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214-150
ConocoPhillips Alaska P.O. BOX 100360 ANCHORAGE,ALASKA 99510-0360 SG �� JUL 1 6 201 June 22, 2015 Commissioner Cathy Foerster a Alaska Oil & Gas Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 Commissioner Cathy Foerster: Enclosed please find a spreadsheet with a list of wells from the Kuparuk field(KRU). Each of these wells was found to have a void in the conductor. These voids were filled with cement(one with carbolite) and corrosion inhibitor, engineered to prevent water from entering the annular space. As per previous agreement with the AOGCC,this letter and spreadsheet serves as notification that the treatments took place and meets the requirements of form 10-404, Report of Sundry Operations. The attached spread sheet presents the well name,top of cement depth prior to filling and volumes used on each conductor. Please call MJ Loveland or Martin Walters at 907-659-7043, if you have any questions. Sincerely, /./r:// MJ Loveland ConocoPhillips Well Integrity Projects Supervisor ConocoPhillips Alaska Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations(10-404) Kuparuk Field Date 6/22/2015 1E,1Y,2E,2F,2M,2N,2V,3N&3S Pads Corrosion Initial top Vol.of cement Final top of Cement top off Corrosion inhibitor/ Well Name API# PTD# of cement pumped cement date inhibitor sealant date ft bbls ft gal 1E-32 50029227880000 1971320 15" na 15" na 1.8 6/18/2015 1Y-10 50029209340000 1830510 36' 3.70 13" 5/10/2015 4.6 6/20/2015 2E-02 50029235170000 2140780 9' 0.60 24" 6/14/2015 5.1 6/16/2015 2E-03 50029235090000 2132030 4' 0.62 7" 6/13/2015 3.9 6/16/2015 2E-04 50029235050000 2131680 10' 1.29 19" 6/15/2015 7.7 6/16/2015 2F-20 50029227390000 1970160 6' 0.80 13" 4/20/2015 3 6/20/2015 2F-21 50029223525000 2141360 22" 0.10 22" 4/25/2015 15.3 6/19/2015 (.)2F-22 5002923530000 2141500 64" 1.10 17" 4/25/2015 11.5 6/19/2015 2M-36 50103206910000 2141020 8'7" 0.70 10" 5/23/2015 2.1 6/20/2015 2N-322 50103206780000 2131790 13" na 13" na 2.5 6/19/2015 2V-02 50029210370000 1831610 11" 1.00 14" 5/20/2015 2 6/16/2015 3N-11A 50029215800100 2120950 34' 27 cu.ft carbolite 10" 5/26/2015 2 6/18/2015 3S-620 50103206950000 2141670 6'3" 0.60 12" 4/26/2015 2.6 6/18/2015 ZIf —/; T Loepp, Victoria T (DOA) From: Loepp, Victoria T (DOA) Sent: Tuesday, April 21, 2015 8:05 AM To: 'NSK Prod Engr Specialist' Subject: RE: 2F-22 (PTD 214-150) Producer Well Status Follow Up Flag: Follow up Flag Status: Completed Darrell, SCANNED JUN 3 02015 The current status of this well is producer. No additional sundries are needed at this time. Thanx, Victoria From: NSK Prod Engr Specialist [mailto:n1139©co__nocophiIlips.com] Sent: Monday, April 20, 2015 3:48 PM To: Loepp, Victoria T(DOA) Subject: 2F-22 Victoria- I have a question regarding sundry notices for 2F-22 (PTD 2141500).We filed a 10-404 in March stating we were going to produce this well for longer than 30 days and now they want to keep it as a producer indefinitely. In reviewing your database I could not find the current well status listed. Could you tell me what is the status of this well and do I need to file any additional sundries to continue producing this well indefinitely? Thanks Darrell Humphrey / Bob Christensen ConocoPhillips Alaska, Inc. Production Engineering Specialist Office (907) 659-7535 NSK-69 Pager(907) 659-7000 (924) 1 11 4150 RE EIVED 2 5 6 3 6 APR 0 8 2015 Schlumberger V -OGC Drilling & Measurements Transmittal#: 08APR15-SP01 DATA LOGGED MWD/LWD Log Product Delivery M K BENDER Customer: ConocoPhillips Alaska Dispatched To: AOGCC: Makana Bender Well No: 2F-22 *Revision-1* Date Dispatched: 8-Apr-15 Job#: 14AKA0057 Dispatched By: Stephanie Pacillo Well/ Product Description Hardcopy Digital Copy E-Delivery Date Color Log Prints: N/A Contents on CD N/A LAS Digital Data N/A Contents on CD N/A x Directional Data 1 Contents on CD N/A Nad27 x x REVISION-1 updated X,Y values*** As-Built Survey N/A Contents on CD N/A CD 1 Contents on CD N/A Data: DLIS/ASCII x Graphics:pdf/tiff x _ Surveys:pdf,txt ***REV-1 updated X,Y values*** x Please sign and email a copy to: Please sign and email a copy to: Catherine.Roso(a�conocophillips.com AlaskaPTSPrintCenter(c�slb.com Catherine Roso Attn:Stephanie Pacillo 907-265-6189 ATO 1707 it,-) A.442..ftet.,Received By: SNE© JUN 2 6 Zo15 214150 25636 RECEIVED APR 08 2015 AOGCC FINAL _, NADConversion Kuparuk River Unit Kuparuk 2F Pad 2F-22 Definitive Survey Report N A D 2 7) 27 January, 2015 • Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well 2F-22 Project: Kuparuk River Unit TVD Reference: Rig:95.8+27.75 @ 123.55usft(Doyon 141) Site: Kuparuk 2F Pad MD Reference: Rig:95.8+27.75 @ 123.55usft(Doyon 141) Well: 2F-22 North Reference: True Wellbore: 2F-22 Survey Calculation Method: Minimum Curvature Design: 2F-22 Database: OAKED M P2 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 2F-22 Well Position +N/-S 0.00 usft Northing: 5,948,652.00 usft Latitude: 70°16'15.190 N +EI-W 0.00 usft Easting: 517,511.06 usft Longitude: 149°51'30.172 W Position Uncertainty 0.00 usft Wellhead Elevation: usft Ground Level: 95.80 usft Wellbore 2F-22 Magnetics Model Name Sample Date Declination Dip Angle Field Strength (0) (0) (nT) BGGM2014 11/25/2014 19.05 80.87 57,567 Design 2F-22 Audit Notes: Version: 1.0 Phase: ACTUAL Tie On Depth: 27.75 Vertical Section: Depth From(TVD) +NI-S +E/-W Direction (usft) (usft) (usft) (°) 27.75 0.00 0.00 183.00 Survey Program Date From To (usft) (usft) Survey(Wellbore) Tool Name Description Survey Date 79.61 1,008.41 2F-22 Srvy#1-GYD-GC-SS(2F-22) GYD-GC-SS Gyrodata gyro single shots 12/12/2014 3:1E 1,063.31 3,770.69 2F-22 Srvy#2-MWD+IFR-AK-CAZ-SC( MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 12/12/2014 3:1E 3,770.69 13,406.12 2F-22 Srvy#3-MWD+IFR-AK-CAZ-SC( MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 12/18/2014 9:12 13,506.29 21,928.00 2F-22 Srvy#4-MWD+IFR-AK-CAZ-SC( MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 1/2/2015 5:11:01 Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +E/-W Northing Easting DLS Section (usft) (°) (°) (usft) (usft) (usft) (usft) (ft) (ft) (°1100') (ft) Survey Tool Name 27.75 0.00 0.00 27.75 -95.80 0.00 0.00 5,948,652.00 517,511.06 0.00 0.00 UNDEFINED 79.62 0.23 265.47 79.62 -43.93 -0.01 -0.10 5,948,651.99 517,510.95 0.44 0.01 GYD-GC-SS(1) 182.45 0.46 217.97 182.45 58.90 -0.35 -0.56 5,948,651.65 517,510.49 0.34 0.38 GYD-GC-SS(1) 265.72 0.37 214.18 265.72 142.17 -0.84 -0.92 5,948,651.16 517,510.14 0.11 0.88 GYD-GC-SS(1) 357.72 0.69 240.40 357.71 234.16 -1.36 -1.57 5,948,650.64 517,509.49 0.43 1.44 GYD-GC-SS(1) 453.67 1.58 247.75 453.64 330.09 -2.14 -3.30 5,948,649.85 517,507.77 0.94 2.31 GYD-GC-SS(1) 546.40 2.34 260.25 546,32 422.77 -2.95 -6.34 5,948,649.04 517,504.72 0.94 3.27 GYD-GC-SS(1) 638.12 3.11 264.69 637.93 514.38 -3.49 -10.67 5,948,648.48 517,500.40 0.87 4.05 GYD-GC-SS(1) 731.57 5.74 266.92 731.10 607.55 -3.98 -17.86 5,948,647.98 517,493.21 2.82 4.91 GYD-GC-SS(1) 826.60 9.95 264.08 825.22 701.67 -5.08 -30.78 5,948,646.85 517,480.29 4.45 6.69 GYD-GC-SS(1) 915.27 12.72 260.69 912.15 788.60 -7.45 -48.03 5,948,644.44 517,463.04 3.21 9.96 GYD-GC-SS(1) i 1/27/2015 10:29:49AM Page 2 COMPASS 5000.1 Build 65 Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well 2F-22 Project: Kuparuk River Unit TVD Reference: Rig:95.8+27.75 @ 123.55usft(Doyon 141) Site: Kuparuk 2F Pad MD Reference: Rig:95.8+27.75 @ 123.55usft(Doyon 141) Well: 2F-22 North Reference: True Wellbore: 2F-22 Survey Calculation Method: Minimum Curvature Design: 2F-22 Database: OAKEDMP2 Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +E/-W Northing Easting DLS Section (usft) (°) r) (usft) (usft) (usft) (usft) (ft) (ft) r/100') (ft) Survey Tool Name 1,008.41 14.15 262.44 1,002.74 879.19 -10.61 -69.44 5,948,641.23 517,441.65 1.60 14.23 GYD-GC-SS(1) 1,063.31 16.97 260.70 1,055.62 932.07 -12.79 -84.00 5,948,639.02 517,427.09 5.21 17.17 MWD+IFR-AK-CAZ-SC(2) 1,122.73 20.05 258.68 1,111.96 988.41 -16.19 -102.55 5,948,635.57 517,408.55 5.29 21.53 MWD+IFR-AK-CAZ-SC(2) 1,158.10 21.73 257.16 1,145.01 1,021.46 -18.83 -114.88 5,948,632.90 517,396.23 4.99 24.82 MWD+IFR-AK-CAZ-SC(2) 1,207.34 22.32 256.15 1,190.65 1,067.10 -23.10 -132.85 5,948,628.59 517,378.28 1.42 30.02 MWD+IFR-AK-CAZ-SC(2) 1,251.53 22.96 255.34 1,231.44 1,107.89 -27.29 -149.33 5,948,624.37 517,361.80 1.61 35.07 MVVD+IFR-AK-CAZ-SC(2) 1,346.03 21.90 254.44 1,318.79 1,195.24 -36.68 -184.14 5,948,614.89 517,327.02 1.18 46.27 MWD+IFR-AK-CAZ-SC(2) 1,439.88 21.46 253.71 1,405.99 1,282.44 -46.20 -217.50 5,948,605.30 517,293.69 0.53 57.51 MWD+IFR-AK-CAZ-SC(2) 1,531.81 23.47 247.64 1,490.95 1,367.40 -57.88 -250.59 5,948,593.54 517,260.63 3.32 70.92 MWD+IFR-AK-CAZ-SC(2) 1,628.24 26.31 241.06 1,578.43 1,454.88 -75.54 -287.07 5,948,575.80 517,224.20 4.11 90.46 MWD+IFR-AK-CAZ-SC(2) 1,720.45 28.11 239.22 1,660.43 1,536.88 -96.54 -323.62 5,948,554.71 517,187.70 2.15 113.35 MWD+IFR-AK-CAZ-SC(2) 1,816.96 28.19 238.07 1,745.53 1,621.98 -120.23 -362.50 5,948,530.93 517,148.88 0.57 139.04 MWD+IFR-AK-CAZ-SC(2) 1,913.45 30.73 235.12 1,829.54 1,705.99 -146.39 -402.07 5,948,504.69 517,109.37 3.03 167.23 MWD+IFR-AK-CAZ-SC(2) 2,008.67 32.06 231.04 1,910.82 1,787.27 -176.20 -441.69 5,948,474.79 517,069.83 2.63 199.07 MWD+IFR-AK-CAZ-SC(2) 2,100.43 35.23 225.62 1,987.22 1,863.67 -210.04 -479.56 5,948,440.86 517,032.04 4.76 234.85 MWD+IFR-AK-CAZ-SC(2) 2,195.13 38.35 225.07 2,063.05 1,939.50 -249.90 -519.89 5,948,400.91 516,991.80 3.31 276.77 MVVD+IFR-AK-CAZ-SC(2) 2,289.34 41.58 222.06 2,135.25 2,011.70 -293.77 -561.54 5,948,356.95 516,950.26 3.99 322.76 MWD+IFR-AK-CAZ-SC(2) 2,383.00 43.50 221.18 2,204.26 2,080.71 -341.11 -603.59 5,948,309.52 516,908.32 2.15 372.23 MWD+IFR-AK-CAZ-SC(2) 2,468.98 45.03 217.26 2,265.84 2,142.29 -387.60 -641.49 5,948,262.94 516,870.53 3.65 420.64 MWD+IFR-AK-CAZ-SC(2) 2,564.60 46.45 215.40 2,332.58 2,209.03 -442.77 -682.05 5,948,207.68 516,830.11 2.04 477.86 MWD+IFR-AK-CAZ-SC(2) 2,657.20 49.07 211.56 2,394.84 2,271.29 -499.95 -719.81 5,948,150.42 516,792.48 4.17 536.94 MWD+IFR-AK-CAZ-SC(2) 2,748.49 52.56 207.08 2,452.52 2,328.97 -561.65 -754.38 5,948,088.65 516,758.06 5.39 600.36 MWD+IFR-AK-CAZ-SC(2) 2,819.51 53.91 204.63 2,495.03 2,371.48 -612.84 -779.18 5,948,037.41 516,733.38 3.35 652.78 MWD+IFR-AK-CAZ-SC(2) 2,842.45 53.97 204.33 2,508.54 2,384.99 -629.72 -786.86 5,948,020.51 516,725.74 1.09 670.04 MWD+IFR-AK-CAZ-SC(2) 2,934.83 55.11 203.25 2,562.13 2,438.58 -698.57 -817.21 5,947,951.60 516,695.55 1.56 740.38 MWD+IFR-AK-CAZ-SC(2) 3,027.00 57.68 201.85 2,613.14 2,489.59 -769.46 -846.63 5,947,880.64 516,666.30 3.06 812.72 MWD+IFR-AK-CAZ-SC(2) 3,120.12 60.71 199.71 2,660.83 2,537.28 -844.24 -874.98 5,947,805.81 516,638.13 3.81 888.87 MWD+IFR-AK-CAZSC(2) 3,212.18 61.25 199.23 2,705.49 2,581.94 -920.13 -901.81 5,947,729.86 516,611.48 0.74 966.07 MWD+IFR-AK-CAZSC(2) 3,305.12 63.03 197.79 2,748.92 2,625.37 -998.05 -927.89 5,947,651.89 516,585.59 2.35 1,045.24 MWD+IFR-AK-CAZSC(2) 3,396.84 65.11 196.46 2,789.03 2,665.48 -1,076.87 -952.17 5,947,573.02 516,561.49 2.62 1,125.23 MWD+IFR-AK-CAZ-SC(2) 3,491.62 67.26 194.77 2,827.30 2,703.75 -1,160.38 -975.49 5,947,489.47 516,538.36 2.79 1,209.84 MWD+IFR-AK-CAZ-SC(2) 3,585.58 68.57 192.07 2,862.63 2,739.08 -1,245.06 -995.69 5,947,404.75 516,518.37 3.01 1,295.46 MWD+IFR-AK-CAZ-SC(2) 3,679.77 70.33 190.19 2,895.69 2,772.14 -1,331.59 -1,012.70 5,947,318.19 516,501.55 2.64 1,382.76 MWD+IFR-AK-CAZ-SC(2) 3,770.69 70.13 188.59 2,926.45 2,802.90 -1,416.00 -1,026.66 5,947,233.76 516,487.79 1.67 1,467.79 MWD+IFR-AK-CAZ-SC(2) 3,836.66 71.73 189.53 2,948.00 2,824.45 -1,477.57 -1,036.48 5,947,172.17 516,478.12 2.77 1,529.79 MWD+IFR-AK-CAZ-SC(3) 3,904.00 71.44 188.62 2,969.27 2,845.72 -1,540.66 -1,046.56 5,947,109.06 516,468.19 1.36 1,593.32 MWD+IFR-AK-CAZ-SC(3) 10 3/4"x 13-1/2 3,935.28 71.31 188.19 2,979.26 2,855.71 -1,569.98 -1,050.89 5,947,079.73 516,463.93 1.36 1,622.83 MWD+IFR-AK-CAZ-SC(3) 3,999.54 72.33 187.79 2,999.31 2,875.76 -1,630.44 -1,059.38 5,947,019.26 516,455.58 1.69 1,683.65 MWD+IFR-AK-CAZ-SC(3) 4,091.35 71.16 186.56 3,028.07 2,904.52 -1,716.74 -1,071.77 5,946,932.94 516,443.39 1.50 1,770.48 MWD+IFR-AK-CAZ-SC(3) 1/27/2015 10:29.49AM Page 3 COMPASS 5000.1 Build 65 Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well 2F-22 Project: Kuparuk River Unit TVD Reference: Rig:95.8+27.75 @ 123.55usft(Doyon 141) Site: Kuparuk 2F Pad MD Reference: Rig:95.8+27.75 @ 123.55usft(Doyon 141) Well: 2F-22 North Reference: True Wellbore: 2F-22 Survey Calculation Method: Minimum Curvature Design: 2F-22 Database: OAKEDMP2 Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +EI-W Northing Easting DLS Section (usft) (') (°) (usft) (usft) (usft) (usft) (ft) (ft) r1100) (ft) Survey Tool Name 4,183.94 71.33 188.24 3,057.84 2,934.29 -1,803.47 -1,084.58 5,946,846.19 516,430.78 0.38 1,857.76 MWD+IFR-AK-CAZ-SC(3) 4,279.19 70.61 188.55 3,088.90 2,965.35 -1,892.55 -1,097.72 5,946,757.09 516,417.85 0.82 1,947.41 MWD+IFR-AK-CAZ-SC(3) 4,372.49 70.69 188.84 3,119.81 2,996.26 -1,979.57 -1,111.03 5,946,670.05 516,404.74 0.31 2,035.00 MWD+IFR-AK-CAZ-SC(3) 4,464.41 70.72 189.07 3,150.19 3,026.64 -2,065.27 -1,124.54 5,946,584.32 516,391.44 0.24 2,121.29 MWD+IFR-AK-CAZSC(3) 4,560.77 70.56 190.28 3,182.13 3,058.58 -2,154.89 -1,139.81 5,946,494.68 516,376.37 1.20 2,211.59 MWD+IFR-AK-CAZSC(3) 4,655.31 70.45 190.56 3,213.68 3,090.13 -2,242.54 -1,155.93 5,946,407.00 516,360.46 0.30 2,299.96 MWD+IFR-AK-CAZSC(3) 4,747.57 70.44 190.85 3,244.56 3,121.01 -2,327.96 -1,172.08 5,946,321.55 516,344.51 0.30 2,386.11 MWD+IFR-AK-CAZSC(3) 4,840.10 70.51 190.77 3,275.49 3,151.94 -2,413.62 -1,188.44 5,946,235.86 516,328.35 0.11 2,472.51 MWD+IFR-AK-CAZSC(3) 4,933.29 70.54 190.87 3,306.56 3,183.01 -2,499.92 -1,204.93 5,946,149.53 516,312.06 0.11 2,559.55 MWD+IFR-AK-CAZSC(3) 5,026.96 70.47 190.67 3,337.82 3,214.27 -2,586.66 -1,221.43 5,946,062.76 516,295.77 0.21 2,647.04 MWD+IFR-AK-CAZSC(3) 5,122.63 70.36 190.89 3,369.88 3,246.33 -2,675.21 -1,238.29 5,945,974.18 516,279.12 0.25 2,736.35 MWD+IFR-AK-CAZSC(3) 5,214.46 70.29 190.83 3,400.80 3,277.25 -2,760.13 -1,254.58 5,945,889.23 516,263.02 0.10 2,822.01 MWD+IFR-AK-CAZSC(3) 5,310.61 70.49 190.51 3,433.07 3,309.52 -2,849.14 -1,271.35 5,945,800.20 516,246.46 0.38 2,911.77 MWD+IFR-AK-CAZSC(3) 5,404.73 70.99 190.29 3,464.12 3,340.57 -2,936.53 -1,287.39 5,945,712.78 516,230.63 0.58 2,999.88 MWD+IFR-AK-CAZSC(3) 5,497.45 70.99 190.90 3,494.32 3,370.77 -3,022.70 -1,303.51 5,945,626.58 516,214.71 0.62 3,086.77 MWD+IFR-AK-CAZSC(3) 5,589.44 71.02 190.71 3,524.26 3,400.71 -3,108.13 -1,319.82 5,945,541.11 516,198.61 0.20 3,172.95 MVVD+IFR-AK-CAZ-SC(3) 5,683.39 70.93 190.90 3,554.89 3,431.34 -3,195.38 -1,336.47 5,945,453.84 516,182.16 0.21 3,260.94 MWD+IFR-AK-CAZSC(3) 5,775.45 70.99 190.24 3,584.92 3,461.37 -3,280.92 -1,352.43 5,945,368.26 516,166.40 0.68 3,347.21 MWD+IFR-AK-CAZ-SC(3) 5,870.15 71.05 188.82 3,615.72 3,492.17 -3,369.24 -1,367.25 5,945,279.92 516,151.78 1.42 3,436.18 MWD+IFR-AK-CAZ-SC(3) 5,962.92 70.93 188.61 3,645.94 3,522.39 -3,455.94 -1,380.54 5,945,193.21 516,138.69 0.25 3,523.45 MWD+IFR-AK-CAZ-SC(3) 6,055.51 70.65 188.68 3,676.41 3,552.86 -3,542.38 -1,393.69 5,945,106.74 516,125.75 0.31 3,610.46 MWD+IFR-AK-CAZSC(3) 6,148.00 70.69 189.06 3,707.02 3,583.47 -3,628.61 -1,407.14 5,945,020.49 516,112.50 0.39 3,697.28 MWD+IFR-AK-CAZ-SC(3) 6,240.11 70.57 189.23 3,737.57 3,614.02 -3,714.40 -1,420.95 5,944,934.67 516,098.89 0.22 3,783.68 MWD+IFR-AK-CAZSC(3) 6,333.12 70.50 189.18 3,768.56 3,645.01 -3,800.96 -1,434.98 5,944,848.08 516,085.06 0.09 3,870.86 MWD+IFR-AK-CAZ-SC(3) 6,427.37 70.56 189.21 3,799.98 3,676.43 -3,888.68 -1,449.18 5,944,760.34 516,071.07 0.07 3,959.20 MWD+IFR-AK-CAZSC(3) 6,520.58 70.56 190.04 3,831.00 3,707.45 -3,975.34 -1,463.88 5,944,673.66 516,056.58 0.84 4,046.51 MWD+IFR-AK-CAZ-SC(3) 6,612.63 70.57 189.93 3,861.63 3,738.08 -4,060.83 -1,478.93 5,944,588.14 516,041.72 0.11 4,132.67 MWD+IFR-AK-CAZ-SC(3) 6,706.10 70.45 190.10 3,892.82 3,769.27 -4,147.60 -1,494.25 5,944,501.34 516,026.60 0.21 4,220.12 MWD+IFR-AK-CAZ-SC(3) 6,799.85 70.57 188.99 3,924.10 3,800.55 -4,234.76 -1,508.91 5,944,414.17 516,012.15 1.12 4,307.92 MWD+IFR-AK-CAZ-SC(3) 6,892.41 70.50 188.51 3,954.94 3,831.39 -4,321.01 -1,522.18 5,944,327.89 515,999.08 0.49 4,394.75 MWD+IFR-AK-CAZ-SC(3) 6,985.30 70.44 188.50 3,985.99 3,862.44 -4,407.59 -1,535.13 5,944,241.29 515,986.34 0.07 4,481.89 MWD+IFR-AK-CAZ-SC(3) 7,077.37 70.82 188.77 4,016.53 3,892.98 -4,493.47 -1,548.17 5,944,155.39 515,973.50 0.50 4,568.33 M1ND+IFR-AK-CAZSC(3) 7,169.13 70.37 188.93 4,047.02 3,923.47 -4,578.98 -1,561.49 5,944,069.85 515,960.38 0.52 4,654.43 MWD+IFR-AK-CAZ-SC(3) 7,263.54 70.35 188.35 4,078.75 3,955.20 -4,666.89 -1,574.84 5,943,981.92 515,947.23 0.58 4,742.92 MWD+IFR-AK-CAZSC(3) 7,356.21 70.39 189.04 4,109.88 3,986.33 -4,753.17 -1,588.04 5,943,895.62 515,934.24 0.70 4,829.77 MWD+IFR-AK-CAZ-SC(3) 7,448.46 70.41 189.81 4,140.83 4,017.28 -4,838.90 -1,602.27 5,943,809.86 515,920.21 0.79 4,916.13 MWD+IFR-AK-CAZ-SC(3) 7,541.64 70.78 189.65 4,171.78 4,048.23 -4,925.52 -1,617.12 5,943,723.22 515,905.56 0.43 5,003.41 MWD+IFR-AK-CAZ-SC(3) 7,636.07 70.81 190.67 4,202.85 4,079.30 -5,013.30 -1,632.85 5,943,635.41 515,890.03 1.02 5,091.89 MWD+IFR-AK-CAZ-SC(3) 7,727.50 70.77 191.44 4,232.93 4,109.38 -5,098.04 -1,649.41 5,943,550.65 515,873.68 0.80 5,177.37 MWD+IFR-AK-CAZSC(3) 7,820.25 70.84 191.33 4,263.43 4,139.88 -5,183.91 -1,666.70 5,943,464.75 515,856.59 0.14 5,264.03 MWD+IFR-AK-CAZSC(3) 1/27/2015 10:29:49AM Page 4 COMPASS 5000.1 Build 65 Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well 2F-22 Project: Kuparuk River Unit TVD Reference: Rig:95.8+27.75 @ 123.55usft(Doyon 141) Site: Kuparuk 2F Pad MD Reference: Rig:95.8+27.75 @ 123.55usft(Doyon 141) Well: 2F-22 North Reference: True Wellbore: 2F-22 Survey Calculation Method: Minimum Curvature Design: 2F-22 Database: OAKEDMP2 Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/.S +E/-W Northing Easting DLS Section (usft) (0) (') (usft) (usft) (usft) (usft) (ft) (ft) (`/100') (ft) Survey Tool Name 7,912.41 7078 191.61 4,293.72 4,170.17 -5,269.21 -1,684.01 5,943,379.41 515,839.48 0.29 5,350.12 MWD+IFR-AK-CAZ-SC(3) 8,004.59 70.80 190.69 4,324.05 4,200.50 -5,354.61 -1,700.84 5,943,293.98 515,822.85 0.94 5,436.29 MWD+IFR-AK-CAZ-SC(3) 8,096.10 70.83 191.37 4,354.12 4,230.57 -5,439.44 -1,717.38 5,943,209.12 515,806.51 0.70 5,521.87 MWD+IFR-AK-CAZ-SC(3) 8,189.06 70.90 191.29 4,384.59 4,261.04 -5,525.55 -1,734.63 5,943,122.98 515,789.46 0.11 5,608.76 MWD+IFR-AK-CAZ-SC(3) 8,281.88 70.90 190.28 4,414.97 4,291.42 -5,611.71 -1,751.04 5,943,036.79 515,773.25 1.03 5,695.66 MWD+IFR-AK-CAZ-SC(3) 8,374.58 70.81 189.07 4,445.37 4,321.82 -5,698.04 -1,765.76 5,942,950.44 515,758.73 1.24 5,782.64 MWD+IFR-AK-CAZ-SC(3) 8,466.97 70.86 188.19 4,475.70 4,352.15 -5,784.32 -1,778.86 5,942,864.13 515,745.84 0.90 5,869.49 MWD+IFR-AK-CAZ-SC(3) 8,559.31 70.87 188.38 4,505.97 4,382.42 -5,870.65 -1,791.43 5,942,777.79 515,733.47 0.19 5,956.36 MWD+IFR-AK-CAZ-SC(3) 8,652.06 70.81 189.09 4,536.41 4,412.86 -5,957.24 -1,804.73 5,942,691.17 515,720.37 0.73 6,043.53 MWD+IFR-AK-CAZ-SC(3) 8,744.62 70.47 190.04 4,567.10 4,443.55 -6,043.35 -1,819.24 5,942,605.03 515,706.06 1.04 6,130.28 MWD+IFR-AK-CAZ-SC(3) 8,838.16 70.33 190.41 4,598.47 4,474.92 -6,130.07 -1,834.88 5,942,518.29 515,690.62 0.40 6,217.70 MWD+IFR-AK-CAZ-SC(3) 8,932.02 70.29 190.41 4,630.10 4,506.55 -6,216.99 -1,850.85 5,942,431.34 515,674.86 0.04 6,305.33 MWD+IFR-AK-CAZ-SC(3) 9,025.77 70.29 189.77 4,661.72 4,538.17 -6,303.88 -1,866.31 5,942,344.42 515,659.60 0.64 6,392.92 MWD+IFR-AK-CAZ-SC(3) 9,121.23 70.33 188.99 4,693.88 4,570.33 -6,392.56 -1,880.96 5,942,255.72 515,645.16 0.77 6,482.24 MWD+IFR-AK-CAZ-SC(3) 9,214.67 70.31 188.35 4,725.35 4,601.80 -6,479.53 -1,894.22 5,942,168.72 515,632.10 0.65 6,569.79 MWD+IFR-AK-CAZ-SC(3) 9,309.79 70.82 187.66 4,757.00 4,633.45 -6,568.36 -1,906.71 5,942,079.88 515,619.82 0.87 6,659.15 MWD+IFR-AK-CAZ-SC(3) 9,402.57 70.84 188.17 4,787.47 4,663.92 -6,655.16 -1,918.78 5,941,993.06 515,607.95 0.52 6,746.46 MWD+IFR-AK-CAZ-SC(3) 9,494.53 70.81 188.25 4,817.67 4,694.12 -6,741.13 -1,931.19 5,941,907.07 515,595.75 0.09 6,832.96 MWD+IFR-AK-CAZ-SC(3) 9,587.51 70.78 189.15 4,848.26 4,724.71 -6,827.92 -1,944.47 5,941,820.25 515,582.67 0.91 6,920.33 MWD+IFR-AK-CAZ-SC(3) 9,679.82 70.87 190.54 4,878.58 4,755.03 -6,913.82 -1,959.37 5,941,734.33 515,567.97 1.43 7,006.89 MVVD+IFR-AK-CAZ-SC(3) 9,772.05 70.81 190.61 4,908.85 4,785.30 -6,999.46 -1,975.36 5,941,648.66 515,552.18 0.10 7,093.25 MWD+IFR-AK-CAZ-SC(3) 9,865.73 70.83 194.51 4,939.64 4,816.09 -7,085.81 -1,994.60 5,941,562.28 515,533.14 3.93 7,180.48 MWD+IFR-AK-CAZ-SC(3) 9,958.53 70.84 190.02 4,970.12 4,846.57 -7,171.43 -2,013.22 5,941,476.61 515,514.73 4.57 7,266.97 MWD+IFR-AK-CAZ-SC(3) 10,052.49 70.86 189.12 5,000.94 4,877.39 -7,258.96 -2,027.97 5,941,389.06 515,500.18 0.91 7,355.15 MWD+IFR-AK-CAZ-SC(3) 10,144.74 70.87 188.76 5,031.18 4,907.63 -7,345.05 -2,041.52 5,941,302.95 515,486.84 0.37 7,441.83 MWD+IFR-AK-CAZ-SC(3) 10,238.14 70.87 188.36 5,061.79 4,938.24 -7,432.31 -2,054.65 5,941,215.67 515,473.91 0.40 7,529.66 MWD+IFR-AK-CAZ-SC(3) 10,330.92 70.87 188.66 5,092.19 4,968.64 -7,519.00 -2,067.62 5,941,128.95 515,461.14 0.31 7,616.91 MWD+IFR-AK-CAZ-SC(3) 10,422.53 70.92 188.65 5,122.18 4,998.63 -7,604.58 -2,080.65 5,941,043.35 515,448.31 0.06 7,703.05 MVVD+IFR-AK-CAZ-SC(3) 10,516.36 70.34 188.18 5,153.30 5,029.75 -7,692.15 -2,093.60 5,940,955.77 515,435.56 0.78 7,791.18 MWD+IFR-AK-CAZ-SC(3) 10,611.60 70.29 187.70 5,185.38 5,061.83 -7,780.96 -2,105.99 5,940,866.93 515,423.38 0.48 7,880.52 MWD+IFR-AK-CAZ-SC(3) 10,706.55 70.48 188.05 5,217.25 5,093.70 -7,869.56 -2,118.24 5,940,778.32 515,411.34 0.40 7,969.63 MWD+IFR-AK-CAZ-SC(3) 10,799.05 70.39 188.57 5,248.23 5,124.68 -7,955.80 -2,130.84 5,940,692.05 515,398.94 0.54 8,056.42 MWD+IFR-AK-CAZSC(3) 10,892.96 70.38 190.33 5,279.76 5,156.21 -8,043.06 -2,145.36 5,940,604.77 515,384.62 1.77 8,144.31 MWD+IFR-AK-CAZSC(3) 10,987.14 70.41 190.46 5,311.36 5,187.81 -8,130.32 -2,161.37 5,940,517.48 515,368.82 0.13 8,232.30 MWD+IFR-AK-CAZSC(3) 11,081.74 70.50 190.28 5,343.00 5,219.45 -8,218.01 -2,177.42 5,940,429.76 515,352.98 0.20 8,320.71 MWD+IFR-AK-CAZSC(3) 11,179.28 70.87 189.73 5,375.27 5,251.72 -8,308.66 -2,193.41 5,940,339.08 515,337.20 0.65 8,412.07 MWD+IFR-AK-CAZ-SC(3) 11,274.31 70.90 189.95 5,406.39 5,282.84 -8,397.13 -2,208.76 5,940,250.59 515,322.06 0.22 8,501.22 MWD+IFR-AK-CAZ-SC(3) 11,366.07 70.93 190.06 5,436.39 5,312.84 -8,482.53 -2,223.82 5,940,165.16 515,307.20 0.12 8,587.29 MWD+IFR-AK-CAZ-SC(3) 11,459.77 70.96 190.36 5,466.98 5,343.43 -8,569.69 -2,239.52 5,940,077.97 515,291.70 0.30 8,675.16 MWD+IFR-AK-CAZSC(3) 11,550.97 70.97 191.07 5,496.72 5,373.17 -8,654.40 -2,255.55 5,939,993.23 515,275.87 0.74 8,760.59 MWD+IFR-AK-CAZSC(3) 1/27/2015 10:29:49AM Page 5 COMPASS 5000.1 Build 65 Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well 2F-22 Project: Kuparuk River Unit TVD Reference: Rig:95.8+27.75 @ 123.55usft(Doyon 141) Site: Kuparuk 2F Pad MD Reference: Rig:95.8+27.75©123.55usft(Doyon 141) Well: 2F-22 North Reference: True Wellbore: 2F-22 Survey Calculation Method: Minimum Curvature Design: 2F-22 Database: OAKEDMP2 Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +E/-W Northing Easting DLS Section (usft) (') (') (usft) (usft) (usft) (usft) (ft) (ft) (°/100') (ft) Survey Tool Name 11,642.21 70.69 191.31 5,526.69 5,403.14 -8,738.94 -2,272.27 5,939,908.66 515,259.34 0.39 8,845.89 MWD+IFR-AK-CAZ-SC(3) 11,737.09 70.88 190.82 5,557.91 5,434.36 -8,826.87 -2,289.47 5,939,820.70 515,242.36 0.53 8,934.60 MWD+IFR-AK-CAZ-SC(3) 11,828.79 70.82 190.09 5,587.99 5,464.44 -8,912.06 -2,305.19 5,939,735.49 515,226.84 0.75 9,020.49 MWD+IFR-AK-CAZ-SC(3) 11,921.83 70.37 190.23 5,618.91 5,495.36 -8,998.44 -2,320.67 5,939,649.08 515,211.56 0.50 9,107.56 MWD+IFR-AK-CAZ-SC(3) 12,014.20 70.39 190.23 5,649.92 5,526.37 -9,084.06 -2,336.12 5,939,563.43 515,196.31 0.02 9,193.88 MWD+IFR-AK-CAZ-SC(3) 12,106.02 70.32 189.17 5,680.79 5,557.24 -9,169.30 -2,350.69 5,939,478.17 515,181.94 1.09 9,279.76 MWD+IFR-AK-CAZSC(3) 12,198.75 70.33 188.59 5,712.01 5,588.46 -9,255.57 -2,364.17 5,939,391.88 515,168.66 0.59 9,366.62 MWD+IFR-AK-CAZSC(3) 12,292.53 70.38 188.29 5,743.54 5,619.99 -9,342.93 -2,377.13 5,939,304.49 515,155.90 0.31 9,454.54 MWD+IFR-AK-CAZSC(3) 12,384.91 70.58 188.48 5,774.41 5,650.86 -9,429.07 -2,389.83 5,939,218.33 515,143.41 0.29 9,541.22 MVVD+IFR-AK-CAZ-SC(3) 12,477.20 70.72 188.79 5,804.99 5,681.44 -9,515.16 -2,402.90 5,939,132.22 515,130.54 0.35 9,627.88 MWD+IFR-AK-CAZ-SC(3) 12,569.97 70.78 188.89 5,835.57 5,712.02 -9,601.71 -2,416.36 5,939,045.65 515,117.28 0.12 9,715.01 MWD+IFR-AK-CAZ-SC(3) 12,662.67 70.81 189.09 5,866.07 5,742.52 -9,688.17 -2,430.04 5,938,959.17 515,103.80 0.21 9,802.07 MWD+IFR-AK-CAZ-SC(3) 12,756.47 70.84 189.80 5,896.88 5,773.33 -9,775.57 -2,444.58 5,938,871.75 515,089.47 0.72 9,890.11 MWD+IFR-AK-CAZSC(3) 12,850.93 70.77 189.68 5,927.93 5,804.38 -9,863.49 -2,459.67 5,938,783.80 515,074.58 0.14 9,978.70 MWD+IFR-AK-CAZ-SC(3) 12,943.65 70.82 189.88 5,958.43 5,834.88 -9,949.78 -2,474.55 5,938,697.48 515,059.91 0.21 10,065.65 MWD+IFR-AK-CAZ-SC(3) 13,034.79 70.72 190.36 5,988.45 5,864.90 -10,034.49 -2,489.67 5,938,612.74 515,044.99 0.51 10,151.04 MWD+IFR-AK-CAZ-SC(3) 13,128.21 72.65 190.90 6,017.81 5,894.26 -10,121.65 -2,506.03 5,938,525.55 515,028.83 2.14 10,238.94 MWD+IFR-AK-CAZ-SC(3) 13,219.99 75.91 191.19 6,042.67 5,919.12 -10,208.35 -2,522.95 5,938,438.82 515,012.11 3.56 10,326.40 MWD+IFR-AK-CAZ-SC(3) 13,313.52 78.72 191.41 6,063.21 5,939.66 -10,297.82 -2,540.83 5,938,349.32 514,994.44 3.01 10,416.68 MWD+IFR-AK-CAZSC(3) 13,406.12 81.01 191.62 6,079.50 5,955.95 -10,387.13 -2,559.03 5,938,259.97 514,976.46 2.48 10,506.83 MVVD+IFR-AK-CAZ-SC(3) 13,423.61 81.37 191.78 6,082.18 5,958.63 -10,404.06 -2,562.53 5,938,243.04 514,972.99 227 10,523.91 MWD+IFR-AK-CAZSC(4) 2F-22 01.TDInt 081214 LL 13,460.00 82.13 192.12 6,087.40 5,963.85 -10,439.29 -2,569.99 5,938,207.80 514,965.61 2.27 10,559.49 MWD+IFR-AK-CAZ-SC(4) 7.618"x 9-7/8" 13,506.29 83.09 192.55 6,093.35 5,969.80 -10,484.14 -2,579.80 5,938,162.93 514,955.91 2.27 10,604.78 MWD+IFR-AK-CAZ-SC(4) 13,601.11 83.04 193.28 6,104.80 5,981.25 -10,575.88 -2,600.84 5,938,071.15 514,935.09 0.77 10,697.50 MWD+IFR-AK-CAZ-SC(4) 13,696.16 84.75 191.04 6,114.91 5,991.36 -10,668.26 -2,620.74 5,937,978.73 514,915.40 2.95 10,790.80 MWD+IFR-AK-CAZ-SC(4) 13,790.67 86.29 190.12 6,122.29 5,998.74 -10,760.88 -2,638.04 5,937,886.09 514,898.32 1.90 10,884.19 MWD+IFR-AK-CAZ-SC(4) 13,885.65 87.49 189.87 6,127.45 6,003.90 -10,854.28 -2,654.50 5,937,792.66 514,882.08 1.29 10,978.33 MWD+IFR-AK-CAZ-SC(4) 13,951.50 89.24 188.38 6,129.32 6,005.77 -10,919.26 -2,664.93 5,937,727.65 514,871.80 3.50 11,043.77 MWD+IFR-AK-CAZ-SC(4) 2F-22 02.B 081214 LI. 13,979.98 90.00 187.73 6,129.51 6,005.96 -10,947.46 -2,668.92 5,937,699.45 514,867.88 3.50 11,072.14 MWD+IFR-AK-CAZSC(4) 14,075.08 91.52 187.90 6,128.25 6,004.70 -11,041.67 -2,681.85 5,937,605.22 514,855.17 1.61 11,166.89 MWD+IFR-AK-CAZSC(4) 14,170.41 91.82 189.61 6,125.47 6,001.92 -11,135.84 -2,696.36 5,937,511.02 514,840.88 1.82 11,261.70 MWD+IFR-AK-CAZSC(4) 14,264.77 92.27 192.67 6,122.11 5,998.56 -11,228.35 -2,714.57 5,937,418.48 514,822.88 3.28 11,355.04 MWD+IFR-AK-CAZSC(4) 14,313.74 91.97 196.56 6,120.29 5,996.74 -11,275.70 -2,726.92 5,937,371.11 514,810.65 7.96 11,402.96 MWD+IFR-AK-CAZ-SC(4) 14,358.81 92.73 197.76 6,118.44 5,994.89 -11,318.72 -2,740.20 5,937,328.06 514,797.46 3.15 11,446.62 MWD+IFR-AK-CAZSC(4) 14,403.70 92.58 197.30 6,116.37 5,992.82 -11,361.48 -2,753.71 5,937,285.27 514,784.06 1.08 11,490.03 MWD+IFR-AK-CAZ-SC(4) 14,453.00 92.92 197.45 6,114.00 5,990.45 -11,408.48 -2,768.42 5,937,238.25 514,769.46 0.75 11,537.73 MWD+IFR-AK-CAZSC(4) 14,505.71 92.86 196.41 6,111.34 5,987.79 -11,458.84 -2,783.75 5,937,187.85 514,754.25 1.97 11,588.83 MWD+IFR-AK-CAZSC(4) 2F-22 08.BaseC4 081214 LL 1/27/2015 10:29:49AM Page 6 COMPASS 5000.1 Build 65 Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well 2F-22 Project: Kuparuk River Unit TVD Reference: Rig:95.8+27.75 @ 123.55usft(Doyon 141) Site: Kuparuk 2F Pad MD Reference: Rig:95.8+27.75 @ 123.55usft(Doyon 141) Well: 2F-22 North Reference: True Wellbore: 2F-22 Survey Calculation Method: Minimum Curvature Design: 2F-22 Database: OAKEDMP2 Survey Map Map Vertical MD Inc Az( TVD TVDSS +N/-8 +E/-W Northing Easting DLS Section (usft) (°) (°) (usft) (usft) (usft) (usft) (ft) (ft) (°/100') (ft) Survey Tool Name 14,547.94 92.82 195.58 6,109.25 5,985.70 -11,499.38 -2,795.37 5,937,147.29 514,742.73 1.97 11,629.92 MWD+IFR-AK-CAZ-SC(4) 14,643.08 92.17 195.45 6,105.10 5,981.55 -11,590.97 -2,820.79 5,937,055.65 514,717.52 0.70 11,722.71 MWD+IFR-AK-CAZ-SC(4) 14,737.96 90.04 195.44 6,103.27 5,979.72 -11,682.40 -2,846.05 5,936,964.17 514,692.47 2.24 11,815.34 MWD+IFR-AK-CAZ-SC(4) 14,832.40 91.22 195.24 6,102.24 5,978.69 -11,773.47 -2,871.04 5,936,873.05 514,667.70 1.27 11,907.59 MWD+IFR-AK-CAZ-SC(4) 14,926.29 90.07 196.14 6,101.18 5,977.63 -11,863.85 -2,896.43 5,936,782.62 514,642.53 1.56 11,999.18 MWD+IFR-AK-CAZ-SC(4) 15,020.80 88.39 196.04 6,102.45 5,978.90 -11,954.65 -2,922.62 5,936,691.77 514,616.55 1.78 12,091.22 MWD+IFR-AK-CAZSC(4) 15,024.51 88.33 196.03 6,102.56 5,979.01 -11,958.22 -2,923.64 5,936,688.20 514,615.53 1.62 12,094.84 MWD+IFR-AK-CAZ-SC(4) 2F-22 04.Fault2 081214 LL 15,115.54 86.88 195.78 6,106.36 5,982.81 -12,045.68 -2,948.56 5,936,600.69 514,590.82 1.62 12,183.49 MWD+IFR-AK-CAZ-SC(4) 15,210.61 88.46 194.71 6,110.22 5,986.67 -12,137.32 -2,973.54 5,936,509.00 514,566.06 2.01 12,276.31 MWD+IFR-AK-CAZ-SC(4) 15,304.40 90.81 192.36 6,110.82 5,987.27 -12,228.50 -2,995.49 5,936,417.79 514,544.33 3.54 12,368.51 MWD+IFR-AK-CAZ-SC(4) 15,399.33 91.43 191.00 6,108.97 5,985.42 -12,321.44 -3,014.70 5,936,324.81 514,525.33 1.57 12,462.33 MWD+IFR-AK-CAZ-SC(4) 15,493.98 89.95 191.86 6,107.83 5,984.28 -12,414.20 -3,033.45 5,936,232.01 514,506.79 1.81 12,555.95 MWD+IFR-AK-CAZ-SC(4) 15,588.55 90.24 190.99 6,107.67 5,984.12 -12,506.90 -3,052.19 5,936,139.28 514,488.28 0.97 12,649.50 MWD+IFR-AK-CAZ-SC(4) 15,590.04 90.24 190.97 6,107.66 5,984.11 -12,508.36 -3,052.47 5,936,137.81 514,488.00 1.48 12,650.97 MWD+IFR-AK-CAZ-SC(4) 2F-22 05.C4Crest 081214 LL 15,683.26 90.04 189.60 6,107.44 5,983.89 -12,600.08 -3,069.11 5,936,046.07 514,471.57 1.48 12,743.44 MWD+IFR-AK-CAZ-SC(4) 15,777.62 90.12 189.71 6,107.31 5,983.76 -12,693.10 -3,084.94 5,935,953.02 514,455.96 0.14 12,837.16 MWD+IFR-AK-CAZ-SC(4) 15,872.15 88.97 188.75 6,108.06 5,984.51 -12,786.40 -3,100.10 5,935,859.69 514,441.02 1.58 12,931.13 MWD+IFR-AK-CAZ-SC(4) 15,966.96 88.41 187.25 6,110.22 5,986.67 -12,880.26 -3,113.29 5,935,765.81 514,428.05 1.69 13,025.55 MWD+IFR-AK-CAZ-SC(4) 16,062.18 88.91 186.82 6,112.45 5,988.90 -12,974.74 -3,124.95 5,935,671.32 514,416.61 0.69 13,120.51 MWD+IFR-AK-CAZSC(4) 16,156.77 89.04 185.89 6,114.14 5,990.59 -13,068.73 -3,135.42 5,935,577.31 514,406.36 0.99 13,214.92 MWD+IFR-AK-CAZ-SC(4) 16,251.98 89.32 185.12 6,115.51 5,991.96 -13,163.49 -3,144.55 5,935,482.54 514,397.45 0.86 13,310.03 MWD+IFR-AK-CAZSC(4) 16,347.17 90.03 190.57 6,116.05 5,992.50 -13,257.75 -3,157.54 5,935,388.26 514,384.68 5.77 13,404.84 MWD+IFR-AK-CAZSC(4) 16,441.08 87.51 194.45 6,118.06 5,994.51 -13,349.39 -3,177.87 5,935,296.58 514,364.57 4.93 13,497.41 MWD+IFR-AK-CAZ-SC(4) 16,535.99 87.31 195.55 6,122.35 5,998.80 -13,440.97 -3,202.41 5,935,204.95 514,340.24 1.18 13,590.15 MWD+IFR-AK-CAZ-SC(4) 16,630.99 89.39 194.53 6,125.09 6,001.54 -13,532.67 -3,227.05 5,935,113.20 514,315.82 2.44 13,683.02 MWD+IFR-AK-CAZ-SC(4) 16,725.02 90.56 190.91 6,125.13 6,001.58 -13,624.38 -3,247.75 5,935,021.46 514,295.34 4.05 13,775.68 MWD+IFR-AK-CAZ-SC(4) 16,820.22 90.47 188.18 6,124.27 6,000.72 -13,718.25 -3,263.53 5,934,927.56 514,279.77 2.87 13,870.25 MWD+IFR-AK-CAZ-SC(4) 16,914.74 88.96 189.29 6,124.74 6,001.19 -13,811.66 -3,277.89 5,934,834.12 514,265.64 1.98 13,964.29 MWD+IFR-AK-CAZ-SC(4) 17,010.52 88.67 188.09 6,126.72 6,003.17 -13,906.32 -3,292.35 5,934,739.44 514,251.39 1.29 14,059.57 MWD+IFR-AK-CAZSC(4) 17,073.37 88.64 188.42 6,128.20 6,004.65 -13,968.50 -3,301.37 5,934,677.24 514,242.52 0.53 14,122.14 MWD+IFR-AK-CAZSC(4) 2F-22 06.BassC4,2 08121411 17,104.09 88.63 188.58 6,128.93 6,005.38 -13,998.88 -3,305.91 5,934,646.86 514,238.05 0.53 14,152.71 MWD+IFR-AK-CAZ-SC(4) 17,199.24 88.45 187.82 6,131.35 6,007.80 -14,093.02 -3,319.48 5,934,552.69 514,224.70 0.82 14,247.44 MWD+IFR-AK-CAZ-SC(4) 17,293.87 89.50 185.51 6,133.05 6,009.50 -14,186.99 -3,330.46 5,934,458.71 514,213.94 2.68 14,341.85 MWD+IFR-AK-CAZ-SC(4) 17,388.79 89.56 186.90 6,133.82 6,010.27 -14,281.35 -3,340.72 5,934,364.34 514,203.90 1.47 14,436.62 MWD+IFR-AK-CAZ-SC(4) 17,483.99 89.56 185.41 6,134.55 6,011.00 -14,376.00 -3,350.93 5,934,269.68 514,193.92 1.57 14,531.67 MWD+IFR-AK-CAZSC(4) 17,578.89 89.90 186.16 6,135.00 6,011.45 -14,470.41 -3,360.49 5,934,175.25 514,184.57 0.87 14,626.45 MWD+IFR-AK-CAZSC(4) 17,673.22 89.76 186.31 6,135.28 6,011.73 -14,564.18 -3,370.74 5,934,081.46 514,174.55 0.22 14,720.63 MWD+IFR-AK-CAZSC(4) 17,771.27 89.38 184.50 6,136.02 6,012.47 -14,661.79 -3,379.97 5,933,983.85 514,165.54 1.89 14,818.59 MWD+IFR-AK-CAZ-SC(4) 1/27/2015 10:29:49AM Page 7 COMPASS 5000.1 Build 65 Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well 2F-22 Project: Kuparuk River Unit TVD Reference: Rig:95.8+27.75 @ 123.55usft(Doyon 141) Site: Kuparuk 2F Pad MD Reference: Rig:95.8+27.75 @ 123.55usft(Doyon 141) Well: 2F-22 North Reference: True Wellbore: 2F-22 Survey Calculation Method: Minimum Curvature Design: 2F-22 Database: OAKEDMP2 Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +E/-W Northing Easting DLS Section (usft) (°) (°) (usft) (usft) (usft) (usft) (ft) (ft) (°/100') (ft) Survey Tool Name 17,863.34 90.15 183.17 6,136.40 6,012.85 -14,753.65 -3,386.13 5,933,891.98 514,159.60 1.67 14,910.65 MWD+IFR-AK-CAZ-SC(4) 17,957.75 89.55 181.92 6,136.64 6,013.09 -14,847.96 -3,390.32 5,933,797.67 514,155.62 1.47 15,005.05 MWD+IFR-AK-CAZ-SC(4) 18.050.99 90.15 183.79 6,136.89 6,013.34 -14,941.08 -3,394.97 5,933,704.55 514,151.20 2.11 15,098.29 MWD+IFR-AK-CAZ-SC(4) 18,144.24 89.56 185.40 6,137.12 6,013.57 -15,034.03 -3,402.44 5,933,611.59 514,143.94 1.84 15,191.50 MWD+IFR-AK-CAZ-SC(4) 18.239.33 89.49 191.35 6,137.91 6,014.36 -15,128.06 -3,416.28 5,933,517.54 514,130.32 6.26 15,286.12 MWD+IFR-AK-CAZ-SC(4) 18.334.70 90.00 189.85 6,138.34 6,014.79 -15,221.80 -3,433.82 5,933,423.77 514,113.00 1.66 15,380.65 MWD+IFR-AK-CAZ-SC(4) 18,426.43 89.87 192.53 6,138.44 6,014.89 -15,311.78 -3,451.62 5,933,333.76 514,095.41 2.93 15,471.44 MWD+IFR-AK-CAZ-SC(4) 18,524.63 88.86 193.01 6,139.53 6,015.98 -15,407.54 -3,473.33 5,933,237.95 514,073.93 1.14 15,568.21 MWD+IFR-AK-CAZ-SC(4) 18,619.35 89.09 195.24 6,141.22 6,017.67 -15,499.38 -3,496.44 5,933,146.07 514,051.04 2.37 15,661.12 MWD+IFR-AK-CAZ-SC(4) 18,713.28 88.24 193.87 6,143.41 6,019.86 -15,590.26 -3,520.03 5,933,055.14 514,027.65 1.72 15,753.12 MWD+IFR-AK-CAZ-SC(4) 18,737.56 88.27 193.28 6,144.15 6,020.60 -15,613.86 -3,525.73 5,933,031.54 514,022.01 2.45 15,776.98 MWD+IFR-AK-CAZ-SC(4) 2F-22 07.C4 081214 LL 18,809.39 88.36 191.52 6,146.26 6,022.71 -15,683.98 -3,541.14 5,932,961.39 514,006.76 2.45 15,847.81 MWD+IFR-AK-CAZ-SC(4) 18,904.31 89.08 189.06 6,148.38 6,024.83 -15,777.34 -3,558.09 5,932,868.00 513,990.03 2.70 15,941.93 MWD+IFR-AK-CAZ-SC(4) 18,999.47 89.39 187.49 6,149.65 6,026.10 -15,871.50 -3,571.79 5,932,773.82 513,976.56 1.68 16,036.68 MWD+IFR-AK-CAZ-SC(4) 19,093.74 90.43 187.66 6,149.80 6,026.25 -15,964.94 -3,584.22 5,932,680.35 513,964.35 1.12 16,130.65 MWD+IFR-AK-CAZ-SC(4) 19,188.62 89.17 187.25 6,150.13 6,026.58 -16,059.02 -3,596.53 5,932,586.26 513,952.26 1.40 16,225.24 MWD+IFR-AK-CAZ-SC(4) 19,282.88 88.94 185.62 6,151.69 6,028.14 -16,152.67 -3,607.09 5,932,492.59 513,941.92 1.75 16,319.31 MWD+IFR-AK-CAZ-SC(4) 19.375.79 88.63 182.38 6,153.66 6,030.11 -16,245.32 -3,613.57 5,932,399.94 513,935.65 3.50 16,412.17 MWD+IFR-AK-CAZ-SC(4) 19.472.47 88.31 180.17 6,156.24 6,032.69 -16,341.93 -3,615.72 5,932,303.33 513,933.73 2.31 16.508.77 MWD+IFR-AK-CAZ-SC(4) 19,566.18 89.15 181.18 6,158.32 6,034.77 -16,435.61 -3,616.82 5,932,209.65 513,932.84 1.40 16,602.38 MWD+IFR-AK-CAZ-SC(4) 19,657.13 89.28 179.75 6,159.56 6,036.01 -16,526.55 -3,617.56 5,932,118.73 513,932.31 1.58 16,693.23 MWD+IFR-AK-CAZ-SC(4) 19,753.38 89.08 177.87 6,160.94 6,037.39 -16,622.76 -3,615.56 5,932,022.52 513,934.54 1.96 16,789.21 MWD+IFR-AK-CAZ-SC(4) 19,848.83 89.18 177.58 6,162.39 6,038.84 -16,718.13 -3,611.77 5,931,927.18 513,938.55 0.32 16,884.24 MWD+IFR-AK-CAZ-SC(4) 19,943.41 88.39 177.69 6,164.40 6,040.85 -16,812.60 -3,607.87 5,931,832.72 513,942.67 0.84 16,978.38 MWD+IFR-AK-CAZ-SC(4) 20.038.15 87.91 172.41 6,167.46 6,043.91 -16,906.91 -3,599.70 5,931,738.45 513,951.05 5.59 17,072.13 MWD+IFR-AK-CAZ-SC(4) 20,131.96 86.80 165.30 6,171.79 6,048.24 -16,998.79 -3,581.60 5,931,646.61 513,969.36 7.66 17,162.94 MWD+IFR-AK-CAZ-SC(4) 20,225.83 87.61 165.23 6,176.37 6,052.82 -17,089.47 -3,557.76 5,931,556.01 513,993.42 0.87 17,252.24 MWD+IFR-AK-CAZ-SC(4) 20,319.86 86.98 160.68 6,180.81 6,057.26 -17,179.24 -3,530.23 5,931,466.30 514,021.15 4.88 17,340.46 MWD+IFR-AK-CAZ-SC(4) 20,358.95 86.76 160.12 6,182.94 6,059.39 -17,216.01 -3,517.14 5,931,429.57 514,034.33 1.53 17,376.49 MWD+IFR-AK-CAZ-SC(4) 2F-22 08.NearBaseC4 081214 LL 20,416.07 86.45 159.30 6,186.32 6,062.77 -17,269.49 -3,497.37 5,931,376.14 514,054.22 1.53 17,428.86 MVVD+IFR-AK-CAZ-SC(4) 20.511.15 88.23 160.78 6,190.73 6,067.18 -17,358.76 -3,464.95 5,931,286.96 514,086.85 2.43 17,516.31 MWD+IFR-AK-CAZ-SC(4) 20,605.13 88.67 160.16 6,193.28 6,069.73 -17,447.30 -3,433.54 5,931,198.50 514,118.45 0.81 17,603.09 MWD+IFR-AK-CAZ-SC(4) 20.658.68 88.80 160.05 6,194.46 6,070.91 -17,497.64 -3,415.32 5,931,148.20 514,136.79 0.32 17,652.40 MWD+IFR-AK-CAZ-SC(4) 20,699.36 89.11 158.22 6,195.20 6,071.65 -17,535.64 -3,400.84 5,931,110.24 514,151.36 4.56 17,689.60 MWD+IFR-AK-CAZ-SC(4) 20,741.60 91.36 158.10 6,195.03 6,071.48 -17,574.85 -3,385.13 5,931,071.07 514,167.16 5.33 17,727.93 MWD+IFR-AK-CAZ-SC(4) 20,793.28 92.83 160.64 6,193.14 6,069.59 -17,623.18 -3,366.93 5,931,022.79 514,185.47 5.68 17,775.24 MWD+IFR-AK-CAZ-SC(4) 20,835.64 92.23 163.02 6,191.27 6,067.72 -17,663.38 -3,353.74 5,930,982.62 514,198.76 5.79 17,814.70 MWD+IFR-AK-CAZ-SC(4) 20,885.63 91.11 165.62 6,189.81 6,066.26 -17,711.49 -3,340.23 5,930,934.55 514,212.37 5.66 17,862.03 MWD+IFR-AK-CAZ-SC(4) 1/27/2015 10:29:49AM Page 8 COMPASS 5000.1 Build 65 A Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well 2F-22 Project: Kuparuk River Unit TVD Reference: Rig:95,8+27.75 @ 123.55usft(Doyon 141) Site: Kuparuk 2F Pad MD Reference: Rig:95.8+27.75 @ 123.55usft(Doyon 141) Well: 2F-22 North Reference: True Wellbore: 2F-22 Survey Calculation Method: Minimum Curvature Design: 2F-22 Database: OAKEDMP2 Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +El-W Northing Easting DLS Section (usft) (°) (°) (usft) (usft) (usft) (usft) (ft) (ft) (11001 (ft) Survey Tool Name 20,981.77 90.45 172.33 6,188.50 6,064.95 -17,805.79 -3,321.86 5,930,840.30 514,230.96 7.01 17,955.24 MWD+IFR-AK-CAZ-SC(4) 21,076.66 92.69 179.95 6,185.90 6,062.35 -17,900.35 -3,315.48 5,930,745.76 514,237.56 8.37 18,049.34 MWD+IFR-AK-CAZ-SC(4) 21,137.29 90.45 183.42 6,184.23 6,060.68 -17,960.92 -3,317.26 5,930,685.20 514,235.92 6.81 18,109.92 MWD+IFR-AK-CAZ-SC(4) 2F-22 09.C4_2 081214 LL 21,171.79 89.18 185.40 6,184.34 6,060.79 -17,995.32 -3,319.91 5,930,650.80 514,233.35 6.81 18.144.41 MWD+IFR-AK-CAZ-SC(4) 21,266.65 88.63 188.44 6,186.16 6,062.61 -18,089.46 -3,331.34 5,930,556.64 514,222.14 3.26 18,239.01 MWD+IFR-AK-CAZ-SC(4) 21,361.16 88.94 188.28 6,188.16 6,064.61 -18,182.94 -3,345.08 5,930,463.14 514,208.62 0.37 18,333.09 MWD+IFR-AK-CAZ-SC(4) 21,456.40 88.55 187.62 6,190.25 6,066.70 -18,277.24 -3,358.25 5,930,368.81 514,195.67 0.80 18,427.95 MWD+IFR-AK-CAZ-SC(4) 21,551.15 86.16 188.24 6,194.62 6,071.07 -18,370.98 -3,371.30 5,930,275.06 514,182.84 2.61 18.522.24 MWD+IFR-AK-CAZ-SC(4) 21,645.03 86.71 187.66 6,200.46 6,076.91 -18,463.78 -3,384.26 5,930,182.24 514,170.09 0.85 18.615.59 MWD+IFR-AK-CAZ-SC(4) 21,739.07 86.22 187.76 6,206.26 6,082.71 -18,556.79 -3,396.86 5,930,089.21 514,157.72 0.53 18,709.14 MWD+IFR-AK-CAZ-SC(4) 21,833.88 91.88 188.09 6,207.83 6,084.28 -18,650.64 -3,409.92 5,929,995.33 514,144.87 5.98 18.803.54 MWD+IFR-AK-CAZ-SC(4) 21,928.00 89.97 182.56 6,206.31 6,082.76 -18,744.30 -3,418.65 5,929,901.66 514,136.36 6.22 18,897.53 MWD+IFR-AK-CAZ-SC(4) 21,990.00 89.97 182.56 6,206.34 6,082.79 -18,806.24 -3,421.42 5,929,839.72 514,133.74 0.00 18,959.53 PROJECTED to TD 4 1/2"x 6-3/4" 22,009.00 89.97 182.56 6,206.35 6,082.80 -18,825.22 -3,422.27 5,929,820.74 514,132.93 0.00 18,978.53 PROJECTED to TD Projection to TD-2F-22 10.TD 081214 LL 1/27/2015 10:29:49AM Page 9 COMPASS 5000.1 Build 65 Image Project Well History File Cover Page XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspectiontiof the file. c 1 `4 5- 1 0 Well History File Identifier Organizing(done) ❑ Two-sided ❑ Rescan Needed RESCAN: OVERSIZED: NOTES: :;/2or Items: ❑ Maps: yscale Items: s: ❑ Poor Quality Originals: ❑ Other: ❑ Other: BY: C=2) Date: gi/06-- /s/ wiP Project Proofing BY: C Maria Date: VII /V /s/ MI) Scanning Preparation S x 30 = /50 + r).. I = TOTAL PAGES 1 7/ (Count does not include cover sheet) im BY: Date: S I /s/ Production Scanning Stage 1 Page Count from Scanned File: ) 7,„1-..(Count does include cover sheet) Page Count Matches Number in Scanni g Preparation: ✓ YES NO BY: Maria Date: 5 11//5 /s/ 0V Stage 1 If NO in stage 1, page(s) discrepancies were found: YES NO BY: Maria Date: /s/ Stage 2 Additional Well Reports: 1115 NOTOTAL PAGES: j Digital version appended by: Meredith • Michal Date:5/i6(15-- Is! Final Page Count: Stage 1 + Stage 2: TOTAL PAGES: coca Scanning is complete at this point unless rescanning is required. ReScanned BY: Maria Date: /s/ Comments about this file: Quality Checked 7/8/2014 Well History File Cover Page_20140708.doc o ,n o I. o �' W ca o • d �. C)) N l ^o •"', co co • NI N N • N. 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N O o W ° V 0 Z U Q 1`6 N GI J 0 CO CG r cog 4 Om .a I O .ti pE a N O 0 c w et m I o J E E Q N O I N (� G U.N H in zC > N CO ' CO %_ W TeT Ir n y 41 10 a 0 0 Q 0 c Y g r m < C n Z EI p E U c Z a) • c 0 N O 0 CD 0 > II CODiI T 1 rNOO to w N G CO CEJ E 0E a CO o d I O I1 E a 2 0 0 C) Guhl, Meredith D (DOA) From: Hunter, Lindsey L [Lindsey.Hunter@conocophillips.com] Sent: Friday, April 17, 2015 2:16 PM To: Guhl, Meredith D (DOA) Cc: Bettis, Patricia K (DOA) Subject: RE: KRU 2F-22, PTD 214-150, Geologic Markers and Logs Obtained Meredith, Please see the complete list of 2F-22 formation tops below. Thank you, Lindsey 2F-22 Pick MD TVD TVDSS base permafrost 1452 1416 1292 Top Ugnu (Ugnu C) 1814 1744 1620 Top W Sak(W Sak D) 2688 2415 2291 base W Sak 3719 2909 2785 top HRZ(K-2 mkr) 12129 5689 5565 upper_kalubik (base HRZ) 12784 5907 5783 lower_kalubik (K-1 mkr) 13041 5991 5867 top Kuparuk C4 13383 6076 5952 top Kuparuk B2 13453 6087 5963 base Kuparuk C4/top Kuparuk B2 14540 6110 5986 top Kuparuk B2 15204 6110 5986 base Kuparuk C4/top Kuparuk B2 15346 6111 5987 TD (Kuparuk C4) 22009 6207 6083 MD where entered Top of Fm at 2F-22 TD Fm at TD Kuparuk C4 15346 From: Guhl, Meredith D (DOA) [mailto:meredith.guhl@alaska.gov] Sent: Friday,April 17, 2015 1:30 PM To: Hunter, Lindsey L Cc: Bettis, Patricia K(DOA); Alvord,Chip Subject: (EXTERNAL]RE: KRU 2F-22, PTD 214-150,Geologic Markers and Logs Obtained Lindsey, I'd appreciate receiving the complete list of formations and markers via email, by Friday,April 24, 2015, so I may complete the compliance review of the well. Thank you, Meredith 1 From: Guhl, Meredith D (DOA) Sent: Wednesday, April 15, 2015 4:18 PM To: 'Hunter, Lindsey L' Cc: Bettis, Patricia K (DOA) Subject: RE: KRU 2F-22, PTD 214-150, Geologic Markers and Logs Obtained Lindsey, My response to 2F-22 is identical to the one I just sent you for 2E-02. Given the PTD application list of formations, a complete list of formations and geologic markers encountered is required. I will update the 10-407 form to reflect the logs actually run. Please note that only GR/Res was listed on the 10-407 form and as such, the form is incomplete. I will include your email in the well history file as back up for updating the 10-407 form.Thank you for the explanation. Thank you, Meredith From: Hunter, Lindsey L [mailto:Lindsey.Hunter@conocophillips.com] Sent: Wednesday, April 15, 2015 4:13 PM To: Guhl, Meredith D (DOA) Subject: RE: KRU 2F-22, PTD 214-150, Geologic Markers and Logs Obtained Meredith, The story for 2F-22 is similar to that I just sent you for 2E-02. The file of the 10-407 we have indicates we sent the formation data when we submitted the 10-407. As for the production BHA, we originally planned to run the stethoscope log for formation pressures, however high pressures seen in the intermediate landing zone deterred us from running it due to risk of differential sticking. We did run periscope, Gamma/Res, Density/Neutron, and microscope logs in the production section, as well as sonic(though only recorded data for top of cement evaluation.) Thanks, Lindsey From:Guhl, Meredith D (DOA) [mailto:meredith.guhl@alaska.gov] Sent: Monday, March 23, 2015 8:56 AM To: Hunter, Lindsey L Cc: Bettis, Patricia K(DOA) Subject: [EXTERNAL]KRU 2F-22, PTD 214-150, Geologic Markers and Logs Obtained Lindsey, Please provide the complete list of formation tops and geologic markers for KRU 2F-22, PTD 214-150, completed January 18, 2015. You may provide this list via email, and I will append it to the 10-407 form. Also, the PTD application for this well stated that stethoscope, periscope, neutron, density and sonic would be run on the production section. However, in box 21 you only listed GR/Res for logs obtained. Were the additional logs run? Please provide an explanation for the discrepancy between the permit to drill application and the 10-407 form. 2 Please provide the geologic markers and an explanation about logs run by April 18, 2015. If you have any questions, please contact me. Thank you, Meredith Meredith Guhl Petroleum Geology Assistant Alaska Oil and Gas Conservation Commission 333 W. 7th Ave,Suite 100,Anchorage, AK 99501 meredith.guhl@alaska.gov Direct: (907) 793-1235 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 Meredith Guhl at 907-793-1235 or meredith.guhl@alaska.gov. 3 Guhl, Meredith D (DOA) From: Guhl, Meredith D (DOA) Sent: Monday, March 23, 2015 8:56 AM To: 'Hunter, Lindsey L' Cc: Bettis, Patricia K(DOA) Subject: KRU 2F-22, PTD 214-150, Geologic Markers and Logs Obtained Lindsey, Please provide the complete list of formation tops and geologic markers for KRU 2F-22, PTD 214-150, completed January 18, 2015. You may provide this list via email, and I will append it to the 10-407 form. Also,the PTD application for this well stated that stethoscope, periscope, neutron, density and sonic would be run on the production section. However, in box 21 you only listed GR/Res for logs obtained.Were the additional logs run? Please provide an explanation for the discrepancy between the permit to drill application and the 10-407 form. Please provide the geologic markers and an explanation about logs run by April 18, 2015. IfY ou have any questions, please contact me. Thank you, Meredith Meredith Guhl Petroleum Geology Assistant Alaska Oil and Gas Conservation Commission 333 W. 7th Ave,Suite 100,Anchorage, AK 99501 meredith.quhl@alaska.gov Direct: (907) 793-1235 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 Meredith Guhl at 907-793-1235 or meredith.guhl@alaska.gov. 1 21 4150 25 547 conoc'PhiII r s RECEIVED MAR 1 9 2015 DATA LOGGED TRANSMITTAL AOGCC M ODER ^e.A tP ENT-I A L r+A T A T /►A G. FROM: Sandra D. Lemke, ATO3-0340 TO: Makana Bender ConocoPhillips Alaska, Inc. AOGCC P.O. Box 100360 333 W. 7th Ave, Suite 100 Anchorage AK 99510-0360 Anchorage, Alaska 99501 RE: 2F-22 DATE: 03/18/2015 Transmitted: Kuparuk River Unit, Alaska 2F-22 1 CD and hardcopy report Halliburton-Surface data logging and End of Well report- mud logging data for 2F-22; 12/28/2014; general information, daily summary, days vs. depth, after action review, mud record, bit record, morning reports, survey reports; 'color log presentations, one set each for wellbore 1 color print each: Formation Evaluation 2" MD Gas ratio 2" MD Drilling Engineering 2" MD Please promptly sign, scan and return electronically to Sandra.D.LemkeCOP.com CC: 2F-22 transmittal folder, production well files, eSearch Receipt: tM47)al fol k' ",. h ► - GIS-Technical Data Management I ConocoPhillips !Anchorage, Alaska I Ph: 907.265.6947 STATE OF ALASKA A .KA OIL AND GAS CONSERVATION CON, ,SION REPORT OF SUNDRY WELL OPERATIONS 1 Operations Performed Abandon r Repair w ell r Rug Perforations r Perforate rOther WINJ to Prod Atter Casing r Pull Tubing r Stimulate-Frac r Waiver r Time Extension r Change Approved Program rOperat.Shutdown r Stimulate-Other r Re-enter Suspended Well r 2.Operator Name: 4.Well Class Before Work. 5.Permit to Drill Number: ConocoPhillips Alaska, Inc. - Development r Exploratory r 214-150-0 3.Address. 6.API Number: Stratigraphic r Service r-• P. O. Box 100360,Anchorage,Alaska 99510 50-029-23530-00 7 Property Designation(Lease Number): 8 Well Name and Number: ADL 25657,25666,25668,302364 KRU 2F-22 9 Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s) Kuparuk River Field/Kuparuk River Oil Pool 11.Present Well Condition Summary: Total Depth measured 22009 feet Plugs(measured) None true vertical 6206 feet Junk(measured) None Effective Depth measured 13317 feet Packer(measured) 554, 13206,13212, 13237, 13256 true vertical 6064 feet (true vertical) 554,6039,6041,6047,6051 Casing Length Size MD TVD Burst Collapse CONDUCTOR 129 20 157 157 0 0 SURFACE 3877 14.78 3904 2969 0 0 INTERMEDIATE 13434 10.625 13460 6088 0 0 LINER-5 1/2 X 4 8713 7.625 21990 6206 0 0 0 0 0 0 0 0 Perforation depth: Measured depth: Slotted Liner 14617-21980 RECEIVED True Vertical Depth: 6107-6206 MAR I 0 2015 Tubing(size,grade,MD,and ND) 3.51, L-80, 13304 MD,6061 TVD AOGCC Packers&SSSV(type,MD,and ND) NIPPLE-CAMCO DS NIPPLE @ 554 MD and 554 TVD PBR-BAKER PBR SEAL ASSEMBLY 80-40 @ 13206 MD and 6039 TVD PBR-POLISHED BORE RECEPTACLE @ 13212 MD and 6041 TVD PACKER-BAKER PREMIER PRODUCTION PACKER TC-II @ 13237 MD and 6047 TVD NIPPLE-CAMCO D NIPPLE @ 13256 MD and 6051 TVD 12.Stimulation or cement squeeze summary: Intervals treated(measured): Treatment descriptions including volumes used and final pressure. 13. Representative Daily Average Production or Injection Data 011-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 0 0 0 0 0 Subsequent to operation 2817 1559 76 1153 85 14.Attachments 15.Well Class after work: Copies of Logs and Surveys run Exploratory r Development r Service r Stratigraphic r 16.Well Status after work. Oil r Gas r WDSPL r Daily Report of Well Operations X GSTOR r WINJ r WAG r GINJ r SUSP r SPLUG r 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C 0.Exempt: N/A Contact Bob Christensen/Darrell Humphrey Email n1139aconocophillips.com Printed Name Darrell R. Humphrey Title NSK Production Engineering Specialist Signature � Phone:659-7535 Date ? Form 10-404 Revised 10/2012 RBDMS\)t4 MAR 1 2 2015 Submit Original Only T IPG 33/17"//7— /° /7%✓'_ • 2F-22 DESCRIPTION OF WORK COMPLETED SUMMARY Date Event Summary 02/16/15 Pre Produced injector brought online- production for greater than 30 days 02/12/15 MEASURED BHP @ 13241' SLM. BHP 3302 PSI. COMPLETE. . ` fi KUP SVC 2F-22 ConocoPhillips ; Well Attributes Max Angle&MD TD Alaska,Inc. Wellbore API/UWI Field Name Wellbore Status ncl C) MD(ftKB) Act Btm(ftKB) Cmcxolldnips 500292353000 KUPARUK RIVER UNIT SVC 92 92 14,452.99 22,009.0 ... Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date HORIZONTAL-2F-22,2/18/2015940'03 AM SSSV:NIPPLE Last WO 27.75 1/19/2015 Vertical schematic(actual) Annotation Depth(ftKB) End Date Annotation Last Mod By End Date ,____ _....... Last Tag: Rev Reason.ADD NOTE hipshkf 2/18/2015 HANGER;24.1 G'! Casing Strings I Casing Description OD(in) ID lin) Top(ftKB) Set Depth)ftKB) Set Depth(ND)... Wt/Len(I...Grade Top Thread CONDUCTOR 20 18.430 28.4 157.4 157.4 154.00 H-40 Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)...Wt/Len(I...Grade Top Thread SURFACE 10 3/4 9.950 27.6 3,904.4 2,969.4 45.50 L-80 HYD 563 Casing Description 'OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)...Wt/Len(I...Grade Top Thread INTERMEDIATE 75/8 6.875 26.1 13,460.0 6,087.4 29.70 L-80 Hyd 563 Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)...Wt/Len(I...Grade Top Thread LINER-51/2x41/2 41/2 3.958 13,276.7 21,990.0 6,206.3 11.60 L-80 HYD 563 @13308.37 Liner Details Nominal ID Top(ftKB) Top(ND)(ftKB) Top Incl(°) Item Des Com (in) 13,276.7 6,055.7 77.61 PACKER BAKER ZXP PACKER W/HRDE PROFILE 5.750 Is 13,295.8 6,059.6 78.19 NIPPLE BAKER RS PACKOFF SEAL NIPPLE 4.870 CONDUCTOR;28.4-157.4 III 13,298.6 6,060.2 78.27 HANGER BAKER DG FLEX LOCK LINER HANGER 4.790 13,308.4 6,062.2 78.57 XO Reducing Cross-over sub 5W'H563 box x 4W'HYD 563 3.870 I 14,606.7 6,106.6 92.42 SWELL PACKERS PLUS OD SWELL PACKER 3.958 NIPPLE;553.7 - PACKER al Tubing Strings Tubing Description String Ma...ID(in) Top(ftKB) Set Depth(ft...Set Depth(TOO)(...Wt(Iblft) Grade Top Connection TUBING-UPPER-4 31/2 2.992 24.1 13,228.8 6,044.8 9.30 L-80 EUE II 1/2 x 3 1/2 @59.53 GAS LIFT;2,837.6 Completion Details Nominal ID Top(ftKB) Top(ND)(ftKB) Top Incl(°) Item Des Com (in) 24.1 24.1 0.00 HANGER CAMERON TUBING HANGER 3.900 1 ( 553.7 553.7 240 NIPPLE CAMCO DS NIPPLE 2.875 13,124.1 6,016.6 72.57 SLEEVE BAKER CMU SLIDING SLEEVE W/2.813 NIPPLE 2.812 PROFILE SURFACE;27.6-3,904.4 13,206.1 6,039.2- 75.42 LOCATOR LOCATOR SUB 2.990 ?1 II 13,206.4 6,039.3 75.43 PBR BAKER PBR SEAL ASSEMBLY 80-40 2.990 ' Tubing Description String Ma...ID(in) Top(ftKB) Set Depth(ft..JSet Depth)ND)(...Wt(lb/ft) Grade Top Connection TUBING-LOWER 3.51 2.970 13,211.8 13,305.21 6,061.6 9.20 L-80 IBT Completion Details Nominal ID Top(ftKB) Top(ND)(ftKB) Top Incl(°) Item Des Com (in) 13,211.8 6,040.7 75.62 PBR POLISHED BORE RECEPTACLE 4.000 SLEEVE;13,124.1 II - 13,237.0 6,046.7 76.42 PACKER BAKER PREMIER PRODUCTION PACKER TC-II 3.500 I 13,256.0 6,051.1 76.99 NIPPLE CAMCO D NIPPLE 2.750 III 13,273.7 6,055.0 77.52 SUB,NO GO NO GO SUB 3.000 III �,13,274.7 6,055.2 77.55 SOS SHEAR SUB 3.000 LOCATOR;13206.1 13,304.2 6,061.4 78.44 SHOE MULE SHOE W/WLEG 3.010 PBR;13,206.4, Perforations&Slots PBR;13,211211.88 Shot Den X0 Threads;13,234.9 Top(TVD) Btm(TVD) (shotslf Top(ftKB) Btm(ftKB) (ftKB) (ftKB) Zone Date t) Type Com PACKER;13,237.0 14,616.7 15,188.0 6,106.1 6,109.5 1/14/2015 SLOTS SLOTTED LINERS 15,354.7 21,980.5 6,110.0 6,206.3 1/14/2015 SLOTS SLOTTED LINERS 1 Mandrel Inserts NIPPLE.13.256.0St on Top(ND) Valve Latch Port Size TRO Run N Top(ftKB) (ftKB) Make Model OD(in) Sent Type Type (in) (psi) Run Date Com SUB,NO GO;13,273.7 ig t 2,837.6 2,505.7 CAMCO MMG 11/2 GAS LIFT OV RK 0250 2/5/2015 SOS;13,2747 .-- Notes:General&Safety End Date Annotation 2/12/2015 NOTE. DRIFTED TO 13,480'SLM.TOOLS STOPPED DUE TO DEVIATION. 1 SHOE;13,304.2 IIf II IIf IIi INTERMEDIATE;26.1-13,460.0 - SLOTS;14,616.7.15,188.0 Li SLOTS;15,354.721,980.5 LINER-510e41/2 ` 013306.37;13,276.7-21,990.0 RECEIV STATE OF ALASKA FEB 17 2015 ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT ANCikMC la.Well Status: Oil ❑ Gas ❑ SPLUG ❑ Plugged ❑ Abandoned ❑ Suspended ❑ lb.Well Class: 20AAC 25.105 20AAC 25.110 Development ❑ Exploratory ❑ GINJ ❑ WINJ Q WAG ❑ WDSPL ❑ Other ❑ No.of Completions: Service CI StratigraphicTest❑ 2.Operator Name: 5.Date Comp.,Susp., 12.Permit to Drill Number: ConocoPhillips Alaska, Inc. orAband.: .January 18,2015 214-150/ • 3.Address: 6.Date Spudded: 13.API Number: P.O.Box 100360,Anchorage,AK 99510-0360 • December 5,2014 50-029-23530-00 , 4a.Location of Well(Governmental Section): 7.Date TD Reached: 14.Well Name and Number: Surface: 231'FNL, 1721'FEL,Sec.33,T11 N, R9E, UM • January,9'2015 146 K(,t.) 2F-22. Top of Productive Horizon: 8. KB(ft above MSL): 123.6'RKB 15.Field/Pool(s): 26'FSL, 993'FWL,Sec.4,T10N, R9E, UM GL(ft above MSL): 95.8'AMSL Kuparuk River Field Total Depth: 9.Plug Back Depth(MD+TVD): 3219'FNL,92'FWL,Sec. 16,T1 ON, R9E, UM 13317'MD/6064'TVD Kupuruk River Oil Pool 4b.Location of Well(State Base Plane Coordinates,NAD 27): 10.Total Depth(MD+TVD): 16.Property Designation: Surface: x-517511 y- 5948652 Zone-4 22009'MD/6206'TVD ADL 25657,25666,25668,302364 TPI: x-514994 y- 5938345 Zone-4 11.SSSV Depth(MD+TVD): 17.Land Use Permit: Total Depth: x-514133 y- 5929819 Zone-4 nipple @ 554'MD/554'ND 2583,2587,2589 18.Directional Survey: Yes Q No❑ 19.Water Depth,if Offshore: 20.Thickness of Permafrost MD/TVD: (Submit electronic and printed information per 20 AAC 25.050) na (ft MSL) 1452'MD/1416'TVD 21.Logs Obtained(List all logs here and submit electronic and printed information per 20 AAC 25.071): 22.Re-drill/Lateral Top Window MD/TVD GR, Res , Dt;'N/Ne-u t P�visco c., rvkic,✓uscc.,l t Sow:C.-TOG. not applicable 23. CASING,LINER AND CEMENTING RECORD SETTING DEPTH MD SETTING DEPTH ND HOLE AMOUNT CASING SIZE WT.PER FT. GRADE TOP BOTTOM TOP BOTTOM SIZE CEMENTING RECORD PULLED 1 20" 154# H-40 28' 157' 28' 157' 24" Driven 10.75" 45.5# L-80 28' 3904' 28' 2969' 13.5" 1582 sx LiteCRETE,214 sx Class G 7.625" 29.7# L-80 26' 13460' 26' 6088' 9.875" 183 sx Class G,177 sx Class G 4.5" 11.6# L-80 13317' 21990' 6064' 6206' 6.75" slotted liner 24.Open to production or injection? Yes ❑ No ❑ If Yes,list each 25. TUBING RECORD Interval open(MD+TVD of Top&Bottom;Perforation Size and Number): SIZE DEPTH SET(MD) PACKER SET(MD/TVD) 3.5" 13305' 13237'MD/6047'ND and slotted liner from 14617'-21980'MD 6107'-6206'ND 13277'MD/6056'ND,14607'MD/6107'ND 26. ACID,FRACTURE,CEMENT SQUEEZE,ETC. Was hydraulic fracturing used during completion? Yes❑ No Q ('' rl DEPTH INTERVAL(MD) AMOUNT AND KIND OF MATERIAL USED ` none 27. PRODUCTION TEST Date First Production Method of Operation(Flowing,gas lift,etc.) waiting on facility hook-up Date of Test Hours Tested Production for OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE GAS-OIL RATIO Test Period--> Flow Tubing Casing Pressure Calculated OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-API(corr) Press. 24-Hour Rate-> 28. CORE DATA Conventional Core(s)Acquired? Yes ❑ No Q Sidewall Cores Acquired? Yes ❑ No Q If Yes to either question,list formations and intervals cored(MD+TVD of top and bottom of each),and summarize lithology and presence of oil,gas or water (Submit separate sheets with this form,if needed).Submit detailed descriptions,core chips,photographs and laboratory analytical results per 20 AAC 25.071. NONE Form 10-407 Revised 10/2012 CONTINUED ON REVERSE �A-6. -/2-9/15--- Submit original only UTA 37/?//5- /6$7z/6 RBDMSJ FEB 2 3 2015 6 29. GEOLOGIC MARKERS(List all formations and ma, encountered) 30 FORMATION TESTS NAME MD TVD Well tested? ❑ Yes Q No If yes,list intervals and formations tested, Permafrost-Top ground surface ground surface briefly summarizing test results. Attach separate sheets to this form,if Permafrost-Bottom 1452' 1416' needed,and submit detailed test information per 20 AAC 25 071 Top Kuparuk C4 13383' 6076' Top Kuparuk B2 13453' 6087' Base Kuparuk C4/Top Kuparuk B2 14540' 6110' Top Kuparuk B2 15204' 6110' Base Kuparuk C4/Top Kuparuk B2 15346' 6111' Ste, �,i`a�.( `{1li 4- CdK.p(t - 12'4-'• ')C N/A �i✓� s� t( mar !?.•mss 6*-114 1/s Formation at total depth: Kuparuk C4 31. LIST OF ATTACHMENTS Summary of Daily Operations, schematic,final directional survey,cement detail reports 32. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Lindsey Hunter @ 263-6427 Email Lindsev.Hunt on.con cop fillips conn Printed Name G.L.Alvord Title Alaska Drilling Manager Signature Z Phone 265-6120 Date 211315 INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases 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. Item 1a: Classification of Service wells: Gas injection,water injection,Water-Alternating-Gas Injection,Salt Water Disposal,Water Supply for Injection,Observation,or Other.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 4b: TPI(Top of Producing Interval). Item 8: The Kelly Bushing and Ground level 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 13:The API number reported to AOGCC must be 14 digits(ex.50-029-20123-00-00). Item 20: Report true vertical thickness of permafrost in Box 20. Provide MD and TVD for the top and base of permafrost in Box 28. Item 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool Item 23: 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 26: Method of Operation: Flowing,Gas Lift,Rod Pump,Hydraulic Pump,Submersible,Water Injection,Gas Injection,Shut-in,or Other (explain). Item 27:Provide a listing of intervals cored and the corresponding formations,and a brief description in this box.Submit detailed description and analytical laboratory information required by 20 AAC 25.071. Item 29: Provide a list of intervals tested and the corresponding formation,and a brief summary of this box.Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Form 10-407 Revised 10/2012 • KUP SVC 2F-22 1 ConocoPhillips itt Well Attributes Max Angle&MD TD Alaska,Inc, Wellbore API/UWI Field Name Wellbore Status ncl(°) MD(ftKB) Act Btm(ftKB) c c)," 500292353000 KUPARUK RIVER UNIT SVC 92.92 14,452.99 22,009.0 °°. Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date HORIZONTAL-2F-22,2/12/2015 12:3105 PM SSSV:NIPPLE Last WO: 27.75 1/19/2015 Vertical schematic(actual) Annotation Depth(ftKB) End Date Annotation Last Mod By End Date Last Tag: Rev Reason:NEW WELL smsmith 2/11/2015 HANGER:24.1 Casing Strings C Casing Description 00(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)... Wt/Len(1...Grade Top Thread CONDUCTOR 20 18.430 28.4 157.4 157.4 154.00 H-40 Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)...Wt/Len(I...Grade Top Thread - SURFACE 103/4 9.950 27.6 3,904.4 2,969.4 45.50 L-80 HYD 563 wool-,.,.-.�m--.....rd......--. Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)...WULen(1...Grade Top Thread INTERMEDIATE 7 5/8 6.875 26.1 13,460.0 6,087.4 29.70 L-80 Hyd 563 Casing Description OD(in) ID(in) 'Top(ftKB) Set Depth(MB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread - LINER-51/2x41/2 41/2 3.958 13,276.7 21,990.0 6,206.3 11.60 L-80 HYD 563 @13308.37 Liner Details Nominal ID Top(ftKB) Top(TVD)(ftKB) Top Inel C) Item Des Com (in) 13,276.7 6,055.7 77.61 PACKER BAKER ZXP PACKER WI HRDE PROFILE 5.750 1 13,295.8 6,059.6 78.19 NIPPLE BAKER RS PACKOFF SEAL NIPPLE 4.870 CONDUCTOR;28.4-157.4 13,298.6 6,060.2 78.27 HANGER BAKER DG FLEX LOCK LINER HANGER 4.790 13,308.4 6,062.2 78.57 XO Reducing Cross-over sub 5W H563 box x 4 HYD 563 3.870 14,606.7 6,106.6 92.42 SWELL PACKERS PLUS OD SWELL PACKER 3.958 NIPPLE,553.7 PACKER I Tubing Strings II Tubing Description String Ma...ID(I0/ I Top(ftKB) I Set Depth(ft..f Set Depth(TVD)(...Wt(Ib/(t) Grade Top Connection TUBING-UPPER-4 31/2 2.992 24.1 13,2288 6,044.8 9.30 L-80 EWE I 1/2 x 3 1/2 @59.53 GAS LIFT;2,837.6 Completion Details Nominal ID Tap(ftKB) Top(ND)(ftKB) Top Incl(°) Item Des Com (in) 1� 24.1 24.1 0.00 HANGER CAMERON TUBING HANGER 3.900 0 553.7 553.7 2.40 NIPPLE CAMCO DS NIPPLE 2.875 13,124.1 6,016.6 72.57 SLEEVE BAKER CMU SLIDING SLEEVE W/2.813 NIPPLE 2.812 PROFILE SURFACE:27.6 39044 13,206.1 6,039.2 75.42 LOCATOR LOCATOR SUB 2.990 13,206.4 6,039.3 75.43'PBR BAKER PBR SEAL ASSEMBLY 80-40 2.990 ■I II Tubing Description String Ma...ID(in) Top(ftKB) Set Depth(ft..Set Depth(TVD)(...Wt(lb/ft) Grade Top Connection 1 TUBING-LOWER 3.51 2.970 13,211.8 13,305.2 6,061.6 9.20 L-80 IBT Completion Details Nominal ID ITop(ftKB) Top(ND)(ftKB) Top Incl(°) Item Des Com (in) . 13,211.8 6,040.7 75.62 PBR POLISHED BORE RECEPTACLE 4.000 SLEEVE;13,124.1 C 13,237.0 6,046.7 76.42 PACKER BAKER PREMIER PRODUCTION PACKER TC-II 3.500 II 13,256.0 6,051.1 76.99 NIPPLE CAMCO D NIPPLE W/RHC PLUG 2.750 111 13,273.7 6,055.0 77.52 SUB,NO GO NO GO SUB 3.000 13,274.7 6,055.2 77.55 SOS SHEAR SUB 3.000 LOCATOR;13,206.1 MI 13,304.2 6,061.4 78.44 SHOE MULE SHOE W/WLEG 3.010 PBR;13,2 . Perforations&Slots PBR;13,21111.88 _ Sent IMI Dens XO Threads;13,234,9 Top(ND) Min(ND) (shotslf Top(ftKB) Blot(ftKB) (ftKB) (ftKB) Zone _ Date t) Type Com PACKER;13,237.0 14,616.7 15,188.0 6,106.1 6,109.5 1/14/2015 SLOTS SLOTTED LINERS 15,354.7 21,980.5 6,110.0 6,206.3 1/14/2015 SLOTS SLOTTED LINERS Mandrel Inserts NIPPLE;13,256,0 St ali -- Top(ND) Valve Latch Port Size TRO Run N Top(ftKB) (560) Make Model OD(in) Sery Type Type (in) (psi) Run Date Com Sue,NO GO;13,273.7 SOS;13,274/ H1 2,837.6 2,505.7 CAMCO MMG 1 1/2 GAS LIFT OV RK 0.250 2/5/2015 SOS;13,274.7 - Notes:General&Safety End Date Annotation NOTE -- - -- flSHOE;13,304.2 1111 INTERMEDIATE;26.1.13,480.0 • • SLOTS;14,616.7-15,188.0 SLOTS;15,354.7-21,980.5 LINER-5 1/2 x 4 1/1 613308.37;13,276.7-21,9900 ConocoPhillips Time Log & Summary We/View Web Reporting Report Well Name: 2F-22 Rig Name: DOYON 141 Job Type: DRILLING ORIGINAL Rig Accept: 12/5/2014 12:00:00 AM Rig Release: 1/19/2015 12:00:00 AM Time Logs Date From To Dur S.Depth E. Depth Phase Code Subcode T Comment 12/03/2014 24 hr Summary RDMO modules staged for 2F-22. Remove diverter system from behind 2F-21. 18:00 22:30 4.50 0 0 MIRU MOVE MOB P PJSM, move pipe sheds, rock washer, boiler, motor, pump,&pits modules with sub base to stage out of way for pad prep. 22:30 00:00 1.50 0 0 MIRU MOVE RURD P Remove snow around 2f-22. Sim-ops begin digging out diverter system from 2F-21. 12/04/2014 Prep pad&install diverter system. Spot rig on 2F-22. Complete rig acceptance checklist. 00:00 01:30 1.50 0 0 MIRU MOVE RURD P Continue to remove snow around 2F-22. Sim-ops dig out to remove diverter system from 2F-21. 01:30 03:00 1.50 0 0 MIRU MOVE RURD P PJSM;spot crane&remove diverter system from 2F-21. Sim-ops continue to prep pad around 2F-22. 03:00 06:30 3.50 0 0 MIRU MOVE RURD P PJSM;finish prepping pad&spot crane near 2F-22. Spot counter weight&saddles for diverter line with crane. 06:30 10:15 3.75 0 0 MIRU MOVE NUND T PJSM: attempt to set CIW diverter riser connector,would not go past upper seal, hanging up on snap ring. Redress seals&snap rings in shop. 10:15 11:15 1.00 0 0 MIRU MOVE NUND P PJSM; install CIW diverter riser connector. 11:15 12:00 0.75 0 0 MIRU MOVE NUND P PJSM;set diverter spool, annular,& knife valve. 12:00 14:00 2.00 0 0 MIRU MOVE NUND P PJSM; set diverter line with crane. 14:00 20:30 6.50 0 0 MIRU MOVE MOB P PJSM; move sub base over 2F-22. Mate up pits, pump, motor, &boiler modules. Set rock washer&pipe sheds. Sim-ops electrical&service interconnects. 20:30 00:00 3.50 0 0 MIRU MOVE RURD P Work on rig acceptance check list. Calibrate&test gas alarms. Rig accepted @ 24:00. 12/05/2014 Finish nipple up of diverter system. Load 5" DP in shed.Take on spud mud in pits. Pick up 5"DP&rack back in derrick. Perform diverter test with AOGCC Jeff Jones witness. Pick up clean out BHA. Flood all lines, PT high pressure mud lines&check for leaks. Clean out conductor w/BHA 1 &drill to 188'MD. 00:00 07:00 7.00 0 0 MIRU MOVE NUND P Continue to NU diverter system. Sim-ops load shed w/5"DP&take on mud. 07:00 10:00 3.00 0 0 MIRU MOVE RURD P Dress TD for 5"DP changing out saver sub,grabbers, &bell guide. Page 1 of 41 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 10:00 10:15 0.25 0 0 MIRU MOVE BOPE P Function test diverter system. 10:15 11:00 0.75 0 0 MIRU MOVE RURD P Clear rig floor of all 4"handling equipment. 11:00 12:00 1.00 0 0 MIRU MOVE BOPE P Perform diverter test, system pressure 2950 psi,after closure 1850 psi,200 psi recharge time 52 sec, full recharge time 180 sec. 5 nitrogen bottles averaged 2100 psi. Knife vavle open time 9 sec, annular closed time 22 sec. Tested gas&PVT alarms, good.Test witnessed by AOGCC Rep Jeff Jones. 12:00 13:00 1.00 0 0 MIRU MOVE RURD P Rig up to pick up 5" DP in the mousehole. C/O heads on IR for 5" DP. 13:00 18:00 5.00 0 0 MIRU MOVE PULD P Pick up 43 stands of 5"DP&6 stands of 5"HWDP, racking back in the derrick. 18:00 19:45 1.75 0 0 MIRU MOVE RURD P Clear&clean rig floor, mobilize BHA to rig floor,&pre-spud derrick inspection. 19:45 20:15 0.50 0 0 MIRU MOVE SFTY P Pre-spud meeting with rig crew& service personnel. Diverter drill table top discussion. 20:15 21:00 0.75 0 50 MIRU MOVE PULD P Make up clean out BHA 1 as per SLB DD. 21:00 21:30 0.50 50 50 MIRU MOVE SEQP P Flood all lines&conductor, check for leaks. PT high psi mud lines to 3500 psi for 10 min. 21:30 23:30 2.00 50 157 SURFA( DRILL DDRL P Clean out conductor f/50'-157'MD, 450 gpm,275 psi, 50 rpm,Tq 1K, FO 91 %. 23:30 00:00 0.50 157 188 SURFA( DRILL DDRL P Drill f/157'-188'MD, 188'TVD,ADT .33,AST 0, Bit= 1.42, Jars 0, PU 42K, SO 47K, ROT 42K,Tq on 1k, off 1K, FO 77%,WOB 3-5K, 50 rpm, 450 gpm,275 psi. 12/06/2014 Drill to 254' MD w/cleanout BHA1.TOH&PU surface BHA 2.TIH&DDrill as per plan to 1425'MD, 1392' TVD. 00:00 00:45 0.75 188 254 SURFA( DRILL DDRL P Drill f/188'-254'MD, 188'TVD, ART=.92,AST=ADT.92, Bit hours= 2.5 Jars hours=0, PU 42K, SO 47K, ROT 42K,Tq on 1k, off 1K, FO 77%, WOB 5-10K, 50 rpm,450 gpm, 300 psi., Max Gas=24 units 00:45 01:30 0.75 254 40 SURFA( DRILL REAM P BROOH to 40' MD @ 450 gpm. 01:30 04:00 2.50 40 121 SURFA( DRILL PULD P PJSM, M/U BHA#2 as per SLB. 04:00 06:00 2.00 121 224 SURFA( DRILL DHEQ P Test GWD/MWD tools @ 121'and 221'as per Gyrodata. 06:00 12:00 6.00 224 622 SURFA( DRILL DDRL P Drill f/254'-622'MD,622'TVD, ART=1.2,AST=1.8 ADT 3.0, Bit hours=5.50 Jar hours=5.5, PU 72K, SO 74K, ROT 74K,Tq on 2k, off 1K, FO 88%,WOB 15-20K, 50 rpm, 450 gpm, 650 psi., ECD=10.23 Page 2 of 41 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 12:00 18:00 6.00 622 1,025 SURFA( DRILL DDRL P Drill f/622'-1025' MD, 1019'TVD, ART=1.03,AST=2.54 ADT 3.57, Bit hours=9.07 Jar hours=9.07 , PU 84K, SO 83K, ROT 81 K,Tq on 5k, off 2K, FO 77%, WOB 20-30K, 50 rpm, 500 gpm, 675 psi., ECD=9.93 18:00 00:00 6.00 1,025 1,425 SURFA( DRILL DDRL P Drill f/1025'-1425'MD, 1392'TVD, ART=1.58,AST=2.03 ADT 3.61, Bit hours= 12.68 Jar hours= 12.68 , PU 88K, SO 87K, ROT 88K,Tq on 3-7k, off 1-2K, FO 72%,WOB 20-25K, 50 rpm, 500 gpm, 775 psi., ECD=9.78 Fire Drill CRT= 165 sec @ 23:00 hrs. 12/07/2014 DDrilled surface section f/1425'-3347' MD,2766'TVD as per plan. Load&tally 10 3/4" Hyd 563 casing. 00:00 06:00 6.00 1,425 1,993 SURFA( DRILL DDRL P Drill f/1425'-1993' MD, 1883'TVD, ART=1.37,AST=2.62 ADT=3.99, Bit hours= 16.16 Jar hours= 14.11 , PU 102K, SO 92K, ROT 94K,Tq on 4-5k, off 2-3K, FO 65%,WOB 10-15K, 50 rpm, 515 gpm, 960 psi., ECD=9.95 Spill Drill CRT 140 sec @ 04:00 hrs. 06:00 12:00 6.00 1,993 2,552 SURFA( DRILL DDRL P Drill f/1993'-2552' MD, 2322'TVD, ART=1.35,AST=2.09 ADT=3.44, Bit hours=20.05 Jar hours= 17.55, PU 105K, SO 90K, ROT 100K,Tq on 9-10k, off 4-6K, FO 65%,WOB 20-25K, 50 rpm, 610 gpm, 1375 psi., ECD=9.90 12:00 18:00 6.00 2,552 3,015 SURFA( DRILL DDRL P Drill f/2552'-3015' MD, 2607'TVD, ART=1.54,AST=1.34 ADT=2.88, Bit hours=22.93 Jar hours=20.43, PU 110K, SO 92K, ROT 100K,Tq on 8-10k, off 4-6K, FO 64%,WOB 20-25K, 50 rpm, 600 gpm, 1200 psi., ECD= 10.27 18:00 00:00 6.00 3,015 3,347 SURFA( DRILL DDRL P Drill f/3015'-3347' MD, 2677'TVD, ART=1.78,AST=1.89 ADT=3.67, Bit hours=26.60 Jar hours=24.10, PU 111K, SO 86K, ROT 101 K,Tq on 7-9k, off 3-6K, FO 62%,WOB 20-25K, 50 rpm, 600 gpm, 1250 psi., ECD= 10.10 12/08/2014 DDrilled ahead as per plan to surface hole TD @ 3919' MD, 2973'TVD. CBU 2X. BROOH to HWDP @ 775' MD. 00:00 06:00 6.00 3,347 3,552 SURFA( DRILL DDRL P Drill f/3347'-3552' MD, 2847'TVD, ART=1.78,AST=3.0 ADT=4.74, Bit hours=31.34 Jar hours=28.84 , PU 111K, SO 92K, ROT 102K,Tq on 7-9k, off 5K, FO 62%,WOB 25-30K, 50 rpm, 616 gpm, 1530 psi., ECD= 10.14 Fire Drill CRT= 100 sec Page 3 of 41 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 06:00 12:00 6.00 3,552 3,823 SURFA( DRILL DDRL P Drill f/3552-3823'MD,2944'TVD, ART=2.25,AST=1.95 ADT=4.20, Bit hours=35.54 Jar hours=33.04, PU 115K, SO 90K, ROT 102K,Tq on 8-15k,off 6-7K, FO 65%,WOB 20-30K,60 rpm,700 gpm, 1880 psi., ECD= 10.11 12:00 13:45 1.75 3,823 3,916 SURFA( DRILL DDRL P Drill f/3823-3916'MD,2973'TVD, ART=O,AST=1.13 ADT= 1.13, Bit hours=36.67 Jar hours=34.17 , PU 114K, SO 90K, ROT 100K,Tq on 8-10k,off 4-6K, FO 65%,WOB 15-20K, 50 rpm, 700 gpm, 1750 psi., ECD= 10.4 TD @ 3916'MD,2973'TVD. 13:45 15:15 1.50 3,916 3,853 SURFA( CASING CIRC P Survey at TD. CBU 2X, 750 gpm, 1925 psi, 60 rpm,Tq 5-7K, FO 66%. Rack back stand at BU to 3853'MD. 15:15 15:30 0.25 3,853 3,853 SURFA( CASINGOWFF P Monitor well,static. 15:30 23:30 8.00 3,853 775 SURFA( CASING REAM P BROOH f/3852'-775'MD,650 gpm, 1500 psi,60 rpm,Tq 5k, FO 58%. From 1616'-775'MD 550 gpm,850 psi,60 rpm, Tq 4K. Calculated displacement 26.25, actual 55.23 bbls. Losses attributed to hole unloading with cuttings&mud across the end of the shakers. PU 80, SO 80. 23:30 23:45 0.25 775 775 SURFA( CASING RURD P Blow down TD. 23:45 00:00 0.25 775 775 SURFA( CASING OWFF P Monitor well, static. 12/09/2014 Continue POOH&lay down BHA 2. Dummy run w/10 3/4"hanger. Rig up Volant CRT&casing equipment. Run 10 3/4"surface casing as per detail to TD @ 3904' MD. C&C mud for cement job. 00:00 01:00 1.00 775 221 SURFA( CASING TRIP P PJSM, POOH from 775'MD to 221' MD, Pump @ 2 bpm=50 psi. 01:00 03:15 2.25 221 0 SURFA( CASING PULD P PJSM, L/D BHA#2 as per SLB rep. Actual displacement=34.14, Calculated displacement=22.03 03:15 04:30 1.25 0 0 SURFA( CASING RURD P Clean and clear rig floor. 04:30 06:30 2.00 0 0 SURFA( CASING RURD P PJSM, Pick up and rig up GBR Volant tool, bail extensions and slips as per GBR rep. 06:30 07:30 1.00 0 0 SURFA( CASING SVRG P Service rig,top drive and draw works. 07:30 07:45 0.25 0 0 SURFA( CASING RURD P Drain stack, PU hanger/landing joint, &perform dummy run as per CIW. 07:45 08:00 0.25 0 0 SURFA( CASING RURD P Finish casing equipment rig up. 08:00 13:15 5.25 0 1,498 SURFA( CASING PUTB P PJSM, RIH w/10 3/4",45.5#, L-80, Hyd 563 casing to 1498'MD as per detail. PU 85K, SO 75K, calculated displacement 25.01, actual-19.25 bbls. 13:15 14:00 0.75 1,498 1,498 SURFA( CASING CIRC P CBU staging up pump f/1.5-5 bpm. 5 bpm= 100 psi, FO 38%. Page 4of41 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 14:00 17:30 3.50 1,498 2,812 SURFA( CASING PUTB P PJSM, RIH w/10 3/4",45.5#, L-80, Hyd 563 casing 1498'-2812'MD as per detail. PU 150K, SO 100K, calculated displacement 46.54, actual-13.3 bbls. 17:30 18:45 1.25 2,812 2,812 SURFA( CASING CIRC P CBU staging up pump f/1.5-4 bpm.4 bpm= 180 psi, FO 40%. 18:45 22:30 3.75 2,812 3,873 SURFA( CASING PUTB P PJSM, RIH w/10 3/4",45.5#, L-80, Hyd 563 casing 2812'-3873'MD as per detail. PU 200K, SO 110K, calculated displacement 63.9, actual 5.6 bbls. 22:30 23:00 0.50 3,873 3,904 SURFA( CASING HOSO P Pick up&make up hanger with landing joint per CIW Rep. Land hanger on depth 3904.36'MD. PU 190K, SO 110K. 23:00 00:00 1.00 3,904 3,904 SURFA( CEMEN-CIRC P CBU staging up pump f/1.5-7 bpm.7 bpm=275 psi, FO 42%. 12/10/2014 Continue to condition mud for cement. RD CRT&RU cement head. Cement as per plan. Monitor well&lay down landing joint. ND diverter system. NU well head as per CIW. NU BPOE. C/O lower rams. C/O kill HCR valve. 00:00 01:15 1.25 3,904 3,904 SURFA( CEMEN'RURD P PJSM, Rig down Volant tool and R/U cement head. 01:15 04:00 2.75 3,904 3,904 SURFA( CEMEN-CIRC P Circulate and condition mud for cement job, stage pumps up from 1.5 bpm=100 psi to 7 bpm=400 psi. P/U= 180K, S/O= 125K. 04:00 04:15 0.25 3,904 3,904 SURFA( CEMEN-SFTY P Hold PJSM on cementing surface casing with SLB cementers. 04:15 07:45 3.50 3,904 3,904 SURFA( CEMEN-CMNT P Batch up 10.5 ppg MP II, pump 5 bbls of H2O. Pressure test lines to 1500/4000 psi, good. SLB came online, pumped 103 bbls of 10.5 ppg MP II,shut down and drop bottom plug. Batch up lead as per SLB, come online and pump 551 bbls of 11.0 ppg LiteCRETE lead cement and 63.5 bbls of 12.0 ppg LiteCRETE tail cement, shut down and drop top plug, kick plug out with 10 bbls of H2O. Spill Drill CRT 120 sec @ 04:30 hrs. 07:45 09:00 1.25 3,904 3,904 SURFA( CEMEN-CMNT P Displace cement with 9.4 ppg mud with rig pumps @ 7 bpm, ICP 500 psi, FCP 750 psi. Slow rate to 3 bpm 500 psi @ 3400 stks. Bump plug @ 3520 stks. Pressure up to 1000 psi &hold for 5 min. Bleed of psi& check float,good. CIP @ 08:45 hrs. 09:00 10:15 1.25 3,904 3,904 SURFA( CEMEN-RURD P PJSM, rig down cement equipment, landing jt, and clean tools. Sim-ops, flush stack w/black water. 10:15 15:30 5.25 3,904 3,904 SURFA(WHDBO NUND P PJSM, nipple down diverter system. Function&flush annular w/black water. Sim-ops clear rig floor & cellar of tools/equipment. Swap to rig generators @ 13:45 hrs. Page 6 of 41 Time Logs Date From To Dur S.Depth E. Depth Phase Code Subcode T Comment 15:30 18:15 2.75 3,904 3,904 SURFA( WHDBO NUND P PJSM, NU well head per CIW Rep. Orient per DSO. TOC 7.5'below landing ring 18:15 18:30 0.25 3,904 0 SURFA(WHDBO SEQP P PJSM test seals between hanger& wellhead to 5000 psi for 10 min, witnessed. 18:30 21:30 3.00 0 0 SURFA( WHDBO NUND P PJSM, NU 13 5/8"BOPE. 21:30 22:15 0.75 0 0 SURFA( WHDBO NUND P PJSM, install 3.5"X 6"VBR's in lower rams body. 22:15 00:00 1.75 0 0 SURFA( WHDBO NUND P PJSM, C/O Kill HCR valve. 12/11/2014 PU 5" DP&rack back in derrick. Finish NU of MPD equipment.Test BOPE. 00:00 02:00 2.00 0 0 SURFA( CEMEN'RURD P PJSM, Install mouse hole, install 5" bell guide on top drive. Hook up choke line.SIMOPS,ASRC install scaffolding in cellar. 02:00 08:00 6.00 0 0 SURFA( CEMEN'PULD P PJSM, Pick up 70 stands on 5"DP from pipe shed and stand back in derrick. Rig Evac.Table Top Drill @ 06:00 hrs. 08:00 08:30 0.50 0 0 SURFA( CEMEN-RURD P PJSM, lay down mouse hole&clear rig floor. 08:30 14:30 6.00 0 0 SURFA( CEMEN'SEQP P PJSM, NU MPD, lines&drip pan. Attempt to set trip nipple. Rig back on shore power @ 14:00 hrs. 14:30 18:30 4.00 0 0 SURFA( CEMEN-SEQP T Re-dress trip nipple for easier installation. Install trip nipple. 18:30 19:30 1.00 0 0 SURFA( CEMEN"SVRG P Service rig&perform derrick inspection. 19:30 21:15 1.75 0 0 SURFA(WHDBO RURD P Rig up to test BPOE. 21:15 00:00 2.75 0 0 SURFA(WHDBO BOPE P Test BOPE with 5"TJ to 250/3500 psi 5 min each charted.#1-Top pipe rams,Valve 1,12,13,14.#2-Upper IBOP, HCR kill,Valves 9,11.#3- Lower IBOP,Valves 5,8,10.#4-Dart valve,valves 4,6,7.#5-Floor valve& valve 2.#6-HCR choke,4"kill line, Demco valve.#7-Manual choke valve, HCR kill. 12/12/2014 Completed BOP test and tested MPD manifold and lines. M/U BHA#3 and RIH,tested casing to 3000 psi. Slip and cut line and service rig.Wash down to TOC. Page 6 of 41 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 00:00 03:15 3.25 0 0 SURFA(WHDBO BOPE P Cont.to test BOPE w/5"test joint to 250/3500 psi for 5 min each. Test#8: Annular preventer.Test#9: Blind rams.Leak on double adapter flange on stack,tighten bolds and retest, good.Test manual choke, remote choke,Totco alarms and gas alarms. Accumulator test:system pressure= 3050 psi, pressure after closing= 1700 psi, 200 psi attained after 39 sec,full pressure attained after 204 sec. Nitrogen five bottle avg.=2000 psi.AOGCC inspector Matt Herrera waived witness of the test. Accumulator Drill with crew @ 03:00 hrs. 03:15 03:30 0.25 0 0 SURFA(WHDBO RURD P Blow down choke line,choke,top drive and kill line. 03:30 11:15 7.75 0 0 SURFA( CEMEN'SEQP P Pull trip nipple and test MPD manifold as per Safe Kick and MPD rep.to 250 psi for 5 min and 1800 psi for 10 min.The pressure test consisted of 6 tests,testing line valves and lines on MPD system. After testing removed test cap and installed trip nipple. 11:15 12:00 0.75 0 0 SURFA( CEMEN-RURD P Remove test plug, install 10"OD wear bushing and install split bushings. SIMOPS, clean and clear cellar. 12:00 13:45 1.75 0 0 SURFA( CEMEN-PULD P PJSM, P/U BHA#3 tools from the beaver slide and steam tools off. 13:45 15:30 1.75 0 155 SURFA( CEMEN-PULD P PJSM, M/U BHA#3 as per SLB rep. 15:30 16:30 1.00 155 705 SURFA( CEMEN-TRIPP PJSM, RIH w/ HWDP out of derrick to 705'MD. 16:30 17:30 1.00 705 1,500 SURFA( CEMEN PULD P PJSM, RIH picking up 5"DP from pipe shed f/705' MD to 1500'MD. 17:30 17:45 0.25 1,500 1,500 SURFA( CEMEN'DHEQ P Shallow hole test MWD tools, pump 0 450 psi=900 psi, good test. 17:45 19:45 2.00 1,500 3,690 SURFA( CEMEN"PULD P Cont to RIH picking up 5"DP f/1500' MD to 3690' MD. Calculated displacement=38.2 bbls,Actual displacement=38.1 bbls. 19:45 20:15 0.50 3,690 3,690 SURFA( CEMEN'CIRC P CBU @ 450 gpm=1200 psi. P/U= 124K, S/O=78K, ROT=96K 20:15 20:45 0.50 3,690 3,690 SURFA( CEMEN-RURD P PJSM, Blow down top drive and rig up to test 10-3/4"surface casing. 20:45 21:30 0.75 3,690 3,690 SURFA( CEMEN PRTS P Test 10-3/4"casing to 3000 psi for 30 minutes on chart,good test. 21:30 22:00 0.50 3,690 3,690 SURFA( CEMEN RURD P Rig down testing equipment. 22:00 23:00 1.00 3,690 3,690 SURFA( CEMEN SLPC P Slip and cut drilling line, cut 85'of drilling line. 23:00 23:30 0.50 3,690 3,690 SURFA( CEMEN'SVRG P Service rig and calibrate block height as per SLB MWD rep. Page 7 of 41 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 23:30 00:00 0.50 3,690 3,782 SURFA( CEMEN-COCF P Obtain SPR's @ 3700'MD, 2975' TVD, 9.4 ppg MW.Wash down from 3690'MD to 3782'MD, pump @ 450 gpm= 1100 psi, Rot @ 60 rpm w/ 5-10K Tq. FO=46%, P/U= 124K, S/O=78K, ROT=96K. 12/13/2014 Drill out cement&shoe track, plus 20'new formation to 3936'MD. CBU&perform LOT to 13.2 ppg EMW. Displace well to 9.2 ppg LSND mud system. Drill ahead as per plan. 00:00 00:15 0.25 3,782 3,813 SURFA( CEMEN-COCF P PJSM, Cont to wash down to top of float collar to 3813'MD. Pump @ 450 gpm=1100 psi, Rot @ 60 rpm's w/5-10K Tq, FO=46%, P/U= 124K, S/O=78K, ROT=96K. 00:15 05:15 5.00 3,813 3,916 SURFA( CEMEN'DRLG P Drill out float collar,shoe track,float shoe and rat hole to 3904'MD. Pump @ 450 gpm= 1100 psi, Rot @ 60 rpm's w/5-10K Tq, FO=46%, P/U= 124K, S/O=78K, ROT=96K,WOB= 5-12K. 05:15 05:30 0.25 3,916 3,936 SURFA( CEMEN-DDRL P Drill 20'of new hole f/3916' MD to 3936'MD.TVD=2979,ADT=.17, But hrs=.17,Jar hrs= 109.07. Pump @ 450 gpm= 1100 psi, Rot @ 60 rpm's w/5-10K Tq, FO=53%, P/U= 126K, S/O=74K, ROT=96K,WOB= 15K., ECD=9.95 ppg EWM. 05:30 06:15 0.75 3,936 3,936 SURFA( CEMEN-CIRC P CBU @ 450 gpm=1100 psi, FO=53%, ROT @ 40 rpm's w/5-10K Tq. 06:15 06:30 0.25 3,936 3,870 SURFA( CEMEN TRIP P PJSM, POOH f/3936'MD to 3870' MD, blow down top drive. 06:30 06:45 0.25 3,870 3,870 SURFA( CEMEN'RURD P PJSM rig up to perform FIT. 06:45 07:15 0.50 3,870 3,870 SURFA( CEMEN FIT P Perform FIT/LOT to 13.2 ppg EWM 07:15 07:30 0.25 3,870 3,870 INTRM1 DRILL RURD P Rig down testing equipment and blow down lines. 07:30 09:00 1.50 3,870 3,936 INTRM1 DRILL DISP P PJSM,displace well to 9.2 ppg LSND mud system. Pump 30 bbls of High Vis LSND followed by 9.2 ppg LSND mud. Pump @ 450 gpm=1100 psi, FCP=920 F0=42%, Rot @ 40 RPM, 8-9K Tq. P/U= 125K, S/O= 81K, ROT=98K. Obtain SPR's w/ new mud system @ 3936'MD TVD= 2979, MW=9.2 ppg.,08:55 hours. SPR's @ 3936'MD,2979'TVD, 9.2 ppg MW, 08:55 hrs. #1 @ 30=140 @ 40=170 psi #2 @ 30=130 @ 40=190 psi 09:00 12:00 3.00 3,936 4,290 INTRM1 DRILL DDRL P Drilled ahead f/3936'MD to 4290' MD, TVD=3092'.ADT=2.01, Bit hrs=2.18, Jar hrs= 111.08, P/U= 118K, S/O=84K, ROT=98K, Pump @ 675 gpm= 1800 psi. FO=55%, Rot @ 140 rpm's w/8-10K on, 5-10K off. ECD= 10.24 EMW,WOB 10-12K. Page 8 of 41 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 12:00 18:00 6.00 4,290 5,091 INTRM1 DRILL DDRL P Drilled ahead f/4290' MD to 5091' MD, TVD=3359'. ADT=3.68, Bit hrs=5.86, Jar hrs= 114.76, P/U= 114K, SIO=93K, ROT= 103K, Pump @ 700 gpm=2200 psi. F0=60%, Rot @ 160 rpm's w/8-10K on, 3-4K off. ECD= 11.07 EMW,WOB 9-13K. 18:00 00:00 6.00 5,091 5,723 INTRM1 DRILL DDRL P Drilled ahead f/5091' MD to 5723' MD, TVD=3567'.ADT=3.44, Bit hrs=9.3, Jar hrs= 118.2, P/U= 116K, S/O=96K, ROT= 104K, Pump @ 700 gpm=2450 psi. F0=60%, Rot @ 160 rpm's w/9-10K on, 3-4K off. ECD= 11.34 EMW,WOB 10-13K. SPR's @ 5651'MD, 3545'TVD, 9.2 ppg MW, 23:45 hrs. #1 @ 30=195 @ 40=250 psi #2 @ 30=190 @ 40=235 psi Kick w/Drilling CRT=99 SEC. @ 23:45 HRS. 12/14/2014 DDrill intermediate section to 5723'-5931' MD. Pack off @ 5855'MD during back ream for connection. Rack back 1 stand, establish circulation @ 5780' MD, stage up pumps&rotary.Wash&ream f/5749-5931' MD. Continue DDrilling 5931-7048. CBU 2X&TOH to 6863'MD. 00:00 01:45 1.75 5,723 5,931 INTRM1 DRILL DDRL P Drilled ahead f/5723' MD to 5931' MD, TVD=3635'.ADT= 1.34, Bit hrs= 10.64,Jar hrs= 119.54, P/U= 119K, S/O=96K, ROT= 111K, Pump @ 700 gpm=2380 psi. F0=57%, 160 rpm, 9-10K on, 5-10K off. ECD= 11.34 EMW, WOB 10-13K. Kick w/Tripping Drill CRT=85 sec @ 01:00 hrs. 01:45 06:45 5.00 5,931 5,749 INTRM1 DRILL CIRC T Pack off while back reaming for a connection @ 5855' MD. Rack back one stand to 5841'MD. No torque or drag increase, observed. Pump 1 bpm, 610 psi, 60 rpm, Tq 10K, FO 0%,work pipe f/5841-5749' MD. Lost 50 bbls trying of establish circulation. Establish circulation @ 5780'MD, staging pumps up from 21 -613 gpm,200- 1890 psi, 30-80 rpm, Tq 5-6K. Observed wellbore give back initial 50 bbls lost. 06:45 07:45 1.00 5,749 5,931 INTRM1 DRILL WASH T Wash&ream hole f/5749-5931' MD, 613 gpm, 1890 psi, 80 rpm,Tq 5-6K, FO 54%. No gain, no losses. Page 9 of 41 Time Logs Date From To Dur S.Depth E. Depth Phase Code Subcode T Comment 07:45 12:00 4.25 5,931 6,289 INTRM1 DRILL DDRL P Drilled ahead f/5931' MD to 6289' MD, TVD=3754'.ADT=2.50, Bit hrs= 13.14,Jar hrs= 122.04, P/U= 124K, S/O=96K, ROT= 110K, Pump ©700 gpm=2400 psi. FO=58%, 160 rpm, 9-10K on,4-5K off. ECD= 10.7 EMW,WOB 8-15K. SPR's @ 6118'MD, 3695'TVD, MW 9.2 ppg, 09:30 hrs. #1 @ 30=200, @ 40=220 psi #2 @ 30= 190, @ 40=240 psi 12:00 18:00 6.00 6,289 6,748 INTRM1 DRILL DDRL P DDrilling f/6289-6748'MD, 3907' TVD,ADT 4.23, Bit 17.37,Jars 126.27, PU 125K, SO 99K, ROT 112K,Tq on 11-13K, off 6-10K, ECD 10.32, FO 58%,WOB 6-10K, 160 rpm, 700 gpm, 2500 psi,gas 143 units. SPR's @ 6770'MD, 3913'ND, MW 9.2 ppg, 18:00 hrs. #1 @ 30= 195, @ 40=260 psi #2 @ 30= 185, @ 40=250 psi 18:00 21:45 3.75 6,748 7,048 INTRM1 DRILL DDRL P DDrilling f/6748-7048' MD,4006' TVD,ADT 2.86, Bit 20.23,Jars 129.13, PU 132K, SO 104K, ROT 117K,Tq on 11-12K, off 4-5K, ECD 10.38, FO 58%,WOB 6-10K, 160 rpm, 700 gpm,2525 psi,gas 194 units. 21:45 23:00 1.25 7,048 7,048 INTRM1 DRILL CIRC P CBU 2X, 700 gpm, 2525 psi, 160 rpm, Tq 8-9K. SPR's @ 7047'MD,4006'ND, MW 9.2 ppg,23:00 hrs. #1 @ 30= 180, @ 40=240 psi #2 @ 30= 170, @ 40=230 psi 23:00 23:30 0.50 7,048 7,048 INTRMI DRILL OWFF P Monitor well,static. 23:30 00:00 0.50 7,048 6,863 INTRM1 DRILL WPRT P PJSM,TOH f/7048'-6863'MD, PU 130K, SO 101K 12/15/2014 Pump out of hole f/7048-3875'MD(surface shoe). Remove trip nipple&install RCD. Function test MPD equipment.TIH to 7048'MD, CBU&activate reamer. DDrill ahead utilizing MPD&under reaming the hole to 7232'MD. 00:00 00:15 0.25 6,863 6,572 INTRM1 DRILL WPRT P PJSM,TOH on elevators f/ 6863-6572'MD, hole not taking the correct amount of fluid. 00:15 00:45 0.50 6,572 7,048 INTRM1 DRILL WPRT T TIH f/6572-7048'MD. 00:45 01:30 0.75 7,048 7,048 INTRMI DRILL CIRC T CBU,650 gpm, 2300 psi, FO 57%, 80 rpm, Tq 6-7K, PU 130K, SO 101K. 01:30 01:45 0.25 7,048 7,048 INTRMI DRILL OWFF T Monitor well, static, 01:45 06:15 4.50 7,048 4,624 INTRM1 DRILL WPRT P PJSM, pump out of hole f/ 7048-4624'MD,2 bpm, 175 psi, FO 25%. 06:15 06:45 0.50 4,624 4,624 INTRM1 DRILL CIRC P CBU @ 650 gpm,2125 psi, FO 57%, 60 rpm,Tq 5-6K, significant increase in cuttings at BU. Page 10 of 41 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 06:45 08:15 1.50 4,624 3,875 INTRM1 DRILL WPRT P PJSM, pump out of hole f/ 4624-3875'MD,2 bpm, 180-250 psi, FO 20%, PU 100K, SO 75, ROT 93K, calculated fill for entire trip 25.5, actual 39.56 bbls. 08:15 09:00 0.75 3,875 3,875 INTRM1 DRILL CIRC P CBU 2X @ 550 gpm, 1600 psi, FO 50%, 35 rpm,Tq 5-6K, significant increase in cuttings at BU. 09:00 09:15 0.25 3,875 3,875 INTRM1 DRILL RURD P Blow down TD. 09:15 09:30 0.25 3,875 3,875 INTRM1 DRILL OWFF P Monitor well, static. PJSM on removing trip nipple/installing RCD. 09:30 13:30 4.00 3,875 3,875 INTRM1 DRILL SEQP P Remove trip nipple&install RCD. 13:30 15:30 2.00 3,875 3,875 INTRM1 DRILL SEQP P PJSM, function test MPD RCD, chokes,&equipment. 15:30 17:00 1.50 3,875 3,904 INTRM1 DRILL DHEQ P PJSM,function under reamer and pull test at shoe as per SLB rep. 17:00 19:45 2.75 3,904 6,866 INTRM1 DRILL WPRT P PJSM,TIH f/3904-6866'MD, calculated displacement 22.5,actual 20.15 bbls. 19:45 20:15 0.50 6,866 7,048 INTRM1 DRILL REAM P Wash down f/6866-7048'MD,450 gpm, 1300 psi, 60 rpm, Tq 6-7K. 20:15 21:00 0.75 7,048 7,048 INTRM1 DRILL CIRC P CBU©700 gpm, 2550 psi, 60 rpm, Tq 6-7K, PU 115K, SO 105K, ROT 112K. 21:00 21:15 0.25 7,048 7,048 INTRM1 DRILL CIRC P Open under reamer&establish parameters as per SLB rep. 21:15 00:00 2.75 7,048 7,232 INTRM1 DRILL DDRL P DDrilling f/7408-7232' MD,4066' TVD,ADT 1.98, Bit 22.21,Jars 131.11, PU 132K, SO 104K, ROT 117K,Tq on 10-15K,off 6-7K, ECD 10.37, FO 84%,WOB 10-15K, 160 rpm, 750 gpm,2550 psi,gas 121 units. 12/16/2014 DDrill intermediate section, utilizing MPD while under reaming hole f/7232-8850'MD. 00:00 06:00 6.00 7,232 7,632 INTRM1 DRILL DDRL P DDrilling f/7232-7632'MD,4202' TVD,ADT 4.13, Bit 26.34,Jars 135.24, PU 150K, SO 92K, ROT 118K,Tq on 13-14K, off 8K, ECD 10.47, FO 84%,WOB 5-10K, 160 rpm, 750 gpm, 2700 psi, gas 236 units. 06:00 12:00 6.00 7,632 8,067 INTRM1 DRILL DDRL P DDrilling f/7632-8067'MD,4346' TVD,ADT 4.18, Bit 30.52,Jars 139.42, PU 150K, SO 99K, ROT 119K,Tq on 14-16K, off 9K, ECD 10.64, FO 84%,WOB 5-10K, 160 rpm, 750 gpm,2900 psi,gas 209 units. SPR's @ 7697'MD,4224'TVD, MW 9.2 ppg, 07:00 hrs. #1 @30= 183, @40=241 psi #2 @ 30=209, @ 40=243 psi Spill Drill CRT= 153 sec @ 09:00 hrs. Page 11 of 41 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 12:00 18:00 6.00 8,067 8,438 INTRM1 DRILL DDRL P DDrilling f/8067-8438' MD, 4468' TVD,ADT 3.62, Bit 34.14,Jars 143.04, PU 156K, SO 97K, ROT 118K, Tq on 13-16K, off 8-10K, ECD 10.44, FO 86%,WOB 10-15K, 160 rpm, 750 gpm, 2850 psi,gas 270 units. SPR's @ 8153'MD,4367'TVD, MW 9.2 ppg, 14:30 hrs. #1 @30= 153, @40=222psi #2 @ 30= 174, @ 40=244 psi 18:00 00:00 6.00 8,438 8,850 INTRM1 DRILL DDRL P DDrilling f/8438-8850' MD, 4604' TVD,ADT 4.21, Bit 38.35,Jars 147.25, PU 156K, SO 97K, ROT 118K, Tq on 12-14K, off 8-9K, ECD 10.43, FO 85%,WOB 10-15K, 160 rpm, 750 gpm, 2700 psi, gas 145 units. SPR's @ 8804'MD,4588'TVD, MW 9.2 ppg, 23:15 hrs. #1 @ 30=248, @ 40=295 psi #2 @ 30=255, @ 40=305 psi Spill Drill CRT= 120 sec @ 21:00 hrs. 12/17/2014 DDrill intermediate section, utilizing MPD while under reaming hole f/8850-10579' MD. 00:00 06:00 6.00 8,850 9,316 INTRM1 DRILL DDRL P DDrilling f/8850-9316' MD,4761' TVD,ADT 4.33, Bit 42.68, Jars 151.58, PU 165K, SO 99K, ROT 121K, Tq on 15-16K, off 7-8K, ECD 10.46, FO 84%, WOB 9-10K, 160 rpm, 750 gpm, 2620 psi, gas 247 units. Kick w/Drilling CRT=89 sec @ 04:30 hrs. 06:00 12:00 6.00 9,316 9,743 INTRM1 DRILL DDRL P DDrilling f/9316-9743' MD, 4901' TVD, ADT 4.55, Bit 47.23, Jars 156.13, PU 160K, SO 100K, ROT 120K, Tq on 14-16K, off 4-5K, ECD 10.40, FO 86%,WOB 10-15K, 160 rpm, 750 gpm, 3100 psi, gas 207 units. SPR's @ 9463'MD, 4809'TVD, MW 9.2+ppg, 07:30 hrs. #1 @ 30=249, @ 40=304 psi #2 @ 30=248, @ 40=329 psi 12:00 18:00 6.00 9,743 10,155 INTRM1 DRILL DDRL P DDrilling f/9743-10155'MD, 5023' TVD, ADT 4.18, Bit 51.41,Jars 160.31, PU 170K, SO 108K, ROT 127K, Tq on 12-15K, off 8-9K, ECD 10.28, FO 83%,WOB 5-10K, 160 rpm, 750 gpm, 3075 psi, gas 205 units. SPR's @ 9928' MD,4961'TVD, MW 9.2 ppg, 14:30 hrs. #1 @ 30=242, @ 40=293 psi #2 @ 30=235, @ 40=295 psi Page 12 of 41 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 18:00 00:00 6.00 10,155 10,579 INTRM1 DRILL DDRL P DDrilling f/10155-10579'MD, 5175' TVD,ADT 4.72, Bit 56.13,Jars 165.03, PU 173K, SO 105K, ROT 127K,Tq on 12-16K,off 10-11K, ECD 10.34, FO 84%,WOB 6-10K, 160 rpm, 750 gpm,3150 psi, Max gas 922 units. SPR's @ 10486'MD, 5144'TVD, MW 9.3 ppg, 22:00 hrs. #1 @30=246, @ 40=320 psi #2 @ 30=239, ©40=320 psi 12/18/2014 DDrill intermediate section, utilizing MPD while under reaming hole f/10579-11708'MD. Observe 300 psi drop.Attempt to shut reamer several times. Test surface equipment to 2000 psi, all good. Pump out of hole 11708'-10833' MD, finding washout in DP. C/O jt&test string utilizing MPD,good. CBU to clean up wellbore. 00:00 06:00 6.00 10,579 11,050 INTRM1 DRILL DDRL P DDrilling f/10579-11050'MD,5335' TVD,ADT 4.32, Bit 60.45,Jars 169.35, PU 180K, SO 110K, ROT 136K,Tq on 18-19K, off 15K, ECD 10.31, FO 85%,WOB 10K, 160 rpm, 750 gpm, 3000 psi, Max gas 246 units. SPR's @ 10956'MD, 5303'TVD, MW 9.3 ppg, 04:30 hrs. #1 @ 30=280, @ 40=335 psi #2©30=253, @ 40=324 psi Fire Drill CRT= 138 sec @ 03:45 hrs. 06:00 12:00 6.00 11,050 11,580 INTRM1 DRILL DDRL P DDrilling f/11050-11580'MD,5509' TVD,ADT 3.96, Bit 64.41,Jars 173.31, PU 175K, SO 112K, ROT 138K,Tq on 17-18K, off 15K, ECD 10.45, FO 83%,WOB 5-10K, 160 rpm, 750 gpm, 3090 psi, Max gas 345 units. 12:00 13:30 1.50 11,580 11,708 INTRM1 DRILL DDRL P DDrilling f/11580-11708'MD, 5551' TVD,ADT 1.29, Bit 65.70,Jars 174.6, PU 185K, SO 112K, ROT 134K,Tq on 15-20K,off 10-11K, ECD 10.22, FO 81%,WOB 5-10K, 160 rpm, 750 gpm,2825 psi, Max gas 640 units. 13:30 15:15 1.75 11,708 11,708 INTRM1 DRILL CIRC T Observe pressure loss f/3080-2730 psi.Attempt to close reamer 3X with multiple pump rates&no success. 15:15 15:30 0.25 11,708 11,708 INTRM1 DRILL SEQP T Pressure test surface equipment to 2000 psi, all good. 15:30 16:00 0.50 11,708 11,708 INTRM1 DRILL CIRC T Attempt to close reamer 2X with multiple pump rates¬ able to confirm closure with wash out psi loss. 16:00 16:45 0.75 11,708 11,708 INTRM1 DRILL OWFF T Perform finger print test to show 9.4 ppg MW was adequate. 16:45 18:15 1.50 11,708 11,708 INTRM1 DRILL CIRC T Weight up to 9.6 ppg for.2 ppg trip margin,450 gpm, 1015 psi, PU 175K, SO 114K. Page 13 of 41 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 18:15 19:30 1.25 11,708 11,708 INTRM1 DRILL OWFF T Monitor well, slight flow decreasing. Perform exhale test to confirm flow steadly decreasing to a trickle. 19:30 21:45 2.25 11,708 10,833 INTRM1 DRILL WPRT T PJSM, pump out of hole f/ 11708-10833' MD,2 bpm, 250 psi, 600 fph, PU 175K, SO 110K. Calculated fill 7.5, actual 9.8 bbls. SPR's @ 111612'MD, 5519'TVD, MW 9.65 ppg, 19:30 hrs. #1 @ 30=250, @ 40=320 psi #2 @30=250, @40=310 psi 21:45 22:00 0.25 10,833 10,833 INTRM1 DRILL PULD T Washout found&joint changed out. Pressure test w/MPD holding 200 psi on back side to ensure no more washouts in string, good. 22:00 00:00 2.00 10,833 10,833 INTRM1 DRILL CIRC T CBU @ 700 gpm, 3150 psi, 90 rpm, Tq 10-14K, PU 175K, SO 132K ROT 135K. Fire Drill CRT=87 sec @ 23:30 hrs. 12/19/2014 Change out RCD.TIH to bottom&activate reamer. DDrill intermediate section, utilizing MPD while under reaming hole 11708-13007'MD. 00:00 01:45 1.75 10,833 10,833 INTRM1 DRILL SEQP T PJSM,change out RCD on MPD system. 01:45 02:45 1.00 10,833 11,708 INTRM1 DRILL WPRT T PJSM, TIH f/10833-11708' MD, calculated displacement 6.75, actual 5.92 bbls. 02:45 03:00 0.25 11,708 11,708 INTRM1 DRILL CIRC T Stage up pumps to establish MPD parameters. 03:00 06:00 3.00 11,708 11,893 INTRM1 DRILL DDRL P DDrilling f/11708-11893'MD, 5612' TVD,ADT 1.88, Bit 67.58,Jars 176.48, PU 180K, SO 107K, ROT 139K,Tq on 19-24K, off 14-16K, ECD 10.7, FO 84%,WOB 5-14K, 160 rpm,735 gpm,3325 psi, Max gas 275 units. SPR's @ 11800' MD, 5581'TVD, MW 9.6 ppg, 04:15 hrs. #1 @ 30=325, @ 40=389 psi #2 @ 30=336, @ 40=409 psi 06:00 12:00 6.00 11,893 12,262 INTRM1 DRILL DDRL P DDrilling f/11893-12262'MD, 5737' TVD,ADT 4.17, Bit 71.75,Jars 180.65, PU 194K, SO 108K, ROT 139K,Tq on 18-22K,off 13-14K, ECD 10.52, FO 86%,WOB 7K, 160 rpm, 735 gpm, 3250 psi, Max gas 667 units. 12:00 18:00 6.00 12,262 12,656 INTRM1 DRILL DDRL P DDrilling f/12262-12656'MD,5867' TVD,ADT 4.0, Bit 75.75,Jars 184.65, PU 200K, SO 107K, ROT 139K,Tq on 19-20K,off 11-12K, ECD 10.42, FO 86%,WOB 7-11K, 160 rpm, 735 gpm, 3325 psi, Max gas 426 units. SPR's @ 12354'MD, 5767'TVD, MW 9.6 ppg, 14:00 hrs. #1 @ 30=320, @ 40=402 psi #2 @ 30=307, @ 40=398 psi I Page 14 of 41 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 18:00 00:00 6.00 12,656 13,007 INTRM1 DRILL DDRL P DDrilling f/12656-13007'MD, 5982' TVD,ADT 3.64, Bit 79.39,Jars 188.29, PU 205K, SO 110K, ROT 145K,Tq on 19-23K,off 14-15K, ECD 10.5, FO 86%,WOB 5-10K, 160 rpm, 735 gpm,3400 psi, Max gas 305 units. SPR's @ 12912'MD, 5951'TVD, MW 9.6 ppg,22:30 hrs. #1 @ 30=255, @ 40=354 psi #2 @ 30=273, @ 40=349 psi 12/20/2014 DDrill intermediate section, utilizing MPD while under reaming hole,to TD 13470'MD,6093'TVD. CBU 3X. Attempt to finger print well, CBU, &attempt to finger print again. Chokes not functioning properly.While circulating before weight up(9.9-10.2ppg),well bore packed off&torqued up.Work pipe to find free spot& reestablish circulation, staging the pumps back up to full rate. Finish CBU. 00:00 06:00 6.00 13,007 13,284 INTRM1 DRILL DDRL P DDrilling f/13007-13284'MD,6060' TVD,ADT 5.71, Bit 85.1, Jars 194.0, PU 225K, SO 97K, ROT 145K, Tq on 20K, off 15K, ECD 10.62, FO 85%, WOB 5-12K, 160 rpm, 730 gpm, 3500 psi, Max gas 4880 units. 06:00 10:30 4.50 13,284 13,430 INTRM1 DRILL DDRL P DDrilling f/13284-13430'MD,6086' TVD,ADT 3.69, Bit 88.79,Jars 197.69, PU 225K, SO 97K, ROT 145K,Tq on 20K, off 17K, ECD 10.61, FO 61%,WOB 5-13K, 160 rpm, 730 gpm,3600 psi, Max gas 10000 units. 10:30 12:00 1.50 13,430 13,430 INTRM1 DRILL CIRC T CBU for gas cut mud @ 730 gpm, 3500 psi, 100 rpm,Tq 17K, 12:00 13:00 1.00 13,430 13,470 INTRMI DRILL DDRL P DDrilling f/13430-13470'MD,6093' TVD,ADT 1.36, Bit 90.15,Jars 199.05, PU 225K, SO 97K, ROT 146K,Tq on 20-21K, off 16K, ECD 10.7, FO 81%,WOB 5-10K, 160 rpm, 730 gpm, 3650 psi, Max gas 10000 units. TD© 13470' MD, 6093'TVD 13:00 13:45 0.75 13,470 13,470 INTRM1 CASING CIRC P Circulate @ 730 gpm, 3650 psi, 80 rpm, 15-16k Tq, cycle pumps for MWD surveys. 13:45 14:00 0.25 13,470 13,470 INTRM1 CASING CIRC P Cylcle pump rates to close under reamer. 14:00 14:30 0.50 13,470 13,470 INTRM1 CASING CIRC P SPR's @ 13470'MD,6093'TVD, MW 9.7 ppg, 14:00 hrs. #1 @30=261, @40=360psi #2 @ 30=260, @ 40=340 psi 14:30 17:15 2.75 13,470 13,470 INTRM1 CASING CIRC P CBU 3X @ 675 gpm,3350 psi, 105 rpm, Tq 14-15K 17:15 18:00 0.75 13,470 13,470 INTRM1 CASING OWFF T Attempt to finger print well bore. MPD chokes not functioning properly. 18:00 20:00 2.00 13,470 13,470 INTRM1 CASING CIRC P CBU 2X @ 675 gpm, 3350 psi, 105 rpm, Tq 16-18K, 20:00 21:00 1.00 13,470 13,470 INTRM1 CASING OWFF P Attempt to finger print well bore in manual mode w/MPD chokes. Page 15 of 41 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 21:00 00:00 3.00 13,470 13,433 INTRM1 CASING CIRC T Start circulating @ 675 gpm, 3350 psi, 105 rpm, Tq 16-18K. Pack off& torque up while reciprocating pipe at 13455'.Work pipe to find free spot© 13433' MD. Reestablish circulation staging up pumps f/100-640 gpm, 60 rpm, Tq 18-19K. 12/21/2014 Finish staging up parameters from pack off.Weight up mud system f/9.9-10.2 ppg,w/MPD schedule @13470'MD. OWFF,flow observed decreasing then maintaining same rate. Begin to CBU&hole packed off. Work pipe¶meters to reestablish circulation. CBU&observe gas entrained in mud on BU. Circulate till hole clean.Attempt to pump out of hole and encounter pack off.Work pipe¶meters to reestablish circulation f/13470-13265'MD. Lubricate out of hole f/13265-12637'MD. 00:00 00:30 0.50 13,433 13,470 INTRM1 CASING CIRC T Finish staging up pumps to 640 gpm, 3150 psi, PU 150K, SO 135K, 90 rpm,Tq 18-20K. 00:30 03:45 3.25 13,470 13,470 INTRM1 CASING CIRC T Pump 30 bbls LCM pill&weight up to 10.2 ppg @ 640 gpm, 3050 psi, 90 rpm,Tq 15-18K,following MPD weight up schedule. 03:45 04:15 0.50 13,470 13,470 INTRMI CASING CIRC T SPR's @ 13470'MD, 6093'TVD, MW 10.2 ppg, 04:30 hrs. #1 @ 30=290, @ 40=390 psi #2 @ 30=295, @ 40=400 psi 04:15 04:45 0.50 13,470 13,470 INTRMI CASING RURD T Blow down the top drive. 04:45 05:45 1.00 13,470 13,470 INTRM1 CASING OWFF T Monitor well, observe flow. Perform exhale test. Observe initial decrease in flow,then level off&stay the same rate @ 4 bph. 05:45 11:30 5.75 13,470 13,265 INTRM1 CASING CIRC T Begin to CBU staging up pumps, pack off @ 13440'MD.Work pipe f/13440'-13265'MD. Try varying rates &depths to find free spot, 25-400 gpm, 60-100 rpm,Tq 17-25K. 11:30 15:45 4.25 13,265 13,265 INTRM1 CASING CIRC T Establish circulation staging up pumps f/25-400 gpm, 250-1425 psi, 40-60 rpm,Tq 16-18K. Observe entrained gas back at BU,continue circulating till clean. Table Top Review of Rig Evac Drill. 15:45 17:15 1.50 13,265 13,265 INTRM1 CASING CIRC T Attempt to pull up w/360 gpm, 1250 psi, 50 rpm,Tq 18-20K, pack off& torque up.Work pipe to find free spot _ with varying parameters. 17:15 22:30 5.25 13,265 12,930 INTRM1 CASING TRIP T Pump out of hole from 13265-12930' MD. PU 250-285k, 3-6 spm, 200-350 psi,70-150 fph. 22:30 00:00 1.50 12,930 12,637 INTRM1 CASING TRIP T Continue to pump out of hole f/ 12930'-12637' MD. Observe decrease in PU weight f/265-225K. Increased parameters as hole conditions allowed 70-200 fph, 3-8 spm, 390-280 psi, FO 2%. Calculated fill 3.75, actual 6.05 bbls. Total losses for 24 hrs 33bbls Page 16 of 41 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 12/22/2014 24 hr Summary Pump OOH 12637'-12081'MD&CBU.Weight up mud system to 10.6 ppg as per MPD schedule. CBU 3X to clean hole. OWFF.TOH using MPD f/12081'- 10080'MD. Observe overpull for 3 stands&incorrect hole fill. TIH 10080'-10304'MD&CBU to clean up hole.TOH f/10304'-8436'MD. 00:00 04:00 4.00 12,637 12,081 INTRM1 CASING TRIP T Pump out of hole f/12630'-12081' MD,4 spm, 17 gpm,200 psi, 150-200 fph, PU 235-210K, SO 100K 04:00 09:45 5.75 12,081 12,081 INTRM1 CASING CIRC T Weight up mud system f/10.4-10.6 ppg, .5-5 bpm,200-625 psi,60 rpm, Tq 15-20k, Max gas @ BU 8100 units. 09:45 14:45 5.00 12,081 12,081 INTRM1 CASING CIRC T CBU 3X @ 408 gpm, 1450 psi, 60-100 rpm,Tq 15-18k, PU 210K, SO 98K, ROT 135K, 11.26 ECD. 14:45 15:30 0.75 12,081 12,081 INTRM1 CASING OWFF T Monitor well 30 min. 15:30 19:15 3.75 12,081 10,080 INTRM1 CASING TRIP P PJSM, line up&TOH w/MPD 12031'-10080'MD. Observe increase overpull&incorrect fill on last 3 stands. 19:15 19:45 0.50 10,080 10,304 INTRM1 CASING TRIP T PJSM,TIH f/10080-10304' MD. 19:45 21:45 2.00 10,304 10,304 INTRM1 CASING CIRC T CBU @ 300 gpm, 900 psi, 90 rpm, Tq 13-14K, PU 131K, SO 126K, ROT 130K. 21:45 22:00 0.25 10,304 10,304 INTRM1 CASING OWFF T Monitor well, observe flow decrease to static. 22:00 00:00 2.00 10,304 8,436 INTRM1 CASING TRIP P PJSM,TOH w/MPD 10304'-8436' MD, PU 165K, SO 89K, calculated fill 26.25, actual 43.05 bbls. Total losses 30 bbls for 24 hrs. 12/23/2014 TOH using MPD to the shoe. CBU inside surface shoe&OWFF. TOH to HWDP. Remove RCD&install trip nipple. Rack back HWDP&L/D BHA 3. CIO upper rams to 7 5/8"rams. Pull wear bushing. Flush stack. Rig up to test.Test BOPE 00:00 05:45 5.75 8,436 3,875 INTRM1 CASING TRIP P Strip OOH f/8436'MD t/3875'MD w/MPD per trip schedule. PU 160K 05:45 07:00 1.25 3,875 3,875 INTRM1 CASING CIRC P CBU @ shoe. Stage pumps to 400gpm. Rot @ 60 rpm w/5K tq 07:00 08:30 1.50 3,875 3,875 INTRM1 CASING OWFF P Blow do TD. Monitor well thru IA. valve. 08:30 10:45 2.25 3,875 787 INTRM1 CASING TRIP P Strip OOH f/3875'MD t/787'MD w/MPD per trip schedule. Cal disp=91.5 bbls.Act disp=146 bbls. 10:45 11:15 0.50 787 787 INTRM1 CASING RURD P Clean rig floor. Blow down MPD lines and manifold. 11:15 12:00 0.75 787 787 INTRM1 CASING OWFF P Drain stack. Monitor well. Prep to remove MPD bearing assy. 12:00 13:45 1.75 787 787 INTRM1 CASING SEQP P Remove MPD bearing assy. and install trip nipple 13:45 14:30 0.75 787 150 INTRM1 CASING TRIP P TOH w/HWDP 14:30 16:30 2.00 150 0 INTRM1 CASING PULD P Lay down BHA#3 as per SLB. Cal disp=14.66 bbls Act disp=14.28 bbls 16:30 17:15 0.75 0 0 INTRM1 CASING RURD P Clear rig floor of drilling tools. 17:15 18:15 1.00 0 0 INTRM1 CASING SLPC P Slip and cut 78'drilling line Page 17 of 41 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 18:15 18:45 0.50 0 0 INTRM1 CASING SVRG P 'Service rig. 18:45 19:30 0.75 0 0 INTRM1 CASING BOPE P Rig down BOP scaffold to gain _access to upper ram doors. 19:30 21:00 1.50 0 0 INTRM1 CASING BOPE P Change upper VBR's to 7 5/8"solid body rams. 21:00 21:45 0.75 0 0 INTRM1 CASING RURD P Pull wear bushing. Bushing packed _with mud 21:45 22:30 0.75 0 0 INTRM1 CASING WWWH P Flush well head and BOPE. 22:30 23:15 0.75 0 0 INTRM1 WHDBO RURD P Rig up to test BOPE 23:15 00:00 0.75 0 0 INTRM1 WHDBO BOPE P Test annular and lower VBR's w/4" test joint. 253/3500 psi for 5 min's each.Witness waived by AOGCC Bob Noble 12/23/14 @ 14:32 hrs. 12/24/2014 Complete BOPE test. Make hanger dummy run . Rig up to run 7 5/8"casing. Run 7 5/8"casing to 3890' MD. CBU. Continue to run 7 5/8"casing to 5705' MD 00:00 06:30 6.50 0 0 INTRM1 WHDBO BOPE P Test BOPE with 4"&7.625"test joints. Test to 250 psi low/3500 psi high. 5 mins each/charted. Test#1 W/4"TJ, annular preventer, LPR's. Test#1 with 7 5/8"TJ,TPR's, solid body casing rams, annular.Also choke valves 1,12,13,14&manual kill line valve, Test#2 upper IBOP, HCR kill, choke valves 9,11. Test#3, Lower IBOP, choke valves 5,8,10. Test#4 Dart valve, choke valves 4,6,7 Test#5 Floor valve, choke valve 2.Test#6 HCR choke,4"kill line, demco valve, 5"dart. Test#7 Manual choke valve, HCR kil, 5"floor valve. Test#8 Annular preventer.Test#9 Blind rams, choke valve 3. Accumulator test: System pressure= 3000 psi Pressure after closure= 1850 psi 200 psi attained=43 secs. Full system pressure=176 secs. 5 nitrogen bottles average=2075 psi. Test gas alarms, pit level alarms high and low levels. 06:30 07:30 1.00 0 0 INTRM1 WHDBO RURD P Rig down test equipment. blow down chokes and kill lines. 07:30 08:00 0.50 0 0 INTRM1 CASING RURD P Conduct dummy run with Cameron well head hand. Measure 26.00 feet from rig floor to top of hanger. L/D LJ. leave hanger on rig floor. 08:00 09:00 1.00 0 0 INTRM1 CASING RURD P Pick up/stage casing running equipment to rig floor from outside via the beaver slide, Volant tools. 09:00 09:30 0.50 0 0 INTRM1 CASING SFTY P Pre job safety meeting: Rigging up casing running equipment. Discussed pinch points, no mans land, high pressure, and well control while running casing. Page 18 of 41 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 09:30 10:30 1.00 0 0 INTRM1 CASING RURD P Rig up Volant casing running equipment. 10:30 11:00 0.50 0 0 INTRM1 CASING SFTY P Pre job safety meeting: Running casing. Discussed make up torque, Baker Loc joints,stop the job authority. 11:00 12:00 1.00 0 222 INTRM1 CASING PUTB P Run 4 joints of 29.7#L-80 7.625" HYD 563 casing. Crew change. 12:00 19:45 7.75 222 3,890 INTRM1 CASING PUTB P Run 29.7#L-80 7.625"HYD 563 casing f/222' MD t/3890'MD as per trip schedule. 19:45 20:45 1.00 3,890 3,890 INTRM1 CASING CIRC P CBU. Stage pumps f/2 bpm t/4 bpm, 200 psi. PU 110K, SO 95K. 20:45 00:00 3.25 3,890 5,705 INTRM1 CASING PUTB P Run 29.7#L-80 7.625"HYD 563 casing f/3890' MD t/5705' MD as per trip schedule. Cal disp=62.2 bbls. Act disp=54 bbls 12/25/2014 Run 7 5/8"csg to 6680'MD.Attempt to establish circ. Run 7 5/8"csg to 7017'MD.Attempt to establish circ. Run 7 5/8"csg to 12768'MD 00:00 02:30 2.50 5,705 6,680 INTRM1 CASING PUTB P Run 29.7#L-80 7.625"HYD 563 casing(/5705'MD t/6680'MD as per trip schedule.Losing returns after 6200'MD. PU 155K SO 100K 02:30 03:00 0.50 6,680 6,680 INTRM1 CASING CIRC P Attempt to break circ. @.5 bpm, 200 psi. Stage up to 1 bpm,200 psi. w/no returns.27 bbls lost to hole. 03:00 04:00 1.00 6,680 7,017 INTRM1 CASING PUTB P Run 29.7#L-80 7.625"HYD 563 casing f/6680'MD t/7017'MD as per trip schedule. 04:00 06:30 2.50 7,017 7,017 INTRM1 CASING CIRC P Attempt to establish circ. Rotate and reciprocate pipe. 15 rpm, 15K tq, PU 130K, SO 125K, Rot 127K. Partial returns on up stroke. Lost 220 bbls to hole. 06:30 12:00 5.50 7,017 8,850 INTRM1 CASING PUTB P Run 29.7#L-80 7.625"HYD 563 casing f/7017' MD t/8850' MD as per trip schedule. 12:00 18:00 6.00 8,850 11,252 INTRM1 CASING PUTB P Run 29.7#L-80 7.625"HYD 563 casing f/8850' MD t/11252' MD as per trip schedule. 18:00 00:00 6.00 11,252 12,768 INTRM1 CASING PUTB P Run 29.7#L-80 7.625"HYD 563 casing f/11252'MD t/12768' MD as per trip schedule. Mud loss for the day=777 bbls. 12/26/2014 Run 7 5/8"csg to 13220'MD. Lost down wt.Attempt to establish circ.and rotation. No go Run 7 5/8"csg to 13460'MD.Land hanger Attempt to establish circ. Rig dn. CRT. Rig up cmt head.Attempt to repair leak on cmt. head.Wait on replacement cmt,. head manifold. Perform first stage cmt.ob. 00:00 02:00 2.00 12,768 13,220 INTRM1 CASING PUTB P Run 29.7#L-80 7.625"HYD 563 casing f/12768' MD t/13220'MD as per trip schedule. 02:00 03:00 1.00 13,220 13,220 INTRM1 CASING CIRC P Lost slack off wt.Attempt to circ. Packing off and unable to establish circ.Attempt to rotate pipe.Work max of 25K tq. Unable to rotate. Work pipe. Pipe broke over @ 325 K PU. Page 19 of 41 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 03:00 05:30 2.50 13,220 13,434 INTRM1 CASING PUTB P Run 29.7#L-80 7.625" HYD 563 casing f/13220' MD t/13434' MD @ 40 to 200 fph. 70-100K SO wt. 05:30 06:00 0.50 13,434 13,460 INTRM1 CASING HOSO P Make up hanger and landing jt. Land csg. SO 100K. 06:00 12:00 6.00 13,460 13,460 INTRM1 CEMEN-CIRC P Break circ. @ .5 bpm.400 psi. Slight returns. Stage up pump to 2 bpm, 420 psi. Hole packing off. Reduce rate to.5 bpm. Flow show @ 2%. Lost 380 bbls. 12:00 15:00 3.00 13,460 13,460 INTRM1 CEMEN-CIRC P Continue to attempt to establish circ. Reciprocate pipe up to 335K. Hole became sticky. 15K of TD wt. required to land csg. Stage pump up to 1 bpm, 1000 psi. Bleed off and continue to work pipe to 300K PU wt. Land csg. 15:00 16:15 1.25 13,460 13,460 INTRM1 CEMEN-RURD P Rig down Volant CRT. MU Halliburton cmt head. 16:15 19:45 3.50 13,460 13,460 INTRM1 CEMEN-CIRC T Attempt to establish circ. 1.5 bpm, 1000 psi. Manifold on cmt head leaking. Remove manifold and attempt to repair. Still leaking. Wait on replacement manifold. Rig up circ. hose and attempt to establish circ. 1.5 bpm, 1070 psi. 19:45 20:30 0.75 13,460 13,460 INTRM1 CEMEN-RURD T Rig down circ. hose Install replacement manifold on cmt. head. 20:30 22:45 2.25 13,460 13,460 INTRM1 CEMEN CMNT P Perform first stage cement job as per program. Pump 5 bbls. water. Test lines to 4000 psi. Check low and high pressure trips. Batch mix 41 bbls. 15.8 ppg GASBLOK cmt. slurry. Pump 20 bbls CW100 followed by 20 bbls Mudpush II. Drop bypass plug. Load shut off plug into cmt head. Pump 41 bbls 15.8 ppg Class G GASBLOK cmt. Drop shut off plug. Pump 10 bbls water. 22:45 00:00 1.25 13,460 13,460 INTRM1 CEMEN-CMNT P Displace cmt w/10.7 ppg mud. 2 bpm, 1370 psi. Stage up to 3.5 bpm 1115 psi. Total losses to the formation for the day=873 bbls. 12/27/2014 Complete first stage cmt.job. Open ES cementer. Circ. OWFF. Perform second stage cmt.job.Set and test packoff.Rig up to lay down DP. Lay down 5" DP. Page 20 of 41 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 00:00 01:45 1.75 13,460 13,460 INTRM1 CEMEN-CMNT P Displace cmt w/10.7 ppg mud.. Stage up pump f/3.5 bpm , 1125 psi t/5 bpm 1270 psi. Slight returns beginning @ 4.5 bpm. Slow rate to 3 bpm when cmt @ shoe. Pumped max 6000 stks. Did not bump. Consult w/drilling engineer. Decision made to pump additional 3.1 bbls. Bump plug 0 6023 stks. Pressure up 500 psi over FCP to 1600 psi.and hold for 500 min. Bleed off pressure and check floats. Good. CIP 0 01:34 hrs 01:45 03:30 1.75 13,460 13,460 INTRM1 CEMEN-CIRCT Pressure up and open ES cementer @ 2800 psi. Establish circ @ 3 bpm, 500 psi.w/2%FO. Stage pump up to 4 bpm, 500 psi. Pump 400 bbls. Lost 330 bbls to formation 03:30 08:00 4.50 13,460 13,460 INTRM1 CEMEN-OWFF T Bleed off 280 psi. Observed flow. Monitor flow back. Steadily decreasing flow. Shut in 10 mins and pressure built to 140 psi. Continue to flow back. Flowed back total of 193 bbls. before well became static. 08:00 09:00 1.00 13,460 13,460 INTRM1 CEMEN-CMNT T Load closing plug into cmt head. Monitor well 09:00 10:15 1.25 13,460 13,460 INTRM1 CEMEN-CMNT T Perform second stage cement job as per program. Break circ. Pump 20 bbls 10.7 ppg mud. Pump 20 bbls CW100 followed by 20 bbls Mudpush II. Pump 37 bbls 15.8 ppg Class G cmt. Drop closing plug. Pump 10 bbls water. 10:15 12:00 1.75 13,460 13,460 INTRM1 CEMEN-CMNT T Displace cmt w/10.7 ppg mud.4 bpm, 700 psi. 12:00 13:00 1.00 13,460 13,460 INTRM1 CEMEN-CMNT T Continue to displace cmt w/10.7 ppg mud.4 bpm 750 psi. Slow pump to 3 bpm prior to bumping plug. Bump plug 0 5768 stks. Pressure up to 1900 psi to close ES cementer. Hold for 5 min. Bleed pressure, OWFF. ___ Static.CIP @ 12:35 hrs. 13:00 14:00 1.00 0 0 INTRM1 CEMEN'RURD P Blow down and rig down cmt. equip. Lay down landing jt. 14:00 16:30 2.50 0 0 INTRM1 CEMEN-WWSP P Rig up and set pack off.Test to 5000 psi.f/10 min. Sim-ops-Clear rig floor of casing and cementing tools. 16:30 18:30 2.00 0 0 INTRM1 CEMEN-RURD P Change out bell guide on TD. RU to lay down 5"DP. 18:30 22:45 4.25 0 0 INTRM1 CEMEN-PULD P Lay down 5" DP using mousehole. Sim-ops-Test MPD choke manifold 250 psi/low for 5 min.and 1800 psi/ high for 10 min. 22:45 00:00 1.25 0 0 INTRM1 CEMEN-OTHR P Unload pipeshed of 5"DP. Sim-ops-Continue to test MPD choke manifold. Lost 1328 bbls mud to the formation for the day. Page 21 of 41 Time Logs • Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 12/28/2014 24 hr Summary Lay down 5" DP. Freeze protect OA. Change upper pipe rams. Lay down 5"DP. Conduct full bi-weekly BOPE test.Test MPD equip. 00:00 01:15 1.25 0 0 INTRM1 CEMEN.PULD P PJSM. Continue to lay down 5" G-105 DP. SIMOPS:Test MPD choke manifold in cellar wtih MPD crew. 01:15 01:45 0.50 0 0 INTRM1 CEMEN'SFTY P PJSM: Freeze protection 10%by 7.625"annulus. Little Red, Peak truck driver, Mud Engineer. 01:45 02:30 0.75 0 0 INTRM1 CEMEN'FRZP P Position Little Red truck,water truck, Isotherm truck, rig up lines in cellar. 02:30 05:30 3.00 0 0 INTRM1 CEMEN-FRZP P Pressure test lines from Little Red. 3500 psi. Good. Pump freeze protection job. Pumping down OA. 171 bbls of water. ICP @% bpm=100 psi, FCP @ 3 bpm=600 psi. Followed by 100 bbls of MI Swaco Isotherm, ICP @ 3 bpm=600psi, FCP @ 3bpm=1075 psi. PJSM: SIMOPS: Change out saver subs. 05:30 06:30 1.00 0 0 INTRM1 CEMEN'FRZP P Rig down lines to Little Red. Secure well. SIMOPS: Finish changing out saver sub,grabber, bell guide to 4" DP. 06:30 09:45 3.25 0 0 INTRM1 CEMEN'BOPE P PJSM: Change out upper pipe rams from solid body 7.625"to VBR's 3% x 6". SIMOPS:Change out leaking hydraulic line on top drive. 0A=375 psi @09:00 hrs. 09:45 12:00 2.25 0 0 INTRM1 CEMEN-PULD P Continue to lay down 5"DP.via mouse hole. 12:00 12:30 0.50 0 0 INTRM1 CEMEN SFTY P PJSM for testing BOPE 12:30 14:00 1.50 0 0 INTRM1 WHDBO RURD P Rig up BOP test equip. Page 22 of 41 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 14:00 22:00 8.00 0 0 INTRM1 WHDBO BOPE P Test BOPE w/4"test jt. 250/3500 psi. 5 min. ea.#1 Upper pipe rams, CV's 1,12,13,14, manual kill line valve.#2 Upper IBOP, Kill line HCR, CV's 9, 11.#3 Lower IBOP, CV's 5,8,10.#4 Dart valve, CV's 4,6,7.#5 Floor safety valve, CV 2.#6 Choke line HCR,4" kill line Demco valve,#7 Choke line manual valve.#8 Annular preventer.#9 Lower pipe rams.#10 Blind rams. Change out test jt.to 3 1./2". Test upper and lower pipe rams and annular to 250/3500 psi for 5 min ea. Change out test jt to 4 1/2". Test upper and lower pipe rams and annular to 250/3500 psi for 5 min ea. Perform draw down on manual and hyd. chokes. Accumulator test: System pressure= 3000 psi Pressure after closure= 1800 psi 200 psi attained=40 secs. Full system pressure=185 secs. 5 nitrogen bottles average=2100 psi. Test gas alarms, pit leve/flow show alarms high and low levels. 22:00 22:30 0.50 0 0 INTRM1 CEMEN-SFTY P PJSM on conducting MPD RCD online pressure test. 22:30 00:00 1.50 0 0 INTRM1 CEMEN.SEQP P Remove trip nipple. Set RCD test plug. Test#1 BV7, LT1, pressure sensor, RCD body. 250 psi/5 min and 1800 psi/10 min. OA=450 psi@23:45 hrs. 12/29/2014 Finish laying down 5"DP. Pick up and stand back 106 stds of 4" DP. Install trip nipple Pick up 63/4"bit MDi513 and x6 Power Drive rotary steerable assembly. 00:00 00:45 0.75 0 0 INTRM1 CEMEN-SEQP P Continue to test MPD RCD. Test#2 AV, LT2, LT3. 250 psi/5 min and 1800 psi/10 min. 00:45 01:45 1.00 0 0 INTRM1 CEMEN-RURDP Rig down test equip. Pull RCD test plug. Pull BOPE test plug. Blow down choke manifold. Change heads in iron roughneck. Blow down TD. 01:45 06:00 4.25 0 0 INTRM1 CEMEN-PULD P Lay down 5" DP using mouse hole. 06:00 07:45 1.75 0 0 INTRM1 CEMEN-RURD P Set 10" ID wear bushing. Unload pipeshed. Change out elevators to 4". PU 4" handling tools. 07:45 10:00 2.25 0 0 INTRM1 CEMEN RURD P Load and strap 4" DP in pipe shed. 10:00 12:00 2.00 0 0 INTRM1 CEMEN-PULDP Pick up and rack back in derrick 4" XT-39 DP using mouse hole. 12:00 12:15 0.25 0 0 INTRM1 CEMEN-SFTY P PJSM on picking up DP. 12:15 12:45 0.50 0 0 INTRM1 CEMEN-SVRG P Service rig. Page 23 of 41 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 12:45 20:15 7.50 0 0 INTRM1 CEMEN-PULDP Pick up and rack back in derrick 4" XT-39 DP using mouse hole. Total of 106 stds picked up. 20:15 20:30 0.25 0 0 INTRM1 CEMEN-RURD P Lay down mouse hole. Remove thread protectors from floor. 20:30 22:00 1.50 0 0 INTRM1 CEMEN-SEQP P Install trip nipple. 22:00 23:30 1.50 0 0 INTRM1 CEMEN-RURD P Mobilize BHA to rig floor. 23:30 00:00 0.50 0 0 INTRM1 CEMEN PULD PU 6 3/4"rotary steerable BHA 12/30/2014 Make up 6 3/4"rotary steerable BHA. PU 4"DP. Cut drilling line. MAD pass 11885'MD to 12856'MD. Drill ES cementer 00:00 02:00 2.00 0 157 INTRM1 CEMEN-PULD P Pick up 6 3/4"rotary steerable BHA to 157'MD 02:00 02:30 0.50 157 157 INTRM1 CEMEN"SVRG P Service rig 02:30 03:15 0.75 157 157 INTRM1 CEMEN-PULD P Load nuclear sources in LWD. 03:15 04:30 1.25 157 440 INTRM1 CEMEN-PULD P Continue to pick up 6 3/4"rotary steerable BHA 04:30 05:45 1.25 440 1,575 INTRM1 CEMEN-PULD P Pick up 4"XT-39 DP. 05:45 06:15 0.50 1,575 1,575 INTRM1 CEMEN-DHEQ P Shallow pulse test MWD. 210 gpm, 1100 psi,20 rpm, 2K tq 06:15 12:00 5.75 1,575 8,007 INTRM1 CEMEN-PULD P Continue to pick up 4"XT-39 DP. 12:00 16:15 4.25 8,007 11,791 INTRM1 CEMEN-PULD P Continue to pick up 4"XT-39 DP. 16:15 19:15 3.00 11,791 11,791 INTRM1 CEMEN"SLPC P Slip and cut 55'drlg line. 19:15 22:00 2.75 11,791 12,856 INTRM1 CEMEN-QEVL P MAD pass with SonicScope 475 for cmt. evaluation f/11885'MD t/12856' MD 22:00 00:00 2.00 12,856 12,919 INTRM1 CEMEN-DRLG P Break circ.Tag ES cementer @12856'MD. Drill closing plug and cementer.60 rpm,200 gpm, 1800 psi,12K tq, 1-5K WOB.Wash down to 12919' MD 12/31/2014 Wait on weather. Clean out to baffle adapter. CBU Test casing to 3500 psi. Drill shoe track and 20'new hole. CBU. Perform LOT. Install RCD bearing assy. Displace to 10.2 ppg Flo Pro WBM.. Fingerprint MPD. Drill 6 3/4"production section. 00:00 02:00 2.00 12,919 12,919 INTRM1 CEMEN-CIRC P Cont to CBU @ 12845'MD, Pump @ 200 gpm=1600 psi. 02:00 12:00 10.00 12,919 12,919 INTRM1 CEMEN-OTHR T Weather conditions went to Phase III. Reduce pump rate to 150 gpm=1050 psi,wait on Phase III weather. 12:00 00:00 12.00 12,919 12,919 INTRM1 CEMEN-OTHR T Pump@ 150 gpm=1050 psi,wait on Phase III weather. Convoyed out drilling crew,Tool pusher, Co man and rig electrician @ 17:00 hours. 31/01/2015 CBU after drilling ES cementer.Wait on Phase III weather.Power up MWD/downlink Powerdrive.Wash and ream to 13300' MD. CBU.Test csg to 3500 psi/30 min.Wash and ream to 13320'MD. Drill float track. Clean out rat hole and drill 20'new hole. CBU. Perform LOT. Remove trip nipple/install RCD bearing assy. 00:00 07:00 7.00 12,919 12,919 INTRM1 CEMEN-OTHR T Wait on Phase III weather, pump @ 150 gpm=1050 psi. 07:00 07:30 0.50 12,919 12,919 INTRM1 CEMEN CIRC P Stage pumps up to 200 gpm= 1800 psi, attempt to downlink tools. Page 24of41 1 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 01/01/2015 24hrSummary CBU after drilling ES cementer.Wait on Phase III weather.Power up MWD/downlink Powerdrive.Wash and ream to 13300' MD. CBU. Test csg to 3500 psi/30 min.Wash and ream to 13320'MD. Drill float track. Clean out rat hole and drill 20' new hole. CBU. Perform LOT. Remove trip nipple/install RCD bearing assy. 07:30 08:30 1.00 12,919 12,919 INTRM1 CEMEN-CIRC T Trouble shoot tools and attempt to downlink. Successfully downlinked tools 08:30 10:00 1.50 12,919 13,300 INTRM1 CEMEN QEVL P Cont. logging cement job with sonic tool.Wash and ream to 13,000'MD. Hit cement stringer @ 13134'MD. Pump @ 200 gpm=1500 psi,40 rpm's w/10K Tq 10:00 11:45 1.75 13,300 13,300 INTRM1 CEMEN-CIRCP CBU. 210 gpm, 1850 psi. 11:45 12:00 0.25 13,300 13,300 INTRMI CEMEN-RURD P Blow down top drive. Rig up to test csg. 12:00 13:15 1.25 13,300 13,300 INTRMI CEMEN-PRTS P Rig up and perform and chart csg. test. 3500 psi/30 min. 13:15 13:30 0.25 13,300 13,300 INTRM1 CEMEN'RURD P Rig down test equip. Blow down cmt line. 13:30 13:45 0.25 13,300 13,320 INTRM1 CEMEN'COCF P Wash and ream f/13300'MD t/13320' MD.Tag baffle adapter. 190 gpm, 80 rpm, 15K tq, 1800 psi, FO=36% 13:45 17:00 3.25 13,320 13,460 INTRMI CEMEN-DRLG P Drlg shoe track f/13320'MD t/13460' MD. 190 gpm, 80 rpm, 15L tq, 1800 psi, FO=36%. 3-15K WOB 17:00 17:15 0.25 13,460 13,470 INTRM1 CEMEN REAM P Wash and ream rat hole.f/13460'MD t/13470'MD. 190 gpm, 80 rpm, 15K tq, 1800 psi, FO=36%,5-10K WOB 17:15 17:30 0.25 13,470 13,490 INTRM1 CEMEN-DDRL P DDrlg f/13470' MD t13490'MD,6092' TVD.ADT=.32, Bir hrs=.32 Jar hrs=58.82. PU 110K, SO 106K, 104K Rot, 14K tq on, 11.98 ECD, FO=36%, 3-15K WOB,80 rpm, 190 gpm, 1800 psi. 17:30 19:00 1.50 13,490 13,490 INTRM1 CEMEN-CIRCP CBU.240 gpm,2300 psi, FO=36%, ECD=11.98, PU 110K, SO 106K, 80 rpm 19:00 19:15 0.25 13,490 13,394 INTRM1 CEMEN"OWFF P OWFF. Stand back one std. DP. 19:15 19:30 0.25 13,394 13,394 INTRM1 CEMEN-RURD P Rig up to perform LOT. 19:30 20:00 0.50 13,394 13,394 INTRM1 CEMEN'LOT P Perform LOT. 13.2 EMW 20:00 20:30 0.50 13,394 13,394 PROD1 DRILL RURD P Rig down test equip. Blow down lines 20:30 00:00 3.50 13,394 13,490 PROD1 DRILL SEQP P Remove trip nipple. Install RCD bearing assy. Make connection and R I H to 13490 31/02/2015 Displace to 10.2 ppg Flo Pro mud. Perform MPD fingerprint procedure.Determine that 10.5 ppg mud wt is required.Weight up mud to 10.5 ppg. Repeat fingerprint procedure. Directional drill 6 3/4"production hole section to 14221'MD. 00:00 02:45 2.75 13,490 13,490 PROD1 DRILL DISP P PJSM, displace well to 10.2 ppg FLO-PRO NT mud system. Pump 30 bbls Hi Vis spacer and chase with FLO-PRO NT mud. Pump©240 gpm=2500 psi, ROT©20 rpm's w/ 15K Tq. ECD= 11.22 ppg. Page 25 of 41 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 02:45 04:00 1.25 13,490 13,490 PROD1 DRILL OWFF P Obtain SPR's and blow down top drive. Perform fingerprint test,shut MPD chokes for 10 min and observe pressures, 1st test: pressure build f/0 psi to 89 psi in 10 min, opened up and bleed back to trip tank for 10 min,gained .1 bbls..2nd test:: pressure build f/0 psi to 86 psi in 10 min, opened up and bleed back to trip tank for 10 min, gained.50 bbls. Shut in a 3rd time and pressure build f/0 psi to 97 psi in 10 min., .27 ppg EWM. Decision made to increase MW to 10.5 ppg. 04:00 11:30 7.50 13,490 13,488 PROD1 DRILL CIRC T Open MPD choke,establish circulation @ 200 gpm=2250 psi. wash down to 13488' MD, ROT @ 20 rpm's. Increase pumps to 240 gpm= 2250 psi, 11.23 ppg ECD.Observed gas increase from 200 units to 410 units at BU. Increase MW f/10.2 ppg to 10.4+ppg with salt and Safe Carb. 11:30 12:30 1.00 13,488 13,488 PROD1 DRILL OWFF T Perform fingerprint test, shut MPD chokes for 10 min and observe pressures, 1st test: pressure build f/0 psi to 47 psi in 10 min, opened up and bleed back to trip tank for 10 min,gained.34 bbls. Flow slowed from 12 sec a quart to 22 sec a quart. Shut back in for 10 min and pressure built slowly to 38 psi. Discussed test with town,decision made to drill ahead monitoring BU for gas. 12:30 13:00 0.50 13,488 13,490 PROD1 DRILL CIRC P Obtain SPR's. SPR @ 13490'MD,6090'TVD. MW=10.5 12:30 hrs. #1 20 spm=560 psi 30 spm=840 psi #2 20 spm=540 psi 30 spm=840 psi 13:00 18:00 5.00 13,490 13,844 PROD1 DRILL DDRL P DDrlg f/13490' MD t/13844' MD 6128' TVD.ADT=4.59 Bit hrs=4.91 Jar hrs=63.41. PU 165K, SO 70K, Rot 109K Tq on 16K, Tq off 14K, ECD 11.99, FO 40%,WOB 15K, 110 rpm, 239 gpm,2600 psi. Max gas=266 Page 26 of 41 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 18:00 00:00 6.00 13,844 14,221 PROD1 DRILL DDRL P DDrIg f/13844' MD t114221' MD 6125' TVD.ADT=3.95 Bit hrs=8.86 Jar hrs=67.36. PU 165K, SO 66K, Rot 115KTgon 16.5K,Tgoff 13K, ECD 12.07, FO 40%,WOB 10-15K, 110 rpm, 239 gpm, 2750 psi. Max gas=230 SPR @ 13870' MD, 6128'TVD. MW=10.5 18:30 hrs. #1 20 spm=710 psi 30 spm=1010 psi #2 20 spm=700 psi 30 spm=980 psi 01/03/2015 Directional drill 6 3/4"production hole section to 14345' MD. Service rig. Directional drill 6 3/4"production hole section to 15574'MD 00:00 02:00 2.00 14,221 14,345 PROD1 DRILL DDRL P DDrlg f/ 14221' MD to14345'MD 6120'TVD. ADT= 1.88 Bit hrs=10.74 Jar hrs=69.24. PU 165K, SO 66K, Rot 109KTgon 16K,Tgoff 16K, ECD 12.12, FO 40%,WOB 5-10K, 140 rpm, 240 gpm,2700 psi. Max gas=230 02:00 02:30 0.50 14,345 14,345 PROD1 DRILL SVRG P Service rig, tighten bolts on top drive. 02:30 06:00 3.50 14,345 14,533 PROD1 DRILL DDRL P DDrIg f/14345' MD to 14533' MD 6114'TVD.ADT=3.96 Bit hrs=13.41 Jar hrs=71.91. PU 165 K, SO 66 K, Rot 109 K Tq on 16 K, Tq off 16 K, ECD 12.12 ppg , FO 40%,WOB 5-10K, 140 rpm, 240 gpm,2680 psi. Max gas=230 SPR @ 14439' MD, 6115'TVD. MW=10.5 4:00 hrs. #1 20 spm=680 psi 30 spm=1060 psi #2 20 spm=690 psi 30 spm=1020 psi 06:00 12:00 6.00 14,533 14,871 PROD1 DRILL DDRL P DDrIg f/14533' MD to 14871' MD 6103'TVD. ADT=4.02 Bit hrs=17.43 Jar hrs=75.93. PU 165 K, SO 66 K, Rot 110KTgon 17 K, Tq off 16 K, ECD 12.16 ppg , FO 40%,WOB 10-12K, 140 rpm, 240 gpm, 2700 psi. Max gas=110 12:00 18:00 6.00 14,871 15,240 PROD1 DRILL DDRL P DDrIg f/14871' MD to 15240' MD 6113'TVD.ADT=4.78 Bit hrs=22.21 Jar hrs=80.71. PU 163 K, SO 70 K, Rot 107KTgon 16 K, Tgoff 11 K, ECD 12.13 ppg , FO 40%,WOB 10-15K, 140 rpm,240 gpm, 2800 psi. Max gas=125 SPR @ 15194'MD,6107'TVD. MW=10.5 15:20 hrs. #1 20 spm=700 psi 30 spm=975 psi #2 20 spm=700 psi 30 spm=975 psi Page 27 of 41 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 18:00 00:00 6.00 15,240 15,574 PROD1 DRILL DDRL P DDrlg f115240' MD to 15574' MD 6105'TVD. ADT=4.12 Bit hrs=26.33 Jar hrs=84.83. PU 160 K, SO 70 K, Rot 110KTgon 16K, Tgoff 10K, ECD 12.16 ppg , FO 40%,WOB 5-8K, 140 rpm, 238 gpm, 2830 psi. Max gas=131 01/04/2015 Directional drill 6 3/4"production hole section to 17065' MD. 00:00 06:00 6.00 15,574 15,951 PROD1 DRILL DDRL P DDrIg f/15574' MD to 15951' MD 6106'TVD.ADT=4.90 Bit hrs=31.23 Jar hrs=89.73. PU 162 K, SO 68 K, Rot 112KTgon 14 K, Tgoff 11 K, ECD 12.2 ppg , FO 41%,WOB 5-10K, 120 rpm, 240 gpm,2800 psi. Max gas=139 SPR @ 15857' MD,6107'TVD. MW=10.5 04:00 hrs. #1 20 spm=730 psi 30 spm=1020 psi #2 20 spm=740 psi 30 spm=1040 psi 06:00 12:00 6.00 15,951 16,284 PROD1 DRILL DDRL P DDrIg f/15951' MD to 16284' MD 6116'TVD. ADT=5.28 Bit hrs=36.51 Jar hrs=95.01. PU 165 K, SO 63 K, Rot 112KTgon 14K, Tgoff 11 K, ECD 12.17 ppg , FO 40%,WOB 15K, 100 rpm, 240 gpm, 2850 psi. Max gas=130 12:00 18:00 6.00 16,284 16,745 PROD1 DRILL DDRL P DDrlg f/16284' MD to 16745' MD 6126'TVD. ADT=5.53 Bit hrs=42.04 Jar hrs=100.54. PU 165 K, SO 60 K, Rot 110 K Tq on 14 K, Tq off 11 K, ECD 12.37 ppg , FO 40%,WOB 5-15K, 100 rpm, 240 gpm,3000 psi. Max gas=231 18:00 00:00 6.00 16,745 17,065 PROD1 DRILL DDRL P DDrIg f/16745' MD to 17065'MD 6127'TVD.ADT=3.91 Bit hrs=45.95 Jar hrs=104.45. PU 165 K, SO 55 K, Rot 113 K Tq on 13.5 K, Tq off 11 K, ECD 12.34 ppg , FO 40%,WOB 5-15K, 140 rpm, 240 gpm, 3050 psi. Max gas=110 SPR @ 16804' MD, 6123'TVD. MW=10.5 19:20 hrs. #1 20 spm=800 psi 30 spm=1130 psi #2 20 spm=780 psi 30 spm=1140 psi Function check annular, upper and lower rams. 01/05/2015 Directional drill 6 3/4"production hole section to 18794' MD. Page 28of41 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 00:00 06:00 6.00 17,065 17,564 PROD1 DRILL DDRL P DDrIg f/17065' MD to 17564' MD 6134'TVD.ADT=4.68 Bit hrs=50.63 Jar hrs=109.13. PU 170 K, ( Lost SO weight)SO 0 K, Rot 110 K Tq on 13.5K, Tgoff 12K, ECD 12.28ppg , FO 40%, WOB 8-12K, 80-110 rpm, 240 gpm, 2980 psi. Max gas=132 SPR @ 17564' MD, 6135'TVD. MW=10.5+ 3:20 hrs. #1 20 spm=800 psi 30 spm=1100 psi #2 20 spm=800 psi 30 spm=1100 psi 06:00 12:00 6.00 17,564 18,068 PROD1 DRILL DDRL P DDrIg f/17564' MD to 18068' MD 6137'TVD.ADT=4.47 Bit hrs=55.10 Jar hrs=113.60. PU 170 K, SO 55 K, Rot 110 K Tq on 16-17K, Tq off 11.5 K, ECD 12.23 ppg , FO 40%, WOB 5-10K, 80-120 rpm, 240 gpm, 2990 psi. Max gas=364 12:00 18:00 6.00 18,068 18,656 PROD1 DRILL DDRL P DDrlg f/18068' MD to 18656' MD 6138'TVD.ADT=5.15 Bit hrs=60.25 Jar hrs=118.75. PU 175 K, SO 0 K, Rot 114KTgon14K,Tgoff 12K, ECD 12.36 ppg , FO 40%,WOB 6K, 80 rpm, 239 gpm, 3150 psi. Max gas=190 18:00 00:00 6.00 18,656 18,794 PROD1 DRILL DDRL P DDrIg f/18656' MD to 18794' MD 6145'TVD.ADT=4.36 Bit hrs=64.61 Jar hrs=123.11. PU 175 K, SO 0 K, Rot 111 KTgon 14.5 K, Tq off 11.5 K, ECD 12.45 ppg , FO 40%,WOB 6-10K, 90 rpm, 237 gpm, 3280 psi. Max gas=71 SPR @ 18605' MD, 6138'TVD. MW=10.5 19:29 hrs. #1 20 spm=810 psi 30 spm=1160 psi #2 20 spm=800 psi 30 spm=1150 psi 01/06/2015 Directional drill 6 3/4"production hole section from 18794-20401'MD. 00:00 06:00 6.00 18,794 19,129 PROD1 DRILL DDRL P DDrlg f/18794-19129' MD, 6150'TVD. ADT=5.56, Bit hrs=70.17, Jar hrs=128.67. PU 176K, SO OK, Rot 108K Tq on 12-14K,Tq off 10K, ECD 12.31 ppg, FO 40%,WOB 3-10K, 80 rpm, 240 gpm, 3190 psi. Max gas=181 Spill Drill CRT= 158 sec @ 04:00 hrs. Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 06:00 12:00 6.00 19,129 19,552 PROD1 DRILL DDRL P DDrIg f/19129-19552' MD, 6157'TVD. ADT=4.37, Bit hrs=74.54,Jar hrs=133.04. PU 180K, SO OK, Rot 113K Tq on 13K, Tq off 11K, ECD 12.52 ppg, FO 40%,WOB 5-10K, 80 rpm, 240 gpm, 3250 psi. Max gas=191 SPR @ 19268' MD, 6148'TVD. MW=10.5 08:15 hrs. #1 20 spm=830 psi 30 spm=1210 psi #2 20 spm=840 psi 30 spm=1190 psi 12:00 18:00 6.00 19,552 20,097 PROD1 DRILL DDRL P DDrIg f/19552-20097' MD, 6169'TVD. ADT=5.04, Bit hrs=79.58,Jar hrs=138.08. PU 175K, SO OK, Rot 107K Tq on 13K, Tq off 11K, ECD 12.5 ppg, FO 40%,WOB 5-12K, 80 rpm, 240 gpm, 3325 psi. Max gas=189 18:00 00:00 6.00 20,097 20,401 PROD1 DRILL DDRL P DDrlg f/20097-20401' MD, 6185'TVD. ADT=3.97, Bit hrs=83.55,Jar hrs=142.05. PU 195K, SO OK, Rot 110K Tq on 14K, Tq off 12K, ECD 12.39 ppg, FO 40%,WOB 5-8K, 80 rpm, 237 gpm, 3350 psi. Max gas=158 SPR @ 20212' MD, 6173'TVD. MW=10.5+ 19:40 hrs. #1 20 spm=820 psi 30 spm=1220 psi #2 20 spm=840 psi 30 spm=1200 psi D1/07/2015 Directional drill 6 3/4"production hole section from 20401-21175' MD. 00:00 06:00 6.00 20,401 20,707 PROD1 DRILL DDRL P DDrlg f/20401-20707' MD,6195'TVD. ADT=5.17, Bit hrs=88.72,Jar hrs=147.22. PU 190K, SO OK, Rot 112KTgon14-15K, Tgoff 11K, ECD 12.44 ppg, FO 40%,WOB 5-10K, 80 rpm, 243 gpm, 3480 psi. Max gas=182 Table Top Rig Evac. Drill @ 04:30 hrs. Page 30 of 41 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 06:00 12:00 6.00 20,707 20,792 PROD1 DRILL DDRL P DDrlg f/20707-20792' MD, 6191'TVD. ADT=5.02, Bit hrs=93.74, Jar hrs=152.24. PU 185K, SO OK, Rot 111KTgon 12.5K,Tgoff 11K, ECD 12.40 ppg, FO 41%,WOB 4-5K, 60 rpm, 255 gpm, 3700 psi. Max gas=190 SPR @ 20779' MD, 6196'TVD. MW=10.5+ 10:55 hrs. #1 20 spm=830 psi 30 spm=1140 psi #2 20 spm=850 psi 30 spm=1160 psi 12:00 18:00 6.00 20,792 20,990 PROD1 DRILL DDRL P DDrlg f/20792-20990' MD, 6187'TVD. ADT=5.53, Bit hrs=99.27,Jar hrs=157.77. PU 190K, SO OK, Rot 107K Tq on 13K, Tq off 12K, ECD 12.38 ppg, FO 41%,WOB 5-10K, 80 rpm, 255 gpm, 3600 psi. Max gas=178 Spill Drill CRT 60 sec @ 15:00 hrs. 18:00 00:00 6.00 20,990 21,175 PROD1 DRILL DDRL P DDrlg f/20990-21175' MD, 6180'TVD. ADT=4.44, Bit hrs=103.71, Jar hrs=165.21. PU 188K, SO OK, Rot 113K Tq on 14K, Tq off 10.5K, ECD 12.33 ppg, FO 40%,WOB 5-10K, 80 rpm, 240 gpm, 3400 psi. Max gas=274 SPR @ 21155' MD, 6186'TVD. MW=10.5+ 22:50 hrs. #1 20 spm=800 psi 30 spm=1200 psi #2 20 spm=830 psi 30 spm=1180 psi 01/08/2015 Directional drill 6 3/4"production hole section to TD @ 22009' MD, 6206'TVD. Shoot surveys, obtain SPR's, &monitor well. BROOH to 19365' MD. 00:00 06:00 6.00 21,175 21,536 PROD1 DRILL DDRL P DDrlg f/21175-21536' MD, 6191'TVD. ADT=4.69, Bit hrs=108.40, Jar hrs=166.90. PU 200K, SO OK, Rot 115K Tq on 15-16K, Tq off 12K, ECD 12.49 ppg, FO 40%,WOB 5-12K, 80 rpm, 240 gpm, 3400 psi. Max gas=361 Fire Drill CRT 148 sec @ 04:45 hrs. Page 31 of 41 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 06:00 12:00 6.00 21,536 21,880 PROD1 DRILL DDRL P DDrlg f/21536-21880'MD, 6215'TVD. ADT=4.79, Bit hrs=113.19, Jar hrs=171.69. PU 210K, SO OK, Rot 114K Tq on 16-17K,Tq off 12K, ECD 12.51 ppg, FO 40%,WOB 10K, 50-80 rpm,242 gpm, 3500 psi. Max gas=571 SPR @ 21725'MD,6205'TVD. MW=10.5+ 08:45 hrs. #1 20 spm=830 psi 30 spm=1190 psi #2 20 spm=850 psi 30 spm=1210 psi 12:00 15:45 3.75 21,880 22,009 PROD1 DRILL DDRL P DDrIg f/21880-22009' MD,6206'TVD. ADT=3.25, Bit hrs=116.44,Jar hrs=174.94. PU 207K, SO OK, Rot 115KTgon 14K,Tgoff 12K, ECD 12.46 ppg, FO 39%,WOB 5K, 80 rpm, 250 gpm, 3790 psi. Max gas=603 TD @ 22009' MD; 6206'TVD. Fire Drill CRT 140 sec @ 14:40 hrs. 15:45 16:00 0.25 22,009 22,009 PROD1 CASING CIRC P Obtain SPR's @ 22009'MD,6206' TVD. MW=10.5+ 15:45 hrs. #1 20 spm=870 psi 30 spm=1230 psi #2 20 spm=840 psi 30 spm=1240 psi 16:00 16:30 0.50 22,009 22,009 PROD1 CASING SRVY P Shoot surveys on bottom at TD. 16:30 16:45 0.25 22,009 22,009 PROD1 CASING OWFF P Monitor well with MPD chokes shut in, no increase in pressure. 16:45 00:00 7.25 22,009 19,365 PROD1 CASING REAM P BROOH f/22009-19365'MD, 220 gpm,2900 psi, 80 rpm,Tq 14k. Calculated fill 13.5,actual 16.01 bbls. 01/09/2015 BROOH to the shoe. C&C to increase MW to 10.7 ppg. OWFF. SOOH w/MPD to 6401' MD. 00:00 14:00 14.00 19,365 13,398 PROD1 CASING REAM P PJSM, BROOH f/19365-13398'MD, 220 gpm, 2900 psi, 80 rpm, Tq 14K, 800-1000 fph, calculated fill 35.64, actual 40.36 bbls. 14:00 16:30 2.50 13,398 13,398 PROD1 CASING CIRC P Circulate&weight up f/10.5- 10.7 ppg @ 215 gpm, 2300 psi, 80 rpm, Tq 7K, FO 38%. 16:30 16:45 0.25 13,398 13,398 PROD1 CASING OWFF P Shut in MPD chokes, pressure built up to 63 psi in 2 min. Pressure then bled down to 34 psi at the end of 15 minutes. 16:45 17:30 0.75 13,398 13,398 PROD1 CASING OWFF P Monitor well, observe slight flow decreasing to stop. 17:30 17:45 0.25 13,398 13,398 PROD1 CASING SEQP P Line up MPD chokes for SOOH. (Drop 1 7/8"hollow drift) Page 32 of 41 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 17:45 00:00 6.25 13,398 6,401 PROD1 CASING TRIP P SOOH f/13398'-6401'MD, PU 100K, SO 72K, 2000-3000 fph, BPSI pulling 180-120 psi, BPSI in slips 70 psi,calculated fill 37.8, actual 58.1 bbls. 01/10/2015 SOOH to 2017'MD. Remove RCD, install trip nipple. Continue to TOH laying down drill pipe. Lay down BHA 4. Service rig&C/O KR valve on Koomey. Remove wear bushing. Install test plug&rig up to test BOPE. Observe flow at OA valve. Perform exhale test. Remove test plug& line up to trip tank. Monitor well& continue exhale test. 00:00 01:45 1.75 6,401 4,321 PROD1 CASING TRIP P Cont to Strip OOH using MPD f/ 6401'MD to 4321'MD @ 3000 fph. Choke pressure= 120 psi pulling,70 psi in slips.Actual displacement=21 bbls, Calculated displacement=13.5 bbls. P/U 100K, S/0=72K. 01:45 02:45 1.00 4,321 4,321 PROD1 CASING RURD P PJSM,clean and clear rig floor. Prep to L/D drill pipe. 02:45 06:15 3.50 4,321 2,017 PROD1 CASING PULD P POOH L/D 4" DP f/4321' MD to 2017' MD. Hold 75 psi on well using MPD choke. Observed floats not holding, unable to get accurate hole fill numbers. Decision made to remove MPD bearing and install trip nipple after modeling swab pressure. 06:15 07:00 0.75 2,017 2,017 PROD1 CASING OWFF P Clean and clear floor-OWFF, slight flow to static. SIMOPS, hold PJSM on removing MPD bearing. 07:00 09:00 2.00 2,017 2,017 PROD1 CASING SEQP P Remove MPD bearing, adjust BOP stack and install trip nipple. 09:00 11:00 2.00 2,017 440 PROD1 CASING TRIP P TOH f/2017'-440'MD,2000 fph, calculated fill 21.6,actual 39.2 bbls. 11:00 11:15 0.25 440 440 PROD1 CASING OWFF P Monitor well, static. 11:15 14:45 3.50 440 0 PROD1 CASING PULD P Lay down BHA 4 as per SLB DD. 14:45 16:00 1.25 0 0 PROD1 CASING RURD P Clear&clean rig floor. Sim-ops C/O KR vavle on Koomey. 16:00 17:00 1.00 0 0 PROD1 CASING SVRG P Service rig. 17:00 17:30 0.50 0 0 PROD1 WHDBO RURD P Rig up to test BOPE. 17:30 18:00 0.50 0 0 PROD1 WHDBO RGRP T Finish C/O of KR valve on Koomey. 18:00 19:15 1.25 0 0 PROD1 WHDBO RURD T Attempt to remove wear bushing. 19:15 19:30 0.25 0 0 PROD1 WHDBO RURD T Rig up to wash the stack. 19:30 20:00 0.50 0 0 PROD1 WHDBO WWWH T Flush stack. 20:00 20:30 0.50 0 0 PROD1 WHDBO RURD P Pull wear bushing. 20:30 21:00 0.50 0 0 PROD1 WHDBO RURD P Set Test plug&rig up to test. 21:00 21:45 0.75 0 0 PROD1 WHDBO OWFF T Observe slight flow at the OA valve while rigging up to test. Monitor flow &perform exhale test. Observe no increase or decrease in flow,with 3.3 bph. Page 33 of 41 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 21:45 00:00 2.25 0 0 PROD1 WHDBO OWFF T Remove test plug&line up on trip tank. Observe initial flow at 2 bph returning to 3.3 bph. MW 10.1 ppg flowing out,suspect weight material sag. Confer with town. 01/11/2015 TIH to the shoe,to condition mud for weight material sag. Monitor well. Set&test storm packer. Rig up& test BOPE with AOGCC Rep.Johnnie Hill witnessed. 00:00 00:15 0.25 0 0 PROD1 WHDBO RURD T PJSM, install 10"wear bushing. 00:15 00:45 0.50 0 12 PROD1 WHDBO PULD T Pick up BHA 5, mule shoe,XO's& float sub. 00:45 03:45 3.00 12 7,575 PROD1 WHDBO TRIP T TIH f/12'-7575'MD,filling every 20 stands, calculated displacement 37.8, actual 36.33 bbls. 03:45 06:45 3.00 7,575 7,575 PROD1 WHDBO CIRC T Circulate&condition weighting up for sag back to 10.7 ppg, 3 bpm, 510 psi, FO 36%, MW out 10.2 ppg. 06:45 07:45 1.00 7,575 9,468 PROD1 WHDBO TRIP T TIH f/7575-9468'MD, calculated displacement 13.5,actual 13.74 bbls. 07:45 09:45 2.00 9,468 9,468 PROD1 WHDBO CIRC T Circulate&condition weighting up for sag back to 10.7 ppg, 3-5 bpm, 625-950 psi, FO 36-44%, MW out 10.2-10.7 ppg. 09:45 12:30 2.75 9,468 13,445 PROD1 WHDBO TRIP T TIH f/9468'-13445'MD,filling every 20 stands,4000-3000 fph, calcualted displacement 22.68, actual 24.34 bbls. 12:30 14:45 2.25 13,445 13,445 PROD1 WHDBO CIRC T Circulate&condition weighting up for sag back to 10.7 ppg, 3-5 bpm, 1050-1450 psi, FO 41-43%, MW out 10.2-10.7 ppg, max gas 2154. 14:45 15:00 0.25 13,445 13,351 PROD1 WHDBO RURD T Stand back 1 stand&blow down TD. 15:00 15:30 0.50 13,351 13,351 PROD1 WHDBO OWFF T Monitor well, static. 15:30 16:30 1.00 13,351 13,348 PROD1 WHDBO MPSP T Lay down a jt of DP&make up Baker Storm Packer as per Baker Rep. 16:30 17:15 0.75 13,348 13,437 PROD1 WHDBO MPSP T Make up stand&set storm packer 100'below rotary table. 17:15 17:45 0.50 13,437 13,437 PROD1 WHDBO MPSP T Rig up&test packer to 1500 psi, charted for 10 min. 17:45 18:45 1.00 13,437 13,437 PROD1 WHDBO RURD T Rig up to test BOPE. Page 34 of 41 Time Logs Date From To Dur S.Depth E. Depth Phase Code Subcode T Comment 18:45 00:00 5.25 13,437 13,437 PROD1 WHDBO BOPE P Test BOPE w/4"test jt. 250/3500 psi. 5 min.ea.#1 Upper pipe rams, CV's 1,12,13,14, manual kill line valve.#2 Upper IBOP, Kill line HCR, CV's 9, 11.#3 Lower IBOP, CVs 5,8,10.#4 Dart valve, CV's 4,6,7.#5 Floor safety valve, CV 2.#6 Choke line HCR,4"kill line Demco valve,#7 Choke line manual valve&HCR kill. #8 Annular preventer.#9 Lower pipe rams.#10 Blind rams&CV 3.Accumulator test: System pressure=3000 psi Pressure after closure= 1900 psi 200 psi attained=51 secs. Full system pressure=184 secs. 5 nitrogen bottles average=2000 psi. Test gas alarms, pit leve/flow show alarms high and low levels. Test witnessed by AOGCC Rep Johnnie Hill. 01/12/2015 Finish testing BOPE. Retreive storm packer. CBU. Slip&cut drill line. TIH f/13351'-14580'MD. Break circulation&rotate OOH 14580'-13445'MD. CBU&OWFF. Pump out of hole to 6347'MD. 00:00 02:30 2.50 13,437 13,437 PROD1 WHDBO BOPE P PJSM, continue testing BOPE's. Change out test jt.to 3%2'. Test upper and lower pipe rams and annular to 250/3500 psi for 5 min ea. Change out test jt to 4%2'.Test upper and lower pipe rams and annular to 250/3500 psi for 5 min ea. Perform draw down on manual and hyd. chokes. 3% &4% test waived by AOGCC Rep Johnnie Hill. 02:30 03:00 0.50 13,437 13,437 PROD1 WHDBO RURD P Rig down test equipment, blow down lines, &set wear bushings. 03:00 04:30 1.50 13,437 13,351 PROD1 CASING MPSP T PJSM, pull storm packer&lay down as per Baker Rep. (well static). 04:30 07:15 2.75 13,351 13,351 PROD1 CASING CIRC T Circulate&condition 5 bpm, 1330 psi, FO 47%, 10.5 ppg mud back at BU,continue till MW 10.7 ppg around. 07:15 07:45 0.50 13,351 13,351 PROD1 CASING OWFF T Monitor well, static. 07:45 09:00 1.25 13,351 13,351 PROD1 CASING SLPC T PJSM, slip&cut 65'of drill line. 09:00 09:30 0.50 13,351 13,351 PROD1 CASING SVRG T Service top drive. 09:30 10:45 1.25 13,351 14,580 PROD1 CASING TRIP T TIH f/13351'-14580'MD, Calculated displacement 7.56,actual 6.76 bbls. 10:45 11:15 0.50 14,580 14,580 PROD1 CASING CIRC T Break circulation,staging up from 2-4 bpm, 1590 psi, FO 42%, 60 rpm, Tq 10K, PU 155K, SO 80K, ROT 105K. 11:15 13:00 1.75 14,580 13,445 PROD1 CASING REAM T Circulate&rotate OOH f/ 14580'-13445' MD,4 bpm, 1500 psi, 60 rpm,Tq 9K,2000 fph, calculated fill 5.4, actual 21 bbls. Page 35 of 41 • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 13:00 14:45 1.75 13,445 13,445 PROD1 CASING CIRC T CBU 5 bpm, 1525 psi, FO 45%, 60 rpm,Tq 8K, PU 145K, SO 82K, max gas 701. L/D 1 jt&blow down TD. 14:45 16:00 1.25 13,445 13,445 PROD1 CASING OWFF T Monitor well, slight flow to static. 16:00 00:00 8.00 13,445 6,347 PROD1 CASING TRIP T Pump OOH f/13414'-6347' MD,4 bpm, 1200 psi, FO 39%,4000 fph, calculated fill 40.5,actual 63.3 bbls. 01/13/2015 Pump OOH 6347'-3885'MD&OWFF. POOH 3885'-surface. Rig up&run 4%"liner per detail. M/U liner hanger packer per Baker Rep. TIH w/Liner on DP 8910'-14867'MD. 00:00 02:15 2.25 6,347 3,885 PROD1 CASING TRIP T PJSM, pump OOH f/6347'-3885'MD, 4 bpm, 1200 psi, FO 39%,4000 fph, calculated fill 15.12, actual 17.5 bbls. 02:15 02:30 0.25 3,885 3,885 PROD1 CASING OWFF T Monitor well, static. 02:30 05:30 3.00 3,885 11 PROD1 CASING TRIP T POOH f/3885-11' MD, 1800 fph, calculated fill 22.18, actual 24.48 bbls. Kick w/Tripping Drill CRT 158 sec @ 02:45 hrs. 05:30 05:45 0.25 11 0 PROD1 CASING PULD T PJSM, lay down BHA. 05:45 06:15 0.50 0 0 PROD1 CASING RURD T PJSM, clear&clean rig floor. 06:15 08:15 2.00 0 0 COMPZ CASING RURD P PJSM, P/U&RU casing handling equipment. 08:15 14:45 6.50 0 8,714 COMPZ CASING PUTB P PJSM, run 4%", 11.6#, L-80, Hyd 563,slotted liner as per detail to 8714'MD. Calculated displacement 36.36, actual 30.13 bbls. 14:45 16:45 2.00 8,714 8,910 COMPZ CASING OTHR P PJSM, make up liner hanger/ZXP,fill with Pal mix as per Baker Rep. Sim-ops rig down casing handling equipment. M/U stand&obtain parameter 3 bpm,225 psi, FO 36%, PU 95K, SO 63K. Blow down TD. 16:45 22:00 5.25 8,910 13,449 COMPZ CASING RUNL P TIH w/4'/"liner on DP f/ 8910'-13449'MD. 22:00 22:30 0.50 13,449 13,449 COMPZ CASING RUNL P Obtain parameters @ the shoe 13449'MD, PU 135K, SO 80, ROT 104K,20 rpm, Tq 7K, 3 bpm, 750 psi. Blow down TD. 22:30 00:00 1.50 13,449 14,867 COMPZ CASING RUNL P TIH w/4%"liner on DP f/13449'-14867' MD. Calculated displacement 32.4, actual 24.99 bbls. 01/14/2015 Continue TIH w/liner on DP to TD @ 21990'MD. OWFF. Set liner hanger packer as per Baker Rep. PT liner top to 1500 psi. Displace well to 10.7ppg filtered brine. OWFF&POOH w/DP from 13302'-9230'MD. 00:00 09:15 9.25 14,867 21,990 COMPZ CASING RUNL P TIH W/4'/" LINER ON DP F/14867'-21990'MD. CALCULATED DISPLACEMENT 43.2,ACTUAL 42.16 BBLS. 09:15 09:30 0.25 21,990 21,990 COMPZ CASING OWFF P MONITOR WELL, SLIGHT FLOW TO STATIC. 09:30 09:45 0.25 21,990 21,990 COMPZ CASING CIRC P BREAK CIRC @ 2 BPM, 1150 PSI, 22%FLOW, PUMP 10 BBLS. OBTAIN P/U WT=180K, S/O WT=70 Page 36 of 41 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 09:45 12:00 2.25 21,990 21,990 COMPZ CASING PACK P DROP 1.5" BALL, CHASE DOWN @ 3 BPM, 1390 PSI, 36% FLOW, SLOW PUMPS DOWN TO 2BPM, 1050 PSI, 30% FLOW, SLOW PUMPS DOWN TO 1 BPM, 800 PSI, 18% FLOW. BALL ON SEAT @ 111 BBLS(1111 STKS) INCREASE PRESSURE TO 1500 PSI THEN UP TO 2500 PSI AND HOLD, SLACK OFF SETTING DOWN 40K TO CONFIRM LINER HANGER IS SET, PRESSURE UP TO 3500 PSI AND HOLD, BLEED PRESSURE OFF, P/U 145K TO CONFIRM RELEASE. PRESSURE UP TO 4400 PSI FAIL TO OPEN BALL SEAT, BLEED OFF PRESSURE, PRESSURE UP TO 5100 PSI, OBSERVED BALL SEAT OPEN. P/U 5' SET DOWN 50K, TO SET LINER TOP PACKER. ROTATE 25 RPM&SET DOWN 50K TO CONFIRM LINER TOP PACKER SET. LINER SET @ 21990' MD, LINER TOP @ 13276' MD. (BLOW DOWN T.D.) 12:00 12:30 0.50 21,990 21,990 COMPZ CASING RURD P RIG UP TO TEST LINER TOP PACKER. 12:30 13:00 0.50 21,990 21,990 COMPZ CASING PRTS P TEST LINER TOP PACKER T/1500 PSI, CHARTED. 13:00 13:30 0.50 21,990 21,990 COMPZ CASING RURD P RIG DOWN TEST EQUIPMENT. 13:30 14:00 0.50 21,990 13,302 COMPZ WELLPF OTHR P PULL OUT OF LINER TOP PACKER W/RUNNING TOOL. RACK BACK STAND&BLOW DOWN LINES. 14:00 17:00 3.00 13,302 13,302 COMPZ WELLPF DISP P DISPLACE WELL TO 10.7 PPG FILTERED BRINE @ 6 BPM, 1300 PSI, F0=45%, PU=149K, SO=79K. 17:00 17:45 0.75 13,302 13,302 COMPZ WELLPF OWFF P MONITER WELL, STATIC. BLOW DOWN TOP DRIVE. 17:45 19:15 1.50 13,302 12,923 COMPZ WELLPF TRIP P PUMP OOH F/13302'-12923'MD @ 3 BPM, PSI=300, F0=32%, PU=165K, SO=80K. SPR'@ 13302' MD,TVD=6063', MW=10.7 PPG, TIME=18:00 #1 @ 20=120©30=260 #2 @20= 100@30=264 19:15 20:15 1.00 12,923 12,923 COMPZ WELLPF SVRG P SERVICE TOP DRIVE. KICK W/TRIPPING DRILL CRT 120 SEC @ 19:30 HRS. 20:15 21:30 1.25 12,923 12,449 COMPZ WELLPF TRIP P PUMP OOH F/12923'-12449' MD @ 3 BPM, 300 PSI, FO=32% CALCULATED FILL 5.4,ACTUAL 11.16 BBLS. 21:30 00:00 2.50 12,449 9,230 COMPZ WELLPF TRIP P POOH F/12449'-9230'MD, CALCULATED FILL 16.2,ACTUAL 21.35 BBLS. Page 37 of 41 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 01/15/2015 24 hr Summary Continue TOH&lay down liner running tool. Pull wear bushing&perform dummy run w/tubing hanger. Rig up casing handling equipment. PJSM&start to run upper completion. Inadvertently set packer while trying to test Mirage plug. Lay down seal bore assembly. Punch hole through Mirage plug to observe well. Pick up Baker cutter assembly attempt to cut packer mandrel.Attempt to pull with no success. Redress cutters& begin cutting packer mandrel. 00:00 04:00 4.00 9,230 55 COMPZ WELLPFTRIP P PJSM, POOH F/9230'-55'MD, calcualted fill 59.4,actual 60.9 bbls. 04:00 04:15 0.25 55 0 COMPZ WELLPF PULD P PJSM, lay down running tool as per Baker Rep. 04:15 04:45 0.50 0 0 COMPZ WELLPF RURD P PJSM, clear&clean rig floor. 04:45 05:15 0.50 0 0 COMPZ RPCOM RURD P PJSM,drain stack, pull wear bushing, &perform dummy run with tubing hanger. 05:15 06:00 0.75 00 COMPZ RPCOM RURD P PJSM, rig up tubing handling equipment. 06:00 07:00 1.00 0 120 COMPZ RPCOM PUTB P PJSM, pick up&make up nogo sub, mirage plug&packer. 07:00 07:15 0.25 120 120 COMPZ RPCOM RURD P Rig up to test Mirage plug to 300 psi. 07:15 07:45 0.50 120 120 COMPZ RPCOM PRTS T Inadvertently pressured up to 1575 psi, setting the packer @ 33.35'MD. Chart recorder was not plugged in, therefore pressure could not be observed. 07:45 09:45 2.00 120 120 COMPZ RPCOM OTHR T Call town&discuss plan forward. 09:45 10:00 0.25 120 0 COMPZ RPCOM PULD T Lay down seal bore assembly per Baker Rep. 10:00 11:30 1.50 0 0 COMPZ RPCOM OTHR T Wait on tools. 11:30 11:45 0.25 0 0 COMPZ RPCOM RURD T Strap 1"pipe&make mule shoe. 11:45 13:00 1.25 0 78 COMPZ RPCOM PULD T Pick up mule shoe&2 joints of pac-pipe. Sim-op rig up to pump. 13:00 13:45 0.75 78 78 COMPZ RPCOM OTHR T Work through salt plug in mirage, observe.5 bbl loss. Filled hole& monitor via trip tank,static. 13:45 14:00 0.25 78 0 COMPZ RPCOM PULD T Lay down pac pipe&blow down cement line. 14:00 16:00 2.00 0 0 COMPZ RPCOM OTHR T Wait on fishing tools, montior well via trip tank. 16:00 16:45 0.75 0 0 COMPZ RPCOM RURD T Mobilize fishing tools to rig floor. 16:45 18:15 1.50 0 63 COMPZ RPCOM PULD T Pick up&run in the hole w/cutter assembly per Baker Rep. 18:15 20:42 2.45 63 63 COMPZ RPCOM CPBO T Attempt to cut mandrel inside packer 71gpm,2400 psi, FO 22%. 20:42 21:12 0.50 63 0 COMPZ RPCOM PULD T Lay down cutter assembly as per Baker Rep. 21:12 21:27 0.25 0 34 COMPZ RPCOM PULD T Make up retrieval tool as per Baker Rep. 21:27 22:12 0.75 34 34 COMPZ RPCOM FISH T Engage packer,set down 10K, pick up 10K over to confirm. Stage up pull weight to 45K, setting back down 10K each time. Hold 45K for 15 min, weight did not drop off. Release from packer. 22:12 22:27 0.25 34 0 COMPZ RPCOM PULD T Lay down Baker retrieval tool. Page 38 of 41 Time Logs _ Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 22:27 23:12 0.75 0 0 COMPZ RPCOM RURD T Redress cutter assembly. 23:12 23:27 0.25 0 63 COMPZ RPCOM PULD T Pick up&run in the hole w/cutter assembly per Baker Rep. 23:27 23:42 0.25 63 63 COMPZ RPCOM CPBO T Cut packer mandrel @ 75 gpm, 3700 psi, FO 24%. 31/16/2015 Finish cutting packer mandrel. POOH laying down packer&Mirage plug. Pick up D nipple with RHC plug& replacement packer. Run 3%2'upper completion as per detail. Set packer&test tubing 3000 psi, annulus 1500 psi for 10 min. 00:00 00:45 0.75 63 63 COMPZ RPCOM CPBO T Cut packer mandrel @ 75 gpm, 3700 psi, FO 24%. Pressure gradually dropped to 2300 psi, indicating cut through mandrel, per Baker Rep. 00:45 01:30 0.75 63 0 COMPZ RPCOM PULD T Lay down cutter assembly as per Baker Rep. 01:30 01:45 0.25 0 34 COMPZ RPCOM PULD T Make up retrieval tool as per Baker Rep. 01:45 02:00 0.25 34 120 COMPZ RPCOM FISH T Engage packer w/retrieval tool, set down 10k, PU 5K,weight broke over. Fish on.Wait 10 min.for elements to relax. 02:00 03:30 1.50 120 0 COMPZ RPCOM PULL T Pull packer&mirage plug to rig floor, lay down same. Inspect shear sub. 03:30 03:45 0.25 0 0 COMPZ RPCOM RURD T Clear&clean rig floor. 03:45 04:00 0.25 0 0 COMPZ RPCOM SFTY P PJSM on running 3.5"upper completion run. 04:00 05:15 1.25 0 646 COMPZ RPCOM PUTB P TIH w/3'/2', 9.3#, L-80, EUE 8RD-Mod tubing upper completion as per detail surface to 646'MD. 05:15 05:45 0.50 646 646 COMPZ RPCOM SVRG P Lubricate Rig. 05:45 12:00 6.25 646 4,607 COMPZ RPCOM PUTB P TIH w/3Y2', 9.3#, L-80, EUE 8RD-Mod tubing upper completion as per detail f/646'-4607'MD. Calculated displacement 14.22, actual 12.07 bbls. 12:00 19:45 7.75 4,607 11,573 COMPZ RPCOM PUTB P TIH w/3%", 9.3#, L-80, EUE 8RD-Mod tubing upper completion as per detail f/4607'-11573'MD. 19:45 20:15 0.50 11,573 11,573 COMPZ RPCOM SVRG P Service rig. 20:15 22:00 1.75 11,573 13,301 COMPZ RPCOM PUTB P TIH w/3%", 9.3#, L-80, EUE 8RD-Mod tubing upper completion as per detail f/11573'-13301'MD. PU 105K, SO 65K, calculated displacement 30.65,actual 26.96 bbls. 22:00 22:15 0.25 13,301 13,305 COMPZ RPCOM HOSO P Tag up @ 13306'MD on shear pins, set down on no-go w/5K @ 13307' MD. Pick up 2'for space out. 22:15 23:00 0.75 13,307 13,305 COMPZ RPCOM RURD P Rig up to circulate down the tubing. Drop ball&rod w/1.30"ball. Page 39 of 41 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 23:00 00:00 1.00 13,305 13,305 COMPZ RPCOM PACK P Set packer, pressure up to 3300 psi &shut in for 30 min. Bleed down tubing to 1000 psi&shut in. Pressure up annulus to 1500 psi. & hold for 10 min. Bleed off tubing& annulus. 01/17/2015 Space out&make up tubing hanger,with landing joint. Spot corrosion inhibited brine. Land hanger&RILDS. PT tubing&annulus to 3500 psi. Shear DCR-1 valve. Install BPV&PT hanger seals, PT IA&tubing hanger direction of flow to 3000 psi. ND BOPE&NU tree.Test tree. Pull dart&BPV. 00:00 01:30 1.50 13,305 13,277 COMPZ RPCOM HOSO P Space out, lay down 3 jts of 3.5" tubing. PU 2-10'pups, 1 -4'pup, XO, & 1 jt of 4.5"tubing. 01:30 02:30 1.00 13,277 13,286 COMPZ RPCOM THGR P Make up hanger&landing joint. 02:30 05:30 3.00 13,286 13,286 COMPZ RPCOM CRIH P PJSM, pump 355 bbls of 2% CRW-132 corrosion inhibited 10.7 ppg kill weight brine followed by 115 bbls of 10.7 ppg kill weight brine. Pump @ 4 bpm,600 psi. 05:30 06:15 0.75 13,286 13,286 COMPZ RPCOM OWFF P Monitor well, static. Sim-op blow down choke&kill lines. 06:15 06:45 0.50 13,286 13,305 COMPZ RPCOM THGR P Land tubing hanger, PU 105K, SO 65K, RILDS. 06:45 07:00 0.25 13,305 13,305 COMPZ RPCOM PRTS P Test hanger void to250 psi for 5 min. &5000 psi for 10 min,witnessed by CPAI Rep. 07:00 10:15 3.25 13,305 13,305 COMPZ RPCOM PRTS P PJSM, PT annulus to test SBE seals 1000 psi for 10 min. PT tubing 3500 psi for 30 min, bleed to 2000 psi& shut in. PT annulus to 3500 psi for 30 min. Dump tubing pressure& observe shear on SOV. Bleed off all pressure.All test recorded on a chart. 10:15 11:00 0.75 13,305 13,305 COMPZ RPCOM OWFF P Monitor well,static. 11:00 11:30 0.50 13,305 0 COMPZ WHDBO MPSP P PJSM, set BPV. Pressure up IA to 3000 psi to test BPV&hanger in the direction of flow, charted. 11:30 12:00 0.50 0 0 COMPZ WHDBO OWFF P Monitor well,static. OA 340 psi. 12:00 14:45 2.75 0 0 COMPZ WHDBO SEQP P PJSM, blow down MPD lines& choke skid. clean rig floor. Sim-ops flush pumps. 14:45 16:30 1.75 0 0 COMPZ WHDBO SEQP P PJSM, pull trip nipple, rig down MPD lines&Katch Kan. Spill Drill CRT 137 sec&16:30 hrs. 16:30 18:00 1.50 0 0 COMPZ WHDBO OTHR P PJSM, clean BOPE&rig down scaffolding. 18:00 18:45 0.75 0 0 COMPZ WHDBO NUND P PJSM, nipple down BOPE. 18:45 19:15 0.50 0 0 COMPZ WHDBO MPSP P PJSM, CIW rep, install dart in BPV. 19:15 21:15 2.00 0 0 COMPZ WHDBO NUND P Prep adapter flange, orient adapter flange per drawing&DSO, nipple up adapter flange. Page 40 of 41 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 21:15 22:15 1.00 0 0 COMPZ WHDBO PRTS P Fill adapter void. Test SRL seals& dart to 5000 psi per CIW procedure. Test hanger&adapter void to 5000 psi for 10 min,witnessed by CPAI rep. 22:15 23:15 1.00 0 0 COMPZ WHDBO NUND P Nipple up CIW 4.0625"tree as per CIW rep. 23:15 23:45 0.50 0 0 COMPZ WHDBO PRTS P PJSM,test tree, SRL seals&dart to 5000 psi for 10 min,witnessed by CPAI rep. 23:45 00:00 0.25 0 0 COMPZ WHDBO MPSP P Pull dart&BPV per CIW rep. OA 200 psi. 31/18/2015 Freeze protect well&u-tube. Set type H, BPV&test in the direction of flow to 1000 psi. Secure well. Lay down 4"DP from derrick. Slip&cut drill line. Demob in preparation for RDMO to 3S-620 Rig release©24:00 hrs. 00:00 02:30 2.50 0 0 COMPZ WHDBO FRZP P PJSM, rig up Little Red lines&PT to 2500 psi. Pump 88 bbls of diesel down IA,taking returns from tubing, 2 bpm, ICP 650 psi, FCP 1050 psi. Shut in with 500 psi. Line up to U-tube. 02:30 03:30 1.00 0 0 COMPZ WHDBO FRZP P PJSM, remove valve from RCD head. Continue to U-tube diesel. Sim-ops clean pits, disassemble mud pumps, &RU mouse hole. 03:30 04:30 1.00 0 0 COMPZ WHDBO FRZP P PJSM,continue to U-tube well. Sim-ops RU&lay down 4"DP from derrick. 04:30 05:30 1.00 0 0 COMPZ WHDBO FRZP P PJSM, rig up lubricator&continue to U-tube well. 05:30 06:00 0.50 0 0 COMPZ WHDBO FRZP P Observe U-tube @ 320 psi on tubing &IA. Shut in. 06:00 08:00 2.00 0 0 COMPZ WHDBO MPSP P PJSM,test lubricator to 1500 psi, set type H BPV. Rig down lubricator. Test BPV in direction of flow to 1000 psi. 08:00 09:30 1.50 0 0 DEMOB MOVE RURD P PJSM, rig down&blow down all lines. Secure well. Spill Drill CRT 120 sec @ 08:30 hrs. 09:30 21:45 12.25 0 0 DEMOB MOVE PULD P PJSM, lay down 4"DP from derrick. 21:45 22:15 0.50 0 0 DEMOB MOVE RURD P PJSM, lay down mouse hole&clear rig floor. 22:15 23:30 1.25 0 0 DEMOB MOVE SLPC P PJSM, slip&cut 60'of drill line. 23:30 00:00 0.50 0 0 DEMOB MOVE RURD P Clean up in preparation for rig move. Rig Release @ 24:00 hrs. Page 41 of 41 2F-22 WELL WORK SUMMARY POST RIG WELL WORK DATE SUMMARY 2/2/2015 GAUGED TBG TO 2.77"TO 13230' SLM. SET CATCHER @ 2887' SLM. PULLED SOV AND SET OV @ 2835' RKB. MIT TBG 3000 PSI, PASSED. PULLED CATCHER @ 2887' SLM. PULLED BALL/ROD AND RHC @ 13256' RKB. COMPLETE. NADConversion Kuparuk River Unit Kuparuk 2F Pad 2F-22 Definitive Survey Report N A D 2 7 27 January, 2015 Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well 2F-22 Project: Kuparuk River Unit TVD Reference: Rig:95.8+27.75 @ 123.55usft(Doyon 141) Site: Kuparuk 2F Pad MD Reference: Rig:95.8+27.75 @ 123.55usft(Doyon 141) Well: 2F-22 North Reference: True Wellbore: 2F-22 Survey Calculation Method: Minimum Curvature Design: 2F-22 Database: OAKEDMP2 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 2F-22 Well Position +N/-S 0.00 usft Northing: 5,948,652.00 usft Latitude: 70°16'15.190 N +E/-W 0.00 usft Easting: 517,511.06 usft Longitude: 149°51'30.172 W Position Uncertainty 0.00 usft Wellhead Elevation: usft Ground Level: 95.80 usft Wellbore 2F-22 Magnetics Model Name Sample Date Declination Dip Angle Field Strength (°) (°) (nT) BGG M2014 11/25/2014 19.05 80.87 57,567 Design 2F-22 -- -- -_- - Audit Notes: Version: 1.0 Phase: ACTUAL Tie On Depth: 27.75 Vertical Section: Depth From(TVD) +N/-S +EI-W Direction (usft) (usft) (usft) (°) 27.75 0.00 0.00 183.00 Survey Program Date From To (usft) (usft) Survey(Wellbore) Tool Name Description Survey Date 79.61 1,008.41 2F-22 Srvy#1-GYD-GC-SS(2F-22) GYD-GC-SS Gyrodata gyro single shots 12/12/2014 3:1E 1,063.31 3,770.69 2F-22 Srvy#2-MWD+IFR-AK-CAZ-SC( MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 12/12/2014 3:1E 3,770.69 13,406.12 2F-22 Srvy#3-MWD+IFR-AK-CAZ-SC( MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 12/18/2014 9:11 13,506.29 21,928.00 2F-22 Srvy#4-MWD+IFR-AK-CAZ-SC( MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 1/2/2015 5:11:01 Survey Map Map Vertical MD Inc Azi TVD TVDSS +NIS +E/-W Northing Easting DLS Section (usft) (°) (°) (usft) (usft) (usft) (usft) (ft) (ft) (°/100') (ft) Survey Tool Name 27.75 0.00 0.00 27.75 -95.80 0.00 0.00 5,948,652.00 517,511.06 0.00 0.00 UNDEFINED 1 79.62 0.23 265.47 79.62 -43.93 -0.01 -0.10 5,948,651.99 517,510.95 0.44 0.01 GYD-GC-SS(1) 182.45 0.46 217.97 182.45 58.90 -0.35 -0.56 5,948,651.65 517,510.49 0.34 0.38 GYD-GC-SS(1) 265.72 0.37 214.18 265.72 142.17 -0.84 -0.92 5,948,651.16 517,510.14 0.11 0.88 GYD-GC-SS(1) 357.72 0.69 240.40 357.71 234.16 -1.36 -1.57 5,948,650.64 517,509.49 0.43 1.44 GYD-GC-SS(1) 453.67 1.58 247.75 453.64 330.09 -2.14 -3.30 5,948,649.85 517,507.77 0.94 2.31 GYD-GC-SS(1) 546.40 2.34 260.25 546.32 422.77 -2.95 -6.34 5,948,649.04 517,504.72 0.94 3.27 GYD-GC-SS(1) 638.12 3.11 264.69 637.93 514.38 -3.49 -10.67 5,948,648.48 517,500.40 0.87 4.05 GYD-GC-SS(1) 731.57 5.74 266.92 731.10 607.55 -3.98 -17.86 5,948,647.98 517,493.21 2.82 4.91 GYD-GC-SS(1) 826.60 9.95 264.08 825.22 701.67 -5.08 -30.78 5,948,646.85 517,480.29 4.45 6.69 GYD-GC-SS(1) 915.27 12.72 260.69 912.15 788.60 -7.45 -48.03 5,948,644.44 517,463.04 3.21 9.96 GYD-GC-SS(1) 1/27/2015 10:29:49AM Page 2 COMPASS 5000.1 Build 65 Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well 2F-22 Project: Kuparuk River Unit TVD Reference: Rig:95.8+27.75 @ 123.55usft(Doyon 141) Site: Kuparuk 2F Pad MD Reference: Rig:95.8+27.75 @ 123.55usft(Doyon 141) Well: 2F-22 North Reference: True Wellbore: 2F-22 Survey Calculation Method: Minimum Curvature Design: 2F-22 Database: OAKEDMP2 Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +E/-W Northing Easting DLS Section (usft) (°) (°) (usft) (usft) (usft) (usft) (ft) (ft) (°1100') (ft) Survey Tool Name 1,008.41 14.15 262.44 1,002.74 879.19 -10.61 -69.44 5,948,641.23 517,441.65 1.60 14.23 GYD-GC-SS(1) 1,063.31 16.97 260.70 1,055.62 932.07 -12.79 -84.00 5,948,639.02 517,427.09 5.21 17.17 MWD+IFR-AK-CAZ-SC(2) 1,122.73 20.05 258.68 1,111.96 988.41 -16.19 -102.55 5,948,635.57 517,408.55 5.29 21.53 MWD+IFR-AK-CAZ-SC(2) 1,158.10 21.73 257.16 1,145.01 1,021.46 -18.83 -114.88 5,948,632.90 517,396.23 4.99 24.82 MWD+IFR-AK-CAZ-SC(2) 1,207.34 22.32 256.15 1,190.65 1,067.10 -23.10 -132.85 5,948,628.59 517,378.28 1.42 30.02 MWD+IFR-AK-CAZ-SC(2) 1,251.53 22.96 255.34 1,231.44 1,107.89 -27.29 -149.33 5,948,624.37 517,361.80 1.61 35.07 MWD+IFR-AK-CAZ-SC(2) 1,346.03 21.90 254.44 1,318.79 1,195.24 -36.68 -184.14 5,948,614.89 517,327.02 1.18 46.27 MWD+11R-AK-CAZ-SC(2) 1,439.88 21.48 253.71 1,405.99 1,282.44 -46.20 -217.50 5,948,605.30 517,293.69 0.53 57.51 MWD+IFR-AK-CAZ-SC(2) 1,531.81 23.47 247.64 1,490.95 1,367.40 -57.88 -250.59 5,948,593.54 517,260.63 3.32 70.92 MWD+IFR-AK-CAZ-SC(2) 1,628.24 26.31 241.06 1,578.43 1,454.88 -75.54 -287.07 5,948,575.80 517,224.20 4.11 90.46 MWD+IFR-AK-CAZ-SC(2) 1,720.45 28.11 239.22 1,660.43 1,536.88 -96.54 -323.62 5,948,554.71 517,187.70 2.15 113.35 MW3+1FR-AK-CAZ-SC(2) 1,816.96 28.19 238.07 1,745.53 1,621.98 -120.23 -362.50 5,948,530.93 517,148.88 0.57 139.04 MWD+IFR-AK-CAZ-SC(2) 1,913.45 30.73 235.12 1,829.54 1,705.99 -146.39 -402.07 5,948,504.69 517,109.37 3.03 167.23 MWD+IFR-AK-CAZ-SC(2) 2,008.67 32.06 231.04 1,910.82 1,787.27 -176.20 -441.69 5,948,474.79 517,069.83 2.63 199.07 M1D+IFR-AK-CAZ-SC(2) 2,100.43 35.23 225.62 1,987.22 1,863.67 -210.04 -479.56 5,948,440.86 517,032.04 4.76 234.85 MWD+IFR-AK-CAZ-SC(2) 2,195.13 38.35 225.07 2,063.05 1,939.50 -249.90 -519.89 5,948,400.91 516,991.80 3.31 276.77 MWD+IFR-AK-CAZ-SC(2) 2,289.34 41.58 222,06 2,135.25 2,011.70 -293.77 -561.54 5,948,356.95 516,950.26 3.99 322.76 MWD+IFR-AK-CAZ-SC(2) 2,383.00 43.50 221.18 2,204.26 2,080.71 -341.11 -603.59 5,948,309.52 516,908.32 2.15 372.23 M1MD+IFR-AK-CAZSC(2) 2,468.98 45.03 217.26 2,265.84 2,142.29 -387.60 -641.49 5,948,262.94 516,870.53 3.65 420.64 MWD+1FR-AK-CAZSC(2) 2,564.60 46.45 215.40 2,332.58 2,209.03 -442.77 -682.05 5,948,207.68 516,830.11 2.04 477.86 MWD+IFR-AK-CAZ-SC(2) 2,657.20 49.07 211.56 2,394.84 2,271.29 -499.95 -719.81 5,948,150.42 516,792.48 4.17 536.94 MWD+IFR-AK-CAZ-SC(2) 2,748.49 52.56 207.08 2,452.52 2,328.97 -561.65 -754.38 5,948,088.65 516,758.06 5.39 600.36 M1MD+IFR-AK-CAZSC(2) 2,819.51 53.91 204.63 2,495.03 2,371.48 -612.84 -779.18 5,948,037.41 516,733.38 3.35 652.78 MWD+IFR-AK-CAZSC(2) 2,842.45 53.97 204.33 2,508.54 2,384.99 -629.72 -786.86 5,948,020.51 516,725.74 1.09 670.04 MWD+IFR-AK-CAZ-SC(2) 2,934.83 55.11 203.25 2,562.13 2,438.58 698.57 -817.21 5,947,951.60 516,695.55 1.56 740.38 MWD+1FR-AK-CAZ-SC(2) 3,027.00 57.68 201.85 2,613.14 2,489.59 -769.46 -846.63 5,947,880.64 516,666.30 3.06 812.72 MWD+1FR-AK-CAZ-SC(2) 3,120.12 60.71 199.71 2,660.83 2,537.28 -844.24 -874.98 5,947,805.81 516,638.13 3.81 888.87 MWD+IFR-AK-CAZ-SC(2) 3,212.18 61.25 199.23 2,705.49 2,581.94 -920.13 -901.81 5,947,729.86 516,611.48 0.74 966.07 MWD+1FR-AK-CAZ-SC(2) 3,305.12 63.03 197.79 2,748.92 2,625.37 -998.05 -927.89 5,947,651.89 516,585.59 2.35 1,045.24 MIND+1FR-AK-CAZ-SC(2) 3,396.84 65.11 196.46 2,789.03 2,665.48 -1,076.87 -952.17 5,947,573.02 516,561.49 2.62 1,125.23 MWD+IFR-AK-CAZSC(2) 3,491.62 67.26 194.77 2,827.30 2,703.75 -1,160.38 -975.49 5,947,489.47 516,538.36 2.79 1,209.84 MWD+IFR-AK-CAZ-SC(2) 3,585.58 68.57 192.07 2,862.63 2,739.08 -1,245.06 -995.69 5,947,404.75 516,518.37 3.01 1,295.46 MWD+IFR-AK-CAZ-SC(2) 3,679.77 70.33 190.19 2,895.69 2,772.14 -1,331.59 -1,012.70 5,947,318.19 516,501.55 2.64 1,382.76 MWD+IFR-AK-CAZ-SC(2) 3,770.69 70.13 188.59 2,926.45 2,802.90 -1,416.00 -1,026.66 5,947,233.76 516,487.79 1.67 1,467.79 MWD+IFR-AK-CAZ-SC(2) 3,836.66 71.73 189.53 2,948.00 2,824.45 -1,477.57 -1,036.48 5,947,172.17 516,478.12 2.77 1,529.79 MW0+1FR-AK-CAZ-SC(3) 3,904.00 71.44 188.62 2,969.27 2,845.72 -1,540.66 -1,046.56 5,947,109.06 516,468.19 1.36 1,593.32 MWD+IFR-AK-CAZ-SC(3) 10 3/4"x 13-1/2 3,935.28 71.31 188.19 2,979.26 2,855.71 -1,569.98 -1,050.89 5,947,079.73 516,463.93 1.36 1,622.83 MWD+IFR-AK-CAZ-SC(3) 3,999.54 72.33 187.79 2,999.31 2,875.76 -1,630.44 -1,059.38 5,947,019.26 516,455.58 1.69 1,683.65 MW0+IFR-AK-CAZ-SC(3) 4,091.35 71.16 188.56 3,028.07 2,904.52 -1,716.74 -1,071.77 5,946,932.94 516,443.39 1.50 1,770.48 MWD+IFR-AK-CAZ-SC(3) 1/27/2015 10:29:49AM Page 3 COMPASS 5000.1 Build 65 Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well 2F-22 Project: Kuparuk River Unit TVD Reference: Rig:95.8+27.75 @ 123.55usft(Doyon 141) Site: Kuparuk 2F Pad MD Reference: Rig:95.8+27.75 @ 123.55usft(Doyon 141) Well: 2F-22 North Reference: True Wellbore: 2F-22 Survey Calculation Method: Minimum Curvature Design: 2F-22 Database: OAKEDMP2 Survey Map Map Vertical MD Inc Azi TVD TVDSS +NI-S +EI-W Northing Easting DLS Section (usft) (°) (°) (usft) (usft) (usft) (usft) (ft) (ft) (°/100') (ft) Survey Tool Name 4,183.94 71.33 188.24 3,057.84 2,934.29 -1,803.47 -1,084.58 5,946,846.19 516,430.78 0.38 1,857.76 MWD+IFR-AK-CAZ-SC(3) 4,279.19 70.61 188.55 3,088.90 2,965.35 -1,892.55 -1,097.72 5,946,757.09 516,417.85 0.82 1,947.41 MWD+IFR-AK-CAZ-SC(3) 4,372.49 70.69 188.84 3,119.81 2,996.26 -1,979.57 -1,111.03 5,946,670.05 516,404.74 0.31 2,035.00 MWD+IFR-AK-CAZ-SC(3) 4,464.41 70.72 189.07 3,150.19 3,026.64 -2,065.27 -1,124.54 5,946,584.32 516,391.44 0.24 2,121.29 MWD+IFR-AK-CAZ-SC(3) 4,560.77 70.56 190.28 3,182.13 3,058.58 -2,154.89 -1,139.81 5,946,494.68 516,376.37 1.20 2,211.59 MWD+IFR-AK-CAZ-SC(3) 4,655.31 70.45 190.56 3,213.68 3,090.13 -2,242.54 -1,155.93 5,946,407.00 516,360.46 0.30 2,299.96 MWD+IFR-AK-CAZ-SC(3) 4,747.57 70.44 190.85 3,244.56 3,121.01 -2,327.96 -1,172.08 5,946,321.55 516,344.51 0.30 2,386.11 MWD+IFR-AK-CAZ-SC(3) 4,840.10 70.51 190.77 3,275.49 3,151.94 -2,413.62 -1,188.44 5,946,235.86 516,328.35 0.11 2,472.51 M1.MD+IFR-AK-CAZ-SC(3) 4,933.29 70.54 190.87 3,306.56 3,183.01 -2,499.92 -1,204.93 5,946,149.53 516,312.06 0.11 2,559.55 MW3+IFR-AK-CAZ-SC(3) 5,026.96 70.47 190.67 3,337.82 3,214.27 -2,586.66 -1,221.43 5,946,062.76 516,295.77 0.21 2,647.04 MWD+IFR-AK-CAZ-SC(3) 5,122.63 70.36 190.89 3,369.88 3,246.33 -2,675.21 -1,238.29 5,945,974.18 516,279.12 0.25 2,736.35 MWD+IFR-AK-CAZ-SC(3) 5,214.46 70.29 190.83 3,400.80 3,277.25 -2,760.13 -1,254.58 5,945,889.23 516,263.02 0.10 2,822.01 MWD+IFR-AK-CAZ-SC(3) 5,310.61 70.49 190.51 3,433.07 3,309.52 -2,849.14 -1,271.35 5,945,800.20 516,246.46 0.38 2,911.77 MWD+IFR-AK-CAZ-SC(3) 5,404.73 70.99 190.29 3,464.12 3,340.57 -2,936.53 -1,287.39 5,945,712.78 516,230.63 0.58 2,999.88 MWD+IFR-AK-CAZ-SC(3) 5,497.45 70.99 190.90 3,494.32 3,370.77 -3,022.70 -1,303.51 5,945,626.58 516,214.71 0.62 3,086.77 MWD+IFR-AK-CAZ-SC(3) 5,589.44 71.02 190.71 3,524.26 3,400.71 -3,108.13 -1,319.82 5,945,541.11 516,198.61 0.20 3,172.95 MW3+IFR-AK-CAZ-SC(3) 5,683.39 70.93 190.90 3,554.89 3,431.34 -3,195.38 -1,336.47 5,945,453.84 516,182.16 0.21 3,260.94 MWD+IFR-AK-CAZ-SC(3) 5,775.45 70.99 190.24 3,584.92 3,461.37 -3,280.92 -1,352.43 5,945,368.26 516,166.40 0.68 3,347.21 MWD+IFR-AK-CAZ-SC(3) 5,870.15 71.05 188.82 3,615.72 3,492.17 -3,369,24 -1,367.25 5,945,279.92 516,151.78 1.42 3,436.18 MWD+IFR-AK-CAZ-SC(3) 5,962.92 70.93 188.61 3,645.94 3,522.39 -3,455.94 -1,380.54 5,945,193.21 516,138.69 0.25 3,523.45 MWD+IFR-AK-CAZ-SC(3) 6,055.51 70.65 188.68 3,676.41 3,552.86 -3,542.38 -1,393.69 5,945,106.74 516,125.75 0.31 3,610.46 MWD+IFR-AK-CAZ-SC(3) 6,148.00 70.69 189.06 3,707.02 3,583.47 -3,628.61 -1,407.14 5,945,020.49 516,112.50 0.39 3,697.28 MWD+IFR-AK-CAZ-SC(3) 6,240.11 70.57 189.23 3,737.57 3,614.02 -3,714.40 -1,420.95 5,944,934.67 516,098.89 0.22 3,783.68 MWD+IFR-AK-CAZ-SC(3) 6,333.12 70.50 189.18 3,768.56 3,645.01 -3,800.96 -1,434.98 5,944,848.08 516,085.06 0.09 3,870.86 MWD+IFR-AK-CAZ-SC(3) 6,427.37 70.56 189.21 3,799.98 3,676.43 -3,888,68 -1,449.18 5,944,760.34 516,071.07 0.07 3.959.20 MWD+IFR-AK-CAZSC(3) 6,520.58 70.56 190.04 3,831.00 3,707.45 -3,975.34 -1,463.88 5,944,673.66 516,056.58 0.84 4,046.51 MWD+IFR-AK-CAZ-SC(3) 6,612.63 70.57 189.93 3,861.63 3,738.08 -4,060.83 -1,478.93 5,944,588.14 516,041.72 0.11 4,132.67 M1MD+IFR-AK-CAZ-SC(3) 6,706.10 70.45 190.10 3,892.82 3,769.27 -4,147.60 -1,494.25 5,944,501.34 516,026.60 0.21 4,220.12 MWD+IFR-AK-CAZ-SC(3) 6,799.85 70.57 188.99 3,924.10 3,800.55 -4,234.76 -1,508.91 5,944,414.17 516,012.15 1.12 4,307.92 MWD+IFR-AK-CAZ-SC(3) 6,892.41 70.50 188.51 3,954.94 3,831.39 -4,321.01 -1,522.18 5,944,327.89 515,999.08 0.49 4,394.75 MWD+IFR-AK-CAZSC(3) 6,985.30 70.44 188.50 3,985.99 3,862.44 -4,407.59 -1,535.13 5,944,241.29 515,986.34 0.07 4,481.89 MWD+IFR-AK-CAZ-SC(3) 7,077.37 70.82 188.77 4,016.53 3,892.98 -4,493.47 -1,548.17 5,944,155.39 515,973.50 0.50 4,568.33 MWD+IFR-AK-CAZ-SC(3) 7,169.13 70.37 188.93 4,047.02 3,923.47 -4,578.98 -1,561.49 5,944,069.85 515,960.38 0.52 4,654.43 MWD+IFR-AK-CAZ-SC(3) 7,263.54 70.35 188.35 4,078.75 3,955.20 -4,666.89 -1,574.84 5,943,981.92 515,947.23 0.58 4,742.92 MWD+IFR-AK-CAZ-SC(3) 7,356.21 70.39 189.04 4,109.88 3,986.33 -4,753.17 -1,588.04 5,943,895.62 515,934.24 0.70 4,829.77 MWD+IFR-AK-CAZ-SC(3) 7,448.46 70.41 189.81 4,140.83 4,017.28 -4,838.90 -1,602.27 5,943,809.86 515,920.21 0.79 4,916.13 MWD+IFR-AK-CAZ-SC(3) 7,541.64 70.78 189.65 4,171.78 4,048.23 -4,925.52 -1,617.12 5,943,723.22 515,905.56 0.43 5,003.41 MW3+IFR-AK-CAZ-SC(3) 7,636.07 70.81 190.67 4,202.85 4,079.30 -5,013.30 -1,632.85 5,943,635.41 515,890.03 1.02 5,091.89 MW3+IFR-AK-CAZSC(3) 7,727.50 70.77 191.44 4,232.93 4,109.38 -5,098.04 -1,649.41 5,943,550.65 515,873.68 0.80 5,177.37 MWD+IFR-AK-CAZ-SC(3) 7,820.25 70.84 191.33 4,263.43 4,139.88 -5,183.91 -1,666.70 5,943,464.75 515,856.59 0.14 5,264.03 MWD+IFR-AK-CAZ-SC(3) 1/27/2015 10:29:49AM Page 4 COMPASS 5000.1 Build 65 Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well 2F-22 Project Kuparuk River Unit TVD Reference: Rig:95.8+27.75 @ 123.55usft(Doyon 141) Site: Kuparuk 2F Pad MD Reference: Rig:95.8+27.75 @ 123.55usft(Doyon 141) Well: 2F-22 North Reference: True Wellbore: 2F-22 Survey Calculation Method: Minimum Curvature Design: 2F-22 Database: OAKEDMP2 Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +E/-W Northing Easting DLS Section (usft) (°) (°) (usft) (usft) (usft) (usft) (ft) (ft) (°/100') (ft) Survey Tool Name 7,912.41 70.78 191.61 4,293.72 4,170.17 -5,269.21 -1,684.01 5,943,379.41 515,839.48 0.29 5,350.12 MWD+IFR-AK-CAZ-SC(3) 8,004.59 70.80 190.69 4,324.05 4,200.50 -5,354.61 -1,700.84 5,943,293.98 515,822.85 0.94 5,436.29 MWD+IFR-AK-CAZ-SC(3) 8,096.10 70.83 191.37 4,354.12 4,230.57 -5,439.44 -1,717.38 5,943,209.12 515,806.51 0.70 5,521.87 MWD+IFR-AK-CAZ-SC(3) 8,189.06 70.90 191.29 4,384.59 4,261.04 -5,525.55 -1,734.63 5,943,122.98 515,789.46 0.11 5,608.76 MWD+IFR-AK-CAZ-SC(3) 8,281.88 70.90 190.28 4,414.97 4,291.42 -5,611.71 -1,751.04 5,943,036.79 515,773.25 1.03 5,695.66 MWD+IFR-AK-CAZ-SC(3) 8,374.58 70.81 189.07 4,445.37 4,321.82 -5,698.04 -1,765.76 5,942,950.44 515,758.73 1.24 5,782.64 MWD+IFR-AK-CAZ-SC(3) 8,466.97 70.86 188.19 4,475.70 4,352.15 -5,784.32 -1,778.86 5,942,864.13 515,745.84 0.90 5,869.49 MWD+IFR-AK-CAZ-SC(3) 8,559.31 70.87 188.38 4,505.97 4,382.42 -5,870.65 -1,791.43 5,942,777.79 515,733.47 0.19 5,956.36 MWD+IFR-AK-CAZ-SC(3) 8,652.06 70.81 189.09 4,536.41 4,412.86 -5,957.24 -1,804.73 5,942,691.17 515,720.37 0.73 6,043.53 MWD+IFR-AK-CAZ-SC(3) 8,744.62 70.47 190.04 4,567.10 4,4.43.55 -6,043.35 -1,819.24 5,942,605.03 515,706.06 1.04 6,130.28 MWD+1FR-AK-CAZ-SC(3) 8,838.16 70.33 190.41 4,598.47 4,474.92 -6,130.07 -1,834.88 5,942,518.29 515,690.62 0.40 6,217.70 MWD+IFR-AK-CAZ-SC(3) 8,932.02 70.29 190.41 4,630.10 4,506.55 -6,216.99 -1,850.85 5,942,431.34 515,674.86 0.04 6,305.33 MWD+IFR-AK-CAZ-SC(3) 9,025.77 70.29 189.77 4,661.72 4,538.17 -6,303.88 -1,866.31 5,942,344.42 515,659.60 0.64 6,392.92 MWD+1FR-AK-CAZ-SC(3) 9,121.23 70.33 188.99 4,693.88 4,570.33 -6,392.56 -1,880.96 5,942,255.72 515,645.16 0.77 6,482.24 MWD+IFR-AK-CAZ-SC(3) 9,214.67 70.31 188.35 4,725.35 4,601.80 -6,479.53 -1,894.22 5,942,168.72 515,632.10 0.65 6,569.79 MWD+IFR-AK-CAZSC(3) 9,309.79 70.82 187.66 4,757.00 4,633.45 -6,568.36 -1,906.71 5,942,079.88 515,619.82 0.87 6,659.15 MWD+IFR-AK-CAZ-SC(3) 9,402.57 70.84 188.17 4,787.47 4,663.92 -6,655.16 -1,918.78 5,941,993.06 515,607.95 0.52 6,746.46 MWD+IFR-AK-CAZSC(3) 9,494.53 70.81 188.25 4,817.67 4,694.12 -6,741.13 -1,931.19 5,941,907.07 515,595.75 0.09 6,832.96 MWD+IFR-AK-CAZSC(3) 9,587.51 70.78 189.15 4,848.26 4,724.71 -6,827.92 -1,944.47 5,941,820.25 515,582.67 0.91 6,920.33 MWD+IFR-AK-CAZ-SC(3) 9,679.82 70.87 190.54 4,878.58 4,755.03 .6,913.82 -1,959.37 5,941,734.33 515,567.97 1.43 7,006.89 MWD+IFR-AK-CAZ-SC(3) 9,772.05 70.81 190.61 4,908.85 4,785.30 -6,999.46 -1,975.36 5,941,648.66 515,552.18 0.10 7,093.25 MWD+IFR-AK-CAZ-SC(3) 9,865.73 70.83 194.51 4,939.64 4,816.09 -7,085.81 -1,994.60 5,941,562.28 515,533.14 3.93 7,180.48 MWD+IFR-AK-CAZSC(3) 9,958.53 70.84 190.02 4,970.12 4,846.57 -7,171.43 -2,013.22 5,941,476.61 515,514.73 4.57 7,266.97 MWD+1FR-AK-CAZSC(3) 10,052.49 70.86 189.12 5,000.94 4,877.39 -7,258.96 -2,027.97 5,941,389.06 515,500.18 0.91 7,355.15 MWD+1FR-AK-CAZ-SC(3) 10,144.74 70.87 188.76 5,031.18 4,907.63 -7,345.05 -2,041.52 5,941,302.95 515,486.84 0.37 7,441.83 MWD+IFR-AK-CAZSC(3) 10,238.14 70.87 188.36 5,061.79 4,938.24 -7,432.31 -2,054.65 5,941,215.67 515,473.91 0.40 7,529.66 MWD+1FR-AK-CAZ-SC(3) 10,330.92 70.87 188.66 5,092.19 4,968.6.4 -7,519.00 -2,067.62 5,941,128.95 515,461.14 0.31 7,616.91 MWD+IFR-AK-CAZ-SC(3) 10,422.53 70.92 188.65 5,122.18 4,998.63 -7,604.58 -2,080.65 5,941,043.35 515,448.31 0.06 7,703.05 MWD+IFR-AK-CAZ-SC(3) 10,516.36 70.34 188.18 5,153.30 5,029.75 -7,692.15 -2,093.60 5,940,955.77 515,435.56 0.78 7,791.18 MWD+IFR-AK-CAZ-SC(3) 10,611.60 70.29 187.70 5,185.38 5,061.83 -7,780.96 -2,105.99 5,940,866.93 515,423.38 0.48 7,880.52 MWD+IFR-AK-CAZSC(3) 10,706.55 70.48 188.05 5,217.25 5,093.70 -7,869.56 -2,118.24 5,940,778.32 515,411.34 0.40 7,969.63 MWD+IFR-AK-CAZ-SC(3) 10,799.05 70.39 188.57 5,248.23 5,124.68 -7,955.80 -2,130.84 5,940,692.05 515,398.94 0.54 8,056.42 MIND+IFR-AK-CAZ-SC(3) 10,892.96 70.38 190.33 5,279.76 5,156.21 -8,043.06 -2,145.36 5,940,604.77 515,384.62 1.77 8,144.31 MWD+IFR-AK-CAZSC(3) 10,987.14 70.41 190.46 5,311.36 5,187.81 -8,130.32 -2,161.37 5,940,517.48 515,368.82 0.13 8,232.30 MWD+IFR-AK-CAZ-SC(3) 11,081.74 70.50 190.28 5,343.00 5,219.45 -8,218.01 -2,177.42 5,940,429.76 515,352.98 0.20 8,320.71 MWD+IFR-AK-CAZ-SC(3) 11,179.28 70.87 189.73 5,375.27 5,251.72 -8,308.66 -2,193.41 5,940,339.08 515,337.20 0.65 8,412.07 MWD+IFR-AK-CAZ-SC(3) 11,274.31 70.90 189.95 5,406.39 5,282.84 -8,397.13 -2,208.76 5,940,250.59 515,322.06 0.22 8,501.22 MWD+1FR-AK-CAZ-SC(3) 11,366.07 70.93 190.06 5,436.39 5,312.84 -8,482.53 -2,223.82 5,940,165.16 515,307.20 0.12 8,587.29 MWD+1FR-AK-CAZ-SC(3) 11,459.77 70.96 190.36 5,466.98 5,343.43 -8,569.69 -2,239.52 5,940,077.97 515,291.70 0.30 8,675.16 MWD+IFR-AK-CAZ-SC(3) 11,550.97 70.97 191.07 5,496.72 5,373.17 -8,654.40 -2,255.55 5,939,993.23 515,275.87 0.74 8,760.59 M1ND+IFR-AK-CAZ-SC(3) 1/27/2015 10.29:49AM Page 5 COMPASS 5000.1 Build 65 Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well 2F-22 Project: Kuparuk River Unit TVD Reference: Rig:95.8+27.75 @ 123.55usft(Doyon 141) Site: Kuparuk 2F Pad MD Reference: Rig:95.8+27.75 @ 123.55usft(Doyon 141) Well: 2F-22 North Reference: True Wellbore: 2F-22 Survey Calculation Method: Minimum Curvature Design: 2F-22 Database: OAKEDMP2 Survey Map Map Vertical MD Inc Azi TVD TVDSS +N!-S +E/-W Northing Easting DLS Section (usft) (0) (°) (usft) (usft) (usft) (usft) (ft) (ft) (°/100') (ft) Survey Tool Name 11,642.21 70.69 191.31 5,526.69 5,403.14 -8,738.94 -2,272.27 5,939,908.66 515,259.34 0.39 8,845.89 MWD+IFR-AK-CAZ-SC(3) 11,737.09 70.88 190.82 5,557.91 5,434.36 -8,826.87 -2,289.47 5,939,820.70 515,242.36 0.53 8,934.60 MWD+IFR-AK-CAZSC(3) 11,828.79 70.82 190.09 5,587.99 5,464.44 -8,912.06 -2,305.19 5,939,735.49 515,226.84 0.75 9,020.49 MWD+IFR-AK-CAZ-SC(3) 11,921.83 70.37 190.23 5,618.91 5,495.36 -8,998.44 -2,320.67 5,939,649.08 515,211.56 0.50 9,107.56 MWD+IFR-AK-CAZ-SC(3) 12,014.20 70.39 190.23 5,649.92 5,526.37 -9,084.06 -2,336.12 5,939,563.43 515,196.31 0.02 9,193.88 MWD+IFR-AK-CAZ-SC(3) 12,106.02 70.32 189.17 5,680.79 5,557.24 -9,169.30 -2,350.69 5,939,478.17 515,181.94 1.09 9,279.76 MWD+IFR-AK-CAZ-SC(3) 12,198.75 70.33 188.59 5,712.01 5,588.46 -9,255.57 -2,364.17 5,939,391.88 515,168.66 0.59 9,366.62 MWD+IFR-AK-CAZ-SC(3) 12,292.53 70.38 188.29 5,743.54 5,619.99 -9,342.93 -2,377.13 5,939,304.49 515,155.90 0.31 9,454.54 MWD+IFR-AK-CAZ-SC(3) 12,384.91 70.58 188.48 5,774.41 5,650.86 -9,429.07 -2,389.83 5,939,218.33 515,143.41 0.29 9,541.22 MWD+IFR-AK-CAZ-SC(3) 12,477.20 70.72 188.79 5,804.99 5,681.44 -9,515.16 -2,402.90 5,939,132.22 515,130.54 0.35 9,627.88 MW3+IFR-AK-CAZ-SC(3) 12,569.97 70.78 188.89 5,835.57 5,712.02 -9,601.71 -2,416.36 5,939,045.65 515,117.28 0.12 9,715.01 MWD+IFR-AK-CA2-SC(3) 12,662.67 70.81 189.09 5,866.07 5,742.52 -9,688.17 -2,430.04 5,938,959.17 515,103.80 0.21 9,802.07 MWD+1FR-AK-CAZ-SC(3) 12,756.47 70.84 189.80 5,896.88 5,773.33 -9,775.57 -2,444.58 5,938,871.75 515,089.47 0.72 9,890.11 MWD+IFR-AK-CAZ-SC(3) 12,850.93 70.77 189.68 5,927.93 5,804.38 -9,863.49 -2,459.67 5,938,783.80 515,074.58 0.14 9,978.70 MWD+IFR-AK-CAZ-SC(3) 12,943.65 70.82 189.88 5,958.43 5,834.88 -9,949.78 -2,474.55 5,938,697.48 515,059.91 0.21 10,065.65 MWD+IFR-AK-CAZ-SC(3) 13,034.79 70.72 190.36 5,988.45 5,864.90 -10,034.49 -2,489.67 5,938,612.74 515,044.99 0.51 10,151.04 MWD+IFR-AK-CAZ-SC(3) 13,128.21 72.65 190.90 6,017.81 5,894.26 -10,121.65 -2,506.03 5,938,525.55 515,028.83 2.14 10,238.94 MWD+IFR-AK-CAZSC(3) 13,219.99 75.91 191.19 6,042.67 5,919.12 -10,208.35 -2,522.95 5,938,438.82 515,012.11 3.56 10,326.40 MWD+IFR-AK-CAZSC(3) 13,313.52 78.72 191.41 6,063.21 5,939.66 -10,297.82 -2,540.83 5,938,349.32 514,994.44 3.01 10,416.68 MWD+IFR-AK-CAZ-SC(3) 13,406.12 81.01 191.62 6,079.50 5,955.95 -10,387.13 -2,559.03 5,938,259.97 514,976.46 2.48 10,506.83 MWD+IFR-AK-CAZ-SC(3) 13,423.61 81.37 191.78 6,082.18 5,958.63 -10,404.06 -2,562.53 5,938,243.04 514,972.99 2.27 10,523.91 MWD+IFR-AK-CAZ-SC(4) 2F-22 01.TDInt 081214 LL 13,460.00 82.13 192.12 6,087.40 5,963.85 -10,439.29 -2,569.99 5,938,207.80 514,965.61 2.27 10,559.49 MWD+IFR-AK-CAZ-SC(4) 7-5/8"x 9-7/8" 13,506.29 83.09 192.55 6,093.35 5,969.80 -10,484.14 -2,579.80 5,938,162.93 514,955.91 2.27 10,604.78 MWD+IFR-AK-CAZSC(4) 13,601.11 83.04 193.28 6,104.80 5,981.25 -10,575.88 -2,600.84 5,938,071.15 514,935.09 0.77 10,697.50 MWD+IFR-AK-CAZ-SC(4) 13,696.16 84.75 191.04 6,114.91 5,991.36 -10,668.26 -2,620.74 5,937,978.73 514,915.40 2.95 10,790.80 MWD+IFR-AK-CAZ-SC(4) 13,790.67 86.29 190.12 6,122.29 5,998.74 -10,760.88 -2,638.04 5,937,886.09 514,898.32 1.90 10,884.19 MWD+IFR-AK-CAZ-SC(4) 13,885.65 87.49 189.87 6,127.45 6,003.90 -10,854.28 -2,654.50 5,937,792.66 514,882.08 1.29 10,978.33 MWD+IFR-AK-CAZSC(4) 13,951.50 89.24 188.38 6,129.32 6,005.77 -10,919.26 -2,664.93 5,937,727.65 514,871.80 3.50 11,043.77 MWD+IFR-AK-CAZ-SC(4) 2F-22 02.B 081214 LL 13,979.98 90.00 187.73 6,129.51 6,005.96 -10,947.46 -2,668.92 5,937,699.45 514,867.88 3.50 11,072.14 MWD+IFR-AK-CAZSC(4) 14,075.08 91.52 187.90 6,128.25 6,004.70 -11,041.67 -2,681.85 5,937,605.22 514,855.17 1.61 11,166.89 MWD+IFR-AK-CA2SC(4) 14,170.41 91.82 189.61 6,125.47 6,001.92 -11,135.84 -2,696.36 5,937,511.02 514,840.88 1.82 11,261.70 MWD+IFR-AK-CAZ-SC(4) 14,264.77 92.27 192.67 6,122.11 5,998.56 -11,228.35 -2,714.57 5,937,418.48 514,822.88 3.28 11,355.04 MW3+IFR-AK-CAZSC(4) 14,313.74 91.97 196.56 6,120.29 5,996.74 -11,275.70 -2,726.92 5,937,371.11 514,810.65 7.96 11.402.96 MW3+IFR-AK-CAZSC(4) 14,358.81 92.73 197.76 6,118.44 5,994.89 -11,318.72 -2,740.20 5,937,328.06 514,797.46 3.15 11,446.62 MWD+IFR-AK-CAZSC(4) 14,403.70 92.58 197.30 6,116.37 5,992.82 -11,361.48 -2,753.71 5,937,285.27 514,784.06 1.08 11,490.03 MWD+IFR-AK-CA2-SC(4) 14,453.00 92.92 197.45 6,114.00 5,990.45 -11,408.48 -2,768.42 5,937,238.25 514,769.46 0.75 11,537.73 MWD+IFR-AK-CAZ-SC(4) 14,505.71 92.86 196.41 6,111.34 5,987.79 -11,458.84 -2,783.75 5,937,187.85 514,754.25 1.97 11,588.83 MV43+IFR-AK-CAZ-SC(4) 2F-22 03.BaseC4 081214 LL 1/27/2015 10.29:49AM Page 6 COMPASS 5000.1 Build 65 Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well 2F-22 Project: Kuparuk River Unit TVD Reference: Rig:95.8+27.75 @ 123.55usft(Doyon 141) Site: Kuparuk 2F Pad MD Reference: Rig:95.8+27.75 @ 123.55usft(Doyon 141) Well: 2F-22 North Reference: True Wellbore: 2F-22 Survey Calculation Method: Minimum Curvature Design: 2F-22 Database: OAKEDMP2 Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +E/-W Northing Easting DLS Section (usft) (0) (0) (usft) (usft) (usft) (usft) (ft) (ft) 01001 (ft) Survey Tool Name 14,547.94 92.82 195.58 6,109.25 5,985.70 -11,499.38 -2,795.37 5,937,147.29 514,742.73 1.97 11,629.92 MWD+IFR-AK-CAZ-SC(4) 14,643.08 92.17 195.45 6,105.10 5,981.55 -11,590.97 -2,820.79 5,937,055.65 514,717.52 0.70 11,722.71 MW3+IFR-AK-CAZ-SC(4) 14,737.96 90.04 195.44 6,103.27 5,979.72 -11,682.40 -2,846,05 5,936,964.17 514,692.47 2.24 11,815.34 MW1D+IFR-AK-CAZ-SC(4) 14,832.40 91.22 195.24 6,102.24 5,978.69 -11,773.47 -2,871.04 5,936,873.05 514,667.70 1.27 11,907.59 MWD+1FR-AK-CAZ-SC(4) 14,926.29 90.07 196.14 6,101.18 5,977.63 -11,863.85 -2,896.43 5,936,782.62 514,642.53 1.56 11,999.18 MWD+1FR-AK-CAZ-SC(4) 15,020.80 88.39 196.04 6,102.45 5,978.90 -11,954.65 -2,922.62 5,936,691.77 514,616.55 1.78 12,091.22 MWD+1FR-AK-CAZ-SC(4) 15,024.51 88.33 196.03 6,102.56 5,979.01 -11,958.22 -2,923.64 5,936,688.20 514,615.53 1.62 12,094.84 MWD+1FR-AK-CAZ-SC(4) 2F-22 04.Fault2 081214 LL 15,115.54 86.88 195.78 6,106.36 5,982.81 -12,045.68 -2,948.56 5,936,600.69 514,590.82 1.62 12,183.49 MWD+1FR-AK-CAZ-SC(4) 15,210.61 88.46 194.71 6,110.22 5,986.67 -12,137.32 -2,973.54 5,936,509.00 514,566.06 2.01 12,276.31 MWD+IFR-AK-CAZ-SC(4) 15,304.40 90.81 192.36 6,110.82 5,987.27 -12,228.50 -2,995.49 5,936,417.79 514,544.33 3.54 12,368.51 MW3+IFR-AK-CAZ-SC(4) 15,399.33 91.43 191.00 6,108.97 5,985.42 -12,321.44 -3,014.70 5,936,324.81 514,525.33 1.57 12,462.33 MWD+IFR-AK-CAZ-SC(4) 15,493.98 89.95 191.86 6,107.83 5,984.28 -12,414.20 -3,033.45 5,936,232.01 514,506.79 1.81 12,555.95 M1.ND+IFR-AK-CAZ-SC(4) 15,588.55 90.24 190.99 6,107.67 5,984.12 -12,506.90 -3,052.19 5,936,139.28 514,488.28 0.97 12,649.50 MW3+IFR-AK-CAZ-SC(4) 15,590.04 90.24 190.97 6,107.66 5,984.11 -12,508.36 -3,052.47 5,936,137.81 514,488.00 1.48 12,650.97 MWD+1FR-AK-CAZ-SC(4) 2F-22 05.C4Crest 081214 LL 15,683.26 90.04 189.60 6,107.44 5,983.89 -12,600.08 -3,069.11 5,936,046.07 514,471.57 1.48 12,743.44 MWD+1FR-AK-CAZ-SC(4) 15,777.62 90.12 189.71 6,107.31 5,983.76 -12,693.10 -3,084.94 5,935,953.02 514,455.96 0.14 12,837.16 MWD+1FR-AK-CAZ-SC(4) 15,872.15 88.97 188.75 6,108.06 5,984.51 -12,786.40 -3,100.10 5,935,859.69 514,441.02 1.58 12,931.13 MWD+IFR-AK-CAZ-SC(4) 15,966.96 88.41 187.25 6,110.22 5,986.67 -12,880.26 -3,113.29 5,935,765.81 514,428.05 1.69 13,025.55 MW3+1FR-AK-CAZ-SC(4) 16,062.18 88.91 186.82 6,112.45 5,988.90 -12,974.74 -3,124.95 5,935,671.32 514,416.61 0.69 13,120.51 MVVD+IFR-AK-CAZ-SC(4) 16,156.77 89.04 185.89 6,114.14 5,990.59 -13,068.73 -3,135.42 5,935,577.31 514,406.36 0.99 13,214.92 MWD+IFR-AK-CAZ-SC(4) 16,251.98 89.32 185.12 6,115.51 5,991.96 -13,163.49 -3,144.55 5,935,482.54 514,397.45 0.86 13,310.03 MWD+1FR-AK-CAZ-SC(4) 16,347.17 90.03 190.57 6,116.05 5,992.50 -13,257.75 -3,157.54 5,935,388.26 514,384.68 5.77 13,404.84 MWD+IFR-AK-CAZ-SC(4) 16,441.08 87.51 194.45 6,118.06 5,994.51 -13,349.39 -3,177.87 5,935,296.58 514,36.4.57 4.93 13,497.41 MWD+1FR-AK-CAZ-SC(4) 16,535.99 87.31 195.55 6,122.35 5,998.80 -13,440.97 -3,202.41 5,935,204.95 514,340.24 1.18 13,590.15 M1MD+1FR-AK-CAZ-SC(4) 16,630.99 89.39 194.53 6,125.09 6,001.54 -13,532.67 -3,227.05 5,935,113.20 514,315.82 2.44 13,683.02 MWD+IFR-AK-CAZ-SC(4) 16,725.02 90.56 190.91 6,125.13 6,001.58 -13,624.38 -3,247.75 5,935,021.46 514,295.34 4.05 13,775.68 MWD+1FR-AK-CAZ-SC(4) 16,820.22 90.47 188,18 6,124.27 6,000.72 -13,718.25 -3,263.53 5,934,927.56 514,279.77 2.87 13,870.25 MWD+IFR-AK-CAZ-SC(4) 16,914.74 88.96 189.29 6,124.74 6,001.19 -13,811.66 -3,277.89 5,934,834.12 514,265.64 1.98 13,964.29 MWD+1FR-AK-CAZ-SC(4) 17,010.52 88.67 188.09 6,126.72 6,003.17 -13,906.32 -3,292.35 5,934,739.44 514,251.39 1.29 14,059.57 MWD+iFR-AK-CA2-SC(4) 17,073.37 88.64 188.42 6,128.20 6,004.65 -13,968.50 -3,301.37 5,934,677.24 514,242.52 0.53 14,122.14 MW0+1FR-AK-CAZ-SC(4) 2F-22 06.BaseC4_2 081214 LL 17,104.09 88.63 188.58 6,128.93 6,005.38 -13,998.88 -3,305.91 5,934,646.86 514,238.05 0.53 14,152.71 MWD+1FR-AK-CAZ-SC(4) 17,199.24 88.45 187.82 6,131.35 6,007.80 -14,093.02 -3,319.48 5,934,552.69 514,224.70 0.82 14,247.44 MWD+IFR-AK-CAZ-SC(4) 17,293.87 89.50 185.51 6,133.05 6,009.50 -14,186.99 -3,330.46 5,934,458.71 514,213.94 2.68 14,341.85 MWD+1FR-AK-CAZ-SC(4) 17,388.79 89.56 186.90 6,133.82 6,010.27 -14,281.35 -3,340.72 5,934,364.34 514,203.90 1.47 14,436.62 MWD+1FR-AK-CAZ-SC(4) 17,483.99 89.56 185.41 6,134.55 6,011.00 -14,376.00 -3,350.93 5,934,269.68 514,193.92 1.57 14,531.67 MWD+1FR-AK-CAZ-SC(4) 17,578.89 89.90 186.16 6,135.00 6,011.45 -14,470.41 -3,360.49 5,934,175.25 514,184.57 0.87 14,626.45 MWD+IFR-AK-CAZ-SC(4) 17,673.22 89.76 186.31 6,135.28 6,011.73 -14,564.18 -3,370.74 5,934,081.46 514,174.55 0.22 14,720.63 MWD+1FR-AK-CAZ-SC(4) 17,771.27 89.38 184.50 6,136.02 6,012.47 -14,661.79 -3,379.97 5,933,983.85 514,165.54 1.89 14,818.59 MWD+1FR-AK-CAZ-SC(4) 1/27/2015 10.29:49AM Page 7 COMPASS 5000.1 Build 65 Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well 2F-22 Project Kuparuk River Unit TVD Reference: Rig:95.8+27.75 @ 123.55usft(Doyon 141) Site: Kuparuk 2F Pad MD Reference: Rig:95.8+27.75 @ 123.55usft(Doyon 141) Well: 2F-22 North Reference: True Wellbore: 2F-22 Survey Calculation Method: Minimum Curvature Design: 2F-22 Database: OAKEDMP2 Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +El-W Northing Easting DLS Section (usft) (°) (1 (usft) (usft) (usft) (usft) (ft) (ft) ('/100') (ft) Survey Tool Name 17,863.34 90.15 183.17 6,136.40 6,012.85 -14,753.65 -3,386.13 5,933,891.98 514,159.60 1.67 14,910.65 MWD+IFR-AK-CAZ-SC(4) 17,957.75 89.55 181.92 6,136.64 6,013.09 -14,847.96 -3,390.32 5,933,797.67 514,155.62 1.47 15,005.05 MWD+IFR-AK-CAZ-SC(4) 18,050.99 90.15 183.79 6,136.89 6,013.34 -14,941.08 -3,394.97 5,933,704.55 514,151.20 2.11 15,098.29 MWD+IFR-AK-CAZ-SC(4) 18,144.24 89.56 185.40 6,137.12 6,013.57 -15,034.03 -3,402.44 5,933,611.59 514,143.94 1.84 15,191.50 MW3+IFR-AK-CAZ-SC(4) 18,239.33 89.49 191.35 6,137.91 6,014.36 -15,128.06 -3,416.28 5,933,517.54 514,130.32 6.26 15,286.12 MWD+1FR-AK-CAZ-SC(4) 18,334.70 90.00 189.85 6,138.34 6,014.79 -15,221.80 -3,433.82 5,933,423.77 514,113.00 1.66 15,380.65 MWD+1FR-AK-CAZ-SC(4) 18,426.43 89.87 192.53 6,138.44 6,014.89 -15,311.78 -3,451.62 5,933,333.76 514,095.41 2.93 15,471.44 MWD+1FR-AK-CAZSC(4) 18,524.63 88.86 193.01 6,139.53 6,015.98 -15,407.54 -3,473.33 5,933,237.95 514,073.93 1.14 15,568.21 MWD+1FR-AK-CAZ-SC(4) 18,619.35 89.09 195.24 6,141.22 6,017.67 -15,499.38 -3,496.44 5,933,146.07 514,051.04 2.37 15,661.12 MWD+1FR-AK-CAZSC(4) 18,713.28 88.24 193.87 6,143.41 6,019.86 -15,590.26 -3,520.03 5,933,055.14 514,027.65 1.72 15,753.12 MW3+1FR-AK-CAZSC(4) 18,737.56 88.27 193.28 6,144.15 6,020.60 -15,613.86 -3,525.73 5,933,031.54 514,022.01 2.45 15,776.98 MIND+IFR-AK-CAZ-SC(4) 2F-22 07.C4 081214 LL 18,809.39 88.36 191.52 6,146.26 6,022.71 -15,683.98 -3,541.14 5,932,961.39 514,006.76 2.45 15,847.81 MWD+IFR-AK-CAZSC(4) 18,904.31 89.08 189.06 6,148.38 6,024.83 -15,777.34 -3,558.09 5,932,868.00 513,990.03 2.70 15,941.93 MWD+1FR-AK-CAZ-SC(4) 18,999.47 89.39 187.49 6,149.65 6,026.10 -15,871.50 -3,571.79 5,932,773.82 513,976.56 1.68 16,036.68 MWD+1FR-AK-CAZ-SC(4) 19,093.74 90.43 187.66 6,149.80 6,026.25 -15,964.94 -3,584.22 5,932,680.35 513,964.35 1.12 16,130.65 MWD+1FR-AK-CAZ-SC(4) 19,188.62 89.17 187.25 6,150.13 6,026.58 -16,059.02 -3,596.53 5,932,586.26 513,952.26 1.40 16,225.24 MWD+IFR-AK-CAZ-SC(4) 19,282.88 88.94 185.62 6,151.69 6,028.14 -16,152.67 -3,607.09 5,932,492.59 513,941.92 1.75 16,319.31 MWD+IFR-AK-CAZ-SC(4) 19,375.79 88.63 182.38 6,153.66 6,030.11 -16,245.32 -3,613.57 5,932,399.94 513,935.65 3.50 16,412.17 MWD+IFR-AK-CAZ-SC(4) 19,472.47 88.31 180.17 6,156.24 6,032.69 -16,341.93 -3,615.72 5,932,303.33 513,933.73 2.31 16,508.77 MWD+IFR-AK-CAZ-SC(4) 19,566.18 89.15 181.18 6,158.32 6,034.77 -16,435.61 -3,616.82 5,932,209.65 513,932.84 1.40 16,602.38 MWD+IFR-AK-CAZ-SC(4) 19,657.13 89.28 179.75 6,159.56 6,036.01 -16,526.55 -3,617.56 5,932,118.73 513,932.31 1.58 16,693.23 MWD+IFR-AK-CAZ-SC(4) 19,753.38 89.08 177.87 6,160.94 6,037.39 -16,622.76 -3,615.56 5,932,022.52 513,934.54 1.96 16,789.21 MWD+IFR-AK-CAZ-SC(4) 19,848.83 89.18 177.58 6,162.39 6,038.84 -16,718.13 -3,611.77 5,931,927.18 513,938.55 0.32 16,884.24 MWD+IFR-AK-CAZ-SC(4) 19,943.41 88.39 177.69 6,164.40 6,040.85 -16,812.60 -3,607.87 5,931,832.72 513,942.67 0.84 16,978.38 MWD+1FR-AK-CAZ-SC(4) 20,038.15 87.91 172.41 6,167.46 6,043.91 -16,906.91 -3,599.70 5,931,738.45 513,951.05 5.59 17,072.13 MWD+IFR-AK-CAZ-SC(4) 20,131.96 86.80 165.30 6,171.79 6,048.24 -16,998.79 -3,581.60 5,931,646.61 513,969.36 7.66 17,162.94 MWD+1FR-AK-CAZ-SC(4) 20,225.83 87.61 165.23 6,176.37 6,052.82 -17,089.47 -3,557.76 5,931,556.01 513,993.42 0.87 17,252.24 MWD+1FR-AK-CAZ-SC(4) 20,319.86 86.98 160.68 6,180.81 6,057.26 -17,179.24 -3,530.23 5,931,466.30 514,021.15 4.88 17,340.46 MWD+IFR-AK-CAZ-SC(4) 20,358.95 86.76 160.12 6,182.94 6,059.39 -17,216.01 -3,517.14 5,931,429.57 514,034.33 1.53 17,376.49 MWD+1FR-AK-CAZSC(4) 2F-22 08.NearBaseC4 081214 LL 20,416.07 86.45 159.30 6,186.32 6,062.77 -17,269.49 -3,497.37 5,931,376.14 514,054.22 1.53 17.428.86 MWD+1FR-AK-CAZ-SC(4) 20,511.15 88.23 160.78 6,190.73 6,067.18 -17,358.76 -3,464.95 5,931,286.96 514,086.85 2.43 17,516.31 MWD+1FR-AK-CAZSC(4) 20,605.13 88.67 160.16 6,193.28 6,069.73 -17,447.30 -3,433.54 5,931,198.50 514,118.45 0.81 17,603.09 MWD+1FR-AK-CAZ-SC(4) 20,658.68 88.80 160.05 6,194.46 6,070.91 -17,497.64 -3,415.32 5,931,148.20 514,136.79 0.32 17,652.40 M1M2+IFR-AK-CAZ-SC(4) 20,699.36 89.11 158.22 6,195.20 6,071.65 -17,535.64 -3,400.84 5,931,110.24 514,151.36 4.56 17,689.60 MWD+1FR-AK-CAZ-SC(4) 20,741.60 91.36 158.10 6,195.03 6,071.48 -17,574.85 -3,385.13 5,931,071.07 514,167.16 5.33 17,727.93 MWD+1FR-AK-CAZSC(4) 20,793.28 92.83 160.64 6,193.14 6,069.59 -17,623.18 -3,366.93 5,931,022.79 514,185.47 5.68 17,775.24 MWD+1FR-AK-CAZ-SC(4) 20,835.64 92.23 163.02 6,191.27 6,067.72 -17,663.38 -3,353.74 5,930,982.62 514,198.76 5.79 17,814.70 MWD+IFR-AK-CAZ-SC(4) 20,885.63 91.11 165.62 6,189.81 6.066.26 -17,711.49 -3,340.23 5,930,934.55 514,212.37 5.66 17,862.03 MWD+1FR-AK-CAZSC(4) 1/27/2015 10:29:49AM Page 8 COMPASS 5000.1 Build 65 Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well 2F-22 Project: Kuparuk River Unit TVD Reference: Rig:95.8+27.75©123.55usft(Doyon 141) Site: Kuparuk 2F Pad MD Reference: Rig:95.8+27.75 @ 123.55usft(Doyon 141) Well: 2F-22 North Reference: True Wellbore: 2F-22 Survey Calculation Method: Minimum Curvature Design: 2F-22 Database: OAKEDMP2 Survey Map Map Vertical MD Inc Azi TVD TVDSS +NI-S +EI-W Northing Easting DLS Section (usft) (°) () (usft) (usft) (usft) (usft) (ft) (ft) 0100') (ft) Survey Tool Name 20,981.77 90.45 172.33 6,188.50 6,064.95 -17,805.79 -3,321.86 5,930,840.30 514,230.96 7.01 17,955.24 MWD+IFR-AK-CAZ-SC(4) 21,076.66 92.69 179.95 6,185.90 6,062.35 -17,900.35 -3,315.48 5,930,745.76 514,237.56 8.37 18,049.34 MW3+IFR-AK-CAZ-SC(4) 21,137.29 90.45 183.42 6,184.23 6,060.68 -17,960.92 -3,317.26 5,930,685.20 514,235.92 6.81 18,109.92 MWD+IFR-AK-CAZ-SC(4) 2F-22 09.C4_2 081214 LL 21,171.79 89.18 185.40 6,184.34 6,060.79 -17,995.32 -3,319.91 5,930,650.80 514,233.35 6.81 18,144.41 MW3+IFR-AK-CAZ-SC(4) 21,266.65 88.63 188.44 6,186.16 6,062.61 -18,089.46 -3,331.34 5,930,556.64 514,222.14 3.26 18,239.01 MWD+IFR-AK-CAZ-SC(4) 21,361.16 88.94 188.28 6,188.16 6,064.61 -18,182.94 -3,345.08 5,930,463.14 514,208.62 0.37 18,333.09 M1.AdD+IFR-AK-CAZ-SC(4) 21,456.40 88.55 187.62 6,190.25 6,066.70 -18,277.24 -3,358.25 5,930,368.81 514,195.67 0.80 18,427.95 MWD+IFR-AK-CAZ-SC(4) 21,551.15 86.16 188.24 6,194.62 6,071.07 -18,370.98 -3,371.30 5,930,275.06 514,182.84 2.61 18,522.24 MWD+IFR-AK-CAZ-SC(4) 21,645.03 86.71 187.66 6,200.46 6,076.91 -18,463.78 -3,384.26 5,930,182.24 514,170.09 0.85 18,615.59 MWD+IFR-AK-CAZ-SC(4) 21,739.07 86.22 187.76 6,206.26 6,082.71 -18,556.79 -3,396.86 5,930,089.21 514,157.72 0.53 18,709.14 MWD+IFR-AK-CAZ-SC(4) 21,833.88 91.88 188.09 6,207.83 6,084.28 -18,650.64 -3,409.92 5,929,995.33 514,144.87 5.98 18,803.54 MWD+IFR-AK-CAZ-SC(4) 21,928.00 89.97 182.56 6,206.31 6,082.76 -18,744.30 -3,418.65 5,929,901.66 514,136.36 6.22 18.897.53 MWD+IFR-AK-CAZSC(4) 21,990.00 89.97 182.56 6,206.34 6,082.79 -18,806.24 -3,421.42 5,929,839.72 514,133.74 0.00 18,959.53 PROJECTED to TD 41/2"z 6314" 22,009.00 89.97 182.56 6,206.35 6,082.80 -18,825.22 -3,422.27 5,929,820.74 514,132.93 0.00 18,978.53 PROJECTED to TD Projection to TD-2F-22 10.TD 081214 LL 1/27/2015 10:29:49AM Page 9 COMPASS 5000.1 Build 65 Cement Detail Report 2F-22 ConocoPhillips String: Surface Casing Cement Job: DRILLING ORIGINAL, 12/3/2014 18:00 Cement Details Description Cementing Start Date Cementing End Date Wellbore Name Surface Casing Cement 12/10/2014 04:15 12/10/2014 08:45 2F-22 Comment Batch up 10.5 ppg MP II, pump 5 bbls of H2O. Pressure test lines to 1500/4000 psi,good. SLB came online,pumped 103 bbls of 10.5 ppg MP II, shut down and drop bottom plug. Batch up lead as per SLB,come online and pump 551 bbls of 11.0 ppg LiteCRETE lead cement and 63.5 bbls of 12.0 ppg LiteCRETE tail cement, shut down and drop top plug, kick plug out with 10 bbls of H20. Displace cement with 9.4 ppg mud with rig pumps @ 7 bpm, ICP 500 psi, FCP 750 psi. Slow rate to 3 bpm 500 psi @ 3400 stks. Bump plug @ 3520 stks. Pressure up to 1000 psi&hold for 5 min. Bleed of psi&check float,good.CIP @ 08:45 hrs. Cement Stages Stage#1 Description Objective Top Depth(ftKB) Bottom Depth(ftKB) Full Return? Vol Cement... Top Plug? Btm Plug? Surface Casing Cement 27.6 3,916.0 Yes 212.0 Yes Yes Q Pump nit(bbl/m...Q Pump Final(bbl/... Q Pump Avg(bbl/... P Pump Final(psi) P Plug Bump(psi) Recip? Stroke(ft) Rotated? Pipe RPM(rpm) 5 7 6 750.0 1,000.0 Yes 20.00 No Tagged Depth(ftKB) Tag Method Depth Plug Drilled Out To(ftKB) Drill Out Diameter(in) Comment Run surface casing and cemented w/538 bbls of 11.0 ppg lead and 63.5 bbls of 12.0 ppg tail.212 bbls returned to surface. Full circulation was observed. Cement Fluids&Additives Fluid Fluid Type Fluid Description Estimated Top(ftKB) Est Btm(ftKB) Amount(sacks) Class Volume Pumped(bbl) Pre Flush Mud Push I I Yield(ft'/sack) Mix H2O Ratio(gallsa... Free Water(%) Density(lb/gal) Plastic Viscosity(Pa•s) Thickening Time(hr) CmprStr 1(psi) 10.50 Additives Additive Type Concentration Conc Unit label Fluid Fluid Type Fluid Description Estimated Top(ftKB) Est Btm(ftKB) Amount(sacks) Class Volume Pumped(bbl) Lead Cement 27.6 3,439.0 1,582 G 538.0 Yield(ft'/sack) Mix H2O Ratio(gal/sa... Free Water(%) Density(Ib/gal) Plastic Viscosity(Pa•s) Thickening Time(hr) CmprStr 1(psi) 1.91 6.82 11.00 61.9 Additives Additive Type Concentration Conc Unit label Fluid Fluid Type Fluid Description Estimated Top(ftKB) Est Btm(ftKB) Amount(sacks) Class Volume Pumped(bbl) Tail Cement 3,439.0 3,916.0 214 G 63.0 Yield(ft'/sack) Mix H2O Ratio(gal/sa... Free Water(%) Density(lb/gal) Plastic Viscosity(Pa•s) Thickening Time(hr) CmprStr 1(psi) 1.65 5.82 12.00 73.8 Additives Additive Type Concentration Conc Unit label Page 1/1 Report Printed: 2/3/2015 Cement Detail Report 0 2F-22 ConocoPhillips String: Intermediate Casing Cement Job: Cement Details Description Cementing Start Date Cementing End Date Wellbore Name Intermediate Casing Cement 12/26/2014 00:00 12/27/2014 12:40 2F-22 Comment Cement Stages Stage#1 Description Objective Top Depth(ftKB) Bottom Depth(ftKB) Full Return? Vol Cement...Top Plug? Btm Plug? Intermediate Casing 12,960.0 13,459.9 No 0.0 Yes Yes Cement Q Pump!nit(bbl/m...Q Pump Final(bbl/...Q Pump Avg(bbl/... P Pump Final(psi) P Plug Bump(psi) Recip? Stroke(ft) Rotated? Pipe RPM(rpm) 3 3 4 1,060.0 1,068.0 No No Tagged Depth(ftKB) Tag Method Depth Plug Drilled Out To(ftKB) Drill Out Diameter(in) Comment Line up to SLB; PT lines to 4000 psi; Pump 20 bbls CW100,20 bbls MUDPUSH II. Drop plug; pump 38.1 bbls 15.8 ppg cement. Drop top plug&pump 10 bbls fresh water.Swap to rig pumps for displacement. Displace cement with 604.8 bbls 10.7 ppg mud,3 bpm, ICP 1007 psi, FCP 1068 psi. Cement Fluids&Additives Fluid Fluid Type Fluid Description Estimated Top(ftKB) Est Btm(ftKB) Amount(sacks) Class Volume Pumped(bbl) CW100 12,414.1 12,687.1 20.0 Yield(W/sack) Mix H2O Ratio(gal/sa... Free Water(%) Density(lb/gal) Plastic Viscosity(Pa.$) Thickening Time(hr) CmprStr 1(psi) 8.33 Additives Additive Type Concentration Conc Unit label Fluid Fluid Type Fluid Description Estimated Top(ftKB) Est Btm(ftKB) Amount(sacks) Class Volume Pumped(bbl) MUDPUSH II 12,687.1 12,960.0 20.0 Yield(fP/sack) Mix H2O Ratio(gal/sa... Free Water(%) Density(lb/gal) Plastic Viscosity(Pa.$) Thickening Time(hr) CmprStr 1(psi) 11.50 Additives Additive Type Concentration Conc Unit label Fluid Fluid Type Fluid Description Estimated Top(ftKB) Est Btm(ftKB) Amount(sacks) Class Volume Pumped(bbl) GASBLOK Slurry 12,960.0 13,459.9 183 G 38.1 Yield(ft'/sack) Mix H2O Ratio(gal/sa... Free Water(%) Density(lb/gal) Plastic Viscosity(Pa•s) Thickening Time(hr) CmprStr 1(psi) 1.17 5.24 15.80 63.3 9.00 449.0 Additives _ Additive Type Concentration Conc Unit label Antifoam D047 0.2 %BWOC Additive Type Concentration Conc Unit label Dispersant D065 0.4 %BWOC Additive Type Concentration Conc Unit label Fluid Loss Control D167 0.2 %BWOC Additive Type Concentration Conc Unit label Gas Block D600G 2.0 gal/sx Fluid Fluid Type Fluid Description Estimated Top(ftKB) Est Btm(ftKB) Amount(sacks) Class Volume Pumped(bbl) Fresh Water 10.0 Yield(ft'/sack) Mix H2O Ratio(gal/sa... Free Water(%) Density(lb/gal) Plastic Viscosity(Pa•s) Thickening Time(hr) CmprStr 1(psi) 8.32 Additives Additive Type Concentration Conc Unit label Page 1/2 Report Printed: 2/3/2015 .1 041% Cement Detail Report 2F-22 Cono AF,x:k+a String: Intermediate Casing Cement Job: Cement Stages Stage#2 Description Objective Top Depth(ftKB) Bottom Depth(ftKB) Full Return? Vol Cement... Top Plug? Btm Plug? Intermediate Casing 12,360.0 12,642.0 No 0.0 Yes Yes Cement Q Pump Mit(bbl/m...Q Pump Final(bbl/... Q Pump Avg(bbl/... P Pump Final(psi) P Plug Bump(psi) Recip? Stroke(ft) Rotated? Pipe RPM(rpm) 4 3 4 574.0 608.0 No No Tagged Depth(ftKB) Tag Method -Depth Plug Drilled Out To(ftKB) Drill Out Diameter(in) Comment Line up to SLB; blow down hard line; PT lines to 4000 psi; Pump 20 bbls CW100,20 bbls MUDPUSH II. Drop plug; pump 37 bbls 15.8 ppg cement. Drop top plug&pump 10 bbls fresh water. Swap to rig pumps for displacement. Displace cement with 580.5 bbls 10.7 ppg mud,4 bpm, ICP 420 psi, FCP 608 psi. Bump plug and pressure up to 1900 psi, holding for 5 mins.Bleed off,test ES cementer tool,tool closed. Cement Fluids&Additives Fluid Fluid Type Fluid Description Estimated Top(ftKB) Est Btm(ftKB) Amount(sacks) Class Volume Pumped(bbl) CW100 11,814.0 12,087.0 8 Pre Flush 20.0 Yield(ft'/sack) Mix H2O Ratio(gal/sa...-Free Water(%) Density(lb/gal) Plastic Viscosity(Pa.$) Thickening Time(hr) CmprStr 1(psi) 8.33 Additives Additive Type Concentration Conc Unit label Fluid Fluid Type Fluid Description Estimated Top(ftKB) Est Btm(ftKB) Amount(sacks) Class Volume Pumped(bbl) MUDPUSH II 12,807.0 12,360.0 12 Flush 20.0 Yield(W/sack) Mix H2O Ratio(gal/sa... Free Water(%) Density(lb/gal) Plastic Viscosity(Pa•s) Thickening Time(hr) CmprStr 1(psi) 11.50 Additives Additive Type Concentration Conc Unit label Fluid Fluid Type Fluid Description Estimated Top(ftKB) Est Btm(ftKB) Amount(sacks) Class Volume Pumped(bbl) 2nd Stage Slurry 12,360.0 12,642.0 177 G 37.0 Yield(fV/sack) Mix H2O Ratio(gal/sa... Free Water(%) Density(lb/gal) Plastic Viscosity(Pa.$) Thickening Time(hr) CmprStr 1(psi) 1.16 5.08 15.80 102.6 9.00 621.0 Additives Additive Type Concentration Conc Unit label Antifoam D046 0.2 %BWOC Additive Type Concentration •Conc Unit label Dispersant D065 0.4 %BWOC Additive Type Concentration Conc Unit label Fluid Loss Control D167 0.6 %BWOC Fluid Fluid Type Fluid Description Estimated Top(ftKB) Est Btm(ftKB) Amount(sacks) Class Volume Pumped(bbl) Fresh Water 12,642.0 12,858.0 8 Wash 10.0 Yield(W/sack) Mix H2O Ratio(gal/sa... Free Water(%) Density(lb/gal) Plastic Viscosity(Pa•s) Thickening Time(hr) CmprStr 1(psi) 8.32 Additives Additive Type Concentration Conc Unit label Page 2/2 Report Printed: 2/3/2015 214150 RE%-EIVED 25342 I-CD 03 7^1c Schlumberger A°Ge( Transmittal#: 03FEB15-SP02 Drilling & Measurements MWD/LWD Log Product Delivery DATA LOGGED M2KI iE2o1NDP , R Customer: ConocoPhillips Alaska Dispatched To: AOGCC: Makana Bender Well No: 2F-22 Date Dispatched: 3-Feb-15 Job#: 14AKA0057 Dispatched By: Stephanie Pacillo Well/ Product Description Hardcopy Digital Copy E-Delivery Date Color Log Prints: 5 Contents on CD N/A MicroScope MicroScope Resistivity Image 5" MD x x VISION*Service T MD VISION*Service 2'TVD x x VISION*Service 5' MD x x VISION*Service 5"TVD x x LAS Digital Data N/A Contents on CD N/A x Directional Data 1 Contents on CD N/A Nad27 x x As-Built Survey 1 Contents on CD N/A Nad83 x x CD 1 Contents on CD N/A Data: DLIS/ASCII x Graphics:pdf/tiff x Surveys:pdf/txt x Please sign and email a copy to: Please sign and email a copy to: Catherine.Roso(c�conocophillips.com AlaskaPTSPrintCenter0,slb.com Catherine Roso Attn:Stephanie Pacillo 907-265-6189 AT0 1707 Received By: G ✓��� Vy�^`G��Jj 214150 25342 RECEIVED FINAL FEB 0 3 2015 AOGCC NADConversion Kuparuk River Unit Kuparuk 2F Pad 2F-22 Definitive Survey Report N D 2 7 21 January, 2015 • Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well 2F-22 Project: Kuparuk River Unit TVD Reference: Rig:95.8+27.75 @ 123.55usft(Doyon 141) Site: Kuparuk 2F Pad MD Reference: Rig:95.8+27.75 @ 123.55usft(Doyon 141) Well: 2F-22 North Reference: True Wellbore: 2F-22 Survey Calculation Method: Minimum Curvature Design: 2F-22 Database: OAKEDMP2 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 2F-22 Well Position +N/-S 173,152.61 usft Northing: 5,948,652.00 usfl Latitude: 70° 16'15.190 N +E/-W 1,125,167.54 usft Easting: 517,511.06 usfl Longitude: 149°51'30.172 W Position Uncertainty 0.00 usft Wellhead Elevation: usfl Ground Level: 95.80 usft Wellbore 2F-22 Magnetics Model Name Sample Date Declination Dip Angle Field Strength (0) (0) (nT) BGG M2014 11/25/2014 19.05 80.87 57,567 Design 2F-22 Audit Notes: Version: 1.0 Phase: ACTUAL Tie On Depth: 27.75 Vertical Section: Depth From(TVD) +N/-S +E/-W Direction (usft) (usft) (usft) (°) 27.75 173,152.6 -1,125,16 183.00 Survey Program Date From To (usft) (usft) Survey(Wellbore) Tool Name Description Survey Date 79.61 1,008.41 2F-22 Srvy#1 -GYD-GC-SS(2F-22) GYD-GC-SS Gyrodata gyro single shots 12/12/2014 3: i 1,063.31 3,770.69 2F-22 Srvy#2-MWD+IFR-AK-CAZ-SC( MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 12/12/2014 3: 3,770.69 13,406.12 2F-22 Srvy#3-MWD+IFR-AK-CAZ-SC( MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 12/18/2014 9: 13,506.29 21,928.00 2F-22 Srvy#4-MWD+IFR-AK-CAZ-SC( MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 1/2/2015 5:11 Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +E/-W Northing Easting DLS Section (usft) (°) (°) (usft) (usft) (usft) (usft) (ft) (ft) (°/100') (ft) Survey Tool Name 27.75 0.00 0.00 27.75 -95.80 173,152.61-1,125,167.54 5,948,652.00 517,511.06 0.00 0.00 UNDEFINED 79.62 0.23 265.47 79.62 -43.93 173,152.60-1,125,167.64 5,948,651.97 517,510.95 0.44 0.01 GYD-GC-SS(1) 182.45 0.46 217.97 182.45 58.90 173,152.26-1,125,168.10 5,948,651.57 517,510.55 0.34 0.38 GYD-GC-SS(1) 265.72 0.37 214.18 265.72 142.17 173,151.77-1,125,168.46 5,948,651.03 517,510.27 0.11 0.88 GYD-GC-SS(1) 357.72 0.69 240.40 357.71 234.16 173,151.25 -1,125,169.11 5,948,650.42 517,509.71 0.43 1.44 GYD-GC-SS(1) 453.67 1.58 247.75 453.64 330.09 173,150.47-1,125,170.83 5,948,649.38 517,508.12 0.94 2.31 GYD-GC-SS(1) 546.40 2.34 260.25 546.32 422.77 173,149.66-1,125,173.88 5,948,648.12 517,505.22 0.94 3.27 GYD-GC-SS(1) 638.12 3.11 264.69 637.93 514.38 173,149.11 -1,125,178.21 5,948,646.92 517,501.03 0.87 4.05 GYD-GC-SS(1) 731.57 5.74 266.92 731.10 607.55 173,148.63-1,125,185.40 5,948,645.34 517,493.98 2.82 4.91 GYD-GC-SS(1) 826.60 9.95 264.08 825.22 701.67 173,147.52-1,125,198.31 5,948,642.29 517,481.37 4.45 6.69 GYD-GC-SS(1) 915.27 12.72 260.69 912.15 788.60 173,145.15-1,125,215.57 5,948,637.32 517,464.65 3.21 9.96 GYD-GC-SS(1) 1/21/2015 1:05:31PM Page 2 COMPASS 5000.1 Build 65 Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well 2F-22 Project: Kuparuk River Unit TVD Reference: Rig:95.8+27.75 @ 123.55usft(Doyon 141) Site: Kuparuk 2F Pad MD Reference: Rig:95.8+27.75 @ 123.55usft(Doyon 141) Well: 2F-22 North Reference: True Wellbore: 2F-22 Survey Calculation Method: Minimum Curvature Design: 2F-22 Database: OAKEDMP2 Survey Map Map Vertical MD In(; Azi TVD TVDSS +N/-S +E/-W Northing Easting DLS Section (usft) (°) (°) (usft) (usft) (usft) (usft) (ft) (ft) (°/100') (ft) Survey Tool Name 1,008.41 14.15 262.44 1,002.74 879.19 173,142.00-1,125,236.98 5,948,630.94 517,443.94 1.60 14.23 GYD-GC-SS(1) 1,063.31 16.97 260.70 1,055.62 932.07 173,139.82-1,125,251.54 5,948,626.57 517,429.86 5.21 17.17 MWD+IFR-AK-CAZ-SC(2) 1,122.73 20.05 258.68 1,111.96 988.41 173,136.42-1,125,270.09 5,948,620.38 517,412.01 5.29 21.53 MWD+IFR-AK-CAZ-SC(2) 1,158.10 21.73 257.16 1,145.01 1,021.46 173,133.77-1,125,282.42 5,948,615.88 517,400.21 4.99 24.82 MWD+IFR-AK-CAZ-SC(2) 1,207.34 22.32 256.15 1,190.65 1,067.10 173,129.51-1,125,300.38 5,948,608.93 517,383.08 1.42 30.02 MWD+IFR-AK-CAZ-SC(2) 1,251.53 22.96 255.34 1,231.44 1,107.89 173,125.32-1,125,316.87 5,948,602.28 517,367.40 1.61 35.07 MWD+IFR-AK-CAZ-SC(2) 1,346.03 21.90 254.44 1,318.79 1,195.24 173,115.93-1,125,351.68 5,948,587.68 517,334.37 1.18 46.27 MWD+IFR-AK-CAZ-SC(2) 1,439.88 21.48 253.71 1,405.99 1,282.44 173,106.41-1,125,385.03 5,948,573.19 517,302.80 0.53 57.51 MWD+IFR-AK-CAZ-SC(2) 1,531.81 23.47 247.64 1,490.95 1,367.40 173,094.72-1,125,418.13 5,948,556.59 517,271.82 3.32 70.92 MWD+IFR-AK-CAZ-SC(2) 1,628.24 26.31 241.06 1,578.43 1,454.88 173,077.07-1,125,454.60 5,948,533.57 517,238.41 4.11 90.46 MWD+IFR-AK-CAZ-SC(2) 1,720.45 28.11 239.22 1,660.43 1,536.88 173,056.06-1,125,491.15 5,948,507.22 517,205.42 2.15 113.35 MWD+IFR-AK-CAZ-SC(2) 1,816.96 28.19 238.07 1,745.53 1,621.98 173,032.37-1,125,530.03 5,948,477.85 517,170.54 0.57 139.04 MWD+IFR-AK-CAZ-SC(2) 1,913.45 30.73 235.12 1,829.54 1,705.99 173,006.21-1,125,569.61 5,948,445.94 517,135.35 3.03 167.23 MWD+IFR-AK-CAZ-SC(2) 2,008.67 32.06 231.04 1,910.82 1,787.27 172,976.41-1,125,609.22 5,948,410.41 517,100.67 2.63 199.07 MWD+IFR-AK-CAZ-SC(2) 2,100.43 35.23 225.62 1,987.22 1,863.67 172,942.57-1,125,647.09 5,948,371.16 517,068.34 4.76 234.85 MWD+IFR-AK-CAZ-SC(2) 2,195.13 38.35 225.07 2,063.05 1,939.50 172,902.70-1,125,687.43 5,948,325.57 517,034.48 3.31 276.77 MWD+IFR-AK-CAZ-SC(2) 2,289.34 41.58 222.06 2,135.25 2,011.70 172,858.84-1,125,729.08 5,948,275.81 516,999.93 3.99 322.76 MWD+IFR-AK-CAZ-SC(2) 2,383.00 43.50 221.18 2,204.26 2,080.71 172,811.50-1,125,771.12 5,948,222.56 516,965.51 2.15 372.23 MWD+IFR-AK-CAZ-SC(2) 2,468.98 45.03 217.26 2,265.84 2,142.29 172,765.00-1,125,809.03 5,948,170.78 516,935.06 3.65 420.64 MWD+IFR-AK-CAZ-SC(2) 2,564.60 46.45 215.40 2,332.58 2,209.03 172,709.83-1,125,849.59 5,948,110.00 516,903.31 2.04 477.86 MWD+IFR-AK-CAZ-SC(2) 2,657.20 49.07 211.56 2,394.84 2,271.29 172,652.65-1,125,887.35 5,948,047.66 516,874.63 4.17 536.94 MWD+IFR-AK-CAZ-SC(2) 2,748.49 52.56 207.08 2,452.52 2,328.97 172,590.96-1,125,921.92 5,947,981.34 516,849.79 5.39 600.36 MWD+IFR-AK-CAZ-SC(2) 2,819.51 53.91 204.63 2,495.03 2,371.48 172,539.77-1,125,946.72 5,947,926.89 516,833.03 3.35 652.78 MWD+IFR-AK-CAZ-SC(2) 2,842.45 53.97 204.33 2,508.54 2,384.99 172,522.89-1,125,954.40 5,947,909.02 516,828.00 1.09 670.04 MWD+IFR-AK-CAZ-SC(2) 2,934.83 55.11 203.25 2,562.13 2,438.58 172,454.04-1,125,984.75 5,947,836.25 516,808.43 1.56 740.38 MWD+IFR-AK-CAZ-SC(2) 3,027.00 57.68 201.85 2,613.14 2,489.59 172,383.14-1,126,014.17 5,947,761.61 516,790.09 3.06 812.72 MWD+IFR-AK-CAZ-SC(2) 3,120.12 60.71 199.71 2,660.83 2,537.28 172,308.37-1,126,042.52 5,947,683.29 516,773.40 3.81 888.87 MWD+IFR-AK-CAZ-SC(2) 3,212.18 61.25 199.23 2,705.49 2,581.94 172,232.47-1,126,069.35 5,947,604.08 516,758.39 0.74 966.07 MWD+IFR-AK-CAZ-SC(2) 3,305.12 63.03 197.79 2,748.92 2,625.37 172,154.56-1,126,095.43 5,947,522.99 516,744.43 2.35 1,045.24 MWD+IFR-AK-CAZ-SC(2) 3,396.84 65.11 196.46 2,789.03 2,665.48 172,075.73-1,126,119.70 5,947,441.28 516,732.39 2.62 1,125.23 MWD+IFR-AK-CAZ-SC(2) 3,491.62 67.26 194.77 2,827.30 2,703.75 171,992.23-1,126,143.03 5,947,355.08 516,722.00 2.79 1,209.84 MWD+IFR-AK-CAZ-SC(2) 3,585.58 68.57 192.07 2,862.63 2,739.08 171,907.55-1,126,163.23 5,947,268.19 516,714.89 3.01 1,295.46 MW D+I FR-AK-CAZ-SC(2) 3,679.77 70.33 190.19 2,895.69 2,772.14 171,821.02-1,126,180.24 5,947,179.96 516,711.21 2.64 1,382.76 MWD+IFR-AK-CAZ-SC(2) 3,770.69 70.13 188.59 2,926.45 2,802.90 171,736.61-1,126,194.20 5,947,094.28 516,710.23 1.67 1,467.79 MW D+I FR-AK-CAZ-SC(2) 3,836.66 71.73 189.53 2,948.00 2,824.45 171,675.04-1,126,204.02 5,947,031.85 516,709.88 2.77 1,529.79 MWD+IFR-AK-CAZ-SC(3) 3,904.00 71.44 188.62 2,969.27 2,845.72 171,611.95-1,126,214.10 5,946,967.87 516,709.50 1.36 1,593.32 MWD+IFR-AK-CAZ-SC(3) 10 3/4"*13-1/2 3,935.28 71.31 188.19 2,979.26 2,855.71 171,582.63-1,126,218.43 5,946,938.18 516,709.67 1.36 1,622.83 MWD+IFR-AK-CAZ-SC(3) 3,999.54 72.33 187.79 2,999.31 2,875.76 171,522.17-1,126,226.91 5,946,877.05 516,710.47 1.69 1,683.65 MWD+IFR-AK-CAZSC(3) 4,091.35 71.16 188.56 3,028.07 2,904.52 171,435.87-1,126,239.31 5,946,789.74 516,711.33 1.50 1,770.48 MWD+IFR-AK-CAZ-SC(3) 1/21/2015 1:05:31PM Page 3 COMPASS 5000.1 Build 65 Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well 2F-22 Project: Kuparuk River Unit TVD Reference: Rig:95.8+27.75 @ 123.55usft(Doyon 141) Site: Kuparuk 2F Pad MD Reference: Rig:95.8+27.75 @ 123.55usft(Doyon 141) Well: 2F-22 North Reference: True Wellbore: 2F-22 Survey Calculation Method: Minimum Curvature Design: 2F-22 Database: OAKEDMP2 Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +E/-W Northing Easting DLS Section (usft) (°) (°) (usft) (usft) (usft) (usft) (ft) (ft) (°1100') (ft) Survey Tool Name 4,183.94 71.33 188.24 3,057.84 2,934.29 171,349.13-1,126,252.12 5,946,701.95 516,711.84 0.38 1,857.76 MWD+IFR-AK-CAZ-SC(3) 4,279.19 70.61 188.55 3,088.90 2,965.35 171,260.05-1,126,265.26 5,946,611.78 516,712.38 0.82 1,947.41 MWD+IFR-AK-CAZ-SC(3) 4,372.49 70.69 188.84 3,119.81 2,996.26 171,173.04-1,126,278.57 5,946,523.62 516,712.44 0.31 2,035.00 MW D+I FR-AK-CAZ-SC(3) 4,464.41 70.72 189.07 3,150.19 3,026.64 171,087.34-1,126,292.07 5,946,436.74 516,712.11 0.24 2,121.29 MWD+IFR-AK-CAZ-SC(3) 4,560.77 70.56 190.28 3,182.13 3,058.58 170,997.72-1,126,307.35 5,946,345.72 516,710.62 1.20 2,211.59 MW D+I F R-AK-CAZ-SC(3) 4,655.31 70.45 190.56 3,213.68 3,090.13 170,910.07-1,126,323.47 5,946,256.51 516,708.00 0.30 2,299.96 MWD+IFR-AK-CAZ-SC(3) 4,747.57 70.44 190.85 3,244.56 3,121.01 170,824.64-1,126,339.62 5,946,169.50 516,705.01 0.30 2,386.11 MWD+IFR-AK-CAZSC(3) 4,840.10 70.51 190.77 3,275.49 3,151.94 170,738.98-1,126,355.98 5,946,082.22 516,701.85 0.11 2,472.51 MWD+IFR-AK-CAZ-SC(3) 4,933.29 70.54 190.87 3,306.56 3,183.01 170,652.69-1,126,372.47 5,945,994.30 516,698.65 0.11 2,559.55 MWD+IFR-AK-CAZ-SC(3) 5,026.96 70.47 190.67 3,337.82 3,214.27 170,565.94-1,126,388.97 5,945,905.93 516,695.51 0.21 2,647.04 MWD+IFR-AK-CAZ-SC(3) 5,122.63 70.36 190.89 3,369.88 3,246.33 170,477.40-1,126,405.83 5,945,815.72 516,692.29 0.25 2,736.35 MW D+I FR-AK-CAZ-SC(3) 5,214.46 70.29 190.83 3,400.80 3,277.25 170,392.48-1,126,422.12 5,945,729.19 516,689.08 0.10 2,822.01 MWD+IFR-AK-CAZ-SC(3) 5,310.61 70.49 190.51 3,433.07 3,309.52 170,303.47-1,126,438.89 5,945,638.54 516,686.02 0.38 2,911.77 MWD+IFR-AK-CAZSC(3) 5,404.73 70.99 190.29 3,464.12 3,340.57 170,216.08-1,126,454.93 5,945,549.60 516,683.44 0.58 2,999.88 MWD+IFR-AK-CAZ-SC(3) 5,497.45 70.99 190.90 3,494.32 3,370.77 170,129.91-1,126,471.05 5,945,461.86 516,680.59 0.62 3,086.77 MWD+IFR-AK-CAZSC(3) 5,589.44 71.02 190.71 3,524.26 3,400.71 170,044.47-1,126,487.35 5,945,374.81 516,677.44 0.20 3,172.95 MW D+I FR-AK-CAZ-SC(3) 5,683.39 70.93 190.90 3,554.89 3,431.34 169,957.23-1,126,504.00 5,945,285.92 516,674.23 0.21 3,260.94 MW D+I FR-AK-CAZ-SC(3) 5,775.45 70.99 190.24 3,584.92 3,461.37 169,871.68-1,126,519.97 5,945,198.82 516,671.44 0.68 3,347.21 MWD+IFR-AK-CAZSC(3) 5,870.15 71.05 188.82 3,615.72 3,492.17 169,783.37-1,126,534.79 5,945,109.15 516,670.20 1.42 3,436.18 MWD+1FR-AK-CAZSC(3) 5,962.92 70.93 188.61 3,645.94 3,522.39 169,696.67-1,126,548.08 5,945,021.32 516,670.23 0.25 3,523.45 MWD+IFR-AK-CAZ-SC(3) 6,055.51 70.65 188.68 3,676.41 3,552.86 169,610.23-1,126,561.22 5,944,933.76 516,670.37 0.31 3,610.46 MWD+IFR-AK-CAZ-SC(3) 6,148.00 70.69 189.06 3,707.02 3,583.47 169,524.00-1,126,574.68 5,944,846.36 516,670.17 0.39 3,697.28 MWD+1FR-AK-CAZSC(3) 6,240.11 70.57 189.23 3,737.57 3,614.02 169,438.21-1,126,588.49 5,944,759.34 516,669.55 0.22 3,783.68 MWD+1FR-AK-CAZ-SC(3) 6,333.12 70.50 189.18 3,768.56 3,645.01 169,351.64-1,126,602.52 5,944,671.53 516,668.83 0.09 3,870.86 MWD+IFR-AK-CAZ-SC(3) 6,427.37 70.56 189.21 3,799.98 3,676.43 169,263.92-1,126,616.72 5,944,582.54 516,668.12 0.07 3,959.20 MWD+IFR-AK-CAZ-SC(3) 6,520.58 70.56 190.04 3,831.00 3,707.45 169,177.27-1,126,631.42 5,944,494.53 516,666.75 0.84 4,046.51 MWD+IFR-AK-CAZSC(3) 6,612.63 70.57 189.93 3,861.63 3,738.08 169,091.78-1,126,646.47 5,944,407.62 516,664.86 0.11 4,132.67 MWD+IFR-AK-CAZ-SC(3) 6,706.10 70.45 190.10 3,892.82 3,769.27 169,005.00-1,126,661.79 5,944,319.41 516,662.89 0.21 4,220.12 MWD+1FR-AK-CAZ-SC(3) 6,799.85 70.57 188.99 3,924.10 3,800.55 168,917.85-1,126,676.45 5,944,230.91 516,661.64 1.12 4,307.92 MWD+1FR-AK-CAZ-SC(3) 6,892.41 70.50 188.51 3,954.94 3,831.39 168,831.60-1,126,689.72 5,944,143.52 516,661.62 0.49 4,394.75 MWD+IFR-AK-CAZ-SC(3) 6,985.30 70.44 188.50 3,985.99 3,862.44 168,745.01-1,126,702.67 5,944,055.85 516,661.97 0.07 4,481.89 MWD+IFR-AK-CAZ-SC(3) 7,077.37 70.82 188.77 4,016.53 3,892.98 168,659.14-1,126,715.71 5,943,968.87 516,662.12 0.50 4,568.33 MWD+IFR-AK-CAZ-SC(3) 7,169.13 70.37 188.93 4,047.02 3,923.47 168,573.62-1,126,729.02 5,943,882.20 516,661.95 0.52 4,654.43 MWD+IFR-AK-CAZSC(3) 7,263.54 70.35 188.35 4,078.75 3,955.20 168,485.72-1,126,742.38 5,943,793.16 516,662.10 0.58 4,742.92 MWD+IFR-AK-CAZSC(3) 7,356.21 70.39 189.04 4,109.88 3,986.33 168,399.44-1,126,755.58 5,943,705.75 516,662.16 0.70 4,829.77 MWD+IFR-AK-CAZ-SC(3) 7,448.46 70.41 189.81 4,140.83 4,017.28 168,313.70 -1,126,769.81 5,943,618.73 516,661.12 0.79 4,916.13 MWD+IFR-AK-CAZ-SC(3) 7,541.64 70.78 189.65 4,171.78 4,048.23 168,227.08-1,126,784.66 5,943,530.73 516,659.59 0.43 5,003.41 MWD+IFR-AK-CAZ-SC(3) 7,636.07 70.81 190.67 4,202.85 4,079.30 168,139.31-1,126,800.39 5,943,441.46 516,657.37 1.02 5,091.89 MWD+IFR-AK-CAZ-SC(3) 7,727.50 70.77 191.44 4,232.93 4,109.38 168,054.57-1,126,816.95 5,943,355.07 516,653.87 0.80 5,177.37 MWD+IFR-AK-CAZSC(3) 7,820.25 70.84 191.33 4,263.43 4,139.88 167,968.70-1,126,834.24 5,943,267.44 516,649.82 0.14 5,264.03 MWD+IFR-AK-CAZ-SC(3) 1/21/2015 1:05:31PM Page 4 COMPASS 5000.1 Build 65 Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well 2F-22 Project: Kuparuk River Unit TVD Reference: Rig:95.8+27.75 @ 123.55usft(Doyon 141) Site: Kuparuk 2F Pad MD Reference: Rig:95.8+27.75 @ 123.55usft(Doyon 141) Well: 2F-22 North Reference: True Wellbore: 2F-22 Survey Calculation Method: Minimum Curvature Design: 2F-22 Database: OAKEDMP2 Survey Map Map Vertical MD Inc Azi TVD TVDSS +NI-S +E/-W Northing Easting DLS Section (usft) (°) (°) (usft) (usft) (usft) (usft) (ft) (ft) (°/100') (ft) Survey Tool Name 7,912.41 70.78 191.61 4,293.72 4,170.17 167,883.40-1,126,851.55 5,943,180.38 516,645.66 0.29 5,350.12 MWD+IFR-AK-CAZ-SC(3) 8,004.59 70.80 190.69 4,324.05 4,200.50 167,798.00-1,126,868.38 5,943,093.28 516,641.99 0.94 5,436.29 MWD+IFR-AK-CAZ-SC(3) 8,096.10 70.83 191.37 4,354.12 4,230.57 167,713.17 -1,126,884.91 5,943,006.80 516,638.53 0.70 5,521.87 MWD+IFR-AK-CAZ-SC(3) 8,189.06 70.90 191.29 4,384.59 4,261.04 167,627.05-1,126,902.17 5,942,918.95 516,634.55 0.11 5,608.76 MWD+IFR-AK-CAZ-SC(3) 8,281.88 70.90 190.28 4,414.97 4,291.42 167,540.89-1,126,918.58 5,942,831.17 516,631.41 1.03 5,695.66 MWD+IFR-AK-CAZ-SC(3) 8,374.58 70.81 189.07 4,445.37 4,321.82 167,454.57-1,126,933.30 5,942,743.48 516,629.97 1.24 5,782.64 MWD+IFR-AK-CAZ-SC(3) 8,466.97 70.86 188.19 4,475.70 4,352.15 167,368.29-1,126,946.39 5,942,656.09 516,630.13 0.90 5,869.49 MWD+IFR-AK-CAZ-SC(3) 8,559.31 70.87 188.38 4,505.97 4,382.42 167,281.96-1,126,958.96 5,942,568.73 516,630.82 0.19 5,956.36 MWD+IFR-AK-CAZ-SC(3) 8,652.06 70.81 189.09 4,536.41 4,412.86 167,195.37-1,126,972.27 5,942,481.00 516,630.82 0.73 6,043.53 MWD+IFR-AK-CAZ-SC(3) 8,744.62 70.47 190.04 4,567.10 4,443.55 167,109.26-1,126,986.78 5,942,393.56 516,629.56 1.04 6,130.28 MWD+IFR-AK-CAZ-SC(3) 8,838.16 70.33 190.41 4,598.47 4,474.92 167,022.53-1,127,002.42 5,942,305.34 516,627.26 0.40 6,217.70 MWD+IFR-AK-CAZ-SC(3) 8,932.02 70.29 190.41 4,630.10 4,506.55 166,935.62-1,127,018.39 5,942,216.88 516,624.68 0.04 6,305.33 MWD+IFR-AK-CAZ-SC(3) 9,025.77 70.29 189.77 4,661.72 4,538.17 166,848.73-1,127,033.85 5,942,128.52 516,622.59 0.64 6,392.92 MWD+IFR-AK-CAZ-SC(3) 9,121.23 70.33 188.99 4,693.88 4,570.33 166,760.05-1,127,048.50 5,942,038.52 516,621.58 0.77 6,482.24 MWD+IFR-AK-CAZ-SC(3) 9,214.67 70.31 188.35 4,725.35 4,601.80 166,673.07-1,127,061.76 5,941,950.42 516,621.68 0.65 6,569.79 MWD+IFR-AK-CAZ-SC(3) 9,309.79 70.82 187.66 4,757.00 4,633.45 166,584.25-1,127,074.25 5,941,860.60 516,622.83 0.87 6,659.15 MWD+IFR-AK-CAZ-SC(3) 9,402.57 70.84 188.17 4,787.47 4,663.92 166,497.45-1,127,086.32 5,941,772.85 516,624.08 0.52 6,746.46 MWD+IFR-AK-CAZ-SC(3) 9,494.53 70.81 188.25 4,817.67 4,694.12 166,411.48-1,127,098.72 5,941,685.87 516,624.88 0.09 6,832.96 MWD+IFR-AK-CAZ-SC(3) 9,587.51 70.78 189.15 4,848.26 4,724.71 166,324.69 -1,127,112.01 5,941,597.94 516,624.94 0.91 6,920.33 MWD+IFR-AK-CAZ-SC(3) 9,679.82 70.87 190.54 4,878.58 4,755.03 166,238.78-1,127,126.91 5,941,510.65 516,623.25 1.43 7,006.89 MWD+IFR-AK-CAZ-SC(3) 9,772.05 70.81 190.61 4,908.85 4,785.30 166,153.14-1,127,142.90 5,941,423.45 516,620.45 0.10 7,093.25 MWD+IFR-AK-CAZ-SC(3) 9,865.73 70.83 194.51 4,939.64 4,816.09 166,066.80-1,127,162.14 5,941,335.06 516,614.54 3.93 7,180.48 MWD+IFR-AK-CAZ-SC(3) 9,958.53 70.84 190.02 4,970.12 4,846.57 165,981.17-1,127,180.75 5,941,247.47 516,609.14 4.57 7,266.97 MWD+IFR-AK-CAZ-SC(3) 10,052.49 70.86 189.12 5,000.94 4,877.39 165,893.65-1,127,195.51 5,941,158.59 516,607.85 0.91 7,355.15 MWD+IFR-AK-CAZ-SC(3) 10,144.74 70.87 188.76 5,031.18 4,907.63 165,807.55-1,127,209.05 5,941,071.32 516,607.54 0.37 7,441.83 MWD+IFR-AK-CAZ-SC(3) 10,238.14 70.87 188.36 5,061.79 4,938.24 165,720.29-1,127,222.19 5,940,982.95 516,607.81 0.40 7,529.66 MWD+IFR-AK-CAZ-SC(3) 10,330.92 70.87 188.66 5,092.19 4,968.64 165,633.60-1,127,235.16 5,940,895.17 516,608.15 0.31 7,616.91 MWD+IFR-AK-CAZSC(3) 10,422.53 70.92 188.65 5,122.18 4,998.63 165,548.02-1,127,248.19 5,940,808.48 516,608.28 0.06 7,703.05 MWD+IFR-AK-CAZ-SC(3) 10,516.36 70.34 188.18 5,153.30 5,029.75 165,460.46-1,127,261.14 5,940,719.84 516,608.77 0.78 7,791.18 MWD+IFR-AK-CAZ-SC(3) 10,611.60 70.29 187.70 5,185.38 5,061.83 165,371.65-1,127,273.53 5,940,630.05 516,610.02 0.48 7,880.52 MWD+IFR-AK-CAZ-SC(3) 10,706.55 70.48 188.05 5,217.25 5,093.70 165,283.05-1,127,285.78 5,940,540.49 516,611.37 0.40 7,969.63 MWD+IFR-AK-CAZ-SC(3) 10,799.05 70.39 188.57 5,248.23 5,124.68 165,196.81-1,127,298.38 5,940,453.21 516,612.02 0.54 8,056.42 MWD+IFR-AK-CAZ-SC(3) 10,892.96 70.38 190.33 5,279.76 5,156.21 165,109.55-1,127,312.90 5,940,364.64 516,610.91 1.77 8,144.31 MWD+IFR-AK-CAZ-SC(3) 10,987.14 70.41 190.46 5,311.36 5,187.81 165,022.29 -1,127,328.91 5,940,275.83 516,608.34 0.13 8,232.30 MWD+IFR-AK-CAZ-SC(3) 11,081.74 70.50 190.28 5,343.00 5,219.45 164,934.59-1,127,344.96 5,940,186.59 516,605.79 0.20 8,320.71 MWD+IFR-AK-CAZ-SC(3) 11,179.28 70.87 189.73 5,375.27 5,251.72 164,843.94-1,127,360.95 5,940,094.43 516,603.75 0.65 8,412.07 MWD+IFR-AK-CAZSC(3) 11,274.31 70.90 189.95 5,406.39 5,282.84 164,755.47-1,127,376.29 5,940,004.53 516,602.02 0.22 8,501.22 MWD+IFR-AK-CAZ-SC(3) 11,366.07 70.93 190.06 5,436.39 5,312.84 164,670.08-1,127,391.36 5,939,917.71 516,600.10 0.12 8,587.29 MWD+IFR-AK-CAZ-SC(3) 11,459.77 70.96 190.36 5,466.98 5,343.43 164,582.91-1,127,407.06 5,939,829.05 516,597.82 0.30 8,675.16 MWD+IFR-AK-CAZ-SC(3) 11,550.97 70.97 191.07 5,496.72 5,373.17 164,498.20-1,127,423.09 5,939,742.76 516,594.84 0.74 8,760.59 MWD+IFR-AK-CAZ-SC(3) 1/21/2015 1:05:31PM Page 5 COMPASS 5000.1 Build 65 • Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well 2F-22 Project: Kuparuk River Unit TVD Reference: Rig:95.8+27.75 @ 123.55usft(Doyon 141) Site: Kuparuk 2F Pad MD Reference: Rig:95.8+27.75 @ 123.55usft(Doyon 141) Well: 2F-22 North Reference: True Wellbore: 2F-22 Survey Calculation Method: Minimum Curvature Design: 2F-22 Database: OAKEDMP2 Survey Map Map Vertical MD Inc Azi TVD TVDSS +NI-S +EI-W Northing Easting DLS Section (usft) (°) (°) (usft) (usft) (usft) (usft) (ft) (ft) (°/100') (ft) Survey Tool Name 11,642.21 70.69 191.31 5,526.69 5,403.14 164,413.66 -1,127,439.81 5,939,656.54 516,591.14 0.39 8,845.89 MWD+IFR-AK-CAZ-SC(3) 11,737.09 70.88 190.82 5,557.91 5,434.36 164,325.73 -1,127,457.01 5,939,566.89 516,587.49 0.53 8,934.60 MWD+IFR-AK-CAZ-SC(3) 11,828.79 70.82 190.09 5,587.99 5,464.44 164,240.55-1,127,472.73 5,939,480.18 516,584.89 0.75 9,020.49 MWD+IFR-AK-CAZ-SC(3) 11,921.83 70.37 190.23 5,618.91 5,495.36 164,154.17 -1,127,488.21 5,939,392.33 516,582.71 0.50 9,107.56 MWD+IFR-AK-CAZ-SC(3) 12,014.20 70.39 190.23 5,649.92 5,526.37 164,068.54-1,127,503.66 5,939,305.23 516,580.44 0.02 9,193.88 MWD+IFR-AK-CAZ-SC(3) 12,106.02 70.32 189.17 5,680.79 5,557.24 163,983.31-1,127,518.23 5,939,218.65 516,578.98 1.09 9,279.76 MWD+IFR-AK-CAZ-SC(3) 12,198.75 70.33 188.59 5,712.01 5,588.46 163,897.04 -1,127,531.71 5,939,131.21 516,578.76 0.59 9,366.62 MWD+I FR-AK-CAZ-SC(3) 12,292.53 70.38 188.29 5,743.54 5,619.99 163,809.67-1,127,544.67 5,939,042.76 516,579.22 0.31 9,454.54 MWD+IFR-AK-CAZ-SC(3) 12,384.91 70.58 188.48 5,774.41 5,650.86 163,723.53-1,127,557.37 5,938,955.57 516,579.75 0.29 9,541.22 MWD+IFR-AK-CAZ-SC(3) 12,477.20 70.72 188.79 5,804.99 5,681.44 163,637.44-1,127,570.44 5,938,868.37 516,579.91 0.35 9,627.88 MWD+IFR-AK-CAZ-SC(3) 12,569.97 70.78 188.89 5,835.57 5,712.02 163,550.90-1,127,583.90 5,938,780.66 516,579.75 0.12 9,715.01 MWD+IFR-AK-CAZ-SC(3) 12,662.67 70.81 189.09 5,866.07 5,742.52 163,464.44-1,127,597.58 5,938,693.00 516,579.36 0.21 9,802.07 MWD+IFR-AK-CAZ-SC(3) 12,756.47 70.84 189.80 5,896.88 5,773.33 163,377.04-1,127,612.12 5,938,604.28 516,578.26 0.72 9,890.11 MWD+IFR-AK-CAZ-SC(3) 12,850.93 70.77 189.68 5,927.93 5,804.38 163,289.12 -1,127,627.21 5,938,514.96 516,576.70 0.14 9,978.70 MWD+IFR-AK-CAZ-SC(3) 12,943.65 70.82 189.88 5,958.43 5,834.88 163,202.83-1,127,642.08 5,938,427.29 516,575.10 0.21 10,065.65 MWD+IFR-AK-CAZ-SC(3) 13,034.79 70.72 190.36 5,988.45 5,864.90 163,118.12-1,127,657.20 5,938,341.14 516,573.02 0.51 10,151.04 MWD+IFR-AK-CAZ-SC(3) 13,128.21 72.65 190.90 6,017.81 5,894.26 163,030.95-1,127,673.57 5,938,252.38 516,570.08 2.14 10,238.94 MWD+IFR-AK-CAZ-SC(3) 13,216.31 75.78 191.18 6,041.77 5,918.22 162,947.76-1,127,689.80 5,938,167.56 516,566.67 3.56 10,322.87 MWD+IFR-AK-CAZ-SC(3) 2F-22 01.TDInt 081214 LL(copy)(copy)(copy) 13,219.99 75.91 191.19 6,042.67 5,919.12 162,944.26-1,127,690.49 5,938,163.99 516,566.51 3.56 10,326.40 MWD+IFR-AK-CAZ-SC(3) 13,313.52 78.72 191.41 6,063.21 5,939.66 162,854.79-1,127,708.37 5,938,072.71 516,562.43 3.01 10,416.68 MWD+IFR-AK-CAZ-SC(3) 13,406.12 81.01 191.62 6,079.50 5,955.95 162,765.47-1,127,726.57 5,937,981.54 516,558.00 2.48 10,506.83 MWD+IFR-AK-CAZ-SC(3) 13,460.00 82.13 192.12 6,087.40 5,963.85 162,713.32-1,127,737.53 5,937,928.25 516,555.08 2.27 10,559.49 MWD+IFR-AK-CAZ-SC(4) 7-5/8"x 9-7/8" 13,506.29 83.09 192.55 6,093.35 5,969.80 162,668.47-1,127,747.34 5,937,882.37 516,552.19 2.27 10,604.78 MWD+IFR-AK-CAZ-SC(4) 13,601.11 83.04 193.28 6,104.80 5,981.25 162,576.73-1,127,768.37 5,937,788.36 516,545.33 0.77 10,697.50 MWD+IFR-AK-CAZ-SC(4) 13,696.16 84.75 191.04 6,114.91 5,991.36 162,484.35-1,127,788.28 5,937,693.89 516,539.68 2.95 10,790.80 MWD+IFR-AK-CAZ-SC(4) 13,716.27 85.08 190.84 6,116.69 5,993.14 162,464.68-1,127,792.08 5,937,673.85 516,538.91 1.90 10,810.63 MWD+IFR-AK-CAZ-SC(4) 2F-22 02.B 081214 LL(copy) 13,790.67 86.29 190.12 6,122.29 5,998.74 162,391.73-1,127,805.58 5,937,599.59 516,536.64 1.90 10,884.19 MWD+IFR-AK-CAZ-SC(4) 13,885.65 87.49 189.87 6,127.45 6,003.90 162,298.33-1,127,822.04 5,937,504.64 516,534.56 1.29 10,978.33 MWD+IFR-AK-CAZ-SC(4) 13,979.98 90.00 187.73 6,129.51 6,005.96 162,205.15-1,127,836.46 5,937,410.21 516,534.45 3.50 11,072.14 MWD+IFR-AK-CAZ-SC(4) 14,075.08 91.52 187.90 6,128.25 6,004.70 162,110.94-1,127,849.39 5,937,315.00 516,535.98 1.61 11,166.89 MWD+IFR-AK-CAZ-SC(4) 14,170.41 91.82 189.61 6,125.47 6,001.92 162,016.76-1,127,863.89 5,937,219.58 516,535.95 1.82 11,261.70 MWD+IFR-AK-CAZ-SC(4) 14,264.77 92.27 192.67 6,122.11 5,998.56 161,924.25-1,127,882.11 5,937,125.24 516,531.99 3.28 11,355.04 MWD+IFR-AK-CAZ-SC(4) 14,313.74 91.97 196.56 6,120.29 5,996.74 161,876.91-1,127,894.46 5,937,076.50 516,526.97 7.96 11,402.96 MWD+IFR-AK-CAZ-SC(4) 14,358.81 92.73 197.76 6,118.44 5,994.89 161,833.88-1,127,907.74 5,937,031.89 516,520.37 3.15 11,446.62 MWD+IFR-AK-CAZ-SC(4) 14,403.70 92.58 197.30 6,116.37 5,992.82 161,791.12-1,127,921.25 5,936,987.51 516,513.50 1.08 11,490.03 MWD+IFR-AK-CAZ-SC(4) 14,453.00 92.92 197.45 6,114.00 5,990.45 161,744.13-1,127,935.95 5,936,938.76 516,506.09 0.75 11,537.73 MWD+IFR-AK-CAZ-SC(4) 2F-22 03.BaseC4 081214 LL(copy) 14,547.94 92.82 195.58 6,109.25 5,985.70 161,653.22 -1,127,962.91 5,936,844.68 516,493.24 1.97 11,629.92 MWD+IFR-AK-CAZ-SC(4) 1/21/2015 1:05:31PM Page 6 COMPASS 5000.1 Build 65 • Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well 2F-22 Project: Kuparuk River Unit TVD Reference: Rig:95.8+27.75 @ 123.55usft(Doyon 141) Site: Kuparuk 2F Pad MD Reference: Rig:95.8+27.75 @ 123.55usft(Doyon 141) Well: 2F-22 North Reference: True Wellbore: 2F-22 Survey Calculation Method: Minimum Curvature Design: 2F-22 Database: OAKEDMP2 Survey Map Map Vertical MD Inc Azi TVD TVDSS +NI-S +E/-W Northing Easting DLS Section (usft) (°) (°) (usft) (usft) (usft) (usft) (ft) (ft) (°1100') (ft) Survey Tool Name 14,643.08 92.17 195.45 6,105.10 5,981.55 161,561.64-1,127,988.33 5,936,750.16 516,482.01 0.70 11,722.71 MWD+IFR-AK-CAZ-SC(4) 14,737.96 90.04 195.44 6,103.27 5,979.72 161,470.21-1,128,013.59 5,936,655.82 516,470.91 2.24 11,815.34 MWD+IFR-AK-CAZ-SC(4) 14,832.40 91.22 195.24 6,102.24 5,978.69 161,379.14-1,128,038.57 5,936,561.88 516,460.03 1.27 11,907.59 MWD+IFR-AK-CAZ-SC(4) 14,926.29 90.07 196.14 6,101.18 5,977.63 161,288.75-1,128,063.96 5,936,468.56 516,448.65 1.56 11,999.18 MWD+IFR-AK-CAZ-SC(4) 14,944.92 89.74 196.12 6,101.21 5,977.66 161,270.85-1,128,069.14 5,936,450.05 516,446.25 1.78 12,017.33 MWD+IFR-AK-CAZ-SC(4) 2F-22 04.Fault2 081214 LL(copy) 15,020.80 88.39 196.04 6,102.45 5,978.90 161,197.96-1,128,090.15 5,936,374.70 516,436.54 1.78 12,091.22 MWD+IFR-AK-CAZ-SC(4) 15,115.54 86.88 195.78 6,106.36 5,982.81 161,106.93-1,128,116.10 5,936,280.66 516,424.70 1.62 12,183.49 MWD+IFR-AK-CAZ-SC(4) 15,210.61 88.46 194.71 6,110.22 5,986.67 161,015.28-1,128,141.08 5,936,186.15 516,413.92 2.01 12,276.31 MWD+IFR-AK-CAZ-SC(4) 15,304.40 90.81 192.36 6,110.82 5,987.27 160,924.11-1,128,163.02 5,936,092.57 516,406.06 3.54 12,368.51 MWD+1FR-AK-CAZ-SC(4) 15,357.16 91.15 191.60 6,109.92 5,986.37 160,872.51-1,128,173.98 5,936,039.83 516,403.07 1.57 12,420.61 MWD+IFR-AK-CAZ-SC(4) 2F-22 05.C4Crest 081214 LL(copy) 15,399.33 91.43 191.00 6,108.97 5,985.42 160,831.17-1,128,182.24 5,935,997.65 516,401.18 1.57 12,462.33 MWD+IFR-AK-CAZ-SC(4) 15,493.98 89.95 191.86 6,107.83 5,984.28 160,738.40-1,128,200.99 5,935,902.98 516,396.73 1.81 12,555.95 MW D+I FR-AK-CAZ-SC(4) 15,588.55 90.24 190.99 6,107.67 5,984.12 160,645.71-1,128,219.73 5,935,808.38 516,392.28 0.97 12,649.50 MWD+IFR-AK-CAZ-SC(4) 15,683.26 90.04 189.60 6,107.44 5,983.89 160,552.53-1,128,236.65 5,935,713.57 516,389.70 1.48 12,743.44 MWD+IFR-AK-CAZ-SC(4) 15,777.62 90.12 189.71 6,107.31 5,983.76 160,459.50-1,128,252.48 5,935,619.09 516,388.19 0.14 12,837.16 MWD+IFR-AK-CAZ-SC(4) 15,872.15 88.97 188.75 6,108.06 5,984.51 160,366.20-1,128,267.64 5,935,524.44 516,387.37 1.58 12,931.13 MWD+IFR-AK-CAZ-SC(4) 15,966.96 88.41 187.25 6,110.22 5,986.67 160,272.34-1,128,280.83 5,935,429.53 516,388.59 1.69 13,025.55 MWD+IFR-AK-CAZ-SC(4) 16,062.18 88.91 186.82 6,112.45 5,988.90 160,177.87-1,128,292.49 5,935,334.24 516,391.42 0.69 13,120.51 MWD+IFR-AK-CAZ-SC(4) 16,156.77 89.04 185.89 6,114.14 5,990.59 160,083.87-1,128,302.96 5,935,239.61 516,395.36 0.99 13,214.92 MWD+IFR-AK-CAZ-SC(4) 16,251.98 89.32 185.12 6,115.51 5,991.96 159,989.11-1,128,312.09 5,935,144.43 516,400.73 0.86 13,310.03 MWD+IFR-AK-CAZ-SC(4) 16,347.17 90.03 190.57 6,116.05 5,992.50 159,894.85-1,128,325.08 5,935,049.15 516,402.21 5.77 13,404.84 MWD+IFR-AK-CAZ-SC(4) 16,441.08 87.51 194.45 6,118.06 5,994.51 159,803.22-1,128,345.41 5,934,955.36 516,396.03 4.93 13,497.41 MWD+IFR-AK-CAZ-SC(4) 16,535.99 87.31 195.55 6,122.35 5,998.80 159,711.64-1,128,369.95 5,934,860.98 516,385.67 1.18 13,590.15 MWD+IFR-AK-CAZ-SC(4) 16,630.99 89.39 194.53 6,125.09 6,001.54 159,619.94-1,128,394.59 5,934,766.47 516,375.23 2.44 13,683.02 MWD+IFR-AK-CAZ-SC(4) 16,725.02 90.56 190.91 6,125.13 6,001.58 159,528.23-1,128,415.29 5,934,672.55 516,368.68 4.05 13,775.68 MWD+IFR-AK-CAZSC(4) 16,746.97 90.54 190.28 6,124.92 6,001.37 159,506.65-1,128,419.32 5,934,650.58 516,367.97 2.87 13,797.44 MWD+IFR-AK-CAZ-SC(4) 2F-22 06.BaseC4 2 081214 LL(copy) 16,820.22 90.47 188.18 6,124.27 6,000.72 159,434.36-1,128,431.07 5,934,577.24 516,367.34 2.87 13,870.25 MWD+IFR-AK-CAZ-SC(4) 16,914.74 88.96 189.29 6,124.74 6,001.19 159,340.94-1,128,445.42 5,934,482.59 516,367.34 1.98 13,964.29 MWD+IFR-AK-CAZ-SC(4) 17,010.52 88.67 188.09 6,126.72 6,003.17 159,246.28-1,128,459.89 5,934,386.69 516,367.42 1.29 14,059.57 MWD+IFR-AK-CAZ-SC(4) 17,104.09 88.63 188.58 6,128.93 6,005.38 159,153.73-1,128,473.45 5,934,293.02 516,368.07 0.53 14,152.71 MWD+IFR-AK-CAZ-SC(4) 17,199.24 88.45 187.82 6,131.35 6,007.80 159,059.58-1,128,487.02 5,934,197.77 516,368.97 0.82 14,247.44 MW D+I FR-AK-CAZ-SC(4) 17293.87 89.50 185.51 6,133.05 6,009.50 158,965.61-1,128,498.00 5,934,103.09 516,372.39 2.68 14,341.85 MW D+I FR-AK-CAZ-SC(4) 17,388.79 89.56 186.90 6,133.82 6,010.27 158,871.26-1,128,508.26 5,934,008.13 516,376.59 1.47 14,436.62 MW D+I FR-AK-CAZ-SC(4) 17,483.99 89.56 185.41 6,134.55 6,011.00 158,776.61-1,128,518.46 5,933,912.90 516,380.88 1.57 14,531.67 MW D+I FR-AK-CAZ-SC(4) 17,578.89 89.90 186.16 6,135.00 6,011.45 158,682.20-1,128,528.03 5,933,817.99 516,385.77 0.87 14,626.45 MWD+IFR-AK-CAZ-SC(4) 17,673.22 89.76 186.31 6,135.28 6,011.73 158,588.42-1,128,538.27 5,933,723.62 516,389.90 0.22 14,720.63 MW D+I FR-AK-CAZ-SC(4) 17,771.27 89.38 184.50 6,136.02 6,012.47 158,490.82-1,128,547.51 5,933,625.60 516,395.60 1.89 14,818.59 MW D+I FR-AK-CAZ-SC(4) 17,863.34 90.15 183.17 6,136.40 6,012.85 158,398.96-1,128,553.67 5,933,533.74 516,403.48 1.67 14,910.65 MWD+IFR-AK-CAZ-SC(4) 1/21/2015 1:05:31PM Page 7 COMPASS 5000.1 Build 65 Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well 2F-22 Project: Kuparuk River Unit TVD Reference: Rig:95.8+27.75 @ 123.55usft(Doyon 141) Site: Kuparuk 2F Pad MD Reference: Rig:95.8+27.75 @ 123.55usft(Doyon 141) Well: 2F-22 North Reference: True Wellbore: 2F-22 Survey Calculation Method: Minimum Curvature Design: 2F-22 Database: OAKEDMP2 Survey Map Map Vertical MD Inc Azi TVD TVDSS +NI-S +E/-W Northing Easting DLS Section (usft) (°) (°) (usft) (usft) (usft) (usft) (ft) (ft) (°/100') (ft) Survey Tool Name 17,957.75 89.55 181.92 6,136.64 6,013.09 158,304.64-1,128,557.86 5,933,439.75 516,413.67 1.47 15,005.05 MWD+IFR-AK-CAZ-SC(4) 18,050.99 90.15 183.79 6,136.89 6,013.34 158,211.52-1,128,562.50 5,933,346.87 516,423.24 2.11 15,098.29 MWD+IFR-AK-CAZ-SC(4) 18,144.24 89.56 185.40 6,137.12 6,013.57 158,118.58-1,128,569.97 5,933,253.74 516,429.98 1.84 15,191.50 MWD+IFR-AK-CAZ-SC(4) 18,239.33 89.49 191.35 6,137.91 6,014.36 158,024.55-1,128,583.82 5,933,158.56 516,430.58 6.26 15,286.12 MWD+IFR-AK-CAZSC(4) 18,334.70 90.00 189.85 6,138.34 6,014.79 157,930.81-1,128,601.36 5,933,063.11 516,427.48 1.66 15,380.65 MWD+IFR-AK-CAZ-SC(4) 18,426.43 89.87 192.53 6,138.44 6,014.89 157,840.83-1,128,619.16 5,932,971.34 516,423.54 2.93 15,471.44 MWD+IFR-AK-CAZ-SC(4) 18,524.63 88.86 193.01 6,139.53 6,015.98 157,745.07-1,128,640.86 5,932,873.26 516,416.63 1.14 15,568.21 MWD+1FR-AK-CAZ-SC(4) 18,590.73 89.02 194.57 6,140.75 6,017.20 157,680.88 -1,128,656.61 5,932,807.33 516,410.80 2.37 15,633.13 MWD+IFR-AK-CAZ-SC(4) 2F-22 07.C4 081214 LL(copy) 18,619.35 89.09 195.24 6,141.22 6,017.67 157,653.23-1,128,663.97 5,932,778.84 516,407.72 2.37 15,661.12 MWD+IFR-AK-CAZ-SC(4) 18,713.28 88.24 193.87 6,143.41 6,019.86 157,562.34-1,128,687.57 5,932,685.29 516,398.19 1.72 15,753.12 MWD+IFR-AK-CAZ-SC(4) 18,809.39 88.36 191.52 6,146.26 6,022.71 157,468.63-1,128,708.68 5,932,589.32 516,391.54 2.45 15,847.81 MWD+IFR-AK-CAZ-SC(4) 18,904.31 89.08 189.06 6,148.38 6,024.83 157,375.27-1,128,725.63 5,932,494.33 516,388.97 2.70 15,941.93 MWD+IFR-AK-CAZ-SC(4) 18,999.47 89.39 187.49 6,149.65 6,026.10 157,281.11-1,128,739.33 5,932,399.05 516,389.74 1.68 16,036.68 MWD+IFR-AK-CAZSC(4) 19,093.74 90.43 187.66 6,149.80 6,026.25 157,187.66-1,128,751.75 5,932,304.67 516,391.65 1.12 16,130.65 MWD+IFR-AK-CAZ-SC(4) 19,188.62 89.17 187.25 6,150.13 6,026.58 157,093.59-1,128,764.06 5,932,209.68 516,393.77 1.40 16,225.24 MWD+IFR-AK-CAZ-SC(4) 19,282.88 88.94 185.62 6,151.69 6,028.14 156,999.94-1,128,774.63 5,932,115.38 516,397.56 1.75 16,319.31 MWD+IFR-AK-CAZ-SC(4) 19,375.79 88.63 182.38 6,153.66 6,030.11 156,907.29-1,128,781.10 5,932,022.69 516,405.24 3.50 16,412.17 MWD+IFR-AK-CAZSC(4) 19,472.47 88.31 180.17 6,156.24 6,032.69 156,810.67-1,128,783.26 5,931,926.73 516,417.81 2.31 16,508.77 MWD+IFR-AK-CAZ-SC(4) 19,566.18 89.15 181.18 6,158.32 6,034.77 156,716.99-1,128,784.36 5,931,833.84 516,430.96 1.40 16,602.38 MWD+IFR-AK-CAZ-SC(4) 19,640.21 89.26 180.02 6,159.35 6,035.80 156,642.98-1,128,785.13 5,931,760.46 516,441.46 1.58 16,676.33 MWD+IFR-AK-CAZ-SC(4) 2F-22 08.NearBaseC4 081214 LL(copy) 19,657.13 89.28 179.75 6,159.56 6,036.01 156,626.06-1,128,785.10 5,931,743.72 516,444.06 1.58 16,693.23 MWD+IFR-AK-CAZ-SC(4) 19,753.38 89.08 177.87 6,160.94 6,037.39 156,529.84-1,128,783.10 5,931,648.79 516,460.68 1.96 16,789.21 MWD+IFR-AK-CAZ-SC(4) 19,848.83 89.18 177.58 6,162.39 6,038.84 156,434.48 -1,128,779.31 5,931,554.97 516,478.93 0.32 16,884.24 MWD+IFR-AK-CAZ-SC(4) 19,943.41 88.39 177.69 6,164.40 6,040.85 156,340.00 -1,128,775.41 5,931,462.05 516,497.16 0.84 16,978.38 MWD+IFR-AK-CAZ-SC(4) 20,038.15 87.91 172.41 6,167.46 6,043.91 156,245.70-1,128,767.24 5,931,369.95 516,519.59 5.59 17,072.13 MWD+IFR-AK-CAZ-SC(4) 2F-22 08.C4_2 081214 LL(copy) 20,131.96 86.80 165.30 6,171.79 6,048.24 156,153.82-1,128,749.14 5,931,281.76 516,551.48 7.66 17,162.94 MWD+IFR-AK-CAZ-SC(4) 20,225.83 87.61 165.23 6,176.37 6,052.82 156,063.14-1,128,725.29 5,931,195.64 516,588.88 0.87 17,252.24 MWD+IFR-AK-CAZ-SC(4) 20,319.86 86.98 160.68 6,180.81 6,057.26 155,973.37-1,128,697.77 5,931,110.96 516,629.77 4.88 17,340.46 MWD+IFR-AK-CAZ-SC(4) 2F-22110.TD 081214 LL(copy) 20,416.07 86.45 159.30 6,186.32 6,062.77 155,883.11-1,128,664.91 5,931,026.63 516,676.03 1.53 17,428.86 MWD+IFR-AK-CAZ-SC(4) 20,511.15 88.23 160.78 6,190.73 6,067.18 155,793.85-1,128,632.49 5,930,943.21 516,721.70 2.43 17,516.31 MWD+IFR-AK-CAZ-SC(4) 20,605.13 88.67 160.16 6,193.28 6,069.73 155,705.31-1,128,601.08 5,930,860.34 516,766.25 0.81 17,603.09 MW D+I FR-AK-CAZ-SC(4) 20,658.68 88.80 160.05 6,194.46 6,070.91 155,654.97-1,128,582.86 5,930,813.29 516,791.94 0.32 17,652.40 MWD+IFR-AK-CAZ-SC(4) 20,699.36 89.11 158.22 6,195.20 6,071.65 155,616.96-1,128,568.38 5,930,777.87 516,812.06 4.56 17,689.60 MWD+IFR-AK-CAZ-SC(4) 20,741.60 91.36 158.10 6,195.03 6,071.48 155,577.76-1,128,552.66 5,930,741.46 516,833.57 5.33 17,727.93 MWD+IFR-AK-CAZ-SC(4) 20,793.28 92.83 160.64 6,193.14 6,069.59 155,529.43-1,128,534.47 5,930,696.39 516,858.93 5.68 17,775.24 MWD+IFR-AK-CAZ-SC(4) 20,835.64 92.23 163.02 6,191.27 6,067.72 155,489.22-1,128,521.27 5,930,658.60 516,878.11 5.79 17,814.70 MWD+IFR-AK-CAZ-SC(4) 20,885.63 91.11 165.62 6,189.81 6,066.26 155,441.12-1,128,507.77 5,930,613.04 516,898.79 5.66 17,862.03 MWD+IFR-AK-CAZ-SC(4) 1/21/2015 1:05:31PM Page 8 COMPASS 5000.1 Build 65 Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well 2F-22 Project: Kuparuk River Unit TVD Reference: Rig:95.8+27.75 @ 123.55usft(Doyon 141) Site: Kuparuk 2F Pad MD Reference: Rig:95.8+27.75 @ 123.55usft(Doyon 141) Well: 2F-22 North Reference: True Wellbore: 2F-22 Survey Calculation Method: Minimum Curvature Design: 2F-22 Database: OAKEDMP2 Survey Map Map Vertical MD Inc Azi TVD TVDSS +NI-S +EI-W Northing Easting DLS Section (usft) (°) (°) (usft) (usft) (usft) (usft) (ft) (ft) (°/1001 (ft) Survey Tool Name 20,981.77 90.45 172.33 6,188.50 6,064.95 155,346.82-1,128,489.40 5,930,522.49 516,931.32 7.01 17,955.24 MWD+IFR-AK-CAZ-SC(4) 21,076.66 92.69 179.95 6,185.90 6,062.35 155,252.25-1,128,483.01 5,930,429.87 516,952.02 8.37 18,049.34 MWD+IFR-AK-CAZ-SC(4) 21,171.79 89.18 185.40 6,184.34 6,060.79 155,157.29-1,128,487.45 5,930,335.20 516,962.07 6.81 18,144.41 MWD+IFR-AK-CAZ-SC(4) 21,266.65 88.63 188.44 6,186.16 6,062.61 155,063.15-1,128,498.88 5,930,240.28 516,965.08 3.26 18,239.01 MWD+IFR-AK-CAZ-SC(4) 21,361.16 88.94 188.28 6,188.16 6,064.61 154,969.67-1,128,512.62 5,930,145.66 516,965.70 0.37 18,333.09 MWD+IFR-AK-CAZ-SC(4) 21,456.40 88.55 187.62 6,190.25 6,066.70 154,875.36-1,128,525.79 5,930,050.31 516,967.01 0.80 18,427.95 MWD+IFR-AK-CAZ-SC(4) 21,551.15 86.16 188.24 6,194.62 6,071.07 154,781.63-1,128,538.84 5,929,955.55 516,968.35 2.61 18,522.24 MWD+IFR-AK-CAZ-SC(4) 21,645.03 86.71 187.66 6,200.46 6,076.91 154,688.83-1,128,551.80 5,929,861.73 516,969.63 0.85 18,615.59 MWD+IFR-AK-CAZ-SC(4) 21,739.07 86.22 187.76 6,206.26 6,082.71 154,595.82-1,128,564.39 5,929,767.75 516,971.32 0.53 18,709.14 MWD+IFR-AK-CAZ-SC(4) 21,833.88 91.88 188.09 6,207.83 6,084.28 154,501.96-1,128,577.46 5,929,672.86 516,972.66 5.98 18,803.54 MWD+IFR-AK-CAZ-SC(4) 21,928.00 89.97 182.56 6,206.31 6,082.76 154,408.30-1,128,586.19 5,929,578.83 516,978.27 6.22 18,897.53 MWD+IFR-AK-CAZ-SC(4) 21,990.00 89.97 182.56 6,206.34 6,082.79 154,346.37-1,128,588.96 5,929,517.10 516,984.95 0.00 18,959.53 PROJECTED to TD 4 1/2"x 6-3/4" 22,009.00 89.97 182.56 6,206.35 6,082.80 154,327.38-1,128,589.80 5,929,498.18 516,986.99 0.00 18,978.53 PROJECTED to TD Projection to TD 1/21/2015 1:05:31PM Page 9 COMPASS 5000.1 Build 65 214150 25342 RECEIVED FEB 0 3 2015 AOGCC FINAL ConocoPhillips (Alaska) Inc. -Kup2 Kuparuk River Unit Kuparuk 2F Pad 2F-22 Definitive Survey Report r[NI A D 8 3 21 January, 2015 Definitive Survey Report Company: ConocoPhillips(Alaska)Inc.-Kup2 Local Co-ordinate Reference: Well 2F-22 Project: Kuparuk River Unit TVD Reference: Rig:95.8+27.75©123.55usft(Doyon 141) Site: Kuparuk 2F Pad MD Reference: Rig:95.8+27.75 @ 123.55usft(Doyon 141) Well: 2F-22 North Reference: True Wellbore: 2F-22 Survey Calculation Method: Minimum Curvature Design: 2F-22 Database: OAKEDMP2 Project Kuparuk River Unit,North Slope Alaska,United States Map System: US State Plane 1983 System Datum: Mean Sea Level Geo Datum: North American Datum 1983 Using Well Reference Point Map Zone: Alaska Zone 4 Using geodetic scale factor Well 2F-22 Well Position +N/-S 0.00 usft Northing: 5,948,402.54 usft Latitude: 70°16'14.104 N +E/-W 0.00 usft Easting: 1,657,543.27 usft Longitude: 149°51'41.350 W Position Uncertainty 0.00 usft Wellhead Elevation: usft Ground Level: 95.80 usft Wellbore 2F-22 Magnetics Model Name Sample Date Declination Dip Angle Field Strength (") (') (nT) BGG M2014 11/25/2014 19.05 80.87 57,567 Design 2F-22 Audit Notes: Version: 1.0 Phase: ACTUAL Tie On Depth: 27.75 Vertical Section: Depth From(TVD) +N/-S +El-W Direction (usft) (usft) (usft) (0) 27.75 0.00 0.00 183.00 Survey Program Date 1/21/2015 From To (usft) (usft) Survey(Wellbore) Tool Name Description Survey Date 79.61 1,008.41 2F-22 Srvy#1-GYD-GC-SS(2F-22) GYD-GC-SS Gyrodata gyro single shots 12/12/2014 3:1E 1,063.31 3,770.69 2F-22 Srvy#2-MWD+IFR-AK-CAZ-SC( MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 12/12/2014 3:1E 3,770.69 13,406.12 2F-22 Srvy#3-MWD+IFR-AK-CAZ-SC( MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 12/18/2014 9:12 13,506.29 21,928.00 2F-22 Srvy#4-MWD+IFR-AK-CAZ-SC( MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 1/2/2015 5:11:0i Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +E/-W Northing Easting DLS Section (usft) (0) (°) (usft) (usft) (usft) (usft) (ft) (ft) ('/100') (ft) Survey Tool Name 27.75 0.00 0.00 27.75 -95.80 0.00 0.00 5,948,402.54 1,657,543.27 0.00 0.00 UNDEFINED 79.62 0.23 265.47 79.62 -43.93 -0.01 -0.10 5,948,402.53 1,657,543.17 0.44 0.01 GYD-GC-SS(1) 182.45 0.46 217.97 182.45 58.90 -0.35 -0.56 5,948,402.19 1,657,542.71 0.34 0.38 GYD-GC-SS(1) 265.72 0.37 214.18 265.72 142.17 -0.84 -0.92 5,948,401.70 1,657,542.35 0.11 0.88 GYD-GC-SS(1) 357.72 0.69 240.40 357.71 234.16 -1.36 -1.57 5,948,401.18 1,657,541.70 0.43 1.44 GYD-GC-SS(1) 453.67 1.58 247.75 453.64 330.09 -2.14 -3.30 5,948,400.39 1,657,539.98 0.94 2.31 GYD-GC-SS(1) 546.40 2.34 260.25 546.32 422.77 -2.95 -6.34 5,948,399.58 1,657,536.93 0.94 3.27 GYD-GC-SS(1) 638.12 3.11 264.69 637.93 514.38 -3.49 -10.67 5,948,399.02 1,657,532.61 0.87 4.05 GYD-GC-SS(1) 731.57 5.74 266.92 731.10 607.55 -3.98 -17.86 5,948,398.52 1,657,525.42 2.82 4.91 GYD-GC-SS(1) 826.60 9.95 264.08 825.22 701.67 -5.08 -30.78 5,948,397.39 1,657,512.51 4.45 6.69 GYD-GC-SS(1) 915.27 12.72 260.69 912.15 788.60 -7.45 -48.03 5,948,394.98 1,657,495.26 3.21 9.96 GYD-GC-SS(1) 1/21/2015 12:02:13PM Page 2 COMPASS 5000.1 Build 65 Definitive Survey Report Company: ConocoPhillips(Alaska)Inc.-Kup2 Local Co-ordinate Reference: Well 2F-22 Project: Kuparuk River Unit TVD Reference: Rig:95.8+27.75 @ 123.55usft(Doyon 141) Site: Kuparuk 2F Pad MD Reference: Rig:95.8+27.75 @ 123.55usft(Doyon 141) Well: 2F-22 North Reference: True Wellbore: 2F-22 Survey Calculation Method: Minimum Curvature Design: 2F-22 Database: OAKEDMP2 Survey Map Map Vertical MD Inc Azi ND TVDSS +N/-S +E/-W Northing Easting DLS Section (usft) (") (°) (usft) (usft) (usft) (usft) (ft) (ft) (1100') (ft) Survey Tool Name 1,008.41 14.15 262.44 1,002.74 879.19 -10.61 -69.44 5,948,391.77 1,657,473.86 1.60 14.23 GYD-GC-SS(1) 1,063.31 16.97 260.70 1,055.62 932.07 -12.79 -84.00 5,948,389.56 1,657,459.31 5.21 17.17 MWD+IFR-AK-CAZ-SC(2) 1,122.73 20.05 258.68 1,111.96 988.41 -16.19 -102.55 5,948,386.12 1,657,440.77 5.29 21.53 MWD+IFR-AK-CAZ-SC(2) 1,158.10 21.73 257.16 1,145.01 1,021.46 -18.83 -114.88 5,948,383.45 1,657,428.44 4.99 24.82 MVVD+IFR-AK-CAZ-SC(2) 1,207.34 22.32 256.15 1,190.65 1,067.10 -23.10 -132.85 5,948,379.14 1,657,410.49 1.42 30.02 MVVD+IFR-AK-CAZ-SC(2) 1,251.53 22.96 255.34 1,231.44 1,107.89 -27.29 -149.33 5,948,374.92 1,657,394.02 1.61 35.07 MWD+IFR-AK-CAZ-SC(2) 1,346.03 21.90 254.44 1,318.79 1,195.24 -36.68 -184.14 5,948,365.44 1,657,359.23 1.18 46.27 MWD+IFR-AK-CAZ-SC(2) 1,439.88 21.48 253.71 1,405.99 1,282.44 -46.20 -217.50 5,948,355.85 1,657,325.90 0.53 57.51 MWD+IFR-AK-CAZ-SC(2) 1,531.81 23.47 247.64 1,490.95 1,367.40 -57.88 -250.59 5,948,344.09 1,657,292.84 3.32 70.92 MWD+IFR-AK-CAZ-SC(2) 1,628.24 26.31 241.06 1,578.43 1,454.88 -75.54 -287.07 5,948,326.36 1,657,256.41 4.11 90.46 MWD+IFR-AK-CAZ-SC(2) 1,720.45 28.11 239.22 1,660.43 1,536.88 -96.54 -323.62 5,948,305.27 1,657,219.91 2.15 113.35 MWD+IFR-AK-CAZ-SC(2) 1,816.96 28.19 238.07 1,745.53 1,621.98 -120.23 -362.50 5,948,281.49 1,657,181.09 0.57 139.04 MWD+IFR-AK-CAZ-SC(2) 1,913.45 30.73 235.12 1,829.54 1,705.99 -146.39 -402.07 5,948,255.25 1,657,141.57 3.03 167.23 MWD+IFR-AK-CAZ-SC(2) 2,008.67 32.06 231.04 1,910.82 1,787.27 -176.20 -441.69 5,948,225.35 1,657,102.03 2.63 199.07 MWD+IFR-AK-CAZ-SC(2) 2,100.43 35.23 225.62 1,987.22 1,863.67 -210.04 -479.56 5,948,191.43 1,657,064.24 4.76 234.85 MWD+IFR-AK-CAZ-SC(2) 2,195.13 38.35 225.07 2,063.05 1,939.50 -249.90 -519.89 5,948,151.48 1,657,024.00 3.31 276.77 MWD+IFR-AK-CAZ-SC(2) 2,289.34 41.58 222.06 2,135.25 2,011.70 -293.77 -561.54 5,948.107.52 1,656,982.46 3.99 322.76 MWD+IFR-AK-CAZ-SC(2) 2,383.00 43.50 221.18 2,204.26 2,080.71 -341.11 -603.59 5,948,060.09 1,656,940.52 2.15 372.23 MWD+IFR-AK-CAZ-SC(2) 2,468.98 45.03 217.26 2,265.84 2,142.29 -387.60 -641.49 5,948,013.52 1,656,902.72 3.65 420.64 MWD+IFR-AK-CAZ-SC(2) 2,564.60 46.45 215.40 2,332.58 2,209.03 -442.77 -682.05 5,947,958.26 1,656,862.30 2.04 477.86 MWD+IFR-AK-CAZ-SC(2) 2,657.20 49.07 211.56 2,394.84 2,271.29 -499.95 -719.81 5,947,901.00 1,656,824.67 4.17 536.94 MWD+IFR-AK-CAZ-SC(2) 2,748.49 52.56 207.08 2,452.52 2,328.97 -561.65 -754.38 5,947,839.23 1,656,790.24 5.39 600.36 MWD+IFR-AK-CAZ-SC(2) 2,819.51 53.91 204.63 2,495.03 2,371.48 -612.84 -779.18 5,947,787.99 1,656,765.57 3.35 652.78 MWD+IFR-AK-CAZ-SC(2) 2,842.45 53.97 204.33 2,508.54 2,384.99 -629.72 -786.86 5,947,771.09 1,656,757.92 1.09 670.04 MWD+IFR-AK-CAZ-SC(2) 2,934.83 55.11 203.25 2,562.13 2,438.58 -698.57 -817.21 5,947,702.18 1,656,727.73 1.56 740.38 MWD+IFR-AK-CAZ-SC(2) 3,027.00 57.68 201.85 2,613.14 2,489.59 -769.46 -846.63 5,947,631.23 1,656,698.48 3.06 812.72 MWD+IFR-AK-CAZ-SC(2) 3,120.12 60.71 199.71 2,660.83 2,537.28 -844.24 -874.98 5,947,556.40 1,656,670.30 3.81 888.87 MWD+IFR-AK-CAZ-SC(2) 3,212.18 61.25 199.23 2,705.49 2,581.94 -920.13 -901.81 5,947,480.45 1,656,643.64 0.74 966.07 MWD+IFR-AK-CAZ-SC(2) 3,305.12 63.03 197.79 2,748.92 2,625.37 -998.05 -927.89 5,947,402.48 1,656,617.75 2.35 1,045.24 MWD+IFR-AK-CAZ-SC(2) 3,396.84 65.11 196.46 2,789.03 2,665.48 -1,076.87 -952.17 5,947,323.61 1,656,593.65 2.62 1,125.23 MWD+IFR-AK-CAZ-SC(2) 3,491.62 67.26 194.77 2,827.30 2,703.75 -1,160.38 -975.49 5,947,240.06 1,656,570.52 2.79 1,209.84 MWD+IFR-AK-CAZ-SC(2) 3,585.58 68.57 192.07 2,862.63 2,739.08 -1,245.06 -995.69 5,947,155.35 1,656,550.52 3.01 1,295.46 MWD+IFR-AK-CAZ-SC(2) 3,679.77 70.33 190.19 2,895.69 2,772.14 -1,331.59 -1,012.70 5,947,068.79 1,656,533.70 2.64 1,382.76 MWD+IFR-AK-CAZ-SC(2) 3,770.69 70.13 188.59 2,926.45 2,802.90 -1,416.00 -1,026.66 5,946,984.35 1,656,519.93 1.67 1,467.79 MWD+IFR-AK-CAZ-SC(2) 3,836.66 71.73 189.53 2,948.00 2,824.45 -1,477.57 -1,036.48 5,946,922.77 1,656,510.25 2.77 1,529.79 MWD+IFR-AK-CAZ-SC(3) 3,904.00 71.44 188.62 2,969.27 2,845.72 -1,540.66 -1,046.56 5,946,859.66 1,656,500.32 1.36 1,593.32 MWD+IFR-AK-CAZ-SC(3) 10 3/4"x 13-1/2 3,935.28 71.31 188.19 2,979.26 2,855.71 -1,569.98 -1,050.89 5,946,830.33 1,656,496.06 1.36 1,622.83 MWD+IFR-AK-CAZ-SC(3) 3,999.54 72.33 187.79 2,999.31 2,875.76 -1,630.44 -1,059.38 5,946,769.86 1,656,487.71 1.69 1,683.65 MWD+IFR-AK-CAZ-SC(3) 4,091.35 71.16 188.56 3,028.07 2,904.52 -1,716.74 -1,071.77 5,946,683.54 1,656,475.51 1.50 1,770.48 MWD+IFR-AK-CAZ-SC(3) 1/21/2015 12:02:13PM Page 3 COMPASS 5000.1 Build 65 Definitive Survey Report Company: ConocoPhillips(Alaska)Inc.-Kup2 Local Co-ordinate Reference: Well 2F-22 Project: Kuparuk River Unit TVD Reference: Rig:95.8+27.75 @ 123.55usft(Doyon 141) Site: Kuparuk 2F Pad MD Reference: Rig:95.8+27.75 @ 123.55usft(Doyon 141) Well: 2F-22 North Reference: True Wellbore: 2F-22 Survey Calculation Method: Minimum Curvature Design: 2F-22 Database: OAKEDMP2 Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +E/-W Northing Easting DLS Section (usft) (°) (°) (usft) (usft) (usft) (usft) (ft) (ft) (°/100') (ft) Survey Tool Name 4,183.94 71,33 188.24 3,057.84 2,934.29 -1,803.47 -1,084.58 5,946,596.78 1,656,462.91 0.38 1,857.76 MWD+IFR-AK-CAZ-SC(3) 4,279.19 70.61 188.55 3,088.90 2,965.35 -1,892.55 -1,097.72 5,946,507.68 1,656,449.96 0.82 1,947.41 MWD+IFR-AK-CAZ-SC(3) 4,372.49 70.69 188.84 3,119.81 2,996.26 -1,979.57 -1,111.03 5,946,420.64 1,656,436.86 0.31 2,035.00 MWD+IFR-AK-CAZ-SC(3) 4,464.41 70.72 189.07 3,150.19 3,026.64 -2,065.27 -1,124.54 5,946,334.92 1,656,423.55 0.24 2,121.29 M1ND+IFR-AK-CAZSC(3) 4,560.77 70.56 190.28 3,182.13 3,058.58 -2,154.89 -1,139.81 5,946,245.28 1,656,408.48 1.20 2,211.59 MVVD+IFR-AK-CAZ-SC(3) 4,655.31 70.45 190.56 3,213.68 3,090.13 -2,242.54 -1,155.93 5,946,157.60 1,656,392.56 0.30 2,299.96 MWD+IFR-AK-CAZ-SC(3) 4,747.57 70.44 190.85 3,244.56 3,121.01 -2,327.96 -1,172.08 5,946,072.15 1,656,376.60 0.30 2,386.11 MWD+IFR-AK-CAZ-SC(3) 4,840.10 70.51 190.77 3,275.49 3,151.94 -2,413.62 -1,188.44 5,945,986.46 1,656,360.45 0.11 2,472.51 MWD+IFR-AK-CAZ-SC(3) 4,933.29 70.54 190.87 3,306.56 3,183.01 -2,499.92 -1,204.93 5,945,900.13 1,656,344.15 0.11 2,559.55 MWD+IFR-AK-CAZ-SC(3) 5,026.96 70.47 190.67 3,337.82 3,214.27 -2,586.66 -1,221.43 5,945,813.36 1,656,327.85 0.21 2,647.04 MWD+IFR-AK-CAZ-SC(3) 5,122.63 70.36 190.89 3,369.88 3,246.33 -2,675.21 -1,238.29 5,945,724.79 1,656,311.19 0.25 2,736.35 MWD+IFR-AK-CAZ-SC(3) 5,214.46 70.29 190.83 3,400.80 3,277.25 -2,760.13 -1,254.58 5,945,639.84 1,656,295.10 0.10 2,822.01 MWD+IFR-AK-CAZ-SC(3) 5,310.61 70.49 190.51 3,433.07 3,309.52 -2,849.14 -1,271.35 5,945,550.80 1,656,278.53 0.38 2,911.77 MWD+IFR-AK-CAZ-SC(3) 5,404.73 70.99 190.29 3,464.12 3,340.57 -2,936.53 -1,287.39 5,945,463.38 1,656,262.69 0.58 2,999.88 MWD+IFR-AK-CAZ-SC(3) 5,497.45 70.99 190.90 3,494.32 3,370.77 -3,022.70 -1,303.51 5,945,377.19 1,656,246.77 0.62 3,086.77 MWD+IFR-AK-CAZ-SC(3) 5,589.44 71.02 190.71 3,524.26 3,400.71 -3,108.13 -1,319.82 5,945,291.72 1,656,230.66 0.20 3,172.95 MWD+IFR-AK-CAZ-SC(3) 5,683.39 70.93 190.90 3,554.89 3,431.34 -3,195.38 -1,336.47 5,945,204.45 1,656,214.21 0.21 3,260.94 MWD+IFR-AK-CAZ-SC(3) 5,775.45 70.99 190.24 3,584.92 3,461.37 -3,280.92 -1,352.43 5,945,118.87 1,656,198.45 0.68 3,347.21 MWD+IFR-AK-CAZ-SC(3) 5,870.15 71.05 188.82 3,615.72 3,492.17 -3,369.24 -1,367.25 5,945,030.54 1,656,183.82 1.42 3,436.18 MWD+IFR-AK-CAZSC(3) 5,962.92 70.93 188.61 3,645.94 3,522.39 -3,455.94 -1,380.54 5,944,943.82 1,656,170.73 0.25 3,523.45 MWD+IFR-AK-CAZ-SC(3) 6,055.51 70.65 188.68 3,676.41 3,552.86 -3,542.38 -1,393.69 5,944,857.35 1,656,157.79 0.31 3,610.46 MWD+IFR-AK-CAZ-SC(3) 6,148.00 70.69 189.06 3,707.02 3,583.47 -3,628.61 -1,407.14 5,944,771.10 1,656,144.53 0.39 3,697.28 MWD+IFR-AK-CAZ-SC(3) 6,240.11 70.57 189.23 3,737.57 3,614.02 -3,714.40 -1,420.95 5,944,685.29 1,656,130.91 0.22 3,783.68 MWD+IFR-AK-CAZ-SC(3) 6,333.12 70.50 189.18 3,768.56 3,645.01 -3,800.96 -1,434.98 5,944,598.70 1,656,117.08 0.09 3,870.86 MWD+IFR-AK-CAZ-SC(3) 6,427.37 70.56 189.21 3,799.98 3,676.43 -3,888.68 -1,449.18 5,944,510.96 1,656,103.08 0.07 3,959.20 MWD+IFR-AK-CAZ-SC(3) 6,520.58 70.56 190.04 3,831.00 3,707.45 -3,975.34 -1,463.88 5,944,424.27 1,656,088.59 0.84 4,046.51 MWD+IFR-AK-CAZ-SC(3) 6,612.63 70.57 189.93 3,861.63 3,738.08 -4,060.83 -1,478.93 5,944,338.76 1,656,073.73 0.11 4,132.67 MWD+IFR-AK-CAZSC(3) 6,706.10 70.45 190.10 3,892.82 3,769.27 -4,147.60 -1,494.25 5,944,251.96 1,656,058.61 0.21 4,220.12 MWD+IFR-AK-CAZSC(3) 6,799.85 70.57 188.99 3,924.10 3,800.55 -4,234.76 -1,508.91 5,944,164.78 1,656,044.15 1.12 4,307.92 MWD+IFR-AK-CAZSC(3) 6,892.41 70.50 188.51 3,954.94 3,831.39 -4,321.01 -1,522.18 5,944,078.51 1,656,031.07 0.49 4,394.75 MWD+IFR-AK-CAZSC(3) 6,985.30 70.44 188.50 3,985.99 3,862.44 -4,407.59 -1,535.13 5,943,991.91 1,656,018.33 0.07 4,481.89 MWD+IFR-AK-CAZSC(3) 7,077.37 70.82 188.77 4,016.53 3,892.98 -4,493.47 -1,548.17 5,943,906.01 1,656,005.48 0.50 4,568.33 MWD+IFR-AK-CAZSC(3) 7,169.13 70.37 188.93 4,047.02 3,923.47 -4,578.98 -1,561.49 5,943,820.47 1,655,992.36 0.52 4,654.43 MVVD+IFR-AK-CAZ-SC(3) 7,263.54 70.35 188.35 4,078.75 3,955.20 -4,666.89 -1,574.84 5,943,732.54 1,655,979.21 0.58 4,742.92 MWD+IFR-AK-CAZSC(3) 7,356.21 70.39 189.04 4,109.88 3,986.33 -4,753.17 -1,588.04 5,943,646.24 1,655,966.21 0.70 4,829.77 MVVD+IFR-AK-CAZ-SC(3) 7,448.46 70.41 189.81 4,140.83 4,017.28 -4,838.90 -1,602.27 5,943,560.49 1,655,952.17 0.79 4,916.13 MWD+IFR-AK-CAZSC(3) 7,541.64 70.78 189.65 4,171.78 4,048.23 -4,925.52 -1,617.12 5,943,473.84 1,655,937.52 0.43 5,003.41 MWD+IFR-AK-CAZSC(3) 7,636.07 70.81 190.67 4,202.85 4,079.30 -5,013.30 -1,632.85 5,943,386.04 1,655,921.99 1.02 5,091.89 MWD+IFR-AK-CAZSC(3) 7,727.50 70.77 191.44 4,232.93 4,109.38 -5,098.04 -1,649.41 5,943,301.27 1,655,905.63 0.80 5,177.37 MWD+IFR-AK-CAZSC(3) 7,820.25 70.84 191.33 4,263.43 4,139.88 -5,183.91 -1,666.70 5,943,215.37 1,655,888.54 0.14 5,264.03 MWD+IFR-AK-CAZSC(3) 1/21/2015 12 02:13PM Page 4 COMPASS 5000.1 Build 65 Definitive Survey Report Company: ConocoPhillips(Alaska)Inc.-Kup2 Local Co-ordinate Reference: Well 2F-22 Project: Kuparuk River Unit TVD Reference: Rig:95.8+27.75©123.55usft(Doyon 141) Site: Kuparuk 2F Pad MD Reference: Rig:95.8+27.75 @ 123.55usft(Doyon 141) Well: 2F-22 North Reference: True Wellbore: 2F-22 Survey Calculation Method: Minimum Curvature Design: 2F-22 Database: OAKEDMP2 Survey Map Map Vertical MD Inc Azi TVD TVDSS +W/.S +E/-W Northing Easting DLS Section (usft) (°b (') (usft) (usft) (usft) (usft) (ft) (ft) 01001 ((t) Survey Tool Name 7,912.41 70.78 191.61 4,293.72 4,170.17 -5,269.21 -1,684.01 5,943,130.04 1,655,871.42 0.29 5,350.12 MWD+IFR-AK-CAZ-SC(3) 8,004.59 70.80 190.69 4,324.05 4,200.50 -5,354.61 -1,700.84 5,943,044.61 1,655,854.79 0.94 5,436.29 MWD+IFR-AK-CAZSC(3) 8,096.10 70.83 191.37 4,354.12 4,230.57 -5,439.44 -1,717.38 5,942,959.75 1,655,838.45 0.70 5,521.87 MWD+IFR-AK-CAZ-SC(3) 8,189.06 70.90 191.29 4,384.59 4,261.04 -5,525.55 -1,734.63 5,942,873.61 1,655,821.39 0.11 5,608.76 MWD+IFR-AK-CAZ-SC(3) 8,281.88 70.90 190.28 4,414.97 4,291.42 -5,611.71 -1,751.04 5,942,787.42 1,655,805.17 1.03 5,695.66 MVVD+IFR-AK-CAZ-SC(3) 8,374.58 70.81 189.07 4,445.37 4,321.82 -5,698.04 -1,765.76 5,942,701.07 1,655,790.66 1.24 5,782.64 MWD+IFR-AK-CAZSC(3) 8,466.97 70.86 188.19 4,475.70 4,352.15 -5,784.32 -1,778.86 5,942,614.77 1,655,777.76 0.90 5,869.49 MWD+IFR-AK-CAZSC(3) 8,559.31 70.87 188.38 4,505.97 4,382.42 -5,870.65 -1,791.43 5,942,528.42 1,655,765.39 0.19 5,956.36 MWD+IFR-AK-CAZSC(3) 8,652.06 70.81 189.09 4,536.41 4,412.86 -5,957.24 -1,804.73 5,942,441.80 1,655,752.28 0.73 6,043.53 MWD+IFR-AK-CAZSC(3) 8,744.62 70.47 190.04 4,567.10 4,443.55 -6,043.35 -1,819.24 5,942,355.67 1,655,737.97 1.04 6,130.28 MWD+IFR-AK-CAZ-SC(3) 8,838.16 70.33 190.41 4,598.47 4,474.92 -6,130.07 -1,834.88 5,942,268.92 1,655,722.52 0.40 6,217.70 MWD+IFR-AK-CAZ-SC(3) 8,932.02 70.29 190.41 4,630.10 4,506.55 -6,216.99 -1,850.85 5,942,181.98 1,655,706.75 0.04 6,305.33 M1MD+IFR-AK-CAZ-SC(3) 9,025.77 70.29 189.77 4,661.72 4,538.17 -6,303.88 -1,866.31 5,942,095.06 1,655,691.49 0.64 6,392.92 MWD+IFR-AK-CAZ-SC(3) 9,121.23 70.33 188.99 4,693.88 4,570.33 -6,392.56 -1,880.96 5,942,006.36 1,655,677.05 0.77 6,482.24 MWD+IFR-AK-CAZSC(3) 9,214.67 70.31 188.35 4,725.35 4,601.80 -6,479.53 -1,894.22 5,941,919.36 1,655,663.98 0.65 6,569.79 MWD+IFR-AK-CAZSC(3) 9,309.79 70.82 187.66 4,757.00 4,633.45 -6,568.36 -1,906.71 5,941,830.52 1,655,651.70 0.87 6,659.15 MWD+IFR-AK-CAZ-SC(3) 9,402.57 70.84 188.17 4,787.47 4,663.92 -6,655.16 -1,918.78 5,941,743.70 1,655,639.83 0.52 6,746.46 MWD+IFR-AK-CAZ-SC(3) 9,494.53 70.81 188.25 4,817.67 4,694.12 -6,741.13 -1,931.19 5,941,657.71 1,655,627.62 0.09 6,832.96 MWD+IFR-AK-CAZ-SC(3) 9,587.51 70.78 189.15 4,848.26 4,724.71 -6,827.92 -1,944.47 5,941,570.89 1,655,614.54 0.91 6,920.33 MWD+IFR-AK-CAZ-SC(3) 9,679.82 70.87 190.54 4,878.58 4,755.03 -6,913.82 -1,959.37 5,941,484.97 1,655,599.83 1.43 7,006.89 MWD+IFR4K-CAZSC(3) 9,772.05 70.81 190.61 4,908.85 4,785.30 -6,999.46 -1,975.36 5,941,399.30 1,655,584.04 0.10 7,093.25 MWD+IFR-AK-CAZ-SC(3) 9,865.73 70.83 194.51 4,939.64 4,816.09 -7,085.81 -1,994.60 5,941,312.92 1,655,565.00 3.93 7,180.48 MWD+IFR-AK-CAZ-SC(3) 9,958.53 70.84 190.02 4,970.12 4,846.57 -7,171.43 -2,013.22 5,941,227.26 1,655,546.58 4.57 7,266.97 MWD+IFR-AK-CAZSC(3) 10,052.49 70.86 189.12 5,000.94 4,877.39 -7,258.96 -2,027.97 5,941,139.71 1,655,532.02 0.91 7,355.15 MWD+IFR-AK-CAZSC(3) 10,144.74 70.87 188.76 5,031.18 4,907.63 -7,345.05 -2,041.52 5,941,053.59 1,655,518.68 0.37 7,441.83 MWD+IFR-AK-CAZSC(3) 10,238.14 70.87 188.36 5,061.79 4,938.24 -7,432.31 -2,054.65 5,940,966.31 1,655,505.74 0.40 7,529.66 MWD+IFR-AK-CAZ-SC(3) 10,330.92 70.87 188.66 5,092.19 4,968.64 -7,519.00 -2,067.62 5,940,879.60 1,655,492.97 0.31 7,616.91 M1MD+IFR-AK-CAZSC(3) 10,422.53 70.92 188.65 5,122.18 4,998.63 -7,604.58 -2,080.65 5,940,794.00 1,655,480.14 0.06 7,703.05 MWD+IFR-AK-CAZ-SC(3) 10,516.36 70.34 188.18 5,153.30 5,029.75 -7,692.15 -2,093.60 5,940,706.42 1,655,467.38 0.78 7,791.18 MWD+IFR-AK-CAZ-SC(3) 10,611.60 70.29 187.70 5,185.38 5,061.83 -7,780.96 -2,105.99 5,940,617.58 1,655,455.20 0.48 7,880.52 MWD+IFR-AK-CAZ-SC(3) 10,706.55 70.48 188.05 5,217.25 5,093.70 -7,869.56 -2,118.24 5,940,528.97 1,655,443.15 0.40 7,969.63 MWD+IFR-AK-CAZSC(3) 10,799.05 70.39 188.57 5,248.23 5,124.68 -7,955.80 -2,130.84 5,940,442.70 1,655,430.75 0.54 8,056.42 MWD+IFR-AK-CAZSC(3) 10,892.96 70.38 190.33 5,279.76 5,156.21 -8,043.06 -2,145.36 5,940,355.42 1,655,416.43 1.77 8,144.31 MWD+IFR-AK-CAZSC(3) 10,987.14 70.41 190.46 5,311.36 5,187.81 -8,130.32 -2,161.37 5,940,268.13 1,655,400.62 0.13 8,232.30 MWD+IFR-AK-CAZSC(3) 11,081.74 70.50 190.28 5,343.00 5,219.45 -8,218.01 -2,177.42 5,940,180.41 1,655,384.77 0.20 8,320.71 MWD+IFR-AK-CAZSC(3) 11,179.28 70.87 189.73 5,375.27 5,251.72 -8,308.66 -2,193.41 5,940,089.74 1,655,368.99 0.65 8,412.07 MWD+IFR-AK-CAZSC(3) 11,274.31 70.90 189.95 5,406.39 5,282.84 -8,397.13 -2,208.76 5,940,001.24 1,655,353.85 0.22 8,501.22 MWD+IFR-AK-CAZSC(3) 11,366.07 70.93 190.06 5,436.39 5,312.84 -8,482.53 -2,223.82 5,939,915.82 1,655,338.98 0.12 8,587.29 MWD+IFR-AK-CAZSC(3) 11,459.77 70.96 190.36 5,466.98 5,343.43 -8,569.69 -2,239.52 5,939,828.63 1,655,323.48 0.30 8,675.16 MWD+IFR-AK-CAZSC(3) 11,550.97 70.97 191.07 5,496.72 5,373.17 -8,654.40 -2,255.55 5,939,743.89 1,655,307.64 0.74 8,760.59 MWD+IFR-AK-CAZSC(3) 1/21/2015 12:02:13PM Page 5 COMPASS 5000.1 Build 65 Definitive Survey Report Company: ConocoPhillips(Alaska)Inc.-Kup2 Local Co-ordinate Reference: Well 2F-22 Project: Kuparuk River Unit TVD Reference: Rig:95.8+27.75 @ 123.55usft(Doyon 141) Site: Kuparuk 2F Pad MD Reference: Rig:95.8+27.75 @ 123.55usft(Doyon 141) Well: 2F-22 North Reference: True Wellbore: 2F-22 Survey Calculation Method: Minimum Curvature Design: 2F-22 Database: OAKEDMP2 Survey Map Map Vertical MD Inc Azi TVD TVDSS +NI-S +El-W Northing Easting DLS Section (usft) (°) (°) (usft) (usft) (usft) (usft) (ft) (ft) (°/100') (ft) Survey Tool Name 11,642.21 70.69 191.31 5,526.69 5,403.14 -8,738.94 -2,272.27 5,939,659.32 1,655,291.11 0.39 8,845.89 MWD+IFR-AK-CAZ-SC(3) 11,737.09 70.88 190.82 5,557.91 5,434.36 -8,826.87 -2,289.47 5,939,571.36 1,655,274.12 0.53 8,934.60 MWD+IFR-AK-CAZ-SC(3) 11,828.79 70.82 190.09 5,587.99 5,464.44 -8,912.06 -2,305.19 5,939,486.15 1,655,258.60 0.75 9,020.49 MWD+IFR-AK-CAZ-SC(3) 11,921.83 70.37 190.23 5,618.91 5,495.36 -8,998.44 -2,320.67 5,939,399.74 1,655,243.31 0.50 9,107.56 MWD+IFR-AK-CAZ-SC(3) 12,014.20 70.39 190.23 5,649.92 5,526.37 -9,084.06 -2,336.12 5,939,314.09 1,655,228.06 0.02 9,193.88 MWD+IFR-AK-CAZ-SC(3) 12,106.02 70.32 189.17 5,680.79 5,557.24 -9,169.30 -2,350.69 5,939,228.83 1,655,213.68 1.09 9,279.76 MWD+IFR-AK-CAZ-SC(3) 12,198.75 70.33 188.59 5,712.01 5,588.46 -9,255.57 -2,364.17 5,939,142.54 1,655,200.40 0.59 9,366.62 MWD+IFR-AK-CAZ-SC(3) 12,292.53 70.38 188.29 5,743.54 5,619.99 -9,342.93 -2,377.13 5,939,055.15 1,655,187.64 0.31 9,454.54 MWD+IFR-AK-CAZ-SC(3) 12,384.91 70.58 188.48 5,774.41 5,650.86 -9,429.07 -2,389.83 5,938,968.99 1,655,175.14 0.29 9,541.22 MWD+IFR-AK-CAZ-SC(3) 12,477.20 70.72 188.79 5,804.99 5,681.44 -9,515.16 -2,402.90 5,938,882.88 1,655,162.26 0.35 9,627.88 MWD+IFR-AK-CAZ-SC(3) 12,569.97 70.78 188.89 5,835.57 5,712.02 -9,601.71 -2,416.36 5,938,796.32 1,655,149.00 0.12 9,715.01 MWD+IFR-AK-CAZ-SC(3) 12,662.67 70.81 189.09 5,866.07 5,742.52 -9,688.17 -2,430.04 5,938,709.83 1,655,135.52 0.21 9,802.07 MWD+IFR-AK-CAZ-SC(3) 12,756.47 70.84 189.80 5,896.88 5,773.33 -9,775.57 -2,444.58 5,938,622.41 1,655,121.18 0.72 9,890.11 MWD+IFR-AK-CAZ-SC(3) 12,850.93 70.77 189.68 5,927.93 5,804.38 -9,863.49 -2,459.67 5,938,534.46 1,655,106.29 0.14 9,978.70 MWD+IFR-AK-CAZ-SC(3) 12,943.65 70.82 189.88 5,958.43 5,834.88 -9,949.78 -2,474.55 5,938,448.15 1,655,091.62 0.21 10,065.65 MWD+IFR-AK-CAZ-SC(3) 13,034.79 70.72 190.36 5,988.45 5,864.90 -10,034.49 -2,489.67 5,938,363.41 1,655,076.69 0.51 10,151.04 MWD+IFR-AK-CAZ-SC(3) 13,128.21 72.65 190.90 6,017.81 5,894.26 -10,121.65 -2,506.03 5,938,276.22 1,655,060.53 2.14 10,238.94 MWD+IFR-AK-CAZ-SC(3) 13,219.99 75.91 191.19 6,042.67 5,919.12 -10,208.35 -2,522.95 5,938,189.49 1,655,043.80 3.56 10,326.40 MWD+IFR-AK-CAZ-SC(3) 13,313.52 78.72 191.41 6,063.21 5,939.66 -10,297.82 -2,540.83 5,938,099.99 1,655,026.13 3.01 10,416.68 MWD+IFR-AK-CAZ-SC(3) 13,406.12 81.01 191.62 6,079.50 5,955.95 -10,387.13 -2,559.03 5,938,010.65 1,655,008.14 2.48 10,506.83 MWD+IFR-AK-CAZ-SC(3) 13,423.87 81.38 191.79 6,082.22 5,958.67 -10,404.31 -2,562.59 5,937,993.46 1,655,004.62 2.27 10,524.17 MWD+IFR-AK-CAZ-SC(4) 2F-22 01.TDInt 081214 LL 13,460.00 82.13 192.12 6,087.40 5,963.85 -10,439.29 -2,569.99 5,937,958.47 1,654,997.30 2.27 10,559.49 MWD+IFR-AK-CAZ-SC(4) 7-6/8"x 9-7/8" 13,506.29 83.09 192.55 6,093.35 5,969.80 -10,484.14 -2,579.80 5,937,913.61 1,654,987.59 2.27 10,604.78 MWD+IFR-AK-CAZ-SC(4) 13,601.11 83.04 193.28 6,104.80 5,981.25 -10,575.88 -2,600.84 5,937,821.82 1,654,966.76 0.77 10,697.50 MWD+IFR-AK-CAZ-SC(4) 13,696.16 84.75 191.04 6,114.91 5,991.36 -10,668.26 -2,620.74 5,937,729.41 1,654,947.07 2.95 10,790.80 MWD+IFR-AK-CAZ-SC(4) 13,790.67 86.29 190.12 6,122.29 5,998.74 -10,760.88 -2,638.04 5,937,636.76 1,654,929.99 1.90 10,884.19 MWD+IFR-AK-CAZ-SC(4) 13,885.65 87.49 189.87 6,127.45 6,003.90 -10,854.28 -2,654.50 5,937,543.33 1,654,913.74 1.29 10,978.33 MWD+IFR-AK-CAZ-SC(4) 13,951.82 89.25 188.37 6,129.33 6,005.78 -10,919.58 -2,664.98 5,937,478.02 1,654,903.41 3.50 11,044.09 MWD+IFR-AK-CAZ-SC(4) 2F-22 02.B 081214 LL 13,979.98 90.00 187.73 6,129.51 6,005.96 -10,947.46 -2,668.92 5,937,450.13 1,654,899.53 3.50 11,072.14 MWD+IFR-AK-CAZ-SC(4) 14,075.08 91.52 187.90 6,128.25 6,004.70 -11,041.67 -2,681.85 5,937,355.90 1,654,886.82 1.61 11,166.89 MWD+IFR-AK-CAZ-SC(4) 14,170.41 91.82 189.61 6,125.47 6,001.92 -11,135.84 -2,696.36 5,937,261.70 1,654,872.53 1.82 11,261.70 MWD+IFR-AK-CAZ-SC(4) 14,264.77 92.27 192.67 6,122.11 5,998.56 -11,228.35 -2,714.57 5,937,169.16 1,654,854.52 3.28 11,355.04 MWD+IFR-AK-CAZ-SC(4) 14,313.74 91.97 196.56 6,120.29 5,996.74 -11,275.70 -2,726.92 5,937,121.79 1,654,842.29 7.96 11,402.96 MWD+IFR-AK-CAZ-SC(4) 14,358.81 92.73 197.76 6,118.44 5,994.89 -11,318.72 -2,740.20 5,937,078.74 1,654,829.10 3.15 11,446.62 MWD+IFR-AK-CAZ-SC(4) 14,403.70 92.58 197.30 6,116.37 5,992.82 -11,361.48 -2,753.71 5,937,035.95 1,654,815.69 1.08 11,490.03 MWD+IFR-AK-CAZ-SC(4) 14,453.00 92.92 197.45 6,114.00 5,990.45 -11,408.48 -2,768.42 5,936,988.93 1,654,801.10 0.75 11,537.73 MWD+IFR-AK-CAZ-SC(4) 14,505.94 92.86 196.41 6,111.33 5,987.78 -11,459.06 -2,783.81 5,936,938.32 1,654,785.82 1.97 11,589.05 MWD+IFR-AK-CAZ-SC(4) 2F-22 03.BaseC4 081214 LL 1/21/2015 12:02:13PM Page 6 COMPASS 5000.1 Build 65 Definitive Survey Report Company: ConocoPhillips(Alaska)Inc.-Kup2 Local Co-ordinate Reference: Well 2F-22 Project: Kuparuk River Unit TVD Reference: Rig:95.8+27.75 @ 123.55usft(Doyon 141) Site: Kuparuk 2F Pad MD Reference: Rig:95.8+27.75 @ 123.55usft(Doyon 141) Well: 2F-22 North Reference: True Wellbore: 2F-22 Survey Calculation Method: Minimum Curvature Design: 2F-22 Database: OAKEDMP2 Survey Map Map Vertical MD Inc Azi TVD TVDSS +NI-S +EI-W Northing Easting DLS Section (usft) (°) (°) (usft) (usft) (usft) (usft) (ft) (ft) (°/100•) (ft) Survey Tool Name 14,547.94 92.82 195.58 6,109.25 5,985.70 -11,499.38 -2,795.37 5,936,897.97 1,654,774.35 1.97 11,629.92 MWD+IFR-AK-CAZ-SC(4) 14,643.08 92.17 195.45 6,105.10 5,981.55 -11,590.97 -2,820.79 5,936,806.34 1,654,749.14 0.70 11,722.71 MWD+IFR-AK-CAZ-SC(4) 14,737.96 90.04 195.44 6,103.27 5,979.72 -11,682.40 -2,846.05 5,936,714.86 1,654,724.09 2.24 11,815.34 MWD+IFR-AK-CAZ-SC(4) 14,832.40 91.22 195.24 6,102.24 5,978.69 -11,773.47 -2,871.04 5,936,623.74 1,654,699.32 1.27 11,907.59 MWD+IFR-AK-CAZ-SC(4) 14,926.29 90.07 196.14 6,101.18 5,977.63 -11,863.85 -2,896.43 5,936,533.31 1,654,674.14 1.56 11,999.18 MWD+IFR-AK-CAZ-SC(4) 15,020.80 88.39 196.04 6,102.45 5,978.90 -11,954.65 -2,922.62 5,936,442.46 1,654,648.16 1.78 12,091.22 MWD+IFR-AK-CAZ-SC(4) 15,024.76 88.33 196.03 6,102.56 5,979.01 -11,958.46 -2,923.71 5,936,438.65 1,654,647.07 1.62 12,095.08 MWD+IFR-AK-CAZ-SC(4) 2F-22 04.Fault2 081214 LL 15,115.54 86.88 195.78 6,106.36 5,982.81 -12,045.68 -2,948.56 5,936,351.38 1,654,622.42 1.62 12,183.49 MWD+IFR-AK-CAZ-SC(4) 15.210.61 88.46 194.71 6,110.22 5,986.67 -12,137.32 -2,973.54 5,936,259.69 1,654,597.65 2.01 12,276.31 MWD+IFR-AK-CAZ-SC(4) 15,304.40 90.81 192.36 6,110.82 5,987.27 -12,228.50 -2,995.49 5,936,168.48 1,654,575.92 3.54 12,368.51 MWD+IFR-AK-CAZ-SC(4) 15,399.33 91.43 191.00 6,108.97 5,985.42 -12,321.44 -3,014.70 5,936,075.50 1,654,556.91 1.57 12,462.33 MWD+IFR-AK-CAZ-SC(4) 15,493.98 89.95 191.86 6,107.83 5,984.28 -12,414.20 -3,033.45 5,935,982.71 1,654,538.37 1.81 12,555.95 MWD+IFR-AK-CAZ-SC(4) 15,588.55 90.24 190.99 6,107.67 5,984.12 -12,506.90 -3,052.19 5,935,889.98 1,654,519.85 0.97 12,649.50 MWD+IFR-AK-CAZ-SC(4) 15,590.39 90.24 190.96 6,107.66 5,984.11 -12,508.70 -3,052.54 5,935,888.17 1,654,519.51 1.48 12,651.32 MWD+IFR-AK-CAZ-SC(4) 2F-22 06.C4Crest 081214 LL 15,683.26 90.04 189.60 6,107.44 5,983.89 -12,600.08 -3,069.11 5,935,796.77 1,654,503.14 1.48 12,743.44 MWD+IFR-AK-CAZ-SC(4) 15,777.62 90.12 189.71 6,107.31 5,983.76 -12,693.10 -3,084.94 5,935,703.72 1,654,487.53 0.14 12,837.16 MWD+IFR-AK-CAZ-SC(4) 15,872.15 88.97 188.75 6,108.06 5,984.51 -12,786.40 -3,100.10 5,935,610.39 1,654,472.58 1.58 12,931.13 MWD+IFR-AK-CAZ-SC(4) 15,966.96 88.41 187,25 6,110.22 5,986.67 -12,880.26 -3,113.29 5,935,516.51 1,654,459.60 1.69 13,025.55 MVVD+IFR-AK-CAZ-SC(4) 16,062.18 88.91 186.82 6,112.45 5,988.90 -12,974.74 -3,124.95 5,935,422.02 1,654,448.16 0.69 13,120.51 MVVD+IFR-AK-CAZ-SC(4) 16,156.77 89.04 185.89 6,114.14 5,990.59 -13,068.73 -3,135.42 5,935,328.01 1,654,437.91 0.99 13,214.92 MWD+IFR-AK-CAZ-SC(4) 16.251.98 89.32 185.12 6,115.51 5,991.96 -13,163.49 -3,144.55 5,935,233.24 1,654,428.99 0.86 13,310.03 MWD+IFR-AK-CAZ-SC(4) 16,347.17 90.03 190.57 6,116.05 5,992.50 -13,257.75 -3,157.54 5,935,138.96 1,654,416.22 5.77 13,404.84 MWD+IFR-AK-CAZ-SC(4) 16,441.08 87.51 194.45 6,118.06 5,994.51 -13,349.39 -3,177.87 5,935,047.29 1,654,396.10 4.93 13,497.41 MWD+IFR-AK-CAZ-SC(4) 16,535.99 87.31 195.55 6,122.35 5,998.80 -13,440.97 -3,202.41 5,934,955.66 1,654,371.77 1.18 13,590.15 MWD+IFR-AK-CAZ-SC(4) 16,630.99 89.39 194.53 6,125.09 6,001.54 -13,532.67 -3,227.05 5,934,863.91 1,654,347.34 2.44 13,683.02 MWD+IFR-AK-CAZ-SC(4) 16,725.02 90.56 190.91 6,125.13 6,001.58 -13,624.38 -3,247.75 5,934,772.17 1,654,326.85 4.05 13,775.68 MWD+IFR-AK-CAZ-SC(4) 16,820.22 90.47 188.18 6,124.27 6,000.72 -13,718.25 -3,263.53 5,934,678.27 1,654,311.29 2.87 13,870.25 MWD+IFR-AK-CAZ-SC(4) 16,914.74 88.96 189.29 6,124.74 6,001.19 -13,811.66 -3,277.89 5,934,584.83 1,654,297.15 1.98 13,964.29 MWD+IFR-AK-CAZ-SC(4) 17,010.52 88.67 188.09 6,126.72 6,003.17 -13,906.32 -3,292.35 5,934,490.15 1,654,282.90 1.29 14,059.57 MWD+IFR-AK-CAZ-SC(4) 17,073.79 88.64 188.42 6,128.21 6,004.66 -13,968.92 -3,301.44 5,934,427.54 1,654,273.96 0.53 14,122.56 MWD+IFR-AK-CAZ-SC(4) 2F-22 06-BaseC4_2 081214 LL 17,104.09 88.63 188.58 6,128.93 6,005.38 -13,998.88 -3,305.91 5,934,397.57 1,654,269.55 0.53 14,152.71 MWD+IFR-AK-CAZ-SC(4) 17,199.24 88.45 187.82 6,131.35 6,007.80 -14,093.02 -3,319.48 5,934,303.40 1,654,256.20 0.82 14,247.44 MWD+IFR-AK-CAZ-SC(4) 17,293.87 89.50 185.51 6,133.05 6,009.50 -14,186.99 -3,330.46 5,934,209.42 1,654,245.43 2.68 14,341.85 MWD+IFR-AK-CAZ-SC(4) 17,388.79 89.56 186.90 6,133.82 6,010.27 -14,281.35 -3,340.72 5,934,115.05 1,654,235.39 1.47 14,436.62 MWD+IFR-AK-CAZ-SC(4) 17,483.99 89.56 185.41 6,134.55 6,011.00 -14,376.00 -3,350.93 5,934,020.39 1,654,225.40 1.57 14,531.67 MWD+IFR-AK-CAZ-SC(4) 17,578.89 89.90 186.16 6,135.00 6,011.45 -14,470.41 -3,360.49 5,933,925.96 1,654,216.05 0.87 14,626.45 MWD+IFR-AK-CAZ-SC(4) 17,673.22 89.76 186.31 6,135.28 6,011.73 -14,564.18 -3,370.74 5,933,832.18 1,654,206.02 0.22 14,720.63 MWD+IFR-AK-CAZ-SC(4) 17,771.27 89.38 184.50 6,136.02 6,012.47 -14,661.79 3,379.97 5,933,734.56 1,654,197.01 1.89 14,818.59 MWD+IFR-AK-CAZ-SC(4) 1/21/2015 12:02:13PM Page 7 COMPASS 5000.1 Build 65 Definitive Survey Report Company: ConocoPhillips(Alaska)Inc.-Kup2 Local Co-ordinate Reference: Well 2F-22 Project: Kuparuk River Unit TVD Reference: Rig:95.8+27.75©123.55usft(Doyon 141) Site: Kuparuk 2F Pad MD Reference: Rig:95.8+27.75©123.55usft(Doyon 141) Well: 2F-22 North Reference: True Wellbore: 2F-22 Survey Calculation Method: Minimum Curvature Design: 2F-22 Database: OAKEDMP2 Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-$ +E/-W Northing Easting DLS Section (usft) (°) (') (usft) (usft) (usft) (usft) (ft) (ft) (°/100') (ft) Survey Tool Name 17,863.34 90.15 183.17 6,136.40 6,012.85 -14,753.65 -3,386.13 5,933,642.69 1,654,191.06 1.67 14,910.65 MWD+IFR-AK-CAZ-SC(4) 17,957.75 89.55 181.92 6,136.64 6,013.09 -14,847.96 -3,390.32 5,933,548.38 1,654,187.08 1.47 15,005.05 MWD+IFR-AK-CAZ-SC(4) 18,050.99 90.15 183.79 6,136.89 6,013.34 -14,941.08 -3,394.97 5,933,455.26 1,654,182.65 2.11 15,098.29 MWD+IFR-AK-CAZ-SC(4) 18,144.24 89.56 185.40 6,137.12 6,013.57 -15,034.03 -3,402.44 5,933,362.31 1,654,175.39 1.84 15,191.50 MWD+IFR-AK-CAZ-SC(4) 18,239.33 89.49 191.35 6,137.91 6,014.36 -15,128.06 -3,416.28 5,933,268.25 1,654,161.76 6.26 15,286.12 MWD+IFR-AK-CAZSC(4) 18,334.70 90.00 189.85 6,138.34 6,014.79 -15,221.80 -3,433.82 5,933,174.48 1,654,144.44 1.66 15,380.65 MWD+IFR-AK-CAZ-SC(4) 18,426.43 89.87 192.53 6,138.44 6,014.89 -15,311.78 -3,451.62 5,933,084.47 1,654,126.84 2.93 15,471.44 MWD+IFR-AK-CAZ-SC(4) 18,524.63 88.86 193.01 6,139.53 6,015.98 -15,407.54 -3,473.33 5,932,988.67 1,654,105.36 1.14 15,568.21 MWD+IFR-AK-CAZ-SC(4) 18,619.35 89.09 195.24 6,141.22 6,017.67 -15,499.38 -3,496.44 5,932,896.79 1,654,082.46 2.37 15,661.12 MWD+IFR-AK-CAZ-SC(4) 18,713.28 88.24 193.87 6,143.41 6,019.86 -15,590.26 -3,520.03 5,932,805.86 1,654,059.07 1.72 15,753.12 MWD+IFR-AK-CAZ-SC(4) 18,737.94 88.27 193.27 6,144.16 6,020.61 -15,614.23 -3,525.82 5,932,781.89 1,654,053.34 2.45 15,777.36 MWD+IFR-AK-CAZ-SC(4) 2F-22 07.C4 081214 LL 18,809.39 88.36 191.52 6,146.26 6,022.71 -15,683.98 -3,541.14 5,932,712.11 1,654,038.18 2.45 15,847.81 MWD+IFR-AK-CAZSC(4) 18,904.31 89.08 189.06 6,148.38 6,024.83 -15,777.34 -3,558.09 5,932,618.72 1,654,021.44 2.70 15,941.93 MWD+IFR-AK-CAZ-SC(4) 18,999.47 89.39 187.49 6,149.65 6,026.10 -15,871.50 -3,571.79 5,932,524.54 1,654,007.96 1.68 16,036.68 M1M2+IFR-AK-CAZ-SC(4) 19,093.74 90.43 187.66 6,149.80 6,026.25 -15,964.94 -3,584.22 5,932,431.07 1,653,995.75 1.12 16,130.65 MWD+IFR-AK-CAZ-SC(4) 19,188.62 89.17 187.25 6,150.13 6,026.58 -16,059.02 -3,596.53 5,932,336.98 1,653,983.65 1.40 16,225.24 MWD+IFR-AK-CAZSC(4) 19,282.88 88.94 185.62 6,151.69 6,028.14 -16,152.67 -3,607.09 5,932,243.32 1,653,973.31 1.75 16,319.31 MWD+IFR-AK-CAZSC(4) 19,375.79 88.63 182.38 6,153.66 6,030.11 -16,245.32 3,613.57 5,932,150.66 1,653,967.04 3.50 16,412.17 MWD+IFR-AK-CAZSC(4) 19,472.47 88.31 180.17 6,156.24 6,032.69 -16,341.93 -3,615.72 5,932,054.05 1,653,965.11 2.31 16,508.77 MWD+IFR-AK-CAZSC(4) 19,566.18 89.15 181.18 6,158.32 6,034.77 -16,435.61 -3,616.82 5,931,960.38 1,653,964.22 1.40 16,602.38 MWD+IFR-AK-CAZ-SC(4) 19,657.13 89.28 179.75 6,159.56 6,036.01 -16,526.55 -3,617.56 5,931,869.45 1,653,963.69 1.58 16,693.23 MWD+IFR-AK-CAZ-SC(4) 19,753.38 89.08 177.87 6,160.94 6,037.39 -16,622.76 -3,615.56 5,931,773.25 1,653,965.90 1.96 16,789.21 MVVD+IFR-AK-CAZ-SC(4) 19,848.83 89.18 177.58 6,162.39 6,038.84 -16,718.13 -3,611.77 5,931,677.90 1,653,969.91 0.32 16,884.24 MWD+IFR-AK-CAZSC(4) 19,943.41 88.39 177.69 6,164.40 6,040.85 -16,812.60 -3,607.87 5,931,583.45 1,653,974.02 0.84 16,978.38 MWD+IFR-AK-CAZ-SC(4) 20,038.15 87.91 172.41 6,167.46 6,043.91 -16,906.91 -3,599.70 5,931,489.17 1,653,982.41 5.59 17,072.13 MWD+IFR-AK-CAZSC(4) 20,131.96 86.80 165.30 6,171.79 6,048.24 -16,998.79 -3,581.60 5,931,397.34 1,654,000.71 7.66 17,162.94 MWD+IFR-AK-CAZSC(4) 20,225.83 87.61 165.23 6,176.37 6,052.82 -17,089.47 -3,557.76 5,931,306.73 1,654,024.76 0.87 17,252.24 MWD+IFR-AK-CAZSC(4) 20,319.86 86.98 160.68 6,180.81 6,057.26 -17,179.24 -3,530.23 5,931,217.02 1,654,052.49 4.88 17,340.46 MWD+IFR-AK-CAZ-SC(4) 20,359.92 86.76 160.11 6,183.00 6,059.45 -17,216.92 -3,516.81 5,931,179.38 1,654,065.99 1.53 17,377.38 MVVD+IFR-AK-CAZ-SC(4) 2F-22 04.NearBaseC4 081214 LL 20,416.07 86.45 159.30 6,186.32 6,062.77 -17,269.49 -3,497.37 5,931,126.86 1,654,085.56 1.53 17,428.86 MWD+IFR-AK-CAZSC(4) 20,511.15 88.23 160.78 6,190.73 6,067.18 -17,358.76 4,464.95 5,931,037.67 1,654,118.17 2.43 17,516.31 MWD+IFR-AK-CAZSC(4) 20,605.13 88.67 160.16 6,193.28 6,069.73 -17,447.30 -3,433.54 5,930,949.21 1,654,149.78 0.81 17,603.09 MWD+IFR-AK-CAZSC(4) 20,658.68 88.80 160.05 6,194.46 6,070.91 -17,497.64 4,415.32 5,930,898.92 1,654,168.11 0.32 17,652.40 MWD+IFR-AK-CAZ-SC(4) 20,699.36 89.11 158.22 6,195.20 6,071.65 -17,535.64 -3,400.84 5,930,860.95 1,654,182.68 4.56 17,689.60 MWD+IFR-AK-CAZ-SC(4) 20,741.60 91.36 158.10 6,195.03 6,071.48 -17,574.85 4,385.13 5,930,821.78 1,654,198.48 5.33 17,727.93 MWD+IFR-AK-CAZSC(4) 20,793.28 92.83 160.64 6,193.14 6,069.59 -17,623.18 -3,366.93 5,930,773.50 1,654,216.78 5.68 17,775.24 MWD+IFR-AK-CAZ-SC(4) 20,835.64 92.23 163.02 6,191.27 6,067.72 -17,663.38 -3,353.74 5,930,733.33 1,654,230.07 5.79 17,814.70 MWD+IFR-AK-CAZSC(4) i 20,885.63 91.11 165.62 6,189.81 6,066.26 -17,711.49 -3,340.23 5,930,685.26 1,654,243.68 5.66 17,862.03 MWD+IFR-AK-CAZSC(4) 1/21/2015 12:02:13PM Page 8 COMPASS 5000.1 Build 65 Definitive Survey Report Company: ConocoPhillips(Alaska)Inc.-Kup2 Local Co-ordinate Reference: Well 2F-22 Project: Kuparuk River Unit TVD Reference: Rig:95.8+27.75 @ 123.55usft(Doyon 141) Site: Kuparuk 2F Pad MD Reference: Rig:95.8+27.75 @ 123.55usft(Doyon 141) Well: 2F-22 North Reference: True Wellbore: 2F-22 Survey Calculation Method: Minimum Curvature Design: 2F-22 Database: OAKEDMP2 Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +E/-W Northing Easting DLS Section (usft) (°) (°) (usft) (usft) (usft) (usft) (ft) (ft) (°11001 (ft) Survey Tool Name 20,981.77 90.45 172.33 6,188.50 6,064.95 -17,805.79 -3,321.86 5,930,591.01 1,654,262.27 7.01 17,955.24 MWD+IFR-AK-CAZ-SC(4) 21,076.66 92.69 179.95 6,185.90 6,062.35 -17,900.35 -3,315.48 5,930,496.47 1,654,268.86 8,37 18,049.34 MWD+IFR-AK-CAZ-SC(4) 21,137.91 90.43 183.46 6,184.23 6,060.68 -17,961.54 -3,317.30 5,930,435.29 1,654,267.18 6.81 18,110.54 MWD+IFR-AK-CAZ-SC(4) 2F-22 09.C4_2 081214 LL 21,171.79 89.18 185.40 6,184.34 6,060.79 -17,995.32 -3,319.91 5,930,401.51 1,654,264.64 6.81 18,144.41 MWD+IFR-AK-CAZ-SC(4) 21,266.65 88.63 188.44 6,186.16 6,062.61 -18,089.46 -3,331.34 5,930,307.35 1,654,253.43 3.26 18,239.01 MWD+IFR-AK-CAZ-SC(4) 21,361.16 88.94 188.28 6,188.16 6,064.61 -18,182.94 -3,345.08 5,930,213.85 1,654,239.91 0.37 18,333.09 MWD+IFR-AK-CAZ-SC(4) 21,456.40 88.55 187.62 6,190.25 6,066.70 -18,277.24 -3,358.25 5,930,119.52 1,654,226.95 0.80 18,427.95 MWD+IFR-AK-CAZ-SC(4) 21.551.15 86.16 188.24 6,194.62 6,071.07 -18,370.98 -3,371.30 5,930,025.77 1,654,214.11 2.61 18,522.24 MWD+IFR-AK-CAZ-SC(4) 21,645.03 86.71 187.66 6,200.46 6,076.91 -18,463.78 -3,384.26 5,929,932.95 1,654,201.37 0.85 18,615.59 MWD+IFR-AK-CAZ-SC(4) 21,739.07 86.22 187.76 6,206.26 6,082.71 -18,556.79 -3,396.86 5,929,839.92 1,654,188.99 0.53 18,709.14 MWD+IFR-AK-CAZ-SC(4) 21,833.88 91.88 188.09 6,207.83 6,084.28 -18,650.64 -3,409.92 5,929,746.05 1,654,176.14 5.98 18,803.54 MWD+IFR-AK-CAZ-SC(4) 21,928.00 89.97 182.56 6,206.31 6,082.76 -18,744.30 -3,418.65 5,929,652.37 1,654,167.62 6.22 18,897.53 MWD+IFR-AK-CAZ-SC(4) 21,990.00 89.97 182.56 6,206.34 6,082.79 -18,806.24 -3,421.42 5,929,590.44 1,654,164.99 0.00 18,959.53 PROJECTED to TD 4 1/2"x 6-3/4" 22,009.00 89.97 182.56 6,206.35 6,082.80 -18,825.22 -3,422.27 5,929,571.46 1,654,164.19 0.00 18,978.53 PROJECTED to TD Projection to TD-2F-22 10.TD 081214 LL 1/21/2015 12:02:13PM Page 9 COMPASS 5000.1 Build 65 714150 RECEIVED 25 34 3 FEB 032015 Transmittal#: 03FEB15-SPO1 Schlum erger ®GC' Drilling & Measurements ED MWD/LWD Log Product Delivery DZA3/2015 M.K.BENDER Customer: ConocoPhillips Alaska Dispatched To: AOGCC: Makana Bender Well No: 2F-22 Date Dispatched: 3-Feb-15 Job#: 14AKA0057 Dispatched By: Stephanie Pacillo Well/ Product Description Hardcopy Digital Copy E-Delivery Date Color Log Prints: 1 Contents on CD N/A SonicScope Top of Cement 11750' - 13700' MD x x LAS Digital Data N/A Contents on CD N/A x Directional Data N/A Contents on CD N/A As-Built Survey N/A Contents on CD N/A CD 1 Contents on CD N/A Data:DLIS/ASCII x Graphics:pds/pdf x Please sign and email a copy to: Please sign and email a copy to: Catherine.Rosoconocophillips.com AlaskaPTSPrintCenter(c�slb.com Catherine Roso Attn:Stephanie Pacillo 907-265-6189 ATO 1707 Received By: ,q,(U��'y�-' �/✓J gra Z/ 4 -/SD Loepp, Victoria T (DOA) From: Loepp,Victoria T(DOA) Sent Tuesday,January 13, 2015 11:58 AM To: 'Klem,Adam' Cc: Callahan, Mike S(Mike.Callahan@conocophillips.com);Schwartz,Guy L(DOA);Wallace, Chris D (DOA) Subject: RE: PTD - 214-150 KRU 2F-22 Adam, Mike Callahan just verified the TOC determined with the sonic log as 12850'. A variance is granted to set the production packer approximately 230' above the 7-5/8" casing shoe. Thanx, Victoria Victoria Loepp Senior Petroleum Engineer State of Alaska Oil&Gas Conservation Commission 333 W 7th Ave,Ste 100 Anchorage,AK 99501 Work (907)793-1247 Victoria Loeppalaska.qov CONFIDENTIALITY NOTICE:This e-mail message,including any attachments,contains information from the Alaska Oil and Gas Conservation Commission (AOGCC),State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information.The unauthorized review,use or disclosure of such information may violate state or federal law.If you are an unintended recipient of this e-mail,please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Victoria Ferguson at(907)793-1247 or Victoria.Ferguson@alaska.gov From: Loepp,Victoria T(DOA) Sent:Tuesday, January 13, 2015 11:50 AM To: 'Klem, Adam' Subject: RE: PTD - 214-150 KRU 2F-22 How did the cement job go on the 7-5/8"? Let me know and we can grant a variance. From: Klem, Adam [mailto:Adam.Klem@conocophillios.com] Sent:Tuesday,January 13, 2015 11:05 AM To: Schwartz, Guy L(DOA); Loepp, Victoria T(DOA); Wallace, Chris D (DOA) Cc: Callahan, Mike S; Kurnia, Dadang Subject: PTD -214-150 KRU 2F-22 Hello, We are running the 4'A" OH liner completion right now,and have a slight issue with the space out.The 7 5/8" casing shoe is set at 13459', but we have two baffles at 13367'and 13322' MD.We want to set the liner top above these,since there is drilled out cement in the casing below,and worry about setting the liner as well as future leaks. However,we need roughly 50'to space out the production packer on the upper completion.Therefore,for the spacing to work out, 1 t we would need to set the production packer somewhere around the 210'-230' range above the 7 5/8"casing shoe, which would put us out of compliance. Ideally these are the depths we would set at: Production Packer: 13,227' (232'from shoe) Liner hanger/packer: 13,275' 7 5/8"Shoe: 13459' Can we get a variance for this? Adam Klem Senior Completions Engineer Greater Kuparuk Area ConocoPhillips Alaska 700 G St ATO 2044 Anchorage,AK 99510 907-263-4529 Office 970-317-0300 Cell Adam.Klem@conocophillips.com 2 pro Z14 — / Z Loepp, Victoria T (DOA) From: Loepp,Victoria T(DOA) Sent: Wednesday, December 10, 2014 2:51 PM To: 'Hunter, Lindsey L' Subject: RE: PTD - 214-150 KRU 2F-22 Under-reaming Revision Lindsey, The revisions in red on the attached PTD application are approved. Thanx, Victoria Victoria Loepp Senior Petroleum Engineer State of Alaska Oil&Gas Conservation Commission 333 W 7th Ave,Ste 100 Anchorage,AK 99501 Work. (907)793-1247 Victoria LoeppCaialaska oov CONFIDENTIALITY NOTICE:This e-mail message,including any attachments,contains information from the Alaska Oil and Gas Conservation Commission (AOGCC),State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information.The unauthorized review,use or disclosure of such information may violate state or federal law.If you are an unintended recipient of this e-mail,please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Victoria Ferguson at(907)793-1247 or Victoria.Ferguson©alaska.gov From: Hunter, Lindsey L [mailto:Lindsey.Hunter(aconocophillips.com] Sent: Wednesday, December 10, 2014 2:13 PM To: Loepp, Victoria T(DOA) Subject: RE: PTD - 214-150 KRU 2F-22 Thanks Victoria. Here is the updated PTD application. Lindsey Lindsey Hunter Drilling Engineer ConocoPhillips Alaska D&W Office - 907-265-6427 Cell -907-952-3173 lindsey.hunter@conocoph ill ips.com From: Loepp,Victoria T(DOA) [mailto:victoria.loepp@a alaska.gov] Sent: Wednesday, December 03, 2014 2:34 PM To: Hunter, Lindsey L Subject: [EXTERNAL]RE: PTD - 214-150 KRU 2F-22 Lindsey, 1 Please show the edits in red on your PTD application and email them to me for review and approval. Thanx, • Victoria Victoria Loepp Senior Petroleum Engineer State of Alaska Oil&Gas Conservation Commission 333 W.7th Ave,Ste 100 Anchorage,AK 99501 Work (907)793-1247 Victoria Loepp(a alaska qov CONFIDENTIALITY NOTICE:This e-mail message,including any attachments,contains information from the Alaska Oil and Gas Conservation Commission (AOGCC),State of Alaska and is for the sole use of the intended recipient(s).It may contain confidential and/or privileged information.The unauthorized review,use or disclosure of such information may violate state or federal law.If you are an unintended recipient of this e-mail,please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Victoria Ferguson at (907)793-1247 or Victoria.Ferguson@alaska.gov From: Hunter, Lindsey L [mailto:Lindsey.Hunter@conocophillips.com] Sent:Tuesday, December 02, 2014 10:40 AM To: Loepp, Victoria T(DOA) Cc: Schwartz, Guy L(DOA) Subject: PTD - 214-150 KRU 2F-22 Victoria, I have a question regarding 2F-22. Due to a tight casing run on an adjacent well we decided to add an under-reamer to the shale section in our intermediate. All other plans will stay the same, however the hole interval from 12,100'to TD of intermediate at 13,426 will be opened from 9-7/8"to 11" and the cement volumes will be adjusted for the hole change. Do I need to submit a new PTD or will this email suffice for notification? Thanks, Lindsey Lindsey Hunter Drilling Engineer ConocoPhillips Alaska D&W Office - 907-265-6427 Cell-907-952-3173 lindsey.hunterni,conocophillips.com 2 ConocoPhillips Alaska, Inc. Post Office Box 1 ConocoPhillips Anchorage,Alaskaa 995 99510-0360 Telephone 907-276-1215 September 19th,2014 Alaska Oil and Gas Conservation Commission 333 West 7th Avenue,Suite 100 Anchorage,Alaska 99501 Re: Application for Permit to Drill Well 2F-22,A Kuparuk C Sand Water Injector Dear Commissioner: ConocoPhillips Alaska,Inc.hereby applies for a permit to drill an onshore grassroots pre-produced water injector well from the 2F pad. The expected spud date for this well is December 1st,2014. It is planned to use Rig Doyon 141. 2F-22 is planned to be a horizontal Kuparuk C sand pre-produced water injector.The planned pre-production time is approximately 1-2 weeks(to clean up the lateral.) The surface section will be drilled with 13-1/2"bit and run 10-3/4" casing to+/-3,939'MD/2,974'TVD.The intermediate section will be drilled with 9-7/8"bit to 7000' and opened up to 11" with an under-reamer below (7000' to TD at 13,423')and run 7-5/8"casing to 13,423'MD/6,081'TVD.The production hole will be drilled with 6-3/4"bit and run 4-1/2"slotted liner to+/-22,000'MD/6,239'TVD. The upper completion will be run with 3-1/2"tubing. Please find attached the information required by 20 ACC 25.005 (a) and (c) for your review. Pertinent information attached to this application includes the following: 1. Form 10-401 Application for Permit to Drill per 20 ACC 25.005 (a). 2. Pressure information as required by 20 ACC 25.035 (d)(2). 3. Casing and Cementing program. 4. A drilling fluids program summary. 5. A proposed drilling program. 6. Directional drilling/collision avoidance information as required by 20 ACC 25.050(b). 7. A proposed completion diagram. Information pertinent to the application that is presently on file at the AOGCC: 1. Diagrams of the BOP equipment, diverter equipment and choke manifold lay out as required by 20 ACC 25.035(a)and(b). 2. A description of the drilling fluids handling system. 3. Diagram of riser set up. If you have any questions or require further information, please contact Lindsey Hunter at 263-6427 (lindsey.hunter@cop.com or Chip Alvord at 265-6120.) Sincerely, Chip Alvord Drilling Manager Application for Permit to Drill Document Kuparuk Well 2F-22 Well Name Requirements of 20 AAC 25.005(f) The well for which this application is submitted will be designated as 2F-22 Location Summary Requirements of 20 AAC 25.005(c)(2) In application for a Permit to 1 trill inuiit he accompanied hr each of 1lie,ftlloii nig items except fon an Nem already on file it ith the coinnnssion and identified in the application C2)a plat identifying the properlt and the properrt''s miners and showing (I11hc coordinates of the proposed location of the well at the surface,at the lop of each objective formation,anti at total depth,referenced to governmental section lines (R)the coordinates of the proposed location of the well at the surface,referenced to the stale plane coordinate system for this stale as maintained by the \anonul(feocleticSurvey in the.\auonalOceanic and Atmospheric Administration. 0.')the proposed depth of the well at the top of each ohlectn'e formation and at total depth, Location at Surface 231'FNL, 1721'FEL, Sec 33, T 11N,R009E,UM NGS Coordinates RKB Elevation 120.6'AMSL Northings: 5,948,652' Eastings: 517,511' Pad Elevation 92.6' AMSL Location at Top of 75' FNL,4310'FEL,Sec 9,T1ON,R009E,UM Productive Interval (Kuparuk C4 Sand) NGS Coordinates Measured Depth, RKB: 13,422' Northings: 5,938,244' Eastings:514,971' Total Vertical Depth, RKB: 6,081' Total Vertical Depth, SS: 5,960' Location at Total Depth 3270'FNL, 121'FEL, Sec 17,T1ON,R009E,UM NGS Coordinates Measured Depth,RKB: 22,001' Northings: 5,929,767' Eastings:513,919' Total Vertical Depth, RKB: 6,239' Total Vertical Depth, SS: 6,118' and OD)other information required by 20.1.1('25 0 0(b) Requirements of 20 AAC 25.050(b) 11 a well is to he intentionally deviated.the application for a Permit to Drill 0-orm 10-401)nurse (l)include a plat, draw ii to a.suitable scale, stunting the path of the proposed wellbore, including all adjacent is cllbores uvthni 2110 feet glans.portion of the proposed well Please see Attachment: Directional Plan Ind (2)for sill is ells is itlnn 200 feet of the proposed wellbore (.1)lust the names o/the operators of those wells, to the es1e111 that those names are ktiou n or discoverable in public records,and show that each named operator has been furnished a cops of the application by certified trail or (131 state that the applicant is the only a/fecled owner The Applicant is the only affected owner. Blowout Prevention Equipment Information Requirements of 20 AAC 25.005(c)(3) in application for a Permit to!Will mast he accompanied hr each of tliefolloirmg rtem.s.except lot an items alreadv on file is tilt the c oniinssion and identified in the application (3)a diagram anal description of the blowout prevention equipment(RC)PE)us required by 20 I i('25 035 20 25 036, or 20.-4.1C 25 037 as applicable. Please reference BOP schematics on file for Doyon 141. Drilling Hazards Information Requirements of 20 AAC 25.005(c)(4) An application for a Permit to brill must he accompanied hi each of the follon ung items,except for an item already on file with the commission and identified in the application (-I)information on drilling hazards. including I1 the maximum downhole pressure that may he encountered, criteria used to determine a end maxrnumi potential surface pressure hated on a methane gradient. The maximum potential surface pressure(MPSP) while drilling 2F-22 is calculated using an estimated maximum reservoir pressure of 3160 psi (10.0 ppg), a gas gradient of 0.10 psi/ft, and the estimated depth of the Kuparuk C sand at 6,071' TVD (WP08): C Sand Estimated. BHP = 3,160 psi C Sand estimated depth(WP08) =6,071' TVD Gas Gradient =0.10 psi/ft as per 20 AAC 25.005 (c)(4)(A) Hydrostatic of full gas column =607 psi (6,071' TVD * 0.10 psi/ft) MPSP=BHP—gas column =2,553 psi (3,160 psi—607 psi) 1131 data on potential gas_onus The well bore is not expected to penetrate any shallow gas zones. Incl (()data concerning potential causes of hole problems such us abnormally geo-pressured strata,lost circulation zones,and_ones that have a propensit,)',for differential sticking See attached 2F-22 Drilling Hazards Summary Requirements of 20 AAC 25.005(c)(5) In application for a Permit to Drill must he accompanied by each of the follouvng items,except for an item already on file with the commission and identified in the application (5)a description of the procedure for conducting formation integi itt'tests,as required under 20 I I('25 030(6 A procedure is on file with the commission for performing LOT's. Casing and Cementing Program Requirements of 20 AAC 25.005(c)(6) -In application for a Permit to Drill must he accompanied h''each of the following items.except jor an item already on file nvtli the commission and identified In the upphcation (6)a complete proposed casing and cementing program as required by 20.-I,I( _'?030,and a description of-any clotted lute, pre-perforated liner, or screen to he installed Casing and Cement Program Casing and Cementing Program Csgrrbg Hole Weight Length Top MD/TVD Btm MD/TVD Cement Program OD(in) �� Grade Conn (/ ) . (g) (ft) (ft) 20 20 68 H-40 Welded 78 Surf 106/106 Existing Cement to Surface with 3- Hydri 10-3/4 1�2 45.5 L-80 5631 3,911 Surf 3,939/2,974 1,539 sx ALC Lead 11.00 ppg, 195 sx DeepCRETE Tail Slurry 12.0 ppg Hydril 225 sx Class G at 15.8 ppg w/TOC at 7-5/8 9-7/8 29.7 L-80 563 6972 Surf 7,000/3,991 12,552'MD 7-5/8 11 29.7 L-80 Hydril 6395 7000' 13,423/6,081 Hydril563 4 1/2 6-3/4 11.6 L-80 563 8,727 13,273/6,055 22,000/6,239 Open hole slotted liner Diverter System Information Requirements of 20 AAC 25.005(c)(7) .In application for a Permit to Drill must he accompanied by each oldie follow mg rte ms,except for an Item already on file with the commission anti identified in the application (7)a diagram and description of the diverter system as required by 20 AAC 25.035, unless this requirement is waived by the commission under 20 AAC 25.035(h)(2); Please reference diverter schematic on file for Doyon 141. Drilling Fluid Program Requirements of 20 AAC 25.005(c)(8) .1n application for a l'ernnt to Drell invest he accompanied h_y each of the following items, except for un Nem already on file with the conanisston and Identified In the application (8)a drilling fluid program,including a diagram and description of the drilling fluid system, as required by 20 MC 25.033; Mud Program Summary Surface Intermediate Production 13-1/2"Hole 9-7/8"/11" Hole 6-3/4" Hole 10-3/4"Casing 7-5/8"Casing 4-1/2" Liner FLO-PRO NT Mud System Drilplex LSND(WBM) (WBM) Density 8.8-9.6 9.5- 10.5 9.0-10.0 PV 30-50 10-20 10-20 YP 40-80 16-24 16-24 Funnel Viscosity 200-300 N/A N/A Initial Gel 30-50 10-12 5-8 10 minute Gel 30-50 10- 18 5- 12 API Filtrate NC <6 <6 HTHP Fluid Loss at 160 F N/A < 10 < 10 pH 9.0-10.0 9.0- 10.0 9.5- 10.0 Diagram of Doyon 141 Mud System is on file with AOGCC. Drilling fluid practices will be in accordance with appropriate regulations stated in 20 AAC 25.033. Abnormally Pressured Formation Information Requirements of 20 AAC 25.005(c)(9) N/A- Application is not for an exploratory or stratigraphic test well. Seismic Analysis Requirements of 20 AAC 25.005(c)(10) N/A -Application is not for an exploratory or stratigraphic test well. Seabed Condition Analysis Requirements of 20 AAC 25.005(c)(11) N/A-Application is not for an offshore well. Evidence of Bonding Requirements of 20 AAC 25.005(c)(12) Evidence of bonding for ConocoPhillips Alaska, Inc. is on file with the Commission. Proposed Drilling Program Requirements of 20 AAC 25.005(c)(13) to application for a Pet ma to/)rill must he accompanied hi each of the folios'mg items except for an item ahead) on file lath the commission and identified in the application The proposed drilling program is listed below. Please refer to attachment for proposed well schematic. 1. Move in/rig up Doyon Rig 141. Install 21-1/4"Annular with 16"diverter line and function test. 2. Spud and directionally drill 13.5"hole to casing point at+/-3,939' MD/2,974'TVD as per directional plan (wp08). Survey with MWD,Gamma,Resistivity,GWD. 3. Run and cement 10-3/4",45.5#,L80,Hyd-563 casing to surface. Displace cement with mud. Evacuate top 2 feet of cement from annulus for sealant job(post rig.) 4. In the event cement returns are not seen at surface,perform a top job. 5. Remove diverter system,install and test 13-5/8"x 5,000 psi BOP's to 3500 psi(annular preventer to 2500 psi). Notify AOGCC 24 hrs before test. 6. PU 9-7/8"PDC bit and directional drilling assembly,with MWD/LWD(Gamma,resistivity). RIH and clean out to 100'above shoe. Test surface casing to 3000 psi for 30 minutes. 7. Drill out shoe track and 20'of new hole. Perform formation integrity test to a minimum of 12.5 ppg,maximum of 16 ppg EMW leak off,recording results. 8. Conventionally drill 9-7/8"hole to 7000' MD, short trip to surface shoe and install MPD elements in rotating control device. RIH to 7000'. 9. Open under-reamer to 11"and directionally(using annular pressure on demand)drill to TD at 13,423'MD/ 6,081' TVD,landing in the Kuparuk C sand. Wellsite geologist will call intermediate TD. Circulate and rotate until shakers are clean. Pump out of hole at 2 bpm to HWDP. (If tight spots are encountered,back ream through only tight areas.) 10. POOH on elevators. 11. Laydown intermediate BHA and rack back 5"DP(to lay down after casing run,this will minimise shale exposure time.) 12. Run 7-5/8",29.7#L80,Hydril 563 casing from TD to surface. 13. Pump cement job as per Schlumberger proposal,top of cement to be 12,552'MD(800' MD above top of the Kuparuk C sands). 14. Set slips and install wellhead x 7-5/8"packoff and test to 3500 psi. 15. Flush 10-3/4"x 7-5/8"annulus with water,followed by diesel to freeze protect. 16. Lay down 5"DP. 17. PU 4"DP,6-3/4"bit,and drilling assembly with MWD/LWD(Gamma,resistivity,stethoscope,periscope, microscope,neutron density,and sonic for top of cement evaluation.) 18. RIH and log top of cement with sonic on trip in hole.,continue to RIH and clean out cement to 100' above shoe. Test intermediate casing to 3500 psi for 30 minutes. 19. Drill out shoe track and 20'of new hole. Perform formation integrity test to minimum of 12.0 ppg,maximum of 16 ppg EMW leak off,recording results. 20. Directionally drill 6-3/4"hole geosteering though the Kuparuk C sand to TD-22,000'MD as per directional plan (wp08). 21. Circulate hole clean and Backream out of hole. 22. Lay down Production BHA. 23. PU and run 4-1/2", 11.6#,Hydril 563 slotted liner. The top of liner will be placed at 13,273'MD,allowing for 150' of overlap in the 7-5/8"casing. 24. Set liner hanger. Slackoff and set liner top packer. 25. Monitor well for flow for 15 minutes 26. Displace to clear brine. PT liner to 3,000 psi at surface for 30 minutes,chart results. 27. Flow check well for 30 minutes to run 3-1/2"upper completion. 28. Nipple down BOPE,nipple up tree and test. 29. Freeze protect well with diesel and install BPV. 30. RDMO. Discussion of Mud and Cuttings Disposal and Annular Disposal Requirements of 20 AAC 25.005(c)(14) An application,for a Permit to Drill music he accompanied by each of the,following items,except for an item already on file with the conrnnssion and identified in the application (14)a general description of hon the operator plans to dispose of drilling and and cuttings and a statement ofwhether the operator Intends to request authorr_ation under'(I (-1('25 080 for an annular disposal operation in the lie . • 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 DS 1B 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.(659-7212). Attachments: Attachment 1 Directional Plan Attachment 2 Drilling Hazards Summary Attachment 3 Well Schematic (‘--'7"---, OF 1//%�,� THE STATE A 1,acka C.T,_l: a.;.�.c . C-,-,z z o f iS sl /, h• �_ -r; ; ,,�y _ ,,v,, I _` sy _ `tr te2_,_,�y�_ 333 West Seventh Avenue y`� GCl\'ER \(>K SFA\' PAIZYk I Anchorage, Alaska 99501-3572 �+��! .11,,,AA.* •' Mair: 907.279 1433 iy C.�tvJ � 1- .., it% -/� ,•,C' , G. Alvord Alaska Drilling Manager ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510-0360 Re: Kuparuk River Field, Kuparuk River Oil Pool, KRU 2F-22 ConocoPhillips Alaska, Inc. Permit No: 214-150 Surface Location: 231' FNL, 1721' FEL, SEC. 33, T1 IN, R9E, UM Bottomhole Location: 3270' FNL, 121' FEL, SEC. 17, T1ON, R9E, UM Dear Mr. Alvord: Enclosed is the approved application for permit to drill the above referenced service well. 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. 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 a AOGCC order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. • Sincerely, �/ / ,4 e 4 4 7 7„,___ Cathy '. Foerster Chair DATED this 9_ day of October, 2014. 1 RECEIVED 4 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION SEP 23 2014 PERMIT TO DRILL ��G�� 20 AAC 25.005 1 a Type of Work lb Proposed Well Class Development-Oil ❑ Service-W inl 0. Single Zone Q. 1 c Specify if well is proposed for Drill • Q Lateral ❑ Stratigraphic Test ❑ Development-Gas ❑ Service-Supply ❑ Multiple Zone❑ Coalbed Gas ❑ Gas Hydrates❑ Redrill ❑ Reentry E Exploratory ❑ Service-WAG ❑ Service-Disp ❑ Geothermal ❑ Shale Gas ❑ 2 Operator Name 5 Bond ,U Blanket LJ Single Well 11 Well Name and Number ConocoPhillips Alaska, Inc. Bond No 59-52-180• 2F-22 - 3 Address 6 Proposed Depth 12. Field/Pool(s) P.O. Box 100360 Anchorage,AK 99510-0360 MD 22001' • TVD 6239' 4a Location of Well(Governmental Section) 7 Property Designation QLe�seyNumber).1� Kuparuk River Field Surface 231'FNL, 1721'FEL, Sec 33,T11N, R9E, UM' ADL 2565 ,275666 25668 Kupruk River Pool • Top of Productive Horizon 8 Land Use Permit 13 Approximate Spud Date 75'FNL,4310'FEL,Sec 9,T1ON, R9E, UM • 2583,2587,2589 11/1/2014 Total Depth 9.Acres in Property 71f,0 14 Distance to 3270'FNL, 121'FEL, Sec 17, T1ON, R9E, UM • 2�6t1 1014,z Nearest Property 121' 4b Location of Well(State Base Plane Coordinates-NAD 27) 10 KB Elevation above MSL . 120 6 feet 15 Distance to Nearest Well Open Surface:x- 517511 y- 5948652 Zone- 4' GL Elevation above MSL • 92 6 feet to Same Pool 2G-11AL1 ,297 16 Deviated wells Kickoff depth . 400 ft. 17.Maximum Anticipated Pressures in psig(see 20 AAC 25 035) Maximum Hole Angle • 92° deg Downhole 3160 psig• Surface 2553 psig . 18 Casing Program Specifications Top - Setting Depth -Bottom _ Cement Quantity,c f or sacks Hole l Casing Weight Grade Coupling Length MD TVD MD TVD (including stage data) 20" 20" 68# H-40 Welded 78' 28' 28' 106' 106' pre-installed 13 5" 10.75" 45.5# L-80 Hydril 563 3911' 26' 26' 3939' 2974' 1539 sx ALC,195 sx DeepCRETE 9.875" 7.625" I 29.7# L-80 Hydril 563 13395' 28' 28' 13423' 6081' 255 sx Class G 6.75" 4.5" 11.6# L-80 Hydril 563 8727' 13273' 6055' 22000' 6239' open hole slotted liner <J 19 PRESENT WELL CONDITION SUMMARY (To be completed for Redrill and Re-Entry Operations) Total Depth MD(ft) Total Depth TVD(ft) Plugs(measured) Effective Depth MD(ft) Effective Depth TVD(ft) Junk(measured) Casing Length Size Cement Volume MD TVD Conductor/Structural Surface Intermediate Production Liner Perforation Depth MD(ft). Perforation Depth TVD(ft): 20 Attachments Property Plat❑ BOP Sketch ❑ Drilling Program ❑✓ Time v Depth Plot ❑ Shallow Hazard Analysis ❑ Diverter Sketch ❑ Seabed Report El Drilling Fluid Program Q 20 MC 25 050 requirements 0 21 Verbal Approval Commission Representative Date 22 I hereby certify that the foregoing is true and correct Contact Lindsey Hunter @ 263-6427 L.3% Email indse Hunter. co. corn Printed Name G. L. Alvord Title Alaska Drilling Manager if r NIP. Signature 40-lPhone 265-6021 Date 9/2. /I } Commission Use Only Permit to Drill API Number Permit Approval / See cover letter Number ay-1 - 150 50- 0 2q- )35 30 -00-00 Date 1 I O I i i for other requirements Conditions of approval. If box is checked,well may not be used to explore for,test,or produce coalbed m thane,gas hydrates,or gas contained in shales (� Other: co p tcs f to 3 5 e4 p5 i Samples req'd: Yes ❑ No [` Mud log req'd: Yes El No Tir Aviv,v/a r tlS pc to 2,.,--‘,70/2S . H2S measures. Yes [J No ❑ Directional svy req'd. Yes[v� No 5fa tc wl fnc.5cel An JTi'4 Spacing exception req'd: Yes El No I Inclination-only svy req'd. Yes❑ No E1 17_,41-1',.;-`.,:::11af�l�- 6f4b: I?Cd 11r)cct:rn. . horc) is aypro✓to/, t 5e f a�AC -(, to 23 abo✓G 71 op pc'-� oE<, V� /� APPROVED BY THE •_ / Approved by ) se �� COMMISSIONER COe da f G0 n ' n ` Date?Kis 2 /j' 10--401((F(evised 10/2012 This permit is valid for 24 months from the daf iRrv 0fzi•u`51BM 5 „, yJ j/, VL i o/Z/r 4 s� Y' �// 4 ConocoPhillips Alaska, Inc. RECEIVED Post Office Box 100360 Anchorage,Alaska 99510-0360 SEP 2 3 2014 ConocoPhillips Telephone 907-276-1215 September 19th,2014 AOGCC Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage,Alaska 99501 Re: Application for Permit to Drill Well 2F-22,A Kuparuk C Sand Water Injector`' Dear Commissioner: ConocoPhillips Alaska,Inc.hereby applies for a permit to drill an onshore grassroots pre-produced water injector well from the 2F pad. The expected spud date for this well is November 1st,2014.It is planned to use Rig Doyon 141./ J 2F-22 is planned to be a horizontal Kuparuk C sand pre-produced water injector. The planned pre-production time is approximately 1-2 weeks(to clean up the lateral.) The surface section will be drilled with 13-1/2"bit and run 10-3/4" casing to+/-3,939'1VID/2,974'TVD. The intermediate section will be drilled with 9-7/8"bit and run 7-5/8"casing to 13,423'MD/6,081'TVD.The production hole will be drilled with 6-3/4"bit and run 4-1/2"slotted liner to+/- 22,000'MD/6,239'TVD.The upper completion will be run with 3-1/2"tubing. Please find attached the information required by 20 ACC 25.005 (a) and (c) for your review. Pertinent information attached to this application includes the following: 1. Form 10-401 Application for Permit to Drill per 20 ACC 25.005 (a). 2. Pressure information as required by 20 ACC 25.035(d)(2). 3. Casing and Cementing program. 4. A drilling fluids program summary. 5. A proposed drilling program. 6. Directional drilling/collision avoidance information as required by 20 ACC 25.050(b). 7. A proposed completion diagram. Information pertinent to the application that is presently on file at the AOGCC: J 1. Diagrams of the BOP equipment, diverter equipment and choke manifold lay out as required by 20 ACC 25.035 (a)and(b). 2. A description of the drilling fluids handling system. 3. Diagram of riser set up. If you have any questions or require further information, please contact Lindsey Hunter at 263-6427 (lindsey.hunter@cop.com or Chip Alvord at 265-6120.) Sincerely, 1.l --c3411.Grecf,�' Fcn- 61-11P M,lAt 1) 4110 Chip Alvord Drilling Manager Application for Permit to Drill Document Kuparuk Well 2F-22 Well Name Requirements of 20 AAC 25.005(f) The well for which this application is submitted will be designated as 2F-22 Location Summary Requirements of 20 AAC 25.005(c)(2) An application for a Permit to Drill must be accompanied by each of the following items,except for an item already on file with the commission and identified in the application: (2)a plat identifying the property and the property's owners and showing (A)the coordinates of the proposed location of the well at the surface,at the top of each objective formation,and at total depth,referenced to governmental section lines. (B)the coordinates of the proposed location of the well at the surface.referenced to the state plane coordinate system for this state as maintained by the National Geodetic Survey in the National Oceanic and Atmospheric Administration: (C)the proposed depth of the well at the top of each objective formation and at total depth: Location at Surface 231'FNL, 1721'FEL, Sec 33, T 11N,R009E,UM NGS Coordinates RKB Elevation 120.6'AMSL Northings: 5,948,652' Eastings: 517,511' Pad Elevation 92.6'AMSL Location at Top of 75'FNL,4310'FEL,Sec 9,T1ON,R009E,UM Productive Interval (Kuparuk C4 Sand) NGS Coordinates Measured Depth,RKB: 13,422' Northings. 5,938,244' Eastings: 514,971' Total Vertical Depth, RKB: 6,081' Total Vertical Depth, SS: 5,960' Location at Total Depth 3270'FNL, 121'FEL, Sec 17,T1ON,R009E,UM NGS Coordinates Measured Depth, RKB: 22,001' Northings: 5,929,767' Eastings: 513,919' Total Vertical Depth, RKB: 6,239' Total Vertical Depth, SS: 6,118' and (D)other information required by 20 AAC 25 050(b): Requirements of 20 AAC 25.050(b) If a well is to be intentionally deviated,the application for a Permit to Drill(Forst/0-401)must (I)include a plat,drawn to a suitable scale,showing the path of the proposed wellbore,including all adjacent wellbores within 200 feet of an)portion of the proposed well: Please see Attachment: Directional Plan And (2)for all wells within 200 feet of the proposed wellbore (A)list the names of the operators of those hells,to the extent that those names are known or discoverable in public records,and show that each named operator has been furnished a copy of the application by certified mail:or (B)state that the applicant is the only affected owner. The Applicant is the only affected owner. Blowout Prevention Equipment Information Requirements of 20 AAC 25.005(c)(3) An application for a Permit to Drill must be accompanied by each of the following items,except for an item already on file with the commission and identified in the application: (3,)a diagram and description of the blowout prevention equipment(ROPE)as required by 20 AAC 25.035,20 AAC 25.036,or 20 AAC 25.037.as applicable: Please reference BOP schematics on file for Doyon 141. ORIGINAL Drilling Hazards Information Requirements of 20 AAC 25.005(c)(4) An application for a Permit to Drill must be accompanied by each of the following items,except for an item already on file with the commission and identified in the application: (4)information on drilling ha=arils,including (A)the maximum downhole pressure that may be encountered,criteria used to determine it,and Max/17111m potential surface pressure based on a methane gradient,- The maximum potential surface pressure (MPSP) while drilling 2F-22 is calculated using an estimated maximum reservoir pressure of 3160 psi (10.0 ppg), a gas gradient of 0.10 psi/ft, and the estimated depth of the Kuparuk C sand at 6,071' TVD (WP08): C Sand Estimated. BHP =3,160 psi C Sand estimated depth (WP08) =6,071' TVD Gas Gradient =0.10 psi/ft as per 20 AAC 25.005 (c)(4)(A) Hydrostatic of full gas column =607 psi (6,071' TVD * 0.10 psi/ft) ✓ MPSP =BHP—gas column =2,553 psi (3,160 psi—607 psi) (B)data on potential gas=ones; The well bore is not expected to penetrate any shallow gas zones. And (C)data concerning potential causes of hole problems such as abnormally geo-pressured strata.lost circulation:ones,and=ones that have a propensity for differential sticking; See attached 2F-22 Drilling Hazards Summary Requirements of 20 AAC 25.005(c)(5) An application for a Permit to Drill must be accompanied by each of the following items,except for an item already on file with the commission and identified in the application: (5)a description of the procedure for conducting formation integrity tests,as required under 20 AAC 25.0300; A procedure is on file with the commission for performing LOT's. Casing and Cementing Program Requirements of 20 AAC 25.005(c)(6) An application for a Permit to Drill must be accompanied by each of the following items,except for an items ah-eady on file with the commission and identified in the application: (6)a complete proposed casing and cementing program as required by 20.AAC 25.030,and a description of any slotted liner.pre-perforated liner.or screen to be installed Casing and Cement Program Casing and Cementing Program Csg/Tbg Hole Weight Length Top MD/TVD Elm MD/TVD OD(in) ���� (lb/ft) Grade Conn- (ft) (ft) (ft) Cement Program 20 20 68 H-40 Welded 78 Surf 106/106 Existing Cement to Surface with 10-3/4 1% 45.5 L-80 H563 ydril 3,911 Surf 3,939/2,974 1,539 sx ALC Lead 11.00 ppg, 195 sx DeepCRETE Tail Slurry 12.0 ppg Hydril 255 sx Class G at 15.8 ppg w/TOC at 7-5/8 9-7/8 29.7 L-80 563 13,395 Surf 13,423/6,081 12,552'MD 4 1/2 6-3/4 11.6 L-80 H56311 8,727 13,273/6,055 22,000/6,239 Open hole slotted liner Diverter System Information Requirements of 20 AAC 25.005(c)(7) An application for a Permit to Drill must be accompanied by each of the following items,except for an item already on file with the commission and identified in the application: ORIGINAL (7)a diagram and description of the diverter system as required by 20 AAC 25.035, unless this requirement is waived by the commission under 20 AAC 25.035(h)(2); Please reference diverter schematic on file for Doyon 141. Drilling Fluid Program Requirements of 20 AAC 25.005(c)(8) An application for a Permit to Drill must be accompanied by each of the following items,except for an lienr already on file with the commission and identified in the application: (8)a drilling fluid program,including a diagram and description of the drilling fluid system,as required by 20 AAC 25.033; Mud Program Summary Surface Intermediate Production 13-1/2" Hole 9-7/8" Hole 6-3/4" Hole 10-3/4" Casing 7-5/8"Casing 4-1/2" Liner FLO-PRO NT Mud System Drilplex LSND(WBM) (WBM) Density 8.8-9.6 9.5- 10.5 9.0-10.0 ✓ PV 30-50 10-20 10-20 YP 40-80 16-24 16-24 Funnel Viscosity 200-300 N/A N/A Initial Gel 30-50 10- 12 5-8 10 minute Gel 30-50 10- 18 5- 12 API Filtrate NC <6 <6 HTHP Fluid Loss at 160 F N/A <10 < 10 pH 9.0- 10.0 9.0- 10.0 9.5- 10.0 Diagram of Doyon 141 Mud System is on file with AOGCC. Drilling fluid practices will be in accordance with appropriate regulations stated in 20 AAC 25.033. Abnormally Pressured Formation Information Requirements of 20 AAC 25.005(c)(9) N/A -Application is not for an exploratory or stratigraphic test well. Seismic Analysis Requirements of 20 AAC 25.005(c)(10) N/A -Application is not for an exploratory or stratigraphic test well. Seabed Condition Analysis Requirements of 20 AAC 25.005 f c)(11) N/A -Application is not for an offshore well. Evidence of Bonding Requirements of 20 AAC 25.005(c)(12) Evidence of bonding for ConocoPhillips Alaska, Inc. is on file with the Commission. QR1GINAL • Proposed Drilling Program Requirements of 20 AAC 25.005(c)(13) An application for a Permit to Drill must be accompanied by each of the following items,except for an nem already on file with the commission and identified in the application: The proposed drilling program is listed below. Please refer to attachment for proposed well schematic. DRIGINAL 1. Move in/rig up Doyon Rig 141. Install 21-1/4"Annular with 16"diverter line and function test. 2. Spud and directionally drill 13.5"hole to casing point at+/-3,939' MD/2,974'TVD as per directional plan (wp08). Survey with MWD,Gamma,Resistivity,GWD. 3. Run and cement 10-3/4",45.5#,L80,Hyd-563 casing to surface. Displace cement with mud. Evacuate top 2 feet of cement from annulus for sealant job(post rig.) 4. In the event cement returns are not seen at surface,perform a top job. 5. Remove diverter system,install and test 13-5/8"x 5,000 psi BOP's to 3500 psi(annular preventer to 2500 psi). Notify AOGCC 24 hrs before test. V 6. PU 9-7/8"PDC bit and directional drilling assembly,with MWD/LWD(Gamma,resistivity). RIH and clean out to 100' above shoe. Test surface casing to 3000 psi for 30 minutes. 7. Drill out shoe track and 20' of new hole. Perform formation integrity test to a minimum of 12.5 ppg,maximum of 16 ppg EMW leak off,recording results. 8. Directionally drill to TD at 13,423'MD/6,081'TVD,landing in the Kuparuk C sand. Wellsite geologist will call intermediate TD. Circulate and rotate until shakers are clean. Pump out of hole at 2 bpm to HWDP. (If tight spots are encountered,back ream through only tight areas.) 9. POOH on elevators. 10. Laydown intermediate BHA and rack back 5"DP(to lay down after casing run,this will minimize shale exposure time.) 11. Run 7-5/8",29.7#L80,Hydril 563 casing from TD to surface. 12. Pump cement job as per Schlumberger proposal,top of cement to be 12,552'MD(800'MD above top of the Kuparuk C sands). 13. Set slips and install wellhead x 7-5/8"packoff and test to 3500 psi. 14. Flush 10-3/4"x 7-5/8"annulus with water,followed by diesel to freeze protect. 15. Lay down 5"DP. 16. PU 4"DP,6-3/4"bit,and drilling assembly with MWD/LWD(Gamma,resistivity,stethoscope,periscope/ microscope,neutron density,and sonic for top of cement evaluation.)I 17. RIH and log top of cement with sonic on trip in hole.,continue to RIH and clean out cement to 100' above shoe. Test intermediate casing to 3500 psi for 30 minutes. 18. Drill out shoe track and 20' of new hole. Perform formation integrity test to minimum of 12.0 ppg,maximum of 16 ppg EMW leak off,recording results. 19. Directionally drill 6-3/4"hole geosteering though the Kuparuk C sand to TD-22,000'MD as per directional plan (wp08). 20. Circulate hole clean and Backream out of hole. 21. Lay down Production BHA. 22. PU and run 4-1/2", 11.6#,Hydril 563 slotted liner. The top of liner will be placed at 13,273'MD,allowing for 150'of overlap in the 7-5/8"casing. 23. Set liner hanger. Slackoff and set liner top packer. 24. Monitor well for flow for 15 minutes 25. Displace to clear brine. PT liner to 3,000 psi at surface for 30 minutes,chart results. ORIGINAL 26. Flow check well for 30 minutes to run 3-1/2"upper completion. 27. Nipple down BOPE,nipple up tree and test. 28. Freeze protect well with diesel and install BPV. 29. RDMO. Discussion of Mud and Cuttings Disposal and Annular Disposal Reguirements of 20 AAC 25.005(c)(14) An application for a Permit to Drill mustc be accompanied by each of the following items,except for an item already on file with the commission and identified in the application: (14)a general description of how the operator plans to dispose of drilling mud and cuttings and a statement of whether the operator intends to request authorisation under 20 AAC 25.080 for an annular disposal operation in the 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 DS 1B 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 Enviromnental Coordinator for questions regarding waste classification. (659-7212). Attachments: Attachment 1 Directional Plan Attachment 2 Drilling Hazards Summary Attachment 3 Well Schematic ORIGINAL Area of Review which includes review of 2G-11 and 2G-17. See AOR notes below. The quarter mile plot originally included does not clearly depict wells within 1/4 of a mile of 2F-22 because it shows 2G-17 crossing over the top of 2F-22, however this crossing is 1343'vertically above the lateral of 2F-22. 2G-17 has two C sand laterals in the same pay zone as 2F-22 however they are located^'2000' away to the south east, as shown below. G-11 2F-22 wp08 `, Intermediate landing Start of horizontal in C4 Sand Map view intersection w12G-17 2F-22wp08: MD 15300', SSTVD 6977' 2G-17: MD 10850, SSTVD 4634' 0. horizontal separation + ,� 1343'verticahs e pa ration + — 2 -17 ■ ■ ■ ■ ■ ■ ■ ■ ■ ■ ■ ■ ■� �E -- s s■ — Na M IN N 2G-11 does have laterals within 1/4 mile of 2F-22 but they are located in the A5 and A4 sands. See the pictures below that better describe the proximity of 2G-11 and 2F-22, and the answer to question#2 which goes into detail of why the risk of colliding with 2G-11 is low. ._ t + G-11 • 2F-22 wpitil r 2G-11AL1 is a horizontal Intermediate landing lateral drilled in the A5 Start of horizontal in C4 Sand Sand i \ 2G-11AL1-01 is a horizontal lateral drilled in the A4 Sand Map view closest point to 2G-11AL1-01 2f-22wp08: MD 15100'. SSTVD 5979' See cross-section on next lb, 2G-11AL1-01: MD 12506. SSTVD 6064' 415' horizontal separation slide 932' vertical separation + + I Map view closest point to 2G-11AL1 2F-22wp08: MD 15700', SSTVD 5978' 2G-11AL1: MD 12506, SSTVD 6064' 285' horizontal separatioi 86' vertical separation 2, -17 ■ ■ m • ! ■ ■ ■ ■ m ■ ■ Ef i ■e• N i nowow e maiau aimam ria 2. Anti-collision analysis:What are your plans for 2G-11 while you are drilling 2F-22? Please provide TCR for 2F-22. 2G-11 is an A5 sand producer and will remain online while we drill 2F-22. The close approach zone will be encountered while drilling the C sand lateral of 2F-22. Since we will be geosteering based off of formation geology with the sole objective of staying within the C sand (a target footage of approximately 15'TVD),there is very little risk of exiting the C sand. In the event that we exit the C sand there is 80'of B shale and A6 sand between our well and the 2G-11 AU lateral,where we will be able to steer back up and into the C sand. See the picture below for a visual description. The cross section represents the 2G-11 well and shows the two laterals drilled from that well that have close approaches with 2F-22 and their vertical distances from the 2F-22 lateral, as well as the geologic formations separating them. 2G-11AL1 ConocoPhillips North South Measured Deed, � �._—' � 1 -.. •.. MgTWM Deed, IS 3531 415'Lateral separation 260'literal separation 2-22-wp06 I 2f-22wall MO 15160' MO 16760' 2G-11 SS1VD 5979' SSTVO 8576' At1.01 [OP 10151 M M r..4. ID1 lord 1114 MD ---- [091913N14 K' 'MD aergM TO.11505 MD -.. 2502 MO told l —5115C w ,.:•: ^� e4 g, sham 1 � A4 --- ;�` All-U' 1 A TCR is a Tolerable Collision Risk worksheet and is an internal document to ConocoPhillips that calculates financial risk. The text from the document mentions what I did above,there is very little risk of exiting the C sand at all, and in the event that we do exit the C sand we will have a long time in the B shales to get turned back up in the correct direction. There is no greater risk to colliding with 2G-11 than there is with just encountering the A sand while drilling the C sand lateral of 2F-22. 3. Please provide a pad schematic of Doyon Rig 141 on 2F-22 with a sketch of the diverter route with approximate lengths. See the attached document entitled Doyon 141 diverter lay out. 4. If the packer is located more than 200' above the production zone then a variance is required. See 20 AAC 25.412(b). Request a variance if this is the case. The packer is 150'from the intermediate TD(within the C sand)and meets regulations. See drawing below. i x i s s E e s :. ,1 E¢ n n s is roc %a 2Q-OOi a I a_ a NOLL ME MOM • ----------- to MOTOI WQ. -- - P 1 -- -/ 7------1 - *- L -1 - - L S 1 } its' T 1.5;,S• ,r-r A • w o b I _ . i o 16 ul Y—_ `• ,���,�� Ili ','aTm�:_ _—__ IY c p ��I ��6 i-��-r.��11 �~ p J 1 2I } 5 &1 •'r�`Een+ugl smwrs. } I z e Y — _ --- - Il 10 I! -!.$}_ /T.pWt 6M -_-1 - S $—�--- __--__ E o- ' .sb _ ,w. -I aaaal-irr.-a.• J . L e•<• I ..�sn-.-•&w•-r,. _33...r .p-r ' I lP. • �—T —_-__....7___.=.:-..—..,:,' T 1 L-- ' ------------------- — ------- — -----1--J W MNTCM OMC 1 N- _M ESSUED FOR JUN 3O2014 =Mb�„ • CONST 44UCTION conoatops MK _ . .. .. . . ........ .... t•smtt • 5, •,o,on - ».ea•,....«. 0 a Jurat qw. —_{.--.. rz� I..., a-Es-zom p 1__.__ _ x _ ursmf�..s Ku b.. t.s _.J�k1[� ■�Rq'�� . �. _��.sE�_.d._$ t —om „��I, ••._•- 7�-4'---,I' a cm.....'...W.4:,.,," w:. P'• F. 2F-22wp08 7.1416 Plan Summary SURVEY PROGRAM 1525,Sep,.ember 09201, pth From Depth To Survey/Plan Tool 28.00 850.00 2F-22wp08 (Plan:2F-22) GYD-GC-SS 850.00 1850.00 2F-22wp08(Plan:2F-22) MWD \_ __ ---oma 850.00 3938.78 2F-22wp08(Plan:2F-22) MWD+IFR-AK-CAZ-SC 3938.78 5438.78 2F-22wp08 (Plan:2F-22) MWD 200° 3938.78 13422.46 2F-22wp08 (Plan:2F-22) MWD+IFR-AK-CAZ-SC \ e 13422.46 14922.46 2F-22wp08 (Plan:2F-22) MWD N - 2000 13422.46 22000.54 2F-22wp08(Plan:2F-22) MWD+IFR-AK-CAZ-SC i .-.... •.. _----woo ... - -str o N CASING DETAILS } r -800° ..... . TVD MD Name Size . • 2973.75 3938.78 10-3/4"x 13-1/2" 10-3/4 .i i. 12000 1poo -Iw00 6080.60 13422.46 7-5/8"x 9-7/8" 7-5/8 . . 6238.60 22000.54 4-1/2"x 6-3/4" 4-1/2 - -I6000 -18000 I 0o Ugnu(Ugnu C)Top W Sak(W Sak D) lowerkalubik A C(t�) op B2 _ 0 0° upper kalubik(base H 1 ( y 0 10-3/4"x 13-1/2" � -Iaun I - -5 0 000 0 B K-1:Mark r to a W Sak Al `� 11 t ', ,' base C4/top Bf-(Irv) - o o0 0 0 7-5/8"x 9-7/8" 4 $ o 0 4-1/2"x 6-3/4" top 7 3,.'� -' top HRZ(K-2 mk� ' ' CD i cv III 43® o bo a o _ . ..base W.Sak �� ��. 11 ..�' ...Fault 2 _....... _.. - o 00 ^ o a 0 0 0l g o ° ran a g 0 0 O ^ OH$fN 7-5/8'x 9-7/6" 1111 0 y t 1 t ,�.._� l f 1 1 f t f 0 ®® #, �- Base F@rmafrost t 5000 10000 15000 20000 0 3000 6000 9000 420)0 15000 18000 10-3/4"x 13-1/2" Measured Depth Horizontal Departure 0 28 345 C - 2•F21 urp04.1.. .___ _ .._...... _..._. .. _ _ _ 930. `: 1 0 -... so 2,....., - a 60 r,1 t l:i7j: 70p 903 `m v., -1.1PB1 'a. 30 60 - 0 cp n'''::" aha 6u-0z - '2 _ 18L1-01 1.....Hf t"� I ' iirrrm 30 2�•18L1 * T y� 1Iyp�{ 270 ® Ire4200 5003218 I "�U�IG(J ...... .:...':����0®�rp ,e4, t _E' 14 240 120 - mis - v I .� Imo F-13 _- 0 It ' III 1 I I 1 11 1 i 1 1 i i i I i i I I �` ''r"u , 210 0 2000 4000 6000 8000 10000 12000 14000 16000 18000 leo ; MO MOO SECTION DETAILS ,.., --- - Sec MD Inc Azi TVD +N/-S +E/-W Dleg TFace VSect Target Annotation 1 28.00 0.00 0.00 28.00 0.00 0.00 0.00 0.00 0.00 -82g 6 2 345.00 0.00 0.00 345.00 0.00 0.00 0.00 0.00 0.00 KOP:Start 1.5°/100'DLS,265°TF,for 250.18' - 10 6T--3 Sand 3 595.18 3.75 265.00 595.00 -0.71 -8.16 1.50 265.00 1.14 Start 2.51100'DLS,-5°TF,for 297.73' K-15 Marker 4 892.91 11.19 261.66 890.00 -5.76 -46.49 2.50 -5.00 8.18 Adjust TF to-15°,for 502.36' - 1418.6 5 1395.27 23.54 253.56 1368.60 -41.35 -191.51 2.50 -15.00 51.32 Hold for 100' e Permafrost 6 1495.27 23.54 253.56 1460.28 -52.65 -229.81 0.00 0.00 64.61 Start 3°/100'DLS,-60°TF,for 1200' - 1795.6Base 7 2695.27 51.37 212.90 2416.61 -529.80 -730.82 3.00 -60.00 567.32 Adjust TF to-52.85°,for 928.58' 8 3623.84 70.64 189.65 2869.34 -1281.02 -1006.68 3.00 -52.85 1331.95 Hold for 9440.6' Top Ugnu(Ugnu C) 913064.44 70.64 189.65 5999.11-10061.77 -2499.29 0.00 0.0010178.78 Start 3.51100'DLS,9.72°TF,for 358.03' 1013422.46 83.00 191.76 6080.60-10403.58 -2564.07 3.50 9.7210523.52 2F-22 01.TDInt 081214 LL Hold for 20' -2471.6 11 13442.46 83.00 191.76 6083.04-10423.01 -2568.12 0.00 0.0010543.13 Start 2.081100'DLS,-157.49°TF,for 66.83' pg�'• Top g W,,Sak(W Sak D) 1213509.29 81.72 191.22 6091.92-10487.92 -2581.32 2.08 -157.4910608.64 Hold for 39' _7_294tN6Sak Al 1313548.29 81.72 191.22 6097.54-10525.77 -2588.83 0.00 0.0010646.84 Start 2.081100'DLS,8.65°TF,for 402.58' 1413950.88 90.00 192.48 6126.60-10918.39 -2671.26 2.08 8.6511043.23 2F-22 02.8 081214 LL Start 1.51100'DLS,-0.1°Ti,for 90.46' 1514041.34 91.36 192.48 6125.53-11006.71 -2690.80 1.50 -0.1011132.45 Hold for 461.49' 1614502.83 91.36 192.48 6114.60-11457.17 -2790.50 0.00 0.0011587.51 2F-22 03.BaseC4 081214 LL Start 1.5°/100'DLS,47.17°TF,for 58.62' 1714561.45 91.95 193.12 6112.91-11514.31 -2803.48 1.50 47.1711645.25 Hold for 293.71' 1814855.16 91.95 193.12 6102.89-11800.18 -2870.13 0.00 0.0011934.22 Start 1.51100'DLS,131.24°TF,for 166.81' 1915021.98 90.30 195.01 6099.60-11961.95 -2910.66 1.50 131.2412097.89 2F-22 04.Fault2 081214 LL Start 1.13°/100'DLS,86.23°TF,for 197.09' 2015219.07 90.45 197.22 6098.30-12151.28 -2965.35 1.13 86.2312289.83 Hold for 64.73' base V/F,:, 21 15283.80 90.45 197.22 6097.79-12213.11 -2984.51 0.00 0.0012352.57 Start 2.251100'DLS,-93.76°TF,for 303.52' 2215587.31 90.00 190.40 6096.60-12507.67 -3056.91 2.25 -93.7612650.52 2F-22 05.C4Crest 081214 LL Start 1.5°/100'DLS,-179.91°TF,for 93.13' 2315680.44 88.60 190.39 6097.74-12599.26 -3073.71 1.50 -179.91 12742.86 Hold for 1389.15' 2417069.59 88.60 190.39 6131.60-13965.21 -3324.26 0.00 0.0014120.05 2F-22 06.BaseC4 2 081214 LL Start 0.39°/100'DLS,-89.75°TF,for 1660.99' 2518730.58 88.64 183.92 6171.60-15611.91 -3531.02 0.39 -89.7515775.32 2F-22 07.C4 081214 LL Start 3.62°/100'DLS,-103.32°TF,for 34.38' 2618764.97 88.35 182.71 6172.50-15646.23 -3533.01 3.62 -103.3215809.69 Hold for 1604.13' 2720369/0 88.35 182.71 6218.60-17247.90 -3608.75 0.00 0.0017413.13 2F-22 08.NearBaseC4 081214 LL Start 8.35°/100'DLS,-64.79°TF,for 23.67' -- 56 7" 2820392.77 89.20 180.92 6219.11 -17271.56 -3609.50 8.35 -64.7917436.79 Hold for 676.54' r.,. RZ(K-2 mkr) 2921069.31 89.20 180.92 6228.60-17947.95 -3620.35 0.00 0.0018112.82 2F-22 09.C4 2 081214 LL Start 5.99°/100'DLS,-14.77°TF,for 3.27' 3z c''r k I b k( �se rZ) 3021072.58 89.39 180.87 6228.64-17951.21 -3620.40 5.99 -14.7718116.09 Hold for 927.96' e "s )�C(i 1 31 22000.54 89.39 180.87 6238.60-18879.01 -3634.47 0.00 0.0019043.35 2F-22 10.TD 081214 LL TD:22000.54'MD,6238.6'TVD Fault 2 Surface Location Geodetic Datum: North American Datum 1983 Magnetic Model: BGGM2014 T M Depth Reference: Plan:96+28 @ 120.60usft(Doyon 141) MagnetMagnetic Model Date: 09-Sep-14 System SS Reference: Mean Sea Level a Magnetic c Direction a Tru ciiii North /Y. 5948402.35 ( ) To convert a Magnetic Direction to a True Direction,Add 19.17°East Ground Level/Mud Line: 92.60 East/X: 1657543.14 Rig: Doyon 141 trror creams Ab er or 7\ L 0 i E _, V s. eow N a 0 I 0 . +.+ V as C _ , L ca 0 to0 as 0 Q a as d E ®d — co r L CL L CCS 1 a ^' N ee V/ 2 a - 0 iM NI N N B;S E rm = = CV N 6V C L L Q ,,... 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U7 d co O N V N V N V N 7 V V 0 CO '' N m 00 cal N O V m o 00), Mo M 00 -p m (0 CO CO c0 m m (O CO V CO '7 N r d ® ui (O L i (O Vi (O (ri c0 (L (O c0 (D O O V O N N IN.: N N N' a L (0 V) m V) CO(O V) V) N 10 N 7 N V) N O M CO CO CO CO h CO N (y CL N ..,_, coy co (0 m (O CO (O m (O CO m m 0) CO CO r O CO CO N CO N O N 0) 4 ((fid d Lo- ,--- Vl r r r r r r r r 'C- -0 d V 0111 N d' N V' N 7 N N CO N O N CO CO N m VN) N) 7 o VO 7 CO oi G N O N O N O N4 N N NN O V) E d N N N N N r N O o V' O N O N O N O C7 i (0 o U $ co co m m m m m co c0 m m m m co CO 1' CO CO V) CO CO CO CO N (0 C r r r r r r r r r r CO 7 CO CO V) CO CO CO N CO N i m p E 01 N r r r r r r r r r r r V O O C N 3 .L 2 O Na �v d CI N N N 7 N d' N V' N d' V V' d' V' N m CO O Z-•-1 CO CO CO VCO M CO M 0) 'O (0 (o m m m CO CO CO CO 7 m VN r f N N 0) i L V) (o V) (O V) c0 V) m m m c0 c0 O CO V' O N CO N N N N • N 5' 7 9' co V) (0 V) (O V) m 0) (0) N V) N- V N V) N C) M N N CO N N- CO N C.. LL — N O. co (O COc0 m (O m COm COm (0 COV) m COr CO CO CO N 0) N CO N- CO L N W O d V) r r r r r r r r r a W d = m m m 5 cc d , Ti Or c-IV Z �''''C.C @ I (0 M ' r 0 C 0 01 m add 6 a s L O L. 7 V v U N U0 (d N as G Q N d N C LL d dr r j " 7 N V ' L' 0 CO 2 d Z o 0 ® a am 3 3 4— p o ' m o 0 4.4 C a • .7 .0 N CO Q L1. L U Oi„ N .13_: N N N CO M CO O] o] CO N N J J J Q n ® co LL . U Q Q Q Q Q Q a. a. O_ a Q Q Q r J J `- .- CL a- Q. N (= co m m m rn m 6 0 rn ` Q N 0,) Y d Q Q N N N N N E L 0 Ti E O O LL LL LL LL lL LL (L LL lL LL . LL r N N N h N. C� U` r e�- �(' O N O 3 n3 N N N N N N N N N N N N A r0 N N r0 O p �' O. O N N Z N N N N M M N N C C 0. N J J J J a N N N 0 N 0) J J J J J J o7 O] o] CO Q Q Q Q Q Q J J J J m ® r m Q Q Q Q Q Q Q Q a a a a a s (7 N N N N N N Q '� t o (") m m m m m m m m m m CO m N r r r r r r r 'N d N LL LL LL LL LL 11 LL LL LL LL CO LL ` N N N N N N N N N N N N 4 y d • N N NN N N N N N N N N GI O d co ni N N (Q N N N N N N V) L-5 d c z 0 CO CO m m CO CO CO CO m CO CO m D. r r r03 HH f6 f0 LL LL LL LL Y NNN NNN N N N N A �"L c -0' 0 a. x • o c; U G LY H ._ C^3 0 an a, e an Cr Pi O U 0 0 (...) UU U -5o en Un Un F- IV N N aa) U U U L' Y Y Y 9 UJ Q Q Q N ❑ C II U LL LL LL 0 + + + 6000000>- (9 2 2 2 2 2 2(9222222 co O .1- CO 00 m 0 ctn O as d 0_t. CU N N 3 1 y LL N 1 • T r, m `m 06 0_ cn M a) r o ro co co co co co Q 0 0 0 0 0 0 0 N N N N N N N ',4 = C 3 3 3 3 3 3 3 w CDG a d N N N N N N N U N U a) w N N N N N N NN 2 E Z.....- T.) c d N o o co m co co v ui 3 m m N o o N- N. v v in c c 3 Z O� .0 M M N N O C m U I F y co CO_ (n V V' O O c N N .== ,— el N co V N O N U N 0 N •E C. p y G N ^ct 0 2 N ❑ 1..1. T N 3 \ r-� • a a N o 0 o ro ro 4 o 2 g cu rn L R O O O t` r d' 7 O N c Q c 0 L N O O N ad N N N — 'y ^. N u7 CO CO N N N N a_ O O o co CO a co 'Cr v N a) U L ++ L IL a M CO- U 'A m _ U L2 U a) c4 CO O O N /� m a U Lii ii. 0 al a) , CO CO d N 6 U n/ i1 � N N U N LL a) o o_ a m 3 0 N N f12 a O U U ❑ a) ....- 0 N N a N U N _ . E I^ ,- Q a) N U -O m m N U O O -U c co N ✓ N a] 3 N U p 0O C L. a 0 QcaN a iTi N Q� � o � ORGNAL Conoc hiIIips 2F-22wp08 SChleeibergar Alaska ,1:,7,:7 Y. LL Q n, N N 300 ' Fl I rli4 I I , 1r,P i ; ` it ir i iii 4i i ,, 61 at CD CL 1 IiiimmimiN 150 kIEL, 0 I ti I 1 all re re ill' 2 _.a.0,,,, 4l 1 _ .. 0 1 11 1 1 , l I 1 1 1 I 1 , I 1 I 1 , l l l l i , 11 , 0 2500 5000 7500 10000 12500 15000 17500 Egulvelant Magnetic Distance Measured Depth Displayed interval could be less than entire range: 28.00 To 22000.54 ANTI-COLLISION SETTINGS Interpolation Method: MD+Stations,interval:25.00 Depth Range From: 28.00 To 22000.54 Results Limited By: Centre Distance:2397.25 SURVEY PROGRAM Depth From Depth To Survey/Plan Tool 28.00 850.00 2F-22wp08(Plan:2F-22) GYD-GC-SS 850.00 1850.00 2F-22wp08(Plan:2F-22) MWD 850.00 3938.78 2F-22wp08(Plan:2F-22) MWD+IFR-AK-CAZ-SC 3938.78 5438.78 2F-22wp08(Plan:2F-22) MWD 3938.78 13422.46 2F-22wp08(Plan:2F-22) MWD+IFR-AK-CAZ-SC 13422.46 14922.46 2F-22wp08(Plan:2F-22) MWD 13422.46 22000.54 2F-22wp08(Plan:2F-22) MWD+IFR-AK-CAZ-SC CASING DETAILS TVD MD Name Size 2973.75 3938.78 10-3/4"x 13-1/2" 10-3/4 6080.60 13422.46 7-5/8"x 9-7/8" 7-5/8 6238.60 22000.54 4-1/2"x 6-3/4" 4-1/2 LEGEND --e- 3S-08C Doyon 141,38 NC,3S-08C-to delete incorrect VO -i- 2F-18,2F-18L1-01,2F-18L1-01 VO $ 2G-11,2G 11A,2G-11A V0 -1-- 2F-13,2F-13,2F-13 V1 --X- 2F-18,2F-18L1-02,2F-18L1-02 VO -& 2G-11,2G-11AL1,2G-11AL1 VO -i- 2F-14,2F-14,2F-14 V7 -A- 2F-18,2F-18PB1,2F-18P81 VO -I- 2G-11,25-11AL1-01,2G-11AL1-01 VO -B- 2F-15,2F-15,2F-15 V1 -e- 2F-19,2F-19,2F-19 V2 -X- 2G-11,2G-11AL2,2G-11AL2 VO - 2F-16,2F-16,2F-16 V1 $- 2F-19,2F-19A,2F-19A VO -9- 25-11,2G-11APB1,2G-11APB1 VO - 2F-17,2F-17,2F-17 V3 -8- 2F-19,2F-19AL1,2F-19AL1 VO - 2G-17,2G-17,25-17 V1 - 2F-17,2F-17L1,2F-17L1 VO -0- 2F-19,2F-19AL2,2F-19AL2 VO -A- 25-17,2G-17L1,2G-17L1 VO -e- 2F-17,2F-17L1.O1,2F-17L1-01 VO -I- 2F-19,2F-19AL3,2F-19AL3 VO --0- 25-17,2G-17L1-01,2G-17L1-01 VO 2F-17,2F-17L1-02,2F•17L1-02 VO -A-- 2F-19,2F-19PB1,2F-19PB1 V5 -9- 2F-22,008 -e- 2F-18,2F-18,2F-18 VO -X- 2F-19,2F-19PB2,2F-19PB2 V3 2F-18,2F-18L1,2F-18L1 VO -e- Plan:2F-21,Plan:2F-21,2F-21wp04.1 VO f-'1 " I S I N A L ConocoPhillips 2 F-22w 08 Schlumberger Alaska • s N LL LL LL LL N N N N 60 di Q 30 ungilIIIill umrr 'Allt1101 44/0/a v Equivelant Magnetic Distance _. _ _. .... 0 I I I I I I I I I I I I I I I I I I I I I I 0 500 1000 1500 2000 2500 3000 350C Measured Depth Displayed interval could be less than entire range: 28.00 To 22000.54 ANTI-COLLISION SETTINGS Interpolation Method: MD+Stations, interval:25.00 Depth Range From: 28.00 To 22000.54 Results Limited By: Centre Distance:2397.25 SURVEY PROGRAM Depth From Depth To Survey/Plan Tool 28.00 850.00 2F-22wp08(Plan:2F-22) GYD-GC-SS 850.00 1850.00 2F-22wp08(Plan:2F-22) MWD 850.00 3938.78 2F-22wp08 (Plan:2F-22) MWD+IFR-AK-CAZ-SC 3938.78 5438.78 2F-22wp08(Plan:2F-22) MWD 3938.78 13422.46 2F-22wp08(Plan:2F-22) MWD+IFR-AK-CAZ-SC 13422.46 14922.46 2F-22wp08(Plan:2F-22) MWD 13422.46 22000.54 2F-22wp08(Plan:2F-22) MWD+IFR-AK-CAZ-SC CASING DETAILS TVD MD Name Size 2973.75 3938.78 10-3/4" x 13-1/2" 10-3/4 6080.60 13422.46 7-5/8"x 9-7/8" 7-5/8 6238.60 22000.54 4-1/2"x 6-3/4" 4-1/2 LEGEND $- 3S-08C Doyon 141,3S-0BC,3S-08C-to delete incorrect VO - - 2F-18,2F-18L1-01,2F-18L1-01 VO --9-- 2G-11,2G-11A,2G-11A VO - - 2F-13,2F-13,2F-13 V1 -X- 2F-18,2F-18L1-02,2F-18L1-02 VO -A- 23-11,23-11AL1,2G-11AL1 VO - 2F-14,2F-14,2F-14 V1 -a- 2F-18,2F-18P81,2F-18PB1 VO -i- 2G-11,2G-11AL1-01,2G-11AL1-01 VO -8- 2F-15,2F-15,2F-15 V1 $ 2F-19,2F-19,2F-19 V2 - 2G-11,2G-11AL2,2G-11AL2 VO -8- 2F-16,2F-16,2F-16 V1 -- 2F-19,2F-19A,2F-19A VO -8- 2G-11,20-11APB1,2G-11APB1 VO -X- 2F-17,2F-17,2F-17 V3 -8- 2F-19,2F-19AL1,2F-19AL1 VO -X- 2G-17,2G-17,20-17 V1 --0- 2F-17,2F-17L1,2F-17L1 VO -0- 2F-19,2F-19AL2,2F-19AL2 VO -3 - 2G-17,20-17L1,20-17L1 VO - 2F-17,2F-17L1-01,2F-17L1-01 VO 2F-19,2F-19AL3,2F-19AL3 VO _e_ 20-17,2G-17L1-01,2G-17L1-01 VO 2F-17,2F-17L1-02,2F-17L1-02 VO 2F-19,2F-19PB1,2F-19PB1 V5 -9- 2F-22ep08 - 2F-18,2F-18,2F-18 VO -X- 2F-19,2F-19PB2,2F-19PB2 V3 --8- 2F-18,2F-18L1,2F-18L1 VO Plan:2F-21,Plan:2F-21,2F-21 wp04.1 VO nrml p I A i oec MD Inc Azi TVD +N/-S +E/-W Dleg TFace vo...t Target Ltf .34b 1 28.00 0.00 0.00 28.00 0.00 0.00 0.00 0.00 0.00 2F-22wp08 2 345.00 0.00 0.00 345.00 0.00 0.00 0.00 0.00 0.00 345 500 3 595.18 3.75 265.00 595.00 -0.71 -8.16 1.50 265.00 1.14 _ 4 892.91 11.19 261.66 890.00 -5.76 -46.49 2.50 -5.00 8.18 500 /00 28.00 To 22000.54 5 1395.27 23.54 253.56 1368.60 -41.35 -191.51 2.50 -15.00 51.32 6 1495.27 23.54 253.58 1460.28 -52.65 -229.81 0.00 0.00 64.61 700 900 7 2695.27 51.37 212.90 2416.61 -529.80 -730.82 3.00 -60.00 567.32 8 3623.84 70.64 189.65 2869.34 -1281.02 -1006.68 3.00 -52.85 1331.95 1534.1e11srellEi[ir 09 2Q14 9 13064.44 70.64 189.65 5999.11 -10061.77 -2499.29 0.00 0.00 10178.78 900 1100 R 10 13422.46 83.00 191.76 6080.60 -10403.58 -2564.07 3.50 9.72 10523.52 2F-22 01.TDIn1081214 LL 11 13442.46 83.00 191.76 6083.04 -10423.01 -2568.12 0.00 0.00 10543.13 1100 1200 SURVEY PROGRAM 12 13509.29 81.72 191.22 6091.92 -10487.92 -2581.32 2.08 -157.49 10608.64 icp,ft From Oepzh Ta survevmlan T°ai 13 13548.29 81.72 191.22 6097.54 -10525.77 -2588.83 0.00 0.00 10646.84 zeua 650.00 2F22wp88(FIaw 2F]Z) GYo.Gcss 14 13950.88 90.00 192.48 6126.60 -10918.39 -2671.26 2.08 8.65 11043.23 2F-22 02.6 081214 LL 1200 1400 650.00 1850.00 2F22wp06(P000:2F2) MWD 15 14041.34 91.36 192.48 6125.53 -11006.71 -2690.80 1.50 -0.10 11132.45 850.00 3838.76 2F.22wp08(PIan,2F22) MWD.IFR-AK-c0z-Sc 16 14502.83 91.36 192.48 6114.60 -11457.17 -2790.50 0.00 0.00 11587.51 2F-22 03.BaseC4 081214 LL 1400 1600 3936.]8 5438.76 2F22wp08(Plan:2F-22) MWD 3930.78 13422.06 2F22wp08(Plan:2F-22) MOD.IFR-AK-CAz.sc 17 14561.45 91.95 193.12 6112.91 -11514.31 -2803.48 1.50 47.17 11645.25 13422.46 14822.46 2F-22wp0e(100:2F-22) MD 18 14855.16 91.95 193.12 6102.89 -11800.18 -2870.13 0.00 0.00 11934.22 1600 2500 1342z."s 22000.59 2Fzzwpo6(PI.n:2F-22) Mwwlm-ac<Ansc 19 15021.98 90.30 195.01 6099.60 -11961.95 -2910.66 1.50 131.24 12097.89 2F-2204.FauIt2081214 LL 20 15219.07 90.45 197.22 6098.30 -12151.28 -2965.35 1.13 86.23 12289.83 CASING DETAILS 21 15283.80 90.45 197.22 6097.79 -12213.11 -2984.51 0.00 0.00 12352.57 2500 3300 22 15587.31 90.00 190.40 6096.60 -12507.67 -3056.91 2.25 -93.76 12650.52 2F-22 05.C4Crest 081214 LL TVD MD Name Size 23 15680.44 88.60 190.39 6097.74 -12599.26 -3073.71 1.50 -179.91 12742.88 3300 4200 2973.75 3938.78 10-3/4"x 13-1/2" 10-3/4 24 17069.59 88.60 190.39 6131.60 -13965.21 -3324.26 0.00 0.00 14120.05 2F-22 06.BaseC4_2 081214 LL 6080.60 13422.46 7-5/8"x 9-7/8" 7-5/8 25 18730.58 88.64 183.92 6171.60 -15611.91 -3531.02 0.39 -89.75 15775.32 28-22 07.C4 081214 LL 4200 5000 6238.60 22000.54 4-1/2"x6-3/4" 4-1/2 26 18764.97 88.35 182.71 6172.50 -15646.23 -3533.01 3.62 -103.32 15809.69 27 20369.10 88.35 182.71 6218.60 -17247.90 -3608.75 0.00 0.00 17413.13 2F-22 08.NearBaseC4 081214 LL 28 20392.77 89.20 180.92 6219.11 -17271.56 -3609.50 8.35 -64.79 17436.79 5000 5900 29 21069.31 89.20 180.92 6228.60 -17947.95 -3620.35 0.00 0.00 18112.82 2F-22 09.C4_2 081214 LL 30 21072.58 89.39 180.87 6228.64 -17951.21 -3620.40 5.99 -14.77 18116.09 5900 6/00 31 22000.54 89.39 180.87 6238.60 -18879.01 -3634.47 0.00 0.00 19043.35 2F-22 10.11)081214 LL 6700 7600 0/360 7600 8400 '�- -__.._._ 0 .Ot** ` 8400 10100 3 ;tib moi. icy 5i....." 46eittet ttc, � `�' 11800 -30/330 �/f"moi 1s+`Av' � \�\`' � g`�a r 30 12F-161 10100 /�0,$ii0A i%1y73G� �`Ewa �liikgal91-MALA-: tI :aUez& _ 11800 13500 ��I1cV ►� �• ,i pie♦ ` � ►,0..s��.�.e ttw\Fi�;�=10..�,�-,,all`, zF1s 13500 15200 I`� '01.4 4 �� . ,, (7 1 '��.0 �$.r�T� 12F-131 , 1 15200 16900 'il I. i ;; jV(I 1 I `°' a ,° �'ii�a�a4.� v /12F1s116900 .. .. 18600 I !i; / i ` /y�r;�,�. \\`C� /� e0e♦0416.10 r .• c -r c ►�►,`��\�A:' � 5.3 'ft � ��� � � : �z iCI�� ►c ' ►o,•;aPFkft a °�� t 18600 - 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MwD.lm-118.887-SC 19 15021.98 90.30 195.01 6099.60 -11961.95 -2910.66 1.50 131.24 12097.89 2F-22 04.Fault2 081214 LL 1600 2500 20 15219.07 90.45 197.22 6098.30 -1215128 -2965.35 1.13 86.23 12289.83 CASING DETAILS 21 15283.80 90.45 197.22 6097.79 -12213.11 -2984.51 0.00 0.00 12352.57 2500 3300 22 15587.31 90.00 190.40 6096.60 -12507.67 -3056.91 2.25 -93.76 12650.52 2F-22 05.C4Crest 081214 LL TVD MD Name Size 23 15680.44 88.60 190.39 6097.74 -12599.26 -3073.71 1.50 -179.91 12742.86 3300 4200 2973.75 3938.78 10-3/4"x 13-1/2" 10-3/4 24 17069.59 88.60 190.39 6131.60 -13965.21 -3324.26 0.00 0.00 14120.05 2F-22 06.BaseC4_2 081214 LL 6080.60 13422.46 7-5/8"x 9-7/8" 7-5/8 25 18730.58 88.64 183.92 6171.60 -15611.91 -3531.02 0.39 -89.75 15775.32 2F-22 07.C4 081214 LL 6236.60 22000.54 4-1/2'x 6.3/4" 4-1/2 26 18764.97 88.35 182.71 6172.50 -15646.23 -3533.01 3.62 -103.32 15809.69 4200 5000 27 20369.10 88.35 182.71 6218.60 -17247.90 -3608.75 0.00 0.00 17413.13 2F-22 08.NearBaseC4 081214 LL 28 20392.77 89.20 180.92 6219.11 -17271.56 -3609.50 8.35 -64.79 17436.79 5000 5900 29 21069.31 8920 180.92 6228.60 -17947.95 -3620.35 0.00 0.00 18112.82 2F-22 09.C4_2 081214 LL 30 21072.58 89.39 180.87 6228.64 -17951.21 -3620.40 5.99 -14.77 18116.09 5900 6700 31 22000.54 89.39 180.87 6238.60 -18879.01 -3634.47 0.00 0.00 19043.35 2F-22 10.TD 081214 LL 0/360 6700 7600 7600 8400 8400 10100 -30/330 210 30 10100 11800 195 11800 13500 I 180 -,,- :` N- 13500 15200 6 15200 16900 150--•.- ` 16900 18600 j 18600 20300 j -60/300 '/ ` 60 20300 22001 00.0 1,1- ,....111,...7,.N\ii%\ (7\.' 751,:.-::---1-:. '''-\\. \ \%\1\1:‘1\ ("(li .,(I, ., ,:., ‘, . ,,, 1 i 90/270I � 90 ��1 111� l90 10 - //// / / \\'' -120/240 120 � �_ 150 .. -,�.. 165 180 .10°./.." ;; 195 150/210 ; 210 fTI- 150 `�..�-;.__ 225-180/180 -9- xsaec moonl4I.aSmc.asacwmom eemsf v9 -tr a.n.a-ml.ai7L1w -} a -} a 20 ..2SnADLI VO $ aa2apoe -el- OF.,a a.,a a,ao -N- a,,,.a.mum.28111.,81 w f a,e.a19e91.aneai yew -N- as.a,oPel,a,sea,vs -N- town.owl ,20-11u2w -I- a.,..a.l.,an.w $ 2817.an7l02.2F171.102w $ a.M.a,a 2F-1e V2 $ a.ro.a.,ece7.a.,avezw $ 2011.20.fVPM,20.114381 VO $ 2F-19,a-14 2815 VI $ aM,aa4 a.lew -e- an,aOWA.2F1efw $ Marc 2F21,pan 2Pm,z 'E}' 2814944 2;46 Vs aM.atll.28184 VO -1- a.ie,a.tett.a•Isau Vo $ 26 28.118.2D4Vo 1 V It -Z- a,7,a.17.an va -13- a.M.9.,0.1.01.2FIeL181 w $ 9.,8.9,8113.a.,Hlaw 200.20-0411,20-11.4n R I 4 f '"1 tM1) I VO iimir oec MD Inc Azi TVD +N/-S +E/-W Dleg TFace VSect Target „ R 1 28.00 0.00 0.00 28.00 . 0.00 0.00 0.00 0.00 0.00 C 2F-22wp08 3 595.108 3.75 265.00 595.00 0.00 8.106 1.50 265.00 10 0 2 0.00 BOO ,14 345 500 14500.00 !o 16000.00 4 892.91 11.19 261.66 890.00 -5.76 -46.49 2.50 -5.00 8.18 500 700 5 1395.27 23.54 253.56 1368.60 41.35 -191.51 2.50 -15.00 51.32 6 1495.27 23.54 253.56 1460.28 -52.65 -229.81 0.00 0.00 64.61 7 2695.27 51.37 212.90 2416.61 -529.80 -730.82 3.00 -60.00 567.32 700 900 M 8 3623.84 70.64 189.65 2869.34 -1281.02 -1006.68 3.00 -52.85 1331.95 f'th81F 09 15.414 Sept@2014 9 13064.44 70.64 189.65 5999.11 -10061.77 -2499.29 0.00 0.00 10178.78 900 1100 --J"-- 10 13422.46 83.00 197.76 6080.60 -10403.58 -2564.07 3.50 9.72 10523.52 2F-22 01.TD Int 081214 LL 11 13442.46 83.00 191.76 6083.04 -10423.01 -2568.12 0.00 0.00 10543.13 1100 1200 SURVEY PeOGRAM 12 13509.29 81.72 191.22 6091.92 -10487.92 -2581.32 2.08 -157.49 10608.64 >epth From Depth To sureymlan Tool 13 13548.29 81.72 191.22 6097.54 -10525.77 -2588.83 0.00 0.00 10646.84 29.00 850.00 20,-22wp09(Plan:2822) GYO-GCSs 14 13950.88 90.00 192.48 6126.60 -10918.39 -2671.26 2.08 8.65 11043.23 2F-22 02.8 081214 LL 1200 1 400 859.09 1959.00 2F22wp0870n:20,22) MWD 15 14041.34 91.36 192.48 6125.53 -11006.71 -2690.80 1.50 -0.10 11132.45 e50.00 5930.79 2F22wp08(Plan:2F.22) I WO.IRl-Ax-caasc 3933.78 22 16 14502.83 91.36 192.48 6114.60 -11457.17 -2790.50 0.00 0.00 11587.51 2F-22 03.BaseC4 081214 LL 1400 1600 3938.0 13622.48 2F-22wppOS Tan:2F22) MND+IFR-a(.CO.SC 17 14561.45 91.95 193.12 6112.91 -11514.31 -2803.48 1.50 47.17 11645.25 13422.48 14922.49 2F-22wp087Ian:20,22) 5500 18 14855.16 91.95 193.12 6102.89 -11800.18 -2870.13 0.00 0.00 11934.22 13422.49 22000.54 zFxzwp69(Plan:2F42) rmvG.iFR-aKcAz-SC 1600 250019 15021.98 90.30 195.01 6099.60 -11961.95 -2910.66 1.50 131.24 12097.89 2F-22 04.FauIt2 081214 LL - 20 15219.07 90.45 197.22 6098.30 -12151.28 -2965.35 1.13 86.23 12289.83 CASING DETAILS 21 15283.80 90.45 197.22 6097.79 -12213.11 -2984.51 0.00 0.00 12352.57 2500 3300 22 15587.31 90.00 190.40 6096.60 -12507.67 -3056.91 2.25 -93.76 12650.52 2F-22 05.C4Crest 081214 LL TVD MD Name Size 23 15680.44 88.60 190.39 6097.74 -12599.26 -3073.71 1.50 -179.91 12742.86 3300 4200 2973.75 3938.78 10-3/4"x 13-1/2" 10-3/4 24 17069.59 88.60 190.39 6131.60 -13965.21 -3324.26 0.00 0,00 14120,05 2F-22 06.BaseC4_2 081214 LL 6080.60 13422.46 7-5/8"x 9-7/8" 7-5/8 25 18730.58 88.64 183.92 6171.60 -15611.91 -3531.02 0.39 -89.75 15775.32 2F-22 07.C4 081214 LL 6238.60 22000.54 4-1/2"x 6-3/4" 4-1/2 26 18764.97 88.35 182.71 6172.50 -15646.23 -3533.01 3.62 -103.32 15809.69 4200 5000 27 20369.10 88.35 182.71 6218.60 -17247.90 -3608.75 0.00 0.00 17413.13 2F-22 08.NearBaseC4 081214 LL 28 20392.77 89.20 180.92 6219.11 -17271.56 -3609.50 8.35 -64.79 17436.79 5000 5900 29 21069.31 89.20 180.92 6228.60 -17947.95 -3620.35 0.00 0.00 18112.82 2F-22 09.C4 2 081214 LL 30 21072.58 89.39 180.87 6228.64 -17951.21 -3620.40 5.99 -14.77 18116.09 5900 6700 31 22000.54 89.39 180.87 6238.60 -18879.01 -3634.47 0.00 0.00 19043.35 2F-22 10.TD 081214 LL 0/360 6700 7600 7600 8400 ''.•••..."';- __.L 8400 10100 s I ����..4. 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O CD tri* 1 GAL ConocoPhillips (Alaska) Inc. -Ku p2 Kuparuk River Unit Kuparuk 2F Pad Plan: 2F-22 ('tween 13 & 14) Plan: 2F-22 Plan: 2F-22wp08 Error Ellipse Survey Report 09 September, 2014 (Th 1-_ tniNAL Schlurnberger Error Ellipse Report Company: ConocoPhillips(Alaska)Inc.-Kup2 Local Co-ordinate Reference: Well Plan:2F-22('tween 13&14) Project: Kuparuk River Unit TVD Reference: Plan:96+28 @ 120.60usft(Doyon 141) Site: Kuparuk 2F Pad MD Reference: Plan:96+28 @ 120.60usft(Doyon 141) Well: Plan:2F-22('tween 13&14) North Reference: True Wellbore: Plan:2F-22 Survey Calculation Method: Minimum Curvature Design: 2F-22wp08 Output errors are at 1.00 sigma Database: OAKEDMP2 Project Kuparuk River Unit,North Slope Alaska,United States Map System: US State Plane 1983 System Datum: Mean Sea Level Geo Datum: North American Datum 1983 Using Well Reference Point Map Zone: Alaska Zone 4 Using geodetic scale factor Site Kuparuk 2F Pad Site Position: Northing: 5,949,092.38 usft Latitude: 70°16'20.892 N From: Map Easting: 1,657,424.77 usft Longitude: 149°51'44.755 W Position Uncertainty: 0.00 usft Slot Radius: 0" Grid Convergence: 0.13° Well Plan:2F-22('tween 13&14) Well Position +N/-S 0.00 usft Northing: 5,948,402.35 usft Latitude: 70°16'14.102 N +D-W 0.00 usft Easting: 1,657,543.14 usft Longitude: 149°51'41.354 W Position Uncertainty 0.00 usft Wellhead Elevation: usft Ground Level: 92.60 usft Wellbore Plan:2F-22 Magnetics Model Name Sample Date Declination Dip Angle Field Strength (°) (°) (nT) EGGM2014 9/9/2014 19.17 80.87 57,574 Design 2F-22wp08 Audit Notes: Version: Phase: PLAN Tie On Depth: 28.00 Vertical Section: Depth From(TVD) +N/-S +El-W Direction (usft) (usft) (usft) (°) 23.00 0.00 0.00 183.00 Survey Tool Program Date 9/9/2014 From To (usft) (usft) Survey(Wellbore) Tool Name Description 28.00 850.00 2F-22wp08(Plan:2F-22) GYD-GC-SS Gyrodata gyro single shots 850.00 1,850.00 2F-22wp08(Plan:2F-22) MWD MWD-Standard 850.00 3,938.78 2F-22wp08(Plan:2F-22) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 3,938.78 5,438.78 2F-22wp08(Plan:2F-22) MWD MWD-Standard 3,938.78 13,422.46 2F-22wp08(Plan:2F-22) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 13,422.46 14,922.46 2F-22wp08(Plan:2F-22) MWD MWD-Standard 13,422.46 22,000.54 2F-22wp08(Plan:2F-22) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC Position uncertainty and bias at survey station Measured Inclination Azimuth Vertical Highside Lateral Vertical Magnitude Semi-major Semi-minor Depth Depth Error Bias Error Bias Error Bias or Bias Error Error Azimuth Tool (usR) 1°1 I°) buss) lust) (usft) (usft) (usft) (Liss) (usft) (usft) (usft) (usft) Ii 23.00 0,00 0.00 29.00 0 00 0 00 0.00 0.00 0.00 0.00 0 00 0.00 0.00 0.00 UNDEFINED 345.00 0.00 0.00 345.00 0.41 0.00 0.41 0.00 1.15 0.02 0.02 0.41 0.41 0.00 GYD-GC-5S(1,1) 595.18 3.75 265.00 595.00 0.67 0.00 0.67 0.00 1.16 0.05 0.05 0.67 0.67 173.91 GYD-GC-55(1,1) 826.43 9.53 261.96 824.60 0.98 -0.01 1.02 -0.01 1.15 0.11 0.11 1.02 1.01 87.63 MWD(1.2) 9/9/2014 3:32:43PMPage 2 COMPASS 5000.1 Build 65 DRIG1 \ AL • Schlumberger Error Ellipse Report Company: ConocoPhillips(Alaska)Inc.-Kup2 Local Co-ordinate Reference: Well Plan:2F-22('tween 13&14) Project: Kuparuk River Unit TVD Reference: Plan:96+28 @ 120.60usft(Doyon 141) Site: Kuparuk 2F Pad MD Reference: Plan:96+28 @ 120.60usft(Doyon 141) Well: Plan:2F-22('tween 13&14) North Reference: True Wellbore: Plan:2F-22 Survey Calculation Method: Minimum Curvature Design: 2F-22wp08 Output errors are at 1.00 sigma Database: OAKEDMP2 Position uncertainty and bias at survey station Measured Inclination Azimuth Vertical Highside Lateral Vertical Magnitude Semi-major Sean-minor Depth Depth Error Bias Error Bias Error Bias of Bias Error Error Azimuth Tool (usft) (°) (°) lush) (usft) (ash) (usft) (usft) (usft) (usft) (usft) (usft) (usft) (°) 892.91 11.19 261.66 890.00 0.98 -0.01 1.02 -0.01 1.15 0.11 0.11 1.02 1.01 87.63 MWD(1,2) 1,011.39 14.07 258.51 1,005.60 1.03 -0.02 1.37 -0.07 1.14 0.16 0.17 1.37 1.09 78.59 MWD(1,2) 1,395.27 23.54 253.58 1,368.60 1.25 -0.04 2.71 -0.23 1.14 0.25 0.34 2.71 1.35 75.74 MWD(1,2) 1,449.81 23.54 253.56 1,418.60 1.37 -0.04 3.31 -0.30 1.16 0.28 0.42 3.31 1.46 75.14 MWD(1,2) 1,495.27 23.54 253.56 1,460.28 1.37 -0.04 3.31 -0.30 1.16 0.28 0.42 3.31 1.46 75.14 MWD(1,2) 1,871.50 30.69 234.17 1,795.60 1.58 -0.11 2.66 0.04 1.19 0.43 0.46 2.71 1.65 66.62 MWD+IFR-AK-CAZ-SC(2,2) 2,695.27 51.37 212.90 2416.61 2.42 -0.34 5.45 0.12 1.54 0.74 0.84 5.67 2.40 50.35 MWD+IFR-AK-CAZ-SC(2,2) 2,784.98 53.02 210.21 2,471.60 2.55 -0.37 5.85 0.14 1.63 0.77 0.89 8.11 2.49 48.54 MWD+IFR-AK-CAZ-SC(2,2) 3,445.99 66.67 193.48 2,804.60 3.28 -0.64 8.86 0.31 2.44 0.97 1.23 9.59 3.07 38.14 MWD+IFR-AK-CAZ-SC(2,2) 3,623.84 70.64 189.65 2,869.34 3.37 -0.69 9.44 0.34 2.62 0.99 1.29 10.27 3.15 34.07 MWD+IFR-AK-CAZ-SC(2,2) 3,838.78 70.64 189.65 2,940.60 3.78 -0.69 10.78 0.34 3.03 1.04 1.42 11.52 3.23 31.23 MWD+IFR-AK-CAZSC(2,2) 3,938.78 70.64 189.65 2,973.75 3.87 -0.89 11.31 0.39 3.07 1.06 1.48 12.04 3.33 30.44 MWD(2,3) 12,094.63 70.64 189.65 5,877.60 14.74 -0.69 49.62 0.34 13.80 3.59 8.89 49.67 7.19 12.30 MWD+IFR-AK-CAZ-SC(3,3) 12,712.99 70.64 189.85 5,882.60 15.92 -0.69 53.41 0.34 14.93 3.90 9.82 53.46 7.53 12.07 MWD+IFR-AK-CAZ-SC(3,3) 12,993.52 70.64 189.85 5,975.60 16.26 -0.69 54.50 0.34 15.25 3.99 10.09 54.55 7.63 12.01 MWD+IFR-AK-CAZ-SC(3,3) 13,064.44 70.64 189.65 5,999.11 16.37 -0.69 54,85 0.34 15.35 4.02 10.18 54.89 7.67 11.99 MWD+IFR-AK-CAZ-SC(3,3) 13,352.43 80.58 191.36 6,070.60 16.52 -2.78 56.72 0.01 15.91 4.11 10.58 56.72 7.80 11.92 MWD+IFR-AK-CAZ-SC(3,3) 13,422.46 83.00 191.76 6,080.60 16.49 -2.89 56.87 0.00 15.91 4.12 10.81 56.87 7.87 11.92 MWD(3,4) 13,442.46 83.00 191.78 6,083.04 16.49 -2.89 57.01 0.01 15.91 4.12 10.63 57.01 7.87 11.92 MWD(3,4) 13,506.41 81.77 191.25 6,091.51 18.58 -2.66 57.49 0.16 15.92 4.13 10.70 57.50 7.88 11.93 MWD(3,4) 13,509.29 81.72 191.22 6,091.92 16.58 -2.66 57.49 0.16 15.92 4.13 10.70 57.50 7.88 11.93 MWD(3,4) 13,548.29 81.72 191.22 6,097.54 16.58 -2.66 . 57.78 0.19 15.92 4.13 10.74 57.78 7.88 11.94 MWD(3,4) 13,557.46 81.90 191.25 8,098.85 16.52 -2.86 58.17 0.20 15.93 4.14 10.79 58.17 7.89 11.94 MWD(3,4) 13,691.97 84.67 191.68 6,114.57 18.39 -3.23 58.94 0.22 15.95 4.15 10.89 58.94 7.90 11.96 MWD(3,4) 13,770.67 86.29 191.92 6,120.77 16.26 -3.60 59.75 024 15.98 4.16 10.98 59.75 7.91 11.98 MWD(3,4) 13,950.88 90.00 192.48 6,126.60 16.03 -4.16 61.00 0.26 16.03 4.16 11.11 81.01 7.92 12.01 MWD(3,4) 14,041.34 91.36 192.48 6,125.53 15.94 -4.41 61.79 0.32 16.08 4.16 11.18 61.79 7.93 12.03 MWD(3,4) 14,502.83 91.36 192.48 6,114.60 16.27 -4.41 66.04 0.63 16.41 4.15 11.52 66.04 7.98 12.13 MWD(3,4) 14,561.45 91.95 193.12 6,112.91 16.27 -4.52 66.59 0.55 16.46 4.15 11.56 66.60 7.99 12.15 MWD(3,4) 14,855.16 91.95 193.12 8,102.89 16.58 -4.52 69.53 0.72 16.77 4.15 11.77 69.54 8.03 12.23 MWD(3,4) 15,021.98 90.30 195.01 6,099.60 16.14 -4.20 60.56 -0.62 16.17 4.14 11.88 60.64 8.04 12.05 MWD+(FR-AK-CAZSC(4,4) 15,219.07 90.45 197.22 6,098.30 16.20 -4.23 60.87 -1.05 1824 4.14 12.01 61.11 8.07 12.09 MWD+IFR-AK-CAZ-SC(4,4) 15,283.80 90.45 197.22 6,097.79 16.22 -4.23 61.04 -1.05 16.28 4.14 12.06 61.28 8.08 12.11 MWD+IFR-AK-CAZ-SC(4,4) 15,587.31 90.00 190.40 6,096.60 16.38 -4.14 61.94 0.31 16.38 4.14 12.29 61.97 8.12 12.15 MWD+IFR-AK-CAZ-SC(4.4) 15,680.44 88.60 190.39 6,097.74 16.55 -3.86 62.13 0.31 16.42 4.14 12.36 62.16 8.13 12.15 MWD+IFR-AK-CAZSC(4,4) 17,069.59 88.60 190.39 6,131.60 17.33 -3.86 66.36 0.31 17.21 4.17 13.52 66.39 8.27 12.10 MWD+IFR-AK-CAZ-SC(4,4) 18,730.58 88.64 183.92 6,171.60 18.66 -3.87 70.38 1.84 18.55 4.21 14.93 71.04 8.45 11.79 MWD+IFR-AK-CAZ-SC(4,4) 18,764.97 88.35 182.71 6,172.50 18.72 -3.80 70.27 2.14 18.58 4.21 14.96 71.15 8.46 11.78 MWD+IFR-AK-CAZSC(4,4) 20,369.10 88.35 182.71 6,218.60 20.34 -3.80 76.09 2.14 20.21 425 16.35 76.90 8.68 11.08 MWD+IFR-AK-CAZ-SC(4,4) 20,392.77 89.20 180.92 8,219.11 20.30 -4.03 75.79 2.63 20.24 425 16.37 76.98 8.69 11.07 MWD+IFR-AK-CAZ-SC(4,4) 21,069.31 89.2D 180.92 6,228.60 21.07 -4.03 78.45 2.63 21.01 4.26 16.94 79.60 8.83 10.71 MWD+IFR-AK-CAZ-SC(4,4) 21,072.58 89.39 180.87 8,228.64 21.08 -4.08 78.46 2.64 21.01 426 16.94 79.61 8.83 10.70 MWD+IFR-AK-CAZSC(4,4) 22,000.54 89.39 180.87 8,238.60 22.18 -4.08 82.27 2.64 22.13 427 17.71 83.36 9.06 10.21 MWD+IFR-AK-CAZ-SC(4,4) 3,938.78 2,973.75 10-3/4"x 13-1/2" 10-3/4 13-1/2 13,422.46 8,080.60 7-5/8"x 9-7/8" 7-5/8 9-7/8 22,000.54 6,238.60 4-1/2"x 6-3/4" 4-1/2 6-3/4 9/9/2014 3:32:43PM Page 3 COMPASS 5000.1 Build 65 ORG \ NAL Schlumberger Error Ellipse Report Company: ConocoPhillips(Alaska)Inc.-Kup2 Local Co-ordinate Reference: Well Plan:2F-22('tween 13&14) Project: Kuparuk River Unit TVD Reference: Plan:96+28 @ 120.60usft(Doyon 141) Site: Kuparuk 2F Pad MD Reference: Plan:96+28 @ 120.60usft(Doyon 141) Well: Plan:2F-22('tween 13&14) North Reference: True Wellbore: Plan:2F-22 Survey Calculation Method: Minimum Curvature Design: 2F-22wp08 Output errors are at 1.00 sigma Database: OAKEDMP2 Formations Measured Vertical Dip Depth Depth Dip Direction (usft) (usft) Name Lithology (°) (1 826.43 824.60 top T-3 Sand 1,011.39 1,005.60 K-15 Marker 1,449.81 1,418.60 Base Permafrost 1,871.50 1,795.60 Top Ugnu(Ugnu C) 2,784.98 2,471.60 Top W Sak(W Sak D) 3,445.99 2,804.60 top W Sak A1 3,838.78 2,940.60 base W Sak 12,094.63 5,677.60 top HRZ(K-2 mkr) 12,712.99 5,882.60 upper kalubik(base HRZ) 12,993.52 5,975.60 lower_kalubik(K-1 mkr) 13,352.43 6,070.60 top C(top C4) 13,506.41 6,091.51 top B2 13,557.46 6,098.85 Fault 2 13,691.97 6,114.57 Fault 1 13,770.67 6,120.77 base C4/top B2(inv) Plan Annotations Measured Vertical Local Coordinates Depth Depth +N/-S +E/-W (usft) (usft) (usft) (usft) Comment 345.00 345.00 0.00 0.00 KOP:Start 1.5°/100'DLS,265°TF,for 250.18' 595.18 595.00 -0.71 -8.16 Start 2.5°/100'DLS,-5°TF,for 297.73' 892.91 890.00 -5.76 -46.49 Adjust TF to-15°,for 502.36' 1,395.27 1,368.60 -41.35 -191.51 Hold for 100' 1,495.27 1,460.28 -52.65 -229.81 Start 3°/100'DLS,-60°TF,for 1200' 2,695.27 2,416.61 -529.80 -730.82 Adjust TF to-52.85°,for 928.58' 3,623.84 2,869.34 -1,281.02 -1,006.68 Hold for 9440.6' 13,064.44 5,999.11 -10,061.77 -2,499.29 Start 3.5°/100'DLS,9.72°TF,for 358.03' 13,422.46 6,080.60 -10,403.58 -2,564.07 Hold for 20' i 13,442.46 6,083.04 -10,423.01 -2,568.12 Start 2.08°/100'DLS,-157.49°TF,for 66.83' 13,509.29 6,091.92 -10,487.92 -2,581.32 Hold for 39' 13,548.29 6,097.54 -10,525.77 -2,588.83 Start 2.08°/100'DLS,8.65°TF,for 402.58' 13,950.88 6,126.60 -10,918.39 -2,671.26 Start 1.5°/100'DLS,-0.1°TF,for 90.46' 14,041.34 6,125.53 -11,006.71 -2,690.80 Hold for 461.49' 14,502.83 6,114.60 -11,457.17 -2,790.50 Start 1.5°/100'DLS,47.17°TF,for 58.62' 14,561.45 6,112.91 -11,514.31 -2,803.48 Hold for 293.71' 14,855.16 6,102.89 -11,800.18 -2,870.13 Start 1.5°/100'DLS,131.24°TF,for 166.81' 15,021.98 6,099.60 -11,961.95 -2,910.66 Start 1.13°/100'DLS,86.23°TF,for 197.09' 15,219.07 6,098.30 -12,151.28 -2,965.35 Hold for 64.73' 15,283.80 6,097.79 -12,213.11 -2,984.51 Start 2.25°/100'DLS,-93.76°TF,for 303.52' 15,587.31 6,096.60 -12,507.67 -3,056.91 Start 1.5°/100'DLS,-179.91°TF,for 93.13' 15,680.44 6,097.74 -12,599.26 -3,073.71 Hold for 1389.15' 17,069.59 6,131.60 -13,965.21 -3,324.26 Start 0.39°/100'DLS,-89.75°TF,for 1660.99' ! 18,730.58 6,171.60 -15,611.91 -3,531.02 Start 3.62°/100'DLS,-103.32°TF,for 34.38' 18,764.97 6,172.50 -15,646.23 -3,533.01 Hold for 1604.13' 20,369.10 6,218.60 -17,247.90 -3,608.75 Start 8.35°/100'DLS,-64.79°TF,for 23.67' 20,392.77 6,219.11 -17,271.56 -3,609.50 Hold for 676.54' 21,069.31 6,228.60 -17,947.95 -3,620.35 Start 5.99°/100'DLS,-14.77°TF,for 3.27' 21,072.58 6,228.64 -17,951.21 -3,620.40 Hold for 927.96' 22,000.54 6,238.60 -18,879.01 -3,634.47 TD:22000.54'MD,6238.6'TVD 9/9/2014 3:32:43PM Page 4 0RIGINAL COMPASS 5000.1 Build 65 Schlumberger Error Ellipse Report Company: ConocoPhillips(Alaska)Inc.-Kup2 Local Co-ordinate Reference: Well Plan:2F-22('tween 13&14) Project: Kuparuk River Unit TVD Reference: Plan:96+28 @ 120.60usft(Doyon 141) Site: Kuparuk 2F Pad MD Reference: Plan:96+28 @ 120.60usft(Doyon 141) Well: Plan:2F-22('tween 13&14) North Reference: True Wellbore: Plan:2F-22 Survey Calculation Method: Minimum Curvature Design: 2F-22wp08 Output errors are at 1.00 sigma Database: OAKEDMP2 Checked By: Approved By: Date: 9/9/2014 3:32:43PM Page 5 COMPASS 5000.1 Build 65 ORIGINAL Pool Report ; 1I \ ,A U I \, -/ V T as - 2F-22 Drilling Risks Summary 13-1/2" Hole/ 10-3/4" Casing Interval Event Risk Level Mitigation Strategy Broach of Conductor Low Monitor cellar continuously during interval. Gas Hydrates Low If observed-control drill,reduce pump rates,reduce drilling fluid temperatures,Additions of Lecithin. Anti-collision Low Run Gyro as needed for magnetic interference. Gravel/Sand Sloughing Low Increase mud weight/viscosity,High viscosity sweeps. Monitor fill on connections Hole Swabbing/Tight Hole on Moderate Circulate hole clean prior to trip. Proper hole fill(use of Trips trip sheets),Pumping out of hole as needed. Lost circulation Low Prevent by keeping hole clean. If losses occur-reduce pump rates and mud rheology,use LCM Unsuccessful cement job Moderate Use lower density cement slurry.Adjust the mud properties prior pump cement.Use proper pump rate. 9-7/8" Hole/7-5/8" Casing Interval Event Risk Level Mitigation Strategy Shale stability Moderate For the unstable HRZ and Kalubik shales with high inclination control with higher MW and proper tripping practices to avoid surging or swabbing. High ECD and swabbing Low Condition mud prior to trips. Monitor ECD's with PWD tool while drilling across pay interval. Backream out on trips as a last resort. Lost circulation Low Use PWD and TAD to monitor hole cleaning. Reduced pump rates,adjust mud rheology,add LCM. Use GKA LC decision tree. Hole cleaning Low Use PWD and TAD to monitor hole cleaning.Control the ROP and use the best hole cleaning practice. Stuck pipe Low Good hole cleaning,stabilized BHA,proper mud weight, PWD monitor ECD. Sub-normal Reservoir Pressure Moderate Reservoir pore pressure is estimated at 8.0 ppg,but could be as low as 6.9 ppg based on offset well 2G-17. Addition of LCM to control any losses,good hole cleaning and ROP limits to maintain a low ECD. 6-3/4" Hole/4-1/2" Liner Interval Event Risk Level Mitigation Strategy High ECD and swabbing Moderate Condition mud prior to trips. Monitor ECD's with PWD tool while drilling across pay interval. Backream out on trips as a last resort. Sub-normal Reservoir Pressure Moderate Reservoir pore pressure is estimated at 8.0 ppg,but could be as low as 6.9 ppg based on offset well 2G-17. Addition of LCM to control any losses,good hole cleaning and ROP limits to maintain a low ECD. Lost Circulation Moderate Use PWD and TAD to monitor hole cleaning. Reduced pump rates,adjust mud rheology,add LCM. Use GKA LC decision tree. Stuck pipe Moderate Good hole cleaning, stabilized BHA,proper mud weight to minimize differential stuck,PWD monitor ECD. Hole swabbing on trips Low Control trip speeds,monitor proper hole fill while tripping,good hole cleaning. Prepared by Lindsey Hunter s-.., r i C' I t\ ( ! • 2F-22 (wpo8) ConocoPhillipls Grassroots Horizontal C-Sand Injector Last Edited: Proposed Wellbore Schematic(3 String-Primary) Hunter—9/9/14 4,LAMERON ) 4-W tree,top joint is 4-'/'12.6#IBTM 13.5" Surface Hole ® 20"Conductor to— 110' CLrn "` 3-'/"2.875"DS Landing X ;.$1*! Nipple CL 65° @ 3,400' MD Top West Sak: 2,785' MD/2,471' TVD GL 70° @ 3,600' MD Base West Sak: 3,839' MD/2,941' TVD Surface Casing 10-3/4"45.5# L-80 Hydri1563 9-7/8" Intermediate Hole 3,939' MD/2,974' TVD 3-'/2"GLM 3-1/2" 9.3#L-80 EUE 8RD-MOD -4111 Tubing Intermediate Casing 7-5/8" 29.7#L-80 Hyd563 Casing 13,423' MD/6,081'TVD (83° ) Baker 2.812"CMU Sliding Sleeve Baker 7-5/8"Premier Packer wl PBR Planned TOC @13,203'MD/6,039'TVD 12,552'MD 7-518"Flex Lock Liner 6-3/4" Production Hole Hanger/ZXP Top Packer @13,273'MD/6,05 'TVD r 6.38"x 4-1/2"Swell Packer /342.3 MO Top Kuparuk C: 13,352' MD/6,071' TVD At::*** ®- --------�-'/:„OShoerange Peel a 3'/2"2.75"DNipple -- ---® -- :;I- I 3-1/2"HES Mirage —8300 ft Hzl Section Disappearing Plug TD:22,001'MD/6,239'TVD Production Liner: 4-1/2" 11.6# L-80 Hyd563 Slotted Liner @ 89° NOTE:Swell Packer will be adjusted as necessary using microscope and periscope data ORGINA1 2F-22 Schlumberger CemCADE Preliminary Job Design 10 3/4" Surface Casino (V1) Preliminary Job Design based on limited input data.For estimate purposes only. Volume Calculations and Cement Systems Rig: Doyon 141 Volumes are based on 250%excess in the permafrost and 50%excess below the Location: Kuparuk permafrost. The top of the tail slurry is designed to be at 3439' MD. Client:CPAI Revision Date:Sept.18,2014 Prepared by:Jenna Houston Location:Anchorage,AK Lead Slurry Minimum pump time: -260 min. (pump time plus 120 min.) Phone: (907)263-4207 DeepCRETE @ 11.00 ppg-1.91 ft3/100 lb sk Mobile: (907)223-8916 email:jhouston2@slb.com 1.339 ft3/ft x 110 x 1.0 (0% excess) = 148 ft3 0.3637 ft3/ft x (1449-110) x 3.50 (250%excess) = 1704 ft3 < TOC at Surface 0.3637 ft3/ft x (3439-1449) x 1.50 (50%excess) = 1086 ft3 1704 ft3+ 1086 ft3+ 148 ft3= 2938 ft3 2938 ft3/1.91 ft3/sk= 1539 sks(1550 sks) Have additional DeepCRETE on location for Top Out stage, if necessary. Tail Slurr\r Minimum pump time: -190 min. (pump time plus 120 min.) 12.0 ppg DeepCRETE-1.63 ft3/1001b sk 0.3637 ft3/3t x (3939-3439) x 1.50 (50% excess) = 273 ft3 0.54000 ft /ft x 80' (Shoe Joint) = 44 ft 273 ft3+44 ft3 = 317 ft3 317 ft3/ 1.63 ft3/sk= 195 sks Round up to 205 sks BHST= 82°F, Estimated BHCT= 76°F. (Based on 2.1 °F/100 ft. from surface) PUMP SCHEDULE < Base of Permafrost at 1,449'MD(1,418'TVD) Pump Rate Stage Stage Time Cumulative Stage Volume Time (bpm) (bbl) (min) (min) MUDPUSH II 7.0 100.0 14.3 14.3 Pause 0.0 0.0 5.0 19.3 11 ppg DeepCRETE 7.0 523.2 74.7 94.0 < Top of Tail at Surface Tail 7.0 56.3 8.0 102.0 DeepCRETE Slurry 3439'MD Pause 0.0 0.0 5.0 107.0 Fresh Water 7.0 10.0 1.4 108.4 Pause 0.0 0.0 5.0 113.4 Mud 8.0 351.1 43.9 157.3 Mud 3.0 10.0 3.3 160.6 MUD REMOVAL < 10 3/4",45.5#casing in 13.5"OH Expected Mud Properties:9.5 ppg, Pv<20, Ty<20 Spacer Properties:10.5 ppg MudPUSH* II, Pv= 17-21, Ty=20-25 { TD at 3939'MD Centralizers: As per CPAI program. (2974'TVD) Mark of Schlumberger J - I G 1 N A L 2F-22 Schlumberger CemCADE Preliminary Job Design 7 5/8" Intermediate (v1) Preliminary Job Design based on limited input data.For estimate purposes only. Rig: Doyon 141 Volume Calculations and Cement Systems Location: Kuparuk Client:CPAi Revision Date:Sept. 18,2014 Volumes are based on 40%excess. Prepared by:Jenna Houston Location:Anchorage,AK Tail Slurry Minimum thickening time: -230 min. (pump time plus 120 min.) Phone: (907)263-4207 15.8 ppg Class G +adds- 1.16 ft3/sk Mobile: (907)223-8916 email:jhouston2@slb.com Annular Volume: 0.2148 ft3/ft x (13422'-12552') x 1.4 (40%excess) = 262 ft3 Shoe Volume: 0.2394 ft3/ft x 80' x 1.00 (no excess) = 20 ft3 Totals: 262 ft3+20 ft3= 282 ft3 282 ft3/ 1.16 ft3/sk= 244 sks(255 sks) BHST= 148 °F, Estimated BHCT= 114 °F. (BHST calculated using a gradient of 2.1 °F/100 ft. from surface) PUMP SCHEDULE Stage Cumulative Pump Rate Stage Time 10 3/4",45.5# Stage (bpm) Volume (min) Time (bbl) (min) at 3939'MD CW100 7.0 40.0 5.7 5,7 MUDPUSH II 7.0 40.0 5.7 11.4 Pause 0.0 0.0 5.0 16.4 Tail Slurry 7.0 50.3 7.2 23.6 Pause 0.0 0.0 5.0 28.6 Fresh Water 7.0 10.0 1.4 30.0 Top of Tail at end of pumping Pause 0.0 0.0 5.0 35.0 < 12552'MD Mud 7.0 592.6 84.7 119.7 Mud 3.0 10.0 3.3 123.0 MUD REMOVAL 9 7/8'°off Recommended Mud Properties:10.0 ppg, Pv<20, Ty<20. As thin and light as possible to aid in mud removal during cementing. Spacer Properties:11.5 ppg MudPUSH* II, Pv 25 -30, Ty=30 -40 Centralizers: As per CPAi program 7 5/8"29.7# TD at- 13422'MD (6080'TVD) Mark of Schlumberger ORIGINAL Loepp, Victoria L (DOA) From: Hunter, Lindsey L <Lindsey.Hunter@conocophillips.com> Sent: Tuesday, September 30, 2014 3:57 PM To: Ferguson,Victoria L(DOA) Subject: RE:2F-22(PTD 214-150) Attachments: Question Responses for AOGCC.docx; Doyon 141.diverter lay out.pdf Follow Up Flag: Follow up Flag Status: Flagged Victoria, Please see the attached documents to answer your questions below. I will be out of the office from this Thursday through October 11th. If you have any more questions after tomorrow (I will be in the office) please call my cell phone at 907-952-3173. Thank you, Lindsey Lindsey Hunter Drilling Engineer ConocoPhillips Alaska D&W Office - 907-265-6427 Cell -907-952-3173 lindsey.hunter a conocophillips.com From: Ferguson, Victoria L(DOA) [mailto:victoria.ferguson@alaska.gov] Sent: Monday, September 29, 2014 2:49 PM To: Hunter, Lindsey L Subject: [EXTERNAL]2F-22(PTD 214-150) Lindsey, Please provide: 1. Area of Review which includes review of 2G-11 and 2G-17. See AOR notes below. 2. Anti-collision analysis:What are your plans for 2G-11 while you are drilling 2F-22?Please provide TCR for 2F-22. 3. Please provide a pad schematic of Doyon Rig 141 on 2F-22 with a sketch of the diverter route with approximate lengths. 4. If the packer is located more than 200'above the production zone then a variance is required. See 20 MC 25.412(b). Request a variance if this is the case. Area of Review—Infection or Service Wells The construction and abandonment requirements for wells drilled in Alaska are not dependent on whether the well is a producer or injector. However, verification of the adequacy of the construction or abandonment of any well is subject to greater scrutiny if a well is proposed as a service well. This verification process is known as the Area of Review (AOR) and it applies to all wells, whether active or abandoned, that are within %mile radius 1 of a service well. The process also applies when annular disposal is proposed for a well. See: 20 AAC 25.080(b)(4), 25.252(c)(1) and (c)(12) and 25.402(b) and (b)(1). The verification process for the well to be drilled or converted is not very difficult. Generally sufficient information can be developed and gathered while drilling the new well or the existing information in the well file is sufficient to make the determination. For some conversions, a cement evaluation log may be needed to verify current wellbore conditions. In some cases, follow-up logs (temperature, water flow, etc.) may also be needed to confirm placement and confinement of the injected fluids. In order to perform an effective AOR, it is critical that all proximate wellbores and wellbore sections be identified including existing and abandoned wells, plugbacks and "lost" hole sections. For purposes of the assessment, the reference point used to establish an AOR for a proposed injection well is the point at which the wellbore penetrates the productive horizon or for annular disposal, the surface casing shoe. For horizontal service wells, the % mile radius continues along the well path through the reservoir to TD. Any wellbore or section identified within an AOR must not provide a pathway that could allow fluids to escape from the receiving zone. Where multiple producing formations are penetrated by a well, an AOR for each zone may need to be assessed. Victoria Ferguson Senior Petroleum Engineer State of Alaska Oil&Gas Conservation Commission 333 W 7th Ave,Ste 100 Anchorage,AK 99501 Work (907)793-1247 victoria.ferquson[a7alaska cloy CONFIDENTIALITY NOTICE:This e-mail message,including any attachments,contains information from the Alaska Oil and Gas Conservation Commission(AOGCC),State of Alaska and is for the sole use of the intended recipient(s).It may contain confidential and/or privileged information.The unauthorized review,use or disclosure of such information may violate state or federal law.If you are an unintended recipient of this e-mail,please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Victoria Ferguson at(907)793-1247 or Victoria.Ferguson@alaska.gov 2 1. Area of Review which includes review of 2G-11 and 2G-17. See AOR notes below. The quarter mile plot originally included does not clearly depict wells within 1/4 of a mile of 2F-22 because it shows 2G-17 crossing over the top of 2F-22, however this crossing is 1343'vertically above the lateral of 2F-22. 2G-17 has two C sand laterals in the same pay zone as 2F-22 however they are located^'2000' away to the south east, as shown below. 2F-22_tivp08 t t Intermediate landing Start of horizontal in C4 Sand Map view intersection wl26-17 2F-22wp08: MD 15300', SSTVD 5977' ' 26-17: MD 10850, SSTVD 4634'0'horizontal separation 1343' verticaf-se pa ratio n r� + -17 • • ■ ■ ■ ■ ■ ■ ■ al ■ ■ ■ • _ _MI _ • NM MIR r a>• a1 M 2G-11 does have laterals within % mile of 2F-22 but they are located in the A5 and A4 sands. See the pictures below that better describe the proximity of 2G-11 and 2F-22, and the answer to question#2 which goes into detail of why the risk of colliding with 2G-11 is low. _ t G-11 2F-22 wPOs \. • 2G-11AL1 is a horizontal Intermediate landing lateral drilled in the AS Start of horizontal in C4 Sand Sand \N\ 2G-11AL1-01 is a /11 horizontal lateral drilled in the A4 Sand i9ap view closest point to 2G-11AL1-01 2F-22wo08: IAD 15100'. SSTVD 5979' See cross-section on next 2G-11AL1-01: MD 12506, SSTVD 6064' 415' horizontal sepal slide 132' vertical separati + + Map view closest point to 2G-11 AL 1 2F-22wpO11: MD 15700', SSTVD 5978' 2G-11AL1: MD 12506, SSTVD 6064' 285' horizontal separation 86' vertical separation 2,- —17 ■ ■ ■ ■ ■ ■ ■ ■ ■ ■ ■ ■ ■ 1111 I• >• MN Wait NO MI NI MB NI 2. Anti-collision analysis:What are your plans for 2G-11 while you are drilling 2F-22? Please provide TCR for 2F-22. 2G-11 is an A5 sand producer and will remain online while we drill 2F-22. The close approach zone will be encountered while drilling the C sand lateral of 2F-22. Since we will be geosteering based off of formation geology with the sole objective of staying within the C sand (a target footage of approximately 15'ND),there is very little risk of exiting the C sand. In the event that we exit the C sand there is 80' of B shale and A6 sand between our well and the 2G-11 AL1 lateral,where we will be able to steer back up and into the C sand. See the picture below for a visual description. The cross section represents the 2G-11 well and shows the two laterals drilled from that well that have close approaches with 2F-22 and their vertical distances from the 2F-22 lateral, as well as the geologic formations separating them. 2G-11 AL1 ConotoPhi hps NorthSouth .. . .... 11� -... .._. Measwrd Orvm ............. --T---.— _. 1n Ism [JA 416'lateral separation 285'lateral separation 2f.22-1MpD5� 2i-22_wp08 MO15100' MO 15100' 2G-ll SSTVO 6Q0'I 55TVO 5918' A11-01 All KOP 10131NAA Maa NYr 10 Or fr13'In M I Y at 1 SMD tocol lenefa TO•12505 MO .•..- _ 25r7 MD tool c fit` AL1 /. B Shah ^ _! A5 AS -a A4 AL1-01 A TCR is a Tolerable Collision Risk worksheet and is an internal document to ConocoPhillips that calculates financial risk. The text from the document mentions what I did above,there is very little risk of exiting the C sand at all, and in the event that we do exit the C sand we will have a long time in the B shales to get turned back up in the correct direction. There is no greater risk to colliding with 2G-11 than there is with just encountering the A sand while drilling the C sand lateral of 2F-22. 3. Please provide a pad schematic of Doyon Rig 141 on 2F-22 with .9 sketch of the diverter route with approximate lengths. See the attached document entitled Doyon 141 diverter lay out. 4. If the packer is located more than 200' above the production zone then a variance is required. See 20 AAC 25.412(b). Request a variance if this is the case. • The packer is 150'from the intermediate TD (within the C sand)and meets regulations. See drawing below. za s i e - s 7 n Ie n 7 t00? XaZQ-OOd –_ ... Txlwa 11- -A ANW GRILL SITE MEAN .. � IN70/OTIC. r„._ _. 1 r _ F,T A. ._ I B 15.-If I1 '417-11 s E I ter — 4 b t hMY�j I^u .. Ar-I'21. r-s ,04 i!r' •-7. G ..mg 5 ® I o =—— ....— •I M - '-. -' - I x-5111 I11, i• ►_ t 0- _ "'_—__ _ - -__ !t was— �_�iC ,.. iiAAOO a rax 6: • IY♦ I wn�o ..c Q TS'-r u' '''' gi �--- �- - -- -- ------- ------- -- - -- ------------_'1..1 NO MATCH MC. “-- I ISSUED FOR JUN 302014 - . CONSTRUCTION oxiocatiaaps , WI la Nen ._IMAM.01. S PUS wAI I r.o....w...–..0=7 ' ,n.7R, nisei=- .U .—_r...�.. zxxa I.r.., a-Is-21101 .gra _— -__ .. - ", , -� ` '�•rowmaw�RTW i..– • r'..A' e�iV2 ^A ��� �b.1a.tiL S It 1 6. il t_ — 0x.11 _▪ '— .•A,,K D..w z .... t s.. -�K • amara�It.:i"nsi.2-.. •k1. r. I Ferguson. Victoria L (DOA) From: Hunter, Lindsey L <Lindsey.Hunter@conocophillips.com> Sent: Wednesday,October 01, 2014 2:47 PM To: Loepp,Victoria L(DOA) Cc: Tam, Sindy P Subject FW:2F-22(PTD 214-150) Follow Up Flag: Follow up Flag Status: Flagged Victoria, I apologize, I miss-read our completion design for 2F-22 and incorrectly answered your question number 4 below. As it is currently designed the packer is 220'from the open hole. I've cced Sindy Tam,our completion engineer on this email so that you and she can discuss what is needed for a variance. Thanks, Lindsey Lindsey Hunter Drilling Engineer ConocoPhillips Alaska D&W Office - 907-265-6427 Cell - 907-952-3173 lindsey.hunter(cr�conocophi l l ips.com From: Ferguson, Victoria L(DOA) (mailto:victoria.ferguson@)alaska.gov] Sent: Monday, September 29, 2014 2:49 PM To: Hunter, Lindsey L Subject: EXTERNAL 2F-22 PTD 214-150) Lindsey, Please provide: 1. Area of Review which includes review of 2G-11 and 2G-17. See AOR notes below. 2. Anti-collision analysis:What are your plans for 2G-11 while you are drilling 2F-22?Please provide TCR for 2F-22. 3. Please provide a pad schematic of Doyon Rig 141 on 2F-22 with a sketch of the diverter route with approximate lengths. 4. If the packer is located more than 200'above the production zone then a variance is required. See 20 MC 25.412(b). Request a variance if this is the case. Area of Review—infection or Service Wells The construction and abandonment requirements for wells drilled in Alaska are not dependent on whether the well is a producer or injector. However, verification of the adequacy of the construction or abandonment of any well is subject to greater scrutiny if a well is proposed as a service well. This verification process is known as the Area of Review(AOR) and it applies to all wells, whether active or abandoned, that are within %mile radius 1 OVERSIZED DOCUMENT INSERT This file contains one or more oversized documents. These materials may be found in the original hard file or check the parent folder to view it in digital format. TRANSMITTAL LETTER CHECKLIST WELL NAME: I$i.(. PTD: .214-- IS U Development /Service Exploratory Stratigraphic Test Non-Conventional FIELD: 14.1)ca,l`�„1� '`� J r POOL: 14 < ���� J J� �✓i r Or) r - I Check Box for Appropriate Letter/ Paragraphs to be Included in Transmittal Letter CHECK OPTIONS TEXT FOR APPROVAL LETTER MULTI LATERAL The permit is for a new wellbore segment of existing well Permit (If last two digits No. , API No. 50- - - - . in API number are Production should continue to be reported as a function of the original between 60-69) API number stated above. 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 name Pilot Hole ( PH) and API number (50- - - - ) from records, data and logs acquired for well (name on permit). The permit is approved subject to full compliance with 20 AAC 25.055. Approval to produce / inject is contingent upon issuance of a Spacing Exception conservation order approving a spacing exception. (Company Name) Operator assumes the liability of any protest to the spacing exception that may occur. All dry ditch sample sets submitted to the AOGCC must be in no greater Dry Ditch Sample than 30' sample intervals from below the permafrost or from where samples are first caught and 10' sample intervals through target zones. Please note the following special condition of this permit: Production or production testing of coal bed methane is not allowed for Non-Conventional (name of well) until after (Company Name) has designed and Well implemented a water well testing program to provide baseline data on water quality and quantity. (Company Name) must contact the AOGCC to obtain advance approval of such water well testing program. Regulation 20 AAC 25.071(a) authorizes the AOGCC to specify types of well logs to be run. In addition to the well logging program proposed by (Company Name) in the attached application, the following well logs are Well Lo ,n also required for this well: gg g Requirements /der 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 4/2014 FI L To co a 0)' a N W a) o @a) a 3 c O) N N a) °r c J c J p O O Q Z m N n E. o. `O o -2 ui '5 p O : 4 m CK r a) n o v O od o 7 c 6 3 °CD c U ° _c •3 O 3 O - 3' ' ' I C N >N > U n N a) 3, 0 a HI @: C:a00 c: d� n O : �^ p. o N d J O C ' r �: N. d Y @ O > 0 3' O C O I- O d E a' a LO co 2, a ` . Z 1 ac--c p J co a). °_ O 'N y co O. co > U5 0 co c°co '5 o v 0 to n 0 uS v o' a) N . a) Q' N C LOO. .-. 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H w ° 3 as as 0 o °' .ca V E 0 v > _ �, -: y. ° C c� a Lo v c _ Z c V O V 0 f0 O O N O 0 O c 0 0, O, O, f0: -O, w: t tlA Q' E': '3 0 c. 0 -p to O ... a) x 0 0 0 .5 .> a) m n o =0 d o ° v > > 3 C a) ° a) w: w: m a as " a o w J c.) E co Q - - - a) a) a) E E c - 3 c c t, H H F -� ( a°j >- - '' n 0 8 d ° E �, M m C: ' m 0 .c a) a) a) ° v n n a) a) as m - 2 o 0 3: 2' 2' 2 co a, c0 v, .° 'c O' O L, ° 0 a) a), a) a) o, I 0 ----- o (Ti a J 0 co 4_ O O d a 0 S Q d z 0 cn 0 0 0 0 Q Q w 0 m' m 0 5 N' 2 d 0, co,, m; 0,, I v E c-- O r- N M 7 )f) co N. 00 0) O N M V LO CO N- a0 0) O N M to (O N. a0 co I N M V LO (O r aD O) N N N N N N N N Cl N CO CI M M M M !CO CO M CO CO U v v v O c r N w co N w NO C) 0 0 b CNAO O N 0 Ln p y w V V c O cc N•E k J N 'N a> O O O c L_ c O w it UL 0_ Q w 0 Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically organize this category of information. Technical Report Title Date Client: ConocoPhillips Alaska, Inc Field: Kuparuk Rig: Doyon 141 Date: December 28, 2014 Surface Data Logging End of Well Report 2F-22 TABLE OF CONTENTS 1.General Information 2.Daily Summary 3.Days vs. Depth 4.Mud Record 5.Bit Record 6.Morning Reports 7.Survey Report Digital Data to include: Final Log Files Final End of Well Report Final LAS Exports Halliburton Log Viewer EMF Log Viewer GENERAL WELL INFORMATION Company: ConocoPhillips Alaska Rig: Doyon 141 Well: 2F-22 Field: Kuparuk Borough: North Slope Borough State: Alaska Country: United States API Number: 50-029-23530-00-00 Sperry Job Number: AK-AM-0901903291 Job Start Date: 07 December 2014 Spud Date: 05 December 2014 Total Depth: 13470’ MD, 6089’ TVD North Reference: True Declination: 19.05° Dip Angle: 80.87° Total Field Strength: 57567.30 nT Date Of Magnetic Data: 25 November 2014 Wellhead Coordinates N: North 70° 16’ 14.10” Wellhead Coordinates W: West 149° 51’ 44.76“ Drill Floor Elevation 123.55’ Ground Elevation: 95.80’ Permanent Datum: Mean Sea Level SDL Engineers: Douglas Acker, Megan Cardenas Company Representatives: Dave Coates / Andy Lundale SSDS Unit Number: 105 DAILY SUMMARY 12/07/2014 Drilled from 1,425’ MD to 3,347’ MD, SDL arrived on location. 12/08/2014 Drilled from 3,347’ MD to 3,916’ MD and circulated a bottoms up. Back reamed out of the hole before pulling out on the elevators. 12/09/2014 Lay down BHA, clean and service the rig. Drain stack, pick up casing hanger and landing and run in the hole. Land hanger at 3,904’ MD and circulate bottoms up. 12/10/2014 Rig up cement head and pump two plugs of cement. Nipple down diverter and nipple up BOP. 12/11/2014 Install mouse hole, pick up 70 stands of 5” drill pipe from the pipe shed. Rig up MPD unit. Rig up to test BOP’s. 12/12/2014 Tested BOP’s with 5” drill pipe; blew down the choke, choke lines and top drive. Pulled nipple and test MPD manifold. Picked up BHA #3 and singled in the 5” drill pipe. Pressure tested the casing. Tested casing pressure and cleared rig floor. Washed down from 3,690’ MD to 3,782’ MD. 12/13/2014 Continue to wash down from 3782’ MD to 3810’ MD. Drilled out the float and shoe track. Drilled out cement plug and cement. Drilled from 3916’ MD to 3936’ MD. Circulated bottoms up and pulled out to 3,870’ to perform a formation integrity test. Drilled from 3,936’ MD to 5,723’ MD. Gas: The max gas was 528 units at 4371’ MD and the average drilling background gas was 96 units. Fluids: No fluid losses 12/14/2014 Drilled ahead from 5,723’ MD to 5,855’ MD where the well packed off. Back reamed out to 5,780’ MD, re-established circulation and continued drilling to 7048’ MD. Circulated 2 bottoms up and monitored the well. Pulled out of the hole on evaluators from 7047’ MD to 6863’ MD. Gas: The max gas was 405 units at 5919’ MD and the average drilling background gas was 86 units. Fluids: No fluid losses 12/15/2014 Tripped out of the hole from 7048’MD and circulated bottoms up. Continued tripping to 3,875’MD and circulated bottoms up. Pulled the trip nipple, installed MPD bearing, RCD, and tested equipment. Tested the Rhino reamer at the shoe. Tripped in the hole from 3,904’MD to 7,048’MD and opened the reamer. Continue to drill ahead from 7,048’MD to 7,232’MD. Gas: The max gas was 289 units at 7099’ MD and the average drilling background gas was 86 units. Fluids: No fluid losses 12/16/2014 Drilled ahead from 7,232' MD to 8,850' MD. Established lower pump rates and continued to drill from 8,067' MD to 8,850' MD. Gas: The max gas was 135 units at 8181’ MD and the average drilling background gas was 47 units. Fluids: No fluid losses 12/17/2014 Drilled ahead from 8,850' MD to 10,579' MD. Gas: The max gas was 353 units at 10579’ MD and the average drilling background gas was 88 units. Fluids: No fluid losses 12/18/2014 Drilled ahead from 10,579' MD to 11,705' MD and stopping because of a 300psi standpipe pressure loss. Theorized there is a wash out in the drill pipe. Increased mud weight to 9.6ppg. Trip out of the hole to 10,833' MD and found the wash out. . Gas: The max gas was 1281 units at 11666’ MD and the average drilling background gas was 126 units. Fluids: No fluid losses 12/19/2014 Changed out the MPD bearing and tripped in hole from 10,864' MD to 11,705' MD. Established ECD drilling parameters with MPD and drilled from 11,705' MD to 13,007' MD. Gas: The max gas was 5551 units at 11705’ MD and the average drilling background gas was 525 units. Fluids: No fluid losses 12/20/2014 Drilled from 13,007' MD to 13,425' MD and began to circulate because of high gas cut mud. Drill to TD at 13,470' MD, circulate bottom's up and close the reamer. Fingerprint the well for MPD after an unsuccessful attempt. Circulate and rotate, and packed off. Staged up the pumps to and weighted up to 10.2 ppg. Gas: The max gas was 405 units at 10017’ MD and the average drilling background gas was 1401units. Fluids: No fluid losses 12/21/2014 Continue to stage up pumps to 640 GPM. Pumped 30 BBL LCM sweep and weighted up to 10.2ppg. Hole packing off, work pipe up to 13376' MD. Stage up pumps slowly and back ream to 13261' MD. Regained circulation and staged up pumps from 2.5 BPM to 400 GPM. Back reamed stand slowly. Pack off. No success in regaining circulation. Decision made to pull from 13265' MD to 12637' MD; Weight fell off. Increased pull rate from 70 FPH to 200 FPH. Gas: The max gas was 10017 units and the average background gas was 454 units. Fluids: There was 32 barrels loss to the formation 12/22/2014 Continue to pull out of the hole from 12630' MD to 12081' MD. Break Circulation and circulate bottoms up while weighting up the mud to 10.6ppg. Work pipe and stage pumps up to 9.5 BPM. Continue to circulate and clean the hole at 12081' MD. Drain the stack and monitor well. Tripped out of the hole with MPD from 12081' MD to 10080' MD. Packed off. Decision was made to run in the hole to 12300' MD and circulate bottoms up. Shut down pumps and monitor well. Line up MPD. Continue to trip out of the hole with MPD from 12300' MD to 8436' MD Gas: The max gas was 8100 units and the average background gas was 98 units. Fluids: There was 30 barrels loss to the formation 12/23/2014 Continue to trip out of the hole from 8436' MD to 3875' MD. Circulate bottoms up at the surface casing shoe. Staged up pumps to 400GPM while rotating at 60 RPM and monitor well. Continue to trip out of the hole to 787' MD. Racked back heavy weight drill pipe and laid down BHA as per SLB. Slip and cut drill line. Lubricate rig, changed out rams from 3.5" to 7.625" and pulled the wear bushing. Flush stack and blow down the top drive. Rig up to test BOPE. Gas: The max gas was 188 units and the average background gas was 47 units. Fluids: There was 54 barrels loss to the formation 12/24/2014 Tested BOPE's and rigged down test equipment, Blow down choke and kill lines. Pick up casing equipment and Volant tool from slide. Rigged up casing equipment and begin running casing, make up shoe track to 222'. Continue running 7 5/8" 29.7# L-80 Hydril casing from 222' MD at 1500-2000 FPH. Circulate bottoms up at the shoe 3890' MD. Stage pumps up from 2 BPM to 4 BPM. Continue to run 7 5/8" CSG from 3890' MD to 5745' MD. Gas: The max gas was 109 units and the average background gas was 50 units. Fluids: There was 9 barrels loss to the formation 12/25/2014 Continue to run in the hole with 7 5/8" CSG from 5705' MD to 6680' MD. Attempt to break circulation at 5 BPM, stage up to 1 BPM, No Returns. Shut down pumps and continued to run in the hole to 7017' MD. Attempted to establish circulation and could not. Rotate pipe at15 RPM and stage pumps up to 2 BPM, minimal returns. Continue run in the hole from 7017' MD to 12768' MD. Gas: The max gas was 108 units and the average background gas was 27 units. Fluids: There was 777 barrels loss to the formation 3000 4000 5000 6000 7000 8000 9000 10000 11000 12000 13000 14000 15000 0 5 10 15 Me a s u r e d D e p t h Rig Days Prognosed Actual WELL NAME: 2F-22 OPERATOR: ConocoPhillips Alaska, Inc MUD CO: MI Swaco RIG: Doyon 141 SPERRY JOB: AK-XX-0901903291 Days vs. Depth 04 April 2013 Sperry SDL Arrived on Location LOCATION: Kuparuk AREA: North Slope Borough STATE: Alaska SPUD: 11-Dec-2014 TD: 20-Dec-2014 Opened 11" Rhino Reamer @ 7025" 15 Dec 2014 Commenced 9.875" Intermediate Hole Section On Bot: 05:21 13 Dec 2014 Drill 9.875" hole to 7024' TIH to Shoe to Install MPD 15 Dec 2014 TD Intermediate Hole Section 13470' MD, 6089' TVD Off Bot: 13:00 20 Dec 2014 Landed 7.625" Casing 13461' MD, 6087' TVD 26 Dec 2014 2F-22 ConocoPhillips Alaska, Inc MI Swaco Doyon 141 AK-XX-0901903291 Date Depth Wt Vis PV YP Gels Filt R600/R300/R200/R100/ R6/R3 Cake Solids Oil/Water Sd Pm pH MBT Pf/Mf Chlor Hard ft - MD ppg sec lb/100 lb/100ft2 m/30m Rheometer 32nds %%%ppb Eqv mg/l Ca++ 11-Dec 3916 9.40 50 14 10 2/3/4 -38/24/18/11/4/3 -5.5 0/94 -1.50 9.7 15.0 1.70/6.00 600 120 P/U DP / Test BOPs 12-Dec 3916 9.40 52 20 10 9/22/34 -50/30/24/15/6/5 -5.5 0/94 -1.80 10.5 15.0 1.70/6.40 600 120 BOP Test / RIH with BHA 13-Dec 4651 9.20 55 9 28 10/12/15 -46/37/32/26/12/10 1 6.0 2/92-0.10 0.30 9.8 7.5 .20/1.05 500 68 Drill Out, FIT, Drill Ahead 14-Dec 6972 9.30 51 13 19 8/8/9 -45/32/27/21/10/8 1 5.0 3/92-0.10 0.30 9.7 12.5 .20/.95 700 38 Drill Ahead 15-Dec 7048 9.30 53 11 23 8/9/10 -45/34/28/22/10/8 1 6.0 3/92-0.10 0.18 9.6 12.5 .17/.87 410 42 Short Trip, Drill Ahead 16-Dec 8648 9.20 54 14 30 11/15/20 -58/44/36/28/12/11 1 7.0 3/90-0.10 0.24 9.9 22.5 .19/1.08 470 40 Drill Ahead 17-Dec 10441 9.30 51 12 26 11/13/17 -50/38/31/24/11/10 1 6.3 4/90-0.15 0.11 9.7 22.5 .80/1.10 500 58 Drill Ahead 18-Dec 11705 9.60 54 11 24 11/13/15 -46/35/31/25/12/11 1 6.3 4/90-0.15 0.15 9.7 20.0 .20/.90 510 45 POOH and Circulate 19-Dec 13007 9.70 44 12 19 9/11/14 -43/31/27/22/10/9 1/1 7.0 4/89-0.10 0.15 9.6 22.5 .18/1.70 450 88 Change MPD bearing 20-Dec 13470 9.90 44 11 23 9/12/14 -45/34/30/24/10/9 1 8.0 4/88-0.10 0.12 9.6 22.0 .18/1.50 550 72 TD Intermediate Section 21-Dec 13470 10.60 44 120 28 10/12/15 -50/39/33/26/11/9 1 11.5 4/85-0.10 0.12 9.8 21.3 .10/1.30 520 64 BROOH/TIH 22-Dec 13470 10.70 49 14 31 11/14/20 2.6 59/45/38/30/12/10 1 12.0 4/84-0.10 0.10 9.7 23.8 .12/1.20 530 84 BROOH/TIH 23-Dec 13470 10.70 51 13 27 11/13/16 2.6 53/40/34/28/12/10 1/-13.3 4/83-0.10 0.28 10.0 22.0 .25/1.95 600 80 BROOH/TIH, test BOP 24-Dec 13470 10.70 57 13 29 11/14/15 2.6 55/42/35/22/12/11 1/-12.3 4/84-0.10 0.28 9.9 20.8 .24/1.80 600 50 Test BOP, RIH w/ casing 25-Dec 13470 10.70 56 10 27 12/14/15 2.7 47/37/32/26/13/12 1/-12.3 4/84-0.10 0.30 9.9 20.8 .24/1.85 600 52 RIH w/ casing Casing Record Remarks 10.75" Casing @ 3905' MD, 2973'TVD 7.625" Casing @ 13461' MD, 6087' TVD WELL NAME:LOCATION:Kuparuk OPERATOR:AREA:North Slope Borough MUD CO:STATE:Alaska RIG:SPUD:11-Dec-2014 SPERRY JOB:TD:20-Dec-2014 W a t e r a n d O i l B a s e d M u d R e c o r d BHA#SDL RUN #Bit #Bit Type Bit Size Depth In Depth Out Footage Bit Hours TFA AVG ROP WOB (max) RPM (max) SPP (max) FLOW GPM (max)Bit Grade Comments #3 100 #2 HAL FX65 PDC 9.875 3916 13470 9554 90.20 1.131 106.0 20 160 3800 625 0-1-WT-G-X-In-N/A-TD Intermediate Section WELL NAME:2F-22 LOCATION:Kuparuk OPERATOR:ConocoPhillips Alaska, Inc AREA:North Slope Borough MUD CO: SPERRY JOB:AK-XX-0901903291 TD:20-Dec-2014 MI Swaco STATE:Alaska RIG:Doyon 141 SPUD:11-Dec-2014 B i t R e c o r d . . * 24 hr Recap: (max)(current) 0 0 Cly 0 Set AtSize 45.5# Grade 10.75'' 907-670-4906Unit Phone: 0 Megan Cardenas Maximum Report By:Logging Engineers:D. Acker / M. Cardenas 0 0 Units* Casing Summary Lithology (%) 0 MBT pH 0.000 0 0 0 Siltst SPP (psi) Gallons/stroke TFABit Type Depth 15.050 C-5nC-2 in Minimum Depth Time: 3916' 3916' 0' Max @ ft Current Date: Avg to Yesterday's Depth: Current Depth: 24 Hour Progress: Flow In (gpm) Flow In (spm) Gas Summary 0 0 0 (current) Coates / Lundale ShClyst TuffGvlCoal cP 14 3662' Footage 34.20 Ss (ppb Eq) C-1 C-5i AK-AM-0901903291 Testing BOP's PV 24 hr Max Weight 0 Hours C-3 00 CementChtSilt C-4i C-4n YP (lb/100ft2) 9.70 000 50.0 DRILPLEX NC3916'10 Depth in / out Mud Type Lst Type Average Background (max)Trip Avg Min Comments RPM ECD (ppg) ml/30min Tools API FL Chromatograph (ppm) 5 to 38K254' 3916' WOB Casing 100% Gas In Air=10,000 UnitsConnection 0 There is no gas to report at this time. 3916' ConditionBit # 1 13.5 9.40 Baker BHI VM-3 9.40 Size Job No.: Daily Charges: Total Charges: MWD Summary 96% Rig Activity: Doyon 141 Report For: Morning Report Report # 1 Customer: Well: Area: Location: Rig: 2F-22 ConocoPhillips Alaska, Inc. North Slope AK Kuparuk ROP ROP (ft/hr) 4.23 @ Mud Data Depth 11-Dec-2014 12:00 AM Current Pump & Flow Data: Max 0 Chlorides mg/l Rig up MPD, service rig and inspect derrick, rig up and test BOP. Density (ppg) out (sec/qt) Viscosity Cor Solids % . . * 24 hr Recap: (max)(current) 0 0 Cly 0 Set AtSize 45.5# Grade 10.75'' 907-670-4906Unit Phone: 0 Megan Cardenas Maximum Report By:Logging Engineers:D. Acker / M. Cardenas 0 0 Units* Casing Summary Lithology (%) 0 MBT pH 0.000 0 0 0 Siltst SPP (psi) Gallons/stroke TFABit Type Depth 15.050 C-5nC-2 in Minimum Depth Time: test, slip and cut the drilling line. Begin drilling cement to 3,785' MD 3916' 3916' 0' Max @ ft Current Date: Avg to Yesterday's Depth: Current Depth: 24 Hour Progress: Flow In (gpm) Flow In (spm) Gas Summary 0 0 0 (current) Coates / Lundale ShClyst TuffGvlCoal cP 14 3662' 9.875 1.131 Footage 34.20 Ss (ppb Eq) C-1 C-5i AK-AM-0901903291 Drilling Out Cement PV 24 hr Max Weight 0 Hours C-3 00 CementCht Silt C-4i C-4n YP (lb/100ft2) 9.70 000 50.0 FX65 PDC Bit DRILPLEX NC 3916' 3916'10 Depth in / out Mud Type Lst Type Average Background (max) Trip Avg Min Comments RPM ECD (ppg) ml/30min Tools API FL Chromatograph (ppm) 5 to 38K254' 3916' WOB Casing 100% Gas In Air=10,000 UnitsConnection 0 2 There is no gas to report at this time. 3916' ConditionBit # 1 13.5 9.40 Baker BHI VM-3 9.40 Size Job No.: Daily Charges: Total Charges: MWD Summary 96% Rig Activity: Doyon 141 Report For: Morning Report Report # 2 Customer: Well: Area: Location: Rig: 2F-22 ConocoPhillips Alaska, Inc. North Slope AK Kuparuk ROP ROP (ft/hr) 4.23 @ Mud Data Depth 12-Dec-2014 12:00 AM Current Pump & Flow Data: Max 0 Chlorides mg/l Complete BOPE testing and test the MPD manifold. Pick up BHA and begin tripping in the hole. After the casing Density (ppg) out (sec/qt) Viscosity Cor Solids % . . * 24 hr Recap: (max)(current) 248 0 Cly 22094 Set AtSize 45.5# Grade 10.75'' 907-670-4906Unit Phone: 14 Megan Cardenas Maximum Report By:Logging Engineers:D. Acker / M. Cardenas 15532 121 694 164 Units* Casing Summary Lithology (%) 37 MBT 5737' pH 0.000 0 18 0 Siltst SPP (psi) Gallons/stroke TFABit Type Depth 7.555 C-5n 4371' 185.9 C-2 528 in 0 4167'Minimum Depth Time: and POOH to 3,870' MD. Performed FIT and displaced the well. Drilled from 3,936'MD to 5,723' MD. Drilling ahead at the time of report. 144 3916' 5723' 1807' Max @ ft Current 4555'118.4 Date: Avg to3916' Yesterday's Depth: Current Depth: 24 Hour Progress: 332.8 Flow In (gpm) Flow In (spm) Gas Summary 0 22 12 (current) Coates / Lundale ShClyst TuffGvlCoal cP 9 3662' 9.875 1.131 Footage 34.20 Ss (ppb Eq) C-1 C-5i AK-AM-0901903291 Drilling Ahead PV 24 hr Max Weight 359 Hours C-3 00 CementChtSilt C-4i C-4n YP (lb/100ft2) 9.80 394939 50.0 FX65 PDC Bit LSND 5.5 3916' 4651'28 Depth in / out Mud Type Lst Type Average 96Background (max)Trip Avg Min Comments RPM ECD (ppg) ml/30min Tools GR / Res / Den / Neu / PWD API FL Chromatograph (ppm) 5 to 38K254' 3916' WOB Casing 100% Gas In Air=10,000 UnitsConnection 58 2 Max gas is 528 units. 3916' ConditionBit # 1 6.0 13.5 9.20 Baker BHI VM-3 9.20 Size Job No.: Daily Charges: Total Charges: MWD Summary 96% Rig Activity: Doyon 141 Report For: Morning Report Report # 3 Customer: Well: Area: Location: Rig: 2F-22 ConocoPhillips Alaska, Inc. North Slope AK Kuparuk ROP ROP (ft/hr) 4.23 @ Mud Data Depth 13-Dec-2014 12:00 AM Current Pump & Flow Data: 2435 Max 92 Chlorides mg/l 500.00 Drilled out cement plugs and cement, then from surface section TD at 3,916' MD to 3,936' MD. Circulated a bottoms up, Density (ppg) out (sec/qt) Viscosity Cor Solids % . . * 24 hr Recap:Drilled from 5,723' MD to 5,931' MD when the hole packed off. Back reamed to 5,841' MD before continuing to 7,048' MD. Density (ppg) out (sec/qt) Viscosity Cor Solids % Chlorides mg/l 700.00 9 14-Dec-2014 12:00 AM Current Pump & Flow Data: 0 Max ROP ROP (ft/hr) 4.23 @ Mud Data Depth Morning Report Report # 4 Customer: Well: Area: Location: Rig: 2F-22 ConocoPhillips Alaska, Inc. North Slope AK Kuparuk Job No.: Daily Charges: Total Charges: MWD Summary 96% Rig Activity: Doyon 141 Report For: ConditionBit # 1 5.0 13.5 9.30 Baker BHI VM-3 9.25 Size 2 Max Gas was 405 bbls 3916' 100% Gas In Air=10,000 UnitsConnection 55 Tools GR / Res / Den / Neu / PWD API FL Chromatograph (ppm) 5 to 38K254' 3916' WOB Casing 10.34 Avg Min Comments RPM ECD (ppg) ml/30min 86Background (max)Trip Average Mud Type Lst Type 50.0 FX65 PDC Bit LSND 5.3 3916' 6972'19 Depth in / out YP (lb/100ft2) 9.70 230 00 CementChtSilt C-4i C-4n 24 hr Max Weight 92 Hours C-3 Ss (ppb Eq) C-1 C-5i AK-AM-0901903291 Short Trip PV 3662' 9.875 1.131 Footage 34.20 Coates / Lundale ShClyst TuffGvlCoal cP 13 Gas Summary 0 16 14 (current) Avg to3916' Yesterday's Depth: Current Depth: 24 Hour Progress: 309.1 Flow In (gpm) Flow In (spm) 5723' 7048' 1325' Max @ ft Current 6396'55.9 Date: Time: Stopped circulating to check flow. Well was static, preparing to POOH on elevators. 67 in 2 6810'Minimum Depth C-5n 5919' 0.0 C-2 405 SPP (psi) Gallons/stroke TFABit Type Depth 12.551 MBT 7048' pH 0.000 0 14 0 Siltst 0 0 Units* Casing Summary Lithology (%) 38453 58 907-670-4906Unit Phone: 14 Megan Cardenas Maximum Report By:Logging Engineers:D. Acker / M. Cardenas Set AtSize 45.5# Grade 10.75'' (max)(current) 424 0 Cly 31825 . . * 24 hr Recap: (max)(current) 70 0 Cly 6343 Set AtSize 45.5# Grade 10.75'' 907-670-4906Unit Phone: 6 Megan Cardenas Maximum Report By:Logging Engineers:D. Acker / M. Cardenas 4147 51 91 84 Units* Casing Summary Lithology (%) 4 MBT 7232' pH 0.000 0 4 0 Siltst SPP (psi) Gallons/stroke TFABit Type Depth 12.553 C-5n 7099' 98.0 C-2 289 in 15 7098'Minimum Depth Time: bottoms up. Pull trip nipple and install MPD bearing, RCD and test equipment. Pull test rhino reamer at the shoe. Trip in the hole from 44 Max Trip Gas was 817 units 7048' 7232' 184' Max @ ft Current 7065'8.6 Date: Avg to3916' Yesterday's Depth: Current Depth: 24 Hour Progress: 142.0 Flow In (gpm) Flow In (spm) Gas Summary 0 6 0 (current) Coates / Lundale ShClyst TuffGvlCoal cP 11 3662' 9.875 1.131 Footage 34.20 Ss (ppb Eq) C-1 C-5i AK-AM-0901903291 Drilling Ahead PV 24 hr Max Weight 54 Hours C-3 00 CementChtSilt C-4i C-4n YP (lb/100ft2) 9.60 050 50.0 FX65 PDC Bit LSND 4.9 3916' 7048'23 Depth in / out Mud Type Lst Type Average 81755Background (max)Trip 10.34 Avg Min Comments RPM ECD (ppg) ml/30min Tools GR / Res / Den / Neu / PWD API FL Chromatograph (ppm) 5 to 38K254' 3916' WOB Casing 100% Gas In Air=10,000 UnitsConnection 12 2 Max Formation Gas was 289 units 3,904' MD to 7,048' and open reamer. Currently drilling ahead at the time of the report. 3916' ConditionBit # 1 6.0 13.5 9.30 Baker BHI VM-3 9.25 Size Job No.: Daily Charges: Total Charges: MWD Summary 96% Rig Activity: Doyon 141 Report For: Morning Report Report # 5 Customer: Well: Area: Location: Rig: 2F-22 ConocoPhillips Alaska, Inc. North Slope AK Kuparuk ROP ROP (ft/hr) 4.23 @ Mud Data Depth 15-Dec-2014 12:00 AM Current Pump & Flow Data: 2568 Max 9 Chlorides mg/l 410.00 Trip out of hole from 7,048' MD to 4,624' MD and circulated a bottoms up. Continue tripping to 3,875' MD and circulate Density (ppg) out (sec/qt) Viscosity Cor Solids % . . * 24 hr Recap: (max)(current) 243 0 Cly 14849 Set AtSize 45.5# Grade 10.75'' 907-670-4906Unit Phone: 0 Megan Cardenas Maximum Report By:Logging Engineers:D. Acker / M. Cardenas 5198 40 176 744 Units* Casing Summary Lithology (%) 3 MBT 8850' pH 0.000 0 5 0 Siltst SPP (psi) Gallons/stroke TFABit Type Depth 22.554 C-5n 8181' 96.3 C-2 135 in 2 8046'Minimum Depth Time: 8,850' MD. Drilling ahead at time of the report. 47 7232' 8850' 1618' Max @ ft Current 7874'73.6 Date: Avg to3916' Yesterday's Depth: Current Depth: 24 Hour Progress: 193.4 Flow In (gpm) Flow In (spm) Gas Summary 0 4 0 (current) Coates / Lundale ShClyst TuffGvlCoal cP 14 3662' 9.875 1.131 Footage 34.20 Ss (ppb Eq) C-1 C-5i AK-AM-0901903291 Drilling Ahead PV 24 hr Max Weight 128 Hours C-3 00 CementChtSilt C-4i C-4n YP (lb/100ft2) 9.90 020 50.0 FX65 PDC Bit LSND 5.1 3916' 8648'30 Depth in / out Mud Type Lst Type Average 45Background (max)Trip 10.0910.42 Avg Min Comments RPM ECD (ppg) ml/30min Tools GR / Res / PWD API FL Chromatograph (ppm) 5 to 38K254' 3916' WOB Casing 100% Gas In Air=10,000 UnitsConnection 23 2 Max Gas was 135 units. 3916' ConditionBit # 1 7.0 13.5 9.25 Baker BHI VM-3 9.20 Size Job No.: Daily Charges: Total Charges: MWD Summary 96% Rig Activity: 11.28 Doyon 141 Report For: Morning Report Report # 6 Customer: Well: Area: Location: Rig: 2F-22 ConocoPhillips Alaska, Inc. North Slope AK Kuparuk ROP ROP (ft/hr) 4.23 @ Mud Data Depth 16-Dec-2014 12:00 AM Current Pump & Flow Data: 2793 Max 17 Chlorides mg/l 470.00 Drilled ahead from 7,232' MD to 8,067' MD before establishing lower pump rates. Continued drilling from 8,067' MD to Density (ppg) out (sec/qt) Viscosity Cor Solids % . . * 24 hr Recap:Continued drilling ahead from 8,850' MD to 10,579' MD. Density (ppg) out (sec/qt) Viscosity Cor Solids % Chlorides mg/l 500.00 334 17-Dec-2014 12:00 AM Current Pump & Flow Data: 3044 Max ROP ROP (ft/hr) 4.23 @ Mud Data Depth Morning Report Report # 7 Customer: Well: Area: Location: Rig: 2F-22 ConocoPhillips Alaska, Inc. North Slope AK Kuparuk Job No.: Daily Charges: Total Charges: MWD Summary 96% Rig Activity: 10.95 Doyon 141 Report For: ConditionBit # 1 6.3 13.5 9.30 Baker BHI VM-3 9.25 Size 2 Max gas was 353 units 3916' 100% Gas In Air=10,000 UnitsConnection 330 Tools GR / Res / PWD API FL Chromatograph (ppm) 5 to 38K254' 3916' WOB Casing 10.1710.34 Avg Min Comments RPM ECD (ppg) ml/30min 136Background (max)Trip Average Mud Type Lst Type 50.0 FX65 PDC Bit LSND 5.0 3916' 10579'26 Depth in / out YP (lb/100ft2) 9.70 2610722 02 CementChtSilt C-4i C-4n 24 hr Max Weight 676 Hours C-3 Ss (ppb Eq) C-1 C-5i AK-AM-0901903291 Drilling Ahead PV 3662' 9.875 1.131 Footage 34.20 Coates / Lundale ShClyst TuffGvlCoal cP 12 Gas Summary 0 45 9 (current) Avg to3916' Yesterday's Depth: Current Depth: 24 Hour Progress: 172.1 Flow In (gpm) Flow In (spm) 8850' 10579' 1729' Max @ ft Current 10018'89.1 Date: Time: 88 in 19 9011'Minimum Depth C-5n 9747' 108.1 C-2 353 SPP (psi) Gallons/stroke TFABit Type Depth 22.551 MBT 10579' pH 0.000 15 34 3 Siltst 175 740 Units* Casing Summary Lithology (%) 407332 2173 907-670-4906Unit Phone: 8 Megan Cardenas Maximum Report By:Logging Engineers:D. Acker / M. Cardenas Set AtSize 45.5# Grade 10.75'' (max)(current) 1128 68 Cly 17692 . . * 24 hr Recap:Drilled from 10,579' MD to 11,708' MD then stopped drilling because of standpipe pressure loss. Theorized there is a Density (ppg) out (sec/qt) Viscosity Cor Solids % Chlorides mg/l 510.00 344 18-Dec-2014 12:00 AM Current Pump & Flow Data: 2717 Max ROP ROP (ft/hr) 4.23 @ Mud Data Depth Morning Report Report # 8 Customer: Well: Area: Location: Rig: 2F-22 ConocoPhillips Alaska, Inc. North Slope AK Kuparuk Job No.: Daily Charges: Total Charges: MWD Summary 96% Rig Activity: 10.80 Doyon 141 Report For: ConditionBit # 1 6.3 13.5 9.60 Baker BHI VM-3 9.60 Size 2 of the report. 3916' 100% Gas In Air=10,000 UnitsConnection 4012 Tools GR / Res / PWD API FL Chromatograph (ppm) 5 to 38K254' 3916' WOB Casing 10.1510.34 Avg Min Comments RPM ECD (ppg) ml/30min 26Background (max)Trip Average Mud Type Lst Type 50.0 FX65 PDC Bit LSND 4.1 3916' 11705'24 Depth in / out YP (lb/100ft2) 9.70 299727 3693 CementChtSilt C-4i C-4n 24 hr Max Weight 912 Hours C-3 Ss (ppb Eq) C-1 C-5i AK-AM-0901903291 Circulating PV 3662' 9.875 1.131 Footage 34.20 Coates / Lundale ShClyst TuffGvlCoal cP 11 Gas Summary 28 772 167 (current) Avg to3916' Yesterday's Depth: Current Depth: 24 Hour Progress: 176.7 Flow In (gpm) Flow In (spm) 10579' 11705' 1126' Max @ ft Current 11537'84.5 Date: Time: wash out in the drill pipe, weight up mud to 9.6 ppg. Trip out of the hole to 10,833' MD and found the wash out. Circulating at the time 126 Max Gas was 1,281 units in 32 10870'Minimum Depth C-5n 11666' 0.0 C-2 1281 SPP (psi) Gallons/stroke TFABit Type Depth 20.054 MBT 11705' pH 0.000 149 449 29 Siltst 151 639 Units* Casing Summary Lithology (%) 4711342 1328 907-670-4906Unit Phone: 144 Megan Cardenas Maximum Report By:Logging Engineers:D. Acker / M. Cardenas Set AtSize 45.5# Grade 10.75'' (max)(current) 11139 172 Cly 116352 . . * 24 hr Recap:Changed out MPD bearing, tripped in hole from 10,864' MD to 11,705' MD and established ECD drilling parameters with Density (ppg) out (sec/qt) Viscosity Cor Solids % Chlorides mg/l 450.00 1020 19-Dec-2014 12:00 AM Current Pump & Flow Data: 3516 Max ROP ROP (ft/hr) 4.23 @ Mud Data Depth Morning Report Report # 9 Customer: Well: Area: Location: Rig: 2F-22 ConocoPhillips Alaska, Inc. North Slope AK Kuparuk Job No.: Daily Charges: Total Charges: MWD Summary 96% Rig Activity: 11.06 Doyon 141 Report For: ConditionBit # 1 7.0 13.5 9.70 Baker BHI VM-3 9.65 Size 2 Max Formation Gas was 5,551 units 3916' 100% Gas In Air=10,000 UnitsConnection 10964 Tools GR / Res / PWD API FL Chromatograph (ppm) 5 to 38K254' 3916' WOB Casing 10.4310.60 Avg Min Comments RPM ECD (ppg) ml/30min 549Background (max)Trip Average Mud Type Lst Type 50.0 FX65 PDC Bit LSND 3.6 3916' 12867'19 Depth in / out YP (lb/100ft2) 9.60 8432583 052 CementChtSilt C-4i C-4n 24 hr Max Weight 2586 Hours C-3 Ss (ppb Eq) C-1 C-5i AK-AM-0901903291 Drilling Ahead PV 3662' 9.875 1.131 Footage 34.20 Coates / Lundale ShClyst TuffGvlCoal cP 12 Gas Summary 17 1913 379 (current) Avg to3916' Yesterday's Depth: Current Depth: 24 Hour Progress: 167.0 Flow In (gpm) Flow In (spm) 11705' 13007' 1302' Max @ ft Current 122263'111.9 Date: Time: MPD. Drilled from 11,705' MD to 13,007' MD. Drilling ahead at the time of the report 525 in 40 11704'Minimum Depth C-5n 11935' 112.4 C-2 5551 SPP (psi) Gallons/stroke TFABit Type Depth 22.544 MBT 13007' pH 0.000 119 1123 22 Siltst 171 723 Units* Casing Summary Lithology (%) 12127876 2285 907-670-4906Unit Phone: 323 Megan Cardenas Maximum Report By:Logging Engineers:D. Acker / M. Cardenas Set AtSize 45.5# Grade 10.75'' (max)(current) 32040 191 Cly 385543 . . * 24 hr Recap: (max)(current) 98729 715 Cly 473926 Set AtSize 45.5# Grade 10.75'' 907-670-4906Unit Phone: 1982 Megan Cardenas Maximum Report By:Logging Engineers:D. Acker / M. Cardenas 123963 7015 149 630 Units* Casing Summary Lithology (%) 295 MBT 13470' pH 0.000 438 4022 69 Siltst SPP (psi) Gallons/stroke TFABit Type Depth 22.044 C-5n 13386' - C-2 10017 in 113 13262'Minimum Depth Time: circulate bottom's up and close reamer. Fingerprint well for MPD after an unsuccessful attempt. Circulate and rotate, and packed off. 1401 Max Gas was 10,017 units at 13,425' MD, at 15:30, 19:00 and 23:02. 13007' 13470' 463' Max @ ft Current 122263'17.0 Date: Avg to3916' Yesterday's Depth: Current Depth: 24 Hour Progress: 345.8 Flow In (gpm) Flow In (spm) Gas Summary 63 8949 1892 (current) Coates / Lundale ShClyst TuffGvlCoal cP 11 3662' 9.875 1.131 Footage 34.20 Ss (ppb Eq) C-1 C-5i AK-AM-0901903291 Circulating PV 24 hr Max Weight 7738 Hours C-3 64198 CementChtSilt C-4i C-4n YP (lb/100ft2) 9.60 134639151 50.0 FX65 PDC Bit LSND 3.4 3916' 13470'23 Depth in / out Mud Type Lst Type Average 1345Background (max)Trip 10.4610.62 Avg Min Comments RPM ECD (ppg) ml/30min Tools GR / Res / PWD API FL Chromatograph (ppm) 5 to 38K254' 3916' WOB Casing 100% Gas In Air=10,000 Units4892Connection 41257 2 Stage up pumps to drilling rate and weight up to 10.2 ppg. 3916' ConditionBit # 1 8.0 13.5 9.90 Baker BHI VM-3 9.90 Size Job No.: Daily Charges: Total Charges: MWD Summary 96% Rig Activity: 10.72 Doyon 141 Report For: Morning Report Report # 10 Customer: Well: Area: Location: Rig: 2F-22 ConocoPhillips Alaska, Inc. North Slope AK Kuparuk ROP ROP (ft/hr) 4.23 @ Mud Data Depth 20-Dec-2014 12:00 AM Current Pump & Flow Data: 3074 Max 2653 Chlorides mg/l 550.00 Drilled from 13,007' MD to 13,425' MD and began to circculate because of gas cut mud. Drill to TD aat 13,470' MD, Density (ppg) out (sec/qt) Viscosity Cor Solids % . . * 24 hr Recap:Pump 30 bbls LCM sweep, weight up to 10.2 ppg. Packed off, worked pipe up to 13,376' MD. Slowly stage up pumps Density (ppg) out (sec/qt) Viscosity Cor Solids % Chlorides mg/l 520.00 7448 21-Dec-2014 12:00 AM Current Pump & Flow Data: 107 Max ROP ROP (ft/hr) 4.23 @ Mud Data Depth Morning Report Report # 11 Customer: Well: Area: Location: Rig: 2F-22 ConocoPhillips Alaska, Inc. North Slope AK Kuparuk Job No.: Daily Charges: Total Charges: MWD Summary 96% Rig Activity: Doyon 141 Report For: ConditionBit # 1 11.5 13.5 10.35 Baker BHI VM-3 10.60 Size 2 fell from 280 klb to 220 klb. Increased pull rate to 200 fph. pumps to 400 gpm and back ream stand slowly. No success regaining circulation. Pulled from 13,265' MD to 12,637' MD and hookload 3916' 100% Gas In Air=10,000 UnitsConnection 30994.2 Tools GR / Res / PWD API FL Chromatograph (ppm) 5 to 38K254' 3916' WOB Casing Avg Min Comments RPM ECD (ppg) ml/30min 454Background (max)Trip Average Mud Type Lst Type 50.0 FX65 PDC Bit LSND 3.0 3916' 13470'28 Depth in / out YP (lb/100ft2) 9.80 135535791168 00 CementChtSilt C-4i C-4n 24 hr Max Weight 8044 Hours C-3 Ss (ppb Eq) C-1 C-5i AK-AM-0901903291 $3,475.00 $58,775.00 Circulating PV 3662' 9.875 1.131 Footage 34.20 Coates / Lundale ShClyst TuffGvlCoal cP 11 Gas Summary 0 7757 1961 (current) Avg to3916' Yesterday's Depth: Current Depth: 24 Hour Progress: - Flow In (gpm) Flow In (spm) 13470' 13470' 0' Max @ ft Current -- Date: Time: and BROOH to 13,261' MD Continue to BROOH and packed off again. Re-establish circulation, Stage up pumps to 3 bpm. Stage up 1131 Max gas was 10,016 units seen at 12:51, 13:02 and 14:25. in 3 -Minimum Depth C-5n - - C-2 10016 SPP (psi) Gallons/stroke TFABit Type Depth 21.344 MBT 13470' pH 0.000 0 3448 0 Siltst 13 3 Units* Casing Summary Lithology (%) 128237070 19 907-670-4906Unit Phone: 2079 Megan Cardenas Maximum Report By:Logging Engineers:D. Acker / M. Cardenas Set AtSize 45.5# Grade 10.75'' (max)(current) 80022.7 0 Cly 832662 . . * 24 hr Recap: (max)(current) 53046 0 Cly 421029 Set AtSize 45.5# Grade 10.75'' 907-670-4906Unit Phone: 1946 Megan Cardenas Maximum Report By:Logging Engineers:D. Acker / M. Cardenas 10982 14 309 73 Units* Casing Summary Lithology (%) 1086 MBT 13470' pH 0.000 0 3242 0 Siltst SPP (psi) Gallons/stroke TFABit Type Depth 23.849 C-5n - - C-2 8100 in 1 -Minimum Depth Time: pumps, continue to circulate and clean the hole. Monitor the well and ready to trip out of the hole w/ MPD. POOH to 10,080' MD and 599 13470' 13470' 0' Max @ ft Current -- Date: Avg to3916' Yesterday's Depth: Current Depth: 24 Hour Progress: - Flow In (gpm) Flow In (spm) Gas Summary 0 7453 1871 (current) Coates / Lundale ShClyst TuffGvlCoal cP 14 3662' 9.875 1.131 Footage 34.20 Ss (ppb Eq) C-1 C-5i AK-AM-0901903291 Circulating PV 24 hr Max Weight 3040 Hours C-3 00 CementChtSilt C-4i C-4n YP (lb/100ft2) 9.70 115330311028 50.0 FX65 PDC Bit LSND 2.6 3916' 13470'31 Depth in / out Mud Type Lst Type Average 810098Background (max)Trip Avg Min Comments RPM ECD (ppg) ml/30min Tools GR / Res / PWD API FL Chromatograph (ppm) 5 to 38K254' 3916' WOB Casing 100% Gas In Air=10,000 UnitsConnection 25620 2 Packed off, ran in to 12,300' MD and circulate bottom's up. Line up MPD and continue to trip out w/ MPD to 8,436' MD. 3916' ConditionBit # 1 12.0 13.5 10.70 Baker BHI VM-3 10.70 Size Job No.: Daily Charges: Total Charges: MWD Summary 96% Rig Activity: Doyon 141 Report For: Morning Report Report # 12 Customer: Well: Area: Location: Rig: 2F-22 ConocoPhillips Alaska, Inc. North Slope AK Kuparuk ROP ROP (ft/hr) 4.23 @ Mud Data Depth 22-Dec-2014 12:00 AM Current Pump & Flow Data: 469 Max 4763 Chlorides mg/l 530.00 Pumps on as pulling out of the hole 12,630' MD to 12,081' MD. Weight up to 10.6 ppg and work pipe. Slowly work up Density (ppg) out (sec/qt) Viscosity Cor Solids % . . * 24 hr Recap:Trip out of the hole from 8,436' MD to 787' MD. Remove the RCD element and install trip nipple. Rack back HWDP, lay Density (ppg) out (sec/qt) Viscosity Cor Solids % Chlorides mg/l 600.00 88 23-Dec-2014 12:00 AM Current Pump & Flow Data: - Max ROP ROP (ft/hr) 4.23 @ Mud Data Depth Morning Report Report # 13 Customer: Well: Area: Location: Rig: 2F-22 ConocoPhillips Alaska, Inc. North Slope AK Kuparuk Job No.: Daily Charges: Total Charges: MWD Summary 96% Rig Activity: Doyon 141 Report For: ConditionBit # 1 13.3 13.5 10.70 Baker BHI VM-3 10.70 Size 2 Max Gas was 188 units 3916' 100% Gas In Air=10,000 UnitsConnection 1056 Tools GR / Res / PWD API FL Chromatograph (ppm) 5 to 38K254' 3916' WOB Casing Avg Min Comments RPM ECD (ppg) ml/30min -Background (max)Trip Average 188 Mud Type Lst Type 50.0 FX65 PDC Bit LSND 2.6 3916' 13470'27 Depth in / out YP (lb/100ft2) 10.00 12316394 00 CementChtSilt C-4i C-4n 24 hr Max Weight 15 Hours C-3 Ss (ppb Eq) C-1 C-5i AK-AM-0901903291 Testing BOPE PV 3662' 9.875 1.131 Footage 34.20 Wall / Lundale ShClyst TuffGvlCoal cP 13 Gas Summary 0 913 365 (current) Avg to3916' Yesterday's Depth: Current Depth: 24 Hour Progress: - Flow In (gpm) Flow In (spm) 13470' 13470' 0' Max @ ft Current -- Date: Time: down BHA, and slip and cut drill line. Pull wear bushing, flush stack and break down top drive. Rig up to test BOPE. 47 in 0 -Minimum Depth C-5n - - C-2 188 SPP (psi) Gallons/stroke TFABit Type Depth 22.051 MBT 13470' pH 0.000 0 306 0 Siltst - - Units* Casing Summary Lithology (%) 4625 0 907-670-4906Unit Phone: 419 Megan Cardenas Maximum Report By:Logging Engineers:D. Acker / M. Cardenas Set AtSize 45.5# Grade 10.75'' (max)(current) 624 0 Cly 4468 . . * 24 hr Recap:Test BOPE. Rig down BOP testing equipment. Rig up to begin casing run with hangar. Pick up 7 5/8" 29.7# casing and Density (ppg) out (sec/qt) Viscosity Cor Solids % Chlorides mg/l 600.00 118 24-Dec-2014 12:00 AM Current Pump & Flow Data: 0 Max ROP ROP (ft/hr) 4.23 @ Mud Data Depth Morning Report Report # 14 Customer: Well: Area: Location: Rig: 2F-22 ConocoPhillips Alaska, Inc. North Slope AK Kuparuk Job No.: Daily Charges: Total Charges: MWD Summary 96% Rig Activity: - Doyon 141 Report For: ConditionBit # 1 12.3 13.5 10.70 Baker BHI VM-3 10.70 Size 2 Max Gas was 109 units. 3916' 100% Gas In Air=10,000 UnitsConnection 63 Tools GR / Res / PWD API FL Chromatograph (ppm) 5 to 38K254' 3916' WOB Casing -- Avg Min Comments RPM ECD (ppg) ml/30min 40Background (max)Trip Average Mud Type Lst Type 50.0 FX65 PDC Bit LSND 2.6 3916' 13470'29 Depth in / out YP (lb/100ft2) 9.90 139187111 7175 CementChtSilt C-4i C-4n 24 hr Max Weight 40 Hours C-3 Ss (ppb Eq) C-1 C-5i AK-AM-0901903291 RIH w/ Casing PV 3662' 9.875 1.131 Footage 34.20 Wall / Finkbiner ShClyst TuffGvlCoal cP 13 Gas Summary 52 107 69 (current) Avg to3916' Yesterday's Depth: Current Depth: 24 Hour Progress: - Flow In (gpm) Flow In (spm) 13470' 13470' 0' Max @ ft Current -- Date: Time: run in hole to 5,745' MD. 50 in 32 -Minimum Depth C-5n - - C-2 109 SPP (psi) Gallons/stroke TFABit Type Depth 20.857 MBT 13470' pH 0.000 39 29 20 Siltst 0 0 Units* Casing Summary Lithology (%) 52167 169 907-670-4906Unit Phone: 93 Megan Cardenas Maximum Report By:Logging Engineers:D. Acker / M. Cardenas Set AtSize 45.5# Grade 10.75'' (max)(current) 27 15 Cly 353 . . * 24 hr Recap:Continue to run in the hole with 7 5/8" casing from 5,705' MD to 6,680' MD and started taking losses. Attempt to regain Density (ppg) out (sec/qt) Viscosity Cor Solids % Chlorides mg/l 600.00 27 25-Dec-2014 12:00 AM Current Pump & Flow Data: 0 Max ROP ROP (ft/hr) 4.23 @ Mud Data Depth Morning Report Report # 15 Customer: Well: Area: Location: Rig: 2F-22 ConocoPhillips Alaska, Inc. North Slope AK Kuparuk Job No.: Daily Charges: Total Charges: MWD Summary 96% Rig Activity: - Doyon 141 Report For: ConditionBit # 1 12.3 13.5 10.70 Baker BHI VM-3 10.70 Size 2 to run in hole to 12,768' MD. 3916' 100% Gas In Air=10,000 UnitsConnection 191 Tools GR / Res / PWD API FL Chromatograph (ppm) 5 to 38K254' 3916' WOB Casing -- Avg Min Comments RPM ECD (ppg) ml/30min 14Background (max)Trip Average 108 Mud Type Lst Type 50.0 FX65 PDC Bit LSND 2.7 3916' 13470'27 Depth in / out YP (lb/100ft2) 9.90 464932 7175 CementChtSilt C-4i C-4n 24 hr Max Weight 13 Hours C-3 Ss (ppb Eq) C-1 C-5i AK-AM-0901903291 RIH w/ Casing PV 3662' 9.875 1.131 Footage 34.20 Wall / Finkbiner ShClyst TuffGvlCoal cP 10 Gas Summary 52 175 91 (current) Avg to3916' Yesterday's Depth: Current Depth: 24 Hour Progress: - Flow In (gpm) Flow In (spm) 13470' 13470' 0' Max @ ft Current -- Date: Time: circulation while running in to 7,017' MD with no returns. Reciprocate pipe, stage up pumps and rotate - got minimal returns. Continue 27 Max Gas was 108 units. Total losses to formation was 777 bbls in 14 -Minimum Depth C-5n - - C-2 108 SPP (psi) Gallons/stroke TFABit Type Depth 20.856 MBT 13470' pH 0.000 39 61 20 Siltst 0 0 Units* Casing Summary Lithology (%) 13248 169 907-670-4906Unit Phone: 109 Megan Cardenas Maximum Report By:Logging Engineers:D. Acker / M. Cardenas Set AtSize 45.5# Grade 10.75'' (max)(current) 219 15 Cly 8236 . . * 24 hr Recap: (max)(current) Casing 14 0 Cly 302 Set AtSize 45.5# Grade 10.75'' 907-670-4906Unit Phone: 27 Megan Cardenas Maximum Report By:Logging Engineers:D. Acker / M. Cardenas 15 0 7.63'' 169 40 Units* Casing Summary Lithology (%) 0 MBT 13470' pH 0.000 0 8 0 Siltst SPP (psi) Gallons/stroke TFABit Type Depth 5.058 C-5n - - C-2 40 in 0 -Minimum Depth Time: times, no to minimal returns at surface. Made up cement head which leaked, fixed leak and began first stage of cementing. 17 Total losses for day was 841 bbls 13470' 13470' 0' Max @ ft Current -- Date: Avg to3916' Yesterday's Depth: Current Depth: 24 Hour Progress: - Flow In (gpm) Flow In (spm) Gas Summary 0 27 17 (current) Wall / Finkbiner ShClyst TuffGvlCoal cP 11 3662' 9.875 1.131 Footage 9554' 34.20 Ss (ppb Eq) C-1 C-5i AK-AM-0901903291 Cementing PV 24 hr Max 29.7# Weight 0 Hours C-3 00 CementChtSilt C-4i C-4n YP (lb/100ft2) 9.80 1170 160 50.0 FX65 PDC Bit LSND 3.5 3916' 13470'28 13470' Depth in / out Mud Type Lst Type Average 4011Background (max)Trip -- Avg Min Comments RPM ECD (ppg) ml/30min Tools GR / Res / PWD API FL Chromatograph (ppm) 20 5 to 38K254' 3916' WOB Casing 100% Gas In Air=10,000 UnitsConnection 19 2 Max Gas was 40 units. 13470' 3916' ConditionBit # 1 11.3 13.5 10.70 Baker BHI VM-3 10.70 Size Job No.: Daily Charges: Total Charges: MWD Summary 96% Rig Activity: - Doyon 141 Report For: Morning Report Report # 16 Customer: Well: Area: Location: Rig: 2F-22 ConocoPhillips Alaska, Inc. North Slope AK Kuparuk ROP ROP (ft/hr) 4.23 @ Mud Data Depth 26-Dec-2014 12:00 AM Current Pump & Flow Data: 1134 Max 3 Chlorides mg/l 600.00 Continue running casing from 12,768' MD and landed casing at 13,462' MD. Attempted to circulate but packed off multiple Density (ppg) out (sec/qt) Viscosity Cor Solids % WELL INFORMATION Created On : Jan 16 2015 Customer :ConocoPhillips Alaska, Inc Well Name :2F-22 Job Number :AK-XX-0901903291 Rig Name :Doyon 141 Field Name :Kuparuk Country :USA Survey Report SURVEY HEADER Survey data provided by Schlumberger. DIRECTIONAL SURVEY DATA Tie-in 0.00 0.00 0.00 0.00 0.00 N 0.00 E (ft) Measured Depth DoglegVertical SectionDeparture (ft) Latitude (ft) Vertical Depth (deg) DirectionInclination (deg)(ft)(ft)(°/100') 79.61 0.23 265.47 79.61 0.01 S 0.16 W -0.01 0.29 182.45 0.46 217.97 182.45 0.35 S 0.62 W -0.35 0.34 265.72 0.37 214.18 265.72 0.84 S 0.98 W -0.84 0.11 357.72 0.69 240.40 357.71 1.36 S 1.62 W -1.36 0.43 453.67 1.58 247.75 453.64 2.15 S 3.35 W -2.15 0.94 546.40 2.34 260.25 546.32 2.95 S 6.40 W -2.95 0.94 638.12 3.11 264.69 637.93 3.50 S 10.72 W -3.50 0.87 731.57 5.74 266.92 731.10 3.98 S 17.91 W -3.98 2.82 826.60 9.95 264.08 825.22 5.09 S 30.83 W -5.09 4.45 915.27 12.72 260.69 912.15 7.46 S 48.09 W -7.46 3.21 1008.41 14.15 262.44 1,002.74 10.61 S 69.49 W -10.61 1.60 1063.31 16.97 260.70 1,055.62 12.79 S 84.06 W -12.79 5.21 1122.73 20.05 258.68 1,111.96 16.19 S 102.61 W -16.19 5.29 1158.10 21.73 257.16 1,145.01 18.84 S 114.94 W -18.84 4.99 1207.34 22.32 256.15 1,190.65 23.10 S 132.90 W -23.10 1.42 1251.53 22.96 255.34 1,231.44 27.29 S 149.39 W -27.29 1.61 1346.03 21.90 254.44 1,318.79 36.68 S 184.20 W -36.68 1.18 1439.88 21.48 253.71 1,405.99 46.20 S 217.55 W -46.20 0.53 1531.81 23.47 247.64 1,490.95 57.89 S 250.65 W -57.89 3.32 1628.24 26.31 241.06 1,578.43 75.54 S 287.12 W -75.54 4.11 1720.45 28.11 239.22 1,660.43 96.55 S 323.67 W -96.55 2.15 1816.96 28.19 238.07 1,745.53 120.24 S 362.55 W -120.24 0.57 1913.45 30.73 235.12 1,829.54 146.40 S 402.13 W -146.40 3.03 2008.67 32.06 231.04 1,910.82 176.20 S 441.74 W -176.20 2.63 2100.43 35.23 225.62 1,987.22 210.04 S 479.61 W -210.04 4.76 2195.13 38.35 225.07 2,063.05 249.91 S 519.94 W -249.91 3.31 2289.34 41.58 222.06 2,135.25 293.77 S 561.59 W -293.77 3.99 2383.00 43.50 221.18 2,204.26 341.12 S 603.64 W -341.12 2.15 2468.98 45.03 217.26 2,265.84 387.61 S 641.55 W -387.61 3.65 2564.60 46.45 215.40 2,332.58 442.78 S 682.11 W -442.78 2.04 INSITE V8.1.10 Page 1Job No:AK-XX-0901903291 Well Name:2F-22 Survey Report DIRECTIONAL SURVEY DATA (ft) Measured Depth DoglegVertical SectionDeparture (ft) Latitude (ft) Vertical Depth (deg) DirectionInclination (deg)(ft)(ft)(°/100') 2657.20 49.07 211.56 2,394.84 499.96 S 719.87 W -499.96 4.17 2748.49 52.56 207.08 2,452.52 561.65 S 754.44 W -561.65 5.39 2819.51 53.91 204.63 2,495.03 612.85 S 779.23 W -612.85 3.35 2842.45 53.97 204.33 2,508.54 629.72 S 786.92 W -629.72 1.09 2934.83 55.11 203.25 2,562.13 698.58 S 817.26 W -698.58 1.56 3027.00 57.68 201.85 2,613.14 769.47 S 846.69 W -769.47 3.06 3120.12 60.71 199.71 2,660.83 844.24 S 875.04 W -844.24 3.81 3212.18 61.25 199.23 2,705.49 920.14 S 901.87 W -920.14 0.74 3305.12 63.03 197.79 2,748.92 998.05 S 927.94 W -998.05 2.35 3396.84 65.11 196.46 2,789.03 1,076.88 S 952.22 W -1076.88 2.62 3491.62 67.26 194.77 2,827.30 1,160.38 S 975.55 W -1160.38 2.79 3585.58 68.57 192.07 2,862.63 1,245.06 S 995.74 W -1245.06 3.01 3679.77 70.33 190.19 2,895.69 1,331.59 S 1,012.76 W -1331.59 2.64 3770.69 70.13 188.59 2,926.45 1,416.00 S 1,026.72 W -1416.00 1.67 3836.66 71.73 189.53 2,948.00 1,477.57 S 1,036.54 W -1477.57 2.77 3935.28 71.31 188.19 2,979.26 1,569.99 S 1,050.94 W -1569.99 1.36 3999.54 72.33 187.79 2,999.31 1,630.44 S 1,059.43 W -1630.44 1.69 4091.35 71.16 188.56 3,028.07 1,716.75 S 1,071.83 W -1716.75 1.50 4183.94 71.33 188.24 3,057.84 1,803.48 S 1,084.63 W -1803.48 0.38 4279.19 70.61 188.55 3,088.90 1,892.56 S 1,097.78 W -1892.56 0.82 4372.49 70.69 188.84 3,119.81 1,979.58 S 1,111.09 W -1979.58 0.31 4464.41 70.72 189.07 3,150.19 2,065.27 S 1,124.59 W -2065.27 0.24 4560.77 70.56 190.28 3,182.13 2,154.89 S 1,139.87 W -2154.89 1.20 4655.31 70.45 190.56 3,213.68 2,242.54 S 1,155.99 W -2242.54 0.30 4747.57 70.44 190.85 3,244.56 2,327.97 S 1,172.14 W -2327.97 0.30 4840.10 70.51 190.77 3,275.49 2,413.63 S 1,188.49 W -2413.63 0.11 4933.29 70.54 190.87 3,306.56 2,499.92 S 1,204.99 W -2499.92 0.11 5026.96 70.47 190.67 3,337.82 2,586.67 S 1,221.49 W -2586.67 0.21 5122.63 70.36 190.89 3,369.89 2,675.21 S 1,238.34 W -2675.21 0.25 5214.46 70.29 190.83 3,400.80 2,760.13 S 1,254.64 W -2760.13 0.10 5310.61 70.49 190.51 3,433.07 2,849.14 S 1,271.41 W -2849.14 0.38 5404.73 70.99 190.29 3,464.12 2,936.53 S 1,287.44 W -2936.53 0.58 5497.45 70.99 190.90 3,494.32 3,022.70 S 1,303.56 W -3022.70 0.62 5589.44 71.02 190.71 3,524.26 3,108.14 S 1,319.87 W -3108.14 0.20 5683.39 70.93 190.90 3,554.89 3,195.38 S 1,336.52 W -3195.38 0.21 5775.45 70.99 190.24 3,584.92 3,280.93 S 1,352.48 W -3280.93 0.68 5870.15 71.05 188.82 3,615.72 3,369.24 S 1,367.31 W -3369.24 1.42 5962.92 70.93 188.61 3,645.94 3,455.94 S 1,380.60 W -3455.94 0.25 6055.51 70.65 188.68 3,676.41 3,542.38 S 1,393.74 W -3542.38 0.31 6148.00 70.69 189.06 3,707.02 3,628.61 S 1,407.20 W -3628.61 0.39 6240.11 70.57 189.23 3,737.57 3,714.40 S 1,421.01 W -3714.40 0.22 6333.12 70.50 189.18 3,768.56 3,800.97 S 1,435.04 W -3800.97 0.09 6427.37 70.56 189.21 3,799.98 3,888.69 S 1,449.24 W -3888.69 0.07 6520.58 70.56 190.04 3,831.00 3,975.35 S 1,463.93 W -3975.35 0.84 6612.63 70.57 189.93 3,861.63 4,060.84 S 1,478.98 W -4060.84 0.11 INSITE V8.1.10 Page 2Job No:AK-XX-0901903291 Well Name:2F-22 Survey Report DIRECTIONAL SURVEY DATA (ft) Measured Depth DoglegVertical SectionDeparture (ft) Latitude (ft) Vertical Depth (deg) DirectionInclination (deg)(ft)(ft)(°/100') 6706.10 70.45 190.10 3,892.82 4,147.61 S 1,494.31 W -4147.61 0.21 6799.85 70.57 188.99 3,924.10 4,234.76 S 1,508.96 W -4234.76 1.12 6892.41 70.50 188.51 3,954.94 4,321.01 S 1,522.24 W -4321.01 0.49 6985.30 70.44 188.50 3,985.99 4,407.60 S 1,535.18 W -4407.60 0.07 7077.37 70.82 188.77 4,016.53 4,493.47 S 1,548.23 W -4493.47 0.50 7169.13 70.37 188.93 4,047.02 4,578.99 S 1,561.54 W -4578.99 0.52 7263.54 70.35 188.35 4,078.75 4,666.90 S 1,574.90 W -4666.90 0.58 7356.21 70.39 189.04 4,109.88 4,753.18 S 1,588.09 W -4753.18 0.70 7448.46 70.41 189.81 4,140.83 4,838.91 S 1,602.32 W -4838.91 0.79 7541.64 70.78 189.65 4,171.79 4,925.53 S 1,617.18 W -4925.53 0.43 7636.07 70.81 190.67 4,202.85 5,013.30 S 1,632.91 W -5013.30 1.02 7727.50 70.77 191.44 4,232.93 5,098.04 S 1,649.46 W -5098.04 0.80 7820.25 70.84 191.33 4,263.43 5,183.91 S 1,666.75 W -5183.91 0.14 7912.41 70.78 191.61 4,293.72 5,269.21 S 1,684.06 W -5269.21 0.29 8004.59 70.80 190.69 4,324.05 5,354.61 S 1,700.89 W -5354.61 0.94 8096.10 70.83 191.37 4,354.12 5,439.44 S 1,717.43 W -5439.44 0.70 8189.06 70.90 191.29 4,384.60 5,525.56 S 1,734.68 W -5525.56 0.11 8281.88 70.90 190.28 4,414.97 5,611.72 S 1,751.10 W -5611.72 1.03 8374.58 70.81 189.07 4,445.37 5,698.04 S 1,765.81 W -5698.04 1.24 8466.97 70.86 188.19 4,475.70 5,784.32 S 1,778.91 W -5784.32 0.90 8559.31 70.87 188.38 4,505.97 5,870.65 S 1,791.48 W -5870.65 0.19 8652.06 70.81 189.09 4,536.41 5,957.25 S 1,804.78 W -5957.25 0.73 8744.62 70.47 190.04 4,567.10 6,043.36 S 1,819.29 W -6043.36 1.04 8838.16 70.33 190.41 4,598.48 6,130.08 S 1,834.94 W -6130.08 0.40 8932.02 70.29 190.41 4,630.10 6,216.99 S 1,850.90 W -6216.99 0.04 9025.77 70.29 189.77 4,661.72 6,303.89 S 1,866.37 W -6303.89 0.64 9121.23 70.33 188.99 4,693.88 6,392.56 S 1,881.01 W -6392.56 0.77 9214.67 70.31 188.35 4,725.35 6,479.54 S 1,894.28 W -6479.54 0.65 9309.79 70.82 187.66 4,757.00 6,568.36 S 1,906.77 W -6568.36 0.87 9402.57 70.84 188.17 4,787.47 6,655.16 S 1,918.83 W -6655.16 0.52 9494.53 70.81 188.25 4,817.67 6,741.13 S 1,931.24 W -6741.13 0.09 9587.51 70.78 189.15 4,848.26 6,827.92 S 1,944.52 W -6827.92 0.91 9679.82 70.87 190.54 4,878.58 6,913.83 S 1,959.43 W -6913.83 1.43 9772.05 70.81 190.61 4,908.85 6,999.47 S 1,975.42 W -6999.47 0.10 9865.73 70.83 194.51 4,939.64 7,085.81 S 1,994.65 W -7085.81 3.93 9958.53 70.84 190.02 4,970.12 7,171.44 S 2,013.27 W -7171.44 4.57 10052.49 70.86 189.12 5,000.94 7,258.96 S 2,028.02 W -7258.96 0.91 10144.74 70.87 188.76 5,031.18 7,345.06 S 2,041.57 W -7345.06 0.37 10238.14 70.87 188.36 5,061.79 7,432.32 S 2,054.70 W -7432.32 0.40 10330.92 70.87 188.66 5,092.19 7,519.01 S 2,067.67 W -7519.01 0.31 10422.53 70.92 188.65 5,122.18 7,604.59 S 2,080.70 W -7604.59 0.06 10516.36 70.34 188.18 5,153.30 7,692.15 S 2,093.65 W -7692.15 0.78 10611.60 70.29 187.70 5,185.38 7,780.97 S 2,106.04 W -7780.97 0.48 10706.55 70.48 188.05 5,217.25 7,869.56 S 2,118.30 W -7869.56 0.40 10799.05 70.39 188.57 5,248.23 7,955.81 S 2,130.89 W -7955.81 0.54 INSITE V8.1.10 Page 3Job No:AK-XX-0901903291 Well Name:2F-22 Survey Report DIRECTIONAL SURVEY DATA (ft) Measured Depth DoglegVertical SectionDeparture (ft) Latitude (ft) Vertical Depth (deg) DirectionInclination (deg)(ft)(ft)(°/100') 10892.96 70.38 190.33 5,279.76 8,043.06 S 2,145.42 W -8043.06 1.77 10987.14 70.41 190.46 5,311.36 8,130.33 S 2,161.42 W -8130.33 0.13 11081.74 70.50 190.28 5,343.01 8,218.02 S 2,177.47 W -8218.02 0.20 11179.28 70.87 189.73 5,375.27 8,308.67 S 2,193.46 W -8308.67 0.65 11274.31 70.90 189.95 5,406.39 8,397.14 S 2,208.81 W -8397.14 0.22 11366.07 70.93 190.06 5,436.39 8,482.54 S 2,223.87 W -8482.54 0.12 11459.77 70.96 190.36 5,466.98 8,569.70 S 2,239.57 W -8569.70 0.30 11550.97 70.97 191.07 5,496.73 8,654.41 S 2,255.60 W -8654.41 0.74 11642.21 70.69 191.31 5,526.69 8,738.95 S 2,272.33 W -8738.95 0.39 11737.09 70.88 190.82 5,557.91 8,826.88 S 2,289.52 W -8826.88 0.53 11828.79 70.82 190.09 5,588.00 8,912.06 S 2,305.24 W -8912.06 0.75 11921.83 70.37 190.23 5,618.91 8,998.44 S 2,320.72 W -8998.44 0.50 12014.20 70.39 190.23 5,649.92 9,084.07 S 2,336.17 W -9084.07 0.02 12106.02 70.32 189.17 5,680.79 9,169.30 S 2,350.74 W -9169.30 1.09 12198.75 70.33 188.59 5,712.01 9,255.57 S 2,364.22 W -9255.57 0.59 12292.53 70.38 188.29 5,743.54 9,342.94 S 2,377.18 W -9342.94 0.31 12384.91 70.58 188.48 5,774.41 9,429.08 S 2,389.88 W -9429.08 0.29 12477.20 70.72 188.79 5,804.99 9,515.17 S 2,402.95 W -9515.17 0.35 12569.97 70.78 188.89 5,835.57 9,601.71 S 2,416.41 W -9601.71 0.12 12662.67 70.81 189.09 5,866.07 9,688.18 S 2,430.09 W -9688.18 0.21 12756.47 70.84 189.80 5,896.88 9,775.57 S 2,444.63 W -9775.57 0.72 12850.93 70.77 189.68 5,927.93 9,863.49 S 2,459.72 W -9863.49 0.14 12943.65 70.82 189.88 5,958.43 9,949.78 S 2,474.60 W -9949.78 0.21 13034.79 70.72 190.36 5,988.45 10,034.50 S 2,489.72 W -10034.50 0.51 13128.21 72.65 190.90 6,017.81 10,121.66 S 2,506.08 W -10121.66 2.14 13219.99 75.91 191.19 6,042.67 10,208.36 S 2,523.00 W -10208.36 3.56 13313.52 78.72 191.41 6,063.21 10,297.82 S 2,540.88 W -10297.82 3.01 13406.12 81.01 191.62 6,079.50 10,387.14 S 2,559.08 W -10387.14 2.48 DIRECTIONAL SURVEY DATA NOTES - Calculation based on minimum curvature method. - Survey coordinates relative to well system reference point. - TVD values given relative to drilling measurement point. - Vertical section relative to well head. - Vertical section is computed along a direction of 0.00 degrees (Grid) - A total correction of 0.00 deg from Magnetic north to Grid north has been applied - Horizontal displacement is relative to the well head. - Horizontal displacement (closure) at 13,406.12 feet is 10,697.73 feet along 193.84 degrees (Grid) INSITE V8.1.10 Page 4Job No:AK-XX-0901903291 Well Name:2F-22 Survey Report WARRANTY HALLIBURTON ENERGY SERVICES, INC. WILL USE ITS BEST EFFORTS TO FURNISH CUSTOMERS WITH ACCURATE INFORMATION AND INTERPRETATIONS THAT ARE PART OF, AND INCIDENT TO, THE SERVICES PROVIDED. HOWEVER, HALLIBURTON ENERGY SERVICES, INC. CANNOT AND DOES NOT WARRANT THE ACCURACY OR CORRECTNESS OF SUCH INFORMATION AND INTERPRETATIONS. UNDER NO CIRCUMSTANCES SHOULD ANY SUCH INFORMATION OR INTERPRETATION BE RELIED UPON AS THE SOLE BASIS FOR ANY DRILLING, COMPLETION, PRODUCTION, OR FINANCIAL DECISION OR ANY PROCEDURE INVOLVING ANY RISK TO THE SAFETY OF ANY DRILLING VENTURE, DRILLING RIG OR ITS CREW OR ANY THIRD PARTY. THE CUSTOMER HAS FULL RESPONSIBILITY FOR ALL DRILLING, COMPLETION, AND PRODUCTION OPERATION. HALLIBURTON ENERGY SERVICES, INC. MAKES NO REPRESENTATIONS OR WARRANTIES, EITHER EXPRESSED OR IMPLIED, INCLUDING, BUT NOT LIMITED TO, THE IMPLIED WARRANTIES OF MERCHANTABILITY OR FITNESS FOR A PARTICULAR PURPOSE, WITH RESPECT TO THE SERVICES RENDERED. IN NO EVENT WILL HALLIBURTON ENERGY SERVICES, INC. SERVICES BE LIABLE FOR FAILURE TO OBTAIN ANY PARTICULAR RESULTS OR FOR ANY DAMAGES, INCLUDING, BUT NOT LIMITED TO, INDIRECT, SPECIAL OR CONSEQUENTIAL DAMAGES, RESULTING FROM THE USE OF ANY INFORMATION OR INTERPRETATION PROVIDED BY HALLIBURTON ENERGY SERVICES, INC. INSITE V8.1.10 Page 5Job No:AK-XX-0901903291 Well Name:2F-22 Survey Report
