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MICROFILMED 6/30/2010 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE C:\temp\Temporary Internet Fites\OLK9\Microfilm Marker.doc v ~-c ~~~~-~ a c1 l ~g~ ConocoPhillips Alaska Greater Kuparuk Area*** Data Distribution RECIPIENTS FteservorAnalysis Completion No other distribution is allowed without OH FIEEd OH FINAL OH FINAL CH FINAL CW FINAL CH FINAL Directional Ifilid Logs written approval from ConocoPhillips Image files andlor Digital Data Image files andtr~r .Image files andlor . faigital Qata Data /endor contact: Lisa Wri ht, 907 263-4823 hardcop rints harden rints; hardco ring Finai ate urt <'W ConocoPhillips Alaska, Ina 1 Disk*/ , ` Sharon Allsup-Drake Electronic Drillin Tech, ATO-1530 ~ - ConocoPhillips Alaska, Inc. 1 Hardcopy Print 1 hardcopy NSK Wells Aide, NSK 69 1 Disk*/Electronic ConocoPhillips Alaska, Ina ; ; ` , ~ hardcopy re~rts and s Ricky Elgarico 1 Graphic Image 1 Disk*/ 1 Graphic Image, .: 1 Graphic image 1 pick*/ 1' Disk*/ , disk~^ wa3h al~ctronic Well Data Specialist, ATO 1802 File**/*** Electronic Fife**!'** ~ File"",/*** Electronic Electronic repork. LAS ~~®~, Graphic ftp://b2bftp.conocophillips.com **** ~ ~ CGM /TIFF LIS ~ fma a Fitt~-•/'*` AOGCC 1 Hardcopy Print, 1 Hardct~py f~rinf, 1 Hardcopy Print, 1 rdcopy, Christine Mahnken 1 Graphic image file 1 Disk*/ ,1 Graphic image f#e 1. Disk*/ 1 Disk*/ 1 disk, , 333 West 7th Ave, Suite 100 ~ in lieu of sepia** Electronic in lieu of septa" ~tectronic Electronic distributed by GOP Anchora e, Alaska 99501 CGM /TIFF LIS BP 1 Hardcopy Print, 1 Ward`copy Iarinf, 1 Hardcopy Print, 1 disk, Petrotechnical Data Center, M633 ,~{.~~ 1 Graphic image file 1 Disk*/ 1 Graphic image fi#~ 1 Disk*T 1 Disk•/ distributed by GOP David Douglas in lieu of sepia** Electronic °in Ireu pf sepia** Electronic Electronic P.O. Box 196612 ~~ "= ' ~ CGM /TIFF LIS - Anchora e, Alaska 99519-6612 CHEVRON/KRU REP 1 Hardcopy Print, 1 Hardcopy Prin#, 1 Hardcopy Print, 1 disk, Glenn Fredrick 1 Graphic image file 1 Disk*/ 1 Grapfric image fife 1 Disk'/ 1 Disk*/ distributed by COP P.O.Box 196247 in lieu of sepia** Electronic iftlieci of sepia** Electr'anic Electronic Anchora e, Alaska 99519 CGM /TIFF LIS Kristen Dirks, Geologist 1 Hardcopy Print, 1 trardcopy, State of Alaska; DNR, Div. of Oil and Gas 1 Disk*/ 1 IJisk*% 1 Disk*/ 1 disk, 550 W. 7th Ave, Suite 800 Electronic Eiectrortic Electronic distr~i~ated by GOP Anchora e, Alaska 99501-3510 LIS DS Engineer /Rig Foreman -. 2. Prirfta TOTAL Hardcop Prints ~ 4 ~ 3 ~ 4 3 Graphic Imo a File 4 4, a °`: 1 5^ Electronic Data 5 6 " *Vault documents must be pre-inventoried (bar coding on documents with digital inventory files), also tapes/disks for Well Data Specialist. Please see page 2 for definition of Reservoir Analysis Logs and Completion Logs (Cased Hole Final Services). ** AOGCC guidelines for Graphical Image File in lieu of reproducible: "The graphical file must contain information equivalent to the hardcopy materials and consist of a separate file for each blueline or sepia. A publicly distributable viewer for the graphical format is required." *** ConocoPhillips, Alaska requests anon-proprietary archive format image file (.tiff) to facilitate discontinuation of mylar reproducibles **** Files larger than 20 MB should be hosted on a CD/DVD and be sent by mail. Files less than 20 MB should be sent via FTP site. ^ Disk includes Well End Report, LAS files and Graphic Image Files. COP will distribute one hardcopy and disk to DNR, and disks to partners. ConocoPhillips Alaska Greater Kuparuk Area*** Data Distribution Reservoir Analysis Logs: IPROF, PPROF (any Production Profile Log), CNL, TDT, RST, Directional Survey, Temp, Gas Detection (and other logs that evaluate formation or tell relationship between reservoir & depth), spinner surveys .open hole evaluation logs (DIL, GR, etc.) Page 1 of 2 ConocoPhillips Transmittal #889 Detail Date: 12/9/2008 To (External Party): Email: howard.okland@alaska.gov First Name: Howard Last Name: Okland Phone (907) 793-1235 Number: Company: AOGCC Address: 333 W. 7th Ave., Ste. 100 City: Anchorage State: AK Zip Code: 99501 Sent Via: Hand Delivery Justification: Regular Distribution From (PAI Contact): Email: richard.e.elgarico@conocophillips.com First Name: Ricky Last Name: Elgarico Phone Number: (907) 265-6580 Company: CPAI Address: 700 G St. ATO-1484 City: Anchorage State: AK Zip Code: 99501 Transmittal Info: Tracking #: Data Detail: Quantity Description Type 1 1 C-25L 1 Final Digital MWD Data in TAP .with CD images in PDF and TIF. 1C-25L1 Directional Data 1 1 C-25L 1 Directional Data Print 1 1C-25L1 1:240 TVD and 1:600 and 1:240 MD Print Attachments: Filename: None Filesize: N/A Received By: Signature: Approver: Signature: a Date: ~ ~ ~~~ Date: ~~~ - lvo • 1C-251 Survey listing.txt !well: 1C-251 !Path: Original Path !Reference North is: TRUE !Magnetic Declination is: 23.76 !True to G rid Convergence: 0.00 !Tie In Po int data: !MD 94.15 INC 0.00 Azicorr 0.00 TVD 0.00 N/S 0.00 E/w 0.00 !Measured Depth Inclination Azimuth valid Closure Dist Planar vs Course length Incr vs Dogleg Position North Vertical Depth Position East Tool Type ------------ ---------- ---------- 206.12 ---------------------- ---------------------- 0.51 ----------------- ----------------- 306.29 -------------- -------------- Y --------- ----------------- 0.50 0.45 111.97 0.50 0.46 0.29 111.97 -0.40 MwD - standard (declination corrected) 288.53 0.59 290.71 Y 1.28 1.19 82.41 1.28 0.20 0.66 194.37 -1.09 MwD - standard (declination corrected) 376.26 0.63 235.18 Y 1.99 1.98 87.73 2.11 0.65 0.55 282.10 -1.91 MwD - Standard (declination corrected) 466.81 0.99 82.28 Y 1.59 1.59 90.55 2.52 1.74 0.37 372.65 -1.55 MwD - standard (declination corrected) 557.89 2.64 90.12 Y 1.41 -1.23 91.08 5.40 1.83 0.47 463.68 1.33 MwD - standard (declination corrected) 649.49 5.96 73.45 Y 8.21 -7.56 91.60 12.20 3.84 1.82 555.01 8.00 MwD - Standard (declination corrected) 739.18 10.16 65.39 Y 20.69 -18.25 89.69 24.75 4.84 6.44 643.80 19.66 MwD - Standard (declination corrected) 822.94 12.73 65.88 Y 37.26 -31.97 83.76 41.36 3.07 13.29 725.88 34.80 MwD - standard (declination corrected) 916.76 14.40 68.68 Y 59.25 -50.49 93.82 63.36 1.91 21.76 817.09 55.11 MwD - standard (declination corrected) 1006.50 16.54 72.59 Y 83.16 -71.37 89.74 87.28 2.65 29.64 903.57 77.70 MwD - Standard (declination corrected) 1091.22 19.34 79.69 Y 109.04 -95.24 84.72 113.33 4.19 35.76 984.17 103.01 MWD - Standard (declination corrected) 1186.39 21.09 84.47 Y 141.41 -126.52 95.17 146.19 2.53 40.23 1073.48 135.56 MwD - standard (declination corrected) 1279.07 22.37 86.59 Y 175.10 -159.74 92.68 180.50 1.62 42.89 1159.58 169.77 MwD - standard (declination corrected) 1372.83 25.00 87.12 Y 212.19 -196.42 93.76 218.16 2.81 44.94 1245.43 207.37 MWD - standard (declination corrected) 1465.17 27.44 88.74 Y 252.44 -236.31 92.34 258.95 2.75 46.39 1328.27 248.14 MwD - standard (declination corrected) 1557.25 28.72 89.43 Y 295.25 -278.87 92.08 302.29 1.43 47.08 1409.51 291.47 MwD - standard (declination corrected) 1648.63 31.34 89.07 Y 340.55 Page 1 °~ Q~ hs~~ ~v~- !ate • • 1C-251 Survey listing.txt -323.79 91.38 348.02 2.87 47.68 1488.61 337.20 Mw~ - Standard (declination corrected) 1743.93 34.15 88.90 Y 391.76 -374.39 95.30 399.56 2.95 48.60 1568.76 388.73 Mw~ - Standard (declination corrected) 1836.04 36.61 87.03 Y 444.90 -426.53 92.11 452.88 2.92 50.52 1643.86 442.02 MwD - Standard (declination corrected) 1930.02 39.22 87.87 Y 502.52 -482.90 93.98 510.62 2.83 53.07 1717.99 499.71 Mw~ - Standard (declination corrected) 2025.19 42.83 85.27 Y 564.91 -543.62 95.17 573.07 4.20 56.86 1789.79 562.04 Mw~ - Standard (declination corrected) 2120.69 45.82 87.00 Y 631.59 -608.40 95.50 639.79 3.38 61.33 1858.10 628.60 Mw~ - Standard (declination corrected) 2213.86 48.80 85.74 Y 700.03 -674.94 93.17 708.26 3.35 65.69 1921.27 696.94 MwD - standard (declination corrected) 2307.00 52.38 87.18 Y 771.94 -744.90 93.14 780.21 4.02 70.10 1980.39 768.75 Mw~ - Standard (declination corrected) 2400.98 53.07 86.33 Y 846.68 -817.69 93.98 854.99 1.03 74.34 2037.31 843.41 MwD - Standard (declination corrected) 2489.49 54.42 87.38 Y 918.01 -887.19 88.51 926.36 1.80 78.25 2089.65 914.67 MwD - Standard (declination corrected) 2587.98 54.04 85.28 Y 997.90 -964.83 98.49 1006.26 1.77 83.36 2147.23 994.41 MWD - Standard (declination corrected) 2682.51 53.62 85.80 v 1074.21 -1038.72 94.53 1082.57 0.63 89.30 2203.02 1070.49 MwD - Standard (declination corrected) 2774.30 55.73 86.51 Y 1149.09 -1111.43 91.79 1157.46 2.38 94.31 2256.09 1145.21 MWD - standard (declination corrected) 2868.17 55.20 87.34 Y 1226.38 -1186.76 93.87 1234.78 0.92 98.46 2309.30 1222.43 Mw~ - Standard (declination corrected) 2960.35 54.19 86.21 Y 1301.59 -1259.99 92.18 1310.01 1.48 102:69 2362.58 1297.53 MwD - Standard (declination corrected) 3057.12 55.41 87.87 Y 1380.63 -1337.04 96.77 1389.08 1.89 106.76 2418.36 1376.49 Mw~ - Standard (declination corrected) 3150.76 54.69 87.43 Y 1457.33 -1412.02 93.64 1465.83 0.86 109.91 2472.00 1453.18 Mw~ - Standard (declination corrected) 3244.75 54.25 87.24 Y 1533.79 -1486.65 93.99 1542.32 0.50 113.47 2526.62 1529.59 Mw~ - Standard (declination corrected) 3337.59 53.57 87.42 Y 1608.79 -1559.84 92.84 1617.34 0.75 116.96 2581.31 1604.53 Mw~ - Standard (declination corrected) 3432.03 52.94 88.28 Y 1684.42 -1633.82 94.44 1693.02 0.99 119.80 2637.81 1680.15 Mw~ - Standard (declination corrected) 3528.35 55.71 89.61 Y 1762.55 -1710.61 96.32 1771.25 3.09 121.23 2693.98 1758.37 MwD - Standard (declination corrected) 3622.54 55.14 89.77 Y 1839.95 Page 2 • 1C-25L1 Survey listing.txt -1786.91 94.19 1848.80 0.62 121.65 2747.43 1835.92 MwD - Standard (declination corrected) 3715.51 54.63 89.40 Y 1915.87 -1861.71 92.97 1924.85 0.64 122.20 2800.91 1911.97 MwD - standard (declination corrected) 3812.82 54.10 89.68 v 1994.84 -1939.48 97.31 2003.94 0.59 122.83 2857.60 1991.06 MwD - Standard (declination corrected) 3907.46 53.56 88.98 Y 2071.15 -2014.56 94.64 2080.34 0.83 123.72 2913.46 2067.45 MwD - standard (declination corrected) 4002.47 56.41 89.15 Y 2148.88 -2090.95 95.01 2158.14 3.00 124.99 2967.97 2145.25 MwD - Standard (declination corrected) 4096.16 55.84 88.97 Y 2226.60 -2167.32 93.69 2235.93 0.63 126.27 3020.19 2223.02 MwD - standard (declination corrected) 4189.15 55.19 89.12 Y 2303.19 -2242.57 92.99 2312.58 0.71 127.55 3072.84 2299.66 MwD - Standard (declination corrected) 4274.92 54.67 90.04 Y 2373.31 -2311.61 85.77 2382.78 1.07 128.06 3122.12 2369.85 MWD - standard (declination corrected) 4374.84 53.74 89.32 Y 2454.26 -2391.35 99.92 2463.82 1.10 128.51 3180.56 2450.90 MwD - standard (declination corrected) 4467.49 55.88 89.47 Y 2529.91 -2465.77 92.65 2539.53 2.31 129.31 3233.95 2526.61 MwD - standard (declination corrected) 4564.03 55.27 89.58 Y 2609.48 -2544.07 96.54 2619.17 0.64 129.97 3288.53 2606.24 MwD - Standard (declination corrected) 4657.99 55.12 89.56 Y 2686.56 -2619.95 93.96 2696.32 0.16 130.55 3342.16 2683.39 MwD - standard (declination corrected) 4746.66 54.63 89.60 Y 2759.02 -2691.28 88.67 2768.84 0.55 131.08 3393.18 2755.91 MwD - standard (declination corrected) 4842.94 54.03 89.25 Y 2837.18 -2768.16 96.28 2847.06 0.69 131.86 3449.32 2834.12 MwD - Standard (declination corrected) 4936.93 52.93 90.06 Y 2912.66 -2842.47 93.99 2922.59 1.36 132.32 3505.25 2909.65 MwD - Standard (declination corrected) 5026.13 54.81 89.19 Y 2984.64 -2913.33 89.20 2994.63 2.25 132.80 3557.85 2981.69 MwD - Standard (declination corrected) 5121.59 54.03 89.01 Y 3062.25 -2989.57 95.46 3072.27 0.83 134.02 3613.39 3059.32 MwD - standard (declination corrected) 5217.24 53.36 89.87 Y 3139.29 -3065.34 95.65 3149.35 1.01 134.78 3670.02 3136.39 MwD - standard (declination corrected) 5311.56 56.00 89.06 Y 3216.20 -3140.99 94.32 3226.30 2.89 135.50 3724.55 3213.34 MwD - standard (declination corrected) 5404.81 55.49 88.93 Y 3293.25 -3216.65 93.25 3303.37 0.56 136.85 3777.04 3290.40 MwD - standard (declination corrected) 5499.16 55.08 88.90 Y 3370.78 -3292.76 94.35 3380.93 0.44 138.32 3830.77 3367.95 MwD - standard (declination corrected) 5591.49 54.30 88.22 Y 3446.12 Page 3 • 1C-251 Survey listing.txt -3366.61 92.33 3456.27 1.04 140.21 3884.13 3443.26 Mw~ - standard (declination corrected) 5686.89 53.85 88.10 Y 3523.37 -3442.22 95.40 3533.53 0.48 142.69 3940.11 3520.48 MwD - Standard (declination corrected) 5780.86 53.50 88.06 Y 3599.08 -3516.29 93.97 3609.23 0.37 145.23 3995.77 3596.14 MwD - standard (declination corrected) 5870.35 52.71 87.70 Y 3670.64 -3586.26 89.49 3680.80 0.94 147.88 4049.50 3667.66 MwD - standard (declination corrected) 5965.45 54.52 88.59 Y 3747.20 -3661.19 95.10 3757.36 2.05 150.35 4105.91 3744.18 MwD - Standard (declination corrected) 6057.62 54.28 88.11 Y 3822.13 -3734.59 92.17 3832.30 0.50 152.51 4159.56 3819.09 Mw~ - Standard (declination corrected) 6147.96 53.61 87.68 Y 3895.17 -3806.00 90.34 3905.34 0.84 155.19 4212.74 3892.08 Mw~ - Standard (declination corrected) 6244.06 52.91 87.52 v 3972.18 -3881.21 96.10 3982.35 0.74 158.41 4270.22 3969.02 Mw~ - Standard (declination corrected) 6338.39 55.02 88.00 Y 4048.45 -3955.76 94.33 4058.62 2.27 161.39 4325.71 4045.24 Mw~ - Standard (declination corrected) 6431.52 54.36 88.23 Y 4124.45 -4030.12 93.13 4134.62 0.74 163.89 4379.54 4121.19 MwD - Standard (declination corrected) 6525.16 53.65 87.60 Y 4200.21 -4104.20 93.64 4210.38 0.93 166.64 4434.57 4196.90 MwD - standard (declination corrected) 6619.88 53.15 86.58 Y 4276.25 -4178.32 94.72 4286.42 1.01 170.50 4491.05 4272.85 MWD - Standard (declination corrected) 6712.90 52.59 87.87 Y 4350.40 -4250.65 93.02 4360.58 1.26 174.10 4547.20 4346.92 MwD - Standard (declination corrected) 6808.83 54.90 88.12 Y 4427.75 -4326.31 95.93 4437.93 2.42 176.80 4603.93 4424.22 Mw~ - Standard (declination corrected) 6901.49 54.85 87.89 Y 4503.54 -4400.44 92.66 4513.72 0.21 179.44 4657.24 4499.96 MwD - Standard (declination corrected) 6997.01 54.59 88.20 Y 4581.51 -4476.72 95.52 4591.69 0.38 182.10 4712.41 4577.89 Mw~ - Standard (declination corrected) 7093.33 54.20 87.26 Y 4659.83 -4553.25 96.32 4670.00 0.89 185.20 4768.49 4656.14 MwD - standard (declination corrected) 7184.26 53.85 87.45 Y 4733.41 -4625.05 90.93 4743.59 0.42 188.59 4821.90 4729.65 MwD - Standard (declination corrected) 7277.81 53.43 88.65 Y 4808.74 -4698.75 93.55 4818.93 1.13 191.16 4877.36 4804.94 Mw~ - standard (declination corrected) 7372.41 53.12 87.20 Y 4884.56 -4772.89 94.60 4894.75 1.27 193.90 4933.93 4880.71 MwD - standard (declination corrected) 7466.55 55.19 89.59 Y 4960.85 -4847.63 94.14 4971.04 3.01 196.02 4989.06 4956.98 Mw~ - Standard (declination corrected) 7562.35 54.78 87.94 Y 5039.30 Page 4 • 1C-25L1 Survey listing.txt -4924.59 95.80 5049.50 1.47 197.71 5044.04 5035.42 MwD - Standard (declination corrected) 7655.03 54.64 88.41 Y 5114.94 -4998.63 92.68 5125.15 0.44 200.12 5097.58 5111.03 MwD - standard (declination corrected) 7748.17 54.17 88.01 Y 5190.68 -5072.77 93.14 5200.88 0.61 202.48 5151.79 5186.73 MwD - Standard (declination corrected) 7843.09 53.95 89.56 Y 5267.51 -5148.15 94.92 5277.73 1.34 204.11 5207.51 5263.56 MwD - Standard (declination corrected) 7935.87 53.58 87.95 Y 5342.33 -5221.54 92.78 5352.56 1.46 205.74 5262.35 5338.37 MwD - standard (declination corrected) 8028.99 56.11 89.68 Y 5418.45 -5296.22 93.12 5428.68 3.11 207.29 5315.97 5414.48 MwD - standard (declination corrected) 8123.05 55.89 89.76 Y 5496.38 -5372.95 94.06 5506.66 0.24 207.67 5368.56 5492.46 MwD - standard (declination corrected) 8216.81 55.32 91.31 Y 5573.66 -5449.26 93.76 5584.03 1.49 206.96 5421.53 5569.82 MwD - Standard (declination corrected) 8310.00 54.86 90.24 Y 5649.98 -5524.69 93.19 5660.45 1.06 205.92 5474.86 5646.23 MwD - Standard (declination corrected) 8403.81 54.29 91.09 Y 5726.34 -5600.12 93.81 5736.89 0.96 205.03 5529.24 5722.66 MWD - Standard (declination corrected) 8496.29 53.84 89.55 Y 5801.15 -5673.93 92.48 5811.76 1.43 204.61 5583.51 5797.54 MwD - standard (declination corrected) 8590.42 53.14 89.69 Y 5876.77 -5748.35 94.13 5887.42 0.75 205.12 5639.52 5873.19 MwD - Standard (declination corrected) 8685.34 55.51 90.10 Y 5953.83 -5824.26 94.92 5964.52 2.52 205.25 5694.87 5950.30 MwD - Standard (declination corrected) 8778.03 55.53 89.27 Y 6030.21 -5899.43 92.69 6040.93 0.74 205.67 5747.34 6026.70 MwD - Standard (declination corrected) 8870.34 55.18 91.24 Y 6106.09 -5974.27 92.31 6116.86 1.80 205.34 5799.82 6102.64 MwD - standard (declination corrected) 8964.79 55.06 88.54 Y 6183.52 -6050.53 94.45 6194.33 2.35 205.49 5853.84 6180.11 MwD - Standard (declination corrected) 9057.85 54.57 89.45 Y 6259.57 -6125.19 93.06 6270.39 0.96 206.82 5907.47 6256.15 MwD - Standard (declination corrected) 9150.64 54.10 90.65 Y 6334.91 -6199.44 92.79 6345.77 1.17 206.76 5961.57 6331.53 MwD - Standard (declination corrected) 9244.01 53.90 91.25 Y 6410.36 -6274.04 93.37 6421.31 0.56 205.51 6016.45 6407.06 MwD - standard (declination corrected) 9338.47 53.47 90.47 Y 6486.38 -6349.18 94.46 6497.42 0.81 204.36 6072.39 6483.16 MWD - Standard (declination corrected) 9430.55 53.18 90.64 Y 6560.17 -6422.03 92.08 6571.27 0.35 203.65 6127.39 6557.01 MwD - Standard (declination corrected) 9510.00 52.78 90.17 Y 6623.56 Page 5 • 1C-25L1 survey listing.txt -6484.58 79.45 6634.71 0.69 203.20 6175.23 6620.44 MwD - Standard (declination corrected) 9601.40 53.33 88.86 Y 6696.59 -6556.41 91.40 6707.75 1.29 203.82 6230.16 6693.49 MwD - Standard (declination corrected) 9696.09 52.83 88.54 Y 6772.29 -6630.64 94.69 6783.46 0.59 205.54 6287.04 6769.17 MwD - Standard (declination corrected) 9793.67 53.09 90.02 Y 6850.16 -6707.17 97.58 -6707.12 1.24 206.51 6345.83 6847.05 Mw~ - standard (declination corrected) 9795.00 53.10 90.04 Y 6851.23 -6708.21 1.33 -6706.05 1.42 206.51 6346.62 6848.11 Mw~ - Standard (declination corrected) 9800.55 55.92 87.94 Y 6855.74 -6712.65 5.55 -6701.53 59.42 206.59 6349.85 6852.63 MwD - Standard (declination corrected) 9810.09 55.85 84.46 Y 6863.63 -6720.32 9.54 -6693.64 30.21 207.12 6355.20 6860.51 MwD - Standard (declination corrected) 9830.21 63.31 77.80 Y 6880.82 -6736.70 20.12 -6676.31 46.76 209.83 6365.39 6877.62 MwD - standard (declination corrected) 9862.15 79.40 68.78 Y 6909.90 -6763.56 31.94 -6646.19 56.97 218.60 6375.58 6906.44 Mw~ - Standard (declination corrected) 9894.43 86.97 55.40 Y 6938.60 -6788.75 32.28 -6614.23 47.35 233.58 6379.43 6934.66 Mw~ - standard (declination corrected) 9925.06 89.95 38.28 v 6961.56 -6807.04 30.63 -6583.73 56.73 254.45 6380.26 6956.91 MwD - standard (declination corrected) 9963.78 89.34 14.57 Y 6980.00 -6817.91 38.72 -6545.29 61.24 288.87 6380.50 6974.02 Mw~ - Standard (declination corrected) 9993.82 90.97 355.21 Y 6983.84 -6815.24 30.04 -6515.39 64.69 318.66 6380.42 6976.57 Mw~ - standard (declination corrected) 10022.60 89.40 337.47 Y 6978.41 -6803.74 28.78 -6486.73 61.85 346.51 6380.32 6969.80 MwD - standard (declination corrected) 10053.19 89.46 317.00 Y 6963.28 -6783.08 30.59 -6456.30 66.91 372.10 6380.63 6953.33 MwD - Standard (declination corrected) 10084.43 88.63 306.82 Y 6941.25 -6756.60 31.24 -6425.11 32.71 392.94 6381.15 6930.12 MwD - Standard (declination corrected) 10118.47 89.77 304.72 Y 6914.84 -6725.95 34.04 -6391.07 7.02 412.83 6381.62 6902.50 MwD - Standard (declination corrected) 10148.86 90.84 302.56 Y 6890.61 -6698.11 30.39 -6360.69 7.92 429.66 6381.46 6877.21 MwD - Standard (declination corrected) 10174.97 91.64 300.64 Y 6869.30 -6673.85 26.11 -6334.58 7.97 443.34 6380.90 6854.97 Mw~ - standard (declination corrected) 10207.15 91.70 299.24 Y 6842.54 -6643.61 32.18 -6302.42 4.36 459.40 6379.96 .6827.10 Mw~ - Standard (declination corrected) 10237.19 91.30 297.02 v 6817.09 -6615.07 30.04 -6272.39 7.50 473.56 6379.17 6800.62 MwD - Standard (declination corrected) 10262.02 92.29 295.27 Y 6795.64 Page 6 • 1C-251 Survey listing.txt -6591.24 24.83 -6247.57 8.10 484.49 6378.39 6778.34 Mw~ - standard (declination corrected) 10294.55 94.41 293.72 Y 6767.14 -6559.80 32.53 -6215.10 8.06 497.96 6376.49 6748.80 MwD - Standard (declination corrected) 10324.08 93.52 291.68 Y 6740.89 -6531.06 29.53 -6185.64 7.54 509.32 6374.45 6721.62 MwD - Standard (declination corrected) 10354.36 93.18 289.31 Y 6713.47 -6501.34 30.28 -6155.42 7.89 519.91 6372.68 6693.31 MwD - Standard (declination corrected) 10386.34 93.24 287.36 Y 6684.04 -6469.75 31.98 -6123.49 6.09 529.95 6370.89 6663.00 MwD - Standard (declination corrected) 10417.62 92.69 284.91 Y 6654.83 -6438.69 31.28 -6092.25 8.00 538.63 6369.27 6632.99 MwD - Standard (declination corrected) 10445.92 91.80 282.78 Y 6628.02 -6410.48 28.30 -6063.98 8.16 545.40 6368.16 6605.54 MwD - Standard (declination corrected) 10479.37 91.00 280.99 Y 6595.98 -6377.06 33.45 -6030.54 5.85 552.28 6367.35 6572.82 MWD - Standard (declination corrected) 10503.15 90.11 279.43 Y 6573.02 -6353.28 23.78 -6006.76 7.57 556.50 6367.12 6549.42 Mw~ - Standard (declination corrected) 10543.23 90.57 276.56 Y 6533.95 -6313.23 40.08 -5966.69 7.24 562.08 6366.88 6509.73 MwD - Standard (declination corrected) 10576.74 91.64 275.23 Y 6501.05 -6279.81 33.51 -5933.18 5.11 565.52 6366.23 6476.41 MwD - Standard (declination corrected) 10605.95 92.35 273.31 Y 6472.24 -6250.77 29.21 -5903.99 6.99 567.69 6365.22 6447.30 MwD - Standard (declination corrected) 10634.64 93.18 270.90 Y 6443.81 -6222.39 28.69 -5875.34 8.88 568.75 6363.83 6418.66 MwD - Standard (declination corrected) 10664.06 93.30 269.36 Y 6414.56 -6193.45 29.42 -5845.97 5.25 568.82 6362.17 6389.29 MwD - standard (declination corrected) 10695.28 92.62 270.39 Y 6383.50 -6162.76 31.22 -5814.79 3.95 568.75 6360.56 6358.11 Mw~ - standard (declination corrected) 10727.24 90.87 274.69 Y 6351.85 -6131.09 31.96 -5782.85 14.50 570.16 6359.58 6326.21 MwD - Standard (declination corrected) 10760.31 91.89 278.66 v 6319.50 -6098.09 33.07 -5749.80 12.39 574.00 6358.78 6293.38 MwD - Standard (declination corrected) 10784.58 92.50 282.00 Y 6296.14 -6073.84 24.27 -5725.55 14,00 578.35 6357.85 6269.52 Mw~ - standard (declination corrected) 10816.58 91.31 285.43 Y 6265.91 -6041.93 32.00 -5693.57 11.36 585.94 6356.79 6238.46 MwD - Standard (declination corrected) 10843.25 90.23 287.88 Y 6241.20 -6015.45 26.67 -5666.91 10.03 593.58 6356.43 6212.91 MwD - standard (declination corrected) 10875.24 89.28 286.39 Y 6211.68 -5983.71 31.99 -5634.92 5.54 603.01 6356.57 6182.34 Mw~ - Standard (declination corrected) 10918.42 90.81 282.78 Y 6171.17 Page 7 • • 1C-25L1 Survey listing.txt -5940.68 43.18 -5591.75 9.09 613.88 6356.53 6140.56 MwD - Standard (declination corrected) 10952.58 91.52 278.88 Y 6138.45 -5906.53 34.16 -5557.60 11.58 620.29 6355.83 6107.02 MwD - Standard (declination corrected) 10979.69 91.37 275.78 Y 6112.06 -5879.46 27.11 -5530.51 11.44 623.75 6355.15 6080.15 MWD - Standard (declination corrected) 11009.45 88.51 278.27 Y 6083.06 -5849.75 29.76 -5500.75 12.73 627.39 6355.18 6050.62 MwD - Standard (declination corrected) 11045.52 86.11 280.88 Y 6048.35 -5813.73 36.07 -5464.73 9.82 633.38 6356.87 6015.09 MwD - Standard (declination corrected) 11076.17 86.11 283.94 Y 6019.35 -5783.18 30.65 -5434.15 9.97 639.95 6358.95 5985.23 MwD - standard (declination corrected) 11107.81 84.38 286.39 Y 5989.98 -5751.78 31.64 -5402.62 9.46 648.20 6361.58 5954.80 MwD - Standard (declination corrected) 11145.26 84.54 288.00 Y 5955.79 -5714.80 37.45 -5365.35 4.28 659.22 6365.19 5919.20 MwD - standard (declination corrected) 11178.23 85.86 291.19 v 5926.27 -5682.41 32.97 -5332.50 10.47 670.23 6367.95 5888.25 MwD - Standard (declination corrected) 11207.34 86.48 294.21 Y 5900.94 -5654.08 29.11 -5303.46 10.57 681.44 6369.90 5861.46 MwD - standard (declination corrected) 11236.15 86.39 296.56 Y 5876.58 -5626.36 28.81 -5274.71 8.14 693.77 6371.69 5835.48 MwD - standard (declination corrected) 11267.88 88.08 297.50 Y 5850.27 -5596.05 31.73 -5243.01 6.09 708.17 6373.22 5807.25 MwD - Standard (declination corrected) 11303.52 88.36 294.29 Y 5820.38 -5561.80 35.64 -5207.40 9.02 723.73 6374.33 5775.21 MwD - Standard (declination corrected) 11332.70 89.89 292.46 Y 5795.27 -5533.42 29.18 -5178.22 8.19 735.31 6374.77 5748.43 MWD - standard (declination corrected) 11365.18 89.77 290.50 Y 5766.82 -5501.59 32.48 -5145.74 6.04 747.20 6374.87 5718.21 MwD - Standard (declination corrected) 11395.62 89.71 288.29 Y 5739.68 -5471.56 30.44 -5115.31 7.29 757.31 6375.01 5689.50 MwD - standard (declination corrected) 11428.29 87.53 287.14 Y 5710.17 -5439.20 32.67 -5082.65 7.53 767.25 6375.80 5658.39 MwD - Standard (declination corrected) 11465.96 86.54 285.07 Y 5675.78 -5401.79 37.67 -5045.03 6.08 777.68 6377.74 5622.25 MwD - Standard (declination corrected) 11496.54 86.64 283.12 Y 5647.48 -5371.35 30.58 -5014.51 6.39 785.12 6379.56 5592.64 MwD - standard (declination corrected) 11525.23 86.30 281.32 Y 5620.62 -5342.73 28.69 -4985.87 6.37 791.18 6381.33 5564.66 MwD - Standard (declination corrected) 11555.36 85.68 279.29 Y 5592.11 -5312.68 30.13 -4955.82 7.03 796.55 6383.44 5535.09 MwD - Standard (declination corrected) 11590.09 85.65 277.20 Y 5558.91 Page 8 1C-25L1 Survey listing.txt -5278.07 34.73 -4921.19 6.00 801.52 6386.06 5500.82 MwD - Standard (declination corrected) 11623.27 85.84 275.33 Y 5526.89 -5245.05 33.18 -4888.10 5.65 805.13 6388.52 5467.93 MwD - standard (declination corrected) 11656.69 86.02 271.68 Y 5494.27 -5211.93 33.42 -4854.77 10.91 807.16 6390.90 5434.66 MwD - Standard (declination corrected) 11688.75 85.95 268.99 Y 5462.67 -5180.41 32.06 -4822.79 8.35 807.35 6393.14 5402.68 MwD - standard (declination corrected) 11718.04 85.50 266.03 Y 5433.63 -5151.89 29.29 -4793.59 10.19 806.08 6395.33 5373.51 MwD - Standard (declination corrected) 11752.87 81.93 266.54 Y 5399.14 -5118.27 34.83 -4758.97 10.35 803.84 6399.14 5338.96 MwD - standard (declination corrected) 11804.00 81.93 266.54 Y 5348.72 -5069.03 51.13 -4708.35 0.00 800.79 6406.32 5288.43 Page 9 ~! J~ ~~~q DATA SUBMITTAL COMPLIANCE REPORT 10/15/2008 Permit to Drill 2061000 Well Name/No. KUPARUK RIV UNIT 1C-25L1 Operator CONOCOPHILLIPS ALASKA INC API No. 50-029-22941-60-00 MD 11804 TVD 6500 Completion Date 12/4/2006 Completion Status 1-OIL Current Status WAGIN I Y REQUIRED 1NFORMATION Mud Log No Samples No Directional Survey es - -- DATA INFORMATION Types Electric or Other Log s Run: GR / CNL / CCL / RES (data taken from Logs Portion of Master Well Data Maint Well Log Information: Log/ Electr Data Digital Dataset Log Log Run Interval OH / Ty Med/Frmt Number Name Scale Media No Start Stop CH Received Comments D D Asc _ Directional Survey 9793 11804 Open 12/8/2006 Directional Survey 9793 11804 Open 12/8/2006 Well Cores/Samples Information: Name Interval Start Stop Sent Received Sample Set Number Comments ADDITIONAL INFORMATION Well Cored? Y~ Chips Received? "' "' Analysis l~/~' Received? Comments: Daily History Received? Formation Tops ~~"'" ( YJ/, N Compliance Reviewed By: Date: ~U ~Ov ~~ ~_ ~ ~~C~ STATE OF ALASKA ~U~ ~ ~ ~~0~ ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATION~aS~~ ~~~ ~ ~~~ ~~~~. C~mmissian 1. Operations Performed: Abandon ^ Repair Well ^ Plug Perforations ^ Stimulate ^ Other .'Ilt,^ 'P'rod to WAG d'" Alter Casing ^ Pull Tubing ^ Perforate New Pool ^ Waiver ^ Time Extension ^ Change Approved Program. ^ Operat. Shutdown^ Perforate ^ Re-enter Suspended Well ^ 2. Operator Name: 4. Current Well Status: 5. Permit to Drill Number: ConocoPhillips Alaska, InC. Development 0 Exploratory ^ 206-100 / 3. Address: Strati ra hic g p ^ Service ^ 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-029-22941-60 7. KB Elevation (ft): 9. Well Name and Number. RKB 94' 1 C-25L1 - 8. Property Designatio Z$LS~Z ~ ?~ Z7 b~ ADL 2 10. Field/Pool(s): ALK 2292 Kuparuk River Field /Kuparuk Oil Pool 11. Present Well Condition Summary: Total Depth .measured .11804' feet true vertical 6500' feet Plugs (measured) Effective Depth measured 11804' feet Junk (measured) 9795' true vertical 6500' feet 2-3/8" Casing Length Size MD TVD -Burst ~ Collapse Structural CONDUCTOR 115' 16" 115' 115' SURFACE 6473' 9-5/8" 6567 4554' PRODUCTION 9656' 7" 9750' 6414' PRODUCTION LI 378' 3-1/2" 9794' 6440' L1 WINDOW 1' 2-7/8" 9796' Perforation depth: Measured depth: 9775-9788; 9788-9793 '; 9793-10454' true vertical depth: 6429-6437; 6437-6440 ; 6440-6462' Tubing (size, grade, and measured depth) 3-1/2" , L-80, 9452' MD . Packers &SSSV (type & measured depth) PKR =Baker 7" x 5" ZXP LT PKR = 9416' SSSV=NIP SSSV= 502' 12. Stimulation or cement squeeze summary: 5 ~F~ f~(jG ®~ 2~D7 ` Intervals treated (measured) Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casin Pressure Tubin Pressure Prior to well operation 712 ~ 237 8 931 295 Subsequent to operation 1805 979 75 14. Attachments 15. Well Class after proposed work: Copies of Logs and Surveys run _ Exploratory ^ Development ^ .Service 0 Daily Report of Well Operations X 16. Well Status after proposed work: Oil^ Gas^ WAGQ GINJ^ WINJ ^ WDSPL^ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or NIA if C.O. Exempt: 307-015 contact Bob Christensen /Bob Buchholz Printed Name Robert D. C istensen Title Production Engineering Technician Signature Phone 659-7535 Date ~~~ O.RiG1NAl..- ~ ~Z~.a7 Form 10-404 Revised 04/2004 i nl ~~~ y -- 1 C-25L1 DESCRIPTION OF WORK COMPLETED SUMMARY Date Even# Summary 07!23107 Commenced WAG Injection SARAH PAUN, GOVERNOR 333 W. 7th AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Robert Christensen Production Engineering Technician ConocoPhillips Alaska, Inc. PO Box 100360 Anchorage, AK 99510 Re: Kuparuk River Field, Kuparuk River Oil Pool, 1C-25L1 Sundry Number: 307-015 Dear Mr. Christensen: 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. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager). 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 rehearing. A request for rehearing 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. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. Sincerely, ~~~/ Dan T. Seamount Commissioner DATED this ~ day of January, 2007 Encl. aDCo -~oa ~a 1.19-~7 ~~ RECEIVED STATE OF ALASKA ~r~ ,~~~ 1 O Z~~7 ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROV~~a Oii & Gas Gans. Commission! 20 AAC 25.2so ~nl;E~orage 1. Type of Request: Abandon ^ Suspend ^ Operational Shutdown ^ Perforate ^ Waiver ^ Other Q Alter casing ^ Repairwell ^ Plug Perforations ^ Stimulate ^ Time Extension. ^ Producer to Chan e a roved ro ram g pp p g ^ Pull Tubing ^ Perforate New Pool ^ Injector Re-enter Suspended Well ^ Conversion 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development ^~ ~ Exploratory ^ 206-100 ' 3. Address: Stratigraphic ^ Service ^ 6. API Number:. P. O. Box 100360, Anchorage, Alaska 99510 50-029-22941-60 7. If perforating, closest approach in pool(s) opened by this operation to nearest property line 8. Well Name and .Number: where ownership or landownership changes: Spacing Exception Required? YeS ^ NO ^ 1C-25L1 " 9. Property Designation: ythL Z$L`/Z ,~D /,/O.a'7 ~ 10. KB Elevation (ft}: 11. Field/Pool(s): ~PL~82J3, ALK 2292 /' RKB 94' Kuparuk River Field / Kuparuk Oil Pool 12. PRESENT WELL CONDITION SUMMARY Total depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ff): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 11804' 6500' ~ 11804' 6500' 9795' Casing Length Size MD TVD Burst Collapse CONDUCTOR 115' 16" 115' 115' SURFACE 6473' 9-5/8" 6567 4554' PRODUCTION 9656' 7" 9750' 6414' PRODUCTION LINER TOP 378' 3-1/2" 9794' 6440' L1 WINDOW 1' 2_7/g~~ 9796' 6441' Slotted Liner 2029' 2-3/8" 10487 6461' Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 9775-9788'; 9788-9793'; 9793-10454' 6429-6437; 6437-6440;6440-6462' 3-~/2" L-80 9452' Packers and SSSV Type: Packers and SSSV MD (ft) PKR =Baker 7" x 5" ZXP LT PKR = 9416' SSSV=NIP SSSV= 502' 13. Attachments: Description Summary of Proposal Q 14. Well Class after proposed work: Detailed Operations Program ^ BOP Sketch ^ Exploratory ^ Development ^ Service ^~ 15. Estimated Date for 16. Well Status after proposed work: Commencing Operations: January 26, 2007 Oil ^ . Gas ^ Plugged ^ Abandoned ^ 17. Verbal Approval Date: WAG ~ GINJ ^ WINJ ^ WDSPL ^ Commission Representative: 18. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Bob Christensen /Bob Buchholz Printed Nam Ro D. C ri r1Ser1 Title: Production Engineering Technician Signature ~ Phone 659-7535 Date ) g B Commission Use Only Sundry Number: Conditions of approval: Notify Commission so that a representative may witness ~ ~ _. ~ f 5 Plug Integrity ^ BOP Test ^ Mechanical Integrity Test ~ Location Clearance ^ Other: ~~ .1~~4 ~ ~~Q! Subsequent Form Required: ~ APPROVED BY /~ J Approved by: ~"' ~ ~ OMMISSIONER THE COMMISSION Date: ` ` Form 10-403 Revised 06!2006 ' ,, ~ ~', ; ~,.,. (F; V /~'°~ ~..,, /~!s -D, Submit in Duplicat ~`~~ 1 C-25L1 DESCRIPTION SUMMARY OF PROPOSAL I ~~~~ ~l ~,~ ConocoPhillips Alaska Inc. requests approval to change the approved program for Kuparuk well 1 C-25L1 from Oil production to WAG FOR injection service.'/The conversion of well 1 C- 25L1 will provide pressure support to off-set producer 1C-21L1 (568 BOPD and 598 FGOR) and is expected to allow 1C-21 L1 to remain on-line full-time. The mother well (1 C-25) was completed as a 3-1/2" Slimhole Oil producer on April 29, 1999. The targeted "C" sands were encountered between 9781' - 9989' and (6432' - 6557' tvd). The CTD "C" sand lateral (1C-25L1) was completed on Dec. 05, 2006 utilizing 2-38" slotted liner to 10487 and (6461' tvd). The 1C-25/1C-25L1 7" production casing Inner Annulus is isolated from the 3-112" tubing and 3-112" production casing utilizing a Baker 7" x 5" ZXP LT Packer at 9416' and (6213' tvd). A Baker GEN II Monobore Flow-thru Whipstock (1C-25L1) is located at 6 and (6441' tvd). The 1C-25L1 lateral window is located at 9795' and (6441' tvd). A Cement Bond Log obtained on June 24, 2006 indicates good cement integrity from 9452' - 9792' and (6234' - 6439' tvd). The 9-5/8" Surface casing (6567 tvd / 4554' tvd) was cemented with 790 sx AS Ill and 650 sx Class G. The 7" Production casing (9750' and / 6414' tvd) was cemented with 170 sx Class G. The 3-1/2" Production liner (10138' and / 6648' tvd) was cemented with 260 sx Class G. ~~ J~ f • ~• • ~ • i•- ~ ~ ~ , Cement Bond Log __ _ ° STMT-~B PS~tIS 24 June ~~~5 N Q ` [ L EY} . 16833 FNL 13277 FWL ~ Efev.: K.B. . ' a N ~ r ~ ~ z at Surface. ~ G.L. 60.2 ft o :A ~ z "- ,L o O ~ D,F. 94:2 ft ,. t ~ ~ n. cM. N UO o Q ~ -, Permanent Datum: M$L _ . Elev:: ~ z Y ~ .- v r U ~ Log.Measured From: KB. above Perm. Datum .>_ c c' Drilling Measured From: !B: - ~ ~ o ~ o . ~ o ~,. ~ o ~ RPI Serial No. - m ~ ~ ~ ' U 50=029-22941-00 Section 12 . ' To~ninship i i N Range 10E .loggia Dafe` . 24-Jun-2006 Run Number ~ .Depth Driller . , 10034 ft ,_ Schiumberger Depth, 9954 ft ~otttsm Lag tn#-ervat 9948 #t Top log interval 9400 ft Caslnrd =1uld Ty~2 Sea~a~zr Salinity Densit 8lbm/ al Fluid Level • BIT/GASING/TUBWG STRING Bit Size 8.000 in - From To Casirig/Tubing Size 3,500 in 'i Wei ht 9:31bm/ft I Grade L-80 From 0 ft To 9452 #t Maximum Recorded Temperatures Logger On Bottom Time 24-Jun-2006 Unit Number Location 2128 Prudhoe Ba Recorded By Hines ` Witnessed B ~ Evan Refill - 1 l 1-`- ~ j '~ ~ ~ ~ r f ~ F I ' ~~ ~^ ~ ~{ I a ~~ ~~i I~ r " ~ _ ~ ~ . ~ n ~ r :I' ~ ~ d -~~ ~~I~ r l l , ~, _~ ~ a ' .~ ~ II ~ ~ I ~~'j~ ~ ,~ t - r x ~ ~~ ~ ~ ~ ~~ ~ f ~~ o ~ ~ ~ ~ ;~ r t I~ ~ ~ ~ ~ 7 ~r I l e 1 ~ ~ t i k ~_ I ~ ~ , ~I ~~ f . i , y i t~7 I 4 f~ ~'~ ~ y f t , .: tit ~ ~ i j ~ ~~ ,{ 1 ~ i~ 77 : U'. ~ ,I~ ~ ~~ S . 1~ ~ F ~ , 1 i ~, .i ' , ~ ~ ` ~ I t , iE ~ "- a ~ ~ ~ ~ _. ~ ~ ~ I , ~ v~l ~ ; l ~, ~ ~ ~ ~ , ~! n -? a~~ a, ~ I K ,~ I i ~~ ~ ~ ~ ; I ~ ~ ~ r ~ 1 ~ ~ k ~ ,~ I{ ~I ~ ,I ]~_ _ r 5u r f 5 ~ I~ ; ~ ~ ~ ~r 3 ~~ ' ~'! ~ - ~ . 'r.. :~~ 9 ~'4~ ~.i~ { ~ ~ ` H k 1 I ~ ~ I } r '_ I P ~ ui I2 ~ ~if CI ~ ~ r ~ ~ i. ~ ~~~i ~h i ~ ,i~ l ; t, .' ~ ~ I I -r ~~ ~ ~ ~I I ~ ' E E- ~``'~ ' ~ ~ ti j f~~ ~'ff I ,~ ~~' ' k r. i ~ ~~~ _ , . I ~i ',, 1 ,I . I ~ ~ ~ < L ; a II ~~ ~ _ ~ ~ ~ ~ , ~ ~ 1 1 ; y ~ ~ ~ 4 ~ ~ I I~ i 6 f '~, i ~ Fe :. k f I I ~f ~ ~ ~ ` ~ ~ ~ ,'',~ - ~ . r"' ~~ i 1 I ~ 3t,v, ~[ r ~ ` ~a a \ : ~ l it r i~ ~ , ~' k ~~1 i ~i ti. ~ ..~ ~' ~~ ~ ~ ~~ I , r (, F 9 I ~ ~ { ~ l ~ it3k .b~ • • ~~ ~ KRU 1 C-25L1 • • i~C:3A_NICAL INTEGRITY REvORT .PUD ~-___ --G r.....,~~ .. ~ . ~~~~ ~~~ ~ ~~ OPER ~ FIELD ~,Q~'~_ 1~~~-~,`-J 1~ i.~~I,.I. NUI~ER 1~~~5 ~- ac~ S ~~~ n ~ LL DAT ~_ TD : ?~.. TV`D ; ?BTD : ?~D TVD Cas i:-:g : ~y~ Shoe : ~'l5~ t-~ C~~\~^` TVD ; DV : ?~ TVA _;:,e= . `~l~ ~ Shoe . ~b l`3~S '~ ~Obt1 ~ T`TS ; .C: ~-~ _'~D _~oi~v. 3ti1~. Packer 5~,~ :~ ~~`~ k~T~TD; Set ~t c_ ole S~ce ZS\11_ and ~~ Perfs ~t~~~ " ~~~`1 fi ~ to ~~ Rlq~~ . Sto~~ \; ~ ~' ~'1, ~ ~ -- lt~ ~~~ `~C'r'.~?~=Cam.'., INTEGRITY - P?_RT #? n~.nlus Press Test _~ 15 nin :;0 min CoQents i ~CH11?~IC~_%, 1NTEGRIT'i - PART # 2 ~-°''~I,15 "~ 3h ~~~~ Cement Volumes : Amt. Liner ~~5~ Cs~ DV Cr.t Jo'1 to cover oers ~ 30~a~ S ~~ ~~~s o~ Crcy"~rc+n~ C~yQ~` ~t~'~j~~yC SGI~` eoretical TCC CG~~~ T~ ~~5 C`lC~~~n~~~ `~~F ~ mar ~~ Cement Bond Log (Yes or No) ~~_-~ 7n AOGCC File ~~;~_ C3L Evaluation, gone above perfs ~ - ~21t~v~ ~ i~ ~~OC~ Production I..og: 'r'y-pe CONCLUS?Oi1S : Part r 1 :_ -7- ?ar~ l2. _ M~ ~ ~~ ~ F,valuati on • • Well IC-2SL1 ~dCo--- ~d~ Assessment of Cement and Wells Within One-Qua~-te~- Mile Aj~~plicatiou to Convert to Water Injection January 12, 2007 1C-25 Cement Evaluation Well 1C-2S is a Kupanik C sand producer equipped with 3'/z" tubing and 3%" production liner. The 3'/2" liner spans the entire C sand from 9416' - 10,138' MD, 6213' - 6648' TVD. The Ll lateral in well 1C-25 was recently drilled and completed with 23/s" slotted liner in the C Sand, while still leaving the original perforations open in the 1C-25 wellbore. It is proposed that well 1 C-25 and the 1 C-25L 1 lateral be converted to water injection. The only other well within one-quarter mile of the C sand of 1C-25 or 1C-25L1 is well 1C-27 to the east. The 3'/z" liner across the Kuparuk C sand in well 1 C-25 was cemented in place on April 26, 1999. A total of 33 bbl of 15.8 ppg cement were pumped, which compares to a gauge open hole volume of 13.9 bbl. The cement job proceedec] smoothly without any problems. hull rehu7~s were maintained throughout the cementing operation, and the pipe was reciprocated until shortly before the plug was bumped. Gemoco "spirolator" centralizers were installed on every joint. After releasing .from the liner hanger, 13 bbl of cement were circulated off the top of the liner. A SCMT log run on June 24, 2006 shows excellent cement coverage over the entire 3'/z" liner. The 1 C-25L1 lateral exits the 3'/z" liner at 9793' MD (6440' TVD), which leaves a 223' cemented interval across the 3'/z" liner up to the 7" shoe at 9570' MD. 1C-27 Cement Evaluation Well 1 C-27 is a horizontal producer in the Kuparlik C sand, although there are plans to convert it to water injection in 2007. It is completed with 7" production casing cemented to a depth of 10,787' MD (6403' TVD) with 4'/z" slotted liner installed in the horizontal section. There is approximately 490' of separation from well l C-25L1 at 6482' TVD in the C Sand. The 7" casing in well 1 C-27 was cemented in place on June 3, 1999 using 37.5 bbl of 15.8 ppg cement. The job proceeded smoothly without any problems. The calculated top of ceme~it is reported as 9987' MD (6202' TVD), but no cement evaluation log was run. Full reh~nls were maintained during the cement job, and the casing was reciprocated until shortly before the plug was bumped. Gemoco bow-spring centralizers were installed on every joint far the bottom 25 joints. The 7" casing was pressure tested to 3500 psi prior to drilling out, but for some unk~iown reason no LOT or hIT was conducted after drilling out the shoe. J. Gary Eller ConocoPhillips Wells Engineer .~ • • Review of Sundry Applications 307-014&015 ConocoPhillips Alaska, Inc. Wells Kuparuk River Unit 1C-25 & 1C-25L1 Kuparuk River Field, Kuparuk River Oil Pool AOGCC Permits 199-031 & 206-100 Requested Action: ConocoPhillips Alaska, Inc. (CPAI) proposes to convert an existing development wellbore and recently completed lateral to WAG injection. Recommendation: I recommend approval of CPAI's proposed actions Discussion: CPAI proposes to convert well 1 C-25 and it's lateral 1 C-25L1 from development oil status to WAG injection service. Both wellbores are completed in the Kuparuk `C sand' and the conversion is intended to provide production support to other `C sand development wells in the area. The original wellbore was completed and began production in September 1999 and the lateral was drilled and completed in December 2006. The permit to drill application for the lateral indicated that the well was intended for conversion to a WAG injector upon its completion. To date the original wellbore has produced a total of 1.8 million barrels of oil and is still producing at over 500 barrels per day. There is no production data available for the lateral. In December 2004, the most recent available data, the bottomhole pressure was 1,750 psi at a depth of 6,209' TVDSS. This is well below the original Kuparuk pressure of 3,135 psi and the bubble point of 2,600 psi. The pressure is also significantly less than that reported during 2005 for other 1C producers, which ranged from 2,100 psi to almost 3,500 psi. The significant pressure difference between this well and the other producers on the pad indicates that the portion of the reservoir surrounding 1C-25 and 1C-25L is not receiving adequate pressure support. Therefore, converting this well to a WAG injector even though it is still capable of producing at a high rate should enhance ultimate recovery for this portion of the reservoir. • • Conclusion: Converting these wells to WAG injection service should improve current operations in this portion of the pool. Therefore, it is prudent to authorize CPAI to perform their requested actions because of the future benefits that should be achieved. D.S. Roby ~! Reservoir Engineer January 11, 2007 STATE OF ALASKA ~ ALASKA AND GAS CONSERVATION COMMI ~ ON ~~CElVEC~ DEC 2 8 2006 WELL COMPLETION OR RECOMPLETION REPORT AND L4~tska Qif & Gas Cons. Commission Anch 1a. Well Status: ®Oil ~ ^ Gas ^ Plugged ^ Abandoned ^ Suspended ^ WAG 20AAC25.105 2oAAC2s.,,o ^ GINJ ^ WINJ ^ WDSPL No. of Completions One Other 1b. Well Class: ®Development. ^ Exploratory ^ Stratigraphic ^ Service 2. Operator Name: Conoco Phillips Alaska Inc. 5. Date Comp., Susp., or Aban ~ U~ 12/4/2006 ~ Q~ 12. Permit to Drill Number 206-100 3. Address: Go P.O. Box 196612, Anchorage, Alaska 99519-6612 6. Date Spudded ~ 11/25/2006 13. API Number 50-029-22941-60-00 4a. Location of Well (Governmental Section): Surface: 1 ' ' 7. Date T.D. Reached 11/30/2006 ~ 14. Well Name and Number: 1C-25L1 693 FNL, 1327 FWL, SEC. 12, T11 N, R10E, UM • Top of Productive Horizon: 1487' FNL, 2017' FEL, SEC 07, T11 N, R11 E, UM 8. KB Elevation (ft): 94.15 15. Field /Pool(s): Kuparuk River Unit /Kuparuk Total Depth: 893' FNL, 3574' FEL, SEC 07, T11 N, R11 E, UM 9. Ptug Back Depth (MD+TVD) 11804 + 6500 Ft River Pool 4b. Location of Well (State Base Plane Coordinates): Surface: x- 562335 • y- 5968546 • Zone- ASP4 10. Total Depth (MD+TVD) 11804 + 6500. Ft 16. Property Designation: ADL 028242 ' TPI: x- 569180 y- 5968813 Zone- ASP4 Total Depth: x- 567615 • y- 5969392 • Zone- ASP4 11. Depth where SSSV set None MD 17. Land Use Permit: 18. Directional Survey ®Yes ^ No 19. Water depth, if offshore N/A MSL 20. Thickness of Permafrost 1915' (Approx.) 21. Logs Run: GR/CNL/CCL/RES //1' ® ~ ' 6`~~/~~'1'V'~ /sd /•2•~7 22. CASING, LINER AND CEMENTING RECORD CASING SETTING DEPTH MD SETTING DEPTH TVD HOLE AMOUNT S{ZE WT. PER FT. GRADE TOP BOTTOM TOP BOTTOM SIZE CEMENTING RECORD PULLED 16" 62.5# R-3 Surface 114' Surface 114' 24" 9 cu ds Hi h Earl 9-5/8" 29.7# L-80 Surface 6567' Surface 4554' 12-1/4" 796 sx AS III L 653 sx Class 'G' 7" 26# L-8 Surf ce 9570' Surface 63 8-1/2" 180 sx CI 'G' 3-1/2" 9.3# L-80 9416' 6213' 6441' 6-1/8" 180 sx Class'G' 2-3/8" 4.7# L-80 9775' 10487' 6429' 6461' 3" Uncemented Slotted Liner 23. Perforations open to Production (MD + TVD of Top and 24. TUBING RECORD BOttOm InteNal, Size and Number; if none, state "none"): SIZE DEPTH .SET MD PACKER SET MD 2-3/8" Slotted Section 3" Open Hole 3-1/2", 9.3#, L-80 9452' 9422' MD TVD MD TVD 9781' - 10454' 6432' - 6462' 1048T - 11804' 6461' - 6500' Z5- ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL MD AMOUNT Hi KIND OF MATERIAL USED 2500' Freeze Protect with 33 Bbls Diesel 26. PRODUCTION TEST Date First Production: December 11, 2006 Method of Operation (Flowing, Gas Lift, etc.): Gas Lift Date of Test 12/28/2006 Hours Tested 24 PRODUCTION FOR TEST PERIOD OIL-BBL 702 GAS-MCF 400 WATER-BBL 97 CHOKE SIZE 176 GAS-OIL RATIO 570 Flow Tubing Press. 229 Casing Pressure 1,330 CALCULAreD 24-HouR RATE OIL-BBL 702 GAS-MCF 400 WATER-BBL 97 OIL GRAVITY-API (CORK) 22 27. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water (attach sOparate sheet, if necessary). Submit core chips; if none, state "none". ~ ~ ~ ~~4° None M~, t~~~.'a ~~~- .Ic'~~~' ~ !u~f 12`,1~'p~ Form 10-407 Revised 12/2003 CONTINUED ON REVERSE SIDE CR161NgL / t7 28. GEOLOGIC MARKERS 29. TION TESTS Include and briefly s marize test results. List intervals tested, NnanE MD TVD and attach detailed supporting data as necessary. If no tests were conducted, state "None". KOP (Kuparuk C4) 9795' 6441' None Base C4 /Top C3 9870' 6471' Top C3 /Base C4 (Inverted) 10190' 6475' Base C4 /Top C3 11583' 6480' 30. List of Attachments: Summary of Daily Drilling Reports, Well Schematic Diagram, Surveys 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. Si d / ~ ~2 ~ ~ gne Title Technical Assistant Date Terrie Hubble ' P l 1 C-25L1 206-100 Prepared By NameMumber: Terrie Hubble, 564-4628 Well Number Permit No. / A royal NO. Drilling Engineer: Gary Eller, 263-4172 INSTRUCTIONS GeNew-~: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. bean 1a: Classification of Service Wells: Gas Injection, Water Injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. bear 4b: TPI (Top of Producing Interval). IreM 8: The Kelly Bushing elevation in feet above mean low low water. Use same as reference for depth measurements given in other spaces on this form and in any attachments. Irenr 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). bear 20: True vertical thickness. Irenr 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. bean Z3: 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). bear 28: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, or Other (explain). bear 27: If no cores taken, indicate "None". bear 29: List all test information. If none, state "None". Form 10-407 Revised 12/2003 Submit Original Only BP AMERICA Operations Summary Report Legal Well Name: 1 C-25 Common Well Name: 1C-25 Event Name: REENTER+COMPLETE Start: 11/23/2006 Contractor Name: NORDIC CALISTA Rig Release: 12/5/2006 Rig Name: NORDIC 2 Rig Number: Date From - To ~ Hours Task Code i NPT ~ Phase 11 /23/2006 12:00 - 17:00 5.00 MOB P I PRE 17:00 - 17:25 I 0.42 I MOB I P I I PRE 17:25 - 17:35 I 0.171 MOB P I PRE 17:35 - 18:00 0.42 MOB P PRE 18:00 - 18:20 0.33 MOB P PRE 18:20 - 19:00 I 0.671 MOB I P I I PRE 19:00 - 23:00 I 4.001 BOPSUFj P I PRE 23:00 - 00:00 I 1.001 BOPSUFi P I I PRE 11/24/2006 100:00 - 04:30 I 4.501 BOPSUR P I I PRE 04:30 - 04:45) 0.251 RIGU I P I I PRE 04:45 - 07:30 2.75 RIGU P PRE 07:30 - 10:30 3.00 BOPSU P PRE 10:30 - 11:15 I 0.751 RIGU (P I I PRE 11:15 - 14:00 I 2.751 RIGU I P I I PRE 14:00 - 00:00 I 10.00 I RIGU I N I SFAL I PRE Page 1 of 10 Spud Date: 11/20/2006 End: Description of Operations Safety mtg to move off well. Rig has been running on generator 3. Prep to jack up rig and couldn't get generator 1 started due to low batteries. Generator 2 head gaskets have been removed for major repairs. Need two generators to move. Fire up #1 and #3 went down. Wait on repairs Move off of 1C-14. Move rig down the Pad and line up in front of 1 C-25 PSJM review moving over new well procedures and job assignments. Spot rig over wellhead. Crew change. PJSM review plan forward and work to do prior to rig acceptance. Finish spotting and leveling rig over wellhead. Rig acceptted at 1900 hrs. Start NU BOPE. Prep reel to drop out and change for 2" a-line reel. Install Handi-Berm around cellar. Test 7-1/16" BOPE 250psi low / 3500psi high for 5 min each. AOGCC contacted. Continue to test BOP's. Load out 2" cementing coil reel from rig. Install a-line reel # 14683. MU internal connector w/ 1/2" pullback line. Drawdown test on Koomey -good. PJSM: review procedures for pulling coil from reel house and stabbing into injector. Pull and stab coil into injector. FMC Kuparuk hand bring Kuparuk lubricator tools to floor. Pull BPV after several attempts (latched okay w/o using a bowspring centralizer). RDMO FMC lubricator. Find tubing is on a vac, IA 810, OA 300 DTH crew move tiger tank w/ two loaders and RU hardline Attempt to fill CT w/ biozan while circ to bung hole, but found HP line frozen Circ fill CT w/ biozan water 0.95/700. PT reel and hardline to 4000 psi Stab on with injector. Reverse slack back. PT inner reel valve ~ 3800 psi. Cut off 170' of 2" CT. Install Kendall CTC BHI find that they have lost continuity in cable running from reel house to BHI shack on ground. This gets confusing to say the least. First problem found was with a 1/4 turn wire connection on end of the cable in MWD shack. Soldered connection came apart. Fixed that but still a problem. Replaced the entire "Artie Grade shielded coaxial cable" from the reel house to the BHI MWD shack. Soldered connections at both ends again. Still had "open" connection some place. Checked pigtail from coil's a-line to SLB's collector -good. Connections on this pigtail are "terminal" block type. E-line side comes into a junction box which is mounted inside the reel, a pigtail wire comes out of junction box and is connected with a Jupiter fitting at the collector. (SLB's collector has Jupiter connections in/out) We have not had a problem here for some time. Tested the BHI's coaxial wire /Jupiter connection on reel house side and found this to again be the problem. Now for Printed: 12/11/2006 1:43:02 PM BP AMERICA Operations Summary Report Page 2 of 10 Legal Well Name: 1 C-25 Common Well Name: 1 C-25 Spud Date: 11 /20/2006 Event Name: REENTER+COMPLETE Start: 11/23/2006 End: Contractor Name: NORDIC CALISTA Rig Release: 12/5/2006 Rig Name: NORDIC 2 Rig Number: Date ~ From - To ~, Hours Task ~ Code NPT Phase Description of Operations ~L__ 11/24/2006 14:00 - 00:00 10.00 RIGU N SFAL PRE the real story behind this connection point. Historically this simple connection point has caused delays and downtime amounting to tens of thousands of dollars in lost time over the past several years. tt's almost impossible to solder the stiff coaxial cable to the Jupiter connector and have a lasting connection. There's too much movement at the collector and this movement causes the soldered connection to break. Why this hasn't been reengineered is a mystery. So to temporarilly solve the problem until something better can be found we have constructed a pigtail made of sutible wire for the Jupiter connection on the collector going to another junction box mounted on the reel stand. BHI's coaxial cable comes into this box. Wire ends are screwed to a terminal block. No soldering involved. Megged all wires and no problems found. Obviously the less connection points there is the less chance for something to cause a problem. We suggest BHI look for sutible cable going to the reel house with the correct connections (professionally made) on each end and to have spare cables ready to go if needed. Or move the MW D package to the Ops cab and shorten the wire runs entirely. 11/25/2006 00:00 - 00:10 0.17 RIGU P PRE Pull test Kendall CTC to 35k. 00:10 -00:45 0.58 RIGU P PRE Head-up BHI's upper quick connect. Meg tested -failed. Must have nicked wire during head-up procedure. 00:45 - 01:45 1.00 RIGU N HMAN PRE Cut-off Kendal connector. Cut-off 10' of coil. Circulate to warm coil. Rehead Kendall CTC and pull test to 35k. circ and warm coil. 01:45 - 03:05 1.33 STWHIP N WEXIT Head-up BHI's UOC again. Meg tested good. Tryed to circulate. Coil frozen. 03:05 - 04:45 1.67 STWHIP N WEXIT PU stinger RIH to 1450' and unthaw coil. POH. LD stinger. P7 Kendal CTC and UOC to 3500psi. 04:45 - 06:30 1.75 STWHIP P WEXIT PU BHA #1. MU injector with a 3' and 5' sections of lubricator in case pressure undeployment in required. Currently well is taking fluid at a rate of 6bbls/hr 06:30 - 06:50 0.33 STWHIP P WEXIT Tag up. RIH 2.5'. Set 2-3/8" combis and perform push pull test 06:50 - 08:40 1.83 STWHIP P WEXIT RIH w/ BHA #1 w/ 2.74" HCC window mill w/ 2.74" SR on BHI MW D assy circ thru motor 0.28/580 w/ bio water w/o returns. See FL at 1750'. At 4400' lost 100 psi CTP to 480 psi-must be frac press ECD=7.7. Now are pushing fluid away while RIH. PU at 8450' 24.5k-still no returns, 0.25/430 = 7.5 ECD Initial PVT 158, IA 410, OA 205 08:40 - 09:00 0.33 STWHIP P WEXIT 9750' 28.5k 0.4/480 RIH and tag at 9806' CTD. PUH 28k to 9800'. Start pump 1.52/0/2330 ECD 8.2 Ease in hole and first MW at 9805.4'. Corr to TOWS at 9795.0' and flag 09:00 - 10:45 1.75 STWHIP P WEXIT Begin time milling from 9795.0' 1.53/0/2430 ECD 8.5 w/ 1% KCI w/ 2 ppb biozan. Mill to 9797' 10:45 - 11:05 0.33 STWHIP P WEXIT Pickup 20' at 9797' 26.4k Swap to used Flo Pro after fin pump 290 bbls bio water. Resume time milling from 9797.0' 1.55/0/2525 w/ 1.5k wob 100 psi dill w/ 9.0 ECD 11:05 - 12:30 1.42 STWHIP P WEXIT Swap to SW at 9797.4' 1.54/0/2300 w/ 8.65 ECD. Mill to 9799' 12:30 - 14:00 1.50 STWHIP P WEXIT Pickup 20' at 9799' 27.6k Resume time milling from 9799' 1.56/0/2230 w/ 8.7 ECD. Drilling formation from 9800.6' to r Printed: 12/11/2006 1:43:02 PM BP AMERICA Operations Summary Report Page 3 of 10 Legal Well Name: 1 C-25 Common W ell Name: 1 C-25 Spud Date: 11/20/2006 Event Nam e: REENTE R+COM PLET E Start : 11/23/2006 End: Contractor Name: NORDIC CALIST A Rig Release: 12/5/2006 Rig Name: NORDIC 2 Rig Number: Date ~ From - To ', Hours ' Task Cade ~ RIPT ~ Phase ~ Description of Operations 11 /25/2006 12:30 - 14:00 1.50 STW H I P P WEXIT 9801' 14:00 - 14:30 0.50 STWHIP P WEXIT Pickup 20' at 9801' 27.5k Resume drilling formation from 9801-9811' 14:30 - 15:00 0.50 STWHIP P WEXIT Backream and ream until clean 1.55/0/2460 w/ 8.74 ECD. Dry drift, clean 15:00 - 16:45 1.75 STWHIP P WEXIT POH circ 1.5/2000 to surface (not a drop of returns all day) 16:45 - 17:25 0.67 STWHIP P WEXIT LD milling assy. Mill and SR were in gauge and mill had center wear 17:25 - 19:30 2.08 DRILL P PRODi MU build BHA. Trouble clearing wellhead with 2.8 motor. 19:30 - 21:45 2.25 DRILL P PROD1 RIH w/ BHA #2 (61.40') open EDC pumping min rate .43 no returns to 9540'. 21:45 - 22:25 0.67 DRILL P PROD1 Log tie-in -12.5' 22:25 - 22:40 0.25 DRILL P PROD1 Close EDC RIH w/ HSTF tagged at 9812'. Rate= 1.47 FS= 1630 22:40 - 00:00 1.33 DRILL P PROD1 Directionally drill build section f/ 9812' 1.47 bpm / 1630psi FS pumping seawater no returns. Ann= 2890psi small returns at midnight 0.2bpm 11/26/2006 00:00 - 05:00 5.00 DRILL P PRODi Directionally drill ahead with build section f/ 9835' 1.46/0.22 free-spin= 1830psi ann= 2914psi 1-2K wob 20-30'/hr TF= 55L pumping seawater with 20 bbl flo-pro sweeps. 05:00 - 05:30 0.50 DRILL P PROD1 Pump 10 bbls flo-pro make wiper trip to window. Repeat wiper trip PU wt 26k pump another 10 bbl sweep. 05:30 - 06:00 0.50 DRILL P PROD1 Dill ahead f/ 9912' 1.52 / 0.30 2100fs motor wants to stall fairly easily. Increase rate to 1.65 2275fs. 06:00 - 10:30 4.50 DRILL P PROD1 Drill from 9915' 1.54/0.35/2220/85L w/ 9.27 ECD at 90 deg NBI. Drill to 10020' and returns steadily improved to as high as 0.6 bpm. Pumping avg 100 bbs SW followed by 10 bbls used Flo Pro mud to aid slide and cuttings transport 10:30 - 10:50 0.33 DRILL P PROD1 W iper to window was clean 10:50 - 12:55 2.08 DRILL P PROD1 Drill from 10020' 1.6/0.58/2380/85L w! 9.31 ECD at 89 deg NBI and finish turn at 10070' (6380' TVD) 1.61/0.65/2260. Stage 20 bbl Flo Pro sweep followed by SW 12:55 - 13:10 0.25 DRILL P PROD1 Wiper thru window, clean. Open EDC 13:10 - 15:00 1.83 DRILL P PROD1 POOH. Had trouble getting by all completion equipment and GLM 6 at 9391'. Had to orient straight up to get by. Also, saw overpull at nearly every connection to 8200'. Pull OOH at reduced speed and continue to catch collars and min ID's 15:00 - 15:30 0.50 DRILL P PROD1 LD build assy. Bit was 1-1-I w/ no chipped cutters anywhere. Assume hardband (wear ring) on motor was catching min ID's 15:30 - 16:00 0.50 LCR P PROD1 MU nozzle BHA 16:00 - 17:40 1.67 LCR P PROD1 RIH w/ BHA #3 (2.25" nozzle w/ 0.75" hole on 5' stinger) circ SW C~ min rate w/o returns 0.33/0/30 17:40 - 17:50 0.17 LCR P PROD1 Corr -10' at 9760'. RIH clean thru window to 9850', clean. PUH 28.1 k at 30'/min thru window 17:50 - 20:15 2.42 LCR P PROD1 Park above window at 9775' and pump min rate SW to keep CT warm while WO CaC03 pill from MI. MI had trouble building a 25 bbl pill due to not having any small pits available. Hold PJSM review pumping procedures. 20:15 - 23:00 2.75 LCR P PROD1 With coil at 9775' pump 10 bbls flo-pro, 25 bbls CaC03 pill (mixed at 75#/bbl wt= 9.5ppg), followed by 10 bbls flo-pro. Rate 2 bpm 2350psi, no returns after 30 bbls fluid pumped returns > .70bpm (U-tube). Purnp 2bbls out EOP slow rate to lbpm and TOH 1:1 laying remaining pill Printed: 12/11/2006 1:43:02 PM BP AMERfCA Operations Summary Report Page 4 of 10 Legal Well Name: 1 C-25 Common Well Name: 1C-25 Spud Date: 11/20/2006 Event Name: REENTER+COMPLETE Start: 11/23/2006 End: Contractor Name: NORDIC CALISTA Rig Release: 12/5/2006 Rig Name: NORDIC 2 Rig Number: Date (From - To Hours Task ~ Code NPT Phase Description of Operations 11/26/2006 120:15 - 23:00 ~ 2.75 LCR ~ P ~ ~ PROD1 Stop at 5000' check in/out rate 1.0 to .38 continue OOH at 11/27/2006 00:00 - 02:20 ~ 2.33 DRILL N SFAL PROD1 02:20 - 03:40 1.331 DRILL P I (PROD1 03:40 - 05:30 I 1.831 DRILL I P I I PROD1 05:30 - 06:30 I 1.001 DRILL I P I I PROD1 06:30 - 07:00 I 0.501 DRILL I P I I PROD1 07:00 - 09:00 2.00 DRILL P PROD1 09:00 - 10:10 1.17 DRILL P PROD1 10:10 - 12:00 I 1.831 DRILL I P I I PROD1 12:00 - 12:45 I 0.751 DRILL I P I I PROD1 12:45 - 13:20 I 0.581 DRILL I P I I PROD1 13:20 - 13:45 I 0.421 DRILL I P I I PROD1 13:45 - 14:15 0.50 DRILL P PROD1 14:15 - 15:30 1.25 DRILL P PROD1 15:30 - 16:00 0.50 DRILL P PROD1 16:00 - 17:30 1.50 DRILL P PROD1 17:30 - 18:30 1.00 DRILL P PROD1 18:30 - 20:35 2.08 DRILL P PROD1 min rate. LD stinger. Meg tested line...problem somewhere Continue tracing open connection on a-tine. Narrowed down to flow sub. PU lateral BHA w/ resistivity. Surface tested good. Stab on injector. TIH 106'/min pumping .23 min rate w/open EDC no returns. Should have +/- 1.23 bpm returns. Tagged 'D' nipple at 9410'. PU orient around at differrent TF's. Possibly tagging on motors wear pad. Nipple has a 2.75" ID Work to get thru D nipple w/o success using all tricks including trying to rotate by Open EDC. Pump leftover 19 bbls of 75#/bbl SafeCarb mixture in pit 4 and chased w/ 10 bbls mud followed by SW down the CT 1.43/0.4/1440 PUH from 9400' after one bbl above BHA and maintain 1.3 bpm while adjusting POH speed to get 0.1 bpm return rate while letting well take the rest. No increase in returns noted POOH circ thru EDC 1.3/0.1/1300 At surface. BHA is covered with dry asphaltines. No damage to bit. Bit would not pass a 2.80" gauge ring at the gauge protection cutter on the shoulder (this is a TC cutter that is normally ground down to guage of <2.73") MU rebuilt Hycalog on same BHA RIH w/ BHA #4 circ thru EDC 0.25/0/44 w/ mud. Slow to 20'/min at 9380' and have very sli wt loss thru all restrictions. RIH to 9540' Log tie-in down from 9540' circ at min rate w/o returns, corr -9'. Close EDC RIH thru window, clean. Precationary ream to TD 10-20'/min w/ 1.5/0/2200 initially. Finally start getting returns at 9900' 1.5/0.5/2400 which is about the same as yesterday when on SW. Swap back to SW Tag at 10071' w/ 1.5/0.82/2500 w/ 10.0 ECD Wiper back to window. Pulled tite and couldn't go back down at 9870' w/ no MW. Assume CTC is hung up in cuttings just below window. Took three tries to wash away solids. Continue up hole to 9830' 1.49/0.75/2330 w/ SW at bit and 9.93 ECD Log MAD pass down from 9835' 1.5/0.63/2460/DTF Drill from 10071' 1.5/0.63/2460/90L w/ 100-200 psi dill, 1.5-2.5k wob w/ 9.78 ECD at 90 deg while pumping 100 bbls SW followed by 10 bbls Flo Pro. Drill to 10150' Wiper to window was clean Drill from 10150' 1.50/0.93/2400/45L w/ 100-200 psi dill, 1.3-2.5k wob w/ 9.63 ECD at 91 deg. Drill to 10300' while bringing inch up to 95 deg. Pump 20 bbl mud sweep Wiper to window Directionally drill ahead f/ 10300' 1.50 / .94 2100psi free-spin 2-300psi motorwork 1-2k wob 70-80'/hr ann= 3260psi. Good wt transfer +4k coil wt. Pumping 10bb1 used flo-pro sweeps for every 100bb1 of seawater. At 10450 returns decreased fro .95 to .55 bpm Printed: 12/11/2006 1:43:02 PM BP AMERICA Operations Summary Report Legal Well Name: 1 C-25 Common Well Name: 1 C-25 Event Name: REENTER+COMPLETE Start: 11/23/2006 Contractor Name: NORDIC CALISTA Rig Release: 12/5/2006 Rig Name: NORDIC 2 Rig Number: I Date From - To Hours Task Code NPT I Phase 11/27/2006 20:35 - 21:20 0.75 DRILL P PROD1 21:20 - 00:00 2.67 DRILL P PROD1 11/28/2006 00:00 - 00:20 0.33 DRILL P 00:20 - 01:30 1.17 DRILL P 01:30 - 04:00 2.50 DRILL P 04:00 - 06:30 2.50 DRILL N 06:30 - 10:30 4.00 DRILL N 10:30 - 11:00 I 0.501 DRILL I N 11:00 - 12:30 I 1.501 DRILL I N 12:30 - 14:15 1.75 DRILL N 14:15 - 14:40 0.42 DRILL N 14:40 - 15:15 0.58 DRILL N 15:15 - 20:20 5.08 DRILL P 20:20 - 21:20 I 1.001 DRILL I P 21:20 - 23:00 1.67 DRILL P 23:00 - 00:00 1.00 DRILL P 11/29/2006 100:00 - 01:40 I 1.671 DRILL 1 P 01:40 - 03:00 I 1.331 DRILL I P PROD1 PROD1 PROD1 DFAL PROD1 DFAL PROD1 DFAL PROD1 DFAL PROD1 DFAL PROD1 DFAL PROD1 DFAL PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PRODi Page 5 of 10 Spud Date: 11 /20/2006 End: Description of Operations Wiper trip to window. 29-31 k up wts hole good. Directionally drill ahead f/ 10452' 1.51 / .64 1-200psi MW 1-2k wob 50-60'/hr ann= 3205psi 2-3k coil wt Returns increasing back to .90+ by midnight. Continued drilling ahead to 10603'. Wiper trip to window and tie-in +5' correction. Wiper to bottom. Directionally drill ahead f/ 10603' 1.50 / .88 2100psi free-spin 2-300psi motor work 1-2k wob 20-30'/hr ann= 3137psi. Drilling has slowed considerably starting at 10694', might be on a siderite stringer. Drilled to 10697' then lost communications with Baker tools. TOH LD drilling BHA. Bit was 1-1-I w/ only micro dulling. LD BHI MWD assy and pinpoint a short in the Power and Comms section. Replace with the backup tool and now cannot get power in tool to convert from 400v to 36v. Replace a few parts and tests okay Fill hole every 30 min and losing 6 bbls/hr static MU rebuilt Hycalog bit on same motor. Add MW D assy. Meg line and no test Check connections in reel house and repair. Determined that the prior 4 hours of work was for naught since the reelhouse connections were the problem all along! Stab back on RIH w/ BHA #6 w/ resistivity circ min rate w/ SW thru EDC. Caught returns at 8000' Log tie-in down from 9580', corr -9' W iper to TD was clean Directionally drill ahead f/ 10697' 1.56 / .31 2350psi free-spin 100-200psi motorwork 1 k wob ann= 3089psi. Returns gradually increasing up to .97 at 10766'. ROP 80-100'/hr ann= 3737 ecd= 9.52. Drilling lateral with 45L TF using Seawater with Flo-Pro sweeps Op = 1.57 / 1.02 BPM Density = 8.83 / 8.69 ppg CTP = 2200 / 2350 psi WOB = 0.54 CTW = 4200 Ibf; ROP = 50-60 fph Have some trouble with WOB transfers Wiper trip, Clean trip in and out of hole. Drilling lateral with 180 130 RTF. At 84 deg turned TF to 90 R. Using seawater with Flo-Pro sweeps Op =1.57/1.18 BPM Density = 8.83 / 8.69 ppg CTP = 2,200 / 2,350 psi BHP 3208 psi 9.70 ppg EDC WOB = 0.54 CTW = 2,000 Ibf; ROP 50-70 fph Drilling lateral using seawater with Flo-Pro sweeps. TF at 90 R holding 85 deg hole angle Op = 1.55 / 1.12 BPM Density = 8.83 / 8.69 ppg CTP = 2,200 / 2,350 psi BHP 3068 psi 9.28 ppg EDC WOB = 1-2k CTW = 2k-5k Ibf; ROP 50-80 fph Wiper trip up to 9810 tt. Tie-in at whipstock's RA marker at Printed: 12/11/2006 1:43:02 PM BP AMERICA Page 6 of 10 Operations Summary- Report Legal Well Name: 1 C-25 Common Well Name: 1 C-25 Event Name: REENTER+COMPLETE Contractor Name: NORDIC CALISTA Rig Name: NORDIC 2 Date From - To Hours ~ Task Code ~ NPT 11/29/2006 01:40 - 03:00 1.33 DRILL P 03:00 - 04:00 1.00 DRILL P 04:00 - 06:00 2.00 DRILL P 06:00 - 07:15 1.25 DRILL P 07:15 - 08:40 I 1.421 DRILL I P 08:40 - 10:30 1.83 DRILL P 10:30 - 12:40 2.17 DRILL P 12:40 - 15:00 2.33 DRILL P 15:00 - 15:25 0.42 DRILL P 15:25 - 16:10 0.75 DRILL P 16:10 - 16:40 I 0.501 DRILL I P 16:40 - 18:45 I 2.081 DRILL I P 18:45 - 20:45 I 2.001 DRILL I P Spud Date: 11/20/2006 Start: 11 /23/2006 End: Rig Release: 12/5/2006 Rig Number: Phase Description of Operations PROD1 9800 ft. Corrected +9 ft PROD1 RIH. Clean trip in the hole. Still losingfluid PROD1 Drilling lateral using seawater with Flo-Pro sweeps. TF at 90 R holding 85 deg hole angle. Pumped 20 bbl flo-pro sweep white RIH Op = 1.55 / 0.95 BPM Density = 8.83 / 8.69 ppg CTP = 2,200 / 2,350 psi BHP 3068 psi 9.28 ppg EDC WOB = 1-2k CTW = 2k-5k Ibf; ROP 50-80 fph PROD1 Wiper trip to window. 32k PU wt One setdown at 11200' PU went through clean to bottom PROD1 Continue drilling ahead f/ 11300' 1.53 / 1.09 2150 freespin 200psi motorwork 1.5k wob 100-120'/hr ann= 3250 ecd= 9.81 ppg PROD1 Wiper trip to window. PRODi Directionally drill ahead f/ 11450' 1.53 / 1.00 2150 fs 100-200 mw 2-3k wob 100-120'/hr CTW 1-2k ann= 3210psi ecd= 9.69PP9 Drilled to 11577'. Wt transfer bad unalbe to take off drilling again after PU. Pill didn't help. PROD1 Wiper trip hole good. PROD1 Drill ahead f/ 11577' 1.53 / 1.0 100-200 MW 2k wob 100-120'/hr wt transfer not good. PU not able to return to bottom. PROD1 Pumping flo-pro seeps made 200' wiper trip still problems. Make 300' wiper trip returns have steadily increased 1.53 /1.30 PROD1 Drill ahead f/ 11607' 1.53 / 1.20 100psi MW 1 k wob 70'/hr good wt transfer CTW 1-3k PRODi Make short wiper trip to help continue drilling. Turned hole over to Flo-Pro PROD1 Drilling lateral with flo-pro around with 70L TF Op = 1.52 / 0.85 BPM Density = 8.77 / 8.62 ppg CTP = 2,620 / 2,950 psi with flo-pro around BHP 3435 psi 10.26 ppg EDC WOB = 1-2k CTW = 2k-5k Ibf; ROP 50-80 fph With 40 bbl outside CT the WOB at 1.4 k with good ROP of 100 fph. Loses increased from 1.3 bpm to 0.51 bpm while maintaining in rate of 1.58 bpm. Had to reboot BHI's computer. 20:45 - 21:50 1.08 DRILL N DPRB PRODi CT stacking, PU and was dealing with tight hole at 11,708 ft. Differential above the DPS Working CT weight between 60k and 0 k. Called for dead crude. Working stuck pipe. RU and pressured up to 650 psi on the annulus and the CT popped free. 21:50 - 23:48 1.97 DRILL P PROD1 PUH for wiper trip, Conversed with town engineer on plan forward. Tied -in at 9,810 ft. Unable to find RA Marker. PUH to 9,20 ft (inside tubing) Tie-in + 23.5 ft. RIH and confirmed Tie-In at RA Marker at 9801 ft 23:48 - 00:00 0.20 DRILL P PROD1 PUH above WS, open EDC and cir well waiting on seawater for wellbore displacement Printed: 12/11/2006 1:43:02 PM BP AMERICA Operations Summary Report Legal Well Name: 1C-25 Common Well Name: 1 C-25 Event Name: REENTER+COMPLETE Start: 11/23/2006 Contractor Name: NORDIC CALISTA Rig Release: 12/5/2006 Rig Name: NORDIC 2 Rig Number: Date From - To 11 /29/2006 23:48 - 00:00 11 /30/2006 00:00 - 03:00 03:00 - 06:15 Hours I Task I Cade i NPT I Phase 0.20 DRILL P 3.00 DRILL N 3.251 DRILL I N 06:15 - 08:10 1.92 DRILL N 08:10 - 08:35 0.42 DRILL N 08:35 - 11:15 2.67 DRILL P 11:15 - 12:15 I 1.001 DRILL I P 12:15 - 14:15 I 2.001 DRILL I P 14:15 - 15:40 1.42 DRILL P 15:40 - 18:30 2.83 DRILL P 18:30 - 20:30 2.00 DRILL P 20:30 - 20:50 0.33 DRILL P 20:50 - 00:00 3.17 CASE P 12/1/2006 00:00 - 02:00 2.00 CASE P 02:00 - 05:30 3.50 CASE P 05:30 - 07:40 ~ 2.171 CASE N 07:40 - 07:50 0.17 CASE N 07:50 - 08:05 0.25 CASE N 103:105 - 14:15 I 1.00 CASE N 14:15 - 17:05 I 2.831 CASE I N Page 7 of 10 Spud Date: 11 /20/2006 End: Description of Operations PROD1 EDC only open 6%, SD and evaulated EDC problem. DFAL PROD1 POOH filling down annulus. Held PJSM on BHA handling with hands DFAL PROD1 Changed out EDC, PU agitator and RR bit and motor. Stab on injector. Check tool comms -good. DFAL PROD1 RIH to 9810' w/ open EDC. Pumping .43 bpm SW out rate .50 DFAL PROD1 Run tie-in log -15' correction PROD1 Close EDC RIH w/ as drilled TF's 1.57 / 1.30 3280psi (aggitator? something partially plugged) problems at 10960' pull back up at 10700' lost 500psi CTP. RIH continue stacking. Reduce pump rate to 1.Obpm RIH smoothly 24'/min slow to 10'/min at 10930' able to get past fault zone at 10990' area. Stopped at 11120'. PU 50' > pump while PU. RIH reducing rate to lbpm go past 11120 no problem continue RIH at 12'/min w/ 1 bpm .89 out 7K CTW at 11640 bring up pump to 1.50 / .91 2650psi fs ann= 3230 ecd= 9.73ppg 4k CTW mw at 11670. PU 50' from 11684' 32k pump 5 bbl pill RIH 8'/min 3.5k CTW tagged at 11719'. PROD1 Drill f/ 11719' 1.55 / 1.09 2700 fs 2-300psi mw TF 180 deg 1-2k wob 60-70'/hr 3-4k CTW BHI downhole vibratiions indicate agitator is working. Drilled to 11,800' wo problems. PROD? Wiper trip to window. No overpulls or motorwork. Make tie-in starting with bit at 9810' +3-1/2' correction PROD1 Wiper trip to bottom. Tagged at 11804'. PROD1 Circulate and start new Flo-Pro pill from EOP. TOH for liner laying in FP 1:1 to window. Painted flag at 9750' EOP PROD1 OOH, Held PJSM, monitored well, LD BHA PROD1 PJSM on PU and running 2-3/8"" slotted and solid liner RUNPRD Run 2-3/8" liner and BHI's MWD system RUNPRD Finished PU liner and BHI's CoilTrac System RUNPRD RIH with Liner, Wt check at 9700 ft = 28.4k Ib, 12k down. Tagged at 10,420 ft, PU wt = 40k, tagged 10461 ft, worked down to 10,508 ft, unable to come up or down. Tried several things and unable to move. Cleared out pipe shed and loaded 65 jts of 1"CSH in pipe shed. Ordered out BOT stinger and 2-1/18" drill collars DPRB RUNPRD Released from liner at 8474 ft TOL and the bottom of liner at 10,508 ft POOH to pick up 1"CSH and slick stick DPRB RUNPRD LD BHi tools DPRB RUNPRD PJSM on the rig floor: Review procedures for p/u 1"hydril tbg. Point out correct hand placement, explain whip tendencies of the pipe. Correct MU torque etc. Same time install new SLB junction box w/ pigtail to outlet side of collector. Install new BHi cable that runs from MWD shack to the new junction box. DPRB RUNPRD PU 64jts 1"hydril and 7jts 2-1/8" drill collars. Stab on injecotr. SFAL RUNPRD RIH but no comms with BHi tools. Checking new junction box installation. DPRB RUNPRD Continue RIH (conference call with town group) wt chk at 8350' 22.4 K RIH tagged at 8467' (uncorrected) PU increase pump rate to .9 bpm 4000psi try again still tagging. Try various things, RIH fast and stop, pump down backside. Not going to go in. Printed: 12/11/2006 1:43:02 PM BP AMERICA Page 8 of 10 Operations Summary Report Legal Well Name: 1 C-25 Common Well Name: 1C-25 Spud Date: 11/20/2006 Event Name: REENTER+COMPLETE Start: 11/23/2006 End: Contractor Name: NORDIC CALISTA Rig Release: 12/5/2006 Rig Name: NORDIC 2 Rig Number: Date From - To ~ Hours Task Code NPT Phase Description of Operations - - --- -- 12/1/2006 17:05 - 19:15 I 2.171 CASE I N DPRB RUNPRD TOH. Will inspect stinger. Maybe cut a 45 deg bevel and PU 19:15 - 21:45 2.501 CASE N 21:45 - 22:30 I 0.751 CASE I N 12/2/2006 (010'30 - 03.00 I 1.501 CASE N 03:00 - 04:50 ~ 1.831 CASE N 04:50 - 06:15 I 1.421 CASE I N 06:15 - 07:30 I 1.251 CASE I N 07:30 - 09:30 2.00 CASE N 09:30 - 10:45 1.25 CASE N 10:45 - 16:05 5.33 CASE N 16:05 - 19:30 3.42 CASE N 19:30 - 21:30 I 2.001 CASE I N 21:30 - 22:30 I 1.00 I CASE I N 22:30 - 23:30 1.00 CASE N 23:30 - 00:00 0.50 CASE N 12/3/2006 100:00 - 03:05 I 3.081 CASE I N orienter. RUNPRD Tagged up, filled hole down back side. LD BHI's BHA and 7 drill collars. Stand back 32 std 1"CSH in derrick. Bottom of stinger blunt, with cut marks on the leading edge of the stinger. RUNPRD PU injector to meg and check continuity of the monocable in the CT. RUNPRD RIH with new stinger with greater taper and BHA as before. DPRB RUNPRD Finishe PU BHA with addition og orienter and modified stinger SFAL RUNPRD Working on Eline conductivity. Replace jumper wire, found connector shorted out. DPRB RUNPRD Stab on well and RIH RIH past the deployment sleeve. Saw a bobble at 8,464 ft, RIH DPRB RUNPRD RIH through liner Op = 0.95 / 0.63 bpm at 4000 psi, Zeroed WOB indicators. At 9800 ft, started 5 bbl flo-pro pill down CT. Wt check at 10400'. 26.5k / 11 k tagged o-ring sub with stinger at 10475' with pump at min rate. DPRB RUNPRD After many attempts to latch GS it appears that the stinger is bottoming out on it's no-go before the GS latches in. Without pump we can see the stinger entering the o-ring sub at 10465.5' and bottoms out at 10475'+. The GS should have latched in with only 8' of stinger in the o-ring sub. DPRB RUNPRD TOH tag up with BHA DPRB RUNPRD UD 7 DC's, inspect GS spear, working fine. UD 5.90' hydril pup jt. PU 7 collars. MU BHi tools DPRB RUNPRD This was the 10th run on this CTC. Also coil life is at 30% (45% max allowable) where TOL is. Remove UOC dress end of e-line. Perform slack mgmt. Blow back fluids with rig air. Cut off coil found wire at 63', cut total of 121'. Install Kendal CTC pull test to 35k. Rehead BHi UOC tested good electrically, pressure tested to 3500psi -good. Install flow sub. DPRB RUNPRD Stab on injector. RIH. Wt check at 8400' 22k RIH went through TOL without problem. RIH CT Wts = 26.5/11.5 k wo pumps. RIH and stung into O-Ring sub at 10,464 ft, set GS at 10464 ft. Circulating thru CSH at Op 0.9 bpm at 3,500 psi Pumped 8 bbl Flo-Pro pill DPRB RUNPRD With 3 bbl Flo-Pro out, PU on CT to 60 k and finished pumping the 8 bbl Flo-Pro Sweep. With 8 bbl Flo-Pro out CTP dropped to 2200 psi, increased Op to 1.3 / 0.75 bpm. Worked string from 67k to 0 k . No movement pumped another 10 bbl Flo-Pro Cir at 0.94 /0.67 bpm at 4000 psi With 2 bbl outside work CT between -5 k and 60 k without using jars. Pumped 10 bbl and work CT between -5k and 60 k. No movement DPRB RUNPRD Circulate 3rd 10 bbl pill down CT and circulated 3 bbl around. Worked CT and at this time there is no movement either up or down. DPRB RUNPRD Checked Dead Crude. < 0.95 psi. RU to pump dead crude down CT. Pump 10 bbl dead crude down CT DPRB RUNPRD With 2.5 bbl's crude out, SD pump and work CT from 60k to -4k. Small jar action. Pumped 5 bbl crude around and worked CT DPRB RUNPRD Circulate out crude and work CT. Spotted another 10 bbl of Printed: 12/11/2006 1:43:02 PM BP AMERICA Page 9 of 10 Operations Summary Report Legal Well Common W Event Nam Contractor Rig Name: Date Name: 1 ell Name: 1 e: Name: From - To C-25 C-25 REENTE NORDIC NORDIC Hours ~ R+COM CALIST 2 Task PLET A Code E NPT ' Start Rig Rig Phase Spud Date: 11/20/2006 : 11/23/2006 End: Release: 12/5/2006 Number: Description of Operations 12/3/2006 00:00 - 03:05 3.08 CASE N DPRB RUNPRD crude, Spotted 3 bbl around annulus and worked CT Pumped 0.5 bbl crude and worked CT again between 63k and -11 k down, no movement. Pumped 0.5 bbl crude and worked CT again between 63k and -10k down, no movement ' Pumped down the annulus to 800 psi and working the CT between 63k and -10k. Circulate clean SW down,CT to spot around liner before POOH 03:05 - 06:10 3.08 CASE N DPRB RUNPRD Increase Op and release from Liner. POOH washing out liner. TOH tag-up 06:10 - 06:20 0.17 CASE N DPRB RUNPRD PJSM: review plan forward for LD BHA. Identify hazards with LD dc's and 1 "hyd tbg. 06:20 - 09:00 2.67 CASE N DPRB RUNPRD LD BHi tools, 7 - 2 1/8" dc's, and 64jts of 1"hyd tbg. Conducted 'Kick While Tripping Drill' 09:00 - 11:15 2.25 CASE N DPRB RUNPRD Watch for hole fill and wait for SLB e-liners. Unload pipe shed. Clean up rig floor area. BHi reorganized their tools. 11:15 - 12:30 1.25 CASE N DPRB RUNPRD Bring a-line tools to floor. Set up chemical cuttoer and other tools on ground. 12:30 - 12:40 0.17 CASE N DPRB RUNPRD PJSM: review rig up procedures and hazards with the SLB chemical cutter. 12:40 - 13:30 0.83 CASE N DPRB RUNPRD Continue rig up SLB tools, sheave's etc.. PU chemical cutter. 13:30 - 14:30 1.00 CASE N DPRB RUNPRD RIH with CC. 14:30 - 14:45 0.25 CASE N DPRB RUNPRD Tie-in to RA tag at 9800'. Set Chem cutter on depth at 9775' and fire. Good indication. Tool free. Cut 6' above 2-3/8" collar. 14:45 - 15:50 1.08 CASE N DPRB RUNPRD POH. LD SLB tools. 15:50 - 16:00 0.17 CASE N DPRB RUNPRD PJSM review plan forward and PU BHA. 16:00 - 16:45 0.75 CASE N DPRB RUNPRD PU BHi Power/Comms and EDC. PU BTT jars-and 3" GS spear. PU stab on injector. 16:45 - 18:30 1.75 CASE N DPRB RUNPRD RIH to 8400' wt chk Tagged TOL at 8465 ft Set GS and POOH with 4400 Ib extra string weight 18:30 - 20:00 1.50 CASE N DPRB RUNPRD POOH with liner fish Denver lost to Seattle 20:00 - 22:15 2.25 CASE N DPRB RUNPRD LD MWD tool and fishing tools. LD 2-3/8" Recovered 41 jts and a 26.02 ft cutoff joint Top of fish at 9775 ft ELMD 22:15 - 00:00 1.75 WHSUR P POST RU to FP the top 2500 ft of 3-1/2" tubing. With well taking fluid, bull headed 33 bbl diesel down the wellbore at Op = 1 bpm Pt = 180 12/4/2006 00:00 - 01:00 1.00 W HSUR P POST Make ready to install FMC BPV and installed same with T-Bar 01:00 - 06:00 5.00 DEMOB P POST Clean mud pits. Circulate CT while waiting on N2 pump truck, (SLB personel out of hours) 06:00 - 07:15 1.25 DEMOB P POST N2 on location. RU 2" lines. Cool down N2 07:15 - 07:30 0.25 DEMOB P POST PJSM: Review procedures and hazards for handling N2. Alert vac truck that N2 will be coming to the Tiger Tank. No other personel downwind of tank. 07:30 - 08:45 1.25 DEMOB P POST Blow down reel and lines with N2. 08:45 - 12:15 3.50 DEMOB P POST Safety SD 12:15 - 13:30 1.25 DEMOB P POST Blow down all other rig lines with air. 13:30 - 14:00 0.50 DEMOB P POST Prep injector 14:00 - 15:00 1.00 DEMOB P POST RU to pull back coil to reel 15:00 - 15:10 0.17 DEMOB P POST PJSM: Review procedures and hazards for pull coil back to reel and securing. 15:10 - 17:00 1.83 DEMOB P POST Pull back and secure 2" a-line. 17:00 - 19:00 2.00 DEMOB P POST RD and secure injector and make ready to ND BOP's Crew change at 18:00 hrs Printed: 12/11/2006 1:43:02 PM Printed: 12/17/2006 1:43:02 PM • • by BP Alaska Baker Hughes INTEQ Survey Report mar INTEQ Company: BP Amoco Date: 12/5/2006 Time: 13:52:17 Page: I Field: Kuparuk Co-ordinate(NE) Reference: Well: 25, True North Site: KRU 1 C Pad Vertical (T'VD) Reference: 1 G25 Orig Datum 94.2 Well: 25 Section (VS) Reference: Well (O.OON,O.OOE,81.39Azi) Wellpath: 1C-25L1 Survey Calculation Method: Minimum Curvature Db: Oracle Field: Kuparuk Map System:US State Plane Coordinate System 1927 Map Zone: Alaska, Zone 4 Geo Datum: NAD27 (Clarke 1866) Coordinate System: Well Centre Sys Datum: Mean Sea Level Geomagnetic Model: bggm2006 Site: KRU 1 C Pad UNITED STATES :North Slope Site Position: Northing: 5968605.00 ft Latitude: 70 19 29.107 N From: Map Easting: 562247.20 ft Longitude: 149 29 42.918 W Position Uncertainty: 0.00 ft North Reference: True Ground Level: 0.00 ft Grid Convergence: 0.48 deg Well: 25 Slot Name: Well Position: +N/-S -59.33 ft Northing: 5968546.41 ft Latitude: 70 19 28.524 N +E/-W 87.81 ft Easting : 562335.49 ft Longitude: 149 29 40.355 W Position Uncertainty: 0.00 ft Wellpath: 1 C-25L1 Drilled From: 1 C-25 Tie-on Depth: 9793.67 ft Current Datum: 1 C-25 Orig Datum Height 94.15 ft Above System Datum: Mean Sea Level Magnetic Data: 4/25/2006 Declination: 24.00 deg Field Strength: 57607 nT Mag Dip Angle: 80.84 deg Vertical Section: Depth From (TVD) +N/-S +E/-W Direction ft ft ft deg 94.15 0.00 0.00 81.39 Survey Program for Definitive Wellpath Date: 10/6/2006 Validated: Yes Version: 4 Actual From To Survey Toolcode Tool Name ft ft 206.12 9793.67 MWD (206.12-10140.00) (0) MWD MWD -Standard 9795.00 11804.00 MWD (9795.00-11804.00) MWD MWD -Standard Annotation MD 1"VD ft ft 9793.67 6439.98 TIP 9795.00 6440.77 KOP 11804.00 6500.48 TD Survey: MWD Start Date: 11/27/2006 Company: Baker Hughes INTEQ Engineer: Tool: MWD;MWD -Standard Tied-to: From: Definitive Path Survey MD Incl Azim TVD Sys TVD N/S E/W MapN MapE VS DLS Tool ft deg deg ft ft ft ft ft ft ft deg/100ft 9793.67 53.09 90.02 6439.98 6345.83 206.51 6847.05 5968809.77 569179.93 6800.80 0.00 MWD 9795.00 53.10 90.04 6440.77 6346.62 206.51 6848.11 5968809.78 569181.00 6801.85 1.42 MWD 9800.55 55.92 87.94 6444.00 6349.85 206.59 6852.63 5968809.90 569185.51 6806.33 59.42 MWD 9810.09 55.85 84.46 6449.35 6355.20 207.12 6860.51 5968810.48 569193.39 6814.20 30.21 MWD 9830.21 63.31 77.80 6459.54 6365.39 209.83 6877.62 5968813.33 569210.47 6831.52 46.76 MWD 9862.15 79.40 68.78 6469.73 6375.58 218.60 6906.44 5968822.34 569239.22 6861.33 56.98 MWD 9894.43 86.97 55.40 6473.58 6379.43 233.58 6934.66 5968837.56 569267.31 6891.48 47.34 MWD 9925.06 89.95 38.28 6474.41 6380.26 254.45 6956.91 5968858.61 569289.38 6916.60 56.71 MWD 9963.78 89.34 14.57 6474.65 6380.50 288.87 6974.02 5968893.17 569306.20 6938.67 61.25 MWD 9993.82 90.97 355.21 6474.57 6380.42 318.66 6976.57 5968922.98 569308.50 6945.65 64.67 MWD 10022.60 89.40 337.47 6474.48 6380.33 346.51 6969.80 5968950.77 569301.50 6943.13 61.88 MWD • bP BP Alaska Baker Hughes INTEQ Survey Report r1 LJ mitt s INTEQ Company: BP Amoco Date: 12/5/2006 Time: 13:52:17 Page: 2 Field: Kuparuk Co-ordinate(NE) Reference: Well: 25, True North Site: KRU 1 C Pad Vertical (TVD) Reference: 1 C-25 Orig Datum 94.2 Wett: 25 Section (VS) Reference: Well (O.OON,O.OOE,81.39Azi) Wellpath: 1 C-251.1 Survey Calculation Method: Minimum Curvature Db: OraGe Survey MD Incl Azim TVD Sys TVD N/S E/V1' ft deg deg ft ft ft ft 10053.19 89.46 317.00 6474.78 6380.63 372.10 6953.33 10084.43 88.63 306.82 6475.30 6381.15 392.94 6930.12 10118.47 89.77 304.72 6475.78 6381.63 412.83 6902.50 10148.86 90.84 302.56 6475.62 6381.47 429.66 6877.21 10174.97 91.64 300.64 6475.05 6380.90 443.34 6854.97 10207.15 91.70 299.24 6474.12 6379.97 459.39 6827.10 10237.19 91.30 297.02 6473.33 6379.18 473.55 6800.62 10262.02 92.29 295.27 6472.55 6378.40 484.49 6778.34 10294.55 94.41 293.72 6470.65 6376.50 497.95 6748.79 10324.08 93.52 291.68 6468.61 6374.46 509.32 6721.62 10354.36 93.18 289.31 6466.84 6372.69 519.90 6693.30 10386.34 93.24 287.36 6465.05 6370.90 529.94 6663.00 10417.62 92.69 284.91 6463.43 6369.28 538.63 6632.99 10445.92 91.80 282.78 6462.32 6368.17 545.39 6605.54 10479.37 91.00 280.99 6461.50 6367.35 552.28 6572.82 10503.15 90.11 279.43 6461.27 6367.12 556.49 6549.41 10543.23 90.57 276.56 6461.03 6366.88 562.07 6509.73 10576.74 91.64 275.23 6460.39 6366.24 565.51 6476.40 10605.95 92.35 273.31 6459.37 6365.22 567.68 6447.29 10634.64 93.18 270.90 6457.99 6363.84 568.73 6418.66 10664.06 93.30 269.36 6456.32 6362.17 568.80 6389.29 10695.28 92.62 270.39 6454.71 6360.56 568.73 6358.11 10727.24 90.87 274.69 6453.74 6359.59 570.15 6326.20 10760.31 91.89 278.66 6452.94 6358.79 573.99 6293.37 10784.58 92.50 282.00 6452.01 6357.86 578.34 6269.52 10816.58 91.31 285.43 6450.95 6356.80 585.92 6238.45 10843.25 90.23 287.88 6450.59 6356.44 593.56 6212.91 10875.24 89.28 286.39 6450.73 6356.58 602.99 6182.34 10918.42 90.81 282.78 6450.69 6356.54 613.86 6140.56 10952.58 91.52 278.88 6450.00 6355.85 620.27 6107.02 10979.69 91.37 275.78 6449.31 6355.16 623.73 6080.14 11009.45 88.51 278.27 6449.35 6355.20 627.37 6050.61 11045.52 86.11 280.88 6451.04 6356.89 633.36 6015.09 11076.17 86.11 283.94 6453.12 6358.97 639.93 5985.23 11107.81 84.38 286.39 6455.74 6361.59 648.18 5954.80 11145.26 84.54 288.00 6459.36 6365.21 659.20 5919.19 11178.23 85.86 291.19 6462.12 6367.97 670.22 5888.24 11207.34 86.48 294.21 6464.06 6369.91 681.42 5861.45 11236.15 86.39 296.56 6465.85 6371.70 693.75 5835.48 11267.88 88.08 297.50 6467.38 6373.23 708.15 5807.25 11303.52 88.36 294.29 6468.49 6374.34 723.71 5775.21 11332.70 89.89 292.46 6468.94 6374.79 735.28 5748.43 11365.18 89.77 290.50 6469.03 6374.88 747.18 5718.20 11395.62 89.71 288.29 6469.17 6375.02 757.28 5689.49 11428.29 87.53 287.14 6469.96 6375.81 767.22 5658.38 11465.96 86.54 285.07 6471.91 6377.76 777.66 5622.24 11496.54 86.64 283.12 6473.73 6379.58 785.09 5592.64 11525.23 86.30 281.32 6475.49 6381.34 791.15 5564.65 11555.36 85.68 279.29 6477.60 6383.45 796.53 5535.08 11590.09 85.65 277.20 6480.22 6386.07 801.49 5500.81 11623.27 85.84 275.33 6482.69 6388.54 805.10 5467.92 11656.69 86.02 271.68 6485.06 6390.91 807.14 5434.65 11688.75 85.95 268.99 6487.30 6393.15 807.33 5402.68 MapN biapE ft ft 5968976.22 569284.83 5968996.86 569261.44 5969016.52 569233.67 5969033.14 569208.23 5969046.63 569185.89 5969062.45 569157.89 5969076.39 569131.29 5969087.14 569108.93 5969100.35 569079.27 5969111.49 569052.00 5969121.84 569023.61 5969131.63 568993.22 5969140.06 568963.15 5969146.60 568935.64 5969153.21 568902.86 5969157.23 568879.43 5969162.47 568839.70 5969165.64 568806.35 5969167.57 568777.23 5969168.38 568748.59 5969168.21 568719.22 5969167.88 568688.05 5969169.03 568656.14 5969172.60 568623.28 5969176.75 568599.39 5969184.07 568568.27 5969191.50 568542.66 5969200.67 568512.02 5969211.19 568470.15 5969217.33 568436.56 5969220.56 568409.66 5969223.96 568380.10 5969229.65 568344.54 5969235.97 568314.62 5969243.97 568284.13 5969254.69 568248.44 5969265.45 568217.40 5969276.43 568190.52 5969288.54 568164.45 5969302.71 568136.10 5969317.99 568103.93 5969329.34 568077.06 5969340.98 568046.74 5969350.85 568017.95 5969360.53 567986.76 5969370.66 567950.54 5969377.85 567920.88 5969383.68 567892.85 5969388.81 567863.24 5969393.49 567828.93 5969396.83 567796.01 5969398.59 567762.73 5969398.51 567730.76 VS DLS Tool ft deg/100ft 6930.67 66.91 MWD 6910.84 32.69 MWD 6886.52 7.02 MWD 6864.02 7.93 MWD 6844.09 7.96 MWD 6818.93 4.35 MWD 6794.87 7.51 MWD 6774.48 8.09 MWD 6747.28 8.07 MWD 6722.11 7.52 MWD 6695.70 7.89 MWD 6667.24 6.09 MWD 6638.88 8.02 MWD 6612.74 8.15 MWD 6581.42 5.86 MWD 6558.91 7.55 MWD 6520.51 7.25 MWD 6488.08 5.09 MWD 6459.62 7.00 MWD 6431.46 8.88 MWD 6402.43 5.24 MWD 6371.60 3.95 MWD 6340.26 14.52 MWD 6308.38 12.39 MWD 6285.44 13.98 MWD 6255.86 11.34 MWD 6231.75 10.04 MWD 6202.94 5.52 MWD 6163.25 9.08 MWD 6131.06 11.60 MWD 6105.00 11.44 MWD 6076.35 12.74 MWD 6042.12 9.82 MWD 6013.58 9.96 MWD 5984.73 9.46 MWD 5951.17 4.30 MWD 5922.22 10.44 MWD 5897.41 10.57 MWD 5873.57 8.15 MWD 5847.82 6.09 MWD 5818.46 9.04 MWD 5793.72 8.17 MWD 5765.62 6.05 MWD 5738.74 7.26 MWD 5709.47 7.54 MWD 5675.30 6.08 MWD 5647.14 6.37 MWD 5620.38 6.37 MWD 5591.95 7.03 MWD 5558.81 6.00 MWD 5526.83 5.65 MWD 5494.24 10.91 MWD 5462.65 8.37 MWD • • bP BP Alaska Baker Hughes INTEQ Survey Report ~t~ ~~ INTEQ Company: BP Amoco Date: 12/5/2006 Tim e: 13:52:17 Page: 3 Field: Kuparuk Co-ordinate(NE) Reference: Well: 25, True North Site: KRU 1 C Pad Vertical (TVD) Reference: 1 C-25 Orig Datum 94.2 Well: 25 Section (VS) Reference: Well (O.OON,O.OOE,81.39A zi) ~Wellpath: 1 C-251.1 Survey Calculation Method: Minimum Curvature Db: OraGe Survey NID Incl Azim TVD Sys TVD N/S E/W MapN MapE VS DLS Tool ft deg deg ft ft ft ft ft ft ft deg/100ft 11718.04 85.50 266.03 6489.49 6395.34 806.06 5373.50 5969397.00 567701.59 5433.61 10.19 MWD 11752.87 81.93 266.54 6493.30 6399.15 803.82 5338.96 5969394.47 567667.07 5399.12 10.35 MWD 11804.00 81.93 266.54 6500.48 6406.33 800.76 5288.42 5969390.99 567616.58 5348.71 0.00 MWD Hole Angle -- 53.99 Deg Top of Chemical Cut at 9,775 ft ELMD TOW at 9795 f Wel I 1 C-25 Wellbore Diagram Post CTD Sidetrack 3-Dec-2006 8.4 ppg Seawater GLM 8,594 ft GLM 7,775 ft 3-1/2" 9.3 #fft L-80 EUE 8 rd ID = 2.992" Production Tubing ~ GLM 8,616 ft 2-3/8" 6.5#!ft L-80 STL Tubing ID = 1.995" -8.4 ppg Seawater GLM 9,391 ft ~`~ ~~~ .I~. .~r ~'' ~~~ ~ ConocoPh i 11 i s I~ Alaska "D"nipple (~ 9410 ft ID = 2.75" Hole Angle = 53.52 Deg 2-3/8" 6.5#/ft L-80 Solid Liner 1 joint \ \\ 2-3/8" 6.5#/ft L-80 Slotted Liner \\ ~ \ -.-- 22 jts 2-3/8" Tubing in the open hole ~~/ Shoe at 10,487 ft 3" Hole • TD at 11,804 ft i ~~ 11/09!04 STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION BO PE Test Report Submit to: .E~E°3..rf'g~~i~~r~i~3_sf~'Ef.~ x_u~ ,t a cox ~i~.~~.~:.; ~'+ii.EE~n~~~? iSC'v {(~~~r.~t3:~~e~~ °~t ~.F.~ .., .ak.us ....... ........ ...........................xa...+__________.._____.________.__.___._____.. I'3~2i"~ i?~?::I{E`l~St£'ofdr-3J~~L'e£T3i~3.Stc~'~fi..~.c?C.~.3~i Contractor: Nordic Rig No.: 2 DATE: 11/24/06 Rig Rep.: Mckeirnan / Sloan Rig Phone: 659-4398 Rig Fax: 659-4356 Operator: BPX Op. Phone: 659-4393 Op. Fax: 659-4356 Rep.: Sevcik / Feketi E-Mail s~~~c~~~~c~rl~rr~_;~ic?~c?~:I~?ushE~E_ ~~~?_~,~.3 Well Name: 1C-25L1 PTD # 206-100 Operation: Drlg: XXX Workover: Explor.: Test: Initial: XXX Weekly: Bi-Weekly Test Pressure: Rams: 250-3500 Annular: 250-2500 Valves: 250-3500 MISC. INSPECTIONS: TEST DATA FLOOR SAFETY VALVES: Test Result Test Result Quantity Test Result Location Gen.: P Well Sign P Upper Kelly NA Housekeeping: P Drl. Rig P Lower Kelly NA PTD On Location P Hazard Sec. P Ball Type 2 P Standing Order Posted P Inside BOP NA BOP STACK: Quantity Size/Type Test Result MUD SYSTEM: Visual Alarm Stripper 1 2" P Trip Tank P P Annular Preventer 1 7 1/16" P Pit Level Indicators P P #1 Rams 1 Blind /Shear P Flow Indicator P P #2 Rams 1 2" Combi P Meth Gas Detector P P #3 Rams 1 2 3/8" Combi P H2S Gas Detector P P #4 Rams 1 2" Combi P #5 Rams N/A NA Quantity Test Result Choke Ln. Valves 1 3 1/8" P Inside Reel valves 1 P HCR Valves 2 3 1/8" P Kill Line Valves 1 3 1/8" P ACCUMULATOR SYSTEM: Check Valve N/A NA Time/Pressure Test Result System Pressure 2950 P CHOKE MANIFOLD: Pressure After Closure 2100 P Quantity Test Result 200 psi Attained 22 sec P No. Valves 14 P Full Pressure Attained 77 secs P Manual Chokes 1 P Blind Switch Covers: All stations Y Hydraulic Chokes 1 P Nitgn. Bottles (avg): 4 2100 Test Results Number of Failures: 0 Test Time: 5.5 Hours Components tested 28 Repair or replacement of equipment will be made within 0 days. Notify the North Slope Inspector 659-3607, follow with written confirmation to Superviser at: ,~iE~3__rE~r~;~.~~r~it3,s~.~t f.~~c_q Remarks: Distribution: 24 HOUR NOTICE GIVEN orig-Well File YES XXX NO c - Oper./Rig Waived By Lou Grimaldi c -Database Date 11/22/00 Time 18:00 c -Trip Rpt File Witness c -Inspector Test start 23:00 Finish 04:30 Coil Tubing BFL 11/09/04 Nordic 2 BOP 11-24-06p.xls v }~ { t , i~ ~s ~; '~ i -~~ a. .~~ gad '.~~ '®.a ~. ~ ~:z.~ a~~ ~ ~ S,Di .s..m. ._ .~, ffi~ , ; ..~ _ ~ ._.e d~,~3 ALASSA OIL A1~TD .GAS CON5ER`QATIOI~T COMI~IISSI0.1~ Gary Eller Drilling Engineer ConocoPhillips Alaska, Inc. PO Box 196612 Anchorage, AK 99519-6612 333 W. 7`" AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Re: Kuparuk River Unit, Kuparuk River Oil Pool, 1C-25L1 ConocoPhillips Alaska, Inc. Permit No: 206-100 Surface Location: 1693' FNL, 1327' FWL, SEC. 12, T11N, R10E, UM Bottomhole Location: 801' FNL, 3432' FEL, SEC. 07, T11N, R1 lE, UM Dear Mr. Eller: Enclosed is the approved application for permit to redrill the above referenced development well. This permit to drill does not exempt you from obtaining additional permits or an approval required by law from other governmental agencies and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the Commission reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the 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. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager). Sincerely, Dan eamount Commissioner DATED this ,. ay of July, 2006 FRANK H. MURKOWSKI, GOVERNOR cc: Department of Fish 8v Game, Habitat Section w/ o encl. Department of Environmental Conservation w/o encl. STATE OF ALASKA ALA~OIL AND GAS CONSERVATION COMN~ON PERMIT TO DRILL 20 AAC 25.005 ~E,~EIVED 1~i3 JUL 0 6 2006 „~, ~ r__ ~„~~ r.~n,misson 1 a. Type of work ^ Drill ®Redrill ^ Re-Entry 1 b. Current Well Class ^ Exploratory ^ Development Gas ^ Service ^ Multiple Zone ^ Stratigraphic Test ®Development Oil ^ Single Zone 1 c. Speci a or: ^ Coalbed Methane ~i 1~rates ^ Shale Gas 2. Operator Name: Conoco Phillips Alaska Inc. 5. Bond: ®Blanket ^ Single Well Bond No. 59-52-180 11. Well Name and Number: 1C-25L1 3. Address: c/o P.O. Box 196612, Anchorage, Alaska 99519-6612 6. Proposed Depth: MD 11800 • TVD 6398ss 12. Field /Pool(s): Kuparuk River Unit / Kuparuk 4a. Location of Well (Governmental Section): Surface: 1693' FNL 1327' FWL SEC 12 T11 N R10E UM 7. Property Designation: ADL 028242 ' River Pool • , , . , , , Top of Productive Horizon: 1490' FNL, 2025' FEL, SEC 07, T11 N, R11 E, UM 8. Land Use Permit: 13. Approximate Spud Date: October 2, 2006 Total Depth: 801' FNL, 3432' FEL, SEC 07, T11 N, R11 E, UM 9. Acres in Property: 2560 14. Distance to Nearest Property: 6780' 4b. Location of Well (State Base Plane Coordinates);... _ Surface: x-562335 y-5968546 Zone-ASP4 10. KB Elevation (Height above GL): 94.15 feet 15. Distance to Nearest well within Pool: 1130' 16. Deviated Wells: Kickoff Depth: 9790 ~ feet Maximum Hole Angle: 93 de tees 17. Maximum Anticipated Pressures in psig (see 20 AAC 25.035) Downhole: 3415 Surface: 2771 ' t8. Casio Pr' ram: Specifications T -Setting De' th -Bottom Quantity of Cement, c.f. or sacks Hole Casin Wei ht Grade Cou lin Len th MD TVD MD TVD includin sta a data 3" 2-3/8" 4.6# L-80 STL 2050' 9750' 6320' 11800' 6398' Uncemented Slotted Liner 19. PRESENT WELL CONDITION SUMMARY (To be completed for Redril l and Re-entry Operations) Total Depth MD (ft): 10140 Total Depth TVD (ft): 6649 Plugs (measured): None Effective Depth MD (ft): 10039 Effective Depth TVD (ft) 6587 Junk (measured): None :Casing 'Length Size Cement Volume MD TVD Conductor /Structural 114' 16" 9 cu ds Hi h Earl 114' 114' Surface 6567' 9-5/8" 796 sx AS III 'L', 653 sx Class 'G' 6567' 4554 Intermediate 9570' 7" 180 sx Class 'G' 9570' 6306 Production Liner 722' 3-1/2" 180 sx Class 'G' 9416' - 10138' 6213' - 6648' Perforation Depth MD (ft): 9788' - 9987' Perforation Depth TVD (ft): 6437' - 6556' PL.J r ~ 20. Attachments i .Filing Fee, $100 ®BOP Sketch ®Drilling Program ^ Time vs Depth Plot ^ Shallow Hazard Analysis ^ Property Plat ^ Diverter Sketch ^ Seabed Report ®Drilling Fluid Program ®20 AAC 25.050 Requirements 21. Verbal Approval: Commission Representative: Date: 22. I hereby c that the forego ig is true and correct. Contact Gary Eller, 263-4172 Printed Na Gary Eller Title Drilling Engineer an en aus, -4 7 Prepared By Name/Number: Si nature Phone 263-4172 Date Terrie Hubble, 564-4628 .Commission Use Only Permit To Drill Number: ~.d~o /~~ I Number: Permit Appro al 50-029-22941-60-00 Date: `~ • ~ (p See coverletter for other requirements Conditions of Approval: If box is checked, well may notQQbe used to explore for, test, or produce coalbed methane, gas hydrates, or gas contained shales~~ 3S~C O ~i~ ~p '~fiS~ aS p `C~.nnCCJ`, Samples Req'd: ^ Y s [v]~No Mud Log Req'd: ^ Yes ~o ~•~ ~ ~ ~ p ~ ~ ~'O AQC.a S,p'~C,~c~'~`y> ,~ HZS Measures: ~s ^ No Directional Survey Req'd: Q'S'es ^ No Other: Corv ~~'"~\eso~ ~tl ~ ~jacL'~OC'vZ C,~ 3 cs OQ~1 c~~o r~ ~_ j APPROVED BY THE COMMISSIO Date ,COMMISSIONER Form 10-401 Revised'~2/2005 O ~ ~ ~ ~ ~ ~ i , .~../ Submit I uplicate ~~ 7lal KR~-25L1 Sidetrack Lateral - Coile~ubing Drilling Summary of Operations: A coiled tubing drilling unit will drill a lateral in producer KRU 1C-25 using the managed pressure drilling technique. This horizontal lateral will target Kuparuk C4 sand reserves for injection support. CTD Drill and Complete 1C-25 program: Planned for October, 2006 Pre-Rig Work 1. Positive pressure and drawdown tests on MV and SV 2. Test Packoffs - T&IC 3. Dummy GLV's 4. MIT-IA, MIT-OA 5. Caliper 3'/z" liner, memory GR/CCL/SCMT log 6. Drift tubing/liner with dummy whipstock 7. Obtain static BHP measurement. 8. Run SCMT log across 3'h" liner. 9. Set 3'/z" monobore flow-through whipstock on a-line @ 9790' MD. Rig Work 10. MIRU Nordic Rig #2. NU 7-1/16" BOPE, test. 11. Mi112.74" window and 10' of open hole. 12. Drill 2.70" x 3" bi-center horizontal lateral from window to 11,800' TD targeting Kuparuk C4 sand. 13. Kill well with brine. Complete with 23/8" slotted liner from TD up into the 3'/z" liner to 9750' MD. 14. ND BOPE. RDMO Nordic 2. Post-Rig Work 15. Post CTD rig -Run GLVs, obtain static BHP. Mud Program: Step 10: chloride-based biozan brine (8.6 ppg) Steps 11: chloride-based Flo-Pro (8.6 ppg) Steps 12: chloride-based KWF (9.6 ppg) Disposal: • No annular injection on this well. • Class II liquids to KRU 1R Pad Class II disposal well • Class II drill solids to Grind & Inject at PBU Drill site 4 • Class I wastes will go to Pad 3 for disposal. Casing Program: • 1C-25L1: 23/8", 4.6#, L-80, STL slotted liner from 9750' MD to 11,800' MD Casing/Liner Information 95/8", L-80, 40# Burst 5750 psi; Collapse 3090 psi. 7", L-80, 26# Burst 7240 psi; Collapse 5410 psi 3%z", L-80, 9.3# Burst 10,160 psi; Collapse 10,530 psi Well Control: • Two well bore volumes 0210 bbl) of KWF will be location during drilling operations. • BOP diagram is attached. June 22, 2006, FINAL KRt~C-25L1 Sidetrack Lateral - Coile~ubing Drilling • Pipe rams, blind rams and the CT pack off will be pressure tested to 250 psi and to 3500 psi. • The annular preventer will be tested to 400 psi and 2500 psi. •~'~ Directional See attached directional plans for 1C-25L1. Magnetic and inclination surveys will be taken every 30 ft. No gyro will be run. The nearest well to 1C-25L1 is 1C-15L1 which is offset by 1130' at 11800' MD in 1C-25. KRU boundary is 6780' away. Logging • MWD directional, resistivity, and gamma ray will be run over the entire open hole section. Hazards Lost circulation is a risk due to low BHP (i.e. 5.5 ppg EMW) in the mother bore and potentially high ECD. Expect to encounter increasing pressure as lateral is drilled away from the mother well. The target fault block is believed to be isolated from the 1C-15 injector to the north by sealing faults. There is a risk that L1 will encounter elevated pressures (±12.9 ppg EMW) if it were to tap into fault blocks supported by 1C-15. To mitigate this risk, hardlines have been established to the north and west of the target wellplan such that we maintain at least 400' standoff from two major faults. Well 1C-25 has a HZS reading of 65 ppm as measured on 07/23/05. Well 1C-27 is the nearest offset well to 1C-25, and it has 80 ppm HZS as measured on 07/23/05. All HZS monitoring equipment will be operational. Reservoir Pressure The most recent static BHP survey in well 1C-25 was taken in December 2004 after the well had been shut-in for 10 days. The measured reservoir pressure was 1750 psi at 6209' TVD which corresponds to 5.5 ppg EMW. Expect to encounter increasing pressure as lateral is drilled away from mother well. Maximum expected pressure is 3415 psi (original reservoir pressure) which corresponds to an EMW of 10.2 ppg at 6438' TVD (L1 KOP). Maximum surface pressure with gas (0.1 psi/ft) to surface is 2771 psi. ` Variance request GCS ~-~,,,~j~E ~7 ~ (f • ConocoPhillips requests a varianc Po 20 AAC 25.036(d)(4) re~ ding the requirement to function pressure test ram-type BOP equipment after using such for purposes other than well control. The variance will not apply when the use of ram-type BOP equipment may have compromised their effectiveness, such as if the pipe rams are inadvertently closed on a tool joint during routine operations. While drilling 1C-25L1 it will be routine to close the 23/8" combi-rams (i.e. pipe/slip} on the BHA during deployment and undeployment. These activiti will~compromis~ e integri the BOP equipment. ~--~vi~~~~jc ~~ ~ tip ~t7 • A variance of the requiremenfs of 20 AAC 25.412(b) will be required for the depth of the packer prior to converting 1C-25L1 to injection. The existing ZXP liner-top packer at 9416' MD is greater than 200' from the Ll kickoff depth of 9790' MD. A cement bond log will be required in the existing 3'/i" liner to help support the variance request, along with an evaluation of cementing in wells within aquarter-mile of the planned trajectory of 1C-25L1. Managed Pressure Drilling Managed pressure drilling (MPD) techniques will be employed to provide constant bottom hole pressure by using 8.6 ppg drilling fluid in combination with annular friction losses and applied surface pressure. Constant BHP will be utilized to reduce pressure fluctuations to help with hole stability. Applying annular friction and choke pressure also allow use of less expensive drilling fluid and minimizes fluid losses and/or fracturing at the end of the long well bores. A hydraulic choke for regulating surface June 22, 2006, FINAL KR~-25L1 Sidetrack Lateral - Coile~ubing Drilling pressure will be installed between the BOPE choke manifolding and the mud pits and will be independent of the BOPE choke. Using this technique will require deployment of the BHA under trapped wellhead pressure. However, actual well conditions (ex: drilling mud adequately overbalances formation pressure and the hole is stable) may not necessarily require pressure deployment. If needed, pressure deployment of the BHA will be accomplished utilizing the BOP pipe/slips (i.e. 23/8" rams, see attached BOP configuration). This well is not equipped with a tubing retrievable subsurface safety valve. The annular preventer will act as a secondary containment during deployment and not as a stripper. Operating parameters and fluid densities will be adjusted based on real-time bottom hole pressure measurements while drilling and shale behavior. The following scenario is expected at TD: • Estimated reservoir pressure: 1830 psi at 6398' TVD, 5.5 ppg EMW. • Expected annular friction losses while circulating: 944 psi (based on 80 psi/1000 ft). • Planned mud density: 8.6 ppg equates to 2861 psi hydrostatic bottom hole pressure. • While circulating 8.6 ppg fluid, bottom hole circulating pressure is estimated to be 3805 psi or 11.5 ppg ECD. • When circulation is stopped, it is anticipated that the mud weight will provide 100 psi or more overbalance on the reservoir. June 22, 2006, FINAL • • ConocoPhillips Alaska, Inc. TUBING (0-9452, OD:3.500, ID:2.992) 'RODUCTION (0-9570, OD:7.000, wt:zs.oo) SURFACE (0-6567, OD:9.625, W t:40.00) Gas Li MandrelNal 2 (5166-5167, Gas Li MandrelNal (6594-6595 Gas Li MandrelNal (7n5-n7s Gas Li MandrelNal (8616-8617 Gas Li MandrelNal (9391-9392 NI (9410-9411 OD:4.50 ~RODUCTIO LINE (9416-1013 OD:3.50 W C9.3 Pe (9788-982 FRA (9788-984 Pe (9834-984 Pe (9967.998 KRU 1 C-25 1 C-25 API: 500292294100 Well T e: PROD An le TS: 53 d 9781 SSSV Type: Nipple Orig Com letion: 4/28/1999 Angle @ TD: 52 deg @ 10140 Annular Fluid: Last W/O: Rev Reason: PERF Reference Lo : Ref Lo Date: Last U date: 6/21/2006 Last Ta : 9991 TD: 10140 ftKB Last Ta Date: 5/16/2006 Max Hole An le: 56 d 4002 Casin Strin -ALL CASINGS Descri lion Size To Bottom TVD Wt Grade Thread PRODUCTION 7.000 0 9570 6305 26.00 L-80 BTC-MOD CONDUCTOR 16.000 0 115 115 62.58 H-40 WELDED SURFACE 9.625 0 6567 4554 40.00 L-80 BTC-MOD PRODUCTION LINER 3.500 9416 10138 6648 9.30 L-80 EUE 8rd Tubin Strin -TUBING Size To Bottom TVD Wt Grade Thread 3.500 0 9452 6234 9.30 L-80 EUE 8rd Perforations Summa Interval ND Zone Status Ft SPF Date T e Comment 9788 - 9824 6437 -6458 C-4 36 4 8/27/1999 (PERF 2.5 HC, DP, 180 de h 9834 - 9844 6464 - 6470 C-4 10 10 8/27/1999 (PERF 2.5 HC, DP, 180 de h 9967 - 9987 6544 - 6556 C-1 20 6 5/16/2006 APERF 2" 2006 PJ Om a Char es Stimulations & Treatments Interval Date T e Comment 9788 - 9844 11/9/2002 FRAC Gas Lift MandrelsNalves St MD TVD Man Mfr Man Type V Mfr V Type V OD Latch Port TRO Date Run Vlv Cmnt 1 3230 261 2 CAMCO KBMM CAMCO GLV 1.0 BK 0.125 1290 1/15/200 ' 2 5166 373 4 CAMCO KBMM CAMCO GLV 1.0 BK 0.156 1316 1/15/200 3 6594 457 0 CAMCO KBMM CAMCO GLV 1.0 BK 0.188 1339 1/17/200 4 7775 526 2 CAMCO KBMM CAMCO GLV 1.0 BK 0.188 1327 1/15/200 5 8616 574 9 CAMCO MM KB CAMCO GLV 1.0 BK 0.250 1420 1/14/200 6 9391 619 8 CAMCO __ _ MMM CAMCO OV 1.5 RK 0.250 0 1/14/200 LRY Other lu s e ui ., etc. - JEWE De th TVD T e _ Descri lion ID ' 502 502 NIP CAMCO DS ni le 2.875 9410 6209 NIP CAMCO D 9/21 /99 nipple NO GO profile, ELMD @ 9413 ON SWS JEWL LOG 2.750 9422 6216 SEAL BAKER 80-40 casin seal assembl 3.000 t ft e 6 P ) N R , , ) rf ) C ) rf ) rf ) - n ve n ve 3 n ve 4 f ve 5 v 0 8 0 0 q 4 4 7 KRU 1C-25L1 C-sand Producer Proposed Completion 3-1/2" Camco DS Hippie, 2.875" min !D @ 502' MD 3-1/2" 9.3# L-80 EUE 8rd Mod Tubing to 9452' MD ~ono~ P . o h~l~ps Alaska, Il~c. 9-5/8" 40# L-80 ~ 65s7' 3'/" Camco KBMM GLM's @ 3230', 5166', 6594', 7775', and 8616' MD • 3-%" Camco MMM GLM @ 9391' MD 3-%" Camco D nipple, 2.75" min ID @ 9410' MD Baker 80-40 seal assembly @ 9422' MD r' 2s# L-so 9570' MD 2-3/8" STL liner top w/ "G" fishneck and seal bore @ 9750' MD C sand perfs 2-318" slotted liner 9788' - 9824' and 9834' - 9844' and ~ ~ I~ - - -~"' 3" openhole . KOP 9790' MD, in ' C-sand 3'/Z' flowthru whipstock 1 C-25A TD @ 11,800' and _~_ ~. ~. 3-1/2" 9.3# L-80 Liner 9416'-10138'MD BP Alaska by Baker Hughes INTEQ Planning Report BAIQ~R • Ins INTEQ Company: BP Amoco- Date: 4/26/2006 Time: 09:08:20 Page: 1 Fieh1: Kuparuk Co-ordinate(NE) Reference: WeIL 25, Tnre North ' Site: KRU 1CP2d Vertical (TVD) Reference: 1 C-25 Orig Datum 94.2 We1L• 25` Section (VS) Reference: Well (O.OON,O.OOE,260.65Azi) WeUpath: Plan 3, 1C-25L1 'Survey Calculation Method: Minimum Curvature Db: Oracle Field: Kuparuk Map System:US State Plane Coordinate System 1927 Map Zone: Alaska, Zone 4 Geo Datum: NAD27 (Clarke 1866) Coordinate System: Well Centre Sys Datum: Mean Sea Level Geomagnetic Model: bggm2005 Site: KRU 1C Pad UNITED STATES :North Slope Site Position: Northing: 5968605. 00 ft Latitude: 70 19 29.107 N From: Map Easting: 562247. 20 ft Longitude: 149 29 42.918 W Position Uncertainty: 0.00 ft North Reference: True Ground Level: 0.00 ft Grid Convergence: 0.48 deg Well: 25 Slot Name: Well Position: +N/-S -59.33 ft Northing: 5968546. 41 ft Latitude: 70 19 28.524 N +E/-W" 87.81 ft Easting : 562335. 49 ft Longitude: 149 29 40.355 W Position Uncertainty: 0.00 ft Wellpath: Plan 3, 1 C-25L1 Drilled From: 1 C-25 Tie-on Depth: 9696.09 ft Current Datum: 1C-25 Orig Datum Height 94. 15 ft Above System Datum: Mean Sea Level Magnetic Data: 4/25/2006 Declination: 24.15 deg Field Strength: 57570 nT Mag Dip Angle: 80.82 deg Vertical Section: Depth From (TVD) +N/-S +E/-W Direction ft ft ft deg 94.15 0.00 0.00 260.65 Plan: Plan #3 Date Composed: 4/25/2006 copy Lamar's PIan3 Version: 5 Principal: Yes Tied-to: From: Definitive Patli Targets Map Msp <--.~ Latitude. ---> <-- Longitude ---> Name Description TVD +N/-S +E/-W Northing Easting Deg' Min `Sec .Deg Min Sec Dip. Din ft ft ft ft ft 1C-25L1 Polygon 94.15 211.20 6802.15 5968814.08 569135.00 70 19 30.571 N 149 26 21.809 W -Poygon 1 94.15 211.20 6802.15 5968814.08 569135.00 70 19 30.571 N 149 26 21.809 W -Polygon 2 94.15 129.86 6961.49 5968734.08 569295.00 70 19 29.769 N 149 26 17.160 W -Polygon 3 94.15 224.54 7122.30 5968830.08 569455.00 70 19 30.699 N 149 26 12.463 W -Polygon 4 94.15 432.15 7172.03 5969038.08 569503.00 70 19 32.740 N 149 26 11.006 W -Polygon 5 94.15 562.69 6869.07 5969166.08 569199.00 70 19 34.027 N 149 26 19.846 W -Polygon 6 94.15 630.80 6374.58 5969230.08 568704.00 70 19 34.701 N 149 26 34.278 W -Polygon 7 94.15 714.13 5975.22 5969310.08 568304.00 70 19 35.524 N 149 26 45.934 W -Polygon 8 94.15 925.52 5449.90 5969517.08 567777.00 70 19 37.607 N 149 27 1.264 W -Polygon 9 94.15 830.18 5369.10 5969421.08 567697.00 70 19 36.670 N 149 27 3.624 W -Polyyon 10 94.15 702.91 5400.05 5969294.08 567729.00 70 19 35.418 N 149 27 2.724 W -Polygon 11 94.15 471.59 6277.24 5969070.08 568608.00 70 19 33.136 N 149 26 37.124 W -Polygon 12 94.15 386.81 6851.61 5968990.08 569183.00 70 19 32.297 N 149 26 20.360 W 1C-25L1 Faultl 94.15 263.48 6648.56 5968865.08 568981.00 70 19 31.086 N 149 26 26.290 W -Poygon 1 94.15 263.48 6648.56 5968865.08 568981.00 70 19 31.086 N 149 26 26.290 W -Polygon 2 94.15 531.24 6801.80 5969134.08 569132.00 70 19 33.718 N 149 26 21.810 W -Polygon 3 94.15 710.40 6905.31 5969314.08 569234.00 70 19 35.479 N 149 26 18.784 W -Polygon 4 94.15 531.24 6801.80 5969134.08 569132.00 70 19 33.718 N 149 26 21.810 W 1C-25L1 Faultl 94.15 847.36 5707.28 5969441.07 568034.99 70 19 36.836 N 149 26 53.752 W -Polygon 1 94.15 847.36 5707.28 5969441.07 568034.99 70 19 36.836 N 149 26 53.752 W -Polyyon 2 94.15 770.00 5749.64 5969364.07 568077.99 70 19 36.075 N 149 26 52.517 W -Polygon 3 94.15 495.04 5860.37 5969090.07 568190.99 70 19 33.370 N 149 26 49.291 W -Polygon 4 94.15 770.00 5749.64 5969364.07 568077.99 70 19 36.075 N 149 26 52.517 W 1C-25L1 Target2 6434.15 698.81 5892.07 5969294.07 568220.99 70 19 35.374 N 149 26 48.361 W 1C-25L1 Target1 6455.15 534.34 6548.79 5969135.08 568878.99 70 19 33.751 N 149 26 29.195 W 1C-25L1 Target3 6492.15 893.72 5423.63 5969485.06 567750.99 70 19 37.294 N 149 27 2.031 W i BP Alaska by Baker Hughes INTEQ Planning Report BAI~R • Nue~s INTEQ Company: BP Amoco Date: 4!26!2006 Time: 09:08:20 Page: 2 Field: Kuparuk Co-ordiuate(NE) Reference: WeA: 25, True North Sitee KRU 1G Pad Vertical (TVD) Reference: 1 C-25 Orig Datum 94.2 WeIL 25 Section (VS) Reference: Weft (0.OON,O.OOE,260.65Azi) Wellpath: Plan 3, 1C-25 L7 Survey Calculation Method: Minimum Curvature Db: O raGe Annotation MD TVD ft ft 9696.09 6381.19 TIP 9790.00 6437.77 KOP 9810.00 6449.55 End of 9 Deg/100' DLS 9890.00 6479.95 4 9914.80 6481.50 5 10039.80 6477.00 6 10164.80 6472.33 End of 45 Deg/100' DLS 10340.00 6465.66 Fault 1 10514.80 6458.79 8 10614.80 6455.00 9 10714.80 6450.74 10 10914.80 6440.81 11 10964.80 6439.52 12 11264.80 6452.37 13 11450.00 6467.53 Fault 2 11514.80 6472.41 14 11800.00 0.00 TD Plan Section Information MD Inc! Azim TVD +N/-S +FJ-W DLS Build Turn TFO Target ft deg deg ft it ft deg/100ft deg/100tt deg/100ft deg:_ 9696.09 52.83 88.54 6381.19 205.54 6769.17 0.00 0.00 0.00 0.00 • 9790.00 53.08 89.96 6437.77 206.52 6844.12 1.24 0.27 1.51 77.99 9810.00 54.77 89.21 6449.55 206.63 6860.28 9.00 8.47 -3.77 340.00 9890.00 80.91 62.08 6479.95 226.23 6930.17 45.00 32.67 -33.91 310.00 9914.80 91.90 60.15 6481.50 238.17 6951.80 45.00 44.33 -7.77 350.00 10039.80 91.89 3.87 6477.00 339.89 7015.38 45.00 -0.01 -45.03 271.00 10164.80 92.05 307.58 6472.33 449.23 6966.07 45.00 0.13 -45.03 271.20 10514.80 92.19 265.55 6458.79 546.74 6638.32 12.00 0.04 -12.01 271.00 10614.80 92.14 277.56 6455.00 549.44 6538.61 12.00 -0.05 12.01 90.00 10714.80 92.72 289.56 6450.74 572.82 6441.66 12.00 0.58 12.00 87.00 10914.80 92.89 265.53 6440.81 598.85 6245.08 12.00 0.09 -12.01 271.00 10964.80 90.06 270.82 6439.52 597.26 6195.15 12.00 -5.65 10.59 118.00 11264.80 85.18 306.53 6452.37 691.52 5915.81 12.00 -1.63 11.90 98.30 11514.80 85.83 276.45 6472.41 781.74 5686.59 12.00 0.26 -12.04 270.00 11800.00 86.55 310.74 6491.93 - 893.96 5429.73 12.00 0.25 12.02 90.00 Survey MD Inc! Azim Sys TVD N/S FJW MapN MapE DIS VS TFO Tool ft deg deg ft ft ft ft ft deg/100ft ft deg 9696.09 52.83 88.54 6287.04 205.54 6769.17 5968808.14 569102.07 0.00 -6712.63 0.00 MWD 9700.00 52.84 88.60 6289.41 205.61 6772.28 5968808.25 569105.19 1.24 -6715.71 77.99 MWD 9783.97 53.06 89.87 6340.00 206.51 6839.30 5968809.70 569172.18 1.24 -6781.98 77.95 1C-25L1 9790.00 53.08 89.96 6343.62 206.52 6844.12 5968809.75 569177.00 1.24 -6786.74 77.19 MWD 9800.00 53.93 89.58 6349.57 206.55 6852.15 5968809.85 569185.04 9.00 -6794.68 340.00 MWD 9810.00 54.77 89.21 6355.40 206.63 6860.28 5968810.00 569193.16 9.00 -6802.71 340.23 MWD 9820.00 57.74 85.13 6360.95 207.05 6868.58 5968810.48 569201.46 45.00 -6810.96 310.00 MWD 9820.09 57.74 85.13 6361.00 207.06 6868.65 5968810.49 569201.53 0.00 -6811.04 0.00 1C-25L1 9830.00 60.82 81.32 6366.06 208.07 6877.11 5968811.57 569209.98 45.40 -6819.55 312.27 MWD 9840.00 64.01 77.73 6370.69 209.68 6885.82 5968813.26 569218.68 45.00 -6828.41 314.21 MWD 9850.00 67.27 74.34 6374.82 211.88 6894.66 5968815.53 569227.49 45.00 -6837.48 315.88 MWD 9860.00 70.61 71.10 6378.41 214.66 6903.57 5968818.38 569236.38 45.00 -6846.72 317.28 MWD 9870.00 74.00 68.00 6381.45 217.99 6912.49 5968821.79 569245.27 45.00 -6856.07 318.44 MWD 9880.00 77.44 65.00 6383.92 221.85 6921.38 5968825.73 569254.12 45.00 -6865.46 319.39 MWD 9890.00 80.91 62.08 6385.80 226.23 6930.17 5968830.17 569262.87 45.00 -6874.85 320.13 MWD 9900.00 85.34 61.29 6386.99 230.94 6938.90 5968834.95 569271.57 45.00 -6884.23 350.00 MWD 9910.00 89.77 60.52 6387.42 235.80 6947.63 5968839.88 569280.26 45.00 -6893.64 350.09 MWD 9914.80 91.90 60.15 6387.35 238.17 6951.80 5968842.29 569284.40 45.00 -6898.13 350.13 MWD 9920.00 91.94 57.81 6387.17 240.85 6956.25 5968845.01 569288.84 45.00 -6902.97 271.00 MWD 9930.00 92.01 53.31 6386.83 246.50 6964.49 5968850.73 569297.03 45.00 -6912.01 270.92 MWD 9940.00 92.06 48.80 6386.48 252.78 6972.26 5968857.07 569304.75 45.00 -6920.70 270.77 MWD 9950.00 92.10 44.30 6386.11 259.65 6979.52 5968864.00 569311.94 45.00 -6928.97 270.61 MWD 9960.00 92.13 39.80 6385.74 267.07 6986.21 5968871.47 569318.57 45.00 -6936.78 270.44 MWD BP Alaska by Baker Hughes INTEQ Planning Report s~R ~ I}Itittil!$ INTEQ Company: BP Amoco.. Dater 4/26/2006 Time: 09:08:20 Page: 3 :Field: Kuparuk Co-ordinate(NE) Reference: WeIL• 25, True North Site:.' ifRU 1C Pad Vertical (TVD)Reference: 1 C-25 Orig Datum 94.2 Well:: 25' Section (VS) Reference: V1feI1(O.OON;O:OOE,260.65Azi) Wellpatb: Plan 3; 1C-25L1 Survey Calcalation Method: Minimum Curvature Bb: Orate Survey MD Incl . Azim - Sys TVD N!S E/W MapN MapE DLS ` VS TFO Tool ft deg .. deg: ft ft ft ft ft deg/100ft ft dEg 9970.00 92.14 35.29 6385.37 274.99 6992.30 5968879.44 569324.59 45.00 -6944.08 270.28 MWD 9980.00 92.15 30.79 6385.00 283.37 6997.74 5968887.86 569329.97 45.00 -6950.81 270.11 MWD 9990.00 92.13 26.29 6384.62 292.14 7002.52 5968896.68 569334.67 45.00 -6956.95 269.94 MWD 10000.00 92.11 21.78 6384.25 301.27 7006.59 5968905.84 569338.66 45.00 -6962.45 269.77 MWD 10010.00 92.07 17.28 6383.89 310.68 7009.93 5968915.28 569341.93 45.00 -6967.27 269.61 MWD 10020.00 92.02 12.78 6383.53 320.33 7012.52 5968924.95 569344.44 45.00 -6971.40 269.44 MWD 10030.00 91.96 8.28 6383.18 330.16 7014.34 5968934.78 569346.18 45.00 -6974.79 269.28 MWD 10039.80 91.89 3.87 6382.85 339.89 7015.38 5968944.52 569347.13 45.00 -6977.40 269.12 MWD 10050.00 91.98 359.27 6382.51 350.08 7015.66 5968954.72 569347.33 45.00 -6979.33 271.20 MWD 10060.00 92.05 354.77 6382.16 360.06 7015.14 5968964.69 569346.73 45.00 -6980.44 271.05 MWD 10070.00 92.12 350.27 6381.79 369.96 7013.84 5968974.58 569345.34 45.00 -6980.76 270.89 MWD 10080.00 92.17 345.77 6381.42 379.74 7011.77 5968984.34 569343.19 45.00 -6980.30 270.72 MWD 10090.00 92.20 341.26 6381.04 389.32 7008.93 5968993.89 569340.27 45.00 -6979.06 270.55 MWD 10100.00 92.23 336.76 6380.65 398.64 7005.35 5969003.19 569336.62 45.00 -6977.05 270.38 MWD 10110.00 92.24 332.26 6380.26 407.66 7001.05 5969012.17 569332.25 45.00 -6974.27 270.21 MWD 10120.00 92.23 327.75 6379.87 416.31 6996.06 5969020.78 569327.18 45.00 -6970.75 270.03 MWD 10130.00 92.21 323.25 6379.48 424.55 6990.40 5969028.96 569321.45 45.00 -6966.50 269.86 MWD 10140.00 92.18 318.75 6379.10 432.31 6984.11 5969036.67 569315.10 45.00 -6961.56 269.68 MWD 10150.00 92.14 314.24 6378.72 439.55 6977.23 5969043.86 569308.17 45.00 -6955.95 269.51 MWD 10160.00 92.08 309.74 6378.35 446.24 6969.81 5969050.48 569300.69 45.00 -6949.71 269.34 MWD 10164.80 92.05 307.58 6378.18 449.23 6966.07 5969053.44 569296.92 45.00 -6946.50 269.17 MWD 10175.00 92.07 306.36 6377.82 455.36 6957.92 5969059.51 569288.72 12.00 -6939.46 271.00 MWD 10200.00 92.11 303.35 6376.90 469.64 6937.42 5969073.61 569268.11 12.00 -6921.55 270.96 MWD 10225.00 92.16 300.35 6375.97 482.82 6916.20 5969086.62 569246.78 12.00 -6902.76 270.85 MWD 10250.00 92.19 297.35 6375.02 494.88 6894.32 5969098.49 569224.81 12.00 -6883.13 270.73 MWD 10275.00 92.22 294.35 6374.06 505.77 6871.84 5969109.19 569202.24 12.00 -6862.72 270.62 MWD 10300.00 92.24 291.35 6373.09 515.47 6848.83 5969118.70 569179.14 12.00 -6841.58 270.51 MWD 10325.00 92.26 288.34 6372.11 523.95 6825.33 5969126.98 569155.58 12.00 -6819.78 270.39 MWD 10350.00 92.27 285.34 6371.12 531.18 6801.43 5969134.02 569131.62 12.00 -6797.36 270.27 MWD 10375.00 92.28 282.34 6370.12 537.16 6777.17 5969139.79 569107.32 12.00 -6774.40 270.15 MWD 10400.00 92.28 279.34 6369.13 541.86 6752.64 5969144.28 569082.75 12.00 -6750.96 270.03 MWD 10425.00 92.27 276.33 6368.14 545.26 6727.90 5969147.48 569057.98 12.00 -6727.10 269.91 MWD 10450.00 92.25 273.33 6367.15 547.37 6703.01 5969149.38 569033.08 12.00 -6702.88 269.79 MWD 10475.00 92.23 270.33 6366.18 548.16 6678.04 5969149.97 569008.11 12.00 -6678.38 269.68 MWD 10500.00 92.21 267.33 6365.21 547.65 6653.07 5969149.25 568983.15 12.00 -6653.65 269.56 MWD 10514.80 92.19 265.55 6364.64 546.74 6638.32 5969148.21 568968.40 12.00 -6638.95 269.44 MWD 10525.00 92.19 266.78 6364.25 546.05 6628.14 5969147.45 568958.23 12.00 -6628.80 90.00. MWD 10550.00 92.18 269.78 6363.30 545.30 6603.17 5969146.49 568933.27 12.00 -6604.04 90.05 MWD 10575.00 92.17 272.78 6362.35 545.86 6578.20 5969146.84 568908.30 12.00 -6579.49 90.16 MWD 10600.00 92.15 275.78 6361.40 547.73 6553.29 5969148.50 568883.38 12.00 -6555.21 90.28 MWD 10614.80 92.14 277.56 6360.85 549.44 6538.61 5969150.09 568868.68 12.00 -6541.00 90.39 MWD 10625.00 92.20 278.78 6360.46 550.89 6528.51 5969151.46 568858.58 12.00 -6531.28 87.00 MWD 10650.00 92.36 281.78 6359.47 555.35 6503.94 5969155.71 568833.97 12.00 -6507.75 87.05 MWD 10675.00 92.50 284.78 6358.41 561.09 6479.63 5969161.25 568809.62 12.00 -6484.70 87.17 MWD 10700.00 92.64 287.78 6357.28 568.09 6455.66 5969168.05 568785.59 12.00 -6462.19 87.29 MWD 10714.80 92.72 289.56 6356.59 572.82 6441.66 5969172.66 568771.55 12.00 -6449.14 87.43 MWD 10725.00 92.74 288.33 6356.11 576.13 6432.02 5969175.89 568761.89 12.00 -6440.17 271.00 MWD 10750.00 92.78 285.33 6354.90 583.36 6408.12 5969182.92 568737.93 12.00 -6417.76 270.94 MWD 10775.00 92.82 282.32 6353.68 589.33 6383.88 5969188.68 568713.64 12.00 -6394.81 270.80 MWD 10800.00 92.85 279.32 6352.44 594.01 6359.35 5969193.17 568689.08 12.00 -6371.37 270.65 MWD 10825.00 92.87 276.32 6351.19 597.41 6334.62 5969196.36 568664.32 12.00 -6347.52 270.50 MWD 10850.00 92.89 273.31 6349.94 599.51 6309.74 5969198.25 568639.43 12.00 -6323.31 270.35 MWD 10875.00 92.90 270.31 6348.67 600.30 6284.79 5969198.83 568614.48 12.00 -6298.82 270.20 MWD 10900.00 92.89 267.31 6347.41 599.78 6259.83 5969198.10 568589.52 12.00 -6274.11 270.05 MWD 10914.80 92.89 265.53 6346.66 598.85 6245.08 5969197.06 568574.79 12.00 -6259.40 269.90 MWD 10925.00 92.31 266.61 6346.20 598.15 6234.91 5969196.27 568564.62 12.00 -6249.26 118.00 MWD 10950.00 90.90 269.26 6345.50 597.25 6209.94 5969195.17 568539.66 12.00 -6224.47 118.05 MWD BP Alaska by Baker Hughes INTEQ Planning Report s~R~ s INTEQ Company: BP Amoco DAte: 4 /2006 Time: 09:08:20 Pagr. 4 Field: Kuparuk Co-ordinat~(NE) Reference: Well: 25, True North Site: KRU 1C Pad Vertical D)Referenee: 1 C-25 Orig Datum 94.2 Well: 25 Section (VS' Reference: Well (O.OON,O.OOE,260.65Azi) Wellpath: Plan 3, 1C-35L1 Survey CaI ulation Method: Minimum C urvature Db: Oracle Survey MD Intl Azim Sys TVD N/S E/W Mep~ N i1lapE DLS VS TFO Toot ft deg deg ft ft ft ft`' ft deg/100ft ft deg 10964.80 90.06 270.82 6345.37 597.26 6195.15 59691 95.05 568524.87 12.00 -6209.87 118.12 MWD 10975.00 89.89 272.04 6345.38 597.52 6184.95 5969 95.22 568514.67 12.00 -6199.85 98.30 MWD 11000.00 89.45 275.00 6345.52 599.05 6160.00 5969 96.55 568489.71 12.00 -6175.48 98.30 MWD 11025.00 89.02 277.97 6345.85 601.88 6135.16 5969 99.17 568464.85 12.00 -6151..44 98.28 MWD 11050.00 88.60 280.94 6346.37 605.98 6110.51 5969 03.07 568440.17 12.00 -6127.78 98.24 MWD 11075.00 88.17 283.91 6347.08 611.36 6086.11 5969 08.25 568415.73 12.00 -6104.57 98.18 MWD 11100.00 87.75 286.89 6347.97 618.00 6062.02 5969 14.68 568391.59 12.00 -6081.89 98.10 MWD 11125.00 87.34 289.86 6349.04 625.87 6038.32 5969 22.35 568367.83 12.00 -6059.78 97.99 MWD 11150.00 86.93 292.84 6350.29 634.96 6015.07 5969 31.25 568344.50 12.00 -6038.31 97.86 MWD 11175.00 86.53 295.81 6351.72 645.24 5992.33 5969 41.34 568321.68 12.00 -6017.54 97.72 MWD 11200.00 86.14 298.80 6353.32 656.68 5970.16 5969 52.59 568299.42 12.00 -5997.53 97.55 MWD 11225.00 85.76 301.78 6355.08 669.26 5948.63 5969 64.99 568277.79 12.00 -5978.33 97.35 MWD 11250.00 85.40 304.77 6357.01 682.93 5927.79 5969 78.49 568256.84 12.00 -5959.99 97.14 MWD 11264.80 85.18 306.53 6358.22 691.52 5915.81 596 86.98 568244.79 12.00 -5949.56 96.91 MWD 11275.00 85.19 305.31 6359.08 697.49 5907.58 9 5969 92.88 568236.51 12.00 -5942.41 270.00 MWD 11300.00 85.20 302.29 6361.18 711.35 5886.88 5969 06.56 568215.69 12.00 -5924.24 270.10 MWD 11325.00 85.22 299.28 6363.26 724.10 5865.48 5969 19.13 568194.19 12.00 -5905.19 270.36 MWD 11350.00 85.26 296.27 6365.34 735.71 5843.44 5969 30.56 568172.06 12.00 -5885.33 270.61 MWD 11375.00 85.31 293.26 6367.39 746.14 5820.82 5969 0.81 568149.35 12.00 -5864.71 270.86 MWD 11400.00 85.38 290.26 6369.42 755.38 5797.68 5969 9.85 568126.14 12.00 -5843.38 271.10 MWD 11425.00 85.45 287.25 6371.42 763.39 5774.08 5969 57.66 568102.48 12.00 -5821.40 271.35 MWD 11450.00 85.54 284.24 6373.38 770.15 5750.10 5969 64.22 568078.44 12.00 -5798.83 271.59 MWD 11475.00 85.64 281.23 6375.30 775.65 5725.79 5969 69.51 568054.09 12.00 -5775.73 271.82 MWD 11500.00 85.76 278.23 6377.18 779.86 5701.22 5969 73.52 568029.49 12.00 -5752.18 272.06 MWD 11514.80 85.83 276.45 6378.26 781.74 5686.59 5969 75.28 568014.84 12.00 -5738.04 272.28 MWD 11525.00 85.83 277.67 6379.00 782.99 5676.49 5969 $76.45 568004.73 12.00 -5728.28 90.00 MWD 11550.00 85.84 280.68 6380.82 786.97 5651.87 5969 80.22 567980.09 12.00 -5704.64 89.91 MWD 11575.00 85.86 283.69 6382.63 792.23 5627.50 5969 $85.28 567955.68 12.00 -5681.45 89.69 MWD 11600.00 85.90 286.70 6384.42 798.77 5603.44 5969 $91.61 567931.57 12.00 -5658.77 89.47 MWD 11625.00 85.94 289.70 6386.20 806.55 5579.76 5969 $99.21 567907.82 12.00 -5636.66 89.26 MWD 11650.00 86.00 292.71 6387.96 815.57 5556.51 5969 108.03 567884.50 12.00 -5615.19 89.04 MWD 11675.00 86.06 295.72 6389.69 825.80 5533.77 596 18.07 567861.68 12.00 -5594.41 88.83 MWD 11700.00 86.14 298.72 6391.39 837.21 5511.59 5969 129.29 567839.41 12.00 -5574.38 88.63 MWD 11725.00 86.23 301.73 6393.05 849.77 5490.04 5969 441.67 567817.76 12.00 -5555.16 88.42 MWD 11750.00 86.33 304.73 6394.68 863.44 5469.18 5969 455.16 567796.78 12.00 -5536.79 88.22 MWD 11775.00 86.44 307.74 6396.26 878.18 5449.05 5969 469.74 567776.54 12.00 -5519.33 88.03 MWD . 11800.00 86.55 310.74 6397.78 893.96 5429.73 5969 485.36 567757.09 12.00 -5502.83 87.84 MWD r~ • ~~ ~ ,~ ~ Ilil !III}+II i,l +i l u l to (+} i`tl# 41 I,. 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' dle:.ec.cidca ; tccz;li:~ji~jcj #~~ - I =si:37i3773fj: :~i~!ci:sitill~#. s •~7 as 3 iaiF7aA BP Alaska ~ s~R ~ by Nuc~s Anticollision Report INTEQ Company: BP Amoco bate: 4/26/2006 ` Time: 13;10:48 Page: I Fieldt Kuparuk Reference Site: KRU 1C Pad `Co-ordinate(NE) Reference: Well: 25, True North Reference Well: 25' Vertical (TVD) Reference: 10-25 Orig Datum 94.2 Reference Wellpath: Plan 3, 1C-25L1 Db: prate NO GLOBAL SCAN: Using user defined selection & scan criteria Reference: Principal Plan & PLANNED PROGRAM Interpolation Method: MD Interval: 100.00 ft Error Model: ISCWSA Ellipse Depth Range: 9696.09 to 11800.00 ft Scan Method: Trav Cylinder North Maximum Radius: 2000.00 ft Error Surface: Ellipse + Casing Survey Program for Defmitive Wellpath Date: 4/25/2006 Validated: No Version: 0 Planned From To Survey Toolcode Tool Name ft ft 94.15 9696.09 MWD (206.12-10140.00) (0) MWD MWD - Standard 9696.09 11800.00 Planned: Plan #3 V5 MWD MWD - Standard Casing Points MD TVD Diameter Hok Size. Name' ft _ ft in in 11800.00 6491.93 3.500 4.500 3.5 Summary G---- OffseYWellpath ---------> Reference Offset Ctr-Ctr No-Go Allowable Site Weil Wellpath MD MD Distance Area.- Deviation ~'1'arning ft ft ft ft ft KRU 1C Pad 15 1C-15 VO Out of range KRU 1C Pad 15 1C-15L1 VO Out of range KRU 1C Pad 27 1C-27 VO 9945.64 9900.00 493.40 436.98 56.42 Pass: Major Risk Site: KRU 1C Pad Well: 27 Rule Assigned: Major Risk Wellpath: 1C-27 VO Inter-Site Error: 0.00 ft Reference Offset Semi-Major Axis Ctr-Ctr No-Go Allowable MD TVD MD TVD Ref Offset TFO+AZI TFO-IiS Casing/It~istance Area Deviation Warning ft ft ft ft ft ft deg deg in ft 8 ft 11664.91 6483.15 7300.00 4758.36 89.20 73.11 265.83 331.33 1971.57 264.54 1707.04 Pass 11639.33 6481.36 7400.00 4813.22 91.59 76.02 262.94 331.51 1903.61 272.44 1631.16 Pass 11612.17 6479.44 7500.00 4866.47 93.87 78.88 259.78 331.61 1839.04 280.95 1558.08 Pass 11584.02 6477.43 7600.00 4919.62 95.94 81.57 256.37 331.60 1776.55 290.04 1486.52 Pass 11555.21 6475.35 7700.00 4973.45 97.74 84.03 252.74 331.43 1715.58 299.78 1415.80 Pass 11211.17 6448.23 7800.00 5027.65 86.42 75.66 270.25 330.12 1643.45 265.91 1377.54 Pass 11188.06 6446.68 7900.00 5082.19 89.02 78.80 267.86 330.48 1572.20 275.15 1297.05 Pass 11163.48 6445.19 8000.00 5136.98 91.58 81.96 265.18 330.74 1502.97 285.02 1217.95 Pass 11136.88 6443.76 8100.00 5190.38 94.12 85.13 262.14 330.86 1437.71 295.80 1141.91 Pass 11108.60 6442.47 8200.00 5243.17 96.52 88.21 258.72 330.81 1375.93 307.53 1068.40 Pass 11075.00 6441.23 8300.00 5296.26 99.01 91.28 254.46 330.55 1317.00 321.24 995.76 Pass 11050.00 6440.52 8400.00 5349.67 100.54 93.65 250.93 329.99 1260.98 333.74 927.24 Pass 11016.61 6439.87 8500.00 5403.28 102.16 96.01 246.13 329.16 1208.47 349.07 859.40 Pass 9728.91 6401.00 9700.00 6064.12 108.11 112.91 117.27 28.23 480.53 367.64 112.89 Pass 9928.68 6481.03 9800.00 6114.80 90.67 92.49 94.81 40.90 485.97 418.32 67.64 Pass 9945.64 6480.42 9900.00 6162.55 82.01 83.94 95.99 49.73 493.40 436.98 56.42 Pass 9958.28 6479.96 10000.00 6207.94 74.73 76.71 99.08 58.50 522.64 440.92 81.72 Pass 9967.71 6479.61 10100.00 6249.66 68.85 70.90 102.49 66.17 571.62 432.65 138.97 Pass 9974.84 6479.34 10200.00 6286.96 64.20 66.33 105.42 72.31 636.19 417.89 218.30 Pass 9980.00 6479.15 10300.00 6319.66 60.78 62.96 107.78 76.99 712.36 402.74 309.63 Pass 9983.98 6479.00 10400.00 6347.45 58.05 60.31 109.43 80.43 797.17 388.12 409.05 Pass 9986.84 6478.89 10500.00 6370.01 56.08 58.42 110.60 82.89 887.59 376.43 511.16 Pass 9990.00 6478.77 10600.00 6386.37 53.92 56.18 110.82 84.53 981.86 362.52 619.34 Pass 9990.00 6478.77 10700.00 6397.74 53.92 56.49 111.95 85.66 1078.31 362.89 715.43 Pass 9990.00 6478.77 10800.00 6403.40 53.92 56.79 112.62 86.33 1176.16 363.39 812.78 Pass 9994.05 6478.62 10900.00 6404.33 51.10 53.64 111.08 86.62 1274.61 344.55 930.07 Pass 9995.29 6478.58 11000.00 6411.58 50.23 52.84 111.07 87.16 1372.72 338.81 1033.91 Pass 9996.16 6478.54 11100.00 6420.48 49.63 52.31 111.22 87.70 1471.21 334.70 1136.51 Pass 10000.00 6478.40 11200.00 6428.38 46.95 49.12 109.86 88.08 1570.45 315.50 1254.95 Pass 10000.00 6478.40 11300.00 6432.05 46.95 49.16 110.10 88.32 1670.21 315.24 1354.97 Pass 10000.00 6478.40 11400.00 6436.22 46.95 49.19 110.33 88.54 1769.98 314.93 1455.05 Pass 10000.00 6478.40 11500.00 6439.23 46.95 49.23 110.50 88.71 1869.83 314.72 1555.10 Pass 10000.00 6478.40 11600.00 6441.58 46.95 49.30 110.63 88.85 1969.69 314.60 1655.09 Pass • • a Kuparuk DOBCTD BOP configuration • 2" CT Well ~ 1 C-25L1 ~ Riq Floor I ~~~ Lubricator ID = SSV ~ W / Master Valve Base Flan e Unions Page 1 KRU 1C-25L1 Subject: KR~_! 1C-25L1 From: Thomas Maunder<tom maundcrru~admin.state.ak.us> Date: Mon, l 0 .Tul ?006 15:34:33 -0800 I'O: ~i~ll'y ~".~li.[ ' ~.~tl['~~.~I~tI' Cl)C~IIlOCO~~}111~1p5.C0111%', D~ln V~~'fl~l~llls -~~ Dan. ~. Vcnh~~us<<1`conocophi t lips.com~= Gary and Dan, A couple of questions as I review this application. 1. What is the proposed BOP test pressure? 2. Is it known when the well will be converted to an injector? Thanks in advance. Tom Maunder, PE AOGCC 1 of 1 7/10/2006 3:34 PM • Terri Hubble BP Exploration AK :Inc. PO Box 196612. MB 7-5 Anchorage, AK_99519 "Mastercard Check" LJ 89-6/1252 286 DATE ~~ ~ p ° J~ PAY TO THE ~~~(J,~ A ~~ /' /~ ORDER OF k~~C. a('7( ( $ //111, O~ (~~ First ational Bank Alaska RS Anchorage,,.. AK 99501 MEMO ' V ~"" "~/ CiI // n A ,. . ~:125200(]60~:9914622?i55611• 0286 • • TRANSMITTAL LETTER CHECKLIST WELL NAME /~~~ ~~" 2S L ~ PTD# Zoe- ~ ~~ 'Development Service Exploratory Stratigraphic Test Non-Conventional Well Circle Appropriate Letter /Paragraphs to be Included in Transmittal Letter CHECK ADD-ONS TEXT FOR APPROVAL LETTER I WHAT (OPTIONS) ~ APPLIES MULTI LATERAL The permit is for a new wellbore se ment of existing ~ ~ '2 well /~/~~ / • ~ V (If [ast two digits in permit No. 19~q-o3/, API No. 50-D~- ZZ„~j / - C7~ API number are between 60-69) I 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. Please note the following special condition of this permit: Non-Conventional production or production testing of coal bed methane is not allowed Well 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 NameZmust contact the Commission to obtain advance approval of such water well testing rogram. Rev: l /25/06 C:\j odyltransmittal_checklist WELL PERMIT CHE KLIST Field 8 Pool KUPARUK RIVER, KUPARUK RIVOIL-490100 Well Name: KUPARUK RIV UNIT 1C-25L1 Program DEV Well bore seg 0 PTD#:2061000 Company CONOCOPHILLIPS ALASKA INC Initial Class/Type DEV! PEND GeoArea 890 Unit 11160 On/off Shore On Annular Disposal ^ Administration 1 Pecmitfee attached - - - - Yes - - - 2 Lease number appropriate- - - - - - - - - - - - - - - - - - Yes Multilateral_wellsegrnent: _top productive interval and-TD in ADL 028242.- - _ - _ _ _ - _ _ _ - - _ _ _ _ _ - - - - - - - 3 Uniquewell_nameandnumb_er____________________________-..___--, Yes_ _-__________,______-__--_- 4 Well located in a_defnedpool ---------------------------- Yes _ - - _ . - KUPARUK RIVER,_KUPARUK RV OIL - 490100, governed by Conservation Ord_eC No. 4320. 5 Well located proper distance from drilling unitboundary- - _ - - Yes _ - - - - - -Conservation Order No. 4320 contains no Spacing restrictions with respect to drilling unit boundaries. 6 Well located proper distance from- other wells . . . . . . . . . . . .... Yes Conservation Order No. 4320 has no interwell_spacing-restrictions, - _ _ _ - - - - . - _ - - _ _ - _ - _ - _ - - - - - - 7 Sufficient acreage available in_drillinqunit- - - _ _ . _ - _ - - Yes - - - - - - -Conservation Order No. 4320 has.no irlterwell-s acin _restrictions, Wellbore will be more than 500' from - p 9 8 If deviated, is wellbore plat_inc_lu_ded _ - . _ _ - - _ - - Yes _ _ _ - - - - an external property linewhe[e_ownership or_landownership changes. 9 Ope[atoronlyaffectedparty--------------------- ----------------- Yes- _____--__. - - 10 OpQ[atorhas_appropriate.bondinforce_________________________________ Yes- _____-___-__- ------------------------------------------------------------- 11 Pecmitcan be issued without co_nseryationorder- _ - Yes - _ _ - _ - - . _ ------------------------------------------------------------------ Appr Date 12 Pecmitcan be issued without ad_minist[ativ_e-approval _ _ - Yes _ - ------------------------------------------------------------- SFD 7110/2006 13 Can permit be approved before 15-day wait Yes 14 Well located within area and strata authorized by Injection Order # (put_1O# in-comments)-(For- NA- - - - - - - - - - - - - - - - ----------- 15 Allwells,within1l4_mileareaofreyiewidentified(FOCServicewellonly)_______________ NA_. _-.... __-.___._____--______-----_------_--_------------ 16 Pre-produced injector: duration of pre production Less than_ 3 months_ (For service well only) - - NA- - - - - - - - - - - - - 17 Nonconyen,gasconformstoAS31,05,030(j.1.A),Q.2.A-D)----_-_______________ NA-- ------------------------------------------------------ -------------------- Engineering 18 _C_onductorstcing_provided---------------------___________________ NA__ ----_-Conductorsetinmotherbore,-1C-25_(199-031).__-_----___________ ____________--__-_ 19 Surface-casing-protect&all_knownUSDWs_______________________________ NA__ -_____Allaquifersexempted,40CFR-147.1Q2_(b)~3).-_---_---__--__-_____ _____________-----_ 20 CMT_voladeguate-tocirculate_onconductor&su_rf_csg----------------____- NA _ Surf_acecasingsetin_motherbore.____-______-____-___-__-_-_-_---_----__----- 21 CMT-voladequate_totie-in long string to surfcsg__-________________________ NA__ _----_Production_easingset in-motherbore._-__-___-------___--_--__-----__-______ -____ 22 CMT_will ccuer all known_productive horizons_ _ _ _ - - - -- - - - - - --- - - - - - - - - - - - - No_ _ _ _ _ Slotted liner completion planned, _ _ _ _ _ _ _ _ _ _ - - - - - _ - _ _ - - - _ - - _ _ . -- - - 23 Casing desgns adequate for- C, T B & permaf[ost- _ _ _ _ _ _ _ _ _ _ _ _ _ NA_ - _ - _ - - - 9[iginal well met design_requirements, NA for slotted_liner, _ - - - - _ - - - - - _ _ _ - _ _ - - - - . - 24 Adequate tankage-or reserve pit _ _ . _ _ - - _ - Yes Rig is_equipped with steel_pits. No r_esen!e_pitplanned, All waste to approved annulus ordisposal wel_Is - - - . - - 25 If a_re-drill, has_a 10-403 far abandonment been approved NA_ _ - - _ - . - - - . _ 26 Adequate wellbore separation-proposed . . ........... . ... . . . . . . . . . . . . .. . . Yes _ _ _ _ _ _ _ Only proximate wellbore section is_motherbor@. _Both.are located within rese[voir._ - .. - . _ _ . _ - - - _ - . - _ - - 27 If_diverterrequired, does it meet regulations. - - - - - - - - - - - - - NA_ _ - _ - _ - BOP stackwill ai[eady-be in place. - ------------------------------------- Appr Date 28 Drillingf1uid-program schematic & equip list adequate- - - - - - - - - -- - - - - - - - - - -- - Yes - - _ - . -Maximum expected formation pressure 10 2 EMW._ Planned MW 9.6 ppgwith-imposQd surface pressure.- - - - - - TEM 7113l2D06 29 BOPEs,_dotheymeetregu_lotion----------------------------- Yes- ---------------------.-------------------------------------------- e~/~ 30 BOPE_press rating appropriate; test to_(put p&ig in comments)_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes _ - _ - - - - MASP calculatedat 2771 psi. 3500_psi_BOP testplanned, . _ _ _ . _ _ _ _ _ _ - _ _ _ _ _ . _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ 31 Choke_manif4ldcomplieswlAPI-RP-53(M_ay84)____________________________ Yes- _-_--__--_--__--__--__ 32 Work willoccurwithoutoperationshutdown_______ _____________________ Yes_ -__---_--_- -- 33 Is presence of N2Sgas-probable - . _ - _ _ - _ _ - - _ _ - - _ Yes _ .. _ - .. H2S up t9 84 ppm has_beQn [eported in offsetproduction._ Rig has_seosors and alarms. 34 Mechanical condition of wells within AOR verified (Forse[vice well only) NA_ Well is planned to bean-injector.. Bond_loq and AOR-are planned-- - - - -- - - - - - - - - - - Geology 35 Permit_can be issued w/o hydrogen-sulfide measures . _ - - No_ - - - - - . -Parent wellbore KRU 1C-25-measured 60 ppm H2S on 6/18106, 36 Data_presented on potential overpressure zones - - - - - - - - - - - - - Yes - - - _ - - - Parent wellbore measured 5.5 ppq EMW._ Pressure expected to increase as lateral is drilled- - - _ - - , - - . - - - - Appr Date 37 Seismic analysis of shallow gas-zones- . - - - - - - NA_ _ - _ _ - - -away from-paregt wellbore. -Will be drilled with coiled_tubinq using Managed Pressure SFD 7/4012006 38 Seabed condition Surrey-(rfgff-shore) - - - ...... - .. - - NA_ _ Drillin p y g p _ _ _ - g techniques to-adjustbottomhole ressure d namically_durin o erations._ 39 Contact namelphone for weekly_progress repods [exploratory only] - - _ NA_ Geologic Date: Engineering Date Public Date Horizontal lateral producer targeting the Kuparuk C4 sand. Will be drilled from existing well KRU 1 C-25. Commissioner: issio er C o mm n : Commissioner ~ ~ ~ / l , C~/1~7T~C~ ~ ~~-C~,lo •