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Home My WebLink About216-159DATA SUBMITTAL COMPLIANCE REPORT 4/3/2017 Permit to Drill 2161590 Well Name/No. KUPARUK RIV UNIT 111-11-16A MD 10216 TVD 6772 Completion Date 1/1/2017 REQUIRED INFORMATION Mud Log No v Operator CONOCOPHILLIPS ALASKA INC API No. 50-029-22315-01-00 Completion Status 1 -OIL Current Status 1-0I1- UIC No Samples No -' Directional Survey Yes DATA INFORMATION Types Electric or Other Logs Run: GR/Res (data taken from Logs Portion of Master Well Data Maint) Well Log Information: Log/ Electr Data Digital Dataset Log Log Run Interval OH / Type Med/Frmt Number Name Scale Media No Start StopReceived CH Comments ED C 27952 Digital Data Q 2/3/2017 Electronic File: 1H-16A_MFC24_20DEC16.pdf - ED C 27952 Digital Data 2/3/2017 Electronic File: 11-1- 16A_MFC24_20DEC16_LAS.zip ' ED C 27952 Digital Data 2/3/2017 Electronic File: 1H- 16A_MFC24_20DEC16_img.tif` ED C 27952 Digital Data 2/3/2017 Electronic File: 1 H- 16A_MFC24_21 DEC16_Report.pdf ' ED C 27952 Digital Data 2/3/2017 Electronic File: WIVArun.zip - ED C 27952 Digital Data 2/3/2017 Electronic File: 1H- 16A_MFC24_21DEC16_CENTERED.cmi ED C 27952 Digital Data 2/3/2017 Electronic File: 1H- 16A_MFC24 21DEC16 CENTERED.wvd ED C 27952 Digital Data 2/3/2017 Electronic File: 1H- 16A_MFC24_21DEC16_CENTERED.wvp ED C 27952 Digital Data 2/3/2017 Electronic File: 1H- 16A_MFC24_21DEC16_UNCENTERED.cmi ED C 27952 Digital Data 2/3/2017 Electronic File: 1H- 16A_MFC24_21DEC16_UNCENTERED.wvd ' ED C 27952 Digital Data 2/3/2017 Electronic File: 1H- 16A_MFC24_21 DEC16_UNCENTERED.wvp Log C 27952 Log Header Scans 0 0 2161590 KUPARUK RIV UNIT 11-1-16A LOG HEADERS ED C 27957 Digital Data 6726 10216 2/8/2017 Electronic Data Set, Filename: 1H -16A GAMMA RES.Ias ED C 27957 Digital Data 2/8/2017 Electronic File: 1 H-1 6A 21VID Final Log.cgm - AOGCC Page l of 3 Monday, April 3, 2017 DATA SUBMITTAL COMPLIANCE REPORT 4/3/2017 Permit to Drill 2161590 Well Name/No. KUPARUK RIV UNIT 111-11-16A Operator CONOCOPHILLIPS ALASKA INC API No. 50-029-22315-01-00 MD 10216 TVD 6772 Completion Date 1/1/2017 Completion Status 1-0I1- Current Status 1-0I1- UIC No ED C 27957 Digital Data 2/8/2017 Electronic File: 1 H -16A 5MD Final Log.cgm ED C 27957 Digital Data 2/8/2017 Electronic File: 1 H -16A 5TVDSS Final Log.cgm ED C 27957 Digital Data P 2/8/2017 Electronic File: 1 H -16A 2MD Final.pdf ED C 27957 Digital Data F 2/8/2017 Electronic File: 1 H -16A 5MD Final.pdf ED C 27957 Digital Data p2/8/2017 Electronic File: 1 H -16A 5TVDSS Final Log.pdf ' ED C 27957 Digital Data 2/8/2017 Electronic File: 1 H -16A EOW - NAD27.pdf ED C 27957 Digital Data 2/8/2017 Electronic File: 1 H-1 6A EOW - NAD27.txt - ED C 27957 Digital Data 2/8/2017 Electronic File: 1 H-1 6A Final Surveys.csv . ED C 27957 Digital Data 2/8/2017 Electronic File: IH -16A Survey Listing.txt ' ED C 27957 Digital Data 2/8/2017 Electronic File: 1H -16A Surveys.txt ED C 27957 Digital Data 2/8/2017 Electronic File: 11-1- 16A 25_tapescan_BHI_CTK.txt - ED C 27957 Digital Data 2/8/2017 Electronic File: 1H-16A_5_tapescan_BHI_CTK.txt. ED C 27957 Digital Data 2/8/2017 Electronic File: 1H-16A_output.tap ED C 27957 Digital Data 2/8/2017 Electronic File: 1H -16A 2MD Final Log.tif ' ED C 27957 Digital Data 2/8/2017 Electronic File: 1H -16A 51VID Final Log.tif ED C 27957 Digital Data 2/8/2017 Electronic File: 1H -16A 5TVDSS Final Log.tif' Log C 27957 Log Header Scans 0 0 2161590 KUPARUK RIV UNIT 1 H-1 6A LOG HEADERS ED C 27967 Digital Data 2/15/2017 Electronic File: 1H -16A EOW - NAD27.pdf , ED C 27967 Digital Data 2/15/2017 Electronic File: 1H -16A EOW - NAD27.txt Log C 27967 Log Header Scans 0 0 2161590 KUPARUK RIV UNIT 1 H-1 6A LOG HEADERS Well Cores/Samples Information: Sample Interval Set Name Start Stop Sent Received Number Comments INFORMATION RECEIVED AOGCC Page 2 of 3 Monday, April 3, 2017 DATA SUBMITTAL COMPLIANCE REPORT 4/3/2017 PermittoDrill 2161590 WellName/No. KUPARUK RIV UNIT 11-1-16A Operator CONOCOPHILLIPS ALASKA INC API No. 50-029-22315-01-00 MD 10216 TVD 6772 Completion Date 1/1/2017 Completion Status 1 -OIL CurrentStatus 1 -OIL UIC No Completion Report Directional / Inclination Data 6) Mud Logs, Image Files, Digital Data Y /6 Core Chips y Production Test InformatioeNA Mechanical Integrity Test Information Y Composite Logs, Image, Data Files b Core Photographs y /S Geologic Markers/Tops (9 Daily Operations Summary 0 Cuttings Samples y / 16) Laboratory Analyses Y Q COMPLIANCE HISTORY Completion Date: 1/1/2017 Release Date: 12/14/2016 Description Date Comments Comments: Compliance Reviewed By: Date: AOGC(' Page 3 of 3 Monday, Aptil 3, 2017 Few a a BAKER HUGHES To RECEIVED FEB 15 2017 AOGCC 21 61 59 2796 7 Letter of Transmittal Date: DATA LOGGED 2 / t5 /2017 February 10, 2017 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): 1H -16A 1H-16ALIPB1 1H-16AL1 3H -22L1 CD in 1 H-1 6A 216-159 27 3H -22L1-02 3H-22L1-03PB1 CD in 3H -22L1 216-145 27 3H-22L1-03PB2 CD in 2T-41 L1 216-167 27 3H -22L1-03 2T-41 L 1 2T -41L1-01 (10) 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.Ragbirsing4@BakerHughes.com 967 970 375 ConocoPhilli s p RECEIVED FEB 15 2017 AOGC ConocoPhillips (Alaska) Inc. -Kup1 Kuparuk River Unit Kuparuk 1H Pad 1 H-1 6A 50-029-22315-01 Baker Hughes I NTEQ Definitive Survey Report 27 January, 2017 21 61 59 2796 7 F&A a I BAKER HUGHES ConocoPhillips ConocoPhillips Definitive Survey Report Company: ConocoPhillips (Alaska) Inc. -Kup1 Local Co-ordinate Reference: Well 1 H-16 Project: Kuparuk River Unit TVD Reference: 1 H-16 @ 96.00usft (1 H-16) Site: Kuparuk 1 H Pad MD Reference: 1 H-16 @ 96.00usft (1 H-16) Well: 1H-16 North Reference: True Wellbore: 1H-16 Survey Calculation Method: Minimum Curvature Design: 1H-16 Database: EDM Alaska NSK Sandbox Project Kuparuk River Unit, North Slope Alaska, United States Map System: Geo Datum: Map Zone: Well Well Position Position Uncertainty US State Plane 1927 (Exact solution) NAD 1927 (NADCON CONUS) Alaska Zone 04 1H-16 +Nl-S 0.00 usft +El -W 0.00 usft 0.00 usft System Datum: Mean Sea Level Using Well Reference Point Using geodetic scale factor Northing: 5,980,029.08 usft Easti ng: 549,192.10 usft Wellhead Elevation: usft rias BAKER HUGHES Latitude: Longitude: Ground Level: 70° 21'22.424 N 1490 36'1.811 W 0.00 usft Wellbore 11-1-16A Magnetics Model Name Sample Date Declination Dip Angle a Field Strength (nT) i BGGM2016 1/1/2017 17.87 80.97 57,549 Design 1H -16A Audit Notes: Version: 1.0 Phase: ACTUAL Tie On Depth: 7,084.10 Vertical Section: Depth From (TVD) +N/ -S +E/ -W Direction (usft) (usft) (usft) (°) 96.00 0.00 0.00 0.00 Survey Program Date 1/19/2017 From To Survey Survey (usft) (usft) Survey (Wellbore) Tool Name Description Start Date End Date 150.70 7,084.10 1 H-16 (1 H-16) GCT -MS Schlumberger GCT multishot 1/8/2001 7,137.50 10,169.94 1H-16A(1H-1 6A) MWD MWD - Standard 12/19/2016 12/24/2016 1/27/2017 1:51:53PM Page 2 COMPASS 5000.1 Build 74 ConocoPhillips F/aI ConocoPhillips BAKER p Definitive Survey Report HUGHES Company: ConocoPhillips (Alaska) Inc. -Kupl Local Co-ordinate Reference: Well 1 H-16 Project: Kuparuk River Unit TVD Reference: 1 H-16 @ 96.00usft (1 H-16) Site: Kuparuk 1 H Pad MD Reference: 1 H-16 @ 96.00usft (1 H-16) Well: 11-1-16 North Reference: True Wellbore: 11-1-16 Survey Calculation Method: Minimum Curvature Design: 11-1-16 Database: EDM Alaska NSK Sandbox Survey 's Map Map Vertical MD Inc Azi TVD TVDSS +N/ -S +E/ -W Northing Easting DLS Section (usft) (°) (°) (usft) (usft) (usft) (usft) (1/1001) Survey Tool Name Annotation (ft) (ft) (ft) 7,084.10 32.63 1.53 6,547.29 6,451.29 1,993.45 9.14 5,982,022.35 549,188.15 0.13 1,993.45 MWD (2) TIP °z 7,137.50 32.45 1.74 6,592.30 6,496.30 2,022.16 9.96 5,982,051.07 549,188.78 0.40 2,022.16 MWD (2) KOP 7,170.30 40.74 2.05 6,618.62 6,522.62 2,041.69 10.61 5,982,070.59 549,189.30 25.28 2,041.69 MWD (2) 7,200.37 51.77 2.25 6,639.36 6,543.38 2,063.36 11.43 5,982,092.27 549,189.98 36.68 2,063.36 MWD (2) 7,230.77 62.36 2.40 6,655.88 6,559.88 2,088.82 12.46 5,982,117.73 549,190.85 34.84 2,088.82 MWD (2) 7,260.97 73.63 4.91 6,667.18 6,571.18 2,116.71 14.27 5,982,145.63 549,192.47 38.10 2,116.71 MWD (2) 7,290.85 61.90 359.00 6,673.51 6,577.51 2,145.86 15.24 5,982,174.78 549,193.25 33.75 2,145.86 MWD (2) 7,321.05 68.13 350.74 6,676.14 6,580.14 2,175.78 12.55 5,982,204.66 549,190.36 34.16 2,175.78 MWD (2) k 7,351.48 93.72 342.18 6,675.65 6,579.65 2,205.32 5.43 5,982,234.18 549,183.05 33.58 2,205.32 MWD (2) 7,360.56 93.90 338.82 6,673.71 6,577.71 2,232.67 -4.25 5,982,261.46 549,173.19 11.55 2,232.67 MWD (2) i 7,411.01 e 92.70 337.18 6,671.96 6,575.96 2,260.85 -15.64 5,982,289.56 549,161.62 6.67 2,260.85 MWD (2) I 7,440.28 92.37 335.65 6,670.67 6,574.67 2,287.65 -27.34 5,982,316.28 549,149.74 5.34 2,287.65 MWD (2) 7,470.62 92.06 337.74 6,669.49 6,573.49 2,315.49 -39.33 5,982,344.04 549,137.57 6.96 2,315.49 MWD (2) S 7,500.56 93.53 338.83 6,668.03 6,572.03 2,343.28 -50.40 5,982,371.75 549,126.32 6.11 2,343.28 MWD (2) M y 7,530.16 93.32 342.38 6,666.26 6,570.26 2,371.14 -60.21 5,982,399.54 549,116.33 11.99 2,371.14 MWD (2) fi 7,560.56 92.40 343.99 6,664.75 6,568.75 2,400.20 -68.99 5,982,426.55 549,107.36 6.09 2,400.20 MWD (2) 7,589.87 91.07 346.23 6,663.86 6,567.86 2,426.51 -76.52 5,982,456.80 549,099.65 8.88 2,428.51 MWD (2) 7,621.41 90.28 348.64 6,663.49 6,567.49 2,459.29 -83.38 5,982,487.53 549,092.59 8.04 2,459.29 MWD (2) 7,650.33 89.88 350.56 6,663.45 6,567.45 2,487.74 -88.60 5,982,515.94 549,087.18 6.78 2,487.74 MWD (2) 7,660.56 88.53 353.63 6,663.87 6,567.87 2,517.67 -92.75 5,982,545.84 549,082.83 11.09 2,517.67 MWD (2) 7,710.73 86.56 354.56 6,665.16 6,569.16 2,547.65 -95.85 5,982,575.80 549,079.53 7.22 2,547.65 MWD (2) 7,740.06 86.59 357.34 6,666.91 6,570.91 2,576.86 -97.92 5,982,604.99 549,077.27 9.46 2,576.86 MWD (2) 7,765.14 87.45 355.46 6,668.22 6,572.22 2,601.85 -99.49 5,982,629.97 549,075.53 8.23 2,601.85 MWD (2) yy 7,795.02 89.36 354.23 6,669.05 6,573.05 2,631.60 -102.18 5,982,659.69 549,072.65 7.60 2,631.60 MWD (2) 7,825.10 89.60 353.50 6,669.32 6,573.32 2,661.50 -105.39 5,982,689.57 549,069.24 2.55 2,661.50 MWD (2) 7,855.18 87.02 353.76 6,670.21 6,574.21 2,691.38 -108.73 5,982,719.43 549,065.71 8.62 2,691.38 MWD (2) 7,885.19 84.32 353.25 6,672.47 6,576.47 2,721.11 -112.11 5,982,749.13 549,062.13 9.16 2,721.11 MWD (2) 7,915.09 84.03 351.31 6,675.51 6,579.51 2,750.59 -116.11 5,982,778.58 549,057.94 6.53 2,750.59 MWD (2) 7,945.58 84.34 348.81 6,678.60 6,582.60 2,780.46 -121.34 5,982,808.41 549,052.51 8.22 2,780.46 MWD (2) 7,974.96 84.65 346.76 6,681.42 6,585.42 21809.04 -127.53 5,982,836.95 549,046.14 7.03 2,809.04 MWD (2) 1/27/2017 1:51:53PM Page 3 COMPASS 5000.1 Build 74 1/27/2017 1:51:53PM Page 4 COMPASS 5000.1 Build 74 ConocoPhillips F&M ConocoPhillips p BAKER Map Definitive Survey Report Vertical HUGHES Company: ConocoPhillips (Alaska) Inc. -Kup1 Local Co-ordinate Reference: Well 1H-16 TVD Project: Kuparuk River Unit TVD Reference: 1 H-16 @ 96.00usft (1H-16) Site: Kuparuk 1 H Pad MD Reference: 1 H-16 @ 96.00usft (1 H-16) Well: 11-1-16 North Reference: True (usft) Wellbore: 11-1-16 Survey Calculation Method: Minimum Curvature Northing Design: 11-1-16 Database: EDM Alaska NSK Sandbox 1 Survey _ 0 1/27/2017 1:51:53PM Page 4 COMPASS 5000.1 Build 74 Map Map Vertical MD Inc Azi TVD TVDSS +N/ -S +E/ -W DLS (usft) N (I (usft) (usft) (usft) (usft) Northing Easting V/100') Section Survey Tool Name Annotation (ft) (ft) (ft) 8,005.47 85.39 344.79 6,684.07 6,588.07 2,838.50 -135.00 5,982,866.36 549,038.48 6.87 2,838.50 MWD (2) 8,035.55 86.96 343.92 6,686.07 6,590.07 2,867.40 -143.09 5,982,895.20 549,030.20 5.96 2,867.40 MWD (2) 8,065.20 87.54 341.24 6,687.50 6,591.50 2,895.66 -151.96 5,982,923.40 549,021.15 9.24 2,895.66 MWD (2) 8,095.02 87.42 339.49 6,688.81 6,592.81 2,923.71 -161.97 5,982,951.38 549,010.95 5.88 2,923.71 MWD (2) 8,125.37 89.45 343.19 6,689.64 6,593.64 2,952.45 -171.67 5,982,980.05 549,001.06 13.90 2,952.45 MWD (2) 8,155.58 87.02 344.55 6,690.57 6,594.57 2,981.46 -180.06 5,983,009.00 548,992.48 9.22 2,981.46 MWD (2) 8,185.51 86.80 346.94 6,692.18 6,596.18 3,010.42 -187.42 5,983,037.91 548,964.93 8.01 3,010.42 MWD (2) 8,215.50 87.42 349.96 6,693.69 6,597.69 3,039.76 -193.42 5,983,067.21 548,978.75 10.27 3,039.76 MWD (2) 8,245.34 87.70 352.72 6,694.96 6,598.96 3,069.23 -197.91 5,983,096.65 548,974.06 9.29 3,069.23 MWD (2) 8,275.35 86.65 354.34 6,696.44 6,600.44 3,099.01 -201.28 5,983,126.40 548,970.49 6.43 3,099.01 MWD (2) 8,305.44 84.22 356.00 6,698.84 6,602.84 3,128.90 -203.81 5,983,156.27 548,967.77 9.77 3,128.90 MWD (2) 8,334.71 81.97 357.93 6,702.36 6,606.36 3,157.91 -205.35 5,983,185.27 548,966.04 10.10 3,157.91 MWD (2) 8,365.30 80.00 359.80 6,707.15 6,611.15 3,188.12 -205.95 5,983,215.46 548,965.24 8.83 3,188.12 MWD (2) 8,395.28 77.35 1.88 6,713.04 6,617.04 3,217.50 -205.52 5,983,244.85 548,965.48 11.15 3,217.50 MWD (2) 8,425.16 76.12 0.62 6,719.89 6,623.89 3,246.58 -204.88 5,983,273.93 548,965.92 5.81 3,246.58 MWD (2) 8,454.96 75.96 358.32 6,727.08 6,631.08 3,275.50 -205.15 5,983,302.84 548,965.47 7.51 3,275.50 MWD (2) 8,464.35 76.14 355.94 6,734.17 6,638.17 3,303.98 -206.58 5,983,331.31 548,963.85 7.88 3,303.98 MWD (2) 8,514.99 76.27 353.50 6,741.48 6,645.48 3,333.61 -209.32 5,983,360.92 548,960.92 7.75 3,333.61 MWD (2) 8,545.68 76.72 351.61 6,748.64 6,652.64 3,363.20 -213.19 5,983,390.48 548,956.86 6.16 3,363.20 MWD (2) 8,575.91 79.32 351.18 6,754.92 6,658.92 3,392.43 -217.61 5,983,419.68 548,952.24 8.71 3,392.43 MWD (2) 8,605.79 81.06 350.19 6,760.01 6,664.01 3,421.49 -222.38 5,983,448.70 548,947.28 .6.68 3,421.49 MWD (2) 8,636.27 82.64 348.76 6,764.33 6,668.33 3,451.15 -227.89 5,983,478.32 548,941.58 6.96 3,451.15 MWD (2) 8,665.61 85.14 347.54 6,767.45 6,671.45 3,479.70 -233.88 5,983,506.83 548,935.40 9.47 3,479.70 MWD (2) 8,695.27 86.25 346.83 6,769.68 6,673.68 3,508.54 -240.44 5,983,535.62 548,928.65 4.44 3,508.54 MWD (2) 8,725.80 85.24 348.90 6,771.94 6,675.94 3,538.30 -246.84 5,983,565.34 548,922.06 7.53 3,538.30 MWD (2) 8,756.01 85.98 349.87 6,774.26 6,678.26 3,567.90 -252.39 5,983,594.90 548,916.32 4.03 3,567.90 MWD (2) 8,785.82 86.01 351.56 6,776.34 6,680.34 3,597.25 -257.19 5,983,624.21 548,911.33 5.66 3,597.25 MWD (2) 8,815.73 87.21 353.08 6,778.11 6,682.11 3,626.84 -261.18 5,983,653.77 548,907.14 6.47 3,626.84 MWD (2) 8,845.61 88.71 354.98 6,779.17 6,683.17 3,656.54 -264.28 5,983,683.45 548,903.84 8.10 3,656.54 MWD (2) 8,875.02 88.31 356.65 6,779.94 6,683.94 3,685.86 -266.43 5,983,712.75 548,901.50 5.84 3,685.86 MWD (2) 8,905.61 88.37 0.61 6,780.82 6,684.82 3,716.42 -267.16 5,983,743.30 548,900.57 12.94 3,716.42 MWD (2) 1/27/2017 1:51:53PM Page 4 COMPASS 5000.1 Build 74 ConocoPhillips Company: ConocoPhillips (Alaska) Inc. -Kupl Project: Kuparuk River Unit Site: Kuparuk 1 H Pad Well: 1H-16 Wellbore: 1H-16 Design: 11-1-116 Survey ConocoPhillips // jl BAKER Definitive Survey Report HUGHES Annotation 1/27/2017 1:51:53PM Page 5 COMPASS 5000.1 Build 74 Map Map Vertical MD Inc. Azi TVD TVDSS +N/ -S +El -W DLS (usft) (°) (°) (usft) (usft) (usft) (usft) Northing Easting (°/100') Section Survey Tool Name (ft) (ft) (ft) 8,935.78 86.90 1.02 6,782.07 6,686.07 3,746.56 -266.73 5,983,773.44 548,900.80 5.06 3,746.56 MWD (2) 8,965.29 88.62 1.42 6,783.22 6,687.22 3,776.04 -266.10 5,983,802.92 548,9D1.24 5.98 3,776.04 MWD (2) 8,995.40 89.79 359.41 6,783.64 6,687.64 3,806.14 -265.88 5,983,833.02 548,9D1.26 7.72 3,806.14 MWD (2) 9,025.49 90.28 0.13 6,783.62 6,687.62 3,836.23 -266.00 5,983,863.11 548,900.94 2.89 3,836.23 MWD (2) 9,055.62 90.71 358.37 6,783.36 6,687.36 3,866.36 -266.40 5,983,893.23 548,900.35 6.01 3,866.36 MWD (2) 9,085.54 91.99 357.33 6,782.66 6,686.66 3,896.25 -267.52 5,983,923.11 548,899.03 5.51 3,896.25 MWD (2) 9,115.62 92.70 355.51 6,781.42 6,685.42 3,926.24 -269.40 5,983,953.09 548,896.96 6.49 3,926.24 MWD (2) 9,145.86 93.69 354.31 6,779.74 6,683.74 3,956.32 -272.07 5,983,983.14 548,894.08 5.14 3,956.32 MWD (2) 9,175.54 94.43 352.32 6,777.64 6,681.64 3,985.72 -275.52 5,984,012.51 548,890.44 7.14 3,985.72 MWD (2) 9,205.53 93.13 351.88 6,775.66 6,679.66 4,015.36 -279.63 5,984,042.12 548,886.13 4.58 4,D15.36 MWD (2) 9,235.80 91.17 349.77 6,774.52 6,678.52 4,045.22 -284.46 5,984,071.95 548,881.12 9.51 4,045.22 MWD (2) 9,265.40 91.38 347.93 6,773.87 6,677.87 4,074.25 -290.18 5,984,100.94 548,875.20 6.26 4,074.25 MWD (2) 9,295.50 91.01 346.24 6,773.24 6,677.24 4,103.58 -296.90 5,984,130.22 548,868.29 5.75 4,103.58 MWD (2) 9,325.13 91.69 344.98 6,772.54 6,676.54 4,132.27 -304.27 5,984,158.86 548,860.74 4.83 4,132.27 MWD (2) 9,357.32 90.58 342.65 6,771.90 6,675.90 4,163.18 -313.24 5,984,189.71 548,851.57 8.02 4,163.18 MWD (2) 9,390.81 90.31 339.18 6,771.64 6,675.64 4,194.82 -324.18 5,984,221.27 548,840.41 10.39 4,194.82 MWD (2) 9,420.44 89.02 337.36 6,771.82 6,675.82 4,222.34 -335.15 5,984,248.72 548,829.26 7.53 4,222.34 MWD (2) 9,450.44 89.82 335.94 6,772.12 6,676.12 4,249.88 -347.04 5,984,276.18 548,817.19 5.43 4,249.88 MWD (2) 9,480.42 89.29 338.67 6,772.35 6,676.35 4,277.54 -358.61 5,984,303.76 548,805.45 9.28 4,277.54 MWD (2) 9,510.71 88.71 340.45 6,772.88 6,676.88 4,305.92 -369.18 5,984,332.06 548,794.69 6.18 4,305.92 MWD (2) 9,540.51 86.99 341.37 6,774.00 6,678.00 4,334.06 -378.92 5,984,360.13 548,784.76 6.54 4,334.06 MWD (2) 9,570.26 86.50 343.42 6,775.69 6,679.69 4,362.37 -387.91 5,984,368.38 548,775.60 7.07 4,362.37 MWD (2) 9,599.92 86.87 345.71 6,777.40 6,681.40 4,390.91 -395.79 5,984,416.86 548,767.53 7.81 4,390.91 MWD (2) 9,630.99 86.99 348.24 6,779.07 6,683.07 4,421.13 -402.78 5,984,447.04 548,760.34 8.14 4,421.13 MWD (2) 9,661.27 86.04 349.68 6,780.91 6,684.91 4,450.79 -408.57 5,984,476.66 548,754.36 5.69 4,450.79 MWD (2) 9,690.46 86.31 351.59 6,782.86 6,686.86 4,479.53 -413.30 5,984,505.36 548,749.43 6.59 4,479.53 MWD (2) 9,720.31 67.88 351.74 6,784.37 6,688.37 4,509.03 -417.63 5,984,534.83 548,744.92 5.28 4,509.03 MWD (2) 9,750.06 9D.18 352.79 6,784.87 6,688.87 4,538.50 -421.63 5,984,564.27 548,740.72 8.50 4,538.50 MWD (2) 9,780.05 91.78 353.16 6,784.36 6,688.36 4,568.26 -425.30 5,984,594.00 548,736.86 5.48 4,568.26 MWD (2) 9,810.52 93.72 353.72 6,782.90 6,686.90 4,598.49 -428.77 5,984,624.21 548,733.18 6.63 4,598.49 MWD (2) 9,843.75 94.09 355.09 6,780.63 6,684.63 4,631.49 -432.01 5,984,657.18 548,729.73 4.26 4,631.49 MWD (2) Annotation 1/27/2017 1:51:53PM Page 5 COMPASS 5000.1 Build 74 ConocoPhillips //aI ConocoPhillips Definitive Survey Report BAKER Company: ConocoPhillips (Alaska) Inc. -Kupl Project: Kuparuk River Unit Site: Kuparuk 1 H Pad Well: 1 H-16 Wellbore: 11-1-16 Design: 1 H-16 Survey Local Co-ordinate Reference: Well 1 H-16 TVD Reference: 1 H-16 @ 96.00usft (1 H-16) MD Reference: 1 H-16 @ 96.00usft (1 H-16) North Reference: True Survey Calculation Method: Minimum Curvature 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 (°/loo') Section Survey Tool Name Annotation (ft) (ft) (ft) 9,870.00 94.45 355.27 6,778.68 6,682.68 4,657.57 -434.21 5,984,683.25 548,727.36 1.53 4,657.57 MWD (2) 9,900.70 92.52 355.19 6,776.81 6,680.81 4,688.11 -436.75 5,984,713.76 548,724.62 6.29 4,688.11 MWD (2) 9,930.82 94.70 355.39 6,774.92 6,678.92 4,718.06 -439.22 5,984,743.70 548,721.95 7.27 4,718.06 MWD (2) 9,960.15 94.30 355.55 6,772.62 6,676.62 4,747.21 -441.53 5,984,772.83 548,719.45 1.47 4,747.21 MWD (2) 9,990.70 92.73 355.87 6,770.74 6,674.74 4,777.62 -443.81 5,984,803.21 548,716.97 5.24 4,777.62 MWD (2) 10,020.36 89.94 355.31 6,770.05 6,674.05 4,807.18 -446.09 5,984,832.76 548,714.50 9.59 4,807.18 MWD (2) 10,050.75 88.65 356.01 6,770.43 6,674.43 4,837.48 -448.39 5,984,863.04 548,712.00 4.83 4,837.48 MWD (2) 10,080.03 90.09 357.02 6,770.75 6,674.75 4,866.70 -450.17 5,984,892.25 548,710.03 6.01 4,866.70 MWD (2) 10,110.47 89.63 359.58 6,770.82 6,674.82 4,897.12 -451.07 5,984,922.66 548,708.92 8.54 4,897.12 MWD (2) 10,140.26 89.54 1.82 6,771.04 6,675.04 4,926.91 -450.71 5,984,952.44 548,709.09 7.53 4,926.91 MWD (2) 10,169.94 88.65 3.65 6,771.51 6,675.51 4,956.55 -449.29 5,984,982.09 548,710.31 6.86 4,956.55 MWD (2) 10,216.00 88.65 3.65 6,772.59 6,676.59 5,002.50 -446.36 5,985,028.06 548,712.94 0.00 5,002.50 PROJECTED to TO 1/27/2017 1:51:53PM Page 6 COMPASS 5000.1 Build 74 wt all BAKER HUGHES RECEI (r . FEB 0 8 2017 PRINT DISTRIBUTION LIST COMPANY Ao QQi Qaska, Inc. WELL NAME 1H -16A FIELD Prudhoe Bay Unit COUNTY North Slope Borough BHI DISTRICT Alaska AUTHORIZED BY Patrick Rider EMAIL Patrick. RiderCa)bakerhughes.com STATUS Final Replacement: COMPANY ADDRESS (FEDEX WILL NOT DELIVER TO P.O. BO$ PERSON ATTENTION 2 16 i 5 9 279,7 Please sign and return one copy of this transmittal form to: ConocoPhillips Alaska, Inc. Tom Osterkamp DATA LOGGED 700 G Street. 2./'S /201"t M. K.BENDEP Anchorage, Alaska 99510 to acknowledge receipt of this data. LOG TYPE GR - RES LOG DATE December 30, 2016 TODAYS DATE February 6, 2017 Revision No Details: Requested by: FIELD FINALCD CD LOGS LOGS (digital/image) Surveys (Final Surveys) # OF PRINTS # OF PRIN 1 S # OF COPIES # OF COPIES # OF COPIE 1 BP North Slope 0 0 0 EOA, PBOC, PRB-20 (Office 109) D&C Wells Project Aids Agatha Rutka & Barbara Glassmaker 900 E. Benson Blvd. Anchorage, Alaska 99508 2 ConocoPhillips Alaska Inc. Attn: Ricky Elgaricio ATO 3-344 700 G Street Anchorage, AK 99510 3 ExxonMobil, Alaska Attn: Lynda M. Yaskell and/or Leonardo Elias 3201 C Street, Suite 505 Anchorage, AK 99503 4 State of Alaska - AOGCC Attn: Makana Bender 333 W. 7th Ave, Suite 100 ,Anchorage, Alaska 99501 5 DNR -Division of Oil &Gas *** 0 1 1 Attn: Resource Evaluation 550 West 7th Avenue, Suite 1100 Anchorage, Alaska 99501 ** Stamp "confidential' on all material deliver to DNR_J 6 BP Exploration (Alaska) Inc. Petrotechnical Data Center, LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 TOTALS FOR THIS PAGE: 0 2 3 3 0 0 TOTALS FOR ALL PAGES: 0 2 3 3 0 0 ConocoPhilli s p RECEIVED FEB 0 8 2017 AOCaCC ConocoPhillips (Alaska) Inc. -Kup1 Kuparuk River Unit Kuparuk 1 H Pad 1 H-1 6A 50-029-22315-01 Baker Hughes I NTEQ Definitive Survey Report 27 January, 2017 WCA k I BAKER HUGHES 1/27/2017 1.51:53PM Page 2 COMPASS 5000.1 Build 74 ConocoPhillips w1fts 1w-1 ConocoPhillips Survey Report KER HUGHES Definitive Company: ConocoPhillips (Alaska) Inc. -Kupl Local Co-ordinate Reference: Well 1 H-16 Project: Kuparuk River Unit TVD Reference: 1H-16 @ 96.00usft (1H-16) Site: Kuparuk 1 H Pad MD Reference: 1 H-16 @ 96.00usft (1 H-16) Well: 11-1-16 North Reference: True Wellbore: 11-1-16 Survey Calculation Method: Minimum Curvature Design: 11-1-16 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 IH-16 Well Position +N/-S 0.00 usft Northing: 5,980,029.08usft Latitude: 700 21'22.424 N +E/-W 0.00 usft Easting: 549,192.10usft Longitude: 149° 36'1.811 W Position Uncertainty 0.00 usft Wellhead Elevation: usft Ground Level: 0.00 usft Wellbore 11-1-16A Magnetics Model Name Sample Date Declination Dip Angle Field Strength (I (°) (nT) BGG M2016 1/1/2017 17.87 80.97 57,549 Design 11-1-16A Audit Notes: Version: 1.0 Phase: ACTUAL Tie On Depth: 7,084.10 Vertical Section: Depth From (TVD) +N/-S +E/-W Direction (usft) (usft) (usft) (°) 96.00 0.00 0.00 0.00 Survey Program Date 1/19/2017 From To Survey Survey (usft) (usft) Survey (Wellbore) Tool Name Description Start Date End Date 150.70 7,084.10 1H-16 (1H-16) GCT-MS Schlumberger GCT multishot 1/8/2001 7,137.50 10,169.94 1 H-1 6A (1 H-1 6A) MWD MWD - Standard 12/19/2016 12/24/2016 1/27/2017 1.51:53PM Page 2 COMPASS 5000.1 Build 74 Survey ConocoPhillips //j9 ConocoPhillips Definitive Survey Report HUGHES Company: ConocoPhillips (Alaska) Inc. -Kupl Local Co-ordinate Reference: Well 1 H-16 MD Project: Kuparuk River Unit TVD Reference: 1 H-16 @ 96.00usft (1 H-16) TVDSS Site: Kuparuk 1H Pad MD Reference: 1 H-16 @ 96.00usft (1 H-16) Easting Well: 11-1-16 North Reference: True (I Wellbore: 11-1-16 Survey Calculation Method: Minimum Curvature (usft) Design: 11-1-16 Database: EDM Alaska NSK Sandbox (°l100') Survey 1/27/2017 1:51:53PM Page 3 COMPASS 5000.1 Build 74 Map Map Vertical MD Inc AzI TVD TVDSS +N/ -S +EI -W Northing Easting DLS Section (usft) (I (I (usft) (usft) (usft) (usft) (°l100') Survey Toot Name Annotation (ft) (ft) (ft) 7,084.10 32.63 1.53 6,547.29 6,451.29 1,993.45 9.14 5,982,022.35 549,188.15 0.13 1,993.45 MWD (2) TIP 7,137.50 32.45 1.74 6,592.30 6,496.30 2,022.16 9.96 5,982,051.07 549,188.78 0.40 2,022.16 MWD (2) KOP 7,170.30 40.74 2.05 6,618.62 6,522.62 2,041.69 10.61 5,982,070.59 549,189.30 25.28 2,041.69 MWD (2) 7,200.37 51.77 2.25 6,639.38 6,543.38 2,063.36 11.43 5,982,092.27 549,189.98 36.68 2,063.36 MWD (2) 7,230.77 62.36 2.40 6,655.88 6,559.88 2,088.82 12.46 5,982,117.73 549,190.85 34.84 2,088.82 MWD (2) 7,260.97 73.63 4.91 6,667.18 6,571.18 2,116.71 14.27 5,982,145.63 549,192.47 38.10 2,116.71 MWD (2) 7,290.85 81.90 359.00 6,673.51 6,577.51 2,145.86 15.24 5,982,174.78 549,193.25 33.75 2,145.86 MWD (2) 7,321.05 88.13 350.74 6,676.14 6,580.14 2,175.78 12.55 5,982,204.68 549,190.36 34.16 2,175.78 MWD (2) 7,351.48 93.72 342.18 6,675.65 6,579.65 2,205.32 5.43 5,982,234.18 549,183.05 33.58 2,205.32 MWD (2) 7,380.56 93.90 338.82 6,673.71 6,577.71 2,232.67 -4.25 5,982,261.46 549,173.19 11.55 2,232.67 MWD (2) 7,411.01 92.70 337.18 6,671.96 6,575.96 2,260.85 -15.64 5,982,289.56 549,161.62 6.67 2,260.85 MWD (2) 7,440.28 92.37 335.65 6,670.67 6,574.67 2,287.65 -27.34 5,982,316.28 549,149.74 5.34 2,287.65 MWD (2) 7,470.62 92.06 337.74 6,669.49 6,573.49 2,315.49 -39.33 5,982,344.04 549,137.57 6.96 2,315.49 MWD (2) - 7,500.56 93.53 338.83 6,668.03 6,572.03 2,343.28 -50.40 5,982,371.75 549,126.32 6.11 2,343.28 MWD (2) 7,530.16 93.32 342.38 6,666.26 6,570.26 2,371.14 - -60.21 5,982,399.54 549,116.33 11.99 2,371.14 MWD (2) 7,560.56 92.40 343.99 6,664.75 6,568.75 2,400.20 -68.99 5,982,428.55 549,107.36 6.09 2,400.20 MWD (2) 7,589.87 91.07 346.23 6,663.86 6,567.86 2,428.51 -76.52 5,982,456.80 549,099.65 8.88 2,428.51 MWD (2) 7,621.41 90.28 348.64 6,663.49 6,567.49 2,459.29 -83.38 5,982,487.53 549,092.59 B.04 2,459.29 MWD (2) 7,650.33 89.88 350.56 6,663.45 6,567.45 2,487.74 -88.60 5,982,515.94 549,087.18 6.78 2,487.74 MWD (2) 7,680.56 88.53 353.63 6,663.87 6,567.87 2,517.67 -92.75 5,982,545.84 549,082.83 11.09 2,517.67 MWD (2) 7,710.73 86.56 354.56 6,665.16 6,569.16 2,547.65 -95.85 5,982,575.80 549,079.53 7.22 2,547.65 MWD (2) 7,740.06 86.59 357.34 6,666.91 6,570.91 2,576.86 -97.92 5,982,604.99 549,077.27 9.46 2,576.86 MWD (2) 7,765.14 87.45 355.46 6,668.22 6,572.22 2,601.85 -99.49 5,982,629.97 549,075.53 8.23 2,601.85 MWD (2) 7,795.02 89.36 354.23 6,669.05 6,573.05 2,631.60 -102.18 5,982,659.69 549,072.65 7.60 2,631.60 MWD (2) 7,825.10 89.60 353.50 6,669.32 6,573.32 2,661.50 -105.39 5,982,689.57 549,069.24 2.55 2,661.50 MWD (2) - 7,855.18 87.02 353.76 6,670.21 6,574.21 2,691.38 -108.73 5,982,719.43 549,065.71 8.62 2,691.38 MWD (2) 7,885.19 84.32 353.25 6,672.47 6,576.47 2,721.11 -112.11 5,982,749.13 549,062.13 9.16 2,721.11 .MWD (2) 7,915.09 84.03 351.31 6,675.51 6,579.51 2,750.59 -116.11 5,982,778.58 549,057.94 6.53 2,750.59 MWD (2) 7,945.58 84.34 348.81 6,678.60 6,582.60 2,780.46 -121.34 5,982,808.41 549,052.51 8.22 2,780.46 MWD (2) 7,974.96 84.65 346.76 6,681.42 6,585.42 2,809.04 -127.53 5,982,836.95 549,046.14 7.03 2,809.04 MWD (2) 1/27/2017 1:51:53PM Page 3 COMPASS 5000.1 Build 74 Survey ConocoPhillips FUS ConocoPhillips Definitive Survey Report HUGHES Company: ConocoPhillips (Alaska) Inc. -Kupl Local Co-ordinate Reference: Well 1 H-16 MD Project: Kuparuk River Unit TVD Reference: 1 H-16 @ 96.00usft (1 H-16) TVDSS Site: Kuparuk 1 H Pad MD Reference: 1 H-16 @ 96.00usft (1 H-16) EMap ting Well: 11-1-16 North Reference: True 0 Wellbore: 11-1-16 Survey Calculation Method: Minimum Curvature (usft) Design: 11-1-16 Database: EDM Alaska NSK Sandbox (°/100') Survey 1127/2017 1:51:53PM Page 4 COMPASS 5000.1 Build 74 ` Map Vertical MD Inc Azi TVD TVDSS +N1S +E/.W Northing EMap ting DLS Section Survey Tool Name Annotation (usft) 0 r) (usft) (usft) (usft) (usft) (ft) (ft) (°/100') (ft) 8,005.47 85.39 344.79 6,684.07 6,588.07 2,838.50 -135.00 5,982,866.36 549,038.48 6.87 2,838.50 MWD (2) 8,035.55 86.96 343.92 6,686.07 6,590.07 2,867.40 -143.09 5,982,895.20 549,030.20 5.96 2,867.40 MWD (2) 8,065.20 87.54 341.24 6,687.50 6,591.50 2,895.66 -151.96 5,982,923.40 549,021.15 9.24 2,895.66 MWD (2) 8,095.02 87.42 339.49 6,688.81 6,592.81 2,923.71 -161.97 5,982,951.38 549,010.95 5.88 2,923.71 MWD (2) 8,125.37 89.45 343.19 6,689.64 6,593.64 2,952.45 -171.67 5,982,980.05 549,001.06 13.90 2,952.45 MWD (2) 8,155.58 87.02 344.55 6,690.57 6,594.57 2,981.46 -180.06 5,983,009.00 548,992.48 9.22 2,981.46 MWD (2) 8,185.51 86.80 346.94 6,692.18 6,596.18 3,010.42 -187.42 5,983,037.91 548,984.93 .8.01 3,010.42 MWD (2) 8,215.50 87.42 349.96 6,693.69 6,597.69 3,039.76 -193.42 5,983,067.21 548,978.75 10.27 3,039.76 MWD (2) 8,245.34 87.70 352.72 6,694.96 6,598.96 3,069.23 -197.91 5,983,096.65 548,974.06 9.29 3,069.23 MWD (2) 8,275.35 86.65 354.34 6,696.44 6,600.44 3,099.01 -201.28 5,983,126.40 548,970.49 6.43 3,099.01 MWD (2) 8,305.44 84.22 356.00 6,698.84 6,602.84 3,128.90 -203.81 5,983,156.27 548,967.77 9.77 3,128.90 MWD (2) 8,334.71 81.97 357.93 6,702.36 6,606.36 3,157.91 -205.35 5,983,185.27 548,966.04 10.10 3,157.91 MWD (2) 8,365.30 80.00 359.80 6,707.15 6,611.15 3,188.12 -205.95 5,983,215.46 548,965.24 8.83 3,188.12 MWD (2) 8,395.28 77.35 1.88 6,713.04 6,617.04 3,217.50 -205.52 5,983,244.85 548,965.48 11.15 3,217.50 MWD (2) 8,425.16 76.12 0.62 6,719.89 6,623.89 3,246.58 -204.88 5,983,273.93 548,965.92 5.81 3,246.58 MWD (2) 8,454.96 75.96 358.32 6,727.08 6,631.08 3,275.50 -205.15 5,983,302.84 548,965.47 7.51 3,275.50 MWD (2) 8,484.35 76.14 355.94 6,734.17 6,638.17 3,303.98 -206.58 5,983,331.31 548,963.85 7.88 3,303.98 MWD (2) 8,514.99 76.27 353.50 6,741.48 6,645.48 3,333.61 -209.32 5,983,360.92 548,960.92 7.75 3,333.61 MWD (2) 8,545.68 76.72 351.61 6,748.64 6,652.64 3,363.20 -213.19 5,983,390.48 548,956.86 6.16 3,363.20 MWD (2) 8,575.91 79.32 351.18 6,754.92 6,658.92 3,392.43 -217.61 5,983,419.68 548,952.24 8.71 3,392.43 MWD (2) 8,605.79 81.06 350.19 6,760.01 6,664.01 3,421.49 -222.38 5,983,448.70 548,947.28 6.68 3,421.49 MWD (2) 8,636.27 82.64 348.76 6,764.33 6,668.33 3,451.15 -227.89 5,983,478.32 548,941.58 6.96 3,451.15 MWD (2) 8,665.61 85.14 347.54 6,767.45 6,671.45 3,479.70 -233.88 5,983,506.83 548,935.40 9.47 3,479.70 MWD (2) 8,695.27 86.25 346.83 6,769.68 6,673.68 3,508.54 -240,44 5,983,535.62 548,928.65 4.44 3,508.54 MWD (2) 8,725.80 85.24 348.90 6,771.94 6,675.94 3,538.30 -246.84 5,983,565.34 548,922.06 7.53 3,538.30 MWD (2) 8,756.01 85.98 349.87 6,774.26 6,678.26 3,567.90 -252.39 5,983,594.90 548,916.32 4.03 3,567.90 MWD (2) 8,785.82 86.01 351.56 6,776.34 6,680.34 3,597.25 -257.19 5,983,624.21 548,911.33 5.66 3,597.25 MWD (2) 8,815.73 87.21 353.08 6,778.11 6,682.11 3,626.84 -261.18 5,983,653.77 548,907.14 6.47 3,626.84 MWD (2) 8,845.61 88.71 354.98 6,779.17 6,683.17 3,656.54 -264.28 5,983,683.45 548,903.84 8.10 3,656.54 MWD (2) 8,875.02 88.31 356.65 6,779.94 6,683.94 3,685.86 -266.43 5,983,712.75 548,901.50 5.84 3,685.86 MWD (2) 8,905.61 88.37 0.61 6,780.82 6,684.82 3,716.42 -267.16 5,983,743.30 548,900.57 12.94 3,716.42 MWD (2) 1127/2017 1:51:53PM Page 4 COMPASS 5000.1 Build 74 ConocoPhillips p ConocoPhillips Definitive Survey Report Azl NA j, BAKER HUGHES Company: ConocoPhillips (Alaska) Inc. -Kup1 Local Coordinate Reference: Well 1 H-16 Map Project: Kuparuk River Unit TVD Reference: 1 H-16 @ 96.00usft (1 H-16) (usft) Site: Kuparuk 1 H Pad MD Reference: 1 H-16 @ 96.00usft (1 H-16) (usft) Well: 11-1-16 North Reference: True Easting Wellbore: 11-1-16 Survey Calculation Method: Minimum Curvature Design: 11-1-16 Database: EDM Alaska NSK Sandbox Survey MD Inc Azl TVD TVDSS +N/ -S +E/ -W Map Map DLS Vertical (usft) (°) (°) (usft) (usft) (usft) (usft) Northing Easting (°/100') Section Survey Tool Name Annotation (ft) (ft) (ft) 8,935.78 86.90 1.02 6,782.07 6,686.07 3,746.56 -266.73 5,983,773.44 548,900.80 5.06 3,746.56 MWD (2) 8,965.29 88.62 1.42 6,783.22 6,687.22 3,776.04 -266.10 5,983,802.92 548,901.24 5.98 3,776.04 MWD (2) 8,995.40 89.79 359.41 6,783.64 6,687.64 3,806.14 -265.88 5,983,833.02 548,901.26 7.72 3,806.14 MWD (2) 9,025.49 90.28 0.13 6,783.62 6,687.62 3,836..23 -266.00 5,983,863.11 548,900.94 2.89 3,836.23 MWD (2) 9,055.62 90.71 358.37 6,783.36 6,687.36 3,866.36 -266.40 5,983,893.23 548,900.35 6.01 3,866.36 MWD (2) 9,085.54 91.99 357.33 6,782.66 6,686.66 3,896.25 -267.52 5,983,923.11 548,899.03 5.51 3,896.25 MWD (2) 9,115.62 92.70 355.51 6,781.42 6,685.42 3,926.24 -269.40 5,983,953.09 548,896.96 6.49 3,926.24 MWD (2) 9,145.86 93.69 354.31 6,779.74 6,683.74 3,956.32 -272.07 5,983,983.14 548,894.08 5.14 3,956.32 MWD (2) 9,175.54 94.43 352.32 6,777.64 6,681.64 3,985.72 -275.52 5,984,012.51 548,890.44 7.14 3,985.72 MWD (2) 9,205.53 93.13 351.88 6,775.66 6,679.66 4,015.36 -279.63 5,984,042.12 548,886.13 4.58 4,015.36 MWD (2) 9,235.80 91.17 349.77 6,774.52 6,678.52 4,045.22 -284.46 5,984,071.95 548,881.12 9.51 4,045.22 MWD (2) 9,265.40 91.38 347.93 6,773.87 6,677.87 4,074.25 -290.18 5,984,100.94 548,875.20 6.26 4,074.25 MWD (2) 9,295.50 91.01 346.24 6,773.24 6,677.24 4,103.58 -296.90 5,984,130.22 548,868.29 5.75 4,103.58 MWD (2) 9,325.13 91.69 344.98 6,772.54 6,676.54 4,132.27 -304.27 5,984,158.86 548,860..74 4.83 4,132.27 MWD (2) 9,357.32 90.58 342.65 6,771.90 6,675.90 4,163.18 -313.24 5,984,189.71 548,851.57 8.02 4,163.18 MWD (2) 9,390.81 90.31 339.18 6,771.64 6,675.64 4,194.82 -324.18 5,984,221.27 548,840.41 10.39 4,194.82 MWD (2) 9,420.44 89.02 337.36 6,771.82 6,675.82 4,222.34 -335.15 5,984,248.72 548,829.26 7.53 4,222.34 MWD (2) 9,450.44 89.82 335.94 6,772.12 6,676.12 4,249.88 -347.04 5,984,276.18 548,817.19 - 5.43 4,249.88 MWD (2) - 9,480.42 89.29 338.67 6,772.35 6,676.35 4,277.54 -358.61 5,984,303.76 548,805.45 9.28 4,277.54 MWD (2) 9,510.71 88.71 340.45 6,772.88 6,676.88 4,305.92 -369.18 5,984,332.06 548,794.69 6.18 4,305.92 MWD (2) 9,540.51 86.99 341.37 6,774.00 6,678.00 4,334.06 -378.92 5,984,360.13 548,784.76 6.54 4,334.06 MWD (2) 9,570.26 86.50 343.42 6,775.69 6,679.69 4,362.37 -387.91 5,984,388.38 548,775.60 7.07 4,362.37 MWD (2) 9,599.92 86.87 345.71 6,777.40 6,681.40 4,390.91 -395.79 5,984,416.86 548,767.53 7.81 4,390.91 MWD (2) 9,630.99 86.99 348.24 6,779.07 6,683.07 4,421.13 -402.78 5,984,447.04 548,760.34 8.14 4,421.13 MWD (2) - 9,661.27 86.04 349.68 6,780.91 6,684.91 4,450.79 -408.57 5,984,476.66 548,754.36 5.69 4,450.79 MWD (2) 9,690.46 86.31 351.59 6,782.86 6,686.86 4,479.53 -413.30 5,984,505.36 548,749.43 6.59 4,479.53 MWD (2) 9,720.31 87.88 351.74 6,784.37 6,688.37 4,509.03 -417.63 5,984,534.83 548,744.92 5.28 4,509.03 MWD (2) 9,750.06 90.18 352.79 6,784.87 6,688.87 4,538.50 -421.63 5,984,564.27 548,740.72 8.50 4,538.50 MWD (2) 9,780.05 91.78 353.16 6,784.36 6,688.36 4,568.26 -425.30 5,984,594.00 548,736.86 5.48 4,568.26 MWD (2) 9,810.52 93.72 353.72 6,782.90 6,686.90 - 4,598.49 -428.77 5,984,624.21 548,733.18 6.63 4,598.49 MWD (2) 9,843.75 94.09 355.09 6,780.63 6,684.63 4,631.49 1332.01 5,984,657.18 548,729.73 4.26 4,631.49 MWD (2) 1/27/2017 1:51:53PM Page 5 COMPASS 5000,1 Build 74 Annotation ri.I BAKER HUGHES 1/27/2017 1:51:53PM Page 6 COMPASS 5000 1 Build 74 ConocoPhillips ConocoPhillips Definitive Survey Report Company: ConocoPhillips (Alaska) Inc. -Kupl Local Co-ordinate Reference: Well 1 H-16 Project: Kuparuk River Unit TVD Reference: 1 H-16 @ 96.00usft (1 H-16) Site: Kuparuk 1 H Pad MD Reference: 1 H-16 @ 96.00usft (1 H-16) Well: 11-1-16 North Reference: True Wellbore: 1H-16 Survey Calculation Method: Minimum Curvature Design: 11-1-16 Database: EDM Alaska NSK Sandbox Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/ -S +E1 -W NorthingEasting DLS Section Survey Tool Name (usft) (°) (°) (usft) (usft) (usft) (usft) (ft) (ft) (°1100') (ft) 9,870.00 94.45 355.27 6,778.68 6,682.68 4,657.57 -434.21 5,984,683.25 548,727.36 1.53 4,657.57 MWD (2) 9,900.70 92.52 355.19 6,776.81 6,680.81 4,688.11 -436.75 5,984,713.76 548,724.62 6.29 4,688.11 MWD (2) 9,930.82 94.70 355.39 6,774.92 6,678.92 4,718.06 -439.22 5,984,743.70 548,721.95 7.27 4,718.06 MWD (2) 9,960.15 94.30 355.55 6,772.62 6,676.62 4,747.21 -441.53 5,984,772.83 548,719.45 1.47 4,747.21 MWD (2) 9,990.70 92.73 355.87 6,770.74 6,674.74 4,777.62 -443.81 5,984,803.21 548,716.97 5.24 4,777.62 MWD (2) 10,020.36 89.94 355.31 6,770.05 6,674.05 4,807.18 -446.09 5,984,832.76 548,714.50 9.59 4,807.18 MWD (2) 10,050.75 88.65 356.01 6,770.43 6,674.43 4,837.48 -448.39 5.984,863.04 548,712.00 4.63 4,837.48 MWD (2) 10,080.03 90.09 357.02 6,770.75 6,674.75 4,866.70 -450.17 5,984,892.25 548,710.03 6.01 4,866.70 MWD (2) 10,110.47 89.63 359.58 6,770.82 6,674.82 4,897.12 -451.07 5,984,922.66 548,708.92 8.54 4,897.12 MWD (2) 10,140.26 89.54 1.82 6,771.04 6,675.04 4,926.91 -450.71 5,984,952.44 548,709.09 7.53 4,926.91 MWD (2) 10,169.94 88.65 3.65 6,771.51 6,675.51 4,956.55 -449.29 5,984,982.09 548,710.31 6.86 4,956.55 MWD (2) 10,216.00 88.65 3.65 6,772.59 6,676.59 5,002.50 -446.36 5,985,028.06 548,712.94 0.00 5,002.50 PROJECTED to TD Annotation ri.I BAKER HUGHES 1/27/2017 1:51:53PM Page 6 COMPASS 5000 1 Build 74 RECEIVED FEB 0 3 2017 WELL LOG TRANSMITTAL #903738108 AOGCCi To: Alaska Oil and Gas Conservation Comm. Attn.: Makana Bender 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: Multi Finger Caliper: 1H -16A Run Date: 12/20/2016 21 6159 27 95 2 January 27, 2017 DATA LOGGED 2/G/2o1-7 d K. BENDER The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Chris Gullett, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 FRS—ANC@halliburton.com 1H -16A Digital Data (LAS), Digital Log file, Casing Inspection Report, 3D Viewer 1 CD Rom 50-029-22315-01 Multi Finger Caliper (Field Log) 1 color log 50-029-22315-01 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline & Perforating Attn: Chris Gullett 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907-273-3527 Fax: 907-273-3535 FRS_ANC @halliburton.com Date: Signed: ,�v 45-4u� STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION RECEIVED FEB 0 12017 WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1a. Well Status: oil Gas❑ SPLUG ❑ Other ❑ Abandoned ❑ Suspended[] 20AAC 25.105 20AAC 25.110 GINJ ❑ WINJ ❑ WAG❑ WDSPL ❑ No. of Completions: 1b. Well Class: Development E Exploratory ❑ Service ❑ Stratigraphic Test ❑ 2. Operator Name: ConocoPhillips Alaska, Inc. 6. Date Comp., Susp., or Aband.: 0%ltd42,� 14. Permit to Drill Number / Sundry: 216-159 / 3. Address: P.O. Box 100360 Anchorage, AK 99510-0360 7. Date Spudded: _._"'__5 lZ/2I t(o 15. API Number: 50-029-22315-01-00 4a. Location of Well (Governmental Section): Surface: 672' FNL, 11 56'FEL, Sec 33, T12N, R1 OE, UM Top of Productive Interval: 3887' FNL, 1139' FEL, Sec 28, T12N, R10E, UM Total Depth: 949' FNL, 1591' FEL, Sec 28, T12N, R1 OE, UM 8. Date TD Reached: +2424;2e G i4isko 16. Well Name and Number: KRU 1 H-1 6A ` 9. Ref Elevations: KB:9 GL: 54 BF: 17. Field / Pool(s): Kuparuk River Field/Kuparuk River Oil Pool 10. Plug Back Depth MD/TVD: N/A 4LJe5 v (p('(y"�" 18. Property Designation: ADL 25639 , 4b. Location of Well (State Base Plane Coordinates, NAD 27): Surface: x- 549192 y- 5980029 Zone -4 TPI: x- 549190 y- 5982093 Zone -4 Total Depth: x- 548713 y- 5985028 Zone -4 11. Total Depth MD/TVD: f0 10216/633 (,p r7 Sj 19. Land Use Permit: ALK 464 12. SSSV Depth MD/TVD: 1793/1793 20. Thickness of Permafrost MD/TVD: 1600/1600 5. Directional or Inclination Survey: Yes FZ] (attached) No ❑ Submit electronic and printed information per 20 AAC 25.050 13. Water Depth, if Offshore: (ft MSL) 21. Re-drill/Lateral Top Window MD/TVD: 7138/6592 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 SETTING DEPTH TVD WT. PER GRADE SETTING DEPTH MD HOLE SIZE CASING FT TOP BOTTOM TOP BOTTOM AMOUNT CEMENTING RECORD PULLED 16 62.5 H-40 41 121 41 121 24 200 sx CSI 9.625 40 L-80 40 2672 40 2671 12.25 570 sx PF E CMT, 190 SX Class G 150 sx PF C Top Job 7 26 J-55 1 39 17485 39 6887 18.5 590 sx Class G CMT 23/8 4.6 L-80 1 7402 110216 6672 16773 13 Slotted Liner 24. Open to production or injection? Yes 2 No ❑ If Yes, list each interval open (MD/TVD of Top and Bottom; Perforation Size and Number): SLOTTED LINER @ 7402 -10216 MD and 6672 - 6773 TVD ,-OR^PI ET;0i', npTF. /,AT PieIF r 25. TUBING RECORD SIZE DEPTH SET (MD) PACKER SET (MD/TVD) 31/2 6841 6805/6312 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: 1/13/2017 Method of Operation (Flowing, gas lift, etc.): GAS LIFT Date of Test: 1/16/2017 Hours Tested: 8hrs Production for Test Period Oil -Bbl: 309 Gas -MCF: 528 Water -Bbl: 180 Choke Size: 176 bean Gas -Oil Ratio: 1 1710 scf/stb Flow Tubing Press. 217 Casinq Press: 1124 Calculated 24 -Hour Rate Oil -Bbl: 856 Gas -MCF: 1647 Water -Bbl: 534 Oil Gravitv - API (corr): 23.5 Form 10-407 Revised 11/2015 _ �, Zl �7 O/�__CONTINUED ON PAGE 2 RBDMS V- FEB - 2 2017 Submit ORIGINIAL or,,),G 28. CORE DATA Conventional Core(s): Yes ❑ No 21 Sidewall Cores: Yes ❑ No 0 If Yes, list formations and intervals cored (MD/TVD, From/To), and summarize lithology and presence of oil, gas or water (submit separate pages with this form, if needed). Submit detailed descriptions, core chips, photographs, and all subsequent laboratory analytical results per 20 AAC 25.071. 29. GEOLOGIC MARKERS (List all formations and markers encountered): 30. FORMATION TESTS NAME MD TVD Well tested? Yes ❑ No El If yes, list intervals and formations tested, briefly summarizing test results. Permafrost - Top Surface Surface Permafrost - Base 1454 1646 Attach separate pages to this form, if needed, and submit detailed test Top of Productive Interval 7203 6641 information, including reports, per 20 AAC 25.071. Total Depth 10216 6373 Formation at total depth: Ku aruk A Sand 31. List of Attachments: Daily Operations Summary, Definitive Survey, Schematic Information to be attached includes, but is not limited to: summary of daily operations, wellbore schematic, directional or inclination survey, core analysis, i)aleontoloaical rer)ort, production or well test results, i)er 20 AAC 25.070. 32. 1 hereby certify that the foregoing is true frid correct to the best of my knowledge. Contact: Mike Ca n 263-4180 Email: Mike. Callahan co .com Printed Name: G. Eller Title: Lead CTD Engineer Signature: Phone: 263-4172 Date: 3 INSTRUCTIONS �aachments General: This form and the requi 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 1 H-16 Proposed CTD Schematic 16" 62# H-40 shoe at 121' MD 9-5/8" 40# L-80 shoe at 2672' MD C -sand perts (sgz'd) ; 6914'-6974' MD 7013'-7033' MD and perts (sqz'd) 8'-7243' MD 7.'26# J-55 shoe at 7485' MD Modified by RLP 1/3/2017 3-1/2" TRDP-4A SSSV at 1793' MD (includes 2.813" X -profile) 3-1/2" 9.3# J-55 EUE 8rd Tubing to surface 3-1/2" Camco KBUG gas lift mandrels at 2498', 3930', 4634', 5337', 6071', & 6426' 3-1/2" Camco MMG gas lift mandrel at 6755' Baker GBH -22 Locator Seal Assembly at 6803' MD Baker FB -1 packer 6805' MD Otix XN landing nipple 6828' MD (2.80" min ID) 3-1/2" tubing tail at 6840' MD IKOP@7138'MD iH-111ALI wp02. West TD at 8601' MD Liner Top at 6833' MD M-164L1PBi TDM-164L1PB/ TD at 9641' MD Billet �t @81W MD e 1H-i6A Wp01, Nonh TD at 10040' MD Liner Billet .17500' MD Operations Summary (with Timelog Depths) 1H-16 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time I our (hr) Phase Op Code Activity Code Time P -T -X Operation (ftKB) End Depth (ftKB) 12/17/2016 12/18/2016 12.00 MIRU MOVE MOB P Mob from 2X-13 to 1H-16, Leave 0.0 0.0 12:00 00:00 location 16:00 Arrive 1 H pad @ 21:00. Remove jeeps, spot drilling sub over the well. 12/18/2016 12/18/2016 1.50 MIRU MOVE MOB P On location, spot pit sub, safe out 0.0 0.0 00:00 01:30 walkways and landings 12/18/2016 12/18/2016 2.50 MIRU MOVE RURD P Start working rig up checklist, Connect 0.0 0.0 01:30 04:00 PUTZ, get steam around 12/18/2016 12/18/2016 2.00 MIRU MOVE NUND P Prep tree and set down stack, nipple 0.0 0.0 04:00 06:00 up BOP 12/18/2016 12/18/2016 2.40 MIRU MOVE RURD P Crew change, Work check list, C/O 4' 0.0 0.0 06:00 08:24 riser to 3', Measure stack, Perform valve checklist 12/18/2016 12/18/2016 0.60 MIRU WHDBOP RURD P PJSM for full BOPE test, fluid pack 0.0 0.0 08:24 09:00 stack. Leaking between Swab #1 & Swab #2. Tighten flange between swab valves. 12/18/2016 12/18/2016 9.00 MIRU WHDBOP BOPE P Start BOP test (3,500 psi / 250 psi, 0.0 0.0 09:00 18:00 2,500 psi annular). Pin hole in MP line. Replace line. **RIG ACCEPT 09:00- 12/18/2016 12/18/2016 3.00 MIRU WHDBOP BOPE T Finished testing that does not require 0.0 0.0 18:00 21:00 MV. Test lower blinds against MV - fail. Close SSV, re -try test - fail. Open lower blinds, close upper blinds (already tested), re -test - pass. Open upper blinds, close lower blinds, re -test - fail (no fluid leaking at rig floor). Open SSV (which failed pre -rig DHD testing), grease MV, re -test lower blinds against MV - high & low pass. 12/18/2016 12/19/2016 3.00 MIRU WHDBOP BOPE P Cont. BOP test 0.0 0.0 21:00 00:00 12/19/2016 12/19/2016 0.70 MIRU WHDBOP BOPE P Cont initial BOP test (3500 psi / 250 0.0 0.0 00:00 00:42 psi, 2500 psi annular) 12/19/2016 12/19/2016 0.50 MIRU WHDBOP BOPE T Generators went down. 0.0 0.0 00:42 01:12 *0.5 hrs NPT for Nabors* 12/19/2016 12/19/2016 0.80 MIRU WHDBOP BOPE P Finish BOP testing. 0.0 0.0 01:12 02:00 *3 hrs NPT for Nabors due to 17 hr total BOP test time w/ 4 hrs backed out for trouble with MV & swabs* 12/19/2016 12/19/2016 1.50 MIRU WHDBOP PRTS P PT ODS PDL and TT line while 0.0 0.0 02:00 03:30 waiting on external coil connector and pull plate. Generators shut down when pumps came on, troubleshoot. 12/19/2016 12/19/2016 2.50 SLOT WELLPR CTOP P Trim marked / scared up CT 24', MU 0.0 0.0 03:30 06:00 external coil connector and pull plate. Overpull to 15k to ensure made up properly. 12/19/2016 12/19/2016 0.50 SLOT WELLPR CTOP P Crew change out, Valve check list 0.0 0.0 06:00 06:30 Page 1/17 Report Printed: 1/16/2017 Operations Summary (with Timelog Depths) 3 _ 1H-16 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Depth. Start Time End Time our (hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth (ftKB) 12/19/2016 12/19/2016 3.70 SLOT WELLPR CTOP P PJSM, Prep to pull test injector. Test 0.0 0.0 06:30 10:12 in stepwise manor 30K, 60K and 90K with 80OPSI tension pressure. Traction per pressure vs pull. No marks on pipe. Lower tension to 500 PSI. Traction to auto. First test produced no marks. Came up to top out speed and retest. Made marks 10' up from pull plate 12/19/2016 12/19/2016 3.70 SLOT WELLPR CTOP P PJSM, Cut 30' of CT - Boot wire. 0.0 0.0 10:12 13:54 Reverse circulate coil. Unstab injector. Trim 20' of coil to find wire ( Cut total of 74' CT) 12/19/2016 12/19/2016 1.50 SLOT WELLPR CTOP P PJSM - Prep Coil and install CTC 0.0 0.0 13:54 15:24 connector - Pull test to 35K 12/19/2016 12/19/2016 1.00 SLOT WELLPR CTOP P PJSM, Head up eline to UQC and test 0.0 0.0 15:24 16:24 wire, 550MOhmes / 63 Ohmes Good test 12/19/2016 12/19/2016 3.30 SLOT WELLPR OTHR P Skid injector back - R/U to pull BPV. 0.0 0.0 16:24 19:42 Lubricator has some frozen ports, BPV out, Lay down BPV lubricator. WHP=950 PSI 12/19/2016 12/19/2016 0.20 SLOT WELLPR CTOP P PT CTC / UQC to 4000 PSI 0.0 0.0 19:42 19:54 12/19/2016 12/19/2016 1.10 SLOT WELLPR PRTS P Skid injector on well, valve frozen on 0.0 0.0 19:54 21:00 TT line, thaw, PT TT line, Bleed off well. 12/19/2016 12/19/2016 0.50 SLOT WELLPR OWFF P Flow check well. 0.0 0.0 21:00 21:30 12/19/2016 12/19/2016 1.50 PROD1 RPEQPT PULD P PJSM - M/U BHA #1 Cement pilot 0.0 62.0 21:30 23:00 hole BHA with D-331 slick guage (2.8" NoGo) and 0.9 AKO motor 12/19/2016 12/20/2016 1.00 PROD1 RPEQPT TRIP P RIH BHA #1 pumping 1 BPM of SW 62.0 6,500.0 23:00 00:00 displacing diesel out of wellbore. 12/20/2016 12/20/2016 0.20 PROD1 RPEQPT TRIP P Cont RIH BHA#1 6,500.0 6,740.0 00:00 00:12 12/20/2016 12/20/2016 0.20 PROD1 RPEQPT DLOG P Tie-in to K1 for a +5.5' correction. 6,740.0 6,764.0 00:12 00:24 12/20/2016 12/20/2016 0.10 PROD1 RPEQPT TRIP P Cont RIH and tag-up @ 6,837'. 6,764.0 6,837.0 00:24 00:30 12/20/2016 12/20/2016 0.60 PROD1 RPEQPT CIRC P PUH, swap to used PowerPro mud for 6,837.0 6,837.0 00:30 01:06 milling. PUW=34k. Close EDC. RBIH. 12/20/2016 12/20/2016 1.30 PROD1 RPEQPT MILL P Couple stalls to get started milling 6,837.0 6,893.0 01:06 02:24 cement. Milled cement for -0.5'. Minimal WOB, increased ROP to 50+ FPH to find cement. 12/20/2016 12/20/2016 2.30 PROD1 RPEQPT MILL P WOB increased @ 6,893', however, 6,893.0 7,000.0 02:24 04:42 ROP has remained in the 40-50 FPH range (suspect cement integrity). 12/20/2016 12/20/2016 0.20 PROD1 RPEQPT WPRT P PUH to 6,780' to ensure hole clean. 7,000.0 7,000.0 04:42 04:54 RBIH. 12/20/2016 12/20/2016 4.80 PROD1 RPEQPT MILL P Milling ahead, WOB 2.2k, ROP 45 7,000.0 7,180.0 04:54 09:42 12/20/2016 12/20/2016 2.86 PROD1 RPEQPT REAM P At Pilot Hole TD of 7,180 ft. Make a 7,180.0 6,820.0 09:42 12:33 dry drift and observe a weight bobble at 6,850 ft / 6,855 ft. Dress off area of interest at a low side orientation and then begin making backreaming passes as per procedure. Page 2/17 Report Printed: 1/16/2017 Operations Summary (with Timelog Depths) t 1H-16 k' ty Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time Dur (hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth (ftKB) 12/20/2016 12/20/2016 0.55 PROD1 RPEQPT OWFF P Conduct a No-Flow Test prior to 6,820.0 6,820.0 12:33 13:06 POOH. No-Flow Test was good. 12/20/2016 12/20/2016 1.58 PROD1 RPEQPT TRIP P POOH pumping at 1.7 bpm 6,820.0 71.4 13:06 14:41 12/20/2016 12/20/2016 0.60 PROD1 RPEQPT OWFF P At surface. Monitor well once again for 71.4 71.4 14:41 15:17 a 30 minute No-flow Test. 12/20/2016 12/20/2016 1.34 PROD1 RPEQPT PULD P L/D Pilot Hole Milling BHA#1 71.4 0.0 15:17 16:37 12/20/2016 12/20/2016 2.00 PROD1 RPEQPT WPRT P RBIH and Jet Stack, Change out, 0.0 0.0 16:37 18:37 blow down chokes, opeen and inspect, 12/20/2016 12/20/2016 0.70 PROD1 RPEQPT WPRT P Pull and lay down Mouse hole #1 in 0.0 0.0 18:37 19:19 preperation to lay down PDL #1 12/20/2016 12/20/2016 0.40 PROD1 RPEQPT PULD P Halliburton Logging on location, 0.0 0.0 19:19 19:43 unoad tools, make up same in pipe shed. 12/20/2016 12/20/2016 0.90 PROD1 RPEQPT PULD P PJSM, make up tools BHA # 2 24 arm 0.0 24.8 19:43 20:37 caliper, bump up, zero. 12/20/2016 12/20/2016 2.40 PROD1 RPEQPT TRIP P RIH, shallow tool test at 300, good, 24.8 7,170.0 20:37 23:01 RIH. Tie into K1 for + 5.5' correction 12/20/2016 12/20/2016 0.20 PROD1 RPEQPT TRIP P When pulling off bottom, observed 7,170.0 7,033.0 23:01 23:13 some noise from the injector, increased chain traction from 830 to 1020 psi, noise subsided. Observed a few small marks in the coil. retracted caliper arms. 12/20/2016 12/20/2016 0.30 PROD1 RPEQPT TRIP P RBIH,inspect pipe and buffed out with 7,033.0 7,170.0 23:13 23:31 file and emery cloth. RBIH Pull up hole with no noise or indication of chain slip. RIH to logging depth 12/20/2016 12/20/2016 0.30 PROD1 RPEQPT DLOG P Open caliper arms and POOH @ 45 7,170.0 6,700.0 23:31 23:49 fp/min logging pilot hole from 7170 - 6700'. Note fingers 4.55' feet up from bottom of caliper, bottom of log starts at 7165.45' RBIH 12/20/2016 12/21/2016 0.17 PROD1 RPEQPT DLOG P RBIH 6,700.0 7,170.0 23:49 00:00 12/21/2016 12/21/2016 0.30 PROD1 RPEQPT DLOG P Perform second logging pass over 7,170.0 6,700.0 00:00 00:18 same interval at 45 ft/min. Note fingers 4.55' feet up from bottom of caliper, bottom of log starts at 7165.45 12/21/2016 12/21/2016 1.30 PROD1 RPEQPT TRIP P Retract caliper arms and POOH 6,624.0 25.8 00:18 01:36 12/21/2016 12/21/2016 1.00 PROD1 RPEQPT PULD P Bump up, 30 min flow check - good. 25.8 0.0 01:36 02:36 PJSM, LD BHA #2. 12/21/2016 12/21/2016 1.00 PROD1 RPEQPT PULD P PJSM, PU BHA #3, whipstock, Open 0.0 74.3 02:36 03:36 EDC, tag up. 12/21/2016 12/21/2016 1.50 PROD1 RPEQPT TRIP P RIH w whipstock, 90 fpm. Tie in at the 74.3 6,770.0 03:36 05:06 K1 for a +4.5' correction, Wt ck, 38k lbs. Pumps down, close EDC, zero WOB. 12/21/2016 12/21/2016 0.55 PROD1 RPEQPT WPST P RIH, Online with the pump, pressure 6,770.0 7,180.0 05:06 05:39 broke back at 3611 psi. Set whipstock at 7150' and 0 deg ROHS. Attempt to set 5k down, unable to stack weight. Consultwith town, push whipstock to bottom. Page 3/17 ReportPrinted: 1/16/2017 Operations Summary (with Timelog Depths) }l 1H-16 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time Dur (hr) Phase Op Code Activity Code Time P -T -X Operation (ftKB) End Depth (ftKB) 12/21/2016 12/21/2016 0.51 PROD1 RPEQPT WPST T Whipstock on bottom at 7,180.6 ft. 7,180.0 7,180.0 05:39 06:09 Release from Whipstock. 12/21/2016 12/21/2016 1.44 PROD1 RPEQPT TRIP T POOH. 7,169.0 78.9 06:09 07:36 12/21/2016 12/21/2016 0.55 PROD1 RPEQPT OWFF T At surface. Perform 30 minute No- 78.9 78.9 07:36 08:09 Flow Test. Hold Undeploy PJSM while waiting on flow test. Note: Just recieved email confirmation on plan forward @ 0739 hrs.. Will set a second Whipstock w/OH Anchor. tows depth will be 7,138 ft (12 ft higher than previous attempt) oriented 5 deg ROHS. 12/21/2016 12/21/2016 0.65 PROD1 RPEQPT PULD T L/DBHA #3. 0.0 0.0 08:09 08:48 Note: Shear stud had all threads on rod and also was in stroked position as it should be. 12/21/2016 12/21/2016 3.00 PROD1 RPEQPT WAIT T Wait on new whipstock to be sent from 0.0 0.0 08:48 11:48 Baker in Deadhorse. 12/21/2016 12/21/2016 0.88 PROD1 RPEQPT PULD T Baker shows up with Whipstock #2. 0.0 72.9 11:48 12:40 P/U BHA #4 with second Whipstock. Open EDC, tag up. 12/21/2016 12/21/2016 1.89 PROD1 RPEQPT TRIP T RIH w whipstock, 80 fpm. Tie in at the 72.9 6,777.0 12:40 14:34 K1 for a +5' correction, Wt ck, 38k lbs. Pumps down, close EDC, zero WOB. 12/21/2016 12/21/2016 0.96 PROD1 RPEQPT WPST T RIH, Online with the pump, having 6,777.0 7,138.0 14:34 15:31 trouble getting the whipstock to set. Have taken the pump pressure up to 6,800 psi numerous times with no luck We set down 10k while pumping, but little overpull when PUH. It appears the OH Anchors have set. We are having difficulty now releasing from the Whipstock. PUH again and now appears we have released off the Whipstock. Set whipstock at 7138' and 5 deg ROHS. 12/21/2016 12/21/2016 1.44 PROD1 RPEQPT TRIP P POOH with open EDC pumping at 7,138.0 70.0 15:31 16:58 1.46 bpm 12/21/2016 12/21/2016 0.55 PROD1 RPEQPT OWFF P At surface. Perform 30 minute No- 70.0 70.0 16:58 17:31 Flow Test. Hold PJSM while waiting on flow test. 12/21/2016 12/21/2016 1.40 PROD1 RPEQPT PULD P L/D BHA #4 and P/U BHA#5 Window 70.0 74.3 17:31 18:55 Milling BHA 12/21/2016 12/21/2016 1.80 PROD1 WHPST TRIP P RIH with Window Milling BHA, 90 fpm. 74.3 7,138.0 18:55 20:43 Tie in at the K1 for a +4.5' correction, Wt ck, 37k lbs. Pumps down, close EDC, zero WOB. 12/21/2016 12/21/2016 2.28 PROD1 WHPST WPST P Tag up @ 7138'. pick up 38k lbs, park 7,138.0 7,139.0 20:43 23:00 and increase pumps to drilling rate 1.80 bpm, CT off bottom, 4170 psi, diff, 512 psi, Stack WOB 2 klbs, 759 diff, 7137,50' Time milling. 12/21/2016 12/22/2016 1.00 PROD1 WHPST WPST P 1.81 bpm, CT 4228 psi, diff, 800 psi, 7,139.0 7,139.9 23:00 00:00 WOB 3.43 k lbs, ROP 0.6 fph, Page 4/17 Report Printed: 1/16/2017 Operations Summary (with Timelog Depths) n r IH -16 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time Dur (hr) Phase Op Code Activity Code Time P -T -X Operation (ftKB) End Depth (ftKB) 12/22/2016 12/22/2016 3.00 PROD1 WHPST WPST P 1.81 bpm, CT 4293 psi, diff, 861 psi, 7,139.9 7,142.0 00:00 03:00 WOB 3.89 k lbs, ROP 0.5 fph, 12/22/2016 12/22/2016 1.00 PROD1 WHPST WPST P 1.81 bpm, CT 4123 psi, diff, 696 psi, 7,142.0 7,143.0 03:00 04:00 WOB 1.78 k lbs, ROP 0.8 fph 12/22/2016 12/22/2016 3.75 PROD1 WHPST WPST P 1.81 bpm, CT 4033 psi, diff, 639 psi, 7,143.0 7,159.0 04:00 07:45 WOB 0.63 k lbs, ROP 2 fph 12/22/2016 12/22/2016 1.00 PROD1 WHPST REAM P At window exit TD of 7,159 ft. Make 7,159.0 7,126.0 07:45 08:45 several reaming passes and a final dry drift through window. Vey smooth dry drift....... no WOB bobbles. 12/22/2016 12/22/2016 1.94 PROD1 WHPST TRIP P POOH after pumping a 5 x 5 sweep 7,126.0 79.8 08:45 10:41 and chase to surface with and open EDC. PUW = 37.5k 12/22/2016 12/22/2016 1.44 PROD1 WHPST PULD P At surface. Conduct Pressure 79.8 79.8 10:41 12:07 Undeploy Operations after PJSM. 12/22/2016 12/22/2016 0.75 PROD1 WHPST PULD P L/D BHA #5 79.8 0.0 12:07 12:52 Note: String Mill and Window Mill 2.79" No -Go 12/22/2016 12/22/2016 1.49 PROD1 DRILL SVRG P Nabors takes their daily 1 hour 0.0 0.0 12:52 14:22 maintenance to install whipchecks on high pressure return hose line and to pressure test the Driller's side PDL 12/22/2016 12/22/2016 0.70 PROD1 DRILL PULD P P/U BHA #6 w/Build Drilling Assembly 0.0 72.9 14:22 15:04 12/22/2016 12/22/2016 1.00 PROD1 DRILL PULD P Pressure Deploy BHA #6 after PJSM. 72.9 72.9 15:04 16:04 12/22/2016 12/22/2016 1.60 PROD1 DRILL TRIP P RIH with open EDC pumping at 1.5 72.9 6,700.0 16:04 17:40 bpm 12/22/2016 12/22/2016 0.30 PROD1 DRILL DLOG P Log for K1 Marker and make 6,700.0 6,800.0 17:40 17:58 correction of +7.5' 12/22/2016 12/22/2016 0.80 PROD1 DRILL TRIP P Swap hole over to new mud, System 6,800.0 7,150.0 17:58 18:46 #1 Close EDc, Wt Ck, 41 k Ibs,RIH 12/22/2016 12/22/2016 2.80 PROD1 DRILL DRLG P Drilling rate, 1.76 bpm, CT 4000 psi, 7,159.0 7,355.0 18:46 21:34 off bottom diff 520 psi. RIH Wt 12.9k lbs, CT Wt 14.6k lbs, WOB 1.3k lbs, ROP 60 OBD. ROP increased from 60 to -120 fph as we cut into A4 pay finioshed TD of build @ 12/22/2016 12/22/2016 1.90 PROD1 DRILL TRIP P TD build section, PUH, Wt 42k lbs. 7,355.0 79.0 21:34 23:28 Drive by, RA tag at 7143.5', six feet below original TOW tag, 7137.5'. Park at 6800', open EDC, POOH pumping 1,22 bpm 12/22/2016 12/23/2016 0.53 PROD1 DRILL PULD P At surface. PJSM, PUD BHA #6, build 79.8 79.8 23:28 00:00 drilling assembly, crew change. PJSM, continue PUD. 12/23/2016 12/23/2016 0.70 PROD1 DRILL PULD P Continue PUD BHA#6. 79.8 0.0 00:00 00:42 12/23/2016 12/23/2016 0.70 PROD1 DRILL PULD P UD BHA #6 0.0 0.0 00:42 01:24 12/23/2016 12/23/2016 0.40 PROD1 DRILL PULD P P/U BHA #7. A lat drilling assembly. 0.0 0.0 01:24 01:48 12/23/2016 12/23/2016 1.40 PROD1 DRILL PULD P PJSM, Pressure Deploy BHA #7 0.0 78.0 01:48 03:12 Page 5117 Report Printed: 1 /1 612 01 7 Operations Summary (with Timelog Depths) fi Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time Dur (hr) Phase Op Code Activity Code Time P -T -X Operation (ftKB) End Depth (ftKB) 12/23/2016 12/23/2016 1.20 PROM DRILL TRIP P RIH, EDC open, pumping min rate. 78.0 6,700.0 03:12 04:24 12/23/2016 12/23/2016 0.20 PROD1 DRILL DLOG P Tie into K1 for+6' correction, Wt Ck, 6,700.0 6,772.0 04:24 04:36 34k lbs, Close EDC. 12/23/2016 12/23/2016 0.58 PROM DRILL TRIP P RIH, 6,772.0 7,355.0 04:36 05:10 12/23/2016 12/23/2016 4.60 PROD1 DRILL DRLG P 1.80 bpm, Off bottom, CT 4392 psi, 7,355.0 7,810.0 05:10 09:46 diff 711 psi, BOBD, CT Wt 12.6 k lbs, WOB 1.11 k lbs, ROP 87 ft/hr Perform numerous BHA wiper trips due to weight transfer issues and to faciliate tool face changes. Average ROP was approximately 112 fph. Encountered Ankerite only briefly. 12/23/2016 12/23/2016 0.68 PROD1 DRILL WPRT P Perform a wiper trip to the window so 7,810.0 6,756.0 09:46 10:27 the K1 and RA can be logged. Average ROP was approx. 112 fph. Encountered Ankerite only briefly. Crossed an unexpected Fault A at 7,758 ft. Geo thinks its a 15 ft down turn...... 12/23/2016 12/23/2016 0.37 PROM DRILL DLOG P RBIH logging the K1 and then the 6,756.0 7,189.0 10:27 10:49 RA.............correction at K1 was +2.0 ft and the RA came exactly where it should have at 7,744 ft. 12/23/2016 12/23/2016 0.40 PROM DRILL TRIP P After logging the K1 and the RA, 7,189.0 7,810.0 10:49 11:13 continue RBIH to bottom. 12/23/2016 12/23/2016 3.76 PROM DRILL DRLG P BOBD. 1.80 bpm, CTP 5,026 Diff 7,810.0 8,260.0 11:13 14:59 1,230 CTW 8 klb WOB 2.23 ROP 178 fph IA 649 OA 293 WHP 409 After crossing Fault A we had turned down thinking it was a 15 ft down turn. Instead the fault was a 17 ft Up thrown. Decision made to not chase the pay and instead turn slightly down until crossing Fault 1 at 8,120 ft and he can determine where we are at. 12/23/2016 12/23/2016 0.68 PROM DRILL WPRT P Perform a 859 ft wiper trip. Average 8,260.0 8,260.0 14:59 15:40 ROP was around 119 fph. 12/23/2016 12/23/2016 3.33 PROM DRILL DRLG P BOBD. 1.80 bpm, CTP 5,232 Diff 8,260.0 8,710.0 15:40 19:00 1,276 CTW 3.1 klb WOB 2.03 ROP 197 fph IA 142 OA 315 WHIP 322 12/23/2016 12/23/2016 1.20 PROM DRILL WPRT P PUH, wiper to window to tie in. PU Wt 8,692.0 6,751.0 19:00 20:12 43K lbs 12/23/2016 12/23/2016 1.20 PROM DRILL DLOG P Tie into K1 for + 3.5' correction RBIH 6,751.0 8,692.0 20:12 21:24 Note, Sat down twice at 8545' and 8565' in some areas of high gamma in the A5. 12/23/2016 12/23/2016 1.50 PROM DRILL DRLG P Off bottom,RIH Wt 9.6k 1.80 bpm, CT 8,710.0 8,871.0 21:24 22:54 4844 psi, diff 758 psi. BOBD, CT 5014 psi, 952 psi diff, Ct Wt 7.4 k lbs, WOB 2.33 k lbs ROP 188 ft/hr 12/23/2016 12/23/2016 1.00 PROM DRILL WPRT P Pull Geo wiper trip, jogging from 8900 8,871.0 8,871.0 22:54 23:54 to 8700' PU Wt 47k Ib Told to turn down. RBIH Page 6/17 Report Printed: 1/16/2017 Operations Summary (with Timelog Depths) �j ; 1H-16 •,_ Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time our (hr) Phase Op Code Activity Code Time P -T -X Operation (ftKB) End Depth (WB) 12/23/2016 12/24/2016 0.10 PROD1 DRILL DRLG P Off bottom, 1.80 bpm, CT 4655 psi, diff 8,871.0 8,874.0 23:54 00:00 7605 psi. BOBD, CT 4866 psi, 894 psi diff, Ct Wt 7.8 k lbs, WOB 1.78 k lbs ROP 34 ft/hr 12/24/2016 12/24/2016 3.00 PROD1 DRILL DRLG P OBD, CT 4889 psi, 945 psi diff, Ct Wt 8,874.0 9,190.0 00:00 03:00 6.18 k lbs, WOB 1.38 k lbs ROP 90 ft/hr 12/24/2016 12/24/2016 0.50 PROD1 DRILL WPRT P Pull wiper trip #1 after 500' drilled. PU 9,190.0 8,368.0 03:00 03:30 Wt 40 k lbs. Encountered overpulls to 60k lbs total between 8565 - 8536, cleaned up area. 12/24/2016 12/24/2016 0.50 PROD1 DRILL WPRT P RBIH, slight weight bobbles @ 8535 8,368.0 9,190.0 03:30 04:00 and 8565' 12/24/2016 12/24/2016 5.10 PROD1 DRILL DRLG P RIH Wt 9 k lbs, Off bottom, @ 1.84 9,190.0 9,651.0 04:00 09:06 bpm, CT 4895 psi, Diff 719 psi OBD, CT 5134 psi, 1000 psi diff, Ct Wt 3.7 k lbs, WOB 1.3 k lbs ROP 150 ft/hr Perform several BHA wiper trips and a 400 ft wiper to facilitate weight transfer 12/24/2016 12/24/2016 0.79 PROD1 DRILL WPRT P Wiper trip #2 after 461 ft drilled. 9,651.0 9,651.0 09:06 09:53 Having weight transfer issues / in the process of swapping to Mud System #2 11,000 ft wiper trip 12/24/2016 12/24/2016 6.30 PROD1 DRILL DRLG P BOBD. 1.80 bpm, CT Press 5,062 9,651.0 10,100.0 09:53 16:11 Diff Press 937 CTW -3.0 WOB 1.78 klb ROP 56 to 119 fpm IA 484 OA 363 12/24/2016 12/24/2016 1.41 PROD1 DRILL WPRT P Perform a wiper trip and log the RA 10,100.0 7,170.0 16:11 17:36 12/24/2016 12/24/2016 0.18 PROD1 DRILL DLOG P Log for the RA and make a correction 7,170.0 7,182.0 17:36 17:46 of +7 ft 12/24/2016 12/24/2016 1.40 PROD1 DRILL TRIP P Continue RBIH to bottom. Weight 7,182.0 10,100.0 17:46 19:10 bobbles from 8365 - 8585' Sat down @ 8656', at the start of the A4 lower silt. 12/24/2016 12/24/2016 1.90 PROD1 DRILL DRLG P Struggled with weight transfer issues. 10,100.0 10,126.0 19:10 21:04 Managed to get drilling at reduced pump rate. OBD, 1.55 bpm, CT 4032 psi, Diff 633 psi, CT wt -1.2 k lbs, WOB 1 k lbs, ROP 20-100 ft/hr Diminishing weight transfers, build and pump 10 bbl lube/bead pill. 12/24/2016 12/24/2016 1.90 PROD1 DRILL DRLG P OBD, 1.2 bbls out the nozzle, surface 10,126.0 10,214.0 21:04 22:58 weight from -7k lbs to neutral, WOB 1.57 ROP 100 ft/hr. Weight transfer issues returned once pill exited annulus at surface. Confer with Geo's, Call TD. 12/24/2016 12/25/2016 1.02 PROD1 DRILL WPRT P Pump 10 x 10 low/ high vis pills. 10,214.0 8,865.0 22:58 00:00 Chase sweeps out of hole out of hole 12/25/2016 12/25/2016 1.03 PROD1 DRILL WPRT P Chasing sweeps CT wt 60k lbs and up 10,214.0 6,800.0 00:00 01:01 to -4 k WOB through ratty area, 8470- 8565' and 8621'. Lots of silt / sand at the shaker, no rocks. PUH to 6700, RBIH jog to 6800'. Page 7117 Report Printed: 1/16/2017 Uperations Summary (with Timelog Depths) :..: 1H-16 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time Dur (hr) Phase Op Code Activity Code Time P -T -X Operation (ftKB) End Depth (ftKB) 12/25/2016 12/25/2016 1.30 PROD1 DRILL WPRT P Open EDC, Pumps up to bpm, 6,800.0 6,800.0 01:01 02:19 Circulate bottoms up. Lots of sand at the shaker on bottoms up, no rocks. Shut down pumps holding 11.8 ppg equiv at the window, wellhead solid, circ pressure falling. Close EDC 12/25/2016 12/25/2016 0.90 PROD1 DRILL WPRT P RBIH, pumping min rate, one slight 6,800.0 8,850.0 02:19 03:13 WOB bobble @ 8557' Clean hole. 12/25/2016 12/25/2016 2.81 PROD1 DRILL WPRT P POOH wiper to window, 1.5 bpm saw 8,850.0 78.0 03:13 06:02 - 1 Ok lbs overpull at 8530, some evidence of minor packing off. Much cleaner. Pull above window, open EDC, POOH. 12/25/2016 12/25/2016 1.36 PROD1 DRILL TRIP P RBIH 78.0 6,700.0 06:02 07:24 12/25/2016 12/25/2016 0.16 PROD1 DRILL DLOG P Tie into K1 for +7.5 ft correction. 6,755.0 6,799.0 07:24 07:33 12/25/2016 12/25/2016 1.37 PROD1 DRILL TRIP P Continue to RIH. Past the bad spot 6,799.0 10,214.0 07:33 08:55 with no weight bobbles. TD confirmed at 10,216.0 ft. 12/25/2016 12/25/2016 1.47 PROD1 DRILL DISP P POOH laying in liner running pill. 10,214.0 6,778.0 08:55 10:24 PUW = 43k Pulled up through bad area with no issues or overpulls. Baker called at 8:53 am for noon arrival. Paint yellow EOP flag at 8,738 ft 12/25/2016 12/25/2016 1.40 PROD1 DRILL DISP P Trip out at 112 fpm laying in 11.8 ppg 6,778.0 80.6 10:24 11:48 NaBr KW fluid to surface. Follow 11.8 ppg Trip Schedule. Paint white EOL flag at 5,578 ft 12/25/2016 12/25/2016 0.55 PROD1 DRILL OWFF P At surface. Perform 30 minute No- 80.6 80.6 11:48 12:21 Flow Test. No -Flow Test good. Hold PJSM for laying down BHA #7. 12/25/2016 12/25/2016 0.71 PROD1 DRILL PULD P UD BHA #7 over a dead well. Bit 80.6 0.0 12:21 13:03 Graded at 1 - 1 12/25/2016 12/25/2016 0.47 COMPZ1 CASING BOPE P Perform BOPE Test (Function). 0.0 0.0 13:03 13:31 12/25/2016 12/25/2016 0.59 COMPZ1 CASING PUTB P BOPE Test completed. Prep Rig floor 0.0 0.0 13:31 14:07 for running liner. PJSM. 12/25/2016 12/25/2016 3.00 COMPZI CASING PUTB P P/U BHA #8, 1 H-1 6A Lower Lateral 0.0 1,548.7 14:07 17:07 Assembly ( 49 jts 2 3/8" Slotted Liner, non -ported bullnose, BHA). 12/25/2016 12/25/2016 3.00 COMPZ1 CASING RUNL P RIH with BHA # 8. tie into window flag, 1,548.7 10,216.0 17:07 20:07 +1.27' foot correction. Wt Ck, 36.7 K lbs. Continue tripping in hole with BHA #8 to TD depth of 10216'. PU 40 k lbs, SD, stack 5 k, pull neutral coil weight, pumps up to 1.5 bpm, CT 4000 psi, PU, CT wt, 34k lbs, off liner. down on pumps 12/25/2016 12/25/2016 2.40 COMPZ1 CASING TRIP P POOH, paint white flag @ 5744.21'. 10,216.0 56.0 20:07 22:31 continue to POOH. 12/25/2016 12/25/2016 0.50 COMPZ1 CASING OWFF P At surface, 30 min no flow - good, 56.0 56.0 22:31 23:01 PJSM 12/25/2016 12/25/2016 0.30 COMPZ1 CASING PULD P LD BHA #8, 56.0 0.0 23:01 23:19 Page 8/17 Report Printed: 1/16/2017 operations Summary (with Timelog Gcpths) 1H-16 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Time End Time Dur (hr) Phase Op Code Activity Code Time P -T -X Operation Start Depth (ftKB) End Depth (ftKB) 12/25/2016 12/26/2016 0.68 COMPZ1 CASING PUTB P Prepar rig floor for running liner. 0.0 1,265.5 23:19 00:00 PJSM, Pick up middle section of A lat, 2 slotted, 30 blank, and 10 slotted joints of 2 3/8", 4.6 #, L-80, ST -L liner hung off a shorty deployment sleeve. 12/26/2016 12/26/2016 3.30 COMPZ1 CASING PUTB P Run middle section of A lat, 2 slotted, 0.0 1,265.5 00:00 03:18 30 blank, and 10 slotted joints of 2 3/8", 4.6 #, L-80, ST -L liner hung off a shorty deployment sleeve. Total length 1265.47. Call well control drill, 4:15 time to simulate S/I. AAR to discuss +/-'s. Lay down safety joint. MU BHA #9, stab on. 12/26/2016 12/26/2016 2.30 COMPZ1 CASING RUNL P RIH W BHA#9, middle section, "A" lat, 1,309.7 8,709.0 03:18 05:36 2 joints slotted, 30 solid, and 10 slotted, 2 3/8", 4.6 #, L-80, ST -L.. Tie into painted flag 5701, for no correction. Wt Ct 39 k lbs, @ 8709', S/D, release off liner. 12/26/2016 12/26/2016 1.71 COMPZ1 CASINGTRIP P POOH, 8,708.0 48.2 05:36 07:18 12/26/2016 12/26/2016 0.55 COMPZ1 CASING]PULD OWFF P At surface, 30 min no flow - good, 48.2 48.2 07:18 07:51 PJSM 12/26/2016 12/26/2016 0.55 COMPZ1 CASING P LD BHA #9 48.2 0.0 07:51 08:24 12/26/2016 12/26/2016 0.76 PROM STK PULD P Run upper A lat, open hole anchor, 1 0.0 104.5 08:24 09:10 joint slotted, 2 3/8", 4.6 #, L-80, ST -L liner hung off an aluminum liner top billet. Total length 42.95'. MU BHA #10, stab on. 12/26/2016 12/26/2016 2.11 PROM STK TRIP P RIH with BHA # 10. tie into window 104.5 7,446.5 09:10 11:16 flag, +6.5 foot correction. Wt Ck, 34 K lbs. Close EDC........ Continue tripping in hole with BHA #9 to TOL tag depth of 7,446.5 ft . PU 38 k lbs at 5 fpm as the HOT is malfunctioning at the DD. MWD tries unsuccessfully to set the anchor oreintation at 340 degrees ROHS (20 LOHS), 12/26/2016 12/26/2016 1.49 PROD2 STK TRIP T POOH to replace HOT. 7,446.5 104.5 11:16 12:46 12/26/2016 12/26/2016 0.55 PROM STK OWFF T At surface, 30 min no flow - good, 104.5 104.5 12:46 13:19 PJSM 12/26/2016 12/26/2016 0.71 PROD2 STK PULD T LD BHA #10 and remove 104.5 0.0 13:19 14:01 malfunctioning HOT 12/26/2016 12/26/2016 0.50 PROM STK PULD T P/U BHA #11 with new working HOT. 0.0 104.5 14:01 14:31 Page 9117 Report Printed: 1/16/2017 Uperations Summary (with Timelog Depths) IH -16 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time Dur (hr) Phase Op Code Activity Code Time P -T -X Operation (ftKB) End Depth (ftKB) 12/26/2016 12/26/2016 1.94 PROD2 STK TRIP T RIH with BHA # 11. tie into window 104.5 7,446.5 14:31 16:28 flag, +5.5 ft correction. Wt Ck, 34 K lbs. Close EDC........ Continue tripping in hole with BHA #11 to TOL tag depth of 7,446.5 ft . PU 38.5 k lbs Set back down and then pull up to neutral weight .......... bring pump online and pressure breaks over at 2,700 psi .... set down 6k ....... PUH .... puw = 38k ........ anchor oreintation at 340 degrees ROHS (20 LOHS), 12/26/2016 12/26/2016 1.63 PROD2 STK TRIP P POOH 7,403.6 62.7 16:28 18:06 12/26/2016 12/26/2016 0.55 PROD2 STK OWFF P At surface, 30 min no flow - good, 62.7 62.7 18:06 18:39 PJSM 12/26/2016 12/26/2016 0.60 PROD2 STK PULD P L/D BHA #11. 62.7 0.0 18:39 19:15 12/26/2016 12/26/2016 1.24 PROD2 STK PULD P Replace UQC / Rehead as UQC was 0.0 0.0 19:15 20:29 houred out. Note: Tested at 210 megs / 61 ohms. Packoffs checked - Good condition 12/26/2016 12/26/2016 1.00 PROD2 STK PULD P P/U BHA #12 with Weatherford 0.7 ° 0.0 74.8 20:29 21:29 Motor and 2.70" x 3.0" HCC Bi -Center Bit after PJSM. WFT Motor SN # 22505, Bi -Center Bit SN# 7041613 12/26/2016 12/26/2016 1.30 PROD2 STK TRIP P RIH with closed EDC pumping at 74.8 6,795.0 21:29 22:47 minimum rate 12/26/2016 12/26/2016 0.30 PROD2 STK DLOG P Log for K1 Marker and make 6,700.0 6,795.0 22:47 23:05 correction of +5' ft, 12/26/2016 12/27/2016 0.91 PROD2 STK DISP P Open EDC, Circulate KWF out with 6,795.0 6,795.0 23:05 00:00 8.6 drilling fluid. 12/27/2016 12/27/2016 0.60 PROD2 STK TRIP P EDC closed and continue RIH to TOL 6,795.0 7,403.0 00:00 00:36 12/27/2016 12/27/2016 0.70 PROD2 STK TRIP P Down on pump, RIH, dry tag top of 7,403.0 7,403.6- 00:36 01:18 billet at 7,403 ft. PUW = 36k.. PUH, slip chains, lots of geese on chains, Inspect area, one old relatively deep gouge, Pressure wash blocks as we slowly POOH, RBIH and re tag to verify counter, ok. PU and set drilling rate, RBIH 12/27/2016 12/27/2016 0.10 PROD2 STK TRIP P Set drilling rate off bottom, 1.73 bpm, 7,403.0 7,403.0 01:18 01:24 CT 4700 psi, diff 722 psi, zero WOB RBIH RIH Wt 13.9k. 12/27/2016 12/27/2016 3.10 PROD2 STK KOST P Time mill on billet. 1.72 bpm 7,403.0 7,460.0 01:24 04:30 CT 4791 psi, CT Wt 15.9 k lbs, Diff 976 psi, WOB 0.32 k lbs, 1 f @ 1 ft/hr, 1 ft@ 2 ft/hr, 2 ft@ 5-6 ft/hr, 2 ft@ 8-10 ft/hr, 2 ft@ 15'ft/hr, /hr, 2 ft @ 20' ft/hr, drilling ahead, WOB 1 k lbs, ROP 136 ft/hr. 12/27/2016 12/27/2016 0.20 PROD2 STK KOST P PU, Wt 38k lbs, PUH , min rate, clean 7,460.0 7,460.0 04:30 04:42 drift, RBIH 10 ft/min, pumps off, clean dry drift. 12/27/2016 12/27/2016 1.80 PROD2 DRILL DRLG P Kicked off billet at 7,408 ft. Drilling 7,460.0 7,736.6 04:42 06:30 ahead in AL1 Lateral as per plan. Off bottom, 1.75 bpm, CT 4559 psi, diff 872 psi, RIH Wt 13.5 k lbs OBD, CT 5389 psi, diff 1500 psi, CT 11, WOB 1.6, ROP 200 ft/hr Page 10/17 Report Printed: 1/16/2017 Operations Summary (with Timelog Depths) { v 1H-16 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time Dur (hr) Phase Op Code Activity Code Time P -T -X Operation (ftKB) End Depth (ftKB) 12/27/2016 12/27/2016 1.00 PROD2 DRILL RGRP T While picking up to perform BHA 7,460.0 6,811.0 06:30 07:30 wiper, encountered difficulty with the injector. Trouble shoot issue, suspect a bad encoder, motors not balancing torque. PUH into casing to repair / replace. Open EDC, pump 2 bpm for 1 hr, reduce to min rate. Discover motor #2 (towards storge reel), love joy connection (lower coupler) from AC VDF to input of right angel drive slid down and slipped a key. Parts sourced and repairs implemented. Counting 1 st hr of troubleshooting against daily rig maint. 12/27/2016 12/27/2016 7.60 PROD2 DRILL RGRP T Repair injector. 7,460.0 6,811.0 07:30 15:06 12/27/2016 12/27/2016 0.40 PROD2 DRILL RGRP T Button up injector drives. Move pipe, 6,811.0 7,736.0 15:06 15:30 all good. Close EDC. test motor @ 1 bpm - good. RIH inspecting pipe. Tie- in to RA tag, no correction. 12/27/2016 12/27/2016 3.00 PROD2 DRILL DRLG P Off bottom, 1.80 bpm, CT 4820 psi, 7,736.0 8,190.0 15:30 18:30 diff 828 psi, RIH Wt 13. k lbs OBD, CT 5178 psi, diff 1179 psi, CT 10.5, WOB 1.5, ROP 132 ft/hr 12/27/2016 12/27/2016 1.10 PROD2 DRILL WPRT P Wiper trip #1, 40K PUW, to 7340', 8,190.0 8,190.0 18:30 19:36 RBIH to drill, establish off bottom rate 1.8 bpm, CT 4870 psi, WH 262 psi, dP 836 psi, 11K RIH Wt, 41K PUW 12/27/2016 12/27/2016 3.80 PROD2 DRILL DRLG P Drill at 1.8 bpm, CT 5480 psi, WH 115 8,190.0 8,622.0 19:36 23:24 psi, 4215 psi diff on bottom, BHA wiper at 8350', 48K PUW, sticky, BHA wiper 8608', weight transfer. 12/27/2016 12/28/2016 0.60 PROD2 DRILL WPRT P Wiper trip #2 early due to weight 8,622.0 8,622.0 23:24 00:00 transfer, 40K PUW, to 7775', RBIH to drill 12/28/2016 12/28/2016 2.00 PROD2 DRILL DRLG P Drilling ahead, crossed fault at 8610', 8,622.0 8,675.0 00:00 02:00 wrap around gamma, almost all clay at shaker. Drill ahead with caution taking frequent PUW, TF oriented to highside. 12/28/2016 12/28/2016 6.60 PROD2 DRILL DRLG P Drill ahead taking frequent PUW, 38K 8,675.0 8,882.0 02:00 08:36 to 42K. Got a PUW of 46K, pulled 100 ft wiper, on bottom parameters, 1.80 bpm, CT weight between +2K after pick-ups dropping off to -5K lbs, CT 5072 psi, WH 265 psi, 930 psi diff 12/28/2016 12/28/2016 0.20 PROD2 DRILL WPRT P Pull short wiper over trouble spot, 8,882.0 8,553.0 08:36 08:48 WOB -4k lbs @ 8679', motor work. 12/28/2016 12/28/2016 0.30 PROD2 DRILL WPRT P RBIH SID 8686' work through, 46k 8,553.0 8,882.0 08:48 09:06 PU Wt 12/28/2016 12/28/2016 4.10 PROD2 DRILL DRLG P OBD, 1.70 bpm, CT 5024 psi, Diff 940 8,882.0 9,130.0 09:06 13:12 psi, CT Wt, negative 2-5k lbs, WOB 1.5 k lbs. ROP 100-20 ft/hr pump 5 x 5 sweeps Page 11/17 ReportPrinted: 1/16/2017 .; Operations Summary (with Timelog Depths) 1H-16 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time Dur (hr) Phase Op Code Activity Code Time P -T -X Operation (ftKB) End Depth (MB) 12/28/2016 12/28/2016 1.30 PROD2 DRILL WPRT P PU Wt 42 k lbs, Long wiper for tie in. 9,130.0 7,167.0 13:12 14:30 10-30k overpulls 8750-8615'. Work through area. Jog above build section, CT wt went from 50k to 41 k. Lots of silt and clay at the shaker some shale chips, 1/4"-3/8". 12/28/2016 12/28/2016 0.40 PROD2 DRILL DLOG P Tie into whipstock RA tag for a +7.5' 71167.0 7,187.0 14:30 14:54 correction. Seeing CT wt go from -- 40 to — 50 k at 7168', suspect solids. 12/28/2016 12/28/2016 2.20 PROD2 DRILL WPRT P Struggle to get diff pressure below 50 7,130.0 7,650.0 14:54 17:06 psi, Open EDC, Rate to 2.16 bpm, circ bottoms up. Steady stream of rocks at the shaker, 1/2" to 3/4" minus, Geo says A5/A6 from near the window. A couple flat sheets of metal in returns, some magnetic some not. Pump 5x5 sweep. Large amount of silt and pea gravel at the shaker as the low vis landed, larger rocks but less as the high vis landed. Continue to PUH, send another 5 x 5 sweep. A small number of rocks back but mostly clean. CT Wt back to 31 k lbs. 12/28/2016 12/28/2016 2.30 PROD2 DRILL WPRT P RBIH, close EDC. sat down at 8651' 7,130.0 9,130.0 17:06 19:24 and 8761', lower pump rate and worked thru with minimal issue, hole trying to pack off, send 5 bbls Hi vis sweep and reciprocate pipe from 9120 to 9015' until sweep reaches bit. 12/28/2016 12/29/2016 4.60 PROD2 DRILL DRLG P OBD, 1.4 bpm, CT 4438 psi, diff 860 9,130.0 9,381.0 19:24 00:00 psi, 1.8K WOB, 0.5K to negative 2-5K, increase drilling rate to 1.6 bpm, hole packing off and have difficulty getting WOB, lower rate back to 1.45 bpm, prep to swap mud to system 3 w/ 1% Lo Torq and 1% 776. ROP 40 to 120 ft/hr. New mud at bit at 9299'@ 22:30 pm. 12/29/2016 12/29/2016 0.20 PROD2 DRILL DRLG P Short BHA wiper to 9280', PUW 42K, 9,381.0 9,381.0 00:00 00:12 12/29/2016 12/29/2016 0.60 PROD2 DRILL DRVE P OBD, 4.4K CW, CT 4535 psi, 932 psi 9,381.0 9,417.0 00:12 00:48 diff, 1.4K WOB, 80 ft/hr ROP, 12/29/2016 12/29/2016 0.30 PROD2 DRILL WPRT P Slow Geo wiper, found top of A4 pay, 9,417.0 9,417.0 00:48 01:06 turn TF down to get to 880 12/29/2016 12/29/2016 2.50 PROD2 DRILL DRLG P OBD, 4K CW, 1.52 bpm, CT 4654 psi, 9,417.0 9,580.0 01:06 03:36 900 psi dif on bottom, 1.5K WOB, 30 to 60 ROP 12/29/2016 12/29/2016 0.30 PROD2 DRILL WPRT P Wiper trip #4, PUW 38K, 50FPM, 1.55 9,580.0 8,780.0 03:36 03:54 bpm, CT 4453 psi, 651 psi diff, pull heavy at 8780', 42K 12/29/2016 12/29/2016 1.20 PROD2 DRILL WPRT P Turn around, RIH, SD several places, 8,780.0 9,580.0 03:54 05:06 PUW 46k to 60k, packing off, work through tight areas 8780' to 8930', pump 5x5 Lo/Hi vis sweep, RIH, stacking weight taking turn arounds, hole conditions marginal, reciprocate to clean hole better at 1.50 bpm Page 12/17 ReportPrinted: 111612017 R , Uperations Summary (with Timelog depths) 1H-16 k:. Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time Dur (hr) Phase Op Code Activity Code Time P -T -X Operation (ftKB) End Depth (ftKB) 12/29/2016 12/29/2016 1.40 PROD2 DRILL DRLG P BOBD, 1.51 bpm, CT 4463 psi, CT Wt 9,580.0 9,636.0 05:06 06:30 0.3 k lbs, WOB 1.1 k lbs, ROP 75 ft/hr. fragile weight transfer. 12/29/2016 12/29/2016 1.50 PROD2 DRILL WPRT P Lose wt transfer and struggle to get 9,636.0 7,958.0 06:30 08:00 started with a couple BHA wipers and variable pump rate. Decide to PUH , clean up trouble spots. CT wt up to 70k from 8764 - 8660. RBIH, send 5x5. large amount of solids returned at the screen, mostly pea gravel and silt/sand, some larger 3/4" minus flakes. 12/29/2016 12/29/2016 1.00 PROD2 DRILL WPRT P Continue to PUH, CT weight 39k lbs, 7,958.0 7,100.0 08:00 09:00 second 5x5 sweep landed at the shaker, lots of solids in the Io vis, heavy silt sand and pea gravel, 1/16" to 1/4". Next to nothing in the high vis. CT Wt 38- 36k. Hole looks to be fairly clean. last 5x5 did surface some solids but the amount was greatly diminished, CT wt 38k. 12/29/2016 12/29/2016 1.00 PROM DRILL DLOG P Tie into the WS RA tag for a +7' 7,100.0 7,182.0 09:00 10:00 correction. 12/29/2016 12/29/2016 0.30 PROD2 DRILL WPRT P Continue to RIH, RIH Wt 13k, two very 7,182.0 9,638.0 10:00 10:18 slight weight bobbles at 8712' S/D 7k and 9394' S/D 2 k 12/29/2016 12/29/2016 0.20 PROD2 DRILL DRLG P Off bottom, 1.51 bpm, CT 4200 psi,diff 9,638.0 9,641.0 10:18 10:30 570 psi, OBD, CT Wt 5 k lbs, WOB 1.5 k lbs, ROP 90 ft/hr. Great weight transfer. Town called TD early, change of plans. 12/29/2016 12/29/2016 3.00 PROD2 STK TRIP T POOH for open hole anchored billet. 9,641.0 77.0 10:30 13:30 Pump 5x5 sweeps, timed to exit nozzle @ 8100'. Pumps to min rate as the coil passed through 8700 to 8600'. Open EDC in tbg, continue to POOH. Sweeps returned all fines, silt and sand. Jog near surface. 12/29/2016 12/29/2016 2.20 PROD2 STK PULD T PJSM, PUD BHA #12. and laydown 77.0 0.0 13:30 15:42 12/29/2016 12/29/2016 0.90 PROD2 STK PULD T PJSM, PU and PD BHA #13, AL1 0.0 72.0 15:42 16:36 open hole anchored billet. While deploying had pressure above closed 2-3/8" pipe/slip rams, attempt to bleed off, pressure builds back to WH. 12/29/2016 12/29/2016 0.70 PROD2 STK PULD T PJSM to discuss plan forward, decide 72.0 0.0 16:36 17:18 to PUD and inspect FVS sub, if float valves are holding, PU and run test joint and test 2-3/8" pipe/slip rams. 12/29/2016 12/29/2016 1.40 PROD2 STK PULD T PUD BHA #13, checked FVS sub, 0.0 0.0 17:18 18:42 checks appear to be holding. MU and deploy test joint, closed lower 2-3/8" rams, pressure up below against closed swabs to 900 psi, rams are holding. Broke apart FVS to fully inspect check valves. Both checks are stuck open with fine grit/shale. Bled off 900 psi, LD test joint. Page 13117 Report Printed: 1/16/2017 Operations Summary (with Timelog Depths) 1H-16 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time our (hr) Phase Op Code Activity Code Time P -T -X Operation (ftKB) End Depth (ftKB) 12/29/2016 12/29/2016 0.90 PROD2 STK PULD T PJSM, clean and clear rig floor, re- 0.0 73.0 18:42 19:36 deploy BHA#14 (swapped FVS with a different sub). Off trouble time at 19:30 pm (3.0 hours of trouble time) 12/29/2016 12/29/2016 0.80 PROD2 STK PULD T Continue with deploying BHA #14. 73.0 19:36 20:24 12/29/2016 12/29/2016 1.90 PROD2 STK TRIP T Trip in with BHA #14 Baker OH anchor 73.0 6,750.0 20:24 22:18 billet, minimum rate 12/29/2016 12/29/2016 0.20 PROD2 STK DLOG T Tie-in to K1, +7 ft correction 6,750.0 6,770.0 22:18 22:30 12/29/2016 12/29/2016 0.80 PROD2 STK TRIP T Get PUW 33.5K, close EDC, RIH at 6,770.0 8,111.6 22:30 23:18 30 FPM until past whipstock and window, speed up to 40 FPM in OH, 12K to 14K RIH Wt, Get PUW 38K, Get on depth, PU 33K, orient top slip at 0° HS, Online 1 bpm, sheared at 4800 psi, SO 4K WOB, good set, pick was clean 12/29/2016 12/30/2016 0.70 PROD2 STK TRIP T POOH, stop at 6785, open EDC, 8,111.6 6,120.0 23:18 00:00 continue OOH 12/30/2016 12/30/2016 1.00 PROD2 STK TRIP T Continue to POOH. 6,120.0 73.0 00:00 01:00 12/30/2016 12/30/2016 1.70 PROD2 STK PULD T At surface, bump up, space out, hold 73.0 0.0 01:00 02:42 PJSM, PUD BHA #14 Baker #10 setting tool. LD BHA #14 12/30/2016 12/30/2016 2.00 PROD2 STK PULD T PU BHA #15 w/ Weatherford 0.65° 0.0 74.8 02:42 04:42 AKO motor, HYC 3.0" bi-center bit, PJSM, PD BHA #15. Pull upper checks, inspect, checks looks good, went ahead and replaced. Inspect stripper/pack-offs, PO's were worn, replaced them 12/30/2016 12/30/2016 1.30 PROD2 STK TRIP T RIH w/ EDC open 74.8 6,710.0 04:42 06:00 12/30/2016 12/30/2016 0.90 PROD2 STK DLOG T Tie into the K1 for + 16' correction, 7,100.0 8,101.0 06:00 06:54 Inspect both injector and storage reel counters and clean same, Close EDC, continue to RIH, log RA tag toverify counters, zero correction. RIH 12/30/2016 12/30/2016 0.40 PROD2 STK KOST T dry tag TOB @ 8101'. PU 36k lbs, 8,101.0 8,101.0 06:54 07:18 RBIH Set drilling rate 1.80 bpm off bottom, CT 5140 psi, diff 909 psi, Zero WOB 12/30/2016 12/30/2016 2.00 PROD2 STK KOST T Tag, stall once, PUH, RBIH, stack 8,101.0 8,110.0 07:18 09:18 weight 8100.4 1 ft/hr for 1' 2 fUhr for 1' 3 'fUhr for 1' then target 1 k WOB. 12/30/2016 12/30/2016 0.50 PROD2 DRILL DRLG T Drilling rat hole 8,110.0 8,140.0 09:18 09:48 12/30/2016 12/30/2016 0.20 PROD2 DRILL WPRT T PU, RBIH, dry drift, clean, RIH 8,140.0 8,140.0 09:48 10:00 12/30/2016 12/30/2016 1.30 PROD2 DRILL DRLG T off bottom, 1.79 bpm, CT 4900 psi, 8,140.0 8,311.0 10:00 11:18 diff, 840 psi, OBD, Ct 5500, Dif, 1696 psi, CT Wt, 12 k lbs, WOB1.9k lbs, 202 ft/hr. pull 2 short DD wiper, PU Wt, 37k 12/30/2016 12/30/2016 0.10 PROD2 DRILL WPRT T Drilled into some hard stuff, pull BHA 8,311.0 8,233.0 11:18 11:24 1 1 1 1wiper Page 14117 Report Printed: 1/16120171 I , Uperations Summary (with Timelog Depths) 1H-16 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time Dur (hr) Phase Op Code Activity Code Time P -T -X Operation (MB) End Depth (ftKB) 12/30/2016 12/30/2016 0.10 PROD2 DRILL WPRT T RBIH 8,233.0 8,311.0 11:24 11:30 12/30/2016 12/30/2016 2.00 PROD2 DRILL DRLG T BOBD, Ct 5017, Dif, 1517 psi, CT Wt, 8,311.0 8,600.0 11:30 13:30 11 k lbs, WOB 1.7k, 150-200 ft/hr. Pump 1 0x1 0 sweeps, 42k lbs 12/30/2016 12/30/2016 1.90 PROD2 DRILL WPRT P Long TD wiper to swab 8,600.0 78.0 13:30 15:24 12/30/2016 12/30/2016 1.60 PROD2 DRILL TRIP P RBIH 78.0 6,000.0 15:24 17:00 12/30/2016 12/30/2016 0.70 PROD2 DRILL TRIP T Field wide Phase 3, 6,000.0 6,000.0 17:00 17:42 12/30/2016 12/30/2016 0.50 PROD2 DRILL DLOG P Tie into K1 for+6.5' correction, Close 6,000.0 6,000.0 17:42 18:12 EDC, 12/30/2016 12/30/2016 0.50 PROD2 DRILL TRIP P RIH, stop to check pressure at window 6,000.0 7,077.0 18:12 18:42 7077' (6407' TVD), crew change, after 30 min, annular pressure was 3685 psi, 11.1 ppg EMW 12/30/2016 12/30/2016 0.80 PROD2 DRILL TRIP P Sat down 2X at 7040' ( bottom of 7,077.0 8,601.0 18:42 19:30 window). Picked up 3rd time, rolled pump, down on pump, run in clean past window, continue RIH. Tag at 8601'. 12/30/2016 12/30/2016 1.70 PROD2 DRILL DISP P POOH, lay in liner pill and displace to 8,601.0 78.0 19:30 21:12 11.8 ppg NaBr, paint yellow TD flag at 6780', EOP depth, paint white Window Flag at 5200' EOP depth, continue POOH 12/30/2016 12/30/2016 0.50 PROD2 DRILL OWFF P At surface, 4 bbl loss laying in KWF, 78.0 78.0 21:12 21:42 perform 30 min flow check. 12/30/2016 12/30/2016 1.90 PROD2 DRILL PULD P PJSM, laydown BHA #15 over dead 78.0 0.0 21:42 23:36 well, insppect coil, observered a deep gouge approx 17 ft up from coil connector. 12/30/2016 12/31/2016 0.40 COMPZ2 CASING PUTB P Prep floor for running liner 0.0 0.0 23:36 00:00 12/31/2016 12/31/2016 2.90 COMPZ2 CASING PUTB P PJSM, PU and run 58jnts, 2-3/8" 0.0 1,767.6 00:00 02:54 slotted liner with solid bullnose. Performed well control drill while running liner, 3 min 20 sec response time to install safety joint. 12131/2016 12/31/2016 1.00 COMPZ2 CASING PULD P Clean & clear rig floor, PJSM, MU liner 1,767.6 1,811.8 02:54 03:54 running BHA # 16, deploy over dead well 12/31/2016 12/31/2016 2.00 COMPZ2 CASING RUNL P Trip in, EDC closed, Blacked out rig, 1,811.8 8,601.0 03:54 05:54 sub and service mod for 6 minutes, Started generator while on shore power, high idle caused the load sharing to kick off shore power. Tie into window flag for +2.66' correction. Set down, PU, and had to work pipe through 8304, 8340, and 8367' near A4 -A5 silt intertface. 12/31/2016 12/31/2016 0.20 COMPZ2 CASING RUNL P Tag bottom, PU Wt 44-55k, SD, pump 8,601.0 8,592.0 05:54 06:06 off, PU 32k lbs, down on pumps, Page 15/17 Report Printed: 1/16/2017 Uperations Summary (with Timelog Depths) 1H-16 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Tme Dur (hr) Phase Op Code Activity Code Time P -T -X Operation (ftKB) End Depth (ftKB) 12/31/2016 12/31/2016 1.30 COMPZ2 CASING DISP P Adjust depths for 1767.64' of liner left 6,824.4 6,774.0 06:06 07:24 in hole, complete seawater transfer, line up to seawater and displace coil to seawater, PUH, open EDC. 12/31/2016 12/31/2016 1.10 COMPZ2 CASING DISP P POOH displacing 11.8 ppg KW fluid 6,774.0 2,563.0 07:24 08:30 with seawater. 12/31/2016 12/31/2016 1.40 COMPZ2 CASING DISP P Pump 30 bbls diesel FP & contin to 2,563.0 45.0 08:30 09:54 POOH 12/31/2016 12/31/2016 1.00 COMPZ2 CASING PULD P Bump up, PJSM, PUD, BHA#16, AL1 45.0 0.0 09:54 10:54 liner running assembly. 12/31/2016 12/31/2016 0.50 COMPZ2 CASING PULD P LD BHA# 16 0.0 0.0 10:54 11:24 12/31/2016 12/31/2016 2.10 DEMOB WHDBOP RURD P Rig up nozzle and jet stack, pop of 0.0 0.0 11:24 13:30 and position reel, remove pressure bulkhead and cap. call out N2. 12/31/2016 12/31/2016 2.30 DEMOB WHDBOP MPSP P PJSM, Rig up Central shops lubricator 0.0 0.0 13:30 15:48 and set BPV,( Note: trapped 1000 psi under BPV) PJSM, w SLB, rig up N2 to customer valve. 12/31/2016 12/31/2016 1.00 DEMOB WHDBOP CTOP P PJSM, Blow down reel for reel swap 0.0 0.0 15:48 16:48 prior to moving from 1 H-16, cool down N2 unit, PT 4000 psi, Pump 1500 scf for 15 min, 12/31/2016 12/31/2016 4.50 DEMOB WHDBOP CTOP P PJSM, LOTO reel, cut off coil 0.0 0.0 16:48 21:18 connector, rig up grapple, sheeve, tie - downs, pull test grapple to 900 psi, prep to unstab coil. 12/31/2016 1/1/2017 2.70 DEMOB WHDBOP CTOP P PJSM, unstabe pipe and secure to 0.0 0.0 21:18 00:00 storage reel. Remove saddle clamps, PEAK on location at 23:40 1/1/2017 1/1/2017 1.50 DEMOB WHDBOP CTOP P Rigged down inner reel iron, removed 0.0 0.0 00:00 01:30 saddle clamps, rigging installed, reel hoisted 1/1/2017 1/1/2017 4.00 DEMOB WHDBOP CTOP P Had to remove hub from the old reel 0.0 0.0 01:30 05:30 (driller side) and swap with hub on new reel. New reel sent over with wrong size hub. 1/1/2017 1/1/2017 1.00 DEMOB WHDBOP CTOP P Completed loading the old storage 0.0 0.0 05:30 06:30 reel onto Peak truck 1/1/2017 1/1/2017 1.40 DEMOB WHDBOP CTOP P Hub installed on new storage reel, 0.0 0.0 06:30 07:54 MS1801400965N 1/1/2017 1/1/2017 1.00 DEMOB WHDBOP CTOP P Set storage reel in place, shim and 0.0 0.0 07:54 08:54 tighten pillow block bolts. 1/1/2017 1/1/2017 2.00 DEMOB WHDBOP CTOP P Install inner reel iron, and bulkhead 0.0 0.0 08:54 10:54 Off High line and on rig power at 10:00 1/1/2017 1/1/2017 1.00 DEMOB WHDBOP CTOP P Stab stripper, prep to pull/stab CT 0.0 0.0 10:54 11:54 1/1/2017 1/1/2017 4.00 DEMOB WHDBOP CTOP P install internal grapple, pull test,stab 0.0 0.0 11:54 15:54 coil 1/1/2017 1/1/2017 2.10 DEMOB WHDBOP CTOP P Install 2" coil connector, install horses 0.0 0.0 15:54 18:00 head. 1/1/2017 1/1/2017 1.50 DEMOB WHDBOP NUND P Blow down lines, suck out stack, pour 0.0 0.0 18:00 19:30 5 gal MEOH to tree. Pull test coil connector to 35K 1/1/2017 1/1/2017 1.00 DEMOB WHDBOP DMOB P Install and test Eline UQC, RD lines in 0.0 0.0 19:30 20:30 PUTZ, lost gen power to rig sub briefly at 20:05 Page 16/17 Report Printed: 1/16/2017 Uperations Summary (with Timelog Depths) r 3 1H-16 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time Dur (hr) Phase Op Code Activity Code Time P -T -X Operation (ftKB) End Depth (W[3) 1/1/2017 1/2/2017 3.50 DEMOB WHDBOP NUND P Finish RD of lines in PUTZ, ND pick 0.0 0.0 20:30 00:00 BOP stack, install tree cap *"Rig Release @ Midnight Page 17117 Report Printed: 1/16/2017 'V-11 ConocoPhillips ConocoPhillips (Alaska) Inc. -Kupl Kuparuk River Unit Kuparuk 1 H Pad 1H -16A 50-029-22315-01 Baker Hughes INTEQ Definitive Survey Report 27 January, 2017 rias BAKER HUGHES ConocoPhillips HIN > ConocoPhillips BA Definitive Survey Report HUGHES Company: ConocoPhillips (Alaska) Inc. -Kupl Local Coordinate Reference: Well 1 H-16 Project: Kuparuk River Unit TVD Reference: 1 H-16 @ 96.00usft (1 H-16) Site: Kuparuk 1 H Pad MD Reference: 1 H-16 @ 96.00usft (1 H-16) Well: IH-16 North Reference: True Wellbore: IH-16 Survey Calculation Method: Minimum Curvature Design: 11-1-16 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 IH-16 Well Position -NI-S 0.00 usft Northing: 5,980,029.08usft Latitude: 70° 21'22.424 N +E1-W 0.00 usft Easting: 549,192.10usft Longitude: 149° 36' 1.811 W Position Uncertainty 0.00 usft Wellhead Elevation: usft Ground Level: 0.00 usft Wellbore IH-16A Magnetics Model Name Sample Date Declination Dip Angle Field Strength (I M (nT) BGGM2016 1/1/2017 17.87 80.97 57,549 Design 1H-16A Audit Notes: Version: 1.0 Phase: ACTUAL Tie On Depth: 7,084.10 Vertical Section: Depth From (TVD) +Nl-S +EI-W Direction (usft) (usft) (usft) N 96.00 0.00 0.00 0.00 Survey Program Date 1/19/2017 From To Survey Survey (usft) (usft) Survey (Wellbore) Tool Name Description Start Date End Date 150.70 7,084.10 1H-16(1H-16) GCT-MS Schlumberger GCT multishot 1/8/2001 7,137.50 10,169.94 1 H-1 6A (1 H-1 6A) MWD MWD - Standard 12/19/2016 12/24/2016 1/272017 1:51:53PM Page 2 COMPASS 5000.1 Build 74 Survey ConocoPhillips WN16 ConocoPhillipsRAKER Definitive Survey Report HUGHES Company: ConocoPhd6ps (Alaska) Inc. -Kup1 Local Co-ordinate Reference: Well 1H-16 Project: Kuparuk River Unit TVD Reference: 1 H-16 @ 96.00usft (11-1-16) TVD Site: Kuparuk 1 H Pad MD Reference: 11-1-16 @ 96.00usft (111-16) Northing Well: 1H-16 North Reference: True Annotation Wellbore: 111-16 Survey Calculation Method: Minimum Curvature WWII Design: 111-16 Database: EDM Alaska NSK Sandbox (n! Survey Map Map Vertical MD Inc AZI TVD TVDSS -NAS+El-W Northing East DLS Section Survey Tool Name Annotation tnslep (°) t°) WWII Nam(usfE} ium) (n! Ift) 1"1100.) Inl 7,084.10 32.63 1.53 6,547.29 6,451.29 1,993.45 9.14 5,982,022.35 549,188.15 0.13 1,993.45 MWD (2) TIP 7,137.50 32.45 1.74 6,592.30 6,496.30 2,022.16 9.96 5,982,051.07 549,188.78 0.40 2,022.16 MWD (2) KOP 7,170.30 40.74 2.05 6,61862 6,522.62 2,041.69 10.61 5,982,070.59 549,189.30 25.28 2,041.69 MWD(2) 7,200.37 51.77 2.25 6,639.38 6,543.38 2,063.36 11.43 5,982,092.27 549,189.98 36.68 2,063.36 MWD (2) A 7,230.77 62.36 2.40 6,655.88 6,559.88 2,088.82 12.46 5,982,117.73 549,190.85 34.84 2,088.82 MWD(2) 7,260.97 73.63 4.91 6,667.18 6,571.18 2,116.71 14.27 5,982,145.63 549,192.47 38.10 2,116.71 MWD(2) 7,290.85 81.90 359.00 6,673.51 6,577.51 2,145.86 15.24 5,982,174.78 549,193.25 33.75 2,145.86 MWD (2) 7,321.05 88.13 350.74 6,676.14 6,580.14 2,175.78 12.55 5,982,204.68 549,190.36 34.16 2,175.78 MWD (2) 7,351.48 93.72 342.18 6,675.65 6,579.65 2,205.32 5.43 5,982,234.18 549,183.05 33.58 2,205.32 MWD (2) 7,380.56 93.90 338.82 6,673.71 6,577.71 2,232.67 4.25 5,982,261.46 549,173.19 11.55 2,232.67 MWD (2) 7,411.01 92.70 337.18 6,671.96 6,575.96 2,260.85 -15.64 5,982,289.56 549,161.62 6.67 2,260.85 MWD (2) - 7,440.28 92.37 335.65 6,670.67 6,574.67 2,287.65 -27.34 5,982,316.28 549,149.74 5.34 2,28765 MWD (2) 7,470.62 92.06 337.74 6,669.49 6,573.49 2,315.49 -39.33 5,982,344.04 549,137.57 6.96 2,315.49 MWD (2) 7,500.56 93.53 338.83 6,668.03 6,572.03 2,343.28 -50.40 5,982,371.75 549,126.32 6.11 2,343.28 MWD (2) 7,530.16 93.32 342.38 6,666.26 6,570.26 2,371.14 -60.21 5,982,399.54 549,116.33 11,99 2,371.14 MWD (2) 7,560.56 92.40 343.99 6,664.75 6,568.75 2,400.20 -68.99 5,982,428.55 549,107.36 6.09 2,400.20 MWD (2) 7,589.87 91.07 346.23 6,663.86 6,567.86 2,428.51 -76.52 5,982,456.80 549,099.65 8.88 2,428.51 MWD (2) 7,621.41 90.28 348.64 6,663.49 6,567.49 2,459.29 -83.38 5,982,487.53 549,092.59 8.04 2,459.29 MWD (2) 7,650.33 89.88 350.56 6,663.45 6,567.45 2,487.74 -88.60 5,982,515.94 549,087.18 6.78 2,487.74 MWD (2) 7,680.56 88.53 353.63 6,663.87 6,567.87 2,517.67 -92.75 5,982,545.84 549,082.83 11.09 2,517.67 MWD (2) 7,710.73 86.56 354.56 6,665.16 6,569.16 2,547.65 -95.85 5,982,575.80 549,079.53 7.22 2,547.65 MWD (2) 7,740.06 86.59 357.34 6,666.91 6,570.91 2,576.86 -97.92 5,982,604.99 549,077.27 9.46 2,576.86 MWD (2) 7,765.14 87.45 355.46 6,668.22 6,572.22 2,601.85 -99.49 5,982,629.97 549,075.53 8.23 2,601.85 MWD (2) 7,795.02 89.36 354.23 6,669.05 6,573.05 2,631.60 -102.18 5,982,659.69 549,072.65 7.60 2,631.60 MWD (2) 7,825.10 89.60 353.50 6,669.32 6,573.32 2,661.50 -105.39 5,982,689.57 549,069.24 2.55 2,661.50 MWD (2) 7,855.18 87.02 353.76 6,670.21 6,574.21 2,691.38 -108.73 5,982,719.43 549,065.71 8.62 2,691.38 MWD (2) 7,885.19 84.32 353.25 6,672.47 6,576.47 2,721.11 -112.11 5,982,749.13 549,062.13 9.16 2,721.11 MWD (2) 7,915.09 84.03 351.31 6,675.51 6,579.51 2,750.59 -116.11 5,982,778.58 549,057.94 6.53 2,750.59 MWD (2) 7,945.58 84.34 348.81 6,67860 6,582.60 2,78046 -121.34 5,982,808.41 549,052.51 8.22 2,780.46 MWD (2) 7,974.96 84.65 346.76 6,681.42 6,585.42 2,809.04 -127.53 5,982836.95 549,046.14 7.03 2,809.04 MWD (2) 1/17M17 1:51:53PM Page 3 COMPASS 5000.1 Build 74 11272017 1;51:53PM Page 4 COMPASS 5000.1 Build 74 ConocoPhillips Nits ConocoPhillips BAKER Map Map Definitive Survey Report Vertical HUGHES Company. ConocoPhillips (Alaska) Inc. -Kupl Local Coordinate Reference: Well 1 H-16 TVDSS Project: Kuparuk River Unit TVD Reference: 1 H-16 @ 96.00usft (1 H-16) Site: Kuparuk 1 H Pad MD Reference: 1 H-16 @ 96.00usft (1 H-16) (9 Well: IH -16 North Reference: True (usft) Wellbore: 1H-16 Survey Calculation Method: Minimum Curvature 0100.) Design: 111-16 Database: EDM Alaska NSK Sandbox 344.79 Survey 6,588.07 2,838.50 -135.00 11272017 1;51:53PM Page 4 COMPASS 5000.1 Build 74 Map Map Map Vertical MD Inc AzF TVD TVDSS -N/-S +�-yy OlS Section Survey Tool Name Annotation (usm (9 (1) (usft) (usft) (usft) (usft) (ft) (ft) 0100.) (it) 8,005.47 85.39 344.79 6,684.07 6,588.07 2,838.50 -135.00 5,982,866.36 549,038.48 6.87 2,838.50 MWD(2) 8,035.55 86.96 343.92 6,686.07 6,590.07 2,867.40 -143.09 5,982,895.20 549,030.20 5.96 2,867.40 MWD (2) 8,065.20 87.54 341.24 6,687.50 6,591.50 2,895.66 -151.96 5,982,923.40 549,021.15 9.24 2,895.66 MWD (2) 8,095.02 87.42 339.49 6,688.81 6,592.81 2,923.71 -161.97 5,982,951.38 549,010.95 5.88 2,923.71 MWD (2) 8,125.37 89.45 343.19 6,689.64 6,593.64 2,952.45 -171.67 5,982,980.05 549,001.06 13.90 2,952.45 MWD(2) 8,155.58 87.02 344.55 6,690.57 6,594.57 2,981.46 -180.06 5,983,009.00 548,992.48 9.22 2,981.46 MWD(2) 8,185.51 86.80 346.94 6,692.18 6,596.18 3,010.42 -187.42 5,983,037.91 548,984.93 8.01 3,010.42 MWD (2) 8,215.50 87.42 349.96 6,693.69 6,597.69 3,039.76 -193.42 5,983,067.21 548,978.75 10.27 3,039.76 MWD (2) 8,245.34 87.70 352.72 6,694.96 6,598.96 3,069.23 -197.91 5,983,096.65 548,974.06 9.29 3,069.23 MWD (2) 8,275.35 86.65 354.34 6,696.44 6,600.44 3,099.01 -201.28 5,983,126.40 548,970.49 6.43 3,099.01 MWD (2) 8,305.44 84.22 356.00 6,698.84 6,602.84 3,128.90 -203.81 5,983,156.27 548,967.77 9.77 3,128.90 MWD (2) 8,334.71 81.97 357.93 6,702.36 6,606.36 3,157.91 -205.35 5,983,185.27 548,966.04 10.10 3,157.91 MWD (2) 8,365.30 80.00 359.80 6,707.15 6,611.15 3,188.12 -205.95 5,983,215.46 548,965.24 8.83 3,188.12 MWD (2) 8,395.28 77.35 1.88 6,713.04 6,617.04 3,21250 -205.52 5,983,244.85 548,965.48 11.15 3,217.50 MWD (2) 8,425.16 76.12 0.62 6,719.89 6,623.89 3,246.58 -204.88 5,983,273.93 - 548,965.92 5.81 3,246.58 MWD (2) 8,454.96 75.96 358.32 6,727.08 6,631.08 3,275.50 -205.15 5,983,302.84 548,965.47 7.51 3,275.50 MWD (2) 8,484.35 76.14 355.94 6,734.17 6,638.17 3,303.98 -206.58 5,983,331.31 548,963.85 7.88 3,303.98 MWD (2) 8,514.99 76.27 353.50 6,741.48 6,645.48 3,333.61 -209.32 5,983,360.92 548,960.92 7.75 3,333.61 MWD (2) 8,545.68 76.72 351.61 6,748.64 6,652.64 3,363.20 -213.19 5,983,390.48 548,956.86 6.16 3,363.20 MWD (2) 8,575.91 79.32 351.18 6,754.92 6,658.92 3,392.43 -217.61 5,983,419.68 548,952.24 8.71 3,392.43 MWD (2) 8,605.79 81.06 350.19 6,760.01 6,664.01 3,421.49 -222.38 5,983,448.70 548,947.28 6.68 3,421.49 MWD (2) 8,636.27 82.64 348.76 6,764.33 6,668.33 3,451.15 -227.89 5,983,478.32 548,941.58 6.96 3,451.15 MWD (2) { 8,665.61 85.14 347.54 6,767.45 6,671.45 3,479.70 -233.88 5,983,506.83 548,935.40 9.47 3,479.70 MWD (2) Yy 8,695.27 86.25 346.83 6,769.68 6,673.68 3,508.54 -240.44 5,983,535.62 548,928.65 4.44 3,508.54 MWD (2) 8,725.80 85.24 348.90 6,771.94 6,675.94 3538.30 -246.84 5,983,565.34 548,922.06 7.53 3,538.30 MWD (2) 8,756.01 85.98 349.87 6,774.26 6,678.26 3,567.90 -252.39 5,983,594.90 548,916.32 4.03 3,567.90 MWD (2) 8,785.82 86.01 351.56 6,776.34 6,680.34 3,597.25 -257.19 5,983,624.21 548,911.33 5.66 3,597.25 MWD (2) 8,815.73 87.21 353.08 6,778.11 6,682.11 3,626.84 -261.18 5,983,653.77 548,907.14 6.47 3,626.84 MWD (2) 8,845.61 88.71 354.98 6,779.17 6,683.17 3,656.54 -264.28 5,983,683.45 548,903.84 8.10 3,656.54 MWD(2) 8,875.02 88.31 356.65 6,779.94 6,683.94 3,685.86 -266.43 5,983,712.75 548,901.50 5.84 3,685.86 MWD (2) 8,905.61 88.37 0.61 6,780.82 6,664.82 3,71642 -267.16 5,983,743.30 548,900.57 12.94 3,716.42 MWD (2) 11272017 1;51:53PM Page 4 COMPASS 5000.1 Build 74 ConocoPhillips hRI ConocoPhillipsDefinitive NOES Survey Report Company: ConocoPhillips (Alaska) Inc. -Kupl Local Co-ordmate Reference: Well 1H-16 Project: Kuparuk River Unit ND Reference: 1H-16 @ 96.00usft (11-1-16) Site: Kupamk 1 H Pad MD Reference: 1 H-16 @ 96.00usft (1 H-16) Well: 1H-16 North Reference: True Wellbore: 11-1-16 Survey Calculation Method: Minimum Curvature Design: 11-1-16 Database: EDM Alaska NSK Sandbox Survey MapMap MD Inc AZI TVD TVDSS +NI -S +El -W Northing East n ® DLS Section Survey Tool Name Annotation (ustt) (°) (°) (usft) (usft) (usft) (usft) (ft) (ft) (1/100') (ft) 8,935.78 86.90 1.02 6,782.07 6,686.07 3,746.56 -266.73 5,983,773.44 548,900.80 5.06 3,746.56 MWD (2) 8,965.29 88.62 1.42 6,783.22 6,687.22 3,776.04 -266.10 5,983,802.92 548,901.24 5.98 3,776.04 MWD (2) 8,995.40 89.79 359.41 6,783.64 6,687.64 3,806.14 -265.88 5,983,833.02 548,901.26 7.72 3,806.14 MWD (2) 9,025.49 90.28 0.13 6,783.62 6,68762 3,836.23 -266.00 5,983,863.11 548,900.94 2.89 3,836.23 MWD (2) 9,055.62 90.71 358.37 6,783.36 6,687.36 3,866.36 -266.40 5,983,893.23 548,900.35 6.01 3,866.36 MWD (2) ` 9,085.54 91.99 357.33 6,782.66 6,686.66 3,896.25 -267.52 5,983,923.11 548,899.03 5.51 3,896.25 MWD (2) 9,115.62 92.70 355.51 6,781.42 6,685.42 3,926.24 -269.40 5,983,953.09 548,896.96 6.49 3,926.24 MWO(2) 9,145.86 93.69 354.31 6,779.74 6,683.74 3,956.32 -272.07 5,983,983.14 548,894.08 5.14 3,956.32 MWO(2) 9,175.54 94.43 352.32 6,777.64 6,681.64 3,985.72 -275.52 5,984,012.51 548,890.44 7.14 3,985.72 MWD (2) 9,205.53 93.13 351.88 6,775.66 6,679.66 4,015.36 -279.63 5,984,042.12 548,886.13 4.58 4,015.36 MWD (2) 9,235.80 91.17 349.77 6,774.52 6,678.52 4,045.22 -284.46 5,984,071.95 548,881.12 9.51 4,045.22 MWD (2) 9,265.40 91.38 347.93 6,773.87 6,677.87 4,074.25 -290.18 5,984,100.94 548,875.20 6.26 4,074.25 MWD (2) 9,295.50 91.01 346.24 6,773.24 6,677.24 4,103.58 -296.90 5,984,130.22 548,868.29 5.75 4,103.58 MWD (2) 9,325.13 91.69 344.98 6,772.54 6,676.54 4,132.27 -304.27 5,984,158.86 548,860.74 4.83 4,132.27 MWD (2) 9,357.32 90.58 342.65 6,771.90 6,675.90 4,163.18 -313.24 5,984,189.71 548,851.57 8.02 4,163.18 MWD (2) 9,390.81 90.31 339.18 6,771.64 6,675.64 4,194.82 -324,18 5,984,221.27 548,840.41 10.39 4,194.82 MWD (2) 9,420.44 89.02 337.36 6,771.82 6,675.82 4,222.34 -335.15 5,984,248.72 548,829.26 7.53 4,222.34 MAD (2) 9,450.44 89.82 335.94 6,772.12 6,676.12 4,249.88 -347.04 5,984,276.18 548,817.19 5.43 4,249.88 MWD (2) 9,480.42 89.29 338.67 6,772.35 6,676.35 4,277.54 -358.61 5,984,303.76 548,805.45 9.28 4,277.54 MWD (2) 9,510.71 88.71 340.45 6,772.88 6,676.88 4,305.92 -369.18 5,984,332.06 548,794.69 6.18 4,305.92 MWD (2) 9,540.51 86.99 341.37 6,774.00 6,678.00 4,334.06 -378.92 5,984,360.13 548,784.76 6.54 4,334.06 MWD (2) 9,570.26 86.50 343.42 6,775.69 6,679.69 4,362.37 -387.91 5,984,388.38 548,775.60 7.07 4,362.37 MWD (2) 9,599.92 86.87 345.71 6,777.40 6,681.40 4,390.91 -395.79 5,984,416.86 548,767.53 7.81 4,390.91 MWD (2) 9,630.99 86.99 348.24 6,779.07 6,683.07 4,421.13 -402.78 5,984,447.04 548,760.34 8.14 4,421.13 MWD (2) 9,661.27 86.04 349.68 6,780.91 6,684.91 4,450.79 -408.57 5,984,476.66 548,754.36 5.69 4,450.79 MWD (2) 9,690.46 86.31 351.59 6,782.86 6,686.86 4,479.53 A13.30 5,984,505.36 548,749.43 6.59 4,479.53 MWD (2) 9,720.31 87.88 351.74 6,784.37 6,688.37 4,509.03 A17.63 5,984,534.83 548,744.92 5.28 4,509.03 MWD (2) 9,750.06 90.18 352.79 6,784.87 6,688.87 4,538.50 -421.63 5,984,564.27 548,740.72 8.50 4,538.50 MWD (2) - 9,780.05 91.78 353.16 6,784.36 6,688.36 4,568.26 -425.30 5,984,594.00 548,736.86 5.48 4,568.26 MWD (2) 9,810.52 93.72 353.72 6,782.90 6,686.90 4,598.49 -428.77 5,984,624.21 548,733.18 6.63 4,598.49 MWD (2) 9,843.75 94.09 355.09 6,780.63 6,68463 4,631.49 432.01 5,984,657.18 548,72973 4.26 4,631.49 MWD (2) 1272017 1:51:53PM Page 5 COMPASS 5000.1 Build 74 ConocoPhillips ■AitI ConocoPhillipsDefinitive Survey Report HUGHES Company: ConocoPhdhps (Alaska) Inc. -Kupt Project: Kuparuk River Unit Site: Kuparuk 1 H Pad Well: 1H-16 Wellbore: 111-16 Design: IH -16 Survey Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Database. Well 1H-16 IH -16 @ 96.00usft (1 H-16) IH -16 @ 96.00usft (1 H-16) True Minimum Curvature EDM Alaska NSK Sandbox Annotation 1272017 1:51; 53PM Page 6 COMPASS 5000.1 Build 74 Map Map Vertical MD Inc Azi TVD TVDSS +NJS +E1 -W Northing EasBng DLS Section Survey Toot Name (usli (I (°I 1uslit) Neill) (+11111111) Wmf (n) (ft) (°noo) (ft) 9,870.00 94.45 355.27 6,778.68 6,682.68 4,657.57 A34.21 5,984,683.25 548,727.36 1.53 4,657.57 MWD (2) 9,900.70 92.52 355.19 6,776.81 6,680.81 4,688.11 -436.75 5,984,713.76 548,724.62 6.29 4,688.11 MWD (2) 9,930.82 94.70 355.39 6,774.92 6,678.92 4,718.06 -439.22 5,964,743.70 548,721.95 7.27 4,718.06 MWD (2) 9,960.15 94.30 355.55 6,772.62 6,676.62 4,747.21 -441.53 5,984,772.83 548,719.45 1.47 4,747.21 MWD (2) 9,990.70 92.73 355.87 6,770.74 6,674.74 4,777.62 -443.81 5,984,803.21 548,716.97 5.24 4,777.62 MWD (2) 10,020.36 89.94 355.31 6,770.05 6,674.05 4,807.18 446.09 5,984,832.76 548,714.50 9.59 4,807.18 MWD (2) 10,050.75 88.65 356.01 6,770.43 6,674.43 4,837.48 -048.39 5,984,863.04 548,712.00 4.83 4,837.48 MWD (2) 10,080.03 90.09 357.02 6,770.75 6,674.75 4,866.70 -450.17 5,984,892.25 548,710.03 6.01 4,866.70 MWD (2) 10,110.47 89.63 359.58 6,770.82 6,674.82 4,897.12 1151.07 5,984,922.66 548,708.92 8.54 4,897.12 MWD (2) 10,140.26 89.54 1.82 6,771.04 6,675.04 4,926.91 A50.71 5,984,952.44 548,709.09 7.53 4,926.91 MWD (2) 10,169.94 88.65 3.65 6,771.51 6,675.51 4,956.55 -449.29 5,984,982.09 548,710.31 6.86 4,956.55 MWD (2) 10,216.00 88.65 3.65 6,772.59 6,676.59 5,002.50 -446.36 5,985,028.06 548,712.94 0.00 5,002.50 PROJECTED to TD Annotation 1272017 1:51; 53PM Page 6 COMPASS 5000.1 Build 74 THE STATE 'ALASKA GOVERNOR BILL WALKER Gary Eller CTD Team Lead ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510-0360 Re: Kuparuk River Field, Kuparuk River Oil Pool, 1H -16A ConocoPhillips Alaska, Inc. Permit to Drill Number: 216-159 Alaska Oil and Gas Conservation Commission 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 www.00gcc.alaska.gov Surface Location: 672' FNL, 1156' FEL, SEC. 33, T12N, R1OE, UM Bottomhole Location: 1143' FNL, 1539' FEL, SEC. 28, T12N, R1OE, UM Dear Mr. Eller: Enclosed is the approved application for permit to re -drill the above referenced development well. This permit to drill does not exempt you from obtaining additional permits or an approval required by law from other governmental agencies and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the AOGCC reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the AOGCC specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or an AOGCC order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. Sincerely, Daniel T. Seamount, Jr. Commissioner DATED this ttday of December, 2016. RECEIVED STATE OF ALASKA DEC 0 2 2016 ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 AAC 25.005 1 a. Type of Work: 1 b. Proposed Well Class: Exploratory -Gas ❑ Service - WAG ❑ Service - Disp (—J 1c. Specify if well is proposed for: Drill ❑ Lateral ❑ Stratigraphic Test ❑ Development - Oil ❑✓ Service - Winj ❑ Single Zone L�i/S� Coalbed Gas ❑ Gas Hydrates ❑ Redrill R1 - Reentry ❑ Exploratory - Oil ❑ Development - Gas ❑ Service - Supply ❑ Multiple Zone Geothermal ❑ Shale Gas ❑ 2. Operator Name: 5. Bond: Blanket Q , Single Well ❑ 11. Well Name and Number: ConocoPhillips Alaska Inc Bond No. 5952180. 1H -16A - 3. Address: 6. Proposed Depth: 12. Field/Pool(s): P.O. Box 100360 Anchorage, AK 99510-0360 MD: 10040 • TVD: 6702 Kuparuk River Field / Kuparuk Oil Pool 4a. Location of Well (Governmental Section): 7. Property Designation (Lease Number): Surface: 672' FNL, 14�6' FEL, Sec 33, T12N, R10E, UM Top of Productive Horizon: 11'�L ADL 25639 8. Land Use Permit: 13. Approximate Spud Date: 3604' FNL, 1166' FEL, Sec 28, T12N, R10E, UM ALK 464 12/15/2016 Total Depth: 9. Acres in Property: 14. Distance to Nearest Property: 1143' FNL, 1539' FEL, Sec 28, T12N, R10E, UM 2560 7800' 4b. Location of Well (State Base Plane Coordinates - NAD 27): 10. KB Elevation above MSL (ft): 96 . 15. Distance to Nearest Well Open Surface: x- 549192 y- 5980029 Zone -4 - GL Elevation above MSL (ft): 54 to Same Pool: 237' (1 H-17) 16. Deviated wells: Kickoff depth: 7150 feet 17. Maximum Potential Pressures in psig (see 20 AAC 25.035) Maximum Hole Angle: 93 degrees , Downhole: 3451 , Surface: 2781- 18. Casing Program: Specifications Top - Setting Depth - Bottom Cement Quantity, c.f. or sacks Hole Casing Weight Grade Coupling Length MD TVD MD TVD (including stage data) 3" 2-3/8" 4.7# L-80 ST -L 2540' 7500' 6572' 10040' 6702' 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): 7510' 6908' N/A 7398' 6813' N/A Casing Length Size Cement Volume MD TVD Conductor/Structural 121' 16" 200 sx CSI 121' 121' Surface 2672' 9-5/8" 570 sx PF E CMT, 190 sx G 2672' 2671' Intermediate 150 sx PF C Top Job Production 7485' 7" 590 sx G 7485' 6887' Liner Perforation Depth MD (ft): Perforation Depth TVD (ft): 6914-6974, 7013-7033, 7218-7243 6404-6455, 6487-6504, 6660-6681 20. Attachments: Property Plat ❑ BOP Sketch ❑ Drilling Program Q Time v. Depth Plot ❑ Shallow Hazard Analysis El Diverter Sketch ❑ Seabed Report ❑ Drilling Fluid Program fl 20 AAC 25.050 requirements0 21. Verbal Approval: Commission Representative: Date 22. 1 hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Mike Callahan X_e' Contact Email mike.callahan(a�cop.com Printed Name Gary Eller Title CTD Team Lead Signature Phone Zb3 - AA' 2 Date \ �b Commission Use Only Permit to Drill 'API Number: Permit Approval See cover letter for other Number:S 50- — 3 5 �� — (� Date: 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:�QP f—�� tn LTJ �(�O 14-1 cf� Samples req'd: Yes ❑ No[� Mud log req'd: Yes❑ N. [Z HzS measures: Yes ❑Nr No❑ Directional svy req'd: Yes[, No❑ Spacing exception req'd: Yes ❑ No[[Z Inclination -only svy req'd: Yes NoGZ y Post initial injection MIT req'd: Yes ❑ No (� APPROVED BY y Approved by: COMMISSIONER THE COMMISSION Date: G 2/ Submit Form and CF40 Revised tit/2gt5)• This perm t is valid for 24 months from the date of approval (20 AAC 25.005(8)) Attachments in Duplicate RIGINAL x(416 ConocoPhilli s p Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 December 1, 2016 Commissioner - State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Dear Commissioner: AECEIVED DEC 02 2016 ConocoPhillips Alaska, Inc. hereby submits applications for permits to drill a dual -lateral out of the Kuparuk Well 1 H-16 using the coiled tubing drilling rig, Nabors CDR3-AC. ✓ _ _ CTD operations are scheduled to begin in December 2016. The objective will be to drill laterals KRU 1H -16A and 1 H-16AL1 targeting the Kuparuk A -sand. Attached to this application are the following documents: — 10-401 Applications for 1H -16A& 1 H-16AL1 — Detailed Summary of Operations — Directional Plans for 1 H-1 6A & 1 H-16AL1 — 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 11-1-16A, 1 H-16AL1 Application for Permit to Drill Document NABOBS ALASKA CDq, 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...........................................................................................6 (Requirements of 20 AAC 25.005(c)(14))............................................................................................................................................... 6 15. Directional Plans for Intentionally Deviated Wells........................................................................6 (Requirements of 20 AAC 25.050(b))..................................................................................................................................................... 6 16. Attachments.................................................................................................................................... 6 Attachment 1: Directional Plans for 1 H-1 6A & 1 H-16AL1 laterals.................................................................................. 6 Attachment 2: Current Well Schematic for 1 H-16........................................................................................................... 6 Attachment 3: Proposed Well Schematic for 1 H-1 6A & 1 H-16AL1 laterals.................................................................... 6 Page 1 of 6 December 1, 2016 PTD Application: 1 H-1 6A, 1 H-16AL1 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 11-1-16A and 1 H-16AL1. Both laterals will be classified as producer wells. 2. Location Summary (Requirements of 20 AAC 25.005(c)(2)) These laterals will target the A sand package in the Kuparuk reservoir. See attached 10-401 form for surface and subsurface coordinates of the 1 H -16A and 1 H-16AL1. 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 CDR3-AC. BOP equipment is as required per 20 AAC 25.036 for thru-tubing drilling operations. — Pipe rams, blind rams and the CT pack off will be pressure tested to 250 psi and to 3 500 psi. Using the maximum formation pressure in the area of 3451 psi in 11-1-07 (i.e. 10.3 ppg EMW) the maximum potential surface pressure in 1H-16, assuming a gas gradient of 0.1 psi/ft, would be 2781 psi./See the "Drilling Hazards Information and Reservoir Pressure" section for more details. — The annular preventer will be tested to 250 psi and 2,500 psi. 4. Drilling Hazards Information and Reservoir Pressure (Requirements of 20 AAC 25.005 (c)(4)) Reservoir Pressure and Maximum Downhole Pressure (Requirements of 20 AAC 25.005 (c)(4)(a)) The formation pressure in KRU 1 H-16 was measured to be 2607 psi (7.7 ppg EMW) on 2/18/2016. The maximum downhole pressure in the 1 H-16 vicinity is to the east in the 1 H-07 injector at 3451 psi (10.3 ppg EMW) from June of 2016. Potential Gas Zones (Requirements of 20 AAC 25.005 (c)(4)(b)) Wells on 1 H pad have injected gas, so there is a chance of encountering free gas while drilling the 1 H-16 laterals. If significant gas is detected in the returns the contaminated mud can be diverted to a storage tank away from the rig. Potential Causes of Hole Problems (Requirements of 20 AAC 25.005 (c)(4)(c)) The major expected risk of hole problems in the 1 H-16 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 1 H-16 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 6 December 1, 2016 PTD Application: 1 H-1 6A, 1 H-16AL1 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 16" 62.5 H-40 Welded 0' 2-3/8", 4.7#, L-80, ST -L slotted liner; IH -16A 7500' 10040' 6572' 6702' aluminum billet on top 40.0 L-80 BTC 0' 2672' 2-3/8", 4.7#, L-80, ST -L slotted liner; 1 H-16AL1 6830' 10500' 6334' 6539` deployment sleeve on top Existing Casing/Liner Information Category OD Weight (ppf) Grade Connection Top MD Btm MD Top TVD Btm TVD Burst psi Collapse psi Conductor 16" 62.5 H-40 Welded 0' 121' 0' 121' 1640 670 Surface 9-5/8" 40.0 L-80 BTC 0' 2672' 0' 2671' 5910 3090 Production 7" 26.0 J-55 ABMOD 0' 7485' 0' 6887' 4980 4320 Tubing 3-1/2" 9.3 J-55 ABM-EUE 0 6841' 0 6343' 7180 7400 7. Diverter System Information (Requirements of 20 AAC 25.005(c)(7)) Nabors CDR3-AC will be operating under 20 AAC 25.036, for thru-tubing drilling operations. Therefore, a diverter system is not required. 8. Drilling Fluids Program (Requirements of 20 AAC 25.005(c)(8)) Diagram of Drilling System A diagram of the Nabors CDR3-AC mud system is on file with the Commission. Description of Drilling Fluid System — Window milling operations: Water-based Power -vis milling fluid (8.6 ppg) — Drilling operations: Water-based Flo -Pro drilling mud (8.6 ppg).VThis 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 potassium formate completion fluid in order to provide formation over -balance and well bore stability while running completions. If higher pressure is encountered, potassium formate will be used to provide over -balance. 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 1H-16 laterals we will target a constant BHP of 11.8 ppg EMW at the window. The constant BHP target will be adjusted through choke pressure and/or mud weight increases to maintain overbalanced conditions if increased reservoir pressure is encountered. Additional choke pressure or increased mud weight may also be employed for improved borehole stability. Any change of circulating friction pressure due to change in pump rates or change in depth of circulation will be offset with back pressure adjustments. Page 3 of 6 December 1, 2016 PTD Application: 1 H-1 6A, 1 H-16AL1 Pressure at the 1 H-16 Window (7150' MD, 6506' TVD) Using MPD 9. Abnormally Pressured Formation Information (Requirements of 20 AAC 25.005(c)(9)) N/A - Application is not for an exploratory or stratigraphic test well. 10. Seismic Analysis (Requirements of 20 AAC 25.005(c)(10)) N/A - Application is not for an exploratory or stratigraphic test well. 11. Seabed Condition Analysis (Requirements of 20 AAC 25.005(c)(11)) N/A - Application is for a land based well. 12. Evidence of Bonding (Requirements of 20 AAC 25.005(c)(12)) Evidence of bonding for ConocoPhillips Alaska, Inc. is on file with the Commission. 13. Proposed Drilling Program (Requirements of 20 AAC 25.005(c)(13)) Summary of Operations Background KRU well 1H-16 is a Kuparuk A Sand producer equipped with 3-1/2" tubing and 7" production casing. The CTD sidetrack will utilize two laterals to target the A4 Sands to north and west of 1 H-16. Prior to CTD operation, coil tubing will lay in a cement plug to isolate the existing A Sand perfs and provide the cement for the cement pilot hole exit. Nabors CDR3-AC will kick-off at 7150' MD. Both laterals will be completed with 2-3/8" slotted liner from TD with the last lateral liner top located inside the tubing tail. The 1H -16A n prthern lateral will exit the cement pilot hole at 7150' MD and TD at 10040' MD, targeting the A4 Sand.+lt will be completed with 2-3/8" slotted liner from TD up to 7500'MD with an aluminum billet for kicking off the 1H-16AL1. The 1H-16AL1 lateral will drill to the west to a TD of 10500' MD targeting the A4 Sand. It will be completed with 2-3/8" slotted liner from TD up to 6830' MD inside the tubing tail with a deployment sleeve. Page 4 of 6 December 1, 2016 Pumps On 1.5 bpm) Pumps Off A -sand Formation Pressure 7.7 pp) 2607 psi 2607 psi Mud Hydrostatic 8.6 ) 2909 psi 2909 psi Annular friction i.e. ECD, 0.090 psi/ft 644 psi 0 psi Mud + ECD Combined no choke pressure) 3553 psi 2909 psi Target BHP at Window 11.8 p) 3992 psi 3992 psi Choke Pressure Required to Maintain Target BHP 439 psi 1083 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 1H-16 is a Kuparuk A Sand producer equipped with 3-1/2" tubing and 7" production casing. The CTD sidetrack will utilize two laterals to target the A4 Sands to north and west of 1 H-16. Prior to CTD operation, coil tubing will lay in a cement plug to isolate the existing A Sand perfs and provide the cement for the cement pilot hole exit. Nabors CDR3-AC will kick-off at 7150' MD. Both laterals will be completed with 2-3/8" slotted liner from TD with the last lateral liner top located inside the tubing tail. The 1H -16A n prthern lateral will exit the cement pilot hole at 7150' MD and TD at 10040' MD, targeting the A4 Sand.+lt will be completed with 2-3/8" slotted liner from TD up to 7500'MD with an aluminum billet for kicking off the 1H-16AL1. The 1H-16AL1 lateral will drill to the west to a TD of 10500' MD targeting the A4 Sand. It will be completed with 2-3/8" slotted liner from TD up to 6830' MD inside the tubing tail with a deployment sleeve. Page 4 of 6 December 1, 2016 PTD Application: 1 H-1 6A, 1 H-16AL1 Pre -CTD Work 1. RU Slickline: Obtain SBHP, perform injectivity test. 2. RU E -line: Mill out D -nipple to 2.80" diameter, punch 2' of holes in tubing tail 3. RU Coil Tubing: Lay in cement plug in 7" production casing up to holes in tubing tail. 4. RU Slickline: Tag TOC and pressure test to 2000 psi. 5. Prep site for Nabors CDR') -AC and set BPV. Rig Work 1. MIRU Nabors CDR3-AC rig using 2" coil tubing. NU 7-1/16" BOPE, test. 2. 1H -16A Sidetrack (A4 sand - North) i. Mill pilot hole and 2.80" window at 7150' MD. ii. Drill 3" bi-center lateral to TD of 10040' MD. iii. Run 2%" slotted liner with an aluminum billet from TD up to 7500' MD. '). 1H-I6AL1 Lateral (A4 sand - West) i. Kick off of the aluminum billet at 7500' MD. ii. Drill 3" bi-center lateral to TD of 10500' MD. iii. Run 2%" slotted liner with deployment sleeve from TD up to 6830' MD. 4. Freeze protect, set BPV, ND BOPS, and RDMO Nabors CRD3-AC. Post -Rig Work 1. Pull BPV 2. Obtain SBHP 3. Install gas lift design 4. Put on 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. Page 5 of 6 December 1, 2016 PTD Application: 1 H-1 6A, 1 H-16AL1 Liner Running — The 1 H-16 laterals will be displaced to an overbalanced fluid (11.8 ppg potassium formate) prior to running liner. See "Drilling Fluids" section for more details. — While running 2-3/8" slotted liner, a joint of 2-3/8" non -slotted tubing will be standing by for emergency deployment. A floor valve is made up onto this joint ahead of time, and the rig crew conducts a deployment drill with this emergency joint on every slotted liner run. The 2-3/8" rams will provide secondary well control while running 2-3/8" liner. 14. Disposal of Drilling Mud and Cuttings (Requirements of 20 AA 25.005(c)(14)) • No annular injection on this well. • All solid waste will be transported to the grind and inject facility at DS -4 Prudhoe Bay for disposal. • Incidental fluids generated from drilling operations will be injected in a Kuparuk Class II disposal well (1R-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 1H -16A 7800' 1 H-16ALl 8890' — Distance to Nearest Well within Pool Lateral Name Distance Well 1 H-1 6A 237' 1H-17 1 H-16AL1 277' 1 H-1 OA 16.Attachments Attachment 1: Directional Plans for 1H -16A & 1H-16AL1 laterals Attachment 2: Current Well Schematic for 1H-16 Attachment 3: Proposed Well Schematic for 1H -16A & 1H-16AL1 laterals Page 6 of 6 December 1, 2016 ConocoPhillips ConocoPhillips (Alaska) Inc. -Kup1 Kuparuk River Unit Kuparuk 1 H Pad IH -16 1 H-1 6A Plan: 1 H -16A wp01 Standard Planning Report 30 November, 2016 WE P& I BAKER HUGHES ConocoPhillips ConocoPhillips Database: EDM Alaska NSK Sandbox Company: ConocoPhillips (Alaska) Inc. -Kupl Project: Kuparuk River Unit Site: Kuparuk 1 H Pad Well: 1H-16 Wellbore: 1 H-1 6A Design: 1 H-16A_wp01 ConocoPhillips Planning Report Local Co-ordinate Reference: Well 1H-16 TVD Reference: Mean Sea Level MD Reference: 1 H-16 @ 96.00usft (1 H-16) North Reference: True Survey Calculation Method: Minimum Curvature Project Kuparuk River Unit, North Slope Alaska, United States Map System: US State Plane 1927 (Exact solution) System Datum: Mean Sea Level Geo Datum: NAD 1927 (NADCON CONUS) Using Well Reference Point Map Zone: Alaska Zone 04 Using geodetic scale factor rias RAKER HUGHES Site Kuparuk 1 H Pad Site Position: Northing: 5,979,968.84 usft Latitude: 70° 21'21,831 N From: Map Easting: 549,197.16 usft Longitude: 149° 36' 1.675 W Position Uncertainty: 0.00 usft Slot Radius: 0.000 in Grid Convergence: 0.38 ° Wellbore IH -16A Magnetics Model Name Sample Date Declination Dip Angle Field Strength (nT) BGGM2016 1/1/2017 17.87 80.97 57,549 Design 1 H-16A_wp01 Audit Notes: Version: Phase: PLAN Tie On Depth: 7,084.10 Vertical Section: Depth From (TVD) +Nl-S +E/ -W Direction (usft) (usft) (usft) (°) 0.00 0.00 0.00 0.00 11/30/2016 8:11:58AM Page 2 COMPASS 5000.1 Build 74 Well 1H-16 Well Position +N/ -S 0.00 usft Northing: 5,980,029.08 usft Latitude: 700 21' 22.424 N +E/ -W 0.00 usft Easting: 549,192.10 usft Longitude: 149° 36' 1.811 W Position Uncertainty 0.00 usft Wellhead Elevation: usft Ground Level: 0.00 usft Wellbore IH -16A Magnetics Model Name Sample Date Declination Dip Angle Field Strength (nT) BGGM2016 1/1/2017 17.87 80.97 57,549 Design 1 H-16A_wp01 Audit Notes: Version: Phase: PLAN Tie On Depth: 7,084.10 Vertical Section: Depth From (TVD) +Nl-S +E/ -W Direction (usft) (usft) (usft) (°) 0.00 0.00 0.00 0.00 11/30/2016 8:11:58AM Page 2 COMPASS 5000.1 Build 74 ConocoPhillips WE al ConocoPhillips Planning Report BAKER HUGHES Database: EDM Alaska NSK Sandbox Company: ConocoPhillips (Alaska) Inc. -Kup1 Project: Kuparuk River Unit Site: Kuparuk 1 H Pad Well: 1H-16 Wellbore: IH -16A Design: 1 H-16A_wp01 Plan Sections Dogleg Build Turn Measured Rate Rate TVD Below TFO Depth Inclination Azimuth System +N/ -S (usft) (°) (°) (usft) (usft) 7,084.10 32.63 1.53 6,451.29 1,993.45 7,150.00 32.42 1.81 6,506.85 2,028.87 7,170.00 36.62 1.81 6,523.33 2,040.19 7,284.16 80.00 1.81 6,581.87 2,134.98 7,323.31 94.00 356.76 6,583.92 2,173.96 7,475.00 93.93 346.12 6,573.40 2,323.38 7,600.00 90.21 338.19 6,568.88 2,442.17 7,700.00 88.99 331.30 6,569.58 2,532.56 7,860.00 88.24 342.48 6,573.46 2,679.43 8,010.00 90.08 352.81 6,575.67 2,825.74 8,150.00 86.74 2.03 6,579.56 2,965.37 8,350.00 72.74 2.03 6,615.10 3,161.56 8,550.00 80.07 349.75 6,662.24 3,354.89 8,710.00 89.80 344.18 6,676.35 3,509.90 8,860.00 92.51 334.03 6,673.31 3,649.81 9,090.00 89.66 349.88 6,668.93 3,867.75 9,320.00 88.28 5.92 6,673.09 4,096.80 9,620.00 87.68 344.92 6,683.77 4,393.98 10,040.00 87.49 14.35 6,701.86 4,808.99 Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Well 1H-16 Mean Sea Level 1 H-16 @ 96,00usft (1 H-16) True Minimum Curvature Target 11/30/2016 8:11:58AM Page 3 COMPASS 5000.1 Build 74 Dogleg Build Turn +E/ -W Rate Rate Rate TFO (usft) (°/100ft) (°/100ft) (°/100ft) (°) 9.14 0.00 0.00 0.00 0.00 10.17 0.39 -0.32 0.42 144.48 10.53 21.00 21.00 0.00 0.00 13.53 38.00 38.00 0.00 0.00 13.03 38.00 35.76 -12.90 340.00 -9.47 7.00 -0.05 -7.02 270.00 -47.72 7.00 -2.98 -6.34 245.00 -90.36 7.00 -1.21 -6.89 260.00 -153.05 7.00 -0.47 6.99 94.00 -185.10 7.00 1.23 6.89 80.00 -191.39 7.00 -2.38 6.58 110.00 -184.42 7.00 -7.00 0.00 180.00 -198.63 7.00 3.67 -6.14 300.00 -234.58 7.00 6.08 -3.48 330.00 -287.98 7.00 1.80 -6.77 285.00 -358.96 7.00 -1.24 6.89 100.00 -367.36 7.00 -0.60 6.98 95.00 -391.14 7.00 -0.20 -7.00 268.00 -393.81 7.00 -0.05 7.01 91.00 Target 11/30/2016 8:11:58AM Page 3 COMPASS 5000.1 Build 74 ConocoPhillips WGaI ConocoPhillips Planning Report BAKER HUGHES Database: Company: Project: Site: Well: Wellbore: Design: EDM Alaska NSK Sandbox ConocoPhillips (Alaska) Inc. -Kupl Kuparuk River Unit Kuparuk 1 H Pad 11-1-16 IH -16A 1H-16A_wp01 Planned Survey 2,347.52 -15.79 Measured Dogleg Toolface Depth Inclination Azimuth (usft) (o) (a) 7,084.10 32.63 1.53 TIP Easting (usft) 7,100.00 32.58 1.60 7,150.00 32.42 1.81 KOP 6,451.29 1,993.45 7,170.00 36.62 1.81 End 21 dls, Start 38 dls 549,188.15 7,200.00 48.02 1.81 7,284.16 80.00 1.81 4 549,188.33 6,506.85 7,300.00 85.66 359.75 7,323.31 94.00 356.76 End 38 dls, Start 7 dls 2,040.19 7,400.00 93.98 351.38 7,475.00 93.93 346.12 6 2,060.35 11.17 7,500.00 93.19 344.53 7,600.00 90.21 338.19 7 13.53 2,134.98 7,700.00 88.99 331.30 8 6,583.85 2,150.69 7,800.00 88.51 338.28 7,860.00 88.24 342.48 9 2,173.96 13.03 7,900.00 88.72 345.23 8,000.00 89.96 352.13 8,010.00 90.08 352.81 10 -90.00 5,982,278.88 8,100.00 87.93 358.74 8,150.00 86.74 2.03 11 5,982,352.12 549,167.38 8,200.00 83.24 2.03 8,300.00 76.24 2.03 8,350.00 72.74 2.03 12 8,400.00 74.51 358.89 8,500.00 78.19 352.75 8,550.00 80.07 349.75 13 8,600.00 83.11 347.99 8,700.00 89.20 344.52 8,710.00 89.80 344.18 14 8,800.00 91.43 338.09 8,860.00 92.51 334.03 16 8,900.00 92.02 336.79 9,000.00 90.78 343.68 9,090.00 89.66 349.88 16 9,100.00 89.59 350.58 9.200.00 88.99 357.55 11/30/2016 8:11:58AM Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Well 1H-16 Mean Sea Level 1 H-16 @ 96.00usft (1 H-16) True Minimum Curvature TVD Below 2,347.52 -15.79 Vertical Dogleg Toolface Map Map System +N/ -S +E/ -W Section Rate Azimuth Northing Easting (usft) (usft) (usft) (usft) (°1100ft) (°) (usft) (usft) 6,451.29 1,993.45 9.14 1,993.45 0.00 0.00 5,982,022.35 549,188.15 6,464.68 2,002.01 9.37 2,002.01 0.39 144.48 5,982,030.92 549,188.33 6,506.85 2,028.87 10.17 2,028.87 0.39 144.42 5,982,057.77 549,188.95 6,523.33 2,040.19 10.53 2,040.19 21.00 0.00 5,982,069.10 549,189.23 6,545.47 2,060.35 11.17 2,060.35 38.00 0.00 5,982,089.26 549,189.74 6,581.87 2,134.98 13.53 2,134.98 38.00 0.00 5,982,163.89 549,191.61 6,583.85 2,150.69 13.74 2,150.69 38.00 -20.00 5,982,179.60 549,191.72 6,583.92 2,173.96 13.03 2,173.96 38.00 -19.74 5,982,202.87 549,190.85 6,578.58 2,250.03 5.13 2,250.03 7.00 -90.00 5,982,278.88 549,182.45 6,573.40 2,323.38 -9.47 2,323.38 7.00 -90.37 5,982,352.12 549,167.38 6,571.85 2,347.52 -15.79 2,347.52 7.00 -115.00 5,982,376.22 549,160.90 6,568.88 2,442.17 -47.72 2,442.17 7.00 -115.10 5,982,470.65 549,128.35 6,569.58 2,532.56 -90.36 2,532.56 7.00 -100.00 5,982,560.74 549,085.12 6,571.75 2,622.96 -132.92 2,622.96 7.00 94.00 5,982,650.85 549,041.98 6,573.46 2,679.43 -153.05 2,679.43 7.00 93.85 5,982,707.19 549,021.47 6,574.52 2,717.84 -164.17 2,717.84 7.00 80.00 5,982,745.52 549,010.10 6,575.67 2,815.83 -183.79 2,815.83 7.00 79.93 5,982,843.37 548,989.85 6,575.67 2,825.74 -185.10 2,825.74 7.00 79.85 5,982,853.27 548,988.47 6,577.24 2,915.44 -191.72 2,915.44 7.00 110.00 5,982,942.91 548,981.26 6,579.56 2,965.37 -191.39 2,965.37 7.00 109.90 5,982,992.84 548,981.26 3,015.15 3,015.15 7.00 -180.00 5,983,042.62 548,982.70 6,601.73 3,113.42 3,113.42 7.00 -180.00 5,983,140.91 548,985.55 3,161.56 3,161.56 7.00 -180.00 5,983,189.06 548,986.94 3,209.53 3,209.53 7.00 -60.00 5,983,237.02 548,987.00 3,306.37 3,306.37 7.00 -59.11 5,983,333.81 548,979.25 3,354.89 3,354.89 7.00 -57.66 5,983,382.27 548,971.46 3,403.42 3,403.42 7.00 -30.00 5,983,430.73 548,961.60 3,500.28 3,500.28 7.00 -29.74 5,983,527.42 548,937.26 3,509.90 3,509.90 7.00 -29.51 5,983,537.02 548,934.51 3,595.02 3,595.02 7.00 -75.00 5,983,621.95 548,904.87 3,649.81 3,649.81 7.00 -75.07 5,983,676.57 548,880.19 6,671.72 3,686.16 3,686.16 7.00 100.00 5,983,712.80 548,863.32 3,780.18 3,780.18 7.00 100.11 5,983,806.59 548,828.92 3,867.75 3,867.75 7.00 100.28 5,983,894.01 548,807.78 3,877.61 3,877.61 7.00 95.00 5,983,903.86 548,806.02 6,670.23 3,977.00 -370.99 3,977.00 7.00 95.00 5,984,003.17 548,795.04 6,583.93 6,615.10 6,629.19 6,652.81 6,662.24 6,669.55 6,676.26 6,676.35 6,675.37 6,673.31 6,669.27 6,668.93 6,669.00 -189.62 -186.13 -184.42 -184.05 -191.16 -198.63 -208.18 -231.88 -234.58 -263.66 -287.98 -304.61 -338.39 -358.96 -360.66 Page 4 COMPASS 5000.1 Build 74 6,583.93 6,615.10 6,629.19 6,652.81 6,662.24 6,669.55 6,676.26 6,676.35 6,675.37 6,673.31 6,669.27 6,668.93 6,669.00 -189.62 -186.13 -184.42 -184.05 -191.16 -198.63 -208.18 -231.88 -234.58 -263.66 -287.98 -304.61 -338.39 -358.96 -360.66 Page 4 COMPASS 5000.1 Build 74 1 ConocoPhillips FGFAI ConocoPhillips Planning Report BAKER HUGHES Database: Company: Project: Site: Well: Wellbore: Design: EDM Alaska NSK Sandbox ConocoPhillips (Alaska) Inc. -Kupl Kuparuk River Unit Kuparuk 1 H Pad 1 H-16Survey 1 H -16A ✓ IH -16A wpOl Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Calculation Method: Well 1 H-16 Mean Sea Level 1 H-16 @ 96.00usft (1 H-16) True Minimum Curvature Planned Survey Measured TVD Below Vertical Dogleg Toolface Map Map Depth Inclination Azimuth System +N/ -S +E/ -W Section Rate Azimuth Northing Easting (usft) (o) (1 (usft) (usft) (usft) (usft) (°1100ft) (1) (usft) (usft) 9,300.00 88.40 4.53 6,672.51 4,076.90 -369.18 4,076.90 7.00 94.91 5,984,103.07 548,796.19 9,320.00 88.28 5.92 6,673.09 4,096.80 -367.36 4,096.80 7.00 94.75 5,984,122.98 548,797.88 17 9,400.00 88.10 0.32 6,675.62 4,176.61 -363.00 4,176.61 7.00 -92.00 5,984,202.81 548,801.72 9,500.00 87.89 353.32 6,679.13 4,276.34 -368.53 4,276.34 7.00 -91.82 5,984,302.49 548,795.53 9,600.00 87.71 346.32 6,682.97 4,374.63 -386.18 4,374.63 7.00 -91.58 5,984,400.65 548,777.24 9,620.00 87.68 344.92 6,683.77 4,393.98 -391.14 4,393.98 7.00 -91.31 5,984,419.97 548,772.15 18 9,700.00 87.59 350.52 6,687.07 4,472.06 -408.13 4,472.06 7.00 91.00 5,984,497.93 548,754.65 9,800.00 87.52 357.53 6,691.34 4,571.36 -418.52 4,571.36 7.00 90.77 5,984,597.15 548,743.61 9,900.00 87.48 4.54 6,695.71 4,671.19 -416.72 4,671.19 7.00 90.47 5,984,696.98 548,744.76 10,000.00 87.48 11.54 6,700.11 4,770.05 -402.76 4,770.05 7.00 90.16 5,984,795.92 548,758.07 10,040.00 87.49 14.35 6,701.86 4,808.99 -393.81 4,808.99 7.00 89.86 5,984,834.91 548,766.76 Planned TD at 10040.00 11/30/2016 8:11:58AM Page 5 COMPASS 5000.1 Build 74 ConocoPhillips FIC kI ConocoPhillips Planning Report BAKER HUGHES Database: EDM Alaska NSK Sandbox Company: ConocoPhillips (Alaska) Inc. -Kupl Project: Kuparuk River Unit Site: Kuparuk 1 H Pad Well: 11-1-16 Wellbore: 1 H-1 6A Design: 1 H-16A_wp01 Targets 5,981,773.00 Target Name 7300.00usft MD (6583.85 TVD, 2150.69 N, 13.74 E) hit/miss target Dip Angle Dip Dir. TVD +N/ -S Shape (1) (1) (usft) (usft) Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: +El -W Northing (usft) (usft) 1H-16A_T07 0.00 0.00 6,677.00 -4,224.081,139,855.59 5,983,290.00 plan misses target center by 1139859.68usft at 7300.00usft MD (6583.85 TVD, 2150.69 N, 13.74 E) Point 1H -16A T08 0.00 0.00 6,669.00 -3,868.461,139,767.92 5,983,645.00 plan misses target center by 1139770.07usft at 7300.00usft MD (6583.85 TVD, 2150.69 N, 13.74 E) Point 1H -16A T05 0.00 0.00 6,615.00 -4,571.381,139,895.32 5,982,943.00 plan misses target center by 1139901.40usft at 7300.00usft MD (6583.85 TVD, 2150.69 N, 13.74 E) Point 1H -16A T03 0.00 0.00 6,574.00 -5,057.921,139,968.13 5,982,457.00 plan misses target center by 1139977.18usft at 7300,00usft MD (6583.85 TVD, 2150.69 N, 13.74 E) Point 1H -16A T02 0.00 0.00 6,568.00 -5,294.621,140,070.59 5,982,221.00 plan misses target center by 1140081.16usft at 7300.00usft MD (6583.85 TVD, 2150.69 N, 13.74 E) Point 1H -16A T04 0.00 0.00 6,579.00 -4,772.531,139,914.00 5,982,742.00 plan misses target center by 1139921.28usft at 7300.00usft MD (6583.85 TVD, 2150.69 N, 13.74 E) Point 1H -16A T09 0.00 0.00 6,683.00 -3,333.961,139,701.42 5,984,179.00 plan misses target center by 1139700.88usft at 7300.00usft MD (6583.85 TVD, 2150.69 N, 13.74 E) Point 1H -16A T10 0.00 0.00 6,702.00 -2,931.071,139,725.07 5,984,582.00 plan misses target center by 1139722.66usft at 7300.00usft MD (6583.85 TVD, 2150.69 N, 13.74 E) Point 11-1-16A T01 0.00 0.00 6,585.00 -5,578.111,140,139.73 5,981,938.00 plan misses target center by 1140152.19usft at 7300.00usft MD (6583.85 TVD, 2150.69 N, 13.74 E) Point 11-1-16A_Fault1_M 0.00 0.00 0.00 -4,792.601,139,924.87 5,982,722.00 plan misses target center by 1139951.29usft at 7300.00usft MD (6583.85 TVD, 2150.69 N, 13.74 E) Rectangle (sides W1,000.00 1-11.00 D0.00) 1H-16 CTD Polygon We 0.00 0.00 0.00 -5,743.651,140,219.66 5,981,773.00 - plan misses target center by 1140252.25usft at 7300.00usft MD (6583.85 TVD, 2150.69 N, 13.74 E) Polygon Point 1 0.00 0.00 0.00 5,981,773.00 Point 2 0.00 45.68 50.30 5,981,819.00 Point 0.00 417.97 12.72 5,982,191.00 Point 0.00 554.64 -87.40 5,982,327.00 Point 5 0.00 713.92 -282.38 5,982,484.98 Point 6 0.00 834.38 -503.62 5,982,603.97 Point 7 0.00 937.68 -854.99 5,982,704.95 Point 0.00 1,014.17 -1,081.52 5,982,779.95 Point 0.00 1,136.16 -1,384.76 5,982,899.93 Point 10 0.00 1,436.69 -1,768.85 5,983,197.90 Point 11 0.00 1,664.23 -2,154.41 5,983,422.89 Point 12 0.00 1,910.01 -2,575.86 5,983,665.87 Point 13 0.00 2,037.17 -2,752.05 5,983,791.86 Point 14 0.00 1,735.70 -2,839.03 5,983,489.85 Point 15 0.00 1,628.51 -2,658.71 5,983,383.86 Point 16 0.00 1,406.77 -2,242.10 5,983,164.88 Point 17 0.00 1,160.03 -1,825.66 5,982,920.90 Point 18 0.00 881.51 -1,444.43 5,982,644.92 Point 19 0.00 754.82 -1,033.20 5,982,520.95 Point 20 0.00 695.01 -756.56 5,982,462.96 Well 1 H-16 Mean Sea Level 1 H-16 @ 96.00usft (1 H-16) True Minimum Curvature Easting (usft) Latitude Longitude 1,688,940.00 70° 6'34.585 N 140' 25' 30.197 W 1,688,850.00 70° 6' 38.167 N 140° 25' 31.157 W 1,688,982.00 70° 6'31.155 N 140° 25' 30.568 W 1,689,058.00 70° 6'26.324 N 140° 25' 30.599 W 1,689,162.00 700 6'23.875 N 140° 25' 28.704 W 1,689,002.00 70° 6' 29.175 N 140° 25' 30.907 W 1,688,780.00 70° 6'43.454 N 140° 25'30.738 W 1,688,801.00 70° 6'47.330 N 1400 25 28.318 W 1,689,233.00 700 6' 21.021 N 140° 25'27.960 W 1,689,013.00 70° 6' 28.964 N 140° 25'30.684 W 1,689,314.00 70° 6' 19.296 N 140° 25'26.399 W 1,689,314.00 1, 689, 363.99 1, 689, 323.97 1,689,222.97 1, 689, 026.97 1, 688, 804.96 1,688,452.95 1,688,225.95 1, 687, 921.94 1, 687, 535.93 1,687,148.92 1, 686, 725.90 1, 686, 548.90 1,686,463.91 1, 686, 644.91 1, 687, 062.93 1,687,480.94 1,687,863.95 1,688,275.97 1,688,552.97 11/30/2016 8.11:58AM Page 6 COMPASS 5000.1 Build 74 ConocoPhillips /GbI ConocoPhillips Planning Report BAKER HUGHES Database: EDM Alaska NSK SandboxLocal Co-ordinate Reference: Well 1 H-16 Company: ConocoPhillips (Alaska) Inc. -Kup1 TVD Reference: Mean Sea Level Project: Kuparuk River Unit MD Reference: 1 H-16 @ 96.00usft (IH -16) Site: Kuparuk 1 H Pad North Reference: True Well: 1H-16 Survey Calculation Method: Minimum Curvature Wellbore: 1H -16A 1,689,314.00 Design: 1 H-16A_wp01 -4.755.311,138,813.98 5,982,752.00 Point 21 0.00 584.94 -440.24 5,982,354.98 1,688,869.97 Diameter Point 22 0.00 459.94 -289.04 5,982,230.99 1,689,021.97 3.000 Point 23 0.00 20.99 -150.88 5,981,793.00 1,689,163.00 Point 24 0.00 0.00 0.00 5,981,773.00 1,689,314.00 1 H-16AL1_Fault2 0.00 0.00 6,533.00 -4.755.311,138,813.98 5,982,752.00 1,687,902.00 700 6' 30.963 N 140° 26'2.194 W plan misses target center by 1138821.18usft at 7300.00usft MD (6583.85 TVD, 2150.69 N, 13.74 E) Polygon Point 1 6,533.00 0.00 0.00 5,982,752.00 1,687,902.00 Point 6,533.00 1.00 1.00 5,982,753.01 1,687,902.99 1 H-16AL1_Faultl 0.00 0.00 6,587.00 -4,885.381,139,279.18 5,982,625.00 1,688,368.00 70° 6' 29.015 N 140° 25'49.494 W -plan misses target center by 1139287.17usft at 7300.00usft MD (6583.85 TVD, 2150.69 N, 13.74 E) - Polygon Point 1 6,587.00 0.00 0.00 5,982,625.00 1,688,368.00 Point 6,587.00 1.00 1.00 5,982,626.01 1,688,368.99 1 H-16 CTD Polygon Nor 0.00 0.00 0.00 -5,732.621,140,062.71 5,981,783.00 1,689,157.00 70° 6' 19.635 N 140° 25'30.825 W - plan misses target center by 1140095.24usft at 7300.00usft MD (6583.85 TVD, 2150.69 N, 13.74 E) Polygon Point 1 0.00 0.00 0.00 5,981,783.00 1,689,157.00 Point 0.00 373.81 -117.58 5,982,155.99 1,689,036.98 Point 0.00 757.79 -261.09 5,982,538.99 1,688,890.97 Point 0.00 1,246.00 -283.92 5,983,026.99 1,688,864.93 Point 5 0.00 1,811.02 -431.25 5,983,590.97 1,688,713.91 Point 0.00 2,415.53 -497.32 5,984,194.98 1,688,643.88 Point 0.00 2,823.52 -489.66 5,984,602.97 1,688,648.86 Point 0.00 3,090.32 -452.92 5,984,869.98 1,688,683.84 Point 0.00 3,027.21 -131.29 5,984,808.99 1,689,005.85 Point 10 0.00 2,745.58 -193.14 5,984,526.99 1,688,945.85 Point 11 0.00 2,161.47 -186.94 5,983,942.99 1,688,955.89 Point 12 0.00 1,844.19 -149.00 5,983,625.99 1,688,995.91 Point 13 0.00 1,345.03 19.77 5,983,128.00 1,689,167.94 Point 14 0.00 467.98 165.07 5,982,252.01 1,689,318.98 Point 15 0.00 29.62 212.22 5,981,814.01 1,689,369.00 Point 16 0.00 -11.06 161.95 5,981,773.00 1,689,319.00 Point 17 0.00 0.00 0.00 5,981,783.00 1,689,157.00 1 H-16A_Faultl 0.00 0.00 6,578.00 -4,792.601,139,924.87 5,982,722.00 1,689,013.00 70° 6' 28.964 N 140° 25'30.684 W plan misses target center by 1139932.27usft at 7300,00usft MD (6583.85 TVD, 2150.69 N, 13.74 E) Polygon Point 1 6,578.00 0.00 0.00 5,982,722.00 1,689,013.00 Point 6,578.00 1.00 1.00 5,982,723.01 1,689,013.99 1 H-16AL1_Fau1t2_M 0.00 0.00 0.00 -4,755.311,138,813.98 5,982,752.00 1,687,902.00 70° 6'30.963 N 140° 26'2.194 W plan misses target center by 1138840.21 usft at 7300.00usft MD (6583.85 TVD, 2150.69 N, 13.74 E) Rectangle (sides W1,000.00 H1.00 D0.00) 1 H-16A_T06 0.00 0.00 6,663.00 -4,376.321,139,889.60 5,983,138.00 1,688,975.00 700 6' 33.057 N 140° 25'29.887 W plan misses target center by 1139894.55usft at 7300.00usft MD (6583.85 TVD, 2150.69 N, 13.74 E) Point 1 H-16AL1_Faultl_M 0.00 0.00 0.00 -4,885.381,139,279.18 5,982,625.00 1,688,368.00 70° 6'29.015 N 140° 25'49.494 W plan misses target center by 1139306.19usft at 7300.00usft MD (6583.85 TVD, 2150.69 N, 13.74 E) Rectangle (sides W1,000.00 H1.00 D0.00) Casing Points Measured Depth (usft) 10,040.00 Vertical Casing Hole Depth Diameter Diameter (usft) Name (in) (in) 6,701.86 2 3/8" 2 375 3.000 11/30/2016 8:11:58AM Page 7 COMPASS 5000.1 Build 74 Plan Annotations ConocoPhillips WGaI ConocoPhillips Planning Report Vertical BAKER Depth Depth HUGHES Database: EDM Alaska NSK Sandbox Local Co-ordinate Reference: Well 1 H-16 (usft) Company: ConocoPhillips (Alaska) Inc. -Kupl ND Reference: Mean Sea Level 7,084.10 Project: Kuparuk River Unit MD Reference: 1 H-16 @ 96.00usft (1 H-16) TIP Site: Kuparuk 1H Pad North Reference: True 10.17 Well: IH -16 Survey Calculation Method: Minimum Curvature 2,040.19 Wellbore: 1H -16A End 21 dls, Start 38 cls 7,284.16 6,581.87 Design: 1 H-16A_wp01 13.53 4 7,323.31 Plan Annotations Measured Vertical Local Coordinates Depth Depth +N/ -S +E/ -W (usft) (usft) (usft) (usft) Comment 7,084.10 6,451.29 1,993.45 9.14 TIP 7,150.00 6,506.85 2,028.87 10.17 KOP 7,170.00 6,523.33 2,040.19 10.53 End 21 dls, Start 38 cls 7,284.16 6,581.87 2,134.98 13.53 4 7,323.31 6,583.92 2,173.96 13.03 End 38 cls, Start 7 dls 7,475.00 6,573.40 2,323.38 -9.47 6 7,600.00 6,568.88 2,442.17 -47.72 7 7,700.00 6,569.58 2,532.56 -90.36 8 7,860.00 6,573.46 2,679.43 -153.05 9 8,010.00 6,575.67 2,825.74 -185.10 10 8,150.00 6,579.56 2,965.37 -191.39 11 8,350.00 6,615.10 3,161.56 -184.42 12 8,550.00 6,662.24 3,354.89 -198.63 13 8,710.00 6,676.35 3,509.90 -234.58 14 8,860.00 6,673.31 3,649.81 -287.98 15 9,090.00 6,668.93 3,867.75 -358.96 16 9,320.00 6,673.09 4,096.80 -367.36 17 9,620.00 6,683.77 4,393.98 -391.14 18 10,040.00 6,701.86 4,808.99 -393.81 Planned TD at 10040.00 11/30/2016 8:11:58AM Page 8 COMPASS 5000.1 Build 74 Baker Hughes INTEQ WIN aI ConocoPhillips Travelling Cylinder Report BAKER HUGHES Company: ConocoPhillips (Alaska) Inc. -Kupl Project: Kuparuk River Unit Reference Site: Kuparuk 1 H Pad Site Error: 0.00 usft Reference Well: 1 H-16 Well Error: 0.00 usft Reference Wellbore 1 H -16A Reference Design: 1 H-16A_wp01 Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Output errors are at Database: Offset TVD Reference: Well 1H-16 11-1-16 @ 96.00usft (11-1-16) 1 H-16 @ 96.00usft (1 H-16) True Minimum Curvature 1.00 sigma OAKEDMP2 Offset Datum Reference 1 H-16A_wp01 Filter type: GLOBAL FILTER APPLIED: All wellpaths within 200'+ 100/1000 of reference Interpolation Method: MD Interval 25.00usft Error Model: ISCWSA Depth Range: 7,084.10 to 10,040.00usft Scan Method: Tray. Cylinder North Results Limited by: Maximum center -center distance of 1,194.40 usft Error Surface: Elliptical Conic Survey Tool Program Date 11/29/2016 From To (usft) (usft) Survey (Wellbore) Tool Name Description 150.70 7,084.10 1 H-16 (1 H-16) GCT -MS Schlumberger GCT multishot 7,084.10 10,040.00 1H-16A_wp01 (11-1-16A) MWD MWD - Standard Casing Points Measured Vertical Casing Hole Depth Depth Diameter Diameter (usft) (usft) Name 10,040.00 6,797.86 2 3/8" 2-3/8 3 Summary Site Name Offset Well - Wellbore - Design Kuparuk 1 H Pad 1 H-03 - 1 H-03 - 1 H-03 1 H-10 - 1 H-1 OA - 1 H-1 OA 1 H-14 - 1 H-14 - 1 H-14 1 H-16 - 1 H-16 - 1 H-16 1 H-16 - 1 H-16AL1 - 1 H-16AL1_wp02 1 H-17 - 1 H-17 - 1 H-17 1 H-19 - 1 H-19 - 1 H-19 1 H-19 - 1 H-1 9A - 1 H-1 9A 1 H-19 - 1 H-19AL1 - 1 H-19AL1 1 H-19 - 1 H-19ALl-01 - 1 H-19AL1-01 1 H-19 - 1 H-19AL1-01 PB1 - 1 H-19AL1-01 PB1 1 H-19 - 1 H-19AL1 PB1 - 1 H-19AL1 PB1 1H-19-1H-19AL2-1H-19AL2 1 H-19 - 1 H-19APB1 - 1 H-19APB1 1 H-20 - 1 H-20 - 1 H-20 Reference Offset Centre to No -Go Allowable Measured Measured Centre Distance Deviation Warning Depth Depth Distance (usft) from Plan (usft) (usft) (usft) (usft) Offset Design Kuparuk 1 H Pad - 1 H-10 - 1 H-1 OA - 1 H-1 OA Out of range 7,500.00 10,518.00 277.21 278.99 54.87 Pass - Major Risk -GCT -MS, 6994 -MWD Out of range 7,150.00 7,150.00 0.02 1.99 -1.94 FAIL - Major Risk 7,525.00 7,525.00 0.32 1.06 -0.41 FAIL - Minor 1/10 9,400.00 8,150.00 237.07 8.09 236.85 Pass- Minor 1/10 Measured Vertical Measured Vertical Out of range Offset Toolface + Offset Wellbore Centre Out of range Centre to No Go Allowable Warning Depth Depth Out of range Depth Azimuth Out of range +E/ -W Hole Size Centre Distance Out of range (usft) (usft) {usft) (usft) (usft) Out of range (°) (usft) (usft) () Out of range (usft) (usft) 7,084.10 6,547.29 10,200.00 Out of range 32.86 55.20 61.18 2,165.96 Out of range Offset Design Kuparuk 1 H Pad - 1 H-10 - 1 H-1 OA - 1 H-1 OA Offset Site Error: 0.00 usft Survey Program: 97 -GCT -MS, 6994 -MWD Rule Assigned: Major Risk Offset Well Error: 0.00 usft Reference Offset Semi Major Axis Measured Vertical Measured Vertical Reference Offset Toolface + Offset Wellbore Centre Casing - Centre to No Go Allowable Warning Depth Depth Depth Depth Azimuth +N/ -S +E/ -W Hole Size Centre Distance Deviation (usft) (usft) {usft) (usft) (usft) (usft) (°) (usft) (usft) () (usft) (usft) (usft) 7,084.10 6,547.29 10,200.00 6,42968 32.86 55.20 61.18 2,165.96 384.60 2-11/16 429.60 276.80 155.76 Pass - Major Risk 7,095.47 6,556.86 10,225.00 6,431.42 32.89 55.52 58.32 2,185.91 369.63 2-11/16 424.61 277.77 148.64 Pass - Major Risk 7,107.55 6,56704 10,250.00 6,433.37 32.90 55.83 55.41 2205.73 354.51 2-11/16 420.45 278.69 142.66 Pass - Major Risk 7,358.86 6,677.44 10,275.00 6,435.67 33.03 56.16 47.88 2,225.39 339.24 2-11/16 408.59 258.05 179.78 Pass - Major Risk 7,373.66 6,676.41 10,300.00 6,43826 33.05 56.48 46.08 2,244 66 323.53 2-11/16 395.34 260.63 166.07 Pass - Major Risk 7,388.55 6,675.37 10,325.00 6,440.58 33.07 56.82 44.16 2,263.46 307.22 2-11/16 382.12 262.81 152.63 Pass - Major Risk CC - Min Centre to center distance or covergent point, SF - min separation factor, ES - min ellipse separation 11/29/2016 2:26:17PM Page 2 COMPASS 5000.1 Build 74 �, Baker Hughes INTEQ rias ConocoPhillips Travelling Cylinder Report BAKER HUGHES Company: ConocoPhillips (Alaska) Inc. -Kupl Project: Kuparuk River Unit Reference Site: Kuparuk 1 H Pad Site Error: 0.00 usft Reference Well: 1 H-16 Well Error: 0.00 usft Reference Wellbore 11-1-16A Reference Design: 11-1-16A_wp01 Local Co-ordinate Reference: ND Reference: MD Reference: North Reference: Survey Calculation Method: Output errors are at Database: Offset ND Reference: Well 1H-16 1 H-16 @ 96.00usft (1 H-16) 1H-16 @ 96.00usft (1H-16) True Minimum Curvature 1.00 sigma OAKEDMP2 Offset Datum Offset Design Kuparuk 1 H Pad - 1 H-10 - 1 H-1 OA - 1 H-1 OA Offset Site Error: 0.00 usft Survey Program: 97 -GCT -MS, 6994 -MWD Rule Assigned: Major Risk Onset 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 DepthAzimuth +N/ -S +E/ -W Hole Size Centre Distance Deviation (usft) (usft) (usft) (usft) (usft) (usft) (1 (usft) (usft) (") (usft) (usft) (usft) 7,400.00 6,674.58 10,350.00 6,442.88 33.08 57.15 42.42 2,281.83 290.42 2-11/16 368.90 264.67 139.67 Pass - Major Risk 7,418.69 6,673.28 10,375.00 6,445.44 33.11 57.49 40.10 2.299.85 273.28 2-11/16 355.57 267.20 126.21 Pass - Major Risk 7,433.89 6672.23 10,400.00 6,448.34 33.14 57.84 37.99 2,317.35 255.67 2-11/16 342.01 269.41 112.99 Pass - Major Risk 7,450.00 6,671 12 10,425.00 6,451.51 33.16 58.19 35.73 2,334.22 237.49 2-11/16 328.19 271.68 99.72 Pass - Major Risk 7,464.33 6,670.13 10,450.00 6,454.77 33.19 58.54 33.48 2,350.49 218.80 2-11/16 314.26 273.80 86.83 Pass - Major Risk 7,479.44 6,669.10 10,475.00 6,458.00 33.22 58.90 31.07 2,366.29 199.69 2-11/16 300.42 275.94 74.33 Pass - Major Risk 7,494.01 6,668.19 10,500.00 6,461.19 33.24 59.21 28.59 2,381.55 180.15 2-11/16 286.72 277.94 62.41 Pass - Major Risk 7,500.00 6,667.85 10,518.00 6,463.49 33.26 59.40 27.03 2,392.49 166.05 2-11/16 277.21 278.99 54.87 Pass - Major Risk, CC, ES, SF CC - Min Centre to center distance or covergent point, SF - min separation factor, ES - min ellipse separation 11/29/2016 2:26:17PM Page 3 COMPASS 5000.1 Build 74 ConocoPhillips Project: Kuparuk River Unit Site: Kuparuk 1H Pad Azimuths to True North M,pn,ti. North: 17.87' lgnetio Field WELLBORE DETAILS: IH -16A REFERENCE INFORMATION Parent Wellbore: 1H-16 Coordinate, (NE Reference: Well 1H-16, True North Well: 1H-16 spsr,Mh Tie on MID 7084.10 Ventral (TVD) Reference: Mean Sea Laval Wellbore: 1H -16A Plan: IH-16Awpol (11H -16/111-16A) Dip Angle: BO.97' Data 111/2017 Made BGGM2016 +EAW Section (VS) Reference: Slit- (O.00N, 0.001: Measured Depth Reference: 1H.16 @ 96.00usft (lH-16) Easting Calculation Method: Minimum Curvature 6160 6240 6320 6400 CD 648000 -a 6560 6640 6720 6800 6880 6960 7040 Mean Sea L 5700 5400 5100 4800 4500 4200 = 3900 CD O �23600 3300 3000 2700 2400 2100 1800 1500 war a I BAKER HUGHES WELL DETAILS: 1H-16 West( -)/East(+) (3 00 usft/in) +N/ S +EAW Northing Easting Latitude Longitude 0.00 0.00 5980029.08 549192.10 70' 21'22.424 N 149* 36' 1.811 W Sec MD Inc Azi TVDSS +N/ -S +E/ -W Dleg TFace VSect Annotation 1 7084.10 32.63 1.53 6451.29 1993.45 9.14 0.00 0.00 1993.45 TIP 2 7150.00 32.42 1.81 6506.85 2028.87 10.17 0.39 144.48 2028.87 KOP 3 7170.00 36.62 1.81 6523.33 2040.19 10.53 21.00 0.00 2040.19 End 21 d1s, Start 38 dIs 4 7284.16 80.00 1.81 6581.87 2134.98 13.53 38.00 0.00 2134.98 4 5 7323.31 94.00 356.76 6583.92 2173.96 13.03 38.00 340.00 2173.96 End 38 dis, Start 7 dIs 6 7475.00 93.93 346.12 6573.40 2323.38 -9.47 7.00 270.00 2323.38 6 7 7600.00 90.21 338.19 6568.88 2442.17 -47.72 7.00 245.00 2442.17 7 8 7700.00 88.99 331.30 6569.58 2532.56 -90.36 7.00 260.00 2532.56 8 9 7860.00 88.24 342.48 6573.46 2679.43 -153.05 7.00 94.00 2679.43 9 10 8010.00 90.08 352.81 6575.67 2825.74 -185.10 7.00 80.00 2825.74 10 11 8150.00 86.74 2.03 6579.56 2965.37 -191.39 7.00 110.00 2965.37 11 12 8350.00 72.74 2.03 6615.10 3161.56 -184.42 7.00 180.00 3161.56 12 13 8550.00 80.07 349.75 6662.24 3354.89 -198.63 7.00 300.00 3354.89 13 14 8710.00 89.80 344.18 6676.35 3509.90 -234.58 7.00 330.00 3509.90 14 15 8860.00 92.51 334.03 6673.31 3649.81 -287.98 7.00 285.00 3649.81 15 16 9090.00 89.66 349.88 6668.93 3867.75 -358.96 7.00 100.00 3867.75 16 17 9320.00 88.28 5.92 6673.09 4096.80 -367.36 7.00 95.00 4096.80 17 18 9620.00 87.68 344.92 6683.77 4393.98 -391.14 7.00 268.00 4393.98 18 19 10040.00 87.49 14.35 6701.86 4808.99 -393.81 7.00 91.00 4808.99 Planned TD at 10040.00 6160 6240 6320 6400 CD 648000 -a 6560 6640 6720 6800 6880 6960 7040 Mean Sea L 5700 5400 5100 4800 4500 4200 = 3900 CD O �23600 3300 3000 2700 2400 2100 1800 1500 war a I BAKER HUGHES -3600 -3300 -3000 -2700 -2400 -2100 -1800 -1500 -1200 -900 -600 -300 0 300 600 900 1200 1500 1800 West( -)/East(+) (3 00 usft/in) Planno 1004C 00 ,J; !1! 1 A T! 16/, ;-16A IH -16 T09 - ------- - - T kE1 ---------- -- I. 16A -07_ IHA 0/ H-IDJ ----- ---- I Iq-JI6A_rO6_, d 21 c[L, Start & 1 --- _1( A -TO! 7 /,H -16A /0, ---------- 7' ----------- I11-1 I A Fatt 11 6 7 8 9 F I H -y A -T03 03T IH.ICA "'-'C 114- 16A T 2 12 0 - ----- H-16ALI-Fault2 IH 16A � of N I - d 3 d1s, S 7 d rt 7 d s Ei Id 38 d 7 dls IH -I VIH-1 . 21 dIs tart 8 dIs 1 4 1 5 1 6 ALI Fault J1<0P 8 �i TIP I H- 6A: I�Fau Ph nned 7 D `pt I C -3600 -3300 -3000 -2700 -2400 -2100 -1800 -1500 -1200 -900 -600 -300 0 300 600 900 1200 1500 1800 246u 24ou 2366 26v6 7- -u Loau -ou -4u -v uu -bu -ou j44U JDZU JOUU 366U JAW 3640 3920 4000 41060 4160 4240 4320 4400 4480 4560 4640 4720 4800 4880 4960 5040 Vertical Section at 0.00' (80 usft/in) West( -)/East(+) (3 00 usft/in) T kE1 KO �111. IHA 0/ H-IDJ d 21 c[L, Start & 1 7 7' %L1 6 7 8 9 12 Ei Id 38 d 7 dls - 1 3 . 1 4 1 5 1 6 8 �i H-16/ 11-16 I H- 6A: I�Fau Ph nned 7 D `pt I C D40.001 1H- � 6/1 H- 6A L 246u 24ou 2366 26v6 7- -u Loau -ou -4u -v uu -bu -ou j44U JDZU JOUU 366U JAW 3640 3920 4000 41060 4160 4240 4320 4400 4480 4560 4640 4720 4800 4880 4960 5040 Vertical Section at 0.00' (80 usft/in) ConocoPhillips ConocoPhillips (Alaska) Inc. -Kupl Kuparuk River Unit Kuparuk 1H Pad 11-1-16 1 H-16AL1 Plan: 1 H-16AL1_wp02 Standard Planning Report 30 November, 2016 BAKER HUGHES ConocoPhillips ConocoPhillips Database: EDM Alaska NSK Sandbox Company: ConocoPhillips (Alaska) Inc. -Kupl Project: Kuparuk River Unit Site: Kuparuk 1 H Pad Well: 11-1-16 Wellbore: 1 H-16ALl Design: 1 H-16AL1_wp02 ConocoPhillips Planning Report Local Co-ordinate Reference: Well 1 H-16 TVD Reference: Mean Sea Level MD Reference: 1 H-16 @ 96.00usft (1 H-16) North Reference: True Survey Calculation Method: Minimum Curvature Project Kuparuk River Unit, North Slope Alaska, United States Map System: US State Plane 1927 (Exact solution) System Datum: Mean Sea Level Geo Datum: NAD 1927 (NADCON CONUS) Using Well Reference Point Map Zone: Alaska Zone 04 Using geodetic scale factor rias HUGHES Site Kuparuk 1 H Pad Site Position: Northing: 5,979,968.84 usft Latitude: 700 21' 21.831 N From: Map Easting: 549,197.16usft Longitude: 1490 36' 1.675 W Position Uncertainty: 0.00 usft Slot Radius: 0.000 in Grid Convergence: 0.38 ° Well 11-1-16 Well Position +N/ -S 0.00 usft Northing: 5,980,029.08 usft Latitude: 70° 21' 22.424 N +E/ -W 0.00 usft Easting: 549,192.10 usft Longitude: 149° 36' 1.811 W Position Uncertainty 0.00 usft Wellhead Elevation: usft Ground Level: 0.00 usft Wellbore 1 H-16AL1 Magnetics Model Name Sample Date Declination Dip Angle Field Strength (°) C) (nT) BGGM2016 1/11/2017 17.87 80.97 57,549 Design 11-1-16AL1_wp02 Audit Notes: Version: Phase: PLAN Tie On Depth: 7,500.00 Vertical Section: Depth From (TVD) +N/ -S +E/ -W Direction (usft) (usft) (usft) (I 0.00 0.00 0.00 300.00 11/30/2016 8:13:07AM Page 2 COMPASS 5000.1 Build 74 ConocoPhillips rias ConocoPhillips Planning Report BAKER HUGHES Database: EDM Alaska NSK Sandbox Company: ConocoPhillips (Alaska) Inc. -Kup1 Project: Kuparuk River Unit Site: Kuparuk 1 H Pad Well: 11-1-16 Wellbore: 1 H-16AL1 Design: 1 H-16AL1_wp02 Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Well 1 H-16 Mean Sea Level 1 H-16 @ 96.00usft (1 H-16) True Minimum Curvature Plan Sections Measured TVD Below Dogleg Build Turn Depth Inclination Azimuth System +N/ -S +E/ -W Rate Rate Rate TFO (usft) (1) (1) (usft) (usft) (usft) (°/100ft) (°/100ft) (°/100ft) (1) Target 7,500.00 93.19 344.53 6,571.85 2,347.52 -15.79 0.00 0.00 0.00 0.00 7,570.00 87.13 341.03 6,571.65 2,414.34 -36.50 10.00 -8.66 -5.00 210.00 7,640.00 88.36 334.13 6,574.41 2,478.96 -63.16 10.00 1.76 -9.85 280.00 7,740.00 90.96 324.48 6,575.01 2,564.84 -114.14 10.00 2.60 -9.66 285.00 8,000.00 88.67 298.58 6,575.86 2,735.74 -307.12 10.00 -0.88 -9.96 265.00 8,300.00 87.85 268.57 6,585.18 2,805.33 -595.28 10.00 -0.27 -10.00 268.00 8,480.00 91.03 286.29 6,586.95 2,828.52 -773.02 10.00 1.77 9.84 80.00 8,600.00 101.40 292.38 6,573.97 2,867.89 -885.40 10.00 8.64 5.07 30.00 8,700.00 101.22 282.18 6,554.31 2,896.98 -978.90 10.00 -0.18 -10.20 270.00 8,800.00 94.08 275.11 6,540.99 2,911.81 -1,076.76 10.00 -7.14 -7.07 225.00 8,900.00 91.45 284.77 6,536.15 2,929.04 -1,175.02 10.00 -2.63 9.66 105.00 9,100.00 91.36 304.78 6,531.20 3,012.40 -1,355.64 10.00 -0.04 10.00 90.00 9,260.00 94.05 320.57 6,523.60 3,120.36 -1,472.78 10.00 1.68 9.87 80.00 9,460.00 89.74 301.02 6,516.91 3,250.26 -1,623.36 10.00 -2.16 -9.77 258.00 9,610.00 88.46 286.08 6,519.28 3,310.02 -1,760.46 10.00 -0.86 -9.96 265.00 9,910.00 88.16 316.09 6,528.33 3,463.06 -2,014.35 10.00 -0.10 10.00 91.00 10,150.00 89.14 292.10 6,534.07 3,596.56 -2,211.59 10.00 0.40 -9.99 272.00 10,300.00 90.46 307.04 6,534.60 3,670.38 -2,341.68 10.00 0.88 9.96 85.00 10,500.00 87.03 287.33 6,539.04 3,761.29 -2,518.63 10.00 -1.72 -9.86 260.00 11/30/2016 8:13:07AM Page 3 COMPASS 5000.1 Build 74 ConocoPhillips WGaI ConocoPhillips Planning Report BAKER HUGHES Database: EDM Alaska NSK Sandbox Local Co-ordinate Reference: Well 11-1-16 Company: ConocoPhillips (Alaska) Inc. -Kupl TVD Reference: Mean Sea Level Project: Kuparuk River Unit MD Reference: 11-1-16 @ 96.00usft (1H-16) Site: Kuparuk 1H Pad North Reference: True Well: 11-1-16 Survey Calculation Method: Minimum Curvature Wellbore: 1 H-16ALl Design: 1 H-16AL1_wp02 Planned Survey Measured TVD Below Vertical Dogleg Toolface Map Map Depth Inclination Azimuth System +N/ -S +E/ -W Section Rate Azimuth Northing Easting (usft) (I (I (usft) (usft) (usft) (usft) (°/100ft) (°) (usft) (usft) 7,500.00 93.19 344.53 6,571.85 2,347.52 -15.79 1,187.44 0.00 0.00 5,982,376.22 549,160.90 TIP/KOP 7,570.00 87.13 341.03 6,571.65 2,414.34 -36.50 1,238.78 10.00 -150.00 5,982,442.90 549,139.75 Start 10 dls 7,600.00 87.65 338.07 6,573.02 2,442.42 -46.97 1,261.89 10.00 -80.00 5,982,470.90 549,129.10 7,640.00 88.36 334.13 6,574.41 2,478.96 -63.16 1,294.18 10.00 -79.87 5,982,507.33 549,112.67 3 7,700.00 89.92 328.34 6,575.32 2,531.53 -92.02 1,345.45 10.00 -75.00 5,982,559.70 549,083.47 7,740.00 90.96 324.48 6,575.01 2,564.84 -114.14 1,381.27 10.00 -74.91 5,982,592.87 549,061.13 4 7,800.00 90.43 318.50 6,574.28 2,611.76 -151.48 1,437.07 10.00 -95.00 5,982,639.54 549,023.48 7,900.00 89.55 308.54 6,574.30 2,680.54 -223.91 1,534.18 10.00 -95.07 5,982,707.83 548,950.62 8,000.00 88.67 298.58 6,575.86 2,735.74 -307.12 1,633.85 10.00 -95.07 5,982,762.48 548,867.05 5 8,100.00 88.35 288.58 6,578.47 2,775.67 -398.63 1,733.06 10.00 -92.00 5,982,801.80 548,775.29 8,200.00 88.07 278.58 6,581.61 2,799.11 -495.66 1,828.81 10.00 -91.74 5,982,824.60 548,678.12 8,300.00 87.85 268.57 6,585.18 2,805.33 -595.28 1,918.19 10.00 -91.43 5,982,830.17 548,578.47 6 8,400.00 89.61 278.42 6,587.40 2,811.42 -694.94 2,007.55 10.00 80.00 5,982,835.60 548,478.78 8,480.00 91.03 286.29 6,586.95 2,828.52 -773.02 2,083.72 10.00 79.78 5,982,852.19 548,400.60 7 8,500.00 92.76 287.29 6,586.29 2,834.30 -792.16 2,103.18 10.00 30.00 5,982,857.84 548,381.43 8,600.00 101.40 292.38 6,573.97 2,867.89 -885.40 2,200.73 10.00 30.03 5,982,890.82 548,287.97 8 8,700.00 101.22 282.18 6,554.31 2,896.98 -978.90 2,296.24 10.00 -90.00 5,982,919.29 548,194.29 9 8,800.00 94.08 275.11 6,540.99 2,911.81 -1,076.76 2,388.4.1 10.00 -135.00 5,982,933.47 548,096.34 10 8,900.00 91.45 284.77 6,536.15 2,929.04 -1,175.02 2,482.12 10.00 105.00 5,982,950.06 547,997.99 11 9,000.00 91.43 294.77 6,533.64 2,962.82 -1,268.98 2,580.37 10.00 90.00 5,982,983.21 547,903.82 9,100.00 91.36 304.78 6,531.20 3,012.40 -1,355.64 2,680.22 10.00 90.25 5,983,032.22 547,816.84 12 9,200.00 93.07 314.64 6,527.33 3,076.15 -1,432.42 2,778.59 10.00 80.00 5,983,095.46 547,739.65 9,260.00 94.05 320.57 6,523.60 3,120.36 -1,472.78 2,835.64 10.00 80.38 5,983,139.40 547,699.01 13 9,300.00 93.21 316.65 6,521.06 3,150.30 -1,499.17 2,873.47 10.00 -102.00 5,983,169.16 547,672.43 9,400.00 91.05 306.88 6,517.33 3,216.77 -1,573.61 2,971.17 10.00 -102.25 5,983,235.13 547,597.55 9,460.00 89.74 301.02 6,516.91 3,250.26 -1,623.36 3,031.00 10.00 -102.61 5,983,268.30 547,547.59 14 9,500.00 89.39 297.04 6,517.21 3,269.67 -1,658.33 3,070.99 10.00 -95.00 5,983,287.47 547,512.50 9,600.00 88.54 287.07 6,519.02 3,307.17 -1,750.88 3,169.89 10.00 -94.97 5,983,324.36 547,419.72 9,610.00 88.46 286.08 6,519.28 3,310.02 -1,760.46 3,179.61 10.00 -94.79 5,983,327.14 547,410.12 1s 9,700.00 88.32 295.08 6,521.82 3,341.60 -1,844.60 3,268.27 10.00 91.00 5,983,358.18 547,325.78 9,800.00 88.22 305.08 6,524.85 3,391.64 -1,930.98 3,368.10 10.00 90.75 5,983,407.64 547,239.08 9,900.00 88.17 315.09 6,528.01 3,455.92 -2,007.35 3,466.38 10.00 90.44 5,983,471.41 547,162.29 9,910.00 88.16 316.09 6,528.33 3,463.06 -2,014.35 3,476.00 10.00 90.13 5,983,478.50 547,155.25 16 10,000.00 88.50 307.09 6,530.96 3,522.71 -2,081.56 3,564.04 10.00 -88.00 5,983,537.70 547,087.65 10,100.00 88.92 297.10 6,533.22 3,575.76 -2,166.15 3,663.82 10.00 -87.74 5,983,590.19 547,002.73 10,150.00 89.14 292.10 6,534.07 3,596.56 -2,211.59 3,713.58 10.00 -87.51 5,983,610.69 546,957.15 11/30/2016 8:13:07AM Page 4 COMPASS 5000.1 Build 74 10-1 ConocoPhillips Had ConocoPhillips Planning Report BAKER HUGHES Database: EDM Alaska NSK Sandbox Company: ConocoPhillips (Alaska) Inc -Kupl Project: Kuparuk River Unit Site: Kuparuk 1 H Pad Well: 1 H-16 Wellbore: 1 H-16AL1 Design: 1 H-16AL1_wp02 Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Well 1 H-16 Mean Sea Level 1 H-16 @ 96.00usft (1 H-16) True Minimum Curvature Planned Survey Measured TVD Below Vertical Dogleg Toolface Map Map Depth Inclination Azimuth System +Nl-S +El -W Section Rate Azimuth Northing Easting (usft) (°) (°) (usft) (usft) (usft) (usft) (°1100ft) (°) (usft) (usft) 17 10,200.00 89.57 297.08 6,534.63 3,617.36 -2,257.04 3,763.34 10.00 85.00 5,983,631.19 546,911.58 10,300.00 90.46 307.04 6,534.60 3,670.38 -2,341.68 3,863.14 10.00 84.94 5,983,683.64 546,826.60 18 10,400.00 88.72 297.19 6,535.32 3,723.48 -2,426.27 3,962.95 10.00 -100.00 5,983,736.18 546,741.67 10,500.00 87.03 287.33 6,539.04 3,761.29 -2,518.63 4,061.84 10.00 -99.93 5,983,773.39 546,649.07 Planned TD at 10500.00 11/30/2016 8:13:07AM Page 5 COMPASS 5000.1 Build 74 ConocoPhillips WIPAFA. ConocoPhillips Planning Report BAKER HUGHES Database: EDM Alaska NSK Sandbox Company: ConocoPhillips (Alaska) Inc. -Kupl Project: Kuparuk River Unit Site: Kuparuk 1H Pad Well: 1 H-16 Wellbore: 1 H-16AL1 Design: 1 H-16AL1_wp02 Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Targets Target Name hit/miss target Dip Angle Dip Dir. TVD +N/ -S +E/ -W Northing Shape (1) (1) (usft) (usft) (usft) (usft) 1H-16AL1_T03 0.00 0.00 6,588.00 -4,920.851,139,349.96 5,982,590.00 plan misses target center by 1139388.93usft at 7500.00usft MD (6571.85 TVD, 2347.52 N, -15.79 E) Point 1H-16AL1_T01 0.00 0.00 6,576.00 -5,014.771,139,793.39 5,982,499.00 plan misses target center by 1139832.96usft at 7500.00usft MD (6571.85 TVD, 2347.52 N, -15.79 E) Point 1H-16AL1_T08 0.00 0.00 6,530.00 -4,221.221,138,048.39 5,983,281.00 plan misses target center by 1138083.14usft at 7500.00usft MD (6571.85 TVD, 2347.52 N, -15.79 E) Point 1H-16A_Fault1_M 0.00 0.00 0.00 -4,792.601,139,924.87 5,982,722.00 -plan misses target center by 1139981.96usft at 7500.00usft MD (6571.85 TVD, 2347.52 N, -15.79 E) - Rectangle (sides W1,000.00 H1.00 D0.00) 1H-16 CTD Polygon We 0.00 0.00 0.00 -5,743.651,140,219.66 5,981,773.00 - plan misses target center by 1140283.09usft at 7500.00usft MD (6571.85 TVD, 2347.52 N, -15.79 E) Polygon Point 1 0.00 0.00 0.00 5,981,773.00 Point 0.00 45.68 50.30 5,981,819.00 Point 3 0.00 417.97 12.72 5,982,191.00 Point 4 0.00 554.64 -87.40 5,982,327.00 Point 5 0.00 713.92 -282.38 5,982,484.98 Point 6 0.00 834.38 -503.62 5,982,603.97 Point 7 0.00 937.68 -854.99 5,982,704.95 Point 0.00 1,014.17 -1,081.52 5,982,779.95 Point 0.00 1,136.16 -1,384.76 5,982,899.93 Point 10 0.00 1,436.69 -1,768.85 5,983,197.90 Point 11 0.00 1,664.23 -2,154.41 5,983,422.89 Point 12 0.00 1,910.01 -2,575.86 5,983,665.87 Point 13 0.00 2,037.17 -2,752.05 5,983,791.86 Point 14 0.00 1,735.70 -2,839.03 5,983,489.85 Point 15 0.00 1,628.51 -2,658.71 5,983,383.86 Point 16 0.00 1,406.77 -2,242.10 5,983,164.88 Point 17 0.00 1,160.03 -1,825.66 5,982,920.90 Point 18 0.00 881.51 -1,444.43 5,982,644.92 Point 19 0.00 754.82 -1,033.20 5,982,520.95 Point 20 0.00 695.01 -756.56 5,982,462.96 Point 21 0.00 584.94 -440.24 5,982,354.98 Point 22 0.00 459.94 -289.04 5,982,230.99 Point 23 0.00 20.99 -150.88 5,981,793.00 Point 24 0.00 0.00 0.00 5,981,773.00 1H-16AL1_T02 0.00 0.00 6,587.00 -4,940.151,139,547.85 5,982,572.00 plan misses target center by 1139586.95usft at 7500.00usft MD (6571.85 TVD, 2347.52 N, -15.79 E) Point 1H-16AL1 Fault2 0.00 0.00 6,533.00 -4,755.311,138,813.98 5,982,752.00 plan misses target center by 1138851.92usft at 7500.00usft MD (6571.85 TVD, 2347.52 N, -15.79 E) Polygon Point 1 6,533.00 0.00 0.00 5,982,752.00 Point 2 6,533.00 1.00 1.00 5,982,753.01 1H-16AL1 Faultl 0.00 0.00 6,587.00 -4,885.381,139,279.18 5,982,625.00 plan misses target center by 1139317.93usft at 7500.00usft MD (6571.85 TVD, 2347.52 N, -15.79 E) Polygon Point 1 6,587.00 0.00 0.00 5,982,625.00 Point 2 6,587.00 1.00 1.00 5,982,626.01 1H-16 CTD Polygon Nor 0.00 0.00 0.00 -5,732.621,140,062.71 5,981,783.00 Ian misses target center by 1140126.07usft at 7500.00usft MD 6571.85 TVD 2347.52 N -15.79 E Well 1 H-16 Mean Sea Level 1 H-16 @ 96.00usft (1 H-16) True Minimum Curvature Easting (usft) Latitude Longitude 1,688,439.00 70° 6'28.566 N 140' 25'47,630 W 1,688,883.00 70° 6'27.001 N 140° 25' 35.394 W 1,687,133.00 70° 6'37.276 N 140° 26'21.713 W 1,689,013.00 70° 6'28.964 N 140° 25'30.684 W 1,689,314.00 70° 6' 19.296 N 140° 25' 26.399 W 1,689,314.00 1,689,363.99 1,689,323.97 1,689,222.97 1, 689, 026.97 1, 688, 804.96 1,688,452.95 1,688,225.95 1, 687, 921.94 1, 687, 535.93 1,687,148.92 1, 686, 725.90 1,686,548.90 1,686,463.91 1,686,644.91 1, 687, 062.93 1,687,480.94 1, 687, 863.95 1,688,275.97 1,688,552.97 1,688,869.97 1, 689, 021.97 1,689,163.00 1, 689, 314.00 1, 688, 637.00 70° 6'28.087 N 1400 25'42.071 W I 1,687,902.00 70° 6' 30.963 N 140° 26'2.194 W 1, 687, 902.00 1, 687, 902.99 1,688,368.00 70° 6'29.015 N 140° 25'49.494 W 1, 688, 368.00 1, 688, 368.99 1,689,157.00 70° 6' 19.635 N 140° 25'30.825 W 11/30/2016 8:13:07AM Page 6 COMPASS 5000.1 Build 74 ConocoPhillips ConocoPhillips Planning Report Database: EDM Alaska NSK Sandbox Local Co-ordinate Reference: Company: ConocoPhillips (Alaska) Inc. -Kup1 TVD Reference: Project: Kuparuk River Unit MD Reference: Site: Kuparuk 1H Pad North Reference: Well: IH -16 Survey Calculation Method: Wellbore: 1 H-16AL1 757.79 Design: 1 H-16AL1_Wp02 Point4 Polygon Casing Points Measured Point 1 0.00 0.00 0.00 5,981,783.00 Point 0.00 373.81 -117.58 5,982,155.99 Point 3 0.00 757.79 -261.09 5,982,538.99 Point4 0.00 1,246.00 -283.92 5,983,026.99 Point 0.00 1,811.02 -431.25 5,983,590.97 Point 0.00 2,415.53 -497.32 5,984,194.98 Point 7 0.00 2,823.52 -489.66 5,984,602.97 Point 8 0.00 3,090.32 -452.92 5,984,869.98 Point 9 0.00 3,027.21 -131.29 5,984,808.99 Point 10 0.00 2,745.58 -193.14 5,984,526.99 Point 11 0.00 2,161.47 -186.94 5,983,942.99 Point 12 0.00 1,844.19 -149.00 5,983,625.99 Point 13 0.00 1,345.03 19.77 5,983,128.00 Point 14 0.00 467.98 165.07 5,982,252.01 Point 15 0.00 29.62 212.22 5,981,814.01 Point 16 0.00 -11.06 161.95 5,981,773.00 Point 17 0.00 0.00 0.00 5,981,783.00 1H-16AL1_T09 0.00 0.00 6,535.00 -4,060.361,137,768.42 5,983,440.00 plan misses target center by 1137802.25usft at 7500.00usft MD (6571.85 TVD, 2347.52 N, -15.79 E) Point 1H-16AL1_T05 0.00 0.00 6,532.00 -4,683.181,138,796.45 5,982,824.00 plan misses target center by 1138833.94usft at 7500.00usft MD (6571.85 TVD, 2347.52 N, -15.79 E) Point 1H-16AL1_T06 0.00 0.00 6,515.00 -4,504.041,138,473.59 5,983,001.00 plan misses target center by 1138510.00usft at 7500.00usft MD (6571.85 TVD, 2347.52 N, -15.79 E) Point 1H-16A_Fault1 0.00 0.00 6,578.00 -4,792.601,139,924.87 5,982,722.00 plan misses target center by 1139963.02usft at 7500.00usft MD (6571.85 TVD, 2347.52 N, -15.79 E) Polygon Point 1 6,578.00 0.00 0.00 5,982,722.00 Point 6,578.00 1.00 1.00 5,982,723.01 1H-16AL1 Fault2 M 0.00 0.00 0.00 -4,755.311,138,813.98 5,982,752.00 plan misses target center by 1138870.88usft at 7500.00usft MD (6571.85 TVD, 2347.52 N, -15.79 E) Rectangle (sides W1,000.00 H1.00 D0.00) 11-1-16AL1_T04 0.00 0.00 6,554.00 -4,867.421,139,134.28 5,982,642.00 plan misses target center by 1139172.92usft at 7500.00usft MD (6571.85 TVD, 2347.52 N, -15.79 E) Point 1H-16AL1_T10 0.00 0.00 6,540.00 -3,968.461,137,633.01 5,983,531.00 plan misses target center by 1137666.33usft at 7500.00usft MD (6571.85 TVD, 2347.52 N, -15.79 E) Point 1H-16AL1 Fault1 M 0.00 0.00 0.00 -4,885.381,139,279.18 5,982,625.00 plan misses target center by 1139336.88usft at 7500.00usft MD (6571.85 TVD, 2347.52 N. -15.79 E) Rectangle (sides W1,000.00 H1.00 D0.00) 11-1-16AL1_T07 0.00 0.00 6,521.00 -4,396.961,138,311.27 5,983,107.00 plan misses target center by 1138347.04usft at 7500.00usft MD (6571.85 TVD, 2347.52 N, -15.79 E) Point Name i ri.l BAKER HUGHES Well 1H-16 Mean Sea Level 1 H-16 @ 96.O0usft (1 H-16) True Minimum Curvature 1,689,157.00 1, 689, 036.98 1, 688, 890.97 1, 688, 864.93 1,688,713.91 1, 688, 643.88 1, 688, 648.86 1,688,683.84 1, 689, 005.85 1, 688, 945.85 1, 688, 955.89 1,688,995.91 1,689.167.94 1, 689, 318.98 1,689,369.00 1, 689, 319.00 1,689.157.00 1, 686, 852.00 700 6'39.250 N 1400 26'29.001 W 1,687,884.00 70° 6' 31.689 N 140° 262.382 W 1,687,560.00 70° 6' 33.904 N 140° 26'10.813 W 1,689,013.00 70° 6'28.964 N 140° 25' 30.684 W 1,689,013.00 1,689,013.99 1,687,902.00 70° 6' 30.963 N 140° 26'2.194 W 1,688,223.00 70° 6'29.403 N 140° 25'53.547 W 1,686,716.00 70° 6'40.341 N 140'26'32.465 W 1,688,368.00 70° 6'29.015 N 140° 25'49.494 W 1,687,397.00 70° 6'35.183 N 140° 26' 14.978 W Casing Diameter (in) 2 375 Hole Diameter (in) 3.000 11/30/2016 8:13:07AM Page 7 COMPASS 5000.1 Build 74 Casing Points Measured Vertical Depth Depth (usft) (usft) 10,500.00 6,539.04 2 3/8" Name i ri.l BAKER HUGHES Well 1H-16 Mean Sea Level 1 H-16 @ 96.O0usft (1 H-16) True Minimum Curvature 1,689,157.00 1, 689, 036.98 1, 688, 890.97 1, 688, 864.93 1,688,713.91 1, 688, 643.88 1, 688, 648.86 1,688,683.84 1, 689, 005.85 1, 688, 945.85 1, 688, 955.89 1,688,995.91 1,689.167.94 1, 689, 318.98 1,689,369.00 1, 689, 319.00 1,689.157.00 1, 686, 852.00 700 6'39.250 N 1400 26'29.001 W 1,687,884.00 70° 6' 31.689 N 140° 262.382 W 1,687,560.00 70° 6' 33.904 N 140° 26'10.813 W 1,689,013.00 70° 6'28.964 N 140° 25' 30.684 W 1,689,013.00 1,689,013.99 1,687,902.00 70° 6' 30.963 N 140° 26'2.194 W 1,688,223.00 70° 6'29.403 N 140° 25'53.547 W 1,686,716.00 70° 6'40.341 N 140'26'32.465 W 1,688,368.00 70° 6'29.015 N 140° 25'49.494 W 1,687,397.00 70° 6'35.183 N 140° 26' 14.978 W Casing Diameter (in) 2 375 Hole Diameter (in) 3.000 11/30/2016 8:13:07AM Page 7 COMPASS 5000.1 Build 74 `- ConocoPhillips Few aI ConocoPhillips Planning Report Vertical BAKER Depth Depth HUGHES Database: EDM Alaska NSK Sandbox Local Co-ordinate Reference: Well 1H-16 (usft) Company: ConocoPhillips (Alaska) Inc -Kupl TVD Reference: Mean Sea Level 7,500.00 Project: Kuparuk River Unit MD Reference: 1 H-16 @ 96.00usft (1 H-16) TIP/KOP Site: Kuparuk 1 H Pad North Reference: True -36.50 Well: 1H-16 Survey Calculation Method: Minimum Curvature 2,478.96 Wellbore: 1 H-16AL1 3 7,740.00 6,575.01 Design: 1 H-16AL1_wp02 -114.14 4 8,000.00 Plan Annotations Measured Vertical Local Coordinates Depth Depth +N/ -S +E/ -W (usft) (usft) (usft) (usft) Comment 7,500.00 6,571.85 2,347.52 -15.79 TIP/KOP 7,570.00 6,571.65 2,414.34 -36.50 Start 10 dls 7,640.00 6,574.41 2,478.96 -63.16 3 7,740.00 6,575.01 2,564.84 -114.14 4 8,000.00 6,575.86 2,735.74 -307.12 5 8,300.00 6,585.18 2,805.33 -595.28 6 8,480.00 6,586.95 2,828.52 -773.02 7 8,600.00 6,573.97 2,867.89 -885.40 8 8,700.00 6,554.31 2,896.98 -978.90 9 8,800.00 6,540.99 2,911.81 -1,076.76 10 8,900.00 6,536.15 2,929.04 -1,175.02 11 9,100.00 6,531.20 3,012.40 -1,355.64 12 9,260.00 6,523.60 3,120.36 -1,472.78 13 9,460.00 6,516.91 3,250.26 -1,623.36 14 9,610.00 6,519.28 3,310.02 -1,760.46 15 9,910.00 6,528.33 3,463.06 -2,014.35 16 10,150.00 6,534.07 3,596.56 -2,211.59 17 10,300.00 6,534.60 3,670.35 -2,341.68 18 10,500.00 6,539.04 3,761.29 -2,518.63 Planned TD at 10500.00 11/30/2016 8:13:07AM Page 8 COMPASS 5000.1 Build 74 '%- Baker Hughes INTEQ RAN ConocoPhillips Travelling Cylinder Report BAKER HUGHES Company: ConocoPhillips (Alaska) Inc. -Kupl Project: Kuparuk River Unit Reference Site: Kuparuk 1H Pad Site Error: 0.00 usft Reference Well: 11-1-16 Well Error: 0.00 usft Reference Wellbore 1 H-16AL1 Reference Design: 1H-16AL1_wp02 Local Co-ordinate Reference TVD Reference: MD Reference: North Reference: Survey Calculation Method: Output errors are at Database: Offset TVD Reference: Well 1 H-16 1 H-16 @ 96.00usft (1 H-16) 1 H-16 @ 96.00usft (1 H-16) True Minimum Curvature 1.00 sigma OAKEDMP2 Offset Datum leference 1 H-16AL1_wp02 ilter type: GLOBAL FILTER APPLIED: All wellpaths within 200'+ 100/1000 of reference iterpolation Method: MD Interval 25.00usft Error Model: ISCWSA )epth Range: 7,500.00 to 10,500.00usft Scan Method: Tray. Cylinder North results Limited by: Maximum center -center distance of 1,240.40 usft Error Surface: Elliptical Conic Survey Tool Program Date 11/29/2016 - 1 H-10 - 1 H-1 OA - 1 H-1 OA From To offset Site Error: 0.00 us (usft) (usft) Survey (Wellbore) Tool Name Description 150.70 7,084.10 1 H-16 (1 H-16) GCT -MS Schlumberger GCT multishot 7,084.10 7,500.00 1 H-16A_wp01 (11-1-16A) MWD MWD - Standard 7,500.00 10,500.00 1 H-16AL1_wp02 (1 H-16AL1) MWD MWD - Standard Casing Points I Measured Vertical Casing Hole Depth Depth Diameter Diameter (usft) (usft) Name 10,500.00 6,635.04 2 3/8" 2-3/8 3 Summary Kuparuk 1 H Pad - 1 H-10 - 1 H-1 OA - 1 H-1 OA offset Site Error: 0.00 us Reference Offset Centre to No -Go Allowable Offset Well Error: 0.00 us Reference Measured Measured Centre Distance Deviation Warning Site Name Depth Depth Distance (usft) from Plan Casing - Centre to Offset Well - Wellbore - Design (usft) (usft) (usft) Azimuth (usft) +E/ -W Kuparuk 1 H Pad Distance Deviation (usft) (usft) (usft) (usft) (usft) (usft) (°) (usft) 1 H-03 - 1 H-03 - 1 H-03 (") (usft) (usft) (usft) 7,500.00 6,667.85 10,518.00 6,46349 Out of range 1 H-04 - 1 H-04 - 1 H-04 166.05 2-11/16 277.21 278.99 54.87 Pass - Major Risk, CC, ES, SF Out of range 1 H-04 - 1 H-0411 - 1 H-041-1 Out of range 1 H-04 - 1 H-0411-01 - 1 H-0411-01 Out of range 1 H-10 - 1 H-1 OA - 1 H-1 OA 7,500.00 10,518.00 277.21 278.99 54.87 Pass - Major Risk 1 H-14 - IH -14 - IH -14 Out of range 1H-16-1H-16A-1H-16A_wp01 7,524.99 7,525.00 0.32 1.05 -0.32 FAIL - Minor 1/10 1 H-17 - 1 H-17 - 1 H-17 8,100.00 7,250.00 1,091.51 220.48 874.47 Pass - Major Risk 1 H-19 - 1 H-19 - 1 H-19 10,478.58 8,150.00 688.30 318.33 392.03 Pass - Major Risk 1 H-19 - 1 H-1 9A - 1 H-1 9A 10,478.58 8,150.00 688.30 318.14 392.22 Pass - Major Risk 1 H-19 - 1 H-19AL1 - 1 H-19AL1 10,478.58 8,150.00 688.30 318.14 392.22 Pass - Major Risk 1 H-19 - 1 H-19ALl-01 - 1 H-19ALl-01 10,478.58 8,150.00 688.30 318.14 392.22 Pass - Major Risk 1 H-19 - 1 H-19ALl-01 PB1 - 1 H-19ALl-01 PB1 10,478.58 8,150.00 688.30 318.14 392.22 Pass - Major Risk 1 H-19 - 1 H-19AL1 PB1 - 1 H-19AL1 PB1 10,478.58 8,150.00 688.30 318.14 392.22 Pass - Major Risk 1 H-19 - 1 H-19AL2 - 1 H-19AL2 10,478.58 8,150.00 688.30 318.14 392.22 Pass - Major Risk 1 H-19 - 1 H-19APB1 - 1 H-19APB1 10,478.58 8,150.00 688.30 318.14 392.22 Pass - Major Risk 1 H-20 - 1 H-20 - 1 H-20 Out of range )ffset Design Kuparuk 1 H Pad - 1 H-10 - 1 H-1 OA - 1 H-1 OA offset Site Error: 0.00 us i-ey Program: 97 -GCT -MS, 6994 -MWD Rule Assigned: Major Risk Offset Well Error: 0.00 us Reference Offset Semi Major Axis Measured Vertical Measured Vertical Reference Offset Toolface + Offset Wellbore Centre Casing - Centre to No Go Allowable Warning Depth Depth Depth Depth Azimuth +N/ -S +E/ -W Hole Size Centre Distance Deviation (usft) (usft) (usft) (usft) (usft) (usft) (°) (usft) (usft) (") (usft) (usft) (usft) 7,500.00 6,667.85 10,518.00 6,46349 33.26 59.40 27.03 2,392.49 166.05 2-11/16 277.21 278.99 54.87 Pass - Major Risk, CC, ES, SF CC - Min centre to center distance or covergent point, SF - min separation factor, ES - min ellipse separation 11/29/2016 3:00.47PM Page 2 COMPASS 5000.1 Build 74 ConocoPhillips Project: Kuparuk River Unit Site: Kuparuk 1 H Pad Azimuths to True N.rth Magnetic North: 17.87• Magnetic Field WELLBORE DETAILS: 1H-16ALl REFERENCE INFORMATION Parent Wellbore: 1H -16A Co-ordinate (NE) Reference: Well iH-16, True North Well: 1H-16 Strength: 57649.4-T Tie on MD: 7500.00 vertical (TVD) Reference: Mean See Level Wellbore: 1H-16AL1 Dip % glet 80.97• Section (VS) Reference: Slot -(0.60N, 0.00E) Plan: 1H-16AL1_w 02 1H- H- 16/116AL1 P ( t oaf.: 1/12017 Model: BGGM2016 Measured Depth Reference: 1H-16@96.00usfi(l H-16) Northing Calculation Method: Minimum Curvature 600 610 620 O 630 O 640 650 Q c; 660 .V. 670 d) 680 690 700 Mean Sea 5700 5400 5100 4800 4500 ~ 4200 =3900 O 0 X3600 C3300 0 3000 y 2700 0 2400 2100 1800 1500 riF1I BAKER HUGHES WELL DETAILS: 1H-16 +N/ -S +E/ -W Northing Easting Latitude t 4.16/1 ----- Longitude 0.00 0.00 5980029.08 P4 549192.10 70° 21'22.424 N 149° 36' 1.811 W Sec MD Inc Azi TVDSS +N/ -S +E/ -W Dleg TFace VSect Annotation 1 7500.00 B 93.19 344.53 6571.85 2347.52 -15.79 0.00 0.00 1187.44 TIP/KOP 2 7570.00 87.13 341.03 6571.65 2414.34 -36.50 10.00 210.00 1238.78 Start 10 dls 3 7640.00 88.36 . b r p'�' 334.13 6574.41 2478.96 -63.16 10.00 280.00 1294.18 3 4 7740.00 90.96 324.48 6575.01 2564.84 t -114.14 10.00 285.00 1381.27 7 4 5 8000.00 88.67 298.58 6575.86 2735.74 -307.12 10.00 265.00 1633.85 5 6 8300.00 87.85 101"1 H IDA 268.57 6585.18 2805.33 -595.28 10.00 268.00 I, 1918.19 6 7 8480.00 91.03 286.29 6586.95 2828.52 �r rtV/KC -773.02 10.00 80.00 2083.72 TIP/I{P 7 8 8600.00 101.40 292.38 6573.97 2867.89 1H -885.40 10.00 30.00 2200.73 Plann 8 9 8700.00 1 16/111-16 101.22 282.18 6554.31 2896.98 -978.90 10.00 270.00 2296.24 9 10 8800.00 94.08 275.11 6540.99 2911.81 -1076.76 10.00 225.00 2388.41 10 11 8900.00 91.45 284.77 6536.15 2929.04 -1175.02 10.00 105.00 2482.12 11 12 9100.00 91.36 304.78 6531.20 3012.40 -1355.64 10.00 90.00 2680.22 4 12 13 9260.00 Itl IH -1 A 1 .,N 94.05 320.57 6523.60 3120.36 -1472.78 10.00 80.00 2835.64 13 14 9460.00 89.74 301.02 6516.91 3250.26 -1623.36 10.00 258.00 3031.00 14 15 9610.00 88.46 286.08 6519.28 3310.02 -1760.46 10.00 265.00 3179.61 15 16 9910.00 88.16 316.09 14-16/1 -16A 6528.33 3463.06 -2014.35 10.00 91.00 3476.00 16 17 10150.00 89.14 292.10 6534.07 3596.56 -2211.59 10.00 272.00 3713.58 17 18 10300.00 90.46 307.04 6534.60 3670.38 -2341.68 10.00 85.00 3863.14 18 19 10500.00 87.03 287.33 6539.04 3761.29 -2518.63 10.00 260.00 4061.84 Planned TD at 10500.00 600 610 620 O 630 O 640 650 Q c; 660 .V. 670 d) 680 690 700 Mean Sea 5700 5400 5100 4800 4500 ~ 4200 =3900 O 0 X3600 C3300 0 3000 y 2700 0 2400 2100 1800 1500 riF1I BAKER HUGHES -3600 -3300 -3000 -2700 -2400 -2100 -1800 -1500 -1200 -900 -600 -300 0 300 600 900 1200 1500 1800 West( -)/East(+) (300 usft/in) t 4.16/1 ----- -16A P4 nn ad at 10 500.00 tH-161N-16 Ll --- IH -1 /III -1 B o �6j c 6 I b� �o . b r p'�' 13 e 1 I H- 16 A_Fau t 7 1" 101"1 H IDA `rt I, bP "•"r �� 10 Ms �r rtV/KC P TIP/I{P 1H 16AL Fault Plann TI) a 1050000 1 16/111-16 1H-16 Ll F ult] -3600 -3300 -3000 -2700 -2400 -2100 -1800 -1500 -1200 -900 -600 -300 0 300 600 900 1200 1500 1800 .__ .-__ .___ _.__ ......, .--- ---- .,.-- .,--- ---- ... ...... .... 1-1 -1 1-1 1Y 1 I'll I'll I'll I.UU oluu 4VUU 41VU 4LUU 43UU 44VU 4o VU 4000 4/UU Vertical Section at 300.00° (100 usft/in) 11 West( -)/East(+) (300 usft/in) ^I o �6j I e 1" 101"1 H IDA I, TIP/I{P Plann TI) a 1050000 Sta 10 dl 0 11 1 2 13 14 15 17 1 4 Itl IH -1 A 1 .,N 1H-16 Fa 14-16/1 -16A 1H-1 1H-1 H-16 1 F I[2 .__ .-__ .___ _.__ ......, .--- ---- .,.-- .,--- ---- ... ...... .... 1-1 -1 1-1 1Y 1 I'll I'll I'll I.UU oluu 4VUU 41VU 4LUU 43UU 44VU 4o VU 4000 4/UU Vertical Section at 300.00° (100 usft/in) 11 ConocoPhillips Project: Kuparuk River Unit Site: Kuparuk 1H Pad A��mmnsm True Nonn Megne6c Nonn: 17.87° Magnetic Field WELLBORE DETAILS: 1H -16A REFERENCE INFORMATION Parent Wellbore: 1H-16 co-ordinate (N/E) Reference: Well 1H-16, True North Well: 1H-16 Seen ginB7B49.nsnT Tie on MD: 7064.10 Vertical(TVD)Relore.—, 1H-16 @ 96.ODucft (1H-16) Wellbore: 1H -16A Dip Angle: 60.97° Secher,(VS) Reference. Slot -(O.00N, 0.00E) PIan:1H-16A w 01 (IH -16/1H -16A _ P ( j Date: 1/112017 Model: BGGM2016 Measured�e thReference. 1H-16 96.00ucf1(1H-16) P @ Celculalion Method: Minimum Curvature _ //.raI BAKER HUGHES West( -)/East(+) (400 usft/in) KUP PROD 1H-16 COiIOCOI�itIIIIpS Well Attributes Max Angle & MD TD Alaska, Inc. Wellbore API/UW Fieltl Name Wellbore Status ncl (°) MD (ftKB) Act Btm (RKB) 500292231500 KUPARUK RIVER UNIT PROD 35.02 5,383.10 7,510.0 •. i;�Comment H2S (ppm) I Date Annotation End Date KB-Grd (R) Rig Release Date 1H-16, 42120154:14:13 PM SSSV: TRDP 125 12/18/2013 Last W0: 1/10/1993 m ertica sc eanc ectua Annotation Depth (ft B) End Date Annotation Last Mod By End Date Last Tag: SLM 7,192.0 4/192015 Rev Reason: TAG Iehallf 4/21/2015 HANGER; 37.6 �I Casing Strings Casing Description OD (in) ID (in) Top (RKB) Set Depth (RKB) Set Depth (TVD)... WVLen (I... Grade Top Thread i CONDUCTOR i6 15.062 41.0 121.0 121.0 62.50 H40 WELDED ( Casing Description OD (in)ID (in) Top (ftKB) Set Depth (ftKB) Set Depth (TVD)... WVLen (1... Grade Top Thread SURFACE 9 5/8 8.835 40.3 2,671.9 2,671.0 40.00 L-80 BTC Casing Description OD (in)ID (in) Top (ftKB) Set Depth (ftKB) Set Depth (TVD)... IR (I... Grade Top Thread PRODUCTION 7 6.276 39.3 7,485.4 6,886.9 26.00 J-55 ABMOD Tubing Strings Tubing Description String Ma... ID (in) Top (ftKB) Set Depth (ft.. Set Depth (TVD) (... Wt (18Ht1 Grade Top Connection TUBING 31/2 2.992 37.6 6,840.9 6,342.8 9.30 J-55 ABM-EUE Completion Details CONDUCTOR; 41 6121 0 Nominal ID Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des Com (in) 37.6 37.6 0.09 HANGER FMC GEN IV HANGER 3.500 1,793.2 1,793.1 1.00 SAFETY VLV CAMCO TRDP-4A SAFETY VALVE 2.812 SAFETY VLV; 1793.z 6,802.6 6,310.6 32.99 SEAL ASSY BAKER GBH -22 LOCATOR SEAL ASSEMBLY 3.000 6,804.9 6,312.5 32.98 PACKER BAKER FB -1 PERMANENT PACKER (1.5 SPACE OUT 3.000 ABOVE PKR) 6,828.4 6,332.2 32.86 NIPPLE OTIS XN NIPPLE NO GO 2.750 GAS LIFT; 2.498 ,3- 6,840.0 6,342.0 32.80 SOS BAKER SHEAR OUT SUB 3.015 Perforations & Slots Shot Den Top (TVD) Btm (TVD) (shotstt Top (ftKB) St. (ftKB) (ftKB) (ftKB) Zone Date t) Type Com 6,914.0 6,974.0 6,404.2 6,454.6 UNIT D, C4, 11/20/1993 4.0 APERF 180 deg Phasing; 50 deg C-3, 111-16 CCW Orientation; 2.5' Titan Guns SURFACE; 40.3-2,671.9- 7,013.0 7,033.0 6,487.4 6,504.2 C-1, 1H-16 10/13/1993 4.0 APERF 180 deg Phasing; 86 deg CCW Orientation; 2.5' GAS LIFT, 3,930.1 Titan Guns 7,218.0 7,243.0 6,660.3 6,681.4 �A-I, IH -16 6/13/1993 4.0 (PERF 180 deg Phasing; 1 deg CCW oriented;4.5' SWS Mandrel Inserts GAS LIFT; 4,633.5 St ati Top (TVD) Valve Latch Port Size TRO Run N Top (ftKB) (ftKB) Make Model DD(in) S., Type Type (in) (psi) Run Date Com GAS LIFT; 5,337.1 2,498.3 2,498.0 CAMCO KBUG 1 GAS LIFT GLV BTM 0.156 1,278.0 8212010 2 3,930.1 3,889.6 CAMCO KBUG 1 GAS LIFT GLV BK 0.156 1,282.0 8/21/2010 3 4,633.5 4499.5 CAMCO KBUG 1 GAS LIFT GLV BK 0.156 1,274.0 8/21/2010 GAS LIFT; 6,071.1 4 5,337.1 5,095.8 CAMCO KBUG 1 GAS LIFT GLV BK 0.188 1,304.0 821/2010 5j 6,071.1 5,702.1 CAMCO KBUG 1 GAS LIFT GLV BK 0.188 1,296.0 j 8/21/2010 61 6425.9 5,998.3 CAMCO I KBUG 1 JUAS LIFT OV IBK 0.188 11 0.0 8212010 GAS LIFT; 6,425.9 71 6,15481 6,270.5 1 CAMCO IMMU 11/2 1 GAS LIFT jDMY IRK 1 0,0001 0.0 18121r2010 Notes: General & Safety End Date Annotation 9124/2010 NOTE: View Schematic w1 Alaska SchematK9.0 GAS LIFT: 6, 754.8 SEAL ASSY; 6,802.6 PACKER; 6,804.9 NIPPLE; 6,828.4 SOS; 6.8400 APERF; 6,914 0-6,974 0- APERF; 7,013.0-7,033.0 (PERF; 7,218.0.7,243.0 - PRODUCTION; 393-7,485.4 1 H-16 Proposed CTD Schematic 16" 62# H-40 shoe at 121' MD 9-5/8" 40# L-80 shoe at 2672' MD C -sand perfs (sqz'd) 6914'-6974' MD 7013'-7033' MD I IKOP @ 7150' MD "A, and perfs (sqz'd) 8'-7243' MD 7" 26# J-55 shoe at 7485' MD 3-1/2" TRDP-4A SSSV at 1793' MD (includes 2.813" X -profile) 3-1/2" 9.3# J-55 EUE 8rd Tubing to surface 3-1/2" Camco KBUG gas lift mandrels at 2498', 3930', 4634', 5337', 6071', & 6426- 3-1/2" Camco MMG gas lift mandrel at 6755' Baker GBH -22 Locator Seal Assembly at 6803' MD Baker FB -1 packer 6805' MD Otix XN landing nipple 6828' MD (2.75" min ID, will be drilled out to 2.80" ID) 3-1/2" tubing tail at 6840' MD 1H-16AL1 wp02, West TD at 10500' MD Liner Top at 6830' MD 1H-16Awp01, North TD at 10040' MD Liner Billet at 7500' MD Bettis, Patricia K (DOA) From: Callahan, Mike S <Mike.Callahan@conocophillips.com> Sent: Monday, December 05, 2016 2:49 PM To: Bettis, Patricia K (DOA) Subject: RE: KRU 1H -16A: Permit to Drill Application (PTD 216-159) Attachments: LK6108D31.pdf Good afternoon Patricia, You are correct, that is a typo on my part. The correct numbers are 671' FNL and 1156' FEL. Attached is the as built for 1H Pad. Sorry for the confusion, and please let me know if you need anything else. Thanks, Mike From: Bettis, Patricia K (DOA) [mailto:patricia.bettis@alaska.gov] Sent: Monday, December 05, 2016 2:11 PM To: Callahan, Mike S <Mike.Callahan@conocophillips.com> Subject: [EXTERNAL]KRU 1H -16A: Permit to Drill Application (PTD 216-159) Good afternoon Mike, AOGCC records show the surface footage for KRU 1H-16 as 671 FNL and 1156 FEL of Section 33, T12N, R10E. On the application Form 10-401, Box 4a, it is stated that the surface footage is 672 FNL and 1116 FEL. Please confirm the correct FEL footage. And as -built for the surface location would be appreciated. Thank you, Patricia Patricia Bettis Senior Petroleum Geologist Alaska Oil and Gas Conservation Commission 333 West 7th Avenue Anchorage, AK 99501 Tel: (907) 793-1238 CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Patricia Bettis at (907) 793-1238 or patricia.bettis@alaska.gov. 1 12/05/051 MRTJ CC I IRev. Per K05014ACS NOTES 1. BASIS OF LOCATIONS AND ELEVATIONS ARE D.S. 1-H MONUMENTS PER LHD AND ASSOCIATES. 2. COORDINATES SHOWN ARE A.S.P. ZONE 4, N.A.D. 27. 3. ALL ELEVATIONS SHOWN ARE BRITISH PETROLEUM MEAN SEA LEVEL. 4. ALL DISTANCES ARE TRUE. 5. DRILL SITE 1-H GRID NORTH IS ROTATED 4'11'39" WEST FROM GRID NORTH. 6. WELLS 3-8, 16, & 20 SEE DWG. NSK-3.2.1-11, WELLS 1,2,10,11,15,17,19 SEE DWG. CEA-DIHX-6108D9, WELLS 9, 12-14, 18, 21, & 22 SEE DWG. CEA-DIHX-6108D11, AND FOR WELLS UGNU 01 DWG. CEA-DIHX-6108D17. Sec. 33, T. 12 N., R. 10 E. Well No ,Y, A.S.P.s ,X, LATITUDE LONGITUDE SEC. LINE SEC. LINE PAD ELEV. O.G. ELEV. F.N.L. F.E.L. 1 5,979,969.32 549,197.55 70'21'21.836" 149.36'01.663" 732' 1151' 1 54.4' 49.9' 2 5,979,939.43 549,199.75 70'21'21.542" 149'36'01.605" 762' 1149' 54.2' 49.8' 3 5,979,909.70 549,201.04 70'21'21.249" 149'36'01.573" 791' 1148' N/A N/A 4 5,979,789.20 549,210.20 70'21'20.064" 149'36'01.328" 911' 1140' N/A N/A 5 5,980,174.54 549,543.27 70'21'23.832" 149°35'51.517" 528' 803' N/A N/A 6 5,980,054.85 549,551.90 70'21'22.654" 149°35'51.287" 648' 796' N/A N/A 7 5,979,935.13 549,560.55 70'21'21.476" 149'35'51.058" 768' 788' N/A N/A 8 5,979,815.46 549,569.18 70'21'20.299" 149'35'50.828" 888' 781' N/A N/A 9 5,979,964.85 549,559.64 70'21'21.768" 14935'51.079" 738' 789' 54.6' 50.2' 10 5,980,084.49 549,550.97 70'21'22.946" 14935'51.309" 619' 796' 54.4' 50.3' 11 5,980,114.39 549,548.80 70'21'23.240" 149'35'51.367" 589' 798' 54.3' 50.4' 12 5,980,144.15 549,546.49 70'21'23.533" 149'35'51.428" 559' 800' 54.3' 50.3' 13 5,979,993.93 549,557.42 70'21'22.055" 149'35'51.138" 709' 791' 54.4' 50.3' 14 5,980,204.14 549,542.05 70'21'24.123" 149'35'51.547" 499' 804' 54.2' 50.1' 15 5,979,999.18 549,195.34 70'21'22.130" 149'36'01.722" 702' 1153' 54.5' 50.0' 16 5,980,029.08 549,192.10 70'21'22.424" 149°36'01.811" 671' 1156' 1 N/A N/A 17 5,980,058.86 549,191.00 70'21'22.717" 14936'01.838" 642' 1156' 54.4' 49.7' 18 5,979,904.84 549,564.14 70'21'21.178" 149'35'50.959" 799' 785' 54.5' 50.4' 19 5,980,118.88 549,186.59 70'21'23.308" 149'36'01.955" 582' 1160' 54.6' 49.5' 20 5,980,148.10 549 183.14 70'21'23.595" 149'36'02.051" 552' 1164' N/A I N/A 21 5,980,024.57 549 555.22 70`21'22.356" 149'35'51.196" 679' 793' 54.4' 50.2' 22 5,980,089.04 549 188.93 70'21'23.014" 149'36'01.893" 612' 1158' 54.7' 49.6' u9 01 5,980,234.12 549,542.20 70'21'24.418" 149'35'51.536" 469' 804' 54.1' 50.0' Q "I + 49th ................................................ ALAN J. ROOKUS �o A J LS -8035 ,0 AV 40 Ar SURVEYOR'S CERTIFICATE I HEREBY CERTIFY THAT I AM PROPERLY REGISTERED AND LICENSED TO PRACTICE LAND SURVEYING IN THE STATE OF ALASKA AND THAT THIS PLAT REPRESENTS A SURVEY DONE BY ME OR UNDER MY DIRECT SUPERVISION AND THAT ALL DIMENSIONS AND OTHER DETAILS ARE CORRECT AS OF MAY 8, 1998. `." AREA: 1H MODULE:XXXX UNIT: D1 ConocePh i l l i ps DS1 H WELL CONDUCTORS Alaska, Inc. ASBUILT LOCATIONS CADD FILE NO. DRAWING N0: PART: REV: LK6108D31 2/05/05 CEA -D1 HX -6108D31 1 2 of 2 1 TRANSMITTAL LETTER CHECKLIST WELL NAME: LKA U-1 N'= PTD: ✓ Development _ Service _ Exploratory _ Stratigraphic Test Non -Conventional FIELD: ]� 1/�J POOL: � ,rwk 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. , API No. 50- - - - (If last two digits Production should continue to be reported as a function of the original in API number are API number stated above. between 60-69) In accordance with 20 AAC 25.005(f), all records, data and logs acquired for the pilot hole must be clearly differentiated in both well Pilot Hole name ( PH) and API number (50- - - -) from records, data and logs acquired for well (name onpermit). The permit is approved subject to full compliance with 20 AAC 25.055. Approval to produce/inject is contingent upon issuance of a conservation Spacing Exception order approving a spacing exception. (Company Name) Operator assumes the liability of any protest to the spacing exception that may occur. All dry ditch sample sets submitted to the AOGCC must be in no greater Dry Ditch Sample than 30' sample intervals from below the permafrost or from where sam les 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: KUP_ARUK RIV UNIT 11-1-16A Program DEV Well bore seg ❑ PTD#:2161590 Company CON_OCOPHILLIPS ALASKA INC Initial Class/Type DEV / PEND __GeoArea 890_ _ Unit 1116.0_ _ On/Off Shore On Annular Disposal ❑ Administration 17 Nonconven. gas conforms to AS31.05.0300.1.A),0.2.A-D) NA 1 Permit fee attached NA 8 2 Lease number appropriate Yes ADL0025639, entire wellbore, 3 Unique well name and number Yes KRU 11-1-16A. 4 Well located in a defined pool Yes KUPARUK RIVER, KUPARUK RIV OIL - 490100, governed by Conservation Order No. 432D. 5 Well located proper distance from drilling unit boundary Yes CO 432D contains no spacing restrictions with respect to drilling unit boundaries. '6 Well located proper distance from other wells Yes CO 432D has no intenvell spacing_ restrictions. 7 Sufficient acreage available in drilling unit Yes 8 If deviated, is wellbore plat included Yes 9 Operator only affected party Yes 10 Operator has appropriate bond in force Yes Appr Date 11 Permit can be issued without conservation order Yes 12 Permit can be issued without administrative approval Yes PKB 12/6/2016 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 All wells within 1/4 mile -area of review identified (For service well only) NA 16Pre-produced injector: duration of pre -production less than 3 months (For service well only) NA 18 Conductor string provided NA Engineering 19 Surface casing protects all known USDWs NA 20 II I CMT vol adequate to circulate on conductor & surf csg NA 21 CMT vol adequate to tie-in long string to surf csg NA 22 CMT will coverall known productive horizons No 23 Casing designs adequate for C, T B & permafrost Yes 24 Adequate tankage or reserve pit Yes '25 If a re -drill, has a 10-403 for abandonment been approved NA 26 Adequate wellbore separation proposed Yes 27 If diverter required, does it meet regulations NA Appr Date 28 Drilling fluid program schematic & equip list adequate Yes VTL 12/13/2016 29 BOPEs, do they meet regulation Yes 30 BOPS press rating appropriate; test to (put psig in comments) Yes 31 Choke manifold complies w/API RP -53 (May 84) Yes 32 Work will occur without operation shutdown Yes 33 Is presence of H2S gas probable Yes NA Wellbore will be more than 500' from an external property line where ownership or landownership changes. Conductor set in KRU 1 H-16 Surface casing set in KRU 1 H-16 Surface casing set and fully cemented Productive interval will be completed with slotted liner Rig has steel tanks; all waste to approved disposal wells Anti -collision analysis complete; no major risk failures Max formation pressure is 3451 psig(10.3 ppg EMW); will drill w/ 8.6 ppg EMW andmaintainoverbal w/ MPD MPSP is 2781 psig; will test BOPs to 3500-psig H2S measures required 34 Mechanical condition of wells within AOR verified (For service we on y) 35 Permit can be issued w/o hydrogen sulfide measures No Wells on 1H -Pad are 1-12S -bearing. 1-12S measures required. Geology 36 Data presented on potential overpressure zones Yes Max. potential reservoir pressure is 10.3 ppg EMW; will be drilled using 8.6 ppg mud and MPD technique. Appr Date 37 Seismic analysis of shallow gas zones NA PKB 12/6/2016 38 Seabed condition survey (if off -shore) NA 39 Contact name/phone for weekly progress reports [exploratory only] NA Onshore development to be drilled. Geologic Engineering Public Commissioner: Date: Commissioner: Date Commissioner Date