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C rp U y O oa .v2 a) c o E o T• E aU -Qda 3 °a a 5 0 <X I 0 0 v�- OO\ k`S Schlumberger Transmittal#: 6824 Drilling& Measurements MWD/LWD Log Product Delivery DATA LOGGED 4,14/.6/2014 M K BENDER Customer: Brooks Range Petroleum Corp. Dispatched To: Makana Bender Well No: North Tarn 1 Date Dispatched: 2-Apr-14 Job#: 11AKA0032 Dispatched By: Stephanie Pacillo Well/ Product Hardcopy Digital Copy E-Delivery Date Color Log Prints: 4 Vision Service 2"MD 1 each Contents on CD Vision Service 2"TVD 1 each Contents on CD Vision Service 5"MD 1 each Contents on CD Vision Service 5"TVD 1 each Contents on CD LAS Digital Data Contents on CD SURVEYS 1 Contents on CD FINAL SURVEY 1 each EOW CD 1 CD RECEIVED APR 02 2014 AOGCC Please sign and email/fax a copy to: Please sign and email/fax a copy to: Irose(a�brpcak.com spacilloslb.com Stephanie Pacillo Laurette Rose Fax:907-561-8317 Fax:907-339-9961 Received By: Zkl-off t -2._L- k. 5 RECEIVED APR 0 2 2014 AOGCC Brooks Rai Corporation Schlumberger North Tarn 1 Survey Report (Def Survey) Report Date: April 5,2011 Survey I OLS Computation: Minimum Curvature/Lubinski Client: Brooks Range Petroleum Vertical Section Azimuth: 223.110°(True North) Field: Tam Vertical Section Origin: 0.000 R.0.000 R Structure/Slot: North Tam 1/North Tam 1 TVD Reference Datum: Rotary Table Well: North Tam 1 TVD Reference Elevation: 97.8008 above MSL Borehole: North Tam l Seabed/Ground Elevation: 69.3008 above MSL APR: 501032063300 Magnetic Declination: 20.930° Survey Name: North Tam 1 Total Field Strength: 57605.697 nT Survey Date: March 22 2011 Magnetic Dip Angle: 80.781• Tort/AHD/DDI/ERO Ratio: 29.823.1929.8258/4.448/0.151 Declination Date: March14.2011 Coordinate Reference System: NAD27 Alaska State Plane.Zone 04,US Feet Magnetic Declination Model: BOOM 2010 Location Let/Long: N 70°14 57.10245,W 150°10 52.18253" North Reference: True North Location Grid N/E Tot: N 5940773.00011116 E 465198.000 8US Grid Convergence Used: -0.265° CRS Grid Convergence Angle: -0.26462166° Total Corr Mag North.vTrue North: 20.930° Grid Scale Factor: 0.99990138 Local Coord Referenced To: Well Head ' Comments MD Incl Asir True TVDSS TVD VSEC AHD Closure NS BIN DLS Northing Beating Latitude Longitude IM rt Ph IM MI 181 IRI IS) MI 1111 riigg81 MUM MIND 11 r1 RTE 0.00 0.00 0.00 -97.80 0.00 0.00 0.00 0.00 0.00 0.00 N/A 5940773.00 465198.00 70.24919512 -150.28116181 ' WRP 28.50 0.00 0.00 -69.30 28.50 0.00 0.00 0.00 0.00 0.00 0.00 5940773.00 465198.00 70.24919512 -150.28116181 100.00 0.27 215.51 2.20 100.00 0.17 0.17 0.17 -0.14 -0.10 0.38 5940772.86 465197.90 7024919475 -150.28116260 200.00 0.65 215.51 102.20 200.00 0.96 0.97 0.97 -0.79 -0.58 0.38 5940772.21 465197.43 70.24919298 -150.28116837 21091 0.69 215.51 113.11 210.91 1.09 1.10 1.10 -0.89 -0.64 0.38 5940772.11 465197.36 70.24919268 -150.28116897 300.00 0.82 214.03 202.19 299.99 2.25 2.28 2.28 -1.88 -1.31 0.15 5940771.14 465196.68 70.24919004 -150.28117238 303.65 0.83 213.98 205.84 303.64 2.31 2.33 2.33 -1.91 -1.34 0.15 5940771.10 465196.65 70.24918992 -150.28117282 39565 1.01 219.67 297.83 395.63 3.77 3.80 3.80 -3.08 -223 0.22 5940769.93 485195.76 70.24918670 -150.28117981 400.00 1.08 220.81 302.17 399.97 3.85 3.86 3.88 3.14 -2.28 1.66 5940769.87 485195.71 70.24918654 -15028118022 489.08 2.53 23020 391.21 489.01 6.64 6.68 6.65 5.04 -4.34 1.66 5940767.98 465193.64 70.24918137 -15028119685 500.00 2.63 230.21 402.12 499.92 7.13 7.17 7.13 5.35 4.72 093 5940787.67 465193.28 70.24915051 -15028119991 581.38 3.39 23028 483.38 581.18 11.37 11.46 11.37 -8.08 -8.00 0.93 5940764.95 465189.96 70.24917304 -150.28122645 600.00 3.73 228.39 501.97 599.77 12.52 1261 12.53 -8.83 5.89 1.85 5940764.21 465189.07 70.24917100 -150.28123359 673.38 5.08 227.04 575.13 672.93 18.13 18.24 18.16 -12.60 -13.08 1.85 5940760.46 465184.87 70.24916071 -150.28128744 700.00 5.59 227.11 601.63 699.43 20.60 20.72 20.63 -14.28 -14.89 1.90 5940758.79 465183.05 70.24915610 -150.28128207 764.79 8.82 227.24 666.04 763.84 27.58 27.72 27.63 -19.04 -20.02 1.90 5940754.05 465177.89 70.24914310 -150.28132358 800.00 7.31 227.08 700.99 798.79 31.91 32.05 31.96 -21.99 -23.20 1.40 5940751.12 465174.70 70.24913506 -150.28134921 860.78 8.16 226.85 76121 859.01 40.07 40.23 40.14 -27.57 -29.18 1.40 5940745.57 465168.70 70.24911980 -150.28139751 900.00 8.48 227.21 800.02 897.82 45.73 45.90 45.82 -31.44 -33.33 0.82 5940741.72 465164.53 70.24910924 -150.28143105 956.34 8.93 227.69 855.71 953.51 54.23 54.43 54.34 -372) -39.61 0.62 5940735.99 485158.22 70.24909349 -150.28148179 1000.00 8.94 227.92 898.84 996.64 60.98 61.21 81.12 41.76 44.64 0.09 5940731.45 465153.18 70.24808105 -150.28152238 105224 8.96 228.20 950.45 1048.25 69.09 69.34 69.25 47.19 50.68 009 5940726.05 465147.11 70.24906620 -150.28157122 1100.00 9.01 226.80 997.62 1095.42 76.52 76.80 76.71 -52.23 56.18 0.47 5940721.04 465141.58 70.24905244 -150.28161564 1146.31 9.06 225.46 1043.35 1141.15 83.78 84.07 83.98 57.27 -61,42 0.47 5940718.02 465136.32 70.24903887 -150.28165798 1200.00 9.05 225.22 1096.38 1194.16 92.23 92.52 92.43 53.21 -67.43 0,07 5940710.11 465130.28 70.24902244 -150.28170854 1243.25 9.05 225.02 1139.09 1236.89 99.03 99.32 99.23 38.01 -72.26 0.07 5940705.33 465125.44 70.24900932 -150.28174549 1300.00 8.96 225.42 119514 1292.94 107.91 108.21 108.11 -74.27 -78.56 0.19 5940899.10 465119.11 70.24899223 -150.28179642 1339.13 8.90 225.70 1233.79 1331.59 113.98 114.28 114.18 -78.52 -82.90 0.19 5940694.87 465114.75 70.24898061 -15028183145 1400.00 9.31 225.91 1293.90 1391.70 123.60 123.92 123.82 -06.24 39.81 0.68 594068819 465107.81 70.24896226 -15028188725 1433.09 9.54 226.01 1326.54 1424.34 129.01 129.34 129.24 -09.00 -93.70 0.68 5940684.44 465103.90 70.24895197 -15028191673 1500.00 9.57 225.91 1392.52 1490.32 140.11 140.45 140.34 -96.73 -101.69 0.06 5940676.75 465095.88 70.24893087 -150.28198323 1529.83 9.59 225.86 1421.93 1519.73 145.07 145.41 145.31 -100.18 -105.25 0.06 5940673.31 465092.30 70.24892142 -150.28201203 1600.00 9.67 226.69 1491.11 1588.91 156.79 157.15 157.05 -108,30 -113.74 0.23 5940665.24 465083.78 70.24889926 -150.28208056 1625.18 9.70 226.99 1515.94 1613.74 161.02 181.39 16126 -111.19 -116.83 023 5940662.36 465080.67 70.24889134 -150.28210552 1700.00 9.80 222.53 1589.66 1687.48 173.67 174.05 173,94 -120.19 -125.74 1.02 594065341 46507172 70.24886678 -150.28217752 ' 1721.60 9.84 221.26 1610.96 1708.76 177.38 177.73 177.61 -122.93 -128.20 1.02 5940650.68 465069.25 7024885929 -150.28219739 1800.00 9.73 220.94 1688.22 178892 190.67 191.06 190.89 -132.97 -136.96 0.16 5940640.66 46506044 70.24883186 -150.28226813 1817.84 9.70 220.87 1705.80 1803.60 193.68 194.07 193.86 -135.24 -138.93 0.16 5940638.41 465058.46 70.24882565 -15028228406 1900.00 9.62 221.75 1786.80 1884.60 207.46 207.85 207.63 -145.60 -148.03 0.20 5940628.10 485049.32 70.24879735 -150.28235758 Drilling Office 2.0.930.0 Tamworth Tam 1 Worth Tam 1Worth Tam 1 Worth Tam 1 3/31/2014 4:34 PM Page 1 of 3 CommentsMD Mel Mtn True 7V0SS ND 88E0 MD Closure NS EW DL8 Northing Easting Latitude Longitude O8 C1 71 151 181 111 111 IM 00 1111 M10011 11US1 I1US1 CI CI 191253 9.61 221.89 1799.15 1896.95 209.55 209.95 209.72 -147.16 -149.42 0.20 5940626.55 465047.91 70.24879309 -150.28236885 2000.00 9.44 223.34 1885.42 1983.22 224.02 224.42 224.18 -157.81 -15922 0.34 5940615.94 485038.07 70.24876399 -150.28244798 2009.00 9.42 223.49 1894.30 1992.10 225.49 225.89 225.65 -158.88 -160.23 0.34 5940614.88 485037.05 70.24876107 -15028245617 2100.00 9.16 222.57 198410 2087.90 240.18 240.58 240.33 -169.62 -170.28 0.33 5940604.19 485026.98 70.24873174 -15028253713 2105.70 9.14 222.51 1989.73 2087.53 241.09 241.49 241.23 -170.28 -170.87 0.33 5940603.52 465026.36 70.24872992 -150.28254208 2200.00 10.50 222.92 208260 2180.40 257.41 257.81 257.54 -182.27 -181.95 1.78 5940591.59 465015.23 70.24869716 -150.28263155 2200.81 10.81 222.92 2083.40 2181.20 257.56 25796 257.89 -182.38 -182.05 1.76 5940591.48 485015.13 70.24869686 -150.28283238 2285.89 10.84 223.11 2166.96 2264.76 273.54 273.94 273.66 -194.07 -192.95 0.05 5940579.85 465004.18 70.24866494 -150.28272043 2300.00 10.83 223.03 2180.82 2278.62 276.19 276.59 276.31 -196.00 -194.78 0.15 5940577.92 465002.36 70.24865964 -150.28273508 9531 Cog 2347.00 10.78 222.75 2226.99 2324.79 285.00 285.40 285.12 -202.46 -200.76 0.15 5940571.49 464996.33 70.24884202 -150.28278348 2400.00 10.72 222.44 2279.06 2376.86 294.88 295.28 29499 -209.73 -207.44 0.15 5940564.25 464989.61 70.24882214 -150.28283751 2496.09 10.62 221.86 2373.49 2471.29 312.67 313.07 312.77 -222.92 -219.38 0.15 5940551.11 464977.61 70.24558610 -150.28293395 2500.00 10.62 221.89 2377.33 2475,13 313.39 313.79 313.49 -223.46 -219.88 0.18 5940550.58 464977.13 70.24858464 -150.28293784 2590.87 10.50 222.50 2466.66 2584.46 330.04 330.44 330.12 -235.80 -231.05 0.10 5940538.30 484965.89 70.24855094 -150.28302818 2800.00 10.50 222.46 2475.64 2573.44 331.70 332.11 331.79 -237.02 -232.17 0.09 5940537.08 464964.76 70.24854758 -150.28303723 2887.10 10.51 222.05 2561.28 2859.08 347.58 347.99 347.66 -248.78 -242.85 0.09 5940525.37 464954.03 70.24851547 -150.28312349 2700.00 10.50 221.85 2573.97 2871.77 349.93 350.34 350.01 -250.53 -244.42 0.31 5940523.63 464952.45 70.24851069 -150.28313619 2783.85 10.41 220.50 2696.42 2754.22 36513 365.55 365.20 -261.98 -254.44 0.31 5940512.23 464942.38 70.24847941 -150.28321708 2500.00 10.37 220.81 267231 2770.11 368.04 368,46 368.10 -284.19 -25633 0.30 5940510.02 484940.48 70.24847337 -15028323237 2878.46 10.15 221.17 2749.52 2847.32 382,01 382.43 382.05 -274.75 -265.47 0.30 5940499.51 464931.29 70.24844451 -15028330625 2900.00 10.12 221.30 2770.72 2868.52 385,79 386,23 385.84 -277.60 -287.97 0.17 5940496.67 464928.78 70.24843672 -150.28332643 2972.50 10.02 221.73 2842,10 2939.90 398.47 398.90 398.50 -287.09 -276.37 0.17 5940487.21 464920.33 70.24841079 -150.28339429 3000.00 1040 221.50 2869.18 2986.98 40324 403.68 403.28 -290.67 -279.55 0.17 5940483.66 464917.14 70.24840103 -150.28341993 3088.44 9.94 220.94 2936.69 3034.39 415.08 415.53 415.11 -299.58 -287.36 0.17 5940474.78 464909.29 70.24837668 -15028348300 3100.00 986 220.62 2967.68 3085.48 420.51 421.95 420.53 303.69 -290.90 0.31 5940470.69 464905.73 70.24836546 -150.28351162 3183.88 9.70 219.95 3030.63 3128.43 431.34 431,81 43136 311.98 -297.92 0.31 5940462.45 464898.68 70.24834284 -15028356830 3200.00 9.87 22027 3068.24 3164.04 437.41 437.88 437.43 316.61 301.83 0.18 5940457.82 464894.74 70.24533015 -15028359991 3259.77 9.61 220.80 3125.16 3222.96 447.41 447.89 447.42 .32422 308.33 0.18 5940450.24 464888.20 70,24830937 -150.25365244 3300.00 9.66 222.94 3164.83 3282.63 454.14 454.82 454.15 329.23 312.83 0.90 5940445.25 484883.69 70,24829587 -150.28368874 3355.08 9.76 225.82 3219.12 3316.92 483.43 463.91 463.44 335,87 319.33 0.90 5940438.64 464877.16 70.24827753 -150.28374123 3400.00 9.62 225.16 3263.40 3361.21 470.98 471.47 470.99 341.17 324.72 0.40 5940433.37 464871.74 70.24828306 -15028378477 3451.95 9.45 224.38 3314.63 3412.43 479.58 480.07 479.60 -347.27 330.78 0.40 5940427.29 464885.66 70.24824637 -15028383371 • 3500.00 928 223.77 3362.04 3459.84 487.40 487.89 487.42 352.09 338.22 0.40 5940421.70 464880.19 70.24823102 -150.28387766 ' 3547.12 9.12 223.16 3408.55 3506.35 494.93 495.43 494.95 358.36 341.40 0.40 5840418.26 464854.98 7024821609 -150.28391953 3690.00 9.10 223.66 3480.77 3558.57 503.30 503.80 503.32 364.44 347.15 0.15 5940410.21 484849.20 70.24819947 -150.28396599 3643.00 9.08 224.08 3503.23 3601.03 510.09 510.59 510.11 369.34 451.86 0.15 5940405.33 46484447 70.24818609 -150.28400401 3700.00 940 226.10 3559.49 3657.29 519.24 519.74 519.26 375.80 358.34 0.80 5940398.90 464637.96 70.24816844 -15028405636 3738.49 9.62 227.40 3597.45 3695.25 52558 526.10 525.61 380.15 362.87 0.80 594039456 46483331 70.24815854 -15028409377 3800,00 9.37 227.76 3658.11 3755.91 535.70 53625 535.73 387.00 370.46 0.42 5940387.75 464825.79 70.24813784 -15028415428 3834.98 923 227.98 3692.63 3790.43 541.34 541.90 541.37 390.79 374.66 0.42 5940363.98 464821.58 70.24812748 -150.28418814 3900.00 923 227.10 3756.81 3854.61 551.73 552.33 551.78 397.83 382.35 0.22 5940376.98 464813.86 70.24810824 -150.28425029 3929,77 923 226.70 3786.20 3884.00 556.50 557.11 558.55 -401.09 -385.84 022 5940373.73 464810.35 70.24809933 -15028427845 4000.00 952 227.33 3855.49 3953.29 587.91 588.54 567.97 -408.89 -39420 0.43 594036597 484801.95 70.24807803 -150.28434804 4025.39 9.62 227.55 3880.53 3978.33 572.12 572.78 572.18 -411.75 -397.31 0.43 5940363.13 464798.83 70.24807023 -15028437114 4100.00 9.42 226.11 3954.11 4051.91 584.43 585.11 584.51 -421.19 -416.31 0.41 5940354.73 464789.79 70.24804716 -150.28444388 4120.93 9.37 225.70 397476 4072.56 587.84 58852 58712 322.57 -408.77 0.41 5940352.37 464787.33 70.24804067 -150.28446368 4210.00 8.53 228.06 4052.76 4150,56 600.81 601.50 600.90 -431.80 -418.09 021 5940343.38 464777.97 70.24801598 -15028453895 4217.01 9.58 226.14 4069.53 4167.33 603.63 604.32 603.72 -433.56 -420.12 021 5940341.43 464775.93 70.24801084 -15028455538 4300.00 10.19 225.36 4151.29 4249.09 617.84 618.58 617.94 343.49 -430.31 0.78 5940331.54 464765.69 70.24798350 -15028463770 4312.73 10.29 225.25 4163.82 4261.62 62,11 621.82 82121 -445.08 -431.92 0.78 5940329.96 464764.07 70.24797915 -15028465070 4400.00 10.19 224.36 4249.70 4347.50 83521 636.33 635.72 -456.09 -442.88 0.21 5940319.01 464753.09 70.24794908 -15028473900 4408.28 10.18 22428 4257.83 4355.63 637.07 837.79 637.18 -457.13 343.88 021 5940317.97 464752.06 70.24794622 -15028474724 4500.00 10.10 225.48 4348.13 4445.93 653.22 653.95 653.33 -468.58 -455.27 0.24 5940306.57 464740.61 70.24791495 -150.28483931 4505.45 10.10 225.55 4353.50 4451.30 654.17 654.90 654.29 369.25 .455.96 024 5940305 91 464739.93 70.24791312 -15028484481 4598.57 9.98 222.72 4445.20 4543.00 670.38 571.12 670.50 -480.89 -46725 0.55 594029433 464728.58 70.24788133 -15028493602 I 4500.00 9.96 222.71 4446.60 4544.40 670.63 671.37 670.75 -481.07 -467.42 0.11 594029414 464728.42 70.24768084 -15028493738 4895.00 9.89 22225 4540.18 4637.98 687.00 687.74 687.11 -493.14 .478.47 0.11 5940282.12 46471730 70.24784785 -15028502669 4700.00 921 222.32 4545.11 4642.91 687.86 888.60 887.97 483.78 -479.05 0.56 5940251.49 464716.72 70,24784611 -150.28503138 4791.57 10.37 223.63 4635.25 4733.05 703.99 704.72 704.09 505.57 490.05 0.56 5940269.75 464705.67 70.24781389 -150.28512017 4800.00 10.36 223.54 4643.54 4741.34 705.50 70624 705.61 606.67 391.09 0.22 5940268.65 464704.62 70.24781069 -15028512881 i Drilling Office 2.0.930.0 Tam Worth Tarn 1\North Tarn 1 Worth Tarn 1 Worth Tam 1 3/31/2014 4:34 PM Page 2 of 3 • Comments (ft) Incl Azkn True TVDSS TVD VSEC MD Closure NS EW DLS Northing Seating Latitude Longitude IID r1 M 118 ml (m fID nu IRI an 01100111 MUM IRUS1 CI r1 4887.19 10.26 222.62 4729.26 4827.06 721.10 721.83 721.20 518.06 -501.74 0.22 5940257.31 464693.92 70.240/701/ -150.28521464 4900.00 10.20 223.20 4741.93 4839.73 72339 724.13 723.50 -51974 503.31 0.82 5940255.64 464692.35 70.24777518 -150.28522726 498260 10.43 226.86 4823.18 4920.98 736.22 738.97 738.33 530.23 513.81 0.82 5940245.21 464681.80 70.247746.53 -15028531208 5000.00 10.42 226.91 4840.30 4938.10 74136 742.12 741.48 532.38 518.10 0.09 5940243.07 484679.49 70.24774065 -15028533064 5079.19 10.36 227.14 4918.19 5015.99 755.81 755.40 755.74 542.11 526.55 0.09 5940233.38 464669.00 70.24771406 -150.28541502 5100.00 10.28 227.02 4938.66 5036.46 759.33 792.13 759.46 544.65 -529.28 0.38 5940230.85 464666.26 70.24770712 -150.28543708 5175.13 10.01 226.56 5012.62 5110.42 77254 773.38 772.69 553.71 538.93 0.38 5940221.84 4846558.57 70.24768236 -150.28551500 5200.00 9.86 225.43 5037.11 5134.91 776.03 777.66 776.90 556.69 -542.02 0.98 5940218.87 464653.47 70.24787422 -150.28553993 5271.49 9.47 222.01 5107.59 5205.39 788.83 789.68 768.98 565.38 -550.32 0.98 5940210.24 464645.13 70.24765054 -150.28560696 5300.00 9.35 221.63 5135.71 5233.51 793.49 794.32 793.63 568.84 -553.43 0.47 5940206.78 46464201 70.24764104 -15028563207 5367.21 9.07 220.70 5202.06 5299.86 804.24 805.08 804.37 576.93 560.51 0.47 5940196.72 464634.89 70.24761892 -15028568927 ' 5400.00 8.99 220.65 5234.44 5332.24 509.38 810.22 809.51 580.83 -563.87 025 5940194.84 464631.51 70.24760827 -15028571642 5462.45 8.84 221.15 5296.14 539394 81905 819.90 819.18 588.13 570.22 0.25 5940187.56 464625.13 70.24758832 -150.28576770 5500.00 8.96 221.41 5333.23 5431.03 824.86 825.71 824.90 -592.50 574.05 0.32 5940183.22 464621.26 70.24757639 -15028579855 5556.87 9.13 221.79 5389.40 5487.20 833.79 834.65 833.91 599.18 579.98 0.32 5940176.56 484615.31 70.24755813 -15028584658 5600.00 9.36 222.78 5431.97 5529.77 840.72 841.50 840.83 -604.31 -584.65 0.65 5940171.46 464610.83 70.24754413 -150.28588423 5853.93 9.65 223.96 5485.16 5582.96 849.62 850.48 849.74 -610.76 590.76 0.65 5940165.02 464604.48 70.24752645 -150.25593383 5700.00 9.47 223.85 5530.59 5628.39 857.27 858.13 857.39 -61629 -596.07 0.40 5940159.53 484599.15 70.24751139 -15028597648 5749.53 9.27 223.73 5579.48 5677.28 865.33 866.19 885.45 522.11 -601.65 0.40 5940153.74 464593.55 70.24749549 -15028602155 5800.00 8.92 222.56 562929 5727.09 873.31 874.17 873.42 -627.93 -607.10 0.79 5940147.94 464588.07 70.24747959 -15028606560 5845.37 8.60 221.42 5674.13 5771.93 880.22 881.08 880.33 -633.08 -611.72 0.79 5940142.83 464583.42 70.24746557 -15028610293 5900.00 8.13 221.38 572518 5825.90 558.16 889.02 888.27 539.03 516.98 0.88 5940138.90 464578.14 70.24744928 -15028814538 5940.94 7.78 221.34 5768.73 5868.53 893.82 894.69 893.93 543.28 -620.72 0.88 5940132.66 484574.37 70.24743766 -15028617562 6000.00 7.31 21829 5827.28 5925.08 901.56 902.44 901.66 -64823 -625.69 1.05 5540126.73 464569.38 70.24742140 -15028621575 6036.66 7.03 216.19 5863.65 5961.45 906.12 907.02 906.20 -652.87 528.46 1.05 5940123.10 464568.59 70.24741145 -150.28623812 6223.00 7.03 216.19 6048.59 614639 928.78 929.83 926.81 571.28 541.93 0.00 5940104.76 484553.04 70.24738116 -15028634688 Survey Error Model: ISCWSA Rev 0111 3-D 95.000%Confidence 2.7955 sigma Survey Program: MD From MD To EOU Freq(9) Survey Tool Type Borehole/Survey (11) IRI 0.000 2285.890 Act Stns SLB MWD-STD North Tam 1/North Tarn 1 2285.890 6223.000 Act Stns SLB MWD-STD North Tam 1/North Tam 1 Legal Description: Northing ryry�1 Esetingg��X)) Surface:2388.6 FSL 1760.7 FEL 52 T10N R7E UM 0 40773.000 400198.006 8NL:1717 FSL 2423 FEL 2 TION R7EUM 5940104.760 464553.040 Ifalisized marker stations are not Dart of the calculated sunray Final DefinItNe Survey Verify and Sign-off I have checked to the best of my ability that the following data is correct: Surface Coordinates and Reference Elevations Destination Information Survey Tool Codas 516 DE: Client Representative: Date: Drilling Office 2.0.930.0 Tamworth Tam 1 Worth Tam 1 Worth Tam 1 Worth Tam 1 3/31/2014 4:34 PM Page 3 of 3 Brooks Range Petroleum RECEIVED April 2,2014 APR 0 2 2014 AOGCC Meredith Guhl Alaska Oil and Gas Conservation Commission 333 West 7th Ave.,Suite 100 Anchorage,AK 99501 IRDD : 2- 11 — CSD I 0 3 Ms. Guhl, 21i ( di-i As per the attached email request, BRPC is submitting the requested items for North Tarn 1: /• Paper: Formation Evaluation Log/complete mud log, 120'to 6223', 1:240 or 5"scale I2y ( o 3 i'1 0 3 ` .• Paper log of Schlumberger Drilling Mechanics depth composite log,5" a • Digital versions of !, 1. Halliburton Temperature Log,5",April 3,2011 ! 2. Halliburton Freepoint Survey,5",April 5,2011 ' 3. Halliburton Freepoint Survey,2.5",April 3, 2011 2 4. Halliburton Perforating Record,5",April 4-5,2011 5. Halliburton String shot backoff log,5",April 3-4,2011 24 1 b 3 L. Digital log data composite including GR, Res, Density and Neutron. We show that the items below were delivered to AOGCC on 6/16/11: • Schlumberger ProVision Real Time Service 91'to 6222.6', 1:240 or 5"scale • Schlumberger Vision Services Real Time and Recorded 91'to 6222.6', 1:240 or 5" scale A transmittal record and copies of the cover pages of the logs are attached. Please let me know if you have any questions or require any additional information on North Tarn 1. Sincerely, iyar.r/t.... difroi( Lawrence J.Vdl Vice President of Exploration 510 L Street,Suite 601 Anchorage,AK 99501 (907)339-9965 (907)339-9961 fax Laurette Rose From: Guhl, Meredith D (DOA) <meredith.guhl@alaska.gov> Sent: Wednesday, March 05, 2014 10:11 AM To: Larry Vendl Subject: Additional data required for North Tarn 1 Dear Mr.Vendl: I am completing the final compliance check for North Tarn 1, completed on 4/10/2011. As required by 20 AAC 25.071,the operator shall file with the commission: (6)a sepia and a reproduced copy of all logs run, including common derivative formats such as tadpole plots of dipmeter data and borehole images produced from sonic or resistivity data, and including composite log formats; On February 24, I requested the following logs in paper format: • Schlumberger ProVision Real Time Service 91'to 6222.6', 1:240 or 5" scale • Schlumberger Vision Services Real Time and Recorded 91' to 6222.6', 1:240 or 5" scale/ • Formation Evaluation Log/complete mud log, 120' to 6223', 1:240 or 5" scale., After further review,the digital or paper versions of the following logs are also required: • Digital versions of o Halliburton Temperature Log,5",April 3,20117 o Halliburton Freepoint Survey,5",April 5,2011 o Halliburton Freepoint Survey,2.5",April 3, 2011 o Halliburton Perforating Record,5",April 4-5,2011` o Halliburton String shot backoff log,5",April 3-4,2011✓ • Paper log of Schlumberger Drilling Mechanics depth composite log,5"✓ • Digital log data composite including GR, Res, Density and Neutron Please provide all files as requested by March 26,2014. If you have any questions,please contact me. Sincerely, Meredith Meredith Guhl Petroleum Geology Assistant Alaska Oil and Gas Conservation Commission meredith.guhl@alaska.gov Direct: (907) 793-1235 1 Z 4S4VSYNk Brooks Range Petroleum 510 L Street, Suite 601, Anchorage, AK 99501 Phone: 907-339-9965 Fax: 907-339-9961 Attention: Dan Seamount, Chair/Alaska Oil& Gas Conservation Commission Date: 06/15/11 Address: 333 West 7th Ave., Suite 100 Anchorage, AK 99501 Sent By: Larry Smith File Under: Brooks Range Petroleum—North Tarn 1 Transmitting: Log—Schlumberger ProVision Real Time Service 91' —6222.6', 1:600 Log— Schlumberger ProVision Real Time Service 91' —6222.6', 1:240 Log— Schlumberger Vision Services Real Time & Recorded 91' —6222.6', 1:600 Log—Schlumberger Vision Services Real Time & Recorded 91' —6222.6', 1:240 CD— Schlumberger ProVision & Vision Services Log— Halliburton Freepoint Survey, scale 5" Log— Halliburton Perforating Record, scale 5" Log— Halliburton Temperature Log, scale 5" Log— Halliburton String Shot Backoff, scale 5" Log— Halliburton Freepoint Survey, scal 2.5" Description: Additional Comments: Please sign and Fax to 907-339-9961 (T) Signature l I Date Page 1 of 10 Cover page of log North Tarn 1 proVISION Service Schimierver Real Time Log Company: Brooks Range petroleum Corporation Well: North Tarn 1 • Field: Exploratory County: North Slope Borough State: Alaska Country: USA i Section: S2 APIN: 501032053300 township: T 10 N Rig Name: Nabors HCS di a l Range: R 7 E Rig Type: Arctic FL: Fxploratoiy F L 1: X=465,198.38 FL2: Y=5,940,772.89 Log Measured From-Drill Floor.97.8 ft Ground Level:69.3 ft Permanent Datum-Mean Sea Level Acquisition Dates: 12 Mar 11 to 07 Apr 11 Other Services: Log Interval: 91.0(ft)to 6222.6(8) VISION*Service Index Types: Measured Depth DD t Index Scales: 1:240 5'1 100' D&I Z4 Depth Source: Driller's Depth Depth Sensor: DES is Conveyance: Drill Pipe Print Type: Finalill Ili, 411 Spud Date: 13 Mar-2011 Page 3 of 10 Cover page of log North Tam 1 VISION*Service Nine Real Time and Recorded Mode Log Company: • - Brooks Range Petroleum Corporation • : - Well: North Tarn 1 Field: Exploratory County: North Slope Borough State: Alaska Country: USA Section: S2 APIN: 501032063300 i b Township: T 10 N Rig Name: Nabors 9ES Range: H 7 E Rig Type: Arctic hL Fxploramry FL I: X=465,198.38 Ft 2: Y=,940,772.89 Log Measured From-Drill Floor 97.8 R Ground Levet:69.3 ft LL Permanent Datum-Mean Sea Level Acquisition Dates: 12 Mar 11 to 07 Apr 11 Other Services: Log Interval: 91.0(8)to 62226(f) D81 index Types: Measured Depth DD Index Scales: 1240 5"/100' NMR Depth Source: thins Depth Depth Sensor: DES it 8 Conveyance: Dril Pipe Print Type: Final • + it Spud Date. 13-Mar-?_t111 r' 4 f.k f1 Page 5 of 10 Guhl, Meredith (DOA sponsored) From: Guhl, Meredith (DOA sponsored) Sent: Monday, February 24, 2014 12:29 PM To: 'Ivendl@brpcak.com' Subject: North Tarn 1 Dear Mr.Vend!: I am completing the final compliance check for North Tarn 1,completed on 4/10/2011. IIT In order to have the North Tarn 1 well file as complete as possible, please provide the following logs in paper format: • Schlumberger ProVision Real Time Service 91'to 6222.6', 1:240 or 5" scale • Schlumberger Vision Services Real Time and Recorded 91'to 6222.6', 1:240 or 5" scale • Formation Evaluation Log/complete mud log, 120'to 6223', 1:240 or 5" scale Digital versions of the three files listed above have already been provided. If you have any questions, please don't hesitate to contact me via email or telephone. Sincerely, Meredith Meredith Guhl Petroleum Geology Assistant Alaska Oil and Gas Conservation Commission meredith.guhl@alaska.gov Direct: (907)793-1235 1 Page 1 of 2 Okland, Howard D (DOA) From: Laurette Rose [Irose@brpcak.com] Sent: Monday, July 01, 2013 1:40 PM To: Okland, Howard D (DOA) Cc: Dan Shearer; Larry Vendl; Doug Hastings Subject: FW: Reminder Attachments: AOGCC NT1.pdf Revised Form 10-407 attached From: Doug Hastings Sent: Friday,June 28, 2013 2:42 PM To: howard okland@admin.state.ak.us Cc: Dan Shearer; Larry Vendl Subject: FW: Reminder Hi Howard: I'm copying this to Dan Shearer - he is in a better position to complete this form than I. Doug Douglas S Hastings Senior Geoscience Advisor Brooks Range Petroleum Corp (907) 865-5802 (907) 301-6979 From: Okland, Howard D (DOA) [howard.okland@alaska.gov] Sent: Friday, June 28, 2013 1:28 PM To: Doug Hastings Cc: Bettis, Patricia K (DOA); Davies, Stephen F (DOA); Colombie, Jody 3 (DOA) Subject: Reminder Doug, This is a note to remind you to submit a complete Form 10-407 for the North Tarn 1 Well (PTD 211-001). Please inform us when you will be able to send it to us. The original email is copied below. Howard Dear Mr. Hastings, The AOGCC received on May 10, 2013 the Form 10-407"Well Completion Report" for the North Tarn 1 well. As submitted, the report is incomplete, see 20 AAC 25.071. The purpose of Form 10-407 is to provide a concise, two page summary for AOGCC's well records. Entries such as"Not available" or"To be sent under subsequent report" or"N/A" defeat the purpose of the form; they are not acceptable. In order to complete the Form for North Tarn 1, please submit-within 15 days-a revised copy of this Form 10-407 that contains the following data: Page 2 of 2 Box 28: Core Data: Please check the"Yes" No" box to indicate whether"Conventiona, Core(s)" or"Sidewall cores"were acquired. If"Yes" list the formations and intervals cored and briefly summarize the lithology and presence of oil, gas or water. If additional space is needed, submit separate sheets with the revised form. When laboratory analyses are completed, submit detailed descriptions, photographs and, including core analysis determinations, if any, of porosity, permeability, and fluid saturations as specified in 20 AAC 25.071. Box 30: Formation Tests: Please check the"Yes"or"No" box. If"Yes", please submit a list of the intervals and formations tested and briefly summarize test results; and submit copies of all: 1. Drill stem test and production data; and 2. Geochemical and formation fluid analyses obtained. The AOGCC's reporting requirements are found in statute AS 31.05.030 and regulations 20 AAC 25.070 and 20 AAC 25.071. These requirements can be accessed on the Internet at: Statute AS 31.05.030: http://www.legis.state.ak.us/basis/folioproxy.asp?url=http://wwwinu0l.leais.state.ak.us/cgi-bin/folioisa.dll/stattx07/query=31!2E05! 2E030/doc/{t13554}. Regulations 20 AAC 25.070 and 20 AAC 25.25.071: http://www.legis.state.ak.us/basis/folioproxv.asp?url=http://wwwjnu0l.legis.state.ak.us/cqi-bin/folioisa.dll/aac/query= JJUMP:'20+aac+25!2E070'1/doc/{(�1}?firsthit If you have any questions concerning the matter, please do not hesitate to contact me at (907) 793-1235 or at howard.okland aC�,alaska.gov. Sincerely, Howard Okland Geologic Assistant AOGCC 8/14/2013 Jir UPDATED STATE OF ALASKA ',,.( �f a 1 't. ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1a.Well Status: Oil❑ Gas ❑ SPLUG ❑ Other ❑ Abandoned ❑. Suspended-❑ lb.Well Class: 20AAC25.106 20AAC26.110 Development ❑ Exploratory 0 GIN.J WINJ❑ WAG❑ WDSPL 0 No.of Completions: Service 0 Stratigraphic Test❑ 2.Operator Name: 5.Date Comp.,Susp.,or 12.Permit to Drill Number: Brooks Range Petroleum Corporation Abend.: 4/10/2011 211-001 - 3.Address: 6.Date Spudded: 13.API Number: 610 L Street,Suite 601,Anchorage,AK 99501 3/13/2011 50.103-20633-00-00 - 4a.Location of Well(Governmental Section): '7.Date TD Reached: 14.Well Name and Number: Surface: 2388 FSL 1780 FEL S2 T1ON R7E UM 3/22/2011 North Tarn 1 - Top of Productive Horizon: 8.KB(ft above MSL): 15.FieldlPooI(s): 1717 FSL 2423 FEL S2 T1ON R7E UM GL(ft above MSL): Exploratory Total Depth: 9.Plug Back Depth(MD+TVD): 1717 FSL 2423 FEL S2 T1ON R7E UM 2,097 4b.Location of Well(State Base Plane Coordinates,WAD 27): 10.Total Depth(MD+TVD): 16.Property Designation: Surface: x- 465198.000 y- 5940773.000 Zone- 4 6223'MD/6147TVD ADL 390680 , WI: x- 464553.000 y-5940104.000 Zone- 4 11.SSSV Depth(MD+TVD): 17.Land Use Permit Total Depth: x- 464553.000 y- 5940104.000 Zone- 4 None N/A 18.Directional Survey: Yes LJ No U 19.Water Depth,If Offshore: 20.Thickness of Permafrost MD/TVD: (Submit electronic and printed information per 20 AAC 25.050) N/A (ft MSL) 1,348'MD 11,338'TVD 21.Logs Obtained(List all logs here and submit electronic and printed information per 20AAC25.071): 22.Re-drlll/Lateral Top Window MD/TVD: NIA 23. CASING,LINER AND CEMENTING RECORD WT.PER SETTING DEPTH MD SETTING DEPTH TVD AMOUNT CASING GRADE TOP BOTTOM TOP BOTTOM HOLE SIZE CEMENTING RECORD PULLED 16" 65 N/A 0 80' 0 80' 44" Cement to surface: N/A 33bbis 9-5/8" 40 L-80 0 2,347' 0 2,347' 12-1/4" Cement to surface:231bbls N/A 24.Open to production or injection? Yes❑ No Q 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) 26. ACID,FRACTURE,CEMENT SQUEEZE,ETC. DEPTH INTERVAL(MD) AMOUNT AND KIND OF MATERIAL USED 27. PRODUCTION TEST Date First Production: Method of Operation(Flowing,gas lift,etc.): Date of Test: Hours Tested: Production for 011-Bbl: Gas-MCF: Water-Bbl: Choke Size: Gas-Oil Ratio: Test Period �` Flow Tubing Casing Press: 'Calculated Oil-Bbl: Gas-MCF: Water-Bbl: Oil Gravity-API(corr): Press. 24-Hour Rate --01. 28. CORE DATA Conventional Core(s)Acquired? Yes❑ NoY. Sidewall Cores Acquired? Yes❑ No If Yes to either question,list formations and intervals cored(MD+TVD of top and bottom of each),and summarize Ithology 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 MC 25.071. Form 10-407 Revised 12/2009 CONTINUED ON REVERSE Submit original only \ Aiefl RBDMS JUL - 2 2015-� c • 29. GEOLOGIC MARKERS (List all formations and markers encountered): 30. FORMATION TESTS NAME MD ND Well tested? U Yea No If yes,list intervals and formations tested, briefly summarizing to results.Attach separate sheets to this form,if needed, Permafrost-Top 0 0 and submit detailed test information per 20 MC 25.071. Permafrost Base 1346 1338 Surface Casing 2347 2325 K10 top 2576 2551 K10 Base 2856 2629 Torok Fm. 4205 4158 Iceberg Sand 4524 4470 N Tam TARGET 4987 4926 C35 marker 5173 5108 Moraine Sand(C30 Ss) 5549 5479 HRZ 5905 5831 Kalubik 6025 5950 K-1 6111 6035 Kuparuk C 6198 6121 TD 6223 6147 Formation at total depth: Kuparuk C 6198 6121 31. List of Attachments: Well Schematics.Well As-Built.Summary Report of Operations 32. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact:A.Mid(907)264 6130 Printed Name: Bart A infield Tale:VP-Operations / Signature: Phone:(907)339 9965 Date: ,.5/9/wGOf/ 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 1 b: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 23:Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 24: If this well is completed for separate production from more than one interval(multiple completion),so state In Item 1,and in Item 23 show the producing intervals for only the Interval reported in Item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Item 27: Method of Operation: Flowing,Gas Lift,Rod Pump,Hydraulic Pump,Submersible,Water Injection,Gas Injection,Shut-in,or Other(explain). Item 28: Provide a listing of intervals cored and the corresponding formations,and a brief description in this box. Submit detailed description and analytical laboratory information required by 20 MC 25.071. Item 30: Provide a listing of intervals tested and the corresponding formation,and a brief summary in this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Form 10-407 Revised 12/2009 UPDATED STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG la.Well Status: 011❑ Gas 0 SPLUG 0 Other ❑ Abandoned ❑ Suspended ] lb.Wet Class: 20AAC25.105 20AAC25.110 Development ❑ Exploratory❑ GIN.❑ WINJ❑ WAG❑ WDSPL 0 No.of Completions: Service 0 Stratigraphic Test❑ 2.Operator Name: 5.Date Comp.,Susp.,or '12.Permit to Drill Number. Brooks Range Petroleum Corporation Abend.: 4/10/2011 211-001 3.Address: 6.Date Spudded: 13.API Number. 610 L Street,Suite 601,Anchorage,AK 99601 3/13/2011 50.103-20633-00.00 4a.Location of Well(Governmental Section): 7.Date TD Reached: 14.Well Name and Number. Surface: 2388 FSL 1780 FEL S2 T1ON R7E UM 3/22/2011 North Tarn 1 Top of Productive Horizon: 8.KB(ft above MSL): 15.Field/Pool(s): 1717 FSL 2423 FEL S2 T1ON R7E UM GL(ft above MSL): Exploratory Total Depth: 9.Plug Back Depth(MD+TVD): 1717 FSL 2423 FEL S2 Ti ON R7E UM 2,097 4b.Location of Well(State Base Plane Coordinates,NAD 27): 10.Total Depth(MD+TVD): 16.Property Designation: Surface: x- 465198.000 y- 5940773.000 Zone- 4 6223'MD161471VD ADL 390680 WI: x- 464553.000 y-5940104.000 Zone- 4 11.SSSV Depth(MD+TVD): 17.Land Use Permit: Total Depth: x- 464553.000 y- 5940104.000 Zone- 4 None N/A 18.Directional Survey: Yes LJ No U 19.Water Depth,if Offshore: 20.Thickness of Permafrost MD/TVD: (Submit electronic and printed information per 20 MC 25.050) N/A (ft MSL) 1,346'MD 11,338'TVD 21.Logs Obtained(Liat all logs here and submit electronic ad printed information per 20AAC25.071): 22.Re-drlWLateral Top Window MD/TVD: 6 2JS 'Q Si \-L 1_vw-cA NlrlCrutti N/A 23. CASING,LINER AND CEMENTING RECORD WT.PER SETTING DEPTH MD SETTING DEPTH ND AMOUNT CASING i. GRADE TOP BOTTOM TOP BOTTOM HOLE SIZE CEMENTING RECORD PULLED 18" 65 N/A 0 80' 0 80' 44" Cement to surface: N/A 33bbls 9-5/8" 40 L-80 0 2,347' 0 2,347' 12-1/4" Cement to surface:231bbis N/A 24.Open to production or injection? Yes 0 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) 26. ACID,FRACTURE,CEMENT SQUEEZE,ETC. DEPTH INTERVAL(MD) AMOUNT AND KIND OF MATERIAL USED 27. PRODUCTION TEST Date First Production: Method of Operation(Flowing,gas lift,etc.): Date of Test: Hours Tested: Production for Oil-Bbl: Gas-MCF: Water-Bbl: Choke Size: Gas-Oil Ratio: Test Period �p Flow Tubing Casing Press: Calculated Oil-Bbl: Gas-MCF: Water-Bbl: OII Gravity-API(con•): Press. 24-Hour Rate -.► 28. CORE DATA Conventional Core(s)Acquired? Yes❑ No,' Sidewall Cores Acquired? Yes 0 No gr If Yes to either question,list formations and intervals cored(MD+TVD of top and bottom of each),and summarize Ethology 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 MC 25.071. Form 10-407 Revised 12/2009 CONTINUED ON REVERSE Submit original only 29. GEOLOGIC MARKERS (List all formations and markers encountered): 30. FORMATION TESTS NAME MD TVD Well tested? U Yes No If yes,list intervals and formations tested, briefly summarizing test results.Attach separate sheets to this form,if needed, Permafrost-Top 0 0 and submit detailed test information per 20 MC 25.071. Permafrost Base 1346 1338 Surface Casing 2347 2325 K10 top 2576 2551 K10 Base 2656 2629 Torok Fm. 4205 4158 Iceberg Sand 4524 4470 N Tam TARGET 4987 4926 C35 marker 5173 5108 Moraine Sand(C30 Ss) 5549 5479 HRZ 5905 5831 Kalublk 6025 5950 K-1 6111 6035 Kuparuk C 6198 6121 TD 6223 6147 Ili Formation at total depth: Kuparuk C 6198 6121 31. List of Attachments: Well Schematics,Well As-Built.Summary Report of Operations 32. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact:A.Mid(907)264 6130 Printed Name: Balt Ai infield Title:VP-Operations Signature: � Phone:(907)339 9965 Date: 5/9/Gaff 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 wkh each 10407 well completion report and 10-404 well sundry report when the downhole well design is changed. Item lb: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 23: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 24: If this well is completed for separate production from more than one interval(multiple completion),so state In item 1,and in item 23 show the producing Intervals for only the Interval reported in item 26. (Submit a separate form for each additional Interval to be separately produced, showing the data pertinent to such interval). Item 27: Method of Operation: Flowing,Gas Lift,Rod Pump,Hydraulic Pump,Submersible,Water Injection,Gas Injection,Shut-in,or Other(explain). Item 28: Provide a listing of intervals cored and the corresponding formations,and a brief description in this box. Submit detailed description and analytical laboratory information required by 20 MC 25.071. Item 30: Provide a listing of intervals tested and the corresponding formation,and a brief summary in this box. Submit detailed test and analytical laboratory Information required by 20 MC 25,071. Form 10-407 Revised 12/2009 petrolçum FREE UVI/ suascR from, Adverts=mg Subscr Puturcatlons r yes Vol. 16, No. 27 Week of July 03, 2011 Providing coverage of Alaska and northern Canada's oil and gas industry Mounting the Mustang unit D \\_ -00 \ Brooks Range planning exploration and development west of Kuparuk \ By Eric Lidji For Petroleum News A joint venture led by Brooks Range Development Corp. plans to develop a North Slope discovery it made this winter with the aim of producing oil as soon as July 2014. The local subsidiary of Kansas-based Alaska Venture Capital Group drilled the onshore North Tarn No. 1 well this past winter two miles west of the Kuparuk River unit. The 6,223-foot well encountered oil-bearing sandstones, but well control challenges kept the companies from testing the well, which it plans to do this coming winter, according to a partner on the program. Brooks Range believes its discovery—called Mustang—could underpin development in the region by improving the economics of several marginal accumulations. The company wants to form the Southern Miluveach unit over 60,684 acres, build independent processing facilities to serve all of those smaller accumulations and kick off a six-well exploration program between now and 2020. The Southern Miluveach unit would cover 29 State of Alaska leases west of the Kuparuk River unit, including six owned jointly with the Arctic Slope Regional Corp. "The other potential hydrocarbon accumulations are currently believed to be marginally economic and would not be developed without existing infrastructure and a processing facility within(Southern Miluveach)," Brooks Range wrote in its application to the Alaska Department of Natural Resources. "Likewise, future development of the other potential hydrocarbon accumulation within(Southern Miluveach) using the Mustang processing infrastructure will extend the economic life of Mustang production." Brooks Range previously estimated that the Kuparuk Formation at North Tarn No. 1 contained 6 million barrels of oil, enough to make the play economic. The company also said North Tarn included a target in the shallower Brookian Formation that could hold 35 million barrels, but would be more difficult to produce because of complex geology. Six exploration blocks Brooks Range plans to develop and explore simultaneously. For the Mustang development project,the company told the DNR that it plans to have permits in place by the end of 2012, form a participating area by the end of 2013 and begin production by July 1, 2014, according to a plan of development. As of now, Brooks Range plans to build processing facilities that connect the unit to the Alpine Pipeline, which delivers processed Colville River unit oil into the North Slope's main pipeline system that leads to the 800-mile trans-Alaska pipeline, which in turn carries the oil to the Port of Valdez. Meanwhile, Brooks Range would also explore other targets at Southern Miluveach. According to a plan of exploration, Brooks Range wants to break the proposed unit into six blocks. Brooks Range already fulfilled its first drilling obligation for the unit by drilling the North Tarn No. 1 well this winter in the SE Exploration Block. In its proposed plan to form the unit,the company must drill a second well into the block by March 31, 2012, or lose all undrilled acreage. Next, Brooks Range must drill a well in each exploration block by the end of March of 2014, 2015, 2016, 2018 and 2020, respectively, or lose all undrilled exploration blocks. The exploration blocks are prioritized as follows: SE,NE,NW, SW, W and S. Under its proposed unit plan, Brooks Range also is required to submit a plan of operations by Oct. 1 detailing its plans to complete and test the North Tarn No. lA well this coming winter and drill at least one of two planned delineation wells on ADL 390680. The 2011-2012 activities also include a summer clean up and field studies program and performing flow tests on the wells. The program will require a four-mile ice road from existing gravel pads at the Kuparuk River unit to an ice pad that would be constructed at the North Tarn site for drilling work. Discoveries marginal to date Although the fairway between the Kuparuk and Colville units is a natural extension of North Slope development, exploration to date hasn't lead to production. In its filings, Brooks Range identified 18 previous wells drilled in the region between 1966 and 2010—to depths between around 6,400 feet and 13,000 feet—but aside from five wells drilled at Kuparuk, all have been dry holes. That includes the Ataruq No. 2 and Ataruq No. 2A dry holes that Kerr-McGee drilled in the proposed unit area in 2005. Brooks Range said that previous attempts to extend production from the Kuparuk Formation west of Kuparuk over the past decade led to discoveries west and north of the proposed Southern Miluveach unit,but that low oil prices and rising drilling costs in the early part of the 2000s stymied those efforts by requiring discoveries to be huge. As a consequence, operators found it difficult to explore for economically challenged, marginal prospects. Brooks Range believes Southern Miluveach contains several marginal oil prospects that could be economic using new seismic technology and a multiyear drilling program. Costs to date include Ataruq wells The Brooks Range joint venture includes TG World Energy, Inc. and Ramshorn Investments, Inc. Kerr McGee (now owned by Anadarko Petroleum)and Eni own working interests in several leases at the unit. The joint venture acquired its first leases in the area at an October 2003 lease sale and grew its position through lease sales and private deals over the following seven years. The working interest owners have spent$15 million to date, according to Brooks Range, a figure that includes the two Ataruq wells and a proprietary 3-D seismic acquisition in 2008 covering 200 square miles in and around the greater Southern Miluveach area. The state is taking comments on the unit proposal through July 28. /"Sb#4"#\,„ Brooks Range Petroleum 510 L Street, Suite 601, Anchorage, AK 99501 Phone: 907-339-9965 Fax: 907-339-9961 Attention: Dan Seamount, Chair/Alaska Oil& Gas Conservation Commission Date: 06/15/11 Address: 333 West 7th Ave., Suite 100 Anchorage, AK 99501 Sent By: Larry Smith File Under: Brooks Range Petroleum—North Tarn 1 Transmitting: 4,og— Schlumberger ProVision Real Time Service 91' —6222.6', 1:600 'Log— Schlumberger ProVision Real Time Service 91' — 6222.6', 1:240 £Log—Schlumberger Vision Services Real Time & Recorded 91' — 6222.6', 1:600 'Log—Schlumberger Vision Services Real Time & Recorded 91' —6222.6', 1:240 (AD—Schlumberger ProVision & Vision Services! I ' r l -6og—Halliburton Freepoint Survey, scale 5" .-Log—Halliburton Perforating Record, scale 5" -og—Halliburton Temperature Log, scale 5" 'Log—Halliburton String Shot Backoff, scale 5" i Log—Halliburton Freepoint Survey, scal 2.5" Description: Additional Comments: SN 70 006 Please sign and Fax to 907-339-9961 .r 4v`e61115On Cjanloovei0 Signature Date Page 1 of 10 2. / — 60I Brooks Range Petroleum Corporation 510 L Street,Suite 601 *Anchorage,AK 99501 *Phone(907)339-9965* Fax(907)339-9961 May 09, 2011 Mr. Dan Seamount, Chairman RECEIVED Alaska Oil and Gas Conservation Commission MAY 0 ?011 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 Alaska Oil & Gas Com Ganmissron Annerage RE: Well completion Report: Brooks Range Petroleum Corporation,North Tarn#1 Permit to Drill No: 211-001 API No: 50-103-20633-00-00 Dear Commissioner Seamount, Brooks Range Petroleum Corporation is submitting the Well Completion Report for the work performed in drilling its North Tarn#1 (NT-1)exploration well on the North Slope. Please find enclosed the following documents for your files: • Form 10-407 -Well Completion or Recompletion Report and Log • Final Wellbore Diagram • Well As-Built and Ice Pad Configuration Survey • Well Survey Report • Summary Report of Operations If you have any questions or require additional information, please contact me at: (907) 865-5840 or Alket Mici at(907)264-6130 Sincerely, BROOKS RANGE PETROLEUM CORPORATION Bart Armfield Vice resident—Operations d/L4,40 41V d{o-u-aza- cc: Alket Mici - SolstenXP STATE OF ALASKA ALASK L AND GAS CONSERVATION COMMIS& . WELL COMPLETION OR RECOMPLETION REPORT AND LOG irl'i 1 a.Well Status: Oil ID Gas Ill SPLUG ❑ Other El Abandoned 0 Suspended❑ 1 b.Well Class:20AAC 25.105 20AAC 25.110 Development ElExploratory t GINJ❑ WINJ ❑ WAG ❑ WDSPL❑ No.of Completions: Service ❑ Stratigraphic Test ❑ 2.Operator Name: 5.Date Comp.,Susp.,or 12.Permit to Drill Number: Brooks Range Petroleum Corporation Aband.: 4/10/2011 ' 211-001 3.Address: 6.Date Spudded: 13.API Number: 510 L Street,Suite 601,Anchorage,AK 99501 3/13/2011 50-103-20633-00-00 4a.Location of Well(Governmental Section): 7.Date TD Reached: 14.Well Name and Number: Surface: 2388 FSL 1780 FEL S2 T1ON R7E UM 3/22/2011 North Tarn 1 Top of Productive Horizon: 8.KB(ft above MSL): 15.Field/Pool(s): 1717 FSL 2423 FEL S2 T1ON R7E UM GL(ft above MSL): Exploratory Total Depth: 9.Plug Back Depth(MD+TVD): 1717 FSL 2423 FEL S2 T1ON R7E UM 2,097 4b.Location of Well(State Base Plane Coordinates,NAD 27): 10.Total Depth(MD+TVD): 16.Property Designation: Surface: x- 465198.000 y- 5940773.000 Zone- 4 6223'MD/6147'TVD ADL 390680 TPI: x- 464553.000 y- 5940104.000 Zone- 4 11.SSSV Depth(MD+TVD): 17.Land Use Permit: Total Depth: x- 464553.000 y- 5940104.000 Zone- 4 None N/A 18.Directional Survey: Yes ❑ No E 19.Water Depth,if Offshore: 20.Thickness of Permafrost MD/TVD: (Submit electronic and printed information per 20 AAC 25.050) N/A (ft MSL) 1,346'MD/1,338'TVD 21.Logs Obtained(List all logs here and submit electronic and printed inforrmation`per 20AAC25.071): 22.Re-drill/Lateral Top Window MD/TVD: G `` e-,5 0 e.w (s + `r Lt,^ -\. 1V t....`C t'6 v� N/A 23. CASING,LINER AND CEMENTING RECORD WT.PER SETTING DEPTH MD SETTING DEPTH TVD AMOUNT CASING GRADE TOP BOTTOM TOP BOTTOM HOLE SIZE CEMENTING RECORD FT. PULLED 16" 65 N/A 0 80' 0 80' 44 Cement to surface: N/A 33bbls 9-5/8" 40 L-80 0 2,347' ./ 0 2,347' 12-1/4" Cement to surface:231 bbls N/A I 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) i compLacrd 26. ACID,FRACTURE,CEMENT SQUEEZE,ETC. a, ; . u DEPTH INTERVAL(MD) AMOUNT AND KIND OF MATERIAL USED i . I - 27. PRODUCTION TEST Date First Production: Method of Operation(Flowing,gas lift,etc.): Date of Test: 'Hours Tested: Production for Oil-Bbl: Gas-MCF: Water-Bbl: Choke Size: Gas-Oil Ratio: Test Period —p. Flow Tubing Casing Press: Calculated Oil-Bbl: Gas-MCF: Water-Bbl: Oil Gravity-API(corr): Press. 24-Hour Rate .► 28. CORE DATA Conventional Core(s)Acquired? Yes ❑ No ►? Sidewall Cores Acquired? Yes ❑ No,g If Yes to either question,list formations and intervals cored(MD+TVD of top and bottom of each),and sum rize lithology and presence of oil,gas or water 704,1 (submit separate sheets with this form,if needed).Submit detailed descriptions,core chips,photograoh910 laboratory analytical results per 20 AAC 25.071.}6• *0 RECEIVED i�'i'( g, ,1 Q ABDMS MAY 10 ZO11 ii) puska Oil&Gay Cana.fmrrission Incrrerege Form 10-407 Revised 12/2009 CONTINUED ON REVERSE 93 -,/71( Submit original only .) tIF 29. GEOLOGIC MARKERS (List all formations and markers encountered): 30. ,i', FORMATION TESTS NAME MD TVD Well tested? ❑ Yes I'1 No If yes, list intervals and formations tested, briefly summarizing test results.Attach separate sheets to this form,if Permafrost-Top 0 0 needed,and submit detailed test information per 20 AAC 25.071. Permafrost Base 1346 1338 Surface Casing 2347 2325 K10 top 2576 2551 K10 Base 2656 2629 Torok Fm. 4205 4158 Iceberg Sand 4524 4470 N Tarn TARGET 4987 4926 C35 marker 5173 5108 Moraine Sand(C30 Ss) 5549 5479 HRZ 5905 5831 Kalubik 6025 5950 K-1 6111 6035 Kuparuk C 6198 6121 TD 6223 6147 Formation at total depth: Kuparuk C 6198 6121 31. List of Attachments: Well Schematics,Well As-Built, Summary Report of Operations 32. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: A.Mici(907)264 6130 Printed Name: Bart Armfield Title: VP-Operations Signature: 46it,.0 ,644 'jj a(' �p�Phone: (907)339 9965 Date: S/ ) /... j/ 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 1 b: 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 23: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 24: If this well is completed for separate production from more than one interval(multiple completion),so state in item 1,and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced,showing the data pertinent to such interval). Item 27: Method of Operation: Flowing,Gas Lift,Rod Pump, Hydraulic Pump,Submersible,Water Injection,Gas Injection,Shut-in,or Other (explain). Item 28: Provide a listing of intervals cored and the corresponding formations,and a brief description in this box. Submit detailed description and analytical laboratory information required by 20 AAC 25.071. Item 30: Provide a listing of intervals tested and the corresponding formation,and a brief summary in this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Form 10-407 Revised 12/2009 North Tarn # 1 Post P & A Wellbore Diagram •,•,•,• ,.,•,. Am ❖oaAi.. 16" Conductor ".' .z.: 65 lbs/ft •,.,o. •°o• set @ 80' MD/TVD •••.••' •••••• • oa .o ..•, •4 .♦ .. .,.,., •,• ., .,. .;.••, *1:1 •4 •,.• .4 .,.� ••• •,. .,.• . . .•.•• 00 .,•, •;. .,.i • •. .• •. 9 5/8" Casing k. •.• L-80, 40lbs/ft .;1 2•4 gg ••• 0 •,• ON V �i- Top of Cement @ 2,097' Casing MD @ 2,347 Plug #3 - Drill Pipe Cut @ 2,547' Bottom of Cement unknown Top of Plug @ 5,125' Plug #2 8 1/2" Open Hole ~ Bottom of Cement unknown/ Top of Cement @ 5,771' Perforations in DP Plug # 1 @ 5,970' NT # 1 TD 6,223' MD / 6,147' TVD 3L eF ' cc .s! _ s�� ;+ O 111 j a o .O 0 0 o-- r_ ��4 • qjZe. • • .." . 3016 W Q 0366 . =...,, 0 4-,dF -.! 4 J •a wUmj oc q,Ioc=•[ilQ , II Q O NN Lei m �mZ0 in ✓2 ` aa N o ✓f �.. ��� 366 Z I— W (� U N cc �0� o �Qa J J� aO o N~Ci ¢ a� a d Xt. ! O �! 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D 8p5 / d P� a . ,.....-- \ / 7 / / V L.—.% (V(. / o 5 ;0 s 63 � ,` 0 6, — w • / i)/ /\ Brooks Range Petroleum Corporation Summary Report of Operations Brooks Range Petroleum Corp.-North Tarn-1 (PTD#211-001) Start Date: 8 March, 2011 March 8- 12, 2011 0' MD MW 0 ppg Vis N/A Incl 0° Rig move. General rig up. Take spud mud. Test Diverter system on March 11 Perform diverter function test. Test annular and knife valve functions. Test PVT, LEL and flow, LEL, H2s and fire alarms. All tests witnessed by AOGCC's John Crisp. March 13, 2011 1315' MD MW 9.5 ppg Vis 280 Incl 0° Thaw out hole fill pump and suction lines. Day light saving time advance. Fill HP mud lines with water and test 500/3500psi. Drill F 104' to 107' with water, Displace with 8.8ppg spud mud Drill F 107' to 130' Up Wt. 50k S/0 wt. 50klbs. 410gpm 230psi 35rpm. Tool orientation SLB calibrate draw works encoder. POH, Blow down top drive. P/U LWD & MWD Scribe same. RIH, Drill F/ 132' to 187' Up wt. 65klbs S/0 l 65klbs Rt. Wt 65klbs 404 gpm 306psi. POH F/ 187' Stand back HWDP Blow down top drive P/U Monel DC& saver sub RIH. Drill F/ 187' TO 377 - Hst. Wt. 70K Slk wt. 70K -432 GPM @ 530psi -40 RPM. DRIG. 377' to 560' - Hst/Slk /Rot Wt. 72K -432GPM @ 570 PSI - 40RPM 1.8K tq. POH w/ 1 std HWDP @ RIH with stand with Jars. DRLG from 650" to 1315' Hst . Wt. 90K S/O. Wt. 85K- Rot. Wt 90K- 185SPM = 545 GPM. at 1310 PSI - WOB =25K -D30 Tq=2.8 K / AST= 1.72 / ART =6.48. Note: Max Gas 466 units from 1662' MD. March 14, 2011 2355' MD MW 9.5 ppg Vis 280 Incl 1.5° Drill F/1315'- 2358' TD - 2333' TVD of surface section confirmed by BRP geologist. Circ and condition mud @ 2358' Recip & rotate 650gpm 1550psi Reduce pump rate to 350 Gpm 650psi on down stroke. Increase mud weight to 9.5 due to gas sand and 1000units of gas. Blow down top drive Monitor well POH ( wiper trip F-2358' up to 1900 No excessive over pulls pumping or back reaming. RIH F/ 1900to 2358'Tag bottom with pumps off no fill, hole slick. Circulate Recip pump at 650 gpm CBU -Ck for trip gas ( B/U gas 350units) Shut down. Pumps monitor well - blown down top drive. POH ( wiper trip to BHA ) no tight spots pumping or back reaming, Decision made to Continue to POH and run casing. Stand back HWDP and jars, Lay down Stab- Hold PJSM - Lay down MWD—LWD. B/0 bit and lay down Mud Motor- clean up floor. Hold PJSM on rigging up casing tools. Pick up casing tools and rig up floor to run 9 5/8 casing SolstenXP 1 of 11 9 May 2011 March 15, 2011 2355' MD MW 9.5 ppg Vis 160 Incl 5.5° Rig up 9-5/8" casing tools - elevator, spider and tongs. Rig up air lines and install Franks fill-up tool on top drive. Make up shoe track (3 jts). Install 3 bow-spring centralizers, fill pipe and check floats. Run 59 jts 9-5/8", BTC, 40#, L-80 casing w/ 16 centralizers and 4 stop collars. Install 9-5/8" Tam collar at 500.89'. P/U Vetco 9-5/8" hanger and landing jt. Land casing on landing ring with 108 klbs. Circulate casing while RIH at 1,450' and 2,159' @ 5 bpm, 390 psi. No tight spots or packing off while running casing. Rig down casing tools, clear rig floor. Load non-rotating cementing plugs into Halliburton cement head, rig up cement head & lines. Circulate and condition mud at 5 bpm, 380 psi. Initial mud returns 9.6 ppg, 560 vis. Temp 40 deg. Reciprocate pipe while circulating. Up wt 124k lbs, do wt 108k lbs. Wait on new card for Halliburton cement blending unit. Continue circ at reduced rate 75 spm, 83 gpm. PJSM. Repair complete on blending unit. Blow down cementing lines. March 16, 2011 2355' MD MW 9.5 ppg Vis 160 Incl 5.5° Cement 9-5/8" casing: Pump 10 bbls wtr to fill lines, test to 3,800 psi. Drop bottom plug and pump 40 bbls 10.5 ppg dual spacer followed by 414 bbls 10.5 ppg, 19.3 gps lead cement w/ a yield of 14.15 ft3/sk. Followed w/47 bbls of 15.9 ppg, 5 gps w/a yield of 1.19 ft3/sk. Pump 10 bbls of OBM to launch top plug. Displace cement with 173 bbls of 9.6 ppg OBM - 1.4 bbls over calculated volume of 171.6. ✓ Bump plug and hold 1600 psi (500 psi over displacement pressure) for 5 min. Bleed off, floats held. CIP at 03:32 w/ 100% returns. Clean up & RD floor. Clean cellar, nipple down diverter, remove starting head. Install Vetco Gray Multi-bowl MB-230 wellhead & test 9-5/8" lower multi adapter head void to 5,000 psi for 15 min. Install secondary valve on tubing spool. March 17, 2011 2355' MD MW 9.6 ppg Vis 60 Incl 5.5° NU BOPE: N/U annular and double gate. Build mud cross w/ kill and choke line valves. N/U single gate. Clean out mud pump suction screens. Complete cleaning all mud pits. Nipple up choke and kill lines. Start loading pits with OBM (103bbIs). Continue to nipple up BOP's. Hook up koomey lines. Change out block on kill line. Finish changing out flow block on choke line. Torque up bolts on DSA to well head and tubing spool. Take measurements for flow line and have welder modify same. Install air boot on top of annular and secure stack with turnbuckles. Hook koomey lines to single gate and choke & kill valves. Grease manifold valves. Function test BOP's and related components. PJSM. Pick up test joint / plug, TIW & dart valve. Fill stack and equipment with water and body test BOP's and choke manifold - good test. SolstenXP 2 of 11 9 May 2011 March 18, 2011 2355' MD MW 9.6 ppg Vis 60 Incl 5.5° Shell test BOPE. Clean/clear cellar. Test BOPE and all related components to 250/3500 psi. Test flow and PVT monitors. Test LEL and H2S alarms. All tests passed. Pull test plug, set wear bushing. Lay down test jt. Test witnessed by Chuck Scheve & Matt Herrera of AOGCC. Blow down all test lines, choke lines, top drive and kill line.Thaw out ice plug in kelly hose. Suspect kelly hose has internal damage. Rig down kelly hose - new hose enroute from NAD Deadhorse yard. Remove old hose from stand pipe and lay down same. Service top drive and drawworks. New hose on location but too frozen to work with. Move BHA XO's and pups up to rig floor. PJSM & P/U drill pipe from shed while thawing out new hose.Total of 60 jts DP picked up. March 19, 2011 2378' MD MW 9.6 ppg Vis 60 Incl 5.5° Install new rotary hose and test to 3,500 psi - OK. POH with drill pipe and stand back. P/U and drift 5" drill pipe and RIH. POH and stand back. POM test on casing 1500 psi. Good test. PJSM. Make up 8-1/2" hole section BHA: P/U motor, 4x LWD tools, MWD. Load source and run model DC from derrick. RIH with jars and HWDP to 500'. Rotate into Tam collar with no problem. Continue running HWDP. Pulse test BHA. Blow down mud lines. RIH P/U drill-pipe (33 joints) to 2,000'. Rig up and test 9-5/8" casing to 3,000 psi for 30 min. Initial pressure 3,250 psi, final pressure 3,090 psi. (Pressure sensor not reading correctly on first 2 tests.) Circulate and rotate while RIH. Tag up on plugs/float collar at 2,267'. Drill float V equipment, cement and 20' new hole to 2,378'. Circulate hole clean for LOT with 9.6 ppg MW. March 20, 20114080' MD MW 9.6 ppg Vis 60 Incl 5.5° Perform LOT w/ 9.6 ppg MW at 2,336' TVD. 560 psi = 14.2 ppg EMW. Drill 2,378'-2,504'. Up wt 115k, dn wt 110k, RT 1.1k ft-lbs, 400 gpm @ 1400psi. C&C mud @ 2,504' w/ 250 gpm, 730 psi due to what appeared to be excess cuttings. Drill 2,504'-2,983'. Up wt 1225k, dn wt 120k, rot wt 115k, 80 rpm, 525 gpm, 2410 psi. Circulate, clean up cuttings in hole. Drill 2,893'-3,556'. Up wt 137k, dn wt 128k, rot wt 133k, AST .14, ART 4.52, ADT 4.66. 525 GPM, 2,230 psi off btm, 2,410 psi on btm, Tq. 2K-4K, jars 23.4 hrs. Circulate hole after making cnxn. Stage pumps up slow to 500 GPM @ 2,250 psi. Had returns than lost them. SD pumps and stage them on slowly - no returns. Stand back 1 stand. Slowly back ream while circ. &staging pumps up f/225 GPM @ 615 psi to 365 GPM @ 1,235 psi, 50 RPM, 1.4k tq, 135k rot wt. Regain returns. Initial mud loss 28 bbls. POH 3,365' to 3,215' w/ correct fill. Monitor well, getting small amount of mud back (breathing). Service top drive, crown and drawworks. Well stabilized - no flow. RIH to 3,460', wash down to 3,556' @ 325 gpm, 1080 psi, 40 rpm, 1.5K tq. Drill 3,556'-4,080'. 500 gpm, 2209 psi off/2380 psi on btm, 80 rpm, 1.6k tq off/3.1k on btm, 8-10k WOB, up wt 146k, dn wt 135k, rot wt 142k. SolstenXP 3 of 11 9 May 2011 March 21, 2011 5,663' MD MW 9.6 ppg Vis 97 Incl 9° Drill 4,080'-4,718'. Up 152, dn 142k, rot 157k, Tq 2.4k f-lb, rpm 80, gpm 500, 2,180 psi. Drill 4,718'- 5130'. Control drill 100 fph for LWD logging. For interval 4,900'-5,130': Up wt 170k, dn wt 154k, rot wt 165k, tq 3-4k f-lb, 80 rpm, 500 gpm, 2,400 psi. Control drill 5,130'-5,177' at 100 fph. Drill 5,177'-5,663' at normal rate. Circulate and condition mud for wiper trip (boot on drilling nipple leaking). Monitor well, survey, POH (wiper trip) to repair drilling nipple riser. Pull ten stands wet. Pump pill. Blow down top drive and POH up into shoe. Good displacement- no problems. Replace air boot on riser. March 22, 2011 6223' MD MW 10.4 ppg Vis 107 Incl 9° Continue to change out boot on drilling riser. Service rig. RIH 2,334' - 3,365'. Ice falling out of derrick. Remove ice from derrick, large chunks falling to rig floor. Continue RIH 3,365' -5,568'. Fill pipe and wash down to 5,663'. Tag bottom, no fill. Drill 5,663' - 6,047'. Control drill 150 fph for mud loggers 6,047' - 6,109'. Decrease PR to 50 fph 6,109' - 6,223'. 3% increase in flow out. P/U to 6,202'. Shut pumps down and check for flow. Well flowing, shut well in. Had 4 bbl gain. SICP 300 psi, SIDPP 220 psi. Monitor well. Calculate kill weight mud and circ schedule using driller's method while weighting up pits to 10.1 ppg kill mud weight. Fill choke&gas buster(SIDPP dropped to 150 psi). Open well with choke and circulate 10.1 ppg mud around at 30 SPM w/260 psi DP pressure. Monitor well through choke after 10.1 ppg mud had been pumped around - well still flowing. Shut well back in and raise mud wt to 10.4 ppg and start same going down hole at 10.4 ppg in and 10.2 ppg out 29 SPM. 290/310 psi on DP and 150 psi on choke. March 23, 2011 6223' MD MW 10.4 ppg Vis 106 Incl 9° Well control: Circ through choke, weight up mud system to 10.4 ppg. Shut down and monitor well on choke. SIDPP 50 psi, SICP 200 psi. Control bleed in 5 min intervals. 43.3 bbls bled thru choke. SIDPP 30 psi, SICP 200 psi. Circ 10.4 ppg OBM thru choke at 30 spm, 70 psi. Fluid level down in drill-pipe. Shut down, monitor well. SIDPP 30 psi, SICP 420 psi. Monitor well on choke, cont bleed process w/o success. Roll pumps and pump through top drive and standpipe to prevent freeze-ups. All surface mud at 10.4 ppg. Circulate through choke 10.4 ppg, SIDP 30 psi, SICP 290 psi. Lost 245 bbls mud. Mix 40 bbl lost circulation pill w/G-seal and calcium carb at 25# per bbl. Pump 36 bbl LCM pill. Usable pit volume 141 bbls. SIDP 30 psi, SICP 400 psi. Pump 5 bbls 10.4 ppg mud to prevent kelly hose from freezing. Wait on OBM from MI plant. SICP rising. Bleed off from 450 psi to 380 psi. Bleed SIDPP from 30 to 20 psi. Start pumping 10.4 ppg mud followed by 32 bbl 10.5 G-seal, Safe Carb LCM pill. Begin thinning mud back with LVT-YP too high. Continue weighting up to 10.4 ppg. By end of tour had gained 84 bbls back from well. MUD wt in 10.4 ppg, out 10.3 ppg.SIDPP 200 psi,SICP 190 psi, 12,620 stks. SolstenXP 4 of 11 9 May 2011 March 24, 2011 6223' MD MW 10.4 ppg Vis 106 Incl 9° Well control: Continue pumping 10.4 ppg OBM adding 8sx of G-seal per hr. Well control: Wt up mud system to 10.5 ppg adding 25 ppb Safecarb and 10#per bbl G-seal. Shut in and monitor well. 0 psi DP, 240 psi on casing. Cont circulating at 30 spm, 180psi. Shut down and monitor well. DP 0 psi, casing 240 psi. Continue circ 10.5 ppg. Close annular preventer, open upper rams. Strip through annular 6,202'- 6,155'. Cont mix and pump G-seal and Safecarb LCM. Maintain mud wt 10.5 ppg while pumping through choke. DP 0 psi, casing 280 psi. After 15 min DP 0 psi, casing 360 psi. Total 44.6 bbls returned. SICP rose to 390 psi. Begin pumping after 98 bbls pumped. SIDPP 150 psi. Spot 29 bbls 11.7 ppg pill with G-seal LCM on bottom, 30 spm @ 190 psi. PJSM with crews on bleeding off well. Test lines going to bleed tanks @ 500 psi with nitrogen -test good. Begin pumping and taking returns to tiger tank 26 spm, SIDPP 50 psi, 410 SICP before opening choke. No strap on tank at end of tour. Mud gain for tour 55 bbl. March 25, 2011 6,223' MD MW 10.7 ppg Vis 97 Incl 9° Well control: Bleed wellbore annulus through super choke and down secondary choke to tiger tanks. With choke full open,SICP dropped f/440 psi to 170 psi. Unload flow-back mud from tiger tanks back to mud pits. Weight up mud system to 10.7 ppg. SIDPP 40 psi, SICP 330 psi. Samples show 9.6 ppg oil-cut mud returning. Final sample showed 10.4 ppg oil/gas cut mud. Shut in well and let annulus pressure build up. SIDPP 50 psi, SICP 330 psi. Strip drill-string through annular to park tool joint 3" above rotary table. Break off full stand and set back. Continue to monitor casing annulus pressure build-up. Pressure increased to 1,300 psi then dropped to 1,285 psi after 3 hrs and remained static. Monitor pressure. At 23:59 SIDPP 0 psi, SICP 1,290 psi. PJSM with Halliburton wire-line crew on rigging up to run noise/temperature log. Spot wire-line unit and start hoisting tools to rig floor. March 26, 2011 6223' MD MW 11.7 ppg Vis 107 Incl 9° P/U HES lubricator, M/U BOPE, nipple up to top of drill pipe in rotary table. Test to 3,000 psi. P/U temperature and sonic noise tools, RIH to 5,990'. Run temp and noise survey log. POH. with tools and L/D. (No indication on log of cross flow in wellbore.). P/U spangs, 2 sinker bars and source retrieval tool. RIH, latch up on top of LWD. Pull 1,600 lbs wire-line weight, shear pin on nuke source, POH, and recover sources. Rig down Halliburton lubricator& BOP's. Unload 30 bbls of 10.7 ppg mud and start raising mud weight in pits to 11.7 ppg. Send 290 bbls back to plant to also be weighted up to 11.7 ppg. General housekeeping and rig maintenance while waiting on trucks to return with mud. End of tour SIDPP = 0 psi, SICP= 1265 psi SolstenXP 5 of 11 9 May 2011 March 27, 2011 6223' MD MW 11.7 ppg Vis 106 Incl 9° Well control: Monitor well, build mud volume. SICP 1300 psi. SIDPP 0. Start pumping 11.7 ppg OBM @ 30spm. SIDPP increased to 70 psi. DPP increase to 220 psi. Reduce CP 10 psi per 100 stks. Choke open -venting gas on initial flow back to tiger tank. Then 8 ppg crude with gas changing to 11.4 - 11.5 ppg OBM. Last sample 11.4 ppg. SICP 0. Shut down pumps and monitor well for 10 minutes. P built to 70 psi. Line up choke to gas buster in pits, blow down line to tiger tank. Start pumping at 2 bpm. CP 120, DDP 0, no returns to pits. Pump 40 bbls Mix2 LCM. Displace LCM pill out the bit. Shut down pump. CP=0, DDP=0 after 15 minutes. Open rams. Able to move pipe - 220k up, 165 dn. Fill hole w/5 bbls. Monitor for 30 min. Well static. Fluid dropping in stack down to mud cross then began raising fairly fast and going down the flow line. Returns steadily went from 4% up to 28%. Shut well in with upper rams. SIDPP = 30 psi, SICP 130 psi. Fill pipe with ki charge pump. With choke 1/2 open, saw crude-cut returns at 10.8 ppg. March 28, 2011 6223' MD MW 11.7 ppg Vis 106 Incl 9° Well control: Monitor well. SIDPP 0 psi, SICP 1,250 psi. Build mud volume.DPP increasing f/0 to 386 psi, CP increased f/ 1,250 to 1,330psi. Line up and pump down DP at 2 bpm. SIDPP dropped to 40 psi, SICP down to 1,300 psi. Shut well in. Pressure increased to 330 psi,SICP remained at 1,270 psi. Pump 36 bbl 25#/bbl Mix2 LCM pill and spot at 6,139'. Monitor well, build mud volume. Take on second load of mud. SIDP 30 psi, SICP 1,232 psi. Monitor well, wait on truck to return w/ 11.7 ppg mud. SIDP 30 psi, SICP 1,232 psi. Shut in TIW, break out top drive and install pump-in sub. Hook up circ hose. Truck with 290 bbls mud on location at 20:30. SICP 1,260 psi, SIDP 30 psi. PJSM with all hands and Halliburton. Begin pumping 11.7 ppg OBM. Initial SIDP 40 psi, SICP 1,250 psi. Saw DPP pressure increase after 2901 stks (206 bbls). 151 bbls back to tiger tank. Mixed with crude, unusable. March 29, 2011 6223' MD MW 11.7 ppg Vis 106 Incl 9° Pump 11.7 ppg OBM, taking returns through choke to ASRC_gas separator to tiger tanks.0020 hrs - returns are gas. 0040 good 10.3 ppg OBM. Divert returns to tank #2. Halliburton start mixing Thermatek pill. Switch over to Halliburton, pump 5 bbls LVT. Test lines to 3,500 psi. Start pumping Thermatek at 4-1/2 bpm, 1100 psi, build to 1250 psi 1st 50 bbs. Cut rate to 4 bpm @ 1190 psi.At 65 bbs slow to 3 bpm, 890 psi. Last 10 bbs pumped at 2-1/2 bpm, 610 psi. Displace pill out of drill string. Shut down, blow down Halliburton lines. Monitor well. SICP 160 psi, SIDPP 30 psi. Pump 3 bbls OBM down back side at 16 spm. Increased SICP to 170 psi. Fill DP w/ charge pump. Loosing 67 bph. SICP built to 520 psi. Halliburton mixing 2nd pill. Halliburton pump 5 bbl LVT. Test to 3500 psi. Pump 21 bbl pill, chase with 5 bbl LVT. Spot pill out of bit, left 5 bbl LVT in DP. Shut choke when pill left the bit. Initial returns gas then recovered 41 bbls 11.4 ppg OBM. SICP 340 psi, DP on vac. Blow down lines. LOGGING009:30Pump through choke to separator at 42 spm, 30 psi. Pump 49 bbls to catch fluid in DP. SolstenXP 6 of 11 9 May 2011 After circ 11.4 ppg returns, able to go to rig gas buster. Mud loss for tour 998 bbls. Continue pumping 11.7 ppg OBM taking returns through choke back to gas buster at 28 spm. March 30, 2011 6223' MD MW 11.7 ppg Vis 106 Incl 9° Well control: Pump 11.7 ppg OBM taking returns to ASRC separator and tiger tank. Sample returns. Mud wt returning 10.3 ppg oil/gas cut OBM. Rig up and pump/spot HES 15 bbl Thermatek pill at 6,139'. Blow down HES lines. Pump 3 bbl 11.7 ppg OBM down drill pipe. Pump 3 bbl OBM on annulus. ICP 170 psi, DP 30 psi. Monitor well SIDPP 30 psi SICP 160 psi, increasing to 520 psi. Let HES pill soak. Pump 21 bbl HES Thermatek LCM pill. Displace out of drill-pipe with 100 bbls 11.7 ppg OBM and spot in hole. Shut in choke and monitor losses. Fill pipe and circ at 2 bpm keeping hole full. SICP 170 psi. Shut down pumping to rig up HEC to run wire-line plug and perforate HWDP. Rig up wire-line sheaves. BOPE, lubricator and control hoses. Run cement line to pump-in sub. P/T lub &wire-line BOP to 3,300 psi. RIH w/ HES SVB 3.00" packer/plug and set in top of jars at 5,771'. POH, LD running tools. Build mud volume, monitor well. SICP 1280 psi SIDPP 0 psi. March 31, 2011 6223' MD MW 11.7 ppg Vis 106 Incl 9° Well Control: Monitor well, SIDPP 0 psi, SICP 1280 psi. Wait on OBM. M/U perforating gun ( 10',4 spf,0 phase, 40 shots total). Test lubricator to 3,300 psi. RIH, tag plug at 5,771' WLM, space out guns. Top shot 5,742', btm shot 5,752'. Fire guns, DP on vacuum, line wt increased 1,000 lbs. POH, LD lubricator and gun (all shots fired). Pump down DP w/ 11.7 ppg OBM taking returns through choke out to ASRC separator then 500 bbl tiger tank. DPP 120 psi, CP 1,280 psi. Cont. circulate out gas in annulus, pump 60 bbl LCM pill with 35 bbl tail at 90 ppb mix of LCM. Spot in annulus and let soak 2 hrs. Attempt to pump down drill-pipe, pipe on vacuum. Total loss of 622 bbls 11.7 ppg OBM during pumping. Monitor well, wait on OBM from plant. Fill pipe w/ 28 bbls. SIDPP 0 psi, SICP 1,380 psi. Pump 11.7 ppg OBM down hole taking returns through choke to ASRC separator at 28 spm. Final DPP 40 psi, SICP 450 psi. PJSM w/ Halliburton cement crew. Blow through cement line. Line up Halliburton, pump 5 bbls H2O. Test lines to 3,500 psi. Pump 15 bbl spacer,40 bbls 15.8 ppg cement, 5 bbls H2O. Chase w/93 bbls 11.7 ppg OBM. Close choke last 40 bbls. 570 psi gain on SICP, up to 840 psi. CIP at 20:05 hrs. Monitor well. Blow down lines to Halliburton. SICP increased to 900 psi. Pump 28 bbls down DP w/charge pump. SICP increased to 1,050, DP not full. Wait on cement. SICP 1,150 psi, SIDPP 20 psi. Hands cleaning pits in preparation for change to water base mud. Total mud loss for last 12 hour 342 bbls. Total losses for 24 hrs 964 bbls. SolstenXP 7 of 11 9 May 2011 April 1, 2011 6,223' MD MW 11.7 ppg Vis 106 Incl 9° Well Control: Monitor well, SIDPP 0 psi, SICP 1280 psi. Wait on OBM.M/U perforating gun ( 10', 4 spf, 0 phase, 40 shots total). Test lub to 3,300 psi. RIH, tag plug at 5,771' WLM, space out guns. Top shot 5,742', btm shot 5,752'. Fire guns, DP on vacuum, line wt increased 1,000 lbs. POH, LD lubricator and gun (all shots fired). Pump down DP w/ 11.7 ppg OBM taking returns through choke out to ASRC separator then, tiger tank. DPP 120 psi, CP 1,280 psi. Cont circ out gas in annulus, pump 60 bbl LCM pill with 35 bbl tail at 90 ppb mix of LCM. Spot in annulus and let soak 2 hrs. Attempt to pump down drill- pipe, pipe on vacuum. Total loss of 622 bbls 11.7 ppg OBM during pumping. Monitor well, wait on OBM from plant. Fill pipe w/ 28 bbls. SIDPP 0 psi, SICP 1,380 psi. Pump 11.7 ppg OBM down hole taking returns through choke to ASRC separator at 28 spm. Final DPP 40 psi, SICP 450 psi. PJSM w/ Halliburton cement crew. Blow through cement line. Line up Halliburton, pump 5 bbls H2O. Test lines to 3,500 psi. Pump 15 bbl spacer,40 bbls 15.8 ppg cement, 5 bbls H2O. Chase w/93 bbls 11.7 ppg OBM. Close choke last 40 bbls. 570 psi gain on SICP, up to 840 psi. CIP at 20:05 hrs. Monitor well. Blow down lines to Halliburton. SICP increased to 900 psi. April 2, 2011 6223' MD MW 11.7 ppg Vis 106 Incl 9° Well control: Wait on 11.7 ppg OBM f/ plant. Monitor well. SIDP 0 psi, SICP 1,090 psi. Pump down DP through choke to ASRC separator at 42 spm w/ 0 psi. Pumped 9.4 bbls to catch up w/ fluid in DP. Slowed pump down to 2 bpm. FCP 460 psi. Initial gas returns of 1.4 mcfd dropping to .5 mcfd followed by zero gas and no returns of OBM. SICP 0 psi. Open rams- no fluid. Pump 5 bbls OBM down annulus. Could not see fluid. Shut well in. Open rams, pump 2 bbls to prevent freezing. Slack off string to 30 K below original string wt. No jar bleed indications. Pull up to 290K (100k over PU wt). Slack off to 185K. Shut well in and monitor pressures. SIDPP 0 psi, SICP 0 psi. Clean pit #1 and prep cut wt of water base mud. Clean screen #1 MP. Both sides 0 psi. Make preprations for pumping cement. Tour losses 278 bbls. Test kill line 250/3,500 psi, 5 min each. Place cement plug: PJSM w/ Halliburton & crew. Halliburton pumped 5 bbls H2O,test lines to 3,500 psi. Pump 8 bbls H2O, 25 bbls 15.8 ppg G cmt, 5 bbls H2O and chase with 87.8 bbls 11.7 ppg OBM. Blow down lines to Halliburton. Wait on cement. Initial SIDPP 200 psi, down to 100 psi end of tour. Remove wire-line lubricator from pipe shed. Break out 5' pup and pump-in sub from string and blow down circulating lines. Hoist side door entry sub & swivel up to rig floor. Work on water base mud in pits-cutting weight back to 11.0 ppg. April 3, 2011 6223' MD MW 11.7 ppg Vis 106 Incl 9° Wait on cement. SIDPP dropped to 20 psi, SICP 30 psi. Rig up sheave for Halliburton Wire-line. Make up side door entry sub and swivel joint w/ DP on top and bottom. Off load LVT and stage in truck. Clean slop tank in pits. Make up HES pack off and temperature survey tools and MU to top drive with temperature tool, tag cement at 5,125'. Bleed 30 psi off the back side. Open pipe rams and fill hole with 5 bbls LSND hi vis spacer. RD temperature survey tool. Make up free point tool and calibrate. MU SolstenXP 8 of 11 9 May 2011 side door assembly and circ hose. RIH w/free point tool. Check points at 2,000 & 3,500' -free. RIH to 5,104' - no movement. Log up hole and confirm free point at 4,356'. POH with tools and rig down same. Make up string shot and RIH. Apply left-hand torque to drill string and work pipe to get torque down hole. Problems with in-string swivel, had to use tongs.14K left hand tq, fire shot at 4,365'. No indication at rig floor of it going off. POH to verify shot went off - it had fired. PU 20' pup and stand side door assembly in derrick. Pick up joints of DP and make up to top drive. Work 20K left hand tq into string. Connection broke on top and bottom of TIW valve on the down stroke. Screw back into valve. Lay down single. Inspect threads and re-torque connections. Pick drill string up to confirm no other connections broken. Note: No fluid loss after 15:00 hrs. April 4, 2011 6223' MD MW 11.7 ppg Vis 106 Incl 9° Free point/back off. Torque string to 18k ft-lbs,work torque down. Attempt to break pipe free. P/U side door entry swivel assy. Make up string shot #2. Make up top drive. RIH w/ HES string shot on E- line to 4,369', space out and park. Work 20k ft-lbs torque down to tool joint at 4,363'. Fire string shot - no surface indication of back off. Remove torque from string. Lay down string shot, R/D wire-line. Work drill string. Rig down side entry swivel assembly and stand back. Standby for orders. MU side entry sub/swivel assy. Load 10' gun 4 spf, 0 deg phasing. Space out gun below tool joint at 5,000', w/ upper shot at 4980, lower shot at 4990'. Fire gun, POH, B/O swivel, lay guns down. All shots fired. Rig up lines to circulating head, attempt to circ out perfs 4,980' to 4,990'. Pressure up to 1950 psi. Unable to circulate. B/O circ head, P/U swivel. Start to load perforating gun. Wait on Halliburton wire line tools (guns). RIH w/ 10' gun , 4 SPF. Fire at 4,850' to 4,860'. POH, confirm all shots fired. S/B side door assembly, rig up headpin. Attempt to circ at 1,300 psi, 28 spm - no luck.Wait for Halliburton guns-stuck behind rig move. Hands clean up outside of rig. Make up 10', 6 spf gun and RIH. April 5, 2011 6223' MD MW 11.7 ppg Vis 106 Incl 9° RIH w/ 10', 6 spf 60 deg ph perforating gun. Set to shoot at 4,730'-4,740', fire gun. POH, lay down gun, all shots fired. Attempt to circulate 1 bbl per min. Pipe pressured up to 740 psi w/o returns. RIH with 10', 6 spf perforating gun. Set on depth 4,630'-4,640', fire gun. POH, lay down gun, all shots fired Attempt to circulate 1 bbl per min. Pipe pressured up to 755 psi w/o returns.RIH w/ 10', 6 spf, 60 deg ph perforating gun. Set to shoot at 4,530'-4,540', fire gun. POH, lay down spent gun. Attempt to circulate at 1 bpm, 557 psi. Pumped 6 bbls w/o returns. Bleed off, 6 bbls returned. RIH w/ 10', 4 spf, 0 phs perforating gun. Set to shoot at 4,410'-4,420',fire gun. POH, LD spent gun. Attempt to circulate w/o success. MU free point tool, RIH. Place string in neutral w/ 125k lb. P/U string to 235k lb 3x. Run free point tool. Tool indicated pipe free at 3,468'. POH, lay down free point tools. Rig down HES wire-line tools and move off location. Re-head line for Y sub for SLB. PJSM w/crews, R/U SolstenXP 9 of 11 9 May 2011 SLB free point tools and E-line. Had to hand feed wire into lubricator until it had enough wt to pull itself down. Start working pipe and checking for free point. Establish free pipe in casing and stuck pipe. at 3800'. Made 10 different checks between 2,320' and 3,800'RIH w/ 10', 6,spf 60 deg ph perforating gun. Set to shoot at 4,730'-4,740', fire gun. POH, lay down gun, all shots fired. Cut DP, displace hole with water base mud. Set cement plug. POH, test BOP's.0:00 to 06:00 Make 3 more free point checks. POH w/ FP tool. Change E-lines. April 6, 2011 6223' MD MW 11.7 ppg Vis 106 Incl 9° Run SLB free point tool 3,700'to 3,000'. Locate free point at 3.474',_POH, lay down free point tools. RD .39" line and head. Re-head and install packoff on .23" e-line. Make up at 3,474'. POH,. Make up packoff assembly to Y sub. PU Swetek DP severing tool/charge. RIH, locate tool joint at 3,474'. Fire charge. POH, lay down tools. Verify charge fired. Rack back Y sub assy. MU top drive to drill string. Attempt to free drill string. P/U, work pipe up to 450k lbs very little movement. Continue to work pipe and attempt to free up string. Start mud pumps to hydraulic out stuck pipe w/o success. Cont pumping. Flow rate increased w/ gas Increasing. Start displacing 11.7 ppg OBM w/ 11.0 ppg WBM. Shut upper pipe rams and continue displacement through choke and gas buster. At 4,500 stks open pipe rams, cont displacement at 7 bpm with gas breaking out at bell nipple. After 2 btms up gas cleared up and flow rate stabilized at 12%. Circ until all mud returns are 11 ppg WBM. Shut down pumps, monitor well. Well continuing to flow, decreasing after 15 min. Resume working pipe in tempt to free up. Apply 3 rounds LH torque while working pipe. Pull up to 450k lb w/ no progress. Increase pump rate to 660 gpm, 600 psi w/ no success. Circulate and condition. Shut off pump. Well static w/ 11 ppg MW. Blow down lines and manifold. Circ w/ headpin 210 gpm, 260 psi. Reduce to 125 gpm, 136 psi. RIH/ Swetek severing tool. Shoot at 3,089'. POH, SB side door stand. Attempt to work the pipe free. Pull up to 450K while pumping 450 gpm, 350 psi w/ no success. Circ while waiting for SLB to load next tool (130 gpm, 140 psi). 30 jts drill pipe on pipe racks,total of 30 Jts in derrick. 165 jts in string. April 7, 2011 6223' MD MW 11.7 ppg Vis 106 Incl 9° Run Swetek back off charge on e-line. Locate tool joint at 2,829'. Fire charge, good indication at surface charge fired (lost 5k lb on wt indicator after shot). POH w/e-line. Attempt to break Y sub assembly out of top drive w/o success. Repair top drive grabber box dies. Had to lay down side door sub assembly. DP single, circ at 600 gpm. Work string up to 450k lb over string weight with no pipe movement. Continue working pipe in attempt to free up string. PU side door entry sub and MU to jt of DP. Circ w/ headpin 3 bpm, 124 to 140 psi while waiting for SLB to make up new High Performance severing charge. RIH with SLB and fire severing tool at 2.547'. _POH with wire-line. PU 20' pup and stand back side door entry/swivel assembly in derrick. Pipe free. POH with 4 stands past FS and FC. RIH back to 2,574'. Break circ. Circ and condition while waiting for Halliburton cementers. Halliburton pump 5 bbls H2O. Test lines to 3,500 psi. Pump 8 bbls H2O, 37 bbl of 15.8 ppg cement, 5 bbls H2O and displace with 29 bbls mud. POH 5 stds slowly. Pipe flowed back. Stab TIW, M/U top drive, pull up to 1,974'. Circ and SolstenXP 10 of 11 9 May 2011 condition until mud balanced out to 11 ppg all the way around. Clean up rig floor. OH. Break 3 singles off bottom of top drive stand to allow getting top drive down to floor to break off TIW valve. Pull 4 more stands up to 1,592. Latch onto stand in derrick that has side door sub and swivel on it. April 8, 2011 2347' MD MW 11.7 ppg Vis 106 Incl 9° Rig down wire-line side-entry Y swivel assembly and SLB wire-line, Slip and cut drilling line. Service rig: top drive, crown and drawworks. Pump dry job, BD mud lines, POH. Lay down joint with shot tool joint. 85 joints 5", 19.50#, 5-135 drill pipe lost in hole. Also lost 20 joints 49.50# HWDP in hole. Make up plug on test joints, pull wear bushing. Set test plug, RU test joint. Fill stack with H2O. Test BOPE and all related components 250/3500 psi, 5 min test. Test LEL, H2S alarms, PVT and flow system. Perform accumulator draw-down test. Test super& manual chokes to 1,000 psi. Tests witnessed by AOGCC rep Chuck Scheve,John Nicholson (BRP), Bill Bixby (NAD), K. Sullivan operating test pump. Lay down test jt, rig down all test equipment. Blow down all lines & choke manifold. Repair rig, change out air actuator valve on top drive. Test IBOP 250/3,500 psi-OK. Attempt to test TD air actuator valve- NG. Blow down and prepare to remove failed IBOP & top actuator valve. #6 choke valve serviced and re-tested, good test. April 9, 2011 2347' MD MW 11.7 ppg Vis 106 Incl 9° Repair rig: Remove top drive saver sub and lower air-actuated IBOP. Install new lower IBOP and test to 3,500 psi. Make up 8-1/2" mill tooth bit and bit sub w/float. RIH to 1,900'. Wash down tag cement at 2,097'. Set 5k down to confirm cement top. (250' above shoe at 2,347'.) Circulate and condition mud, cut MW from 11 ppg to 9.6 ppg. Circ at 535 gp, 180 spm, 425 psi. Pump dry job, blow down mud lines, POH. Lay down drill pipe from 2,097' (68 joints). RIH with 3 stands from derrick and lay down same. PJSM. Pick up 5" drill pipe from shed and RIH making up stands. POH with 20 stds. RIH with 60 joints pipe from shed. POH and stand back 20 stands.Total of 120 joints picked up. April 10, 2011 2347' MD MW 11.7 ppg Vis 106 Incl 9° P/U, drift and RIH with 5"drill pipe. POH standing back.RIH with 8-1/2" bit, HWDP and jars to 2,097'. Drill firm cement 2,097'to 2,317'. Circulate and condition mud at 2,317'. Pump dry job, blow down mud lines. POH from 2,317'. LD bit and bit sub. Clean rig floor. Service rig: top drive, blocks, swivel, crown. Load pipe shed w/ 51 joints 7" casing. Load out 5" drill pipe used for cementing. Change out lower pneumatic IBOP valve on top and test along with TIW valves. All tests 250 low/3500 high. Change oil in top drive, service iron rough neck and drawworks. PU BOP test tools, pull wear ring. MU ported sub. Flush stack, RU to test BOP's. RIH with test plug and fill stack with water. Re-set test plug. 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Ip<ly W m �I�I'!00 Gg ; u 00000 0 aaaa ndmed0 aammm 0NNNN @ ,_N J N I ro.. • p pGp p p po ”84$ [Ip p GOp�p cqS• ..R^ -1 3 " OM gag �S<gON gSS$`Y $n 8 28 !zQg0•0 • J 11Si�g 9!, 5i 18RII Bill a fl %m b o o ELL 0g H e , Co 0.0.0. E Z % 8OOiI� 0 O petroleun FUII �..--- n r? w s FREE Sul sc, Home tdvrrti ing Sbscript ons PUbf cations ' http://www.petroleumnews.com/pnads/127482408.shtmlD \\- \\ —cS- \ North Tarn, winter's only North Slope exploration well, finds oil 13-a-— \ \ Print this story I Email it to an associate. A joint venture led by Brooks Range Petroleum Corp. found oil at a North Slope exploration well this year, but won't be able to fully test the well until next winter. The companies spud the North Tarn No. 1 well on March 13 from an ice pad two miles west of the Kuparuk River unit and reached a measured depth of 6,223 feet by March 22, deep enough to test reservoir targets in the Brookian and the deeper Kuparuk sandstones. The companies did not log the Kuparuk sandstones and could not estimate net pay, though, because of"well control challenges,"according to partner TVI Pacific Inc., the Calgary-based independent that acquired TG World Energy Corp. earlier this year. "Minor gas kicks and oil shows occurred in the shallower Brookian target sandstones but were much lower-permeability than expected. ... On penetration of the Kuparuk zone, there were strong mud gas shows with high oil-cut mud and gas flow to surface tanks," the company said, adding that"a period of well control operations from March 22 until April 2 was required before mud losses and hydrocarbon flows to surface tanks stopped." Kuparuk estimated at 20-25 feet Based on sandstone cuttings and gas readings taken from the well, TVI Pacific estimated the Kuparuk to be about 20 to 25 feet thick at North Tarn No. 1. That would be comparable to the thickness of the Kuparuk Cl sandstone in the nearest Kuparuk River well, located 2.4 miles to the east, and the 2L-03 well drilled a mile to the south in 2002. On April 11, the companies drilled a"substitute well"using the existing surface hole. By April 14, the well reached a measured depth of 6,086 feet, to the base of the Kalubik formation,just above the Kuparuk C sand, and the companies set intermediate casing. The companies drilled the well using Nabors rig 9ES. BRPC is operating the program on behalf of its parent company, the Kansas-based Alaska Venture Capital Group LLC, as well as three joint venture companies: Brooks Range Development Corp., Ramshorn Investments Inc. and TVI Pacific. "Our team is very encouraged by the information obtained from the North Tarn well," Ken Thompson, managing director of AVCG LLC, said about the results so far. North Tarn No. 1 was the only exploration well on the North Slope this winter. The joint venture farmed-in six Eni Petroleum leases at North Tarn in January 2010 and recently applied to form the Southern Miluveach Unit, covering 56,460 acres in the area. —Eric Lidji WELL LOG TRANSMITTAL PROACTIVE DiAgNOSTIC SERVICES, INC. To: AOGCC Dan Seamount 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 (907) 659-5102 RE : Cased Hole/Open Hole/Mechanical Logs and/or Tubing Inspection(Caliper/ MTT) The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the following : ProActive Diagnostic Services, Inc. Attn: Robert A. Richey 130 West International Airport Road Suite C Anchorage,AK 99518 Fax: (907) 245-8952 a i t (-06 1 Q09,_0 1) WLD/Temp Log 26-Mar-11 North Tarn#1 BL/ EDE 50-103-20633-00 2) RECEVED 410 APR ? 2011 Signed : Date : Print Name: 11110Make 011& .Commiss Anchoraoe PROACTIVE DIAGNOSTIC SERVICES, INC., 130 W.INTERNATIONAL AIRPORT RD SUITE C, ANCHORAGE, AK 99518 PHONE: (907)245-8951 FAX: (907)245-88952 E-MAIL: pdsanchorage(_D,memorylog.com WEBSITE:www.memorvloq.com C:\Documents and Settings\Diane Williams\Desktop\BrooksRange_Transmitdocx • SEAN PARNELL,GOVERNOR ALASKA, OIL AND GAS 333 W.7th AVENUE,SUITE 100 CONSERVATION COMMISSION ANCHORAGE,ALASKA 99501-3539 PHONE (907)279-1433 FAX (907)276-7542 Bart Armfield VP - Operations Brooks Range Petroleum Corporation �11 Q 0 t 510 L Street, Suite 601 Anchorage, AK 99501 Re: Exploratory Field, Exploratory Pool, North Tarn - 1 Sundry Number: 311-067 Dear Mr. Armfield: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Daniel T. Seamount, Jr. Chair DATED this4day of April, 2011. Encl. / /)/\/\ Brooks Range Petroleum Corporation RECEIVED March 7, 2011 MAR 0 7 201 Mr. Dan Seamount, Chair ?Mks Gil&Gas Cons.Commission Alaska Oil and Gas Conservation Commission Int/Drage 333 West 7th Ave., Suite 100 Anchorage, Alaska 99501 RE: Sundry Application to P&A Brooks Range Petroleum Corp.: North Tarn#1 (PTD#211-001) Dear Mr. Seamount, Brooks Range Petroleum Corporation proposes to plug and abandon its North Tarn #1 well. Although, the well has not been drilled yet, the plan is to plug and abandon this well to -3000' MD and to drill the North Tarn-1A sidetrack exploratory well. The wireline and mud logs from this well will be reviewed with your staff for their concurrence on the cemented intervals and our plan to abandon them. The P&A procedure of the North Tarn#1 will be accomplished using two cement plugs as indicated on the attached wellbore diagram and procedure. The wellhead will be left intact on the well. The following documents are included as attachments: 1) Completed form 10-403 Sundry Application 2) P&A procedure 3) Proposed Post P&A well diagram If you have any questions or require additional information, please contact me at 339- 9965 or Natasha Sachivichik at 575-7156. Sincerely, S RANGE PETROLEUM CORPORATION �►— Bart Armfield, 111 Vice President-Operations 591111- .,d-?€.1 STATE OF ALASKA C°2' RECEIVED ALASKA OIL AND GAS CONSERVATION COMMISSION MAR 01 2U1` APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 • 1.Type of Request: Abandon Q • Plug for Redrill❑ Perforate New Pool❑ Repair Well E *94V-angA r°o�r e Suspend❑ Plug Perforations❑ Perforate❑ Pull Tubing❑ ' irttea�i;i.?nsion❑ Operations Shutdown❑ Re-enter Susp.Well❑ Stimulate❑ Alter Casing E Other: ❑ 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: Brooks Range Petroleum Corporation Development ❑ Exploratory Q • 211-001 . 3.Address: Stratigraphic ❑ Service ❑ 6.API Number: 510 L Street,Suite 601,Anchorage,AK 99501 50-103-20633-00-00 - 7.If perforating,closest approach in pool(s)opened by this operation to nearest 8.Well Name and Number: property line where ownership or landownership changes: - Spacing Exception Required? Yes ❑ No North Tarn-1 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL 390680 ' Exploratory - 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD(ft): Effective Depth TVD(ft): Plugs(measured): Junk(measured): 6480 • 6389 . 6480 6389 None None Casing Length Size MD TVD Burst Collapse Structural Conductor 80 16" 80 80 N/A N/A Surface 2500 9 5/8" 2500 2474 5750 3090 Intermediate Production Liner Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): N/A N/A N/A N/A N/A Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft): N/A N/A 12.Attachments: Description Summary of Proposal Q 13.Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory Q • Development ❑ Service ❑ 14.Estimated Date for Apr-01-2011 15.Well Status after proposed work: Commencing Operations: Oil ❑ Gas ❑ WDSPL ❑ Suspended ❑ 16.Verbal Approval: ywj 5-c1.w.4K.Tt.Date: 41-Z-ft WINJ ❑ GINJ ❑ WAG ❑ Abandoned Q • Commission Representative: GSTOR ❑ SPLUG ❑ 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact N.Sachivichik 575-7156 Printed-Pda ie Bart Armfield Title VP-Operations Signature ,,t7lb , ,`'\ Phone 339-9965 Date 31iJ l I COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: \ I —COI Plug Integrity J // BOP Test g. Mechanical Integrity Test ❑ Location Clearance ❑ Other: /VOT• (17 _T-h -, hr a-5 ; /;C<le,O ....r3 52,O p5 s"r- Subsequent Form Required: /o —gl U 7 '0 / APPROVED BY 4ii(S31 ) IApproved by: �MMISSIONER THE COMMISSION Date: • :D� ; ; 1 ORIGINAL . - s ��•; Form 10-403 Revised 1/2010 Zf•/r Submit in Duplicat Brooks Range Petroleum Corporation N Tarn #1 (PTD # 211-001) General P&A plan 1. Ensure regulatory compliance training is complete and key personnel are fully aware of responsibilities. 2. Pick up and stand back enough 5" drill pipe and HWDP. 3. Notify the AOGCC of intent to commence P&A operations and plans 4. PU 5" Drill pipe and run to td. 5. Pump the first cement plug according to the agreed cementing procedure. Balance the plug and pull above the plug slowly. Circulate mud to clean the DP. 6. Pull drill pipe to the Plug#2 setting depth. Circulate mud before pumping cement 7. Pump the second cement plug according to the cementing procedure. Balance the plug and pull above the plug slowly. Circulate mud to clean the DP. 8. Wait on cement. Tag top of cement to confirm the plug is set at the correct depth. tisre_cAirr 9. Prepare to perform an open-hole sidetrack for the North Tarn-1A drilling.. - r At this point the North Tarn-1 will be considered P&A-ed. North Tarn # 1 Proposed Post P&A Wellbore Diagram 16" conductor set @ 80' A NAD/TVD • �t, Ka F Ma l 2-3____5 '1141)J66fMD, 9-5/8",40#, L-80, BTC casing 4 TaL �Saad _ Maximum Hole angle 11 deg at 4800' Plug#2 Hole angle at TD 9 deg 81/2" Open Hole l•0702 0152/0-.) Plug#1 NT-1 TD 6,484' MD/6,398'TVD ns 2/27/11 Brooks Range Petroleum Corporation ./1/\,/ t\s, Cementing Services North Tarn 1 Brooks Range Petroleum Corporation North Tarn 1 8-1/2" OH Plug Well Conditions Hole Size 8-1/2" Volume Excess 30% Mud Wt. 9.5 ppg Mud PV/yP 16/24 MD 6,602' TVD 6,453' Prey.Csg: 9-5/8"40#/ft BHST 105°F Previous Casing Depth: 2,660' BHCT 85°F Objective: $et a series of balanced plugs from TD to 5,014'across the oil bearing zone(KUP C and North Tarn Sands) in the 8-1/2"OH section. Slurry Recommendation: Balance plug calculations will be provided prior to the job. Plug 1:6,600'to 5,514'—Not to be Tagged Spacer 20 bbl 11 ppg Dual Spacer Slurry: 99 bbl—231 Sks. Premium Cement,3%Econolite,+.5%CFR-3,+0.5%Halad-344,and HR-5 as required Plug 2:5,514'to 5,014'—To be Tagged Spacer 20 bbl 13 ppg Dual Spacer Slurry: 45.6 bbl—223 Sks. Premium Cement,+ 1%Calcium Chloride,+0.2%CFR-3,+0.5% Halad-344,and HR-5 as required Spacer Plug 1 Slurry Plug 2 Slurry Density(ppg) 11/13 12 15.8 Yield(cu ft/sk) 2.41 1.15 Water requirements(gal/sk) 14.3 5 Thickening Time Hr:min. 3:00—4:00 3:00-4:00 Volumes based on: Tail Slurry: Top of slurry—5,014'MD 1,586' calculated 8-1/2"OH volume+30%excess HALLIBURTON 19 Brooks Range Petroleum Corporation ~\)/\. Cementing Services North Tarn 1 Brooks Range Petroleum Corporation North Tarn 1 8-1/2" OH Plug - Kick Off Plug Well Conditions Hole Size 8-1/2" Volume Excess 30% Mud Wt. 9.5 ppg Mud PV/yP 16/24 Prey. Csg: 9-5/8"40#/ft BHST 60°F Previous Casing Depth: 2,660' BHCT 55°F Objective: Set a 500'balanced plug from 3,500'to 3,000'in the OH section to provide a plug to sidetrack to the well. Slurry Recommendation: Balance plug calculations will be provided prior to the job. Spacer 20 bbl 11 ppg Dual Spacer Slurry: 45.6 bbl—259 Sks. Premium Cement,+.5%CFR-3,+0.5%Halad-344,and HR-5 as required Displacement: Mud Spacer Tail Slurry Density(ppg) 11 17 Yield(cu ft/sk) 0.99 Water requirements(gal/sk) 3.82 Thickening Time Hr:min. 3:00—4:00 Volumes based on: Tail Slurry: Top of slurry—3,000'MD 500' calculated 8-1/2"OH volume+30%excess HALL1BURTON 20 / /)/ /\ Brooks Range Petroleum Corporation April 4, 2011 P&A Procedure for North Tarn#1 (PTD #211-001) Currently the drilling BHA and a part of the drill string are cemented in place in the well from TD at 6223' to 5105'. No pressure is seen in DP and the annulus side. Drill pipe is stuck with a free point indicated by stretch calculations at 3500'. Free point e-line tool indicated the free point at 4356', however, the DP did not show any movement until the free point was pulled above the 3500' mark. The following procedure is prepared to finalize the P&A of the North Tarn# 1. 1. Run perforating guns to 5000' and perforate holes in DP with 10 ft gun with 4 spf. Note: If unable to establish circulation through perfs at 5000', another set of perforations will be attempted 100' shallower, or until a full circulation rates can be achieved. 2. Establish circulation with OBM(currently in the DP and in the annulus). 3. Circulate 11 ppg water based mud around until the mud weight is balanced inside and outside. 4. Mix and pump cement plug of 35to cover 700' the depth from 5000' (perfs) to 4200'.Note, the only uncovered with cement sand interval is at 4524' MD (top). 5. After the cement plug is placed, attempt to back off the drill string at 3500' (free point depth). 4-„4* or 6. Back off the drill string, establish circulation to clean the DP and POOH. 7. Once the DP is out of hole,perform a full BOP test. 8. Run back to 3500' —DP cutoff depth and tag 9. Mix and pump cement plug with bottom at 3500' and top at 3000'. At this point a decision will be made to either suspend the well until the next drilling season or to drill a sidetrack NT-1A. Schwartz, Guy L (DOA) From: Natasha Sachivichik[natasha.sachivichik@solstenxp.com] Sent: Thursday, April 07, 2011 10:31 PM To: Schwartz, Guy L(DOA) Cc: Rig16e_super; Bill Penrose;Armfield Bart; Darrah Bo; Larry Vendl Subject: RE: Cementing plan after the DP cut at-2550' Guy, ?1 P 2-1/- (70/ We have set the cement plug of at least 400' from the pipe cut at -2550' to 2150' (200' inside the surface shoe) . We've applied some squeeze pressure staying below the shoe strength limit. We believe, we have at least 200' of cement inside the shoe. Currently, pulling out of hole for a BOP test. After the BOP test we will tag the top of the plug and report our tag depth. Regards, Natasha Sachivichik Senior Drilling Engineer 310 K Street, Suite 700 Anchorage, AK 99501 MAIN (907) 264-6100 DIRECT (907) 264-6116 CELL (907) 575-7156 natasha.sachivichik@solstenxp.com Original Message From: Schwartz, Guy L (DOA) [mailto:guy.schwartz@alaska.gov] Sent: Thursday, April 07, 2011 8:47 PM To: Natasha Sachivichik Cc: Rig16e_super; Bill Penrose; Armfield Bart; Darrah Bo; Larry Vendl Subject: Re: Cementing plan after the DP cut at -2550' Very good . . Thanks for the update. Guy Sent from my iPhone On Apr 7, 2011, at 6:51 PM, "Natasha Sachivichik" <natasha.sachivichik@solstenxp.com> wrote: > Guy, > We cut the pipe at 2547' successfully. The pipe got free. > We are planning to pump the cement plug at 8:30 pm tonight as described in the approved plan. > I will send you an update in the morning. > Thanks, > Natasha Sachivichik > Senior Drilling Engineer 1 > > > 310 K Street, Suite 700 > Anchorage, AK 99501 > MAIN (907) 264-6100 > DIRECT (907) 264-6116 > CELL (907) 575-7156 > natasha.sachivichik@solstenxp.com > Original Message > From: Schwartz, Guy L (DOA) [mailto:guy.schwartz@alaska.gov] > Sent: Thursday, April 07, 2011 9:59 AM > To: Natasha Sachivichik > Cc: Rigl6e super; Bill Penrose; Armfield Bart; Darrah Bo; Larry Vendl > Subject: RE: Cementing plan after the DP cut at -2550' > Natasha, > The proposal is acceptable. When squeezing we don't want to break down the shoe however as you state below. > Guy Schwartz > Senior Petroleum Engineer > AOGCC > 793-1226 (office) > 444-3433 (cell) > Original Message > From: Natasha Sachivichik [mailto:natasha.sachivichik@solstenxp.com] > Sent: Thursday, April 07, 2011 9:53 AM > To: Schwartz, Guy L (DOA) > Cc: Rigl6e_super; Bill Penrose; Armfield Bart; Darrah Bo; Larry Vendl > Subject: Cementing plan after the DP cut at -2550' > Guy, > Based on our phone discussion, > We are planning to perform the following steps after we cut the pipe at approximately 2550' . > 1. Cut the pipe at -2550' > 2. Prepare to set 400' of cement plug (200 ft in the OH and 200' inside casing) . > 3. Set a balanced plug. > 4. Pull the DP above the cement plug and apply squeeze pressure . Do not exceed the shoe LOT value of 14.2 ppg (1700 psi) . > 5. Squeeze cement until top of cement at 100 ft above the surface casing shoe. > 6. POOH while circulating the DP clean. > 7. Perform BOP test. > At this point the well will be secured. > Please let me know if this plan is accepted by the commission. > Natasha Sachivichik > Senior Drilling Engineer > 310 K Street, Suite 700 > Anchorage, AK 99501 > MAIN (907) 264-6100 > DIRECT (907) 264-6116 > CELL (907) 575-7156 2 > natasha.sachivichik@solstenxp.._,.,m > Original Message > From: Schwartz, Guy L (DOA) [mailto:guy.schwartz@alaska.gov] > Sent: Thursday, April 07, 2011 9:01 AM > To: Natasha Sachivichik; Rigl6e super; Armfield Bart; Bill Penrose; > Darrah Bo > Subject: RE: Cutting DP at 2550' - 200ft below the surface shoe. > Natasha, > You have approval to cut 200' below surface shoe. . good luck. > Guy Schwartz > Senior Petroleum Engineer > AOGCC > 793-1226 (office) > 444-3433 (cell) > Original Message > From: Natasha Sachivichik [mailto:natasha.sachivichik@solstenxp.com] > Sent: Thursday, April 07, 2011 9:00 AM > To: Natasha Sachivichik; Schwartz, Guy L (DOA) ; Rigl6e_super; Armfield > Bart; Bill Penrose; Darrah Bo > Subject: RE: Cutting DP at 2550' - 200ft below the surface shoe. > Guy, > As we discussed this morning we are planning to cut the DP at +/-200' below the shoe. > I will keep you informed on the progress. > Thanks, > Natasha Sachivichik > Senior Drilling Engineer > 310 K Street, Suite 700 > Anchorage, AK 99501 > MAIN (907) 264-6100 > DIRECT (907) 264-6116 > CELL (907) 575-7156 > natasha.sachivichik@solstenxp.com > Original Message > From: Natasha Sachivichik > Sent: Thursday, April 07, 2011 8:05 AM > To: 'Schwartz, Guy L (DOA) ' ; 'Rigl6e_super' ; 'Armfield Bart' ; Bill Penrose; 'Darrah Bo' > Subject: Cutting DP at 2450' - 100ft below the surface shoe. > Guy, > I left you are message on your office phone. > Last night we made two cuts on the DP at 3089' and at 2850' . > We could not get the DP free in either depth. > We would like to make a new cut at 2450' it is 100 ft below the surface shoe. > If we are not successful, we are proposing to cut at the shoe at 2347' and attempt to get free at the shoe. 3 > Please let us know as soon as possible if this plan is acceptable. > Thanks, > Natasha Sachivichik > Senior Drilling Engineer > 310 K Street, Suite 700 > Anchorage, AK 99501 > MAIN (907) 264-6100 > DIRECT (907) 264-6116 > CELL (907) 575-7156 > natasha.sachivichik@solstenxp.com > Original Message > From: Natasha Sachivichik > Sent: Wednesday, April 06, 2011 9:52 PM > To: 'Schwartz, Guy L (DOA) ' ; Rigl6e_super; Armfield Bart; Bill > Penrose; Darrah Bo > Subject: Cutting DP at 2850' > Guy, > I am letting you know that the pipe was cut at 3070' . After the cut the pipe did not move at all. > It seems to be stuck all the way. > We are now moving up hole and will try to cut the pipe at 2850' , it would be 500' below the shoe (2347 ' ) . > Hopefully, we will be successful at this depth. > The rest of the plan stays the same. > I will keep you updated on the progress. > Thanks, > Natasha Sachivichik > Senior Drilling Engineer > 310 K Street, Suite 700 > Anchorage, AK 99501 > MAIN (907) 264-6100 > DIRECT (907) 264-6116 > CELL (907) 575-7156 > natasha.sachivichik@solstenxp.com > Original Message > From: Schwartz, Guy L (DOA) [mailto:guy.schwartz@alaska.govl > Sent: Wednesday, April 06, 2011 3:53 PM > To: Natasha Sachivichik; Rigl6e_super; Armfield Bart; Bill Penrose; > Darrah Bo > Subject: RE: Cutting DP at 3100'-3200' > Natasha, > 3100' for a cut depth is acceptable. > Guy Schwartz > Senior Petroleum Engineer > AOGCC 4 > 793-1226 (office) • > 444-3433 (cell) > Original Message > From: Natasha Sachivichik [mailto:natasha.sachivichik@solstenxp.com] > Sent: Wednesday, April 06, 2011 3:47 PM > To: Schwartz, Guy L (DOA) ; Rigl6e super; Armfield Bart; Bill Penrose; > Darrah Bo > Subject: Cutting DP at 3100'-3200' > > Guy, > Here is an update from the N Tarn' > The DP was cut at 3474 ' this morning, however the rig was not able to > pull it out. They tried different methods to free the pipe, but were > not successful. > We are getting ready to make another cut and would like to make it 300' > above the previous cut depth. > This will place us at +/- 3100' . > The well is stable. > Please let us know as soon as possible if we can perform the cut at > 3100' and try to move the pipe. There are strong indications that the > hole is collapsing around the DP. > Thanks_ > > Natasha. 5 Page l of 3 Schwartz, Guy L (DOA) From: Schwartz, Guy L (DOA) Sent: Tuesday, April 05, 2011 4:06 PM To: 'Natasha Sachivichik' Cc: 'Bill Penrose'; 'Rig16e_super'; 'Bart Armfield'; DOA AOGCC Prudhoe Bay Subject: RE: N Tarn ops update Natasha, I wanted to add that right after the drillpipe is cut a cement plug of about 500'should be pumped before pipe is pulled out of the well for the BOP test. (I wasn't sure if you were planning on POOH right after cutting to do the BOP test from your email below) . We don't have a solid fullbore plug (without drillpipe in the way)and we need to make very sure that the well is secure while we do the BOP test. Once the BOP test is completed you can run in with pipe, tag the cement plug and then lay in a kickoff plug at the casing shoe. Guy Schwartz Senior Petroleum Engineer AOGCC 793-1226 (office) 444-3433 (cell) From: Schwartz, Guy L (DOA) Sent: Tuesday, April 05, 2011 1:40 PM To: 'Natasha Sachivichik' Cc: Bill Penrose; Rig16e_super; Bart Armfield Subject: RE: N Tarn ops update Natasha, You have conditional approval based on a free point depth of at least 3500' md. The pipe may be cut here and POOH for the needed BOP test. A cement plug above the stub will be needed of course and the placement will be determined by BRP desire to drill a Sidetrack off this point. If the pipe is stuck above that point we will need to discuss some other options. Regards, Guy Schwartz Senior Petroleum Engineer AOGCC 793-1226 (office) 444-3433 (cell) From: Natasha Sachivichik [mailto:natasha.sachivichik@solstenxp.com] Sent: Tuesday, April 05, 2011 9:26 AM To: Schwartz, Guy L (DOA) Cc: Bill Penrose; Rig16e_super; Bart Armfield Subject: RE: N Tarn ops update Guy, As we discussed on the phone,we have perforated the DP in 5 intervals over> 500 ft . They tried to circulate, but were unable to establish circulation, however, the pressure is bleeding down at low Page 2 of 3 rate.(not enough to establish a reasonable injection of> 1 bbl/min). The last perf interval is at 4440'-4450'.They applied pressure of 560 psi and tried to squeeze mud into the perfs and the injection was poor. The pressure slowly bled down to 0 psi in 5 min; no returns were seen at surface. We are asking the commission if we could cut the drill pipe at a free point depth and place a balanced cement plug of at least 500' with a free pipe. After pulling out from the cement plug we could apply some squeeze pressure (not exceeding the surface casing show LOT of 14.2 ppg) to attempt to squeeze the cement below the DP cut. Please review our plan and let us know as soon as possible if we can proceed. I will keep you updated on the progress, Thanks, Natasha Sachivichik Senior Drilling Engineer p 310 K Street,Suite 700 Anchorage,AK 99501 MAIN (907)264-6100 DIRECT (907)264-6116 CELL (907)575-7156 natasha.sachivichik@solstenxp.com From: Schwartz, Guy L (DOA) [mailto:guy.schwartz@alaska.gov] Sent: Tuesday, April 05, 2011 8:30 AM To: Natasha Sachivichik Subject: RE: N Tarn ops update Natasha, Thanks for the update... looks like you don't have much choice on perfing higher. Guy Schwartz Senior Petroleum Engineer AOGCC 793-1226 (office) 444-3433 (cell) From: Natasha Sachivichik [mailto:natasha.sachivichik@solstenxp.com] Sent: Monday, April 04, 2011 8:33 PM To: Schwartz, Guy L (DOA) Cc: Bill Penrose; Bart Armfield Subject: N Tarn ops update 4/6/2011 Page 3 of 3 Guy, Since the last communication we've perforated the DP interval 4980'-4990'. We were unable to establish circulation through the perforations. Performed a second run and perforated at 4870'. Pulled out guns and attempted to establish circulation. Unable to circulate, but saw some minor injection without returns. We believe the hole is caved in around the DP. We are preparing to perforate 100' shallower; currently waiting on perf guns. The next perf interval will be at^ 4750'. I will send you an update in the morning. Natasha. Natasha Sachivichik Senior Drilling Engineer 'A 310 K Street,Suite 700 Anchorage,AK 99501 MAIN (907)264-6100 DIRECT (907)264-6116 CELL (907)575-7156 natasha.sachivichik@solstenxp.com 4/6/2011 Page 1 of 2 Schwartz, Guy L (DOA) From: Natasha Sachivichik[natasha.sachivichik@solstenxp.com] Sent: Saturday, April 02, 2011 10:03 AM To: Schwartz, Guy L (DOA); Regg, James B (DOA); Maunder, Thomas E (DOA); Armfield Bart; Bill Penrose Subject: North Tarn - 1 Plan forward update Guy, I as we noted earlier, the BHA is stuck and the decision was made to pump cement to abandon the BHA and a part of drill string. Current DP and casing pressures are equal and stable at 35 psi. We are planning to pump 25 bbl 15.8ppg cement plug. The bottom of the plug is at 5970' at perfs in HWDP.The calculated top of the 25bbl-balanced plug would be at 5579' inside DP and outside in the annulus. The plug length is calculated as 390' in a gauged hole. This will be true in the perfectly balanced situation. After the cement is placed and set and the hole is stable, we are planning to cut the DP above the cement and pull out of hole with the remainder of dp (5500'). Please call if you have any questions. Natasha Sachivichik Senior Drilling Engineer 310 K Street,Suite 700 Anchorage,AK 99501 MAIN (907)264-6100 DIRECT (907)264-6116 CELL (907)575-7156 natasha.sachivichik@solstenxp.com From: Natasha Sachivichik Sent: Saturday, April 02, 2011 8:24 AM To: Schwartz Guy L (DOA); James Regg B; Maunder Thomas E (DOA); Armfield Bait; Bill Penrose Subject: Fwd: North Tarn Daily Drilling Report Guy, Attached is the daily report from the N Tarn- 1. We tried to move the drillstring and found that BHA is stuck. We are swapping to water based 11 ppg 4/4/2011 • Page 1 of 1 Schwartz, Guy L (DOA) From: Natasha Sachivichik[natasha.sachivichik@solstenxp.com] Sent: Friday, April 01, 2011 4:08 PM To: Schwartz, Guy L (DOA) Cc: Bill Penrose; Jim Winegarner Subject: NT-1 Weekly DrIg Rpt 04-01-11 Attachments: NT-1 Weekly Drlg Rpt 04-01-11.doc Guy, Attached is the weekly report of operations from the N Tarn-1. We are currently waiting on a load of OBM. There are some positive indications that the last cement job stopped losses and the DP pressure is not falling any longer. As soon as we get some mud,we are planning to circulate 11.7 ppg mud around, check is the well is stable and attempt to move the pipe. If the losses are cured completely, the plan is to POOH if the BHA is not cemented at the bottom, run with dumb iron BHA to log and to P&A the well. I will keep you informed through the weekend by sending DDR and quick notes on our progress. Regards, Natasha Sachivichik Senior Drilling Engineer P 310 K Street,Suite 700 Anchorage,AK 99501 MAIN (907)264-6100 DIRECT (907)264-6116 CELL (907)575-7156 natasha.sachivichik@solstenxp.com Page 2 of 2 mud now. Regards, Natasha. Begin forwarded message: From: Laurette Rose <lrose@brpcak.com> Date: April 2, 2011 7:46:59 AKDT To: Bart Armfield<brmfield@brpcak.com> Subject: North Tarn Daily Drilling Report Daily Drilling Report is attached. Happy Saturday!!! Laurette Rose Brooks Range Petroleum Office 907-865-9902 Cell 907-306-1034 Like us on Facebook: http://www.facebook.com/brpcak 4/4/2011 - SwETech AB Page 1 of 2 ChaiNIEllrmkgmlle A D _err■- ■ V •_■■ ■� YN■ INN ■ %I II AY Technology and safety- That's what we're all about- SwETech's Colliding Tool Fishing operations become extremely difficult when drill collars have to be freed. The success rate of back-off is very limited with drill collars, especially in deviated wells, and such fishing operations usually end leaving the drill collars in the hole. The problem can be minimized by severing one collar as deep as possible. Unfortunately, this operation is not feasible with conventional jet cutters since the steel thickness to be cut is too large for the maximum possible cutter diameter. Some years ago a new technique using the detonation wave collision effect became available to the oil industry. Several companies have marketed different colliding tools with success rates varying from fair to poor. Now SwETech provides five types of colliding tools: Two types with the HMX explosives and three types using HNS explosives. Tool Principle The principle of a colliding tool (picture of tool) is to detonate a rod of explosive simultaneously from its two ends. Two detonation waves are generated and travel at the same speed towards the middle of the explosive rod where they meet. At the collision point a large part of the available energy from the explosive is focused in a plane perpendicular to the rod axis. This energy ruptures the drill collar(photo). The principle is relatively simple. Getting it to work is quite difficult. The major problem in any type of colliding tool is to guarantee simultaneous initiation of the explosive. The detonation wave is propagating at about 8000 m/s (26,00 ft/s) and has to travel only one foot maximum to meet the other wave. Even a slight delay in the initiation of one of the two ends and the explosive rod will be initiated from one end only. The tool will then behave as a simple bomb which will not sever the drill collar. The SwETech Tool The main difference between the SwETech tool and other tools already on the market is the accuracy of the initiation system. Any system assembled at the wellsite cannot be as accurate as one made up at the factory. The SwETech tool is shipped fully assembled from the factory thereby guaranteeing a perfect geometry of the pyrotechnic chain which cannot be obtained by a wellsite assembly. Moreover, there is no need for a specialist from the company supplying the colliding tool to be present at the wellsite. To run SwETech"s tool, only a detonator and a bottom nose with a centralizer have to be connected to it. Another advantage of the superior initiation accuracy is that the amount of explosive has been decreased by a factor of three. Competitive tools need about 1,5 kg of - - SwETech AB Page 2 of 2 explosive to cut a 9 1/2-in drill collar. SwETech's tool needs only 0,5kg. One benefit of decreased explosive quantity is the absence of damage to auxiliary equipment-cable head, weights and CCL. Technical Specification, Colliding Detonation drill collar Cutter, CDC type 1-5 Requirements CDC CDC CDC CDC CDC TYPE 1 TYPE 2 TYPE 3 TYPE 4 TYPE 5 Length 29.5" 29.5" 29.5" 29.5" 17.9" Diameter 13/4" 13/4" 21/4" 2'/4" 1.38" Weight per CDC 5.2 kg 5.2 kg 6.5 kg 6.5 kg 4.5 kg Weight 0.5 kg 0.5 kg 0.9 kg 0.9 kg 0.2 kg explosives HMX HNS HMX HNS HNS Package 2 2 1 1 2 CDC/box CDC/box CDC/box CDC/box CDC/box Classification; 1.4S 1.4S 1.4S 1.4S 1.4S *DGR *UN No 0441 0441 0441 0441 0441 Temperature 400°F 500°F 400°F 500°F 500°F Operating5" - 8%2„ 6" and 8" 10" 6W - 4'/2" and recommendations below 9W below ©1999 SwETech AB,Sweden.Design by Swedesign.com http://www.swetech.net/cdc.html 4/8/2011 Page 1 of 3 Regg, James B (DOA) Z 1 i-fro i From: Natasha Sachivichik[natasha.sachivichik@solstenxp.com] it Sent: Thursday, March 24, 2011 9:47 AM ( 1 To: Regg, James B (DOA); Schwartz, Guy L (DOA); DOA AOGCC Prudhoe Bay Cc: Bart Armfield; Jim Winegarner; Bill Penrose; Rig16e_super; Larry Vendl Subject: RE: UPDATE2_Report of BOP use from North Tarn-1 Jim, Here is a short summary of the well control operations on the N Tarn-1. North Tarn-1 Operations since last report: During yesterday, kill mud of 10.5 ppg was circulated in attempt to remove all of the gas and oil from the wellbore. LCM was added to the mud system to stop losses and the current mud weight going in the DP and coming out the annulus is stabilized at 10.5 ppg . Actions to be taken: Currently(at 9:30 am on March-24rd) after pulling the pipe above the Kuparuk formation the rig is circulating the last few BBL through choke with annular preventer closed. We will continue operations as per drilling plan. Note: last regular BOP test was performed on the March-18th Thanks, Natasha Sachivichik Senior Grilling Engineer 310 K Street,Suite 700 Anchorage,AK 99501 MAIN (907)264-6100 DIRECT (90-7)264-6116 CELL (907)575-7156 natasha.sachivichik@solstenxp.com From: Natasha Sachivichik Sent: Wednesday, March 23, 2011 10:19 AM To: Natasha Sachivichik; 'Regg, James B (DOA)'; 'Schwartz, Guy L (DOA)'; 'doa.aogcc.prudhoe.bay@alaska.gov' Cc: 'Bart Armfield'; 'Jim Winegarner'; Bill Penrose; 'Rig16e_super' Subject: UPDATE_Report of BOP use from North Tarn-1 Jim, Here is an update on the well control situation on the North Tarn-1. A reminder: Brooks Range Petroleum is requesting that all communication related to the North Tarn-1 operations are kept confidential. 3/24/2011 Page 2 of 3 North Tarn-1 Operations since last report: Last night, a kill mud of 10.1 ppg was circulated in attempt to kill the gas/oil kick which happened at noon on March- 22nd while drilling Kuparuk formation at 6225' MD/6146'TVD (original mud weight was 9.6 ppg).The circulation of the 10.1 ppg kill mud brought gas bubble and some oil-contaminated mud.After the 10.1 ppg mud circulation was complete, another flow check was performed and the crew noted the well was still flowing.They shut in well with 90 psi SICP and 70 psi SIDPP. A decision was made to weight up to 10.4 ppg and perform a circulation through choke again. During the last 10.4 ppg mud circulation, SIDPP and SICP fluctuated around 270-300 psi.Also, during the last circulation some mud was lost and later re-gained partially. Actions to be taken: Currently(at 9:30 am on March-23rd)the well's SIDPP and SICP are stable at 270 psi. A decision was made to perform another circulation with 10.4 ppg mud to get rid of gas in the annulus. At the moment, an LCM pill with fine particulate materials is being prepared to stop/inhibit lost circulation. Additional 10.4 ppg mud was ordered from mud plant and is coming to location at around noon. Subsequent reports will be submitted later today or tomorrow morning. Thanks, Natasha. From: Natasha Sachivichik Sent: Tuesday, March 22, 2011 5:11 PM To: Regg, James B (DOA); 'Schwartz, Guy L (DOA)'; 'doa.aogcc.prudhoe.bay@alaska.gov' Cc: 'Bart Armfield'; Jim Winegarner; Bill Penrose; Rig16e_super Subject: Report of BOP use from North Tarn-1 Jim, In compliance with AOGCC Industry Guidance Bulletin N. 10-1003 dated August 9, 2010,this is to report the use of blowout prevention equipment to prevent the flow of fluids from a well. Initial Report: Date/Time of BOPE Use: March 22, 2011, 12:30—still ongoing (100 bbl left to circulate at 1.5 BPM) Well/Location/PTD Number: North Tarn#1/ PTD No. 211-001 Rig Name: Nabors-9ES Operator Contact: Operator is Brooks Range Petroleum. Contact is Jim Winegarner-907-339-9965 or Bart Armfield 865- 5840. Operations summary: While drilling an 8 1/2" hole through the Kuparuk formations the rig took a 4 BBL kick.The well was shut in immediately with the initial DP pressure of 250 psi and the Casing pressure of 360 psi. The kick pressure decreased to 140 psi on DP and 190 psi. Currently (at 5PM),the well is being killed with kill mud of 10.1 ppg,the kill operation is going as expected, approximately 120 BBL left to circulate at 1.5 BPM. BOPE Used: Pipe rams Reason for BOPE Use: Divert fluid/gas kick through choke manifold and gas buster to remove gas/fluid entrained in the mud system. Actions Taken/To Be Taken: Upon circulating the kick out, a second circulation will be conducted to make sure the wellbore is under control. BOPE used was last tested on March 18,2011. This is an initial report.Additional information and details will be submitted in the subsequent reports after the well control is established and confirmed. Regards, 2 /1/I/1111 1 Page 3 of 3 Natasha Sachivichik Senior Drilling Engineer 310 K Street,Suite 700 Anchorage,AK 99501 MAIN (907)264-6100 DIRECT (907)264-6116 CELL (907)575-7156 natasha.sachivichikPsolstenxp.com 3/24/2011 Page 1,ref rN • Regg, James B (DOA) P1-1) Z iCol e From: Regg, James B (DOA) q i( Sent: Wednesday, March 23, 2011 11:24 AM (\t(� ' To: Natasha Sachivichik; Schwartz, Guy L (DOA); DOA AOGCC Prudhoe Bay Cc: Bart Armfield; Jim Winegarner; Bill Penrose; Rig16e_super Subject: RE: Report of BOP use from North Tarn-1 Since well is exploratory, it automatically has 24 month confidentiality period; refer to 20 AAC 25.537(d) Jim Regg AOGCC 333 W.7th Avenue,Suite 100 Anchorage,AK 99501 907-793-1236 From: Natasha Sachivichik [mailto:natasha.sachivichik@solstenxp.com] Sent: Tuesday, March 22, 2011 8:02 PM To: Regg, James B (DOA); Schwartz, Guy L (DOA); DOA AOGCC Prudhoe Bay Cc: Bart Armfield; Jim Winegarner; Bill Penrose; Rig16e_super Subject: RE: Report of BOP use from North Tarn-1 Jim, Brooks Range Petroleum is requesting that all communication related to the North Tarn-1 operations including the today's event are kept confidential. Thanks, Natasha Sachivichik Senior Drilling Engineer 310 K Street,Suite 700 Anchorage,AK 99507. MAIN (907)264-6100 DIRECT (907)264-6116 CELL (907)575-7156 natasha.sachivichik@solstenxp.com From: Natasha Sachivichik Sent: Tuesday, March 22, 2011 5:11 PM To: Regg, James B (DOA); 'Schwartz, Guy L (DOA)'; 'doa.ao• ..rudhoe.bay@alaska.gov' Cc: 'Bait Armfield'; Jim Winegarner; Bill Penrose; Rig16-_ per Subject: Report of BOP use from North Tarn-1 Jim, In compliance with AOGCC Industry •'dance Bulletin N. 10-1003 dated August 9, 2010, this is to report the use of blowout prevention e• •ipment to prevent the flow of fluids from a well. 3/23/2011 Page 1 of 2 Regg, James B (DOA) P� 2 t(Cx% ( 0 From: Natasha Sachivichik[natasha.sachivichik@solstenxp.com] Sent: Wednesday, March 23, 2011 10:19 AM ` (Z3I I( To: Natasha Sachivichik; Regg, James B (DOA); Schwartz, Guy L (DOA); DOA AOGCC Prudhoe Bay Cc: Bart Armfield; Jim Winegarner; Bill Penrose; Rig16e_super Subject: UPDATE_Report of BOP use from North Tarn-1 Jim, Here is an update on the well control situation on the North Tarn-1. A reminder: Brooks Range Petroleum is requesting that all communication related to the North Tarn-1 operations are kept confidential. North Tarn-1 Operations since last report: Last night, a kill mud of 10.1 ppg was circulated in attempt to kill the gas/oil kick which happened at noon on March-22nd while drilling Kuparuk formation at 6225' MD/6146'TVD (original mud weight was 9.6 ppg).The circulation of the 10.1 ppg kill mud brought gas bubble and some oil-contaminated mud. After the 10.1 ppg mud circulation was complete, another flow check was performed and the crew noted the well was still flowing.They shut in well with 90 psi SICP and 70 psi SIDPP.A decision was made to weight up to 10.4 ppg and perform a circulation through choke again. During the last 10.4 ppg mud circulation,SIDPP and SICP fluctuated around 270-300 psi. Also, during the last circulation some mud was lost and later re-gained partially. Actions to be taken: Currently (at 9:30 am on March-23rd)the well's SIDPP and SICP are stable at 270 psi. A decision was made to perform another circulation with 10.4 ppg mud to get rid of gas in the annulus. At the moment, an LCM pill with fine particulate materials is being prepared to stop/inhibit lost circulation. Additional 10.4 ppg mud was ordered from mud plant and is coming to location at around noon. Subsequent reports will be submitted later today or tomorrow morning. Thanks, Natasha. From: Natasha Sachivichik Sent: Tuesday, March 22, 2011 5:11 PM To: Regg, James B (DOA); 'Schwartz, Guy L (DOA)'; 'doa.aogcc.prudhoe.bay@alaska.gov' Cc: 'Bart Armfield'; Jim Winegarner; Bill Penrose; Rig16e_super Subject: Report of BOP use from North Tarn-1 Jim, In compliance with AOGCC Industry Guidance Bulletin N. 10-1003 dated August 9, 2010, this is to report the use of blowout prevention equipment to prevent the flow of fluids from a well. Initial Report: Date/Time of BOPE Use: March 22, 2011, 12:30—still ongoing (100 bbl left to circulate at 1.5 BPM) Well/Location/PTD Number: North Tarn#1/ PTD No. 211-001 Rig Name: Nabors-9ES Operator Contact: Operator is Brooks Range Petroleum. Contact is Jim Winegarner-907-339-9965 or Bart Armfield 865-5840. Operations summary: While drilling an 81/2" hole through the Kuparuk formations the rig took a 4 BBL 3/23/2011 Page 2 of 2 kick.The well was shut in immediately with the initial DP pressure of 250 psi and the Casing pressure of 360 psi. The kick pressure decreased to 140 psi on DP and 190 psi. Currently (at 5PM),the well is being killed with kill mud of 10.1 ppg, the kill operation is going as expected, approximately 120 BBL left to circulate at 1.5 BPM. BOPE Used: Pipe rams Reason for BOPE Use: Divert fluid/gas kick through choke manifold and gas buster to remove gas/fluid entrained in the mud system. Actions Taken/To Be Taken: Upon circulating the kick out, a second circulation will be conducted to make sure the wellbore is under control. BOPE used was last tested on March 18,2011. This is an initial report.Additional information and details will be submitted in the subsequent reports after the well control is established and confirmed. Regards, Natasha Sachivichik Senior Drilling Engineer 310 K Street,Suite 700 Anchorage,AK 99501 MAIN (907)264-6100 DIRECT (907)264-6116 CELL (907)575-7156 natasha.sachivichik(a)solstenxp.com 3/23/2011 3 h) s V ..f N -\. F z ,-, i c0r ----- R / r ,..r if, ' 7;4' ',.;;'''I \ 1 N O i • J a y r 2 I.( t 1 ) w iT Nr .4.lei, NS 11rO 4 r a W N.S 7JZ o f r •V3 --. .. _ i CO N r 1 r w ) ,,,a.„ (� N IV N r r I 'S C o li t....t8 (4.-.) N Co __. M A (p 400 IF- ,,.. , N ti N...'..° 2 • '..--,•:•-- N d0 ch !77-.... '. N,.. '''' \ /1"1. i ' N W _ iffrinr-j--"7— i w ! 18 , 4 b ! L:i .• d' 1 N i i r ti b N4.NCJ7. t4114' som=amon . 1 .mo i 1 i� Afi l° . CQ Page 1 of 1 Schwartz, Guy L (DOA) From: Natasha Sachivichik [natasha.sachivichik@solstenxp.com} Sent: Tuesday, March 22, 2011 5:11 PM To: Regg, James B (DOA); Schwartz, Guy L (DOA); DOA AOGCC Prudhoe Bay Cc: Bart Armfield; Jim Winegarner; Bill Penrose; Rig16e_super Subject: Report of BOP use from North Tarn-1 c'TO la—o,: / Jim, In compliance with AOGCC Industry Guidance Bulletin N. 10-1003 dated August 9, 2010, this is to report the use of blowout prevention equipment to prevent the flow of fluids from a well. Initial Report: Date/Time of BOPE Use: March 22, 2011, 12:30—still ongoing (100 bbl left to circulate at 1.5 BPM) Well/Location/PTDNumber: North Tarn#1/ PTD No. 211-001 Rig Name: Nabors-9ES Operator Contact: Operator is Brooks Range Petroleum. Contact is Jim Winegarner-907-339-9965 or Bart Armfield 865-5840. Operations summary: While drilling an 81/2" hole through the Kuparuk formations the rig took a 4 BBL kick.The well was shut in immediately with the initial DP pressure of 250 psi and the Casing pressure of 360 psi. The kick pressure decreased to 140 psi on DP and 190 psi. Currently (at 5PM),the well is being killed with kill mud of 10.1 tong the kill operation is going as expected, approximately 120 BBL left to circulate at 1.5 BPM. BOPE Used: Pipe rams Reason for BOPE Use: Divert fluid/gas kick through choke manifold and gas buster to remove gas/fluid entrained in the mud system. Actions Taken/To Be Taken: Upon circulating the kick out, a second circulation will be conducted to make sure the wellbore is under control. BOPE used was last tested on March 18,2011. This is an initial report. Additional information and details will be submitted in the subsequent reports after the well control is established and confirmed. Regards, Natasha Sachivichik Senior Drilling Engineer SQL STEN;.P 310 K Street,Suite 700 Anchorage,AK 99501 MAIN (907)264-6100 DIRECT (907)264-6116 CELL (907)575-7156 natasha.sachivichik@solstenxp.com 3/23/2011 petrOleum LL FREE sUBst` Home Advertising Subscr!ptions Publications http://www.petroleumnews.com/pnads/913686640.shtml 41k- Co BRPC spuds North Tarn ' \ - Joint venture begins work on the only North Slope exploration well for 2010-11 -%0- 1 k Eric Lidji For Petroleum News Brooks Range Petroleum Corp. spud its North Tarn No. 1 exploration well in the central North Slope of Alaska on March 13, the local independent said. North Tarn No. 1 is on state land east of the Miluveach River, about two miles west of the Kuparuk River unit. BRPC spud the well using Nabors rig 9ES and accessed the well site using a winter ice road and pad system built by Peak Oilfield Services. BRPC plans to drill the well to a total measured depth of 6,440 feet to target both the Brookian formation and the deeper Kuparuk formation. The Brookian is the same formation producing at Tarn, the Kuparuk River unit satellite just to the south, while the Kuparuk is the main formation producing at the prolific Kuparuk River unit to the east. BRPC estimates that the Brookian reservoir could contain some 35 million barrels of oil and that the Kuparuk reservoir could contain an additional 6 million barrels of oil. BRPC previously told Petroleum News that it believes the smaller Kuparuk formation presents a better bet for initial development because of the complex geology of the Brookian. BRPC hopes to complete operations at North Tarn No. 1 by mid-April,but also said it could also end up drilling a sidetrack to the well this winter, depending on results. "The BRPC Group is optimistically looking forward to see the results of the North Tarn No. 1 exploration well," said Jim Winegarner, vice president of land and external affairs for BRPC. "The North Tarn No. 1 exploration well is the only exploration well being drilled on the North Slope this season; therefore, the BRPC Group holds the title as Alaska's exploration company. We'd rather share that title with many more companies." While ConocoPhillips plans to drill a gas hydrates exploration well in Prudhoe Bay this year, North Tarn is the only traditional oil exploration well permitted this winter. BRPC is operating the well on behalf of its parent company, the Kansas-based Alaska Venture Capital Group LLC, as well as three joint venture companies: Brooks Range Development Corp., Ramshorn Investments Inc. and TG World Energy Inc. The joint venture acquired the North Tarn acreage in January 2010, farming-in six Eni Petroleum leases. Earlier this year, it applied to form the 56,460-acre Southern Miluveach unit over the area. That application is still pending with the Division of Oil and Gas. Seven wells in five seasons North Tarn No. 1 continues the joint venture's march toward being the most active explorer in Alaska over the past five years. Following half a decade of stops and starts after arriving in the state in 1999, AVCG formed an operating arm, gathered acreage, partners and data, and began drilling exploration wells across the North Slope. The joint venture drilled two wells in 2007—the North Shore No. 1 well that encountered 70 feet of oil charged Ivishak sandstone and the Sak River No. 1 dry hole. In 2008, the joint venture re-entered North Shore No. 1 to test the Ivishak and the Sag River formation, and drilled the Tofkat No. 1 well on acreage along the Colville River, taking 10 oil samples for four sandstone reservoirs and finding six net feet of pay. In 2009, a lawsuit among partners kept the joint venture from drilling,but the partners resolved it in time to return to the North Slope in 2010 with two wells: Sak River No. 1- A, a sidetrack to the 2007 well, and the North Shore No. 3 well in the Gwydyr Bay area. In addition to work at its Gwydyr Bay, Tofkat and North Tarn acreage, the joint venture wants to shoot seismic at its Slugger prospect, located south of the Point Thomson unit. Partner TG World Energy recently announced that it successfully sold its outstanding stock to the Canadian mining company TVI Pacific Inc. The deal allows TG World to raise capital and TVI to expand its resource development operations in the Philippines. TVI and TG World share a senior executive. I petrqlçujri s FREE sUBS(R Home Advertising SbscriptIons rb icat(ons http://www.petroleumnews.com/pnads/498246663.shtml Vol. 16, No. 11 Week of March 13, 2011 Providing coverage of Alaska and northern Canada's oil and gas industry AOGCC issues permit for North Tarn well 1 \ ._O a \ The Alaska Oil and Gas Conservation Commission issued a permit on Feb. 16 for Brooks Range Petroleum Corp. to drill the North Tarn No. 1 exploration well. North Tarn No. 1 will likely be the only exploration well drilled on the North Slope this winter. The Alaska-based independent plans to start drilling the 6,300-foot well in March from a site some two miles west of the Kuparuk River unit using Nabors rig 9ES. North Tarn No. 1 will test targets in the Brookian formation and the deeper Kuparuk formation. The Brookian is the same formation producing at the Tarn satellite to the south, while the Kuparuk is the main formation producing at the Kuparuk River unit. BRPC estimates that the Brookian reservoir could contain some 35 million barrels of oil and that the Kuparuk reservoir could contain an additional 6 million barrels of oil. BRPC is the operating arm of the Kansas-based Alaska Venture Capital Group and operates a joint venture with partners TG World Energy and Ramshorn Investments. —Eric Lidji Slfalf [E EF 1]. nSEA /SEAN PARNELL,GOVERNOR ALASKA OIL AND GAS333 W.7th AVENUE,SUITE 100 CONSERVATION CO1 L1IIISSIONANCHORAGE,ALASKA 99501-3539 PHONE (907)279-1433 James R. Winegarner FAX (907)276-7542 Vice President of Land Brooks Range Petroleum Corporation 510 L Street, Suite 601 Anchorage, AK 99501 Re: Exploratory Field, Exploratory Pool,North Tarn 1 Brooks Range Petroleum Corporation Permit No: 211-001 Surface Location: 2388' FSL, 1780'FEL, SEC. 02, T1ON, R7E, UM Bottomhole Location: 1679'FSL,2470'FEL, SEC. 02, T1ON, R7E,UM Dear Mr. Winegarner: Enclosed is the approved application for permit to drill the above referenced exploration well. All dry ditch sample sets submitted to the Commission must be in no greater than 30' sample intervals from below the permafrost or from where samples are first caught and 10' sample intervals through target zones. This permit to drill does not exempt you from obtaining additional permits or approvals 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 Commission reserves the right to withdraw the permit in the event it was erroneously issued. A weekly status report is required from the time the well is spudded until it is suspended or plugged and abandoned. The report should be a generalized synopsis of the week's activities and is exclusively for the Commission's internal use. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the Commission 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 Commission order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. 4/ K. No om • : oner DATED this day of February, 2011. cc: Department of Fish &Game, Habitat Section w/o encl. (via e-mail) Department of Environmental Conservation w/o encl. (via e-mail) /V /\ Brooks Range Petroleum Corporation a subsicliarr of AVCG.LLC January 4, 2011 Mr. Dan Seamount, Chair Alaska Oil and Gas Conservation Commission 333 West 7th Ave., Suite 100 REC,`,EiVEin Anchorage, Alaska 99501 JAN 0 4 2011 RE: Application for Permit to Drill: North Tarn#1 Nsrha 3 61,3 Cutis.Ccr trission Dear Mr. Seamount, Ancnordge Brooks Range Petroleum hereby applies for a Permit to Drill a new oil exploration well called North Tarn #1 (NT-1). North Tarn # 1 well will be drilled from an ice pad 2.6 miles north of the Tarn Field D.S. 2L and 4.6 miles to the south-west from Kuparuk Field D.S. 2M on the North Slope of Alaska. An ice road of approximately 5 miles will be built to the north of the Alpine pipeline from Kuparuk 2M Pad to the well site. The North �S oral will consist of 16"conductor pipe, 9 5/8" surface casing. The main objective of the well is to locate and analyze the presence of oil reservoirs in . Brookian sandstones and to evaluate the reservoir properties. The secondary objective is to evaluate oil reserves in underlying Kuparuk River Formation sand penetrated by the KRU 2L-03 well in 2002. • The evaluation of the reservoir fluid type and fluid properties will be accomplished with an open-hole drill stem testing technique (DST). DSTs will be performed in all potentially producing intervals. Full-bore coring operations are planned through all potentially producing intervals. The reservoir fluid samples will be collected at the well site and sent to a laboratory for analysis. OS1 / > Waste drilling fluids and ground cuttings will be disposed of via the Pad 4 G&I facility operated by BP in the Prudhoe Bay Field. Please find attached information as required by 20 AAC 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 2) A plat showing the surface location of the well 3) Proposed drilling program 4) Drilling Time versus Depth Plot 5) North Tarn#1 Proposed Wellbore Diagram 6) Pressure Calculations, Drilling Area Risks and Waste Disposal 7) Casing Properties and Design Factors 8) Diagrams and Descriptions of the BOP Equipment to be Used 9) Directional Drilling Program 10) Drilling Fluid Program 11) Cementing Program 510 L Street,Suite 601,Anchorage,Alaska 99501 Tel:90'.339.9965 Fax: 907.339.9961 / /)/ /\ Brooks Range Petroleum Corporation 12) Brooks Range does not anticipate the presence of H2S in the formation to be encountered in this well. However, H2S monitoring equipment will be functioning on the rig at all times during drilling and completion operations. 13) The following are Brooks Range's designated contacts for reporting responsibilities to the Commission: a) Completion Report Natasha Sachivichik, Drilling Engineer (20 AAC 25.070) (907) 343-0405 b) Geologic Data and Logs Doug Hastings, VP - Exploration (20 AAC 25.071) (907) 865-5802 If you have any questions or require additional information, please contact me at (907) 865-5840 or Natasha Sachivichik at(907) 575-7156. Sincerely, BROOKS RANGE PETROLEUM CORPORATION mes R. Winega er Vice President of IAnd L enclosures cc: Natasha Sachivichik- SolstenXP 51O L Street, 5ulte 601,Anchorage,Alaska 99501 Tel 90'._3399965 Fax: 907,339 9961 STATE OF ALASKA Al CA OIL AND GAS CONSERVATION COMI ,ION IAN 0 4 2011 PERMIT TO DRILL R;,�' s¢ n 20 AAC 25.005 r s9lg ,,f L. t.1►/, , la.Type of Work: lb.Proposed Well Class: Development-Oil • Service- Winj • Single Zone ❑ ic.Specify if woRfolia d for: Drill Q ' Redrill ❑ Stratigraphic Test ❑ Development-Gas ❑ Service-Supply ❑ Multiple Zone ❑ Coalbed Gas all Gas Pgrates ❑ Re-entry ❑ Exploratory ❑✓ • Service- WAG ❑ Service-Disp ❑ Shale Gas ❑ 2.Operator Name: 5. Bond: Blanket ❑ Single Well ❑ 11.Well Name and Number: Brooks Range Petroleum Corporation Bond No. LPIMg8 PfiZF-44 f "/ North Tarn 1 • 3.Address: 6.Proposed Depth: — / /D/,S i/ 12.Field/Pool(s): 510 L Street,Suite 601,Anchorage,AK 99501 MD: 6482 ii/ TVD: 6398 4a. Location of Well(Governmental Section): 7.Property Designation(Lease Number): Exploratory Surface: 2388 FSL 1780 FEL S2 T1ON R7E UM " ADL390680 ` Top of Productive Horizon: 8.Land Use Permit: 13.Approximate Spud Date: 1679 FSL 2470 FEL S2 T1ON R7E UM LAS27505 Jan-28-2011 Total Depth: 9.Acres in Property: 14.Distance to Nearest Property: 1679 FSL 2470 FEL S2 T1ON R7E UM 2,560.00 , 1780 4b.Location of Well(State Base Plane Coordinates-NAD 27): 10.KB Elevation above MSL: 97 feet 15.Distance to Nearest Well Open Surface: x-465198 • y- 5940773• Zone-4 GL Elevation above MSL: 67 feet to Same Pool: N/A 16.Deviated wells: Kickoff depth: 500 feet 17.Maximum Anticipated Pressures in psig(see 20 AAC 25.035) Maximum Hole Angle: 10 degrees Downhole: 3096 psi Surface: 2454 psi 18.Casing Program: Specifications Top - Setting Depth - Bottom Cement Quantity,c.f.or sacks Hole Casing Weight Grade Coupling Length MD TVD MD TVD (including stage data) 24" 16" 0.495"WT N/A Welded 80' 0' 0' 107 107 140 cf arctic grade cement 12.25" 9-5/8" 40# L-80 BTC 2660 0' 0' 2660 . 2631 Cmtd to surf w/502 bbls $.s.• __ ZGlor7� Gy8Z • 0/f se -mi--. 19. PRESENT WELL CONDITION SUMMARY(To be completed for Redrill and Re-Entry Operations) Total Depth MD(ft): Total Depth TVD(ft): Plugs(measured): Effect.Depth MD(ft): Effect.Depth TVD(ft): Junk(measured): 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 Q Time v.Depth Plot ❑✓ Shallow Hazard Analysis Diverter Sketch Seabed Report ❑ Drilling Fluid Program ❑✓ 20 AAC 25.050 requirements 21. Verbal Approval: Commission Representative: Date 22. I hereby certify that the foregoing is true and correct. Contact N.Sachivichik 575-7156 Printed Name Berrr?TYtTi lS .0—A.me '` . ^/ ^ title VP-Japperetions— Signature � G�v — Phone 907-39-996Uy�%�+��f—Date •//,,/ Commission Use Only Permit to Drill / API Nur Permit Appr I 1 See cover letter for other Number. 2 l � j / 50 1/..),.. ,...21i, c � »j i� '�� Date: `� �� requirements. Conditions of app •val: If box is checked,well ma not be used to explore for,test,orproduce coalbe thanegas hydrates,or gas contained in shales: ,p � P . Y � Other: *i3 ' 0 0 D s` .D( f, S f-- Samples req'd: Yes[7 No❑ Mud log req'd: Yes ErNo❑ r ..- / • \ HZS measures: Yes 14 No❑ Directional svy req'd: Yes "No❑ 42S-60 psi A wL4,t (e.s f (..'...u-, ) 5“,.^elyj 1'e.8(4...:.r °6-1 i d r „ r ...I tSor —WO- J le, APPROVED BY THE COMMISSION DATE:R-16-1( ,COMMISSIONER ORIGI1 7 '40 Form 10-401(Revised 7/2009) This permit is valid for 24 months from the date of approval(20 AAC 25.005(g)) Submit in Duplicate Dupiicate REV DATE BY CK APP DESORPTION REV DATE BY ca. 1 APP DESCRIPTION NOTES: 1. COORDINATES ARE FROM MULTIPLE GPS RTK OBSERVATIONS BASED ON DRILL SITE 2M MONUMENTS. 2. GRID COORDINATES ARE ASP, NAD27, ZONE 4. 3. GEODETIC COORDINATES ARE NAD27. 4. ELEVATIONS ARE B.P.M.S.L. 5. ALL DISTANCES ARE TRUE. SCALE: 1" = 200' CONTOUR INTERVAL = 1' NORTH TARN 72 LOCATED WITHIN PROTRACTED SEC 2, T 10 N, R 7 E, UM. LAT = 70' 14' 57.1" LONG = 150' 16' 52.2" Y = 5,940,773' ''✓ 5p� X = 465,198' GROUND ELEVATION = 69.3' rn 0 NORTH TARN TARN 240 • pOs>r0 \CA, 4) 4V3 LOUNSBURY & ASSOCIATES, INC. A')/ssYS\ 111461=91665 MMUSAREA: MODULE: XXXX UNIT: BRPC NORTH TARN Brooks Range Petroleum Corporation EXPLORATORY WELL SITE a subsidiary of AVCG, LLC TOPOGRAPHY AND DRAINAGE CADD FILE NO. DRAWING NO. PART: REV: LK601D750 12/3/10 NSK 6.01-d750 1 OF 1 0 North Tarn #1 General Drilling Program 1. Ensure regulatory compliance training is complete and key personnel are fully aware of responsibilities. 2. Install 16" conductor and a cellar. 3. Diverter riser assembly should be made to length according to diverter space out schematic. i/ 4. Conduct specific tour safety meetings with each crew on the potential of gas hydrates or ,j shallow gas and the handling of same. 5. Pick up and stand back 3,500' of 5" drill pipe and 500' of HWDP. 6. Notify the AOGCC of intent to spud and plans to perform diverter function test and drills. 7. Ensure that pipe rams are available for the following pipe sizes: 9-5/8" casing, 5" drill pipe, i 4" drill pipe, 7" casing and 3-1/2"tubing. 8. Install 21 %" 2000 psi diverter with 16" outlet line as described in pre-rig operations. Fill diverter& riser with water to check for leaks. Function test and record on IADC drilling '' report. Send completed Diverter Test form to AOGCC as specified on the form. Hold diverter drill prior to drilling surface hole. RU cement return lines from the 4" outlets on the 16". 9. A conventional spud mud will be used on the surface hole. 10. PU 12-1/4" bottomhole assembly. Test the BHA below the rotary table. 11. Spud well with reduced drilling parameters. Gradually increase drilling parameters when the BHA is below the conductor shoe. I e 12. Drill 12-1/4" hole vertically to 2,660' as per the directional plan and mud plan. Controlling '? ROP may be necessary to prevent packing off, lost circulation or flow over the top of the bell nipple. No sliding is expected in this section. 13. Actual TD will be based on LWD data so as to place shoe in minimum 50' shale section if possible. Geologist will assist in picking casing seat. 14. Pump a high-vis sweep at TD and note surface to surface strokes as an indication of washouts. Make calculation of average hole size and consider adjusting excess cement volumes based on results. 15. Make short trips as required, circulate and condition mud and POH. Lay down the 12-1/4" BHA and download all memory data from MWD/LWD tools. 16. Rig up casing running equipment and Frank's top drive fill up tool. 17. Run 9 5/8" casing, monitoring returns and filling casing with fill up tool. ./ 18. Cement 9 5/8" casing with 70 bbl of spacer, 382 BBL of lead permafrost cement, 45 BBL of 1 tail Class G cement. Displace with 185 BBI of spud mud. (Notify AOGCC immediately if the cement did not reach surface 19. Nipple down the diverter. 20. Make up wellhead and install, nipple up BOP stack. V 21. Notify AOGCC 24 hours prior to testing BOPE. Test BOPE to 250 psi low and 4,000 psi high ✓ (See Permit to Drill for reference). 22. MU 8-1/2" BHA and test. Spud mud will be used to drillout the shoe track. Test casing to 3,000 psig making sure to chart the test. Drill shoe track and 20' of new formation. ✓ 23. Switch out to OBM before LOT. 24. Perform LOT. Record the results on the Morning Report and in the IADC report. 25. MU 8.5" BHA#1.Circulate and establish baseline parameters. 26. Drill ahead in 81/2 " hole with mud motor and LWD-PWD system to top of the North Tarn at -4800' MD. 27. Slow down drilling and circulate for samples every 10'through the Brookian (H3 Sand - V North Tarn). The wellsite geologist will assist in formation tops determination. Avoid sliding through potential reservoir sections. 28. Circulate and condition mud and POOH. Prepare for Reservoir Evaluation testing- DST. 29. Perform the DST procedure. Record flow rate, pressures and collect fluid samples. POOH with testing tools. '" def Dsr Prod,-.e-w� . 30. MU and RIH with drilling BHA and LWD. The LWD logging suite will include GR, RES, DEN, NEU, NMR. 31. Continue drilling through Kuparuk. Allow ample rat hole to run all LWD tools through the . Kuparuk Sandstones. Back-ream and MAD pass through the Kuparuk sands. POOH BHA. •y Q 32. Prepare for the Reservoir Evaluation testing operations in the Kuparuk. 33. Perform the DST procedure. Record flow rate, pressures and collect fluid samples. 34. After reservoir testing is complete, POOH. At this point a decision will be made whether to run additional open-hole logs. Open-hole wireline logs will include dipole sonic. IVB Pfl) 35. Plug back the NT-1 hole to -3000ft to prepare for the sidetrack NT-1A. --s rer r`QA /Vt(el 36. If the reservoirs were not encountered, the well will bePfd and a decision will be made " about the next steps in the program. : Lfp 3 5 c„iQr.y Ie-3 rtJ[ r Se-C- 14.1,10 CC. / 14�f0 6.4S4 3 /°4 A. r 0 IA a) I— a 0 m IX) Aummomml• R CO 4-, U Q COCO i. 70 a� 2. W-0 CO 2 c, 2 0 Y Y U asH CO Ln -1 a) N ID 4IW C co 0 021 • 3 ;P V co I- CO • WIn P LL Y '4 Z. oN o LU m LO o_ •Q LI) CCS 4110 • 4-0 o V) t Ln O O o O O o O o O 0 0 0 0 0 0 0 0 r N M ct L.6 c. I� cc; (;aa;) gidaa painsea j L O O co co co CO CO CO O O O O O O CV CV CV N N 0 0 0 0 0 0 Lf) Lf) Lf) Lf) Lf) 0 0 0 0 0 0 0 0 0 0 COCCCOO COC (CC) COCL- CO CCO CMO CO CMO � COO COO COO (00 COO O O O O O� CD a) O a) a) a) 0 — CV (V N N N N V V V V V Lf) CO (C) (D (D CO CO CO CO CO CO V CO CO (C) CO CO CO North Tarn # 1 Proposed Wellbore Diagram 16" conductor set @ 80' MD/TVD I2660' MD, 9-5/8",40#, L-80, BTC casing Sidetrack NT-1A below the 9-5/8" shoe Maximum Hole angle 11 deg at 4800' -North Tarn , Hole angle at TD 9 deg core No{- intervals 8'A" Open Hole 8 1A" Open Hole Kuparuk core interval NT-1A 7,49595' MD/6,403' NT-1 TD 6,484' MD/ 6,398'TVD TVD ns 12/27/10 1C/eAJ PM Geo-Mechanical Plot Geomechanical Plot North Tarn #1 8 9 10 11 12 13 14 15 16 17 0 • II 80'TVD 16"conductor 1000 B Permafrost -1595' • r . ' ■ 2000 - • K-10- 2615' --'r--L-OT,-2S2OTVD_1 4 2660' TVD 9 5/8" • w • 0 A LOT,2809 3000 • ■ —.Projected Pore s • w IP t Frac • 0 -LOT 4000 41-7. • • ■ •i. ■ 5000 Top N Tarn 5114' 4iir • • C30 Ss - 5715' ■ • ■ 6000 ___TopHRZ_604n' LV I 63 0' __TgpKalubik -6191' Pore Pres. 9 4 ■ __ p-p 60 fi ' Top Kyp C-1 6340' LCU 6361' 6648'TVD 7000 i I / 1)/\/\. Brooks Range Petroleum Corporation Brooks Range Petroleum Corporations Pressure Calculations,Drilling Area Risks and Waste Disposal Considerations North Tarn#1 Maximum Anticipated Surface Pressure: 12-1/4"Hole Section This hole section will be drilled with a diverter only, no BOPs. While MASP will equal the formation pore pressure at the surface casing shoe depth of 2,660'MD/2533' TVD less a gas gradient to the surface, it cannot be shut in, only diverted. Offsetting well information indicates that the pore pressure at 2,533' TVD will be a maximum of 9.0 ppg (or 0.468 psi/ft). Calculations for MASP (12-1/4"hole) =2,533' (0.468-0.10) = 932 psi 8-1/2"Hole Section The maximum anticipated pressure (MASP) for the 8-1/2" hole section will be the formation pore pressure (less a full gas column to the surface) at 6,483' MD/6398' TVD. • Offsetting well information indicates that pore pressure at TVD will be a maximum of 9.0 ppg (or 0.468 psi/ft). .a- Calculations: 8-1/2"hole section MASP (pore pressure) = (6,398 ft) (0.468-0.10) = 2354 psi • With MASP in the 8-1/2" open hole section is expected to be 2354 psi and the 5,000 psi BOPE system to be used will be adequate. Well Proximity Risks: The closest wellbore to the North Tarn#1 is DS 2L-03, it is located approximately 2.0 ' miles away and the directional simulation indicates there is no anticipated interference expected between wellbores. ~\/\. Brooks Range Petroleum Corporation Drilling Area Risks: 1. There is a possibility of encountering gas hydrates while drilling the surface hole. If gas hydrates do occur in the North Tarn#1, the situation will be treated with extra care, slow down drilling, slightly increase mud weight and set surface casing and cement as soon as possible. 2. There is little risk of encountering H2S in the area as there are no indications that any of the offsetting wells encountered any. However, as a precaution, the rig and mud logging units will have functioning H2S detectors. Disposal of Mud Products and Cuttings: All drill cuttings and waste drilling fluid will be disposed in BP's grind and inject facility at Prudhoe Bay. ./V\/\ Brooks Range Petroleum Corporation North Tarn #1 Casing Design Verification Planned Casing program 9-5/8" Surface Casing Depth (MD) 2,660' Depth (TVD) 2,533' Hole size 12-1/4" Weight(ppf) 40.00 Grade L-80 Connection BTC Nominal ID (in) 8.835 API Casing Design Factors Design factors are essentially "safety factors" that allow the design of safe, reliable casing strings. Each operator may have his own set of design factors based on his experience and the condition of the pipe. Here we use operator's recommended design factors. Design Factors: Tensile Joint Strength: Nt= 1.8 Collapse (from external pressure): Nc= 1.125 Burst (from internal pressure): Ni = 1.1 The pore pressures and fracture gradients used here are those derived from studies of offsetting well North Tarn#1. Design Factor Calculations Burst Requirements Use maximum anticipated surface pressures (MASP) for each casing string. For each casing string MASP is the formation pressure at the next casing point less a gas column to surface. ./V \ Brooks Range Petroleum Corporation 9-5/8", 40#, L-80, BTC Surface Casing: MASP at 8-1/2"hole section TVD of 6398': MASP =(6398') ((9.0 ppg x 0.052)-0.10 psi/ft) =2354 psi DFb =burst strength/burst stress =5,750 psi/2354 psi =2.44 Collapse Requirements Use an external pressure consisting of the formation pore pressure at the casing shoe and an internal pressure of a gas column to surface. 9-5/8", 40#, L-80, BTC Surface Casing: External pore pressure =9.0 x 0.052 x 2,533' = 1185 psi Internal pressure w/gas only =0.10 x 2,533' = 253 psi Collapse stress = 1185 psi - 253 psi =932 psi P DFc=collapse rating/collapse stress = 3,090/932 =3.31 Tension Check Use buoyed weight of casing in mud having the expected density when running the pipe. 9-5/8", 40#, L-80, BTC Surface Casing: Weight in air= 2,660' x 40 lb/ft = 106,400# ✓ Pipe weight in fluid=Pipe wt.(in air) x Buoyancy Factor 106400#x 0.855 =90972# DFt=body tensile strength/buoyed wt = 916,000#/90972# = 10.06 P. . i46IA r g€ R = o 3 � S og a rtW :1,a W o§ a o 1--. ooZ -ria m g g O W� Y Loc-?. ` $ �o 11 11 s m m� I QVC O O uiZ14-1 CQn�O0OmW O = Oo4j �p i---- �J co ` Z mZCB�� r, o J1 H o d -N. 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V E m822P- 22g;;;; NOQDD pts a0bPPp yf% E aa o O KN S 6 08 c I °' w O. ` i " a r _•o 9 .. p C o N & 021 ;2 8 F A LL N y N O 2 6 OE J 2 Ct C .O O'0 {C 8 g NH € mG m m 9 OO l8 OCa 0 TT 9m'OUW 4 ON sa UYO NE N E U TT G.=_.m wm6UNmNU K9 NOU Cm O 0N0 180 rU zn2 Up JA 6 / ')/\/\. Brooks Range Petroleum Corporation Schlumberger WELL FIELD STRUCTURE North Tarn 1 (P8) Tarn North Tarn 1 Magneto Parameters Surface Location N.n.27 Alaska State Pana,Zone 04,US Feet Miscellaneous Motle, 8GGM 2010 Dip: 80.77r Dab'. January 12.2011 Lat. N 7014 57 102 Noi0Mig' 594077300 MIS Grid Done:-026462166' Slot: North Tam 1 ND Ret. Rotary Table(9780 above MSL) Meg Dec. 21017° FS'. 57606 671 Lon. W 150 16 52.163 Ea ting. 465196,00 MIS Scale Fact'.0.99990139 Plan: North Tarn 1(P91 Soey Deb:December 13,2010 -800 0 800 1600 2400 0 RTE 0 KOP Cry 1.5/100 Cry 2.5/100 800 800 • End Bid Yee lsarrn 1600 1600 2400 2400 9-5/0"C.y • 00 c 3200 3200 0) U co 0 4000 4000 • _.._.._.._.._._.._.._.._.._.._.._.._.._.._.._.._.._.._..- orok .._.._.._.._.._.._.._.._..�.._.._.._..�..�.._.._..� Cry 2.5/100 4800 ""EnilUiji%Yyk 1 : 4800 am Sarid..�..�..�. .�..�..�..�. -._.. .._.._.._.._.._..�..�.._.._.._..�..�..�..�..�.. .35._.._.._.._.._.._.._..�.._.._.._.._.._.._.._.._ _.._.._.._.._._.._.._.._.._.._.._.._..�.._.._.._.._.._.._.._..�.._ 311�s_..�..�..�..�..�..�..�..�..�..�..�..�..�..�. 5600 5600 RZ • _.._.._.._.._._.._.._.._.._.._.._.._..i.._.._.._.._.._.._.._.._..i.._._.._.._.._.._.._.._..y.._...................... 6400 TO oreh tam 1(Pti) 6400 -800 0 800 1600 2400 Vertical Section(ft)Azim=224.13°,Scale=1(in):800(ft) Origin=0 N/-S,0 E/-V Brooks Range Petroleum Corporation Schlumberger WELL FIELD STRUCTURE '' North Tarn 1 (P8) Tarn North Tarn 1 Magnetic Parameters Surface Location NRD21 Alaska State Plana,Zone 04.US Feet Miscellaneous Model'. 85DM2010 DIp: 60.711 Date January 12,2011 Let'. N 10145'7102 orthkg: 5940113005010 5th Conn.-0 26462165' Slot North Tarn1 TVU Ref: Rotary Table(91.5ft above MSL( Mag Dec: 21.011' FS- 51606.601 Lon: W 15016 52.183 Easting: assess 000U5 Scale Fact:099990136 Plan. North Tarn 1(76) Dry DMa:December 13,2010 -600 -450 -300 -150 0 150 i. 150 KOP Cry 1.5/100 RTE Cry 2.5/100 0 0 End Bid N -150I _ -150 A I 9dM4 Cs• A A - , Z O -300 z• 4 -300 c u 0) U U) cn -450 -450 V cry 2.5,100 End 099/Tgt 1 -600 • -600 Tpt2 -750 a o -750 • Tam 1(P8) -600 -450 -300 -150 0 «< W Scale=1(in):150(ft) E >>> Brooks Range Petroleum Company North Tarn #1 Mg SWACD /4/41e,A44.44& Brooks Range Petroleum NORTH TARN #1 / 1A Mud Program Name Signature Date Originator: Jim Dwyer December 31, 2010 Reviewed by: Hal Martens Customer Approval: Version: 2.0 Date: December 31, 2010 Confidential 1 Brooks Range Petroleum Company North Tarn #1 Well Summary North Tarn 1 / 1A exploration well is located onshore north of Tarn Field and southwest of the Kuparuk. The ice road will be 5 miles long north of the Alpine pipeline from the Kuparuk 2M pad. A 16"conductor is planned to be set at 80' MD/TVD. The surface interval is planned to be a 12-1/4" hole drilled to a depth of 2,660' MD at which point 9 5/8", 40#, L-80, BTC surface casing will be run and cemented. The production interval is planned to be a 8-1/2" hole drilled to a final TD on North Tarn 1 of 6,602' MD/6,453 TVD and on sidetrack North Tarn 1A of 6995' MD/6,453' TVD where hole will be tested and plugged. The highest mud weight will be found in the production interval, with an expected mud weight of 10.0 ppg. As with all exploration wells some geologic uncertainty exists. Communicate with the rig team to determine what the actual needs of the well are. Remember the main purpose of the well is to gather information in a safe and environmentally sound manner.All decisions made concerning the integrity of the well should keep this in mind. Lost circulation may also occur in the final leg of this well. ECD's should be monitored closely. Contingency should be made to have extra volumes of drill-in fluids on hand prior to drilling ahead. Lost circulation material should also be readily available. Fluid and Drilling Concerns ➢ Wellbore stability throughout the drilling phase of the operations. ➢ Hole cleaning ➢ Control of ECD's ➢ Lost circulation—well control ➢ Minimized torque and drag. ➢ Good cement jobs. ➢ Hole condition to allow logging operations. ➢ Minimization and management of waste costs for the "drill cuttings" and associated fluids. Monitoring and efficient utilization of the trucks and gravel washer as required for this operation. Daily and interval summaries will be tallied and summarized for the end of well report. ➢ HSE Y Date: December 31,2010 Confidential 2 Brooks Range Petroleum Company North Tarn #1 Project Summary Casing Hole TVD Mud Size Size MD ss Density Range (in) (in) Profile (ft) (ft) (ppg) 9.0—9.5 9.625" 12.25" 2,660 TBD SPUD MUD 9.8- 10 OH 8.5" 6,602 6,453 Open Hole VERSAPRO NT "1A" ST Open Hole 9.8— 10 From 8.5" 6,995 6,453 Recyled 9 5/8" VERSAPRO NT Date: December 31, 2010 Confidential 3 Brooks Range Petroleum Company North Tarn #1 Surface Interval Drilling Fluid System Spud Mud Key Products MI Gel, GELEX, Caustic, MI WATE (Barite), PolyPac UL, DRILLZONE, SCREENKLEEN, Solids Control Shakers, Mud Cleaner, Centrifuge Large gravel sizes can cause hole-cleaning problems. Sticky clays in the permafrost can slow ROP from bit and BHA balling. Potential Problems Swabbing in the clays may also be a problem. Hydrates may be encountered. ✓ To help ensure good cement to surface after running the casing, and if practical, condition mud to a funnel viscosity of—55— 100 sec/qt prior to cementing the casing. INTERVAL MUD PROPERTIES Final Value Mud Property Initial Value @ TD • • Density(ppg) 9.0 9.5—9.6 Yield Point (cP) 50- 70 45- 60 PV(Ib/100 sf) 20-45 20- 30 • pH 9.0-9.5 9.0- 9.5 API Filtrate (cc) NC- 8 <8 Solids (%) ±9% ±9% Recommended Initial Spud Mud Formulation Soda Ash 0.2 ppb MI Gel 25 ppb (Add to the make-up water and allow to hydrate as long as is possible) GELEX Add prior to spud to increase the funnel viscosity to 250 - 300 sec/quart. MI WATE (Barite) For weight as needed Caustic Soda 0.02 ppb PolyPac UL 0.25 ppb Recommended Sweep Formulation Add DRILZONE in 0.25% increments to minimize clay to metal sticking. Only use this procedure if deemed absolutely necessary. DRILZONE will be utilized for bit balling and ScreenKleen for screen blinding from clays with an initial concentration of 0.25%. Higher concentrations would be added if required, but results need to be carefully monitored and reported. Date: December 31, 2010 Confidential 4 Brooks Range Petroleum Company North Tarn #1 Surface Interval Treatment Procedures ➢ Gravel can cause hole-cleaning problems. If larger than normal gravel is encountered, be prepared to increase funnel viscosity from 250—350 sec/qt. Have GELEX available for an immediate response to this issue. ➢ Mix the surface interval "Spud Mud" using the coldest water possible. Due to expected flow rates (and the associated temperature increase resulting from the flow rate), the temperature of all water added to the system should also be maintained at as low a temperature as possible. ➢ Avoid washing out the shoe of the conductor pipe by drilling to 150' using a reduced flow rate 500- 600 gpm) and then maintain flow rates as per the "Virtual Hydraulics Hole Cleaning Model" and stay below an effective 100 ft/hr ROP to ensure hole cleaning. Reduce pump rates immediately if packing off occurs. ➢ Drill ahead. Adjust rheology, ROP, pipe rotation speed (60 - 80 rpm minimum), pipe running speeds and pump rates as needed to balance hole cleaning and ECD. ➢ Drill ahead watching for wellbore instability problems. Any fluid weight adjustments should be performed in 0.1 - 0.2 lb/gal increments if absolutely necessary. ➢ Sticky clays in the permafrost and also in the zone below the permafrost can slow ROP from bit and BHA balling. Add DRILZONE (in 0.25% increments) and Nut Plug (as allowed by MWD tools) to minimize clay to metal sticking only if needed. ➢ Add LOTORQ if needed up to a concentration of 3% v/v. Ensure that hole cleaning is adequate prior to any lubricant additions are made to the system. Additions of lubricant over this recommendation concentration should be carefully considered. Do not use lubricants to mask the affects of hole cleaning or other problems that may be manifesting themselves as torque and drag issues. ➢ Once the permafrost has been drilled, additions of small amounts of Mix II to lower fluid loss may be required. ➢ Once the permafrost has been drilled begin to increase the proportion of polymer additions, while reducing the quantities of MI Gel that are used to maintain the rheology of the fluid. ➢ Hydrates may be encountered. Determine severity of any influx and weight up as needed to maintain proper well control. See"Hydrate Issues enclosure." ➢ To help ensure good cement to surface after running the casing, and if practical for existing hole conditions, condition mud to a funnel viscosity of'/_55— 100 sec/qt(YP at 15— 17) prior to cementing the casing. Have water on hand to ensure the desired rheologies can be achieved. Date: December 31,2010 Confidential 5 Brooks Range Petroleum Company North Tarn #1 Surface Interval S.C.E. Operation Standards Shakers- • LO/TO Shakers • Replace all decking rubber on the Derrick shaker beds. This will allow for optimum screen performance during drilling operations. It is important to develop a good preventive maintenance schedule which includes replacing the decking rubber before it becomes a performance related issue. • Install XR Magnum screens (84- 110 mesh). Ensure screens are properly tensioned, per M-I Swaco's best practice suggestions. Spray down new screens with fresh water before operating the shakers. • As fluid shears, screen up as necessary to higher mesh screen sizes. • Ensure jacking system on the Derrick 48 HI G or equivalent shakers enables the fluid to flow to the center of the screens, adjust and lock as necessary. Centrifuge- • Surface interval requires a greater through put during most operations, which require the centrifuge to run at a lower speed (2,500 - 1,800 rpm), high differential as well. This setting allows the centrifuge to process more fluid and discharge more cuttings. With the lower rpm's the cut point is reduce from 3 - 6 micron cut to approximately 6 - 10 micron which gives up cut point but processes more fluid. Swaco recommends and stands behind the suggestion to run the centrifuge at the lower speeds during the upper sections of hole. General- • Proper apex size on the de-silter during this section will greatly improve the performance of the centrifuge and overall solids control performance of pit system. Drilling conditions may dictate several apex adjustments, close supervision of mud cleaner will be highly rewarded. Date: December 31,2010 Confidential 6 Brooks Range Petroleum Company North Tarn#1 Surface Interval Drilling Concerns ➢ Lithology through this zone is a composite of pebble conglomerate and sand in the upper intervals with intermittent clay matrix. Carbonaceous material and coal may be noted. Based upon work done on previous exploration wells, a gel based spud mud is recommended for the surface interval. Initial viscosities of 150 — 175 sec/qt should be maintained through the permafrost. 9-5/8— surface casing will be set and the cement will be pumped in a single stage to surface. ➢ Gravel sizes can cause hole-cleaning problems. If larger than normal gravel is encountered be prepared to increase funnel viscosity to+175-200 sec/qt. ➢ Sticky clays in the permafrost at and also in the zone below the permafrost can slow ROP from bit and BHA balling. If needed add DRILZONE (at 0.5 — 1.5%) and Nur PLUG M(as allowed by MWD tools)to help clean and clear the balled bit. ➢ Use as much cold water as possible for the initial make-up and for additions made to the mud system during the surface drilling operations to help prevent permafrost thawing. Try to keep flow-line temperatures of 60°F or less while drilling this interval. ➢ Maintain low flow rates for the initial 200' of drilling to reduce the chance of washing out the conductor shoe. ➢ Swabbing in the clays may also be a problem. Maintain or slightly increase mud weight (0.1 ppg) and continue additions of surfactant at 15 to 30 gallons per hour and wiper runs through the surface interval may be necessary to clear the wellbore of the problem clays. DRILZONE or ScREENKLEEN maintained at 0.5— 1.5% is also recommended to help with clay related issues. ➢ To help insure good cement to surface after running the casing, condition mud to a YP of at least 25 - 30 prior to cementing the casing. Do not lower the YP beyond 25 to avoid trouble with sands that may be found on this well. Use water sparingly and ensure proper solids control equipment utilization is being observed to reduce the over all haul-off costs for this well. ➢ Although a low potential risk, hydrates may be encountered (particularly at depths below the permafrost). Observe good drilling practices to determine severity of any influx and weight up as needed to maintain proper well control. See v" "Surface Hydrate Issues"enclosure for further information. Date: December 31,2010 Confidential 7 Brooks Range Petroleum Company North Tarn#1 Surface Interval Operations Recommendations Spud mud will be mixed on the rig or at M-I Swaco's Prudhoe Bay mud plant once the rig is spotted over the well. Use as much cold water as possible for the initial make-up and for additions made to the mud system during the surface drilling operations. ➢ Drill ahead maintaining volume as needed. ➢ Maximum fluid weight is planned to be 9.0—9.5 ppg for this interval. ➢ Run all solids control equipment. Run 84 - 110 mesh shaker screens to maintain a moist discharge for enhanced solids removal. Add drill water below shaker to avoid washing unwanted solids back into the active system. Watch for "excessively wet" cuttings and change screens to a larger mesh should this occur. Minimization of "excessively wet" cuttings sent to Grind and Inject for disposal is a major cost reduction factor. Lower API fluid loss with DRISPAC PLUS SL(or Poly Pac Supreme UL) as needed to maintain hole stability. ➢ To control rheology additions of CF DESCO II may be needed. ➢ Add DRILZONE or SCREENKLEEN (at 0.5— 1.5%)and Nut Plug (at 15 ppb)to reduce bit balling in the clay sections if needed. DRILZONE at 0.5- 1.5% may also be used to help with any clay issues. ➢ If hole conditions allow, let the YP drop to 25 — 30 (no lower than 25) prior to cementing of the casing. Allow surface mud volumes to fall during the later stage of this interval to minimize waste fluid disposal costs. ➢ Run and set the casing as per program. Treat the chase fluid and drill out mud for the upcoming cement drill out. ➢ Upon drill-out of the surface casing shoe, treat any cement returns with SAPP, Sodium Bicarbonate, and PH-6 as needed. Date: December 31,2010 Confidential 8 Brooks Range Petroleum Company North Tarn #1 Production Interval 1 Drilling Fluid System VersaPro NT Key Products LVT-200, IMG 400, Lime, VERSACOAT HF, VERSAWET,VERSAMOD, VERSAHRP, Brine (10.6 ppg CaCl2), MI WATE (Barite) Solids Control Shakers, Mud cleaner, Centrifuge Lithologic instability near the wellbore. Potential Problems Lost Circulation Hole cleaning. Production Interval Drill-in Fluid Properties Properties Initial Value Density(ppg) 9.8 ppg -Initial Make-Up Weight 10.0 ppg - Possible by TD Funnel Viscosity(seconds) _ 35-45 Yield Point(cP) 15-28 Plastic Viscosity(lb/100 sf) 15-25 Oil :Water 70 : 30 Electrical Stability(miVolts) 650 -900 HTHP Fluid Loss(m1/30 min/200 psi/150°F) <4 • VersaPro NT Formula Mineral Oil-LVT 200 (.825 SpG) 0.602 bbl IMG 400 6.0 ppb Lime 6.0 ppb VERSACOAT HF 5.0 ppb VERSAWET 2.12 ppb MI WATE 100 ppb Brine (10.6 ppg CaCl2) 0.165 bbl VERSA MOD 0.5 ppb VERSA HRP 0.5 ppb Date: December 31, 2010 Confidential 9 Brooks Range Petroleum Company North Tarn #1 Production Interval Operations ➢ This interval will be drilled using an 8.5" bit to an expected interval TD of 6,602' MD/6,453' TVD. Care should be taken to monitor all drilling criteria to ensure that best drilling practices are being observed. ➢ Maintain low gravity drilled solids to below 6%with solids control equipment and dilution. Use the MI Solids Van to supplement rig equipment, if needed. ➢ Use Virtual Hydraulics ECD predictions vs. PWD actual values to appraise hole cleaning and hole conditions. If possible do not allow actual ECD's to exceed 0.5 ppg over predicted "clean hole" ECD. ➢ Drill to interval TD and circulate the wellbore clean (3—4 bottoms up may be needed)in preparation for logging and testing. ➢ While drilling monitor the interval carefully for losses or gains. ➢ Log and/or test the well as per program. ➢ Plug back to inside 9 5/8"casing as per program. Kickoff of cement plug and drill North Tarn 1A to 6,995' MD/ 6,453 TVD. The VersaPro OBM can be reused and reconditioned upon drilling out cement plug. Date: December 31,2010 Confidential 10 Brooks Range Petroleum Company North Tarn #1 Production Interval 1A Drilling Fluid System VersaPro NT Key Products LVT-200, IMG 400, Lime, VERSACOAT HF, VERSAWET,VERSAMOD, VERSAHRP, S-200, Brine (10.8 ppg CaCl2), MI WATE (Barite) Solids Control Shakers, Mud cleaner, Centrifuge Lithologic instability near the wellbore. Potential Problems Lost Circulation Hole cleaning. Production Interval Drill-in Fluid Properties Properties Initial Value Density(ppg) 10.0 ppg by TD Funnel Viscosity(seconds) 35 -45 Yield Point(cP) 15 -28 Plastic Viscosity(lb/100 sf) 15 -25 Oil :Water 70 : 30 Electrical Stability(mlVolts) 650 -900 HTHP Fluid Loss(ml/30 min/200 psi/150°F) <4 Date: December 31, 2010 Confidential 11 Brooks Range Petroleum Company North Tarn#1 Production Interval "1A" S.C.E. Operation Standards: Shakers- • Inspect decking rubbers, do as necessary. • Install XR Magnum screens (175-210 mesh). Ensure screens are properly tensioned, per M-I Swaco's best practice suggestions. Spray down new screens with fresh water before operating the shakers. • Set counterweights to 90% (7.8 G's)for optimum performance. • As fluid shears, screen up as necessary to higher mesh screen sizes. 210 mesh is optimum to reduce sand sized particles. • Ensure jacking system on ALSII shakers enables the fluid to flow to the center of the screens, adjust and lock as necessary. De-Silter- • Ensure cuttings trough bypasses shakers, and goes into cuttings ditch. Failure to do so will allow small particles to enter right back into system through the flow line shakers (84-110 mesh screens). • Install 3/8"Apexes. • Ensure that"feet of head"gauge is available at the De-Silter, not the pump. • Ensure that De-Silter feed pump can achieve 95' of head. CRITICAL! • Monitor discard, change apexes as necessary to improve solids content in mud (it may be determined that 3/8"apexes can be installed if cuttings in the system happen to be finer than presumed) • Discard should be 2-3 ppg over feed weight. Centrifuge- • Production intervals generally call for a "high-speed" centrifuge, which is rotating at approximately 3200 rpm's. This allows the centrifuge to make the 3-6 micron cut, and eliminate a percentage of the "ultra fine" cuttings from the fluid. Through put must be decreased while running the centrifuge at 3200 rpm's, since there is a greater risk of "packing off' the centrifuge back drive and auger. Swaco would also suggest installation of amp meter on the back drive motor which will allow the operators to monitor the feed rates by knowing how much torque the back drive motor is receiving while trying to discharge the cuttings. • Refer to mud man for solids information to determine speed and feed rate of centrifuge. • Continual processing at low feed rates will yield better results than shutting centrifuge down and starting it up. Slow feed rate down to maintain an acceptable weight if needed. Date: December 31,2010 Confidential 12 Brooks Range Petroleum Company North Tarn #1 Production Sidetrack Interval Considerations :- Ensure that the fluid properties are maintained to provide the best possible hole cleaning. Maintain mud weights as per drilling program guide lines and ensure that rheology is optimized to reduce ECD's to a manageable level while drilling. Monitor for any fluid losses and flow back closely. P Control the ROP and flow rates as needed to avoid inducing a breakdown of any formations. Reduce pump rates immediately if packing off occurs. Pump high viscosity weighted sweeps and ream carefully to clean the hole before proceeding with further drilling Adjust rheology, pipe rotation speed, pipe running speeds and pump rates as needed to balance hole cleaning and ECD. Use good drilling and tripping practices. Break circulation slowly — Reduce pump speed 15 to 20% while reaming down. As an exploration well, pore pressure uncertainty also exists. Use all means possible to evaluate well conditions to determine if fluid properties are in line with the needs of the well. Monitor and record drilling parameters on each connection and before and after any lubricant additions. Upon reaching TD watch the bottoms-up cuttings closely. If the well does not readily cleanup or if there are any excess of torque, drag, pick-up or slack-off weights pump a second high viscosity /weighted sweep and observe bottoms up again. • Establish good hole conditions for any logging and testing that may be performed. • Fluid deliveries, fluid transfers, and cuttings disposal issues will be tracked on a daily basis. Date: December 31,2010 Confidential 13 Brooks Range Petroleum Company North Tarn #1 Surface Interval Hydrate Issues f` Use the following guidelines to help minimize the effect that any hydrates which may have to the drilling operation. • Add 2 ppb Lecithin to the mud prior to drilling into the zone below the permafrost. CF DESCO II may be used to adjust rheology after the Lecithin additions are made. • Weigh the mud at both the possum belly and at the suction pit using pressurized and regular mud balances to determine the amount of gas that has become entrained in the mud. • Maintain the fluid at below 60°F if possible. • Minimize circulation time to reduce hydrate thawing. • Watch both drill rates and flow rates and make adjustments as needed to help diminish any problems that the surface equipment may have in handling the fluid and cuttings while circulating out any hydrates. • Weight up prior to drilling out of the permafrost. Watch the rate of depletion of the hydrates and increase the weight as needed to control the gas breakout from the hydrates. Barite Sag Concerns Barite Sag (a reduction in the MW out due to the dynamic and static settling of barite) is a potential drilling hazard while using weighted fluids. Although this well is designed for a mud weights below—11.5 ppg unexpected conditions may make additional weight ups or lubricant additions necessary. Both of these changes may contribute to a more likely chance of barite sag issues. Barite Sag is also aggravated by circulating at low rates for extended periods of time or while tripping with drill pipe or casing. As a consequence, if it becomes necessary to circulate at reduced rates, it is recommended that the pit watcher weigh and record MW out using a pressurized and un-pressurized balance every 15 minutes. Trips and casing running should also be closely monitored for indications of barite sag. Date: December 31,2010 Confidential 14 Brooks Range Petroleum Company North Tarn#1 Lost Circulation Guidelines for Water-base Mud Losing fluid while drilling i Stop drilling and observe levels w Losses on surface Yes No Locate and stop losses V Yes Well flowing? No Record shut in pressure.Kill the well Measure rate of loss 1 Seepage losses<10 bbl/hr Partial losses 10-100 bbl/hr Total loss of returns 1 1 1 Water-based Water-based Water-based mud mud mud VT Pump 100 bbl pill of: Continual additions of Mix Pump 50 bbl pill of: CaCO3 60-20 ppb II at 4-8 sacks/hr Change CaCO3 60-20 ppb shaker screens to 84 mesh CaCO3 15-15 ppb if convenient. CaCO3 15-20 ppb CaCO3 500-15 ppb MI Seal-20 ppb MI Seal-20 ppb Mix 11 10 ppb Nut Plug-20 ppb Mix ll-10 ppb T Spot pill: No success Spot plug: Mica M 10 lb/bbl VersaPac or"Form-a"pill or No success —Mix II M. 15 lb/bbl Reverse Gunk or Cement Mix II Coarse 10 lb/bbl Spot plug: G-Seal 20 lb/bbl "Form-a"pill or Calc.Carb(C) 10 lb/bbl Gunk or Nut Plug M 10 Ib/bbl Cement Date: December 31,2010 Confidential 15 Brooks Range Petroleum Company North Tarn #1 Recommended Lost Circulation LCM guidelines for VERSAPRO NT MOBM The following lost circulation "Decision Tree" is recommended for use in the event that losses occur while drilling the horizontal production interval. It has been selected because of its' compatibility with base oil and ability to seal with minimal formation damage. These products are predominately acid soluble which will make any stimulated cleanup (if needed) much easier. Losing fluid while drilling Stop drilling and observe levels 1 Yes Losses on surface No Locate and stop losses Yes Well flowing? Record shut in Measure rate of loss pressure. • Kill 1 1 • Seepage losses< 10 bbl/hr Partial losses 10-100 bbl/hr Total loss of returns Oil/synthetic Oil/synthetic Oil/synthetic mud mud mud ♦ l 4, Spot pill: Spot pill: Squeeze pill: G-Seal 15 ppb —I No success —11°. Mica M 7 ppb — No success FORM-A-SQUEEZE 80 ppb Calc.Carb.(M)10 ppb Calc Carb Med. 10 ppb in base oil weighted up to CaIc.Carb(C) 7 ppb G-Seal 20 ppb desired density Calc.Carb(C) 7 ppb No success Ensure particle sizes of bridging materials can pass through the downhole tools and motors prior to mixing and spotting. Spot pill across thief zone, if losses stop, pull into casing and apply 50-100 psi squeeze pressure and watch for pressure bleed- off. If pressure holds for 15 minutes, resume drilling. If pressure does not hold, spot another pill as described above. Be sure to clear the motor with any Lost Circulation pill. Date: December 31,2010 Confidential 16 Brooks Range Petroleum Company North Tarn #1 Recommended LCM Pill for VersaPro System The following lost circulation pill is recommended for use in the event that losses occur while drilling the horizontal production interval. It has been selected because of its' ability to seal with minimized formation damage. These products are predominately acid soluble which will make any stimulated cleanup (if needed) much easier. ➢ To existing VersaPro NT circulating fluid make a LCM pill with: • 15 ppb LoWate (fine calcium carbonate) • 15 ppb Safe-Carb Medium (medium calcium carbonate) • 15 ppb Safe-Carb Coarse (course calcium carbonate) Insure particle sizes of bridging materials can pass through the downhole tools and motors prior to mixing and spotting. 1. Spot pill across thief zone, if losses stop, pull into casing and apply 200-psi squeeze pressure and watch for pressure bleed-off. If pressure holds for 15 minutes, resume drilling. If pressure does not hold, spot another pill as described above. 2. If losses cannot be stopped with calcium carbonate only, mix up a LCM pill with 25 ppb MIX II Fine and 15 ppb MIX II Course cellulosic material and spot as above. If seepage losses occur after drilling is resumed, consideration should be given to adding 5 -8 ppb MIX II Fine cellulosic material to system while circulating. Date: December 31,2010 Confidential 17 Brooks Range Petroleum Company North Tarn #1 HSE Issues Handling of Drilling Fluid Products Health and Safety ➢ Drilling crews should be instructed in the proper procedures for handling fluid products. ➢ Personal Protective Equipment (PPE) charts should be posted in the pit room, the mud lab, and the office of the Drilling Forman. ➢ PPE must be in good working order and be utilized as recommended by the PPE charts. ➢ Product additions should be made with the intent to use complete unit amounts of products (sacks, drums, cans), as much as possible in order to minimize inventory of partial units. ➢ Ensure all MSDS sheets are up to date and readily available for workers to access for information. Environmental ➢ Ensure that all product stored outside is protected from the weather. ➢ Do not store partial units (sacks)outside if possible. ➢ When transferring fluids and/or cuttings from the rig to tanks, ensure all hoses are properly secured. Perform a transfer checklist as needed in order to avoid spills. Date: December 31,2010 Confidential 18 Brooks Range Petroleum Company North Tarn #1 PPE Chart HAZARDOUS MATERIALS IDENTIFICATION SYSTEM Product Function Health Flammability Reactivity PPE CAUSTIC SODA Alkalinity control 3 0 1 X PH-6 pH Adjuster 1 0 _ 0 E DEFOAM X Defoamer _ 1 1 0 J CF DESCO II Dispersant 1 1 _ 0 E SCREENKLEEN Surfactant 1 1 0 E GREEN CIDE 25G Biocide 3 0 0 J MI WATE (Barite) Weighting Agent _ *1 0 0 E MI GEL Viscosifier _ *1 1 0 E MIX II Lost Circulation Material *1 1 0 E DRISPAC PLUS SL Fluid Loss Reducer 1 1 _ 0 E - SAPP Dispersant _ _ 1 1 _ 0 E MI GEL Viscosifier *1 1 0 E GELEX Bentonite Extender 1 1 0 E LVT 200 Mineral Oil 1 1 0 J VG SUPREME 'Viscosifier 2 1 0 J LIME Calcium Source 2 0 0 E VERSACOAT HF Emulsifier *2 3 0 J VERSAWET Drilling Fluid Additive 1 1 0 J CACL2 Weighting Agent 1 0 1 E VERSA-MOD Rheology Modifier 1 2 0 J VERSA HRP Viscosifier 2 1 0 J SAFECARB Bridging Agent *1 0 0 E (HMIS) HAZARD RATINGS 4- Severe hazard 3 -Serious hazard 2- Moderate hazard 1 - Slight hazard 0- Minimal hazard * An asterisk next to the health rating indicates that a chronic hazard is associated with the material. HMIS PERSONAL PROTECTIVE EQUIPMENT INDEX A- Safety Glasses B- Safety Glasses, Gloves C - Safety Glasses, Gloves, Synthetic Apron D- Face Shield, Gloves, Synthetic Apron E - Safety Glasses, Gloves, Dust Respirator F - Safety Glasses, Gloves, Synthetic Apron, Dust Respirator G - Safety Glasses, Gloves, Vapor Respirator H - Splash Goggles, Gloves, Synthetic Apron, Vapor Respirator I - Safety Glasses, Gloves, Dust and Vapor Respirator J - Splash Goggles, Gloves, Synthetic Apron, Dust and Vapor Respirator K-Air Line Hood or Mask, Gloves, Full Suit, Boots X- Consult your supervisor for special handling directions. F Date: December 31, 2010 Confidential 19 Brooks Range Petroleum Company North Tarn #1 See Material Safety Data Sheets(MSDS)for more information M-1 L.L.C,Occupational Health Department (Revision—April 10,2003) Houston,TX,Telephone: 281/561-1509 M-1 L.L.C,Occupational Health Department (Rev.4 Aug-98) Houston,TX,Telephone: 281/561-1509 080598PRHS-1 14/411..rim 5 4V Is sd'aGio,cAw. 11. 0 ® 0 Date: December 31,2010 Confidential 20 4/1\471)/\"\ 111 Brooks Range Petroleum Corporation Brooks Range Petroleum Corporation 510 L Street Suite 601 Anchorage, AK 99501 North Tarn North Slope Alaska North Tarn 1 Cementing Services Prepared for: Natasha Sachivichik Senior Drilling Engineer December 20, 2010 Version: 1 Submitted by: Phillip Clingman Halliburton 6900 Arctic Blvd Anchorage, Alaska 99518 (907) 275-2630—Office (907) 947-5482—Cell HALLIBURTON Brooks Range Petroleum Corporation ./// i \ Cementing Services North Tarn 1 Brooks Range Petroleum Corporation EXECUTIVE SUMMARY 9-5/8" SURFACE CASING SUMMARY The slurry design volumes are based on bring cement to surface and with the top of the tail cement 500' above the shoe with 250%excess for the lead cement and 40%for the tail cement.. Fluid Summary 10 bbl Water Spacer 40 bbl Dual Spacer 417 bbl(557 sk)Type L Permafrost Cement mixed at 10.7 ppg 45.5 bbl(216 sk)Premium Cement with 2%Calcium Chloride mixed at 15.9 ppg 195 bbl Mud Displacement ECD Program based on 2,660'of fill and a frac.gradient of 13 ppg 2,660'MD/2,660'TVD. Lead Slurry Fill Tail Slurry Fill ECD 2,160' 500' \' 12.1 ppg PLUG SUMMARY el ci,vo NT-1 Plug#1—8-1/2"OH Sectio Objective: Set a series of balanced plugs from TD to 5,014' across the oil bearing zone(KUP C and North Tarn Sands)in the 8-1/2"OH section. Spacer 20 bbl 11 ppg Dual Spacer Slurry 99 bbl—231 Sks. Premium Cement, 3%Econolite,+.5%CFR-3, +0.5%Halad-344, and HR-5 as required mixed at 12 ppg Spacer 20 bbl 11 ppg Dual Spacer Slurry 45.6 bbl—223 Sks. Premium Cement, 1%Calcium Chloride,+ .2%CFR-3,+0.5% Halad-344,and HR-5 as required mixed 15.8 ppg NT-1 Plug#2—Kick Off Plug Objective: Set a 500' balanced plug from 3,500' to 3,000' in the OH section to provide a plug to sidetrack to the well. Spacer 20 bbl 11 ppg Dual Spacer Slurry: 45.6 bbl—259 Sks. Premium Cement,+.5%CFR-3,+0.5%Halad-344,and HR-5 as required mixed at 17 ppg HALL#BURTON 3 Brooks Range Petroleum Corporation i�/^ , ,,,,/ , , Cementing Services ,?' North Tarn 1 Brooks Range Petroleum Corporation NT-1A Plug#1—8-1/2"OH Section Objective: Set a series of balanced plugs from TD to 5,014' across the oil bearing zone (KUP C and North Tarn Sands) in the 8-1/2"OH section. Spacer 20 bbl 11 ppg Dual Spacer Slurry 99 bbl—231 Sks. Premium Cement, 3%Econolite,+ .5%CFR-3,+0.5%Halad-344, and HR-5 as required mixed at 12 ppg Spacer 20 bbl 11 ppg Dual Spacer Slurry 45.6 bbl—223 Sks. Premium Cement, 1%Calcium Chloride,+ .2%CFR-3,+0.5% Halad-344, and HR-5 as required mixed 15.8 ppg NT-1 Plug—Surface Shoe Plug Objective: To effectively segregate the uncased and cased portion of the wellbore a EZSV bridge plug will be set 100' above the 9-5/8"casing shoe and cement downsqueezed through the plug.A 200' cement plug will be squeeze through the plug and a 50' cement plug will be placed on top of the bridge plug. Slurry 20.5 bbl—47.8 Sks. Premium Cement, 3%Econolite,+ .5%CFR-3,+0.5%Halad-344, and HR-5 as required mixed at 15.8 ppg NT-1 Plug—Surface P&A Plug Objective: Set a 150' balanced plug from 155' below the surface 5' below grade. Slurry: 12.5 bbl—73 Sks. Type C Permafrost Cement mixed at 15.6 ppg HALLALBURTON 4 ( RGA di7) 4 pro 2/1-001 / /)/ /N. Brooks Range Petroleum Corporation Bottom Hole Conventional DST Procedure 1 Mobilization and Setup surface equipment/prepare for DST operations 1.1 Mobilize surface testing equipment on location Rig up test surface equipment according to surface layout diagram(see attachment).The surface will be setup on 1.2 berms and will include hardlines,test separator,oil tank,gas vent tank 1.3 The plan is to produce a maximum of 500 BBL of well fluid(single tank), Produced gas will be vented in the atmosphere. Expected maximum gas volume is 350k cf(based on average GOR 1.4 of 712 in the Tarn oil field) 1.5 All testing equipment will be positioned at least 100 ft from the rig 1.6 Rig up slickline and a lubricator for the PVT sampling 1.7 Secure area around the test equipment. 1.8 Perform a BOP test before starting the DST test(regular BOP tests are every 7 days on exploration drilling) Review the well control procedure with the rig crew and personnel involved in the DST operations.Stabbing 1.9. valve will be checked and located on the floor at all times 2 Making up DST tools 2.1 Conduct Safety Meeting with rig crew and relevant personnel. 2.2 Pick up first joint/stand of tailpipe,and make up bullnose. Note: HW dp is preferred for tailpipe, but collars can be used if necessary. Do not use regular dp or tubing for tailpipe. 2.3 Make up joints/stands of tailpipe as required, in order to place the packers above the interval, and account for any hole fill. Note:Strap pipe/tools while RIH. 2.4 Pick up the Extension Joint. Pick up the jars,and make up below the extension joint.These are Lee oilfield jars,which jar up. Pick up the safety joint,and make up below the jars.This is a coarse thread ACME equivalent left hand release. Pick up the upper packer,and make up below the safety joint. Pick up the lower packer,and make up below the upper packer. Pick up the perforated pup, and make up below the lower packer. Pick up the dual recorder carrier,and make up below the perforated pup. Make up assembly to tailpipe section. 2.5 Check that the recorders are functioning and set correctly, and load them into the recorder carrier. Note: recorders can be set for 5 sec or 1 min rate. Max timing on 5sec sampling is 35-45hrs from makeup. There is no provision for variable sample rates. 2.6 RIH,tightening/checking joints while doing so. Set in slips with dog collar. 2.7 Pick up the pump-out sub. Pick up the recorder carrier,and make up below pump out sub. Pick up the shut in tool. Ensure upper adaptor is set correctly(turned all the way counter clockwise less%turn), and make up below the recorder carrier. Pick up the hydraulic valve,and make up below the shut in tool. Pick up the fluid sampler,and make up below the hydraulic valve. Pick up the squeeze tool,and make up below the fluid sampler. Note: max sample size is 3-4L 2.8 Make up assembly to string and RIH to recorder carrier, checking/tightening joints while doing so. Check that the recorders are functioning and set correctly,and load them into the recorder carrier. Note: Recorders can be set for 5 sec(Max 500,000 samples) RIH,checking l tightening joints while doing so. Set in slips with dog collar per Northstar. 2.9 Ask the driller to lock the rotary while RIH. This is to ensure that the shut in tool does not rotate from the initial position. 3 Running into the hole 3.1 RIH collars as necessary to achieve required string weight per Northstar. NB: Northstar recommends stands of spiral collars required. Strap while RIH. Note: Observe string weight carefully while RIH. A sudden loss of weight could cause the packer elements to expand and become damaged if pushed through an obstruction. 3.2 Line up well on trip tank. Mudloggers to monitor trip volumes and ensure drill floor advised if any variances on trip in hole.Variance could be an indicator of a string leak or well kick. RIH on stands of dp or tubing to the bottom at 5200' MD/TVD as determined by pipe tally filling the pipe as follows: (Calculated formation pressure at 5200' is 2370 psi. Required underbalance of at least 800 psi corresponds to 2,194' of empty do. Run first 3006'of do with mud. Pressure test the drill pipe to 2,500 psi (Surface MASP) Run the rest of DP empty. Run in the last 2—3 stands very slowly, in case there is an unexpected level of hole fill. Note: EMW in Brookian is 2370 psi/5200'/0.052=8.76 ppg. Hydr. Pressure from Mud column in DP is 9.5 ppg*0.052*3006= 1485 psi. Resulting underbalance 2370 psi- 1485 psi= 885 psi. The cushion height will be adjusted in the field based on the depth and the diesel weight. Tag bottom with no more than 5000 lbs. Mark the pipe, and pick up the string quickly to ensure that the hydraulic valve does not open. Note: When near hole bottom, ensure last movement is up before setting the slips, in order to safeguard against accidental opening of the hydraulic tool. 3.3 Determine the amount of pipe stick-up required, accounting for any hole fill. Note:The string will probably'skid'through any hole fill upon opening of the zone. There should be enough stick-up remaining after this has occurred. 4 4 Installing surface equipment 4.1 The rotational flow head is to be installed above the final single required. See attached flow head diagram. 4.2 Install a pup joint and a second TIW valve just below the Flow Head. This pup joint will be used to drop a bar for the burst disk 4.3 Function test the hydraulic actuated remote control valve on the flow head. Determine and document the string weight when the pipe is moving upwards,this will differ from the string weight on the way down. 4.4 Connect the hard line(with chicksans for flexibility)coming from the flow head to the inlet side of the test separator. Attach the outlet side of the separator to another hard line going to a test tank. Connect the other side of the flow head to the kill line of the rig. Line up the rig pump to pump into the well. 4.4 All lines should be checked for plugging by blowing rig air through it before testing commences. 4.5 With Flow Head Flow and Kill valves open, both kelly cocks closed and P-test the surface lines to 5000 psi with the rig pumps or a test pump. 4.6 Cycle the Flow head lower kelly cock OPEN 4.7 Pick up the top single and Flow Head(pre assembled),and make up the Kelly cock valve(open position)below. Run into the mousehole and make up Flow Head connections to surface pipework. Make up the Flow head assembly to the string. 4.8 Connect the hard lines from the flow head to the test separator choke manifold. Install surface gauges. 4.9 Ensure the lines is adequately anchored in place. Pressure test lines between Flow Head and rig choke manifold. 4.10 Surface recorders are located on the separator choke manifold. Ensure rig gas detector equipment is functional and ready. Check hole is full and monitor for 15 mins before commencing flow after packers set. Ensure various choke inserts available on the test separator.Well to be opened for initial flow on variable choke. Note:A 3/8"choke will be used on main stabilized flow period. 4.11 Conduct pretest meeting JSA. Ensure all necessary safety precautions and equipment are in place. Ensure the roles and responsibilities of all personnel during testing operations are clear. Ensure the channels of communication are clearly defined and understood by all involved personnel. Ensure all required approvals and safety checks have been made before beginning the well test. The proposed duration of flow period is 5 hr and a then shut in for a build-up period (until stabilized). AOGCC production data for the Tarn field shows the average daily production between 950 BFPD (350 BOPD) — 1655 BFPD(1300 BOPD)per well. Based on the expected flow rate range is 40-55 bbl/hr(total fluid rate). This means the first formation fluid will arrive to surface after 2.5 hours(DST string volume is'140 BBL). Note:The volume of produced fluid is limited to 500 bbl(Tank Capacity) Note: Ensure the current wind direction and the predicted wind direction for the duration of the test will blow vented gas away from the rig and camp. 4.12 The packers will engage and set with 20,000 lbs weight. The driller should be instructed to monitor the weight gauge during testing,and ensure the weight on the packers stays within the range determined by Northstar. 4.13 Open the Flow head. RIH,expecting to tag bottom at the previously marked pipe position. Set down 20,000 lbs. 4.14 When the hydraulic valve opens, the string should immediately start to skid. Ensure that the driller stays within the specified weight range.Once skidding stops,check that the weight on packers is the same as at the start. Note: Keep the driller on the brake for the entire pre-flow,as the string may continue to skid throughout. 4.15 Monitor the pressure gauges. Record the time for fluid to surface. Note: If the flow to the tank stops,the well has self killed and will not flow naturally to surface. Note:lf mud losses occur in the annulus,the packer seat may have been lost. Check the set down weight is correct. If weight ok,prepare to kill well and POOH. 4.16 Carry out the flowing and build-up periods in accordance with the pre-programmed plan, modified if necessary by the well response. RIH with a slickline and double sampler bomb (2 x 600m1 PVT sample bottles, double sampler is run to ensure a redundant samples). Stop at least 10 ft above the rupture disks located in the pump-out sub to avoid premature opening of the Pump Out Sub. Draw fluid samples. The well is shut-in for build up, by rotating the string. See the note immediately below. Allow string to bleed down through the separator into the oil tank At the end of the flowing period(s), shut-in the well at the hydraulic valve by picking up the string.After the required build-up period has elapsed, re-open the well(if required)by repeating from step 4.13 Note:To close/open the shut-in valve; Set the slips. Mark both the stationary and rotating parts of the table. If well is deviated, attach a string or tape to the pipe in order to count rotations. Rotate clockwise 5 full turns. Surface pressure should bleed off. Do not move the string vertically,except to keep the weight on the packers within range.The hydraulic valve remains open throughout the test. 4.17 At the end of the final shut-in, prepare to POOH. 4.18 Close safety valve,Close BOP pipe rams.Line up to trip tank. Install the drop bar in the FCH.Drop the bar.Wait required time(per Northstar recommendations). Pump mud down the annulus to reverse out string fluid through the separator into the oil test tank. Capture samples at surface per the sampling schedule(TBA). Open the BOPs when string has been circulated to mud. 4.19 Disconnect the surface test manifold. 4.20 Pick up string until packers release. Close BOP pipe rams immediately and monitor the pressures in the annulus and the tubing for a few minutes to let gas move upwards in the annulus above the circulating ports and then start circulating. Circulate out with BOP pipe rams closed through the open choke. Use standard procedure for circulating out a gas kick. 4.21 POOH 4.22 Break out and lay down test tools per Northstar, taking care to note recorder locations and identification for data integrity. Remove gauges on floor and download data via data cable to Northstar computer. Send ASCII file to BRPC' - Larry Vendl (Larry Vendl [Ivendl@brpcak.com]) Break out sampler sub (may be small HC pressure release of trapped pressure between Hydraulic valve and sampler). Lay sampler down on catwalk. Install in vice, back off bleed off ports and if required, tie in Oil Phase sample bottles to acquire necessary samples(The samples will be under pressure, however,these are not true PVT samples). If pressured samples not required, bleed off pressure and drain sample through port. Break off sampler bottom to remove balance of sample(ensure 5L pail available). 5 Post Test Operations 5.1 Re-dress the DST tools on location. Prepare to test Kuparuk formation in 4 days. 5.2 Secure and disconnect the hard lines. 5.3 Leave the testing equipment on location until the Kuparuk flow test is complete. 5.4 Repeat the DST procedure for the Kuparuk reservoir. Steps 1.1 to 4.21 Produced oil will be measured my the test separator flow meter and by tank strapping,then transported to 5.5 CPF3 and sold to ConocoPhillips and added to the general production steam. 5.6 The produced gas will be released to the atmosphere. 5.7 Secure and disconnect the hard lines. 5.8 Leave the testing equipment on location until the Kuparuk flow test is complete. Northstar `'_/ rLL.5itJ,a ;L) L/,> COMPANY: Fluid : Zone: WELL: BHT: Report No: RIG: 0 DST#: Deviation: Date: STRING DESCRIPTION OD ID TOP BTM LENGTH DEPTH(mtr) REMARKS inch inch CONN CONN Meter TOP BTM 0 ....I'M" FAIL-SAFE HEAD 5" 225" N/A 3-1/2IF 5.35 0 tri 0 _ = STICK-UP (] TIW(STABBING VALVE) 5 2-12" 3-1/2 IF 3-1/2 IF 0.30 5.35 5.65 3-1/2 IF DRILL PIPE 4-3/4" 2-1/2" 3-1/2 IF 3-1/2 IF 2860.00 5.65 5.95 CROSS OVER 4-3/4" 2-1/2 3-1/2 IF 4 1/2 IF 0.30 5.95 2865.96 5 STAND COLLARS 65/8" 35/6 4 1/2 IF 4 1/2 IF 140.00 2865.96 2866.26 APUMP-OUT SUB 6-5/8" 3-5/8" 4-1/2 IF 4-1/2 IF 0.30 2866.26 3006.26 f 1 1 STAND COLLARS 6-5/8" 3-5/8" 4-1/2 IF 4-1/2 IF 28.00 3006.26 3006.56 L CROSS-OVER 500" 2.50' 4-1/2IF 3-1/2IF 0.30 3006.56 3034.56 PUMP-OUT SUB 5" 2.25" 3-1/2 IF 3-1/2 IF 0.30 3034.56 3034.862 3034.86 3035.16 GAUGE CARRIER 5" 00" 3-1/2 IF 3-1/2 IF 1.5 SHUT-IN TOOL 5" 3/4" 3-1/2 IF 3-1/2 IF 1.62 3035.16 3036.68 DH HYDRAULIC VALVE 5" 3/4" 3-1/2 IF 3-1/2 IF 1.62 3036.68 3038.30 DH SAMPLER 5" 3/4" 3-1/2 IF 3-1/2 IF 1.12 3038.30 3039.92 SQUEEZE TOOL 5" 1.00" 3-1/2 IF 3-1/2 IF 1.00 3039.92 3041.04 GAUGE CARRIER 5" 1.00" 3-1/2 IF 3-1/2 IF 1.52 3041.04 3042.04 EXTENSION JOINT 5" 1.00" 3-1/2 IF 3-1/2 IF 1.84 3042.04 3043.56 JAR 5" 1.00" 3-1/2IF 3-1/2 IF 2.10 3043.56 3045.40 SAFETY JOINT 5" 2.00" 3-1/2 IF 3-1/2 IF 0.73 3045.40 3047.50 I I COMPRESSION PACKER 71/2" 2" 3-1/2IF 3-1/2IF 1.78 3047.50 3048.23 I 1 COMPRESSION PACKER 71/2" 2" 3-1/2 IF 3-1/2IF 1.82 3048.23 3050.00 TOP OF INTERVAL 1.11 PERFORATIONS X 2 5" 1-1/2'• 3-1/2 IF 3-1/2 IF 2.99 3050.00 3052.99 Lnl DBL RECOERDER CARRIER 5" N/A 3-1/2 IF 3-1/2 IF 1.86 3052.99 3054.85 SPACING 5" 2-1/4" 3-1/2 IF 3-1/2 IF 3054.85 3054.85 CROSSOVER 5" 2-1/4" 4-1/2 IF 3-1/2IF 0.30 3054.85 3055.15 ziatig COLLARS a3/a" 2' 41/2 IF 41/2 IF 602.00 3055.15 3657.15 Li CROSS-OVER 030 41/2 IF 4 1/2IF 0.30 3657.15 3657.45 BULL NOSE 5" N/A 3-1/2 IF 3-1/2 IF 0.60 3657.45 3658.05 REMARKS: Squeeze Tool should be replaced with a 1'spacing if Injecting or on underbalanced wells. Rupture discs should be replaced with shear pins if injecting or on underbalanced wells. 08/12/20101211 PM W N CC �d O m Co Tr0 ,• , Co co D N 0 % J XOD a N O 7. e..... 0 7 00 0,71 (D 00 m p m N o O O oN It N w N C • 3 IA 7 P1 0 m 0 O 'O O co O .OF 3 1- DI d Z '< O O .=F S IDor W 3 F+ CO G 7 a o m R 0 0 0 3 00 00 Z 0 i z0 VI n m FI Co ID W N F.‘ 1 CO 0 CO rn X X X O O O O X X X y0j 9 9 9 O 3 H Page 1 of 1 Schwartz, Guy L (DOA) From: Schwartz, Guy L (DOA) Sent: Tuesday, February 01, 2011 3:03 PM To: 'Natasha Sachivichik' Subject: RE: Open-Hole Conventional DST Procedure_Rev5 (North Tarn#1 PTD 211-001) Natasha, Thanks for the corrections and updates as we discussed. We will most likely find a few more after the meeting on Friday. See you then. Regards, Guy Schwartz Senior Petroleum Engineer AOGCC 793-1226 (office) 444-3433(cell) From: Natasha Sachivichik [mailto:natasha.sachivichik@solstenxp.com] Sent: Tuesday, February 01, 2011 2:42 PM To: Schwartz, Guy L(DOA) Cc: Bill Penrose; Jon Mitchell; Bart Armfield; Larry Vendl Subject: Open-Hole Conventional DST Procedure_Rev5 Guy, Please find attached the updated the DST procedure for the North Tarn-1 which I prepared for our discussion on Friday, Feb-04,2011. The updates included the following items: 1.Surface equipment includes test separator(with double choke and recording system),test oil tank,gas vent tank, hardlines(no hoses).The previous version had a double choke manifold and an open top tank. 2. Function testing of the hydraulically actuated safety valve on the flow head prior to start of the test. 3. Pressure testing of the tool string(integrity test) prior to testing will be performed with diesel(full column of diesel in the dp will give sufficient underbalance) 4. Reverse circulation after opening the pump-out sub will be done through the separator into the oil tank( not into the mud pit). Please let me know if you have any other questions or concerns. Thanks, Natasha. 2/1/2011 w 0 Him N Q 7n s V <47-11\ ice,.. 0 M z � TEN.► . N O 4 ‘...1 © '44 e N MI -- 1 4 SZ co ; w ; "am mall N n` 0 Ulu - El= .� I�I=C' �� � _ a -aN. a m 4 V (n l.a 01 (n N O b (b V n1 (n A. G N 4 i " F ,1) i cn i i i i i i i N I4 F 4 (.. W 4 CO N 4 ZZi OV O A NI 4 1 NN V V m N of V M O b i V I O to ,„ A V V G 1 b V ', X Q N a Z q & — .1 Z E Fa w o z _x as N ., -0 .n k (, y .1. ovaN "a-,::: Saltmarsh, Arthur C (DOA) From: Larry J. Smith [Ismith@brpcak.com] Sent: Tuesday, February 08, 2011 4:16 PM To: Saltmarsh, Arthur C(DOA) Cc: Natasha Sachivichik(natasha.sachivichik@solstenxp.com); Doug Hastings; Larry Vend! Subject: North Tarn-1 Shallow Hazard Analysis Attachments: North_Tarn-1_SHA Final_Report.pdf Art, Please find attached the North Tarn-1 Shallow Hazard Analysis for the permit to drill. Please confirm that electronic submittal is sufficient or if you prefer hard copies as well. Please let me know if you have any questions. r> pf 4S /. Thanks, CONFIDENT1A 6<dLarry J.Smith G24-1/ Chief Geophysicist Brooks Range Petroleum /4-51A_ !"�S tp 716 /6 510 L Street, Suite 601 Anchorage,AK 99501 f--c_ 4 Direct:907-865-5803 #`-4-:: Main:907-339-9965 Ut ' "`x- Fax:907-339-9961 Cell:907-317-2329 Email:Lsmith(a)brpcak.com z �� s.,s-./st Brooks Range Petroleum To: Art Saltmarsh(A.O.G.C.C) From: Larry Smith Re: Drilling Hazard Analysis for the North Tarn-1 Exploration well. Date: February 7, 2011 North Tarn-1 Gas Hydrates/ Shallow Gas Assessment From Seismic Data: Background: Investigation of seismic data for indications of potential anomalous high pressure zones is a requirement of the AOGCC Regulations. In practice, the only well to have experienced uncontrolled flow of shallow gas is the Cirque#1 well,which blew out in 1992 when it encountered an over pressured K-10 sand shallow to prognosis. Cirque#1 is located approximately 10 miles south of the proposed North Tarn-1 location(see Figure 1). • There were no recordable drilling incidents with any other closer exploration wells in the area(Oberon#1, Atlas#1, Colville River#1, and Ataruq-2). However,the recent incident during drilling of the Tarn 2L-320 development well, which took a kick in the K- 10 interval while drilling under balanced, illustrates that you need to be very careful not ✓ to drill the K-10 under balanced. ConocoPhillips investigated 3D seismic data at the Cirque location for shallow anomalies that could correlate with and indicate the risk of the gas that was subsequently encountered in Cirque#1 but were unsuccessful (from Buggenhagen, 2002). This conclusion makes reliance on seismic detection of shallow hazards uncertain at best. Analysis: Gas Hydrates Analysis: Depending on the geothermal gradient, gas hydrates can be stable to a depth well below the base of the permafrost(Figure 2). In the area of North Tarn-1, gas hydrates are expected to be stable from as shallow as 750 feet(figure 3)down to a depth of as much 2300 feet subsea(Figure 4). Below 2300 feet subsea, only free gas is expected. The locations of the two seismic lines included in this analysis are shown in Figure 5. Based on regional well correlations, the base permafrost is expected at about 1350 feet • subsea or about 0.300 seconds on the seismic. On the west to east seismic profile(Figure 6),there are multiple stacked high amplitude seismic events down to 0.420 seconds, or approximately 1750 ft, which is shallower then the base of the gas hydrate stability zone as predicted by Collett(2008). Below the base of the gas hydrates there are a few 510 L Street,Suite 601,Anchorage,AK 99501 Tel:(907)339-9965 Fax:(907)339-9961 North Tarn-1 Shallow Hazard Analysis scattered amplitude events which probably correlate to scattered sand deposits down to about the base of the K-10 interval at 0.570 seconds or about 2650 feet subsea. The south to north seismic profile which passes through the top-hole section of North Tarn-1 is shown in Figure 7. Again the base of the gas hydrates is expected to correlate to the purple event shown at about 0.410 seconds on the section. Below that depth any amplitudes seen down to the base of the K-10 interval at 0.580 seconds are expected to be scattered sands. The stacking velocity curves nearest to the surface location of North Tarn-1 are shown in Figure 8. From the graph you can see that, from the base of the permafrost, the stacking velocities decrease until 0.900 seconds where, presumably,the compaction effect starts to cause an increase in the rms velocities with depth. In Figure 9 you can see the seismic trace data of the west-east seismic profile overlain on the stacking velocities, which are shown in color in such a way as to clearly high light the permafrost and gas hydrate intervals. You can see the same display on the south-north seismic profile in Figure 10. To mitigate the risk of shallow gas hydrates, the North Tarn-1 drilling plan calls for drilling the hydrate section expeditiously while keeping the drilling fluids as cool as possible to slow the rate of destabilization of the gas hydrates. Over Pressure Analysis: As mentioned in the background section, two wells in the greater North Tarn-1 area have had incidents with encountering over pressured sands in the shallow K-10 section while drilling. The first well was Cirque#1 which blew out in February, 1992, when it encountered an over pressured K-10 sand shallow to prognosis, and was running under balanced while pulling out of the hole in preparation for setting the 9 5/8 inch casing • string (Ruckel, 1992). The primary cause of the blow out was attributed to excessive trip • speed which swabbed the well. The other incident was the Tarn 2L-320 development well in early January of this year. According to word on the street, casing was set above the K-10 sand but when they drilled out of the shoe with 9.1 lb/gallon mud, they took a kick in the K-10 sand and had / to weigh up the mud to 9.5 lbs/gallon to control the kick. On the south- north seismic profile shown in Figure 7 you can see a possible channel sand right at the K-10 interval which may pose a potential drilling risk. To mitigate the risk of encountering an over pressured K-10 sand, the North Tarn-1 drilling plan calls for setting the surface casing shoe above the K-10 sand interval and drilling out of the shoe with 9.5 lbs/gallon mud to ensure that we are overbalanced for the K-10 interval. ✓ 2 North Tarn-1 Shallow Hazard Analysis Shallow Fault Analysis: No apparent shallow faults are imaged on either of the two seismic lines. Conclusions: There appears to be both gas hydrates and K-10 channel sands in the proposed North Tarn-1 exploration well. However we believe that by following prudent drilling practices (careful mud volume monitoring; avoiding quick trips out of the shallow hole; drilling over balanced through the K-10 interval) that these risks can be properly mitigated. 3 North Tarn-1 Shallow Hazard Analysis Figures: Figure 1: Regional map showing the location of North Tarn-1,nearby wells and the seismic profiles included as Figures 6 and 7. Figure 2: Gas Hydrate stability plot(from Collett, 2008) showing that gas hydrates are stable well below the base of the permafrost. In this diagram with the geothermal gradient used, gas hydrates are stable as deep as 1100 meters (3300 ft). See Figure 4 for the predicted depth to the base of gas hydrates stability zone in the North Tarn-1 location. Figure 3: Regional depth map to the top of gas hydrate stability zone (from Collett, 2008). In the vicinity of North Tarn-1 Collett predicts that the top of gas hydrates should . be at about 750 feet. Figure 4: Regional depth map to the base of the gas hydrate stability zone(from Collett, 2008) showing that the approximate base of gas hydrates stability zone should be at approximately 2300 feet. Figure 5: Detailed base map showing the location of the seismic profiles presented in Figures 6 and 7. Figure 6: West to East seismic profile through the North Tarn-1 surface location. The predicted base of permafrost based on regional well correlations is at approximately 1200 • feet subsea. The higher amplitude events seen below the base permafrost are most likely gas hydrates which extend down to the predicted depth of 1800 feet subsea. The red log curve shown in the log track to the left of the well bore is the stacking velocity Vrms curve at the well location. The stacking velocity averages about 9800 ft/sec in the permafrost, then averages about 9600 ft/sec in the gas hydrate layers and then continues to decrease through the base of the hydrates. Figure 7: South to North seismic profile through the North Tarn-1 surface location again showing the base of the gas hydrates at about 1800 feet subsea. • Figure 8: Cross plot of the five nearest stacking velocity(Vrms)curves to the North Tarn-1 surface location showing that the stacking velocities continue to decrease below the base of the gas hydrates until 1.0 second(4100 ft ss)before compaction starts to reverse the trend. Figure 9: West to East seismic profile through the North Tarn-1 surface location with the stacking velocity Vrms velocities shown in color behind the amplitude trace data. Figure 10: South to North seismic profile through the North Tarn-1 surface location with the stacking velocity Vrms velocities in color behind the amplitude trace data. 4 North Tarn-1 Shallow Hazard Analysis References: Buggenhagen, John, 2002: Pre-drill Seismic Pore Pressure Prediction for Proposed Well . Oberon-1. Memo to Laurie St. Aubin and Mark Chambers: AOGCC Oberon-1 Well History File,pages 73- 96. Collett, Timothy, 2008: Assessment of Gas Hydrate Resources on the North Slope, Alaska, 2008. USGS web site: http://energy.usgs.gov/flash/AlaskaGHAssessment_slideshow.swf Ruckel, Douglas, 1992: Memo to Dave Johnston, AOGCC, Regarding the Cirque-1 Blowout of February, 12, 1992. AOGCC Cirque-1 Well History File,pages 5- 20. 5 ,-1 cb -C- = 0 u7 c -c L_ ,,, ro 48 C ity- - I— c — -• r-, itial < -_,k _C lc I , 3t ; . Aimlaw,. ..., 4-0 d coIV- 0 - - 2ffikinflitall U .,,-„ , z ik.....-1_Atettriz-,,15. .mst.“-,;!..-di. § ..-r... tw Ilk 4ipii olt. Pt_:-: -.4111, R ( ) 2 I 0 0., -,t, , _ ,.,„ ,, .0,0.....i....40t;.:,:. :..-....iii. ___I 'IA EVE'. ViZz'AMEkiii-ii111- .00 , ._, il 4 4C4.171, - it 111 150 o 5 C E 2 '-.--; = -, for-z- •:“.-i :Al g i co , , , . 4 I— 1 • N-4.4,-,,A. p 1 I - . „ ,, t ak A - ti,:t., ;.:,..111111111 8„ i , 1 1 iko,A111111 3 1.111‘,.41t . _ 4-0 r•-• . 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C J 1 _ .. ,„;,,„„(...,.., co 0 3 1� Jcoill 0.. � a a 0 a Q ^ Q _ �q• cn �` v g Cli I rr CO .� 2 WMz1 y N `fr C §. - !,N CU _ Dcu t CO• a •' Q M +-) i � � �o > � r, O f° u L (J rc 0 ,--1c--1 _cO ♦' N Oco Z N O 0 0 O O 0o M O O N • • o O O ti ti r o - W - Ce a LL VO 4:11 � O co O o v U o v G1 0 o WO CD ! / 1 , cp z :1- M 0" N „ Q • O a' O W O O O O O 0 0 O O O O O O O O O O O O 0, O 00 CO to LO LO Page 1 of 3 Schwartz, Guy L (DOA) From: Natasha Sachivichik[natasha.sachivichik@solstenxp.com] Sent: Saturday, January 08, 2011 12:39 PM To: Bart Armfield Cc: Jim Winegarner; Bill Penrose; Larry Vendl; Schwartz, Guy L (DOA) Subject: Re: North Tarn#1 - PTD 211-001 Bart, I will start putting together all required documentation and will request job experience and accident statistics from the Northstar people. I will be on the slope on Sunday and Monday, but I should be able to start working on the plan. Natasha. Sent fro my iPhone On Jan 8, 2011, at 7:12 AM, "Bart Armfield" <barmf eld@brpcak.com>wrote: Natasha, Please begin putting together all of the data we will need to support our argument to the AOGCC to get them comfortable with the DST we plan on N Tarn. Background presentation on Northstar as a company We may need to get job history and incident log from Northstar Tool diagrams and operational procedures Detailed DST plan for the Brookian and Kuparuk formations Let's review the policies, and I think there may be some new ones, regarding the reporting and documentation of formation kicks during drilling. I am sure that the AOGCC is under a higher level of scrutiny as a result of the BP incident in the gulf. Let's make sure we put a complete presentation package together and anticipate what their concerns will be. We should probably have a call on this next week to assign work product and develop a plan. Thanks Bait From: Natasha Sachivichik [natasha.sachivichik©solstenxp.com] Sent: Friday, January 07, 2011 4:34 PM To: Jim Winegarner; Bait Armfield Cc: Bill Penrose; Larry Vendl; Schwartz, Guy L (DOA) Subject: FW: North Tarn #1 - PTD 211-001 Jim, Bart, Larry, Page 2 of 3 Please see below the message from Guy Schwartz with AOGCC. Please let me know when would you like to hold a meeting and I will send a meeting invitation. In a mean time, if you wish I could provide more details about the DST procedures and the tool string to Guy. Please let me know. Natasha Sachivichik Senior Drilling Engineer <image001.png> 310 K Street,Suite 700 Anchorage,AK 99501 MAIN (907)264-6100 DIRECT (907)264-6116 CELL (907)575-7156 natasha.sachivichik@solstenxp.com From: Schwartz, Guy L(DOA) [mailto:guy.schwartz@alaska.gov] Sent: Friday, January 07, 2011 3:58 PM To: Natasha Sachivichik Subject: North Tarn #1 - PTD 211-001 Natasha, I am reviewing the PTD application for NT-1 and see that an open hole DST is planned in order to acquire reservoir fluid properties. I think it would be good to have a meeting to discuss this ... I need a lot more detail on the tools, operator expertise , contingencies and steps in order for the commissions to sign off on using this type of downhole assembly. North Slope operations/personnel do not typically see this so there is a higher risk operationally ... especially considering it is a controlled drilling kick. 1/1 1/7(11 1 Page 3 of 3 Could you forward this to Jim Winegarner also ... I don't seem to have his email. Regards, Guy Schwartz Senior Petroleum Engineer AOGCC 793-1226 (office) 444-3433(cell) 1/11/2011 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 �') � / ►� ✓l PTD# _i i ce) I Development Service 11 Exploratory Stratigraphic Test Non-Conventional Well FIELD: 7�� POOL: Circle Appropriate Letter/Paragraphs to be Included in Transmittal Letter CHECK ADD-ONS WHAT (OPTIONS) TEXT FOR APPROVAL LETTER APPLIES MULTI LATERAL The permit is for a new wellbore segment of existing well (If last two digits in Permit No. ,API No. 50- - - API number are between 60-69) Production should continue to be reported as a function of the original API number stated above. PILOT HOLE 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 ( PH) and API number (50- - ) from records, data and logs acquired for well SPACING The permit is approved subject to full compliance with 20 AAC EXCEPTION 25.055. Approval to perforate and produce / inject is contingent upon issuance of a conservation order approving a spacing exception. assumes the liability of any protest to the spacing exception that may occur. DRY DITCH All dry ditch sample sets submitted to the Commission must be in SAMPLE no greater than 30' sample intervals from below the permafrost or from where samples are first caught and 10' sample intervals through target zones. Non-Conventional Please note the following special condition of this permit: Well production or production testing of coal bed methane is not allowed for (name of well) until after (Company Name) has designed and implemented a water well testing program to provide baseline data on water quality and quantity. (Company Name) must contact the Commission to obtain advance approval of such water well testing program. Rev: 1/11/2008 -r,mn > o r- v (c -n -a 3 .�' �) 0 ° o Cr) 'a 3 0 - ..„.0 ' o p. 30 � CD vi 3 o N N j N 0 o ' (7 o - -, (C -. 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Days vs. Depth Digital Data to include: Formation Mud Logs Engineering Logs Gas Ratio Logs Halliburton Log Viewer EMF Log Viewer EOW Report PDF Version ADI Backup GENERAL WELL INFORMATION Company: Brooks Range Petroleum Corporation Rig: Nabors 9ES Well: North Tarn 1 Field: North Tarn Prospect Borough: North Slope Borough State: Alaska Country: United States API Number: 50-103206-33-00-00 Sperry Job Number: AK-AM-0008035432 Job Start Date: 8 Mar 2011 Spud Date: 13-Mar-2011 Total Depth: North Tarn 1 – 12.25 Surface Intvl: 2358’ MD/2336’’TVD Land 9 5/8” Casing: 2347’ MD/2325’ TVD Drilled 8.5” Prod Intvl: 6223’ MD/6146’ TVD North Tarn 1A – Sidetrack Intvl: 6070’ MD/6046’ TVD Land 7” Casing: 6056’ MD/6046’ TVD SDL Release Date: 16 Apr 2011 North Reference: True Declination: 20.940° Dip Angle: 80.780° Total Field Strength: 57605.98 nT Date Of Magnetic Data: 07 Mar 2011 Wellhead Coordinates N: North 70° 14’ 57.10” Wellhead Coordinates W: West 150° 16’ 15.17“ Drill Floor Elevation 97.80’ Ground Elevation: 69.30’ Permanent Datum: Mean Sea Level SDL Engineers: Danny Kane, Ryan Massey, Tom Mansfield, Mark Lindloff SDL Sample Catchers: Chris Woolley, Alton Schwenter, David Mckechnie, Herman Lilgreen Company Geologist: Doug Hastings Company Representatives: John Nicholson, John West SSDS Unit Number: 115 DAILY SUMMARY Begin North Tarn 1 08-Mar-2011 Sperry SDL arrives in Prudhoe Bay and arranges for transport of the unit to the rig site. Once on site, the unit is rough spotted in preparation for rig-up. 09-Mar-2011 Continue rigging up by running exterior lines. Waiting for Electrician to power Sperry SDL unit. 10-Mar-2011 Continue rigging up by finishing exterior line runs. Electrical power supplied to the unit and unit heat powered on; bad leg on the transformer power prevented unit-equipment start-up because of insufficient voltage supplied to the unit. Alton Schwenter (Sample Catcher) arrived on location. 11-Mar-2011 Continued rigging up. Installed computers, created the SDL computer network, & upgraded to latest version of INSITE (7.2.40). Finished installation of gas equipment & powered up gas gear for calibration; gas equipment fully online by mid-morning. CanRig technician installed RigWatch computer within unit allowing for the WITS transfer of rig surface data to INSITE; all rig surface data with the exception of Sperry’s gas equipment & the pump stroke counters are being acquired through third parties (RigWatch or Schlumberger) for this well. Fully online & completed rig up by late evening—standby & further preparations work for new well. Rig picked up 5” drill pipe, HWDP, and jars. Stood back in derrick. Chris Woolley (Sample Catcher) arrived on location. 12-Mar-2011 Continued working on preparations for new well while sample catchers prepped sample supplies. Calibrated Gas Analyzer and Gas Chromatograph to Sperry standard. Rig tested diverter and alarm system. Rig personnel working on cuttings tank steam loop to be fixed as well as the pumps. 13-Mar-2011 Rig crew worked on flow line. Sperry adjusted their databases for Daylight Savings Day before drilling began as to avoid problems with data through out the well. Picked up BHA and drilled out conductor with fresh water; displaced to 300+ spud mud. Spudded well and trouble shot Schlumberger WITS. Due to incompatibility with Sperry WITS and the new version of Schlumberger software, SDL is acquiring depth from Canrig. From spud to till midnight, loggers were constantly adjusting and clearing the gas trap from Clay buildups. First gas was seen at 1150’ MD. Background gas has been trending upwards since first gas was detected. Gas went from 94 units background to 209 units by midnight with a max gas of 466 units at 1662’ MD. There were no other significant gas peaks. Formation started out as a Sandy Gravel with increasing amounts of Clay with depth. Gravel maxed out at 40% of samples and finally fell out at 869’ MD. Clay chunks ranging from 2”x3” to 1”x2” were observed over the shakers making up to 60% of cuttings at times. Noted a Coal section at approximately 1048’ MD to 1081’ MD and again at 1110’ MD to 1149’ MD. Noted minor amounts of Coal in later samples but saw no evidence of Clay caving into the wellbore. Formation transitioned to Clays and Sands by 1169’ MD. Possum belly has been backed up with cuttings through out drilling and has been adversely affecting gas readings and cuttings sampling. No losses or gains noted while drilling. 14-Mar-2011 Drilled from 1794’ MD to 2130’ MD through predominantly Claystones with minor interbedded Siltstones and Sandstone with an average drilled gas of around 210 units. Encountered additional Sandstone stringers at 2130’ MD with an increase of drilled gas up to a maximum of 1060 units at 2186’ MD. No connections gases were noted. Clay continued to be problematic in the possum belly plugging up the intake port of the gas trap. Mud weight was subsequently increased form 9.2ppg to 9.5ppg providing a safety margin for running casing. Drilled ahead 2358’ MD where TD was called for 9 5/8” casing. Rotated and reciprocated while circulating and conditioning mud system prior to pulling out of the hole to 1890’ MD. Ran in the hole to 2358’ MD and tagged bottom with no evidence of fill on bottom. Tripped out of the hole and laid down BHA. Began rigging up to run 9 5/8” casing. 15-Mar-2011 Continued rigging up to run casing. Ran 9 5/8” casing and set at 2347’ MD with no significant issues. Circulated and conditioned mud around casing with an average background gas of 48 units and a maximum of 146 units. Rigged up to cement casing. Cement job delayed due to cementers’ computer failure; circulated at 83gpm until ready. Began cementing 9 5/8” casing in place. 16-Mar-2011 Finished cementing the well while receiving 212 bbls of cement back to surface. Bumped plug with MOBM. Emptied WMB from pits and loaded to trucks heading for MI mud plants. Rig crew cleaned the pits in preparation for MOBM. Rigged down diverter line and rigged up BOP. 17-Mar-2011 Finished Cleaning pits and received MOBM. Nippled up BOP and Testing at midnight. Sample Catchers preparing supplies for Production Hole. 18-Mar-2011 Concluded the BOP test. Rig crew working on thawing line in the top drive, removed Kelly Hose. Received new Kelly Hose from Deadhorse. Picked up 5” drill pipe and stood back in the derrick while warming up new Kelly Hose in pipe shed prior to installation. Rig crew began installing new Kelly Hose. 19-Mar-2011 Rig crew finished installing new Kelly Hose. Calibrated Gas Analyzer and Gas Chromatograph to Sperry Standard. Picked up 5” drill pipe and racked back in derrick. Picked up BHA #2, ran in the hole and shallow pulse tested – good. Ran in the hole picking up joints of 5” drill pipe. Washed 2 stands and displaced well with MOBM. No mud returned to possum belly – no gas data for bottoms up. Continued to wash to bottom and drilled out the float collar, shoe track and 20’ of new formation from 2358’ MD to 2378’ MD. Gas peaked at 136 units. 20-Mar-2011 Performed FIT to 14.2 ppg EMW. Drilled from 2378' MD to 4080' MD. Abundant large Claystone cuttings over shakers during the connection at 2505' MD. Lost returns (28 bbls) after making the connection at 3556’ MD. Average ROP to this point was 245fph with no sustained drilling breaks. SPP was variable throughout this drilling interval with pressures ranging from 1641psi to 2541psi. SPP was obviously increasing with depth and leveled out once 3 stands were drilled with SPP ranging from 2161psi to 2541psi. Stands were being drilling down in 20 minutes; we may have been loading the hole with cuttings without having sufficient circulating time to clean the hole. No significant variations in rotary torque were observed. Staged pumps while troubleshooting. Circulated bottoms up noting 226 units of gas prior to short trip. Pulled out of the hole to 2215’ MD and monitored the well. Trip displacement was as calculated. Rig maintenance was done at this time. Noted well showing signs of slight breathing. Tripped in the hole to 3460' MD and washed down to 3556' MD. Circulated before drilling head where 105 units of trip gas were seen. Drilled ahead where it was noted the average ROP had been reduced. This was confirmed by the cuttings samples as they transitioned from a firm Claystone to a harder Shale. The average ROP was reduced to 192fph to the midnight depth of 4080' MD without a significant change in WOB. The first 3 stands were drilled with SPP from 1130psi to 1694psi. On the 4th stand SPP noticeably increased to a range of 2138psi to 2326psi. Torque varied from 1.6k ft/lbs to 3.5k ft/lbs. Drilling gas was minimal during this section maxing out at 80 units. The hole appears to be in good condition based on lag times for gas peaks. No washout and the amount of cuttings at the shakers show we are cleaning the hole. No more losses observed. 21-Mar-2011 Continued drilling ahead from 4080' MD to 5663' MD. Drilled the Torok Fm at an average ROP of 191fph with a fairly steady ROP. Encountered a 34' Sandstone section from 4525' MD to 4559' MD in which an increase of average ROP was noted, 283fph. The interval produced a gas show of 2094 units over a background gas of 90 units with minor yellow fluorescence and possible milky white flash cut fluorescence (masked by MOBM). The SPP was variable ranging from 2303psi to 2571psi. Began controlled drilling as the encountered the North Tarn Objective at 4976’ MD, 4919’ TVD; noted only 20% sands in cuttings samples. The controlled drilling was complete at 5175’ MD. SPP cleaned up and was a relatively steady 2390psi throughout as well as the rotary torque, 2.1k ft/lbs to 2.5k ft/lbs. Drilled ahead through predominately Shale with minor Siltstone and thinly interbedded Sandstones to 5553' MD. Encountered another 20' section of thick dirty Sandstone (Moraine Sst) from 5560' MD to 5580' MD producing minor gas show with 895 units over a background gas of 190 units. Gradual drilling break noted over the Sandstone interval. Rotary torque increased to 3.3k ft/lbs to 4.0k ft/lbs. Drilled ahead to 5663' MD with an average ROP of 190ft/hr. Circulated bottoms up while reciprocating drill pipe, no significant gas peaks noted. Short tripped to shoe to clean hole and for rig repair. Rig crew performing rig maintenance at midnight. No connection gases noted over entire drilling interval. Sperry did experience difficulties with the gas line freezing; issue was permanently resolved. Again, the hole appears to be in good condition, no evidence of washout and we are cleaning the hole based on cuttings load. No losses noted. 22-Mar-2011 Continued to service the rig. Ran in the hole from the shoe to 5663’ MD. Trip displacement was good with trip gas of 58 units. Began drilling at 5663' MD. HRZ encountered at approximately 5905' MD, 5831' TVD with the Base at approximately 6055' MD, 5985' TVD. Average ROP through the HRZ was 179ft/hr and was steady and a slight increase at the base. Gas peaks of 1101 units over a 380 units background was seen at the top of HRZ and 929 units over 283 units background was seen at the base. SPP was between 2615psi to 2715psi during this interval. Rotary torque was variable at the base of the HRZ however it cleaned up by 5979’ MD. Began controlled drilling at 6110’ MD, as the K1 was approached. The top of the Kuparuk was penetrated at approximately 6198’ MD, 6122’ TVD although drilling parameters and gas data could put the top as high as 6195’ MD. A trend in the pit volume data was noted at 6195’ MD, the pit volume no longer decreased as it would during normal drilling operations. At 6198’ MD the trend turned upwards as pit volume slowly increased. The SPP showed a slight upwards trend once the pit volume change became positive. At calculated lag depth of 6198’ MD, drilling gas went from a background of 125 units and declining to a max gas of 7323 units and increasing rapidly before the well was shut in. C1 through C5 were represented in the chromatograph data; this was the first instance of C5 being detected. Oil was seen coming over the shakers. A 5bbls gain was recorded by the time the well was shut in. A very subtle change in ROP could be seen at 6195’ MD as well, as the rig was still control drilling at this point. Please see the Geology Section for Kuparuk Sand descriptions. Noted an initial casing pressure of 300psi, drill pipe 220psi. Monitored pressures and weighted up mud system to 10.1ppg. Break circulation through choke approximately 2 hours later. Initially pump at 133gpm but see no returns; drop pump rate to 93bbls and see returns. Gas was ranging from 2700 units to 3400 units with occasional peaks of up to 5000 units. Oil continues to be visible in the possum belly and the shakers. Circulating at 90gpm at midnight. 23-Mar-2011 Continue to circulate through choke and weight up mud system to 10.4ppg for well control. Shut down pumps and monitored the well on choke. Drill pipe pressure 50psi, casing pressure 200psi. Bled 43bbls through choke. Circulated 10.4ppg through choke and monitored well. Continue to pump 10.4ppg drilling fluid and circulate through the choke; noted gas peak of 9355 units upon bottoms up. Began adding LVT to the system to drop YP. Gained 84bbls from well while circulating through choke. Gas varying between 3200 units to 4500 units while attempting to keep the gas cut mud at 10.4ppg. The gas chromatograph continues to see C1 through C5 in the mud system. The system is contaminated with oil so the gas readings will continue to be high unless the system was to be changed out. High levels of C1 and C2 are significant while attempting to clean the mud up. As C1 and C2 break out from the mud system much easier than the heavier gases, continually seeing high levels of C1, C2 indicates that the system is being replenished by a hydrocarbon source downhole. Continue to circulate at 88gpm with mud weight in 10.4ppg and mud weight out 10.3ppg; drill pipe pressure 200psi, casing pressure 190psi at midnight. 24-Mar-2011 Continued to circulate 10.4ppg while controlling well through the choke. Weighted system up to 10.5ppg and continued to circulate with gas ranging from 3200 units to 4700 units. Stopped and monitored the well. Bled through the choke and got back 52bbls over a 10 minute period. Closed annular preventer and rotated one turn. No torque noted, broke over 170, pick up 210, and slipped up through bag at a slow rate from 6202’ MD to 6155’ MD. Monitored well and began pumping. Gas initially climbed to 6481 units and settled at 4000 units. Pump LCM pill and continued to circulate through the choke. Stopped circulating and monitored the well; well was static for approximately 15 minutes until gains were seen. Began pumping and dealt with losses until circulation was established with a flow rate of 73gpm; gas was ranging from 4900 units to 5900 units. Shut in well and it remained shut in at midnight. 25-Mar-2011 Controlled well bore through the choke while taking returns to the secondary choke to storage tanks with choke fully opened. Drill pipe pressure decreased from 440psi to 170psi. Circulated at 42gpm and weighted up mud system to 10.7ppg with a drill pipe pressure of 40psi, casing pressure of 330psi. Mud coming back over shakers are 99% LCM with a mud weight of 9.6ppg. Low pit volume on rig; decision made shut down the pumps and close in the well. Drill pipe pressure 50psi, casing pressure 360psi, lost 657bbls to formation. Slacked off and broke over drill string through bag. Stripped through bag from 6155' MD to 6138’ MD with up weight of 22k and slacked off to down weight. Shut in well, made up TIW valve and 5' pup, swapped from annular bag to upper rams. Noted gas readings of 1400 units to 1800 units on mud returning from storage tanks. The chromatograph data shows the C1, C2 are being stripped after going to the tiger tanks, C3 through C5 concentrations show only minimal losses. 26-Mar-2011 Well continued to be shut in with casing pressure of 1290psi. Rigged up lubricator, BOP's and wire line tools. Open TIW valve and ran in the hole with temperature and noise tool to 5990' MD. Pulled out of the hole from 5990' MD to surface. Monitored well with casing pressure of 1290psi. Prep tools ready for dummy run to remove SLB nuke source. Ran in the hole and removed SLB nuke source; pulled out to surface and laid down sources. Weighted up new drilling mud to 11.7ppg. Made up 5' pup on top of TIW, made up top drive. No mud circulated, no gas data to report. 27-Mar-2011 Continued to monitor well shut in pressure of 1300psi. Broke circulation with 91gpm that eventually came down to 74gpm. Pumped 11.7ppg MOBM to kill well, mud weight out came up as 8.0ppg and rose to 11.4ppg. Noted casing pressure dropping to 0psi. Stopped pumping and monitored well, no pressure holding on drill pipe and casing. Well began to flow with gas rising to 6083 units before well was shut in; rig noted a flow out increase to 4% and then quickly rose to 28%. Lined up to gas buster and pits and pumped 40bbls with no returns. Stopped pumping shut in well due to low mud volume. 28-Mar-2011 Monitored well with drill pipe pressure 0psi, casing pressure 1250psi. Lined up out secondary choke to mud/gas separator then to tiger tanks. Drill pipe pressure rose to 330psi; pumped down drill pipe and pressure decreased to 40psi. Drill pipe pressure slow came back up to 90psi. Pumped at 111gpm to mitigate drill pipe pressure back to 0psi and stopped pump. Shut TIW valve, broke out of top drive, installed pump in sub and hooked up to circulate. Broke circulation with 11.7ppg MOBM at 88gpm while building drill pipe pressure and lowering casing pressure. Continue to circulate at midnight, returns diverted from possum belly resulting in no gas data. 29-Mar-2011 Continued pumping at 90gpm (30spm) while receiving mud to the pits from the trucks. Pumps shut down at 02:03 the well shut in; no returns to shakers noted. Note casing pressure building to 514psi. Pumped 15bbls Halliburton ThermaTex at 5942’ MD with cement lines; monitored well with 30psi SIDPP, 160psi SICP. Began pumping 11.7ppg Mud with 28spm and saw no returns to for approximately 2.8 hours. Noted minimal returns and mud was able to be cycled through the gas trap. Initial max gas was 6678 units and came down to 4050 units immediately after peaking. Noted minimal gains or losses as gas bounced between 4400 units and 4900 units. Cycled pumps off and on, continued circulating at 80gpm. Continued to circulate at 80gpm, MW In: 11.7ppg, MW Out: 11.5ppg, and shakers occasionally being blinded by LCM along with oil coming over on the shakers. The mud level in the possum belly varied at times. Gas trap commonly alternated between being buried by mud to the trap being above mud level. Gas varied from 4000 units to 5000 units during this time while dealing with high losses. Casing pressure eventually dropped to 70psi with a drill pipe pressure of 233psi at 89gpm. Rate of mud loss was approximately 45bbls/hr. 30-Mar-2011 Continued circulating the well with 11.7ppg MOBM with drill pipe pressure at 230psi, casing pressure 70psi. Also continued to work on the pump stroke counter; sensor repaired and operating. Losses of 67bph noted while pumping at 2bpm and when pumps were slowed to 1bpm, the loss rate dropped to 11bph. Pump rates at 1.5bpm showed losses of 51bph decreasing to 30bph. Background gas was relatively steady at 3700 units of gas with a gradual increase to 4000 units by 06:00. Mud weight out was continually 11.7ppg but would occasionally fluctuate to 11.65ppg. Background gas increased to 4850 units by 12:00. No notable gas peaks logged. Pumps off at 13:39; well shut in. Over a 4.5 hour period the casing pressure increased to 1329psi, this falls in line with previous shut in pressures over time. Pre-job Safety meeting held for rigging up and running in the hole with wireline. Monitored the well with drill pipe pressure of 0psi, casing pressure 1280psi. An EZ drill plug was run into the hole on wireline and set at 5771’ MD, casing pressure rose to 1280psi. 31-Mar-2011 Continued to run in the hole with wireline. High pressure tested surface equipment. Perforated HWDP at approx 03:40 with 40 shots at 4 shots per foot between 5742’ MD to 5752’ MD. High pressure tested surface equipment. Began circulating through perforations with 11.7ppg MOBM and taking returns to the Tiger tank. Pumped a 50bbls LCM (Magnafiber) pill at 85gpm; Pump pressure increased to 895psi as pill went through perforations. Ceased circulating and shut in well. Casing pressure began as 240psi which built up to 1380psi over x.x hours. Performed cement job. Noted drill pip pressure of 20psi and casing pressure of 1120psi. Wait on cement. No returns noted at surface, no gas to report. 1-Apr-2011 Monitored well while waiting on cement, drill pipe pressure was 0psi, casing pressure 1140psi. Pumped 10 bbls of MOBM down the drill pipe at 85gpm with the annulus shut in. Pump pressure increased to 1300psi and they were shut in. Drill pipe pressure 1300psi, casing pressure 1140psi. Opened choke to the gas separator and drill pipe pressure dropped to 20psi and casing pressure dropped to 1110psi. Pumped 25bbls of MOBM down the drill pipe with 700psi at 30spm. Monitored the well while waiting for next load of MOBM. No returns to possum belly, no gas readings to report. 2-Apr-2011 Monitored the well with drill pipe pressure 0psi, casing pressure 1090psi. Circulated 10.7 MOBM down drill pipe with returns lined up to go through the mud gas separator to the tiger tank. Initial returns were gas followed by no returns. Casing pressure was reduced from 1090psi to 0psi. After pumping a full bottoms up, the rams were opened - no fluid visible. Pumped 5bbls down the annulus with no fluid visible. Shut in the well with a drill pipe pressure of 0psi, casing pressure 0psi. Opened rams, pulled 100k over without any movement and shut in well. Rigged up cementers and perform cement job. Currently waiting on cement. No returns to the possum belly, no gas readings to report. 3-Apr-2011 Continued to wait on cement and monitor the well with drill pipe pressure at 0psi, casing pressure 1090psi. Circulated 10.7 MOBM down the drill pipe with returns lined up through the mud gas separator to tiger tank. Initial returns were gas followed by no returns. Casing pressure decreased from 1090psi to 0psi. After the rig pumped a full bottoms up, the rams were opened and no fluid was in sight. Pumped 5bbls down annulus and noted no fluid was visible. Shut in the well with drill pipe pressure of 0psi, casing pressure 0psi. Opened rams and pulled 100k with the blocks over without any movement. Shut in well and rigged up Halliburton cementers. Performed cement job and waiting on cement. No returns to the possum belly, no gas readings to report. 4-Apr-2011 Torqued drill string to 30k ft/lbs and worked string. Made up and ran in the hole with Halliburton String Shoot Assembly #2 to 4269' MD. Shot String Shoot with no surface indication. Pulled out of the hole to 200' MD and released torque from drill string. Worked drill pipe up on stages to 400K up weight and 75K down weight. Made up Halliburton Perf Gun and plan forward was to perform 40 shots over 10' intervals with 4 shots per foot. Ran in the hole with Perf Gun and fired the String Shoot from 4980' MD to 4990' MD. Line up to pump 3bbls of LVT and pressured up to 2000psi. Bled off pressure and waited for more Perf Guns. Rigged up to run in the hole with Perf Gun from 4850' MD to 4860' MD; did not circulate. Waited on Perf Guns. Rigged up to run in the hole with Perf Guns to 4800' MD at midnight. No returns to the possum belly, no gas readings to report. 5-Apr-2011 Continued to run in the hole with Perf Gun. Fired 6 shots per foot in a 10' interval from 4730’ MD to 4740’ MD. Pulled out of the hole. Attempted to circulate at 80gpm – Circulation was not established. Ran in the hole with Perf Gun and fired 6 shots per foot from 4630' MD to 4640' MD. Pulled out of the hole and attempted to circulate at 80gpm – Circulation was not established. Ran in the hole with Perf Gun and fired 6 shots per foot from 4530' MD to 4540' MD. Pulled out of the hole and attempted to circulate at 80gpm – Circulation was not established. Ran in the hole with Perf Gun and fired 6 shots from 4410' MD to 4420' MD. Pulled out of the hole and attempted to circulate at 80gpm – no success. Rigged down Halliburton Wireline Equipment. Rigged up Schlumberger Wireline Equipment and ran in the hole with Free Point tool, attempting to find free point. 6-Apr-2011 Ran in the hole with Free Point Tool, became stuck at 3700' MD. 70-80% free from 3600' MD to Shoe. Rigged down wireline and rigged up Sever Tool. Ran in the hole to 3474' MD and cut at tool joint. Pulled out of the hole and began to work drill pipe with 75K to 400K over pull, torqued string to 20K and continued to work. Broke Circulation and staged pump rate up to 4bpm. Gas maxed out at 10000 units. Shut well in with initial casing pressure of 50psi building up to 190psi. Displaced OBM with 11.0ppg LSND through the choke and gas buster. Opened up well and pulled 225K to 400K, turned 3 left hand wraps up to 10K with no success. Flow checked well – static. Made up second Sever Tool and ran in the hole to 3089' MD attempted to pull free 450 K over pull, no go. Wait on tool. 7-Apr-2011 Ran in the hole with second Sever Tool to 2829' MD and fired tool. Pulled out of the hole and laid down tool. Worked on top drive grabber box. Picked up joint and attempted to work the drill string up to 450K over pull, torqued up to 26K, and pumped 600gpm – no success. Circulated and worked on new Sever Tool. The gas analyzer pegged out with 10000 units of gas. Ran in the hole with third Sever Tool to 2547' MD and pulled free. Circulated and rigged up cementers. Pumped 35bbls of cement and CIP @ 19:20. Pulled out of hole 5 stands and circulated out of balance. Continued to pull out of hole at midnight. 8-Apr-2011 Rigged down Wireline tools. Cut and Slipped drilling line. Serviced rig, pumped dry job, and tripped out of hole. Rigged up and began testing BOP’s. 9-Apr-2011 Continued testing BOP’s. Ran in the hole with an 8.5" bit and 5" drill pipe to 1823' MD; washed to 2097' MD and tagged cement. Circulated and conditioned WBM to 9.6ppg. Pumped dry Job and pulled out of the hole and laid down 5” drill pipe that was used for previous cement jobs. Picking up 5" drill pipe and standing back in derrick as of midnight. Begin sidetrack: North Tarn 1A 10-Apr-2011 Continued picking up 5" drill pipe. Made up bit with and ran in the hole to 2097' MD. Drilled out cement from 2097' MD to 2317' MD with no issues. Circulated bottoms up to clean hole from cement and noted max gas of 40 units. Pumped dry job and pulled out of the hole. Rig crew performed maintenance of rig. Rigging up to test BOP’s at midnight. 11-Apr-2011 Continued to rig up for BOP test and tested same. Sperry gas analyzer and chromatograph were calibrated to the Sperry standard. Sample catchers arrive this late morning. Picked up BHA #3. Ran in the hole and waited on permission to drill from town. Shallow pulse tested SLB MWD. Began drilling cement at 2317’ MD and officially began the sidetrack in new formation at 2362’ MD. Drilling rates out of cement was steady at 35fph to 40fph and increased to 175fph to 200fph at 2397’ MD. Gas was low, averaging 35 units. SPP was fairly steady at approximately 1340psi when rotating. At 2470’ MD, it was noted that the Sperry THC (Total Hydrocarbon Conditioner) was malfunctioning. The day SDL Engineer drove to Deadhorse to retrieve a spare and was installed at 3362’ MD. Minor sample gas was able to flow to the Chromatograph and spotty data was able to be collected. Drilled to 3103’ MD at midnight. 12-Apr-2011 Continued drilling ahead from 3103' MD. Drilled with steady ROP to 3327’ MD averaging 230fph at which ROP became less consistent ranging from 239fph to 250fph. It was noted that SPP and Torque increased as well. The formation drilled had a more firm Siltstone intervals. ROP dropped off at 3663’ MD to 50fph and increased to 230fph before dropping off again to approximately 50fph. This coincides with the top of the C50 Formation. Gas has averaged 55 units with no peaks. At 3698’ MD, the rig began losing fluid at 21bph. This occurred after drilling a stand, the pumps were shut down and observed the well. Its determined that the well is breathing. Drilled another stand to 3794' MD noting heavy pulls losses of 27bph. Background gas increased slightly to 65 units. Backreamed from 3794' MD to 3324' MD. Lost fluid while backreaming at 3,700' MD. Pumped 43bbl LCM pill at 3397' MD at a rate of 185gpm. Backreamed out of the hole to the shoe with no issues and paused to monitor the well – good. Continued to backream to surface to clean the BHA. Note the well began to flow at 1774’ MD, mud is falling from the drill pipe and joints into the well bore possibly making it appear that the well was flowing as no gas was associated. A good amount of Shales and Clays were seen over shakers during short trip. Inspected BHA and ran in the hole began running in the hole. Ran in the hole to 2122’ MD at circulated bottoms up, noted a trip gas of 1880 units. Gas was quickly circulated out to a background of 25 units. Continued running the hole to bottom at midnight. 13-Apr-2011 Continued running in the hole to 3597’ MD and began circulating bottoms up, noted max trip gas of 1962 units. Pumps were staggered while circulating and the trip gas peak shows this by having 3 distinct peaks. Once the gas was cleaned up, background gas was 43 units. Began drilling ahead with a relatively steady ROP of 154fph. SPP was a stable 1200psi while drilling the first stand and increased to 1850psi at 4457’ MD. Background gas averaged 45 units with no significant peaks. While making the backreaming at the 4082’ MD connection, began losing circulation at 18bph, made connection and began drilling ahead while losses subsided to 10bph. A sweep was pumped and losses ceased. Connection gas was noted since the short trip, it began at 30 units about background to averaging 120 units above background. ROP began to fall off significantly at 4800’ MD to an average of 88fph with a highly variable rotary torque, an increase of ROP was noted at 4859’ MD but was torque was still high at 2.7k ft/lbs to 4.7k ft/lbs and SPP of 1959psi. Connection gas at 4848’ MD was 200 units over background. Decision was made to perform wiper trip; circulated bottoms up and background gas was 70 units. Backreamed from 4944’ MD to 3779’ MD with no significant issues. Sperry SDL checked and recalibrated Gas Analyzer and Gas Chromatograph – good. Ran in the hole to bottom and circulated bottoms up; wiper trip gas was 315 units although gas peak was interrupted by making connection. Began drilling ahead at 4944’ MD with a low ROP averaging 32fph. A significant drilling break was noted at 5034’ MD with an associated gas peak of 350 units. Drilled ahead with an average ROP of 169fph to a midnight depth of 5107’ MD with SPP of 1561psi, Background gas of 91 units, rotary torque of 3.8k ft/lbs to 4.2k ft/lbs. 14-Apr-2011 Continued drilling ahead from 5107’ MD to 6070’ MD, TD of Intermediate Section. ROP remained steady from end of previous 24 hours to TD, averaging 177fph. Sperry SDL experienced difficulty maintaining a sufficient mud level in possum belly resulting in poor quality gas data. Worked with Pit Watcher to increased mud levels with success. At 5685’ MD, Sperry SDL noted Shale cavings coming over shakers estimating 20%. Company man was notified, Sperry SDL was asked to inform him of any changes. Cavings over shakers ranged from 5% to 20% up to 5969’ MD where cavings ceased. Background gas increased over time in lead up to the HRZ at 500 units. The Top of the HRZ had a gas peak of 999 units and a peak of 2271 units at the base. Drilling parameters remained steady whilst drilling the HRZ. Gas peaks were noted in the Kalubik maxing out at 2269 units. Rotary torque ranged from 4.0k ft/lbs to 5.7k ft/lbs, SPP was averaging 1640psi with minor fluctuations and no losses since midnight. TD Intermediate Section at 6070’ MD, 6046’ TVD. Circulated bottoms up with background gas averaging 130 units, pumped a dry job. Proceeded to backream out of the hole to the shoe with no issues and pumped a dry job. Began to pull out of the hole on elevators with no issues and laid down singles as of midnight. 15-Apr-2011 Continued to pull of the hole laying down singles. Serviced rig, laid down HWDP, jars, and BHA. Changed to 7” rams, flushed stack, and tested BOPE. Rigged up and began to run 7” casing. Ran in the hole with 7'' casing and circulated briefly with every joint. Circulated at the shoe noting a max gas of 42 units. Continued running in the hole while circulating at every 10 joints, gas averaged 170 units. 16-Apr-2011 Continued to run in the hole with 7" casing to a depth of 6056' MD while circulating every tenth joint down. Landed casing and circulated with a max gas of 854 units. Rigged up cement head, circulated to thin the mud to a yield point of 14. Pumped cement as per program with no issues. Sperry SDL released from rig by the Company Man. Geology North Tarn 1 • Permafrost Base – […1390’ MD/1382’ TVD to 2568’ MD/2542’ TVD…] o General Descriptions: Sandy to silty Claystone becoming firmer with depth. Section was drilled with WBM and surface casing was set at 2358’ MD. Drilled out of cement with MOBM. Sand : clear to translucent to opaque, light grey to grey, light blue to light green, brown to dark brown, friable, coarse upper to medium upper grain size, sub spherical to spherical, sub elongated, predominantly quartz, angular to sub angular, sub round, poor to occasionally moderately sorted, loose, argillaceous cement, common glauconite, common massive pyrite. Clay : very light grey to light grey, light tan to light brown, calcareous, silty, predominantly soft to firm, occasionally brittle, very gummy, amorphous, hydrated, micro carbonaceous material, fine upper to coarse lower sand grains throughout sample, very weak dull yellow fluorescence, weak bright yellow cut. o Gas Description: Was able to see sustained gas data beginning at 1149’ MD. Drilled formation gas remained below 146 units for the interval being comprised solely of methane. No peaks observed within the drilled interval. No indications of shallow gas danger. o Drilling Notes: Occasional sliding took place while drilling out of the 16” casing. ROPs were averaging 124fph, a drilling increase was seen at 1222’ MD and the average ROP increased to 192fph. Drilling parameters include 2-3.5kfps with rotary 46-77rpm, flow 512gpm, and SPP 1000-1295psi. • K-10 – […2568’ MD/2542’ TVD to 2732’ MD/2703’TVD…] o General Descriptions: Interval containing Siltstones and Claystones interbedded. Siltstone: light grey medium grey, occasionally soft to firm, hard, sightly sandy, rarely very fine to fine sand grains interbedded throughout, argillaceous, micaceous, quartz, volcanics, tuffaceous in part, common carbaceous laminations. Claystone: light to medium grey, firm, blocky, silty in part with occasional think Siltstone laminations, micro carbonaceous material throughout, trace thin tuffaceous laminations, occasional slightly sandy, non calcareous,. o Gas Description: No indications of shallow gas hazards. Drilling gas was consistent averaging 85 units. No connection gases were noted. Primarily Methane was detected with trace amounts of Ethane. o Drilling Notes: Rotated through formation with initial ROP’s averaging 200fph increasing to a sustained 250fph. ROP temporarily dropped off at 2625’ MD and 2633’ MD. A minor spike in torque was noted from 1.8k ft/lbs to 2.7k ft/lbs. SPP fluctuated from 1840psi to 1729psi and increased to 2046psi. • K-10 Base – […2732’ MD/3703’TVD to 4200’ MD/4151’ TVD…] o General Descriptions: A silty Claystone becoming harder with depth maturing into Shale. Siltstone: light grey to medium grey, hard to occasionally soft, slightly sandy, rarely very fine to fine sand grains interbedded, argillaceous, firm, micaceous, quartz, volcanics, tuffaceous, common carbonaceous laminations. Claystone: medium grey to dark grey, blocky, hard to occasionally brittle, rarely fine grained sand, non calcareous, slightly micaceous, PDC bit cuttings, common carbonaceous material, wispy carbonaceous laminations, trace very thin tuffaceous laminations, trace very finely disseminated micro pyrite, grading to Shale. Shale: medium to dark grey, dark grey to very dark grey, blocky, very firm to moderately hard, brittle, slightly to moderately silty, non calcareous, occasional carbonaceous stringers, occasional thin tuffaceous laminations, finely disseminated micro pyrite, trace calcareous reaction. o Gas Description: Background drilling gas averaged 53 units with no connection gases. No gas recorded at 3556’ MD due to no returns to the possum belly. No peaks noted. o Drilling Notes: Abundant large Claystone cuttings over shakers during the connection at 2505' MD. SPP was obviously increasing with depth and leveled out once 3 stands were drilled with SPP ranging from 2161psi to 2541psi. Stands were being drilling down in 20 minutes; we may have been loading the hole with cuttings without having sufficient circulating time to clean the hole. No significant variations in rotary torque were observed. Lost 34bbls at 3556’ MD, stopped drilling and short tripped. Noted good cuttings coming over the shakers. Circulated bottoms up noting 226 units of gas prior to short trip. Pulled out of the hole to 2215’ MD and monitored the well. Trip displacement was as calculated. Noted well showing signs of slight breathing. Tripped in the hole to 3460' MD and washed down to 3556' MD. Circulated before drilling head where 105 units of trip gas were seen. Drilled ahead where it was noted the average ROP had been reduced. This was confirmed by the cuttings samples as they transitioned from a firm Claystone to a harder Shale. The average ROP was reduced to 192fph to the midnight depth of 4080' MD without a significant change in WOB. The first 3 stands were drilled with SPP from 1130psi to 1694psi. On the 4th stand SPP noticeably increased to a range of 2138psi to 2326psi. Torque varied from 1.6k ft/lbs to 3.5k ft/lbs. Drilling gas was minimal during this section maxing out at 80 units. The hole appears to be in good condition based on lag times for gas peaks. No washout and the amount of cuttings at the shakers show we are cleaning the hole. . • Torok – […4200’ MD/4151’TVD to 4976’ MD/4915’ TVD…] o General Descriptions: Massive shale package. Sandstone: clear, white, buff, brown in part, very fine to fine lower, sub angular to sub round, poorly to moderately sorted, friable, silty, clay matrix, rarely glauconitic. Siltstone: light grey to grey, green, argillaceous, very firm to slightly hard, brittle in part, slightly sandy, medium lower to fine lower quartz grains, argillaceous matrix, tuffaceous in part, clay cement, micaceous, carbonaceous material scattered throughout. Shale: medium to dark grey, blocky, v firm to moderately hard, slightly silty in part, non calcareous, moderately carbonaceous, very finely disseminated micro pyrite in trace amounts, micaceous. o Gas Description: Noted a peak of 2094 units over a background gas of 90 units with minor yellow fluorescence and possible milky white flash cut fluorescence (masked by MOBM). Sandstone interval was encountered at 4521’ MD with 2094 units of gas. Methane, Ethane, Propane were common and Butane first appeared with this gas peak and remained to TD. Background gas after the peak averaged 135 units. o Drilling Notes: Drilled the Torok Fm at an average ROP of 191fph with a fairly steady ROP. Encountered a 34' Sandstone section from 4525' MD to 4559' MD in which an increase of average ROP was noted, 283fph. The SPP was variable ranging from 2303psi to 2571psi. • N Tarn Objective – […4976’ MD/4915’ TVD to 5010’ MD/4948’ TVD…] o General Descriptions: Thin Sandstone interval. Sandstone: Clear to white, buff in part, very fine to fine lower grained, sub angular to sub round, poorly to moderately sorted, friable silty clay matrix. Siltstone: light grey to light greenish grey, very firm to slightly hard, brittle in part, slightly sandy, argillaceous matrix, tuffaceous, carbonaceous material present. Shale: Medium to dark grey, trace brown in part, blocky, very firm to medium hard, brittle, increasingly silty, increasing tuffaceous material interbedded throughout, non calcareous. o Gas Description: Primary and secondary gas line froze, unable to blow back to clear ice. Worked on repairing gas line and rigged up an emergency gas line that could run for 15 minutes before freezing. Discussed with Geologist and decided to wait for North Tarn objective on the LWD logs before activating emergency line. o Drilling Notes: Began controlled drilling as the encountered the North Tarn Objective at 4976’ MD, 4919’ TVD; noted only 20% sands in cuttings samples. The controlled drilling was complete at 5175’ MD. SPP cleaned up and was a relatively steady 2390psi throughout as well as the rotary torque, 2.1k ft/lbs to 2.5k ft/lbs. • C-35 – […5010’ MD/4948’ TVD to 5550’ MD/5480’ TVD…] o General Descriptions: Predominately shale with minor Siltstone and thinly interbedded Sandstones Sandstone: Clear, white, translucent, buff in part, green, very fine to fine lower grained, sub angular to sub round, moderately to well sorted, friable, silty, clay matrix, common pyrite present, calcareous. Siltstone: Light grey to medium grey, greyish green, reddish brown in part, very firm to slightly hard, brittle, sandy, argillaceous matrix, carbonaceous material laminated throughout, pyritic, micaceous. Shale: Medium to dark grey, blockly, very firm to medium hard, brittle, silty, increasing amount of tuff interbedded throughout, non to slightly calcareous. o Gas Description: Primary and secondary gas line repaired. Formation background gas began at 64 units and eventually picked up to 193 units. A minor sandy stringer noted at 5465’ MD producing a peak gas of 627 units. Background gas was 180 units at the base of the formation. o Drilling Notes: ROP’s were controlled while drilling the upper 180’ of the formation at 44fph. At 5175’ MD ROP increased to an average of 220fph and remained steady throughout the section. • Moraine Sandstone – […5550’ MD/5480’ TVD to 5905’ MD/5831’ TVD…] o General Descriptions: Silty Sandstone in upper formation grading to a silty Shale with depth. Sandstone: Clear, translucent, very light grey, very fine grained, quartz, sub round to sub angular, moderately sorted, friable, silty clay matrix, non to slightly calcareous. Siltstone: Light grey to rarely medium grey, soft to moderately firm, friable, silty to very sandy, argillaceous matrix, scattered carbonaceous material, very slightly calcareous. Shale: Light grey to medium grey, dark greyish brown, argillaceous matrix, scattered carbonaceous material, fissile, earthy, hard, brittle, silty, non to slightly calcareous. o Gas Description: Section capped with a gas bearing Sandstone maxing out at 895 units over 182 units background at 5560’ MD. Background gas dropped to 366 units. Performed short trip with gas of 58 units over 30 units background. Drilled ahead with background gas of 246 units trending upwards as the HRZ is approached. o Drilling Notes: Encountered another 20' section of thick dirty Sandstone (Moraine Sst) from 5560' MD to 5580' MD producing minor gas show with 895 units over a background gas of 190 units. Gradual drilling break noted over the Sandstone interval. Rotary torque increased to 3.3k ft/lbs to 4.0k ft/lbs. Drilled ahead to 5663' MD with an average ROP of 190ft/hr. Circulated bottoms up while reciprocating drill pipe, no significant gas peaks noted. Short tripped to shoe to clean hole. Ran in the hole from the shoe to 5663’ MD. Trip displacement was good with trip gas of 58 units • HRZ – […5905’ MD/5831’ TVD to 6055’ MD/5985’ TVD…] o General Descriptions: Silty Shale interval. Siltsone: Light grey to grey, medium grey, dark greyish brown in part, firm to hard, friable, argillaceous matrix, scattered carbonaceous laminations, slightly calcareous. Shale: Light grey to medium grey, dark grey, greyish brown, argillaceous matrix, scattered carbonaceous material, fissile, earthy, hard, brittle, friable in part, silty, non to slightly calcareous. o Gas Description: The HRZ had significant gas peaks at the top and bottom of the formation. Max gas at the top was 1101 units over 385 units background. The peak at the base of the HRZ had to two max points. Max gas was 929 units and 940 units over approximately 300 units background. Methane, Ethane, Propane, and Butane are still present. o Drilling Notes: HRZ encountered at approximately 5905' MD, 5831' TVD with the Base at approximately 6055' MD, 5985' TVD. Average ROP through the HRZ was 179ft/hr and was steady and a slight increase at the base. SPP was between 2615psi to 2715psi during this interval. Rotary torque was variable at the base of the HRZ however it cleaned up by 5979’ MD. • Kalubik Formation – […6055’ MD/5985’ TVD to 6111’ MD/6034’ TVD…] o General Descriptions: Silty Shale interval. Shale: Grey to dark grey, dark brown in part, light grey, earthy, moderately hard to very hard, brittle, friable, silty, micaceous, trace pyrite present, non calcareous. o Gas Description: Background gases ranged from 200 units to 300 units with a minor gas peak of 485 units. No connection gases noted. o Drilling Notes: Controlled drilling rates of 125fph were used throughout the section. A slowdown in drilling was noted at 6059’ MD with a slight spike in rotary torque from 2.6k ft/lbs to 4.2k ft/lbs and SPP spike from 2563psi to 2631psi. Both parameters returned to normal quickly. • K-1 – […6111’ MD/6034’ MD to 6198’ MD/6127’ TVD…] o General Descriptions: Thin Shale section. Shale: Grey to dark grey, dark brown in part, blocky, earthy, moderately hard to very hard, brittle, friable, silty, micaceous, non calcareous . o Gas Description: The gas data showed little variance. No peaks were noted and background gas was 200 units at the top of the section and slowly trended downwards with depth to 125 units. o Drilling Notes: Controlled drilled at approximately 55fph in lead up to the Kuparuk C Sandstones. • Top Kuparuk C Sandstone – […6198’ MD/6127’ TVD to 5010’ MD/4948’ TVD…] o General Descriptions: Silty Sandstone interval. Sandstone: very light brown, light grey to medium grey, clear, translucent, fine upper to fine lower grained becoming coarser with depth, sub round to sub angular, quartz, moderately to poorly sorted, dominantly spherical, siderite cement in shallow depths, friable silty clay matrix in part, very common glauconite, moderately calcareous, visible brown oil stain, milky white fluorescence cut . o Gas Description: At calculated lag depth of 6198’ MD, drilling gas went from a background of 125 units and declining to a max gas of 7323 units and increasing rapidly before the well was shut in. Methane through Butane in addition to Pentane being represented in the chromatograph data; this was the first instance of Pentane being detected. Oil was seen coming over the shakers. o Drilling Notes: The top of the Kuparuk was penetrated at approximately 6198’ MD, 6122’ TVD although drilling parameters and gas data could put the top as high as 6195’ MD. A trend in the pit volume data was noted at 6195’ MD, the pit volume no longer decreased as it would during normal drilling operations. At 6198’ MD the trend turned upwards as pit volume slowly increased. The SPP showed a slight upwards trend once the pit volume change became positive. A 5bbls gain was recorded by the time the well was shut in. A very subtle change in ROP could be seen at 6195’ MD as well, as the rig was still control drilling at this point. Controlled ROP was increased at 6210’ MD before well was shut in. Customer: Report #: Well: Date: Area: 04:00 Depth Location: Progress 24 hrs: Rig: Rig Activity: Job No.: Report For: ROP & Gas: . Mud Data:Density (ppg) Viscosity Depth ft (sec/qt) BHA Run #Bit Type TFA Hours Depth in / out Footage WOB RPM Condition Lithology (%): (current) 8.80 8.80 Reed Milltooth 120' Gas (units) H2S Data Sample Line 176 - Hole Condition On Bot Hrs -- in out All Circ-- Max: Prepping to pick up BHA J. Nicholson/J. West -- Flow In (gpm) Current Pump & Flow Data: - Max @ ft Max - - - - Total Charges: Flow In (spm) SPP (psi) Avg % - 3.5 mg/l -A v gMin Max Gallons/stroke pH Chlorides GvlCoal - - Min - Max:Ambient Air Pit Room Daily Charges Avg --- 1 03/12/2011-04:00 120' North Slope 0' Brooks Range North Tarn #1 Tarn Current R.O.P. (ft/hr) Gas (units)-- - Depth Avg Diam (ppb Eq)cP - Nabors 9es AK-AM-8035432 PVMBT PWD Drilling Lst - 31 Size 37 ClystCht 32.0 12.25 Chromatograph (ppm) Depth - Sh Avg: 1 -0.942 Sd Silt Siltst Tuff Gas Breakdown Avg: Sst API Filt 9.20 - 8.2 ml/30min - Ann Corr Cor Solids lb/100ft2 400 24 hr Max YP to to to to to to to to to Gas Type abreviations: BG - Background Gas; GP - Gas Peak; CG - Connection Gas; WTG - Wiper Trip Gas; POG - Pumps Off Gas; PG - Produced Gas; RG - Ream Gas; T-- - Trip…; F-- - Formation…; E-- - Early… 24 hr Recap: , Logging Engineer:* 10000 units = 100% Gas In Air Chromatograph. Rig tested diverter and alarms. Picked up 5" drill pipe, HWDP, and jars - stood back. Standing by at the time of report. Finished rigging up Sperry mudlogging unit and prepped sample supplies. Calibrated Gas Analyzer and Gas md Danny Kane/Ryan Massey Customer: Report #: Well: Date: Area: 04:00 Depth Location: Progress 24 hrs: Rig: Rig Activity: Job No.: Report For: ROP & Gas: . Mud Data:Density (ppg) Viscosity Depth ft (sec/qt) BHA Run #Bit Type TFA Hours Depth in / out Footage WOB RPM Condition Lithology (%): (current) - Ann Corr Cor Solids lb/100ft2 400 24 hr Max YP API Filt 9.20 - 8.2 ml/30min Sst Tuff Gas Breakdown Avg: Sd Silt Siltst 1 -0.942 Depth - Sh Avg: Chromatograph (ppm) Lst - 56 Size 29 ClystCht 32.0 12.25 (ppb Eq)cP - Nabors 9es $3,425.00 AK-AM-8035432 PVMBT PWD Drilling Current R.O.P. (ft/hr) Gas (units)-- - Depth Avg Diam 2 03/13/2011-04:00 120' North Slope 0' Brooks Range North Tarn #1 Tarn Daily Charges Avg --- Max:Ambient Air Pit Room - Min - Gallons/stroke pH Chlorides GvlCoal -A v g % - 3.5 mg/l -A v gMin Max Max - - $20,713.00 - - Total Charges: Flow In (spm) SPP (psi) Testing pumps J. Nicholson/J. West -- Flow In (gpm) Current Pump & Flow Data: - Max @ ft All Circ-- Max: Hole Condition On Bot Hrs -- in out 8.80 8.80 Reed Milltooth 120' Gas (units) H2S Data Sample Line 215 - to to to to to to to to to Gas Type abreviations: BG - Background Gas; GP - Gas Peak; CG - Connection Gas; WTG - Wiper Trip Gas; POG - Pumps Off Gas; PG - Produced Gas; RG - Ream Gas; T-- - Trip…; F-- - Formation…; E-- - Early… 24 hr Recap: , Logging Engineer:* 10000 units = 100% Gas In AirDanny Kane/Ryan Massey Rig worked on cuttings box, pumps, and flowline. Held pre-spud meeting with rig crew, Brooks Range reps, and service md Adjust SDL data for Daylight Savings Time personnel. Running pumps at the time of report while preparing to pick up BHA. Customer:Report #: Well:Date: Area:04:00 Depth Location:Progress 24 hrs: Rig:Rig Activity: Job No.:Report For: ROP & Gas: . Mud Data:Density (ppg)Viscosity Depth ft (sec/qt) BHA Run #Bit Type TFA Hours Depth in / out Footage WOB RPM Condition Lithology (%): (current) to to to to to to to to to Gas Type abreviations: BG - Background Gas; GP - Gas Peak; CG - Connection Gas; WTG - Wiper Trip Gas; POG - Pumps Off Gas; PG - Produced Gas; RG - Ream Gas; T-- - Trip…; F-- - Formation…; E-- - Early… 24 hr Recap: , Logging Engineer:*10000 units = 100% Gas In AirDanny Kane/Ryan Massey - Ann Corr Cor Solids lb/100ft2 400 24 hr Max YP API Filt 9.50 - 6.5 ml/30min Sst Tuff Gas Breakdown Avg: Sd Silt Siltst 1 -0.942 Depth - 95 Sh Avg: Chromatograph (ppm) ClystCht Lst - 51 Nabors 9ES $4,707.00 PVMBT PWD Drilling 52 1625' Depth (ppb Eq)cP - Size 42 0.0 3 03/14/2011-04:00 1794' North Slope 1674' Brooks Range North Tarn #1 Tarn Current Daily Charges Avg 158.0 465.0 R.O.P. (ft/hr) Gas (units)181 Max:Ambient Air Pit Room -Min -Avg - pH Chlorides GvlCoal % - 3.6 mg/l -AvgMin Max Max 1538 2.9620 $25,420.00 643 217 Total Charges: Flow In (spm) SPP (psi) Gallons/stroke Drilling Ahead J. Nicholson/J. West 466 1662' Flow In (gpm) Current Pump & Flow Data: - Max @ ft Tom Mansfield is traveling to location to change out with Danny Kane. md Massive clay chunks no longer coming over shakers at time of report. Noted a coal section at approximately 1048' MD to 1081' MD and again at 1110' MD to 1149' MD. Coal was dominantly sub mature, very firm to soft, friable, sub blocky fracture. Noted minor amounts in later samples with no evidence of coal moving in to wellbore. Formation transitioned to clays and sands by 1169' MD and continue to be dominated by sticky, gummy, amorphous, hydrophyllic clays. Possum belly has been backed up with cuttings was seen at 1150' MD. Background gas has been trending upwards since the first gas was detected. Gas went from 94 units background to 209 units at the time of report with a max gas was 466 units at 1662' MD. There were no other significant gas peaks. Formation started out as a sandy gravel with increasing amounts of clay with depth. Gravel maxed out at 40% of samples and finally All Circ Avg Diam -- through out drilling and has been adversely affecting gas and cuttings sampling. No losses or gains noted. Spudded well and troubleshot Schlumberger WITS. Due to new version of Schlumberger software, SDL is acquiring depth from from the Canrig. From spud to the time of report, Loggers constantly adjusting and clearing gas trap from clay build up. First gas fell out at 869' MD. Clay chunks ranging from 2"x3" to 1"x2" were observed over the shakers making up 60% of cuttings at times. Rigged continued repairs. Picked up BHA and drilled out conductor with fresh water; displaced to 300+ spud mud. Hole Condition On Bot Hrs -- in out 8.90 8.90 Max: 5 Reed Milltooth 996' Gas (units) H2S Data Sample Line 318 - 30.0 12.25 Customer:Report #: Well:Date: Area:04:00 Depth Location:Progress 24 hrs: Rig:Rig Activity: Job No.:Report For: ROP & Gas: . Mud Data:Density (ppg)Viscosity Depth ft (sec/qt) BHA Run #Bit Type TFA Hours Depth in / out Footage WOB RPM Condition Lithology (%): (current) to to to to to to to to to Gas Type abreviations: BG - Background Gas; GP - Gas Peak; CG - Connection Gas; WTG - Wiper Trip Gas; POG - Pumps Off Gas; PG - Produced Gas; RG - Ream Gas; T-- - Trip…; F-- - Formation…; E-- - Early… 24 hr Recap: , Logging Engineer:*10000 units = 100% Gas In Air 9.50 9.50 1060 Reed Milltooth 2358' Gas (units) H2S Data Sample Line 253 16.70 Hole Condition On Bot Hrs -- in out with drilled gas averaging around 210 units. Began encountering increased Sandstone stringers at 2130' with accompanied increase in drilled gas up to a maximum of 1060 units from 2186' MD. No connection gases were noted. Clay again continued to cause bottom. Tripped out of hole and laid down BHA. Rigged up to run 9 5/8" casing. All Circ-- Max: Drilled from 1794' MD to 2130' MD through predominately Claystones with minor interbedded Siltstones and Sandstone Tom Mansfield changed out with Danny Kane. md problems by intermittently plugging of the gas trap inlet. Mud weight was subsequently increased from 9.2 lb/gal to 9.5 lb/gal providing safety margin for running casing. Drilled ahead to 2358' MD and TD'd for 9 5/8" casing point. Rotated and reciprocated while circulating and conditioning mud system prior to POOH to 1890'. RIH to 2358' and tagged bottom. No evidence of fill on Run 9 5/8" CSG J. Nicholson/J. West 1060 2187' Flow In (gpm) Current Pump & Flow Data: - Max @ ft Max na 2.9620 $28,845.00 na na Total Charges: Flow In (spm) SPP (psi) Avg % - 7.2 mg/l -AvgMin Max Gallons/stroke pH Chlorides GvlCoal - - Min - Max:Ambient Air Pit Room 616 13 2114' 2220' Daily Charges Avg 185.3 351.5na 4 03/15/2011-04:00 2358' North Slope 564' Brooks Range North Tarn #1 Tarn Current R.O.P. (ft/hr) Gas (units)na 249 1808' Depth Avg Diam (ppb Eq)cP 2358.00 Nabors 9ES $3,425.00 AK-AM-8035432 PVMBT PWD Drilling Lst 120.00 50 Size 54 ClystCht 32.0 12.25 20 32910 Chromatograph (ppm) 2114' 2220'2358'149 485 325 51762 Depth max 15 2238' 65 C2C1 Sh Avg: 1 23'0.942 Sd Silt Siltst BG TypeC4C5 BG GP Tuff Gas Breakdown 1794' Avg: 210 avg Sst 31 9 C3 775 129222 330 API Filt 9.10 48' 6.5 ml/30min Tom Mansfield/Ryan Massey - Ann Corr Cor Solids lb/100ft2 400 24 hr Max YP Customer:Report #: Well:Date: Area:04:00 Depth Location:Progress 24 hrs: Rig:Rig Activity: Job No.:Report For: ROP & Gas: . Mud Data:Density (ppg)Viscosity Depth ft (sec/qt) BHA Run #Bit Type TFA Hours Depth in / out Footage WOB RPM Condition Lithology (%): (current) to to to to to to to to to Gas Type abreviations: BG - Background Gas; GP - Gas Peak; CG - Connection Gas; WTG - Wiper Trip Gas; POG - Pumps Off Gas; PG - Produced Gas; RG - Ream Gas; T-- - Trip…; F-- - Formation…; E-- - Early… 24 hr Recap: , Logging Engineer:*10000 units = 100% Gas In AirTom Mansfield/Ryan Massey 1-1-WT-A-E-1-ER-TD Ann Corr Cor Solids lb/100ft2 400 24 hr Max YP API Filt 9.10 48' 6.5 ml/30min avg Sst C3 146 Tuff Gas Breakdown TD Avg: 48 Sd Silt Siltst TypeC4C5 BG 1 23'0.942 Depth max 15 2238' 65 C2C1 Sh Avg: 14485 Chromatograph (ppm) ClystCht Lst 120.00 50 Nabors 9ES $3,425.00 AK-AM-8035432 PVMBT PWD Drilling 48 na Depth (ppb Eq)cP 2358.00 Size 54 na 5 03/16/2011-04:00 2358' North Slope 0' Brooks Range North Tarn #1 Tarn Current Daily Charges Avg na na R.O.P. (ft/hr) Gas (units)na Max:Ambient Air Pit Room 12 -Min -Avg - pH Chlorides GvlCoal % - 7.2 mg/l -AvgMin Max Max na 2.9620 $32,270.00 na na Total Charges: Flow In (spm) SPP (psi) Gallons/stroke CMT 9 5/8" CSG J. Nicholson/J. West 146 12:00 Flow In (gpm) Current Pump & Flow Data: - Max @ ft Tom Mansfield changed out with Danny Kane. md All Circ Avg Diam -- with an average background gas of 48 units and a maximum of 146 units. Rigged up for cementing casing. Delayed by cementing unit problems. Cemented around 9 5/8" casing. Continued rigging up to run casing. Ran 9 5/8" casing and set at 2347. Circulated and conditioned mud around casing Hole Condition On Bot Hrs -- in out 9.50 9.50 Max: CMT 20 Reed Milltooth 2358' Gas (units) H2S Data Sample Line 253 16.70 32.0 12.25 Customer:Report #: Well:Date: Area:04:00 Depth Location:Progress 24 hrs: Rig:Rig Activity: Job No.:Report For: ROP & Gas: . Mud Data:Density (ppg)Viscosity Depth ft (sec/qt) BHA Run #Bit Type TFA Hours Depth in / out Footage WOB RPM Condition Lithology (%): (current) to to to to to to to to to Gas Type abreviations: BG - Background Gas; GP - Gas Peak; CG - Connection Gas; WTG - Wiper Trip Gas; POG - Pumps Off Gas; PG - Produced Gas; RG - Ream Gas; T-- - Trip…; F-- - Formation…; E-- - Early… 24 hr Recap: , Logging Engineer:*10000 units = 100% Gas In Air na na Reed Milltooth Pits empty Gas (units) H2S Data Sample Line na 16.70 Hole Condition On Bot Hrs -- in out from pits and returned to MI mudplant. Cleaned pits for MOBM. Rigged down diverter line and in process of rigging up BOPE at report time. All Circ-- Max: Finished cementing while receiving 212 bbls cement back to surface and bumping plug with MOBM. Emptied WBM Tom Mansfield changed out with Danny Kane. md Nipple up BOP J. Nicholson/J. West na na Flow In (gpm) Current Pump & Flow Data: - Max @ ft Max na 2.9620 $35,695.00 na na Total Charges: Flow In (spm) SPP (psi) Avg % - na mg/l -AvgMin Max Gallons/stroke pH Chlorides GvlCoal - - Min - Max:Ambient Air Pit Room Daily Charges Avg na nana 6 03/17/2011-04:00 2358' North Slope 0' Brooks Range North Tarn #1 Tarn Current R.O.P. (ft/hr) Gas (units)na na na Depth Avg Diam (ppb Eq)cP 2358.00 Nabors 9ES $3,425.00 AK-AM-8035432 PVMBT PWD Drilling Lst 120.00 na Size na ClystCht na 12.25 20 Chromatograph (ppm) Depth max 15 2238' 65 C2C1 Sh Avg: 1 23'0.942 Sd Silt Siltst TypeC4C5 Tuff Gas Breakdown Avg: avg Sst C3 API Filt na 48' na ml/30min Tom Mansfield/Ryan Massey 1-1-WT-A-E-1-ER-TD Ann Corr Cor Solids lb/100ft2 na 24 hr Max YP Customer:Report #: Well:Date: Area:04:00 Depth Location:Progress 24 hrs: Rig:Rig Activity: Job No.:Report For: ROP & Gas: . Mud Data:Density (ppg)Viscosity Depth ft (sec/qt) BHA Run #Bit Type TFA Hours Depth in / out Footage WOB RPM Condition Lithology (%): (current) to to to to to to to to to Gas Type abreviations: BG - Background Gas; GP - Gas Peak; CG - Connection Gas; WTG - Wiper Trip Gas; POG - Pumps Off Gas; PG - Produced Gas; RG - Ream Gas; T-- - Trip…; F-- - Formation…; E-- - Early… 24 hr Recap: , Logging Engineer:*10000 units = 100% Gas In Air na na Reed Milltooth Pits empty Gas (units) H2S Data Sample Line na 16.70 Hole Condition On Bot Hrs -- in out All Circ-- Max: Finished cleaning pits and received MOBM. Nippled up BOP. Test BOP. md Test BOP J. Nicholson/J. West na na Flow In (gpm) Current Pump & Flow Data: - Max @ ft Max na 2.9620 $39,120.00 na na Total Charges: Flow In (spm) SPP (psi) Avg % - na mg/l -AvgMin Max Gallons/stroke pH Chlorides GvlCoal - - Min - Max:Ambient Air Pit Room Daily Charges Avg na nana 7 03/18/2011-04:00 2358' North Slope 0' Brooks Range North Tarn #1 Tarn Current R.O.P. (ft/hr) Gas (units)na na na Depth Avg Diam (ppb Eq)cP 2358.00 Nabors 9ES $3,425.00 AK-AM-8035432 PVMBT PWD Drilling Lst 120.00 na Size na ClystCht na 12.25 20 Chromatograph (ppm) Depth max 15 2238' 65 C2C1 Sh Avg: 1 23'0.942 Sd Silt Siltst TypeC4C5 Tuff Gas Breakdown Avg: avg Sst C3 API Filt na 48' na ml/30min Tom Mansfield/Ryan Massey 1-1-WT-A-E-1-ER-TD Ann Corr Cor Solids lb/100ft2 na 24 hr Max YP Customer:Report #: Well:Date: Area:04:00 Depth Location:Progress 24 hrs: Rig:Rig Activity: Job No.:Report For: ROP & Gas: . Mud Data:Density (ppg)Viscosity Depth ft (sec/qt) BHA Run #Bit Type TFA Hours Depth in / out Footage WOB RPM Condition Lithology (%): (current) to to to to to to to to to Gas Type abreviations: BG - Background Gas; GP - Gas Peak; CG - Connection Gas; WTG - Wiper Trip Gas; POG - Pumps Off Gas; PG - Produced Gas; RG - Ream Gas; T-- - Trip…; F-- - Formation…; E-- - Early… 24 hr Recap: , Logging Engineer:*10000 units = 100% Gas In AirTom Mansfield/Ryan Massey 1-1-WT-A-E-1-ER-TD Ann Corr Cor Solids lb/100ft2 na 24 hr Max YP API Filt na 48' na ml/30min avg Sst C3 Tuff Gas Breakdown Avg: Sd Silt Siltst TypeC4C5 1 23'0.942 Depth max 15 2238' 65 C2C1 Sh Avg: Chromatograph (ppm) ClystCht Lst 120.00 na Nabors 9ES $3,425.00 AK-AM-8035432 PVMBT PWD Drilling na na Depth (ppb Eq)cP 2358.00 Size na na 8 03/19/2011-04:00 2358' North Slope 0' Brooks Range North Tarn #1 Tarn Current Daily Charges Avg na na R.O.P. (ft/hr) Gas (units)na Max:Ambient Air Pit Room -Min -Avg - pH Chlorides GvlCoal % - na mg/l -AvgMin Max Max na 2.9620 $42,545.00 na na Total Charges: Flow In (spm) SPP (psi) Gallons/stroke Test BOP J. Nicholson/J. West na na Flow In (gpm) Current Pump & Flow Data: - Max @ ft md All Circ Avg Diam -- new Kelly hose. Picked up 5" drill pipe while warming new Kelly hose in pipe shed prior to installation. Begin installing new kelly hose. Finished testing BOPE. Kelly hose frozen. Attempt to thaw with steam. Hose suspect. Removed Kelly hose. Received Hole Condition On Bot Hrs -- in out na na Max: 20 Reed Milltooth Pits empty Gas (units) H2S Data Sample Line na 16.70 na 12.25 Customer:Report #: Well:Date: Area:04:00 Depth Location:Progress 24 hrs: Rig:Rig Activity: Job No.:Report For: ROP & Gas: . Mud Data:Density (ppg)Viscosity Depth ft (sec/qt) BHA Run #Bit Type TFA Hours Depth in / out Footage WOB RPM Condition Lithology (%): (current) to to to to to to to to to Gas Type abreviations: BG - Background Gas; GP - Gas Peak; CG - Connection Gas; WTG - Wiper Trip Gas; POG - Pumps Off Gas; PG - Produced Gas; RG - Ream Gas; T-- - Trip…; F-- - Formation…; E-- - Early… 24 hr Recap: , Logging Engineer:*10000 units = 100% Gas In AirTom Mansfield/Ryan Massey 1-1-WT-A-E-1-ER-TD Ann Corr Cor Solids lb/100ft2 65,000 24 hr Max YP HTHP Filt 2.08 145 48' 6.4 ml/30min avg Sst C3 146 Tuff Gas Breakdown 2358' Avg: 59 Sd Silt Siltst Type 0 C4 C5 BG0 1 2 DTX619M-D6 15-20 23' 2358' 0.942 Depth max 15 2238' 80 C2C1 Sh Avg: 14353 Chromatograph (ppm) TR ClystCht Lst 120.00 147' 13 Nabors 9ES $3,425.00 AK-AM-8035432 PVGel PWD Drilling 59 2428' Depth 10s/10m/30m cP 2358.00 Size 36 na 9 03/20/2011-04:00 2505' North Slope 147' Brooks Range North Tarn #1 Tarn Current Daily Charges Avg 8.5 0.778 205.0 314.0 R.O.P. (ft/hr) Gas (units)na Max:Ambient Air Pit Room 0 0 -Min -Avg - Lime Cl- Whole GvlCoal % - 3.0 mg/l -AvgMin Max Max 1675 2.9620 $45,970.00 390 130 Total Charges: Flow In (spm) SPP (psi) Gallons/stroke Drilling Ahead J. Nicholson/J. West 146 2396' Flow In (gpm) Current Pump & Flow Data: - Max @ ft md All Circ Avg Diam -- Drilled out float collar, shoe track and 20' new formation to 2378'. Performed FIT to 14.2 ppg EMW. Drilled ahead to current depth. Abundant large Claystone cuttings overshakers during connection at 2505' MD. Replaced and tested Kelly hose. Picked up 5" Drill Pipe. Picked up BHA. Tripped in hole and circulated bottoms up. Hole Condition On Bot Hrs -- in out 9.60 9.60 Max: 2505' 5 Reed Milltooth 2358' Gas (units) H2S Data Sample Line 97 16.70 40338.0 12.25 Customer:Report #: Well:Date: Area:04:00 Depth Location:Progress 24 hrs: Rig:Rig Activity: Job No.:Report For: ROP & Gas: . Mud Data:Density (ppg)Viscosity Depth ft (sec/qt) BHA Run #Bit Type TFA Hours Depth in / out Footage WOB RPM Condition Lithology (%): (current) to to to to to to to to to Gas Type abreviations: BG - Background Gas; GP - Gas Peak; CG - Connection Gas; WTG - Wiper Trip Gas; POG - Pumps Off Gas; PG - Produced Gas; RG - Ream Gas; T-- - Trip…; F-- - Formation…; E-- - Early… 24 hr Recap: , Logging Engineer:*10000 units = 100% Gas In Air 9.60 9.60 228 Reed Milltooth 3744' Gas (units) H2S Data Sample Line 97 16.70 Hole Condition On Bot Hrs 4500'10.8 57 in out 3460' and washed down to bottom at 3556'. Short trip gas of 109 units. Drilled ahead without losses. All Circ0 bbls 8.50'' Max: Drilled ahead from 2505' to 3556'. Lost returns (28 bbls). Short Tripped to 2315' with correct trip displacement. RIH to md Drilling Ahead J. Nicholson/J. West 233 4463' Flow In (gpm) Current Pump & Flow Data: 11.18 Max @ ft Max 2400 2.9620 $49,395.00 490 166 Total Charges: Flow In (spm) SPP (psi) Avg % 11.18 10.8 mg/l 10.75 AvgMin Max 0 Gallons/stroke Lime Cl- Whole GvlCoal BG 10.16 317 52 10.16 Min 10.75 0 0 0 Max:Ambient Air Pit Room 0 0 0 0 23874 4490'233 3556' 3556' Daily Charges Avg 8.5 0.778 226.0 451.081.0 10 03/21/2011-04:00 4530' North Slope 2025' Brooks Range North Tarn #1 Tarn Current R.O.P. (ft/hr) Gas (units)78 83 3286' Depth Avg Diam 10s/10m/30m cP 2358.00 Nabors 9ES $3,425.00 AK-AM-8035432 PVGel PWD Drilling Lst 120.00 147' 14 Size 33 ClystCht 7/9/12 12.25 112 14577 Chromatograph (ppm) TR 4150' 3556' 3556'3556' 4150'3556'12787 129 0 27 109 109 10833 0 BG0 Depth max 2238' C2C1 Sh Avg: 1 2 DTX619M-D6 15-20 23' 2358' 11.30 0.942 Sd Silt Siltst STG Type 0 C4 C5 BG0 0 CG Tuff Gas Breakdown 2505' Avg: 100 88 avg Sst 0 0 C3 228 21879 148 HTHP Filt 1.82 145 48' 5.6 ml/30min Tom Mansfield/Ryan Massey 1-1-WT-A-E-1-ER-TD Ann Corr Cor Solids lb/100ft2 52,300 24 hr Max 0 YP Customer:Report #: Well:Date: Area:04:00 Depth Location:Progress 24 hrs: Rig:Rig Activity: Job No.:Report For: ROP & Gas: . Mud Data:Density (ppg)Viscosity Depth ft (sec/qt) BHA Run #Bit Type TFA Hours Depth in / out Footage WOB RPM Condition Lithology (%): (current) to to to to to to to to to Gas Type abreviations: BG - Background Gas; GP - Gas Peak; CG - Connection Gas; WTG - Wiper Trip Gas; POG - Pumps Off Gas; PG - Produced Gas; RG - Ream Gas; T-- - Trip…; F-- - Formation…; E-- - Early… 24 hr Recap: , Logging Engineer:*10000 units = 100% Gas In AirTom Mansfield/Ryan Massey 1-1-WT-A-E-1-ER-TD Ann Corr Cor Solids lb/100ft2 51,000 24 hr Max 0 YP HTHP Filt 2.34 145 48' 4.8 ml/30min avg Sst 961 186 C3 775 223847 90 0 GP Tuff Gas Breakdown 4490' Avg: 65 74 Sd Silt Siltst BG Type 0 C4 C5 BG0 1 2 DTX619M-D6 15-20 23' 2358' 20.10 0.942 Depth max 30 2238' C2C1 Sh Avg: 63 404 270 33076 721 198 1099 430 133 44195 0 GP93 4520' 4559'5457' 5472'5457'63273 631 5 498 10124 Chromatograph (ppm) 928 ClystCht Lst 120.00 3305' 15 Nabors 9ES $3,425.00 AK-AM-8035432 PVGel PWD Drilling 160 5575' Depth 10s/10m/30m cP 2358.00 Size 35 na 11 03/22/2011-04:00 5663' North Slope 1133' Brooks Range North Tarn #1 Tarn Current Daily Charges Avg 8.5 0.778 163.0 374.0 R.O.P. (ft/hr) Gas (units)na 91169 5663'5589' 5589'895 5552'1637 377 80 301 72 Max:Ambient Air Pit Room 3998 177 GP 34 308 0 BG 10.42 Min 10.74 Avg 10.42 0 Lime Cl- Whole GvlCoal % 11.53 11.8 mg/l 10.74 AvgMin Max Max 2475 2.9620 $52,820.00 473 160 Total Charges: Flow In (spm) SPP (psi) Gallons/stroke RIH @ 3750' J. Nicholson/J. West 2094 4521' Flow In (gpm) Current Pump & Flow Data: 11.53 Max @ ft md dirty Sandstone from 5560' MD to 5580' MD producing minor gas show with 895 units over a background gas of 190 units. Drilled ahead to 5663' MD and short tripped to shoe for rig repair (replace bell nipple o ring seal). Replaced seal and RIH to 3358' MD. Knock ice from derrick. RIH from 3750' MD at report time. No connection gases reported. Experience some difficulty with gas All Circ Avg Diam 0 bbls 8.50'' of 2094 units over background of 90 units with minor yel fluor and possible mlky wh flash cut fluor (masked by OB mud). Drilled ahead through predominately Shale with minor Siltstone and thinly interbedded Sandstones to 5553'. Encountered another 20' thick trapline freezing. Drilled ahead from 3556' to 5663'. Encountered 34' Sandstone from 4525' MD to 4559' MD. Interval produced gas show Hole Condition On Bot Hrs 5663'20.1 440 in out 9.60 9.60 Max: 4520' 4559'2094 Reed Milltooth 5663' Gas (units) H2S Data Sample Line 92 16.70 11/19/26 12.25 Customer:Report #: Well:Date: Area:04:00 Depth Location:Progress 24 hrs: Rig:Rig Activity: Job No.:Report For: ROP & Gas: . Mud Data:Density (ppg)Viscosity Depth ft (sec/qt) BHA Run #Bit Type TFA Hours Depth in / out Footage WOB RPM Condition Lithology (%): (current) to to to to to to to to to Gas Type abreviations: BG - Background Gas; GP - Gas Peak; CG - Connection Gas; WTG - Wiper Trip Gas; POG - Pumps Off Gas; PG - Produced Gas; RG - Ream Gas; T-- - Trip…; F-- - Formation…; E-- - Early… 24 hr Recap: , Logging Engineer:*10000 units = 100% Gas In Air 10.40 10.40 955 Reed Milltooth 5663' Gas (units) H2S Data Sample Line 105 16.70 Avg Diam 0 bbls 8.50'' Max: Hole Condition On Bot Hrs 6223'24.8 6223' MD. HRZ encountered at approximately 5905' MD, 5831' TVD, HRZ Base approximately 6022' MD, 5947' TVD. Topped Kuparuk Sand at approximately 6198' MD, 6122' TVD. Bottoms up from Kup sand yielded 7323 units of gas over a background All Circ 2125 in RIH from short trip to shoe. Trip displacement good with a short trip gas of 58 units. Drilled ahead from 5663' MD to md gas of 130 units. 3% flow increase, flow check well. Well flowing. Shut in well and monitor. 4 bbl gain, 300 psi SICP and 220 psi SIDPP. Circulate through choke at 2 bpm, increasing mud weight from 9.6 ppg to 10.4 ppg. Circulate J. Nicholson/J. West 7323 6198' Flow In (gpm) Current Pump & Flow Data: 11.09 Max @ ft Max 240 2.9620 $56,245.00 86 15 Total Charges: Flow In (spm) SPP (psi) GP 10.52 Min 10.71 Avg % 13.1 mg/l Max Gallons/stroke Lime Cl- Whole GvlCoal 11.0910.71 Avg10.52 Min 78 Max:Ambient Air Pit Room 2226 22380 3940 312 152.0 424.9na Brooks Range North Tarn #1 Tarn 5905' 6022' Daily Charges Avg 8.5 0.778 Gas (units)na 440 5776' Depth 12 03/23/2011-04:00 6223' North Slope 560' Nabors 9ES $3,425.00 AK-AM-8035432 PVGel PWD Drilling Current R.O.P. (ft/hr) 25 Size 35 ClystCht 10s/10m/30m cP 2358.00 out 31/33/35 500144 Chromatograph (ppm) 5905' 6022'6197' 6223'6198'7323 1261 930 359 52946 2238' C2C1 Sh Avg: Lst 120.00 3865'24.80 0.942 Depth max 2535 12.25 107 C4 C5 BG 824 1 2 DTX619M-D6 15-20 23' 240 Sd Silt Siltst BG Type 88935 753 BG Tuff Gas Breakdown 5663' Avg: 40 145 48' 4.6 ml/30min avg Sst C3 2358' 1-1-WT-A-E-1-ER-TD Ann Corr Cor Solids lb/100ft2 31,000 24 hr Max YP HTHP Filt 1.82 65470 1293 281 49 Tom Mansfield/Ryan Massey 559 143 565 Customer:Report #: Well:Date: Area:04:00 Depth Location:Progress 24 hrs: Rig:Rig Activity: Job No.:Report For: ROP & Gas: . Mud Data:Density (ppg)Viscosity Depth ft (sec/qt) BHA Run #Bit Type TFA Hours Depth in / out Footage WOB RPM Condition Lithology (%): (current) to to to to to to to to to Gas Type abreviations: BG - Background Gas; GP - Gas Peak; CG - Connection Gas; WTG - Wiper Trip Gas; POG - Pumps Off Gas; PG - Produced Gas; RG - Ream Gas; T-- - Trip…; F-- - Formation…; E-- - Early… 24 hr Recap: , Logging Engineer:*10000 units = 100% Gas In Air 93347 19551 Tom Mansfield/Ryan Massey 1-1-WT-A-E-1-ER-TD Ann Corr Cor Solids lb/100ft2 45,500 24 hr Max YP HTHP Filt 2.34 145 48' 4.6 ml/30min Sst 13976 5669 C3 2388 227564 9355 2933 Gas Breakdown MAX Avg: 40 avg 858237 150699 Sd Silt Siltst TypeDepthmax 25 C2 C4 C5 Circ 1436 Circ C1 Sh Avg: 1 2 DTX619M-D6 2358' 24.80 AVG Cht Lst 120.00 3865' 25 35 15-20 Nabors 9ES $3,425.00 AK-AM-8035432 PVGel PWD Drilling 2388 na Depth 10s/10m/30m cP 2358.00 Size 30 0.942 2238' na 13 03/24/2011-04:00 6223' North Slope 0' Brooks Range North Tarn #1 Tarn Current Daily Charges Avg 8.5 0.778 na na R.O.P. (ft/hr) Gas (units)3750 Max:Ambient Air Pit Room 105215 Chromatograph (ppm) na Gallons/stroke Lime Cl- Whole GvlCoal 23' Tuff na Min na Avg Clyst % na 18.5 mg/l na AvgMin Max Max 240 216.0000 $59,670.00 88 30 Total Charges: Flow In (spm) SPP (psi) Circulate J. Nicholson/J. West 9355 6223' Flow In (gpm) Current Pump & Flow Data: na Max @ ft md to drop YP. Gained 84 bbls while circulating through choke. Mud gas varying between 3200 to 4500 units. Mud weight out 10.3, mud weight in 10.4. SIDPP - 200 PSI, SICP - 190. Begin weighting up mud system to 10.5 ppg circulating through choke. All Circ Avg Diam 0 bbls 8.50'' SIDPP=50 psi, SICP=200 psi. Bled 43 bbls through choke. Circulated 10.4 ppg mud through choke. Monitored well. Bottoms up produced 9355 units of Gas Continued to pump 10.4 ppg mud and circulate through the choke. Began adding LVT to the system Circulated through choke at 2 bpm, increasing mud weight to 10.4 ppg. Shut down and monitored well on choke. Hole Condition On Bot Hrs 6223'24.8 in out 10.40 10.40 Max: Reed Milltooth 6223' Gas (units) H2S Data Sample Line 115 16.70 25/37/40 12.25 Customer:Report #: Well:Date: Area:04:00 Depth Location:Progress 24 hrs: Rig:Rig Activity: Job No.:Report For: ROP & Gas: . Mud Data:Density (ppg)Viscosity Depth ft (sec/qt) BHA Run #Bit Type TFA Hours Depth in / out Footage WOB RPM Condition Lithology (%): (current) to to to to to to to to to Gas Type abreviations: BG - Background Gas; GP - Gas Peak; CG - Connection Gas; WTG - Wiper Trip Gas; POG - Pumps Off Gas; PG - Produced Gas; RG - Ream Gas; T-- - Trip…; F-- - Formation…; E-- - Early… 24 hr Recap: , Logging Engineer:*10000 units = 100% Gas In AirTom Mansfield/Ryan Massey 1-1-WT-A-E-1-ER-TD Ann Corr Cor Solids lb/100ft2 37,500 24 hr Max YP 1.82 145 48' 4.8 ml/30min 381426 156062 92675 4950 294315 2606 18324 Chromatograph (ppm) MAX Avg: 40 avg 6964 C2 Avg: 35 Gas Breakdown Circ Type 2023 Circ 1 2 DTX619M-D6 24.80 0.942 C4 C5Depthmax Silt Siltst 25 2238' AVG ChtSst Lst 120.00 3865' 22 Sh 15-20 23' 2358' Nabors 9ES $3,425.00 AK-AM-8035432 PVGel PWD Drilling 4958 na Depth 10s/10m/30m cP 2358.00 Size 25 na 14 03/25/2011-04:00 6223' North Slope 0' Brooks Range North Tarn #1 Tarn Current Daily Charges Avg 8.5 0.778 na na R.O.P. (ft/hr) Gas (units)na Max:Ambient Air Pit Room 39703 C1 17961 6614 na Gallons/stroke Lime Cl- Whole GvlCoal Tuff HTHP Filt na Min na Avg C3 Clyst % na 16.8 mg/l na AvgMin Max Max 240 2.9620 $63,095.00 38 13 Total Charges: Flow In (spm) SPP (psi) Circulate J. Nicholson/J. West 6964 6223' Flow In (gpm) Current Pump & Flow Data: na Max @ ft md monitored well. Pumped LCM pill. Mud weight in 10.5 ppg, out 10.3 ppg. Stopped pumping and monitored well. 44 bbls returns after 15 minutes. All Circ Avg Diam 0 bbls 8.50'' through choke with a maximum of 6964 gas units. Monitored well. Bled through choke with 52 bbls returned in 10 minutes. Closed annular preventer and rotated one turn. No Torque. Break over 170, P/U 210. Slipped through bag slowly from 6202' to 6155' and Shut down and monitor well, SIDPP 30 psi, SICP 240 psi. Weight mud system up to 10.5 ppg and continue to circulate Hole Condition On Bot Hrs 6223'24.8 in out 10.50 10.50 Max: Sd Reed Milltooth 6223' Gas (units) H2S Data Sample Line 89 16.70 23/34/36 12.25 Customer:Report #: Well:Date: Area:04:00 Depth Location:Progress 24 hrs: Rig:Rig Activity: Job No.:Report For: ROP & Gas: . Mud Data:Density (ppg)Viscosity Depth ft (sec/qt) BHA Run #Bit Type TFA Hours Depth in / out Footage WOB RPM Condition Lithology (%): (current) to to to to to to to to to Gas Type abreviations: BG - Background Gas; GP - Gas Peak; CG - Connection Gas; WTG - Wiper Trip Gas; POG - Pumps Off Gas; PG - Produced Gas; RG - Ream Gas; T-- - Trip…; F-- - Formation…; E-- - Early… 24 hr Recap: , Logging Engineer:*10000 units = 100% Gas In Air 9.70 Reed Milltooth 6223' Gas (units) H2S Data Sample Line 105 16.70 19/31/34 Avg Diam 0 bbls 8.50'' Max: Hole Condition On Bot Hrs 6223'24.8 SIDDP went from 440 to 170 psi. Rolled pumps 14 spm at 20 psi. Weighted up mud system to 10.7 ppg. SIDPP 40, SICP 330. Samples coming back 99% LCM at 9.6 ppg. Low pit volume. Lost 657 bbls to formation. Shut down pumps and closed in well. Sample catchers released on Mar 25th. All Circ in Controlled well bore through choke while taking returns out secondary choke to storage tanks with choke fully opened. md SIDPP 50 psi, SICP 360 psi. Slacked off and broke over drill string through bag. Stripped through bag from 6,155' to 6,138 with up weight of 22k. Slacked off to down weight. Shut in well. Made up TIW valve and 5' pup. Swapped from annular bag to upper rams. Read 1400 units on mud returning from storage tanks. Wireline J. Nicholson/J. West 1725 6223' Flow In (gpm) Current Pump & Flow Data: na Max @ ft na 2.9620 $65,750.00 na na Total Charges: Flow In (spm) SPP (psi) na 13.3 mg/l na AvgMin Max Max na Min na Avg % na Gallons/stroke Lime Cl- Whole GvlCoal Max:Ambient Air Pit Room C1 C3 na nana Brooks Range North Tarn #1 Tarn Daily Charges Avg 8.5 0.778 Gas (units)na 1400 na Depth 15 03/26/2011-04:00 6223' North Slope 0' Nabors 9ES $2,655.00 AK-AM-8035432 PVGel PWD Drilling Current R.O.P. (ft/hr) Size 41 ClystChtSst 10s/10m/30m cP 2358.00 out 10.70 Lst 120.00 3865' 26 Sh 15-20 23' 2358' 2238'1 2 DTX619M-D6 24.80 0.942 Sd Silt Siltst 12.25 C4 C5 TypeDepthmax 25 C2 Avg: 35 Tuff Gas Breakdown Avg: 40 avg Chromatograph (ppm) HTHP Filt 3.71 145 48' 1.1 ml/30min Tom Mansfield/Ryan Massey 1-1-WT-A-E-1-ER-TD Ann Corr Cor Solids lb/100ft2 77,500 24 hr Max YP Customer:Report #: Well:Date: Area:04:00 Depth Location:Progress 24 hrs: Rig:Rig Activity: Job No.:Report For: ROP & Gas: . Mud Data:Density (ppg)Viscosity Depth ft (sec/qt) BHA Run #Bit Type TFA Hours Depth in / out Footage WOB RPM Condition Lithology (%): (current) to to to to to to to to to Gas Type abreviations: BG - Background Gas; GP - Gas Peak; CG - Connection Gas; WTG - Wiper Trip Gas; POG - Pumps Off Gas; PG - Produced Gas; RG - Ream Gas; T-- - Trip…; F-- - Formation…; E-- - Early… 24 hr Recap: , Logging Engineer:*10000 units = 100% Gas In AirTom Mansfield/Ryan Massey 1-1-WT-A-E-1-ER-TD Ann Corr Cor Solids lb/100ft2 78,000 24 hr Max YP 3.64 145 48' 1.0 ml/30min Chromatograph (ppm) Avg: 40 avg C2 Avg: 35 Gas Breakdown Type 1 2 DTX619M-D6 24.80 0.942 C4 C5Depthmax Silt Siltst 25 2238' ChtSst Lst 120.00 3865' 26 Sh 15-20 23' 2358' Nabors 9ES $2,655.00 AK-AM-8035432 PVGel PWD Drilling 1400 na Depth 10s/10m/30m cP 2358.00 Size 42 na 16 03/27/2011-04:00 6223' North Slope 0' Brooks Range North Tarn #1 Tarn Current Daily Charges Avg 8.5 0.778 na na R.O.P. (ft/hr) Gas (units)na Max:Ambient Air Pit Room C1 na Gallons/stroke Lime Cl- Whole GvlCoal Tuff HTHP Filt na Min na Avg C3 Clyst % na 18.0 mg/l na AvgMin Max Max na 2.9620 $68,405.00 na na Total Charges: Flow In (spm) SPP (psi) Well Control J. Nicholson/J. West 1725 6223' Flow In (gpm) Current Pump & Flow Data: na Max @ ft md All Circ Avg Diam 0 bbls 8.50'' TIW valve. Logged to 5990' and pulled out of the hole. Monitored well with SICP of 1290 psi. Ran in hole and retrieved MWD nuclear source by wireline. Increased mud weight to 11.7 ppg. No gas circulated for report period. Sample catchers released on Mar 25th. Rigged up lubricator, BOP's and wireline tools. Run in hole with temperature and noise wireline logging tool through Hole Condition On Bot Hrs 6223'24.8 in out 11.70 10.50 Max: Sd Reed Milltooth 6223' Gas (units) H2S Data Sample Line 108 16.70 17/30/34 12.25 Customer:Report #: Well:Date: Area:04:00 Depth Location:Progress 24 hrs: Rig:Rig Activity: Job No.:Report For: ROP & Gas: . Mud Data:Density (ppg)Viscosity Depth ft (sec/qt) BHA Run #Bit Type TFA Hours Depth in / out Footage WOB RPM Condition Lithology (%): (current) to to to to to to to to to Gas Type abreviations: BG - Background Gas; GP - Gas Peak; CG - Connection Gas; WTG - Wiper Trip Gas; POG - Pumps Off Gas; PG - Produced Gas; RG - Ream Gas; T-- - Trip…; F-- - Formation…; E-- - Early… 24 hr Recap: , Logging Engineer:*10000 units = 100% Gas In Air na Reed Milltooth 6223' Gas (units) H2S Data Sample Line 99 16.70 18/27/34 Avg Diam 0 bbls 8.50'' Max: Hole Condition On Bot Hrs 6223'24.8 mud weight out. As mud weight out rose from 8.0 ppg to 11.4 SICP dropped to 0. Stopped circulating and monitored well. SICP rose to 70 psi. Lined up on gas buster and pits. Pumped 40 bbls without returns. SICP 0 and SIDPP 0. Fluid started to rise and All Circ in Well shut in with 1300 psi on annulus. Waited on 11.7 ppg mud to arrive. Pumped 11.7 ppg kill weight mud in, 8.0 ppg md flow out increased to 28% with gas units rising rapidly to 6100 units before shutting in well with upper rams. SIDPP 30 psi and SICP 130 psi. Pumped with no returns. Pit volume low. Shut in well. SICP rose gradually to 1300 psi at report time. Well Control J. Nicholson/J. West 6100 6223' Flow In (gpm) Current Pump & Flow Data: na Max @ ft na 2.9620 $71,060.00 na na Total Charges: Flow In (spm) SPP (psi) na 15.8 mg/l na AvgMin Max Max na Min na Avg % na Gallons/stroke Lime Cl- Whole GvlCoal Max:Ambient Air Pit Room C1 C3 na nana Brooks Range North Tarn #1 Tarn Daily Charges Avg 8.5 0.778 Gas (units)na na na Depth 17 03/28/2011-04:00 6223' North Slope 0' Nabors 9ES $2,655.00 AK-AM-8035432 PVGel PWD Drilling Current R.O.P. (ft/hr) Size 45 ClystChtSst 10s/10m/30m cP 2358.00 out 11.70 Lst 120.00 3865' 24 Sh 15-20 23' 2358' 2238'1 2 DTX619M-D6 24.80 0.942 Sd Silt Siltst 12.25 C4 C5 TypeDepthmax 25 C2 Avg: 35 Tuff Gas Breakdown Avg: 40 avg Chromatograph (ppm) HTHP Filt 3.51 145 48' 1.0 ml/30min Tom Mansfield/Ryan Massey 1-1-WT-A-E-1-ER-TD Ann Corr Cor Solids lb/100ft2 76,000 24 hr Max YP Customer:Report #: Well:Date: Area:04:00 Depth Location:Progress 24 hrs: Rig:Rig Activity: Job No.:Report For: ROP & Gas: . Mud Data:Density (ppg)Viscosity Depth ft (sec/qt) BHA Run #Bit Type TFA Hours Depth in / out Footage WOB RPM Condition Lithology (%): (current) to to to to to to to to to Gas Type abreviations: BG - Background Gas; GP - Gas Peak; CG - Connection Gas; WTG - Wiper Trip Gas; POG - Pumps Off Gas; PG - Produced Gas; RG - Ream Gas; T-- - Trip…; F-- - Formation…; E-- - Early… 24 hr Recap: , Logging Engineer:*10000 units = 100% Gas In Air 11.50 Reed Milltooth 6223' Gas (units) H2S Data Sample Line 73 16.70 16/26/32 Avg Diam 0 bbls 8.50'' Max: Hole Condition On Bot Hrs 6223'24.8 to tiger tank. Broke circulation pumping a 40 bbl 26#/bbl Mix II pill with initial SIDPP of 40 psi, SICP of 1250 psi. SPP gradually rose to approx. 200 psi while CP eventually decreased to approx. 120 psi. Lost 409 bbls while circulating. Shut in well. SIDPP 0, All Circ in Monitored well with SIDPP of 0, SICP of 1250. Lined up on secondary choke and divert to mud/gas separator then out md SICP rising gradually to 150 psi. Continued pumping 10 minutes at 10 spm, 30 gpm with 160 psi SPP, 165 psi CP at report time. No gas to report last 24 hrs, flow diverted. Well Control J. Nicholson/J. West 6100 6223' Flow In (gpm) Current Pump & Flow Data: na Max @ ft na 2.9620 $73,715.00 na na Total Charges: Flow In (spm) SPP (psi) na 12.8 mg/l na AvgMin Max Max na Min na Avg % na Gallons/stroke Lime Cl- Whole GvlCoal Max:Ambient Air Pit Room C1 C3 na nana Brooks Range North Tarn #1 Tarn Daily Charges Avg 8.5 0.778 Gas (units)na na na Depth 18 03/29/2011-04:00 6223' North Slope 0' Nabors 9ES $2,655.00 AK-AM-8035432 PVGel PWD Drilling Current R.O.P. (ft/hr) Size 40 ClystChtSst 10s/10m/30m cP 2358.00 out 11.70 Lst 120.00 3865' 24 Sh 15-20 23' 2358' 2238'1 2 DTX619M-D6 24.80 0.942 Sd Silt Siltst 12.25 C4 C5 TypeDepthmax 25 C2 Avg: 35 Tuff Gas Breakdown Avg: 40 avg Chromatograph (ppm) HTHP Filt 3.38 145 48' 2.1 ml/30min Tom Mansfield/Ryan Massey 1-1-WT-A-E-1-ER-TD Ann Corr Cor Solids lb/100ft2 77,000 24 hr Max YP Customer:Report #: Well:Date: Area:04:00 Depth Location:Progress 24 hrs: Rig:Rig Activity: Job No.:Report For: ROP & Gas: . Mud Data:Density (ppg)Viscosity Depth ft (sec/qt) BHA Run #Bit Type TFA Hours Depth in / out Footage WOB RPM Condition Lithology (%): (current) to to to to to to to to to Gas Type abreviations: BG - Background Gas; GP - Gas Peak; CG - Connection Gas; WTG - Wiper Trip Gas; POG - Pumps Off Gas; PG - Produced Gas; RG - Ream Gas; T-- - Trip…; F-- - Formation…; E-- - Early… 24 hr Recap: , Logging Engineer:*10000 units = 100% Gas In AirTom Mansfield/Ryan Massey 1-1-WT-A-E-1-ER-TD Ann Corr Cor Solids lb/100ft2 52,500 24 hr Max YP 1.56 145 48' 2.4 ml/30min Chromatograph (ppm) Avg: 40 avg C2 Avg: 35 Gas Breakdown Type 1 2 DTX619M-D6 24.80 0.942 C4 C5Depthmax Silt Siltst 25 2238' ChtSst Lst 120.00 3865' 25 Sh 15-20 23' 2358' Nabors 9ES $2,655.00 AK-AM-8035432 PVGel PWD Drilling 4000 na Depth 10s/10m/30m cP 2358.00 Size 37 na 19 03/30/2011-04:00 6223' North Slope 0' Brooks Range North Tarn #1 Tarn Current Daily Charges Avg 8.5 0.778 na na R.O.P. (ft/hr) Gas (units)na Max:Ambient Air Pit Room C1 na Gallons/stroke Lime Cl- Whole GvlCoal Tuff HTHP Filt na Min na Avg C3 Clyst % na 13.9 mg/l na AvgMin Max Max 42 2.9620 $76,370.00 58 20 Total Charges: Flow In (spm) SPP (psi) Well Control J. Nicholson/J. West 6678 11:45 am Flow In (gpm) Current Pump & Flow Data: na Max @ ft md down DP slowly staging pump up to 77 gpm while SICP gradually dropped to 160 psi. Gas peaked at a maximum 6678 units. Continued circulating with high losses and gas varying between 5000 units to 3800 units. SICP eventually dropped to 70 psi with SPP of 233 psi at 89 gpm. Reduced rate to 59 gpm with SPP of 48 psi and SICP of 70 waiting to take on new mud. Circulating All Circ Avg Diam 0 bbls 8.50'' at 60 psi. Pumped 3 bbls down annulus with pressure increase of 170 psi. SICP continued to rise to 520 psi. with mud losses of 67 bph. Pumped a second 21 bbl thermatek pill. SIDPP 0 psi, SICP 340 psi increasing to 530 psi. Pumped down drill pipe at 59 gpm with 3500 units background gas and 42 psi SPP, 165 SICP at report time. Mud loss rate approximately 45 bbl/hr. Spotted 15 bbl ThermaTex pill at 5942'. Monitored well with 30 psi SIDPP, 160 psi SICP. Pumped 3 bbls down drill pipe Hole Condition On Bot Hrs 6223'24.8 in out 11.70 11.70 Max: Sd Reed Milltooth 6223' Gas (units) H2S Data Sample Line 80 16.70 19/30/39 12.25 Customer:Report #: Well:Date: Area:04:00 Depth Location:Progress 24 hrs: Rig:Rig Activity: Job No.:Report For: ROP & Gas: . Mud Data:Density (ppg)Viscosity Depth ft (sec/qt) BHA Run #Bit Type TFA Hours Depth in / out Footage WOB RPM Condition Lithology (%): (current) to to to to to to to to to Gas Type abreviations: BG - Background Gas; GP - Gas Peak; CG - Connection Gas; WTG - Wiper Trip Gas; POG - Pumps Off Gas; PG - Produced Gas; RG - Ream Gas; T-- - Trip…; F-- - Formation…; E-- - Early… 24 hr Recap: , Logging Engineer:*10000 units = 100% Gas In AirTom Mansfield/Ryan Massey 1-1-WT-A-E-1-ER-TD Ann Corr Cor Solids lb/100ft2 54,000 24 hr Max YP 1.43 145 48' 2.6 ml/30min Chromatograph (ppm) Avg: 40 avg C2 Avg: 35 Gas Breakdown Type 1 2 DTX619M-D6 24.80 0.942 C4 C5Depthmax Silt Siltst 25 2238' ChtSst Lst 120.00 3865' 16 Sh 15-20 23' 2358' Nabors 9ES $2,655.00 AK-AM-8035432 PVGel PWD Drilling 3600 na Depth 10s/10m/30m cP 2358.00 Size 31 na 20 03/31/2011-04:00 6223' North Slope 0' Brooks Range North Tarn #1 Tarn Current Daily Charges Avg 8.5 0.778 na na R.O.P. (ft/hr) Gas (units)na Max:Ambient Air Pit Room C1 na Gallons/stroke Lime Cl- Whole GvlCoal Tuff HTHP Filt na Min na Avg C3 Clyst % na 13.8 mg/l na AvgMin Max Max 42 2.9620 $79,025.00 58 20 Total Charges: Flow In (spm) SPP (psi) Well Control J. Nicholson/J. West 5145 01:05 pm Flow In (gpm) Current Pump & Flow Data: na Max @ ft md Set EZ drill plug at 5771' with wireline. SICP gradually rose to 1280 psi, SIDPP 0. Prepare to perforate HWDP. All Circ Avg Diam 0 bbls 8.50'' 5145 units then slowly decreased to 4500 units while mud losses varied from 45 to 65 bbls/hr. Pump rate reduced to 42 gpm with corresponding reduction of losses to 30 bbls/hr. Rigged up wireline. Stopped circulating and shut in well. Lost 442 bbls last 24 hrs. Continued circulating at 59 gpm with 32 psi SPP and 170 psi SICP. Gas slowly climbed from 3400 units to a max of Hole Condition On Bot Hrs 6223'24.8 in out 11.70 11.70 Max: Sd Reed Milltooth 6223' Gas (units) H2S Data Sample Line 82 16.70 13/22/26 12.25 Customer:Report #: Well:Date: Area:04:00 Depth Location:Progress 24 hrs: Rig:Rig Activity: Job No.:Report For: ROP & Gas: . Mud Data:Density (ppg)Viscosity Depth ft (sec/qt) BHA Run #Bit Type TFA Hours Depth in / out Footage WOB RPM Condition Lithology (%): (current) to to to to to to to to to Gas Type abreviations: BG - Background Gas; GP - Gas Peak; CG - Connection Gas; WTG - Wiper Trip Gas; POG - Pumps Off Gas; PG - Produced Gas; RG - Ream Gas; T-- - Trip…; F-- - Formation…; E-- - Early… 24 hr Recap: , Logging Engineer:*10000 units = 100% Gas In AirTom Mansfield/Ryan Massey 1-1-WT-A-E-1-ER-TD Ann Corr Cor Solids lb/100ft2 52,000 24 hr Max YP 1.56 145 48' 2.6 ml/30min Chromatograph (ppm) Avg: 40 avg C2 Avg: 35 Gas Breakdown Type 1 2 DTX619M-D6 24.80 0.942 C4 C5Depthmax Silt Siltst 25 2238' ChtSst Lst 120.00 3865' 16 Sh 15-20 23' 2358' Nabors 9ES $2,655.00 AK-AM-8035432 PVGel PWD Drilling na na Depth 10s/10m/30m cP 2358.00 Size 31 na 21 04/01/2011-04:00 6223' North Slope 0' Brooks Range North Tarn #1 Tarn Current Daily Charges Avg 8.5 0.778 na na R.O.P. (ft/hr) Gas (units)na Max:Ambient Air Pit Room C1 na Gallons/stroke Lime Cl- Whole GvlCoal Tuff HTHP Filt na Min na Avg C3 Clyst % na 14.0 mg/l na AvgMin Max Max 42 2.9620 $81,680.00 58 20 Total Charges: Flow In (spm) SPP (psi) Well Control J. Nicholson/J. West 741 21:10 Flow In (gpm) Current Pump & Flow Data: na Max @ ft md well through perfs without returns. Monitored well, waiting on cement with SIDPP 20 psi, SICP 1120 psi. Cleaned pits and brought on LSND mud. SIDPP 0, SICP 1160 at report time. No circulated gas to report as all circulations past 24hr through choke to Tiger Tank. All Circ Avg Diam 0 bbls 8.50'' 5680' TVD). Circulated 11.7 ppg with returns through super choke to Tiger Tank. Pumped 50 bbl LCM pill at 2 bbl/min with SPP of 610 psi increasing to 895 psi when LCM hit perforations. Shut in well with 240 psi SICP. SICP gradually rose to 1380 psi. Cemented Ran in hole with perforation guns. Made 40 shots at 4 shots per foot between 5742' MD and 5752' MD (5670' TVD and Hole Condition On Bot Hrs 6223'24.8 in out 11.70 11.70 Max: Sd Reed Milltooth 6223' Gas (units) H2S Data Sample Line 80 16.70 13/23/28 12.25 Customer:Report #: Well:Date: Area:04:00 Depth Location:Progress 24 hrs: Rig:Rig Activity: Job No.:Report For: ROP & Gas: . Mud Data:Density (ppg)Viscosity Depth ft (sec/qt) BHA Run #Bit Type TFA Hours Depth in / out Footage WOB RPM Condition Lithology (%): (current) to to to to to to to to to Gas Type abreviations: BG - Background Gas; GP - Gas Peak; CG - Connection Gas; WTG - Wiper Trip Gas; POG - Pumps Off Gas; PG - Produced Gas; RG - Ream Gas; T-- - Trip…; F-- - Formation…; E-- - Early… 24 hr Recap: , Logging Engineer:*10000 units = 100% Gas In AirTom Mansfield/Ryan Massey 1-1-WT-A-E-1-ER-TD Ann Corr Cor Solids lb/100ft2 52,000 24 hr Max YP HTHP Filt 1.56 145 48' 2.6 ml/30min Chromatograph (ppm) Tuff Gas Breakdown Avg: 40 avgDepthmax 25 C2 Avg: 35 C4 C5 Type 1 2 DTX619M-D6 24.80 0.942 Sd Silt Siltst 12.25 120.00 3865' 15 Sh 15-20 23' 2358' 2238' Size 31 ClystChtSst 10s/10m/30m cP 2358.00 out 11.70 Nabors 9ES $2,655.00 AK-AM-8035432 PVGel PWD Drilling Current R.O.P. (ft/hr) Gas (units)na na na Depth 22 04/02/2011-04:00 6223' North Slope 0' Brooks Range North Tarn #1 Tarn Daily Charges Avg 8.5 0.778 na nana Max:Ambient Air Pit Room C1 C3 na Gallons/stroke Lime Cl- Whole GvlCoal na Min na Avg % Lst na 14.01 mg/l na AvgMin Max Max 455 2.9620 $84,335.00 84 29 Total Charges: Flow In (spm) SPP (psi) Well Control J. Nicholson/J. West na na Flow In (gpm) Current Pump & Flow Data: na Max @ ft Monitor well waiting on cement with SIDPP of 0 psi, SICP of 1140 psi. Pumped 10 bbls MOBM down drill pipe at 2 bpm md well while waiting on more MOBM. Bring on mud from vac truck and circulate well. At 575 stks SICP dropped rapidly from 870 psi down to 5 psi. Circulation displaced to Tiger Tank, no gas reading available. with annulus shut in. Pump pressure increased to 1300 psi before shut in well with SICP of 1140 psi. Opened choke to gas separator with SIDPP dropping to 20 psi, SICP to 1110 psi. Pumped 25 bbls MOBM down drill pipe at 30 spm and SPP of 700 psi. Monitor All Circ in Avg Diam 0 bbls 8.50'' Max: Hole Condition On Bot Hrs 6223'24.8 11.70 Reed Milltooth 6223' Gas (units) H2S Data Sample Line 80 16.70 13/24/29 Customer:Report #: Well:Date: Area:04:00 Depth Location:Progress 24 hrs: Rig:Rig Activity: Job No.:Report For: ROP & Gas: . Mud Data:Density (ppg)Viscosity Depth ft (sec/qt) BHA Run #Bit Type TFA Hours Depth in / out Footage WOB RPM Condition Lithology (%): (current) to to to to to to to to to Gas Type abreviations: BG - Background Gas; GP - Gas Peak; CG - Connection Gas; WTG - Wiper Trip Gas; POG - Pumps Off Gas; PG - Produced Gas; RG - Ream Gas; T-- - Trip…; F-- - Formation…; E-- - Early… 24 hr Recap: , Logging Engineer:*10000 units = 100% Gas In Air Gas (units) H2S Data Sample Line 80 16.70 13/24/29 Hole Condition On Bot Hrs 6223'24.8 11.70 Reed Milltooth 6223' SPP gradually increased to 470 psi and stabilized. After bottoms up with no returns, shut in well. Pumped 5 bbls down annulus without returns. Shut in well, 0 SICP, 0 SIDPP. Opened rams and attempted to move pipe with 100K overpull, no movement. Shut Avg Diam 0 bbls 8.50'' Max: All Circ in Max @ ft Cirulated well with returns lined up through mud gas separator to Tiger Tank (no gas readings). SICP dropped to 0 psi, md in well. Rigged up Halliburton cementers and performed cement job. Wait on cement. SPP (psi) Wait on Cement J. Nicholson/J. West na na Flow In (gpm) Current Pump & Flow Data: na Min Max Max 455 2.9620 $86,990.00 84 29 Total Charges: Flow In (spm) GvlCoal Left on Fish Lst na 14.01 mg/l na Avgna Gallons/stroke Lime Cl- Whole na Min na Avg % Max:Ambient Air Pit Room C1 C3 Gel na nana Depth Brooks Range North Tarn #1 Tarn na Nabors 9ES $2,655.00 AK-AM-8035432 PV 23 04/03/2011-04:00 6223' North Slope 0' Daily Charges Avg 8.5 0.778 Sh 15-20 PWD Drilling Current R.O.P. (ft/hr) Gas (units)na na out 120.00 Size 31 ClystChtSst 11.70 3865' 15 23' 2358' 2238' 10s/10m/30m cP 2358.001 2 DTX619M-D6 24.80 0.942 Sd Silt Avg: TuffSiltst 12.25 C4 C5 25 TypeDepthmaxC2 35 Gas Breakdown Avg: 40 avg Chromatograph (ppm) HTHP Filt 1.56 145 48' 2.6 ml/30min Tom Mansfield/Ryan Massey 1-1-WT-A-E-1-ER-TD Ann Corr Cor Solids lb/100ft2 52,000 24 hr Max YP Customer:Report #: Well:Date: Area:04:00 Depth Location:Progress 24 hrs: Rig:Rig Activity: Job No.:Report For: ROP & Gas: . Mud Data:Density (ppg)Viscosity Depth ft (sec/qt) BHA Run #Bit Type TFA Hours Depth in / out Footage WOB RPM Condition Lithology (%): (current) to to to to to to to to to Gas Type abreviations: BG - Background Gas; GP - Gas Peak; CG - Connection Gas; WTG - Wiper Trip Gas; POG - Pumps Off Gas; PG - Produced Gas; RG - Ream Gas; T-- - Trip…; F-- - Formation…; E-- - Early… 24 hr Recap: , Logging Engineer:*10000 units = 100% Gas In AirTom Mansfield/Ryan Massey 1-1-WT-A-E-1-ER-TD Ann Corr Solids lb/100ft2 3,000 24 hr Max YP MBT 7.00 145 48' 0.0 (ppb Eq) 40 avg 35 Gas Breakdown Avg: TypeDepthmaxC2 Siltst 12.25 C4 C5 25 Avg: Tuff 1 2 DTX619M-D6 24.80 0.942 Sd Silt 2238' 3865'8.5 0.778 10s/10m/30m cP 2358.00 out 120.00 Size 12 2358' 19 Sh 15-20 PWD Drilling na naAll Circ Clyst 23' 24 04/04/2011-04:00 6223' North Slope 0' Daily Charges Gas (units)na na Depth Current R.O.P. (ft/hr) Avg Brooks Range North Tarn #1 Tarn na Nabors 9ES $3,937.00 AK-AM-8035432 PVGel na nana Max:Ambient Air Pit Room C1 C3 Chromatograph (ppm) Gallons/stroke API Filt Chlorides Min na Avg % GvlCoal ml/30min mg/l na AvgMin Max 84 29 Total Charges: Flow In (spm) SPP (psi) Max 455 2.9620 $90,927.00 na Attempt Back Off J. Nicholson/J. West na na Flow In (gpm) Current Pump & Flow Data: na Max @ ft md hand torque. Confirmed shot fired. Working pipe with top drive to back off without success. Reed Milltooth 6223' Gas (units) H2S Data Waited on cement. Monitored well with SIDPP of 60 psi decreasing to 20 psi and SICP of 30 psi. Switched mud system Left on Fish Lst 9 Mark Lindloff changing out for Tom Mansfield back to LSND. Rigged up and ran temperature log to find top of cement a 5125'. Bled SICP down from 30 psi to 0 psi. Opened rams and filled hole with 5 bbls. Ran in hole with string shot to back off drill pipe above cement at 4365'. Fired string shot with 14K left Max: Hole Condition On Bot Hrs 6223'24.8 in 11.70 Sample Line 42 16.70 7/8/9 Avg Diam 0 bbls 8.50'' ChtSst 11.00 Customer:Report #: Well:Date: Area:04:00 Depth Location:Progress 24 hrs: Rig:Rig Activity: Job No.:Report For: ROP & Gas: . Mud Data:Density (ppg)Viscosity Depth ft (sec/qt) BHA Run #Bit Type TFA Hours Depth in / out Footage WOB RPM Condition Lithology (%): (current) to to to to to to to to to Gas Type abreviations: BG - Background Gas; GP - Gas Peak; CG - Connection Gas; WTG - Wiper Trip Gas; POG - Pumps Off Gas; PG - Produced Gas; RG - Ream Gas; T-- - Trip…; F-- - Formation…; E-- - Early… 24 hr Recap: , Logging Engineer:*10000 units = 100% Gas In Air ChtSst 11.00 8.5 0.778 2358' 0 bbls 8.50'' Max: Hole Condition On Bot Hrs 6223'24.8 Sample Line with no surface indication. POOH to 200' and release torque from drill string. Work drill string up on stages to 400k up and 75k down. Make up HES Perf Gun, 10'-4 shots per foot. Total 40 shots. RIH with HES Perf Gun to 4980' to 4990'. Fire String Shoot. POOH. in 11.00 Reed Milltooth 6223' Gas (units) H2S Data Torque Drill String to 30K ft/lb and work string. Make up and RIH with String Shoot Assy #2 to 4269'. Shoot string shoot md Make Up to circulate. Pump 3 bbls LVT and pressure up to 2000 psi. Bled off and wait for more Perf Guns. Make up and RIH with HES Perf Gun to 4850' to 4860'. No circulation. Wait on Guns. Make up and RIH w/guns to 4800' at report time. Attempt Back Off J. Nicholson/J. West na na Flow In (gpm) Current Pump & Flow Data: na Max @ ft 717 2.9620 $93,582.00 Gallons/stroke 68 23 Total Charges: Flow In (spm) SPP (psi) Lst na 9 ml/30min mg/l na AvgMin Max Max Chlorides Min na Avg % GvlCoal 23' Left on Fish Max:Ambient Air Pit Room C1 C3 na Nabors 9ES $2,655.00 AK-AM-8035432 PVGel na na Gas (units)na na Depth Brooks Range North Tarn #1 Tarn na Avg Diam Current R.O.P. (ft/hr) 25 04/05/2011-04:00 6223' North Slope 0' Daily Charges Avg 20 Sh 15-20 PWD Drilling na naAll Circ Clyst 10s/10m/30m cP 2358.00 out 120.00 Size 12 12.25 43 16.70 7/8/9 2238' 3865' 1 2 DTX619M-D6 24.80 0.942 Sd Silt Siltst Tuff C4 C5 Type 25 Avg: Depth max C2 35 Gas Breakdown Avg: 40 avg Chromatograph (ppm) MBT 7.00 145 48' 0.0 (ppb Eq) API Filt Mark Lindloff/Ryan Massey 1-1-WT-A-E-1-ER-TD Ann Corr Solids lb/100ft2 3,000 24 hr Max YP Customer:Report #: Well:Date: Area:04:00 Depth Location:Progress 24 hrs: Rig:Rig Activity: Job No.:Report For: ROP & Gas: . Mud Data:Density (ppg)Viscosity Depth ft (sec/qt) BHA Run #Bit Type TFA Hours Depth in / out Footage WOB RPM Condition Lithology (%): (current) to to to to to to to to to Gas Type abreviations: BG - Background Gas; GP - Gas Peak; CG - Connection Gas; WTG - Wiper Trip Gas; POG - Pumps Off Gas; PG - Produced Gas; RG - Ream Gas; T-- - Trip…; F-- - Formation…; E-- - Early… 24 hr Recap: , Logging Engineer:*10000 units = 100% Gas In Air ChtSst 11.00 8.5 0.778 2358' 0 bbls 8.50'' Max: Hole Condition On Bot Hrs 6223'24.8 Sample Line 740 psi, no Circ. RIH W/ Perf Gun F/4630' to 4640' 6 shoot per foot. Fire Perf Gun and POOH. Attempt to Circ. 1 bpm 760 psi, no Circ. RIH W/ Perf Gun F/ 4530' to 4540' 6 shoot per foot. Fire Perf Gun and POOH. Attempt to Circ. 1 bpm 557 psi, no Circ. RIH Per Gun 6 in 11.00 Reed Milltooth 6223' Gas (units) H2S Data Cont. RIH W/ Perf Gun F/ 4730' to 4740'. 6 shoots per foot 10'. Fire Perf Gun and POOH. Attempt to Circ. @ 1 bpm md shoot F/ 4410' to 4420' and POOH. Attempt to Circ. 1 bpm, no Circ. R/D HES Wireline Equip. R/U Schlumberger Wireline and RIH W/ Free Point tool, finding free point. Attempt Back Off J. Nicholson/J. West na na Flow In (gpm) Current Pump & Flow Data: na Max @ ft 0 2.9620 $96,273.00 Gallons/stroke 0 0 Total Charges: Flow In (spm) SPP (psi) Lst na 9 ml/30min mg/l na AvgMin Max Max Chlorides Min na Avg % GvlCoal 23' Left on Fish Max:Ambient Air Pit Room C1 C3 na Nabors 9ES $2,655.00 AK-AM-8035432 PVGel na na Gas (units)na na Depth Brooks Range North Tarn #1 Tarn na Avg Diam Current R.O.P. (ft/hr) 26 04/06/2011-04:00 6223' North Slope 0' Daily Charges Avg 20 Sh 15-20 PWD Drilling na naAll Circ Clyst 10s/10m/30m cP 2358.00 out 120.00 Size 12 12.25 43 16.70 7/8/9 2238' 3865' 1 2 DTX619M-D6 24.80 0.942 Sd Silt Siltst Tuff C4 C5 Type 25 Avg: Depth max C2 35 Gas Breakdown Avg: 40 avg Chromatograph (ppm) MBT 7.00 145 48' 0.0 (ppb Eq) API Filt Mark Lindloff/Ryan Massey 1-1-WT-A-E-1-ER-TD Ann Corr Solids lb/100ft2 3,000 24 hr Max YP Customer:Report #: Well:Date: Area:04:00 Depth Location:Progress 24 hrs: Rig:Rig Activity: Job No.:Report For: ROP & Gas: . Mud Data:Density (ppg)Viscosity Depth ft (sec/qt) BHA Run #Bit Type TFA Hours Depth in / out Footage WOB RPM Condition Lithology (%): (current) to to to to to to to to to Gas Type abreviations: BG - Background Gas; GP - Gas Peak; CG - Connection Gas; WTG - Wiper Trip Gas; POG - Pumps Off Gas; PG - Produced Gas; RG - Ream Gas; T-- - Trip…; F-- - Formation…; E-- - Early… 24 hr Recap: , Logging Engineer:*10000 units = 100% Gas In AirMark Lindloff/Ryan Massey 1-1-WT-A-E-1-ER-TD Ann Corr Solids lb/100ft2 1,800 24 hr Max 1451 YP MBT 7.00 145 48' 0.0 (ppb Eq) API Filt avg 5018 987628 2693 19567 Chromatograph (ppm) 35 GP Gas Breakdown 8:00 Avg: 40 587 GP Type 1830 GP Time max C2 159055 9:00 10000 Tuff 5995 7058 92239 1389 C4 C5 8637 25 Avg: 21653 56348 532666 DTX619M-D6 24.80 0.942 Sd Silt Siltst 10000 1926 964283 46839 804737 17927 GP 2238' 3865' 11:30 15:30 18:00 23:3019:30 14:00 cP 2358.00 out 120.00 Size 11 12.25 23 Sh 15-20 PWD Drilling na naAll Circ Clyst 10s/10m/30m 27 04/07/2011-04:00 6223' North Slope 0' Daily Charges Gas (units)na 901 Depth Current R.O.P. (ft/hr) Avg Brooks Range North Tarn #1 Tarn na Nabors 9ES $2,655.00 AK-AM-8035432 PVGel na nana Max:Ambient Air Pit Room 109346 C1 36809 9747 C3 Chlorides Min na Avg % GvlCoal 23' Left on Fish Lst na 9 ml/30min mg/l na AvgMin Max Max 133 45 Total Charges: Flow In (spm) SPP (psi)129 2.9620 $98,892.00 Gallons/stroke RIH to Sever Tool J. Nicholson/J. West 10000 Cir Flow In (gpm) Current Pump & Flow Data: na Max @ ft md Open up well and pull 225K to 400K, 3 left hand wraps 10K. No go. Well static. M/U 2nd Sever Tool, RIH to 3089' attempt to pull free 450 K over pull, no go. Waiting on tool. 913 in 11.00 10000 Reed Milltooth 6223' Gas (units) H2S Data 1 2 Tool Joint. POOH, work D.P. String 75K to 400K over pull, TRQ string to 20K and work string. Broke Circ. Stage pump rate up to 4 bpm @ 185 psi. Shut well in initial SICP 50 psi building to 190 psi. Displace OBM to 11.0 ppg LSND through Choke and Gas Buster. RIH W/ Free Point Tool, Stuck @ 3700', 70-80% free @ 3600' to Shoe. R/D Wireline. R/U Sever Tool RIH to 3474' cut @ Avg Diam 0 bbls 8.50'' Max: Hole Condition On Bot Hrs 6223'24.8 Sample Line 43 16.70 7/8/9 ChtSst 11.00 8.5 0.778 2358' Customer:Report #: Well:Date: Area:04:00 Depth Location:Progress 24 hrs: Rig:Rig Activity: Job No.:Report For: ROP & Gas: . Mud Data:Density (ppg)Viscosity Depth ft (sec/qt) BHA Run #Bit Type TFA Hours Depth in / out Footage WOB RPM Condition Lithology (%): (current) to to to to to Gas Type abreviations: BG - Background Gas; GP - Gas Peak; CG - Connection Gas; WTG - Wiper Trip Gas; POG - Pumps Off Gas; PG - Produced Gas; RG - Ream Gas; T-- - Trip…; F-- - Formation…; E-- - Early… 24 hr Recap: , Logging Engineer:*10000 units = 100% Gas In Air ChtSst 11.00 8.5 0.778 2358' 0 bbls 8.50'' Max: Hole Condition On Bot Hrs 6223'24.8 Sample Line D.S. stage up to 450K over pull, TRQ to 26K and Pump 600 gpm, no go. Circ.and work on new Sever Tool. RIH W/ Sever Tool to 2547' pull free. Circ. and R/U Cementers. Pump cement. CIP @ 19:20. POOH 5 stands and Circ.out of balance. Cont. POOH. in 11.00 5462 Reed Milltooth 6223' Gas (units) H2S Data RIH W/ Sever Tool to 2829' and fire tool. POOH L/D Tool. Work on Top Drive Grabber Box. P/U single and try to work md POOH W/Drill Pipe J. Nicholson/J. West 10000 Cir Flow In (gpm) Current Pump & Flow Data: na Max @ ft 0 2.9620 $101,547.00 Gallons/stroke 0 0 Total Charges: Flow In (spm) SPP (psi) Lst na 9 ml/30min mg/l na AvgMin Max Max Chlorides Min na Avg % GvlCoal 23' Left on Fish Max:Ambient Air Pit Room 26693 C1 10459 3896 C3 na Nabors 9ES $2,655.00 AK-AM-8035432 PVGel na na Gas (units)na 901 Depth Brooks Range North Tarn #1 Tarn na Avg Diam Current R.O.P. (ft/hr) 28 04/08/2011-04:00 6223' North Slope 0' Daily Charges Avg 23 Sh 15-20 PWD Drilling na naAll Circ Clyst 10s/10m/30m cP 2358.00 out 120.00 Size 14 12.25 54 16.70 8/12/14 2238' 3865' 10:30 21:30 23:30 14:30 412 173 20027 1 2 DTX619M-D6 24.80 0.942 Sd Silt Siltst Tuff 1477 14131 C4 C5 2706 GP Type 1032 GP 25 Avg: 3595 Time max C2 39596 9:30 10000 855979 35 GP Gas Breakdown 6:30 Avg: 40 1374 avg 853 496771 1197 4888 Chromatograph (ppm) MBT 6.40 145 48' 0.0 (ppb Eq) API Filt Mark Lindloff/Ryan Massey 1-1-WT-A-E-1-ER-TD Ann Corr Solids lb/100ft2 600 24 hr Max 202 YP Customer:Report #: Well:Date: Area:04:00 Depth Location:Progress 24 hrs: Rig:Rig Activity: Job No.:Report For: ROP & Gas: . Mud Data:Density (ppg)Viscosity Depth ft (sec/qt) BHA Run #Bit Type TFA Hours Depth in / out Footage WOB RPM Condition Lithology (%): (current) to to to to to Gas Type abreviations: BG - Background Gas; GP - Gas Peak; CG - Connection Gas; WTG - Wiper Trip Gas; POG - Pumps Off Gas; PG - Produced Gas; RG - Ream Gas; T-- - Trip…; F-- - Formation…; E-- - Early… 24 hr Recap: , Logging Engineer:*10000 units = 100% Gas In AirMark Lindloff/Ryan Massey 1-1-WT-A-E-1-ER-TD Ann Corr Solids lb/100ft2 600 24 hr Max YP MBT 7.30 145 48' 0.0 (ppb Eq) API Filt avg Chromatograph (ppm) 35 Gas Breakdown Avg: 40 TypeTimemaxC2 Tuff C4 C5 25 Avg: DTX619M-D6 24.80 0.942 Sd Silt Siltst 6223' 2238' 3865' cP 2358.00 out 120.00 Size 14 12.25 22 Sh 15-20 PWD Drilling na naAll Circ Clyst 10s/10m/30m 29 04/09/2011-04:00 6223' North Slope 0' Daily Charges Gas (units)na na Depth Current R.O.P. (ft/hr) Avg Brooks Range North Tarn #1 Tarn na Nabors 9ES $2,655.00 AK-AM-8035432 PVGel na nana Max:Ambient Air Pit Room C1 C3 Chlorides Min na Avg % GvlCoal 23' Left on Fish Lst na 9 ml/30min mg/l na AvgMin Max Max 0 0 Total Charges: Flow In (spm) SPP (psi)0 2.9620 $104,202.00 Gallons/stroke POOH W/Drill Pipe J. Nicholson/J. West na na Flow In (gpm) Current Pump & Flow Data: na Max @ ft md in 11.00 Reed Milltooth 6223' Gas (units) H2S Data 1 2 R/D Wieline and tools. Cut and Slip drilling Line. Service rig. Pump dry Job and trip out of hole. R/U and testing BOP's. Avg Diam 0 bbls 8.50'' Max: Hole Condition On Bot Hrs 6223'24.8 Sample Line 56 16.70 9/12/14 ChtSst 11.00 8.5 0.778 2358' Customer:Report #: Well:Date: Area:04:00 Depth Location:Progress 24 hrs: Rig:Rig Activity: Job No.:Report For: ROP & Gas: . Mud Data:Density (ppg)Viscosity Depth ft (sec/qt) BHA Run #Bit Type TFA Hours Depth in / out Footage WOB RPM Condition Lithology (%): (current) to to to to to Gas Type abreviations: BG - Background Gas; GP - Gas Peak; CG - Connection Gas; WTG - Wiper Trip Gas; POG - Pumps Off Gas; PG - Produced Gas; RG - Ream Gas; T-- - Trip…; F-- - Formation…; E-- - Early… 24 hr Recap: , Logging Engineer:*10000 units = 100% Gas In Air ChtSst 9.60 8.5 0.778 2358' 8.50'' Max: Hole Condition On Bot Hrs Sample Line condition mud. Pump Dry Job and POOH L/D 5" D.P. P/U 5" D.P. and stand back in Derrick. Currently RIH to drill out cement. in 9.60 Reed Milltooth 2097' Gas (units) H2S Data Change out IBOP air valve and test. RIH 8.5" Bit & 5" D.P. to 1823', wash down to 2097' and tag cement. Circ. and md RIH w/5" DP J. Nicholson/J. West na na Flow In (gpm) Current Pump & Flow Data: na Max @ ft 0 2.9620 $106,857.00 Gallons/stroke 0 0 Total Charges: Flow In (spm) SPP (psi) Lst na 6 ml/30min mg/l na AvgMin Max Max Chlorides Min na Avg % GvlCoal 23' Left on Fish Max:Ambient Air Pit Room C1 C3 na Nabors 9ES $2,655.00 AK-AM-8035432 PVGel na na Gas (units)na na Depth Brooks Range North Tarn #1 Tarn na Avg Diam Current R.O.P. (ft/hr) 30 04/10/2011-04:00 2347' North Slope 0' Daily Charges Avg 19 Sh 15-20 PWD Drilling na naAll Circ Clyst 10s/10m/30m cP 2358.00 out 120.00 Size 7 12.25 45 16.70 7/9/9 6223' 2238' 3865' 1 2 DTX619M-D6 24.80 0.942 Sd Silt Siltst Tuff C4 C5 Type Avg: Time max C2 Gas Breakdown Avg: avg Chromatograph (ppm) MBT 7.00 145 48' 0.0 (ppb Eq) API Filt Mark Lindloff/Ryan Massey 1-1-WT-A-E-1-ER-TD Ann Corr Solids lb/100ft2 500 24 hr Max YP Customer:Report #: Well:Date: Area:04:00 Depth Location:Progress 24 hrs: Rig:Rig Activity: Job No.:Report For: ROP & Gas: . Mud Data:Density (ppg)Viscosity Depth ft (sec/qt) BHA Run #Bit Type TFA Hours Depth in / out Footage WOB RPM Condition Lithology (%): (current) to to to to to Gas Type abreviations: BG - Background Gas; GP - Gas Peak; CG - Connection Gas; WTG - Wiper Trip Gas; POG - Pumps Off Gas; PG - Produced Gas; RG - Ream Gas; T-- - Trip…; F-- - Formation…; E-- - Early… 24 hr Recap: , Logging Engineer:*10000 units = 100% Gas In AirMark Lindloff/Ryan Massey Charges for sample catchers start today Left on Fish Ann Corr Solids lb/100ft2 2,700 24 hr Max YP MBT 5.90 0 145 0.0 (ppb Eq) API Filt avg Chromatograph (ppm) Gas Breakdown Avg: TypeTimemaxC2 Tuff C4 C5 Avg: DTX619M-D6 0.00 0.778 Sd Silt Siltst 0' 3865' 0' cP 6223' out 2358' Size 8 8.5 20 Sh 0 PWD Drilling na naAll Circ Clyst 10s/10m/30m 31 04/11/2011-04:00 2317' North Slope 0' Daily Charges Gas (units)na na Depth Current R.O.P. (ft/hr) Avg Brooks Range North Tarn #1 Tarn na Nabors 9ES $3,425.00 AK-AM-8035432 PVGel na nana Max:Ambient Air Pit Room C1 C3 Chlorides Min na Avg % GvlCoal 15-20 0 Lst na 6 ml/30min mg/l na AvgMin Max Max 0 0 Total Charges: Flow In (spm) SPP (psi)0 2.9620 $110,282.00 Gallons/stroke Test BOP's J. Nicholson/J. West na na Flow In (gpm) Current Pump & Flow Data: na Max @ ft md in 9.60 DTX619M-D6 2317' Gas (units) H2S Data 2 3 Drill out Cement F/ 2097' to 2317'. Pump Dry Job and POOH. Service Rig and R/U to test BOP. Currently testing BOP's Avg Diam 8.50'' Max: Hole Condition On Bot Hrs Sample Line 45 24.80 7/9/11 ChtSst 9.60 8.5 0.778 0' Customer:Report #: Well:Date: Area:04:00 Depth Location:Progress 24 hrs: Rig:Rig Activity: Job No.:Report For: ROP & Gas: . Mud Data:Density (ppg)Viscosity Depth ft (sec/qt) BHA Run #Bit Type TFA Hours Depth in / out Footage WOB RPM Condition Lithology (%): (current) to to to to to Gas Type abreviations: BG - Background Gas; GP - Gas Peak; CG - Connection Gas; WTG - Wiper Trip Gas; POG - Pumps Off Gas; PG - Produced Gas; RG - Ream Gas; T-- - Trip…; F-- - Formation…; E-- - Early… 24 hr Recap: , Logging Engineer:*10000 units = 100% Gas In Air ChtSst 9.60 8.5 0.778 2317' 15 bbls 8.50'' Max: Hole Condition On Bot Hrs 3603'7.5 Sample Line track. Drill to 3,050' MD/TVD. Gas remaing steady throughout the day. Lithology gragually getting firmer and silty. in 9.60 DTX619M-D6 2317' Gas (units) H2S Data Continue to test BOP'S, M/U 8 1/2" BHA, RIH, Stand by for go ahead from town, Drill out cement and shoe md Drilling J. Nicholson/J. West 443 2358 Flow In (gpm) Current Pump & Flow Data: na Max @ ft 1529 2.9620 $113,707.00 Gallons/stroke 488 167 Total Charges: Flow In (spm) SPP (psi) Lst na 5 ml/30min mg/l na AvgMin Max Max Chlorides Min na Avg % GvlCoal 15-20 0 Max:Ambient Air Pit Room C1 C3 2489' Nabors 9ES $3,425.00 AK-AM-8035432 PVGel 205.0 454.0 Gas (units)32 26 Depth Brooks Range North Tarn #1A Tarn 194.0 Avg Diam Current R.O.P. (ft/hr) 32 04/12/2011-04:00 3603' North Slope 1245' Daily Charges Avg 18 Sh 0 PWD Drilling na naAll Circ Clyst 10s/10m/30m cP 6223' out 2358' Size 8 8.5 43 24.80 6/7/10 0' 3865' 0' 2 3 DTX619M-D6 0.00 0.778 Sd Silt Siltst Tuff C4 C5 Type 45 55 Avg: Time max C2 Gas Breakdown Avg: avg Chromatograph (ppm) MBT 5.80 0 145 0.3 (ppb Eq) API Filt Mark Lindloff/Ryan Massey Left on Fish Ann Corr Solids lb/100ft2 4,400 24 hr Max YP Customer:Report #: Well:Date: Area:04:00 Depth Location:Progress 24 hrs: Rig:Rig Activity: Job No.:Report For: ROP & Gas: . Mud Data:Density (ppg)Viscosity Depth ft (sec/qt) BHA Run #Bit Type TFA Hours Depth in / out Footage WOB RPM Condition Lithology (%): (current) to to to to to to to to to Gas Type abreviations: BG - Background Gas; GP - Gas Peak; CG - Connection Gas; WTG - Wiper Trip Gas; POG - Pumps Off Gas; PG - Produced Gas; RG - Ream Gas; T-- - Trip…; F-- - Formation…; E-- - Early… 24 hr Recap: , Logging Engineer:*10000 units = 100% Gas In Air ChtSst 9.60 8.5 0.778 2317' 15 bbls 8.50'' Max: Hole Condition On Bot Hrs 3987'10.5 Sample Line 3,794' MD, heavy pulls. Back ream from 3,794' to 3,315' MD. Lost fluid while backreaming at 3,700'. POOH to cleanout BHA. Lots of shales/clays seen over shakers. P/U BHA & RIH. CBU at shoe TG 1880 Units, Continue to RIH to 3650' MD, CBU, TG 1962 Units. in 9.60 DTX619M-D6 3794' Gas (units) H2S Data Cont drilling ahead f/3603' MD. Began losing fluid 3,698' MD. Shut down & check static losses. Well breathing. Drill to md Gas while drilling remains steady between 40-55 units. Samples increasing in claystone content, amorph-blky, sft, stky, hydrated.. Drilling J. Nicholson/J. West 1962 CBU Flow In (gpm) Current Pump & Flow Data: na Max @ ft 1429 2.9620 $117,132.00 Gallons/stroke 448 151 Total Charges: Flow In (spm) SPP (psi) Lst na 8 ml/30min mg/l na AvgMin Max Max Chlorides Min na Avg % GvlCoal 15-20 0 Max:Ambient Air Pit Room C1 C3 3651' Nabors 9ES $3,425.00 AK-AM-8035432 PVGel 145.0 322.0 Gas (units)32 30 Depth Brooks Range North Tarn #1A Tarn 110.0 Avg Diam Current R.O.P. (ft/hr) 33 04/13/2011-04:00 3987' North Slope 384' Daily Charges Avg 23 Sh 0 PWD Drilling na naAll Circ Clyst 10s/10m/30m cP 6223' out 2358' Size 9 8.5 48 24.80 8/11/14 0' 3865' 0' 2 3 DTX619M-D6 0.00 0.778 Sd Silt Siltst Tuff 41 C4 C5 Type BG 20 80 Avg: Depth max C2 61 3907.00 140 4729 Gas Breakdown 3603.00 Avg: 46 avg 0 7 Chromatograph (ppm) MBT 8.20 0 145 6.0 (ppb Eq) API Filt Mark Lindloff/Ryan Massey Left on Fish Ann Corr Solids lb/100ft2 3,800 24 hr Max YP Customer:Report #: Well:Date: Area:04:00 Depth Location:Progress 24 hrs: Rig:Rig Activity: Job No.:Report For: ROP & Gas: . Mud Data:Density (ppg)Viscosity Depth ft (sec/qt) BHA Run #Bit Type TFA Hours Depth in / out Footage WOB RPM Condition Lithology (%): (current) to to to to to to to to Gas Type abreviations: BG - Background Gas; GP - Gas Peak; CG - Connection Gas; WTG - Wiper Trip Gas; POG - Pumps Off Gas; PG - Produced Gas; RG - Ream Gas; T-- - Trip…; F-- - Formation…; E-- - Early… 24 hr Recap: , Logging Engineer:*10000 units = 100% Gas In AirMark Lindloff/Ryan Massey Left on Fish Ann Corr Solids lb/100ft2 2,000 24 hr Max 143 YP MBT 7.40 0 145 10.0 (ppb Eq) API Filt avg 105 10229 318 861 Chromatograph (ppm) BG Gas Breakdown 4517.00 Avg: 428 GP Type 16 GP Depth max C2 3110 4556.00 457 Tuff 507 1789 C4 C5 20 80 Avg: 928 1490 39862 DTX619M-D6 0.00 0.778 Sd Silt Siltst 660 122 25159 0' 3865' 0' 4879.00 5000.00 5052.00 4895.00 cP 6223' out 2358' Size 10 8.5 14 Sh 0 PWD Drilling na naAll Circ Clyst 10s/10m/30m 34 04/14/2011-04:00 5487' North Slope 1500' Daily Charges Gas (units)144 98 Depth Current R.O.P. (ft/hr) Avg Brooks Range North Tarn #1A Tarn 4754' Nabors 9ES $3,425.00 AK-AM-8035432 PVGel 156.0 355.0194.0 Max:Ambient Air Pit Room 509 C1 374 235 C3 Chlorides Min na Avg % GvlCoal 15-20 0 Lst na 6 ml/30min mg/l na AvgMin Max Max 450 153 Total Charges: Flow In (spm) SPP (psi)1636 2.9620 $120,557.00 Gallons/stroke Drilling J. Nicholson/J. West 446 CBU Flow In (gpm) Current Pump & Flow Data: na Max @ ft md shows in the North Tarn formation. Continue drilling ahead at normal ROP's to 5427' md. Between 5120-5180' md, shales were really gassy. Gas bubbles coming from the laminations and when broken open a lot of gas bubbled out. LCM contaminated samples throughout the night. Gas from 4944' to 5400' Max Gas 352 units Average gas 81 Units. in 9.60 107 DTX619M-D6 4944' Gas (units) H2S Data 2 3 Average Gas 106 Units. Circulate & cond hole, 1x btms up. Back ream f/4,848' MD to 3,890' MD, Cir btms up. Max Gas 168 units. . RIH, reaming/washing to 4,944' MD. TG 315 Units. Cont drilling ahead f/4950 t/5030' MD at 40 ft/hr to catch 5 ft samples, no Cont drilling f/3987' MD to 4,465' MD. Cir a bottoms up. Continue drilling ahead to 4,944' MD, Max Gas 446 units, Avg Diam 15 bbls 8.50'' Max: Hole Condition On Bot Hrs 5487'23.6 Sample Line 40 24.80 9/12/14 ChtSst 9.60 8.5 0.778 2317' Customer:Report #: Well:Date: Area:04:00 Depth Location:Progress 24 hrs: Rig:Rig Activity: Job No.:Report For: ROP & Gas: . Mud Data:Density (ppg)Viscosity Depth ft (sec/qt) BHA Run #Bit Type TFA Hours Depth in / out Footage WOB RPM Condition Lithology (%): (current) to to to to to to to to Gas Type abreviations: BG - Background Gas; GP - Gas Peak; CG - Connection Gas; WTG - Wiper Trip Gas; POG - Pumps Off Gas; PG - Produced Gas; RG - Ream Gas; T-- - Trip…; F-- - Formation…; E-- - Early… 24 hr Recap: , Logging Engineer:*10000 units = 100% Gas In Air ChtSst 9.60 8.5 0.778 2317' 17 bbls 8.50'' Max: Hole Condition On Bot Hrs 6070'26.9 Sample Line units through the interval. Pump pill at 5,902' MD. Circ & condition hole. Upon entering HRZ gas increased to a Max gas of 2271 units with Average being 597 units. Drill to 6,070' MD (6,046' TVD) TD. Backream from 6,070' MD to 5,710' MD.. in 9.60 1010 DTX619M-D6 4944' Gas (units) H2S Data Cont to drill to 5,907' MD. Gas increased through the Moraine Sst.to a max gas of 874 units Average gas 232 md No losses seen. Cont to backream f/5,710' MD to 3,890'. Circ & condition hole. Pump dry job. POH to 1,496' MD. Pump 2nd dry job. L/D DP to 197' MD. Samples increasingly shalier and firming up once into HRZ.. L/D BHA J. Nicholson/J. West 2271 CBU Flow In (gpm) Current Pump & Flow Data: na Max @ ft 0 2.9620 $123,982.00 Gallons/stroke 0 0 Total Charges: Flow In (spm) SPP (psi) Lst na 6 ml/30min mg/l na AvgMin Max Max Chlorides Min na Avg % GvlCoal 15-20 TD 8 1/2" Sec Max:Ambient Air Pit Room 4809 C1 1516 455 C3 4754' Nabors 9ES $3,425.00 AK-AM-8035432 PVGel 177.0 350.0 Gas (units)0 242 Depth Brooks Range North Tarn #1A Tarn 0.0 Avg Diam Current R.O.P. (ft/hr) 35 04/15/2011-04:00 6070' North Slope 583' Daily Charges Avg 17 Sh 14 PWD Drilling na naAll Circ Clyst 10s/10m/30m cP 6223' out 2358' Size 11 8.5 44 24.80 6/9/11 6070' 3865' 3753' 5707.00 5874.00 6020.00 5860.00 2271 597 218220 2 3 DTX619M-D6 26.90 0.778 Sd Silt Siltst Tuff 1009 1282 C4 C5 3350 GP Type 102 GP 10 55 Avg: 10167 Depth max C2 3561 5620.00 999 93148 GP Gas Breakdown 5471.00 Avg: 35 320 avg 385 94384 232 571 Chromatograph (ppm) MBT 4.10 202 145 11.3 (ppb Eq) API Filt Mark Lindloff/Ryan Massey Left on Fish Ann Corr Solids lb/100ft2 1,800 24 hr Max 227 YP Customer:Report #: Well:Date: Area:04:00 Depth Location:Progress 24 hrs: Rig:Rig Activity: Job No.:Report For: ROP & Gas: . Mud Data:Density (ppg)Viscosity Depth ft (sec/qt) BHA Run #Bit Type TFA Hours Depth in / out Footage WOB RPM Condition Lithology (%): (current) to to to to to to Gas Type abreviations: BG - Background Gas; GP - Gas Peak; CG - Connection Gas; WTG - Wiper Trip Gas; POG - Pumps Off Gas; PG - Produced Gas; RG - Ream Gas; T-- - Trip…; F-- - Formation…; E-- - Early… 24 hr Recap: , Logging Engineer:*10000 units = 100% Gas In AirMark Lindloff/Ryan Massey Left on Fish Ann Corr Solids lb/100ft2 1,600 24 hr Max YP MBT 4.20 202 145 11.3 (ppb Eq) API Filt avg Chromatograph (ppm) Gas Breakdown Avg: 35 TypeDepthmaxC2 Tuff C4 C5 10 55 Avg: DTX619M-D6 26.90 0.778 Sd Silt Siltst 6070' 3865' 3753' cP 6223' out 2358' Size 9 8.5 16 Sh 14 PWD Drilling na naAll Circ Clyst 10s/10m/30m 36 04/16/2011-04:00 6070' North Slope 0' Daily Charges Gas (units)0 44 Depth Current R.O.P. (ft/hr) Avg Brooks Range North Tarn #1A Tarn 0' Nabors 9ES $2,665.00 AK-AM-8035432 PVGel 0.0 0.00.0 Max:Ambient Air Pit Room C1 C3 Chlorides Min na Avg % GvlCoal 15-20 1-2-CT-G-X-I-WT-TD Lst na 7 ml/30min mg/l na AvgMin Max Max 0 0 Total Charges: Flow In (spm) SPP (psi)0 2.9620 $126,637.00 Gallons/stroke L/D BHA J. Nicholson/J. West 309 cir Flow In (gpm) Current Pump & Flow Data: na Max @ ft md in 9.60 DTX619M-D6 4944' Gas (units) H2S Data 2 3 Change rams, flush stack, & test BOPEs. R/U to run casing. P/U 7'' casing & RIH. Circulate at the Shoe (2,347' MD). Continue to run in hole from 5,451' MD to 6056' md. Circulate Max gas 978 units at Bottoms up. Trouble shot elevator back hinge pin-repair. Service rig. L/D HWDP & Jars to 177' MD. L/D BHA. Clear & clean floor. Avg Diam 17 bbls 8.50'' Max: Hole Condition On Bot Hrs 6070'26.9 Sample Line 44 24.80 6/9/10 ChtSst 9.60 8.5 0.778 2317' W E L L N A M E : No r t h T a r n 1 & N o r t h T a r n 1 A LO C A T I O N : North Tarn Prospect OP E R A T O R : Br o o k s R a n g e P e t r o l e u m C o r p o r a t i o n AR E A : North Slope M/ L W D C O : Sc h l u m b e r g e r ST A T E : Alaska RI G : Na b o r s 9 E S SP U D : 13-Mar-11 SP E R R Y J O B : AK - A M - 0 0 0 8 0 3 5 4 3 2 TD : 14-Apr-11 BI T RE C O R D BH A # S D L RU N # Bi t # B i t T y p e B i t Si z e De p t h In De p t h Ou t Fo o t a g e B i t Ho u r s TF A A V G RO P WO B (m a x ) RP M (m a x ) SP P (m a x ) FL O W G P M (m a x ) Bi t G r a d e R e m a r k s 1 1 0 0 1 R e e d H y c a l o g T C 1 1 C 1 2 . 2 5 1 2 0 2 3 5 8 2 2 3 8 1 6 . 7 0 0 . 9 4 2 1 3 4 . 0 38 83 1 8 6 4 6 6 1 1- 1 - W T - A - E - 1 - E R - T D TD for 9 5/8" Casing 2 2 0 0 2 H y c a l o g P D C B i t D T X 6 1 9 M - D 6 8 . 5 0 2 3 5 8 6 2 2 3 3 8 6 5 2 5 . 0 0 0 . 7 7 8 1 5 4 . 6 33 85 2 9 1 3 5 3 6 N o t G r a d e d T D d u e t o W e l l C o n t r o l I s s u e s ; B i t L o s t i n H o l e 3 3 0 0 3 H y c a l o g P D C B i t D T X 6 1 9 M - D 6 8 . 5 0 2 3 6 2 6 0 7 0 3 7 2 3 2 6 . 9 0 0 . 7 7 8 1 3 8 . 4 25 90 1 9 6 7 4 5 0 1- 2 - C T - G - X - 1 - W T - T D TD Intermediate Section for 7" Casing Be g i n S i d e t r a c k f o r N o r t h T a r n 1 A WE L L N A M E : No r t h T a r n 1 & N o r t h T a r n 1 A LO C A T I O N : No r t h T a r n P r o s p e c t OP E R A T O R : Br o o k s R a n g e P e t r o l e u m AR E A : No r t h S l o p e MU D C O : MI S w a c o ST A T E : A la s k a RI G : Na b o r s 9 E S SP U D : 13 - M a r - 1 1 SP E R R Y J O B : A K- A M - 0 0 0 8 0 3 5 4 3 2 TD : 14 - A p r - 1 1 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 Da t e D e p t h W t V i s P V Y P G e l s F i l t R6 0 0 / R 3 0 0 / R 2 0 0 / R 1 0 0 / R6 / R 3 Ca k e S o l i d s Oi l / W a t e r Sd M B T p H A l k M u d A l k F i l t C h l o r i d e s C a + + R e m a r k s ft - M D p p g s e c l b / 1 0 0 l b / 1 0 0 f t 2 m / 3 0 m R h e o m e t e r 3 2 n d s % % % m l m l P m P f / M f m g / l 11 - M a r - 8 . 8 0 1 7 6 3 7 3 1 1 2 / 2 3 / 2 4 8 . 2 1 0 5 / 6 8 / 5 4 / 3 5 / 1 1 / 9 2 / n a 3 . 5 - / 9 7 - 3 2 9 . 2 0 . 1 5 . 1 0 / . 2 0 4 0 0 4 0 R i g g i n g u p 12 - M a r - 8 . 8 0 2 1 5 2 9 5 6 1 3 / 2 5 / 3 6 8 . 2 1 1 4 / 8 5 / 6 2 / 4 2 / 1 5 / 1 2 2 / n a 3 . 5 - / 9 7 - 3 2 9 . 2 0 . 1 5 . 1 0 / . 2 0 4 0 0 4 0 P i c k i n g u p b i t 13 - M a r 9 9 6 8 . 9 0 3 1 8 4 2 5 1 3 3 / 8 1 / 1 0 4 6 . 5 1 3 5 / 9 3 / 7 2 / 5 0 / 2 2 / 2 1 2 / n a 3 . 6 - / 9 6 t r 3 0 9 . 5 0 . 2 0 . 1 6 / . 2 3 4 0 0 4 0 D r illing A head 14 - M a r 2 3 5 8 9 . 5 0 2 5 3 5 4 5 0 3 6 / 7 8 / 1 0 1 6 . 5 1 5 8 / 1 0 4 / 8 5 / 6 2 / 2 6 / 2 2 2 / n a 7 . 2 - / 9 3 t r 3 2 9 . 1 0 . 1 5 . 1 0 / . 1 7 4 0 0 4 0 R i g u p f o r 9 5 / 8 " C S G r u n 15 - M a r 2 3 5 8 9 . 5 0 6 2 3 5 1 7 4 / 6 / 1 4 6 . 5 8 7 / 5 2 / 3 8 / 2 3 / 5 / 4 2 / n a 7 . 3 - / 9 3 t r 2 4 8 . 6 0 . 0 5 . 0 1 / . 0 5 4 0 0 3 2 S u r f a c e c e m e n t j o b 16 - M a r 2 3 5 8 - - - - - - - - - - - - - - - - - N / U B O P - N o m u d i n p i t s Da t e D e p t h W t V i s P V Y P G e l s HT H P R6 0 0 / R 3 0 0 / R 2 0 0 / R 1 0 0 / R6 / R 3 Ca k e U nc o r So l i d Oi l / W a t e r Sd O i l L i m e P o m Em u l S t a b Cl - w h o l e S a l t Take OBM into Pits (Enviromul) 17 - M a r 2 3 5 8 9 . 6 0 2 1 2 3 5 1 3 6 / 9 / 1 0 n a 8 3 / 4 8 / 3 5 / 2 1 / 5 / 4 n a / 2 1 3 . 2 7 1 / 1 6 t r - - - - - - T e s t B O P 18 - M a r 2 3 5 8 9 . 6 0 1 7 2 3 6 1 4 6 / 9 / 1 0 n a 8 5 / 4 9 / 3 5 / 2 0 / 5 / 4 n a / 2 1 3 . 0 71 / 2 9 - - - 2 . 3 0 7 4 5 - - P / U D r i l l P i p e 19 - M a r 2 3 5 8 9 . 6 0 9 7 3 6 1 3 6 / 9 / 1 0 6 . 2 8 5 / 4 9 / 3 5 / 2 1 / 5 / 4 n a / 2 1 3 . 0 7 0 / 3 0 - 6 1 2 . 0 8 1 . 6 0 7 3 6 6 5 0 0 0 2 8 . 1 2 F I T , D r illing 20 - M a r 3 7 4 4 9 . 6 0 9 7 3 3 1 4 7 / 9 / 1 2 5 . 6 8 0 / 4 7 / 3 5 / 2 2 / 7 / 6 n a / 2 1 3 . 5 73 / 2 7 - 6 3 1 . 8 2 1 . 4 0 8 4 9 5 2 3 0 0 2 5 . 8 3 D r illing ahead 21 - M a r 5 6 6 3 9 . 6 0 9 2 3 5 1 5 1 1 / 1 9 / 2 6 4 . 8 8 8 / 5 2 / 3 5 / 2 4 / 8 / 7 n a / 2 1 3 . 8 7 4 / 2 6 - 6 4 2 . 3 4 1 . 8 0 8 0 7 5 1 0 0 0 2 6 . 4 4 S e r v i c e R i g 22 - M a r 6 2 2 3 1 0 . 4 0 1 0 5 3 5 2 5 3 1 / 3 3 / 3 5 4 . 6 9 5 / 6 0 / 4 6 / 3 3 / 1 4 / 1 3 n a / 2 1 6 . 0 73 / 2 7 - 6 3 1 . 8 2 1 . 4 0 9 5 1 3 1 0 0 0 1 8 . 7 7 C i r c u l a t e d 23 - M a r 6 2 2 3 1 0 . 4 0 1 1 5 3 0 2 5 2 5 / 3 7 / 4 0 4 . 6 8 1 / 5 0 / 4 0 / 2 8 / 1 4 / 1 2 n a / 2 2 0 . 0 7 8 / 2 2 - 6 2 2 . 3 4 1 . 8 0 9 2 2 4 5 5 0 0 2 8 . 3 5 C i r c u l a t e d 24 - M a r 6 2 2 3 1 0 . 5 0 8 9 2 5 2 2 2 3 / 3 4 / 3 6 4 . 8 7 2 / 4 7 / 3 7 / 2 7 / 1 5 / 1 4 n a / 2 1 8 . 0 82 / 1 8 - 6 7 1 . 8 2 1 . 4 0 1 , 1 0 3 3 7 5 0 0 2 8 . 1 2 C i r c u l a t e d 25 - M a r 6 2 2 3 1 0 . 7 0 1 0 5 4 1 2 6 1 9 / 3 1 / 3 4 1 . 1 1 0 8 / 6 7 / 5 2 / 3 5 / 1 5 / 1 3 n a / n a 1 6 . 0 7 1 / 2 9 - 6 0 3 . 7 1 2 . 8 5 8 7 1 7 7 5 0 0 3 3 . 5 7 W e l l C o n t r o l 26 - M a r 62 2 3 1 1 . 7 0 1 0 8 4 2 2 6 1 7 / 3 0 / 3 4 1 . 0 1 1 0 / 6 8 / 5 4 / 3 5 / 1 6 / 1 3 n a / 1 1 8 . 0 71 / 2 9 - 5 8 3 . 6 4 2 . 8 0 8 9 8 7 8 0 0 0 3 3 . 7 1 W e l l C o n t r o l 26 M a r 62 2 3 11 .70 10 8 42 26 17 / 3 0 / 3 4 1 .0 11 0 / 6 8 / 5 4 / 3 5 / 1 6 / 1 3 na / 1 18 .0 71 / 2 9 58 3 .64 2 .80 89 8 78 0 0 0 33 .71 Well Control 27 - M a r 6 2 2 3 1 1 . 7 0 9 9 4 5 2 4 1 8 / 2 7 / 3 4 1 . 0 1 1 2 / 7 0 / 5 5 / 3 6 / 1 8 / 1 6 n a / 2 2 3 . 0 7 2 / 2 8 - 5 8 3 . 5 1 2 . 7 0 3 4 1 7 6 0 0 0 3 4 . 0 9 W e l l C o n t r o l 28 - M a r 6 2 2 3 1 1 . 7 0 7 3 4 0 2 4 1 6 / 2 6 / 3 2 2 . 1 1 0 4 / 6 4 / 5 1 / 3 2 / 1 3 / 1 2 n a / 1 1 6 . 0 71 / 2 9 - 6 0 3 . 3 8 2 . 6 0 3 6 1 7 7 0 0 0 3 3 . 4 3 W e l l C o n t r o l 29 - M a r 6 2 2 3 1 1 . 7 0 8 0 3 7 2 5 1 9 / 3 0 / 3 9 2 . 4 9 9 / 6 2 / 4 8 / 3 4 / 1 5 / 1 4 n a / 2 1 6 . 0 7 1 / 2 9 - 6 0 1 . 5 6 1 . 2 0 2 9 8 5 2 5 0 0 2 5 . 5 0 C i r u l a t i n g 30 - M a r 6 2 2 3 1 1 . 7 0 8 2 3 1 1 6 1 3 / 2 2 / 2 6 2 . 6 7 8 / 4 7 / 3 5 / 2 4 / 1 1 / 1 0 n a / 1 1 6 . 0 73 / 2 7 - 6 2 1 . 4 3 1 . 1 0 2 9 7 5 4 0 0 0 2 7 . 7 5 P r e p f o r p e r f o r a t i o n 31 - M a r 6 2 2 3 1 1 . 7 0 8 0 3 1 1 6 1 3 / 2 3 / 2 8 2 . 6 7 9 / 4 7 / 3 7 / 2 4 / 1 1 / 1 0 n a / 1 2 1 . 0 7 5 / 2 5 - 6 3 1 . 5 6 1 . 2 0 2 9 8 5 2 0 0 0 2 7 . 9 3 W a i t o n C e m e n t 1- A p r 6 2 2 3 1 1 . 7 0 8 2 3 1 1 5 1 3 / 2 4 / 2 9 2 . 6 7 7 / 4 6 / 3 6 / 2 4 / 1 1 / 1 0 n a / 1 1 6 . 0 7 5 / 2 5 - 6 3 1 . 5 6 1 . 2 0 2 9 8 5 2 0 0 0 2 7 . 9 3 M o n i t o r W e l l 2- A p r 6 2 2 3 1 1 . 7 0 8 2 3 1 1 5 1 3 / 2 4 / 3 0 2 . 6 7 7 / 4 6 / 3 6 / 2 4 / 1 1 / 1 1 n a / 2 1 6 . 0 7 5 / 2 5 - 6 3 1 . 5 6 1 . 2 0 2 9 8 5 2 0 0 0 2 7 . 9 3 W a i t o n C e m e n t Da t e D e p t h W t V i s P V Y P G e l s F i l t R6 0 0 / R 3 0 0 / R 2 0 0 / R 1 0 0 / R6 / R 3 Ca k e S o l i d s Oi l / W a t e r Sd M B T p H A l k M u d A l k F i l t C h l o r i d e s C a + + R e m a r k s 3- A p r 6 2 2 3 1 1 . 0 0 4 2 1 2 1 9 7 / 8 / 9 7 . 0 4 3 / 3 1 / 2 3 / 1 7 / 7 / 6 1 / 2 9 . 0 1 / 9 0 - - 9 . 9 0 . 3 0 0 . 2 5 / 1 . 3 0 3 0 0 0 2 0 A t t e m p t t o B a c k o f f D P 4- A p r 6 2 2 3 1 1 . 0 0 4 3 1 3 1 9 7 / 8 / 9 7 . 0 4 5 / 3 2 / 2 4 / 1 8 / 8 / 6 1 / 2 9 . 0 1 / 9 0 - - 9 . 9 0 . 3 0 0 . 2 5 / 1 . 3 0 3 0 0 0 2 0 A t t e m p t t o B a c k o f f D P 5- A p r 6 2 2 3 1 1 . 0 0 4 5 1 3 2 0 7 / 8 / 9 7 . 0 4 6 / 3 3 / 2 5 / 1 9 / 9 / 7 1 / 2 9 . 0 1 / 9 0 - - 9 . 8 0 . 2 5 0 . 2 0 / 1 . 3 0 2 9 0 0 3 0 F i n d F r e e P o i n t 6- A p r 6 2 2 3 1 1 . 0 0 5 3 1 4 2 2 8 / 1 2 / 1 4 6 . 5 5 0 / 3 6 / 3 0 / 2 2 / 9 / 6 1 / 2 9 . 0 1 / 9 0 - - 9 . 6 0 . 1 2 5 0 . 0 5 / 0 . 1 0 6 0 0 1 2 0 0 R I H w i t h S e v e r i n g T o o l 7- A p r 6 2 2 3 1 1 . 0 0 5 6 1 4 2 2 9 / 1 2 / 1 4 6 . 6 5 0 / 3 6 / 3 0 / 2 2 / 9 / 6 1 / 2 9 . 0 1 / 9 0 - - 9 . 8 0 . 2 0 0 . 1 5 / 0 . 9 0 6 0 0 1 8 0 0 P O O H w i t h D r ill Pipe 8- A p r 2 3 4 7 1 1 . 0 0 5 2 1 2 2 2 8 / 1 1 / 1 3 7 . 3 4 6 / 3 4 / 2 4 / 1 7 / 7 / 6 1 / 2 8 . 8 1 / 9 0 - - 1 0 . 1 0 . 1 0 0 . 0 5 / 0 . 1 5 5 0 0 1 6 0 0 T e s t B O P 9- A p r 2 0 9 7 9 . 6 0 4 5 7 1 9 7 / 9 / 9 6 . 0 3 3 / 2 6 / 2 0 / 1 5 / 7 / 6 1 / 1 6 . 2 1 / 9 3 - - 9 . 4 0 . 1 0 0 . 0 5 / 0 . 1 0 5 0 0 6 0 0 P i p e M a n a g e m e n t 10 - A p r 2 3 1 7 9 . 6 0 4 6 8 2 0 7 / 9 / 1 1 5 . 9 3 6 / 2 8 / 2 4 / 1 8 / 8 / 6 1 / 1 6 . 0 1 / 9 3 - - 9 . 8 0 . 0 5 0 . 0 5 / 0 . 3 0 2 7 0 0 7 1 0 R i g u p t o T e s t B O P ' s 11 - A p r 2 7 4 0 9 . 6 0 4 3 8 1 8 6 / 7 / 1 0 5 . 8 3 4 / 2 6 / 2 2 / 1 7 / 7 / 5 1 / 1 5 . 0 - / 9 5 - 0 . 2 5 1 0 . 0 0 . 0 5 0 . 0 5 / 0 . 4 0 4 4 0 0 8 0 0 D r illing A head 12 - A p r 3 7 9 4 9 . 6 0 4 8 9 2 3 8 / 1 1 / 1 4 8 . 2 4 1 / 3 2 / 2 8 / 2 2 / 1 0 / 8 2 / 3 7 . 5 1 / 9 2 t r 6 . 0 0 9 . 5 0 . 1 5 0 . 1 0 / 2 . 5 0 3 8 0 0 2 8 0 R I H f r o m W i p e r T r i p 13 - A p r 4 4 9 4 9 . 6 0 4 0 1 0 1 4 9 / 1 2 / 1 4 7 . 4 3 4 / 2 4 / 2 0 / 1 4 / 4 / 3 2 / 3 6 . 0 2 / 9 3 t r 1 0 . 0 0 9 . 3 0 . 1 5 0 . 1 0 / 0 . 3 0 2 0 0 0 1 8 0 D r illing A head 14 - A p r 6 0 7 0 9 . 6 0 1 0 1 1 1 7 6 / 9 / 1 1 4 . 1 3 9 / 2 8 / 2 5 / 1 8 / 8 / 6 1 / 2 6 . 0 2 / 9 2 t r 1 1 . 2 5 9 . 2 0 . 0 8 0 . 0 5 / 0 . 3 0 1 8 0 0 1 4 0 P O O H w i t h D r ill Pipe 15 - A p r 6 0 7 0 9 . 6 0 4 4 9 1 6 6 / 9 / 1 0 4 . 2 3 4 / 2 5 / 2 2 / 1 6 / 7 / 6 1 / 2 6 . 5 2 / 9 2 t r 1 1 . 2 5 9 . 2 0 . 1 0 0 . 0 5 / 0 . 2 5 1 6 0 0 1 4 0 R u n n i n g 7 " L i n e r 16 - A p r 6 0 7 0 - - - - - - - - - - - - - - - - - R i g D o w n Ca s i n g R e c o r d 16 " C o n d u c t o r @ 1 2 0 ' M D 9 5 / 8 " S u r f a c e @ 2 3 4 7 ' M D 7" I n t e r m e d i a t e @ 6 0 5 6 ' M D Be g i n S i d e t r a c k N o r t h T a r n 1 A w i t h W B M North Tarn 1 KB = 97.8' Formation/Unit MD TVD TVDss Base Permafrost 1390 1382 1284.2 K-10 2568 2542 2444.2 K-10 Base 2732 2703 2605.2 Torok 4200 4151 4053.2 N Tarn Objective 4976 4915 4817.2 C-35 5010 4948 4850.2 Moraine Sst 5550 5480 5382.2 HRZ 5905 5831 5733.2 Kalubik Fm 6055 5985 5887.2 K-1 6111 6034 5936.2 Top Kup C Sst *6198 *6127 6029.2 TD 6223 6147 6049.2 *Estimated Formation Tops North Tarn 1A KB = 97.8' Formation/Unit MD TVD TVDss Surface Casing 2347 2325 2227.2 K-10 2566 2543 2445.2 C50 3673 3649 3551.2 Torok 4174 4151 4053.2 Brookian Sst 1 4518 4494 4396.2 C-35 Marker 5127 5103 5005.2 Brookian Sst 2 5489 5485 5387.2 HRZ 5838 5814 5716.2 Kalubik Fm 5955 5935 5837.2 TD 6070 6046 5948.2 Formation Tops DIRECTIONAL SURVEY REPORT Brooks Range Petroleum Corp North Tarn 1A North Tarn Alaska United States AK-AM-0008035432 Measured Vertical Vertical Depth Inclination Direction Depth Latitude Departure Section Dogleg (feet) (degrees) (degrees) (feet) (feet) (feet) (feet) (deg/100ft) 0.00 0.00 0.00 0.00 0.00 N 0.00 E 0.00 TIE-IN 210.91 0.69 215.51 210.90 1.03 S 0.74 W 1.26 0.33 303.56 0.83 213.98 303.55 2.04 S 1.44 W 2.47 0.15 489.08 2.53 230.20 488.98 5.78 S 5.33 W 7.86 0.94 581.38 3.39 230.28 581.16 8.83 S 9.00 W 12.59 0.93 673.38 5.08 227.04 672.90 13.34 S 14.07 W 19.36 1.85 764.79 6.82 227.24 763.82 19.79 S 21.02 W 28.81 1.90 860.78 8.16 226.85 858.99 28.31 S 30.17 W 41.29 1.40 956.34 8.93 227.69 953.48 37.95 S 40.61 W 55.45 0.82 1052.24 8.96 228.20 1048.22 47.93 S 51.68 W 70.31 0.09 1146.31 9.06 225.46 1141.13 58.01 S 62.42 W 85.01 0.47 1243.25 9.05 225.02 1236.86 68.75 S 73.25 W 100.25 0.07 1339.13 8.90 225.70 1331.57 79.26 S 83.89 W 115.20 0.19 1433.09 9.54 226.01 1424.31 89.75 S 94.70 W 130.24 0.68 1529.83 9.59 225.86 1519.71 100.93 S 106.25 W 146.29 0.06 1625.18 9.70 226.99 1613.71 111.94 S 117.82 W 162.24 0.23 1721.60 9.84 221.26 1708.73 123.67 S 129.19 W 178.58 1.02 1817.84 9.70 220.87 1803.58 135.99 S 139.92 W 194.90 0.16 1912.53 9.61 221.89 1896.93 147.90 S 150.42 W 210.77 0.20 2009.00 9.42 233.49 1992.08 158.59 S 162.14 W 226.59 1.99 2105.70 9.14 222.51 2087.52 168.97 S 173.69 W 242.06 1.85 2285.89 10.84 223.11 2264.97 191.89 S 194.95 W 273.31 0.95 2347.00 10.78 222.75 2325.00 200.28 S 202.75 W 284.77 0.15 2396.06 6.82 223.68 2373.47 205.76 S 207.88 W 292.28 8.08 2492.00 2.99 225.51 2469.04 211.63 S 213.60 W 300.48 3.99 2586.83 5.64 227.31 2563.59 216.53 S 218.79 W 307.60 2.80 2683.31 2.63 229.14 2659.81 221.19 S 223.95 W 314.53 3.12 2778.02 0.94 246.26 2754.47 222.92 S 226.31 W 317.40 1.85 2875.45 0.97 246.06 2851.89 223.58 S 227.79 W 318.90 0.03 2970.32 0.94 261.36 2946.74 224.02 S 229.30 W 320.25 0.27 3065.74 0.93 268.52 3042.15 224.16 S 230.84 W 321.41 0.12 3162.49 0.91 273.77 3138.89 224.13 S 232.40 W 322.44 0.09 3257.63 0.94 273.11 3234.02 224.04 S 233.93 W 323.42 0.03 3353.62 0.81 268.49 3330.00 224.01 S 235.39 W 324.41 0.15 3448.35 0.95 262.47 3424.71 224.13 S 236.84 W 325.48 0.18 3545.22 0.84 263.54 3521.57 224.32 S 238.34 W 326.65 0.11 3640.80 0.52 289.36 3617.15 224.25 S 239.45 W 327.35 0.46 3736.78 0.56 320.61 3713.12 223.75 S 240.16 W 327.47 0.31 3832.27 0.37 314.68 3808.61 223.17 S 240.67 W 327.40 0.20 3927.61 0.38 300.92 3903.95 222.79 S 241.16 W 327.46 0.09 4024.32 0.34 303.31 4000.66 222.47 S 241.68 W 327.57 0.04 4120.27 0.23 319.38 4096.60 222.17 S 242.04 W 327.60 0.14 4214.91 0.26 339.48 4191.24 221.82 S 242.24 W 327.48 0.10 4311.20 0.22 214.80 4287.53 221.77 S 242.42 W 327.57 0.44 4406.11 0.07 225.86 4382.44 221.96 S 242.57 W 327.81 0.16 4503.59 0.02 282.62 4479.92 222.00 S 242.63 W 327.88 0.06 4598.98 0.15 122.65 4575.31 222.06 S 242.54 W 327.86 0.18 4694.30 0.32 124.47 4670.63 222.28 S 242.21 W 327.80 0.18 4790.75 0.34 146.88 4767.08 222.67 S 241.83 W 327.83 0.13 4886.24 0.42 155.51 4862.57 223.22 S 241.53 W 328.03 0.10 4981.51 0.27 173.52 4957.84 223.77 S 241.36 W 328.31 0.19 5077.56 0.30 183.67 5053.88 224.24 S 241.35 W 328.65 0.06 5172.97 0.42 210.10 5149.29 224.79 S 241.55 W 329.18 0.21 5268.60 0.38 225.20 5244.92 225.32 S 241.95 W 329.84 0.12 5365.53 0.51 244.03 5341.85 225.74 S 242.56 W 330.56 0.20 5460.49 0.53 247.98 5436.80 226.09 S 243.35 W 331.36 0.04 5556.84 0.41 257.78 5533.15 226.33 S 244.10 W 332.05 0.15 5651.53 0.43 256.90 5627.84 226.48 S 244.78 W 332.62 0.02 5748.79 0.52 249.53 5725.09 226.71 S 245.55 W 333.32 0.11 5842.57 0.36 243.62 5818.87 226.99 S 246.21 W 333.97 0.18 5939.18 0.16 283.85 5915.48 227.10 S 246.61 W 334.33 0.27 6011.62 0.26 347.21 5987.92 226.91 S 246.75 W 334.28 0.33 6070.00 0.26 347.21 6046.30 226.65 S 246.80 W 334.13 0.00 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 223.11 DEGREES (TRUE ) A TOTAL CORRECTION OF 20.94 DEG FROM MAGNETIC NORTH TO TRUE NORTH HAS BEEN APPLIE D HORIZONTAL DISPLACEMENT IS RELATIVE TO THE WELL HEAD. HORIZONTAL DISPLACEMENT(CLOSURE) AT 6070.00 FEET IS 335.09 FEET ALONG 227.44 DEGREES (TRUE ) Date Printed:10 May 2011 DIRECTIONAL SURVEY REPORT Brooks Range Petroleum Corp North Tarn 1 North Tarn Alaska United States AK-AM-0008035432 Measured Vertical Vertical Depth Inclination Direction Depth Latitude Departure Section Dogleg (feet) (degrees) (degrees) (feet) (feet) (feet) (feet) (deg/100ft) 0.00 0.00 0.00 0.00 0.00 N 0.00 E 0.00 TIE-IN 210.91 0.69 215.51 0.00 0.00 N 0.00 E -1.03 0.00 303.65 0.83 213.98 0.00 0.00 N 0.00 E -2.05 0.00 395.65 1.01 219.67 0.00 0.00 N 0.00 E -3.22 0.00 489.08 2.53 230.20 0.00 0.00 N 0.00 E -5.18 0.00 581.38 3.39 230.28 0.00 0.00 N 0.00 E -8.22 0.00 673.38 5.08 227.04 0.00 0.00 N 0.00 E -12.74 0.00 764.79 6.82 227.24 0.00 0.00 N 0.00 E -19.18 0.00 860.78 8.16 226.85 0.00 0.00 N 0.00 E -27.71 0.00 956.34 8.93 227.69 0.00 0.00 N 0.00 E -37.34 0.00 1052.24 8.96 228.20 0.00 0.00 N 0.00 E -47.33 0.00 1146.31 9.06 225.46 0.00 0.00 N 0.00 E -57.41 0.00 1243.25 9.05 225.02 0.00 0.00 N 0.00 E -68.15 0.00 1339.13 8.90 225.70 0.00 0.00 N 0.00 E -78.66 0.00 1433.09 9.54 226.01 0.00 0.00 N 0.00 E -89.14 0.00 1529.83 9.59 225.86 0.00 0.00 N 0.00 E -100.32 0.00 1625.18 9.70 226.99 0.00 0.00 N 0.00 E -111.33 0.00 1721.60 9.84 221.26 0.00 0.00 N 0.00 E -123.07 0.00 1817.84 9.70 220.87 0.00 0.00 N 0.00 E -135.38 0.00 1912.53 9.61 221.89 0.00 0.00 N 0.00 E -147.30 0.00 2009.00 9.42 233.49 1992.10 157.99 S 161.25 W -157.99 1.99 2105.70 9.14 222.51 2087.55 168.36 S 172.80 W -168.36 1.85 2285.89 10.84 223.11 2265.00 191.28 S 194.05 W -191.28 0.95 2400.25 10.72 222.07 2377.34 207.03 S 208.53 W -207.03 0.20 2496.09 10.62 221.86 2471.52 220.22 S 220.39 W -220.22 0.11 2590.87 10.50 222.50 2564.70 233.09 S 232.05 W -233.09 0.18 2687.10 10.51 222.05 2659.31 246.08 S 243.86 W -246.08 0.09 2783.85 10.41 220.50 2754.46 259.28 S 255.44 W -259.28 0.31 2878.46 10.15 221.17 2847.55 272.05 S 266.48 W -272.05 0.30 2972.50 10.02 221.73 2940.13 284.39 S 277.38 W -284.39 0.17 3068.44 9.94 220.94 3034.62 296.88 S 288.36 W -296.88 0.17 3163.88 9.70 219.95 3128.66 309.26 S 298.92 W -309.26 0.31 3259.77 9.61 220.80 3223.20 321.52 S 309.34 W -321.52 0.18 3355.08 9.76 225.82 3317.15 333.17 S 320.33 W -333.17 0.90 3451.95 9.45 224.38 3412.66 344.57 S 331.78 W -344.57 0.40 3547.12 9.12 223.16 3506.58 355.66 S 342.41 W -355.66 0.40 3643.00 9.08 224.06 3601.26 366.64 S 352.87 W -366.64 0.15 3738.49 9.62 227.40 3695.48 377.45 S 363.98 W -377.45 0.80 3834.98 9.23 227.98 3790.67 388.09 S 375.66 W -388.09 0.42 3929.77 9.23 226.70 3884.23 398.39 S 386.84 W -398.39 0.22 4025.39 9.62 227.55 3978.56 409.05 S 398.32 W -409.05 0.43 4120.93 9.37 225.70 4072.79 419.87 S 409.78 W -419.87 0.41 4217.01 9.56 226.14 4167.56 430.86 S 421.13 W -430.86 0.21 4312.73 10.29 225.25 4261.85 442.38 S 432.93 W -442.38 0.78 4408.26 10.18 224.28 4355.86 454.43 S 444.88 W -454.43 0.21 4505.45 10.10 225.55 4451.53 466.55 S 456.96 W -466.55 0.24 4598.57 9.96 222.72 4543.23 478.19 S 468.26 W -478.19 0.55 4695.00 9.89 222.25 4638.21 490.44 S 479.48 W -490.44 0.11 4791.57 10.37 223.63 4733.28 502.87 S 491.05 W -502.87 0.56 4887.13 10.26 222.62 4827.29 515.36 S 502.75 W -515.36 0.22 4982.60 10.43 226.86 4921.21 527.53 S 514.81 W -527.53 0.82 5079.19 10.36 227.14 5016.22 539.41 S 527.56 W -539.41 0.09 5175.13 10.01 226.56 5110.65 551.01 S 539.94 W -551.01 0.38 5271.49 9.47 222.01 5205.62 562.66 S 551.32 W -562.66 0.98 5367.21 9.07 220.70 5300.09 574.23 S 561.51 W -574.23 0.47 5462.45 8.84 221.15 5394.17 585.43 S 571.22 W -585.43 0.25 5556.87 9.13 221.79 5487.43 596.48 S 580.99 W -596.48 0.32 5749.53 9.27 223.73 5677.61 619.09 S 601.90 W -619.09 0.18 5845.37 8.60 221.42 5772.29 630.04 S 611.98 W -630.04 0.79 5940.94 7.78 221.34 5866.88 640.26 S 620.98 W -640.26 0.86 6036.66 7.03 216.19 5961.80 649.85 S 628.72 W -649.85 1.05 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 (TRUE ) A TOTAL CORRECTION OF 20.94 DEG FROM MAGNETIC NORTH TO TRUE NORTH HAS BEEN APPLIE D HORIZONTAL DISPLACEMENT IS RELATIVE TO THE WELL HEAD. HORIZONTAL DISPLACEMENT(CLOSURE) AT 6036.66 FEET IS 904.21 FEET ALONG 224.05 DEGREES (TRUE ) Date Printed:10 May 2011 0 1000 2000 3000 4000 D ep t h Prognosed Actual North Tarn 1 & North Tarn 1A Days vs. Depth Drill 12.25" Surface Section 120' MD, 120' TVD On Bot: 08:00 13-Mar2011 08-Mar-2011 Sperry SDL on location Run & Land 9 5/8" Casing 2347' MD, 2325' TVD Drill 8.5" Production Section 2358' MD, 2332' TVD On Bot: 23:05 19-Mar2011 TD 12.25" Surface Section 2358' MD, 2336' TVD Off Bot: 09:34 14-Mar2011 Drill 8.5" Sidetrack Section 2362' MD, 2339' TVD On Bot: 16:21 11-Apr-2011 Short Trip to Surface to Clean BHA and Bit from Clay Buildup 5000 6000 7000 8000 9000 0 5 10 15 20 25 30 35 40 45 Me a s u r e d D Rig Days Well Control, Circulate Gas Sperry SDL Released 17-Apr-2011 Run & Land 7" Casing at 6056' MD, 6046' TVD TD 8.5" Hole Section 6070' MD, 6046' TVD Off Bot: 09:56 14-Apr-2011 Short Trip at 5663' MD for rig repair Drill to 6223' MD, 6147' TVD, Encounter high gas, Shut in well & Begin well control operations Perforate HWDP and Pump Magnafiber Pump 1st Batch of Cement with BHA in Hole Weight Up to 10.5ppg and Circulate Weight Up to 11.7ppg and Circulate Attempting to Back Off Drill Pipe Unsuccessful Attempt to Cut Drill Pipe with Free Point Tool, Displace Well with 11.0ppg WBM Successfully Cut Drill Pipe at 2547' MD, Cement, POOH Pump 2nd Batch of Cement Test BOP's Short Trip to 3794' MD Surface Data Logging After Action Review Employee Name: Ryan Massey Date: 8-April-2011 Well: North Tarn 1 Hole Section: Production What went as, or better than, planned: Our plan was to use Rigwatch for pit volume and as a backup for surface parameters. Due to circumstance, WITS from the Rigwatch became our primary and it worked with no issues. In previous year, Rigwatch would lock up daily causing us to miss pit volume data. No gas trap problems encountered and rig crew was accomadating to adjust fluid levels in possum belly most of the time. Due to well control issues, the client was unable to drill past the zone of interest in order to collect LWD data. Sperry SDL data became the client's only source for information regarding a potential pay zone. Time was taken to work with the client with interpreting all surface drilling data along with samples and gas data to estimate resevoir thickness and quality. Difficulties experienced: The WITS setup from Schlumberger that was used in previous year with this client was unabled to be used due to a new version of Schlumberger's operating system. The client was annoyed that they had to walk to and from SDL and MWD shack when approaching potential zones of interest. The gas line from the unit to the gas trap froze up for an extended period. This was due to MOBM splattering onto a section of our insulated gas line combined with freezing air blowing into the pit room along the flow line effectively cancelling out any heat our heat trace could provide. Recommendations: Work with SLB and their new operating system to send WITS strictly real time as opposed to sending real time and batches of historical data. As always, work on improving gas line insulation. SDL was the only group on location who could see real time gas readings as no one else had a Sperry monitor. Had a discussion with Toolpusher, they would like for the driller to see real time gas on the Rigwatch. We attempted this last year but either the Rigwatch or Sperry WITS could not send and recieve data on the same cable. Toolpusher wants to avoid putting another monitor on rig floor. Let's work on the issue before next year. We decided that having a Sperry monitor in Company Man's and Toolpusher's office would be a suitable alternative. Discussed with client the thought of having both Sample Catchers working while drilling pay intervals allowing the rig to drill faster. In retrospect, if ROPs weren't slowed down for samples being caught, the pay interval would've be logged before the well control issue appeared. Innovations and/or cost savings: Sample Catchers were released by the client after day 3 of well control. Surface Data Logging After Action Review Employee Name: Ryan Massey Date: 14-April-2011 Well: North Tarn 1A Hole Section: Intermediate What went as, or better than, planned: Rigwatch WITS continued to work with no issues. Gas trap worked with no failures. SDL services went well as our gas data and samples matched up with SLB's LWD data. Difficulties experienced: This section was drilled with WBM in which hydrophyllic clay would plug up ports to shakers and the gas trap. The only remedy is to constantly check the gas trap and often clear clay from underneath it. The THC (Total Hydrocarbon Conditioner) failed due to the a blockage in the main valve that supplies our gas analyzer and chromatograph with the gas sample. A spare THC was retrieved from Deadhorse. Recommendations: The THC's are usually very reliable and after an inspection was performed, it was determined the failure was the result of age and normal wear and tear. THC will be sent to town to have valves and fittings replaced. Spares valves should be ordered and replaced in all THC's in the field. Innovations and/or cost savings: Sample Catchers were released within 18 hours of TD.
