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HomeMy WebLinkAbout204-195 · . Image Project Well History File Cover Page XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. ~ Q if - ~ 1- S- Well History File Identifier Organizing (done) ~o-sided 11111111111 ""111I D Rescan Needed II I II 11111111111111 RESCAN ~or Items: D Greyscale Items: DIGITAL DATA OVERSIZED (Scannable) D Maps: D Other Items Scannable by a Large Scanner D Diskettes, No. D Other, NolType: D Poor Quality Originals: D Other: OVERSIZED (Non-Scannable) D Logs of various kinds: NOTES: D Other:: BY: ~ 151 ·kììf 11111111111111" III Date:U /:3 0/ Ó?; 151 rvtf I I ~ x 30 =&0 + d. / = TOTAL PAGES tQ I (Count does not include cover sheet) Date: " 151 Date: t I ð () / 0 {¡; I Project Proofing BY: ~ Scanning Preparation BY: Production Scanning 11111111111111" III Stage 1 Page Count from Scanned File: Cl %l.. (Count does include cover sheet) -tL YES NO BY: ~ Page Count Matches Number in Scanning Preparation: Date: 1/ laol DC::> 151 mp NO Stage 1 If NO in stage 1, page(s) discrepancies were found: YES BY: Maria Date: 151 II 1111111 III" 1111I Scanning is complete at this point unless rescanning is required. ReScanned 11111111111111" III BY: Maria Date: 151 Comments about this file: Quality Checked 111111111111111111I 10/6/2005 Well History File Cover Page.doc • • WELL LOG TRANSMITTAL II° PROAcrivE DIAgNOSiic SERVICES, INC. To: AOGCC Christine Mahnken 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 [907) 659 -5102 RE : Cased Hole /Open Hole /Mechanical Logs and /or Tubing Inspection(Caliper/ MTT) The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the following : ProActive Diagnostic Services, Inc. Attn: Robert A. Richey 130 West International Airport Road Suite C Anchorage, AK 99518 Fax: (907) 245 -8952 vZ� cDo r93 a(59a 1 Caliper Report 30- Mar-11 1D-32 L1 1 Report / EDE 50 -029- 22982 -60 2) RECEIVED APR 1 9 2011 Signed : ( - - Date : . Jr, . Print Name: « . PROACTIVE DIAGNOSTIC SERVICES, INC., 130 W. INTERNATIONAL AIRPORT RD SUITE C, ANCHORAGE, AK 99518 C:\Documenis and Settings \Diane Williams \Desktop \CIE_Transmitdocx 1 • • MOM Memory Multi - Finger Caliper a l p � Log Results Summary I Company: ConocoPhillips Alaska, Inc. Well: 1D-32 L1 Log Date: March 30, 2011 Field: Kuparuk I Log No.: SO# 10258377 ZX70 State: Alaska Run No.: 2 API No.: 50 -029- 22982 -60 Pipet Desc.: 3.5" 9.3 Ib. L -80 Top Log Intvl: Surface 1 Pipet Use: Tubing Bot. Log Intvl: 13,275 Ft. (MD) I nspection Type : Corrosive & Mechanical Damage Inspe 1 COMMENTS : This caliper data is tied into the XN Nipple as 13,268' (Driller's Depth). 1 This log was run to assess the condition of the tubing with respect to corrosive and mechanical damages. The caliper recordings indicate the majority of the 3.5" tubing logged is in fair to poor condition with respect to corrosive damages. Probable Holes are recorded at 11,564 ft, 12,603 ft. and 11,808 ft. Wall penetrations from 20% to 98% wall thickness are recorded in 402 of the 425 joints logged. The damage appears in the form of general corrosion with deeper lines of corrosion and isolated pitting. Cross - sectional wall loss of 31% is recorded in an area of corrosion in joint 237 @ 7,475 ft. No Significant ID restrictions are recorded I throughout the interval logged. This is the second time a caliper has been run in this well. A comparison between the current log and the previous log (October 3, 2004), indicates a change in tubing. 1 This summary report is an interpretation of data provided by Halliburton Well Services. 1 MAXIMUM RECORDED WALL PENETRATIONS : Probable Hole ( 98 %) Jt. 369 @ 11,564 Ft. (MD) I Probable Hole ( 97%) (95 %) Jt. 402 @ 12,603 Ft. (MD) Probable Hole Jt. 376 @ 11,808 Ft. (MD) Probable Hole ( 94 %) Jt. 394 © 12,370 Ft. (MD) I Probable Hole ( 93 %) Jt. 390 @ 12,245 Ft. (MD) MAXIMUM RECORDED CROSS - SECTIONAL METAL LOSS : I Corrosion ( 31%) (25 %) Jt. 237 @ 7,475 Ft. (MD) Corrosion Jt. 219 @ 6,883 Ft. (MD) Corrosion ( 23 %) Jt. 198 @ 6,228 Ft. (MD) Corrosion ( 23 %) Jt. 238 @ 7,477 Ft. (MD) 1 Corrosion ( 22 %) Jt. 325 @ 10,219 Ft. (MD) MAXIMUM RECORDED ID RESTRICTIONS : 1 No significant I.D. restrictions are recorded throughout the interval logged. I ( Field Engineer: J. Conrad Analyst: J. Thompson Witness: J. Condio ProActive Diagnostic Services, Inc. / P.0, Box 1369, Stafford, TX 77497 Phone: (281) or (888) 565 -9085 Fax: (281) 565 -1369 E -mail: PDS©memorylog.com Prudhoe Bay Field Office Phone: (907) 659 -2307 Fax: {907) 659 -2314 1 1 L iaOq— i9s aociats- I 110 • Correlation of Recorded Damage to Borehole Profile I ® Pipe 1 3.5 in (49.7' - 13269.9') Well: 1 D-32 L1 Field: Kuparuk I Company: ConocoPhillips Alaska, Inc. Country: USA Survey Date: March 30, 2011 I I ■ Approx. Tool Deviation ■ Approx. Borehole Profile 1 50 IIMAI IML- 50 --- 1578 I/ 100 — 3142 1 I 150 4703 GLM 1 I — 200 6290 E Li c Z a y IL I c n ° 250 7851 .. WO i 00 ill r _ 3 9410 "llg 1 350 = 10970 I 400 . Y 12530 I 422 13270 0 50 100 I Damage Profile (% wall) / Tool Deviation (degrees) Bottom of Survey = 422 I I I • • I Report Overview 1 S Body Region Analysis I Well: 1D-32 L1 Survey Date: March 30, 2011 Field: Kuparuk Tool Type: UW MFC 24 No Hal 10000429 Company: ConocoPhillips Alaska, Inc. Tool Size: 1.69 Country: USA No. of Fingers: 24 Tubing: 3.5 ins 9.3 ppf L -80 Analyst: J. Thompson Tubing: Nom.OD Weight Grade & Thread Nom.ID Nom.Upset Upper len. Lower len. 1 3.5 ins 9.3 ppf L -80 2.992 ins 3.5 ins 6.0 ins 6.0 ins I Penetration(% wall) Damage Profile (% wall) I 300 ■IMM— Penetration body wow Metal loss body 0 50 100 250 I 1 200 150 -- _ 51 I 100 — — 0 101 _ I 0 to 20 to 40 to over 20% 40% 85% 85% Number of joints analysed (total = 425) 151 -- 1 23 107 280 15 GLM 1 199 I Damage Configuration ( body) - 200 nut 249 I 150 299 100 _ I 50 349 0 P I Isolated General Line Other Hole/ — Pitting Corrosion Corrosion Damage Pos. Hole 399 1 I Number of joints damaged (total = 417) 183 196 25 0 13 Bottom of Survey = 422 I I I I I • • PDS REPORT JOINT TABULATION SHEET I Pipe: 3.5 in 9.3 ppf L -80 Well: 1 D -32 L1 Body Wall: 0.254 in Field: Kuparuk I Upset Wall: 0.254 in Company: ConocoPhillips Alaska, Inc. Nominal I.D.: 2.992 in Country: USA Survey Date: March 30, 2011 I Joint Jt. Depth Pen. Pen. Pen. Metal Min. Damage Profile No. (Ft.) U % Upset Body Loss I.D. Comments (% wall) (Ins.) (Ins.) % (Ins.) 0 50 100 I 1 50 0 0.04 15 6 2.93 Shallow Line of Pits. 2 81 0 0.04 16 7 2.93 Shallow Pitting. t 3 112 0 0.03 11 6 2.92 Lt. Deposits. ■ 4 143 0 0.03 13 6 2.91 Shallow Pitting. Lt. Deposits. ■ 5 174 0 0.04 14 7 2.93 Shallow Pitting. Lt. Deposits. i 6 206 0 0.04 17 6 2.93 Shallow Line of Pits. Lt. Deposits. 7 237 0 0.04 14 8 2.93 Shallow Pitting. Lt. Deposits. i 8 268 0 0.03 13 7 2.94 Shallow Pitting. i 9 299 0.03 0.04 15 7 2.92 Shallow Line of Pits. Lt. Deposits. 1 I 10 331 0 0.04 17 9 2.92 Shallow Line of Pits. Lt. Deposits. 11 361 0 0.06 24 10 2.93 Isolated Pitting. 12 392 0 0.05 20 9 2.94 Shallow Pitting. 13 423 0 0.05 21 11 2.93 Isolated Pitting. I 14 453 0 0.03 13 5 2.91 Shallow Pitting. Lt. Deposits. ■ 15 484 0 0.06 25 11 2.92 Line Corrosion. Lt. Deposits. 16 515 0 0.05 19 7 2.93 Shallow Pitting. Lt. Deposits. N 16.1 546 0 0 0 0 2.85 X Nipple I 17 548 0.01 0.06 24 10 2.92 Isolated Pitting. Lt. Deposits. 18 579 0 0.03 12 5 2.93 Shallow Pitting. Lt. Deposits. • 19 611 0 0.05 20 7 2.90 Shallow Pitting. Lt. Deposits. ■ 20 642 0 0.06 23 7 2.92 Isolated Pitting. Lt. Deposits. i 21 673 0 0.05 18 6 2.92 Shallow Pitting. Lt. Deposits. ■ I 22 705 0 0.06 24 6 2.92 Line of Pits. Lt. Deposits. ■ 23 736 0.05 0.05 21 10 2.92 Isolated Pitting. Lt. Deposits. 24 767 0 0.04 14 6 2.93 Shallow Pitting. Lt. Deposits. ■ 25 798 0 0.05 19 7 2.93 Shallow Pitting. Lt. Deposits. 1 I 26 829 0 0.04 17 10 2.93 Shallow Pitting. Lt. Deposits. 27 861 0 0.05 20 9 2.93 Line of Pits. Lt. Deposits. 28 892 0.04 0.05 18 9 2.93 Shallow Pitting. Lt. Deposits. 29 923 0 0.05 19 7 2.92 Shallow Pitting. Lt. Deposits. 1 I 30 954 0 0.06 24 11 2.92 Isolated Pitting. Lt. Deposits. 31 986 0 0.04 17 9 2.90 Shallow Pitting. Lt. Deposits. 32 1017 0.03 0.06 25 9 2.92 Line of Pits. Lt. Deposits. 33 1048 0 0.05 19 9 2.92 Shallow Pitting. Lt. Deposits. 1 34 1079 0 0.05 18 4 2.92 Shallow Pitting. Lt. Deposits. ■ I 35 1110 0 0.06 22 3 2.93 Isolated Pitting. Lt. Deposits. • 36 1142 1) 0.07 28 4 2.92 Line of Pits. Lt. Deposits. ■ 37 1173 0 0.06 22 4 2.93 Line of Pits. Lt. Deposits. ■ 38 1204 0 0.06 23 7 2.93 Line of Pits. Lt. Deposits. I 39 1235 0.04 0.07 29 9 2.94 Line of Pits. i 40 1267 0 0.05 21 4 2.94 Line of Pits. • 41 1298 0 0.06 24 , 6 2.94 Isolated Pitting. ■ 42 1328 0.04 0.06 24 11 2.94 Isolated Pitting. I 43 1360 0.04 0.07 28 8 2.93 Line of Pits. Lt. Deposits. i 44 1391 0 0.05 20 6 2.93 Isolated Pitting. Lt. Deposits. ■ 45 1422 0.06 0.06 24 7 2.92 Line of Pits. Lt. Deposits. 1 46 1453 0.04 0.05 21 9 2.93 Isolated Pitting. Lt. Deposits. 47 1485 0 0.05 19 6 2.92 Shallow Pitting. Lt. Deposits. ■ I 48 1516 0 0.05 20 7 2.95 Line of Pits. i 49 1547 0.04 0.06 22 7 2.93 Line of Pits. Lt. Deposits. Penetration Bo I Metal Loss Body Page 1 Penetra I I I • • PDS REPORT JOINT TABULATION SHEET I Pipe: 3.5 in 9.3 ppf L-80 Well: 1 D-32 L1 Body Wall: 0.254 in Field: Kuparuk I Upset Wall: 0.254 in Company: ConocoPhillips Alaska, Inc. Nominal I.D.: 2.992 in Country: USA Survey Date: March 30, 2011 I Joint Jt. Depth Pen. Pen. Pen. Metal Min. Damage Profile No. (FL) Upset Body % Loss I.D. Comments (% wall) (Ins.) (Ins.) % (Ins.) 0 50 100 I 50 1578 0.08 0.11 , 42 11 2.92 Isolated Pitting. Lt. Deposits. 51 1610 0.06 0.06 25 5 2.94 Isolated Pitting. 52 1641 0.03 0.07 26 6 2.91 Line of Pits. Lt. Deposits. 4 53 1673 0 0.08 31 13 2.93 Isolated Pitting. s. 54 1704 0.04 0.06 22 6 2.92 Line of Pits. Lt. Deposits. L I 55 1735 0.04 0.07 27 6 2.93 Line of Pits. Lt. Deposits. 56 1766 0 0.06 22 5 2.90 Line of Pits. Lt. Deposits. 57 1798 0 0.07 26 4 2.93 Isolated Pitting. Lt. Deposits. 58 1829 0 0.07 27 5 2.93 Isolated Pitting. Lt. Deposits. • I 59 1860 0 0.07 26 7 2.93 Line of Pits. Lt. Deposits. 60 1892 0 0.06 24 6 2.89 Isolated Pitting. Lt. Deposits. 61 1923 0 0.06 24 5 2.93 Line of Pits. Lt. Deposits. 62 1954 0 0.06 22 5 2.95 Isolated Pitting. I 63 1985 0 0.06 24 6 2.93 Isolated Pitting. Lt. Deposits. 64 2017 0 0.06 22 3 2.93 Line of Pits. Lt. Deposits. 65 2048 0 0.07 27 4 2.90 Line of Pits. Lt. Deposits. 66 2079 0.03 0.06 22 7 2.92 Isolated Pitting. Lt. Deposits. I 67 2110 0.04 0.09 37 8 2.93 Isolated Pitting. Lt. Deposits. 68 2141 0 0.09 37 9 2.91 Line of Pits. Lt. Deposits. 69 2173 0.04 0.06 24 6 2.92 Line of Pits. Lt. Deposits. P 70 2204 0 0.06 24 6 2.93 Line of Pits. Lt. Deposits. 71 2235 0 0.05 21 8 2.91 Isolated Pitting. Lt. Deposits. I 72 2266 0 0.08 31 12 2.92 Isolated Pitting. Lt. Deposits. L "I 73 2298 0.04 0.12 46 12 2.93 Line of Pits. Lt. Deposits. L I MN 74 2329 0.07 0.09 37 11 2.93 Line of Pits. Lt. Deposits. L 75 2360 0.07 0.07 29 13 2.93 Line of Pits. Lt. Deposits. I 76 2392 0.05 0.09 34 16 2.93 Corrosion. 77 2423 0.06 0.09 34 13 2.92 Isolated Pitting. Lt. Deposits. 78 2454 0.04 0.08 32 6 2.92 Line of Pits. Lt. Deposits. 79 2485 0 0.05 21 8 2.92 Isolated Pitti ng. Li Deposits. _ _ I 80 2517 0 0.08 33 7 2.93 Isolated Pitting. Lt. Deposits. 81 2548 0.03 0.08 33 6 2.91 Line of Pits. Lt. Deposits. 82 2579 0 0.09 36 7 2.92 Line of Pits. Lt. Deposits. il 83 2610 0 0.09 34 7 2.92 Isolated Pitting. Lt. Deposits. is 84 2642 0 0.07 28 9 2.88 Line of Pits. Lt. Deposits. I 85 2673 0 0.09 34 8 2.92 Line of Pits. Lt. Deposits. L S 86 2704 0.06 0.11 43 18 2.92 Isolated Pitting. Lt. Deposits. M I 87 2736 0.07 0.08 33 17 2.93 Isolated Pitting. Lt. Deposits. 88 2767 0.09 0.11 44 18 2.95 Line Corrosion. I 89 2798 0.13 0.11 44 17 2.93 Isolated Pitting. Lt. Deposits. 90 2829 0.03 0.07 26 7 2.93 Line of Pits. Lt. Deposits. IL IL 91 2861 0.03 0.08 32 9 2.93 Line of Pits. Lt. Deposits. k 92 2892 0 0.11 42 5 2.91 Line of Pits. Lt. Deposits. I 93 2923 0 0.07 29 7 2.93 Isolated Pitting. Lt. Deposits. L 94 2954 0 0.07 27 5 2.92 Line of Pits. Lt. Deposits. 95 2986 0.06 0.12 48 11 2.93 Line of Pits. Lt. Deposits. 96 3017 0.07 0.08 30 13 2.94 Corrosion. 97 3048 0.06 0.07 28 16 2.93 Corrosion. Lt. Deposits. 98 3079 0.07 0.08 31 14 2.90 Isolated Pitting. Lt. Deposits. 99 3110 0.05 0.07 26 14 2.93 Isolated Pitting. - ",1 o I Metal LoPenetratiss n Body Page 2 I I • • PDS REPORT JOINT TABULATION SHEET I Pipe: 3.5 in 9.3 ppf L -80 Well: 1D-32 L1 Body Wall: 0.254 in Field: Kuparuk I Upset Wall: 0.254 in Company: ConocoPhillips Alaska, Inc. Nominal I.D.: 2.992 in Country: USA Survey Date: March 30, 2011 I Joint Jt. Depth Pen. Pen. Pen. Metal Min. Damage Profile No. (Ft.) Upset Body % I oss I.D. Comments (% wall) (Ins.) (Ins.) % (Ins.) 0 50 100 I 100 3142 0.07 0.09 33 15 2.91 Line of Pits. Lt. Deposits. u■� 101 3173 0.05 0.07 28 6 2.93 Line Corrosion. �■■I 102 3204 0.03 0.11 44 5 2.92 Line of Pits. Lt. Deposits. ■■■ 103 3235 0 0.09 33 8 2.93 Line Corrosion. Lt. Deposits. o■■ 104 3267 0 0.09 35 6 2.91 Line Corrosion. Lt. Deposits. L■■ I 105 3298 0 0.08 31 7 2.92 Line of Pits. Lt. Deposits. �■■ 106 3329 0.06 0.11 43 12 2.93 Line of Pits. Lt. Deposits. on 107 3360 0.09 0.09 35 18 2.93 Isolated Pitting. Lt. Deposits. or 108 3391 0.07 0.09 37 11 2.95 Line of Pits. ■■ I 109 3422 0.07 0.08 31 16 2.94 Isolated Pitting. In 110 3454 0.08 0.10 37 14 2.93 Isolated Pitting. ■■ 111 3485 0.06 0.08 33 10 2.93 Isolated Pitting. Lt. Deposits. ■■ 112 3516 0.04 0.11 44 7 2.93 Line of Pits. Lt. Deposits. 1 ■r I 1 13 3548 0.03 0.11 43 6 2.94 Line Corrosion. •■■ 114 3579 0 0.12 46 4 2.92 Line of Pits. Lt. Deposits. ■■■ 115 3610 0 0.10 38 9 2.93 Line of Pits. Lt. Deposits. ■■ 116 3642 0.05 0.08 33 7 2.93 Line Corrosion. Lt. Deposits. u■ I 117 3673 0 0.09 35 9 2.92 Line of Pits. Lt. Deposits. i■■ 118 3704 0.05 0.09 36 10 2.94 Isolated Pitting. Emu 119 3735 0.05 0.10 39 11 2.93 Line of Pits. Lt. Deposits. ■■ 120 3766 0.04 0.09 35 9 2.93 Line of Pits. Lt. Deposits. m■■ 121 3797 0.07 0.09 35 9 2.92 Line of Pits. Lt. Deposits. on I 122 3828 0 0.11 43 7 2.92 Isolated Pitting. Lt. Deposits. moo 123 3859 0.0 3 0.11 44 8 2.95 Line of Pits. t■■ 124 3890 0 0.10 40 8 2.93 Line of Pits. t■■ 125 3922 0.05 0.09 35 14 2.93 Corrosion. on I 126 3953 0.04 0.10 39 13 , 2.94 Corrosion. 127 3984 0 0.11 44 9 2.91 Line of Pits. Lt. Deposits. ■* 128 4015 0.01 0.08 31 7 2.94 Line Corrosion. m■n 129 4046 0.05 0.09 34 14 2.94 Line of Pits. on I 130 4078 0.05 0.08 30 13 2.94 Line of Pits. ■i 131 4108 0 0.09 33 5 2.93 Line of Pits. limn 132 4140 0.04 0.10 39 9 2.92 Line of Pits. Lt. Deposits. on 133 4171 0.06 0.14 57 9 2.93 Line of Pits. Lt. Deposits. ■■ 134 4202 0.08 0.14 55 12 2.93 Line Corrosion. on I 135 4234 0.09 0.11 43 17 2.89 Corrosion. Lt. Deposits. no 4265 0.07 0.13 50 13 2.93 Line Corrosion. Lt. Deposits. ■■ 137 4296 0.05 0.10 41 9 2.91 Corrosion. Lt. Deposits. i■■ 138 4328 0 0.12 48 10 2.90 Line of Pits. Lt. Deposits. ■■ I 139 4359 0 0.09 36 10 2.91 Corrosion. Lt. Deposits. ■■ 140 4390 0 0.11 44 9 2.92 Line Corrosion. Lt. Deposits. i■■ 141 4421 0 0.10 41 13 2.92 Line Corrosion. Lt. Deposits. ■■ 142 4452 0 0.10 38 8 2.93 Isolated Pitting. Lt. Deposits. ill MI I 143 4483 0.06 0.11 41 7 2.90 Line of Pits. Lt. Deposits. moo 144 4515 0.04 0.13 50 9 2.92 Corrosion. Lt. Deposits. ■■ 145 4546 0 0.11 44 9 2.92 Line Corrosion. Lt. Deposits. i■■ 146 4578 0 0.10 39 6 2.92 Line of Pits. Lt. Deposits. u■ 147 4609 0 0.11 , 44 8 2.93 Line of Pits. Lt. Deposits. i■■ I 148 4640 0.06 0.09 35 8 2.92 Isolated Pitting. Lt. Deposits. 1■■ 149 4671 0.07 0.09 35 19 2.93 Corrosion. Lt. Deposits. Penetration Body I Metal Loss Body Page 3 I I I • • PDS REPORT JOINT TABULATION SHEET I Pipe: 3.5 in 9.3 ppf L -80 Well: 1 D -32 L1 Body Wall: 0.254 in Field: Kuparuk I Upset Wall: 0.254 in Company: ConocoPhillips Alaska, Inc. Nominal I.D.: 2.992 in Country: USA Survey Date: March 30, 2011 I Joint Jt. Depth Pen. Pen. Pen. Metal Min. Damage Profile No. (Ft.) Upset Body % I cuss I.D. Comments (% wall) (Ins.) (Ins.) % (Ins.) 0 50 100 f 150 4703 0.06 0.10 40 15 2.93 Corrosion. ENO 151 4734 0.09 0.11 43 11 2.91 Corrosion. Lt. Deposits. MM. 152 4765 0.08 0.16 61 15 2.89 Line of Pits. Lt. Deposits. ANN 153 4797 0 0.14 57 9 2.92 Corrosion. Lt. Deposits. mom II 154 4827 0.04 0.13 50 9 2.92 Line of Pits. Lt. Deposits. mom 155 4859 0 0.15 59 9 2.92 Corrosion. Lt. Deposits. mill■ 156 4890 0.07 0.12 48 13 2.90 Corrosion. Lt. Deposits. ■om 157 4920 0.05 0.15 59 15 2.93 Isolated Pitting. Lt. Deposits. ■mo 158 4951 0.05 0.12 48 7 2.91 Corrosion. Lt. Deposits. MIME I 159 4983 0.04 0.13 50 1 1 , 2.92 Corrosion. Lt. Deposits. mom 160 5013 0 0.11 45 9 2.93 Corrosion. Lt. Deposits. ■om 161 5044 0 0.12 47 1 1 2.92 Corrosion. Lt. Deposits. , mm 162 5076 0.04 0.10 39 12 2.90 Corrosion. Lt. Deposits. moil I 163 5107 0.08 0.12 48 19 2.93 Corrosion. Lt. Deposits. mom 5138 0.09 0.11 42 12 2.93 Corrosion. Lt. Deposits. mom 165 5169 0 0.11 42 8 2.92 Corrosion. Lt. Deposits. mom 165.1 5201 0 0.11 42 9 2.94 Pup Line of Pits. I 165.2 5211 0 0 0 0 2.87 GLM 1 (Latch @ 11:00) �"� 165.3 5217 0 0.09 37 7 2.92 Pup Isolated Pitting. Lt. Deposits. ��� 166 5227 0 0.14 56 12 2.91 Line of Pits. Lt. Deposits. ■■■ 167 5259 0.03 0.12 46 10 2.92 Corrosion. Lt. Deposits. mom 168 5290 0.10 0.14 55 11 2.91 Corrosion. Lt. Deposits. ,m■ I 169 5321 0.06 0.10 40 11 2.90 Corrosion. Lt. Deposits. m�� 170 5352 0.05 0.13 52 14 2.93 Line of Pits. Lt. Deposits. ■om 171 5383 (1.05 0.17 67 14 2.93 Line of Pits. Lt. Deposits. MN 172 5415 0.08 0.10 40 14 2.90 Corrosion. Lt. Deposits. lim■ I 173 5446 0.08 0.18 69 19 2.92 Line Corrosion. Lt. Deposits. ism 174 5477 0.07 0.13 53 13 2.91 Corrosion. Lt. Deposits. mom 175 5509 0.08 0.14 53 10 2.93 Corrosion. Lt. Deposits. mom 176 5540 0.14 0.15 60 10 2.93 Corrosion. Lt. Deposits. mom I 177 5571 0.09 0.15 59 14 2.87 Corrosion. Lt. Deposits. ■�■ 178 5602 0.07 0.12 46 14 2.93 Corrosion. Lt. Deposits. ■o. 179 5633 0.08 0.12 49 9 2.91 Corrosion. Lt. Deposits. mom 180 5664 0.04 0.22 88 9 2.90 Possible Hole! Lt. Deposits. mom 181 5696 0.04 0.16 63 9 2.91 Isolated Pitting. Lt. Deposits. IMIIN I 182 5727 0.03 0.13 50 7 2.91 Isolated Pitting. Lt. Deposits. mom 183 5759 0 0.17 67 7 2.91 Isolated Pitting. Lt. Deposits. mom 184 5790 0 0.11 42 9 2.92 Corrosion. Lt. Deposits. imam 185 5821 (1.04 0.17 65 9 2.90 Isolated Pitting. Lt. Deposits. el I 186 5853 0.04 0.09 37 8 2.92 Lt. Deposits. im�� 187 5884 0 0.09 37 7 2.92 Corrosion. Lt. Deposits. i.. 188 5915 0.05 0.16 64 7 2.91 Line of Pits. Lt. Deposits. mom 189 5946 0.04 0.17 69 8 2.91 Corrosion. Lt. Deposits. imp 190 5978 0 0.09 37 10 2.92 Corrosion. Lt. Deposits. Nod 191 6009 0 0.10 41 8 2.92 Corrosion. Lt. Deposits. maw 192 6040 0.07 0.13 51 17 2.92 Corrosion. Lt. Deposits. INN 193 6071 0.08 0.12 46 18 2.93 Corrosion. Lt. Deposits. moo 194 6102 0.10 0.14 56 19 2.93 Corrosion. Lt. Deposits. mom 195 6133 0.13 50 14 2.91 Corrosion. Lt. Deposits. mom 196 6165 0 0.13 50 2.90 Corrosion. Lt. Deposits. ratdy I Metal Loss ion Body Page 4 Penet I I I • • PDS REPORT JOINT TABULATION SHEET I Pipe: 3.5 in 9.3 ppf L -80 Well: 1 D -32 L1 Body Wall: 0.254 in Field: Kuparuk I Upset Wall: 0.254 in Company: ConocoPhillips Alaska, Inc. Nominal I.D.: 2.992 in Country: USA Survey Date: March 30, 2011 I Joint Jt. Depth Pen. Pen. Pen. Metal Min. Damage Profile No. (Ft.) Upset Body % Loss I.D. Comments (% wall) (Ins.) (Ins.) %> (Ins.) 0 50 100 I 197 6196 0.10 0.20 77 15 2.91 Corrosion. Lt. Deposits. ammo 6227 0.10 0.16 62 23 2.90 Corrosion. Lt. Deposits. ■■■ 199 6258 0.09 0.18 71 21 2.91 Corrosion. Lt. Deposits. ■N■ 200 6290 0.09 0.19 76 16 2.93 Corrosion. Lt. Deposits. IA■ 201 6321 0.07 0.11 43 18 2.88 Corrosion. Lt. Deposits. Emil I 202 6352 0.07 0.15 60 12 2.90 Corrosion. Lt. Deposits. ■■■■ 203 6383 0.03 0.14 54 13 2.92 Corrosion. Lt. Deposits. ■A■■ 204 6414 0 0.18 70 11 2.91 Corrosion. Lt. Deposits. ■A■■ 205 6445 0.07 0.15 59 11 2.92 Isolated Pitting. Lt. Deposits. maw I 206 6476 0.07 0.16 64 11 2.92 Corrosion. Lt. Deposits. ■■■ 207 6508 0.04 0.12 48 8 2.91 tine Corrosion. Lt. Deposits. maim 208 6539 0.08 0.11 42 10 2.90 Corrosion. Lt. Deposits. NN■ 209 6570 0.09 0.10 40 14 2.92 Corrosion. Lt. Deposits. ■Ao I 210 6601 0.08 0.18 72 19 2.93 Corrosion. Lt. Deposits. Nam 6632 0.06 0.14 55 20 2.90 Lt. Deposits. mom 212 6663 0.06 0.17 69 15 2.92 Corrosion. Lt. Deposits. num 213 6694 0 0.13 52 13 2.95 Corrosion. IMAM I 214 6725 0.06 0.15 57 13 2.90 Lt. Deposits. ammo 215 6757 0 0.19 75 15 2.91 Isolated Pitting. Lt. Deposits. imam 216 6788 0,06 0.15 59 17 2.91 Corrosion. Lt. Deposits. I■■N 217 6819 0.09 0.14 57 18 2.92 Corrosion. Lt. Deposits. mom 218 6850 0.10 0.17 65 16 2.92 Corrosion. Lt. Deposits. ENN■ I 219 6882 0.10 0.13 51 25 2.91 Corrosion. Lt. Deposits. 220 6913 0.06 0.11 44 9 2.90 Corrosion. Lt. Deposits. no ■■ ■■d 221 6944 0.05 0.17 66 10 2.94 Corrosion. ■NO■ 222 6975 0.12 0.14 56 19 2.92 Corrosion. Lt. Deposits. i■•■ I 223 7007 0.09 0.16 63 21 2.92 Corrosion. Lt. Deposits. ■■■ 224 7038 0.09 0.17 69 9 2.90 Corrosion. Lt. Deposits. i■■■ 225 7069 0 0.11 44 8 2.92 Isolated Pitting. Lt. Deposits. NEE 3 226 7101 0.06 0.12 47 11 2.92 Corrosion. Lt. Deposits. Moo I 227 7132 0.11 0.13 52 15 2.92 Corrosion. Lt. Deposits. mom 228 7164 0.14 0.13 52 14 2.93 Line Corrosion. Lt. Deposits. am M 229 7194 0.06 0.12 45 10 2.93 Corrosion. Lt. Deposits. Noll 230 7226 0.03 0.15 61 9 2.91 Isolated Pitting. Lt. Deposits. AAA 231 7257 0.04 0.11 42 8 2.92 Corrosion. Lt. Deposits. Ima■II 1 232 7288 0.07 0.14 54 9 2.93 Corrosion. Lt. Deposits. MMMM 233 7319 0.04 0.17 66 9 2.91 Corrosion. Lt. Deposits. ■■■ 234 7351 0.03 0.11 42 13 2.92 Corrosion. Lt. Deposits. moon 235 7382 0.05 0.16 65 15 2.92 Corrosion. Lt. Deposits. ■NIA I 236 7413 0.07 0.13 52 14 2.93 Corrosion. Lt. Deposits. ■NNN 237 7445 0.13 0.15 60 31 2.91 Corrosion. Lt. Deposits. ■A 238 7476 0.12 0.15 57 23 2.90 Corrosion. Lt. Deposits. ■■ 239 7507 0 0.12 45 11 2.91 Corrosion. Lt. Deposits. ■■■ I 240 7538 0 0.12 49 10 2.90 Corrosion. Lt. Deposits. mom 241 7570 0.05 0.11 44 7 2.92 Corrosion. Lt. Deposits. iNN■ 242 7601 0.04 0.11 42 12 2.91 Corrosion. Lt. Deposits. mom 243 7632 0.07 0.12 49 11 2.92 Lt. Deposits. mom 244 7663 0.06 0.12 48 11 2.91 Corrosion. Lt. Deposits. ■N■ I 245 7695 0 0.11 42 8 2.91 Corrosion. Lt. Deposits. um= 246 7726 0 0.11 41 11 2.91 Corrosion. Lt. Deposits. rat I Metal Loss ion Body I Page 5 Penet I • • PDS REPORT JOINT TABULATION SHEET Pipe: 3.5 in 9.3 ppf L -80 Well: 1D-32 L1 Body Wall: 0.254 in Field: Kuparuk Upset Wall: 0.254 in Company: ConocoPhillips Alaska, Inc. I Nominal I.D.: 2.992 in Country: USA Survey Date: March 30, 2011 I Joint Jt. Depth Pen. Pen. Pen. Metal Min. Damage Profile No. (Ft.) Upset Body % Loss I.D. Comments (°/0 wall) (Ins.) (Ins.) % (Ins.) 0 50 100 I 247 7757 0.06 0.11 43 13 2.93 Corrosion. Lt. Deposits. 248 7788 0.06 0.11 42 7 2.92 Corrosion. Lt. Deposits. 249 7820 0.07 0.11 45 17 2.93 Corrosion. Lt. Deposits. 1. 250 7851 0.10 0.10 41 15 2.92 Corrosion. Lt. Deposits. 251 7882 0.09 0.11 41 19 2.92 Corrosion. Lt. Deposits. I 252 7914 0.06 0.12 45 7 2.91 Corrosion. Lt. Deposits. 253 7945 0.03 0.11 44 8 2.90 Corrosion. Lt. Deposits. 254 7976 0.06 0.13 52 8 2.92 Corrosion. Lt. Deposits. x 255 8008 0.07 0.13 50 15 2.90 Isolated Pitting. Lt. Deposits. _, I 256 8039 0.08 0.12 48 10 2.91 Corrosion. Lt. Deposits. "` 257 8070 0 0.13 49 10 2.93 Corrosion. Lt. Deposits. L. 258 8102 0.03 0.13 52 13 2.91 Corrosion. Lt. Deposits. I_ 259 8133 0.05 0.15 60 11 2.90 Corrosion. Lt. Deposits. L __ I 260 8164 0.06 0.14 54 15 2.92 Corrosion. Lt. Deposits. 261 8196 0.12 0.12 48 7 2.92 Corrosion. Lt. Deposits. 262 8227 0.05 0.14 54 11 2.91 Corrosion. Lt. Deposits. 14.._ 263 8258 0 0.22 85 11 2.91 Corrosion. Lt. Deposits. L 264 8289 0 0.16 63 11 2.91 Corrosion. Lt. Deposits. /1._ I 265 8321 0 0.12 48 8 2.91 Corrosion. Lt. Deposits. L 8352 ).03 0.15 57 14 2.91 Corrosion. Lt. Deposits. L 267 8383 ).07 0.16 64 16 2.91 Corrosion. Lt. Deposits. L 268 8414 0.09 0.13 50 19 2.91 Corrosion. Lt. Deposits. I 269 8445 0.15 0.12 46 12 2.92 Corrosion. Lt. Deposits. 270 8477 0.03 0.12 48 7 2.90 Corrosion. Lt. Deposits. 271 8508 0 0.16 62 11 2.90 Corrosion. Lt. Deposits. i_ 272 8539 0 0.16 61 12 2.91 Corrosion. Lt. Deposits. I 273 8570 0 0.14 56 10 2.90 Corrosion. Lt. Deposits. 274 8602 0 0.15 61 9 2.91 Isolated Pitting. Lt. Deposits. 275 8633 0.04 0.18 72 12 2.92 Corrosion. Lt. Deposits. I` 276 8664 0.06 0.13 52 17 2.91 Corrosion. Lt. Deposits. L I 277 8695 0.06 0.18 70 15 2.91 Corrosion. Lt. Deposits. L 278 8727 0.04 0.16 64 13 2.91 Corrosion. Lt. Deposits. L 279 8758 0.04 0.13 50 8 2.90 Corrosion. Lt. Deposits. L 280 8788 0.07 0.14 55 14 2.92 Corrosion. Lt. Deposits. I. 281 8820 0.04 0.14 54 9 2.91 Corrosion. Lt. Deposits. L I 282 8850 0 0.18 69 ) 2.90 Corrosion. Lt. Deposits. L 283 8881 0.08 0.14 55 3 2.92 Corrosion. Lt. Deposits. 284 8911 0.07 0.12 48 i 5 2.93 Corrosion. Lt. Deposits. 285 8943 0.06 0.10 38 7 2.91 Corrosion. Lt. Deposits. - I 286 8974 0.04 0.13 51 10 2.91 Corrosion. Lt. Deposits. 287 9005 0 0.17 66 18 2.90 Corrosion. Lt. Deposits. 288 9037 0.04 0.18 70 11 2.92 Corrosion. Lt. Deposits. L 289 9068 0.04 0.12 47 9 2.90 Corrosion. Lt. Deposits. I 290 9099 0.16 0.12 46 2.90 Corrosion. Lt. Deposits. 291 9130 0.09 0.15 59 8 2.90 Corrosion. Lt. Deposits. 292 9162 0.06 0.14 54 9 2.93 Corrosion. Lt. Deposits. 293 9193 0.04 0.18 72 17 2.91 Corrosion. Lt. Deposits. L 294 9224 0.11 0.14 57 16 2.90 Corrosion. Lt. Deposits. I 295 9256 0.06 0.16 61 13 2.92 Corrosion. Lt. Deposits. 296 9287 0.07 0.10 39 16 2.91 Line of Pits. Lt. Deposits. 1 Prat I Meta enet l Loss ion Body Page 6 I I IIII' , S • PDS REPORT JOINT TABULATION SHEET 1 Pipe: 3.5 in 9.3 ppf L -80 Well: 1 D -32 L1 Body Wall: 0.254 in Field: Kuparuk I Upset Wall: 0.254 in Company: ConocoPhillips Alaska, Inc. Nominal I.D.: 2.992 in Country: USA Survey Date: March 30, 2011 I Joint ft. Depth Pen. Pen. Pen. Metal Min. Damage Profile No. (Ft.) Upset Body % Loss I.D. Comments (% wall) (Ins.) (Ins.) % (Ins.) 0 50 100 I 297 9318 0.04 0.17 67 10 2.91 Isolated Pitting. Lt. Deposits. 298 9348 0.04 0.17 68 12 2.92 Corrosion. Lt. Deposits. 299 9379 0.04 0.15 59 11 2.92 Corrosion. Lt. Deposits. 300 9410 0.05 0.17 68 12 2.92 Corrosion. Lt. Deposits. 301 9442 0.03 0.15 60 9 2.92 Corrosion. Lt. Deposits. I 302 9473 0.07 0.17 68 10 2.92 Corrosion. Lt. Deposits. 303 9503 0.20 0.12 46 15 2.90 Line of Pits. Lt. Deposits. , 304 9534 0.07 0.16 62 18 2.91 Corrosion. Lt. Deposits. 305 9566 0.08 0.21 82 11 2.92 Corrosion. Lt. Deposits. I 306 9597 0.07 0.13 52 14 2.92 Corrosion. Lt. Deposits. 307 9628 0.11 0.12 48 13 2.92 Corrosion. Lt. Deposits. 308 9659 0.07 0.15 60 15 2.92 Corrosion. Lt. Deposits. 309 9691 0.08 0.12 49 14 2.91 Corrosion. Lt. Deposits. I 310 9722 0.11 0.17 66 16 2.90 Lt. Deposits. 311 9753 0.05 0.17 67 17 2.92 Corrosion. Lt. Deposits. 312 9784 0.04 0.15 58 10 2.91 Corrosion. Lt. Deposits. 313 9815 0.04 0.14 56 8 2.91 Isolated Pitting. Lt. Deposits. 314 9846 0.05 0.18 72 11 2.91 Corrosion. Lt. Deposits. 4 '` I 315 9877 0.15 0.16 63 19 2.91 Corrosion. Lt. Deposits. 316 9909 0.12 0.15 59 19 2.92 Isolated Pitting. Lt. Deposits. I I 317 9939 0.09 0.15 61 15 2.91 Corrosion. Lt. Deposits. 318 9970 0.07 0.15 60 6 2.91 Lt. Deposits. holmentig I 319 10002 0.08 0.16 63 8 2.90 Corrosion. Lt. Deposits. 320 10033 0.06 0.14 57 12 2.92 Corrosion. Lt. Deposits. 321 10064 0.11 0.14 54 12 2.90 Corrosion. Lt. Deposits. 322 10095 0.06 0.13 51 14 2.90 Line of Pits. Lt. Deposits. I 323 10127 0.07 0.14 55 10 2.91 Line of Pits. Lt. Deposits. L 324 10158 0.07 0.16 61 20 2.93 Isolated Pitting. Lt. Deposits. 325 10189 0.22 0.15 57 22 2.91 Corrosion. Lt. Deposits. IL 326 10221 0.09 0.14 54 19 2.92 Corrosion. Lt. Deposits. I 327 10252 0 0.18 69 10 2.91 Corrosion. Lt. Deposits. IL 10283 0.05 0.11 42 15 2.92 Isolated Pitting. Lt. Deposits. 329 10314 0 0.16 63 14 2.92 Isolated Pitting. Lt. Deposits. L 330 10345 0.14 0.14 56 10 2.92 Line of Pits. Lt. Deposits. L 331 10377 0.09 0.14 57 9 2.90 Corrosion. Lt. Deposits. ".. ' 332 10408 0.06 0.18 70 19 2.93 Corrosion. Lt. Deposits. 333 10439 0.10 0.15 60 18 2.91 Corrosion. Lt. Deposits. I 334 10470 0.07 0.15 59 18 2.92 Corrosion. Lt. Deposits. r._ 335 10502 0.03 0.10 39 7 2.92 Isolated Pitting. Lt. Deposits. 1 I 336 10533 0.04 0.17 68 11 2.93 Line of Pits. Lt. Deposits. 337 10564 0 0.17 67 8 2.87 Corrosion. Lt. Deposits. 41•11 338 10595 0.03 0.11 44 9 2.92 Isolated Pitting. Lt. Deposits. 339 10626 0.05 0.14 57 6 2.92 Line Corrosion. Lt. Deposits. i 'AM I 340 10658 0.09 0.16 63 13 2.90 Line of Pits. Lt. Deposits. 1 ` 341 10689 0.10 0.18 69 10 2.91 Corrosion. Lt. Deposits. L "� 342 10720 0.11 0.19 76 12 2.93 Corrosion. Lt. Deposits. F 343 10751 0.11 0.21 82 13 2.94 Corrosion. O il 344 10782 0.06 0.12 47 15 2.91 Line of Pits. Lt. Deposits. 345 10814 0.07 0.17 69 12 2.92 Corrosion. Lt. Deposits. y 346 10845 0.05 0.17 65 11 2.91 Corrosion. Lt. Deposits. C rat I Penet Metal Loss ion BoBody dy Page 7 I I I • • PDS REPORT JOINT TABULATION SHEET I Pipe: 3.5 in 9.3 ppf L -80 Well: 1 D -32 L1 Body Wall: 0.254 in Field: Kuparuk Upset Wall: 0.254 in Company: ConocoPhillips Alaska, Inc. I Nominal I.D.: 2.992 in Country: USA Survey Date: March 30, 2011 I Joint Jt. Depth Pen. Pen. Pen. Metal Min. Damage Profile No. (Ft.) Upset Body % Loss I.D. Comments (% wall) (Ins.) (Ins.) % (Ins.) 0 50 100 I 347 10876 0.03 0.15 60 11 2.90 Corrosion. Lt. Deposits. mom 10908 0.05 0.15 61 9 2.92 Corrosion. Lt. Deposits. ■■■■■ 349 10939 0.04 0.19 74 8 2.91 Line of Pits. Lt. Deposits. i■■■■ 350 10970 0.07 0.14 , 54 13 2.92 Lt. Deposits. ■■■■i 351 11001 0.04 0.20 78 9 2.92 Line Corrosion. Lt. Deposits. ■■■ I 352 11033 0.08 0.11 42 11 2.92 Isolated Pitting. Lt. Deposits. ■■�� 353 11064 0.08 0.12 48 14 2.94 Line of Pits. ■■■ 354 11095 0.07 0.15 59 8 2.90 Corrosion. Lt. Deposits. i■■■■ 355 11126 0.05 0.17 66 10 2.92 Corrosion. Lt. Deposits. MI 111111111•M I 356 11157 0.09 0.15 59 13 2.91 Isolated Pitting. Lt. Deposits. 357 11189 0.10 0.14 54 16 2.92 Corrosion. Lt. Deposits. ■■■■ �■■■� 358 11220 0.23 0.18 69 16 2.90 Corrosion. Lt. Deposits. i■■ 359 11251 0 0.11 43 5 2.90 Isolated Pitting. Lt. Deposits. ■■�■ il' I 360 11282 0 0.20 78 13 2.90 Corrosion. Lt. Deposits. i 361 11313 0.05 0.12 48 8 2.91 Line of Pits. Lt. Deposits. ■ ■ 362 11344 0.07 0.14 56 11 2.91 Line of Pits. Lt. Deposits. ■■ 363 11375 0.07 0.14 53 9 2.90 Corrosion. Lt. Deposits. =m 364 11406 0.14 0.14 54 10 2.94 Corrosion. ■ ■ I 365 11438 0.23 0.15 59 7 2.90 Line Corrosion. Lt. Deposits. I■■■■■ 366 11469 0 0.19 74 9 2.92 Line of Pits. Lt. Deposits. ■■■ 367 11500 0.04 0.12 48 10 2.91 Line of Pits. Lt. Deposits. ■■■�' 368 11531 0.07 0.12 48 13 2.92 Line of Pits. Lt. Deposits. ■■■ I 369 11563 0.07 0.25 98 15 2.90 Probable Hole! Lt. Deposits. mums 11593 0 0.16 64 11 2.90 Corrosion. Lt. Deposits. ■■■■■ 371 11625 0.04 0.17 68 9 2.93 Line Corrosion. Lt. Deposits. ■■■■ 372 11656 0.06 0.14 57 15 2.92 Corrosion. Lt. Deposits. a■■■ol I 373 11687 0.09 0.20 79 17 2.95 Corrosion. moms 11718 0 0.23 91 8 2.90 Possible Hole! Lt. Deposits. i■■■■■ ■ ■ ■■ 375 11750 0.06 0.18 71 10 2.90 Corrosion. Lt. Deposits. ■■ ■ 376 11781 0.05 0.24 95 14 2.90 Probable Hole! Lt. Deposits. ■■ull 377 11812 0.06 0.15 59 6 2.90 Line of Pits. Lt. Deposits. I III III ■■■ I 378 11843 0 0.20 80 13 2.92 Line Corrosion. Lt. Deposits. mom 379 11874 0.11 0.17 65 9 2.91 Corrosion. Lt. Deposits. ■■■ 380 11906 0.07 0.10 41 9 2.91 Line of Pits. Lt. Deposits. i■■ ■" 381 11937 0.05 0.19 74 10 2.90 Corrosion. Lt. Deposits. ■■■■■ 382 11968 0.04 0.20 80 9 2.90 Isolated Pitting. Lt. Deposits. loom 383 12000 0.05 0.18 71 9 2.90 Corrosion. Lt. Deposits. ■■■■■ 384 12031 0.04 0.18 71 10 2.91 Line of Pits. Lt. Deposits. ■■■■■ 385 12062 0.09 0.21 82 1:3 2.90 Line Corrosion. Lt. Deposits. ■■•■■ I 386 12093 0.09 0.20 80 20 2.93 Corrosion. Lt. Deposits. ■ ■ ■■ 387 12125 0.07 0.19 76 12 2.93 Corrosion. Lt. Deposits. ■■■■■ 388 12156 0.05 0.16 63 13 2.90 Isolated Pitting. Lt. Deposits. ■■■■■ 389 12187 0.04 0.20 80 6 2.90 Line of Pits. Lt. Deposits. I■■■■■ I 390 12218 0.08 0.24 93 9 2.91 Possible Hole! Lt. Deposits. ■■■■ 391 12250 0.04 0.13 51 12 2.91 Isolated Pitting. Lt. Deposits. ■■ ■ ■� 392 12281 0.05 i U5 0.22 86 11 2.90 Possible Hole! Lt. Deposits. ■■■■■ 393 12312 0 0.23 91 11 2.93 Multiple Possible Holes! Lt. Deposits. ■■■■■ 394 12344 0.04 0.24 94 13 2.91 Possible Hole! Lt. Deposits. ■■■•■ I 395 12375 0.06 0.18 72 7 2.92 Line Corrosion. Lt. Deposits. i ■■■■■ 396 12406 0 0.21 84 10 2.91 Corrosion. Lt. Deposits. I Pration M enet o n Loss Body I Page 8 I I I s • PDS REPORT JOINT TABULATION SHEET I Pipe: 3.5 in 9.3 ppf L -80 Well: 1D-32 L1 Body Wall: 0.254 in Field: Kuparuk Upset Wall: 0.254 in Company: ConocoPhillips Alaska, Inc. I Nominal I.D.: 2.992 in Country: USA Survey Date: March 30, 2011 I Joint Jt. Depth Pen. Pen. Pen. Metal Min. Damage Profile No. (Ft.) Upset Body % toss I.D. Comments ( %wall) (Ins.) (Ins.) % (Ins.) 0 50 100 I 397 12437 0.09 0.23 90 13 2.92 Multiple Possible Holes! Lt. Deposits. ■����� 398 12469 0 0.19 75 15 2.91 Corrosion. Lt. Deposits. ■���■ 399 12499 0.09 0.17 68 6 Corrosion. Lt. Deposits. onommE] 400 12530 0.04 0.18 69 8 2.90 Corrosion. Lt. Deposits. mum= 401 12561 0.05 0.22 85 8 2.92 Line Corrosion. Lt. Deposits. inonnoms I 402 12593 0.13 0.25 97 9 2.90 Multiple Probable Holes! Lt. Deposits. simuunima 403 12623 0 0.21 83 10 2.92 Corrosion. Lt. Deposits. mwmaimmi 404 12655 0.11 0.18 70 11 2.91 Corrosion. Lt. Deposits. ■moolom 405 12686 0.06 0.20 78 22 2.91 Corrosion. Lt. Deposits. ■•••• I 406 12718 0.06 0.18 71 11 2.94 Corrosion. ������ 407 12749 0.07 0.18 72 12 2.90 Corrosion. Lt. Deposits. ■����� 408 12780 0.22 0.20 77 13 2.92 Corrosion. Lt. Deposits. ■ommom 409 12811 0.11 0.22 86 19 2.91 Possible Hole! Lt. Deposits. immeam. I 410 12843 0.05 0.18 72 7 2.91 Line of Pits. Lt. Deposits. 411 12874 0.09 0.14 55 1 1 2.93 Line Corrosion. Lt. Deposits. r���� �����' 412 12905 0.13 0.23 89 22 2.92 Multiple Possible Holes! Lt. Deposits. mtimm 413 12936 0.12 0.16 63 20 2.91 Corrosion. Lt. Deposits. moomin 414 12968 0.07 0.19 76 9 2.91 Line of Pits. Lt. Deposits. lanso m I 415 12999 0.04 0.23 89 11 2.92 Possible Hole! Lt. Deposits. ������ 416 13030 0.06 0.17 67 15 2.93 Corrosion. Lt. Deposits. ■ om 417 13061 0.04 0.21 84 11 2.93 Corrosion. Lt. Deposits. ■NE 418 13092 0.04 0.10 41 8 2.90 Line of Pits. Lt. Deposits. r���1 I 418.1 13124 0.06 0.13 51 8 2.90 Pup Isolated Pitting. Lt. Deposits. "" 418.2 13133 0 0 0 0 2.75 Sliding Sleeve 418.3 13138 0.13 0.13 53 12 2.91 Pup Corrosion. Lt. Deposits. .m.. 419 13147 0.08 _ 0.15 58 8 2.92 Isolated Pitting. Lt. Deposits. Ilii I 419.1 13179 0 0 0 0 2.85 Packer 420 13183 0.05 0.10 39 6 2.93 Line of Pits. Lt. Deposits. „ 420.1 13221 0 0 0 0 4.14 Seal Assembly 421 13230 0.12 0.15 61 14 2.84 Corrosion. Lt. Deposits. 421.1 13268 0 0 0 0 2.75 X Nipple 422 13270 0 0 0 0 2.75 End of Log. IPenetration Body I Metal Loss Body I I I I Page 9 I I I • • I TF.i7IS PDS Report Cross Sections I Well: 1D-32 L1 Survey Date: March 30, 2011 Field: Kuparuk Tool Type: UW MFC 24 No Hal 10000429 Company: ConocoPhillips Alaska, Inc. Tool Size: 1.69 Country: USA No. of Fingers: 24 1 Tubing: 3.5 ins 9.3 ppf L -80 Analyst: J. Thompson I I Cross Section for Joint 369 at depth 11564.250 ft Tool speed = 52 Nominal ID = 2.992 I Nominal OD = 3.5 _� Remaining wall area = 89% `'� Tool deviation = 66° 1 I I 1 1 I 1444441"1111,11■1100.......1 /00°°1111/ I Finger = 3 Penetration = 0.248 ins Probable Hole 0.25 ins = 98% Wall Penetration HIGH SIDE = UP I I I I I 1 • • 1 PDS Report Cross Sections I Well: 1D-32 Ll Kuparuk Survey Date: March 30, 2011 Field: Tool Type: UW MFC 24 No Hal 10000429 Company: ConocoPhillips Alaska, Inc. Tool Size: 1.69 Country: USA No. of Fingers: 24 1 Tubing: 3.5 ins 9.3 ppf L -80 Analyst: J. Thompson I I Cross Section for Joint 402 at depth 12603.230 ft Tool speed = 51 Nominal ID = 2.992 k 1 Nominal OD = 3.5 Remaining wall area = 90% Tool deviation = 67° /� 1 1 1 -- 1 il i 1 . \ / 1 y11111.11/ I Finger = 3 Penetration = 0.246 ins Probable Hole 0.25 ins = 98% Wall Penetration HIGH SIDE = UP 1 1 I 1 I j • • I PDS Report Cross Sections ' Well: 1D-32 L1 Kuparuk Survey Date: March 30, 2011 Field: Tool Type: UW MFC 24 No Hal 10000429 Company: ConocoPhillips Alaska, Inc. Tool Size: 1.69 Country: USA No. of Fingers: 24 II Tubing: 3.5 ins 9.3 ppf L -80 Analyst: J. Thompson 1 I Cross Section for Joint 237 at depth 7474.900 ft Tool speed = 52 Nominal ID = 2.992 0100111111111 Nominal OD = 3.5 Remaining wall area = 69% 1 Tool deviation = 68° ` ii / ` / / \ 1 i 1 1 \ _._ I , , , \ , I \ li, I 44 1414111, I Finger = 4 Penetration = 0.152 ins Corrosion 31% Cross - Sectional Wall Loss HIGH SIDE = UP I I I 1 I • • I PDS Report Cross Sections I Well: 1D -32 Ll Survey Date: Tool Type: March 30, 2011 Field: Kuparuk UW MFC 24 No Hal 10000429 Company: ConocoPhillips Alaska, Inc. Tool Size: 1.69 Country: USA No. of Fingers: 24 I Tubing: 3.5 ins 9.3 ppf L -80 Analyst: J. Thompson I I Cross Section for Joint 219 at depth 6882.540 ft Tool speed = 53 Nominal ID = 2.992 I Nominal OD = 3.5 111111111111144\ Remaining wall area = 75% �--� Tool deviation = 65° \\ 1 1 1 / \ i l I 1 1 / ''"'' • • -.-- • ■ asoll1/10 I Finger = 11 Penetration = 0.130 ins Corrosion 25% Cross - Sectional Wall Loss HIGH SIDE = UP I I I I I I 71 Cono[oPhi ~ 1 KUP 1D -32L1 lops �( Attribut gle a MD TD ".d 3 .A, tv. 'Iplellhoro APl'U1 ReM Nama JJeB tile. Eiiit hci ( NOfit4:81 II Act 91m(14411 cor.0 S:6, 500292298260 KUPARUK RIVER UNIT IINJ 95 15 15,944. Comment If ( l i t 12S (ppm) Dab Edit Annobton /Bad Orb Edit RS-Ord HO Rig Release II,. I SSSV: NIPPLE BS ll120 Last W0: 11!27!20 35.56 12!4!20 u T�•� — Annpbilon Oap41 (tins) Old Edif Alxlpbbn 'Alt Mod B! Bid Data ., Last Tag: CTMD 14,440.0 8!1 Rev Reason: Casing/Tubing TalBes ninam 2115/201 1 L___ Casing Strings Citing Oescnptlon Strang OD.. Strang ID... Top (MEN Set [spill (1... Set Dapu3 Oj... String Wt.. Stang ... Strang Top ill I LINER TOP 312 2.992 13,183.0 13,8500 6,549.9 9.30 L-80 SLHT Oiling Coserlpt!on String 00- Sting ID... Top (TIER) set Cepin it.. Set Depth i TJD)... String' lot.. Sting ... Sting Top TII LINER Lt (GC) 2 3(8 1.995 13,748.4 15,924.0 6,574.8 4.70 L -80 STL Liner Details L : Top Depth Top (T /D} Top EN Nom l... (tt('RI itt(Ri 1 I Ibm Dsscdplon Comm ant !DM) ' tltl.1111ttl(1it nl IL 6,507.8 65.41 DEPLOY SLV LI BAKER DEPLOYMENT SLEEVE 2.250 13,7492 6,508.1 65.41 SLEEVE BAKER TORQUE SLEEVE 1.995 CONDUCTOR Nm,3vuT 15,692.3 6,577.5 95.04 0 -RING BAKER STL O -RING SUB 1.000 Mu 15,9122 6,575.8 95.02 MOTOR Li WEATHERFORD USED 23/8" ADJ. MOTOR, DAL 11' 15,9234 6,574.8 9502 BIT HYCALOG USED BI BIT I Y1PP LE, UI Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Edit Top Captl Top MD) Top hci (1108) (1068) ( °i De Ionpton Comment Ron Date 113( (MI 13,748.0 6,507.6 65.42 Deploy SLV LI BAKER DEPLOYMENT SLEEVE 10/29/2004 2.250 I GAL LIFT, 5,119 15,912.0 6,575.8 95.02 MOTOR Li WEATHERFORD USED 23"ADJ. MOTOR, OALit' 14!292004 0.000 Perforations & Slots IE(1tt 31101 Bin Top (T1131 BM iT /Di Den. Top iit /51 itt1B) fill.' R1 1116 DI Darn Cots i111_. TO. Comment I 13 15,892.9 6,521.0 6,577.6 C2, C -1, C-2, 10/30/2004 8,0 IPERE Slotted Liner with 3/8" holes 1 I C -t, 1D-3211 1 Notes: General & Safety I+ ! End rote Annobton 10/29/2004 NOTE: Bi- LATERAL WELL: 1D32 DRLD 1214,2000; CTD DRLD I D32L110/302004 1 OVP1! • , • 10/2972004 NOTE: 1D-30L1 WILL BE PRE - PRODUCED BEFORE GOING TO INJECTION •oc., 3r9 2/15/2011 NOTE: View Schematic w /Alaska Schematic 9.0 OLE 13,164 iry .'S 'a I I I I '1;'.71 L . 1 1 �E..L, 13,213 I , OI Sl0'Ii '68 P RO RUCTION R1C, 3} EV , 13811- 298. L'N EX 1/ I IVO, W INNOW LI, 13,8,.`6- 13,636 LINEN TDP, 13,18 3-I3R3O • fI -1 — — _ r . I IPEPf, ••••• P80, 13 13 . 810 ��an X P60, ,8/1 .---- IPEPE, 13.9.- 13,94a Mandrel Details 1111 t Top Dopti port Top iT Ol Top CO Leb11 Sias TRO Run I L1NE1,DC. Sin 1 IIIB( 1111 BI Eel i "1 Nape Nodel (In 'I son 'EN ve Toe r (In) ipell Run Gab Om_ 5,179.1 CAM... KBUG -M 1 1/2 GAS LIFT DM'? BK 0.000 0.0 111272005 13,t8}Ia,13. .1)8 U • • MICROFILMED 03!01 /2008 ~;~ ,, r- ~~` R: DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE F:\LaserFicheiCvrPgs_Inserts~lldicrofilm_Marker.doc ') ~ /0~v ~\ð DATA SUBMITTAL COMPLIANCE REPORT 10/13/2006 Permit to Drill 2041950 Well Name/No. KUPARUK RIV UNIT 1D-32L 1 Operator CONOCOPHILLlPS ALASKA INC MD 15944/ TVD 6573 /' Completion Date 10/31/2004 /" Completion Status 1-01L REQUIRED INFORMATION Mud Log No Samples No Current Status WAGIN )"w:!. .</ a~À.\M~ API No. 50-029-22982-60-00 ~--- Directional Survey Yes DATA INFORMATION Types Electric or Other Logs Run: GR / ROP / PRESS Well Log Information: Electr Digital Dataset Med/Frmt Number Name C Lis 13777 Gamma Ray 13777 LIS Verification Gamma Ray Gamma Ray C Lis 13778 Gamma Ray 13778 LIS Verification Gamma Ray Gamma Ray 25 Blu 5 Blu Log Log Run Scale Media No 25 Blu 25 Blu (data taken from Logs Portion of Master Well Data Maint Interval OH/ Start Stop CH Received Comments 13826 15944 Open 4/12/2006 GR plus Graphics Open 4/12/2006 13826 15944 Open 4/12/2006 GR 13826 15944 Open 4/12/2006 GR 13832 15062 Open 4/12/2006 PB 1 GR 13832 15062 Open 4/12/2006 PB 1 GR i 13832 15062 Open 4/12/2006 PB 1 GR - I 13832 15062 Open 4/12/2006 PB 1 GR . Well Cores/Samples Information: Name Interval Start Stop Received Sent ADDITIONAL INFORMATION Well Cored? 1W Chips Received? ~ Daily History Received? Formation Tops Analysis Received? ~ Sample Set Number Comments . ~N 0/N Comments: DATA SUBMITTAL COMPLIANCE REPORT 10/13/2006 Permit to Drill 2041950 Well Name/No. KUPARUK RIV UNIT 1D-32L 1 Operator CONOCOPHILLlPS ALASKA INC API No. 50-029-22982-60-00 MD 15944 Current Status WAGIN", UIC Y Date: ___'1IU Q \l À.~ ~_ TVD 6573 Completion Status 1-01L Compliance Reviewed By: . . Re: FW: Kuparuk ID-32 Leak Detect Log . . Hi Steve, The paper copy will make it over, but if you can send the electrons that would be appreciated. Tom Mukavitz, Steve J wrote, On 4/13/2006 9:56 AM: Tom, Quite a few of us over here got involved with this one, looks like I was the last. We worked over 1 D-32 in November, 2005 to replace tubing prior to conversion to water injection following a coil tubing side track. Sundry numbers for the workover were 305-298 (10-32) and 305-303 (1 D-32L 1). Sharon submitted the 10-404's a few month's back. A caliper log from October, 2004 prior to the sidetrack showed a hole in the 3.5" liner at 13,619' and possibly 3 more holes below this. We ran a leak detection log on April 5, 2006, and per the note below, did not find any fluid leaking from the 3-1/2" liner. Do you need a copy of this log or will you get one through normal channels? I have an electronic copy and can send you one, or get a paper copy if you'd like. Just wanted to give you a heads up. Regards, Steve Mukavitz ConocoPhillips Alaska, Inc. Drilling and Wells Group 907-263-4021 -----Original Message----- From: Gober, Howard Sent: Thursday, April 06, 20064:01 PM To: Mukavitz, Steve J Subject: FW: 10-32 LDL Steve, I think you handled this one. Do you know what we promised the state? Do we need to send them a copy of the log? Thanks, Howard Gober Wells Engineer ConocoPhillips Alaska, Inc. 907 -263-4220 Office 10f2 4/13/200610:30 AM Re: FW: Kuparuk ID-32 Leak Detect Log . . 907-240-5515 Cell Howard. Gober(ç¡¿conocophi lIips. com -----Original Message----- From: NSK Problem Well Supv Sent: Thursday, April 06,2006 1:50 PM To: Gober, Howard Subject: FW: 10-32 LDL Howard Do we need to send this to the state? I think I remember that you were the original contact... Please advise MJ -----Original Message----- From: Reilly, Evan M Sent: Thursday, April 06, 2006 8:23 AM To: CPF1 Prod Engr; NSK Problem Well Supv Subject: 10-32 LDL Please find the log for 10-32 Leak Detection attached to this message. Here's the 24-hour Summary: PERFORM LEAK DETECT LOG WITH WELL ON WATER INJECTION AT 4326 BPD, 2300 PSI WHIP. LOGGED INTERVAL BETWEEN PACKER AND LINER TOP (13,130-13,750 FT) WHILE ON INJECTION AND ONE & THREE-HOUR WARMBACK PASSES AFTER SHUTTING IN . **** NO INDICATION OF LEAKS ****. BOTTOM NOT TAGGED. Evan Reilly Wells Group Cell: (907) 943-1246 Direct: (907) 659-7728 20f2 4/13/200610:30 AM e e Transmittal Form r'l_ BAKEl HUGHU INTEQ Anchorage GEOScience Center To: AOGCC 333 West 7th Ave, Suite 100 Anchorage, Alaska 99501 Attention: Robin Deason Reference: 1D-32L1PB1 Contains the following: if ,() 11~ 1 LDWG Compact Disc (Includes Graphic Image files) 1 LDWG lister summary 1 blueline - GR/Directional Measured Depth Log 1 blueline - GR/Directional True Vertical Depth Log LAC Job#: 776011 Sent By: Gl1[::l tAl Received By: rJ Date: Apr.07, 2006 Date: ~~ PLEASE ACKNOWLEDGE RECEIPT BY SIGNING & RETURNING OR FAXING YOUR COpy FAX: (907) 267-6623 Baker Hughes INTEQ 7260 Homer Drive Anchorage, Alaska 99518 Direct: (907) 267-6612 FAX: (907) 267-6623 .,-, ^~ ~ - /t~- F: ('-. e e Transmittal Form '&111 BAKEl MUGHU INTEQ Anchorage GEOScience Center To: AOGCC 333 West 7th Ave, Suite 100 Anchorage, Alaska 99501 Attention: Robin Deason Reference: ID-32Ll Contains the following: '\ /377Î 1 LDWG Compact Disc (Includes Graphic Image files) 1 LDWG lister summary 1 blueline - GR/Directional Measured Depth Log 1 blue1ine - GR/Directional True Vertical Depth Log LAC Job#: 776011 Sent By: JQifL Received By: a j . Date: Apr.07, 2006 Date: IJJ.r ;lJd'~ PLEASE ACKNOWLEDGE RECEIPT BY SIGNING & RETURNING OR FAXING YOUR COpy FAX: (907) 267-6623 Baker Hughes INTEQ 7260 Homer Drive Anchorage, Alaska 99518 Direct: (907) 267-6612 FAX: (907) 267-6623 ')Ù1- J 9f fJ~ STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION . . [CEIVED JAN 1 7 2006 REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Abandon 0 Repair Well 0 Plug Perforations 0 Stimulate 0 i''',-"w"QtQi & G8~nS. Alter Casing 0 Pull Tubing 0 Perforate New Pool 0 Waiver 0 Time Extens~C~age Change Approved Program 0 Opera!. ShutdownD Perforate 0 Re-enter Suspended Well 0 2. Operator Name: 4. Current Well Status: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development 0 Exploratory 0 204-195 / 305-303 3. Address: Stratigraphic 0 Service 0 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-029-22982-60 7. KB Elevation (ft): 9. Well Name and Number: RKB 104' 1 D-32L 1 8. Property Designation: 10. Field/Pool(s): ADL 028248 Kuparuk River Field / Kuparuk Oil Pool 11. Present Well Condition Summary: Total Depth measured 15944' feet true vertical 6573' feet Plugs (measured) Effective Depth measured 13758' feet Junk (measured) true vertical feet Casing Length Size MD rvD Burst Collapse Structural CONDUCTOR 117' 20" 117' 117' SURFACE 8902' 9-5/8" 9006' 4576' PRODUCTION 13220' 7" 13324' 6330' SLOTTED L 1 LlN 2446' 2-3/8" 15924' 6573' WINDOW TO L1 10' 2-3/8" 13836' 6544' Perforation depth: Measured depth: 13750'-15892' (slotted liner) true vertical depth: 6508'-6578' Tubing (size, grade, and measured depth) 3-1/2" , L-80, 13255' MD. Packers & SSSV (type & measured depth) Baker 5x7" ZXP liner pkr @ 13190' Landing Nipple @ 501' 12. Stimulation or cement squeeze summary: RBDMS BFL ,IAN ] '7 2006 Intervals treated (measured) not applicable Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Met Water-Bbl Casing Pressure Tubina Pressure Prior to well operation -- -- SI Subsequent to operation -- -- SI 14. Attachments 15. Well Class after proposed work: Copies of Logs and Surveys run _ Exploratory 0 Development 0 Service 0 Daily Report of Well Operations _X 16. Well Status after proposed work: oilD GasD WAG 0 GINJD WINJ0 WDSPL 0 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: Contact John Peirce @ 265-6471 Printed Name John Peirce Title Wells Group Tech. Signature li,t:. If £?____ Phone 2&-[;--6471 Date l,...rS-o~ Prenared bv Sharon AI/sun-Drake 263-4612 / I .. . . Form 10-404 Revised 04/2004 ORfGf~JAL Submit Onglnal Only Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1 D-32 1 D-32 WORKOVER/RECOMP Nabors 3S Start: Rig Release: Rig Number: 11/23/2005 11/27/2005 Spud Date: 11/9/2000 End: 11/27/2005 Group: 11/23/2005 00:00 - 02:00 2.00 MOVE DMOB MOVE Prep to move off 1 D-39. 02:00 - 06:00 4.00 MOVE MOVE MOVE PEAK trucks on loc. to assist with move. Begin moving rig mods/spotting up on 1 D-32. Lay rig mats / herculite. 06:00 - 12:30 6.50 MOVE MOVE MOVE Backing rig mods over well and rigging up 12:30 -15:00 2.50 MOVE MOVE MOVE Stand up derrick and secure. State witness of upcoming BOPE test waived by John Spaulding in previous conversation 11/22/05. 15:00 - 18:00 3.00 WELCT DECOMP Except rig @ 15:00 hrs on 11/23/05, start ND well head. OA=330 psi, IA = 0 psi, Tubing = 0 psi. Pictures of tree alignment in well folder. 18:00 - 18:30 0.50 WELCT DECOMP NU BÒP stack 18:30 - 20:00 1.50 WELCT DECOMP Tree ND; BPV is leaking (spout of fluid coming through BPV / blanking plug). Remove blanking plug, troubleshoot BPV; fluid leaking past poppet. FMC Rep on location, ensure BPV is set and poppet is seated. Leaking has stopped; discuss and cont. with NU of stack. NOTE: This time (1.5 hrs) REMOVED from BOPE testing time due to complications with BPV, etc. (delays incurred at no fault of NABORS equipment I personnel). 20:00 - 00:00 4.00 WELCT NUND DECOMP Continue NU of BOPE. 11/24/2005 00:00 - 02:00 2.00 WELCT NUND DECOMP Continue to NU BOPE. 02:00 - 06:00 4.00 WELCT BOPE DECOMP Begin testing of BOPE, 250/3000 psi. 06:00 - 08:30 2.50 FISH PULL DECOMP RU landing joint pull old completion free with 11 OK up wt. string wt is 82K, pull hanger to the floor circulate bottoms up 350 bbls 08:30 - 10:30 2.00 WELCT CIRC DECOMP Circulate bottoms up 350 bbls 9.6 brine taking returns to pits. Rig up and pump kill down the OA 100 bbls 9.6 ppg 2 bpm @ 1740 psi, monitor OA pressure. 10:30 - 18:00 PULD DECOMP POOH with old completion laying down sideways 18:00 - 00:00 PULD DECOMP Tower meeting pad is very congested with other well work. Continue to POOH with old completion 11/25/2005 00:00 - 03:00 DECOMP Continue pulling old completion, laying down pipe. Rig 1" hose from OA to kill tanks and bleed off annulus from 850 psi. Fluid at surface, bled to o psi (bled approx. 2 bbls). Shut back in and monitor. 03:00 - 04:00 DECOMP OA=200 psi. Bleed off again to 70 psi, shut back in to monitor. Continue to pull out of hole with old completion. 04:00 - 06:00 DECOMP Tower meeting Continue to pull out of hole with old completion 06:00 - 08:00 DECOMP Continue to pull out of hole with old completion OA bled down to 20 psi monitor 08:00 - 11 :30 DECOMP Pull and change 9 5/8" x 7" pack-offs. Pack-offs tested to 5000 psi held 11 :30 - 19:00 CMPL TN Load Pipe shed with remainder of new completion 165 jts. strap and drift. 19:00 - 20:30 CMPL TN Pipe tally is complete. Prep to run new 3-1/2" completion. Finished freeze protecting OA with 100 bbls diesel. Pumped 2 bpm @ 1750 psi 20:30 - 00:00 CMPL TN Begin running new completion. 11/26/2005 00:00 - 06:00 CMPL TN Tower meeting, continued. Running in the hole with new 3.5" completion. 06:00 - 13:00 7.00 CMPL TN RUNT CMPL TN Tower meeting, run in the hole. With 419 joints of 3.5 L-80 8rd tubing, 6 Pup joints 4 from Cameo, 1 from Baker, l' on Hanger and one to space out, 1 New GLM with 1" Dummy Valve and 1 new DS nipples from Cameo, 1 Baker CMU sliding Sleeve in the closed position, 1 New seal assembly from Baker, New well head, and Hanger. 70K up wt and 31 K down wt prior to landing tubing, space out with 2.05' pup one full joint and hanger with pup. Pull out of seals to circulate inhibited brine into the IA. 13:00 - 17:30 4.50 CMPL TN CIRC CMPL TN Load 220 bbls brine on vac truck with Inhibitor and circulate inhibited 9.6 Brine down tubing up lA, top of inhibitor @ 5000' RKB in lA, 4.5 Printed: 1/6/2006 10:11:12 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1 D-32 1 D-32 WORKOVER/RECOMP Nabors 3S Start: Rig Release: Rig Number: Spud Date: 11/9/2000 End: 11/27/2005 Group: 11/23/2005 11/27/2005 11/26/2005 4.50 CMPL TN CIRC CMPL TN 1.00 CMPL TN SOHO CMPL TN 13:00 -17:30 17:30 - 18:30 18:30 - 21 :00 2.50 CMPL TN SOHO CMPL TN 21 :00 - 22:30 1.50 CMPL TN SOHO CMPL TN 22:30 - 00:00 1.50 CMPL TN DEQT CMPL TN 11/27/2005 6.00 WELLS 5.00 WELLS CMPL TN CMPL TN 00:00 - 06:00 06:00 - 11 :00 CMPL TN 11 :00 - WELLS bpm @ 460 psi Discrepancy on numbers used for Nabors 3S RKB during spaceout. Appears to be 4' off. Pull back out of hole and break out 2' spaceout pup and replace with 6' Make up completion/hanger and attempt to land. Tag up 5' high. Make up head pin and kick in charge pump while stroking seals into SBE; see pressure increase. Continue RIH, stack out approx. 5' high using pressure spike as seals entered SBE as guide. Discuss options with Baker Rep and Baker Ops Supvr. Pull space-out pup out of completion. RBIH while circulating, see press increase as seals enter SBE. Travel in hole 10.5' further and land. Set depth places bottom of seal assembly at 13,250' RKB. Call W/O Engineer to discuss. Note: Should have seen 16' of stroke once seals were seen entering SBE rather than 10.5'; tubing landed 5' high. Open IA casing valve. Pressure test tubing to 2500 psi; hold for 30 mins and chart (good test). Bleed off tubing to 1500 psi, pressure up on IA to 2500 psi. Hold for 30 mins and chart. Good test. Bleed tbg and csg press to 0 psi. Set BPV, change out rams for next well. Begin nippling down stack. NU tree and test to 5000 psi. Release Rig @ 11 :00 AM 11/27. Prep to move rig. Printed: 1/6/2006 10: 11 : 12 AM ConocoPhillips Ala!. Inc. . KRU 1)-32L 1 1 D-32L 1 API: 500292298260 Well Tvœ: INJ Anale (à) TS: 65 dea (â) 13803 TUBING SSSV Type: NIPPLE Orig 1 0/31/2004 Angle @ TD: 95 deg @ 15944 (0-13255, ComDletion: OD:3.500, ID:2.992) Annular Fluid: Last W/O: 11/27/2005 Rev Reason: Pull Plua SURFACE Reference Loa: Ref Loa Date: Last UDdate: 1/6/2006 (0-9006, Last Taa: 13761 TD: 15944 ftKB OD:9.625, Last Taa Date: 8/31/2005 Max Hole Anale: 96 dea (à) 15682 Wt:40.00) Casino Strina . COMMON STRINGS DescriDtion Size TOD Bottom TVD Wt Grade Thread SURFACE 9.625 0 9006 4577 40.00 L-80 BTCM 'RODUCTION PRODUCTION 7.000 0 13324 6330 26.00 J-55 BTC MOD (0-13324, CONDUCTOR 20.000 0 117 117 91.50 H-40 WELDED OD:7.000, LINER TOP 3.500 13183 13850 6550 9.30 L-80 SLHT Wt:26.00) WINDOW to L 1 3.500 13826 13836 6544 0.00 Casino Strina - L 1 LINER (LINER MINIMUM ID = 1.995"\ DescriDtion 1 Size 1 TOD I Bottom TVD Wt Grade 1 Thread SLOTTED L 1 LINER 1 2.375 13478 I 15924 1 6575 1 4.70 1 L-80 1 STL SLEEVE-C TubinQ Strina - TUBING :13164-13165, Size 1 TOD I Bottom I TVD I Wt 1 Grade 1 Thread OD:3.500) 3.500 1 0 I 13255 I 6302 ~O I EUE 8rd Perforations Summary Interval 1 TVD Zone I Status 1 Ft I. TVDe Comment 13780 - 15892 6521 - 6578 UNIT .I 121121 8 110/30/2004 IPERF Slotted Liner with 3/8" holes ,C-1.C-2,C- Gas Lift MandrelsNalves St 1 MD I rvD I Man Man Type V Mfr 1 V Type VOD Latch Port TRO I Date I Vlv Mfr Run Cmnt 1 I 51791 31661 CAMCO KBUG-M 1 DMY 1.5 BK 0.000 0 111/27/2005 Other pluQs, eQuip" etc.) - COMMON JEWELRY -- DeDth TVD TVDe DescriDtion ID 501 501 NIP CAMCO 'DS' LANDING NIPPLE 2.875 LINER TOP 13164 6265 SLEEVE-C BAKER CMU SLIDING SLEEVE - CLOSED 11/27/2005 2.812 :13183-13850, OD:3.500, 13190 6276 PACKER BAKER ZXP LINER TOP PACKER 4.000 Wt:9.30) 13213 6285 SEAL BAKER 80-40 SBE 36' GBH-22 SEALS 2.992 13268 6307 NIP CAMCO XN NIPPLE 2.750 13826 6540 WhiDstock FLOW-THRU WHIPSTOCK L1 0.000 Other pluas. eQUiD., etc.) - L 1 LINER JEWELRY SEAL DeDth TVD Tvoe Descriotion ID :13213-13214. 13748 6507 L 1 Deploy BAKER DEPLOYMENT SLEEVE 2.250 ODA.ODO) SLV 15912 6576 MOTOR WEATHERFORD USED 2-3/8" ADJ. MOTOR, OAL 11' 0.000 General Notes Date 1 Note 0/29/20~ ~i-LA TERAL WELL: 1 D-32 ORIGINAL COMPLETION; CTD DRILLED 1 D-32L 1 NIP LATERAL LEG 1 WILL BE PRE-PRODUCED BEFORE GOING TO INJECTION : 13268-13269, OD:3.500) SLOTTED L 1 LINER 13478-15924, OD:2.375, Wt:4.70) Perf - I- .13780-15892) - I- - I- - I- - I- - I- - I- - I- Whipstock 13826-13827, OD:3.500) MOTOR 15912-15913, OD:2.380) .1 D-32 /1 D-32L 1 Well Events Summary . DATE Summary Pre Rig Work 11/6/05 PULL 2.81" CA-2 BLANKING PLUG AND PRONG @ 13173' RKB, DRIFT W/2.70" CENT, SHOCK AND GAUGES TO TD @ 13778' RKB, MAKE TWO STATIC STOPS 13470' MD (30 MIN ) 13227' MD (15 MIN). IN PROGRESS. 11/7/05 BRUSH & FLUSH TO 2.75" XN NIPPLE @ 13268' RKB, GET CALL TO GO TO RIG JOB. IN PROGRESS. 11/8/05 SET 3-112" XXN PLUG @ 13268' RKB. I N PROGRESS. 11/9/05 SET 2.70" AVA CATCHER SUB @ 13268' RKB. BLED PRESSURE FROM TBG & IA. 11/14/05 SHOT 9 TBG PUNCHER HOLES FROM 13170' TO 13172' 11/17/05 LOADED WELL WITH 500 BBLS.9.6 BRINE. PUMPED DOWN TUBING, TAKING RETURNS FROM IA. WELL LEFT SHUT IN. 11/22/05 Pre- Rig MITOA- failed, POT IC- passed, PPPOT-IC- failed, Post Rig Work 12/15/05 UNABLE TO PUMP, TBG PRESSURED UP, SLOWLY DRIFTED TBG TO 1750' WLM, IN PROGRESS 12/16/05 LOADED fA WI BRINE AND DIESEL CAP TO 3000' PT TBG & IIA (GOOD TEST) IN PROGRESS 12/17/05 BAILED FROM 13,194' WLM TO 13,235' WLM, IN PROGRESS 12/18/05 BAILED, PULLED CATCHER & PLUG @ 13,268' RKB · . RECEIVED STATE OF ALASKA JAN 1 8 2006 REP~~~KA;~;~~~~;S:~~~N~;~~;IONtska Oil & Gás Cons. COIJJnission 2. Operator Name: ConocoPhillips Alaska, Inc. 3. Address: P. O. Box 100360, Anchorage, Alaska 99510 7. KB Elevation (ft): RKB 104' 8. Property Designation: Kuparuk River Unit 11. Present Well Condition Summary: 5. Permit to Drill Number: 204-195 6. API Number: 50-029-22982-60 9. Well Name and Number; 1D-32L 1 10. Field/Pool{s): Kuparuk River Field I Kuparuk Oil Pool Total Depth measured 15944' feet true vertical 6573' feet Effective Depth measured feet true vertical feet Casing " Length Size MD Structural CONDUCTOR 117' 20" 117' SURFACE 8902' 9-5/8" 9006' PRODUCTION 13220' 7" 13324' PROD. CASING 667' 3-1/2" 13850' WINDOW TO L 1 10' 3-1/2" 13836' Plugs (measured) Junk (measured) TVD Burst Collapse 117' 4577' 6330' 6545' Perforation depth: Measured depth: 13780-15892' true vertical depth: 6521-6578' Tubing (size, grade, and measured depth) 3-1/2" , L-80, 13255' MD. Packers & SSSV (type & measured depth) no packer Form 10-404 Revised 04/2004 ORIGINAL Submit Original Only . . 1 D-32L 1 DESCRIPTION OF WORK COMPLETED SUMMARY Date Event Summary 1/6/2006 Commenced WAG EOR Injection - -- e e rF J :j ,.1.. ;;=J... 1,1 ¡ ~ s..:;:::¡ FRANK H. MURKOWSKI, GOVERNOR AIfASIiA OIL AlÐ) GAS CONSERVATION COMMISSION 333 W. 7'" AVENUE. SUITE 100 ANCHORAGE. ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 John Peirce Wells Group Tech. ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510 , Re: KRU 1D-32 L ~ ~ Sundry Number: 305-303 Dear Mr. Peirce: 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. Please provide at least twenty-four (24) hours 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. DATED thiSI day of October, 2005 Encl. (Iflf-IHr -05" k e STATE OF ALASKA AO/1-!s RECEIVED lOt ALASKA OIL AND GAS CONSERVATION COMMISSION SEP 3 0 Z005 ~ APPLICATION FOR SUNDRY APPROVAL . & G C os Commission 20 AAC 25.280 Alaska 011 85 0 , D Suspend D Operation Shutdown D Perforate 0 Waiver Other 0 D Repair well 0 Plug Perforations D Stimulate D Time Extension 0 D Pull Tubing 0 Perforate New Pool D Re-enter Suspended Well 0 6. 50-029-22982-60 9. Well Name and Number: 1 D-32L 1 10. Field/Pool(s): Kuparuk River Field / Kuparuk Oil Pool PRESENT WELL CONDITION SUMMARY Effective Depth TVD (ft): Plugs (measured): Junk (measured): 'fit' 1. Type of Request: Abandon Alter casing Change approved program 2. Operator Name: ConocoPhillips Alaska, Inc. 3. Address: P. O. Box 100360, Anchorage, Alaska 99510 7. KB Elevation (ft): RKB 104' 4. Current Well Class: Development 0 Stratigraphic 0 Exploratory D Service 0 8. Property Designation: ADL 028248 11. Total depth MD (ft): 15944' Casing Total Depth TVD (ft): Effective Depth MD (ft): 6573' 13758' Length Size rvD 117' 4576' 6330' 6573' MD 117' 9006' 13324' 15924' 13836' 6540' CONDUCTOR 117' 20" SURFACE 8902' 9-5/8" PRODUCTION 13220' 7" SLOTTED L 1 LINE 2446' 2-3/8" WINDOW TO L 1 10' 2-3/8" Perforation Depth TVD (ft): 6508'-6578' Tubing Size: 3-1/2" Perforation Depth MD (ft): 13750'-15892' Packers and SSSV Type: Baker 5x7" ZXP liner pkr @ Landing Nipple @ 12. Attachments: Description Summary of Proposal 0 Detailed Operations Program 0 BOP Sketch 0 14. Estimated Date for Commencing Operations: 16. Verbal Approval: Commission Representative: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Printed Name John Peirce Packers and SSSV MD (ft) 13190' 533' October 14, 2005 Date: 13. Well Class after proposed work: Exploratory D Development D 15. Well Status after proposed work: Oil D Gas 0 WAG 0 GINJ D Contact: Title: Signature Phone Commission Use Onl Conditions of approval: Notify Commission so that a representative may witness 5. Permit to Drill Number: Burst Collapse Tubing Grade: L-80 Tubing MD (ft): 13255' Service 0 Plugged 0 WINJ 0 Abandoned 0 WDSPL D John Peirce @ 265-6471 Wells Group Tech. Date Sundry Number: ~ ':ttJ Ô Location Clearance D Plug Integrity D BOP Test ~ Mechanical Integrity Test D Othec '3C'>oO ~ ,,\ ß \' \<:S \- <>--" '" ~,,~ RBDMS 8Ft 0 CT 0 5 2005 COMMISSIONER o. R 1 r=: i ~\J A- L ., ! '>J ¡ ¡ '0 APPROVED BY THE COMMISSION Form 10-403 Revised 7/2005 Submit in Duplicate e e Kuparuk 1 D-32L 1 General Workover Procedure for Replacement of Corroded Leaky Tubing Pre-Ria Work 1.) Perform POT PPPOT T&IC. Function test lockdown screws. 2.) Pull CA-2 plug from OS Nipple at 13172' RKB. RIH & tag fill. 3.) Obtain SBHP at 13470' & 13227' RKB. (SBHP 8/31/05 indicated KWF is -7.1 ppg) 4.) Set PXN plug wlprong in the XN Nipple at 13268' RKB. Set Catcher Sub on top of PXN. 5.) Tubing punch circulation hole at 13195' RKB in middle of firstfull joint above seal assembly. 6.) Circulate the well to 9.6 ppg Brine through the circulation hole above, and a confirmed tubing leak (0.25 bpm @ 1950 psi leak) located somewhere between 5245' and 13172' RKB. 7.) Bleed tubing down to zero psi and check for flow. 8.) Prep location for Workover Rig. 9.) Set BPV within 24 hours of rig arrival on location. General Workover Procedure 1. ) 2.) 3.) 4.) 5.) 6.) 7.) 8.) MIRU Workover Rig. Verify that the well is dead. ~~~~ &fl}1j NO tree. NU 11" 5M BOPE. Pull BPV. Test BOPE to 250/3000 psi (MASP = 1700 g~i). \;Ö (.3 Unland tubing hanger. If tubing does not pull free from seal assembly, cut the tubing in the - middle of first full joint above the seal assembly. POOH with 3.5" tubing. Run new 3.5" completion and stab into seal assembly, else overshot the tubing stub and set a stacker packer if tubing cut was required. Space out and land hanger. Pressure test tubing and inner annulus. Bleed tubing & IA down to zero psi. NO BOPS, NU tree, PT tree & packoffs. Set BPV. ~T~<:S<è b\s S "-~..j\d ROMO workover rig. . (\ ~ ~ c-b-\~'tJ , t:2~ L~(3 Post-Ria Work 1.) Pull BPV. 2.) RU Slickline. Shift Sliding Sleeve open. 3.) Circ out 9.6 ppg KW Brine via Sliding Sleeve wlcorrosion inhibited Brine & FP w/Oiesel cap. 4.) Retrieve ball & rod and RHC plug (if needed following a stacker packer set). 5.) Shift Sliding Sleeve closed. PT IA & tubing. 6.) Pull Catcher Sub and PXN plug from XN Nipple at 13268' RKB. Tag fill. 7.) Reset the well house and return well to injection. 8.) Run IPROF w/shut-in temp p~ses to verify no water injection into liner holes above C sand. \I\j ~fè.l'- \.Ùe. \ \. {~ \e.~ \f'"{tèJ ~ '\ ~ i E C:--\\~ 1\ . CO"'- ~L -\- r""7 ) Q:c....~..-~.- \J-.J ~~'ò.>c-S k l T ~/á!3 @97 ¡1¡\ lJ'~~r? .~ .~, ." !,.,1,.:iJ, " '. ¡ q::2 ,~ ¡J Lf"IJ i . ® ,r=;:! . '. j !d! Ib J'U' ' UJ lbU i ¡ . fi\ liJ\ Lrù FRANK H. MURKOWSKI, GOVERNOR ALASKA OIL AND GAS CONS£RVATlONCO~SSION 333 W. 7'" AVENUE, SUITE 100 ANCHORAGE. ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Brian Seitz Kuparuk Staff Engineer ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, Alaska 99510 Re: Kuparuk 1D-32L1 Sundry Number: 305-236 Dear Mr. Seitz: 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. Please provide at least twenty-four (24) hours 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 S perior Court unless rehearing has been requested. DATED this l1day of August, 2005 Encl. MJf-l7-0>,/ . STATE OF ALASKA ~ i//~~E ALASKA OIL AND GAS CONSERVATION COMMISSION ~ [- \..¡ APPLICATION FOR SUNDRY APPROVAL AUG 16 Z005 20 AAC 25.280 Operation Shutdown 0 Plug Perforations 0 Perforate New Pool 0 . 1. Type of Request: Abandon 0 o o Suspend 0 o o Alter casing Repair well Change approved program Pull Tubing 2. Operator Name: ConocoPhillips Alaska, Inc. 3. Address: P. O. Box 100360, Anchora e, Alaska 99510 7. KB Elevation (ft): RKB 104' 8. Property Designation: ADL 028248 11. Total depth MD (ft): 15944' Casing Total Depth TVD (ft): Effective Depth MD (ft): 6573' 13758' Length Size CONDUCTOR 117' 20" SURFACE 8902' 9-5/8" PRODUCTION 13220' 7" SLOTTED L 1 LINE 2446' 2-3/8" WINDOW TO L 1 10' 2-3/8" Perforation Depth TVD (ft): 6508'-6578' 1-Sep-05 Date: Perforate 0 o ;,,¡ ';h ~ al~è1"i Time Extension Stimulate Re-enter Suspended Well k- ~'ì .,. ~.........' n' Ö¡h~~ .¡ convert to injector o 4. Current Well Class: Development [2] Stratigraphic 0 Exploratory 0 Service 0 5. Permit to Drill Number: 204-195 6. API Number: 50-029-22982-60 9. Well Name and Number: 1 D-32L 1 10. Field/Pool(s): Kuparuk River Field / Kuparuk Oil Pool PRESENT WELL CONDITION SUMMARY Effective Depth TVD (ft): Plugs (measured): Junk (measured): MD rvD 117' Burst Perforation Depth MD (ft): 13750'-15892' Packers and SSSV Type: Baker 5x7" ZXP liner pkr @ Landing Nipple @ 12. Attachments: Description Summary of Proposal [2] Detailed Operations Program 0 BOP Sketch 0 14. Estimated Date for Commencing Operations: 16. Verbal Approval: Commission Representative: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Printed Name Brian Seitz Signature 6/?'-UÞ-;1 117' 9006' 13324' 15924' 13836' 4576' 6330' 6573' 6540' Tubing Size: 3-1/2" Tubing Grade: L-SO Packers and SSSV MD (ft) 13190' 533' 13. Well Class after proposed work: Exploratory 0 Development 0 15. Well Status after proposed work: Oil 0 Gas 0 WAG 0 GINJ 0 Plugged 0 WINJ [2] v Collapse Tubing MD (ft): 13255' Service [2] Abandoned 0 WDSPL 0 Contact: Brian Seitz @ 265-6961 Title: Kuparuk Staff Engineer Phone ß¿ f--6fðl Date e//>/ /ç;J,; .~ Commission Use Onl Sundry Number: 3o~' Conditions of approval: Notify Commission so that a representative may witness Plug Integrity 0 BOP Test 0 Mechanical Integrity Test ~ Other: Location Clearance 0 RBDMS BFl AUG 1 9 2005 ~ Submit in Duplicate . . J KRU 1 D-32 & 1 D-32L 1 Conversion to Injection Backl!:round KRU ID-32 was drilled and completed as a C-sand injector in December of 2000 to support offset producers ID-30 and ID-32. The well remained on water injection until September of 2004, when the ID-32L 1 horizontal lateral was drilled with coiled tubing while preserving the original wellbore. After the coiled tubing sidetrack, the well was put on pre-production in November of2004 at an initial rate of 600 BOPD and 25% water cut. The well most recently tested on July 4, 2005 at 495 BOPD and 15% wc. However, with only one gas lift mandrel at 3185' tvd, the well is becoming increasingly unstable. The plan is to now complete the necessary facility work to convert the well back to its originally intended service of water injection to support offset producers ID-30 and ID-34. A CBL run on 4/24/01 indicates good cement across the top and above the C-sand pay interval. The last MITIA for ID-32 was performed on 7/24/04 as part ofpre-CTD diagnostics. The well passed the MITIA. Summary of Operations Necessary piping and instrumentation will be put back in place to convert surface slot 32 on DS-ID back to water injection service. Proposed wellwork is limited to changing out the OV at 5,230' rkb with a DV and perform an MITIA per AOGCC requirements. _ STATE OF ALASKA . ALAS~ AND GAS CONSERVATION COM. ION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1a. Well Status: 181 Oil DGas D Plugged D Abandoned D Suspended DWAG 1 b. Well Class: 20AAC 25.105 20AAC 25.110 181 Development D Exploratory DGINJ DWINJ D WDSPL No. of Completions One Other D Stratigraphic D Service 2. Operator Name: 5. Date Comp., Susp., or Aband. 12. Permit to Drill Number Conoco Phillips Alaska Inc. 10/31/2004 ." 204-195 3. Address: 6. Date Spudded 13. API Number c/o P.O. Box 196612, Anchorage, Alaska 99519-6612 10/21/2004 . 50- 029-22982-60-00 4a. Location of Well (Governmental Section): 7. Date T.D. Reached 14. Well Name and Number: Surface: 10/29/2004 I Kuparuk 1 D-32L 1 417' SNL, 420' WEL, SEC. 23, T11N, R10E, UM 8. KB Elevation (ft): 15. Field / Pool(s): Top of Productive Horizon: 104.45 , Kuparuk River Field / Kuparuk 2919' SNL, 1670' EWL, SEC. 30, T11N, R11E, UM River Pool Total Depth: 9. Plug Back Depth (MD+ TVD) 3058' SNL, 3656' EWL, SEC. 30, T11 N, R11 E, UM 15944 + 6573 Ft 4b. Location of Well (State Base Plane Coordinates): 10. Total Depth (MD+TVD) 16. Property Designation: Surface: x- 560671 y- 5959249 Zone- ASP4 15944 . + 6573 Ft ADL 028248 TPI: x- 568108 y- 5951531 Zone- ASP4 11. Depth where SSSV set 17. Land Use Permit: Total Depth: x- 570096 y- 5951410 Zone- ASP4 N/A MD 18. Directional Survey 19. Water depth, if offshore 20. Thickness of Permafrost 181 Yes DNo N/A MSL 1775' (Approx.) 21. Logs Run: GR/ROP/PRESS 2. CASING, LINER AND CEMENTING RECORD CASIl\iG . SE"lTING. EPTH Me SetTli\lG EÞTH ND ~~{ ·i ~ôL~g~ SIZE W'r.PERFT; GRADE TOl" .aÖ'l"TOM TOP l.aOTTOM 20" 91.5# H-40 Surface 130' Surface 130' 30" 15 cu vds ABI, TYDe III 9-5/8" 40# L-80 Surface 9005' Surface 4576' 12-1/4" 490 sx AS III Lite, 450 sx LiteCrete 7" 26# J-55 Surface 13324' Surface 6330' 8-1/2" 190 sx Class 'G' 3-1/2" 9.3# L-80 13183' 13826' 6273' 6540' 6-1/8" '25 sx Class 'G' 2-3/8" 4.7# L-80 13748' 15924' 6508' 6573' 3" Uncemented Slotted Liner 23. Perforations open to Production (MD + TVD of T0,e and 24. T JSING .i/ Bottom Interval, Size and Number; if none, state' none"): SIZE DEPTH SET (MD) PACKER SET (MD) 2-3/8" Slotted Section 3-1/2", 9.3#, L-80 13255' 13191' MD TVD MD TVD 13750' - 15892' 6508' - 6578' 25. .ð.I",n .¥EMJ:NT .;.,.;¡;;,¡ r>v'~, ../ DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 13826' Set Flow-Through Whipstock 13700' Freeze Protect with Diesel 26. PRODUCTION TEST Date First Production: Method of Operation (Flowing, Gas Lift, etc.): November 26, 2004 Gas Lift Date of Test Hours Tested PRODUCTION FOR Oll-Bsl GAs-McF W A TER-Bsl CHOKE SIZE I GAS-Oil RATIO 11/26/2004 10 TEST PERIOD ... 249 133 80 64 534 Flow Tubing Casing Pressure CALCULATED ... Oll-Bsl GAs-McF W A TER-Bsl Oil GRAVITY-API (CORR) Press. 25E 1,000 24-HoUR RATE 597 319 191 27. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water (attach separate sheet, if necessary). Submit core chips; if none, state "none". '......, ··,,'····'O·,,'..__·,~ .. ;:'~ ,'riDn i None RBDMS BFL DEL, (f 7nn4 OR\G\NAL (º~~/'!$f ~', .. ,~ GV -..---.---...---",: "., .-,..,."""'-:C" Form 1 0-407 Revised 12/2003 CONTINUED ON REVERSE SIDE 28. GEOLOGIC MARKERS 29. RMATION TESTS MD Include and briefly summarize test results. List intervals tested, NAME TVD and attach detailed supporting data as necessary. If no tests were conducted, state "None". C3 13863' 6555' None C2 14048' 6585' C1 14233' 6593' C3 14845' 6595' C3 15830' 6583' C4 15925' 6575' 30. List of Attachments: Summary of Pre-Rig Work and Daily Drilling Reports, Well Schematic Diagram, Surveys 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed Terrie HUbble~ . Title Technical Assistant Date \;).../ O~O Kuparuk 1 D-32L 1 204-195 Prepared By Name/Number: Terrie Hubb/e, 564-4628 Well Number Drilling Engineer: Lamar Gantt, 564-5593 Permit No. / A roval No. INSTRUCTIONS GENERAL: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. ITEM 1a: Classification of Service Wells: Gas Injection, Water Injection, Water-Altemating-Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. ITEM 4b: TPI (Top of Producing Interval). ITEM 8: The Kelly Bushing 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. ITEM 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). ITEM 20: True vertical thickness. ITEM 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. ITEM 23: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). ITEM 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, or Other (explain). ITEM 27: If no cores taken, indicate "None". ITEM 29: List all test information. If none, state "None". Form 10-407 Revised 12/2003 Submit Original Only ... .. STATE OF ALASKA _ ALASKA' AND GAS CONSERVATION COM~ION WELL COMPLETION OR RECOMPLETION REPORT AND LOG o GINJ 0 WINJ 0 WDSPL 2. Operator Name: Conoco Phillips Alaska Inc. 3. Address: cia P.O. Box 196612, Anchorage, Alaska 99519-6612 4a. Location of Well (Governmental Section): Surface: 417' SNL, 420' WEL, SEC. 23, T11N, R10E, UM Top of Productive Horizon: 2924' SNL, 1660' EWL, SEC. 30, T11N, R11E, UM Total Depth: 4492' SNL, 2642' EWL, SEC. 30, T11 N, R11 E, UM 4b. Location of Well (State Base Plane Coordinates): Surface: x- 560671 y- 5959249 Zone- ASP4 TPI: x- 568099 y- 5951527 Zone- ASP4 Total Depth: x- 569094 y- 5949967 Zone- ASP4 18. Directional Survey 181 Yes 0 No 1a. Well Status: 181 Oil 0 Gas 0 Plugged 0 Abandoned 0 Suspended 0 WAG 1b. Well Class: 20AAC2S.10S 20AAC2S.110 181 Developmel)t 0 Exploratory No. of Completions One Other 0 Stratigrapþic 0 Service 5. Date Comp., Susp., or Aband. 12. Permit tcjbrill Number 10/31/2004 , 204-191 6. Date Spudded 13. API }4"umber 10121/2004 ' 50~29-22982-60-00 7. Date T.D. Reached, 14. ~ell Name and Number: 10129/2004 / Kuparuk 1D-32L 1 8. KB Elevation (ft): ft. Field 1 Pool(s): 104.45 ' I Kuparuk River Field 1 Kuparuk River Pool 9. Plug Back Depth (MD+TVD)e,s1'3 15944 + ,zsoe.. 7Ft 10. Total Depth (MD+TVD) "''?'13 ~ 16. ,15944 + .J.€J6Y ,flc1 11. Depth where SSSV s¢ 17. N/~tMD 19. Water depth, if ojfshore /N/A MSL I CASING, LINER AND CEMEI)I'tING RECORD SËlÏING EPTH MD~ETTIN(3)EPTHTVD .. HOLE J OP6Q"TTOM IOP/ 160"TTOMSIiE i. Surface 130' Sutfáce 130' Surface 9005' Sórface 4576' Surface 13324' Surface 6330' 13183' 13826' 6273' 6540' 13748' 15~4' 6508' 7500' / 23. Perforations open to Production (MD + T~D ofTo,£ nd Bottom Interval, Size and Number; if none, state one"): 2-3/8" Slotted Section MD TVD MD TVD 13750' - 15892' 6508' -7485' \ . ~ l f &0. t¡l(/ /' / PRODUCTION TEST Method of Operation (Flowing, Gas Lift, etc.): Gas Lift OIL-BBL 249 21. Logs Run: GR I ROP 1 PRESS 22. CASING SIZE WT. PERFT. 91.5# 40# 26# 9.3# 4.7# GRADE H-40 L-80 J-55 L-80 L-80 20" 9-5/8" 7" 3-1/2" 2-3/8" 26. Date First Production: November 26, 2004 Date of Test Hours Test¢" PRODUCTION FOR 11/26/2004 10/ TEST PERIOD .. Flow Tubing Casin~ressure CALCULATED -.II... Press. 25E ¡1.000 24-HoUR RATE"'" 27. OIL-BBL 597 Property Designation: ADL 028248 Land Use Permit: 20. Thickness of Permafrost 1775' (Approx.) /..// AMOUNT PULLED 30" 12-1/4" 8-112" 6-1/8" 15 cu yds ABI, Type III 490 sx AS III Lite, 450 sx LiteCrete 190 sx Class 'G' ?25 sx Class 'G' Uncemented Slotted Liner 3" 24. J JBI/IIG- DEPTH SET (MD) 13255' PACKER SET (MD) 13191' SIZE 3-1/2", 9.3#, L-80 25. ACID, FRACTURE,CEMENtSQI.II;t:4E,$'i'9, DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 13826' Set Flow-Through Whipstock 13700' Freeze Protect with Diesel GAs-McF 133 GAs-OIL RATIO 534 W A TER-BBL 80 CHOKE SIZE 64 OIL GRAVITY-API (CORR) GAs-McF 319 WATER-BBL 191 CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil. gas or water (attach separate sheet, if necessary). Submit core chips; if none, state "none". None Form 10-407 Revised 1212003 OF{\G\NAL CONTINUED ON REVERSE SIDE 28. GEOLOGIC MARKERS 29. ORMATION TESTS Include and briefly summarize test results. List intervals tested, NAME MD TVD and attach detailed supporting data as necessary. If no tests were conducted, state "None". C3 13863' 6556' None C2 14048' 6638' C1 14233' 6723' C3 14845' 7004' C3 15830' 7457' C4 15925' 7500' 30. List of Attachments: Summary of Pre-Rig Work and Daily Drilling Reports, Well Schematic Diagram, Surveys 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed Terrie Hubble Title Technical Assistant Kuparuk 1 D-32L 1 Well Number Prepared By Name/Number: Drilling Engineer: Terrie Hubble, 564-4628 Lamar Gantt, 564-5593 204-195 Permit No. / A roval No. INSTRUCTIONS GENERAL: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. ITEM 1a: Classification of Service Wells: Gas Injection, Water Injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. ITEM 4b: TPI (Top of Producing Interval). ITEM 8: The Kelly Bushing 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. ITEM 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). ITEM 20: True vertical thickness. ITEM 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. ITEM 23: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). ITEM 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, or Other (explain). ITEM 27: If no cores taken, indicate "None". ITEM 29: List all test information. If none, state "None". Form 10-407 Revised 12/2003 Submit Original Only . . Well: 1 D-32L 1 Accept: 10/19/04 Field: Kuparuk Spud: 10/21/04 API: 50-029-22982-60-00 Release: 10/31/04 Permit: 204-195 Ri: Nordic #2 PRE-RIG WORK 09/29/04 CLEANED OUT "SCHMOO" TO 14,075' CTM WI SEAWATER J313 & 2# BIOlAN. WELL LEFT SHUT; DSO AND DSE NOTIFIED TBG & FLOWLINE NEED FREEZE PROTECTED. 09/30/04 POST FCO TAG. FILL @ 14,098' RKB, 154' OF RAT HOLE CTU CLEANED OUT TO 14075' CMT. 10/02/04 DRIFTED DOWN TO 13903' RKB WI KJ, 2.69 CENT., 18' OF 1 7/8 STEM, AND 2.71 GAUGE RING (20.5' OAL) WI NO PROBLEMS (PICKUP WEIGHT WI THIS ASSEMBLY @ 13903' RKB IS 775 LBS). 10/03/04 RAN PDS CALIPER FROM 13898' RKB TO SURFACE PRE CTD SIDETRACK (GOOD DATA). 1 0/15/04 MITMV - FAILED, MITSV - FAILED, DRAW DOWN TEST MV - PASSED, DRAW DOWN TEST SV - PASSED. Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1 0-32 1 0-32 REENTER+COMPLETE NORDIC CALISTA NORDIC 2 Start: 1 0/20/2004 Rig Release: 10/31/2004 Rig Number: 2 Spud Date: 10/18/2004 End: 10/31/2004 10/18/2004 18:00 - 00:00 6.00 MOB P PRE Move from 1 Y Pad to 1 D Pad. 10/19/2004 00:00 - 01 :00 1.00 MOB P PRE Move from 1 Y to 1 D pad. Prep location with herculite & rig mats. 01 :00 - 01 :30 0.50 MOB P PRE Spot rig over well. 01 :30 - 06:00 4.50 MOB P PRE ND tree cap. NU BOPs. Place berm around cellar. Take on fresh water, fuel, seawater. Replace flex choke line with hardline & greylock fittings. 06:00 - 06: 15 0.25 MOB P PRE Continue to replace flex hoses to BOP stack with hardline. Accept rig at 0600 hrs on 10-19-04. 06:15 - 06:30 0.25 MOB P PRE Safety meeting prior to picking up reel into reelhouse. 06:30 - 09:30 3.00 MOB P PRE PU reel, and continue to prep for BOP test. 09:30 - 16:45 7.25 BOPSU P PRE Perform initial BOP test. Problems with test pump and greylock fittings in choke line SWS hands continuing to rig up hardline to new reel. 16:45-18:15 1.50 RIGU P PRE Prep to stab coil. Pull tugger line across pipe shed. Pull CT to floor and stab. Install new packoff. RD tools 18:15 - 22:00 3.75 RIGU P PRE Stab onto lub and fill CT wi seawater @ 0.5 bpm. Reverse slack back 2.6/4000 Bleed IA from 1200 to 250 psi 22:00 - 22:30 0.50 RIGU P PRE RU hyd cutter and cut 10' CT and found e-line. RD cutter 22:30 - 00:00 1.50 CLEAN P WEXIT Install CTC and head up BHI. PT 33k, 3500 psi 1 0/20/2004 00:00 - 01 :00 1.00 CLEAN P WEXIT MU nozzle BHA wI PWD sub. Verify depth of MV, add two 3' lubs. PT lubs @ 3500 psi. Bleed to 1000 psi thru Swaco choke 01 :00 - 03:30 2.50 CLEAN P WEXIT Open well to 870 psi, IA 265, OA 0 RI H wi BHA #1 0.4/1020 holding 900 psi whp to 13950' 03:30 - 03:45 0.25 CLEAN P WEXIT PUH 41k to 13830' (6550' TVD) and park. SD pump/SI choke and monitor BHP. Stabilized after 15 min at 10.12 ppg ECD (3374 psi) wi 750 psi WHP, IA 660, OA 0 03:45 - 04:45 1.00 CLEAN P WEXIT POOH following pressure schedule 1.25/2060 and attempt to take returns to pits, but too much diesel initially 04:45 - 05:15 0.50 CLEAN N SFAL WEXIT Park at 8880' to investigate hyd leak in power pack. Send returns to pits and had 1.25/0.9/2460 wi 1000 psi bp and 3120 psi DHP 05:15 - 06:30 1.25 CLEAN P WEXIT Resume POOH 06:30 - 09:30 3.00 STWHIP P WEXIT At surface. Hold PJSM to discuss plan, slickline, whipstock. Close MV. Get off well. Unstab coil. Cut 50' slickline. Install rope socket. Prep equipment for pressure deployment. 09:30 - 11 :30 2.00 STWHIP P WEXIT Hold PJSM with crews before deploying BHA. Pressure deploy Weatherford whipstock. Total tool length: 67.98' 11:30 -13:00 1.50 STWHIP P WEXIT RIH following pressure schedule. Run at 70-80 fpm. 13:00 - 13:55 0.92 STWHIP N SFAL WEXIT Leak in power pack system. Shut down and replace o-ring seal. 13:55 - 16:45 2.83 STWHIP P WEXIT COntinue to RIH with whipstock at 70 fpm. 16:45 -18:10 1.42 STWHIP P WEXIT Log gr tie in from 13620' and corr -31'. Set WS wi top at 13826' and at 20L and stack 5k 18:10 - 20:30 2.33 STWHIP P WEXIT POOH following pressure schedule 20:30 - 20:45 0.25 STWHIP P WEXIT Close EDC at 500'. Tag up Safety mtg re: undeploy 20:45 - 22:15 1.50 STWHIP P WEXIT Pressure undeploy wi 560 psi SIWHP, IA 620 LD WS setting assy and BHI assy 22:15 - 23:00 0.75 STWHIP P WEXIT MU BHI BHA on catwalk Printed: 11/1/2004 1 :52:37 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1 D-32 1 D-32 REENTER+COMPLETE NORDIC CALISTA NORDIC 2 Start: 10/20/2004 Rig Release: 10/31/2004 Rig Number: 2 Spud Date: 10/18/2004 End: 10/31/2004 1 0/2012004 23:00 . 23: 1 0 0.17 STWHIP P WEXIT Safety mtg re: deploy 23:10·00:00 0.83 STWHIP P WEXIT Pressure deploy milling assy with 455 psi SIWHP, IA 455 (IA appears to be tracking WHP) 10/21/2004 00:00 . 00:30 0.50 STWHIP P WEXIT Finish pressure deploy milling assy w/ 455 psi whp 00:30 . 03:00 2.50 STWHIP P WEXIT RIH wI BHA #3 0.6/1100 holding 600 psi whp. Start fresh 8.7 ppg Flo Pro mud down CT 03:00 . 03:30 0.50 STWHIP P WEXIT Close EDC, tag at min rate of 13861'. PUH 41k. Start pump 1.5/3350 and ease in hole and first motor work at 13857.8', corr to 13826' and flag. Begin annular displacement to mud 03:30 . 04:40 1.17 STWHIP P WEXIT Begin milling window from 13826' 1.52/1.40/3485 w/ choke open and 12.0 ECD (3990 psi) after mud to surface 04:40 - 06:00 1.33 STWHIP P WEXIT Mill from 13827.0' 1.57/1.44/3600 12.35 ECD (4114 psi) w/1k wob, minor diff 06:00 - 10:00 4.00 STWHIP P WEXIT Mill from 12828'. 1.55 in/1.52 out @ 3600 fs. BHP: 4055 psi/ECD: 12.16 ppg/WHP: 12 psi. DHWOB: 0.5 k# to 1.5 k#. Noticed pump pressure and ann press changes, likely indicating having crossed center line. Mill to 13832' 10:00 - 11: 15 1.25 STWHIP P WEXIT Continue to mill ahead. Add WOB as now in open hole. Mill/drill to 13841'. Circulate up sample from TD. Ream & back ream several passes. Dry drift. Window looks smooth. TOWS: 13826'. Will verify TOW, BOW, RA on next run. 11 :15 - 14:45 3.50 STWHIP P WEXIT POOH as per pressure schedule. Paint EOP flag at 13700'. Continue to POOH for drilling assembly. 14:45·16:00 1.25 STWHIP P WEXIT At surface. Hold PJSM to review un-deploy procedure. Begin undeploment with 650 psi WHP. 16:00 . 17:35 1.58 DRILL P PROD1 Pressure deploy build assembly. 17:35 - 20:00 2.42 DRILL P PROD1 RIH w/ BHA #4 following pressure schedule 20:00 - 20:40 0.67 DRILL P PROD1 Log tie-in down from 13570' to GR at 13610', corr -27' 20:40-21:10 0.50 DRILL P PROD1 Close EDC. RIH thru window, clean and tag at 13845'. PUH 26k, start pump and bleed off induced whp of 500 psi to zero 1.58/1.55/3450/20L wI 12.3 ECD, zero wob indicator and RIH and tag at 13844' 21:10 - 00:00 2.83 DRILL P PROD1 Drill from 13844' 1.57/1.55/3420/25L ECD 12.2 at 10-20'/hr while swap to fresh 8.6 ppg formate based Flo Pro mud. See RA pip at 13834' 1 0/22/2004 00:00 - 00:30 0.50 DRILL P PROD1 Continue drilling from 13891' 1.5/1.5/3500/30L wI 12.2 ECD at 1 0-20'/hr to 13900' 00:30 - 00:45 0.25 DRILL P PROD1 Wiper to window, clean. PUH to 13600' 00:45 - 03:15 2.50 DRILL P PROD1 Log tie-in to parent wellbore from 13600' to TD 03:15·06:00 2.75 DRILL P PROD1 Drill from 13900' 1.6/1.6/3560/35L-90L w/ 12.25 ECD and continue build in C1 wI higher pentration rates to EOB at 13975' 06:00 - 06:30 0.50 DRILL P PROD1 Wiper to window 06:30 - 08:15 1.75 DRILL P PROD1 POOH for motor angle change. Follow pressure schedule. At surface with 850 psi WHP. 08: 15 - 08:30 0.25 DRILL P PROD1 Hold PJSM in Ops Cab. Discuss several suggestions by D. Rock to improve un-deploy procedure. Assign tasks. Discuss hazards. 08:30 - 10:00 1.50 DRILL P PROD1 Pressure un-deploy BHA. Both checks leaking. Ball valve holding ok. 10:00 - 12:00 2.00 DRILL P PROD1 Adjust motor to 1.1 deg AKO. PU new Hycalog DS1 00. Deploy BHA. Stab coil. Get on well. 12:00 - 14:30 2.50 DRILL P PROD1 RIH. Follow pressure schedule. Printed: 11/1/2004 1 :52:37 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1 0-32 1 0-32 REENTER+COMPLETE NORDIC CALISTA NORDIC 2 Start: Rig Release: Rig Number: 10/20/2004 1 0/31 /2004 2 Spud Date: 10/18/2004 End: 10/31/2004 1 0/22/2004 14:30-15:15 0.75 DRILL P PROD1 Log primary gr tie in to verify RA tag, etc. -26' correction. RA tag is at 13832'. Top WS: 13826'. TOW: 13826. BOW: 13833. 15:15 -18:40 3.42 DRILL P PROD1 Drill ahead from 13975. 3400 psi @ 1.50 inlout fs. 2K WOB 1.331 DRILL WHP: 20 psi / ECD: 12.10 ppg I BHP: 4060 psi at slow penetration rate PVT 319 18:40 - 20:00 P PROD1 Drill ahead from 14050' 1.7/1.65/3600/80R w/2k wob, 300 psi ditt, 12.26 ECD and penetration rate picking up in lower C1. Drill to 14125' 20:00 - 20:30 0.50 DRILL P PROD1 Wiper to window, clean 20:30 - 23:30 3.00 DRILL P PROD1 Drill ahead from 14125' 1.61/1.57/3400/90R w/1-2k wob, 200-300 psi ditt, 12.23 ECD. Swap to left at 14175' (getting 15-19 deg DLS w/1.1 deg motor) PVT 301 Bleed OA from 585 psi to 120 psi 23:30 - 00:00 0.50 DRILL P PROD1 Wiper to window, clean PVT 297 1 0/23/2004 00:00 - 03:40 3.67 DRILL P PROD1 Drill ahead from 14275' 1.68/1.65/3640/85L wI 0.5-1.5k wob, 200-300 psi ditt, 12.35 ECD. Begin invert at 14300'. Drill to 14425' PVT 287 03:40 - 04:30 0.83 DRILL P PROD1 Wiper to window, clean 04:30 - 06:00 1.50 DRILL P PROD1 Drill ahead from 14425' 1.65/1.62/90L wI 0.5-1.5k wob, 1 k positive str wt, 200-300 psi ditt, 12.3 ECD and hold 92 deg 06:00 - 07:30 1.50 DRILL P PROD1 Drill ahead from 14500. 3600 psi @ 1.62 in/1.58 out fs. WOB: 2-3K# 200-300 dpsi. WHP: 20 psi ECD: 12.38 ppg BHP: 4177 psi. IA: 625 psi OA: 245 psi PVT: 277 bbls 07:30 - 09:30 2.00 DRILL P PROD1 Wiper trip to 500' above window. Hard to decide how far to wipe above window. Hole angle is 65 deg for a long ways! (2500') A lot of cuttings coming over shaker. POOH at 25 fpm for btms up. RIH. 09:30 - 10:30 1.00 DRILL P PROD1 Log gr tie in. Add 11' correction. 10:30 - 11 :00 0.50 DRILL P PROD1 Run in hole. Smooth. 11 :00 - 13:30 2.50 DRILL P PROD1 Drill ahead from 14575'. Having trouble holding angle in soft spot. Climb back to 91.5 deg inc. Drill to 14725'. 13:30 - 15:00 1.50 DRILL P PROD1 Wiper trip to window. Hole smooth. Lots of cuttings across shaker with btms up. 15:00 - 18:00 3.00 DRILL P PROD1 Drill ahead from 14725'. 3700 psi @ 1.56 in/1.40 out fs. 200-400 dpsi. WOB: 2k-3k#. WHP: 18 psi. ECD: 12.45 ppg. BHP: 4198 psi. PVT: 190 bbls. Loss rate has increased to 15 bph. Near bit incl: 95.6 deg. Seem to have recovered from un planned drop. Begin turn to right. ROP variable, alternating between 80 fpm soft spots and 15 fph hard spots. 18:00 - 19:10 1.17 DRILL P PROD1 Wiper to window, clean PVT 120 19:10 - 00:00 4.83 DRILL P PROD1 Drill ahead from 14875' 1.55/1.34/3830/90R w/ 0.5-1.5k wob, -8k string wt, 200-300 psi ditt, 12.68 ECD and hold 92 deg. Swap to fresh mud at 14950', and begin steeper climb at 93-94 deg. Drill to 14972' and penetration was still slow w/ new mud back to surface. 100' wiper didn't help penetration rate. Geo reports considerable siderite from 14800'. New paramenters 1.55/1.44/3540/90L w/1.0-2.5k wob, -6k string wt, 100-300 psi ditt, ECD 12.23 Drill to 15005' (6476' TVD) 10/24/2004 00:00 - 02:00 2.00 DRILL P PROD1 Drill ahead 1.55/1.42/3560/90R w/ 1.5k wob, 100 psi ditt, 12.25 ECD at 93.5 deg in siderite 02:00 - 03:30 1.50 DRILL P PROD1 Wiper to window, clean. Open EDC above window and wiper to 12700' 2.0/3950. RBIH to window (no 'extra' solids seen Printed: 11/1/2004 1 :52:37 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1 0-32 1 0-32 REENTER+COMPLETE NORDIC CALISTA NORDIC 2 Start: Rig Release: Rig Number: 10/20/2004 1 0/31/2004 2 Spud Date: 10/18/2004 End: 10/31/2004 10/24/2004 02:00 - 03:30 1.50 DRILL P PROD1 over shaker) 03:30 - 03:45 0.25 DRILL P PROD1 Log tie-in down from 13800', corr +6.0' 03:45 - 04:30 0.75 DRILL P PROD1 Close EDC. Wiper back to TD, clean Lost 35 bbls on trip due to ECD's PVT 268 04:30 - 06:00 1.50 DRILL 'P PROD1 Drill ahead 1.58/1.44/3580/85R w/1.4k wob, -7k str wt, 50-100 psi diff, 12.3 ECD at 93 deg in siderite and miserably slow 06:00 - 10:30 4.50 DRILL P PROD1 Drill ahead at ~ 3450 psi @ 1.59 in/ 1.46 out fs. 100-150 dpsi. WOB: 0.75 - 1.5K#. WHP: 20 psi ECD: 12.29 ppg BHP: 4129 psi. IA: 577 psi OA: 286 psi. PVT: 251 bbls. Losing about 8-10 bph. ROP: <=10 fph. GR has gone very hot. Samples show we are in D interval. Discuss with town et al. 10:30 - 14:00 3.50 STKOH N DPRB PROD1 Wiper trip to window. Open EDC and circulate out of hole. Plan is to open hole sidetrack. Close EDC at surface. Tag up. m-H 0.5'. Hole did not "unload" while circulating near surface. Shut in well with 500 psi on wellhead. 14:00 - 15:30 1.50 STKOH N DPRB PROD1 Hold PJSM with crew. Get off well. Unstab coil. Un-deploy BHA. 15:30 - 16:45 1.25 STKOH N DPRB PROD1 MU 2.1 deg mtr wI Hughes R60 ST with brass ring. Change out full MWD string. Deploy BHA. Stab coil. Get on well. 16:45 - 19:35 2.83 STKOH N DPRB PROD1 Run in hole. Slow down for all jewelry due to brass ring. Circ at min rate through EDC. 19:35 - 19:55 0.33 STKOH N DPRB PROD1 Log tie-in down from 13825', corr -34' 19:55 - 20:30 0.58 STKOH N DPRB PROD1 Wiper to KOP @ 14665'. Orient to 175R 20:30 - 21 :00 0.50 STKOH N DPRB PROD1 Backream and ream trough from 14665-14630' 1.56/1.45/3380/175R in three passes 21 :00 - 23:00 2.00 STKOH N DPRB PROD1 Park at 14665' and lock brake for 10 min 0.1 '/5 min for 30 min 1.55/1.43/3340/175L ECD 12.16 (4091 psi) 0.1 '/min for 30 min 0.5'/min for 60 min while work TF up from 175R to 90R Stops on orientor are at 160R (the worst spot) so it takes a while to go back around 23:00 - 00:00 1.00 STKOH N DPRB PROD1 Start adding wt wI 100 psi diff and drill to 14680' and seeing loss of incl. Backream at 150R while BHI reboots (30 min). RIH 10/25/2004 00:00 - 00:30 0.50 STKOH N DPRB PROD1 Drill from 14680' 1.56/1.46/3370 control drilling at 1 'Imin while bring TF from 90R to 35R. See incl get as low as 80.5 deg at 14677'. Drill to 14695' and stacking due to radical TF change past KOP (BHA hanging up). PUH and sticky 00:30 - 01 :00 0.50 STKOH N DPRB PROD1 Ream and backream KOP to TD to allow BHA to pass 01 :00 - 01 :20 0.33 STKOH N DPRB PROD1 Drill ahead to get lined out for lateral assy to 14704' and stacking 01 :20 - 02:20 1.00 STKOH N DPRB PROD1 Ream and backream from 14660-14690' 02:20 - 02:30 0.17 STKOH N DPRB PROD1 Drill to 14710' (end of kickoff) and still stacking 02:30 - 03:00 0.50 STKOH N DPRB PROD1 Ream and backream until clean( er) 03:00 - 03:30 0.50 STKOH N DPRB PROD1 Wiper to window 03:30 - 05:30 2.00 STKOH N DPRB PROD1 Open EDC. POOH following pressure schedule 1.68/3200 05:30 - 06:45 1.25 STKOH N DPRB PROD1 Tag up. Pressure un deploy w/400 psi 06:45 - 08:00 1.25 STKOH N DPRB PROD1 MU 1.1 deg extreme mtr with new HTC STRWD-324 bicenter bit. Deploy BHA. Stab coil. Get on well. 08:00 - 10:45 2.75 STKOH N DPRB PROD1 RIH following pressure schedule. 10:45 - 11 :15 0.50 STKOH N DPRB PROD1 Log gr tie in. Subtract. 32' correction. Printed: 11/1/2004 1 :52:37 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1 0-32 1 0-32 REENTER+COMPLETE NORDIC CALISTA NORDIC 2 Start: Rig Release: Rig Number: 10/20/2004 1 0/31/2004 2 Spud Date: 10/18/2004 End: 10/31/2004 1 012512004 11:15-12:15 1.00 STKOH N DPRB PROD1 Continue to RIH. Get through window ok. Close EDC. Monitor TF while RIH. 12:15 - 15:15 3.00 DRILL N DPRB PROD1 Drill ahead from 14710'. 3400 psi @ 1.54 in/1.40 out fs. 200-300 dpsi. WOB: 1.0-2.0k#. WHP/ECD/BHP: 22112.2/4080. IAlOA: 598/317. PVT: 345 bbls. Drill to 14870'. Variable ROP, some soft and some hard spots. 91 deg inc @ 6491' TVD. 15:15 - 16:15 1.00 DRILL N DPRB PROD1 Wiper trip to window at 25 fpm. Hole smooth 16:15-18:50 2.58 DRILL N DPRB PROD1 Drill ahead from 14870-15025' 18:50 - 20:00 1.17 DRILL N DPRB PROD1 Wiper to window was clean both ways, PVT 330 20:00 - 20:20 0.33 DRILL N DPRB PROD1 Drill from 15025' 1.54/1.27/3480/1 OL w/ 100 psi diff, 1-2k wOb, -7k str wt 20:20 - 22:20 2.00 DRILL P PROD1 Drill from 15050' at very slow progress (10-15'/hr) and see GR trending above 100 api 22:20 - 23:10 0.83 DRILL P PROD1 Finally got some motor work at 15079', but which indicated ratty drilling and then started losing returns 1.5/0.3/2800 wI ECD 10.8 initially. Wiper to window while wait on additional mud. Returns increased to 1.5/0.7 w/ ECD 11.2 and stabilized during wiper 23: 10 - 23:35 0.42 DRILL P PROD1 Pull thru window, open EDC, SI choke and maintain 10.6 ECD at 0.38 bpm w/350 psi whp while log tie-in, corr +6' PVT 219 23:35 - 00:00 0.42 DRILL N DPRB PROD1 PUH slow in tubing while WO mud and maintain overbalance 10/26/2004 00:00 - 01 :20 1.33 DRILL N DPRB PROD1 Pump dn CT w/ choke shut at 0.38 bpm wI 350-500 psi to maintain ECD above 10.6 ppg while wo mud. 160 bbls shows up at 0115 hrs 01 :20 - 02:00 0.67 DRILL P PROD1 RIH at 0.7/0.5/1900 wI open choke to TD ECD 11.3 PVT 357 02:00 - 03:00 1.00 DRILL P PROD1 Drill from tag at 15079' 1.55/1.0/3240/80L w/11.8 ECD. Found another loss zone at 15101' and now drilling at 1.5010.5/80L ECD 11.2 Work thru rubble zone with frequent pickups and had some overpulls and setdowns at 15079'. Drill to 15112' and seemed to be out of worst of it. Returns gradually improved to 1.5/1.0/3280 PVT 300 03:00 - 03:50 0.83 DRILL P PROD1 Drill ahead from 15112' 1.54/1.0/3280/90L wI 11.84 ECD and smoother drilling, but found another rubble zone at 15134'. Drill to 15137' and can't get wt to bit 03:50 - 04:05 0.25 DRILL P PROD1 Wiper to 15000', clean until set down at 15079'. Ream thru it and finish wiper to TD PVT 272 04:05 - 04:50 0.75 DRILL P PROD1 Drill ahead from 15137' 1.55/1.00/3280/90L wI 150 psi ditt, 1.5k wob, -5.5k str wt, 11.93 ECD w/ slow penetration rate. Swap to right side at 15150' and started drinking some more 1.55/0.55, ECD 11.37 04:50 - 05:00 0.17 DRILL P PROD1 Wiper to 15050' 32k, clean. Wt loss at 15079' on RIH 05:00 - 06:00 1.00 DRILL P PROD1 Drill ahead w/ better returns 1.55/0.75/3200/50R ECD 11.6, but slow penetration rate w/ 1.6k wob 06:00 - 07:00 1.00 DRILL P PROD1 Drill ahead from 15190. 3300 psi @ 1.55 in/0.90 out fs. 100 dpsi. WOB: 0.5 -1.5k#. WHP/ECD/BHP: 22/11.87/3996. IAlOAlPVT: 360/221/175 bbls. 07:00 - 07:30 0.50 DRILL P PROD1 Wiper trip to 14600'. Hole smooth. 07:30 - 10:00 2.50 DRILL P PROD1 Drill ahead from 15225. 3000 psi @ 1.39 in/O.?? out fs. 100 dpsi. WOB: 0.5 -1.5k#. WHP/ECD/BHP: 22/11.76/3968. IAlOAlPVT: 360/2211175 bbls. Drill to 15300, planned reel swap depth. 10:00 - 13:20 3.33 DRILL P PROD1 Wiper trip to window. Open EDC. CI rculate out of hole at 1.58 Printed: 11/1/2004 1 :52:37 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1 0-32 1 0-32 REENTER+COMPLETE NORDIC CALISTA NORDIC 2 Start: Rig Release: Rig Number: 10/20/2004 10/31/2004 2 Spud Date: 10/18/2004 End: 10/31/2004 1 012612004 10:00 - 13:20 3.33 DRILL P PROD1 bpm. Hold WHP as per schedule. Prep for reel swap. 13:20 - 14:10 0.83 DRILL P PROD1 Pressure undeploy wI 400 psi. LD BHA. Bit was 1-1-BU MIRU DS N2 14:10-15:15 1.08 DRILL P PROD1 Stab back on. Fill CT wI FW, 5 bbls MeOH 15:15-15:30 0.25 DRILL P PROD1 Safety mtg re: N2 15:30 - 16:30 1.00 DRILL P PROD1 Displace CT wI N2 16:30 - 17:30 1.00 DRILL P PROD1 Unstab CT and pull to reel and secure. 17:30 - 18:30 1.00 DRILL P PROD1 Pull bushings 18:30 - 19:45 1.25 DRILL P PROD1 Swap reels. 19:45 - 22:00 2.25 DRILL P PROD1 Install hard line. Pull CT to injector and stab coil. 22:00 - 23:20 1.33 DRILL P PROD1 Fill coil with 10 bbl Methanol and displace with H2O. 23:20 - 00:00 0.67 DRILL P PROD1 Pump slack management. 2.40 bpm at 4700 psi 10/27/2004 00:00 - 02:30 2.50 DRILL P PROD1 Blow back reel. Cut coil. Install coil connector. Pull test. 02:30 - 03:00 0.50 DRILL P PROD1 Circulate reel to mud, 03:00 - 04:00 1.00 DRILL P PROD1 Pressure deploy BHA per step by step procedure. 04:00 - 06:35 2.58 DRILL P PROD1 Log tie-in down from 13840' 06:35 - 07:30 0.92 DRILL P PROD1 I Wiper to TD was clean until set downs at 15079' 07:30 - 07:35 0.08 DRILL P PROD1 Ream thru 15079' 1.5/0.9/3230/90L ECD 11.7 with considerable motor work 07:35 - 07:50 0.25 DRILL P PROD1 Finish wiper to TD, clean except for last 50' (MW and wt loss). Tag TD at 15301' 07:50 - 10:55 3.08 DRILL P PROD1 Drill ahead 1.5/0.95/3320/90L 50-100 psi ditt, 1 k wob, -8k str wt, ECD 11.7 holding 89 deg at 6495' TVD and slow penetration until 15380'. Then, got into steady digging in 120 api rock-no sign of fault Move camp towards rig to allow room for 1 D-11 prep 10:55 - 12:45 1.83 DRILL P PROD1 Wiper to window, clean. RBIH, clean PVT 254 12:45 - 15:00 2.25 DRILL P PROD1 Drill ahead 1.51/0.74/3600/70L wi 100-300 psi diff, 0.85-1.5k wob, -8k str wt, ECD 12.15 Higher circ press/losses/ECD's due to new mud (wi 40k LSRV) being added ... a catch-22 Steady progress to 15500' and had a slow drilling spot 15:00-17:10 2.17 DRILL P PROD1 Penetration rate picked up at 15515' and drilling like sand at 1 00-150'/hr wI no wob. Returns increased to 1.5/0.85 at 12.25 ECD. GR showed 80-90 api rock later. Start building angle to 94 deg assuming this was the main fault expected 150' earlier. Ran into a brick wall at 15585' and took a while to make progress. Drill to 15600' 17:10 - 19:00 1.83 DRILL P PROD1 Wiper to window. Open EDC above window and circ 1.8/3500 to 12500'. RBIH 19:00 - 19:20 0.33 DRILL P PROD1 Tie-in zero correction 19:20 - 20:30 1.17 DRILL P PROD1 Continue to RI H on wiper to 15,600'. 1.2 bpm at 3,180 psi. 20:30 - 00:00 3.50 DRILL P PROD1 Directionally drill 1.5/89 bpm @ 3790 psi, 3700 psi FS, Up Wt 30K, DH coil pressure 4378, DH annular pressure 4091, ECD 12.0, WOB .24K, PT = 248 bbl. ROP = 10-116. 10/28/2004 00:00 - 05:00 5.00 DRILL P PROD1 Directionally drill 1.5/85 bpm @ 3880 psi, 3750 psi FS, Up Wt 30K, DH coil pressure 4385, DH annular pressure 4063, ECD 12.0, WOB ..7K, PT = 318 bbl. ROP = 26. 05:00 - 06:50 1.83 DRILL P PROD1 Directionally drill 1.6/84 bpm @ 3900 psi, 3750 psi FS, Up Wt 30K, DH coil pressure 4495, DH annular pressure 4080, ECD 12.10, WOB ..2K, PT = 439 bbl. ROP = 16. 06:50 - 07:55 1.08 DRILL P PROD1 Wiper to window, one overpull at 15290-15278' just above assumed cuttings bed 07:55 - 08:15 0.33 DRILL P PROD1 Open EDC and log tie-in down from 13810' while circ Printed: 11/1/2004 1 :52:37 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1 0-32 1 0-32 REENTER+COMPLETE NORDIC CALISTA NORDIC 2 Start: Rig Release: Rig Number: 10/20/2004 1 0/31 /2004 2 Spud Date: 10/18/2004 End: 10/31/2004 1 012812004 07:55 - 08:15 0.33 DRILL P PROD1 1.5/1.0/3100, corr +5'. Close EDC 08: 15 - 09:25 1.17 DRILL P PROD1 Wiper to TD was clean except for set down at 15585'. Tag at 15751' 09:25 - 12:55 3.50 DRILL P PROD1 Drill ahead from 15751' 1 .55/1 .00/3720/11 OR to maintain 94 deg wI 50-100 psi diff, up to 0.6k wob wi -8.6k str wt at 11.95 ECD (4020 psi) at avg 20'/hr 12:55 - 17:00 4.08 DRILL P PROD1 Drill ahead from 15805' 1.60/1.03/3860/90R at 94 deg wi 50-100 psi diff, up to 0.6k wob wi -8k str wt at 12.05 ECD at avg 15'/hr 117:00 - 19:20 2.33 DRILL P PROD1 Drill ahead from 15872' same as above. Geo's pick 15930' to be sufficient for TD 19:20 - 21:00 1.67 DRILL P PROD1 Wiper to window. 21 :00 - 21 :25 0.42 DRILL P PROD1 Tie-in log correction +6'. 21 :25 - 22:20 0.92 DRILL P PROD1 Wiper to 15000. 22:20 - 23:15 0.92 DRILL P PROD1 RI H without pump for dummy liner run. 1450 fph .3K WOB,5K surface wt @ 15050'. 20K up wt. Set down @ 15080, Orient 90L. NO GO. Pump 1.3 bpm 2860 psi. Got thru OK. Continue to RIHw/o pump. Set down at 15250. Orient. 120R NO GO. Pump 1.2 bpm OK. Set down @ 15305. Pump to get thru. Set down at 15577. Pump to get thru. 23:15 - 00:00 0.75 DRILL P PROD1 Directionally drill 1.6/1.94 bpm @ 3700 psi, 3550 psi FS, Up Wt 29K, DH coil pressure 4345, DH annular pressure 3950, ECD 11.77, WOB .1.K, PT = 396 bbl. ROP = 27. 1 0/29/2004 00:00 - 04:00 4.00 DRILL P PROD1 Directionally drill 1.42/.97 bpm @ 3300 psi FS 3250psi, Up Wt 29K, Dn Wt 2K,DH Tubing pressure4220, DH annular pressure3944 psi. WOB 1k, ROP 6-8. Drill to 15944 Called TD. 04:00 - 05:40 1.67 DRILL P PROD1 Wiper to window. Chase cutting to surface. 05:40 - 08:00 2.33 DRILL P PROD1 Open EDC. Wiper to surface following pressure schedule to ensure all cuttings removed from tubing 1.87/3550 08:00 - 10:00 2.00 DRILL P PROD1 Wiper from surface to window at min rate 0.4/1450 following pressure schedule 10:00 - 10:15 0.25 DRILL P PROD1 Log tie-in down from 13815', add 5.0'. SI @ choke. Close EDC 10:15-10:25 0.17 DRILL P PROD1 Monitor BHP Initial WHP 425, ECD 10.60, DHP 3500 Final WHP 425, ECD 10.16, DHP 3388 and falling 10:25 - 11 :25 1.00 DRILL P PROD1 Wiper to TD. Clean except for wt loss and MW at 15080', 15250',15305',15800',15907'. RIH and tag at +1-15944'. PUH 33.5k 11 :25 - 12:10 0.75 DRILL P PROD1 Start 10.5# fresh Formate mud wI 4% L T while wiper to 15000' and back to TD 12:10 - 13:00 0.83 DRILL P PROD1 POOH thru open hole 40'/min 0.6/1500 leaving 10.3+ (measured) mud in open hole 13:00 - 15:30 2.50 DRILL P PROD1 POOH displacing 8.6 mud wI 10.5# KWF 15:30 - 15:45 0.25 DRILL P PROD1 Tag up, check for flow 15:45 - 16:15 0.50 DRILL P PROD1 LD drilling BHA 16:15-16:45 0.50 CASE P RUNPRD RU to run liner. Monitor well bore and is taking 1 bbl/10 min PVT 291 16:45 - 17:00 0.25 CASE P RUNPRD Safety mtg 17:00 - 19:30 2.50 CASE P RUNPRD MU used Hycalog bi bit on used 1.1 deg WF motor, one solid jt 2-3/8" 4.7# L-80 STL, O-ring sub, 67 jts 2-3/8" STL predrilled at 8 hpf, one solid jt 2-3/8" STL, BTT torque sleeve deployment sub Printed: 11/1/2004 1 :52:37 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1 0-32 1 0-32 REENTER+COMPLETE NORDIC CALISTA NORDIC 2 Start: 10/20/2004 Rig Release: 10/31/2004 Rig Number: 2 Spud Date: 10/18/2004 End: 10/31/2004 1 012912004 19:30 - 20:00 0.50 CASE P RUNPRD RU floorfor running 1" CSH. 20:00 - 22:00 2.00 CASE P RUNPRD RIH with 1" CSH inner string. 69 JTS + 3.88' pup. for space out. 22:00 - 23:00 1.00 CASE P RUNPRD MU Hydraulic GS, MHA. EDC open. PU 2' lubricator extension. MU NRJ. Stab onto well. 23:00 - 00:00 1.00 CASE P RUNPRD RIH with liner with inner string ,bit and mud motor. Liner wt 14K. RIH to window Circulating thru EDC. at min rate .66 bpm.PT 272bbl @ 3000'MD. 1 0/30/2004 00:00 - 01 :00 1.00 CASE P RUNPRD Containue ti RIH to 13800 Correction -30'. Open EDC. UP wt 37K, DN Wt 6K 01 :00 - 04:20 3.33 CASE P RUNPRD Orient 20L Run thru window no problem. RIH 140 ftImin.W/O pump. ECD 11.14 Set down at 15000. Orient 90L. Pump at .8 bpm 3080 psi. No Go . Up 52K Over pull. Orient 20L. Ok Continue to RIH. set down 15061. Circulate PU 48K. Stacking. 15065, Orient 90L, Set down 15098, Pump.6 bpm PU 47K. Orient 180. Work pipeto15122. Orient 105R set down 15123. Orient 90L. No Pump RIH to 15143. RIH to 15156 stacking. RIH to 15180. Orient 105R. Working pipe. Circulate.2 bpm stacking Orient 60R ,No Go. Orient high side, No Pump. RIH Set down 15194. Orient 15L, Working pipe to 15212. Orient 180R. Work liner to 15303, Orient 220L,work to 15318, Orient 60L, No Go lost gound to 15300. Orient High side. Work liner to 15340'. Orient 15L, Work liner to 15379'. Orient 120L work to 15447. 04:20 - 04:30 0.17 CASE P RUNPRD Circulate 1.1 bpm @ 3800 psi, 86L, PU to 15419, Open EDC and pump at 1.656 @ 4200 psi.Close EDC 04:30 - 05:45 1.25 CASE P RUNPRD Continue RIH Orient low side Worked to 15506. Lost ground. Work back to 15493. Orient 10R. Work to 15510. Orient 30L. Work to 15547' 05:45 - 06:30 0.75 CASE P RUNPRD Work to 15561'. PUH 50k and a little sticky. Start losing ground back to 15495' 06:30 - 07:30 1.00 CASE P RUNPRD Orient to 90L Figure offset and see that we have been wlin 30 deg of drilled TF when getting by setdown points, so will use this on push to TD. RIH from 15460' and set down at 15495' at 90L. Orient to 10R and get to 15505'. Orient to 30L and get to 15527'. Haven't been getting returns and EDC didn't appear to function properly earlier, so not an option. Fill BS wI 5 bbls and hold 500 psi and gained 30' to 15545' 07:30 - 08:00 0.50 CASE P RUNPRD Work at various left side TF's and pump down CT. No progresslmotor work/returns suggests hanging up further back up hole. Resume pounding wI clean pickups at 48k and no progress at 15545' at 45-120L 08:00 - 08:30 0.50 CASE P RUNPRD Apply 500 psi WHP and get to 15560'. Apply 1000 psi WHP and after several attempts, RIH to 15638'! Work for a bit at 120L TF and no-go. PUH and orient to HS. Sorry, Dan, but apply 1500 psi WHP at 0.85 bpm and RIH 15'/min orienting to drilled TF until setdown at 15725'. Work to 15730' and no more progress. Bit may be balled up, but this is also the start of 94 deg hole. Max ECD seen was 11.8 08:30 - 09:00 0.50 CASE P RUNPRD PUH, clean at 38k and swap to pumping dn CT 0.93/3500/105R. No progresslmotor work/ returns. PUH, clean and orient to 80R. Apply 1600 psi whp at 0.95 bpm and RIH at 26'/min to 15789' wI max ECD of 12.2. Work to 15797' Printed: 11/1/2004 1 :52:37 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1 D-32 1 D-32 REENTER+COMPLETE NORDIC CALISTA NORDIC 2 Start: Rig Release: Rig Number: 1 0/20/2004 1 0/31 /2004 2 Spud Date: 10/18/2004 End: 10/31/2004 10/30/2004 08:30 - 09:00 0.50 CASE P RUNPRD and hold stacked wt 09:00 - 09:45 0.75 CASE P RUNPRD Line up wI pump #1 on BS at 1.0 bpm/1600 psi and pump #2 on CT 0.24/1400/90R and RIH immediately to 15827' set down. Red BS rate to 0.6 bpm and bring up CT rate to 0.8 bpm-no motor work. Swap to BS only at 1.05/1670. Work a few times and no progress, then started running rather freely at 12'/min to 15887'. Work a few times, but pulling 58k to PUH. Pump dn CT wI no motor work. PUH 52k. RIH pumping dn BS only 1.2/1680 ECD 12.4 and get to 15914'. Repeat and get to 15920'. Repeat and get to 15924' and call this good (20' from TD). Gives a whole new meaning to coil frac . . . 09:45 - 11 :45 2.00 CASE P RUNPRD Bleed off pressures, line up to pump #1 dn CT. Incr rate to 1.15 bpm/4300 while PUH to 31 k and leave liner with top at 13748' and bottom at 15924'. POOH 11 :45 - 12:45 1.00 CASE P RUNPRD LD BHI and BTT BHA's and load out same 12:45 - 14:15 1.50 CASE P RUNPRD LD 1" CSH and load out 14:15 - 14:30 0.25 WHSUR P RUNPRD MU nozzle BHA 14:30 - 16:50 2.33 WHSUR P RUNPRD RIH wI nozzle to 13700' pumping 75 bbls rig water 0.5/1240 Dilute mud from 7000' 1.0/1700. Swap to diesel at 9000' 1.0/1550 16:50 - 19:00 2.17 WHSUR P RUNPRD POOH displacing well bore to diesel and CT to water following pressure schedule 19:00 - 21 :20 2.33 WHSUR P RUNPRD Close swab and master. Remove check valve from tubing string. Actually, waited on N2 pumper. . . 21 :20 - 21 :30 0.17 WHSUR P RUNPRD PJSM for N2 blow down. 21 :30 - 21:45 0.25 WHSUR P RUNPRD Circulate MEOH lead 21 :45 - 23:00 1.25 WHSUR P RUNPRD Blow down reel with N2. 23:00 - 00:00 1.00 WHSUR P RUNPRD PJSM and pull tubing back to reel. 10/31/2004 00:00 - 01 :00 1.00 RIGD POST One hour time change 00:00 - 05:00 5.00 BOPSU P POST Reel swap.lnstall hardline and grapple. Change out rams in BOP for 2-3/8 CT.ND BOP Rig released at 0500 hrs to 1 D-11 Printed: 11/1/2004 1 :52:37 PM . BP-GDB Baker Hughes INTEQ Survey Report . .,a: INT&Q Field: Kuparuk River Unit North Slope UNITED STATES Map System:US State Plane Coordinate System 1927 Goo Datum: NAD27 (Clarke 1866) Sys Datum: Mean Sea Level Map Zone: Coordinate System: Geomagnetic Model: Alaska, Zone 4 Well Centre bggm2004 Site: KRU 10 Pad UNITED STATES: North Slope Site Position: Northing: 5959249.42 ft Latitude: 70 17 57.217 N From: Map Easting: 560670.61 ft Longitude: 149 30 31.143 W Position Uncertainty: 0.00 ft North Reference: True Ground Level: 0.00 ft Grid Convergence: 0.46 deg Well: 1 D-32 Slot Name: 1 D-32 Well Position: +N/-S 0.00 ft Northing: 5959249.42 ft Latitude: 70 17 57.217 N +E/-W 0.00 ft Easting : 560670.61 ft Longitude: 149 30 31.143 W Position Uncertainty: 0.00 ft Wellpath: 1O-32L 1 Drilled From: 1D-32L1PB1 500292298260 Tie-on Depth: 14665.00 ft Current Datum: 1 D-32 Height 104.45 ft / Above System Datum: Mean Sea Level Magnetic Data: 10/15/2004 Declination: 24.61 deg Field Strength: 57579 nT Mag Dip Angle: 80.75 deg Vertical Section: Depth From (TVD) +N/-S +EI-W Direction ft ft ft deg 0.00 0.00 0.00 130.25 Survey Program for Definitive Wellpath Date: 11/29/2004 Validated: Yes Actual From To Survey ft ft 130.00 13768.22 13826.00 14661.38 14665.00 15944.00 Version: 9 Toolcode Tool Name Survey #1 (130.00-14138.00) (0) MWD (13826.00-15062.00) (2) MWD (14665.00-15944.00) MWD MWD MWD MWD - Standard MWD - Standard MWD - Standard Annotation 13826.00 14661.38 14665.00 15944.00 6540.43 6594.60 6594.80 6573.01 Window TIP KOP TO Survey: MWD CoilTrak Company: Baker Hughes INTEQ Tool: MWD;MWD - Standard Start Date: 10/29/2004 Enginecr: Tied-to: From: Definitive Path . BP-GDB Baker Hughes INTEQ Survey Report . .... ..... INTJ.!.Q 13826.00 64.73 148.79 6540.43 6435.98 -7753.88 7348.12 5951555.86 568080.39 10618.29 0.00 0.00 14661.38 86.55 69.08 6594.60 6490.15 -7892.99 8094.93 5951422.79 568828.22 11278.16 9.48 271.27 14665.00 87.09 68.92 6594.80 6490.35 -7891.70 8098.30 5951424.11 568831.58 11279.90 15.56 343.52 14679.78 81.08 72.05 6596.32 6491.87 -7886.79 8112.15 5951429.13 568845.39 11287.30 45.79 152.76 14705.50 87.47 77.75 6598.89 6494.44 -7880.13 8136.84 5951435.99 568870.02 11301.84 33.21 41.91 14736.01 93.09 85.43 6598.74 6494.29 -7875.68 8166.98 5951440.69 568900.12 11321.97 31.18 53.84 14771.91 92.19 90.28 6597.08 6492.63 -7874.34 8202.81 5951442.32 568935.93 11348.45 13.73 100.41 14803.14 90.32 94.25 6596.40 6491.95 -7875.57 8234.00 5951441.34 568967.13 11373.05 14.05 115.17 14836.69 92.29 99.17 6595.63 6491.18 -7879.49 8267.30 5951437.69 569000.46 11401.00 15.79 68.13 14866.50 92.62 102.99 6594.36 6489.91 -7885.21 8296.52 5951432.20 569029.72 11427.00 12.85 84.98 14906.79 90.23 106.82 6593.36 6488.91 -7895.57 8335.43 5951422.16 569068.71 11463.39 11.20 121.91 14942.15 88.24 109.32 6593.83 6489.38 -7906.53 8369.04 5951411.47 569102.41 11496.12 9.04 128.53 14973.70 86.02 105.89 6595.41 6490.96 -7916.06 8399.07 5951402.18 569132.51 11525.20 12.94 236.98 15005.62 86.82 102.21 6597.40 6492.95 -7923.79 8429.97 5951394.70 569163.46 11553.78 11.78 282.17 15035.78 90.35 99.79 6598.15 6493.70 -7929.54 8459.56 5951389.19 569193.10 11580.08 14.19 325.54 15065.71 91.58 96.80 6597.64 6493.19 -7933.86 8489.17 5951385.11 569222.74 11605.47 10.80 292.38 15096.25 91.46 93.02 6596.83 6492.38 -7936.47 8519.58 5951382.74 569253.17 11630.37 12.38 268.23 15123.22 90.97 90.06 6596.26 6491.81 -7937.20 8546.53 5951382.24 569280.12 11651.40 11.12 260.63 15158.80 89.28 87.12 6596.18 6491.73 -7936.32 8582.09 5951383.40 569315.67 11677.98 9.53 240.12 15184.46 92.14 91.59 6595.86 6491.41 -7936.03 8607.74 5951383.89 569341.31 11697.37 20.68 57.37 15222.21 92.78 97.50 6594.24 6489.79 -7939.02 8645.32 5951381.21 569378.91 11727.98 15.73 83.69 15249.14 89.22 98.91 6593.77 6489.32 -7942.86 8671.97 5951377.59 569405.58 11750.80 14.22 158.38 15268.83 88.17 101.06 6594.22 6489.77 -7946.28 8691.35 5951374.33 569425.00 11767.80 12.15 116.06 15302.50 86.73 103.37 6595.72 6491.27 -7953.39 8724.22 5951367.48 569457.92 11797.49 8.08 122.01 15330.55 86.85 100.64 6597.29 6492.84 -7959.22 8751.61 5951361.88 569485.35 11822.16 9.73 272.44 15361.01 87.19 97.55 6598.87 6494.42 -7964.02 8781.65 5951357.31 569515.42 11848.18 10.19 276.21 15393.08 89.16 94.78 6599.90 6495.45 -7967.47 8813.51 5951354.13 569547.31 11874.73 10.60 305.38 15430.33 88.97 91.83 6600.50 6496.05 -7969.61 8850.69 5951352.28 569584.50 11904.49 7.93 266.29 15459.92 89.56 89.82 6600.88 6496.43 -7970.04 8880.27 5951352.10 569614.08 11927.35 7.08 286.35 15491.84 91.03 86.81 6600.72 6496.27 -7969.10 8912.17 5951353.29 569645.97 11951.09 10.49 296.03 15520.61 92.22 84.32 6599.90 6495.45 -7966.88 8940.84 5951355.75 569674.62 11971.53 9.59 295.58 15550.37 94.96 81.46 6598.04 6493.59 -7963.20 8970.31 5951359.66 569704.06 11991.65 13.29 313.91 15580.94 86.39 73.29 6597.68 6493.23 -7956.53 9000.09 5951366.57 569733.77 12010.06 38.71 223.75 15620.82 88.69 67.64 6599.39 6494.94 -7943.21 9037.62 5951380.19 569771.19 12030.10 15.28 292.03 15650.44 94.11 68.94 6598.67 6494.22 -7932.26 9065.12 5951391.36 569798.60 12044.02 18.82 13.47 15682.26 95.67 73.00 6595.95 6491.50 -7921.93 9095.08 5951401.93 569828.48 12060.21 13.62 68.75 15712.62 95.36 76.26 6593.04 6488.59 -7913.92 9124.22 5951410.18 569857.54 12077.27 10.74 95.30 15741.65 95.49 80.47 6590.29 6485.84 -7908.09 9152.51 5951416.23 569885.79 12095.10 14.44 88.03 15773.25 94.65 86.01 6587.50 6483.05 -7904.39 9183.76 5951420.19 569917.00 12116.56 17.66 98.40 15802.62 94.87 89.76 6585.06 6480.61 -7903.31 9213.00 5951421.50 569946.23 12138.18 12.75 86.48 15832.70 94.04 93.20 6582.72 6478.27 -7904.08 9242.98 5951420.97 569976.21 12161.56 11.73 103.47 15865.73 95.50 97.47 6579.97 6475.52 -7907.14 9275.74 5951418.18 570009.00 12188.54 13.62 70.89 15893.25 95.02 101.00 6577.45 6473.00 -7911.54 9302.79 5951414.00 570036.07 12212.02 12.89 97.61 15944.00 95.02 101.00 6573.01 /" 6468.56 -7921.19 9352.41 5951404.75 570085.77 12256.13 0.00 0.00 Alaska, Inc. WELLPATH DETAILS 1D.32L1 500292298260 Parent Wellpath: TieonMD: 1 D·32L1PB1 14665.00 Rig: Nordic 2 Ref, Datum: 10·32 1M.45ft V,Sectlon Origin ~~i:J ~;:~i~D Angle +NJ..s 130.25" 0.00 0.00 REFERENCE Co-ordinate (NIE) Reference; Well Centre; 10-32. True North Vertical (TVD) Reference: System: Mean Sea Level Section (VS) Reference: Slot - (O.OON,O.OOE) Measured Depth Reference: 10-32 104.45 Calculation Method: Minimum Curvature ANNOTATIONS TVD MD NmQrntion 6435,98 6490.15 6490.3-5 6468:56 ~~----~ Survey: MWD (1D-32/1D-32L 1) BrijPo!nis Date: 11/29/2004 I .' _ 1 ¡ 7800 7900 SOOO 8100 8500 8800 8700 8800 8900 9000 9100 9200 9300 9400 9500 9600 West( -)/Eest(...) [10Qftlin] AM . BP-GDB Baker Hughes INTEQ Survey Report . .,a: INT&Q Field: Kuparuk River Unit North Slope UNITED STATES Map System:US State Plane Coordinate System 1927 Geo Datum: NAD27 (Clarke 1866) Sys Datum: Mean Sea Level Map Zone: Coordinate System: Geomagnetic Model: Alaska, Zone 4 Well Centre bggm2004 Site: KRU 10 Pad UNITED STATES: North Slope Site Position: Northing: 5959249.42 ft Latitude: 70 17 57.217 N From: Map Easting: 560670.61 ft Longitude: 149 30 31.143 W Position Uncertainty: 0.00 ft North Reference: True Ground Level: 0.00 ft Grid Convergence: 0.46 deg Well: 1 D-32 Slot Name: 1 D-32 Well Position: +N/-S 0.00 ft Northing: 5959249.42 ft Latitude: 70 17 57.217 N +E/-W 0.00 ft Easting : 560670.61 ft Longitude: 149 30 31.143 W Position Uncertainty: 0.00 ft Wellpath: 1 D-32L 1 PB1 Drilled From: 1 D-32 500292298270 Tie-on Depth: 13826.00 ft Current Datum: 1 D-32 Height 104.45 ft Above System Datum: Mean Sea Level Magnetic Data: 10/15/2004 Declination: 24.61 deg Field Strength: 57579 nT Mag Dip Angle: 80.75 deg Vertical Section: Depth From (TVD) +N/-S +E/-W Direçtion ft ft ft deg 0.00 0.00 0.00 133.05 Survey Program for Definitive Wellpath Date: 11/29/2004 Validated: Yes Actual From To Survey ft ft 130.00 13768.22 13826.00 15062.00 Version: 8 Toolcode Tool Name Survey #1 (130.00-14138.00)(0) MWD (13826.00-15062.00) MWD MWD MWD - Standard MWD - Standard Annotation 13768.22 13826.00 15062.00 6516.00 6540.43 6577.66 TIP KOP TD Survey: MWD CoilTrak Company: Baker Hughes INTEQ Tool: MWD;MWD - Standard Start Date: 10/24/2004 Engineer: Tied-to: From: Definitive Path Survey 13768.22 65.24 148.86 6516.00 6411.55 -7709.08 7321.02 5951600.43 568052.92 10612.42 0.00 0.00 13826.00 64.73 148.79 6540.43 6435.98 -7753.88 7348.12 5951555.86 568080.39 10662.81 0.89 187.08 13856.87 69.39 141.80 6552.47 6448.02 -7777.21 7364.31 5951532.66 568096.76 10690.57 25.73 304.50 13886.90 75.80 134.90 6561.46 6457.01 -7798.57 7383.36 5951511.45 568115.98 10719.07 30.59 313.15 13917.04 77.19 128.29 6568.51 6464.06 -7818.01 7405.26 5951492.19 568138.04 10748.35 21.82 281.42 13943.03 81.64 121.01 6573.28 6468.83 -7832.52 7426.27 5951477.86 568159.16 10773.59 32.42 301.16 13978.78 83.05 109.03 6578.06 6473.61 -7847.47 7458.31 5951463.17 568191.32 10807.22 33.44 275.95 14008.37 85.28 104.76 6581.07 6476.62 -7856.02 7486.47 5951454.85 568219.54 10833.63 16.21 297.47 14039.55 84.35 99.47 6583.89 6479.44 -7862.53 7516.82 5951448.58 568249.94 10860.26 17.16 259.76 14070.73 86.97 105.76 6586.25 6481.80 -7869.32 7547.14 5951442.04 568280.31 10887.05 21.80 67.59 14105.84 88.88 113.29 6587.53 6483.08 -7881.04 7580.19 5951430.59 568313.45 10919.19 22.11 75.91 . BP-GDB Baker Hughes INTEQ Survey Report . ..I: INT&Q 14137.04 87.03 118.44 6588.64 6484.19 -7894.64 7608.23 5951417.22 568341.60 10948.97 17.53 109.85 14165.91 88.14 125.06 6589.86 6485.41 -7909.81 7632.75 5951402.25 568366.23 10977.24 23.23 80.62 14196.24 87.04 124.48 6591.14 6486.69 -7927.09 7657.64 5951385.17 568391.26 11007.23 4.10 207.77 14228.37 87.59 119.59 6592.64 6488.19 -7944.11 7684.84 5951368.37 568418.59 11038.72 15.30 276.31 14260.30 88.33 113.63 6593.78 6489.33 -7958.39 7713.35 5951354.32 568447.22 11069.31 18.80 276.97 14290.02 87.19 105.65 6594.94 6490.49 -7968.37 7741.30 5951344.57 568475.25 11096.54 27.10 261.72 14321.12 88.39 100.12 6596.14 6491.69 -7975.29 7771.58 5951337.89 568505.58 11123.40 18.18 282.14 14351.51 91.92 96.22 6596.06 6491.61 -7979.61 7801.65 5951333.82 568535.68 11148.32 17.31 312.14 14382.94 89.49 88.39 6595.67 6491.22 -7980.87 7833.03 5951332.81 568567.06 11172.11 26.08 252.83 14415.99 90.20 81.05 6595.76 6491.31 -7977.83 7865.92 5951336.11 568599.92 11194.06 22.31 275.51 14446.32 92.90 76.79 6594.94 6490.49 -7972.01 7895.66 5951342.18 568629.61 11211.82 16.62 302.42 14478.66 91.34 68.47 6593.74 6489.29 -7962.37 7926.48 5951352.06 568660.35 11227.76 26.16 259.55 14510.62 91.12 60.24 6593.06 6488.61 -7948.55 7955.26 5951366.11 568689.01 11239.36 25.75 268.56 14541.97 91.64 63.95 6592.30 6487.85 -7933.89 7982.95 5951381.00 568716.58 11249.58 11.95 81.98 14571.78 88.91 67.50 6592.16 6487.71 -7921.63 8010.12 5951393.47 568743.65 11261.07 15.02 127.54 14604.61 89.74 72.85 6592.54 6488.09 -7910.51 8040.99 5951404.85 568774.42 11276.03 16.49 81.22 14631.78 87.78 73.14 6593.13 6488.68 -7902.56 8066.96 5951413.00 568800.33 11289.59 7.29 171.59 14661.38 86.55 69.08 6594.60 6490.15 -7892.99 8094.93 5951422.79 568828.22 11303.49 14.32 253.03 14688.58 90.63 67.91 6595.27 6490.82 -7883.03 8120.22 5951432.96 568853.43 11315.17 15.60 343.99 14717.13 96.07 69.43 6593.60 6489.15 -7872.66 8146.76 5951443.54 568879.88 11327.48 19.78 15.55 14742.06 95.27 75.42 6591.13 6486.68 -7865.18 8170.40 5951451.21 568903.45 11339.65 24.12 97.34 14775.28 95.27 81.56 6588.08 6483.63 -7858.58 8202.79 5951458.07 568935.79 11358.82 18.40 89.72 14805.15 92.29 84.83 6586.11 6481.66 -7855.05 8232.38 5951461.84 568965.35 11378.03 14.79 132.29 14835.73 91.27 89.15 6585.16 6480.71 -7853.45 8262.90 5951463.69 568995.85 11399.23 14.51 103.22 14865.19 90.41 95.00 6584.73 6480.28 -7854.51 8292.32 5951462.86 569025.28 11421.46 20.07 98.31 14908.29 90.38 101.07 6584.43 6479.98 -7860.53 8334.98 5951457.18 569067.98 11456.74 14.08 90.26 14938.35 92.47 105.37 6583.68 6479.23 -7867.40 8364.22 5951450.55 569097.27 11482.80 15.90 64.03 14971.00 92.93 111.11 6582.14 6477.69 -7877.61 8395.19 5951440.60 569128.31 11512.39 17.62 85.28 15001.29 92.78 115.66 6580.63 6476.18 -7889.61 8422.95 5951428.82 569156.17 11540.87 15.01 91.78 15030.60 92.81 119.59 6579.20 6474.75 -7903.18 8448.88 5951415.46 569182.21 11569.09 13.39 89.47 15062.00 92.81 119.59 6577.66 6473.21 -7918.67 8476.15 5951400.20 569209.60 11599.59 0.00 0.00 Parent·Wêllpath: Tie on MD: 1D·32L1 500292298260 1D-32L1PB1 146135.00 RIg: Re-f. Datum: Nordic 2 10-32 104.45ft V.Section Angie 130.;;t5° o:~~~ ~~i:J Starting From TVO 0.00 0.00 0.00 REFERENCE/INFORMATION Co-ordinale (N/E) Reference: Well Centre: 10-32, True North Verticel (TVO) Reference: System: Mean Sea Levei Secti(m (VS) Reference: Slot - (O.OON,OJJOE) Meaeured Oepth Reference: 10-32 104.45 Calculation Method: Minimum Curvature ANNOTATIONS TVO MD AnflotatiOO Window TIP KOP TO M Azimuths to True North Magnetic North: 24.610 Survey: MWD (1D-32/"ID-32l1) ~ Created By: Brij Potnis Dale: 11129/2004 7100 7200 7300 7400 7500 71;00 77'00 7800 7900 8000 8100 8200 6300 8400 8500 86'00 8700 8800 8900 9000 9100 West( -)JEest(+) (100ttlin] AM ,. . . KRU 1 D-32L 1 ConocoPhillips Alaska, Inc. 1 D·32L 1 API: 500292298260 Well Type: PROD Angle (ãJ TS: deo Iéi) TUBING SSSV Type: NIPPLE Orig Angle @ TD: deg@ (0-13255, Completion: 00:3.500, Annular Fluid: Last W/O: Rev Reason: CTD Lateral Leg, 10:2.992) SURFACE GLV desicn (0-9006, Reference Loo: Ref Log Date: Last Uodate: 11/5/2004 00:9.625, Last Tag: 13758 (main leg) TD: 15924 ftKB Wt:40.00) Last Tag Date: 11/3/2004 Max Hole Ancle: o dec (ãJ Casino Strino· COMMON STRINGS DescriDtion Size TOD Bottom rvD Wt Grade Thread CONDUCTOR 20.000 0 117 117 91.50 H-40 WELDED 'ROOUCTION SURFACE 9.625 0 9006 9006 40.00 L-80 BTCM (0-13324, 00:7.000, PRODUCTION 7.000 0 13324 13324 26.00 J-55 BTC MOD Wt:26.00) WINDOW to L 1 2.375 13826 13836 13836 0.00 Casino Strina - L 1 LiNER (LINER MINIMUM ID. = .1.995") DescriDtion 1 Size I TOD 1 Bottom 1 rvD Wt I Grade I Thread SLOTTED L 1 LINER I 2.375 I 13478 I 15924 I 15924 4.70 L-80 I STL NIP TubinaStñna - TUBING ~13123-13124, Size 1 TOD Bottom 1 rvD 1 Wt 1 Grade Thread 00:3.500) 3.500 1 0 13255 1 13255 1 9.30 I L-80 EUE 8rd Perforations Summary Interval 1 rvD 1 Zone 1 Status 1 Ft ISPF Date TYDe Comment 13780 - 15892 113780 - 15892 1 1 121121 8 10/30/2004 IPERF Slotted Liner with 3/8" holes Gas Lift MandrelslValvas PACKER St I MD rvD Man Man Type I V Mfr V Type I V OD I Latch Port ITRO Date Vlv ~13190-13191, Mfr Run Cmnt 00:7.000) 1 1 5230 5230 CAMCO 1 MMG 1 OV I 1.5 1 RK 0.000 I 0 11/3/2004 Other (I M s. aaui Þ;. ate.) - COMMON JEWELRY Depth TVD TYDe Description ID 533 533 NIP CAMCO 'DS' NIPPLE w2.875" NO GO PROFILE 2.875 13123 13123 NIP CAMCO DS NIPPLE w/2.812" NO GO PROFILE 2.812 SBE 13190 13190 PACKER BAKER 5XT' ZXP LINER TOP PACKER w5" TKC COUPLING 5.000 :13210-13211, 13210 13210 SBE BAKER SBE 80-40 SBE wTKC COUPLINGS 4.000 00:6.000) 13218 13218 SEAL BACK 35' GBH-22 SEAL ASSEMBLY 3.000 13219 13219 JOINT 2.992 13268 13268 NIP HES XN NIPPLE w/2.75" NO GO PROFILE 2.750 14134 14134 SHOE 0.000 Other (I iuas. e auip. etc.) - L 1 LINER JEWELRY SEAL Depth rvD TVDe I DescriDtion 1 ID ~13218-13219, 00:4.000) 13748 13748 SLEEVE I BAKER DEPLOYMENT SLEEVE 1 2.250 15912 15912 MOTOR 1 WEATHERFORD USED 2-3/8" ADJ. MOTOR, OAL 11' 1 0.000 General Notes JOINT Date I Note :13219-13268, 00:3.500) 0/29/2001 Bi-LATERAL WELL: 10-32 ORIGINAL COMPLETION; CTD DRILLED 1O-32L 1 NIP LATERAL LEG 1 WILL BE PRE-PRODUCED BEFORE GOING TO INJECTION :13268-13269, 00:3.500) SLOTTEO L 1 LINER ~13478-15924, 00:2.375, Wt:4.70) WINOOW to L1 - ~13826-13836, - - 00:2.375) - - SHOE - - ~14134-14135, - - 00:3.500) .~m_ -........- Perf - - :13780-15892) - - - - - - - - - - - - -=:.01 io::- MOTOR :15912-15913. 00:2.380) RE: KRU ID-ll and ID-32 L1: Request for w! tram monthly testing - \\)- \\ \~~-O '1~ - \ \ \... \. ~04'-;} \ \ - \ \ '- d... d()~'-ð-\d Subject: RE: KRU ID-ll and ID-32 Ll: Request for waiver from monthly testing From: "Seitz, Brian" <Brian.Seitz@conocophillips.com> Date: Wed, 27 Oct 200409:22:43 -0800 To: Thomas Maunder <tom_maunder@admin.state.ak.us>, "Venhaus, Dan E" <Dan.E. V enhaus@conocophillips.com> CC: John D Hartz <jack_hartz@admin.state.ak.us>, Steve McMains <steve _ mcmains@admin.state.ak.us>, "Johnstone, Sam" <Sam.Johnstone@conocophillips.com>, "Lamar Gantt (E-mail)..<ganttll@bp.com> \~ - ~ J .g{)O - \ 't ~ -"\d'-~ ~C4-\<1Çi\ '~~ Thanks Tom. Dan & Lamar - please note that this applies to 1 D-32 as well with regards to how to file the completions report. Brian -----Original Message----- From: Thomas Maunder [mailto:tom_maunder@admin.state.ak.us] Sent: Wednesday, October 27,20049:16 AM To: Seitz, Brian Cc: John D Hartz; Steve McMains Subject: Re: KRU 1D-11 and 1D-32 L1: Request for waiverfrom monthly testing Brian, With regard to the plan to produce ID-ll, Ll and L2 for some 3 to 6 months, when the lateral completion reports (form 407s) are submitted they should show the completion as I-oil. This will make sure the production record is established appropriately. When CP AI has determined it time to convert to injector, then 403s should be submitted to provide notice and request approval of the conversion. I hope this answers your question. Tom Maunder, PE AOGCC Seitz, Brian wrote: Thanks Tom. I appreciate the quick turn-around on this one. Brian -----Original Message----- From: Thomas Maunder [mailto:tom maunder@admin.state.ak.us] Sent: Thursday, September 30, 2004 3:17 PM To: Seitz, Brian Cc: jack hartz@admin.state.ak.us¡ CPF1 Prod Engr Subject: Re: KRU 1D-11 and 1D-32 L1: Request for waiver from monthly testing Brian, Jack and I have discussed your proposal and find it acceptable. I have received the sundries for the wells and will include a copy of this email with them. Please call with any questions. Tom Maunder, PE AOGCC RE: KRU ID-ll and ID-32 L1: Request for waf from monthly testing e Seitz, Brian wrote: Tom- ConocoPhillips is evaluating the temporary conversion of two Kuparuk water injection wells, KRU 1D-11 and KRU 1D-32 L1, to production. While on production, both wells will be tied into the production header. However, tying into the test header to allow for well testing through the DS-1D test facility is likely to add significant cost and delay to a project that is short term in nature. As such, we request a waiver from the monthly well testing requirement for the estimated 3-6 months that these two wells will be on production. We propose testing the wells through a temporary test skid every other month during the production period. KRU 1D-11 is a current water injector perforated in only the C4 sands. We plan to perforate oil bearing C1 sands and evaluate its productivity in support of other development planned in the area. Depending upon results of the C1 test, perforations may also be added in the C3 sands. Production is expected to last no longer than 6 months. An Application for Sundry Approval for the temporary conversion to production will be filed today. KRU 1D-32 is a current water injector scheduled to be sidetracked as 1D-30 L1 with coiled tubing in October. Following the coiled tubing sidetrack, we plan to flow test the well and if results are encouraging, put it on production for a period expected to last no longer than 6 months. A permit to drill and an Application for Sundry Approval for the temporary conversion to production will be filed this week. Please contact me if you wish to discuss our plans for these wells or require additional detail. Regards, Brian Seitz Kuparuk CPF-1 Lead Engineer (907) 265-6961 STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION BOPE Test Report S u bm it to: Hm...fg.raQ.@ªg.E1jXU~.~ªt~~:.ft~:.~g~ aOOGc _prudhoe _bay@adrnin.statø.ak.us bob_fjeekenstein@admin.state.ak.us Contractor: NORDIC I SLB Rig No.: 2 DATE: 10/19/04 Rig Rep.: Holmes Ilgtanloc Rig Phone: 659-4398 Rig Fax: 659-4356 Operator: BPX Op. Phone: 659-4393 Op. Fax: 659-4356 Rep.: Sarber I Goodrich E-Mail SUAQWDR~GNQfmIC::TOOl.PUSH~:.R@BP. COM Well Name: Kuparuk ..0.-32[1 PTD # 204-196 Meridian: UM Location: Section: 23 Township: 11 N Range: 10E Operation: Drlg: XXX Workover: Explor.: Test: Initial: XXX Weekly: Other: Test Pressure: Rams: 400-4500 Annular: 400/4000 Valves: 400-4500 MISC. INSPECTIONS: TEST DATA FLOOR SAFETY VALVES: P/F P/F Quantity P/F Location Gen.: P Well Sign P Upper Kelly 0 Housekeeping: P Dr!. Rig P Lower Kelly 0 PTD On Location P Hazard Sec. P Ball Type 1 P Standing Order Posted P Inside BOP 0 BOP STACK: Quantity SizelType P/F 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 I 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 NIA Quantity P/F Choke Ln. Valves 1 31/8" P Inside Reel valves 1 NIA HCR Valves 2 31/8" PP Kill Line Valves 1 31/8" P ACCUMULATOR SYSTEM: Check Valve NIA Time/Pressure P/F System Pressure 3000 CHOKE MANIFOLD: Pressure After Closure 2050 Quantity P/F 200 psi Attained 21 sec No. Valves 14 PIP Full Pressure Attained 1 Min 26 sec Manual Chokes 1 P Blind Switch Covers: All stations XX Hydraulic Chokes 1 P Nitgn. Bottles (avg): 4 @ 2000 Test Results Number of Failures: º Test Time: 6.0 Hours Components tested 27 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: Hm...Œfà{!@ªº,mi.Q.,§.~ªH~:.ft~:.~g~ Remarks: There was 1.5 hours of test pump trouble during testing Distribution: 24 HOUR NOTICE GIVEN orig-Well File YES XXX NO c - Oper.lRig ¡ . . Waived By Jeff Jones c - Database Date 10/18/04 Time 07:00 c - Trip Rpt File Witness Brian Pederson c - Inspector Test start 09:00 Finish 16:30 Coil Tubing BFL 05/29/03 ..}ì~A~~~ru Nordic 2 BOP 10-19-04..xls [\ l:" .::C) ,". · ~v 1fŒ lID~ ffi~~ ,. / / FRANK H. MURKOWSKI, GOVERNOR ¡ I / I ;(c?~-/95 AIfASIiA. OIL AND GAS CONSERVATION COMMISSION ì ¡ f 333 W. 7'" AVENUE, SUITE 100 ANCHORAGE. ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Brian Seitz Kuparuk Staff Engineer ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, Alaska 99510-0360 Re: Kuparuk 1D-32L1 Sundry Number: 304-364 Dear Mr. Seitz: Enclosed is the approved Application for Sundry Approval relating to the above- referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for 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. BY ORDER OF 1JIE COMMISSION DATED this -i::2 day of October, 2004 Encl. . . RECEIVEOk/,o SEP 3 0 2004 åiIi STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVAL 20 AAC 25.280 Alter 5. Permit to Drill Number: C:;oL/ /9$0 6. API Number: 50-029-22982~ 6V 9. Well Name and Number: 10-32 L 1 10. Field/Pool(s): Kuparuk Oil Pool PRESENT WELL CONDITION SUMMARY Effective Depth rvD (ft): Plugs (measured): Junk (measured): 1. Type of Request: Change approved program 2. Operator Name: ConocoPhillips Alaska, Inc. 3. Address: P. O. Box 100360 7. KB Elevation (ft): RKB 104' 8. Property Designation: ADL 028248 11. Total depth MD (ft): 14138' Casing Total Depth rvD (ft): Effective Depth MD (ft): 6679' Length Size MD Burst 20" 117' 9-5/8" 9006' 7" 13324' 3-1/2" 14136' CONDUCTOR 117' SURF CASING 8902' PROD CASING 13220' LINER 953' Perforation Depth MD (ft): 13814-13824,13870-13880,13904-13944 Packers and SSSV Type: no packer SSSV= NIP 12. Attachments: Description Summary of Proposal Detailed Operations Program 0 BOP Sketch 14. Estimated Date for Commencing Operations: 16. Verbal Appro Commission Re Perforation Depth rvD (ft): 6535-6540,6559-6564,6574-6592 Packers and SSSV MD (ft) nd correct to the best of my knowledge. xpl 15. Well Status after Oil 0 WAG 0 after proposed work: Development 0 rk: 17. Iherebyce' Printed Name 11/01/04 Date: Signature Phone.;Jtf:)"-ó?6'ì Date 7/.z?þ Commission Use Onl Conditions of approval: Notify Commission so that a representative may witness Sundry Number: .30 4· 3(.,. Plug Integrity 0 BOP Test 0 Mechanical'ntegrity Test 0 Location Clearance 0 Other: ~\,~...:¡~\" ~~~~,,\~ ro~~~~~ ~C£\~'\)J~\\, 1:\"<,,) ~<C~"<l\'..\'-c.. \ \N~~ ~ ~"'\....~r.t.... ,fò~\ \ \, ,,~\ N..<t..-\.J \ '\.. ~ u ""\ Q\ C\ ~Ò I Q '" 'v\D ~ 0.. '-:. ~~ ~~~ ~\~~ \ OC1 Q. 7 o R I .~, ~JA , WIllIS Bfl. \ , ...~, BY ORDER OF COMMISSIONER THE COMMISSION INSTRUCTIONS ON REVERSE Approved by: Form 10-403 Revise . . KRU 1 D-32 and 1 D-32 L 1 Temporary Conversion to Production Back2round KRU ID-32 was drilled and completed as a C-sand water injector in December of 2000. A coiled tubing lateral (lD-32 Ll) is scheduled to be drilled in October of 2004 to provide additional support to recently drilled ID-30 Ll. Following the coiled tubing drilling, the well will be flowed back and tested. If test results are promising, the well will remain on production for an estimated 3-6 months, after which it will be returned to water injection service. Summarv of Operations · Move in Nordic 2 and drilllD-32 Ll per Permit to Drill dated 9/29/04 · At completion of drilling operations, flow well to tank to clean up · Conduct well test through portable test skid during flow-back period · If well is able to sustain viable production, tie into DS 1 D production facilities and produce for an estimated 3-6 months, testing periodically with portable test skid · At end of production period, return to water injection service Re: KRU ID-ll and ID-32 U: Request for waiver tram monthly testing . . Subject: Re: KRU ID-ll and ID-32 Ll: Request for waiver from monthly testing From: Thomas Maunder <tom _ maunder@admin.state.ak.us> Date: Thu, 30 Sep 200415:17:07 -0800 To: "Seitz, Brian" <Brian.Seitz@conocophillips.com> CC: jack_hartz@admin.state.ak.us, CPFl Prod Engr <nI269@conocophillips.com> Brian, Jack and I have discussed your proposal and find it acceptable. I have received the sundries for the wells and will include a copy of this email with them. Please call with any questions. Tom Maunder, PE AOGCC Seitz, Brian wrote: Tom- ConocoPhillips is evaluating the temporary conversion of two Kuparuk water injection wells, KRU ID-ll and KRU ID-32 Ll, to production. While on production, both wells will be tied into the production header. However, tying into the test header to allow for well testing through the DS-ID test facility is likely to add significant cost and delay to a project that is short term in nature. As such, we request a waiver from the monthly well testing requirement for the estimated 3-6 months that these two wells will be on production. We propose testing the wells through a temporary test skid every other month during the production period. KRU ID-ll is a current water injector perforated in only the C4 sands. We plan to perforate oil bearing Cl sands and evaluate its productivity in support of other development planned in the area. Depending upon results of the Cl test, perforations may also be added in the C3 sands. Production is expected to last no longer than 6 months. An Application for Sundry Approval for the temporary conversion to production will be filed today. KRU ID-32 is a current water injector scheduled to be sidetracked as ID-30 Ll with coiled tubing in October. Following the coiled tubing sidetrack, we plan to flow test the well and if results are encouraging, put it on production for a period expected to last no longer than 6 months. A permit to drill and an Application for Sundry Approval for the temporary conversion to production will be filed this week. Please contact me if you wish to discuss our plans for these wells or require additional detail. Regards, Brian Seitz Kuparuk CPF-l Lead Engineer (907) 265-6961 1 of 1 9/30/20043: 17 PM . ~1f~1fŒ [ID~ ~~~~~~~ . AI,ASIiA. ORAND GAS CONSERVATION COMMISSION FRANK H. MURKOWSKI, GOVERNOR 333 W. 7'" AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Lamar Gantt Drilling Engineer ConocoPhillips Alaska Inc. P.O. Box 196612 Anchorage, Alaska 99519-6612 Re: Kuparuk 1D-32L1 ConocoPhillips Alaska Inc. Permit No: 204-195 Surface Location: 417' SNL, 420' WEL, SEC. 23, T11N, RlOE, UM Bottomhole Location: 3081' SNL, 3660' EWL, SEC. 30, T11N, RIlE, UM Dear Mr. Gantt: Enclosed is the approved application for permit to redrill the above development well. The permit is for a new well bore segment of existing well KRU 1D-32, Permit No. 200-173, API No. 50-029-22982-00. Production should continue to be reported as a function of the original API number stated above. This permit to redrill does not exempt you from obtaining additional permits or approvals required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the Commission reserves the right to withdraw the permit in the event it was erroneously issued. 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. Please provide at least twenty-four (24) hours notice for a representative of the Commission to witness any required test. Contact the Commission's petroleum field inspector at (907 659- (pager). BY ORDER 0' THE COMMISSION DATED this --':2 day of October, 2004 cc: Department ofFish& Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. · STATE OF ALASKA I ALASKA dIr AND GAS CONSERVATION COM ISSION PERMIT TO DRILL 20 MC 25.005 '=CEIV~9s- SEP 2 9 2004 1 a. Type of work DDrill BRedrill rb. Current Well Class D Exploratory B Develo~9KQliOìI a ""iGQJJ:ÐI1ÐOmm D Re-Entry D Stratigraphic Test D Service D Development Gas ingle Zone 2. Operator Name: 5. Bond: 1m Blanket o Single Well 11. Well Name and r. umber:'" Conoco Phillips Alaska Inc. Bond No. U-630610 Kuparuk 1D-32L 1 3. Address: 6. Proposed Depth: ,/ 12. Field / Pool(s): c/o P.O. Box 196612, Anchorage, Alaska 99519-6612 MD 15925 ,I TVD 646255 Kuparuk River Field / Kuparuk 4a. Location of Well (Governmental Section): 7. Property Designation: River Pool Surface: ADL 028248 / 417' SNL, 420' WEL, SEC. 23, T11N, R10E, UM I Top of Productive Horizon: 8. Land Use Permit: 13. Approximate Spud Date: 2875' SNL, 1630' EWL, SEC. 30, T11N, R11E, UM October 21, 2004 Total Depth: 9. Acres in Property: 14. Distance to Nearest Property: 3081' SNL, 3660' EWL, SEC. 30, T11N, R11E, UM 2560 2605' 4b. Location of Well (State Base Plane Coordinates): 10. KB Elevation 15. Distance to Nearest Well Within Pool Surface: x-560671 -/ y- 5959249 ~ Zone- ASP4 (Height above GL): 104.45 feet 1 D-30 at 2785' .- 16. Deviated Wells: Kickoff Depth: 13810 feet / 17. Maximum Anticipated Pressures in psig (see 20 MC 25.035) Maximum Hole Angle: 96 deQrees Downhole: 3410 Surface: 2765 .f 18.Çå~ir'l9I-'rogr;am: specifications Setting.~pth ~oOºtity Size Top ·iBottom c.f. or Hole Casino Weioht Grade Couolina Lenath MD TVD MD TVD (includina staae data) 3" 2-3/8" 6.2# L-80 STL 2175' 13750' 6404' 15925' 6462' Uncemented Slotted Liner 19. PRESENTWgl..1.. CONDITION $UMMARY (To bê cornpl~ted for Rêdrill.AND Rø-entry OÞêt~tiöij$) Total Depth MD (ft): Total Depth TVD (ft): Plugs (measured): I Effective Depth MD (ft): Effective Depth TVD (ft): Junk (measured): 14138 6679 None 14101 6662 None iii " i ',:,) ii'i'iJ' ';:i iii< " Conductor 130' 20" 15 cu vds ABI, Type III 130' 130' 9005' 9-5/8" 490 sx AS III Lite, 450 sx LiteCrete 9005' 4576' Int 13324' 7" 190 sx Class 'G' 13324' 6330' Prnrh Ir.tinn Liner 953' 3-1/2" 225 sx Class 'G' 13183' -14136' 6273' - 6679' Perforation Depth MD (ft): 13814' - 13944' IPerfOration Depth TVD (ft): 6535' - 6592' 20. Attachments 1m Filing Fee, $100 1m BOP Sketch 1m Drilling Program o Time vs Depth Plot o Shallow Hazard Analysis o Property Plat o Diverter Sketch o Seabed Report 1m Drilling Fluid Program 1m 20 MC 25.050 Requirements 21. Verbal Approval: Commission Representative: Date: 22. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Lamar Gantt, 564-5593 Printed Name Lamar Gantt Title Drilling Engineer Dan Venhaus, 263-4372 ,I) f, ;f~~tß;t······· Date "/zJIIM Prepared By Name/Number: Signature );tz,V)\ l1J\ Phone 564-5593 Terrie Hubble, 564-4628 ·i,·ii; i; ........... .i' ;;i'':f/fif.,G·.;'(i.:·,:.. .ii .", .... ..... ·.,i;':~ :'. ::·..g'·:ii'i,·.·i iii: ....... Permit To D~;./"IC¡!~ API Number: W ,,DÞ q. ~") 'iYf Permit APprova~ Ii See cover letter for Number: --.s 50-029-22982~00 Date: )0 ~ ¿:;{/ other requirements Conditions of Approval: Samples Required DYes gNo Mud Log Required DYes ~No Hydrogen Sulfide Measures g¡: Y es DNo Directional Survey Required ~es DNo Oth., '-I5~ ~ \t..,. \- ú..~ """~ 6. ßO \' \«..,. \- '\~ ~'-.>û \ L \ ~ 2) ß- 't. <:;., OÇ><t."'- \0 ~:-" ú..L~C~~ \J-..) I. \. a 'd ~ . ADDCQVed B~ ~~ (' I I, I ^ I APPROVED BY loh /ð c¡ -'" THE COMMISSION Date Form 1 0-401 ~ed 061 ~04 '- '.,,...) l \ \ V \ \ \I f\ 1- S6bmÆ In D{¡plicate ssmn .RU 1 D-32L 1 Sidetrack - Coiled TuA Drilling Summary of Operations: Coiled tubing drilling will sidetrack KRU ID-32 using Dynamically Overbalanced pressure drilling technique (DOBCTD, see description below). This horizontal lateral will target Kuparuk C sand reserves for injection. The Kuparuk C Sand perforations in the existing well, ID-32 will be retained allowing injection past the /" whipstock. CTD Drill and Complete ID-32Ll pr02ram: Planned for Oct 21. 2004 1. Pre CTD MIT-IA, MIT-OA 2. Pre CTD Caliper 3-1/2" liner 3. Pre CTD install mechanical whipstock at approx 13810' 4. MIRU Nordic 2. NU 7-1/16" BOPE, test. 5. Mill window at 13810' md and 10' of openhole. 6. Drill 3" bicenter hole horizontal sidetrack from window to -15925' TD targeting Kuparuk C sand interval. 7. Complete with 2 3/8" pre-drilled liner from TD 15925', up into the 3-1/2" liner to -13750 ' . 8. Post CTD rig -Run GL Vs. Perform short-term production test prior to injection service. Mud Program: · Step 5: 8.7 ppg Potassium-Formate biozan brine · Step 6: Potassium-Formate based Flo-Pro (8.7 ppg) · Step 7: Viscosified sodium bromide KWF (10.6 ppg) Disposal: · No annular injection on this well. · Class II liquids to KRU lR Pad Class II disposal well · Class II drill solids to Grind & Inject at PBU Drillsite 4 · Class I wastes will go to Pad 3 for disposal. Casing Program: · ID-32Ll: 23/8",6.2#, L-80, STL slotted liner from 13750' md to 15925' md Well Control: · Two well bore volumes (-280 bbls) of KWF will be on location during drilling operations. · BOP diagram is attached. · Pipe rams, blind rams and the CT pack off will be pressure tested to 400 psi and to 4500 psi. · The annular preventer will be tested to 400 psi and 2500 psi. Directional · See attached directional plans for ID-32Ll · Magnetic and inclination surveys will be taken every 30 ft. No gyro will be run. · The nearest well to ID-32Ll is ID-30, which is offset by 2785'. · ID-32 is approx. 2605' from the KRU boundary. Logging · A MWD Gamma Ray will be the only log run. .RU 1 D-32L 1 Sidetrack - Coiled TuA Drilling Hazards · No mapped faults in the planned well path; lost circulation risk is medium based on C sand drilling results this year. · Mechanically weak shales will require DOCTD to maintain constant bottom hole pressure. · Well1D-32 has a H2S reading of 20 ppm. 1D is an H2S pad, the highest H2S measurement on the pad is 120ppm. All H2S monitoring equipment will be operational. Reservoir Pressure ./ · The latest Shut in bottom hole pressure is approx. 3410 psi at 6450' TVD, 10.2 ppg EMW. Max. surface pressure with gas (0.1 psi/ft) to surface is 2765 psi. I Managed Pressure Drilling Dynamically overbalanced pressure drilling (DOBCTD) techniques will be employed to provide constant bottom hole pressure by using 8.7 ppg drilling fluid in combination with annular friction losses and applied surface pressure. Constant BHP will be utilized to reduce pressure fluctuations on mechanically weak shales. In addition the heavier equivalent mud weight is expected to help with shale stability. A hydraulic choke for regulating surface 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. Pressure deployment of the BHA will be accomplished utilizing the BOP pipe/slips (2" rams, see attached BOP configuration). This well does not have a tubing retrievable sub-surface safety valve. The annular preventer will act as a secondary containment during deployment and not as a stripper. Estimated reservoir pressure: 3410 psi at 6450' TVD, 10.2 ppg EMW. Expected annular friction losses while circulating: 1100 psi Planned mud density: 8.7 ppg equates to 2918 psi hydrostatic bottom hole pressure. While circulating 8.7 ppg fluid, bottom hole circulating pressure is estimated to be 4000 psi or 11.9 ppg ECD When circulation is stopped, a minimum of 1100 psi surface pressure will be applied to maintain constant BHP. Operating parameters and fluid densities will be adjusted based on real-time bottom hole pressure measurements while drilling and shale behavior. The production liner will be deployed by swapping the well bore to the KWF that not only overbalances the well but is found to work best with the exposed shales during the drilling operation (minimum weight = 10.6 ppg for overbalance) PHILLIPSi Alaska, Inc. A Subsidiary of PHILliPS PETROLEUM COMPANY Gas Lift landrel/Dummy Valve 1 (523<Þ5231, OD:5.968) NIP (13172-13173, OD:3.500) PACKER - (13190..13191, OD:7.ooo) SBE (13210..13211, OD:6.ooo) SEAL (13218-13219, OD:4.0oo) NIP (13268-13269, 00:3.500) HPBD (13814-13944) Perf (13870..13880) Perf (13904-13944) LINER (13183-14136, 00:3.500, Wt:9.30) KRU 1 D..32 10 2.875 2.812 5.000 4.000 3.000 2.750 0.000 KRU 1D-32L 1 Injector Proposed Completion 9-5/S" 40# L·SO @ 9006" 7" 26# J-5S @ 13324 MD' Window in 3-1/2" KOP at 13810' MD / 3·y,," Flow-thru whipstock 3-112" 9.3# L-SO @14136MD' 2-3/8" liner top @ +1-13750' MD o 0 o 0 Fill E. 3-1/2" Cameo DS nipple, 2.875" min 10 at 533' MD D.3-1/2" 9.3# L-80 EUE 8rd Mod Tubing with MMG mandrels C. 3-W Cameo DS nipple, 2.813" min ID @ 13172' MD B. Baker ZXP liner top paekerlSBE/seal assembly at 13190' MD A. 3-W Cameo D nipple, 2.75" min ID at 13268' MD o o 0 0 o 0 0 o o o o o o o 0 o 0 o o o o o o o o o o o 2-3/8" pre-drilled liner, 8 holes/ft, 3/8" hole size C3/C2 - Sand eonoc6Phillips Alaska, Inc. . e C3/C2 Lateral, TD @ 15925' md 1/ o o o 0 0 o o o o 4) 4) o o o o 4) o DEV 9/23/04 . . ... ..... INTEQ BP-GDB Baker Hughes INTEQ Planning Report Field: Kuparuk River Unit North Slope UNITED STATES Map System:US State Plane Coordinate System 1927 Goo Datum: NAD27 (Clarke 1866) Sys Datum: Mean Sea Level Map Zone: Coordinate System: Geomagnetie Model: Alaska, Zòne 4 Well Centre bggm2004 Site: KRU 10 Pad UNITED STATES: North Slope Site Position: Northing: From: Map Easting: Position Uncertainty: 0.00 ft Ground Level: 0.00 ft 5959249.42 ft 560670.61 ft Latitude: 70 17 Longitude: 149 30 North Reference: Grid Convergenee: 57.217 N 31.143 W True 0.46 deg WelI: 10-32 1 D-32 WelI Position: +N/-S +E/-W Position Uncertainty: Slot Name: 0.00 ft Northing: 0.00 ft Easting : 0.00 ft 5959249.42 ft -/ Latitude: 560670.61 ft" Longitude: 70 17 57.217 N 149 30 31.143 W WeIlpath: Plan#1 1 D-32L 1 500292298260 Current Datum: 10-32 Magnetic Data: 9/23/2004 Field Strength: 57577 nT Vertical Section: Depth From (TVD) ft 0.00 Targets DrilIed From: Tie-on Depth: Above System Datum: Declination: Mag Dip Angle: +E/-W ft 0.00 10-32 13768.22 ft Mean Sea Level 24.64 deg 80.75 deg Direction deg 130.28 Height 104.45 ft +N/-S ft 0.00 1D-32L1 T1.1 6443.00 -7811.63 7458.28 5951499.00 568191.00 70 16 40.354 N 149 26 53.946 W 1O-32L 1 T1.6 6462.00 -7926.01 9360.61 5951400.00 570094.00 70 16 39.208 N 149 2558.552 W 1 D-32L1 T1.2 6474.00 -7911.02 7875.54 5951403.00 568609.00 70 16 39.372 N 149 2641.798 W 1O-32L 1 T1.5 6482.00 -7920.01 8741.57 5951401.00 569475.00 70 16 39.274 N 149 26 16.578 W 1O-32L 1 T1.3 6492.00 -7913.28 8155.55 5951403.00 568889.00 70 16 39.347 N 149 26 33.644 W 1O-32L1 T1.4 6496.00 -7916.60 8443.56 5951402.00 569177.00 70 16 39.311 N 149 2625.257 W Annotation 13768.22 13810.00 13825.00 13865.00 14001.00 14136.00 14286.00 14411.00 14486.00 14706.00 14976.00 15276.00 15596.00 15925.00 6411.55 6429.17 6435.39 6449.70 6473.45 6477.50 6481.53 6484.73 6486.60 6491.86 6496.24 6481.47 6463.33 6461.96 TIP KOP End 9 DLS I Begin 22 DLS 4 5 End 22 DLS I Begin 12 DLS 7 8 9 10 11 12 13 TO . . 8.. ..... INTßQ BP-GDB Baker Hughes INTEQ Planning Report 13768.22 65.24 148.86 6411.55 -7709.08 7321.02 0.00 0.00 0.00 0.00 13810.00 64.87 148.81 6429.17 -7741.50 7340.62 0.89 -0.89 -0.12 186.98 13825.00 66.14 148.31 6435.39 -7753.14 7347.74 9.00 8.46 -3.37 -20.00 13865.00 71.95 141.22 6449.70 -7783.59 7369.30 22.00 14.53 -17.70 -50.00 14001.00 88.20 115.62 6473.45 -7865.25 7473.45 22.00 11.95 -18.83 -60.00 14136.00 88.44 85.91 6477.50 -7890.16 7604.54 22.00 0.18 -22.01 -90.00 14286.00 88.51 103.91 6481.53 -7902.95 7753.32 12.00 0.05 12.00 90.00 14411.00 88.56 88.91 6484.73 -7916.86 7877.14 12.00 0.04 -12.00 -90.00 14486.00 88.58 79.91 6486.60 -7909.56 7951.69 12.00 0.02 -12.00 -90.00 14706.00 88.73 106.31 6491.86 -7921.39 8169.36 12.00 0.07 12.00 90.00 14976.00 89.46 73.92 6496.24 -7921.92 8435.74 12.00 0.27 -12.00 -89.00 15276.00 96.00 109.38 6481.47 -7930.14 8730.35 12.00 2.18 11.82 79.00 15596.00 90.26 71.34 6463.33 -7931.80 9043.86 12.00 -1.79 -11.89 -97.20 15925.00 90.20 110.82 6461.96 -7937.86 9366.33 12.00 -0.02 12.00 90.00 13844.95 69.00 144.71 6443.00 -7768.51 7357.92 5951541.31 568090.30 10635.86 22.00 310.00 1D-32L1 13850.00 69.74 143.82 6444.78 -7772.35 7360.68 5951537.49 568093.09 10640.44 22.00 311.37 MWD 13865.00 71.95 141.22 6449.70 -7783.59 7369.30 5951526.32 568101.80 10654.29 22.00 311.69 4 13875.00 73.06 139.23 6452.71 -7790.92 7375.40 5951519.04 568107.96 10663.68 22.00 300.00 MWD 13900.00 75.92 134.35 6459.40 -7808.47 7391.89 5951501.63 568124.59 10687.61 22.00 300.60 MWD 13911.21 77.23 132.21 6462.00 -7815.94 7399.83 5951494.22 568132.59 10698.49 22.00 301.90 1 D-32L 1 13925.00 78.87 129.60 6464.86 -7824.77 7410.03 5951485.47 568142.86 10711.98 22.00 302.40 MWD 13950.00 81.89 124.94 6469.04 -7839.69 7429.64 5951470.72 568162.58 10736.59 22.00 302.94 MWD 13975.00 84.97 120.35 6471.90 -7853.08 7450.55 5951457.50 568183.60 10761.19 22.00 303.72 MWD 14000.00 88.08 115.80 6473.41 -7864.81 7472.56 5951445.94 568205.70 10785.57 22.00 304.25 MWD 14001.00 88.20 115.62 6473.45 -7865.25 7473.46 5951445.52 568206.60 10786.54 21.91 304.53 5 14025.00 88.21 110.34 6474.20 -7874.61 7495.53 5951436.33 568228.75 10809.44 22.00 270.00 MWD 14050.00 88.23 104.83 6474.98 -7882.15 7519.34 5951428.98 568252.62 10832.48 22.00 270.17 MWD 14075.00 88.27 99.33 6475.74 -7887.38 7543.77 5951423.95 568277.09 10854.49 22.00 270.34 MWD 14100.00 88.33 93.83 6476.48 -7890.25 7568.58 5951421.29 568301.92 10875.28 22.00 270.50 MWD 14125.00 88.40 88.33 6477.20 -7890.72 7593.56 5951421.02 568326.90 10894.63 22.00 270.67 MWD 14136.00 88.44 85.91 6477.50 -7890.16 7604.54 5951421.66 568337.87 10902.65 22.00 270.83 End 22 14150.00 88.44 87.59 6477.88 -7889.37 7618.51 5951422.57 568351.84 10912.80 12.00 90.00 MWD 14175.00 88.44 90.59 6478.56 -7888.97 7643.50 5951423.17 568376.81 10931.60 12.00 89.95 MWD 14200.00 88.45 93.59 6479.24 -7889.88 7668.47 5951422.46 568401.79 10951.24 12.00 89.87 MWD 14225.00 88.46 96.59 6479.91 -7892.10 7693.36 5951420.44 568426.69 10971.66 12.00 89.79 MWD 14250.00 88.48 99.59 6480.58 -7895.62 7718.10 5951417.12 568451.46 10992.81 12.00 89.71 MWD 14275.00 88.50 102.59 6481.24 -7900.43 7742.62 5951412.51 568476.02 11014.63 12.00 89.63 MWD 14286.00 88.51 103.91 6481.53 -7902.95 7753.32 5951410.08 568486.73 11024.42 12.00 89.55 7 14300.00 88.51 102.23 6481.89 -7906.11 7766.96 5951407.02 568500.39 11036.87 12.00 270.00 MWD 14325.00 88.52 99.23 6482.54 -7910.77 7791.51 5951402.57 568524.98 11058.61 12.00 270.04 MWD 14350.00 88.53 96.23 6483.18 -7914.13 7816.27 5951399.41 568549.77 11079.67 12.00 270.12 MWD 14375.00 88.54 93.23 6483.82 -7916.19 7841.17 5951397.55 568574.68 11100.00 12.00 270.20 MWD 14400.00 88.56 90.23 6484.46 -7916.94 7866.15 5951397.00 568599.66 11119.54 12.00 270.28 MWD . . ... ..... INTEQ BP..GDB Baker Hughes INTEQ Planning Report 14411.00 88.56 88.91 6484.73 -7916.86 7877.14 5951397.17 568610.65 11127.88 12.00 270.35 8 14425.00 88.56 87.23 6485.08 -7916.39 7891.13 5951397.75 568624.64 11138.24 12.00 270.00 MWD 14450.00 88.57 84.23 6485.71 -7914.53 7916.05 5951399.82 568649.54 11156.05 12.00 270.04 MWD 14475.00 88.58 81.23 6486.33 -7911.36 7940.84 5951403.18 568674.30 11172.92 12.00 270.12 MWD 14486.00 88.58 79.91 6486.60 -7909.56 7951.69 5951405.07 568685.13 11180.02 12.00 270.19 9 14500.00 88.58 81.59 6486.95 -7907.31 7965.50 5951407.43 568698.92 11189.11 12.00 90.00 MWD 14525.00 88.59 84.59 6487.57 -7904.30 7990.31 5951410.64 568723.71 11206.09 12.00 89.96 MWD 14550.00 88.59 87.59 6488.18 -7902.60 8015.24 5951412.54 568748.62 11224.01 12.00 89.88 MWD 14575.00 88.61 90.59 6488.80 -7902.20 8040.23 5951413.14 568773.60 11242.81 12.00 89.81 MWD 14600.00 88.62 93.59 6489.40 -7903.11 8065.20 5951412.43 568798.58 11262.45 12.00 89.74 MWD 14625.00 88.64 96.59 6490.00 -7905.33 8090.09 5951410.42 568823.48 11282.88 12.00 89.66 MWD 14650.00 88.66 99.59 6490.59 -7908.85 8114.83 5951407.10 568848.25 11304.03 12.00 89.59 MWD 14675.00 88.69 102.59 6491.16 -7913.66 8139.36 5951402.49 568872.81 11325.84 12.00 89.52 MWD 14700.00 88.72 105.59 6491.73 -7919.74 8163.60 5951396.60 568897.09 11348.27 12.00 89.45 MWD 14706.00 88.73 106.31 6491.86 -7921.39 8169.36 5951395.00 568902.87 11353.73 12.00 89.39 10 14725.00 88.77 104.03 6492.28 -7926.36 8187.70 5951390.18 568921.24 11370.94 12.00 271.00 MWD 14750.00 88.83 101.03 6492.80 -7931.78 8212.09 5951384.95 568945.68 11393.05 12.00 271.05 MWD 14775.00 88.89 98.03 6493.30 -7935.92 8236.74 5951381.01 568970.36 11414.53 12.00 271.11 MWD 14800.00 88.95 95.03 6493.77 -7938.77 8261.57 5951378.37 568995.21 11435.31 12.00 271.17 MWD 14825.00 89.02 92.03 6494.21 -7940.31 8286.51 5951377.03 569020.16 11455.34 12.00 271.23 MWD 14850.00 89.08 89.03 6494.63 -7940.54 8311.51 5951377.00 569045.15 11474.56 12.00 271.28 MWD 14875.00 89.15 86.03 6495.01 -7939.46 8336.48 5951378.28 569070.11 11492.91 12.00 271.33 MWD 14900.00 89.23 83.03 6495.37 -7937.08 8361.36 5951380.86 569094.97 11510.35 12.00 271.38 MWD 14925.00 89.30 80.04 6495.69 -7933.40 8386.08 5951384.74 569119.66 11526.83 12.00 271.42 MWD 14950.00 89.38 77.04 6495.97 -7928.44 8410.58 5951389.90 569144.12 11542.31 12.00 271 .46 MWD 14975.00 89.46 74.04 6496.23 -7922.19 8434.78 5951396.34 569168.27 11556.74 12.00 271.49 MWD 14976.00 89.46 73.92 6496.24 -7921.92 8435.74 5951396.62 569169.22 11557.29 11.95 271.52 11 15000.00 90.01 76.74 6496.35 -7915.84 8458.96 5951402.89 569192.39 11571.07 12.00 79.00 MWD 15025.00 90.59 79.69 6496.22 -7910.73 8483.43 5951408.19 569216.81 11586.44 12.00 78.99 MWD 15050.00 91.16 82.64 6495.84 -7906.89 8508.13 5951412.23 569241.48 11602.80 12.00 79.00 MWD 15075.00 91.73 85.58 6495.21 -7904.33 8532.98 5951414.99 569266.31 11620.11 12.00 79.05 MWD 15100.00 92.29 88.53 6494.33 -7903.05 8557.93 5951416.48 569291.24 11638.31 12.00 79.12 MWD 15125.00 92.85 91.48 6493.21 -7903.05 8582.90 5951416.68 569316.21 11657.36 12.00 79.22 MWD 15150.00 93.40 94.43 6491.85 -7904.34 8607.83 5951415.59 569341.15 11677.21 12.00 79.36 MWD 15175.00 93.94 97.39 6490.25 -7906.91 8632.64 5951413.22 569365.98 11697.80 12.00 79.52 MWD 15200.00 94.47 100.35 6488.42 -7910.75 8657.28 5951409.58 569390.64 11719.08 12.00 79.71 MWD 15225.00 94.99 103.32 6486.36 -7915.86 8681.66 5951404.66 569415.06 11740.98 12.00 79.92 MWD 15250.00 95.49 106.29 6484.07 -7922.22 8705.73 5951398.50 569439.17 11763.45 12.00 80.17 MWD 15275.00 95.98 109.26 6481.57 -7929.81 8729.41 5951391.10 569462.92 11786.43 12.00 80.44 MWD 15276.00 96.00 109.38 6481.47 -7930.14 8730.35 5951390.78 569463.86 11787.36 11.95 80.74 12 15300.00 95.63 106.51 6479.03 -7937.49 8753.06 5951383.61 569486.63 11809.44 12.00 262.80 MWD 15325.00 95.24 103.52 6476.67 -7943.94 8777.10 5951377.36 569510.71 11831.95 12.00 262.51 MWD 15350.00 94.82 100.54 6474.47 -7949.13 8801.45 5951372.36 569535.10 11853.88 12.00 262.23 MWD 15375.00 94.40 97.56 6472.46 -7953.05 8826.06 5951368.65 569559.74 11875.18 12.00 261.96 MWD 15400.00 93.96 94.58 6470.64 -7955.68 8850.85 5951366.21 569584.55 11895.80 12.00 261.72 MWD 15425.00 93.51 91.61 6469.01 -7957.03 8875.76 5951365.06 569609.46 11915.67 12.00 261.51 MWD 15450.00 93.05 88.64 6467.58 -7957.09 8900.71 5951365.21 569634.42 11934.75 12.00 261.31 MWD 15475.00 92.59 85.67 6466.35 -7955.85 8925.65 5951366.65 569659.34 11952.97 12.00 261.14 MWD 15500.00 92.12 82.71 6465.33 -7953.32 8950.50 5951369.38 569684.16 11970.29 12.00 261.00 MWD 15525.00 91.64 79.74 6464.51 -7949.51 8975.19 5951373.39 569708.82 11986.67 12.00 260.88 MWD 15550.00 91.15 76.78 6463.90 -7944.43 8999.65 5951378.67 569733.24 12002.04 12.00 260.78 MWD 15575.00 90.67 73.82 6463.50 -7938.08 9023.83 5951385.20 569757.37 12016.39 12.00 260.71 MWD . . ... ..... INTRQ BP-GDB Baker Hughes INTEQ Planning Report 15596.00 90.26 71.34 6463.33 -7931.80 9043.86 5951391.65 569777.34 12027.61 12.00 260.66 13 15600.00 90.26 71.82 6463.31 -793Q.53 9047.66 5951392.95 569781.13 12029.69 12.00 90.00 MWD 15625.00 90.26 74.82 6463.20 -7923.36 9071.60 5951400.31 569805.01 12043.31 12.00 90.00 MWD 15650.00 90.26 77.82 6463.09 -7917.44 9095.89 5951406.42 569829.25 12058.02 12.00 90.02 MWD 15675.00 90.26 80.82 6462.97 -7912.81 9120.46 5951411.25 569853.77 12073.76 12.00 90.03 MWD 15700.00 90.25 83.82 6462.86 -7909.47 9145.23 5951414.80 569878.52 12090.50 12.00 90.04 MWD 15725.00 90.25 86.82 6462.75 -7907.43 9170.14 5951417.04 569903.41 12108.19 12.00 90.06 MWD 15750.00 90.25 89.82 6462.65 -7906.69 9195.13 5951417.97 569928.39 12126.77 12.00 90.07 MWD 15775.00 90.24 92.82 6462.54 -7907.27 9220.12 5951417.60 569953.38 12146.21 12.00 90.08 MWD 15800.00 90.24 95.82 6462.43 -7909.15 9245.04 5951415.92 569978.32 12166.44 12.00 90.09 MWD 15825.00 90.23 98.82 6462.33 -7912.33 9269.84 5951412.94 570003.13 12187.41 12.00 90.11 MWD 15850.00 90.22 101.82 6462.23 -7916.81 9294.43 5951408.66 570027.76 12209.07 12.00 90.12 MWD 15875.00 90.22 104.82 6462.14 -7922.57 9318.75 5951403.10 570052.13 12231.35 12.00 90.13 MWD 15900.00 90.21 107.82 6462.05 -7929.59 9342.74 5951396.27 570076.17 12254.19 12.00 90.14 MWD ,/15925.00 90.20 110.82 6461.96 .,. -7937.86 9366.33 5951388.19 570099.82 12277.53 12.00 90.15 TO P!an: Plan #1 (1D~32¡P!an#11D"32L Created By: Srij Potois Date: 9/23f2004 Alaska, Inc. Pf«1I#1 10.321:,,, .sð02:In"Ueo Par.ntWellpatb: 10.32 T~ Oft MO: 13161,22 ...' Nordk:2 Ref, Datmn~ '/1).32: 104.4S1't V.s.ction 0.:i$~ ~œ: ~::~ Ana'· 130.2$' (1.00 .... .... REFERENCE INFORMATION -." ,2. th "en .at 'eo DE) -.0 ¡ ,th r. - - .. T&gM ., ., :~ ., :~ :~ ., ;'1 ., ., ~7 - I. st>¡¡pci u if 7900 81008200 8400 8500 8600 8700 West(-)/East(+)[1 OOftlin] [50ft/in] BOP-Tree Well Rig Floor I I Swab Valve I Tree Size I ! SSV I Master Valve . . , Base Flange I Page 1 KRU 1 1 1..INJ Proposed 2041950 TERRIE L HUBBLE BP EXPLORATION AK INC PO BOX 196612 MB 7-5 ANCHORAGE, AK 99519-6612 89-6/1252 152 "Mastercard Check" DATE_OC" ~ 9~()y Cc-- $ IOD. vO . First ational Bank Alaska Anchorage, AK 99501 MEMO \D<3^-LI ~J1~ I: ~ 25 2000(;OI:qq ~l.lIq; 2 2 711' ~ 5 5(;11- 0 ~ 52 . . . TRANSMIT AL LETTER CHECK LIST CIRCLE APPROPRlA TE LETTER/P ARAGRAPHS TO BE INCLUDED IN TRANSMITTAL LETTER WELL NAME /l1/-J¡¿ I ])-3Z L( Z-Dcf ~ /9Ç- PTD# /Development V Service Exploration Stratigraphic CHECK WBA T ADD-ONS ~'CLUEn APPLIES (OPTIONS) M1JLTI Tbe permit is for a new wellboresegment of LATERAL existing well j(Æt( I f) -:- 32- v/. Permit No,-z.a:::>-t73 API No. ~D-tJ21-Z?-782--:;: (If API number fr~~UttUl sbould continue to be reponed as last two. (2) digits ¡f%~ )00 of tbe original API number_ stated are between 60-69) above. PILOT HOLE In accordance witb 20 AAC 25.005(1), aU (PH) records, data and logs acquired for tbe pilot bole must be dearly differentiated In botb name (name on permit plus PH) .' and API Dumber (SO - 70/80) from records, data and logs acquired for well (name on permit). SPACING Tbe permit is approved subject ·to fuD EXCEPTION compliance witb 20 AAC 25._0SS~ Approval to perforate and produce is contingent upon issuance of ~ conservation order approving a spacing e:J cepdon. (Company Name) Bssumes tbe liability of Bny pro1 est to tbe spacing . ex ception tbat may occur. DRY DITCH All dry ditch sample sets submitted to tbe SAMPLE Commission must be in no greater ·than 30' sample intervals from below tbe permafrost or from where samples are first caught and ] 0' sample iIiter:vals through target zones. ~ Field & Pool KUPARUK RIVER, KUPARUK RV OIL - 490100 Well Name: KUPARUK RIV UNIT 1 D-32L 1 Program SER PTD#: 2041950 Company CONOCOPHILLlPS ALASKA INC Initial ClasslType SER I PEND GeoArea 890 Unit 11160 On/Off Shore On 1 PJ3rmitfee attache_d _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _NA _ Multilélte(al welLsegment; Jeewajved per 20 MC _25.005(e). _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ 2 LeaSJ3n!Jmberappropriate_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ YJ3S _ _ Surface location in ADL 25650. passes_through ADL25661; top prod int 8< TD in AOL_2_8248 3 _U_niq!Je well_n_arnJ3_and lJumb_er _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ YJ3S _ _ _ _ _ _ _ _ _ _ _ . _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ 4 WeUlocatJ3d In_a_define~_poo'- _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ YJ3S _ _ _ _ Kup_arul< Rjve( Qil Pool. governJ3d by Conseryation Ord_er No. 4326 _ _ _ _ _ _ _ _ _ _ _ _ _ _ 5 WelUocatJ3d pr_operdistance_ from drUling unitbo!Jnd_ary_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes _ _ _ _ WelJ lies witbin boundary ofKRU" buto!Jtside ofKup PA; confo(T1Js to propertyJine set bélck, 6 WelllocatJ3d proper _distance_ from otber welJs_ _ _ _ _ _ _ _ _ _ _ _YJ3S _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ 7 _S_u{ficientacreageaYailable in_drilling unit _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ 8 Itdeviated, js wellbore pléltincJu_ded _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ YJ3$ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ 9 _Qpe(ator Only affected party _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ YJ3S _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ 10 _Ope(ator bas_approprlate_b.ond inJorce. _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _YJ3$ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ . _ _ _ _ _ _ _ _ _ _ _ . _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ 11 PJ3(1T!it can be issued witbout co_nservation order _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ YJ3S _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Appr Date 12 PJ3rmit ~n be issued witbout éldministratÏ\le_approval _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ YJ3$ _ _ _ _ _ _ _ - _ _ _ _ _ - SFD 9/30/2004 13 Can permit be approved before 15-day wait Yes 14 We.IUocatJ3dwithinareaélndstrélta_authorizedby_lnjectionOrdJ3r#(P!JUO#in_comrnents>-(For_ Yes_ArJ3é1lnjectio_n_Qrde.rNo._2B_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ __ 15 _AJlweIJs_withinJl4_mile_area_oJreyiewidJ3ntlfied(Forservj~well only). _ _ _ _ _ _ _ _ _ _ _ _ _ _ YJ3$_ _ _ _ _ _ _NONI;_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ __ 16 Pre-produ_ced injector; ~urationof pre-pro~uction lJ3sS than:3 mOntbs_ (For_service well onJy) _ YJ3S _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ 17 _ACMPFïndjng.of Consistency_h_as beenJss!Jed forJbis pr_oject _ _ _ _ _ _ _ _ _NA _ _ _ _ _ _ WelJ drilled from exjsting pad, _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Administration Engineering Appr Date TEM 10/5/2004 tr~ð (ç Geology Appr SFD Date 9/30/2004 Geologic Commissioner: f)/S Well bore seg Annular Disposal - - - - - -- - - - - - - 18 "C.onductor string_provided _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ NA _ _ _ _ _ Conductor JnstaJled_ in rn_othe(bore. 1Q-32_. _ _ _ 19S_urfaceCélsing_pJotects all known_ USDWs _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _NA _ _ _ _ _ _ All aquiJe.rs exemptJ3d,AOCFR1<47.1021b)(3). 20 _CMTvoladequ_ateJocirc_ulate_oncOnd_uctor_&suJfcsg _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _NA _ _Surfacecasingsetjn_motberbore. _ _ _ _ _ _ __ 21 _CMT v_ol adequateJo tie-in long _string tosur1 csg_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ NA _ Production_ ~sing set In_mothe_rbore. _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ 22 _CMTwilJ coyer_alll<nown_pro_ductiye bori~on_s_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ No_ _ _ _ _ _ _ Slotte_dlinercompletlon planned. _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ 23 _Casing de_signs éldeQua_te for C,T" B _&_ permafr_ost _ _ _ _ _ _ _ _ _ _ _ Yes _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ . _ _ _ _ _ _ _ _ 24 Adequatetankélge_ orre_serye pit _ _ _ _ _ _ _ _ _ YJ3S _ _ _ _ _ _ _ Rig is e_quippe_dwith steelpits. _ No rese_rve_pjtplanne_d, All wç¡ste to_approve~_annulusor disposal WJ3lJs_. _ _ 25 ltaJe-drill, has_a 10A03 Jor abandonment been ç¡PPJoved _ _ _ _ _ _ _ _ _ _ _NA _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ . _ _ _ _ _ _ _ _ _ _ _ _ _ 26 A~equate_wellbore sepélratio_n_proposed _ _ _ _ _ . _ _ _ _ _ _ _ _ _ _ _ . _ _ _ _ _ _ . . . _ _ _ _ _ _YJ3$. _ _ _ . . . Prpximity- analysis perto(lT!e_d, Neélrest welJ segrnenUs origlnç¡lwellbore beJow, .Lateral diveJges._ _ _ _ _ _ _ _ . _ _ 27 Ifdiverter Jeq_uired, does itmeet regulations_ _ _ _ _ _ _ _ _ _ _ _ _ NA _ BOP willalrea~y be in place. _ _ _ _ _ _ _ _ _ . . _ _ _ _ . . _ _ _ _ _ _ _ . _ _ _ _ _ _ _ _ 28 _DJilling fluid prQgram schem¡;¡tlc& eq,uip listadequate _ _ . . _ _ _ _ _ . _ _ _ _ . _ _ Yes _ _ _ 61:1P expected aU O.2EMW. _ Pléln to _use dynélmic oveJbaJanœ with_ 8. 'Z ppgfl!Jid _and aoo psLon surface. 29 BOPEs,_d_othey meeIJeguJation _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ . . _ _ _ _ _ _ _ _ _ _ _ Yes _ _.. _ _ _ _ _ _ _ _ _ _ . _ _ _ _ _ _ . . 30 _BOPEpressrating appropriate;teslto_(put psig in_commentS). _ _ _ .. _ _ _ _ . _ _ _ _Ye$. . _ Reservor_MASP caJculated _at 27ß5 psi._ MASP circ_ulating4_00Q psL4500 psi BOP_test ploll1ned. 31 _C_hokemanjfold complies w/API RP-5:3 (May 84). _ _ . _ _ _ _ _ _ _ _ _ _ Yes _ . _ _ _ _ _ _ _ _ _ _ _ . . _ . . _ _ _ _ _ . . _ . _ _ _ . _ . _ _ _ _ _ . _ _ . . _ _ _ _ 32 Work will occ_ur withoutoperç¡tionshutdown _ _ _ . . _ _ _ _ _ Yes _ _ _ _ _ _ _ _ _ . _ _ _ _ _ . _ _ _ _ _ . _ _ _ _ _ . _ _ _ _ _ _ _ . _ . _ _ _ _ . _ _ _ _ 33 Is presence_of H2S gas_prob.able _ _ _ . _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ YJ3S WelJs_proxima_te in reservoir have H2S._ Mud should preclude_H2.S.0_n.rig.. Rig_has sensors ç¡ndalarms._ 34 Mecba_nicç¡lcondJtlonpf wells within AOR yeriJied (for_s_ervice welJ only). . _ _ _ _ . _ _ YJ3$ _ _ _ No wells wjtbin 1/<4 mile. _ . . _ _ _ _ . . _ _ _ _ _ - - - - - - - - - - - -- - - - - - - 35 Pe(lT!it can be issued w/o hyd(ogen_ s_ulfide measures. 36 _D_ata_presented on_ pote.ntial oveJpressure _ZOnes _ _ _ _ 37 .SJ3ismlc_an¡;¡lysjs of sballow gas_zPne.s _ _ _ _ _ _ _ _ _ _ _ _ _ 38 _SJ3é1bedcondjtiPn survey lit off-shore) . _ _ _ . _ _ _ _ _ _ _ _ _ _ _ _ . 39 . Conta_ct namelphoneJorweekly progress.report$ [explorç¡toryonIYl _ _ _ _ _ _ _ _ . No _ _ _ _ WelJ 10-30 (1_miN) rneélsured_70ppmH2S;_weJI1J-03 (1miSW)_measured_110ppm._ _ . _ _ _ _ _ . _ _ _ YJ3$ . _ . _ _ _ _ I;¡çpected reservoir pre_S$UJe is 10.2 ppg I;MW; will be drilled using_dYnamicaJly _ _ _ _ _ _ _ _ _ _ _ _ _ . _ _ _ _ _ _ _ _ _ _ _ _ _NA ov_erbç¡lanced coilJ3d tubing d(illing, _ . _ _ _ _ . . _ _ _ _ _ _ _ _ _ _ _ _ . _ _ _ _ . _ _ _ NA.. _ _ _ _ _ _ _. _ _ _ _ _. _ _ _ _ _ _ _ _ _. _ _. _ _ _ _ _ _ _ _ _ _ _ _.. _ _ __ _ _ NA_ _ _.. _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _. _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ __ - - - - - - - - - - - - - -- - - - - - -- Date: Engineering Commissioner: /~/ð)C Date Date lo/Sf<¡-. ~ D . . e e Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically organize this category of information. . . **** REEL HEADER **** MWD 06/04/06 BHI 01 f \)113 LIS Customer Format Tape **** TAPE HEADER **** MWD 04/10/29 776011 01 2.375" CTK *** LIS COMMENT RECORD ! ! ! !! ! ! ! !! ! ! ! ! ! ! ! ! ! !!! ! ! !! !!!!!!!!!!! ! -Version Information VERSo WRAP. ~We11 Information Block #MNEM.UNIT Data Type #--------- ------------- STRT.FT 13832.0000: STOP.FT 15062.0000: STEP.FT 0.5000: NULL. -999.2500: COMPo COMPANY: WELL. WELL: FLD . FIELD: LOC . LOCATION: CNTY. COUNTY: STAT. STATE: SRVC. SERVICE COMPANY: TOOL. TOOL NAME & TYPE: DATE. LOG DATE: API . API NYUMBER: -Parameter Information Block #MNEM.UNIT Value #--------- ------------------------- *** Remark File Version 1.000 Extract File: ldwg.las 1. 20: NO: CWLS log ASCII Standard -VERSION 1.20 One line per frame Information ------------------------------- Starting Depth Ending Depth Level Spacing Absent Value ConocoPhillips Alaska Inc. 1D-32L1PB1 Kuparuk River Unit 70 deg 17' 57.217"N 149 deg 30' 31.143"W North Slope Alaska Baker Hughes INTEQ 2.375" NaviGamma - Gamma Ray 29-0ct-04 500292298270 ----------------------------- Description SECT. TOWN.N RANG. PDAT. EPD .F LMF . FAPD.F DMF EKB .F EDF .F EGL .F CASE.F OSl . ~Remarks 23 11 10 MSL o RKB 104 KB 104 N/A N/A N/A DIRECTIONAL Section Township Range Permanent Datum Elevation Of Perm. Datum Log Measured from Feet Above Perm. Datum Drilling Measured From Elevation of Kelly Bushing Elevation of Derrick Floor Elevation of Ground Level Casing Depth Other Services Line 1 )~L{ - let~- . . (All (2) (3) (4) Advantage depths are Measured Depths (MD) unless otherwise noted. All depths are Bit Depths unless otherwise noted. All Gamma Ray data presented is realtime data. Baker Hughes INTEQ utilized Coil track downhole tools and the (5) Electrical Surface system to log this well. Tools ran in the string included Casing Collar Locator, an Disconnect and Circulating Sub, a Drilling Performance Sub (inner and outer Downhole Pressure and Downhole Weight on Bit), a Gamma and Directional Sub and a Hydraulic Orienting Sub, with a Near Bit inclination Sensor. (6) The data presented here is final and has not been depth shifted to a PDC (Primary Depth Control). Per ConocoPhillips Alaska instructions, the MWD Gamma Ray is the PDC for this borehole. (7) The sidetrack was drilled from 1D-32 through a milled window in 3.5" liner. Top of window 13826 ft.MD (6436 ft SSTVD) Bottom of window 13832 ft.MD (6438 ft SSTVD) (8) The interval from 15034 ft MD to 15062 ft MD(6475.0 ft SSTVD to 6473.0 ft SSTVD) was not logged due to sensor to bit offset. (9) Tied to 1D-32 at 13804 ft MD (6426.6 ft SSTVD) (10) The wellbore, 1D-32L1 was kicked off the plugback wellbore 1D- 32L1PB1 at 14665 ft.MD. MNEMONICS: GRAX -> Gamma Ray MWD-API [MWD] (MWD-API units) ROP -> Rate of Penetration, feet/hour Tape Subfile: 1 64 records... Minimum record length: Maximum record length: 14 bytes 132 bytes **** FILE HEADER **** MWD .001 1024 *** INFORMATION TABLE: CONS MNEM VALU ---------------------------------- WDFN LCC CN WN FN COUN STAT 1d-32LPB1 5.xtf 150 ConocoPhillips Alaska Inc. 1D-32L1PB1 Kuparuk River Unit North Slope Alaska *** LIS COMMENT RECORD *** !!!!!!!!!!! !!!!!!!! Remark File Version 1.000 The data presented here is final and has not been depth shifted to a PDC (Primary Depth Control). Per ConocoPhillips Alaska instructions, the MWD Gamma Ray is the PDC for this borehole. . . *** INFORMATION TABLE: CIFO MNEM CHAN DIMT CNAM ODEP --------------------------------,-------------------- GR ROP GR ROP GRAX ROPA 0.0 0.0 * FORMAT RECORD (TYPE# 64) Data record type is: 0 Datum Frame Size is: 12 bytes Logging direction is down (va1ue= 255) Optical Log Depth Scale Units: Feet Frame spacing: 0.500000 Frame spacing units: [F ] Number of frames per record is: 84 One depth per frame (value= 0) Datum Specification Block Sub-type is: 1 FRAME SPACE = 0.500 * F ONE DEPTH PER FRAME Tape depth ID: F 2 Curves: Name Tool Code Samples Units Size Length 1 2 GR ROP MWD MWD 68 68 1 1 AAPI F/HR 4 4 4 4 ------- 8 Total Data Records: 30 Tape File Start Depth Tape File End Depth Tape File Level spacing Tape File Depth Units 13832.000000 15062.000000 0.500000 feet **** FILE TRAILER **** Tape Subfile: 2 39 records... Minimum record length: Maximum record length: 54 bytes 4124 bytes **** FILE HEADER **** MWD .002 1024 *** INFORMATION TABLE: CONS MNEM VALU . . WDFN LCC CN WN FN COUN STAT 1d-32LPB1.xtf 150 ConocoPhi11ips Alaska In 1D-32LlPB1 Kuparuk River Unit North Slope Alaska *** LIS COMMENT RECORD *** !!! ! ! !! !!!!!!!!! ! !! Remark File Version 1.000 This file contains the raw-unedited field data. *** INFORMATION TABLE: CIFO MNEM CHAN DIMT CNAM ODEP ---------------------------------------------------- GRAX ROPS GRAX ROPS GRAX ROPA 0.0 0.0 * FORMAT RECORD (TYPE# 64) Data record type is: 0 Datum Frame Size is: 12 bytes Logging direction is down (va1ue= 255) Optical Log Depth Scale Units: Feet Frame spacing: 0.250000 Frame spacing units: [F ] Number of frames per record is: 84 One depth per frame (value= 0) Datum Specification Block Sub-type is: 1 FRAME SPACE = 0.250 * F ONE DEPTH PER FRAME Tape depth ID: F 2 Curves: Name Tool Code Samples Units Size Length 1 GRAX MWD 68 1 AAPI 4 4 2 ROPS MWD 68 1 F/HR 4 4 ------- 8 Total Data Records: 59 Tape File Start Depth Tape File End Depth Tape File Level Spacing Tape File Depth Units 13826.000000 15062.000000 0.250000 feet **** FILE TRAILER **** Tape Subfile: 3 68 records... Minimum record length: Maximum record length: 54 bytes 4124 bytes **** TAPE TRAILER **** MWD 04/10/29 . 776011 01 **** REEL TRAILER **** MWD 06/04/06 BHI 01 Tape Subfile: 4 Minimum record length: Maximum record length: . 2 records... 132 bytes 132 bytes . . Tape Subfile 1 is type: LIS . . Tape Subtile 2 is type: LIS DEPTH GR ROP 13832.0000 227.3800 1.1000 13832.5000 154.0400 4.3700 13900.0000 81. 0900 43.9500 14000.0000 104.3100 29.1800 14100.0000 107.0700 61. 4100 14200.0000 81.5800 25.6500 14300.0000 101.2000 49.1800 14400.0000 96.4400 28.7200 14500.0000 91. 5500 16.3900 14600.0000 140.1000 137.0500 14700.0000 69.6000 238.8300 14800.0000 97.6400 50.1300 14900.0000 115.1600 80.8100 15000.0000 122.0400 20.4900 15062.0000 -999.2500 -999.2500 Tape File Start Depth 13832.000000 Tape File End Depth 15062.000000 Tape File Level Spacing 0.500000 Tape File Depth Units teet . . Tape Subfile 3 is type: LIS DEPTH GRAX ROPS 13826.0000 81. 5400 0.0200 13826.2500 -999.2500 0.2000 13900.0000 79.9800 43.9500 14000.0000 108.8000 29.1800 14100.0000 105.9400 61. 4100 14200.0000 81.8000 25.6500 14300.0000 103.0900 49.1800 14400.0000 96.0800 28.7200 14500.0000 84.6500 16.3900 14600.0000 142.8100 137.0500 14700.0000 69.6000 238.8300 14800.0000 97.6400 50.1300 14900.0000 -999.2500 80.8100 15000.0000 122.0400 20.4900 15062.0000 -999.2500 -999.2500 Tape File Start Depth 13826.000000 Tape File End Depth 15062.000000 Tape File Level Spacing 0.250000 Tape File Depth Units feet . . Tape Subfile 4 is type: LIS . . **** REEL HEADER **** MWD 06/03/18 BHI 01 LIS Customer Format Tape # pIll **** TAPE HEADER **** MWD 04/10/29 776011 01 2.375" CTK *** LIS COMMENT RECORD *** !!!!!!!!!!!!!!!!!!! Remark File Version 1.000 ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! !! Extract File: ldwg.las -Version Information VERSo WRAP. -Well Information Block #MNEM.UNIT Data Type #--------- ------------- STRT.FT 13832.0000: STOP.FT 15944.0000: STEP.FT 0.5000: NULL. -999.2500: COMPo COMPANY: WELL. WELL: FLD . FIELD: LOC . LOCATION: CNTY. COUNTY: STAT. STATE: SRVC. SERVICE COMPANY: TOOL. TOOL NAME & TYPE: DATE. LOG DATE: API . API NYUMBER: -Parameter Information Block #MNEM.UNIT Value #--------- ------------------------- 1. 20: NO: CWLS log ASCII Standard -VERSION 1.20 One line per frame Information ------------------------------- Starting Depth Ending Depth Level spacing Absent Value ConocoPhillips Alaska Inc. 1D-32L1 Kuparuk River Unit 70 deg 17' 57.217"N 149 deg 30' 31.143"W North Slope Alaska Baker Hughes INTEQ 2.375" NaviGamma - Gamma Ray 29-0ct-04 500292298260 ------------------------------- Description SECT. TOWN.N RANG. PDAT. EPD .F LMF . FAPD.F DMF EKB .F EDF .F EGL .F CASE.F OSl . -Remarks 23 11 10 MSL o RKB 104 KB 104 N/A N/A N/A DIRECTIONAL Section Township Range Permanent Datum Elevation Of Perm. Datum Log Measured from Feet Above Perm. Datum Drilling Measured From Elevation of Kelly Bushing Elevation of Derrick Floor Elevation of Ground Level Casing Depth Other Services Line 1 ~ðvl- /lfj- . . (1) (2 ) (3) (4 ) Advantage All depths are Measured Depths (MD) unless otherwise noted. All depths are Bit Depths unless otherwise noted. All Gamma Ray data presented is real time data. Baker Hughes INTEQ utilized Coil track downhole tools and the (5 ) Electrical Surface system to log this well. Tools ran in the string included Casing Collar Locator, an Disconnect and Circulating Sub, a Drilling Performance Sub (inner and outer Downhole Pressure and Downhole Weight on Bit), a Gamma and Directional Sub and a Hydraulic orienting Sub, with a Near Bit inclination Sensor. (6) The data presented here is final and has not been depth shifted to a PDC (Primary Depth Control). Per ConocoPhillips Alaska instructions, the MWD Gamma Ray is the PDC for this borehole. (7) The sidetrack was drilled from 1D-32 through a milled window in 3.5" liner. Top of window 13826 ft.MD (6436 ft SSTVD) Bottom of window 13832 ft.MD (6438 ft SSTVD) (8) The interval from 15916 ft MD to 15944 ft MD(6490.9 ft SSTVD to 6468.5 ft SSTVD) was not logged due to sensor to bit offset. (9) Tied to 1D-32 at 13804 ft MD (6426.6 ft SSTVD) (10) The wellbore 1D-32L1 was kicked off the plug back wellbore 1D- 32L1PB1 at 14665 ft. MD. MNEMONICS: GRAX -> Gamma Ray MWD-API [MWD] (MWD-API units) ROP -> Rate of Penetration, feet/hour Tape Subfile: 1 64 records... Minimum record length: Maximum record length: 14 bytes 132 bytes **** FILE HEADER **** MWD .001 1024 *** INFORMATION TABLE: CONS MNEM VALU ---------------------------------- WDFN LCC CN WN FN COUN STAT 1d-32L1 5.xtf 150 ConocoPhillips Alaska Inc. 1D-32L1 Kuparuk River Unit North Slope Alaska *** LIS COMMENT RECORD *** !!!!!!!!!!!!!!!!!!! Remark File Version 1.000 The data presented here is final and has not been depth shifted to a PDC (Primary Depth Control). Per ConocoPhillips Alaska instructions, the MWD Gamma Ray is the PDC for this borehole. . . *** INFORMATION TABLE: CIFO MNEM CHAN DIMT CNAM ODEP ---------------------------------------------------- GR ROPS GR ROPS GRAX ROPA 0.0 0.0 * FORMAT RECORD (TYPE# 64) Data record type is: 0 Datum Frame Size is: 12 bytes Logging direction is down (va1ue= 255) Optical Log Depth Scale Units: Feet Frame spacing: 0.500000 Frame spacing units: [F ] Number of frames per record is: 84 One depth per frame (value= 0) Datum Specification Block Sub-type is: 1 FRAME SPACE = 0.500 * F ONE DEPTH PER FRAME Tape depth ID: F 2 Curves: Name Tool Code Samples Units Size Length 1 2 GR MWD ROPS MWD 68 68 1 1 AAPI F/HR 4 4 4 4 ------- 8 Total Data Records: 51 Tape File Start Depth Tape File End Depth Tape File Level Spacing Tape File Depth Units 13832.000000 15944.000000 0.500000 feet **** FILE TRAILER **** Tape Subfile: 2 60 records... Minimum record length: Maximum record length: 54 bytes 4124 bytes **** FILE HEADER **** MWD .002 1024 *** INFORMATION TABLE: CONS MNEM VALU WDFN LCC CN WN FN COUN STAT . . 1d-32L1.xtf 150 ConocoPhi1lips Alaska In 1D-32L1 Kuparuk River Unit North Slope Alaska *** LIS COMMENT RECORD *** ! !!!!!!!!!!!! ! ! !! !! Remark File Version 1.000 This file contains the raw-unedited field data. *** INFORMATION TABLE: CIFO MNEM CHAN DIMT CNAM ODEP GRAX ROPA ---------------------------------------------------- GRAX ROPA GRAX ROPA 0.0 0.0 * FORMAT RECORD (TYPE# 64) Data record type is: 0 Datum Frame Size is: 12 bytes Logging direction is down (value= 255) Optical Log Depth Scale Units: Feet Frame spacing: 0.250000 Frame spacing units: [F ] Number of frames per record is: 84 One depth per frame (value= 0) Datum Specification Block Sub-type is: 1 FRAME SPACE = 0.250 * F ONE DEPTH PER FRAME Tape depth ID: F 2 Curves: Name Tool Code Samples Units Size Length 1 2 1 1 4 4 68 68 AAPI F/HR 4 4 GRAX MWD ROPA MWD ------- 8 Total Data Records: 101 Tape File Start Depth Tape File End Depth Tape File Level Spacing Tape File Depth Units 13826.000000 15944.000000 0.250000 feet **** FILE TRAILER **** Tape Subfile: 3 110 records... Minimum record length: Maximum record length: 54 bytes 4124 bytes **** TAPE TRAILER **** MWD 04/10/29 . 776011 01 **** REEL TRAILER **** MWD 06/03/18 BHI 01 Tape Subfi1e: 4 Minimum record length: Maximum record length: . 2 records... 132 bytes 132 bytes . . rape Subfile 1 is type: LIS . rape Subfile 2 is type: LIS DEPTH 13832.0000 13832.5000 13900.0000 14000.0000 14100.0000 14200.0000 14300.0000 14400.0000 14500.0000 14600.0000 14700.0000 14800.0000 14 900.0000 15000.0000 15100.0000 15200.0000 15300.0000 15400.0000 15500.0000 15600.0000 15700.0000 15800.0000 15900.0000 15944.0000 GR 227.3800 154.0400 81. 0900 104.3100 107.0700 81.5800 101.2000 96.4400 91. 5500 140.1000 104.8700 104.4200 92.6100 99.4800 98.3000 118.6500 111.8600 123.7600 101.7800 70.7700 107.0333 97.5500 141.1100 -999.2500 Tape File Start Depth Tape File End Depth Tape File Level Spacing Tape File Depth Units . ROPS 1.1000 4.3700 43.9500 29.1800 61.4100 25.6500 49.1800 28.7200 16.3900 137.0500 51. 8900 141. 0000 163.3700 138.0300 46.4700 72.1100 27.5000 62.1300 56.5200 110.6600 8.7000 26.7600 9.1600 47.9800 13832.000000 15944.000000 0.500000 feet . . Tape Subfile 3 is type: LIS DEPTH GRAX ROPA 13826.0000 -999.2500 0.0200 13826.2500 85.9500 0.2000 13900.0000 81. 0900 43.9500 14000.0000 104.3100 29.1800 14100.0000 107.0700 61.4100 14200.0000 81.5800 25.6500 14300.0000 101.2000 49.1800 14400.0000 96.4400 28.7200 14500.0000 91.5500 16.3900 14600.0000 140.1000 137.0500 14700.0000 104.8700 51. 8900 14800.0000 104.4200 141. 0000 14900.0000 92.6100 163.3700 15000.0000 99.4800 138.0300 15100.0000 98.3000 46.4700 15200.0000 118.6500 72.1100 15300.0000 111. 8600 27.5000 15400.0000 123.7600 62.1300 15500.0000 -999.2500 56.5200 15600.0000 70.7700 110.6600 15700.0000 -999.2500 8.7000 15800.0000 97.5500 26.7600 15900.0000 141.1100 9.1600 15944.0000 -999.2500 47.9800 Tape File Start Depth 13826.000000 Tape File End Depth 15944.000000 Tape File Level Spacing 0.250000 Tape File Depth Units feet . . Tape Subfile 4 is type: LIS