) 13,810.18 89.60 193.89 6,262.39 6,115.40 -11,301.43 -1,146.79 5,937,687.39 486,784.47 3.18 11,301.43 MWD (3) 13,841.32 90.68 194.77 6,262.32 6,115.32 -11,331.60 -1,154.49 5,937,657.24 486,776.71 4.47 11,331.60 MWD (3) 13,870.32 90.80 197.90 6,261.94 6,114.94 -11,359.42 -1,162.65 5,937,629.43 486,768.51 10.80 11,359.42 MWD (3) 13,900.43 91.26 197.16 6,261.40 6,114.40 -11,388.13 -1,171.72 5,937,600.74 486,759.40 2.89 11,388.13 MWD (3) 13,930.21 91.93 197.53 6,260.57 6,113.57 -11,416.54 -1,180.59 5,937,572.34 486,750.48 2.57 11,416.54 MWD (3) 13,960.34 92.64 197.20 6,259.37 6,112.37 -11,445.28 -1,189.58 5,937,543.63 486,741.45 2.60 11,445.28 MWD (3) 13,990.16 92.98 194.98 6,257.91 6,110.91 -11,473.89 -1,197.83 5,937,515.03 486,733.15 7.52 11,473.89 MWD (3) 14,020.26 95.47 195.37 6,255.69 6,108.69 -11,502.86 -1,205.69 5,937,486.07 486,725.25 8.37 11,502.86 MWD (3) 14,050.17 98.00 195.51 6,252.19 6,105.19 -11,531.49 -1,213.59 5,937,457.46 486,717.30 8.47 11,531.49 MWD (3) 14,080.22 99.63 193.04 6,247.58 6,100.58 -11,560.27 -1,220.92 5,937,428.70 486,709.93 9.77 11,560.27 MWD (3) 14,108.23 99.78 193.08 6,242.86 6,095.86 -11,587.16 -1,227.16 5,937,401.82 486,703.65 0.55 11,587.16 MWD (3) 14,140.42 99.72 191.33 6,237.41 6,090.41 -11,618.17 -1,233.86 5,937,370.83 486,696.89 5.36 11,618.17 MWD (3) 14,173.14 99.18 191.15 6,232.03 6,085.03 -11,649.82 -1,240.15 5,937,339.18 486,690.55 1.74 11,649.82 MWD (3) 14,205.00 14,229.70 98.01 96.74 190.55 189.34 6,227.27 6,224.10 6,080.27 6,077.10 -11,680.76 -11,704.89 -1,246.08 -1,250.31 5,937,308.26 5,937,284.14 486,684.57 486,680.30 4.12 7.07 11,680.76 11,704.89 MWD (3) MWD (3) a 14,260.07 95.26 188.38 6,220.93 6,073.93 -11,734.73 -1,254.96 5,937,254.31 486,675.60 5.80 11,734.73 MWD (3) 14,290.62 93.90 187.40 6,218.49 6,071.49 -11,764.89 -1,259.14 5,937,224.15 486,671.38 5.48 11,764.89 MWD (3) ± 14,320.00 93.87 185.92 6,216.50 6,069.50 -11,794.01 -1,262.54 5,937,195.05 486,667.93 5.03 11,794.01 MWD (3) `s 14,350.21 93.94 185.19 6,214.44 6,067.44 -11,824.01 -1,265.46 5,937,165.06 486,664.97 2.42 11,824.01 MWD (3) 14,380.10 92.46 182.50 6,212.77 6,065.77 -11,853.78 -1,267.46 5,937,135.29 486,662.92 10.26 11,853.78 MWD (3) p 14,410.13 91.69 179.58 6,211.68 6,064.68 -11,883.78 -1,268.01 5,937,105.29 486,662.33 10.05 11,883.78 MWD (3) F 14,442.08 94.77 179.56 6,209.88 6,062.88 -11,915.68 -1,267.77 5,937,073.40 486,662.51 9.64 11,915.68 MWD (3) 14,462.79 96.09 177.53 6,207.92 6,060.92 -11,936.28 -1,267.24 5,937,052.79 486,663.00 11.65 11,936.28 MWD (3) 14,503.00 96.09 177.53 6,203.66 6,056.66 -11,976.23 -1,265.52 5,937,012.85 486,664.66 0.00 11,976.23 PROJECTED to TD 10/14/2016 10.,05:43AM Page 5 COMPASS 5000.1 Build 74 THE STATE 0f.zi-LASKA GOVERNOR BILL WALKER G. Eller CTD Engineering Supervisor ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510-0360 Alaska Oil and Gas Conservation o;; 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 www.aogcc.alaska.gov Re: Kuparuk River Field, Kuparuk River Oil Pool, KRU 2M -08L1-01 ConocoPhillips Alaska, Inc. Permit to Drill Number: 216-096 Surface Location: 114' FSL, 109' FWL, SEC. 27, TI IN, RBE, UM Bottomhole Location: 4314' FSL, 4079' FWL, SEC. 9, Tl ON, RBE, UM Dear Mr. Eller: Enclosed is the approved application for permit to re -drill the above referenced development well. The permit is for a new wellbore segment of existing well Permit No. 192-101, API No. 50-103- 20184-00-00. Production should continue to be reported as a function of the original API number stated above. This permit to drill does not exempt you from obtaining additional permits or an approval required by law from other governmental agencies and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the AOGCC reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the AOGCC specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or an AOGCC order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. Sincerely, Cathy 0. Foerster Chair DATED this Lv day of August, 2016. JUL. 29 20' STATE OF ALASKA AL :A OIL AND GAS CONSERVATION COMM ON A0GCG PERMIT TO DRILL 20 AAC 25.005 1 a. Type of Work: Drill ❑ Lateral, ❑✓ Redrill ❑ Reentry ❑ 1 b. Proposed Well Class: Exploratory - Gas ❑ Service - WAG ❑ Service - Disp ❑ Stratigraphic Test ❑ Development - Oil Service - Winj ❑ Single Zone Exploratory - Oil ❑ Development - Gas ❑ Service - Supply ❑ Multiple Zone ❑ 1 c. Specify if well is proposed for: Coalbed Gas ❑ Gas Hydrates ❑ 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 2M-081-1-01 3. Address: 6. Proposed Depth: 12. Field/Pool(s): P.O. Box 100360 Anchorage, AK 99510-0360 MD: 14,150't TVD: 6,060' Kuparuk River Field Kuparuk Oil Pool 4a. Location of Well (Governmental Section): 7. Property Designation (Lease Number): Surface: 114' FSL, 109' FWL, Sec. 27, T11 N, R8E, UM ADL 25589 Top of Productive Horizon: 8. Land Use Permit: 13. Approximate Spud Date: 1358' FSL, 4513' FWL, Sec. 4, T10N, R8E, UM Total Depth: 4314' FSL, 4079' FWL, Sec. 9, T10N, R8E, UM 2675 9/11/2016 9. Acres in Property: 7 27�u �i' 14. Distance to Nearest Property: 14,300' 4b. Location of Well (State Base Plane Coordinates - NAD 27): 10. KB Elevation above MSL (ft): 147 15. Distance to Nearest Well Open Surface: x- 487949 y- 5,948,986 Zone- 4 GL Elevation above MSL (ft): 106 to Same Pool: 2K-27, 1700' 16. Deviated wells: Kickoff depth: 12700 feet 11,9M 17. Maximum Potential Pressures in psig (see 20 AAC 25.035) Maximum Hole Angle: . 103 degrees Downhole: 4,547 psig v Surface: 3,930 psig 18. Casing Program: Specifications Top - Setting Depth - Bottom Cement Quantity, c.f. or sacks Hole Casing Weight Grade I Coupling Length MD TVD MD TVD (including stage data) 3" 2.375" 4.7# L-80 ST -L 2,474' 11,676' 6,119' 14,150' 6207' slotted liner 19. PRESENT WELL CONDITION SUMMARY (To be completed for Redrill and Re -Entry Operations) Total Depth MD (ft): Total Depth TVD (ft): Plugs (measured): Effect. Depth MD (ft): Effect. Depth TVD (ft): Junk (measured): 12,151' 6,476' none 12,046' 6,397' none Casing Length Size Cement Volume MD TVD Conductor/Structural 79' 16" 250 sx AS II 121' 121' Surface 4,211' 9-5/8" 660 sx PF E & 760 sx Class G 4253' 2744' Production 12,099' 7" 198 sx Class G 12138' 6466' Perforation Depth MD (ft): 11,721'-11,750' sgz'd Perforation Depth TVD (ft): 6,153'-6,175' sgz'd 11,784'-11,807' sgz'd 6,200'-6,218' sgz'd 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 0 21. Verbal Approval: Commission Representative: Date � Zy L7014 22. 1 hereby certify that the foregoing is true and the procedure approved herein will not Contact J. Connelly @ 263-4112 C be deviated from without prior written approval. Email Ieff.S.COtlnelly gt�COp.COn1 Printed Nam G. Ell* (5 Title CTD Engineering Supervisor t• Signature Phone 263-4172 Date dip Commission Use Only Permit to Drill API Number: Permit Approval See cover letter for other OC�(D_OC( �o3-4Q�g4/-44_0 Date: requirements. Number: `�+ 50- C! �� 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: �30P tv 4-50 r5 1 Samples req'd: Yes ❑ NoV Mud log req'd: Yes ❑ No[z H2S measures: Yes [� No E] Directional svy req'd: Yes d No ❑ f�ST Spacing exception req'd: Yes ❑ No x Inclination -only svy req'd: Yes ❑ No [ y i�✓ r o h k "l Post initial injection MIT req'd: Yes ❑ No LJ 611r)wh15'v`c q/C'", �"L1;�cirt✓IJ lct1trc_ l , J APPROVED BY Approved by COMMISSIONER THE COMMISSION Datezq L Submit Form and Form 10-401 ( evised 11/2015) / This permit is valid for 24 or ft�o� �1R dF adprQval (20 AAC 25.005(g)) Attachments in Duplicate ConocoPhilli s p Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 July 26, 2016 Commissioner - State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Dear Commissioner: ConocoPhillips Alaska, Inc. hereby submits applications for permits to drill a dual -lateral out of the KRU 2M-08 (PTD 192-101) using the coiled tubing drilling rig, Nabors CDR2-AC or Nabors CDR3-AC. The scope of work and window exit type for KRU 2M-08 have been modified from a cement pilot -hole casing exit to a big tail -pipe casing exit. For this reason, please cancel the previously issued sundry (316-116) and permits to drill 216-032, 216-033, 216-034, and 216 -035 for 2M-08. To account for geological uncertainties, ConocoPhillips requests a variance from the requirements of 20 AAC 25.015 to allow the actual kick-off point to be anywhere along the length of the parent lateral instead of being limited to 500' from the original point. The work is scheduled to begin September 11, 2016. The objective will be to drill laterals KRU 2M-081_1 and 2M- 081_1-01 targeting the Kuparuk A -sands. Attached to this application are the following documents: — 10-401 Applications for 2M-081_1 and 2M-081_1-01 — Detailed Summary of Operations — Directional Plans for 2M-081_1 and 2M-081_1-01 — Proposed CTD Schematic If you have any questions or require additional information, please contact me at 907-263-4112. Sincerely, Jeff Connelly ConocoPhillips Alaska Coiled Tubing Drilling Engineer Kuparuk CTD Laterals NABORS ALASKA 2M-081-1, 2M-081-1-01 Application for Permit to Drill Document 2AC 1. Well Name and Classification........................................................................................................ 2 Attachment 2: (Requirements of 20 AAC 25.005(1) and 20 AAC 25.005(b))................................................................................................................... 2 2. Location Summary.......................................................................................................................... 2 Attachment 4: (Requirements of 20 AAC 25.005(c)(2)).................................................................................................................................................. 2 3. Blowout Prevention Equipment Information................................................................................. 2 (Requirements of 20 AAC 25.005(c)(3))................................................................................................................................................. 2 4. Drilling Hazards Information and Reservoir Pressure.................................................................. 2 (Requirements of 20 AAC 25.005(c)(4))................................................................................................................................................. 2 5. Procedure for Conducting Formation Integrity tests................................................................... 2 (Requirements of 20 AAC 25.005(c)(5)).................................................................................................................................................. 2 6. Casing and Cementing Program.................................................................................................... 3 (Requirements of 20 AAC 25.005(c)(6)).................................................................................................................................................. 3 7. Diverter System Information.......................................................................................................... 3 (Requirements of 20 AAC 25.005(c)(7))..................................................................................................................................................3 8. Drilling Fluids Program.................................................................................................................. 3 (Requirements of 20 AAC 25.005(c)(8)).................................................................................................................................................. 3 9. Abnormally Pressured Formation Information............................................................................. 4 (Requirements of 20 AAC 25.005(c)(9)).................................................................................................................................................. 4 10. Seismic Analysis............................................................................................................................. 4 (Requirements of 20 AAC 25.005(c)(10))................................................................................................................................................ 4 11. Seabed Condition Analysis............................................................................................................4 (Requirements of 20 AAC 25.005(c)(11))................................................................................................................................................ 4 12. Evidence of Bonding...................................................................................................................... 4 (Requirements of 20 AAC 25.005(c)(12))................................................................................................................................................ 4 13. Proposed Drilling Program.............................................................................................................4 (Requirements of 20 AAC 25.005(c)(13))................................................................................................................................................ 4 Summaryof Operations...................................................................................................................................................4 LinerRunning...................................................................................................................................................................6 14. Disposal of Drilling Mud and Cuttings.......................................................................................... 6 (Requirements of 20 AAC 25.005(c)(14))................................................................................................................................................ 6 15. Directional Plans for Intentionally Deviated Wells....................................................................... 7 (Requirements of 20 AAC 25.050(b)).. . ........................ .............. . . ..................................... ............ ..... 7 16. Attachments.................................................................................................................................... 7 Attachment 1: Directional Plans for 2M -08L1 laterals.....................................................................................................7 Attachment 2: Current Well Schematic for 2M-08...........................................................................................................7 Attachment 3: Planned rig workover schematic..............................................................................................................7 Attachment 4: Proposed Well Schematic for 2M-081-1 and 2M -08L1-01 laterals............................................................7 Page 1 of 7 July 26, 2016 PTD Application: 21VI-081-1, 21VI-081-1-01 1. Well Name and Classification (Requirements of 20 AAC 25.005(0 and 20 AAC 25.005(b)) The proposed laterals described in this document are 2M-081-1, 2M-08AL1-01. All laterals will be classified as "Development -Oil" wells. 2. Location Summary (Requirements of 20 AAC 25.005(c)(2)) These laterals will target the A sand package in the Kuparuk reservoir. See attached 10-401 form for surface and subsurface coordinates of the 2M-081-1, 2M-081-1-01. 3. Blowout Prevention Equipment Information (Requirements of 20 AAC 25.005 (c)(3)) Please reference blowout prevention (BOP) schematics on file with the Commission for Nabors CDR2-AC. BOP equipment is as required per 20 AAC 25.036 for thru-tubing drilling operations. — Pipe rams, blind rams and the CT pack off will be pressure tested to 250 psi and to 4,500 psi. Using the maximum formation pressure in the area of 4,547 psi in 2M-35 (i.e. 14.1"ppg EMW), the maximum potential surface pressure in 2M-08, assuming a gas gradient of 0.1 psi/ft, would be 3,927 psi. See the "Drilling Hazards Information and Reservoir Pressure" section for more details. — The annular preventer will be tested to 250 psi and 2,500 psi. 4. Drilling Hazards Information and Reservoir Pressure (Requirements of 20 AAC 25.005 (c)(4)) Reservoir Pressure and Maximum Downhole Pressure (Requirements of 20 AAC 25.005 (c)(4)(a)) The formation pressure in KRU 2M-08 was measured to be 3,403 psi (10.8 ppg EMW) on 5/2/2016. All of the wells in the 2M-08 vicinity are SI except the 2M-14 producer. The maximum downhole pressure in the 2M-08 vicinity, but isolated by a sealing fault is the shut in 2M-35 injector at 4,547 psi (14.1 ppg EMW) from April 2016. Potential Gas Zones (Requirements of 20 AAC 25.005 (c)(4)(b)) Wells on 2M pad have injected gas, so there is a chance of encountering free gas while drilling the 2M-08 laterals. If significant gas is detected in the returns the contaminated mud can be diverted to a storage tank away from the rig. Potential Causes of Hole Problems (Requirements of 20 AAC 25.005 (c)(4)(c)) The major expected risk of hole problems in the 2M-08 laterals will be shale instability across faults. Managed pressure drilling (MPD) will be used to reduce the risk of shale instability associated with fault crossings. 5. Procedure for Conducting Formation Integrity tests (Requirements of 20 AAC 25.005(c)(5)) The 2M-08 laterals will be drilled under 20 AAC 25.036 for thru-tubing drilling operations so a formation integrity test is not required. Page 2 of 7 July 26, 2016 PTD Application: 21111-08L1, 21VI-081_1-01 6. Casing and Cementing Program (Requirements of 20 AAC 25.005(c)(6)) New Completion Details Lateral Name Liner Top Liner Btm Liner Top Liner Btm Liner Details Btm MD MD MD TVDSS TVDSS Conductor 21VII-081-1 12,100' 16,000' 6,050' 6,047` 23/", 4.7#, L-80, ST -L slotted liner; 0' 121' 1,640 670 Surface aluminum billet on top 21VI-081_1-01 11,676' 14,150' 5,972' 6,060' 23/", 4.7#, L-80, ST -L slotted liner; 2,744' 6,870 4,760 Production 7" deployment sleeve on top Existing Casing/Liner Information Category OD Weight (ppf) Grade Connection Top MD Btm MD Top TVD Btm TVD Burst psi Collapse psi Conductor 16" 62.5 H-40 Welded 0' 121' 0' 121' 1,640 670 Surface 9-5/8" 47 L-80 AB -MOD 0' 4,253' 0' 2,744' 6,870 4,760 Production 7" 26 J-55 BTC 0' 12,138' 0' 6,466' 4,980 4,320 Tubing 3-1/2" 9.3 J-55 EUE 0 11,610' 0 6,069' 10,160 10,540 Tubing Tail 4-1/2" 12.6 L-80 STC 11,681 11,765 6,123 6,186 NA NA 7. Diverter System Information (Requirements of 20 AAC 25.005(c)(7)) Nabors CDR2-AC will be operating under 20 AAC 25.036, for thru-tubing drilling operations. Therefore, a diverter system is not required. 8. Drilling Fluids Program (Requirements of 20 AAC 25.005(c)(8)) Diagram of Drilling System A diagram of the Nabors CDR2-AC mud system is on file with the Commission. Description of Drilling Fluid System — Window milling operations: Chloride -based FloVis mud (8.6 ppg) — Drilling operations: Chloride -based FloVis mud (8.6 ppg). While this mud weight will not hydrostatically overbalance the reservoir pressure, overbalanced conditions will be maintained using MPD practices described below. — Completion operations: CTD will utilize an Orbit valve for formation isolation while running liner. In the event of an Orbit valve failure 11.8ppg NaBr completion fluid will be utilized to provide formation over- balance and well bore stability while running completions. Managed Pressure Drilling Practice Managed pressure drilling (MPD) techniques will be employed to maintain a constant overbalanced pressure on the open hole formation and promote wellbore stability throughout the coiled tubing drilling (CTD) process. Mud weight is not, in many cases, the primary well control barrier. This is satisfied with the 5,000 psi rated coiled tubing pack off and MPD choke. BOPE equipment provides the secondary well control as detailed in section 3 "Blowout Prevention Equipment Information". In the 2M-08 laterals we will target a constant BHP of 11.8 ppg EMW at the window. The constant BHP target will be adjusted through choke pressure and/or mud weight increases to maintain overbalanced conditions if increased reservoir pressure is encountered. Additional choke pressure or increased mud weight may also be employed for improved borehole stability. Any change of circulating friction pressure due to change in pump rates or change in depth of circulation will be offset with back pressure adjustments. Page 3 of 7 July 26, 2016 PTD Application: 21VI-081-1, 21VI-081-1-01 Pressure at the 21VI-08 Window (11,745' MD, 6171' TVD) Using MPD 9. Abnormally Pressured Formation Information (Requirements of 20 AAC 25.005(c)(9)) N/A - Application is not for an exploratory or stratigraphic test well. 10. Seismic Analysis (Requirements of 20 AAC 25.005(c)(10)) N/A - Application is not for an exploratory or stratigraphic test well. 11. Seabed Condition Analysis (Requirements of 20 AAC 25.005(c)(11)) N/A - Application is for a land based well. 12. Evidence of Bonding (Requirements of 20 AAC 25.005(c)(12)) Evidence of bonding for ConocoPhillips Alaska, Inc. is on file with the Commission. 13. Proposed Drilling Program (Requirements of 20 AAC 25.005(c)(13)) Summary of Operations Background Well 2M-08 was originally drilled and completed in 1992 with 3'/z" tubing and 7" production casing as an A5 -sand, gas lifted producer in Kuparuk. Well 2M-08 has been on production since 1993. In 2013 the A3 - sand was perforated. Prior to CTD operations, a workover will replace the existing completion with 4-1/2" big tail pipe to facilitate the CTD window exit. An Orbit valve will also be installed. Post CTD workover, a mechanical whip -stock will be set inside the 4'/z" big tail pipe at the planned kick off point of 11,745' MD. The 2M -08L1 lateral will exit through the big tail pipe at 11,745' MD and TD at 16,000 MD. Ll lateral will be completed with 2 3/8" slotted liner from TD up to 12,100' MD with an aluminum billet for kicking off the 2M -08L1-01 lateral. The 2M -08L1-01 will drill to a TD of 14,150' MD, with the liner top at 11,676' MD; just above the whipstock. Page 4 of 7 July 26, 2016 Pumps On 1.5 bpm) Pumps Off A -sand Formation Pressure (10.8 p 3466 psi 3466 psi Mud Hydrostatic (8.6 ) 2760 psi 2760 psi Annular friction i.e. ECD, 0.080 psi/ft 940 psi 0 psi Mud + ECD Combined no chokepressure) 3700 psi overbalanced —234psi) 2760 psi underbalanced —706psi) Target BHP at Window 11.8 ) 3787 psi 3787 psi Choke Pressure Required to Maintain Target BHP 87 psi 1027 psi 9. Abnormally Pressured Formation Information (Requirements of 20 AAC 25.005(c)(9)) N/A - Application is not for an exploratory or stratigraphic test well. 10. Seismic Analysis (Requirements of 20 AAC 25.005(c)(10)) N/A - Application is not for an exploratory or stratigraphic test well. 11. Seabed Condition Analysis (Requirements of 20 AAC 25.005(c)(11)) N/A - Application is for a land based well. 12. Evidence of Bonding (Requirements of 20 AAC 25.005(c)(12)) Evidence of bonding for ConocoPhillips Alaska, Inc. is on file with the Commission. 13. Proposed Drilling Program (Requirements of 20 AAC 25.005(c)(13)) Summary of Operations Background Well 2M-08 was originally drilled and completed in 1992 with 3'/z" tubing and 7" production casing as an A5 -sand, gas lifted producer in Kuparuk. Well 2M-08 has been on production since 1993. In 2013 the A3 - sand was perforated. Prior to CTD operations, a workover will replace the existing completion with 4-1/2" big tail pipe to facilitate the CTD window exit. An Orbit valve will also be installed. Post CTD workover, a mechanical whip -stock will be set inside the 4'/z" big tail pipe at the planned kick off point of 11,745' MD. The 2M -08L1 lateral will exit through the big tail pipe at 11,745' MD and TD at 16,000 MD. Ll lateral will be completed with 2 3/8" slotted liner from TD up to 12,100' MD with an aluminum billet for kicking off the 2M -08L1-01 lateral. The 2M -08L1-01 will drill to a TD of 14,150' MD, with the liner top at 11,676' MD; just above the whipstock. Page 4 of 7 July 26, 2016 PTD Application: 2M -08L1, 2M-081_1-01 Pre -CTD Work 1. Perform RWO to install 3-1/2" tubing, Orbit valve, packer, and 4-1/2" big tail pipe. Rid Work 1. MIRU Nabors CDR2-AC or CDR3-AC rig using 2" coil tubing. NU 7-1/16" BOPS, test. 2. 2M -08L1 Lateral (A4 sand to south) a. Set whip -stock at l 1,745' MD b. Mill 2.80" window at 11,745' MD. c. Drill 3" bi-center lateral to TD of 16,000' MD. d. Run 2%" slotted liner with an aluminum billet from TD up to 12,100' MD. 3. 2M -08L1-01 Lateral (A3 sand to south) a. Kickoff of the aluminum billet at 12,100' MD. b. Drill 3" bi-center lateral to TD of 14,150' MD. c. Run 2%" slotted liner from TD up into 3 1/z" tubing at 11,676' MD 4. Freeze protect. Set BPV, ND BOPE. RDMO Nabors CDR2-AC or Nabors CDR3-AC. Post -Rig Work 1. Pull BPV. 2. Obtain SBHP. 3. Install GLV's . 4. Return to production. Page 5 of 7 July 26, 2016 PTD Application: 2M -08L1, 2M-081_1-01 Pressure Deployment of BHA The planned bottom hole assemblies (BHAs) are too long to simply isolate by closing the double swab valves on the Christmas tree. MPD operations require the BHA to be lubricated under pressure, so installed in this well is a deployment valve. This valve, when closed using hydraulic control lines from surface, isolates the well pressure and allows long BHA's to be deployed/un-deployed without killing the well. If the deployment valve fails, operations will continue using the standard pressure deployment process. A system of double swab valves on the Christmas tree, double deployment rams, double check valves and double ball valves in the BHA, and a slick -line lubricator can be used. This pressure control equipment listed ensures there are always two barriers to reservoir pressure, both internal and external to the BHA, during the deployment process. During BHA deployment, the following steps are observed. — Initially the double swab valves on the tree are closed to isolate reservoir pressure. The lubricator is installed on the BOP riser with the BHA inside the lubricator. — Pressure is applied to the lubricator to equalize across the swab valves. The swab valves are opened and the BHA is lowered in place via slickline. — When the BHA is spaced out properly, the double deployment rams are closed on the BHA to isolate reservoir pressure via the annulus. A closed set of double ball valves and double check valves isolate reservoir pressure internal to the BHA. Slips on the double deployment rams prevent the BHA from moving when differential pressure is applied. The lubricator is removed once pressure is bled off above the deployment rams. — The coiled tubing is made up to the BHA with the double ball valves plus the double check valves in the closed position. Pressure is applied to the coiled tubing to equalize internal pressure and then the double ball valves are opened. The injector head is made up to the riser, annular pressure is equalized, and the deployment rams are opened. The BHA and coiled tubing are now ready to run in the hole. During BHA undeployment, the steps listed above are observed, only in reverse. Liner Running — The 2M-08 well has a deployment valve installed. It will serve to deploy liners into the newly drilled laterals. If the valve fails, the laterals will be displaced to an overbalance completion fluid (as detailed in Section 8 "Drilling Fluids Program") prior to running liner. — While running 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 23/" 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 July 26, 2016 PTD Application: 21VI-081-1, 21VI-081-1-01 15. Directional Plans for Intentionally Deviated Wells (Requirements of 20 AAC 25.050(b)) - The Applicant is the only affected owner. - Please see Attachment 1: Directional Plans - Magnetic and inclination surveys will be taken every 30 ft. No gyro will be run. - MWD directional, resistivity, and gamma ray will be run over the entire open hole section. - Distance to Nearest Property Line (measured to KPA boundary at closest point) Lateral Name Distance 2M -08L1 14,294 2M -08L1-01 14,300' - Distance to Nearest Well within Pool 16. Attachments Attachment I.- Attachment :Attachment 2: Attachment 3: Attachment 4: Lateral Name Distance Well. 2M -08L1 240' 2K-27 2M-08AL1-01 1,700' 2K-27 Directional Plans for 2M -08L 1 laterals Current Well Schematic for 2M-08 Planned rig workover schematic Proposed Well Schematic for 2M -08L 1 and 2M -08L 1-01 laterals Page 7 of 7 July 26, 2016 KUP PROD 2M-08 conocornnups Well Attributes Max Angle & MD TD Alaska, Inc. Wellbore API/SWI Field Name Wellbore Status ncl (") MD (ftKB) Act Elm IRKS) 501032018400 KUPARUK RIVER UNIT PROD 68.17 7,756.40 12,151.0 ••• lComment I 142S (ppm)Dale SSSV: TRDP 55 11/21/2015 Annotation End Date Last WO: KB -Td (ft) Rig Release Date 46.21 11/9/1992 2M08, 6/8/20165:57:24 PM Ve,hcalschemaec ac Wal Annotation Depth (ftKB) End Date Annotation Last Motl By End Data Last Tag: SLM 11,842.0 3/2/3016 Rev Reason: GLV C/O, CUT TUBING, SET 2.80 ppmven 6/8/2016 ISO SLEEVE HANGER', 39.2 Strings ICasing Casing Description OD (in) ID (in) Top (ftKB) Set Depth (ftKB) Set Depth (TVD)... WtlLen (1... Grade Top Thread CONDUCTOR 16 15.062 42.0 121.0 121.0 62.58 H-40 WELDED Casing Description OD (in) ID (in) Top (ftKB) Sel Depth (ftKB) Set Depth (TVD)... WtlLen 8... Gmde Top Thread I' SURFACE 95/8 8.921 41.8 4,252.8 2,743.9 47.00 L-80 AB -MOD Casing Description OD (in) ID (in) Top (ftKB) Set Depth (ftKB) Set Depth (TVD)... WVLen (I... Gratle Top Thread PRODUCTION 7 6.276 39.2 12,138.0 6,466.1 26.00 J-55 BTC Tubing Strings Tubing Description Shing Ma... ID (in) Top (ftKB) Set Depth (0% Set Depth (TVD) (AWL 01,1) Grade Top Connection CONDUCTOR;42.0-121.0 TUBING 31/2 2.992 39.2 11,610.5 6,069.4 9.30 J-55 ABM-EUE Completion Details Nominal ID Top (ftKB) Top (TVD) (ftKB) Top Incl (') Item Des Com (in) 39.2 39.2 0.24 HANGER FMC GEN IV TUBING HANGER 3.500 SAFETY VLV, 1,806.9 1,806.9 1,655.5 46.56 SAFETY VLV CAMCO TRDP-4A-RO SAFETY VALVE 2.812 (SET 2.80' ISO SLEEVE IN TRSV ON 6/6/2016) 11,568.1 6,037.7 41.88 PBR BAKER PBR 3.000 11,581.9 6,047.9 41.50 PACKER BAKER HE RETRIEVABLE PACKER 2.870 11,598.0 6,060.1 41.14 NIPPLE CAMCO D NIPPLE 2.750 11,609.6 6,068.8 40.94130S BAKER SHEAR OUT SUB, TTL ELMD @ 11 605'SWS 3.015 PPROF 6/3/2007 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Tap (TVD) Top Incl Top (ftKB) (ftKB) (°) Ges Com Run Data ID (in) 11,548.0 6,022.7 42.35 CUT TUBING CUTTUBING 5/2/2016 SURFACE; 41.6-0,252.6 Perforations & Slots GAS LIFT; 4,384.9 Shot Dens Top (TVD) St. (TVD) (shotsk Top (ftKB) Btm (ftKB) (ftKB) (ftKB) Zone Dale t) Type Co. 11,721.0 11,750.0 6,152.9 6,174.8 A-5, A-4, 2M- 12/26/1992 4.0 (PERF 180 deg. phasing; 41/2" 08 Csg Gun 11,784.0 11,807.0 6,200.3 6,217.5 A-3, 2M-08 4/6/2013 6.0 APERF 2.5" HSD Gun, 60 degree phase Mandrel Inserts St GAS LIFT; 8,855.3 ali on Top (TVD) Valve Latch PortSize TRO Run N Top (ftKB) (ftKB) Make Model OD (in) Sery Type Type (in) (psi) Run Date Com 1 4,384.9 2,800.6 CAMCO KBUG 1 GAS LIFT GLV INT 0.188 1,344.0 1/25/2015 2 8,855.3 4,627.8 CAMCO KBUG 1 GAS LIFT GLV INT 0.188 1,323.0 1/28/2015 GAS LIFT; 11039.0 3 11,039.0 5,669.0 CAMCO KBUG 1 GAS LIFT GLV INT 0.188 1,303.0 5/2/2016 4 11,520.6 6,002.5 CAMCO MMG 1 1/2 GAS LIFT OPEN 6/5/2016 Notes: General & Safety End Dale Annotation 11/1112010 NOTE: View Schematic w/ Alaska Schematic9.0 GAS LIFT; 11,520.6 CUT TUBING; 11,548.0 PBR; 11,568.1 PACKER; 11,581.9 NIPPLE; 11,598.0 SOS; 11,609.5 IPERF; 11,721.0-11,750.0 APERF; 11,784.0-11,807.0 i PRODUCTION', 39.212.138.0 16" 62# H - shoe @ 12 MD 9-5/8" 47# shoe @ 4: CTD KC @ 11,7, A5 -sand pe 11721' - 11' A3 -sand per 11784'- 118 2M-08 Proposed RWO Schematic Modified by JGE 6-6-16 Baker Orbit Valve at 4500' MD (2.835" minimum ID) 3-1/2" 9.3# L-80 ELIE 8rd Tubing to surface 3-1/2" Camco gas lift mandrels @ TBD Baker PBR @ XXXX' MD Baker FHL packer @ xxxx' MD 3-1/2" HES landing nipple — xxxx' MD (2.812" min ID) 4-1/2" Big Tail Pipe (see details below) 1'-11765' MD CRITICAL DEPTH!! 1-112", 12.6#, J-55, STC Range 3 (assume jnts 42' ea) is ported between each wearsox so old perfs not restricted ;h correlated via drill pipe irsox 6" OD, every 2.5-3.0' along the pipe Wshoe on bottom onnections Baker -Locked 2M-08 Proposed CTD Schematic 16" 62# H-40 shoe @ 121' MD 9-5/8" 47# L-80 shoe @ 4253' MD IKOP @ 11,745' MD A5 -sand perfs 11721'- 11750' MD A3 -sand perfs 11784'- 11807' MD 7" 26# J-55 shoe @ 12138' MD Modified by JGE 6 6-16 Baker Orbit Valve at 4500' MD (2.835" minimum ID) 3-1/2" 9.3# L-80 ELIE 8rd Tubing to surface 3-1/2" Camco gas lift mandrels @ TBD Baker PBR @ XXXX' MD Baker FHL packer @ xxxx' MD 3-1/2" HES landing nipple —xxxx' MD (2.812" min ID) 4-1/2" Big Tail Pipe planned at 11,681'-11765' MD 2M-081-1 WP05 (A4 South) TD @ 16,000' MD Billet @ 12,100' MD 2M-OSL1-01 WP04 (A3 South West) TD @ 14,150' MD Top of Liner @ 11,600' MD ConocoPhillips ConocoPhillips (Alaska) Inc. -Kup2 Kuparuk River Unit Kuparuk 2M Pad 2M-08 501032018400 2M -08L1-01 Plan: 2M-08L1-01_wp05 Standard Planning Report 22 July, 2016 Ft A Ed as BAKER HUGHES ConocoPhillips Database: EDM Alaska NSK Sandbox Company: ConocoPhillips (Alaska) Inc. -Kup2 Project: Kuparuk River Unit Site: Kuparuk 2M Pad Well: 2M-08 Wellbore: 2M-081-1-01 Design: 2M -08L1-01 _wp05 ConocoPhillips Planning Report Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Well 2M-08 Mean Sea Level 2M-08 @ 147.00usft (P245) True Minimum Curvature Project Kuparuk River Unit, North Slope Alaska, United States Map System: US State Plane 1927 (Exact solution) System Datum: Mean Sea Level Geo Datum: NAD 1927 (NADCON CONUS) Using Well Reference Point Map Zone: Alaska Zone 04 Using geodetic scale factor ri.I BAKER HUGHES Site Kuparuk 2M Pad Site Position: Northing: 5,948,985.89 usft Latitude: 70° 16'18.578 N From: Map Easting: 487,859.45 usft Longitude: 150° 5'53.484 W Position Uncertainty: 0.00 usft Slot Radius: 0.000 in Grid Convergence: -0.09 ° Well 2M-08 Well Position +N/ -S 0.00 usft Northing: 5,948,985.84 usft Latitude: 70° 16' 18.579 N +E/ -W 0.00 usft Easting: 487,949.23 usft Longitude: 150° 5'50.870 W Position Uncertainty 0.00 usft Wellhead Elevation: usft Ground Level: 105.50 usft Wellbore 2M-081-1-01 Magnetics Model Name Sample Date Declination Dip Angle Field Strength (°) (°) (nT) BGGM2015 5/1/2016 18.26 80.90 57,483 Design 2M-08L1-01_wp05 Audit Notes: Version: Phase: PLAN Tie On Depth: 11,900.00 Vertical Section: Depth From (TVD) +N/ -S +E/ -W Direction (usft) (usft) (usft) (°) -10550 0.00 000 180.00 Plan Sections Measured TVD Below Dogleg Build Turn Depth Inclination Azimuth System +N/ -S +E/ -W Rate Rate Rate rFO (usft) (°) (°) (usft) (usft) (usft) (°/100ft) (°/100ft) (°/100ft) (°) 11,900.00 97.59 175.77 6,072.79 -9,454.08 -867.01 0.00 0.00 0.00 0.00 12,000.00 87.74 177.50 6,068.14 -9,553.67 -861.16 10.00 -9.85 1.73 170.00 12,070.00 83.26 182.90 6,073.64 -9,623.41 -861.39 10.00 -6.40 7.71 130.00 12,170.00 89.72 190.54 6,079.77 -9,722.41 -873.08 10.00 6.47 7.64 50.00 12,300.00 90.18 203.53 6,079.88 -9,846.44 -911.09 10.00 0.35 9.99 88.00 12,550.00 90.16 178.53 6,079.12 -10,089.87 -958.55 10.00 -0.01 -10.00 270.00 12,750.00 89.81 198.53 6,079.16 -10,286.66 -988.07 10.00 -0.18 10.00 91.00 12,950.00 89.82 178.53 6,079.80 -10,483.44 -1,017.59 10.00 0.01 -10.00 270.00 13,150.00 90.18 198.53 6,079.80 -10,680.23 -1,047.10 10.00 0.18 10.00 89.00 13,350.00 90.17 178.53 6,079.20 -10,877.01 -1,076.60 10.00 -0.01 -10.00 270.00 13,600.00 90.15 203.53 6,078.50 -11,120.45 -1,124.04 10.00 -0.01 10.00 90.00 13,800.00 90.14 183.53 6,077.99 -11,313.92 -1,170.58 10.00 0.00 -10.00 270.00 14,000.00 90.13 203.53 6,077.51 -11,507.39 -1,217.13 10.00 0.00 10.00 90.00 14,150.00 103.08 211.16 6,060.26 -11,639.42 -1,285.26 10.00 8.63 5.09 30.00 Target 7/22/2016 4:24:31PM Page 2 COMPASS 5000.1 Build 74 1 ConocoPhillips ConocoPhillips Planning Report BAKER HUGHES Database: EDM Alaska NSK Sandbox Local Co-ordinate Reference: Well 2M-08 Company: ConocoPhillips (Alaska) Inc. -Kup2 TVD Reference: Mean Sea Level Project: Kuparuk River Unit MD Reference: 2M-08 @ 147.00usft (P245) Site: Kuparuk 2M Pad North Reference: True Well: 2M-08 Survey Calculation Method: Minimum Curvature Wellbore: 2M-081-1-01 Design: 2M-08L1-01_wp05 Planned Survey Measured TVD Below Vertical Dogleg Toolface Map Map Depth Inclination Azimuth System +Nl-S +EI -W Section Rate Azimuth Northing Easting (usft) C) (°) (usft) (usft) (usft) (usft) (°/100ft) (°) (usft) (usft) 11,900.00 97.59 175.77 6,072.79 -9,454.08 -867.01 9,454.08 0.00 0.00 5,939,534.11 487,067.18 TIP/KOP 12,000.00 87.74 177.50 6,068.14 -9,553.67 -861.16 9,553.67 10.00 170.00 5,939,434.52 487,072.86 Start 10 dis 12,070.00 83.26 182.90 6,073.64 -9,623.41 -861.39 9,623.41 10.00 130.00 5,939,364.78 487,072.52 3 12,100.00 85.19 185.20 6,076.66 -9,653.18 -863.50 9,653.18 10.00 50.00 5,939,335.02 487,070.36 12,170.00 89.72 190.54 6,079.77 -9,722.41 -873.08 9,722.41 10.00 49.77 5,939,265.82 487,060.67 4 12,200.00 89.83 193.54 6,079.89 -9,751.74 -879.34 9,751.74 10.00 88.00 5,939,236.49 487,054.37 12,300.00 90.18 203.53 6,079.88 -9,846.44 -911.09 9,846.44 10.00 87.99 5,939,141.86 487,022.47 5 12,400.00 90.18 193.53 6,079.57 -9,941.13 -942.83 9,941.13 10.00 -90.00 5,939,047.23 486,990.58 12,500.00 90.17 183.53 6,079.26 -10,039.90 -957.65 10,039.90 10.00 -90.03 5,938,948.49 486,975.60 12,550.00 90.16 178.53 6,079.12 -10,089.87 -958.55 10,089.87 10.00 -90.06 5,938,898.52 486,974.62 6 12,600.00 90.08 183.53 6,079.01 -10,139.85 -959.45 10,139.85 10.00 91.00 5,938,848.56 486,973.64 12,700.00 89.90 193.53 6,079.03 -10,238.62 -974.27 10,238.62 10.00 91.01 5,938,749.82 486,958.67 12,750.00 89.81 198.53 6,079.16 -10,286.66 -988.07 10,286.66 10.00 91.01 5,938,701.81 486,944.79 7 12,800.00 89.81 193.53 6,079.32 -10,334.70 -1,001.88 10,334.70 10.00 -90.00 5,938,653.79 486,930.91 12,900.00 89.82 183.53 6,079.64 -10,433.47 -1,016.69 10,433.47 10.00 -89.98 5,938,555.06 486,915.94 12,950.00 89.82 178.53 6,079.80 -10,483.44 -1,017.59 10,483.44 10.00 -89.95 5,938,505.09 486,914.96 8 13,000.00 89.91 183.53 6,079.92 -10,533.42 -1,018.49 10,533.42 10.00 89.00 5,938,455.12 486,913.98 13,100.00 90.09 193.53 6,079.92 -10,632.19 -1,033.30 10,632.19 10.00 88.99 5,938,356.39 486,899.01 13,150.00 90.18 198.53 6,079.80 -10,680.23 -1,047.10 10,680.23 10.00 88.99 5,938,308.37 486,885.14 9 13,200.00 90.18 193.53 6,079.65 -10,728.27 -1,060.90 10,728.27 10.00 -90.00 5,938,260.36 486,871.26 13,300.00 90.17 183.53 6,079.35 -10,827.04 -1,075.71 10,827.04 10.00 -90.02 5,938,161.62 486,856.30 13,350.00 90.17 178.53 6,079.20 -10,877.01 -1,076.60 10,877.01 10.00 -90.05 5,938,111.65 486,855.32 10 13,400.00 90.16 183.53 6,079.06 -10,926.99 -1,077.50 10,926.99 10.00 90.00 5,938,061.68 486,854.35 13,500.00 90.16 193.53 6,078.77 -11,025.76 -1,092.31 11,025.76 10.00 90.01 5,937,962.95 486,839.38 13,600.00 90.15 203.53 6,078.50 -11,120.45 -1,124.04 11,120.45 10.00 90.04 5,937,868.31 486,807.50 11 13,700.00 90.15 193.53 6,078.24 -11,215.15 -1,155.78 11,215.15 10.00 -90.00 5,937,773.68 486,775.61 13,800.00 90.14 183.53 6,077.99 -11,313.92 -1,170.58 11,313.92 10.00 -90.03 5,937,674.94 486,760.65 12 13,900.00 90.14 193.53 6,077.74 -11,412.69 -1,185.39 11,412.69 10.00 90.00 5,937,576.21 486,745.68 14,000.00 90.13 203.53 6,077.51 -11,507.39 -1,217.13 11,507.39 10.00 90.02 5,937,481.57 486,713.80 13 14,100.00 98.78 208.57 6,069.74 -11,596.85 -1,260.83 11,596.85 10.00 30.00 5,937,392.18 486,669.96 14,150.00 103.08 211.16 6,060.26 -11,639.42 -1,285.26 11,639.42 10.00 30.39 5,937,349.66 486,645.47 Planned TD at 14150.00 7/22/2016 4:24:31PM Page 3 COMPASS 5000.1 Build 74 )0--**' ConocoPh i I I i ps ConocoPhillips (Alaska) Inc. -Ku p2 Kuparuk River Unit Kuparuk 2M Pad 2M-08 501032018400 2M -08L1-01 2M-08L1-01_wp05 Travelling Cylinder Report 21 July, 2016 Few a I BAKER HUGHES ConocoPhillips Company: ConocoPhillips (Alaska) Inc. -Kup2 Project: Kuparuk River Unit Reference Site: Kuparuk 2M Pad Site Error: 0.00 usft Reference Well: 2M-08 Well Error: 0.00 usft Reference Wellbore 2M -08L1-01 Reference Design: 2M-081_1-01_wp05 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 2M-08 2M-08 @ 147.00usft (P245) 2M-08 @ 147.00usft (P245) True Minimum Curvature 1.00 sigma OAKEDMP2 Offset Datum ri.l BAKER HUGHES Reference 2M-08L1-01_wp05 Filter type: GLOBAL FILTER APPLIED: All wellpaths within 200'+ 100/1000 of reference Interpolation Method: TVD Interval 25.00usft Error Model: ISCWSA Depth Range: 11,900.00 to 14,150.00usft Scan Method: Tray. Cylinder North Results Limited by: Maximum center -center distance of 1,610.85 usft Error Surface: Elliptical Conic Casing Points Measured Vertical Casing Hole Depth Survey Tool Program Date 7/21/2016 (usft) (usft) Name From To 121.00 16" 16 24 (usft) (usft) Survey (Wellbore) Tool Name Description 151.90 11,740.89 2M-08 Srvy 1 - GCT -MS (2M-08) GCT -MS Schlumberger GCT multishot 11,740.89 11,900.00 2M-08L1_wp06 (2M-081_1) MWD MWD - Standard 11,900.00 14,150.00 2M-0811-01_wp05(2M-081-1-01) MWD MWD - Standard Casing Points Measured Vertical Casing Hole Depth Depth Diameter Diameter (usft) (usft) Name C) (1') 121.00 121.00 16" 16 24 4,253.00 2,743.97 9 5/8" 9-5/8 12-1/4 14,150.00 6,207.26 2 3/8" 2-3/8 3 Summary Site Name Offset Well - Wellbore - Design Reference Offset Centre to No -Go Allowable Measured Measured Centre Distance Deviation Warning Depth Depth Distance 0 from Plan 0 0 0 0 Out of range CC - Min centre to center distance or covergent point, SF - min separation factor, ES - min ellipse separation 7/21/2016 3:13:30PM Page 2 COMPASS 5000.1 Build 74 ConocoPhillips Project: Kuparuk River Unit Site: Kuparuk 2M Pad Azimuths to Trua North m"""c Nan': ta.', Mageefic Fiala WELLBORE DETAILS: 21MI-081-1 REFERENCE INFORMATION Parent Wellbore: 2M -OB Cc ordinate (NIE) Reference: Well 2M-08, True North Well: 2M-08 strangm: 57483.3anT Tie On MD: 11740.89 Vertical (TVD) Reference: 2M-08 @ 147.00usft (2M-08) Wellbore: 2M-081-1 Dip Angle: 80.90 Section (VS) Reference: Slot-(O.00N, O.00E) Plan: 2M-08L1_wp08 (2M -08/2M-081.1) Date: GM2015 Mosel: BGGM2015 Measured Depth Reference: 2M-08 147.00usft 2M-08 ( ) Calculation Method: Minimum Curvature _ w/.rI BAKER HUGHES West( -)/East(+) (350 usft/in) ConocoPhillips Project: Kuparuk River Unit Site: Kuparuk 2M Pad Ali muthsto111,Naith Magnetic Norm; 18.26• Magnetic Field WELLBORE DETAILS: 2M-081-1 REFERENCE INFORMATION Parent Wellbore: 21VI-08 Coordinate (N/E) Reference: Well 2M-08, True North Well: 2M-08 Strength: 574a3.3anT Tie on MD: 11740.69 Vertical (ND) Reference: 2M-08 @ 147.DOusft (2M-08) Wellbore: 2M-081-1 Dip Angle; 60.96• Section (VS) Reference: Slot -(O.00N, O.00E) Plan: 2M-08L1_W O6 2M-08/21VI-081-1 P ) Date: 5/12016 Model: BGGM2015 Measured Depth Reference'. 2M-08 @ 147.00uslt (2M-08) Calculation Method: Minimum Curvature EdPit BAKER HUGHES 2100 — _- 21% f-(,- /21,105 400 F M -2U/2 2b : 21 f)Ji21f y YIILa/LI4 --_M ,f 2✓r-36 I M ,#a D 2M -N1 M 210 M+21 941 1 211 is Hip Fir,.. T5 4 -Is 1400I2M^I s 1!/2M Ib 2M.ID M-1-9 ,211 7/7H "o �Q - .q• 0 4 011 7004_25,21,1-25_ 11 U; o 1-3F/-MhYnPli' �L D o:c ` �pl)t1 0 _.'� 21A 1521M- -700 52M -700 7!109 p poa .e 211t/°III Q .� L' a5 -1400 — - — _ r� o _ t _ 4-24)2 -24__ i /3HD 1(4/1{.III -2100 — °'- 61 �� 40) 46)" I lXq 3' 1i-14/21 3¢A �5��.{ : J - 2M� t M_.,. v G7� 4!0 5 2H 1 7^_il Irl f;l� T1'f{� 11 (�11.ft1'. .b -2800 I o -- — -I /?E 114 - tS gp0 G SOfO 'Lf-uA[2 ]-09� -3500 �, 'f 30 0- - t2t�r; p b0 i 6ppU .. 40 -4200 .('000 # .� 6000 3g9 1M,I 7121A.17 211-22/2K/ 22 - '211-14/:11-;4 ) AFI -Ib -4900 � 1 _4i 05 )q0 _ 2I�14[ CI 14 ----.. _5600 0,,00 lI0 _ '-K . - .1 f1i 1 2- -04/2K414 K -Oz IK -,,3 21'-02/2K 02 ... _ O -6300 n { '_ 191 M- 9[,plK1 - h^K �o K.05M - - - - O 1.d '�,rp.11o ,M-03 o - �--� :. a ��rt7 .�a0o i I b -7000 1 tvf- 2 i K 3�r- J-.. -7700 �Go tp�© -. .� aK-0'1 2K 0 111 0I Splo I ' SD Lw Al,1 O I s '7 -8400 3 -0813K 181. kdi8/�'K-(IK d40,1)snpo I K-ofc, 2kO'ArITz �" a .C." -9100 _ etir.~ M.o4rz�.rt 14 - � ' -10/1_If-322M 32 3 9800 /_M0 317 -10500 34/2K: Jt.t`-34! 34i'y o.,. .� eK otxzK- snPe3 � 2 � bac -11200 - 1 ' —. _ 2K t•rrK-0 I3P13' - _ _ 27v1-i�IM.s�1- 00p �. r,_ I.. 2' Iz/^_K.11�1 'K -( 12K.09 tVBl c. -17900 M312M-3.. 101 - d �y If 1 3� 2(\1- d o D 3 110 2 51110^4' 1 T a 2 1 2K 14 2 o c D -12600 _M 0x/_51-1 Ll.t 01 _ F _-.� I I' - _ � _ 2K _2iD2 A -b!2 -ISI 0 2K.2�r/2K_2' 2K '13/ K-.13 11 G J 0 4 >/ K -13300} _ 6 q4 _ K 11!21-1311 1 2K -13,21K -11A,2 �Kq 2 a 3 f1 0' ry� 1 -23 �_ S I0f 0 5D 1 - - - 2M-0 /2M4J I - _ 4-04/ V14 -14000 �A:1412K, lA.400 -14700 — ----- � 1�,o K -15400 - 2KrtvzK1„ -- 92K1 14 K:19ALi 2K -!5/2K-2- NI i 2 '�20„2K: 0 .r 5 rl K51 p 11 -16100 —_ � _ _ ._ . _ _ _ r¢ U a IK --Z2 o/2f.-2 ASLAIK--Z2-25PK 6pOp ( ncY,f I'nr 5,28/ K aRAI I IrzK 2-rn 0.22/2K- 2A1 I1-24/ K11 L r' -13300-12600-11900-11200-10500-9800 -9100 -8400 -7700 -7000 -6300 -5600 -4900 -4200 -3500 -2800 -2100 -1400 -700 0 700 1400 2100 2800 3500 4200 4900 5600 6JbCI/W1A 7700 8400 9100 9800 10500 11200 11900 12600 West( -)/East(+) (700 usft/in) ConocoPhillips Project: Kuparuk River Unit Site: Kuparuk 2M Pad A:imuthetoTruallorth Magnetic North: 18.26• Magnetic. Field WELLBORE DETAILS: 2M-08AL2 REFERENCE INFORMATION Parent Wellbore: 2M -08A Co-ordinate (NrE) Reference: We112M-08, True North Well: 2M-08 Strength: 57483.3.. Te on MD: 11900.00 Vertical (TVD) Reference' Mean Sea Level Wellbore:2M-081-1-01 0ipAngle:80.90• Longitude Section(VS)Reference: Slot -(O.00N,O.00E) Plan: 2M-081-1-01_wp05 (21VI-08/2M-081-1-01) Model. BGGM2015 5'50.870 W Measured Depth Reference: 2M -0e @ 147.00usfl (2M-08) Inc Azi TVDSS +N/ -S +E/ -W Cakulafion Method: Minimum Curvature Mean S -700( -750( -800( -850( -900( -950( -1000( 0 0-1050( 0-1150( 1200( CA -1250( -1300( -1350( -1400( rSRI BAKER HUGHES WELL DETAILS: 2M-08 +N/ -S +E/ -W Northing Easting Latitude Longitude 0.00 0.00 5948985.84 487949.23 70° 16' 18.579 N 150° 5'50.870 W Sec MD Inc Azi TVDSS +N/ -S +E/ -W Dleg TFace VSect Annotation 1 11900.00 97.59 175.77 6072.79 -9453.79 -867.33 0.00 0.00 9453.79 TIP/KOP 2 12000.00 87.74 177.50 6068.15 -9553.38 -861.48 10.00 170.00 9553.38 Start 10 cls 3 12070.00 83.26 182.90 6073.64 -9623.12 -861.72 10.00 130.00 9623.12 3 4 12170.00 89.72 190.54 6079.77 -9722.12 -873.40 10.00 50.00 9722.12 4 5 12300.00 90.18 203.53 6079.88 -9846.15 -911.41 10.00 88.00 9846.15 5 6 12550.00 90.16 178.53 6079.12 -10089.58 -958.88 10.00 270.0010089.58 6 7 12750.00 89.81 198.53 6079.16-10286.37 -988.40 10.00 91.0010286.37 7 8 12950.00 89.82 178.53 6079.80 -10483.15 -1017.91 10.00 270.0010483.15 8 9 13150.00 90.18 198.53 6079.80 -10679.94 -1047.42 10.00 89.0010679.94 9 10 13350.00 90.17 178.53 6079.20 -10876.72 -1076.92 10.00 270.0010876.72 10 11 13600.00 90.15 203.53 6078.50 -11120.17 -1124.36 10.00 90.0011120.17 11 12 13800.00 90.14 183.53 6077.99 -11313.63 -1170.91 10.00 270.0011313.63 12 13 14000.00 90.13 203.53 6077.51-11507.10 -1217.45 10.00 90.0011507.10 13 14 14150.00 103.08 211.16 6060.26 -11639.13 -1285.58 10.00 30.0011639.13 Planned TD at 14150.00 Mean S -700( -750( -800( -850( -900( -950( -1000( 0 0-1050( 0-1150( 1200( CA -1250( -1300( -1350( -1400( rSRI BAKER HUGHES 14500 -5000 -4500 -4000 -3500 -3000 -2500 -2600 -1500 -1000 -500 500 1000 ISnn 700n Sinn znnn acnn nnnn Vertical Section at 180.00° (65 usft/in) 2M 08L1 aultl TIP star P - -- 2M 08LI- I Fau tl 2M-O8 1-Ol 02--- ------------ ---- 8 9 'M-08 LI-01_ 03----- - 0 2M -)SLI -01 Faul 2 2M -(SLI -01 T04 -- -------- -------- -- 2M-081-1-01 T05--- -- 2M 8L1 ault2 Planne I TD .1 14150 00 2M- 8/2M- 8LI-0 2K 27/2K 27 14500 -5000 -4500 -4000 -3500 -3000 -2500 -2600 -1500 -1000 -500 500 1000 ISnn 700n Sinn znnn acnn nnnn Vertical Section at 180.00° (65 usft/in) TRANSMITTAL LETTER CHECKLIST WELL NAME: (, .9 M -CALL — O1 PTD: ✓ Development _ Service _ Exploratory _ Stratigraphic Test _ Non -Conventional FIELD: �1/s POOL: Check Box for Appropriate Letter / Paragraphs to he Included in Transmittal Letter CHECK OPTIONS TEXT FOR APPROVAL LETTER MULTI The permit is for a new wellbore segment of existing well Permit LATERAL No. 111, —/01 , API No. 50- /03- - 06 - GO. (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 Well Name: KUPARUK RIV UNIT 2M-081-1-01 Program DEV Well bore seg PTD#:2160960 Company CONOCOPHILLIPS ALASKA INC Initial Class/Type DEV -/ PEND GeoArea 890 Unit 11160 On/Off Shore On _ Annular Disposal ❑ Administration 17 Nonconven. gas conforms to AS31.05.03%.1_.A),(j.2.A-D) - - - - - - - - - - _ - NA_ - - - - - - - - - - - - - - - - - - - - - - - - - - - - 1 Permit fee attached NA Geologic 2 Lease number appropriate- ----- -------- -- Yes ----- ------------ -- ------------- ADL025586 Su_rf_Loc.; ADL025589,_Top Prod TD._ ----- Engineering 3 Unique well name and number - - - - - - - - - - - - - - - - - - - Yes KRU 2M -08L1-01_ _ ------------------- 4 Well located in_a_defined_pool_- - - - - _ - - - - - - Yes _ - - _ _ KUPARUK RIVER,_KUPARUK RIV OIL_- 49Q100,_governed- by Conservation -Order No. 432D. _ 5 Well located proper distance from drilling unit_boundary- - - - - - - - - - - - - - - - - - - - Yes - - - - _ - - CO 432D contains no spacing restriction with respect to drilling -unit boundaries.- - - - - - 6 Well located proper distance from other wells- - - - - - - - - - - - - - - - - - - Yes - - - - - - CO 432D has no interwell spacing restrictions_ - _ _ - - - - 7 Sufficient acreage -available in -drilling unit - - - - - - - - - - - - - - - - - - - - - - Yes - - - - _ 8 If -deviated, is wellbore plat -included _ - - - - - - - - - - - - - - - - - - - - - - - - - Yes _ ------------------------------------------ -------------- 9 Operator only affected party- - _ _ - - - - - Yes Wellbore -will be more than 5QV from an external property line where ownership or landownership_ changes._ 10 Operator has_appropriatebondinforce--------------------- ---------- Yes- --- ---------------------------------- --------- ---------------------- Appr Date 11 -Permit can be issued without conservation order_ Yes- ------------- -------------- PKB 8/1/2016 12 Permit can be issued _without administrative approval - - - - - - - - - - - - - Yes - - - _ _ - - - - - - - - - - - - - - VTL 8/4/2016 13 Can permit be approved before 15 -day - - _ - -_ Yes Well - ------ --- - - - - - - - - -- 14 located within area and authorized by Injection Order # (put 10# in comments)_(For. NA- - - - - - - - - - - - - - - _ - - - - . - - - _ - - - _ - - - - - - - - - - - - - - _ 15 All welis_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_ Geologic 18 Conductor string -provided - - - - - - - - _ _ _ -- - - - NA_ Conductor set in 2M-08 Engineering 19 Surface casing_ protects all -known_ USDWs N_A_ Surface casing set in 2M-08 20 CMT_vol_ adequate to circulate -on conductor & surf - - - _ - - ---- - - -- - 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 _uncemente_d slotted liner_ 23 Casing designs adequate for C,_T B &_ permafrost_ Yes _ 124 Adequate -tankage or reserve pit Yes Rig has steel tanks; all waste 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_ - - - - _N_A_ - _ - - - - - - Appr Date I28 Drilling fluid_ program schematic-&- equip list adequate_ - - - _ . - . .. - Yes - - - - - Max formation_ pres is 4547psig(14.1 ppg EMW); Wil drill w/_8.6 ppg EM_W and- maintain overbal with- MPD VTL 8/4/2016 29 BOPEs,_do they meet regulation - - - - - _ - - Yes - ------ --- - - - - - - - - -- 30 IDPE_press rating appropriate; test to -(put psig in comments)_ _ - - Yes 930 MPSP is 3930 psig; will test BOPs_to 4500 ---- --- --- 31 Choke manifold complies w/API_RP-53 (May 84)_ Yes- 32 Work will occur without operation shutdown_ - _ - - - - - - - - - - Yes 33 Is presence_ of H2S gas probable Yes - - - - - 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 2M -Pad are H2S-bearing. H2Smeasures_ required. _ Geology 36 Data- presented on potential overpressure zones_ -- Y_es Expected reservoirpressure is 14.1 ppg EMW; will be drilled using_8.6 ppgmud and MPD technique. Appr Date 37 Seismic_analysis of shallow gas zones - --------- NA_ --------------- ----------- PKB 8/1!2016 38 Seabed condition survey (if off -shore) - - - - _N_A_ - 39 Contact name/phone for weekly_ progress reports [exploratory only] - - _ _ _ _ _ _ - - - NA_ Onshore development lateral to be drilled- - - - - - - - - - - - - - - - - - - _ - - Geologic Date: Engineering Public o mmission r. Date Commissioner Date �Commissioner: 1{ /O �b l� _ 1;Z -1i Q(l 6