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Home My WebLink About216-088DATA SUBMITTAL COMPLIANCE REPORT 2/17/2017 Permit to Drill 2160880 Well Name/No. KUPARUK RIV UNIT 2B-02AL1 Operator CONOCOPHILLIPS ALASKA INC API No. 50-029-21154-60-00 MD 10230 TVD 5996 Completion Date 10/27/2016 Completion Status 1 -OIL Current Status 1 -OIL UIC No REQUIRED INFORMATION Mud Log No V Sampled No Vl-� Directional Survey Yes VZ DATA INFORMATION Types Electric or Other Logs Run: GR/Res Well Log Information: Log/ Electr Data Digital Dataset Type Med/Frmt Number Name ED C 27708 Digital Data ED C 27708 Digital Data Log C 27708 Log Header Scans ED C ED C ED C ED C ED C ED C ED C ED C ED C ED C ED C ED C ED C ED C ED C AOGCC. 27745 Digital Data 27745 Digital Data 27745 Digital Data 27745 Digital Data 27745 Digital Data 27745 Digital Data 27745 Digital Data 27745 Digital Data 27745 Digital Data 27745 Digital Data 27745 Digital Data 27745 Digital Data 27745 Digital Data 27745 Digital Data 27745 Digital Data (data taken from Logs Portion of Master Well Data Maint) Log Log Run Interval OH / Scale Media No Start Stop CH Received Comments 11/9/2016 Electronic File: 213-02AL1 EOW - NAD27.pdf ' 11/9/2016 Electronic File: 213-02AL1 EOW - NAD27.txt ' 0 0 2160880 KUPARUK RIV UNIT 213-02AL1 LOG HEADERS 6376 10230 12/6/2016 Electronic Data Set, Filename: 213-02AL1 GAMMA RES.Ias 12/6/2016 Electronic File: 26-02AL1 2MD Final.cgm . 12/6/2016 Electronic File: 26-02AL1 5MD Final.cgm - 12/6/2016 Electronic File: 213-02AL1 5TVDSS Final.cgm ' 12/6/2016 Electronic File: 213-02AL1 2MD Final.pdf 12/6/2016 Electronic File: 26-02AL1 5MD Final.pdf ' .012/6/2016 Electronic File: 213-02AL1 5TVDSS Final.pdf' 12/6/2016 Electronic File: 26-02AL1 EOW - NAD27.pdf 12/6/2016 Electronic File: 26-02AL1 EOW - NAD27.txt ' 12/6/2016 Electronic File: 213-02AL1 Survey Listing.txt ' 12/6/2016 Electronic File: 26-02AL1 Surveys.txt . 12/6/2016 Electronic File: 2B-02AL1_Final Surveys TD ' 10230 confirmed.csv 12/6/2016 Electronic File: 213- 02AL 1 _25_ta pescan_B H I_C TK.txt- 12/6/2016 Electronic File: 213- 02AL 1 _5_tapescan_BH I_CTK.txt ' 12/6/2016 Electronic File: 213-02AL1_output.tap , Page I ol'2 Friday, February 17, 2017 DATA SUBMITTAL COMPLIANCE REPORT 2/17/2017 Permit to Drill 2160880 Well Name/No. KUPARUK RIV UNIT 213-02AL1 Operator CONOCOPHILLIPS ALASKA INC API No. 50-029-21154-60-00 MD 10230 TVD 5996 Completion Date 10/27/2016 Completion Status 1 -OIL ED C 27745 Digital Data ED C 27745 Digital Data ED C 27745 Digital Data Log C 27745 Log Header Scans Well Cores/Samples Information: 0 0 Current Status 1 -OIL UIC No 12/6/2016 Electronic File: 213-02AL1 2MD Final.tif' 12/6/2016 Electronic File: 26-02AL1 5MD Final.tif ` 12/6/2016 Electronic File: 213-02AL1 5TVDSS Final.tif 2160880 KUPARUK RIV UNIT 213-02AL1 LOG HEADERS Sample Interval Set Name Start Stop Sent Received Number Comments INFORMATION RECEIVED Completion Report lY Production Test Informatiol NA Geologic Markers/Tops O COMPLIANCE HISTORY Completion Date: 10/27/2016 Release Date: 8/16/2016 Description Comments: Directional / Inclination Data (0 Mud Logs, Image Files, Digital Data Y 116 Core Chips Y (f4R1 Mechanical Integrity Test Information �Y Y 1 /� lA Composite Logs, Image, Data Files t) Core Photographs Y �J Daily Operations Summary / Cuttings Samples YY// NA Laboratory Analyses Y / A) Date Comments Compliance Reviewed By: Date: 0/ 1 AOGCC' Page 2 of 2 Friday, February 17, 2017 E(;E1'V E I VNIS DEC 0 6 291E BAKER 21 6000 PRINT DISTRIBUTION LIST 2 7 4 5 HUGHES0 G G Cy COMPANY ConocoPhillips Alaska, Inc. WELL NAME 2B-02AL1 FIELD Prudhoe Bay Unit COUNTY North Slope Borough BHI DISTRICT Alaska AUTHORIZED BY Patrick Rider EMAIL Patrick. RiderCcDbakerhughes.com Please sign and return one copy of this transmittal form to: ConocoPhillips Alaska, Inc. Tom Osterkamp DATA LOGGED 12 t3/2otCc 700 G Street. M K HFNGE=R Anchorage, Alaska 99510 Ito acknowledge receipt of this data. LOG TYPE GR - RES LOG DATE October 27, 2016 TODAYS DATE December 5, 2016 Revision STATUS Final Replacement: No Details: Requested by: COMPANY ADDRESS (FEDEX WILL NOT DELIVER TO P.O. 80)j PERSON ATTENTION 4 FIELD FINAL CD CD LOGS LOGS I (digital/image) Surveys (Final Surveys) # OF PRINTS # Uk F'KIN I5 # OF COPIES # OF COPIES # OF COPIE V 1 BP North Slope 0 0 1 0 �EOA, PBOC, PRB-20 (Office 109) D&C Wells Project Aids Agatha Rutka & Barbara Glassmaker 1900 E. Benson Blvd. 'Anchorage, Alaska 99508 2 ConocoPhillips Alaska Inc. 0 0 0 Aun: Ricky Elgaricio TATO 3-344 700 G Street Anchorage, AK 99510 3 ExxonMobil, Alaska Attn: Lynda M. Yaskell and/or Leonardo Elias 3201 C Street, Suite 505 'i Anchorage, AK 99503 4 1 State of Alaska - AOGCC Attn: Makana Bender ,333 W. 7th Ave, Suite 100 !Anchorage, Alaska 99501 5 DNR -Division of Oil & Gas *** Attn: Resource Evaluation 550 West 7th Avenue, Suite 1100 Anchorage, Alaska 99501 ,***Stamp "confidential' on all material deliver to DNR 6'I131? Exploration (Alaska) Inc. Petrotechnical Data Center, LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 TOTALS FOR THIS PAGE: 0 2 3 3 0 0 TOTALS FOR ALL PAGES: 0 2 3 3 0 0 ConocoPhillips . VF - JCC Q 6 Nib ConocoPhillips (Alaska) Inc. -Kup2 Kuparuk River Unit Kuparuk 2B Pad 2B-02AL1 50-029-21154-60 Baker Hughes INTEQ Definitive Survey Report 04 November, 2016 21 608a 27 74 5 Few k I BAKER HUGHES ConocoPhillips BAKER`• ConocoPhillips Definitive Survey Report HUGHES Company: ConocoPhillips (Alaska) Inc. -Kup2 Local Co-ordinate Reference: Well 213-02 Project: Kuparuk River Unit TVD Reference: 26-02 @ 126.00usft (26-02) Site: Kuparuk 2B Pad MD Reference: 26-02 @ 126.00usft (213-02) Well: 213-02 North Reference: True Wellbore: 2B-02 Survey Calculation Method: Minimum Curvature Design: 213-02 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 2B-02 Well Position +N/-S 0.00 usft Northing: 5,954,890.07usft Latitude: 700 17' 16.702 N +E/-W 0.00 usft Easting: 508,370.93usft Longitude: 149° 55'56.081 W Position Uncertainty 0.00 usft Wellhead Elevation: usft Ground Level: 0.00 usft Wellbore 213-02AL1 Magnetics Model Name Sample Date Declination Dip Angle Field Strength (1) 1`) (nT) BG G M2016 10/1/2016 17.90 80.90 57,541 Design 26-02AL1 Audit Notes: Version: 1.0 Phase: ACTUAL Tie On Depth: 8.450.91 Vertical Section: Depth From (TVD) +N/-S +E/-W Direction (usft) (usft) (usft) V) 126.00 0.00 0.00 345.00 Survey Program Date 11/1/2016 From To Survey Survey (usft) (usft) Survey (Wellbore) Tool Name Description Start Date End Date 200.00 6,600.00 213-02 (213-02) GCT-MS Schlumberger GCT multishot 1/12/2001 6,640.00 7,560.37 26-02AP81 (28-02AP131) MWD MWD- Standard 10/8/2016 10/15/2016 7,580.00 8,450.91 26-02A (26-02A) MWD MWD - Standard 10/16/2016 10/18/2016 8,465.00 10,193.77 213-02AL1 (213-02AL1) MWD MWD- Standard 10/19/2016 10/22/2016 11/4/2016 7:35:02AM Page 2 COMPASS 5000.1 Build 74 ConocoPhillips FUS ConocoPhillips Definitive Survey Report BAKER ES Company: ConocoPhillips (Alaska) Inc. -Kup2 Local Coordinate Reference: Well 2B-02 Project: Kuparuk River Unit TVD Reference: 2B-02 @ 126.00usft (26-02) Site: Kuparuk 26 Pad MD Reference: 28-02 @ 126.00usft (26-02) Well: 2B-02 North Reference: True Wellbore: 2B-02 Survey Calculation Method: Minimum Curvature Design: 2B-02 Database: EDM Alaska NSK Sandbox Survey MD Inc Azi TVD TVDSS +NIS +E/ -W Map Map Vertical (usft) (°) (1) (usft) (usft) (usft) (usft) Northing Easting (OD O ) Section Survey Tool Name (ft) (ft) (ft) 8,450.91 90.34 290.81 6,118.71 5,992.71 -3,030.80 -1,529.11 5,951,857.87 506,845.35 11.24 -2,531.77 MWD (3) 8,465.00 89.99 288.96 6,118.67 5,992.67 -3,026.01 -1,542.36 5,951,862.65 506,832.10 13.36 -2,523.71 MWD (4) 8,498.11 85.73 292.14 6,119.91 5,993.91 -3,014.40 -1,573.33 5,951,874.22 506,801.12 16.05 -2,504.48 MWD (4) 8,525.72 83.76 294.81 6,122.44 5,996.44 -3,003.45 -1,598.54 5,951,885.14 506,775.89 11.98 -2,487.38 MWD (4) 8,555.69 83.42 298.44 6,125.78 5,999.78 -2,990.11 -1,625.16 5,951,898.46 506,749.26 12.09 -2,467.60 MWD (4) 6,585.66 85.27 301.04 6,128.74 6,002.74 -2,975.31 -1,651.06 5,951,913.22 506,723.35 10.61 -2,446.61 MWD (4) 8,615.61 87.67 303.46 6,130.58 6,004.58 -2,959.36 -1,676.33 5,951,929.14 506,698.06 11.37 -2,424.66 MWD (4) 8,645.55 91.93 305.12 6,130.68 6,004.68 -2,942.50 -1,701.06 5,951,945.97 506,673.31 15.27 -2,401.97 MWD (4) 8,675.63 95.59 306.24 6,128.71 6,002.71 -2,925.00 -1,725.44 5,951,963.45 506,648.92 12.72 -2,378.75 MWD (4) 8,705.72 99.71 307.71 6,124.71 5,998.71 -2,907.07 -1,749.26 5,951,981.35 506,625.08 14.52 -2,355.27 MWD (4) 8,735.73 101.24 311.70 6,119.25 5,993.25 --2,888.22 -1,771.96 5,952,000.17 506,602.36 14.03 -2,331.19 MWD (4) 8,765.65 100.59 316.08 6,113.58 5,987.58 -2,867.86 -1,793.12 5,952,020.51 506,581.18 14.54 -2,306.04 MWD (4) 8,795.64 100.62 320.54 6,108.06 5,982.06 -2,845.85 -1,812.72 5,952,042.49 506,561.56 14.62 -2,279.71 MWD (4) 8,825.73 100.74 324.87 6,102.48 5,976.48 -2,822.33 -1,830.64 5,952,065.98 506,543.62 14.15 -2,252.36 MWD (4) 8,855.69 100.43 328.90 6,096.97 5,970.97 -2,797.67 -1,846.72 5,952,090.62 506,527.51 13.26 -2,224.38 MWD (4) 8,885.62 100.18 333.41 6,091.62 5,965.62 -2,771.89 -1,860.92 5,952,116.39 506,513.28 14.85 -2,195.79 MWD (4) 8,915.67 100.18 336.74 6,086.31 5,960.31 -2,745.07 -1,873.39 5,952,143.19 506,500.79 10.91 -2,166.66 MWD (4) 8,945.55 98.56 339.94 6,081.44 5,955.44 -2,717.67 -1,884.26 5,952,170.57 506,489.88 11.88 -2,137.39 MWD (4) 8,975.74 95.62 342.79 6,077.71 5,951.71 -2,689.29 -1,893.83 5,952,198.94 506,480.28 13.51 -2,107.49 MWD (4) 9,005.72 92.85 345.78 6,075.50 5,949.50 -2,660.51 -1,901.93 5,952,227.71 506,472.15 13.57 -2,077.60 MWD (4) 9,035.84 92.27 349.55 6,074.15 5,948.15 -2,631.12 -1,908.36 5,952,257.09 506,465.70 12.65 -2,047.55 MWD (4) 9,065.56 92.18 352.71 6,073.00 5,947.00 -2,601.78 -1,912.93 5,952,286.42 506,461.08 10.63 -2,018.03 MWD (4) 9,095.85 94.70 356.77 6,071.18 5,945.18 -2,571.69 -1,915.71 5,952,316.51 506,458.28 15.75 -1,988.24 MWD (4) 9,125.65 93.99 0.57 6,068.92 5,942.92 -2,541.98 -1,916.40 5,952,346.21 506,457.56 12.94 -1,959.37 MWD (4) 9,155.67 93.28 3.84 6,067.02 5,941.02 -2,512.05 -1,915.24 5,952,376.14 506,458.68 11.13 -1,930.75 MWD (4) 9,185.60 92.03 7.92 6,065.63 5,939.63 -2,482.32 -1,912.18 5,952,405.87 506,461.71 14.24 -1,902.83 MWD (4) 9,215.83 91.81 11.75 6,064.62 5,938.62 -2,452.55 -1,907.02 5,952,435.64 506,466.83 12.68 -1,875.41 MWD (4) 9,245.25 92.58 14.87 6,063.49 5,937.49 -2,423.95 -1,900.25 5,952,464.25 506,473.57 10.92 -1,849.53 MWD (4) 9,275.25 91.53 17.33 6,062.42 5,936.42 -2,395.15 -1,891.94 5,952,493.06 506,481.85 8.91 -1,823.86 MWD (4) 9,305.26 89.66 19.86 6,062.10 5,936.10 -2,366.71 -1,882.37 5,952,521.50 506,491.38 10.48 -1,798.87 MWD (4) 11/4/2016 7:35:02AM Page 3 Annotation TIP KOP COMPASS 5000.1 Build 74 ConocoPhillips WW1 BAKER ConocoPhillips Definitive Survey Report HUGHES Company: ConocoPhillips (Alaska) Inc. -Kup2 Local Co-ordinate Reference: Well 2B-02 Project: Kuparuk River Unit TVD Reference: 213-02 @ 126.00usft (26-02) Site: Kuparuk 26 Pad MD Reference: 213-02 @ 126.00usft (213-02) Well: 213-02 North Reference: True Wellbore: 2B-02 Survey Calculation Method: Minimum Curvature Design: 213-02 Database: EDM Alaska NSK Sandbox Survey Map Map MD Inc AzI TVD TVDSS +N1 -S +E/ -W Northing Easting DLSVertical Section Survey Tool Name Annotation (usft) (I C) (usft) (usft) (usft) (usft) (ft) (ft) (°/700') MOO (ft) 9,335.19 89.45 23.67 6,062.34 5,936.34 -2,338.92 -1,871.28 5,952,549.30 506,502.45 12.75 -1,774.90 MWD (4) 9,365.22 88.89 26.29 6,062.77 5,936.77 -2,311.70 -1,858.60 5,952,576.53 506,515.09 8.92 -1,751.69 MWD (4) 9,395.21 90.61 30.49 6,062.90 5,936.90 -2,285.33 -1,844.34 5,952,602.92 506,529.32 15.13 -1,730.11 MWD (4) 9,425.35 89.79 33.50 6,062.80 5,936.80 -2,259.77 -1,828.37 5,952,628.49 506,545.26 10.35 -1,709.55 MWD (4) 9,455.33 88.71 36.24 6,063.19 5,937.19 -2,235.18 -1,811.24 5,952,653.10 506,562.36 9.82 -1,690.23 MWD (4) 9,485.16 88.19 39.70 6,064.00 5,938.00 -2,211.67 -1,792.89 5,952,676.62 506,580.68 11.73 -1,672.28 MWD (4) 9,505.51 88.65 42.48 6,064.56 5,938.56 -2,196.34 -1,779.53 5,952,691.97 506,594.03 13.84 -1,660.93 MWD (4) 9,535.24 91.10 47.26 6,064.62 5,938.62 -2,175.28 -1,758.56 5,952,713.05 506,614.97 18.07 -1,646.01 MWD (4) 9,565.19 91.05 50.08 6,064.06 5,938.06 -2,155.51 -1,736.07 5,952,732.85 506,637.43 9.42 -1,632.73 MWD (4) 9,595.24 89.82 48.66 6,063.83 5,937.83 -2,135.94 -1,713.27 5,952,752.44 506,660.21 6.25 -1,619.73 MWD (4) 9,625.37 90.09 45.48 6,063.86 5,937.86 -2,115.42 -1,691.21 5,952,772.98 506,682.24 10.59 -1,605.62 MWD (4) 9,655.28 89.14 40.59 6,064.06 5,938.06 -2,093.57 -1,670.81 5,952,794.85 506,702.62 16.65 -1,589.79 MWD (4) 9,685.21 89.39 36.56 6,064.44 5,938.44 -2,070.17 -1,652.15 5,952,818.26 506,721.25 13.49 -1,572.03 MWD (4) 9,715.39 90.46 33.44 6,064.48 5,938.48 -2,045.46 -1,634.84 5,952,843.00 506,738.53 10.93 -1,552.63 MWD (4) 9,750.19 90.46 28.69 6,064.20 5,938.20 -2,015.66 -1,616.89 5,952,872.82 506,756.45 13.65 -1,528.49 MWD (4) 9,760.11 90.74 26.52 6,063.89 5,937.89 -1,989.15 -1,603.03 5,952,899.34 506,770.28 7.31 -1,506.47 MWD (4) 9,810.19 90.61 29.15 6,063.53 5,937.53 -1,962.55 -1,588.99 5,952,925.95 506,784.29 8.75 -1,484.42 MWD (4) 9,840.28 93.17 31.07 6,062.54 5,936.54 -1,936.54 -1,573.90 5,952,951.97 506,799.34 10.63 -1,463.20 MWD (4) 9,870.08 97.43 31.91 6,059.79 5,933.79 -1,911.24 -1,558.41 5,952,977.29 506,814.81 14.57 -1,442.77 MWD (4) 9,900.20 101.31 32.63 6,054.89 5,928.89 -1,886.12 -1,542.54 5,953,002.42 506,830.64 13.10 -1,422.61 MWD (4) 9,930.15 101.52 36.66 6,048.96 5,922.96 -1,861.97 -1,525.86 5,953,026.59 506,847.30 13.21 -1,403.60 MWD (4) 9,960.21 101.50 40.59 6,042.96 5,916.96 -1,838.96 -1,507.47 5,953,049.61 506,865.65 12.81 -1,386.14 MWD (4) 9,990.22 101.43 40.76 6,036.99 5,910.99 -1,816.66 -1,488.31 5,953,071.94 506,884.80 0.60 -1,369.55 MWD (4) 10,020.11 101.02 37.85 6,031.17 5,905.17 -1,793.97 -1,469.74 5,953,094.64 506,903.34 9.65 -1,352.45 MWD (4) 10,050.36 100.33 34.43 6,025.57 5,899.57 -1,769.97 -1,452.21 5,953,118.66 506,920.84 11.34 -1,333.80 MWD (4) 10,079.49 100.15 31.95 6,020.39 5,894.39 -1,745.98 -1,436.52 5,953,142.66 506,936.50 8.40 -1,314.69 MWD (4) 10,109.56 100.18 27.98 6,015.08 5,889.08 -1,720.35 -1,421.74 5,953,168.31 506,951.25 13.00 -1,293.75 MWD (4) 10,140.05 100.81 24.21 6,009.52 5,883.52 -1,693.43 -1,408.55 5,953,195.24 506,964.40 12.33 -1,271.17 MWD (4) 10,169.94 100.32 22.46 6,004.04 5,878.04 -1,666.45 -1,396.91 5,953,222.23 506,976.01 5.98 -1,248.12 MWD (4) 10,193.77 96.99 21.77 6,000.46 5,874.46 -1,644.63 -1,388.05 5,953,244.06 506,984.85 14.26 -1,229.34 MWD (4) 10,230.00 96.99 21.77 5,996.05 5,870.05 -1,611.23 -1,374.71 5,953,277.47 506,998.15 0.00 -1,200.53 PROJECTED to TD Page 4 COMPASS 5000.1 Build 74 11/4/2016 7.,35:02AM STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1a. Well Status: Oil 0 - Gas[-] SPLUG ❑ Other ❑ Abandoned ❑ Suspended[] 20AAC 25.105 20AAC 25.110 GINJ ❑ WINJ ❑ WAG[_] WDSPL ❑ No. of Completions: 1b. Well Class: Development ❑✓ - Exploratory ❑ Service ❑ Stratigraphic Test ❑ 2. Operator Name: ConocoPhillips Alaska, Inc. 6. Date Comp., Susp., or Aband.: 10/27/2016 14. Permit to Drill Number / Sundry: 216-088 3. Address: P.O. Box 100360 Anchorage, AK 99510-0360 7. Date Spudded: 10/19/2016 15. API Number: 50-029-21154-60-00 4a. Location of Well (Governmental Section): Surface: 744' FSL, 273' FEL, Sec. 19, T11N, R9E, UM Top of Productive Interval: 3186' FSL, 2104' FEL, Sec 30, T11 N, R9E, UM Total Depth: 4411' FSL, 1653' FEL, Sec 30, T1IN, R9E, UM 8. Date TD Reached: 10/23/2016 16. Well Name and Number: KRU 2B-02AL1 , 9. Ref Elevations: KB: 126' GL 92' BF: 92' 17. Field / Pool(s): Kuparuk River Field / Kuparuk Oil Pool 10. Plug Back Depth MD/TVD: 10222'/ 5997' 18. Property Designation: ADL 25656 4b. Location of Well (State Base Plane Coordinates, NAD 27): Surface: x- 508371 y- 5954890 Zone- 4 TPI: x- 506553 y- 5952051 Zone- 4 Total Depth: x- 506998 y- 5953277 Zone- 4 11. Total Depth MD/TVD: 10230'/ 5996' 19. Land Use Permit: ALK 2582 12. SSSV Depth MD/TVD: 1891'/ 1891' 20. Thickness of Permafrost MD/TVD: 1526'/ 1526' 5. Directional or Inclination Survey: Yes, 0(attached) No ❑ Submit electronic and printed information per 20 AAC 25.050 13. Water Depth, if Offshore: N/A (ft MSL) 21. Re-drill/Lateral Top Window MD/TVD: 8465'/ 6119' 22. Logs Obtained: List all logs run and, pursuant to AS 31.05.030 and 20 AAC 25.071, submit all electronic data and printed logs within 90 days of completion, suspension, or abandonment, whichever occurs first. Types of logs to be listed include, but are not limited to: mud log, spontaneous potential, gamma ray, caliper, resistivity, porosity, magnetic resonance, dipmeter, formation tester, temperature, cement evaluation, casing collar locator, jewelry, and perforation record. Acronyms may be used. Attach a separate page if necessary GR/RES 23. CASING, LINER AND CEMENTING RECORD WT. PER GRADE SETTING DEPTH MD SETTING DEPTH TVD CASING FT TOP BOTTOM TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 16" 62.5# H-40 35' 110' 35' 110' 24 119 sx Cold Set II 9-5/8" 36.0# J-55 34' 2727' 34' 2727' 12-1/4" 800 sx Cold Set III & 300 sx Cold Set II 7" 26.0# J-55 31' 6934' 31' 6287' 8-1/2" 280 sx Class G & 250 sx Cold Set I 2-3/8" 4.6 L-80 1 8808' 10222' 6105' 5997' 3 ISlotted Liner 24. Open to production or injection? Yes No ❑ If Yes, list each interval open (MD/TVD of Top and Bottom; Perforation Size and Number): Slotted Liner: 8808'- 10222'/ 6105'- 5997' f, r �p12� f v -w \AHRIFIED I-V 25. TUBING RECORD SIZE DEPTH SET (MD) PACKER SET (MD/TVD) 3-1/2" 6616' 6377'/ 5818' 6600'/ 6005' 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: 11/7/2016 Method of Operation (Flowing, gas lift, etc.): Gas lift Date of Test: 11/8/2016 Hours Tested: 17:08 Production for Test Period -11110. Oil -Bbl: 169 Gas -MCF: 1799 Water -Bbl: 535 Choke Size: 176 Gas -Oil Ratio: 3152 Flow Tubing Press. 182 Casinq Press: 1188 Calculated 24 -Hour Rate Oil -Bbl: 237 Gas -MCF: 749 Water -Bbl: 2520 Oil Gravity -TPI (corr): Not sam led Form 10-407 Revised 11/2015 �� 2/!S /!- CONTINUED ON PAGE 2 �Bp�� L� i 3 �nuemit ORIGINIAL onll V 28. CORE DATA Conventional d s): Yes ❑ No ❑� Sidewall Cores. es ❑ No ❑✓ If Yes, list formations and intervals cored (MD/TVD, From/To), and summarize lithology and presence of oil, gas or water (submit separate pages with this form, if needed). Submit detailed descriptions, core chips, photographs, and all subsequent laboratory analytical results per 20 AAC 25.071. 29. GEOLOGIC MARKERS (List all formations and markers encountered): 30. FORMATION TESTS NAME MD TVD Well tested? Yes ❑ No 0 If yes, list intervals and formations tested, briefly summarizing test results. Permafrost - Top Surface Surface Permafrost - Base 1526' 1526' Attach separate pages to this form, if needed, and submit detailed test information, including reports, per 20 AAC 25.071. Top of Productive Interval 8465' 6119' (Kuparuk A Sand) Formation at total depth: 10230' 5996' (Kuparuk A Sand) K A-y 31. List of Attachments: Summary of daily operations, schematic and final directional surveys. Information to be attached includes, but is not limited to: summary of daily operations, wellbore schematic, directional or inclination survey, core analysis, paleontological report, production or well test results, per 20 AAC 25.070. 32. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Keith Herring @ 263-4321 Email: Keith. E. Herring@_cop.com Printed Name: G. Eller Title: CTD Team Lead Signature: Phone: 263-4172 Date: v Z� 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 6" 62# H-40 hoe @ 110' '40# J-55 @ 2727' A C -sand perfs (sqz'd) 6,526' - 6,568' MD 6,586' - 6,588' MD KOP @ 6640' MD A -sand perfs (sgz'd) 6,620' - 6,710' MD 7" 26# J-55 shoe @ 6934' MD 2B-02 CTD Schematic 3-1/2" 9.3# L-80 ELIE 8rd Tubing to surface 3-1/2" Otis FMX SSSV at 1812' RKB (locked out 4/98) 3-1/2" Camco gas lift mandrels @ 1,929', 3,478', 4,837', 5,864', 6,325' RKB Camco OEJ-10 SBR @ 6,359' RKB (2.973" min ID) Camco HRP -1 -SP Retrievable Packer @ 6,377' RKB Blast Rings @ 6,489' RKB 3-1/2" Camco production mandrels @ 6,415', 6,483', 6582' RKB Baker Locator Assembly @ 6,599' RKB Baker FB -1 packer @ 6,599' RKB (6588' PDC) (4.0" ID) Baker SBE @ 6,602' RKB 3-1/2" Camco DS nipple @ 6,611' RKB (6600' PDC) Milled out to 2.80" ID pre -CTD Camco SOS @ 6,615' RKB (6604' PDC) 2B-02AL1 TD = 10230' MD 2B-02AL1-01 TD = 9754' MD 2-3/8" slotted liner w/ anchored billet 2-3/8" slotted liner w/ deployment sleeve TOL = 8808' MD, BOL = 10222' MD TOL = 6598' MD, BOL = 9750'MD ------------ ----------------- 2B-02APB1 TD = 8070' MD Anchored billet = 7580' MD --------- ---' 2B -02A TD = 9570' MD 2-3/8" slotted liner w/ anchored billet TOL = 8,466'M D, BOL = 9570' MD uperations Summary (with Timelog Vepths) x 2B-02 Rig: NABORS CDR2-AC Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time Dur (hr) Phase Op Code Activity Code Time P -T -X Operation (MB) End Depth (WB) 10/8/2016 10/8/2016 3.50 MIRU MOVE RURD P Trucks on location, PJSM, hook up 06:00 09:30 jeeps, secure cellar, perform premove check list, secure pit module, 10/8/2016 10/8/2016 3.50 MIRU MOVE MOB P Spot modules over well 02, release 09:30 13:00 trucks, lower BOPE's, work on post rig move check list. 10/8/2016 10/8/2016 3.00 MIRU MOVE RURD P Start rig up checklist. Hook up steam. 13:00 16:00 berm celler. Hook up PUTZ interconnect. RU flowline. 10/8/2016 10/8/2016 2.00 MIRU MOVE NUND P NU BOPE. Install choke hose and 16:00 18:00 annular hydraulics. Check tree bolts. Grease tree valves and BOP valves. 10/8/2016 10/8/2016 3.50 MIRU WHDBOP RURD P MU test joint. Fluid pack an shell 18:00 21:30 test.Test swabs. Circulate air out of coiled tubing into sump, Test inner reel valve RIG ACCEPT 18:00 10/8/2016 10/9/2016 2.50 MIRU WHDBOP BOPE P Begin testing BOPE to 250/3750 psi. 21:30 00:00 2,500 psi on the annular. State witness by Jeff Jones. 10/9/2016 10/9/2016 6.00 MIRU WHDBOP BOPE P Continue testing BOPE to 250/3750 0.0 0.0 00:00 06:00 psi. 2,500 psi on the annular. State witness by Jeff Jones. 10/9/2016 10/9/2016 2.00 MIRU WHDBOP RURD P RD testing equipment, freeze protect 0.0 0.0 06:00 08:00 test pump, store test joint back onto rack in pipe shed. Load out AC unit. 10/9/2016 10/9/2016 1.00 MIRU WHDBOP CTOP P Install checks in Upper Quick, P/T 0.0 0.0 08:00 09:00 tiger tank line and pac-off, send 30 slings out the beaver slide 10/9/2016 10/9/2016 2.50 MIRU WHDBOP MPSP P PJSM, load BPV equipment, PT 0.0 0.0 09:00 11:30 lubricator 2,500 psi, pull BPV, 10/9/2016 10/9/2016 1.50 PROD1 RPEQPT PULD P PJSM, MU milling BHA# 1 0.0 62.5 11:30 13:00 10/9/2016 10/9/2016 1.75 PROD1 RPEQPT TRIP P RIH with Milling BHA# 1, with a 0.9° 62.5 6,410.0 13:00 14:45 bend motor and D331 mill, pumping SW. 10/9/2016 10/9/2016 0.50 PROD1 RPEQPT DLOG P Logged the K1 correction of minus 3.5 6,410.0 6,593.0 14:45 15:15 ft,PUW 31 k 10/9/2016 10/9/2016 4.50 PROD1 RPEQPT MILL P Tag TOC at 6,593 ft, PUH, bring rate 6,593.0 6,598.0 15:15 19:45 up to 1.5 bpm at 3,050 psi, BHP 2,971, WHP 38, IA 4, OA 0, start milling cement. Held up at 6598 ft. Multiple stalls. Can't get re -started. Vary milling parameters to try and improve milling rate. Added powervis to seawater system to help move material. 10/9/2016 10/9/2016 1.50 PROD1 RPEQPT MILL P Roll toolface to 180°. Contine to mill 6,598.0 6,600.0 19:45 21:15 cement. Multiple stalls. 10/9/2016 10/9/2016 1.25 PROD1 RPEQPT MILL P Roll toolface back to 20° ROHS. 6,600.0 6,603.0 21:15 22:30 Continue milling cement. Multiple stalls and re -starts. 10/9/2016 10/9/2016 1.25 PROD1 RPEQPT MILL P Roll toolface to 180°. Continue milling 6,603.0 6,603.0 22:30 23:45 cement. Multiple stalls and re -starts. 10/9/2016 10/10/2016 0.25 PROD1 RPEQPT MILL P Roll toolface back to 20° ROHS. 6,603.0 6,604.0 23:45 00:00 Continue milling cement. Multiple stalls and re -starts. Page 1115 Report Printed: 10/31/2016 b , operations Summary (with Timelog Depths) $ 2B-02 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) 10/10/2016 10/10/2016 1.50 PROD1 RPEQPT MILL P Continue milling cement pilot hole. 1.6 6,604.0 6,618.0 00:00 01:30 bpm at 2200 psi, BHP 2,900, WHP 0. Add 0.5% SafeLube to the system to try and improve milling parameters. 10/10/2016 10/10/2016 1.00 PROD1 RPEQPT MILL P Continue milling cement. Multiple 6,618.0 6,619.0 01:30 02:30 stalls and re -starts. Picked up slightly heavy at 38KIbs. 10/10/2016 10/10/2016 0.25 PROD1 RPEQPT WPRT P Wiper trip up to 6565 ft. 6,619.0 6,565.0 02:30 02:45 10/10/2016 10/10/2016 0.25 PROD1 RPEQPT WPRT P RBIH. SOW = 13KIbs. 6,565.0 6,619.0 02:45 03:00 10/10/2016 10/10/2016 3.50 PROD1 RPEQPT MILL P Continue milling cement pilot hole. 6,619.0 6,627.0 03:00 06:30 10/10/2016 10/10/2016 0.25 PROD1 RPEQPT WPRT P PUH for a tie in PUW 35 k 6,627.0 6,435.0 06:30 06:45 10/10/2016 10/10/2016 0.25 PROD1 RPEQPT DLOG P log the K1 correction of plus 2.0 ft. 6,435.0 6,462.3 06:45 07:00 10/10/2016 10/10/2016 0.25 PROD1 RPEQPT WPRT P RBIH, RIW 12 k 6,462.3 6,627.0 07:00 07:15 10/10/2016 10/10/2016 10.00 PROD1 RPEQPT MILL P BOBM 1.3 bpm at 1691 psi, BHP 6,627.0 6,670.0 07:15 17:15 2906, WHP 0, IA 2, OA 0 Multiple stalls and re -starts No tool face changes after 6630 ft, maintaining TF at 20° ROHS. TD pilot hole at 6670 ft. 10/10/2016 10/10/2016 1.50 PROD1 RPEQPT DLOG P PUH and log the K1. No correction. 6,670.0 6,670.0 17:15 18:45 RBIH and confirm TD at 6670 ft. 10/10/2016 10/10/2016 0.75 PROD1 RPEQPT OWFF P PUH. Stop at 6550 ft. Flow check well. 6,670.0 6,550.0 18:45 19:30 Static. 10/10/2016 10/10/2016 1.00 PROD1 RPEQPT CIRC P Pump sweeps, RBIH. 6,550.0 61670.0 19:30 20:30 10/10/2016 10/10/2016 1.00 PROD1 RPEQPT TRIP P POOH chasing sweeps. Observed 6,670.0 3,000.0 20:30 21:30 loose wraps on the reel. 10/10/2016 10/10/2016 0.50 PROD1 RPEQPT SVRG P Service reel and injector PLC's. 3,000.0 3,000.0 21:30 22:00 Restart electronics. 10/10/2016 10/11/2016 2.00 PROD1 RPEQPT RGRP T Troubleshoot loose wraps on the reel. 3,000.0 3,000.0 22:00 00:00 Suspect ODS pillow block/bearing on reel. Continue troubleshooting. 10/11/2016 10/11/2016 0.50 PROD1 RPEQPT TRIP P POOH with BHA#1, monitoring reel 3,000.0 62.0 00:00 00:30 wraps. 10/11/2016 10/11/2016 0.50 PROD1 RPEQPT OWFF P At surface. Flow check well. Static. 62.0 62.0 00:30 01:00 10/11/2016 10/11/2016 1.25 PROD1 RPEQPT PULD P LD milling BHA #1. Mill was measured 62.0 0.0 01:00 02:15 2.79" no-go. 10/11/2016 10/11/2016 0.75 PROD1 RPEQPT WWWH P MU nozzle. Clean and flush BOP 0.0 0.0 02:15 03:00 stack. 10/11/2016 10/11/2016 0.50 PROD1 RPEQPT SVRG P Service rig, Adjust pillow blocks at the 0.0 0.0 03:00 03:30 reel. 10/11/2016 10/11/2016 1.00 PROD1 RPEQPT PULD P RU HAL. PJSM. PU HAL caliper. Stab 0.0 26.0 03:30 04:30 lubricator. 10/11/2016 10/11/2016 1.75 PROD1 RPEQPT TRIP P RIH with Halliburton caliper. Tie-in to 26.0 6,663.0 04:30 06:15 the K1 for a -1 ft correction. 10/11/2016 10/11/2016 0.75 PROD1 RPEQPT DLOG P Perform two logging passes, pulling 6,663.0 6,200.0 06:15 07:00 up hole at 30 fpm to 6200 ft. 10/11/2016 10/11/2016 1.50 PROD1 RPEQPT TRIP P POOH with HAL caliper. 6,200.0 26.0 07:00 08:30 Page 2115 Report Printed: 10/31/2016 operations Summary (with Timelog Depths) 2B-02 WW 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) 10/11/2016 10/11/2016 0.25 PROD1 RPEQPT OWFF P Flow check at surface. Static. 26.0 26.0 08:30 08:45 10/11/2016 10/11/2016 0.50 PROD1 RPEQPT PULD P LD HAL Caliper BHA. Caliper data is 26.0 0.0 08:45 09:15 in town for processing. 10/11/2016 10/11/2016 1.00 PROD1 RPEQPT PULD P PJSM. PU and MU whipstock BHA #3 0.0 73.0 09:15 10:15 with open hole anchors. 10/11/2016 10/11/2016 3.00 PROD1 RPEQPT TRIP P RIH with whipstock assembly. Log K1 73.0 6,650.8 10:15 13:15 for a -6 ft correction. No issues RIH. Pilot hole in good condition. 10/11/2016 10/11/2016 0.25 PROD1 RPEQPT WPST P Set WS per Baker rep. 6,650.8 6,650.8 13:15 13:30 10/11/2016 10/11/2016 1.50 PROD1 RPEQPT TRIP P POOH with whipstock running tools. 6,650.8 62.0 13:30 15:00 10/11/2016 10/11/2016 0.25 PROD1 RPEQPT OWFF P Flow check at surface. Static. 62.0 62.0 15:00 15:15 10/11/2016 10/11/2016 0.50 PROD1 RPEQPT PULD P PJSM. LD whipstock setting BHA #3. 62.0 0.0 15:15 15:45 10/11/2016 10/11/2016 0.50 PROD1 WHPST PULD P PJSM. PU and MU window milling 0.0 62.0 15:45 16:15 BHA #4 with 0.6° AKO motor and 2.79" string mill and 2.80" window mill. 10/11/2016 10/11/2016 3.00 PROD1 WHPST TRIP P Run in hole with BHA #4. Log K1 for a 62.0 6,607.0 16:15 19:15 -7ft correction. Finish displacing well over to milling fluid. Clean trip in the hole until stacked out at 6611 ft. PUH and try to run back through area with no success. Stack out at 6607 ft. 10/11/2016 10/11/2016 2.00 PROD1 WHPST TRIP T Multiple attempts made to try and 6,607.0 6,607.0 19:15 21:15 work past 6607 ft. Various combinations of toolfaces, pump rates and running speeds were tried with no successs. PUW's between 30KIbs and 35KIbs. PUH and tie-in to the K1 for a +1 ft correction to confirm depth Discuss hole condtions with town. Make 2 more attempts to work past 6607 ft. Made decsion to POOH. 10/11/2016 10/11/2016 1.50 PROD1 WHPST TRIP T POOH with BHA #4. No issues on the 6,607.0 75.0 21:15 22:45 way out of the hole. 10/11/2016 10/11/2016 0.50 PROD1 WHPST OWFF T Flow check at surface. Static. 75.0 75.0 22:45 23:15 10/11/2016 10/12/2016 0.75 PROD1 WHPST PULD T PJSM. LID BHA #4. 75.0 0.0 23:15 00:00 10/12/2016 10/12/2016 0.75 PROD1 RPEQPT PULD T PJSM. MU BHA #5 with 0.9° AKO 0.0 62.0 00:00 00:45 motor and D331 mill with side structure. 10/12/2016 10/12/2016 1.50 PROD1 RPEQPT TRIP T RIH with BHA #5. Tie in to the K1 for a 62.0 6,630.0 00:45 02:15 -6ft correction. RIH at 20fpm and minimum rate. No issues running past 6607 ft. Observed 1 Klb bobble at 6620 ft. Clean run to 6630 ft. 10/12/2016 10/12/2016 1.25 PROD1 RPEQPT TRIP T PUH at 180° TF, pumping 1.5 bpm 6,630.0 6,630.0 02:15 03:30 pulling 1 fpm. Small bobble at 6608 ft. Ream down pumping 1.5 bpm at 5 fpm. Ream up hole at 1 fpm. Page 3/15 Report Printed: 10/31/2016 Uperations Summary (with Timelog Depths) 2B-02 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 (WEI) End Depth (ftKB) 10/12/2016 10/12/2016 1.25 PROD1 RPEQPT TRIP T Dry drift pilot hole. Weight bobbles at 6,630.0 6,630.0 03:30 04:45 6621 ft and 6623 ft. Discuss results with town. Made decision to perform 2 more reaming passes. 10/12/2016 10/12/2016 0.25 PROD1 RPEQPT TRIP T Dry drift transition area. Continue to 6,630.0 6,640.0 04:45 05:00 dry drfit down and tag TOWS at 6640 ft. 10/12/2016 10/12/2016 1.25 PROD1 RPEQPT TRIP T PUH to 6585. Open EDC. Continue to 6,640.0 62.0 05:00 06:15 POOH with BHA #5. 10/12/2016 10/12/2016 0.50 PROD1 RPEQPT OWFF T Flow check well. Static. 62.0 62.0 06:15 06:45 10/12/2016 10/12/2016 0.75 PROD1 RPEQPT PULD T PJSM. LD BHA #5. 62.0 0.0 06:45 07:30 10/12/2016 10/12/2016 0.50 PROD1 WHPST PULD T PJSM. MU BHA #6 with 0.6° AKO 0.0 74.0 07:30 08:00 motor, string mill, and window mill. 10/12/2016 10/12/2016 2.25 PROD1 WHPST TRIP T RIH with BHA #6. Tie in to the K1 for - 74.0 6,640.0 08:00 10:15 6.5 ft correction. Close EDC. Continue running in the hole and dry tag top of whipstock at 6640 ft. Clean trip through pilot hole. 10/12/2016 10/12/2016 10.00 PROD1 WHPST WPST P Begin milling window per program and 6,640.0 6,649.0 10:15 20:15 Baker rep. Observed sand in samples from BU at 6644 ft. 10/12/2016 10/12/2016 2.00 PROD1 WHPST WPST P Mill rathole to 6661 ft. 6,649.0 6,661.0 20:15 22:15 10/12/2016 10/12/2016 1.25 PROD1 WHPST REAM P PU and dress window in 4 passes. 6,661.0 6,661.0 22:15 23:30 High side, 30° ROHS, 30°LOHS and 180°. Dry drift window. Clean. 10/12/2016 10/13/2016 0.50 PROD1 WHPST OWFF P PUH to 6590 ft. Close choke, bleed 6,661.0 6,590.0 23:30 00:00 WHIP to zero in stages. Well static. Manual MW = 8.8 ppg. 10/13/2016 10/13/2016 0.50 PROD1 WHPST MPDA P Open EDC. Bring pump up to drilling 6,590.0 6,590.0 00:00 00:30 rate. Hold 11.8ppgemw at the window. WHP = 484 psi. Friction pressure = 78 psi/1000ft. 10/13/2016 10/13/2016 1.50 PROD1 WHPST TRIP P POOH with BHA #6. Tag up and 6,590.0 67.0 00:30 02:00 space out. 10/13/2016 10/13/2016 0.50 PROD1 WHPST PULD P PJSM. PUD BHA #6. Floats not 67.0 67.0 02:00 02:30 holding. 10/13/2016 10/13/2016 0.50 PROD1 WHPST OWFF P Flow check well. Static. 67.0 67.0 02:30 03:00 10/13/2016 10/13/2016 1.00 PROD1 WHPST PULD P PJSM, lay down BHA #6 over a dead 67.0 0.0 03:00 04:00 well. 10/13/2016 10/13/2016 1.00 PROD1 DRILL PULD P PJSM. MU build BHA #7 with 2.2 ° 0.0 72.0 04:00 05:00 AKO motor and RB HCC bit. Surface test. 10/13/2016 10/13/2016 2.00 PROD1 DRILL TRIP P RIH with BHA V. Tie into the K1 for a 72.0 6,660.0 05:00 07:00 -3 ft correction. Tag bottom of 6660 ft. 10/13/2016 10/13/2016 3.00 PROD1 DRILL DRLG P Drill build section pumping 1.45bpm at 6,660.0 6,717.0 07:00 10:00 4050 psi. BHP = 3750 ft. WOB = 1.7KIbs CTW = 10.0 Klbs. 10/13/2016 10/13/2016 0.50 PROD1 DRILL WPRT P Wiper trip. Tie in to K1 for a +2.5 ft 6,717.0 6,717.0 10:00 10:30 correction. RBIH, log the RA for no correction. 10/13/2016 10/13/2016 3.00 PROD1 DRILL DRLG P Continue drilling the build section to 6,717.0 6,800.0 10:30 13:30 planned section TD. Pump sweeps. 10/13/2016 10/13/2016 2.25 PROD1 DRILL TRIP P POOH with BHA #7. Tag up and 6,800.0 72.0 13:30 15:45 space out. Page 4115 Report Printed: 10/31/2016 operations Summary (with Timelog bepths) 2B-02 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 (RKB) End Depth (ftKB) 10/13/2016 10/13/2016 2.00 PROD1 DRILL PULD P PJSM. PUD build BHA#7. 72.0 0.0 15:45 17:45 10/13/2016 10/13/2016 1.25 PROD1 DRILL PULD P PJSM. PU lateral BHA#8 with 0.8° 0.0 72.0 17:45 19:00 AKO motor and new HCC bit. Tag up and rest depth. 10/13/2016 10/13/2016 2.50 PROD1 DRILL TRIP P RIH with BHA #8. Tie in to K1 for a - 72.0 6,800.0 19:00 21:30 5.5ft correction. Clean pass through window and open hole. 10/13/2016 10/14/2016 2.50 PROD1 DRILL DRLG P Continue drilling A lateral. Pump 1.5 6,800.0 6,894.0 21:30 00:00 bpm at 3940 psi. BHP = 3750 psi.WOB = 1.5KIbs. CTW 10 Klbs. Mud swap. New mud at the bit at 6820 ft. 10/14/2016 10/14/2016 6.50 PROD1 DRILL DRLG P Continue drilling A lateral. Pumping 6,894.0 7,210.0 00:00 06:30 1.53 bpm at 4126 psi. BHP = 3770 psi.WOB = 1.5KIbs. CTW 9 Klbs. ROP 30-50 fph. 10/14/2016 10/14/2016 0.25 PROD1 DRILL WPRT P Wiper trip. PUW 36 Klbs 7,210.0 6,660.0 06:30 06:45 10/14/2016 10/14/2016 0.25 PROD1 DRILL WPRT P RBIH. SOW=13KLbs. Clean trip in and 6,660.0 7,210.0 06:45 07:00 out of the hole. 10/14/2016 10/14/2016 4.25 PROD1 DRILL DRLG P BOBD. Purring 1.55 bpm at 4150 psi. 7,210.0 7,406.0 07:00 11:15 BHP 3780 psi. WHP 380 psi. WOB 1.2 -1.9KIbs. CTW = 9 Klbs. ROP 30-60 fph. 10/14/2016 10/14/2016 0.25 PROD1 DRILL WPRT P PUH for BHA wiper. PUW 37KIbs. 7,406.0 7,406.0 11:15 11:30 SOW 9KIbs. 10/14/2016 10/14/2016 4.25 PROD1 DRILL DRLG P BOBD. Puming 1.54 bpm at 4130 psi. 7,406.0 7,610.0 11:30 15:45 BHP 3785 psi. WHP 390 psi. WOB 2.1 Klbs. CTW = 5 Klbs. ROP 30-60 fph. 10/14/2016 10/14/2016 0.25 PROD1 DRILL WPRT P Wiper trip. PUW = 37 Klbs. 7,610.0 6,759.0 15:45 16:00 10/14/2016 10/14/2016 0.25 PROD1 DRILL WPRT P RBIH. SOW 9KIbs 6,759.0 7,610.0 16:00 16:15 10/14/2016 10/14/2016 3.75 PROD1 DRILL DRLG P BOBD. Puming 1.54 bpm at 4130 psi. 7,610.0 7,763.0 16:15 20:00 BHP 3785 psi. WHP 390 psi. WOB 2.1 Klbs. CTW = 5 Klbs. ROP 30-60 fph. 10/14/2016 10/14/2016 0.75 PROD1 DRILL WPRT P Geo wiper. PUH. PUW=36 Klbs. Tie in 7,763.0 6,665.0 20:00 20:45 to the RA for a +5.5ft correction. 10/14/2016 10/14/2016 0.50 PROD1 DRILL WPRT P RBIH. SOW 9KIbs. 6,665.0 7,763.0 20:45 21:15 10/14/2016 10/15/2016 2.75 PROD1 DRILL DRLG P BOBD. Pumping 1.50 bpm at 4160 7,763.0 7,876.0 21:15 00:00 psi. BHP 3812 psi. WHP 380 psi. WOB 2.2 Klbs. CTW = 4 Klbs. Start cross cut down. 10/15/2016 10/15/2016 4.75 PROD1 DRILL DRLG P Continue drilling ahead. Pumping 7,876.0 8,070.0 00:00 04:45 1.50 bpm at 4400 psi. BHP 3860 psi. WHP 420 psi. WOB 2.2 Klbs. CTW = 4 Klbs. Continue cross cut down. 10/15/2016 10/15/2016 2.25 PROD1 DRILL TRIP T Pump sweeps. POOH. Tag up. Space 8,070.0 72.0 04:45 07:00 out. 10/15/2016 10/15/2016 2.00 PROD1 DRILL PULD T PJSM. PUD BHA#8. 72.0 0.0 07:00 09:00 10/15/2016 10/15/2016 2.00 PROD1 STK PULD T PJSM. PU BOT Anchored billet 0.0 7,286.0 09:00 11:00 assembly. Load PDL. PD Anchored billet BHA #9. Page 5/15 Report Printed: 10/31/2016 Uperations Summary (with Timelog Depths) 2B-02 Rig: NABORS CDR2-AC Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time Dur (hr) Phase Op Code Activity Code Time P -T -X Operation (MB) End Depth (ftKB) 10/15/2016 10/15/2016 3.25 PROM STK TRIP T RIH. Log K1 for a -3.5 ft correction. 7,286.0 7,590.0 11:00 14:15 Close EDC. Wt check 6475 ft = 29 Klbs. Saw weight bobble at 7231 ft. Position billet assembly on depth. 10/15/2016 10/15/2016 0.25 FROM STK WPST T Bring up pump. Set anchors. Top of 7,590.0 7,590.0 14:15 14:30 billet at 7580 ft. Set down 5KIbs to confirm set. 10/15/2016 10/15/2016 2.00 PROM STK TRIP T POOH. Tag up and space out. 7,590.0 70.0 14:30 16:30 10/15/2016 10/15/2016 2.50 PROD1 STK PULD T PJSM. PUD anchored billet running 70.0 0.0 16:30 19:00 tools BHA #9. Bled off riser. LEL alarm at shaker went off briefly due to gas cap in riser. Non-essential personnel relocated to the shop as a precaution. Crew change, then continued to PUD. 10/15/2016 10/15/2016 0.50 PROM STK BOPE P Function test BOP 0.0 0.0 19:00 19:30 10/15/2016 10/15/2016 1.50 PROM STK CTOP P Change out, rehead BOT UQC. 0.0 0.0 19:30 21:00 Houred out. 10/15/2016 10/15/2016 1.00 PROM STK PULD T PJSM. PD lateral drilling BHA #10 with 0.0 72.0 21:00 22:00 0.8' AKO motor and RR HCC bit. 10/15/2016 10/16/2016 2.00 PROD1 STK TRIP T Run in hole with BHA #10 72.0 5,079.0 22:00 00:00 10/16/2016 10/16/2016 1.50 PROM STK TRIP T Continue RIH. While running in hole, 5,079.0 7,580.0 00:00 01:30 observed decrease in MW out. Sent returns to the tiger tank. Brought mud back inside after 70 bbls. Dry tag billet at 7580 ft. 10/16/2016 10/16/2016 4.25 PROD1 STK KOST T Time mill off of billet. Aluminum 7,580.0 7,625.0 01:30 05:45 observed over the shaker at BU. One stall. Blow down choke. Continue milling. Dry drift billet area. Clean. 10/16/2016 10/16/2016 4.25 PROM DRILL DRLG T Continue drilling ahead. Pumping 7,625.0 7,980.0 05:45 10:00 1.50 bpm at 4330 psi. BHP 3840 psi. WOB 0.9 Klbs. CTW = 9 Klbs. ROP 70 -110 fph. Startmud swap. New mud at the bit at 7980 ft. 10/16/2016 10/16/2016 0.75 PROM DRILL WPRT T Wiper trip. PUW = 33KIbs. 7,980.0 7,100.0 10:00 10:45 10/16/2016 10/16/2016 0.75 PROM DRILL WPRT T RBIH. SOW =10 Klbs 7,100.0 7,980.0 10:45 11:30 10/16/2016 10/16/2016 1.25 FROM DRILL DRLG T Continue drilling ahead. Pumping 7,980.0 8,070.0 11:30 12:45 1.50 bpm at 4245 psi. BHP 3910 psi. WOB 1.3 Klbs. CTW = 4-6 Klbs. ROP 70 fph. 10/16/2016 10/16/2016 5.25 PROM DRILL DRLG P Continue drilling ahead. Pumping 8,070.0 8,380.0 12:45 18:00 1.50 bpm at 4245 psi. BHP 3910 psi. WOB 1.3 Klbs. CTW = 4-6 Klbs. ROP 50-70 fph. 10/16/2016 10/16/2016 0.50 FROM DRILL WPRT P Wiper trip. PUW = 36 Klbs 8,380.0 7,180.0 18:00 18:30 10/16/2016 10/16/2016 0.50 PROM DRILL WPRT P RBIH. SOW = 8KIbs 7,180.0 8,380.0 18:30 19:00 1 Page 6/15 Report Printed: 10/31/2016 -=' ' Uperations Summary (with Timelog Depths) 2B-02 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) 10/16/2016 10/17/2016 5.00 PROD1 DRILL DRLG P Continue drilling ahead. Pumping 8,380.0 8,659.0 19:00 00:00 1.53 bpm at 4200 psi. BHP 3970 psi. WOB 1.0 Klbs. CTW = -3 to -7 Klbs. ROP 40-140 fph. 10/17/2016 10/17/2016 2.25 PROD1 DRILL DRLG P Continue drilling ahead. Pumping 8,659.0 8,767.0 00:00 02:15 1.53 bpm at 4200 psi. BHP 3970 psi. WOB 1.0 Klbs. CTW = -3 to -7 Klbs. ROP 40-140 fph. 10/17/2016 10/17/2016 1.00 PROD1 DRILL WPRT P Pull up hole for tie-in wiper. PUW = 36 8,767.0 6,650.0 02:15 03:15 Klbs. Tie-into the RA for a +5.5 ft correction. 10/17/2016 10/17/2016 1.00 PROD1 DRILL WPRT P RBIH. SOW = 9 Klbs. No significant 6,650.0 8,767.0 03:15 04:15 increase in material over the shaker with sweep at surface. 10/17/2016 10/17/2016 10.50 PROD1 DRILL DRLG P BOBD. Pumping 1.52 bpm at 4100 8,767.0 9,170.0 04:15 14:45 psi. BHP 3930 psi. WOB 1.2 Klbs. CTW = 0 to -3 Klbs. ROP 30-60 fph. BHA wipers at 8955 ft, 9023 ft and 9155 ft. 10/17/2016 10/17/2016 0.25 PROD1 DRILL WPRT P PUH for wiper trip. PUW = 37 Klbs 9,170.0 8,180.0 14:45 15:00 10/17/2016 10/17/2016 0.50 PROD1 DRILL WPRT P RBIH. SOW = 7 Klbs. 8,180.0 9,170.0 15:00 15:30 10/17/2016 10/17/2016 8.25 PROD1 DRILL DRLG P BOBD. Pumping 1.52 bpm at 4100 9,170.0 9,570.0 15:30 23:45 psi. BHP 3930 psi. WOB 1.2 Klbs. CTW = 0 to -3 Klbs. ROP 30-60 fph. 10/17/2016 10/18/2016 0.25 PROD1 DRILL WPRT P PUH for wiper trip. PUW = 37 Klbs 9,570.0 9,150.0 23:45 00:00 10/18/2016 10/18/2016 1.00 PROD1 DRILL WPRT P Continue POOH. 9,150.0 6,600.0 00:00 01:00 10/18/2016 10/18/2016 1.00 PROD1 DRILL SIPB P PUH to 6600 ft MD. 6005 ft TVDrkb for 6,600.0 6,600.0 01:00 02:00 SBHP test. Shut choke with annular pressure of 3750 psi. WHP 900 psi. No change in pressure. Bleed WHP down to 700 psi. Build back up to 900 psi. Annular pressure = 3747 psi. EMW = 12.0 ppg. 10/18/2016 10/18/2016 1.50 PROD1 DRILL WPRT P Continue wiper trip to the swab valve. 6,600.0 95.0 02:00 03:30 10/18/2016 10/18/2016 4.00 PROD1 DRILL WPRT P RBIH, to tie in depth. 95.0 6,647.0 03:30 07:30 10/18/2016 10/18/2016 0.25 PROD1 DRILL DLOG P 6647 ft, log RA marker for +18.5 ft 6,647.0 6,679.0 07:30 07:45 correction. 10/18/2016 10/18/2016 2.00 PROD1 DRILL CIRC T PUH and wait on fluids. RIH and log 6,679.0 6,679.0 07:45 09:45 RA marker again for -.5 correction 10/18/2016 10/18/2016 2.00 PROD1 DRILL WPRT P RIH to confirm TD, start stacking wt at 6,679.0 9,500.0 09:45 11:45 9543 ft, RIH 10 FPM. Unable to get past 9543 ft. 10/18/2016 10/18/2016 0.75 PROD1 DRILL CIRC P PUH to 9500 ft. Start circulating 9,500.0 9,540.0 11:45 12:30 beaded liner pill to bottom, 5 bbls pumped, slow to min rate .3 BPM. 10/18/2016 10/18/2016 1.00 PROD1 DRILL WPRT P RBIH to confirm TD, 25 FPM, stack 9,540.0 9,570.0 12:30 13:30 39K. Confirm TD at 9570 ft. 10/18/2016 10/18/2016 4.00 PROD1 DRILL TRIP P POOH laying in beaded liner running 9,570.0 72.2 13:30 17:30 pill to surface and completion fluid, 12.2 PPG completion fluid, 50 FPM, 33K PU WT. Paint flags at 8372 ft and 5472 ft. Continue POOH. Page 7115 Report Printed: 10/31/2016 's ' Uperations Summary (with Timelog Depths) 2B-02 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 (WB) End Depth (WEI) 10/18/2016 10/18/2016 0.50 PROD1 DRILL OWFF P Perform 30 min flow check. 72.2 72.2 17:30 18:00 10/18/2016 10/18/2016 0.50 PROD1 DRILL PULD P PJSM, LD drilling BHA# 10 72.2 0.0 18:00 18:30 10/18/2016 10/18/2016 0.50 COMPZ1 CASING PUTB P PJSM, Prep rig floor for MU A lateral 0.0 0.0 18:30 19:00 liner assembly. 10/18/2016 10/18/2016 1.50 COMPZ1 CASING PUTB P MU 36jts of slotted liner with 10.08' 0.0 1,105.0 19:00 20:30 pup joint. 10/18/2016 10/18/2016 1.00 COMPZ1 CASING PULD P PJSM, MU Coiltrak tools 1,105.0 1,150.0 20:30 21:30 10/18/2016 10/18/2016 2.00 COMPZ1 CASING RUNL P RIH, (open EDC) with A lateral liner 1,150.0 6,576.9 21:30 23:30 assembly with open hole anchored billet 10/18/2016 10/18/2016 0.25 COMPZ1 CASING RUNL P Minus 11.38' correction at the 5,400' 6,579.9 7,530.0 23:30 23:45 EOP flag 10/18/2016 10/19/2016 0.25 COMPZ1 CASING DLOG P 7530', tie into the K1 correction of plus 7,530.0 7,563.0 23:45 00:00 4.5' 10/19/2016 10/19/2016 0.75 COMPZ1 CASING RUNL P Continue RIH with A liner assembly 7,563.0 9,570.0 00:00 00:45 10/19/2016 10/19/2016 0.25 COMPZ1 CASING RUNL P PUW 36 k, RIH, bring pump up to 9,570.0 8,465.4 00:45 01:00 4,650 psi, release liner on bottom 9,570', TOL 8,465.45', remove liner length from counters 10/19/2016 10/19/2016 1.75 COMPZ1 CASING TRIP P POOH, with setting tools 8,465.4 60.7 01:00 02:45 10/19/2016 10/19/2016 0.50 COMPZ1 CASING OWFF P PJSM, checked well for flow 60.7 60.7 02:45 03:15 10/19/2016 10/19/2016 0.50 COMPZ1 CASING PULD P LD liner setting tools 60.7 0.0 03:15 03:45 10/19/2016 10/19/2016 1.00 PROD2 DRILL PULD P PJSM, PU/MU AU lateral 0.0 72.2 03:45 04:45 kickoff/drilling BHA# 12, changeout pac-off elements. 10/19/2016 10/19/2016 4.00 PROD2 DRILL TRIP P RIH w/ AL1 lateral drilling BHA#12 72.2 8,444.0 04:45 08:45 and displace 12.2 completion fluid to 8.9 FloPro (System 2). 10/19/2016 10/19/2016 3.00 PROD2 DRILL KOST P RIH and dry tag TOB at 8466'. PU 8,444.0 8,495.0 08:45 11:45 and start pumping. RBIH and start time milling (Dig trough, 2 FPH for 1', 3 FPH 1', 10 FPH for 5', 20 FPH for 2'). DHWOB 1.2k 10/19/2016 10/19/2016 1.00 PROD2 DRILL DRLG P Drill ahead to 8510. 8,495.0 8,510.0 11:45 12:45 10/19/2016 10/19/2016 0.25 PROD2 DRILL DRLG P PUH and dry drift from 8440' to 8510'. 8,510.0 8,440.0 12:45 13:00 No issues. 10/19/2016 10/19/2016 3.50 PROD2 DRILL DRLG P Drill ahead to 8562' and perform BHA 8,440.0 8,606.0 13:00 16:30 wiper, PU WT 35K. Pump 5x5 sweep. Continue drilling ahead, rotate TF to 50 degrees ROHS, DHWOB 1.5K, ROP 50. 10/19/2016 10/19/2016 4.00 PROD2 DRILL DRLG P New mud at the bit 8,606', continue 8,606.0 8,698.0 16:30 20:30 drilling ahead 10/19/2016 10/19/2016 0.25 PROD2 DRILL WPRT P BHA wiper up hole to 8,600', PUW 39 8,698.0 8,698.0 20:30 20:45 k 10/19/2016 10/19/2016 0.75 PROD2 DRILL DRLG P BOBD 1.57 bpm at 3,580 psi off 8,698.0 8,715.0 20:45 21:30 bottom, BHP 3938, WHP 556, IA 10, OA 11, CTSW= minus 2.0 k, DHWOB=1.4 k. 10/19/2016 10/19/2016 0.25 PROD2 DRILL WPRT P BHA wiper up hole to 8,628', PUW 38 8,715.0 8,715.0 21:30 21:45 k Page 8115 Report Printed: 10/31/2016 Y" uperations Summary (with Timelog Uepths) 2B-02 Rig: NABORS CDR2-AC Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time Dur (hr) Phase Op Code Activity Code Time P -T -X Operation (MB) End Depth (ftKB) 10/19/2016 10/20/2016 2.25 PROD2 DRILL DRLG P BOBD 1.58 bpm at 3850 psi off 8,715.0 8,811.0 21:45 00:00 bottom, BHP 3965, WHP 564, IA 10, OA 11, CTSW= minus 7.0 k, DHWOB=1.3 k. 10/20/2016 10/20/2016 1.50 PROD2 DRILL DRLG P OBD 1.56 bpm at 4245 psi, BHP 8,811.0 8,860.0 00:00 01:30 3951, WHP 562, IA 10, OA 11, CTSW=minus 7 k, DHWOB=1.3 k 10/20/2016 10/20/2016 0.50 PROD2 DRILL WPRT P Wiper up hole, PUW 37 k 8,860.0 7,660.0 01:30 02:00 10/20/2016 10/20/2016 0.50 PROD2 DRILL WPRT P Wiper back in hole, RIW 7 k 7,660.0 8,860.0 02:00 02:30 10/20/2016 10/20/2016 4.50 PROD2 DRILL DRLG P BOBD 1.57 bpm at 3580 psi off 8,860.0 8,983.0 02:30 07:00 bottom, BHP 3,963, WHIP 530, IA 15, OA 13 10/20/2016 10/20/2016 0.50 PROD2 DRILL WPRT P Wiper up hole, PUW 37K 8,983.0 8,000.0 07:00 07:30 10/20/2016 10/20/2016 0.50 PROD2 DRILL WPRT P Wiper back in hole, RIW 7K 8,000.0 8,983.0 07:30 08:00 10/20/2016 10/20/2016 2.00 PROD2 DRILL DRLG P BOBD 1.47 BPM at 4309 psi off 8,983.0 9,030.0 08:00 10:00 bottom, BHP 4338 psi 10/20/2016 10/20/2016 4.00 PROD2 DRILL DRLG P Pump 25BBL beaded pill & 25BBL 9,030.0 9,220.0 10:00 14:00 FloPro sweeps and continue drilling. ROP up to 50 ft/hr. 10/20/2016 10/20/2016 0.25 PROD2 DRILL WPRT P Wiper up hole, PUW 44K 9,220.0 9,050.0 14:00 14:15 10/20/2016 10/20/2016 0.25 PROD2 DRILL WPRT P Wiper back in hole, RIW 6K 9,050.0 9,220.0 14:15 14:30 10/20/2016 10/20/2016 1.00 PROD2 DRILL DRLG P BOBD 1.43 BPM at 4269 psi off 9,220.0 9,260.0 14:30 15:30 bottom, BHP 4418 psi. Continue with beaded pill sweeps 10/20/2016 10/20/2016 0.50 PROM DRILL WPRT P Wiper up hole, PUW 38K 9,260.0 8,200.0 15:30 16:00 10/20/2016 10/20/2016 0.50 PROD2 DRILL WPRT P Wiper back in hole, RIW 6K. 8,200.0 9,260.0 16:00 16:30 10/20/2016 10/20/2016 2.00 PROD2 DRILL TRIP P POOH 9,260.0 72.2 16:30 18:30 10/20/2016 10/20/2016 0.25 PROD2 DRILL PULD P PJSM, PUD/LD drilling BHA# 12 72.2 72.2 18:30 18:45 10/20/2016 10/20/2016 2.25 PROD2 DRILL PULD T Check well for flow, checks aren't 72.2 72.2 18:45 21:00 holding, swap to undeploying with closed EDC, function closed EDC, EDC is holding, looks like the upper checks aren't holding, strip up and close double ball valves, bleed pressure from coil, DBV holding, go back to manage pressure on well bore, 10/20/2016 10/20/2016 1.50 PROD2 DRILL PULD P Continue PUD as per standard 72.2 0.0 21:00 22:30 procedure. 10/20/2016 10/21/2016 1.50 PROD2 DRILL PULD P PU/MU/PD Drilling BHA# 13, inspect 0.0 78.3 22:30 00:00 pac-off element 10/21/2016 10/21/2016 0.75 PROD2 DRILL PULD P Continue PD BHA# 13 78.3 78.3 00:00 00:45 10/21/2016 10/21/2016 1.25 PROD2 DRILL TRIP P RIH with BHA# 13 with agitator and 78.3 6,445.0 00:45 02:00 0.8 bend motor and RR bi-center bit. 10/21/2016 10/21/2016 0.25 PROD2 DRILL DLOG P Log K1 marker correction of minus 6,445.0 6,469.0 02:00 02:15 5.01, PUW 10/21/2016 10/21/2016 1.25 PROD2 DRILL TRIP P Continue RIHTB 6,469.0 9,260.0 02:15 03:30 Page 9/15 Report Printed: 10/31/2016 uperations Summary (with Timelog bepths) 2B-02 MW Rig: NABORS CDR2-AC Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time Dur (hr) Phase Op Code Activity Code Time P -TX Operation (ftKB) End Depth (ftKB) 10/21/2016 10/21/2016 2.00 PROD2 DRILL DRLG P OBD 1.4 bpm at 4400 psi, BHP 4008, 9,260.0 9,354.0 03:30 05:30 WHP 463, IA 12, OA 9 10/21/2016 10/21/2016 0.25 PROD2 DRILL WPRT P Wiper up hole, PUW 39K 9,354.0 9,254.0 05:30 05:45 10/21/2016 10/21/2016 0.25 PROD2 DRILL WPRT P Wiper back in hole, RIW 5K 9,254.0 9,354.0 05:45 06:00 10/21/2016 10/21/2016 2.00 PROD2 DRILL DRLG P BOBD 1.4 bpm at 4400 psi, BHP 3985 9,354.0 9,418.0 06:00 08:00 10/21/2016 10/21/2016 0.25 PROD2 DRILL WPRT P Wiper up hole, PUW 40K 9,454.0 9,254.0 08:00 08:15 10/21/2016 10/21/2016 0.25 PROD2 DRILL WPRT P Wiper back in hole, RIW 4K 9,254.0 9,454.0 08:15 08:30 10/21/2016 10/21/2016 2.50 PROD2 DRILL DRLG P BOBD 1.4 bpm at 4400 psi, BHP 3977 9,454.0 9,521.0 08:30 11:00 10/21/2016 10/21/2016 0.25 PROD2 DRILL WPRT P Wiper up hole, PUW 45K, pump 5 bbl 9,521.0 9,302.0 11:00 11:15 to -vis sweep 10/21/2016 10/21/2016 0.25 PROD2 DRILL WPRT P Wiper back in hole, RIW 2K, pump 5 9,302.0 9,521.0 11:15 11:30 bbl hi -vis sweep 10/21/2016 10/21/2016 0.50 PROD2 DRILL WPRT P BOBD 1.44 bpm at 4400 psi, BHP 9,521.0 9,530.0 11:30 12:00 3977, DWOB 1.5K, ROP 20 ft/hr, pump 5x5 sweep 10/21/2016 10/21/2016 0.50 PROD2 DRILL WPRT P Wiper up hole (1000'), PUW 43K. 9,530.0 8,530.0 12:00 12:30 Pump 10bbl hi -vis sweep 10/21/2016 10/21/2016 0.50 PROD2 DRILL WPRT P Wiper back in hole, RIW 5K. Pump 8,530.0 9,530.0 12:30 13:00 10bbl to -vis sweep 10/21/2016 10/21/2016 2.00 PROD2 DRILL DRLG P BOBD 1.4 bpm at 4400 psi, BHP 4000 9,530.0 9,622.0 13:00 15:00 psi, DHWOB 1K 10/21/2016 10/21/2016 0.25 PROD2 DRILL WPRT P Wiper up hole, PUW 43K 9,622.0 9,522.0 15:00 15:15 10/21/2016 10/21/2016 0.25 PROD2 DRILL WPRT P Wiper back in hole, RIW 4K 9,522.0 9,622.0 15:15 15:30 10/21/2016 10/21/2016 2.00 PROD2 DRILL DRLG P BOBD, 1.4 bpm, ROP 33ft/hr, 9,622.0 9,697-0 15:30 17:30 DHWOB .9K 10/21/2016 10/21/2016 3.25 PROD2 DRILL DRLG P OBD 1.4 bpm at 4549 psi, BHP 4038, 9,697.0 9,778.0 17:30 20:45 WHP 450, IA 7, OA 11 10/21/2016 10/21/2016 1.25 PROD2 DRILL WPRT P Wiper up hole to 6,650', PUW 45 k. 9,778.0 6,650.0 20:45 22:00 10/21/2016 10/21/2016 0.25 PROD2 DRILL DLOG P Log the RA correction of plus 7.0', 6,650.0 6,676.0 22:00 22:15 10/21/2016 10/21/2016 1.25 PROD2 DRILL WPRT P Wiper back in hole, RIW 10 k 6,676.0 9,778.0 22:15 23:30 10/21/2016 10/22/2016 0.50 PROD2 DRILL DRLG P BOBD 1.4 bpm at 4500 psi, BHP 9,778.0 9,792.0 23:30 00:00 4050, WHP 426, IA 8, OA 12 10/22/2016 10/22/2016 4.50 PROD2 DRILL DRLG P OBD 1.4 bpm at 4,700 psi, BHP 4040, 9,792.0 9,905.0 00:00 04:30 WHP 437, IA 8, OA 11 10/22/2016 10/22/2016 0.25 PROD2 DRILL DRLG P Start pumping bead pills. 9,905.0 9,905.0 04:30 04:45 10/22/2016 10/22/2016 5.00 PROD2 DRILL DRLG P Continue drilling ahead, 1.37 bpm at 9,905.0 9,976.0 04:45 09:45 4617 psi, BHP 4054, WHP 416, IA 14, OA 12 10/22/2016 10/22/2016 0.75 PROD2 DRILL WPRT P Wiper up hole, PUW 45K 9,976.0 9,776.0 09:45 10:30 10/22/2016 10/22/2016 0.75 PROD2 DRILL WPRT P Wiper back in hole, RIH 6.5K 9,776.0 9,976.0 10:30 11:15 10/22/2016 10/22/2016 5.00 PROD2 DRILL DRLG P BOBD 1.35 bpm at 4750 psi, BHP 9,976.0 10,083.0 11:15 16:15 4054, WHP 390, IA 7, OA 11, ROP 20 ft/hr, DHWOB 1K Page 10/15 Report Printed: 10/31/2016 operations Summary (with Timelog Depths) 4a 2B-02 Rig: NABORS CDR2-AC Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time our (hr) Phase Op Code Activity Code Time P -T -X Operation (MB) End Depth (ftK8) 10/22/2016 10/22/2016 0.25 PROD2 DRILL WPRT P 200' wiper up hole, PUW 45 k 10,083.0 9,883.0 16:15 16:30 10/22/2016 10/22/2016 0.25 PROD2 DRILL WPRT P Wiper back in hole, RIW - 2.Ok 9,883.0 10,083.0 16:30 16:45 10/22/2016 10/22/2016 3.25 PROD2 DRILL DRLG P BOBD 1.35 k at 4,100' psi, BHP 4057, 10,083.0 10,150.0 16:45 20:00 WHP 352, IA 6, OA 11 10/22/2016 10/22/2016 0.50 PROD2 DRILL WPRT P Geo wiper up hole 10,133', PUW 42 k 10,150.0 10,150.0 20:00 20:30 10/22/2016 10/23/2016 3.50 PROD2 DRILL DRLG P BOBD 1.37 bpm at 4,460 psi, WHP 10,150.0 10,203.0 20:30 00:00 4,046, IA 6, OA 11, blow pop off on pump, swap out pop off, and restart drilling. 10/23/2016 10/23/2016 2.00 PROD2 DRILL DRLG P OBD 1.37 bpm at 4642 psi, BHP 10,203.0 10,227.0 00:00 02:00 4058, WHP 357, IA 7, OA 11 10/23/2016 10/23/2016 4.00 PROD2 DRILL WPRT P PUH, PUW 36 k, TD AL1 lateral, 10,227.0 6,694.0 02:00 06:00 pump 1 0x1 0 bbls sweep, clean hole 9,850'-9,530'. Continue POOH. 10/23/2016 10/23/2016 0.25 PROD2 DRILL WPRT P Perform choke calibration at 6,694'. 6,694.0 6,694.0 06:00 06:15 Full rate 12 ECD, Ann Pres 3756 psi, WH 307 psi, DI 8.97 ppg, DO 8.87 ppg, Pump Pres 4320 psi, choke 300, EDC 12.18 10/23/2016 10/23/2016 1.00 PROD2 DRILL WPRT P Continue PUH for swab wiper 6,694.0 78.0 06:15 07:15 10/23/2016 10/23/2016 1.00 PROD2 DRILL WPRT P RBIH, to tie in depth. 78.0 6,400.0 07:15 08:15 10/23/2016 10/23/2016 0.25 PROD2 DRILL DLOG P Log K1 marker for +22 ft correction. 6,400.0 6,469.0 08:15 08:30 10/23/2016 10/23/2016 0.50 PROD2 DRILL DLOG P RIH and perform static BHP at 6,594'. 6,469.0 6,678.0 08:30 09:00 RIH and log RA marker for -.5 correction. 10/23/2016 10/23/2016 2.00 PROD2 DRILL WPRT P Continue RIH. Stack down XX'. 6,678.0 10,230.0 09:00 11:00 Confirm TD at 10,230'. 10/23/2016 10/23/2016 3.50 PROD2 DRILL DISP P POOH laying in beaded liner pill and 10,230.0 78.0 11:00 14:30 12.2 ppf completion fluid. Paint flags at 8,778 and 5,178. Continue POOH 10/23/2016 10/23/2016 0.50 PROD2 DRILL OWFF P Conduct 30 min flow check 78.0 78.0 14:30 15:00 10/23/2016 10/23/2016 0.50 PROD2 DRILL PULD P PJSM, Lay down BHA #13 78.0 0.0 15:00 15:30 10/23/2016 10/23/2016 3.00 PROD2 WHDBOP RURD P Clean and clear rig floor in preparation 0.0 0.0 15:30 18:30 for BOP test. 10/23/2016 10/23/2016 1.50 PROD2 WHDBOP RURD P MU Nozzle, flush stack and surface 0.0 0.0 18:30 20:00 lines while displacing coil to fresh water, Valve crew on location greasing tree valves. 10/23/2016 10/24/2016 4.00 PROD2 WHDBOP BOPE P Perform bi-weekly BOP test, witness 0.0 0.0 20:00 00:00 waived by state tester Brian Bixby, Test pressure 3,750 psi high / 250 psi low / 2,500 psi annular. 10/24/2016 10/24/2016 4.00 PROD2 WHDBOP BOPE P Continue bi-weekly BOP test, witness 0.0 0.0 00:00 04:00 waived by state tester Brian Bixby, Test pressure 3,750 psi high 1250 psi low / 2,500 psi annular. Test complete, no failures. 10/24/2016 10/24/2016 4.50 PROD2 WHDBOP BOPE P Calibrate In and Out MicroMotion. 0.0 0.0 04:00 08:30 Test inner real valve, replace packoffs. Displace coil back to completion fluid. Page 11/15 Report Printed: 10/31/2016 uperations Summary (with Timelog Uepths) 4 2B-02 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) 10/24/2016 10/24/2016 0.50 PROD2 CASING PUTB P PJSM, Prep rig floor for MU A lateral 0.0 0.0 08:30 09:00 liner assembly. 10/24/2016 10/24/2016 1.50 PROD2 CASING PUTB P MU 34 jts of slotted liner with 8.09' pup 0.0 0.0 09:00 10:30 joint. Perform BOP drill 10/24/2016 10/24/2016 1.50 PROD2 CASING PUTB P PJSM, MU Coiltrak tools (BHA#15), 0.0 1,102.0 10:30 12:00 test tools and QTC 10/24/2016 10/24/2016 1.50 PROD2 CASING RUNL P RIH, with lower AL1 lateral liner 1,102.0 6,202.0 12:00 13:30 assembly to EOP flag 10/24/2016 10/24/2016 0.25 PROD2 CASING RUNL P Minus 11.5' correction at the EOP flag 6,202.0 6,202.0 13:30 13:45 10/24/2016 10/24/2016 0.50 PROD2 CASING DLOG P WT CK 36K at 7470. Shut down 6,202.0 7,492.0 13:45 14:15 pumps. Log the K1 marker for a correction of +5.5'. 10/24/2016 10/24/2016 1.00 PROD2 CASING RUNL P RIH to TD at 10,230', PUW 40K. 7,492.0 10,230.0 14:15 15:15 Bring pump online to 4,650 psi, 1.4 bpm, IA 12, OA 4, WH 0. Release liner on bottom 10,230', TOL at 9,172', remove liner length from counters. 10/24/2016 10/24/2016 3.00 PROD2 CASING TRIP P POOH, with setting tools and paint 10,230.0 61.0 15:15 18:15 EOP flags 10/24/2016 10/24/2016 0.50 PROD2 CASING OWFF P At surface, perform flow test 61.0 61.0 18:15 18:45 10/24/2016 10/24/2016 1.75 PROD2 CASING PUTB P PU/MU 11 joints slotted liner, OH 61.0 0.0 18:45 20:30 anchored billet, and liner running assembly BHA #15. Perform BOP drill 10/24/2016 10/24/2016 1.50 PROD2 CASING PUTB P PJSM, MU Coiltrak tools (BHA #15) 0.0 0.0 20:30 22:00 10/24/2016 10/24/2016 1.00 PROD2 CASING RUNL P RIH, with upper AL1 lateral liner 0.0 6,514.0 22:00 23:00 assembly to EOP flag at 6144' 10/24/2016 10/24/2016 0.50 PROD2 CASING RUNL P Minus 10' correction at the EOP flag. 6,514.0 6,514.0 23:00 23:30 WT CK = 32K at 6,514'. Pumps offline, EDC closed. 10/24/2016 10/25/2016 0.50 PROD2 CASING RUNL P RIH to K1 marker 6,514.0 6,790.0 23:30 00:00 10/25/2016 10/25/2016 0.50 PROD2 CASING DLOG P Log the K1 marker for a correction of 6,790.0 6,824.0 00:00 00:30 plus 4.5' 10/25/2016 10/25/2016 0.50 PROD2 CASING TRIP P Continue RIH to bottom 6,824.0 9,168.0 00:30 01:00 10/25/2016 10/25/2016 0.25 PROD2 CASING TRIP P Tag bottom, PUW 36 k, bring pump up 9,168.0 9,168.0 01:00 01:15 to shear at 4,300 psi 10/25/2016 10/25/2016 0.60 PROD2 CASING TRIP P POOH, pumping with closed EDC 9,168.0 6,585.0 01:15 01:51 10/25/2016 10/25/2016 1.25 PROD2 CASING OWFF P trace of crude to surface, transfer 6,585.0 6,585.0 01:51 03:06 additional 12.2 ppg completion fluid to active pit, circulate bottoms up, check well for flow, well is dead. 10/25/2016 10/25/2016 1.50 PROD2 CASING PULD P Continue POOH, pumping pipe 6,585.0 60.8 03:06 04:36 displacement 10/25/2016 10/25/2016 0.50 PROD2 CASING OWFF P OOH, check well for flow, PJSM 60.8 60.8 04:36 05:06 10/25/2016 10/25/2016 1.25 PROD2 CASING PULD P LD AL1 liner setting tools on a dead 60.8 0.0 05:06 06:21 well. 10/25/2016 10/25/2016 0.50 PROD3 DRILL SFTY P Crew change, valve check list, PJSM 0.0 0.0 06:21 06:51 10/25/2016 10/25/2016 1.25 PROD3 DRILL PULD P PJSM, make up BHA# 16 on a dead 0.0 78.4 06:51 08:06 well. Page 12115 Report Printed: 1013112016 operations Summary (with Timelog Depths) f.d.. 2B-02 4 .. Rig: NABORS CDR2-AC Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time our (hr) Phase Op Code Activity Code Time P -T -X Operation (MB) End Depth (ftKB) 10/25/2016 10/25/2016 1.50 PRODS DRILL TRIP P RIH wtih AL1 -01 drilling BHA# 16, 78.4 6,440.0 08:06 09:36 agitator and RR bi-center bit. 10/25/2016 10/25/2016 0.25 PRODS DRILL DLOG P Log K1 marker correction of minus 6,440.0 6,472.0 09:36 09:51 7.0'. 10/25/2016 10/25/2016 1.00 PRODS DRILL TRIP P Continue RIH to billet 6,472.0 8,810.0 09:51 10:51 10/25/2016 10/25/2016 1.00 PRODS DRILL DISP P Tag TOB, 8,810', PUH and displace 8,810.0 8,810.0 10:51 11:51 well to drilling fluid. 10/25/2016 10/25/2016 0.50 PRODS DRILL TRIP P PUH 8,810.0 6,650.0 11:51 12:21 10/25/2016 10/25/2016 0.50 PRODS DRILL DLOG P Log the RA correction of plus 1.5' 6,650.0 6,684.0 12:21 12:51 10/25/2016 10/25/2016 0.60 PRODS DRILL TRIP P RBIH to confirm TOB 6,684.0 8,810.0 12:51 13:27 10/25/2016 10/25/2016 1.00 PRODS DRILL KOST P Tag top of billet, PUH, bring pump up 8,810.0 8,853.0 13:27 14:27 to 1.3 bpm at 4450 psi, trough above billet, kickoff of billet as per procedure. 10/25/2016 10/25/2016 0.25 PRODS DRILL WPRT P PUH, PUW 36 k, drift billet area, clean 8,853.0 8,791.0 14:27 14:42 RBIHTB 10/25/2016 10/25/2016 2.15 PRODS DRILL DRLG P BOBD, 1.3 bpm at 4460 psi FS, BHP 8,791.0 8,870.0 14:42 16:51 3952, WHP 212, IA 10, OA 7 10/25/2016 10/25/2016 4.35 PRODS DRILL DRLG P OBD, 1.3 bpm at 4521 psi, BHP 3943, 8,870.0 9,080.0 16:51 21:12 WHP 217, IA 10, OA 7, PUW at 9,080 ft 38k. Note: New mud out bit at 9,037 ft. 10/25/2016 10/26/2016 2.80 PRODS DRILL DRLG P BOBD 1.42 bpm at 4,402 psi FS, BHP 9,080.0 9,200.0 21:12 00:00 4,003 psi, WHP 542, IA 10, OA 7 10/26/2016 10/26/2016 0.35 PRODS DRILL DRLG P OBD 1.42 bpm at 4,450 psi FS, BHP 9,200.0 9,210.0 00:00 00:21 3,975 psi, WHP 556, IA 11, OA 8. pump 5x5 sweep 10/26/2016 10/26/2016 0.50 PRODS DRILL WPRT P 9,210 ft. Wiper up hole 1,000 ft, PUW 9,210.0 8,210.0 00:21 00:51 38k, pull 6k over at 9,071 ft and 8,659 ft. 10/26/2016 10/26/2016 0.55 PRODS DRILL WPRT P 8,210 ft Wiper back in hole, RIW 9.Ok 8,210.0 9,210.0 00:51 01:24 10/26/2016 10/26/2016 4.50 PRODS DRILL DRLG P BOBD 1.40 bpm at 4,429 psi, BHP 9,210.0 9,405.0 01:24 05:54 4,008, WHP 561, IA 11, OA 8 10/26/2016 10/26/2016 1.00 PRODS DRILL WPRT P PU off bottom for a geo wiper, PUW 9,405.0 6,650.0 05:54 06:54 36 k, discuss plan forward, continue pulling up hole for a tie in. 10/26/2016 10/26/2016 0.25 PRODS DRILL DLOG P Log the RA marker correction of plus 6,650.0 6,650.0 06:54 07:09 5.0' 10/26/2016 10/26/2016 0.75 PRODS DRILL WPRT P Wiper back in hole, RIW 8 k 6,650.0 9,405.0 07:09 07:54 10/26/2016 10/26/2016 3.00 PRODS DRILL DRLG P BOBD 1.4 bpm at 4,330 psi, BHP 9,405.0 9,446.0 07:54 10:54 4024, WHP 464, IA 10, OA 9 10/26/2016 10/26/2016 0.25 PRODS DRILL WPRT P Short 100' wiper up hole 9,446.0 9,446.0 10:54 11:09 10/26/2016 10/26/2016 10.00 PRODS DRILL DRLG P BOBD 1.4 bpm at 3600 psi FS, BHP 9,446.0 9,750.0 11:09 21:09 4075, WHP 618, IA 10, OA 11, couple of PU's for restarts, PUW(s) 44k & 46k, pump 10x10 sweeps. 10/26/2016 10/27/2016 2.85 PRODS DRILL WPRT P 9,750 ft. Called TD. Wiper to swab. 9,750.0 675.0 21:09 00:00 PUW 46k, Jog at EOB, Jog at 600 ft from surface. Page 13115 Report Printed: 10/31/2016 sem., uperations Summary (with Timelog Depths) 2B-02 MW Rig: NABORS CDR2-AC Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time our (hr) Phase Op Code Activity Code Time P-T-X Operation (ftK8) End Depth (ftKB) 10/27/2016 10/27/2016 0.25 PROD3 DRILL WPRT P Continue wiper to swab, tag up, restet 675.0 78.4 00:00 00:15 counters. 10/27/2016 10/27/2016 1.25 PROD3 DRILL TRIP P RBIH to confirm TD 78.4 6,430.0 00:15 01:30 10/27/2016 10/27/2016 0.20 PROD3 DRILL DLOG P Tie in to K1 for minus 1 ft correction 6,430.0 6,470.0 01:30 01:42 10/27/2016 10/27/2016 1.45 PRODS DRILL TRIP P Continue RIH, stop at window for 6,470.0 9,754.0 01:42 03:09 SBHP at 6,641 ft (Bit at 6,690 ft at 01:49) BHP 3,797 psi, 5 minutes 3,798 psi= 12.1 ppg EMW at window, bring pumps back on and continue RIH, clean past billets at 7,580 ft, 8,465 ft and 8,808 ft, stacked 1 k at 9,412 ft, clean to corrected TD at 9,754 ft, CWT 6k. 10/27/2016 10/27/2016 0.85 PROD3 DRILL DISP P 9,754 ft. Tag corrected TD, PUW 40k, 9,754.0 9,754.0 03:09 04:00 pump 12.2 ppg beaded liner pill. 10/27/2016 10/27/2016 3.00 PROD3 DRILL DISP T Lost prime on pump at 20 bbls away, 9,754.0 9,754.0 04:00 07:00 noticed 10.8 ppg fluid at the in MM, Diagnose problem and found that the suction valve was still cracked open, contaminating the liner pill, circulate contaminated flud out of hole 10/27/2016 10/27/2016 3.00 PRODS DRILL TRIP P POOH, laying in liner running pill with 9,754.0 78.6 07:00 10:00 alpine beads up to the window painting EOP flags, 10/27/2016 10/27/2016 0.50 PROD3 DRILL OWFF P Check well for flow, PJSM 78.6 78.6 10:00 10:30 10/27/2016 10/27/2016 0.50 PROD3 DRILL PULD P LD drilling BHA# 16 78.6 0.0 10:30 11:00 10/27/2016 10/27/2016 0.50 COMPZ3 CASING PUTB P PJSM, prep rig floor for MU AL1-01 0.0 0.0 11:00 11:30 liner assembly 10/27/2016 10/27/2016 4.50 COMPZ3 CASING PUTB P MU AL1-01 liner assembly wtih 102 jts 0.0 3,152.3 11:30 16:00 of slotted liner with 2 pups. 10/27/2016 10/27/2016 1.25 COMPZ3 CASING PULD P PU/MU Surface test Coiltrak tools 3,152.3 3,196.5 16:00 17:15 10/27/2016 10/27/2016 3.50 COMPZ3 CASING RUNL P RIH, w/ Liner BHA# 17 102 jts of 3,196.5 9,750.0 17:15 20:45 slotted liner and shorty deployment sleeve. Minus 12.0 ft correction at flag, PUW 49k, RBIH, started stacking at 8,040 ft, work liner, plus 2 ft at bottom flag, work to 9,750 ft. 10/27/2016 10/27/2016 0.30 COMPZ3 CASING RUNL P 9,750 ft. On depth, PUW 56k, on line 9,750.0 6,598.0 20:45 21:03 1.3 bpm to release off liner, PUW 28k, reset counters, TOP of liner at 6,598 ft. 10/27/2016 10/27/2016 1.30 COMPZ3 CASING DISP P 6,598 ft. Displace well to seawater, 6,598.0 6,598.0 21:03 22:21 LRS on site, PJSM with LRS 10/27/2016 10/27/2016 0.75 COMPZ3 CASING TRIP P POOH pumping seawater to 2,500 ft. 6,598.0 2,500.0 22:21 23:06 LRS P/T lines and equipment. 10/27/2016 10/28/2016 0.90 COMPZ3 CASING FRZP P 2,500 ft. LRS pump 30 bbls diesel, 2,500.0 2,500.0 23:06 00:00 RDMO LRS. 10/28/2016 10/28/2016 1.00 COMPZ3 CASING TRIP P POOH pumping diesel. PJSM- PUD 2,500.0 44.2 00:00 01:00 BHA 10/28/2016 10/28/2016 1.75 COMPZ3 CASING PULD P PUD/LD running tool BHA #17. 44.2 0.0 01:00 02:45 1 1 Page 14115 Report Printed: 10/31/2016 uperations Summary (with Timelog Depths) a; W . • y ' t 2B-02 Rig: NABORS CDR2-AC Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time Dur (hr) Phase Op Code Activity Code Time P -T -X Operation (ftKB) End Depth (ftKB) 10/28/2016 10/28/2016 2.00 DEMOB WHDBOP MPSP P PJSM- Bring in BPV equipment, MU 0.0 0.0 02:45 04:45 and lubricate in 3" GRAY BPV, Final TBG 1,230 psi, close master halfway, bleed above BPV to 450 psi, holding good, bleed to zero, close master, RDMO BPV equipment and crew. 10/28/2016 10/28/2016 1.25 DEMOB WHDBOP RURD P PJSM- Skid cart, MU nozzle, flush 0.0 0.0 04:45 06:00 coil, jet BOP stack and surface lines 10/28/2016 10/28/2016 6.00 DEMOB WHDBOP RURD P Start Rig move check list, blow down 0.0 0.0 06:00 12:00 steam lines, blow down coiled tubing reel, disconnect PUTZ, nipple down BOPE, etc .... Trucks on location PJSM for moving subs off of well. Rig Released 12:00 noon Page 15/15 Report Printed: 10/31/2016 ConocoPhillips ConocoPhillips (Alaska) Inc. -Kup2 Kuparuk River Unit Kuparuk 2B Pad 2B-02AL1 50-029-21154-60 Baker Hughes INTEQ Definitive Survey Report 04 November, 2016 WMA.I BAKER HUGHES - ConocoPhillips Mid BAKConocoPhillips Definitive Survey Report HUGHES Company: ConocoPhillips (Alaska) Inc. -Kup2 Local Co-ordinate Reference: Well 28-02 Project: Kuparuk River Unit TVD Reference: 213-02 @ 126.00usft (28-02) Site: Kuparuk 2B Pad MD Reference: 2B-02 @ 126.00usft (2B-02) . Well: 213-02 North Reference: True Wellbore: 2B -D2 Survey Calculation Method: Minimum Curvature Design: 28-02 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 28-02 Well Position -NI-S 0.00 usft Northing: 5,954,890.07usft Latitude: 70° 17' 16.702 N +EI -W 0.00 usft Easting: 508,370.93usft Longitude: 149° 55'56.081 W ,. Position Uncertainty 0.00 usft Wellhead Elevation: usft Ground Level: 0.00 usft Wellbore 2B-02AL1 Magnetics Model Name Sample Date Declination Dip Angle Field Strength (nT) BGGM2016 10/1/2016 17.90 80.90 57,541 Design 2B-02ALl Audit Notes: Version: 1.0 Phase: ACTUAL Tie On Depth: 8,450.91 vertical Section: Depth From (TVD) -N/-S +E/ -W Direction (usft) (usft) (usft) (°) 126.00 0.00 0.00 345.00 Survey Program Date 11/1/2016 From To Survey Survey (usft) (usft) Survey (Wellbore) Tool Name Description Start Date End Date 200.00 6,600.00 213-02 (26-02) GCT -MS Schlumberger GCT multishot 1/12/2001 6,640.00 7,560.37 2B-02APB1 (2B-02AP81) MWD MWD - Standard 10/8/2016 10/15/2016 7,580.00 8,450.91 2B -02A(2 B -02A) MWD MWD - Standard 10/16/2016 10/18/2016 8,465.00 10,193.77 2B-02AL1 (2B-02AL1) MWD MWD - Standard 10/19/2016 10/22/2016 11/4/2016 7'35 02AM Page 2 COMPASS 5000.1 Build 74 Survey ConocoPhillips Ed k ConocoPhillips Definitive Survey Report KER HUGHES Company: ConocoPhillips (Alaska) Inc. -Kup2 Local Co-ordinate Reference: Well 2B-02 Project: Kuparuk River Unit TVD Reference: 2B-02 @ 126.00usft (213-02) ND Waft) Site: Kupamk 2B Pad MD Reference: 213-02 @ 126.00usft (213-02) Northing Well: 2B-02 North Reference: True Annotation Wellbore: 28-02 Survey Calculation Method: Minimum Curvature Design: 28-02 Database. EDM Alaska NSK Sandbox fft) Survey Map Map Vertical MD (usf3y Inc (�) Azi {°) ND Waft) TVDSS (usRj +NIS Weft) +EFW {usR) Northing Easting DLS {°DILS Section Survey Tool Name Annotation fft) (n) (ft) 8,450.91 90.34 290.81 6,118.71 5,992.71 -3,030.60 -1,529.11 5,951,857.87 506,845.35 11.24 -2,531.77 MWD (3) TIP 8,465.00 89.99 288.96 6,118.67 5,992.67 -3,026.01 -1,542.36 5,951,862.65 506,832.10 13.36 -2,523.71 MWD (4) KOP 8,498.11 85.73 292.14 6,119.91 5,993.91 -3,014.40 -1,573.33 5,951,874.22 506,801.12 16.05 -2,504.48 MWD (4) 8,525.72 83.76 294.81 6,122.44 5,996.44 -3,003.45 -1,598.54 5,951,885.14 506,775.89 11.98 -2,487.38 MWD (4) 8,555.69 83.42 298.44 6,125.78 5,999.78 -2,990.11 -1,625.16 5,951,898.46 506,749.26 12.09 -2,467.60 MWD (4) 8,585.66 85.27 301.04 6,128.74 6,002.74 -2,975.31 -1,651.06 5,951,913.22 506,723.35 10.61 -2,446.61 MWD (4) 8,615.61 87.67 303.46 6,130.58 6,004.58 -2,959.36 -1,676.33 5,951,929.14 506,698.06 11.37 -2,424.66 MWD (4) 8,645.55 91.93 305.12 6,130.68 6,004.68 -2,942.50 -1,70106 5,951,945.97 506,673.31 15.27 -2,401.97 MWD (4) 8,67563 95.59 306.24 6,128.71 6,002.71 -2,925.00 -1,725.44 5,951,963.45 506,648.92 12.72 -2,378.75 MWD(4) 8,705.72 99.71 307.71 6,124.71 5,998.71 -2,907.07 -1,749.26 5,951,981.35 506,625.08 14.52 -2,355.27 MWD (4) 8,735.73 101.24 311.70 6,119.25 5,993.25 -2,888.22 -1,771.96 5,952,000.17 506,602.36 14.03 -2,331.19 MWD (4) 8,765.65 100.59 316.08 6,113.58 5,987.58 -2,86786 -1,793.12 5,952,020.51 506,581.18 14.54 -2,306.04 MWD (4) 8,795.64 100.62 320.54 6,108.06 5,982.06 -2,845.85 -1,812.72 5,952,042.49 506,561,56 14.62 -2,279.71 MWD(4) 8,825.73 100.74 324.87 6,102.48 5,976.48 -2,822.33 -1,830.64 5,952,065.98 506,543.62 14.15 -2,252.36 MWD (4) 8,855.69 100.43 328.90 6,096.97 5,970.97 -2,797.67 -1,846.72 5,952,090.62 506,527.51 13.26 -2,224.38 MWD (4) 8,885.62 100.18 333.41 6,091.62 5,965.62 -2,771.89 -1,860.92 5,952,116.39 506,513.28 14.85 -2,195.79 MWD (4) 8,915.67 100.18 336.74 6,086.31 5,960.31 -2,745.07 -1,873.39 5,952,143.19 506,500.79 10.91 -2,16666 MWD (4) 8,945.55 98.56 339.94 6,081.44 5,955.44 -2,717.67 -1,884.26 5,952,170.57 506,489.88 11.88 -2,137.39 MWD (4) 1 8,975.74 95.62 342.79 6,077.71 5,951.71 -2,689.29 -1,893.83 5,952,198.94 506,480.28 13.51 -2,107.49 MWD (4) 9,005.72 92.85 345.78 6,075.50 5,949.50 -2,660.51 -1,901.93 5,952,227.71 506,472.15 13.57 -2,077.60 MWD (4) 9,035.84 92.27 349.55 6,074.15 5,948.15 -2,631.12 -1,908.36 5,952,257.09 506,465.70 12.65 -2,047.55 MWD (4) 9,065.56 92.18 352.71 6,073.00 5,947.00 -2,601.78 -1,912.93 5,952,286.42 506,461.08 10.63 -2,018.03 MWD (4) 1 9,095.85 94.70 356.77 6,071.18 5,945.18 -2,571.69 -1,915.71 5,952,316.51 506,458.28 15.75 -1,988.24 MWD (4) 9,125.65 93.99 0.57 6,068.92 5,942.92 -2,541.98 -1,916.40 5,952,346.21 506,457.56 12.94 -1,959.37 MWD (4) i 9,155.67 93.28 3.84 6,067.02 5,941.02 -2,512.05 -1,915.24 5,952,376.14 506,458.68 11.13 -1,930.75 MWD (4) , 9,185.60 92.03 7.92 6,065.63 5,939.63 -2,482.32 -1,912.18 5,952,405.87 506,461.71 14.24 -1,902.83 MWD (4) 9,215.83 91.81 11.75 6,064.62 5,938.62 -2,452.55 -1907.02 5,952,435.64 506,466.83 12.68 -1,875.41 MWD (4) 9,245.25 92.58 14.87 6,063.49 5,937.49 -2,423.95 -1,900.25 5,952,464.25 505,473.57 10.92 -1,849.53 MWD (4) 9,275.25 91.53 17.33 6,062.42 5,936.42 -2,395.15 -1,891.94 5,952,493.06 506,481.85 8.91 -1,823.86 MWD (4) ,. 9,305.26 89.66 1986. 6,062.10 5,936.10 -2,366.71 -1,882.37 5,952,521.50 506,491.38 10.48 -1,798.87 MWD (4) 11/412016 7:35.:02AM Page 3 COMPASS 5000.1 Build 74 Survey ConocoPhillips FIN ConocoPhillips Definitive Survey Report ANY NES Company: ConocoPhillips (Alaska) Inc. -Kup2 Local Co-ordinate Reference: Well 2B-02 MD Project: Kuparuk River Unit TVD Reference: 2B-02 @ 126.00usft (2B-02) 7VDSS Site: Kuparuk 28 Pad MD Reference: 213-02 @ 126.00usft (2B-02) Easting Well. 28-02 North Reference: True 11 Wellbore: 2B-02 Survey Calculation Method: Minimum Curvature (usft) Design: 28-02 Database: EDM Alaska NSK Sandbox (-M00`) Survey Map Map Vertical MD Inc Azl TVD 7VDSS +N1 -S +Ei•W Northing Easting OLS Section (usft) 11 41 (usft) lusf) (usft) (1401) (-M00`) Survey Tool Name Annolation (rt) (rt) (n) '.. 9,335.19 89.45 23.67 6,062.34 5,936.34 -2,338.92 -1,871.28 5,952,549.30 506,502.45 12.75 -1,774.90 MWD (4) 9,365.22 88.89 26.29 6,062.77 5,936.77 -2,311.70 -1,858.60 5,952,576.53 506,515.09 8.92 -1,751.89 MWD (4) 9,395.21 90.61 30.49 6,062.90 5,936.90 -2,285.33 -1,844.34 5,952,602.92 506,529.32 15.13 -1,730.11 MWD (4) 9,425.35 89.79 33.50 6,062.80 5,936.80 -2,259.77 -1,828.37 5,952,628.49 506,545.26 10.35 -1,709.55 MWD(4) 9,455.33 88.71 36.24 6,063.19 5,937.19 -2,235.18 -1,811.24 5,952,653.10 506,562.36 9.82 -1,690.23 MWD (4) 9,485.16 88.19 39.70 6,064.00 5,938.00 -2,211.67 -1,792.89 5,952,676.62 506,580.68 11.73 -1,672.28 MWD (4) 9,505.51 88.65 42.48 6,064.56 5,938.56 -2,196.34 -1,779.53 5,952,691.97 506,594.03 13.84 -1,660.93 MWD (4) 9,535.24 91.10 47.26 6,064.62 5,938.62 -2,175.28 -1,758.56 5,952,713.05 506,614.97 18.07 -1,646.01 MWD (4) 9,565.19 91.05 50.08 6,064.06 5,938.06 -2,155.51 -1,736.07 5,952,732.85 506,637.43 9.42 -1,632.73 MWD(4) 9,595.24 89.82 48.66 6,063.83 5,937.83 -2,135.94 -1,713.27 5,952,752.44 506,660.21 6.25 -1,619.73 MWD (4) 9,625.37 90.09 45.48 6,063.86 5,937.86 -2,115.42 -1,691.21 5,952,772.98 506,682.24 10.59 -1,605.62 MWD (4) 9,655.28 89.14 40.59 6,064.06 5,938.06 -2,093.57 -1,670.81 5,952,794.85 506,702.62 16.65 -1,589.79 MWD (4) 9,685.21 89.39 36.56 6,064.44 5,938.44 -2,070.17 -1,65215 5,952,818.26 506,721.25 13.49 -1,572.03 MWD (4) 9,715.39 90.46 33.44 6,064.48 5,938.48 -2,045.46 -1,634.84 5,952,843.00 506,738.53 10.93 -1,552.63 MWD(4) 9,750.19 90.46 28.69 6,064.20 5,938.20 -2,015.66 -1,61689 5,952,872.82 506,756.45 13.65 -1,528.49 MWD (4) 9,780.11 90.74 26.52 6,063.89 5,93289 -1,989.15 -1,603.03 5,952,899.34. 506,770.28 7.31 -1,506.47 MWD (4) 9,810.19 90.61 29.15 6,063.53 5,937.53 -1,962.55 -1,588.99 5,952,925.95 506,784.29 8.75 -1,484.42 MWD (4) 9,840.28 93.17 31.07 6,062.54 5,936.54 -1,936.54 -1,573.90 5,952,951.97 506,799.34 10.63 -1,463.20 MWD (4) 9,870.08 9T43 31.91 6,059.79 5,933.79 -1,911.24 -1,558.41 5,952,977.29 506,814.81 14.57 -1,442.77 MWD (4) 9,900.20 101.31 32.63 6,054.89 5,928.89 -1,886.12 -1,542.54 5,953,002.42 506,830.64 13.10 -1,422.61 MWD (4) 9,930.15 101.52 36.66 6,048.96 5,922.96 -1,861.97 -1,525.86 5,953,026.59 506,847.30 13.21 -1,403.60 MWD (4) 9,960.21 101.50 40.59 6,042.96 5,916.96 -1,838.96 -1,507.47 5,953,049.61 506,865.65 12.81 -1,386.14 MWD (4) 9,990.22 101.43 40.76 6,036.99 5,910.99 -1,816.66 -1,488.31 5,953,071.94 506,884.80 0.60 -1,369.55 MWD (4) 10,020.11 101.02 37.85 6,031.17 5,905.17 -1,793.97 -1,469.74 5,953,094.64 506,903.34 9.65 -1,352.45 MWD (4) 10,050.36 100.33 34.43 6,025.57 5,899.57 -1,769.97 -1,452.21 5,953,118.65 506,920.84 11.34 -1,333.80 MWD(4) 10,079.49 100.15 31.95 6,020.39 5,894.39 -1,745.98 -1,436.52 5,953,142.66 506,936.50 8.40 -1,314.69 MWD (4) 10,109.56 100.18 27.98 6,015.08 5,889.08 -1,720.35 -1,421.74 5,953,168.31 506,951.25 13.00 -1,293.75 MWD (4) 10,140.05 100.81 24.21 6,009.52 5,883.52 -1,693.43 -1408.55 5,953,195.24 506,964.40 12.33 -1,271.17 MWD (4) 10,169.94 100.32 22.46 6,004.04 5,878.04 -1,666.45 -1,396.91 5,953,222.23 506,976.01 5.98 -1,248.12 MWD (4) 10,193.77 96.99 21.77 6,000.46 5,874.46 -1,644.63 -1,388.05 5,953,244.06 506,984.85 14.26 -1,229.34 MWD (4) 10,230.00 96.99 21.77 5,996.05 5,870.05 -1,611.23 -1,374.71 5,953,277.47 506,998.15 0.00 -1,200.53 PROJECTED to TO 11/412016 7.,35.02AM Page 4 COMPASS 5000.1 Build 74 BAKER HUGHES To: RECEIVED Nov 0 9 2bio Letter of Transmittal AOGCC Date: DATA LOGGED �� /tI 201r. November 8, 2016 M. K. BENDER Makana Bender AOGCC 333 West 7th Ave, Suite 100 Anchorage, Alaska 99501 From: Yosha Ragbirsingh / Michael Soper Baker Hughes INTEQ 795 East 94th Avenue Anchorage, Alaska 99515 Please find enclosed the directional survey data for the following well(s): 2 160 87 27 70 7 2B-02APBi 2 1 6 0 87 1 7 7 0 61� 2B -02A 2B-02AL1 2 1 6 0 88 27 70 8 2B-02AL1-01 2 1 6 0 89 27 7 0 9 (4) Total prints Enclosed for each well(s): 1 hardcopy print of directional survey reports (NAD27) 1 compact disk containing electronic survey files Note: Please feel free to send us an email in place of return mail. Michael Soper, Baker Hughes, Project Engineer Michael. Soper@BakerHughes.com Yosha Ragbirsingh, Baker Hughes, Survey Manager Yosha.Ragbirsingh@BakerHughes.com s ConocoPhillip 'b ConocoPhillips (Alaska) Inc. -Kup2 Kuparuk River Unit Kuparuk 2B Pad 2 B -02A L 1 50-029-21154-60 Baker Hughes INTEQ Definitive Survey Report 04 November, 2016 16088 X7708 Few BAKER HUGHES �- ConocoPhillips w1fts ConocoPhillips Definitive Survey Report HUGHES Company: ConocoPhillips (Alaska) Inc. -Kup2 Local Co-ordinate Reference: Well 213-02 Project: Kuparuk River Unit TVD Reference: 213-02 @ 126.00usft (213-02) Site: Kuparuk 213 Pad MD Reference: 2B-02 @ 126.00usft (213-02) Well: 213-02 North Reference: True Wellbore: 213-02 Survey Calculation Method: Minimum Curvature Design: 213-02 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 2B-02 Well Position +N/ -S 0.00 usft Northing: 5,954,890.07 usft Latitude: 70° 17' 16.702 N +E/ -W 0.00 usft Easting: 508,370.93 usft Longitude: 149° 55'56.081 W Position Uncertainty 0.00 usft Wellhead Elevation: usft Ground Level: 0.00 usft Wellbore 28-02AL1 Magnetics Model Name Sample Date Declination Dip Angle Field Strength (°) (°) (nT) BGGM2016 10/1/2016 17.90 80.90 57,541 Design 213-02AL1 Audit Notes: Version: 1.0 Phase: ACTUAL Tie On Depth: 8,450.91 z r ( Vertical Section: Depth From (TVD) +N/ -S +E/ -W Direction (usft) (usft) (usft) (°) 126.00 0.00 0.00 345.00 _ Suryey Program .n,�.. .,.--...�m-.... .. .,._., Date 11/1/2016 ..m.�..�.�,-.�.�,..,.,�...�.-v...�=-<s_...�� .............. ....�...,,..�,,_..A,4,�.,�u,.�._�......._..�._y_.., _..,,.mem---.,�-.....-....�..�-�a,-.,<».._-.m�., From To Survey Survey (usft) (usft) Survey (Wellbore) Tool Name Description Start Date End Date 200.00 6,600.00 213-02 (213-02) GCT -MS Schlumberger GCT multishot 1/12/2001 6,640.00 7,560.37 213-02APB1 (213-02APB1) MWD MWD- Standard 10/8/2016 10/15/2016 7,580.00 8,450.91 213-02A (213-02A) MWD MWD - Standard 10/16/2016 10/18/2016 8,465.00 10,193.77 213-02AL1 (213-02AL1) MWD MWD- Standard 10/19/2016 10/22/2016 11/4/2016 7:35:02AM Page 2 COMPASS 5000.1 Build 74 ConocoPhillips I&A &6 ConocoPhillips Definitive Survey Report BHUGHES Company: ConocoPhillips (Alaska) Inc. -Kup2 Project: Kuparuk River Unit Site: Kuparuk 2B Pad Well: 213-02 Wellbore: 213-02 Design: 213-02 Survey Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Database: Well 213-02 ! ) } 213-02 @ 126.00usft (213-02) 213-02 @ 126.00usft (2B-02) True k Minimum Curvature EDM Alaska NSK Sandbox ( Map Vertical Fasting DLS Section Survey Tool Name A t t; (ft) (°1100) (ft) I nn0 a On 506,845.35 11.24 -2,531.77 Map MD Inc Azi ND TVDSS +N/ -S +El -W MWD (4) 506,775.89 11.98 -2,487.38 MWD (4) 506,749.26 12.09 -2,467.60 Northing (usft) (1 (°) (usft) (usft) (usft) (usft) MWD (4) 506,673.31 15.27 -2,401.97 MWD (4) 506,648.92 12.72 -2,378.75 (ft) 8,450.91 90.34 290.81 6,118.71 5,992.71 -3,030.80 -1,529.11 5,951,857.87 8,465.00 89.99 288.96 6,118.67 5,992.67 -3,026.01 -1,542.36 5,951,862.65 8,498.11 85.73 292.14 6,119.91 5,993.91 -3,014.40 -1,573.33 5,951,874.22 8,525.72 83.76 294.81 6,122.44 5,996.44 -3,003.45 -1,598.54 5,951,885.14 8,555.69 83.42 298.44 6,125.78 5,999.78 -2,990.11 -1,625.16 5,951,898.46 8,585.66 85.27 301.04 6,128.74 6,002.74 -2,975.31 -1,651.06 5,951,913.22 8,615.61 87.67 303.46 6,130.58 6,004.58 -2,959.36 -1,676.33 5,951,929.14 8,645.55 91.93 305.12 6,130.68 6,004.68 -2,942.50 -1,701.06 5,951,945.97 8,675.63 95.59 306.24 6,128.71 6,002.71 -2,925.00 -1,725.44 5,951,963.45 8,705.72 99.71 307.71 6,124.71 5,998.71 -2,907.07 -1,749.26 5,951,981.35 8,735.73 101.24 311.70 6,119.25 5,993.25 -2,888.22 -1,771.96 5,952,000.17 8,765.65 100.59 316.08 6,113.58 5,987.58 -2,867.86 -1,793.12 5,952,020.51 8,795.64 100.62 320.54 6,108.06 5,982.06 -2,845.85 -1,812.72 5,952,042.49 8,825.73 100.74 324.87 6,102.48 5,976.48 -2,822.33 -1,830.64 5,952,065.98 8,855.69 100.43 328.90 6,096.97 5,970.97 -2,797.67 -1,846.72 5,952,090.62 8,885.62 100.18 333.41 6,091.62 5,965.62 -2,771.89 -1,860.92 5,952,116.39 8,915.67 100.18 336.74 6,086.31 5,960.31 -2,745.07 -1,873.39 5,952,143.19 8,945.55 98.56 339.94 6,081.44 5,955.44 -2,717.67 -1,884.26 5,952,170.57 8,975.74 95.62 342.79 6,077.71 5,951.71 -2,689.29 -1,893.83 5,952,198.94 9,005.72 92.85 345.78 6,075.50 5,949.50 -2,660.51 -1,901.93 5,952,227.71 9,035.84 92.27 349.55 6,074.15 5,948.15 -2,631.12 -1,908.36 5,952,257.09 9,065.56 92.18 352.71 6,073.00 5,947.00 -2,601.78 -1,912.93 5,952,286.42 9,095.85 94.70 356.77 6,071.18 5,945.18 -2,571.69 -1,915.71 5,952,316.51 9,125.65 93.99 0.57 6,068.92 5,942.92 -2,541.98 -1,916.40 5,952,346.21 9,155.67 93.28 3.84 6,067.02 5,941.02 -2,512.05 -1,915.24 5,952,376.14 9,185.60 92.03 7.92 6,065.63 5,939.63 -2,482.32 -1,912.18 5,952,405.87 9,215.83 91.81 11.75 6,064.62 5,938.62 -2,452.55 -1,907.02 5,952,435.64 9,245.25 92.58 14.87 6,063.49 5,937.49 -2,423.95 -1,900.25 5,952,464.25 9,275.25 91.53 17.33 6,062.42 5,936.42 -2,395.15 -1,891.94 5,952,493.06 9,305.26 89.66 1986. 6,062.10 5,936.10 -2,366.71 -1,882.37 5,952,521.50 Well 213-02 ! ) } 213-02 @ 126.00usft (213-02) 213-02 @ 126.00usft (2B-02) True k Minimum Curvature EDM Alaska NSK Sandbox ( Map Vertical Fasting DLS Section Survey Tool Name A t t; (ft) (°1100) (ft) I nn0 a On 506,845.35 11.24 -2,531.77 MWD (3) TIP 506,832.10 13.36 -2,523.71 MWD (4) KOP 506,801.12 16.05 -2,504.48 MWD (4) 506,775.89 11.98 -2,487.38 MWD (4) 506,749.26 12.09 -2,467.60 MWD (4) 506,723.35 10.61 -2,446.61 MWD (4) 506,698.06 11.37 -2,424.66 MWD (4) 506,673.31 15.27 -2,401.97 MWD (4) 506,648.92 12.72 -2,378.75 MWD (4) 506,625.08 14.52 -2,355.27 MWD (4) 506,602.36 14.03 -2,331.19 MWD (4) 506,581.18 14.54 -2,306.04 MWD (4) 506,561.56 14.62 -2,279.71 MWD (4) 506,543.62 14.15 -2,252.36 MWD (4) 506,527.51 13.26 -2,224.38 MWD (4) 506,513.28 14.85 -2,195.79 MWD (4) 506,500.79 10.91 -2,166.66 MWD (4) 506,489.88 11.88 -2,137.39 MWD (4) 506,480.28 13.51 -2,107.49 MWD (4) 506,472.15 13.57 -2,077.60 MWD (4) 506,465.70 12.65 -2,047.55 MWD (4) 506,461.08 10.63 -2,018.03 MWD (4) 506,458.28 15.75 -1,988.24 MWD (4) 506,457.56 12.94 -1,959.37 MWD (4) 506,458.68 11.13 -1,930.75 MWD (4) 506,461.71 14.24 -1,902.83 MWD (4) 506,466.83 12.68 -1,875.41 MWD (4) 506,473.57 10.92 -1,849.53 MWD (4) 506,481.85 8.91 -1,823.86 MWD (4) 506,491.38 10.48 -1,798.87 MWD (4) 11/4/2016 7:35:02AM Page 3 COMPASS 5000.1 Build 74 ConocoPhillips FICii'd ConocoPhillips Definitive Survey Report BAKER Company: ConocoPhillips (Alaska) Inc. -Kup2 Project: Kuparuk River Unit Site: Kuparuk 26 Pad Well: 26-02 Wellbore: 2B-02 Design: 2B-02 Survey Local Co-ordinate Reference: Well 213-02 TVD Reference: 213-02 @ 126.00usft (2B-02) MD Reference: 213-02 @ 126.00usft (2B-02) North Reference: True Survey Calculation Method: Minimum Curvature Vertical Database: EDM Alaska NSK Sandbox MD Inc Azi TVD TVDSS +N/ -S +E/ -W Map Map DLS Vertical (usft) (°) (°) (usft) (usft) (usft) (usft) Northing Easting (°1100') Section Survey Tool Name Annotation (ft) (ft) (ft) 9,335.19 89.45 23.67 6,062.34 5,936.34 -2,338.92 -1,871.28 5,952,549.30 506,502.45 12.75 -1,774.90 MWD (4) 9,365.22 88.89 26.29 6,062.77 5,936.77 -2,311.70 -1,858.60 5,952,576.53 506,515.09 8.92 -1,751.89 MWD (4) 9,395,21 90.61 30.49 6,062.90 5,936.90 -2,285.33 -1,844.34 5,952,602.92 506,529.32 15.13 -1,730.11 MWD (4) 9,425.35 89.79 33.50 6,062.80 5,936.80 -2,259.77 -1,828.37 5,952,628.49 506,545.26 10.35 -1,709.55 MWD (4) 9,455.33 88.71 36.24 6,063.19 5,937.19 -2,235.18 -1,811.24 5,952,653.10 506,562.36 9.82 -1,690.23 MWD (4) 9,485.16 88.19 39.70 6,064.00 5,938.00 -2,211.67 -1,792.89 5,952,676.62 506,580.68 11.73 -1,672.28 MWD (4) 9,505.51 88.65 42.48 6,064.56 5,938.56 -2,196.34 -1,779.53 5,952,691.97 506,594.03 13.84 -1,660.93 MWD (4) 9,535.24 91.10 47.26 6,064.62 5,938.62 -2,175.28 -1,758.56 5,952,713.05 506,614.97 18.07 -1,646.01 MWD (4) 9,565.19 91.05 50.08 6,064.06 5,938.06 -2,155.51 -1,736.07 5,952,732.85 506,637.43 9.42 -1,632.73 MWD (4) 9,595.24 89.82 48.66 6,063.83 5,937.83 -2,135.94 -1,713.27 5,952,752.44 506,660.21 6.25 -1,619.73 MWD (4) 9,625.37 90.09 45.48 6,063.86 5,937.86 -2,115.42 -1,691.21 5,952,772.98 506,682.24 10.59 -1,605.62 MWD (4) 9,655.28 89.14 40.59 6,064.06 5,938.06 -2,093.57 -1,670.81 5,952,794.85 506,702.62 16.65 -1,589.79 MWD (4) 9,685.21 89.39 36.56 6,064.44 5,938.44 -2,070.17 -1,652.15 5,952,818.26 506,721.25 13.49 -1,572.03 MWD (4) 9,715.39 90.46 33.44 6,064.48 5,938.48 -2,045.46 -1,634.84 5,952,843.00 506,738.53 10.93 -1,552.63 MWD (4) 9,750.19 90.46 28.69 6,064.20 5,938.20 -2,015.66 -1,616.89 5,952,872.82 506,756.45 13.65 -1,528.49 MWD (4) 9,780.11 90.74 26.52 6,063.89 5,937.89 -1,989.15 -1,603.03 5,952,899.34 506,770.28 7.31 -1,506.47 MWD (4) 9,810.19 90.61 29.15 6,063.53 5,937.53 -1,962.55 -1,588.99 5,952,925.95 506,784.29 8.75 -1,484.42 MWD (4) 9,840.28 93.17 31.07 6,062.54 5,936.54 -1,936.54 -1,573.90 5,952,951.97 506,799.34 10.63 -1,463.20 MWD (4) 9,870.08 97.43 31.91 6,059.79 5,933.79 -1,911.24 -1,558.41 5,952,977.29 506,814.81 14.57 -1,442.77 MWD (4) 9,900.20 101.31 32.63 6,054.89 5,928.89 -1,886.12 -1,542.54 5,953,002.42 506,830.64 13.10 -1,422.61 MWD (4) 9,930.15 101.52 36.66 6,048.96 5,922.96 -1,861.97 -1,525.86 5,953,026.59 506,847.30 13.21 -1,403.60 MWD (4) 9,960.21 101.50 40.59 6,042.96 5,916.96 -1,838.96 -1,507.47 5,953,049.61 506,865.65 12.81 -1,386.14 MWD (4) 9,990.22 101.43 40.76 6,036.99 5,910.99 -1,816.66 -1,488.31 5,953,071.94 506,884.80 0.60 -1,369.55 MWD (4) 10,020.11 101.02 37.85 6,031.17 5,905.17 -1,793.97 -1,469.74 5,953,094.64 506,903.34 9.65 -1,352.45 MWD (4) 10,050.36 100.33 34.43 6,025.57 5,899.57 -1,769.97 -1,452.21 5,953,118.66 506,920.84 11.34 -1,333.80 MWD (4) 10,079.49 100.15 31.95 6,020.39 5,894.39 -1,745.98 -1,436.52 5,953,142.66 506,936.50 8.40 -1,314.69 MWD (4) 10,109.56 100.18 27.98 6,015.08 5,889.08 -1,720.35 -1,421.74 5,953,168.31 506,951.25 13.00 -1,293.75 MWD (4) 10,140.05 100.81 24.21 6,009.52 5,883.52 -1,693.43 -1,408.55 5,953,195.24 506,964.40 12.33 -1,271.17 MWD (4) 10,169.94 100.32 22.46 6,004.04 5,878.04 -1,666.45 -1,396.91 5,953,222.23 506,976.01 5.98 -1,248.12 MWD (4) 10,193.77 96.99 21.77 6,000.46 5,874.46 -1,644.63 -1,388.05 5,953,244.06 506,984.85 14.26 -1,229.34 MWD (4) 10,230.00 96.99 21.77 5,996.05 5,870.05 -1,611.23 -1,374.71 5,953,277.47 506,998.15 0.00 -1,200.53 PROJECTED to TD 11/4/2016 7:35:02AM Page 4 COMPASS 5000.1 Build 74 THE STATE 01ALASKA GOVERNOR BILL WALKER Jason Burke CTD Coordinator ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510-0360 Alaska Oil and Gas Conservation Commission 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 213-02AL1 ConocoPhillips Alaska, Inc. Permit to Drill Number: 216-088 Surface Location: 744' FSL, 273' FEL, SEC. 19, TI IN, R9E, UM Bottomhole Location: 4685' FSL, 1617' FEL, SEC. 30, TI IN, R9E, UM Dear Mr. Burke: Enclosed is the approved application for permit to re -drill the above referenced development well. The permit is for a new wellbore segment of existing well Permit No. 216-087, API No. 50-029- 21154-01-00. Production should continue to be reported as a function of the original API number stated above. This permit to drill does not exempt you from obtaining additional permits or an approval required by law from other governmental agencies and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the AOGCC reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the AOGCC specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or an AOGCC order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. Sincerely, Cathy P Foerster Chair DATED this Ody of August, 2016. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 AAC 25.005 .h RECEIVED JUL 13 2016 1 a. Type of Work: 1 b. Proposed Well Class: Exploratory -Gas Drill ❑ Lateral l'J Stratigraphic Test ❑ Development - Oil ❑ Service - WAG ❑ Service - Disp ❑✓ Service - Winj ❑ Single Zone 1 c. Specify if well is proposed for: Coalbed Gas ❑ Gas Hydrates ❑ Redrill [ Reentry ❑ Exploratory - Oil ❑ Development - Gas ❑ Service - Supply ❑ Multiple Zone I I Geothermal ❑ Shale Gas ❑ 2. Operator Name: 5. Bond: Blanket ❑ •- Single Well ❑ 11. Well Name and Number: ConocoPhillips Alaska Inc Bond No. 5952180 2B-02AL1 3. Address: 6. Proposed Depth: 12. Field/Pool(s): P.O. Box 100360 Anchorage, AK 99510-0360 MD: 10425, TVD: 6025 Kuparuk River Field ! Kuparuk Oil Pool 42. Location of Well (Governmental Section): 7. Property Designation (Lease Number): Surface: 744' FSL, 273' FEL, Sec 19, T11 N, R9E, UM ADL 25656 SJ 8. Land Use Permit: 13. Approximate Spud Date: Top of Productive Horizon: 3009' FSL, 1875' FEL, Sec 30, T11 N, R9E, UM ALK 2582 9/15/2016 Total Depth: 4685' FSL, 1617' FEL, Sec 30, T1 IN, R9E, UM 9. Acres in Property: ,ft 2560 aJ.+13O 14. Distance to Nearest Property: 18900' 4b. Location of Well (State Base Plane Coordinates - NAD 27): 10. KB Elevation above MSL (ft): a(Q 3W7W 15. Distance to Nearest Well Open Surface: x-508371 y-5954890 Zone- 4 • GL Elevation above MSL (ft): 92' to Same Pool: 1580' (213-08) 16. Deviated wells: Kickoff depth: 8385 feet 17. Maximum Potential Pressures in psig (see 20 AAC 25.035) Maximum Hole Angle: 101 degrees Downhole: 3973 psi • Surface: 3369 psi 18. Casing Program: Specifications Top - Setting Depth - Bottom Cement Quantity, c.f. or sacks Hole Casing Weight Grade Coupling I Length MD TVD MD TVD (including stage data) 3" 2-3/8" 4.7# L-80 ST -L 1925' 8500' 6119' 10425' 6025' N/A 19. PRESENT WELL CONDITION SUMMARY (To be completed for Redrill and Re -Entry Operations) Total Depth MD (ft): Total Depth TVD (ft): Plugs (measured): Effect. Depth MD (ft): Effect. Depth TVD (ft): Junk (measured): 6976 6322 N/A 6851 6216 Fish - 6685' MD Casing Length Size Cement Volume MD TVD Conductor/Structural 110' 16" 119 sx Cold Set II 110' 110' Surface 2727' 9.625" 800 sx Cold Set III, 300 sx Cold Set II 2727' 2727' Intermediate Production 6934' 7" 280 sx Class G, 250 sx Cold Set 1 6934' 6287' Liner Perforation Depth MD (ft): 6526'-6568', Perforation Depth TVD (ft): 5943'-5978', 6022'-6098' 6620'-6710' 20. Attachments: Property Plat ❑ BOP Sketch ❑ Drilling Program Q Time v. Depth Plot ❑ Shallow Hazard Analysis❑ Diverter Sketch ❑ Seabed Report ❑ Drilling Fluid Program Q 20 AAC 25.050 requirements0 21. Verbal Approval: Commission Representative: 7 Date 22. 1 hereby certify that the foregoing is true and the procedure approved be deviated from without prior written approval. herein will not Mike Callahan 263-4180 Contact mike.callahanCakovcom Email Printed Name Jason Burke Title CTD Coordinator Signature Phone 265-6097 Date Commission Use Only Permit to Drill p� Number: a 160 - OW API Number: 50- © _ -�� Permit ApprovalSee Date: \� ,lQ cover letter for other requirements. Conditions of approval : If box is checked, well may not be used to explore for, test, or produce coalbed methane, gas hydrates, or gas contained in shales: Other: t to 3 -f SO r5 r Samples req'd: Yes E]NoLd Mud log req'd: Yes ❑ NoW ��/t Z 5 U p P51 HzS measures: Yes Z No L1 Directional svy req'd: Yes ❑ ff (-�✓avGAr i �G✓Cl2fL No /4 Vari'cyhC� fo 2bA✓4C 2S.dIS(b) [� Spacin exception req'd: Yes ❑ No� Inclination -only svy req'd: Yes L] N.Z /-5 q t-ct V ted -� a 11 o w f� C IC 1 C (C o f� j� 0 1 ti f fo Post initial injection MIT req'd: Yes ❑ No J C n o #`vt-i a) o vt L� t y p � pa>rr 1,tlafir.��I. Approved by: APPROVED BY COMMISSIONER THE COMMISSION Date: rc 8/i S/ / & Submit Form and Form 10 401vised 11/2015) This permit is v lid for 24 months from the date of approval (20 AAC 25.005(g)) Attachments in Duplicate ORIGINAL ��`b��'� ConocoPhillips p Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 July 13, 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 5 laterals out of the Kuparuk Well 213-02 using the coiled tubing drilling rig, Nabors CDR2-AC or CDR3-AC. To account for geological uncertainties, ConocoPhillips requests a variance from the requirements of 20 AAC 25.015 to allow the actual kick-off point to be anywhere along the length of the parent lateral instead of being limited to 500' from the original point. A sundry application is attached to plug the KRU 213-02 (184-122) perforations to allow these laterals to be drilled. As detailed in the attachments, ConocoPhillips requests a variance from the requirements of 20 AAC 25.112(c)(1) to plug the A/C -sand perforations in 213-02. Attached to this application are the following documents: — 10-403 Sundry Application to Abandon KRU 213-02 (184-122) — Operations Summary in support of the 10-403 sundry application — 10-401 Applications for 213-02A, 213-02AL1, 213-02AL1-01, 213-02AL1-02, and 213-02AL2 — Detailed Summary of Operations — Directional Plans for 213-02A, 213-02AL1, 213-02AL1-01, 213-02AL1-02, and 213-02AL2 — Proposed CTD Schematic If you have any questions or require additional information, please contact me at 907-263-4180. Sincerely, Mike Callahan ConocoPhillips Alaska Coiled Tubing Drilling Engineer Kuparuk CTD Laterals NABOBS ALASKA 213-02A, AL1, AL1 -01, AL2 & AL2 -01 CD, Application for Permit to Drill Document 2AC 1. Well Name and Classification...........................................................................................................2 (Requirements of 20 AAC 25.005(f) and 20 AAC 25.005(b))...................................................................................................................... 2 2. Location Summary.............................................................................................................................2 (Requirements of 20 AAC 25.005(c)(2))...................................................................................................................................................... 2 3. Blowout Prevention Equipment Information...................................................................................2 (Requirements of 20 AAC 25.005(c)(3))..................................................................................................................................................... 2 4. Drilling Hazards Information and Reservoir Pressure....................................................................2 (Requirements of 20 AAC 25.005(c)(4))..................................................................................................................................................... 2 5. Procedure for Conducting Formation Integrity tests.....................................................................2 (Requirements of 20 AAC 25.005(c)(5))...................................................................................................................................................... 2 6. Casing and Cementing Program......................................................................................................3 (Requirements of 20 AAC 25.005(c)(6))...................................................................................................................................................... 3 7. Diverter System Information.............................................................................................................3 (Requirements of 20 AAC 25.005(c)(7))...................................................................................................................................................... 3 8. Drilling Fluids Program.....................................................................................................................3 (Requirements of 20 AAC 25.005(c)(8))...................................................................................................................................................... 3 9. Abnormally Pressured Formation Information...............................................................................4 (Requirements of 20 AAC 25.005(c)(9))......................................................................................................................................................4 10. Seismic Analysis................................................................................................................................4 (Requirements of 20 AAC 25.005(c)(10)).................................................................................................................................................... 4 11. Seabed Condition Analysis...............................................................................................................4 (Requirements of 20 AAC 25.005(c)(11)). ................................................................................................................................................... 4 12. Evidence of Bonding.........................................................................................................................4 (Requirements of 20 AAC 25.005(c)(12)).................................................................................................................................................... 4 13. Proposed Drilling Program...............................................................................................................4 (Requirements of 20 AAC 25.005(c)(13)).................................................................................................................................................... 4 Summaryof Operations.................................................................................................................................................. 4 LinerRunning.................................................................................................................................................................. 6 14. Disposal of Drilling Mud and Cuttings.............................................................................................7 (Requirements of 20 AAC 25.005(c)(14)).................................................................................................................................................... 7 15. Directional Plans for Intentionally Deviated Wells..........................................................................7 (Requirements of 20 AAC 25.050(b)).......................................................................................................................................................... 7 16. Attachments.......................................................................................................................................7 Attachment 1: Directional Plans for 213-02A, AL1, AL1 -01, AL12 & AL2 -01 laterals....................................................... 7 Attachment 2: Current Well Schematic for 2B-02.. .................................................. ...... . ........................................... 7 Attachment 3: Proposed Well Schematic for 26-02A, AL1, AL1 -01, AL2 & AL2 -01 laterals ........................................... 7 Page 1 of 7 July 13, 2016 PTD Application: 213-02A, AL1, AL1 -01, AL2 & AL2 -01 1. Well Name and Classification (Requirements of 20 AAC 25.005(f) and 20 AAC 25.005(b)) The proposed laterals described in this document are 213-02A, 213-02AL1, 213-02AL1-01, 213-02AL2, & 213- 02AL2-01. All laterals will be classified as Production wells. 2. Location Summary (Requirements of 20 AAC 25.005(c)(2)) These laterals will target the A sand package in the Kuparuk reservoir. See attached 10-401 form for surface and subsurface coordinates of the 213-02A, 213-02AL1, 26-02AL1-01, 26-02AL2, & 213-02AL2-01. 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 3750 psi. Using the maximum formation pressure in the area of 3973 psi in 213-08 (12.6 ppg EMW), the maximum potential surface pressure in 213-02, assuming a gas gradient of 0.1 psi/ft, would be 3369 psi. v'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 26-02 was measured to be 2142 psi (6.9 ppg EMW) on 5/7/2016. The maximum downhole pressure in the 213-02 vicinity is to the west in the 213-08 injector at 3973 psi (12.6 ppg EMW) from March of 2014. Pressure management in the area is expected to bring the formation pressure down to —11.0 ppg by the time of drilling. Potential Gas Zones (Requirements of 20 AAC 25.005 (c)(4)(b)) Wells on 213 pad have injected gas, so there is a chance of encountering free gas while drilling the 213-02 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 213-02 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 213-02 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 13, 2016 PTD Application: 213-02A, AL1, AL1 -01, AL2 & AL2 -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 2B -02A 8385' 9900' 5993' 5969' 2-3/8", 4.7#, L-80, ST -L slotted liner; 0' 110' 1640 670 Surface aluminum billet on top 26-02AL1 8500' 10425' 5981' 5899' 2-3/8", 4.7#, L-80, ST -L slotted liner; 2727' 3620 2020 Production 7" aluminum billet on to 2B-02AL1-01 6630' 9800' 5871' 5989' 2-3/8", 4.7#, L-80, ST -L slotted liner,- iner;de 4980 4320 Tubing 3-1/2" 9.3 deployment to ment sleeve on to 2B-02AL2 8300' 9900' 5997' 5965' 2-3/8", 4.7#, L-80, ST -L slotted liner; 7400 aluminum billet on to 2B-02AL2-01 6600' 10500' 5879' 5896' 2-3/8", 4.7#, L-80, ST -L slotted liner; de to ment sleeve on to 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' 110' 0' 110' 1640 670 Surface 9-5/8" 36.0 J-55 BTC 0' 2727' 0' 2727' 3620 2020 Production 7" 26.0 J-55 BTC 0' 6934' 0' 6287' 4980 4320 Tubing 3-1/2" 9.3 J-55 EUE-8rd 0 6616' 0 6019' 6980 7400 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 FloPro mud (8.6 ppg). This mud weight will not hydrostatically overbalance the reservoir pressure, overbalanced conditions will be maintained using MPD practices described below. — Completion operations: The well will be loaded with 11.8 ppg NaBr completion fluid (unless unexpected, higher pressure is encountered, in which case higher density NaBr or potassium formate will be used) in order to provide formation over -balance and well bore stability while running completions. Managed Pressure Drilling Practice Managed pressure drilling (MPD) techniques will be employed to maintain a constant overbalanced pressure on the open hole formation and promote wellbore stability throughout the coiled tubing drilling (CTD) process. Mud weight is not, in many cases, the primary well control barrier. This is satisfied with the 5,000 psi rated coiled tubing pack off and MPD choke. BOPE equipment provides the secondary well control as detailed in section 3 "Blowout Prevention Equipment Information". In the 213-02 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 Page 3 of 7 July 13, 2016 PTD Application: 2B -02A, AL1, AL1 -01, AL2 & AL2 -01 increased reservoir pressure is encountered. Additional choke pressure or increased mud weight may also be employed for improved borehole stability. Any change of circulating friction pressure due to change in pump rates or change in depth of circulation will be offset with back pressure adjustments. Pressure at the 2B-02 Window (6640' MD, 6039' TVD) Usinq MPD 9. Abnormally Pressured Formation Information (Requirements of 20 AAC 25.005(c)(9)) N/A - Application is not for an exploratory or stratigraphic test well. 10. Seismic Analysis (Requirements of 20 AAC 25.005(c)(10)) N/A - Application is not for an exploratory or stratigraphic test well. 11. Seabed Condition Analysis (Requirements of 20 AAC 25.005(c)(11)) N/A - Application is for a land based well. 12. Evidence of Bonding (Requirements of 20 AAC 25.005(c)(12)) Evidence of bonding for ConocoPhillips Alaska, Inc. is on file with the Commission. 13. Proposed Drilling Program (Requirements of 20 AAC 25.005(c)(13)) Summary of Operations Background KRU well 213-02 is a Kuparuk A/C -sand producer equipped with 3-1/2" tubing and 7" production casing. The CTD sidetrack will utilize up to five laterals to target the A3/A4 sands to the north and south of 213-02. Prior to CTD operations, E -Line will punch 2' of holes in the 3-1/2" tubing tail at 6609' MD and the `D" nipple at 661 V MD will be milled out to a 2.80" ID. The existing C -Sand perforations will be squeezed with cement to abandon the C -Sand. A second cement job will then be performed to cover the A -Sand perfs and provide the cement pilot hole for the kick -out of the 7" casing. ConocoPhillips requests a variance from the requirements of 20 AAC 25.112(c)(1) to plug the A -sand and C -sand perforations in this manner. Following the cement squeeze Nabors CDR2-AC will drill a pilot hole to 6650' MD and set a mechanical whip -stock in the 2.80" pilot hole to kick off at 6640' MD. All five laterals will be completed with 2-3/8" slotted liner from TD with the last lateral liner top located inside the 3-1/2" tubing tail. Page 4 of 7 July 13, 2016 Pumps On (1.5 bpm) Pumps Off A -sand Formation Pressure (6.9 pp) 2158 psi 2158 psi Mud Hydrostatic (8.6 pp) 2701 psi 2701 psi Annular friction i.e. ECD, 0.090 psi/ft) 598 psi 0 psi Mud + ECD Combined no chokepressure) 3299 psi 2701 psi Target BNP at Window 11.8 3706 psi 3706 psi Choke Pressure Required to Maintain Target BHP 407 psi 1005 psi 9. Abnormally Pressured Formation Information (Requirements of 20 AAC 25.005(c)(9)) N/A - Application is not for an exploratory or stratigraphic test well. 10. Seismic Analysis (Requirements of 20 AAC 25.005(c)(10)) N/A - Application is not for an exploratory or stratigraphic test well. 11. Seabed Condition Analysis (Requirements of 20 AAC 25.005(c)(11)) N/A - Application is for a land based well. 12. Evidence of Bonding (Requirements of 20 AAC 25.005(c)(12)) Evidence of bonding for ConocoPhillips Alaska, Inc. is on file with the Commission. 13. Proposed Drilling Program (Requirements of 20 AAC 25.005(c)(13)) Summary of Operations Background KRU well 213-02 is a Kuparuk A/C -sand producer equipped with 3-1/2" tubing and 7" production casing. The CTD sidetrack will utilize up to five laterals to target the A3/A4 sands to the north and south of 213-02. Prior to CTD operations, E -Line will punch 2' of holes in the 3-1/2" tubing tail at 6609' MD and the `D" nipple at 661 V MD will be milled out to a 2.80" ID. The existing C -Sand perforations will be squeezed with cement to abandon the C -Sand. A second cement job will then be performed to cover the A -Sand perfs and provide the cement pilot hole for the kick -out of the 7" casing. ConocoPhillips requests a variance from the requirements of 20 AAC 25.112(c)(1) to plug the A -sand and C -sand perforations in this manner. Following the cement squeeze Nabors CDR2-AC will drill a pilot hole to 6650' MD and set a mechanical whip -stock in the 2.80" pilot hole to kick off at 6640' MD. All five laterals will be completed with 2-3/8" slotted liner from TD with the last lateral liner top located inside the 3-1/2" tubing tail. Page 4 of 7 July 13, 2016 PTD Application: 2B -02A, AL1, AL1 -01, AL2 & AL2 -01 213-02A southern lateral will exit the cement pilot hole at 6640' MD and TD at 9900' MD, targeting the A4 and A3 Sands. It will be completed with 2-3/8" slotted liner from TD up to 8385'MD with an aluminum billet for kicking off the 213-02AL1. The 213-02AL 1 lateral will kickoff of the aluminum billet at 8385' and drill to the north to a TD of 10425' MD targeting the A4 Sand. It will be completed with 2-3/8" slotted liner from TD up to 8500' MD with an anchored billet for kicking off the 213-02AL1-01. The 213-02AL 1-01 lateral will kickoff the anchored billet at 8500' and drill to the north to a TD of 9800' MD, targeting the A3 Sand. It will be completed with 2-3/8" slotted liner from TD back into the cement pilot hole with a deployment sleeve. The 213-02AL2 lateral will exit the cement pilot hole at 6630' and drill to the south to a TD of 9900' MD. It will be completed with 2-3/8" slotted liner from TD up to 8300' MD with an anchored billet for kicking off the 2B-02AL2-01. The 2B-02AL2-01 lateral will kickoff the anchored billet at 8300' and drill to the north to a TD of 10500' MD. It will be completed with 2-3/8" slotted liner from TD back into the 3-1/2" tubing tail with a deployment sleeve. Pre -CTD Work 1. RU Slickline: Obtain SBHP, dummy off gas lift mandrels, and pressure test. 2. RU E -line: Punch 2' of holes in the 3'/2" tubing tail at 6609' MD. 3. RU Pumping Unit: perform injectivity test down the tubing. 4. RU Service Coil: Mill out "D" nipple and cement squeeze the C -sand perforations. Wait on cement for 72 hours. 5. RU Service Coil: Cement squeeze A -Sand perforations and leave plug for cement pilot hole. 6. RU Slick -line: Tag top of cement and pressure test cement. 7. Prep site for Nabors CDR2-AC and set BPV. W14 Work 1. MIRU Nabors CDR2-AC rig using 2" coil tubing. NU 7-1/16" BOPE, test. 2. 213-02A Sidetrack (A3/A4 Sands - South) i. Drill 2.80" high -side pilot hole through cement to 6670' MD ii. Caliper pilot hole iii. Set top of whip -stock at 6640' MD iv. Mill 2.80" window at 6640' MD. v. Drill 3" bi-center lateral to TD of 9900' MD. vi. Run 23/8" slotted liner with an aluminum billet from TD up to 8385' MD. 3. 213-02AL1 Lateral (A4 Sand - North) i. Kickoff of the aluminum billet at 8385' MD. ii. Drill 3" bi-center lateral to TD of 10425' MD. iii. Run 23/8" slotted liner with anchored billet from TD up to 8500' MD. Page 5 of 7 July 13, 2016 PTD Application: 2B -02A, AL1, AL1 -01, AL2 & AL2 -01 4. 213-02AL1-01 Lateral (A3 Sand - North) i. Kick off of the aluminum billet at 8500' MD. ii. Drill 3" bi-center lateral to TD of 9800' MD. iii. Run 2%" slotted liner with deployment sleeve from TD up to 6635' MD. 5. 213-02AL2 Lateral (A3/A4 Sand -South) i. Set top of whipstock at 6630' MD. ii. Mill 2.80" window at 6630' MD iii. Drill 3" bi-center lateral to TD of 9900' MD. iv. Run 2'/8" slotted liner with anchored billet from TD up to 8300' MD. 6. 2B-02AL2-01 Lateral (A3/A4 Sand - North) i. Kick off of the aluminum billet at 8300' MD. ii. Drill 3" bi-center lateral to TD of 10500' MD. iii. Run 2V slotted liner with deployment sleeve from TD up to 6600' MD. 7. Freeze protect, set BPV, ND BOPE, and RDMO Nabors CRD2-AC. Post -Rig Work 1. Pull BPV 2. Obtain SBHP 3. Install gas lift design 4. Return to production Pressure Deployment of BHA The planned bottom hole assemblies (BHAs) are too long to simply isolate by closing the double swab valves on the Christmas tree. MPD operations require the BHA to be lubricated under pressure using a system of double swab valves on the Christmas tree, double deployment rams, double check valves and double ball valves in the BHA, and a slick -line lubricator can be used. This pressure control equipment listed ensures there are always two barriers to reservoir pressure, both internal and external to the BHA, during the deployment process. During BHA deployment, the following steps are observed. — Initially the double swab valves on the tree are closed to isolate reservoir pressure. The lubricator is installed on the BOP riser with the BHA inside the lubricator. — Pressure is applied to the lubricator to equalize across the swab valves. The swab valves are opened and the BHA is lowered in place via slick -line. — When the BHA is spaced out properly, the double deployment rams are closed on the BHA to isolate reservoir pressure via the annulus. A closed set of double ball valves and double check valves isolate reservoir pressure internal to the BHA. Slips on the double deployment rams prevent the BHA from moving when differential pressure is applied. The lubricator is removed once pressure is bled off above the deployment rams. — The coiled tubing is made up to the BHA with the double ball valves plus the double check valves in the closed position. Pressure is applied to the coiled tubing to equalize internal pressure and then the double ball valves are opened. The injector head is made up to the riser, annular pressure is equalized, and the deployment rams are opened. The BHA and coiled tubing are now ready to run in the hole. During BHA undeployment, the steps listed above are observed, only in reverse. Liner Running — The 2B-02 laterals will be displaced to an overbalancing fluid (11.8 ppg NaBr) prior to running liner. See "Drilling Fluids" section for more details. Page 6 of 7 July 13, 2016 PTD Application: 213-02A, AL1, AL1 -01, AL2 & AL2 -01 — While running 2-3/8" slotted liner, a joint of 2-3/8" non -slotted tubing will be standing by for emergency deployment. A floor valve is made up onto this joint ahead of time, and the rig crew conducts a deployment drill with this emergency joint on every slotted liner run. The 2-3/8" rams will provide secondary well control while running 2-3/8" liner. 14. Disposal of Drilling Mud and Cuttings (Requirements of 20 AAC 25.005(c)(14)) • No annular injection on this well. f • All solid waste will be transported to the grind and inject facility at DS -4 Prudhoe Bay for disposal. • Incidental fluids generated from drilling operations will be injected in a Kuparuk Class II disposal well (1 R-18 or 1 B disposal facilities) or Prudhoe DS -4 if a Kuparuk facility is unavailable. • All wastes and waste fluids hauled from the pad must be properly documented and manifested. • Contact Kuparuk Environmental Coordinator for questions regarding waste classification. (670-4200). 15. Directional Plans for Intentionally Deviated Wells (Requirements of 20 AAC 25.050(b)) — 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 2B -02A 18000' 2B-02AL1 18900' 2B-02AL1-01 18900' 2B-02AL2 18000' 213-02AL2-01 18900' — Distance to Nearest Well within Pool Lateral Name Distance_- Well 2B -02A 950' 213-07 2B-02AL1 1580' 213-08 2B-02AL1-01 1475' 213-08 2B-02AL2 950' 213-07 2B-02AL2-01 1465' 213-08 16.Attachments Attachment 1: Directional Plans for 2B -02A, AL 1, AL 1-01, AL2 & AL2 -01 laterals Attachment 2: Current Well Schematic for 2B-02 Attachment 3: Proposed Well Schematic for 2B -02A, AL 1, AL 1-01, AL2 & AL2 -01 laterals Page 7 of 7 July 13, 2016 Proposed 2B-02 CTD Schematic 16" 62# H-40 shoe @ 110' '40# J-55 @ 2727' P C -sand perfs (sqz'd) 6,526' - 6,568' MD 6,586' - 6,588' MD 3-1/2" 9.3# L-80 ELIE 8rd Tubing to surface 3-1/2" Otis FMX SSSV at 1812' RKB (locked out 4/98) 3-1/2" Cameo gas lift mandrels @ 1,929', 3,478', 4,837', 5,864', 6,325' RKB Camco OEJ-10 SBR @ 6,359' RKB (2.973" min ID) Camco HRP -1 -SP Retrievable Packer @ 6,377' RKB Blast Rings @ 6,489' RKB 3-1/2" Cameo production mandrels @ 6,415', 6,483', 6582' RKB Baker Locator Assembly @ 6,599' RKB Baker FB -1 packer @ 6,599' RKB (4.0" ID) Baker SBE @ 6,602' RKB Tubing tail perfs at 6609' MD 3-1/2" Cameo DS nipple @ 6,611' MD (2.75" ID) Milled out to 2.80" ID pre -CTD Camco SOS @ 6,615' RKB 2B-02AL2-01 wp01 TD @ 10,425' MD KOP @ 6640' MD Lat#5 2B-02AL2 wp02 TD @ 9,900' MD �......- Lat#4 Liner Billet 8300' MD �Ipt Lat #2 A -sand perfs (sgz'd) ------------ 6,620'- _ ,_ ;.�-- 6,620'- 6.710' MD TD @ 10,425' MD ,Liner Billet @ B500 -MD "� i Lat #3 -- -" ---' _ — • 2B-02AL1-01 wp02.+ - TD @ 9,800' MD - - -. - -- ---- 7" 26# J-55 shoe 26-02A wp05 I @ 6934' MD TD @ 9,900 MD Lat #1 ConocoPhillips ConocoPhillips (Alaska) Inc. -Kup2 Kuparuk River Unit Kuparuk 213 Pad 2B-02 2B-02AL1 Plan: 2B-02AL1_wp02 Standard Planning Report 11 July, 2016 A," -- BAKER HUGHES ConocoPhillips Database: EDM Alaska NSK Sandbox Company: ConocoPhillips (Alaska) Inc. -Kup2 Project: Kuparuk River Unit Site: Kuparuk 2B Pad Well: 213-02 Wellbore: 2B-02AL1 Design: 2 B-02AL 1 _wp02 ConocoPhillips Planning Report Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Well 26-02 Mean Sea Level 2B-02 @ 126.00usft (213-02) 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.s RAKER HUGHES Site Kuparuk 2B Pad Site Position: Northing: 5,954,944.68 usft Latitude: 700 17' 17.239 N From: Map Easting: 508,346.10 usft Longitude: 149° 55 56.803 W Position Uncertainty: 0.00 usft Slot Radius: 0.000 in Grid Convergence: 0.06 ° 5,954,890.07 usft Latitude: 508,370.93 usft Longitude: usft Ground Level: Declination Dip Angle 17.90 80.90 Design 2B-02AL1_wp02 Audit Notes: Version: Phase: PLAN Tie On Depth Vertical Section: Depth From (TVD) +N/ -S +E/ -W (usft) (usft) (usft) 0.00 0.00 0.00 Plan Sections 70° 17' 16.702 N 1490 55' 56.081 W 0.00 usft Field Strength (nT) - 57,541 8.385.00 Direction (°) 345.00 Measured Well 2B-02 Well Position +N/ -S 0.00 usft Northing: +E/ -W 0.00 usft Easting: Position Uncertainty 0.00 usft Wellhead Elevation: +E/ -W Rate Rate Wellbore 2B-02AL1 (usft) Magnetics Model Name Sample Date (usft) BGGM2016 10/1/2016 (°/100ft) (°/100ft) (°) 5,954,890.07 usft Latitude: 508,370.93 usft Longitude: usft Ground Level: Declination Dip Angle 17.90 80.90 Design 2B-02AL1_wp02 Audit Notes: Version: Phase: PLAN Tie On Depth Vertical Section: Depth From (TVD) +N/ -S +E/ -W (usft) (usft) (usft) 0.00 0.00 0.00 Plan Sections 70° 17' 16.702 N 1490 55' 56.081 W 0.00 usft Field Strength (nT) - 57,541 8.385.00 Direction (°) 345.00 Measured TVD Below Dogleg Build Turn Depth Inclination Azimuth System +N/ -S +E/ -W Rate Rate Rate TFO (usft) (°) (°) (usft) (usft) (usft) (°/100ft) (°/100ft) (°/100ft) (°) 8,385.00 90.31 290.16 5,992.89 -3,059.99 -1,487.08 0.00 0.00 0.00 0.00 8,485.00 100.68 296.23 5,983.31 -3,020.90 -1,578.42 12.00 10.37 6.07 30.00 8,700.00 93.22 321.13 5,956.89 -2,888.39 -1,743.32 12.00 -3.47 11.58 105.00 8,900.00 92.94 345.17 5,945.98 -2,711.52 -1,832.86 12.00 -0.14 12.02 90.00 9,150.00 90.05 15.04 5,939.28 -2,464.46 -1,832.36 12.00 -1.16 11.95 95.00 9,475.00 86.27 53.89 5,950.12 -2,201.73 -1,652.19 12.00 -1.16 11.95 96.00 9,575.00 85.94 41.86 5,956.94 -2,134.93 -1,578.33 12.00 -0.33 -12.02 268.00 9,720.00 90.84 25.15 5,961.05 -2,014.53 -1,498.64 12.00 3.38 -11.52 286.00 9,950.00 98.98 358.66 5,941.03 -1,792.58 -1,451.50 12.00 3.54 -11.52 288.00 10,050.00 98.78 10.81 5,925.53 -1,694.31 -1,443.36 12.00 -0.20 12.14 90.00 10,200.00 92.91 27.92 5,910.14 -1,554.16 -1,393.99 12.00 -3.91 11.41 108.00 10,425.00 92.60 0.89 5,899.12 -1,338.51 -1,338.60 12.00 -0.14 -12.01 270.00 Target 711112016 12.10:36PM Page 2 COMPASS 5000.1 Build 74 ConocoPhillips -1,632.43 Vertical Database: EDM Alaska NSK Sandbox Company: ConocoPhillips (Alaska) Inc. -Kup2 Project: Kuparuk River Unit Azimuth Site: Kuparuk 26 Pad (usft) Well: 2B-02 (°/100ft) (°) Wellbore: 2B-02AL1 -3,059.99 -1,487.08 Design: 2 B-02AL1 _wp02 0.00 Planned Survey 506,887.41 -3,054.71 -1,501.11 Measured 12.00 30.00 TVD Below Depth Inclination -3,020.90 Azimuth System (usft) (a) C) (usft) 8,385.00 90.31 290.16 5,992.89 TIP/KOP 5,951,874.43 506,782.90 -2,959.20 8,400.00 91.87 291.06 5,992.61 8,485.00 100.68 296.23 5,983.31 Start 12 dls 12.00 107.06 8,500.00 100.21 298.00 5,980.59 8,600.00 96.86 309.65 5,965.70 8,700.00 93.22 321.13 5,956.89 3 90.67 5,952,176.78 506,541.28 8,800.00 93.15 333.15 5,951.31 8,900.00 92.94 345.17 5,945.98 4 -1,950.74 12.00 95.50 9,000.00 91.84 357.13 5,941.79 9,100.00 90.66 9.07 5,939.60 9,150.00 90.05 15.04 5,939.28 5 96.00 5,952,471.36 506,556.90 9,200.00 89.43 21.01 5,939.51 9,300.00 88.20 32.95 5,941.59 9,400.00 87.05 44.90 5,945.74 9,475.00 86.27 53.89 5,950.12 6 12.00 95.23 5,952,686.73 9,500.00 86.17 50.88 5,951.77 9,575.00 85.94 41.86 5,956.94 7 9,600.00 86.77 38.97 5,958.53 9,700.00 90.16 27.46 5,961.22 9,720.00 90.84 25.15 5,961.05 8 9,800.00 93.78 16.01 5,957.82 9,900.00 97.31 4.48 5,948.12 9,950.00 98.98 358.66 5,941.03 9 10,000.00 98.93 4.74 5,933.24 10,050.00 98.78 10.81 5,925.53 10 10,100.00 96.89 16.55 5,918.71 10,200.00 92.91 27.92 5,910.14 11 10,300.00 92.85 15.90 5,905.10 10,400.00 92.66 3.89 5,900.27 10,425.00 92.60 0.89 5,899.12 Planned TD at 10425.00 ConocoPhillips Planning Report Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Well 2B-02 Mean Sea Level 26-02 @ 126.00usft (213-02) True Minimum Curvature Nal BAKER HUGHES -2,186.50 -1,632.43 Vertical Dogleg Toolface Map Map +Nl-S +E/ -W Section Rate Azimuth Northing Easting (usft) (usft) (usft) (°/100ft) (°) (usft) (usft) -3,059.99 -1,487.08 -2,570.84 0.00 0.00 5,951,828.73 506,887.41 -3,054.71 -1,501.11 -2,562.11 12.00 30.00 5,951,834.00 506,873.37 -3,020.90 -1,578.42 -2,509.44 12.00 30.02 5,951,867.72 506,796.03 -3,014.18 -1,591.55 -2,499.55 12.00 105.00 5,951,874.43 506,782.90 -2,959.20 -1,673.52 -2,425.23 12.00 105.32 5,951,929.31 506,700.87 -2,888.39 -1,743.32 -2,338.77 12.00 107.06 5,952,000.03 506,631.00 -2,804.67 -1,797.40 -2,243.91 12.00 90.00 5,952,083.68 506,576.84 -2,711.52 -1,832.86 -2,144.75 12.00 90.67 5,952,176.78 506,541.28 -2,612.98 -1,848.20 -2,045.60 12.00 95.00 5,952,275.30 506,525.82 -2,513.33 -1,842.80 -1,950.74 12.00 95.50 5,952,374.94 506,531.11 -2,464.46 -1,832.36 -1,906.23 12.00 95.76 5,952,423.82 506,541.49 -2,416.93 -1,816.90 -1,864.33 12.00 96.00 5,952,471.36 506,556.90 -2,328.00 -1,771.63 -1,790.14 12.00 95.97 5,952,560.33 506,602.07 -2,250.41 -1,708.97 -1,731.41 12.00 95.73 5,952,637.98 506,664.64 -2,201.73 -1,652.19 -1,699.09 12.00 95.23 5,952,686.73 506,721.36 -2,186.50 -1,632.43 -1,689.50 12.00 -92.00 5,952,701.97 506,741.10 -2,134.93 -1,578.33 -1,653.68 12.00 -91.80 5,952,753.60 506,795.14 -2,115.94 -1,562.15 -1,639.52 12.00 -74.00 5,952,772.61 506,811.29 -2,032.45 -1,507.50 -1,573.03 12.00 -73.82 5,952,856.14 506,865.84 -2,014.53 -1,498.64 -1,558.01 12.00 -73.51 5,952,874.08 506,874.68 -1,939.78 -1,470.57 -1,493.08 12.00 -72.00 5,952,948.84 506,902.67 -1,842.03 -1,452.86 -1,403.23 12.00 -72.37 5,953,046.61 506,920.26 -1,792.58 -1,451.50 -1,355.82 12.00 -73.49 5,953,096.06 506,921.57 -1,743.23 -1,450.04 -1,308.54 12.00 90.00 5,953,145.40 506,922.98 -1,694.31 -1,443.36 -1,263.00 12.00 90.95 5,953,194.33 506,929.60 -1,646.20 -1,431.65 -1,219.57 12.00 108.00 5,953,242.44 506,941.26 -1,554.16 -1,393.99 -1,140.41 12.00 108.78 5,953,334.51 506,978.81 -1,461.67 -1,356.78 -1,060.71 12.00 -90.00 5,953,427.03 507,015.91 -1,363.46 -1,339.64 -970.27 12.00 -90.61 5,953,525.26 507,032.94 -1,338.51 -1,338.60 -946.44 12.00 -91.19 5,953,550.21 507,033.95 7/11/2016 12:10:36PM Page 3 COMPASS 5000.1 Build 74 ConocoPhillips ConocoPhillips Planning Report Database: EDM Alaska NSK Sandbox Local Co-ordinate Reference: Company: ConocoPhillips (Alaska) Inc. -Kup2 TVD Reference: Project: Kuparuk River Unit MD Reference: Site: Kuparuk 213 Pad North Reference: Well: 26-02 Survey Calculation Method: Wellbore: 2B-02AL1 plan misses target center by 1139697.24usft Design: 2 B-02AL1 _wp02 Point Targets Target Name hit/miss target Dip Angle Dip Dir. TVD +N/ -S +E/ -W Northing Shape (') (1) (usft) (usft) (usft) (usft) 2B-02A_Faultl 0.00 0.00 0.00 -4,064.721,139,312.09 5,952,094.00 plan misses target center by 1140669.21 usft at 10425.00usft MD (5899.12 TVD, -1338.51 N, -1338.60 E) Rectangle (sides W1,000.00 1-11.00 D0.00) 2B-02AL1_T03 0.00 0.00 5,952.00 -4,336.681,138,354.69 5,951,821.00 plan misses target center by 1139697.24usft at 10425.00usft MD (5899.12 TVD, -1338.51 N. -1338.60 E) Point 2B-02AL1 T05 0.00 0.00 5,961.00 -3,525.931,138,649.63 5,952,632.00 plan misses target center by 1139990.33usft at 10425.00usft MD (5899.12 TVD, -1338.51 N, -1338.60 E) Point 213-02 CTD Polygon Soy 0.00 0.00 0.00 -3,303.661,139,325.94 5,952,855.00 - plan misses target center by 1140681.49usft at 10425.00usft MD (5899.12 TVD, -1338.51 N, -1338.60 E) Polygon Point 1 0.00 0.00 0.00 5,952,855.00 Point 0.00 -207.95 -66.23 5,952,647.00 Point 3 0.00 -450.95 -87.49 5,952,404.00 Point 4 0.00 -603.91 -139.66 5,952,251.00 Point 5 0.00 -895.90 -177.97 5,951,958.99 Point 0,00 -1,058.81 -276.15 5,951,795.99 Point 0.00 -1,131.70 -387.24 5,951,722.98 Point 0.00 -1,148.53 -553.28 5,951,705.97 Point 0.00 -1,107.38 -689.25 5,951,746.96 Point 10 0.00 -1,086.18 -876.24 5,951,767.95 Point 11 0.00 -1,126.98 -1,071.30 5,951,726.94 Point 12 0.00 -1,213.81 -1,234.41 5,951,639.94 Point 13 0.00 -1,362.65 -1,397.59 5,951,490.93 Point 14 0.00 -1,560.58 -1,487.81 5,951,292.92 Point 15 0.00 -1,762.58 -1,502.02 5,951,090.93 Point 16 0.00 -1,974.58 -1,527.25 5,950,878.92 Point 17 0.00 -2,293.59 -1,544.59 5,950,559.92 Point 18 0.00 -2,546.56 -1,600.87 5,950,306.91 Point 19 0.00 -2,772.51 -1,663.11 5,950,080.92 Point 20 0.00 -2,835.88 -1,323.14 5,950,017.93 Point 21 0.00 -2,609.91 -1,273.90 5,950,243.93 Point 22 0.00 -2,224.92 -1,225.49 5,950,628.94 Point 23 0.00 -1,915.91 -1,204.16 5,950,937.94 Point 24 0.00 -1,647.90 -1,192.87 5,951,205.94 Point 25 0.00 -1,461.05 -1,033.66 5,951,392.95 Point 26 0.00 -1,398.24 -852.57 5,951,455.95 Point 27 0.00 -1,450.51 -599.60 5,951,403.97 Point 28 0.00 -1,443.76 -362.57 5,951,410.98 Point 29 0.00 -1,344.01 -119.44 5,951,510.99 Point 30 0.00 -1,146.17 50.79 5,951,709.00 Point 31 0.00 -948.22 117.00 5,951,907.01 Point 32 0.00 -670.24 165.30 5,952,185.01 Point 33 0.00 -503.27 210.49 5,952,352.01 Point 34 0.00 -257.27 231.75 5,952,598.01 Point 35 0.00 -80.32 294.94 5,952,775.02 Point 36 0.00 0.00 0.00 5,952,855.00 213-02AL1_T02 0.00 0.00 5,983.00 -4,537.931,138,563.49 5,951,620.00 plan misses target center by 1139906.59usft at 10425.00usft MD (5899.12 TVD, -1338.51 N, -1338.60 E) Point 26-02 CTD Polygon Nor 0.00 0.00 0.00 -4,754.151,138,740.27 5,951,404.00 - plan misses target center by 1140099.25usft at 10425.00usft MD (5899.12 TVD, -1338.51 N, -1338.60 E) - Polygon Point 1 0.00 0.00 0.00 5,951,404.00 FCC kI BAKER HUGHES Well 28-02 Mean Sea Level 2B-02 @ 126.00usft (26-02) True Minimum Curvature Easting (usft) Latitude Longitude 1,647,573.00 70° 2'34.277 N 140° 47'25.345 W 1,646,616.00 70° 2'33.041 N 140° 47'53.729 W 1,646,910.00 70° 2'40.481 N 140'47'41.861 W 1,647,586.00 70° 2'41.646 N 140° 47'21.678 W 1, 647, 586.00 1, 647, 520.01 1,647,499.02 1,647,447.03 1,647,409.05 1, 647, 311.06 1,647,200.06 1, 647, 034.05 1, 646, 898.05 1,646,711.06 1, 646, 516.06 1, 646, 353.07 1,646,190.07 1,646,100.08 1, 646, 086.09 1,646,061.10 1,646,044.12 1, 645, 988.13 1, 645, 926.14 1,646,266.15 1, 646, 315.13 1,646,363.11 1,646,384.09 1, 646, 395.08 1, 646, 554.07 1,646,735.07 1,646,988.07 1,647,225.07 1,647,468.07 1,647,638.06 1,647,704.04 1,647,752.03 1,647,797.03 1, 647, 818.01 1, 647, 881.00 1,647,586.00 1,646,825.00 70° 2'30.781 N 140° 47'48.658 W 1,647,002.00 700 2'28.422 N 140° 4T 44.562 W 0 7/11/2016 12:10:36PM Page 4 COMPASS 5000.1 Build 74 I"" ConocoPhillips ConocoPhillips Planning Report Database: EDM Alaska NSK Sandbox Local Co-ordinate Reference: Company: ConocoPhillips (Alaska) Inc. -Kup2 TVD Reference: Project: Kuparuk River Unit MD Reference: Site: Kuparuk 213 Pad North Reference: Well: 213-02 Survey Calculation Method: Wellbore: 213-02AL1 1,646,477.98 Design: 2 B -02A L1 _wp02 632.70 Well 2B-02 Mean Sea Level 213-02 @ 126.00usft (26-02) True Minimum Curvature Point 0.00 62.22 -200.95 5,951,465.99 1,646,801.00 Point 0.00 187.45 -405.84 5,951,590.98 1,646,595.99 Point 0.00 350.59 -523.68 5,951,753.97 1,646,477.98 Point 5 0.00 632.70 -596.39 5,952,035.97 1,646,404.97 Point 0.00 850.69 -565.15 5,952,253.98 1,646,435.96 Point 0.00 1,041.60 -470.94 5,952,444.97 1,646,529.95 Point 0.00 1,159.51 -366.81 5,952,562.99 1,646,633.94 Point 9 0.00 1,326.44 -286.62 5,952,729.99 1,646,713.93 Point 10 0.00 1,528.41 -241.40 5,952,931.99 1,646,758.92 Point 11 0.00 1,746.36 -175.16 5,953,149.99 1,646,824.91 Point 12 0.00 1,896.32 -119.00 5,953,300.00 1,646,880.90 Point 13 0.00 2,493.14 103.66 5,953,897.00 1,647,102.87 Point 14 0.00 2,433.82 398.63 5,953,838.02 1,647,397.88 Point 15 0.00 1,832.99 182.97 5,953,237.01 1,647,182.91 Point 16 0.00 1,590.04 109.70 5,952,994.00 1,647,109.92 Point 17 0.00 1,309.08 46.40 5,952,713.00 1,647,046.94 Point 18 0.00 1,093.16 -43.84 5,952,497.00 1,646,956.95 Point 19 0.00 920.26 -155.04 5,952,323.99 1,646,845.95 Point 20 0.00 718.34 -256.26 5,952,121.98 1,646,744.97 Point 21 0.00 500.32 -252.49 5,951,903.99 1,646,748.98 Point 22 0.00 350.15 -106.64 5,951,754.00 1,646,894.98 Point 23 0.00 297.97 59.32 5,951,702.01 1,647,060.98 Point 24 0.00 0.00 0.00 5,951,404.00 1,647,002.00 213-02AL1_T04 0.00 0.00 5,939.00 -3,951.611,138,322.12 5,952,206.00 1,646,583.00 plan misses target center by 1139663.72usft at 10425.00usft MD (5899.12 TVD, -1338.51 N, -1338.60 E) Point 2B-02AL1 T01 0.00 0.00 5,992.00 -4,568.01 1,138,629.46 5,951,590.00 1,646,891.00 plan misses target center by 1139972.64usft at 10425.00usft MD (5899.12 TVD, -1338.51 N, -1338.60 E) Point 2B-02A_Fault3 0.00 0.00 0.00 -4,570.011,138,632.46 5,951,588.00 1,646,894.00 plan misses target center by 1139990.91 usft at 10425.00usft MD (5899.12 TVD, -1338.51 N, -1338.60 E) Rectangle (sides W1,000.00 1-11.00 D0.00) 213-02AL1 T07 0.00 0.00 5,903.00 -2,931.041,138,799.30 5,953,227.00 1,647,059.00 plan misses target center by 1140139.02usft at 10425,00usft MD (5899.12 TVD, -1338.51 N, -1338.60 E) Point 2B-02A_Fault2 0.00 0.00 0.00 -4,602.151,138,747.44 5,951,556.00 1,647,009.00 plan misses target center by 1140105.97usft at 10425.00usft MD (5899.12 TVD, -1338.51 N, -1338.60 E) Rectangle (sides W1,000.00 H1.00 D0.00) 213-02AL1_Faultl 0.00 0.00 0.00 -3,525.931,138,649.63 5,952,632.00 1,646,910.00 plan misses target center by 1140005.59usft at 10425.00usft MD (5899.12 TVD, -1338.51 N, -1338.60 E) Rectangle (sides W1,000.00 H1.00 D0.00) 2B-02AL1_T08 0.00 0.00 5,899.00 -2,857.041,138,806.39 5,953,301.00 1,647,066.00 plan misses target center by 1140146.00usft at 10425.00usft MD (5899.12 TVD, -1338.51 N, -1338.60 E) Point WEaI BAKER HUGHES 700 2' 36.828 N 140° 47'53.000 W 70° 2' 30.392 N 140° 47'46.912 W 70° 2' 30.368 N 140° 47'46.836 W 70° 2'46.038 N 140° 47'35.048 W 70° 2' 29.887 N 140° 47'43.705 W 70° 2'40.481 N 140° 47'41.861 W 700 2'46.746 N 1400 47'34,529 W 26-02 CTD Polygon We: 0.00 0.00 0.00 -4,661.861,138,482.34 5,951,496.00 1,646,744.00 70° 2'29.697 N 140° 47'51.497 W - plan misses target center by 1139841.06usft at 10425.00usft MD (5899.12 TVD, -1338.51 N, -1338.60 E) - Polygon Point 1 0.00 0.00 0.00 5,951,496.00 1,646,744.00 Point 0.00 83.16 -138.93 5,951,579.00 1,646,604.99 Point 3 0.00 253.37 -322.76 5,951,748.99 1,646,420.99 Point 0.00 489.49 -416.52 5,951,984.98 1,646,326.98 Point 0.00 732.51 -413.26 5,952,227.98 1,646,329.97 Point 0.00 965.45 -329.01 5,952,460.99 1,646,413.95 Point 0.00 1,107.29 -165.84 5,952,602.99 1,646,576.94 Point 0.00 1,211.08 35.29 5,952,707.00 1,646,777.94 Point 9 0.00 1,256.87 237.36 5,952,753.01 1,646,979.94 Point 10 0.00 1,134.84 260.23 5,952,631.02 1,647,002.94 Point 11 0.00 971.79 292.06 5,952,468.02 1,647,034.95 Point 12 0.00 940.93 157.02 5,952,437.01 1,646,899.96 Point 13 0.00 902.03 55.96 5,952,398.00 1,646,798.95 7/11/2016 12:10.36PM Page 5 COMPASS 5000.1 Build 74 ConocoPhillips MAP tI ConocoPhillips Planning Report BAKER HUGHES Database: EDM Alaska NSK Sandbox Company: ConocoPhillips (Alaska) Inc. -Kup2 Project: Kuparuk River Unit Site: Kuparuk 26 Pad Well: 2B-02 Wellbore: 26-02AL1 Design: 2B-02AL1 _wp02 Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Well 26-02 Mean Sea Level 213-02 @ 126.00usft (213-02) True Minimum Curvature Point 14 0.00 843.11 -27.11 5,952,339.00 1,646,715.95 Point 15 0.00 767.16 -79.19 5,952,262.99 1,646,663.96 Point 16 0.00 663.18 -111.31 5,952,158.99 1,646,631.96 Point 17 0.00 538.17 -107.44 5,952,034.00 1,646,635.97 Point 18 0.00 444.12 -69.54 5,951,940.00 1,646,673.97 Point 19 0.00 350.03 6.37 5,951,846.00 1,646,749.98 Point 20 0.00 294.93 90.32 5,951,791.00 1,646,833.98 Point 21 0.00 0.00 0.00 5,951,496.00 1,646,744.00 2B-02AL1_T06 0.00 0.00 5,929.00 -3,237.951,138,697.95 5,952,920.00 1,646,958.00 70° 2'43.207 N 140° 47'39.249 W plan misses target center by 1140038.14usft at 10425.00usft MD (5899.12 TVD, -1338.51 N, -1338.60 E) 9,720.00 Point -2,014.53 -1,498.64 8 9,950.00 5,941.03 Casirrg Points Measured Vertical Casing Hole Depth Depth Diameter Diameter (usft) (usft) Name (in) (in) 10,425.00 5,899.12 2 3/8" 2.375 3.000 Plan Annotations Measured Vertical Local Coordinates Depth Depth +N/ -S +E/ -W (usft) (usft) (usft) (usft) Comment 8,385.00 5,992.89 -3,059.99 -1,487.08 TIP/KOP 8,485.00 5,983.31 -3,020.90 -1,578.42 Start 12 dls 8,700.00 5,956.89 -2,888.39 -1,743.32 3 8,900.00 5,945.98 -2,711.52 -1,832.86 4 9,150.00 5,939.28 -2,464.46 -1,832.36 5 9,475.00 5,950.12 -2,201.73 -1,652.19 6 9,575.00 5,956.94 -2,134.93 -1,578.33 7 9,720.00 5,961.05 -2,014.53 -1,498.64 8 9,950.00 5,941.03 -1,792.58 -1,451.50 9 10,050.00 5,925.53 -1,694.31 -1,443.36 10 10,200.00 5,910.14 -1,554.16 -1,393.99 11 10,425.00 5,899.12 -1,338.51 -1,338.60 Planned TD at 10425.00 7/11/2016 12: 10 36P Page 6 COMPASS 5000.1 Build 74 'lls" AIM KUP 2B-02 Onoco 1 ips - A , N Attributes Max Angle & MD TO Inc.Wellbore API/UWI Field Name Well Status 500292115400 KUPARUK RIVER UNIT PROD Incl (°J MD (RKB) Act Btm (ftKB) 39.17 4,200.00 6,976.0 Comment H25 (ppm) Date Annotation Entl Date KB-Grtl (ft) Rig Release Date SSSV: LOCKED OUT 100 12/16/2012 Last W0: 38.40 8/23/1984 - Well C - fig: -zB-02 6[19f2013192925 AM Annotation Depth (ftKB) Last Tag: SLM 6,683.0 Entl Date 5/19/2011 Annotation Last Mod ... End Data Rev Reason: H2S, DRILLING DEPTHS/DATES osborl 6/18/2013 :Schemasc-AUual.. Casin Strin s Casing Description String 0... String ID ... Top (ftKB) Set Depth if Set Depth (TVD)... String Wt... String ... String Top Thrd HANGER, 30 CONDUCTOR 16 15.062 35.0 110.0 110.0 62.50 H40 WELDED Casing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Third SURFACE 95/8 8.921 34.1 2,727.2 2,726.8 36.00 J-55 BTC Casing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd PRODUCTION 7 6.276 31.2 6,933.6 6,286.8 26.00 J-55 BTC Tubing Strin s Tubing Description String 0... String to ... Top(kK6) Set Depthh(f- set Depth (TVD) String Wt... String... String Top Thrd TUBING_ 31/2 2.992 30.5, 6_615,6 C 6,018.5 9.30 J-55 EUESRD Com letion Details Top Depth CONDUCTOR, 35110 (WDJ Top Incl Nomi... Top (ftKB) (ftKB) (°) Item Description Comment ID (in) 30.5 30.5 0.01 HANGER GRAY TUBING HANGER 3.500 SAFETY vLv;1. 991 1,891.4 1,891.3 0.73 SAFETY VLV OTIS FMX SAFETY VALVE, LOCKED OUT 4/18/98 2.813 6,359,5 5,803.4 33.71 SBR CAMCO OEJ-10 SBR 2.973 GAS LIFT, 6,377.3 5,818.1 33.59 PACKER CAMCO HRP -1 -SP RETRIEVABLE PACKER 2.867 1.929 6,489.4 5,911.9 32.73 BLAST RINGS BLAST RINGS (3) 2.992 6,598.7 6,004.1 32.26 SEAL ASSY LOCATOR SEAL ASSEMBLY 3.000 6,599.5 6,004.9 32.25 PACKER BAKER FB -1 PERMANENT PACKER 4.000 6,602.0 6,007.1 32.49 SBE BAKER SEAL BORE EXTENSION 3.000 6,611.4 6,015.0 32.49 NIPPLE CAMCO D NIPPLE NO GO 2.750 su�2727 6,614.7 6,017.8 32.49 WLEG CAMCO SHEAR OUT SUB, ELMD TTL @ 6608' ON SWS PPROF 2,937 DATED 1/5/07 GAS LIFT Other In Hole Wireline retrievable plugs, valves, pumps, fish, etc.) Top Depth (TVD) Top incl GAS LIFT, Top(ftKB) (ftKBI (°) Description Comment Run Date ID (in) 4,837 6,685.0 6,077.1 32.48 FISH 3" OK -1 Arm ASSY Lost Downhole on 9/12/96 9/12/1996- 10.000 GAS LIFT 5,864 Perforaltons & slots -- Shot lop (ND) Btm (TVD) Dens Top(ftKB) Sim (ftKB) (ftKB) (ftKB) Zone Date (sh... Type Comment 6,526.0 6,568.0 5,942.8 5,978.2 C-1,213-02 10/9/1984 12.0 (PERF 120 deg. ph; 5" DA Csg Guns GAS LIFT, 6,325 6,586.0 6,588.0 5,993.4 5,995.1 UNIT B, 28-02 10/10/1984 4.0 (PERF Squeeze Perfs; 4" DA Csg Gun 6,620.0 6,710.0 6,022.2 6,098.2 A-3, A4, A-5, 10/9/1984 4.0 IPERF 120 deg. ph; 4" JJ Csg Gun SBR, 6,359 215-02 PACKER, 6,377 Bottom Min Top Max Btm Top Depth Depth PRODUCTION, 6,415 Depth Depth (TVD) (TVD) (ftKB) (ftKB) (ftKB) (ftKB) Type Date Comment 6,526.0 6,568.0 5,942.8 5,978.2 C -SAND FRAC 11/2/2006 Pump C sand fracture treatment at 20 bpm using 50# X-linked gel. Pump total of 138,341# of 16/20 PRODUCTION, ceramic proppant, placing 126,640# prop behind pipe 6.483 with 10 ppa on pers. Screened out while on Flush, recovered all tree saver rubber. Cement Squeezes IPERF, 6.526-6.568 Top Depth (TVD.) Et. Depth (ND) C -SAND FRAC. 6,526 Top (ftKB) Btm (ftKB) (ftKB) (ftKB) Description Start Date Comment 6,586.0 6,588.0 5,993.4 5,995.1 Cement Squeeze 10/10/1984 Squeeze Penis Notes: General & Safety End Date Annotation 9/16/2010 NOTE: View Schematic w/ Alaska Schematic9.0 PRODUCTION, 5/19/2011 NOTE: MANDREL 3 -SLIGHTLY BENT LATCH ,562 6.582- IPERF, IPERF, 6,5866,Se8 Cement, 6,586 SEAL ASSY, 6,599 PACKER, 6,600 SBE, 6,602 NIPPLE. 6.611 WLEG, 6,615 Mandrel Details Top Depth Top ---- - Port IN S... (TVD) Incl OD Valve Latch Size 7R0 Run Top (ftKB) (ftKB) V) Make Model (in) S., Type Type (in) (psi) Run Date Com... 1 1,929.0 1,928.9 0.73 CAMCO KBUG 1 GAS LIFT GLV BK 0.156 1,244.0 11/7/2006 IPERF, 6,6206,710 2 3,478.3 3,458.1 20.84 CAMCO KBUG 1 GAS LIFT GLV BK 0.156 1,245,0 11/772006 3 4,837.0 4,574.3 36.06 CAMCO KBUG 1 GAS LIFT GLV BK 0.188 1,274.0 11/72006 Note FISH. 6,685 4 5,863.9 5,396.9 35.53 CAMCO KBUG 1 GAS LIFT GLV BK 0.188 1,266.0 11(7/2006 5 6,324.7 5,774.5 33.92 CAMCO KBUG 1 GAS LIFT OV BK 0.250 0.0 11/6/2006 6 6,414.7 5,849.4 33.05 CAMCO KBUG 1 PROD HFCV BEK 0.000 0.015/20/2011 7 6,482.9 5,906.5 32.75 CAMCO KBUG 11 PROD HFCV BEK 10.0001 0.015/20/2011 8 6,582.1 5,990.1 32.33 CAMCO KBUG 1 1 PROD HFCV BEK 10.0001 0.0 520/2011 PRODUCTION, 316,934 TD, 6,976 ConocoPhillip5 Project: Kuparuk River Unit Aelmuthsto True NOah WELLBORE DETAILS, 28-02A Site: Kuparuk 2B Paid Magnetk Nalh17,90' Well: 28-02 Magnelc Fleia Parent Wellbore; 28-02 Wellbore: 2B -02A SOengrh:5]6414sn,T roe on MD: 6600.00 Plan: 2B-02A_WpOS (2B -02/213-02A) oioi,, et 8oiol Dale; 14112016 Model, BGGM2016 REFERENCE INFORMATION Co-ardinale (NIE) Reference: Well 2B-02, True No1M Vertical (TVD) Reference: 28-02 @ 126AOusO (28-02) Semon (VS) Rakrence: Slot - (O,OON, 0.00E) Measured f)epih Reference: 2BV@ 126.00usft (28-02) WEkI BAKER HUGHES ...,.,,.1 j, -k , kaw ubiuin) - ---- ConocoPhillips Project: Ku aruk River Unit 1 P Site: Kuparuk 2B Pad Well: 213-02 Azimuths to Tnre North Magnetic North'. 17.90° Magnetic Field WELLBORE DETAILS: 2B-02AL1 REFERENCE INFORMATION Parent Wellbore: 213-02A Co-ordinate (WE) Reference: Well 28-02, True North Wellbore: 2B-02AL1 Strength: 57541.asn Dip Angle: 00.90° Tie on MD: 8365.00 Vertical (TVD) Reference: Mean Sea Level SecUon(VS) Reference: Slot - (GOON, O.00E) Plan: 2B-02AL1_Wp02 (2B-02!213-02AL1) Dale: ion/2016 Model: BGGM2016 Latitude Measured Depth Reference' 2B-02 @ 126.00usfl (2B-02) 0.00 0.00 Calculation Method: Minimum Curvature ;z -30( -60( -90( -120( -150( -180( c -210( O -240( O _270C -300( ,�O , ,330C -360C O to -390( -420C -450C -480C ri.I BAKER HUGHES WELL DETAILS: 213-02 +N/ -S +E/ -W Northing Easting Latitude Longitude 0.00 0.00 5954890.07 508370.93 70e 17' 16.702 N 149° 55' 56,081 W Sec MD Inc Azi TVDSS +N/ -S +E/ -W Dleg TFace VSect Annotation 1 8385.00 90.31 290.16 5992.89 -3059.99 -1487.08 0.00 0.00 -2570.84 TIP/KOP 2 8485.00 100.68 296.23 5983.31 -3020.90 -1578.42 12.00 30.00 -2509.44 Start 12 dls 3 8700.00 93.22 321.13 5956.89 -2888.39 -1743.32 12.00 105.00 -2338.77 3 4 8900.00 92.94 345.17 5945.98 -2711.52 -1832.86 12.00 90.00 -2144.75 4 5 9150.00 90.05 15.04 5939.28 -2464.46 -1832.36 12.00 95.00 -1906.23 5 6 9475.00 86.27 53.89 5950.12 -2201.73 -1652.19 12.00 96.00 -1699.09 6 7 9575.00 85.94 41.86 5956.94 -2134.93 -1578.33 12.00 268.00 -1653.68 7 8 9720.00 90.84 25.15 5961.05 -2014.53 -1498.64 12.00 286.00-1558.01 8 9 9950.00 98.98 358.66 5941.03 -1792.58 -1451.50 12.00 288.00 -1355.82 9 10 10050.00 98.78 10.81 5925.53 -1694.31 -1443.36 12.00 90.00 -1263.00 10 11 10200.00 211-02A 92.91 27.92 5910.14 -1554.16 -1393.99 12.00 108.00-1140.41 11 12 10425.00 92.60 0.89 5899.12 -1338.51 -1338.60 12.00 270.00 -946.44 Planned TD at 10425.00 ;z -30( -60( -90( -120( -150( -180( c -210( O -240( O _270C -300( ,�O , ,330C -360C O to -390( -420C -450C -480C ri.I BAKER HUGHES -4200 -3900 -3600 -3300 -3000 -2700 -2400 -2100 -1800 -1500 -1200 -900 -600 -300 0 300 600 900 1200 Vertical Section at 345.00° (60 usft/in) tanned TD at 0425,CD 2B-0 /2B-0 ALI. 2B-O2,,2B-02 L2-01 _...._ 2B oALli 2B 02AL07 2 -02AL _Fain B-02 I TO -- --- -- 10 211-02A 1 TO ------ ------2B-0 2B-02 2B -0212B-02 1kLI-0 6 _... -.._....._...___.- 2B-02 Faultl 2B 02ALI T02 3 02AL T ----- WE OP `. tart 12 dls 213-02A Faillt3 2B' 02A F lu t2 B-02/ B-02 213 07/2B 07 2 -02/2 -02 2 2B- 3/2B- 3 -4200 -3900 -3600 -3300 -3000 -2700 -2400 -2100 -1800 -1500 -1200 -900 -600 -300 0 300 600 900 1200 Vertical Section at 345.00° (60 usft/in) ConocoPhillips FrAaI ConocoPhillips Travelling Cylinder Report BAKER HUGHES Company: ConocoPhillips (Alaska) Inc. -Kup2 Project: Kuparuk River Unit Reference Site: Kuparuk 2B Pad Site Error: 0.00 usft Reference Well: 26-02 Well Error: 0.00 usft Reference Wellbore 2B-02AL1 Reference Design: 2B-02AL1_wp02 Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Output errors are at Database: Offset TVD Reference: Well 2B-02 26-02 @ 126.00usft (213-02) 213-02 @ 126.00usft (213-02) True Minimum Curvature 1 00 sigma EDM Alaska ANC Prod Offset Datum leference 2B-02AL1_wp02 ilter type: GLOBAL FILTER APPLIED: All wellpaths within 200'+ 100/1000 of reference iterpolation Method: MD Interval 25.00usft Error Model: ISCWSA lepth Range: 8,385.00 to 10,425.00usft Scan Method: Tray. Cylinder North results Limited by: Maximum center -center distance of 1,229.90 usft Error Surface: Elliptical Conic Survey Tool Program Date 7/8/2016 From To (usft) (usft) Survey (Wellbore) Tool Name Description 200.00 6,600.00 26-02 (213-02) GCT -MS Schlumberger GCT multishot 6,600.00 8,385.00 2B-02A_wp05 (213-02A) MWD MWD - Standard 8,385.00 10,425.00 2B-02AL1_wp02 (2B-02AL1) MWD MWD - Standard rasing Points Measured Vertical Casing Hole Depth Depth Diameter Diameter (usft) (usft) Name 10,425.00 6,025.12 2 3/8" 2-3/8 3 Summary Kuparuk 2B Pad - 213-02 - 26-02 - 28-02 Reference Offset Centre to No -Go Allowable Measured Measured Centre Distance Deviation Warning Site Name Depth Depth Distance (usft) from Plan Offset Well - Wellbore - Design (usft) (usft) (usft) Vertical (usft) Vertical Kuparuk 2B Pad Offset Toolface + Offset Wellbore Centre Casing - Centre to 213-02 - 26-02 - 213-02 9,875.00 6,825.00 757.10 46.43 716.25 Pass - Major Risk 213-02 - 2B -02A - 26-02A_wp05 8,399.99 8,400.00 0.41 0.61 -0.19 FAIL - Minor 1/10 213-02 - 26-02AL1-01 - 2B-02AL1-01_wp02 8,524.99 8,525.00 0.50 0.55 0.03 Pass- Minor 1/10 213-02 - 2B-02AL2 - 26-02AL2_wp02 8,402.66 8,450.00 24.34 0.39 24.12 Pass - Minor 1/10 26-02 - 2B-02AL2-01 - 2B-02AL2-01_wp01 8,861.42 8,925.00 1.39 0.40 1.07 Pass - Minor 1/10 2B-03 - 213-03 - 213-03 1.82 115.63 -1,985.55 -727.32 2-11/16 Out of range 28-03 - 26-03A - 26-03A 722.21 Pass - Major Risk 9,850.00 6,079.74 6,950.00 Out of range 213-04 - 26-04 - 2B-04 1.96 117.08 -1,998.31 -731.48 2-11/16 Out of range 213-06 - 26-06 - 213-06 725.33 Pass - Major Risk 9,850.00 6,079.74 6,975.00 Out of range 26-16 - 213-16 - 213-16 2.10 118.52 -2,011.07 -735.65 2-11/16 Out of range Offset Design Kuparuk 2B Pad - 213-02 - 26-02 - 28-02 Offset Site Error: 0 00 usft Survey Program: 200 -GCT -MS Rule Assigned: Major Risk Offset Well Error: 0.00 usft Reference Offset Semi Major Axis Measured Vertical Measured Vertical Reference Offset Toolface + Offset Wellbore Centre Casing - Centre to No Go Allowable Warning Depth Depth Depth Depth Azimuth -NIS +E/ -W Hole Size Centre Distance Deviation (usff) (usft) (usft) (usft) (usft) (usft) M (usft) (usft) ("l lush) (usft) (usft) 9,850.00 6,079.74 6,925.00 6,279.54 3.07 1.82 115.63 -1,985.55 -727.32 2-11/16 764.54 46.96 722.21 Pass - Major Risk 9,850.00 6,079.74 6,950.00 6,300.63 3.07 1.96 117.08 -1,998.31 -731.48 2-11/16 768.04 47.18 725.33 Pass - Major Risk 9,850.00 6,079.74 6,975.00 6,321.72 3.07 2.10 118.52 -2,011.07 -735.65 2-11/16 772.33 47.40 729.25 Pass - Major Risk 9,850.00 6,079.74 6,976.00 6,322.56 3.07 2.11 118.58 -2,011.58 -735.81 2-11/16 772.52 47.41 729.42 Pass - Major Risk 9,862.86 6,07844 6,900.00 6,258.44 3.06 1.68 112.53 -1,972.79 -723.16 2-11/16 761.56 46.92 719.59 Pass - Major Risk 9,875.00 6,077.12 6,825.00 6,195.17 3.04 126 106.54 -1,934.51 -710.67 2-11/16 757.10 46.43 716.25 Pass - Major Risk, ES, SF 9,875.00 6,077.12 6,850.00 6,216.26 3.04 1.40 108.02 -1,947.27 -714.83 2-11/16 757.85 46.65 716.62 Pass - Major Risk 9,875.00 6,077.12 6,875.00 6,237.35 3.04 1.54 109.50 -1,960.03 -718.99 2-11/16 759.42 46.87 717.80 Pass - Major Risk 9,886.87 6,075.74 6,800.00 6,174.08 3.03 1.12 103.52 -1,921.75 -706.50 2-11/16 756.94 46.38 716.43 Pass - Major Risk. CC CC - Min centre to center distance or covergent point, SF - min separation factor, ES - min ellipse separation 7/8/2016 10.24:54AM Page 2 COMPASS 5000.1 Build 74 TRANSMITTAL LETTER CHECKLIST WELL NAME: 0 PTD: V' -/Development _ Service _ Exploratory _ Stratigraphic Test Non -Conventional FIELD: POOL: i Zwr Check Box for Appropriate Letter / Paragraphs to be Included in Transmittal Letter CHECK OPTIONS TEXT FOR APPROVAL LETTER MULTI The permit is for a new wellbore segment of existing well Permit / LATERAL No. Q l �-0g7 API No. 50-_Qn- j/ (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 onermit). 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 2B-02AL1 Program DEV Well bore seg �/❑ PTD#: 2160880 Company CONOCOPHILLIPS ALASKA INC Initial Class/Type DEV/PEND GeoArea 890 Unit 11160 On/Off Shore On Annular Disposal ❑ Administration 17 Nonconven. gas -conforms toAS31,05.030(j.1_.A),Q.2.A-D) - - - - - - - - - NA- - - - - - - - ---- -- - - - - - - - -- - - - - - -- - - - -- - - - - - - - - - - - - - 1 Permit fee attached - - - - - ------------ ---------------- N -A - - - - - - - - 2 Lease number appropriate- - - - - - - - - - - - - - - - - -- - - - - - - - - - - Yes _ - - - - - ADL0025655, Surf Loc; ADL0025656, Top Prod-Intery &_TD_. - - - - - _ - - 3 Uniquewell-name and number - - - . - Yes - - - - - -KRU 2B-02AL1------------- -- - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - 4 Well located in a_defined -pool ----- _ - - - - - - - - - - - - - - - - - - - - - Yes _ - - _ KUPARUK RIVER,_KUPARUK RIV OIL- - 4901.00,_governed- by Conservation -Order No. 432D_ 5 Well located proper distance from drilling unitbound---------- ary- - - - - ---- Yes - . - - - - - CO 432D contains no spacing restrictions with respect to drilling unit boundaries. - - - - - - - - - - 6 Well located proper distance from other wells_ - - - Yes - - - - - CO 432D has no interwell spacing -restrictions._ - _ - 7 Sufficient acreage available in drilling unit - - - - - - - - - - - - - - - - - - - Yes - - - - - - - - - - - - - - - - - - - _ - - - 8 -if deviated, is wellbore plat_induded - - - - - - - - . - - Yes _ - - - - - - - _ - - - - - - - - - - 9 Operator only affected party- - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - Yes . - _ - Wellbore -will be more than 500' from an external property line where_ ownership or landownership_ changes._ - - - - 10 Operator has -appropriate bond in force - - - - - - - - - - - - - - - - - - - - - -- Yes - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - Appr Date 11 Permit can beissued -without conservation order ----- -- - - - - - - - - - - Yes- -- - - - - - - - - - - - -- - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - 12 Permitcanbeissuedwithoutadministrativ_e_appr_oval- - - - - - - - - - - - - - - - - - - - - - - - Yes - - - - - - - - - -- - - - - - - - - - - _ - - - - - _ _ - - - - - - - - - - - - - PKB 7/15/2016 13 Can permit be approved before 15 -day wait_ Yes - - - - - - - - - - - 14 Well located within area and -strata authorized by Injection Order # (put 10# in_comments)-(For_ NA - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - -- - - - - - - - - - - - - - - -- - - - - - - - - - - - -- -15 15 All wells _within _1/4_mile-area_of review identified (For service well only) - - - - - - - - - - - - - - NA-- ----- ------------ - - - - - - - - - - - - - . - - - - - - - - - - - - - - - - - - - - - - - - - - - --- 16 Pre -produced injector: duration -of pre production less than 3 months_ (For service well only) NA- - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - 18 _Conduct -or string -provided - - - - - - - - - - - - - - ----- - -- - - -- NA_ Conductor set-in KRU 2B-02 - _ - - - - - - . Engineering 19 Surface casing_ protects all -known USDWs -- - - NA_ Surface casing set in KRU 2B-02 - - - - - . - -- - - - - - - - - - - 20 CMT_v_ol_ adequate to circulate -on conductor & surf _csg - - - - NA_ Surface casing set and fully cemented - - _ _ 21 CMT_vol adequate to tie -in -long string to -surf csg_ _ NA - - - - - - - - - - - - - - - - - - - - - - - - - - - - 22 CMT_will coverall known -productive horizons- - - - - - - - - - - - - - - - - No. - - - - - Productive interval will -be completed withuncementedslotted liner 23 Casing designs adequate for C,_T, B &_ permafrost_ - - ----------- - - - - --- Yes . - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - 24 Adequate tankage_ or reserve pit Yes - Rig has steel tanks, all_waste_to approved disposal wells_ . . . . 25 -If-a- re -drill, has a 10-403 for abandonment. been approved . - - - - - - - - - - - - - NA_ _ _ _ - _ _ _ _ _ _ _ _ _ - _ _ _ _ _ _ _ - _ - - -- _ - - - - - - - - - I -- - - - - - _ - - - . - 26 Adequate wellbore separaton_proposed - Yes - - Anti -collision analysis complete; no major risk failures - - - - - - - - 27 If_diverter required, does it meet regulations_ - - - - - - - - - - - - - - - - NA- - - - - - - - - - . - - - - - - - - - - - - - - - - - . - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - Appr Date 28 Drilling Drilling fluid_program schematic & equip_ list_ adequate_ - - - Yes - - - - Max formation- pressure is 3973 psig(12_.6 ppg_EMW), will drill -w/ 8.6-ppg EMW and -maintain ov_erbal_w/ MPD VTL 8/15/2016 29 they meet regulation - - - - - - - - - - Yes - - - - - - - - - - - - - - - - - - - - - - - - - - -- - - - - - - - - - - - - - - - - - - - - - - - 30 _B -0 -PE -press rating appropriate; test to -(put psig in comments)- - - - - - - - - Yes - - _ MPSP is 3369 psig, will test BQPs-to 3750-psig _ _ _ _ _ _ 31 Choke_ manifold complies w/API_RP-53(May 54)___--- - -- -- -- Yes ----- ----------- -- ------ - -- --- - - 32 Work will occur without operation shutdown_ ---- Yes _ - - - - - - - - - - - - - - - 33 Is presence of H2S gas probable - - - Yes - - - - - - H2S measures required- - - - - - - - _ - - - - - - - - 34 Mecha-ni-cal-cond-ition of wells within, AOR verified (For service well only) NA_ - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - 35 Permit can be issued w/o hydrogen_ sulfide measures No_ - - - - -- Wells -on -2B -Pad are-H2S-bearing. H2S measures -required. Geology 36 Data_presented on potential overpressure zones - - - - - - - - - - - - Yes - Max. potential. reservoir pressure_ is 12.6 ppg_ EMW: will be drilled using 8.6_ppg mud and MPD techn_ique._ Appr Date 37 Seismic analysis of shallow gas -zones- . - _ - - - - - - - - - - -- - -- - - - NA _ - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - PKB 7/15/2016 38 Seabed condition survey (if off -shore) - - - . - - - - - NA. _ - - - - 39 Contact name/phone for weekly -progress reports [exploratory only] - - - _ - - - NA_ - - Onshore development well to -be -drilled -- - - - - - - - - - - - - - - - Geologic Engineering Public Commissioner: Date: y� /Date Co�� Co missio r Date � /