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Home My WebLink About205-121• 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~Q ~- ~ ~, ~ Well History File Identifier Organizing (done) RESCAN ~olor Items: ^ Greyscale Items: ^ Poor Quality Originals: ^ Other: ^ Two-sided IIIIIIIIIIIIIIIIIII DIGITAL DATA ^ Diskettes, No. ^ Other, No/Type: „Ae,v~~a.aea iuuminiiiuiu OVERSIZED (Scannable) ^ Maps: ^ Other Items Scannable by a Large Scanner OVERSIZED (Non-Scannable) ^ Logs of various kinds: NOTES: BY: Maria Date: ~ ^ Other:: /s/ Project Proofing III IIIIII IIIII II III BY: Maria Date: ~ ~, lp ~ lsl Scanning Preparation ~_ x 30 = ~ + ~~ =TOTAL PAGES v~ / (Count does not include cover sheet) BY: Maria Date: ( °1 1 n /~7 f7 /s/ i'/ V L I Production Scanning Stage 1 Page Count from Scanned File: (count does include cover sheet) Page Count Matches Number in Scanning Preparation: ~~ YES NO BY: Maria Date: ~ ~' ~/~ ~] /s/ ~ p Stage 1 If NO in stage 1, page(s) discrepancies were found: YES NO - l I BY: Maria Date: /s/ Scanning is complete at this point unless rescanning is required. II I II ~I II I II II ((III ReScanned II I II ~I II I I II I I III BY: Maria Date: /s/ Comments about this file: Quality Checked III II'lll III II'I III 10!612005 Well History File Cover Page.doc ConocoPhillips Alaska RECIPIENTS No other distribution is allowed without OH FINAL OH FINAL written approval from ConocoPhillips Image files and/or Digital Data contact: Lisa Wright, 907 263-4823 hardcopy prints ConocoPhillips Alaska, Inc. 1 Hardcopy Print NSK Wells Aide, NSK 69 ATTN: MAIL ROOM 700 G Street, Anchorage, AK 99501 AOGCC 1 Hardcopy Print, Christine Mahnken 1 Graphic image file 1 Disk*/ 333 West 7th Ave, Suite 100 in lieu of sepia"* Electronic Anchorage, Alaska 99501 CGM /TIFF LIS BP 1 Hardcopy Print, Petrotechnical Data Center, MB33 1 Graphic image file 1 Disk*/ David Douglas in lieu of sepia** Electronic P.O. Box 196612 CGM /TIFF LIS Anchorage, Alaska 99519-6612 CHEVRON/KRU REP 1 Hardcopy Print, Glenn Fredrick 1 Graphic image file 1 Disk/ P.O.Box 196247 in lieu of sepia"* Electronic Anchorage, Alaska-99519 CGM /TIFF LIS Brandon Tucker, NRT State cf Alaska; DNR, Div. of Oil and Gas 1 Disk*/ 550 W. 7th Ave, Suite 800 Electronic Anchorage, Alaska 99501-3510 LIS ~~5 -1 a- O ~~ - l ~ i9 ~a ~ !~~ 9 t ni I~~ ~~~b~~9 l1 i~ ~~~ ~~°` ' ;. ``~~`~ v~ s- ProActive Diagnostic Services, Inc. To: AOGCC Christine Mahnken 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 (907) 859-5102 RE : Cased Hole/Open Hole/Mechanical Logs and/or Tubing Inspecfiaon(Caliper/ MTT) The technical data listed below is being submitted herewith. Please acknowledge receipt 6y returning a signed copy of this transmittal letter to the following ProActive Diagnostic Services, Inc. Attn: Robert A. Richey 130 West International Airport Road ~^ ~! , { r ~ ;~ nr Suite C '~~`~,~ ~,~~~ t~ - Z;~,~~x Anchorage, AK 99518 Fax: (907) 245-8952 1) Caliper Report 11-Dec-08 1 J-03 1 Report / EDE 50-029-23002-61 2] was =~a r ~ i~~6 Signed : Date Print Name: ~~~~,yP ~, i~~:~L~x"- - PROACTIVE DIAGNOSTIC SERVICES, INC., 130 W, INTERNATWNAL AIRPORT RD SUITE C, ANCHORAGE, AK 99518 PHONE: (907)245-8951 PAX: (907)24858952 E-MAIL : c~r~9~ehcar~~-~ c~irxo~~-n~lo~r ..corn WEBSITE : y'atvv_~;~reaa;a~ryd~~~ .~;~e°~~ i ~\ C:\Docu[nents and Settings\Owner\Desktop\Tra~umit_Conoco.docx Company: ConocoPhillips Alaska, Inc. WeH: 1J-03 Log Date: December 11,2008 Field: Kuparuk Log No.: 7284 State: Alaska Run No.: 2 API No.: 50-029-23002-61 Pipet Desc.: 3.5" 9.3 Ib. L-80 EU MOD & SLHT Top Log Intvl1.: Surface Pipet Use: Tubing & Liner Bot. Log Intvl1.: 11,218 Ft. (MD) Inspection Type : Corrosive & Mechanical Damage Inspection COMMENTS: This caliper data is tied into the DS Nipple @ 11,078' (Drilier's Depth). This log was run to assess the condition of the 3.5" tubing and liner with respect to internal corrosive and mechanical damage. The caliper recordings indicate the 3.S" tubing and liner logged are in good to fair condition, with a maximum wall penetration of 25% recorded in an isolated pit in pup joint 350.3 (11,038'). No significant areas ofcross-sectional wall loss or I.D. restrictions are recorded throughout the interval logged. This is the second time a PDS caliper has been run in this well and the 3.5" tubing and liner from 10,914' to ' 11,218' have been logged. A comparison of the current and previous log (July 11, 2005) indicates an increase in corrosive damage during the time between logs. A comparison plot illustrating the difference in maximum recorded penetrations between logs on a joint by joint basis is included in this report. MAXIMUM RECORDED WALL PENETRATIONS ' Isolated pitting (25%) Jt. 350.3 @ 11,038 Ft. (MD) isolated pitting (24%) Jt. 352.1 @ 11,121 Ft. (MD) No other significant wall penetrations (> 19°/a) are recorded. ' MAXIMUM RECORDED CROSS-SECTIONAL METAL LOSS No significant areas of cross-sectional wall loss (> 7°~) are recorded. MAXIMUM RECORDED ID RESTRICTIONS : No significant I.D. restrictions are recorded. ~~~~ ~ ; J~N~ 2Q Field Engineer: Wm. McCrossan Analyst; C. Waldrop Witness: C. Fitzpatrick FroActive Diagnostic 5eniices, Inc. ( P.C. box 1369, Stafford, T;~ 77497 Fhone: {281) or {888) 565-9085 Fax: {281} 565-2369 E-mail: PDS~,~xmemorylog.com Prudhoe Bay Field Office Phone: {907) 659-2307 Fax: {907} 659-2314 was r2 t ~ l ~-3~~ • Maximum Recorded Penetration Comparison To Previous Well: 1)-03 Survey Date: December 11, 2008 Field: Kuparuk Prev. Date: July 1 1, 2005 Company: ConocoPhillips Alaska, Inc. Tool: UW MFC 24 No. 211387 Country: USA Tubing: 3.5' 9.3 Ib L~0 EU MOD Overlay Max. R ec. Pen. (mils) 0 10 0 20 0 349 d E z .0 352.1 ^ December 11, 2008 ~ July 11, 2005 Difference -100 -7 D 5 -5 ill. in 0 -2 Max 5 0 . Pen. (mil 25 5 s) 0 7 5 100 1 i f 3 I 49 f $i~ E ~ o z e .a i 3 2.1 -29 -2 2 -1 5 - 7 0 7 1 5 2 2 29 App rox. C orros ion Rate ( mpy) • • Correlation of Recorded Damage to Borehole Profile Pipe 1 3.5 in (-6.5' - 11204.1') Well: 1 J-03 Field: Kuparuk Company: ConocoPhillips Alaska, Inc. Country: USA Survey Date: December 11, 2008 A pprox. T ool De viation ^ A pprox. Borehol e Profil e 0 1543 3106 GLM 1 4675 t.i c 6239 s a v D GLM 2 782 5 GLM 3 9413 GLM 4 GLM 5 10990 354 11204 0 5 0 1 00 Da mage Pr ofile (% wall) / Tool D eviatio n (degr ees) Bottom of Survey = 354 1 50 100 150 " v Z 200 c ~o 250 300 r • a PDS Report Overview ~ ~. Body Region Analysis Well: 1 J-03 Survey Date: December 11, 2008 Field: Kuparuk Tool Type: UW MFC 24 No. 211387 Company: ConocoPhillips Alaska, Inc. Tool Size: 1.69 Country: USA No. of Fingers: 24 Anal st: C. Waldro Tubing: Nom.OD Weight Grade & Thread Nom.ID Nom. Upset Upper len. Lower len. 3.5 ins 9.3 f L-80 EU MOD 2.992 ins 3.5 ins 6.0 ins 6.0 ins Penetration and Metal Loss (°~ wall) ~ penetration body ~ metal loss body 400 300 200 100 0 ~ 0 to 1 to 10 to 20 to 40 to over 1% 10% 20% 40% 85% 85% Number of ~oints anal sed total = 372 pene. 0 195 175 2 0 0 loss 27 345 0 0 0 0 Damage Configuration (body ) 10 0 isolated general line ring hole / poss pining corrosion corrosion corrosion ible hole Number of ~oints dama ed total = 2 2 0 0 0 0 Damage Profile (% wall) ~ penetration body _-~; metal loss body 0 50 100 n GLM 1 GLM 2 GLM 3 GLM 4 GLM 5 Bottom of Survey = 354 Analysis Overview page 2 • PDS REPORT JOINT TABULATION SHEEP Pipe: 3.5 in 9.3 ppf L-80 EU MOD Well: 1 J-03 Body Wall: 0.254 in Field: Kuparuk Upset Wall: 0.254 in Company: Conoco Phillips Alaska, Inc. Nominal I.D.: 2.992 in Country: USA Survey Date: December 1 1, 2008 Joint No. Jt. Depth (Ft.) I'~~n. i )I„~~t 1lin.) Pen. Body (Ins.) P~~n. °/, ~I<~t,il I ~~ss ~~ Min. LD• (Ins.) Comments Damage Profile (%wall) 0 50 100 .1 -6 ~~ 0.01 4 I 2.95 PUP .2 -4 l~ 0.01 6 ~~ 2.88 PUP 1 0 U 0.02 ~) i 2.90 2 33 U 0.03 11 ,' 2.90 3 64 l) 0.03 12 _' 2.91 4 97 ~~ 0.03 11 ~' 2.91 5 129 I~ 0.03 11 _' 2.92 6 160 i ~ 0.03 1 tl s 2.91 7 191 ~~ 0.03 Ili 2.90 8 223 i ~ 0.03 I 1 2.89 9 253 t~ 0.03 t s s 2.91 10 284 ~~ 0.03 1 ~ 2.91 11 314 ~ ~ 0.03 I I -} 2.91 12 346 l ~ 0.03 1 1 -1 2.91 13 376 ll 0.02 ~) I 2.90 14 407 O 0.02 fi 2.91 15 438 t) 0.02 8 -1 2.92 16 4 0 U 0.0 8 2.91 16.1 501 ~ ~ 0.0 I ~l I .90 P P 16.2 507 U 0 l) n 2.88 C rnco DS-Ni le N Go 16.3 509 ~I 0.02 ~I 2.93 PUP 17 515 U 0.02 ~> 2.91 Lt. e osits. 18 544 U 0.02 8 ~ 2.92 19 574 U 0.02 ~) ~ 2.91 20 6 7 U 0.03 I I .91 21 638 II 0.03 1 I 2.91 22 670 ~~ 0.03 1i .90 23 701 a 0.02 8 ~ 2.92 24 732 ~ ~ 0.03 1 U 2.91 25 764 (I 0.03 1:3 ~' 2.91 26 795 U 0.03 13 1 2.92 27 827 ~~ 0.03 111 U 2.89 28 858 a 0.02 ti -1 2.93 29 889 a 0.03 1~ -1 2.91 30 921 l1 0.03 I U 2.91 31 951 l? 0.03 1 I ~' 2.91 Lt. De osits. 32 981 i I 0.02 ') ~' 2.92 33 1013 ~~ 0.04 I i 3 2.91 Lt. De osits. 34 1044 ~ ~ 0.02 ~ ~ t 2.92 35 1075 ~ ~ 0.03 i _3 3 2.91 36 1107 a 0.03 10 .3 2.92 37 1138 a 0.03 1l (~ 2.91 38 1169 t~ 0.03 11 i 2.91 39 1201 ~ ~ 0.03 13 4 2.91 40 1230 ~ I 0.03 I I _' 2.90 41 1260 ~ ~ 0.03 1 ~ 2.91 42 1292 ~~ 0.03 11 ~~ .91 43 1323 i ~ 0.03 1 I -4 2.91 44 1355 ~ i 0.0 ' ~ 1 2.91 45 1386 ! ~ 0.03 1 ~ 1 2.90 Penetration Body Metal loss Body Page 1 • PDS REPORT JOINT TABI. Pipe: 3.5 in 9.3 ppf L-80 EU MOD Well: Body Wall: 0.254 in Field: Upset Wall: 0.254 in Company: Nominal I.D.: 2.992 in Country: Survey Date: • ELATION SHEET 1)-03 Kuparuk ConocoPhillips Alaska, Inc. USA December 11, 2008 Joint No. Jt. Depth (Ft.) I'e~n. Ill„c~t Iln..) Pen. Body (Ins.) Pen. % Metal loss `io Min. LD• (Ins.) Comments Damage Profile (%wall) 0 50 100 46 1417 ~ I 0.02 t3 ? .91 47 1449 t ~ 0.02 ~) ? 2.91 48 1480 t ~ 0.0 ~) ~ 2.91 49 1512 U 0.03 l _' .91 50 154 ~ ~ 0.01 (> 2.9 51 1 73 a 00 1~ s .91 52 1604 ~) 0.03 l U -~ 2.90 53 1636 ~~ 0.03 11 2.90 54 1667 U .02 ti -1 2.92 55 1699 (1 0.03 1 ~ 5 2.91 56 1730 t~ 0.03 1 ~ 4 .92 57 1761 ~ I 0. 3 l U 2.92 5 1793 I I 0.03 l u i 2.91 59 1824 n 0.03 11 4 2.91 60 1856 ~ I 0.03 1 > 3 2.91 61 1887 a 0. 4 1-1 S 2.91 62 1918 t~ 0.03 II ~ 2.91 63 1950 ~ ~ 0.03 1 Z 5 2.91 64 1981 (~ 0.03 11 .91 6 201 1 ~ ~ 0.03 I,' ~ 2.91 66 2043 ~ I 0.03 1 1 t 2.91 67 2074 i ~ 0.02 ~~ _' 2.90 6 2106 U 0.03 I1 2.92 69 213 7 I ~ 0.04 15 -3 2.91 7 2169 i ~ 0.02 ti ~ 2.92 71 2200 ~~ 0.03 1 _; ~ 2.92 7 2231 0 0.02 tf ~ 2.92 73 2261 t) 0.02 9 ~ 2.91 74 2292 U 0.03 11 ~ .90 75 2323 ~~ 0.03 11 ~' 2.91 76 2354 U 0.01 6 2.91 77 2386 ~~ 0.02 ~ I 2.89 78 2416 U 0.03 11 -1 2.91 9 2448 t) 0.02 ~) -~ 2.90 80 2 79 (~ 0.03 11 ~1 2.91 81 2511 U 0.03 11 -1 2.91 82 543 ~ I 0.02 ~) ~ 1 2.91 83 2574 U 0.02 8 l 2.92 84 2606 c ~ 0.03 1(I 2.92 85 2637 i) 0.02 ~~ _' 2.91 86 2668 ~~ 0.03 1 "~ _I .92 87 2700 U 0.03 I ~ a 2.91 88 2730 I) 0.03 11 -1 2.90 89 2761 ~~ 0.03 12 ~l 2.91 90 2793 U 0. 3 111 4 2.91 91 2824 a 0.03 I U 3 2.92 9 2855 t~ 0.03 10 ~ 2.91 93 2886 ~~ 0.03 1Z !> 2.92 94 2917 ~ ~ 0.0 ii 2.91 95 2949 + ~ 0.04 1 ! ~ 2.92 Penetration Body Metal Loss Body Page 2 • PDS REPORT JOINT TABI. Pipe: 3.5 in 9.3 ppf L-80 EU MOD Well: Body Wall: 0.254 in Field: Upset Wall: 0.254 in Company: Nominal I.D.: 2.992 in Country: Survey Date: • ELATION SHEET 1 J-03 Kuparuk ConocoPhillips Alaska, Inc. USA December 11, 2008 Joint No. Jt. Depth {Ft.) I'c~n. tllxet ilrn.) Pen. Body (Ins.) Nen. `%, Metal Loss °~~ Min. LD• (Ins.) Comments Damage Profile (%wall) 0 50 100 96 2980 U 0.03 13 ~ .90 97 30 1 l! 0.02 9 5 2.91 98 3043 t) 0.02 9 ~ 2.91 99 3075 l) 0.0 10 - 2.91 100 3106 t) 0.03 I U ~ 2.91 101 3135 tl 0.03 IZ i .91 102 3165 t l 0.03 l U i 2.92 103 3196 t I 0.01 v ? .91 104 228 t> 0 04 15 92 Lt. e osi 105 3259 U 0.03 11 s 2.92 106 3290 U 0.03 11 t .91 107 3322 t1 0.03 13 > 2.91 108 3353 i? 0.03 II ~' 2.9 109 3384 t t 0. I 1 -3 2.91 110 3416 U 0.0 9 a 2.91 111 3447 U 0.03 1 U .91 112 3478 t) 0.03 11 a 2.93 112.1 510 tl 0.03 11 2.89 PUP 112. 3516 ll 0 l) (t N A GLM 1 atch Z:00 112.3 3523 a 0.02 8 Z 2.9 PUP 11 3529 tt 0.03 1tl ~' 2.91 114 3560 t i 0.02 ~t 1 .91 115 3592 t I 0. 3 10 ~' 2.92 116 3623 t) 0.03 13 3 2.91 117 3654 l) 0.0 1 u 4 2.93 118 3686 U 0.03 1 u 1 2.91 119 3716 U 0.03 12 ~ 2.91 120 3748 tl 0.03 1I ~' 2.91 121 3778 t) 0.03 13 2.91 122 3809 U 0.03 11 ? 2.90 123 3839 a 0.03 12 _' 2.90 124 3871 ~ ~ 0.03 I I ,' 2.91 125 3899 i t 0.03 1) -3 2.91 126 3931 U 0.03 11 -1 2.91 127 3962 (~ 0.04 14 •1 2.90 Lt. De osi 128 3993 tt 0.03 I < _' 2.90 129 24 i) 0.03 l .90 Lt. e osi 130 4055 a 0.03 13 _' 2.92 131 4085 t I 0.0 9 2.91 132 4116 t ~ 0.03 12 2.91 133 4148 a .03 1 t ~ 2.91 Lt. De sits. 134 4179 U 0.03 1 "t s 2.91 135 4211 tI 0.03 1 i 2.91 136 4242 U 0.03 1 Z ~ 2.92 1 7 4 71 t l 0.03 12 5 2.91 138 4302 tl 0.02 9 ? 2.91 139 4334 U 0.0 l a 4 2.91 140 4365 a 0.03 12 4 2.91 141 4397 t t 0.03 12 2.91 142 442 8 t t 0.03 1 ~~ 2.91 Penetration Body Metal Loss Body Page 3 • PDS REPORT JOINT TABI. Pipe: 3.5 in 9.3 ppf L-80 FU MOD Well: Body Wall: 0.254 in Field: Upset Wall: 0.254 in Company: Nominal I.D.: 2.992 in Country: Survey Date: • iLATION SHEET 1 J-03 Kuparuk ConocoPhillips Alaska, Inc USA December 11, 2008 Joint No. Jt. Depth (Ft.) I'~~n. l 11 ~~~ ~t II~,.J Pen. Body (Ins.) I'e~n. %, M~•t,il I ~ ass °~~ Min. LD• (Ins.) Comments Damage Profile (% wall) 0 50 100 143 4459 n 0.0 ~) _' 2.91 144 4488 ~) 0.03 1~' ~ 2.91 145 4519 ~ ~ 0.03 1 1 2.92 146 4551 ~) 0.02 'I 2.92 147 4582 n 0.03 1 ~ ~ 2.91 148 4613 t 1 0.04 1 i ~ 2.91 t. De osi ts. 149 4644 ~ ~ 0.03 1 3 ? .91 150 4675 U 0.02 ') 2.92 151 4707 l) 0.03 Ill -i 2.91 152 4738 i) 0.03 l a 2.90 153 4769 U 0.03 12 ~ 2.91 1 4 4800 0 0.03 1 ~~ 2.90 155 4832 U 0.03 Il 2.91 156 4863 0 0.03 I I -1 2.92 157 4894 a 0.03 1 _~ ! 2.92 158 4926 U 0.03 1 ~' -1 2.91 159 4957 0 0.03 11 5 2.91 16D 4989 tt 0.04 l~ ~ 2-91 161 5020 U 0.03 1 U s 2.91 162 5051 U 0.02 9 s 2.91 163 5083 ~ ~ 0.03 1 "3 -1 2.91 164 51 14 t ~ 0.03 I 1 2.91 165 5146 ~ ~ 0.03 I 0 5 .92 166 5177 ~) 0.03 10 2.92 167 5206 t) .03 12 ~' 2.91 168 5238 t~ 0.03 12 ~ 2.91 169 5269 t~ 0.03 10 3 2.91 170 5300 0 0.03 1 U 1 2.92 171 5331 t~ 0.03 I -1 2.90 172 5363 t ~ 0.03 t l 2.91 173 5394 t) 0.03 I3 -1 2.91 174 5426 t) 0.03 1O ~ 2.91 175 5457 0 0.03 1 Z _' 2 91 176 5488 0 0.03 12 3 2.92 177 5519 U 0. 2 9 t> 2.91 178 5551 a 0.03 10 4 2.91 179 5582 a 0.02 9 i 2.91 180 5613 U 0.03 11 .3 2.91 181 5645 U 0.03 13 -1 2.91 182 5676 a 0.03 1~ ~ 2.92 183 570 n 0.02 ~~ 1 2.93 184 5739 a 0.02 ~) U 2.92 185 5771 O 0.02 9 2 2.94 186 5802 U 0.03 10 2 2.92 187 5831 a 0.03 1 ~' 2 2.93 188 5862 a 0.01 4 2 2.94 189 5894 (~ 0.01 (> I 2.94 190 5925 U 0.01 i _' 2.93 191 5957 i ~ 0.01 4 I 2.93 192 5988 ! ! 0.02 2.9 3 Penetration Body Metal Loss Body Page 4 • PDS REPORT JOINT TABI. Pipe: 3.5 in 9.3 ppf L-80 EU MOD Well: Body Wall: 0.254 in Field: Upset Wall: 0.254 in Company: Nominal I.D.: 2.992 in Country: Survey Date: • iLATION SHEET 1 J-03 Kuparuk ConocoPhillips Alaska, Inc. USA December 11, 2008 Joint No. Jt. Depth (Ft.) Ne~n. I It~sc~t Iln~.) Pen. Body (Ins.) Peen. % Metal I os~ `~~~, Min. LD• (Ins.) Comments Damage Profile (%wall) 0 50 100 193 6020 r,) 0.03 1l ~ 2.91 194 6051 a 0.04 1 ~ .91 195 6083 a 0.0 1O ~' 2.90 1 6 6114 l) 0.04 1 E~ L 2.91 197 6145 0 0.03 11 _' .91 198 6176 U 0.03 10 Z .92 199 6208 t) 0.03 12 -1 2.88 Lt. De osits. 200 6239 a 0.03 11 ~ 2.93 201 6 71 t) 0.02 ~) Z .93 202 6302 0 0.02 ~) ? 2.93 2 3 6334 t> 0.01 6 2 93 204 6365 U 0.02 ~) 2 2.90 205 6396 U 0.03 11 -4 2.91 206 6428 U 0.03 I ~ 2.92 207 6459 U 0.03 1 i ~ 2.91 208 6491 t) 0.03 1 1 3 2. 1 209 6522 U 0.03 11 3 .91 210 6553 l) .03 13 4 .91 _ 11 6584 t) 0.0 13 4 2.91 212 6615 a 0.02 ~) 3 .92 213 6645 t) 0.02 9 t~ 2.92 214 6677 U 0.03 I Z 4 .91 215 6708 ~) 0.03 1 Z S 2.91 216 6739 U 0.02 ~) ,' 2.92 21 6771 t) 00 IU ~ .9 218 6802 t) 0.03 1 U _' 2.92 219 6834 n 0.03 1 ~ 2.91 220 6863 t) 0.03 1:3 2.91 0.1 6895 ~? 0.02 £f 2.91 PUP 220.2 6900 U 0 u ~, ~ N A GLM 2 Latch ~ 5:30 220.3 6907 U 0.02 8 ~ 2.89 PUP Lt. De sits. 221 6914 a 0.03 l i ~ 2.91 222 6945 O 0.04 16 ~ .91 223 6976 t) 0.01 5 I 2.94 224 7008 t) 0.03 1tl ? 2.90 225 7039 a 0.01 5 2.93 226 071 t) 0.01 ~ .94 227 7101 O 0.02 23 I 2.92 2 8 7133 a 0.01 5 2.94 229 7164 O 0.01 '~ 2.94 30 7196 ~) 0.01 ~ I 2.93 231 7227 (> 0.03 1.3 ~ 2.88 Lt. De osits. 232 7258 i) 0.02 ~) 2.95 233 7290 t) 0.02 7 2.94 234 73 a 0.02 ~) :.' 2.92 235 7353 t) 0.02 9 _' .93 236 7385 tt 0.04 16 ~1 2.94 237 7416 r ~ 0.04 1-~ 2.93 238 7447 0.03 ! 1 2.94 239 7479 0.02 2.88 _ Penetration Body Metal Loss Body Page 5 PDS REPORT JOINT TABS Pipe: 3.5 in 9.3 ppf L-80 EU MOD Well: Body Wall: 0.254 in Field: Upset Wall: 0.254 in Company: Nominal I.D.: 2.992 in Country: Survey Date: • -LATION SHEET 1 J-03 Kuparuk ConocoPhillips Alaska, Inc USA December 11, 2008 Joint No. )t. Depth (Ft.) I'an. IJl~set (Ins.) Pen. Body (Ins.) Pen. °~, :'Natal Ios~ ~~ Min. LD• (Ins.) Comments Damage Profile (%wall) 0 50 100 240 7510 a 0.02 ~> 2.94 241 7542 t) 0.02 ~) ' 2.93 242 7573 t) 0.03 1t) 2.94 243 7604 U 0.0 7 ~ 2.92 244 7636 U 0.02 ~) _' 2.95 245 7667 U 0.01 5 2.94 246 7699 c) 0.02 I 2.95 247 7730 i) 0.02 ~ .94 248 7762 a 0.02 9 2.93 249 7793 U 0.01 5 ? .93 250 7 25 U 0.01 5 _' 2.93 25 7857 U 0.01 ~ I 2.94 252 7889 t) 0.01 -t .91 253 7921 t) 0.02 '~ 2.91 254 7952 a 0.03 1 Z _' 2.90 255 7983 U 0.03 1l) 1 .93 256 8014 t) 0.03 12 2.93 257 8045 l) 0.02 2.93 8 8076 l) 0 02 ti .93 259 8107 t) 0.04 14 ~ 2.89 260 8139 a 0.01 > 2.92 261 8170 ~) 0.02 '! 2.95 262 8201 U 0.02 9 > 2.93 263 8233 t) 0.03 1t) 1 2.94 2 4 8 64 U .01 5 ' .94 265 8295 U 0.03 1 tl ~ 2.93 66 8326 t) 0.03 1 t) 2.9 267 8358 t) 0.03 1 Z _' 2.92 268 8389 it 0.02 8 i 2.91 269 8420 t) 0.01 6 ~' 2.94 270 8452 t) 0.01 6 2.94 271 8483 O 0.03 I1 i 2.93 2 72 8514 U 0.02 9 Z 2.94 2 73 8545 t) 0.03 1 t1 ~' 2.93 274 8577 U 0.01 v 1 2.95 275 8608 U 0.02 9 i 2.95 276 86 0 U 0.02 ') ~' 2 94 277 8671 t) 0.04 14 ~ 2.93 278 8703 a 0.01 4 _' .95 279 8734 a 0.01 4 ? 2.96 280 8766 a 0.02 ~) 2 2.95 281 8797 t) 0.02 ~) ? 2.94 82 8829 U 0.02 7 <' 2.95 283 8860 U 0.03 11 2 2.90 284 8892 t) 0.03 12 ? 2.9 285 8923 ll 0.02 9 ~' 2.94 286 8955 t~ 0.01 6 1 2.94 287 8986 t) 0.02 ~) ~ 2.94 88 9017 i) 0.01 h 2.93 289 9049 ~ ~ 0.02 _' 2.93 _ Penetration Body Metal Loss Body Page 6 • PDS REPORT JOINT TABS Pipe: 3.5 in 9.3 ppf L-80 EU MOD Well: Body Wall: 0.254 in Field: Upset Wall: 0.254 in Company: Nominal I.D.: 2.992 in Country: Survey Date: • iLATION SHEET 1 J-03 Kuparuk ConocoPhillips Alaska, Inc USA December 11, 2008 Joint No. Jt. Depth (Ft.) I'~•n. U1,5~•t (ln~.) Pen. Body (Ins.) I'~•n. °~ ~;t~~t,~l I ~~~~ °~~ Min. LD• (Ins.) Comments Damage Profile (%wall) 0 50 100 89.1 9080 t ~ 0 01 6 1 2.92 PUP 289.2 908 U 0 t) l) N A GLM 3 Latch ~ 3:00 289.3 9092 U 0.02 U 2.93 PUP 290 9098 t) 0.02 ~) 2.93 291 9130 U 0.03 11 2.94 292 9161 U 0.0 9 _' 2.94 2 3 9193 t) 0.01 V ~ 2.94 294 9224 t) 0.02 9 I 2.93 29 92 a 0.02 V ' 2.93 296 9287 i) 0.01 5 ~ 2.91 297 9318 i ~ .03 1 1 ~ .95 298 9350 U 0.01 5 _' 2.95 299 9381 t ~ 0.01 (, I 2. 4 300 9413 t) 0.02 ~ 2.94 301 9444 t) 0.03 1 1 2.95 302 9475 t) .03 I ? _' 2.93 303 9507 t ~ 0.03 1 I ? 2.94 304 9537 t) 0.03 13 > 2.92 305 9569 a 0.02 ~) -1 2.93 306 9600 a 0.03 11 2.93 307 9632 O 0.02 ~) 2.92 308 9663 U 0.03 1:1 ~ 2.93 3 9 9694 O 0.03 12 -t 2.93 310 9725 U 0.02 t3 2.93 311 9757 U 0.03 13 -t 2.9 312 9788 tl 0.03 1 u ~ 2.92 13 981 a .03 1O 3 .92 314 9850 U 0.03 1 _', 1 2.92 315 9880 U 0.02 7 2.91 316 9911 a 0.02 ~) a 2.92 317 9942 O 0.02 ~) _' 2.93 318 9974 O 0.03 1 u -1 2.91 319 10005 a 0.05 1 fi -1 2.92 320 10035 U 0.03 11 5 2.95 321 10067 ~) 0.02 ti ? 2.94 322 10098 i) 0.02 ~~ ~ 2.91 323 10129 a 0.03 1,' -J 2.93 324 10161 t) 0.03 I , ~ 2.91 325 10191 a 0.03 I ~ _' 2.94 325.1 10221 l1 0.02 ti ~~ 2.94 PUP 3 5.2 1 227 t) 0 u t) N A GLM 4 Latch ~ 7:30 325.3 10232 t) 0.02 H ~' 2.91 PUP 3 6 10240 a 0.03 12 1 2.91 32 7 102 71 i) 0.02 ~) ; 2.92 328 10303 a 0.02 ~) -1 2.91 329 10333 a 0.03 I U 2.91 330 10364 U 0.02 E~ ~ 2.92 331 10394 t ~ 0.02 i 2.92 332 10425 ~~ 0.03 11 2. 333 10456 t) 0.02 7 ? 2.91 _ Penetration Body Metal Loss Body Page 7 • PDS REPORT JOINT TABI. Pipe: 3.5 in 9.3 ppf L-80 EU MOD Well: Body Wall: 0.254 in Field: Upset Wall: 0.254 in Company: Nominal I.D.: 2.992 in Country: Survey Date: • !CATION SHEET t J-03 Kuparuk ConocoPhillips Alaska, Inc USA December 11, 2008 Joint No. Jt. Depth (Ft.) I'~•n. I)I,~~~i (Irn.j Pen. Body (Ins.) I'c~n. `%> ~,tt~t.il lu„ ~ Min. LD• {Ins.) Comments Damage Profile (%wall) 0 50 100 334 1048 t ~ 0.0 1 i -1 2.92 335 10519 t I 0.03 I ~i ~ 2.91 336 10551 t~ 0.03 11 -1 .92 337 10582 n 0.03 1 ~ 2.93 338 10613 t t 0.02 ~) 2 92 3 9 10644 t ~ 0.04 I t, 2.92 Lt. De sits. 340 10676 ~ ~ 0.03 I 1 2.93 341 10707 t ~ 0.04 I -! 2.93 342 10739 U 0.02 ~~ 2 94 343 10770 a 0.04 I d 2.91 344 108 1 u 0.0 ti 2.93 345 10833 t) .03 I1 2.89 346 108 4 U 0.0 t3 .94 347 10896 U 0.03 I l i > 2. 2 348 10927 (I 0.02 I 2.92 349 10959 t) 0.03 I t I 2.95 350 10990 U 0.03 1 ! i 2.94 350.1 11021 U 0.02 `~ a 2.97 PUP 350.2 11026 tl 0 t) i~ N A GLM 5 Latch~2: 0 35 .3 11033 U 0.06 2 i ; 2.9 PUP Isolated ittin . 351 11042 U 0.05 1 ti 2.95 351.1 11 72 U 0.02 ~> 2.94 UP 351.2 11078 t I 0 t J t ~ 2.81 Camc DS-Ni le No Go 351.3 11079 U 0.04 1(, ~ 2.93 PUP 3 110 5 t ~ 0.05 I `~ 2. 352.1 11116 U 0.06 '-l _' 2.96 PUP Isolated ittin 352.2 11122 u 0 u U 3.00 ak r No Go Loc for 352.3 11131 t? 0 U u 3.00 Baker GBH-22 Seal Assembl 352. 11155 U 0 U u 3.0 Bak r M l Shoe 352.5 11157 U 0 U t t N A Packer 352.6 11166 U 0.03 13 2.95 PUP To of 3.5" Liner 353 1 1 172 (~ 0.04 17 2.96 353.3 11203 U 0 tl U 2.75 Howco XN-Ni le No Go 354 11204 tt 0.04 I ~ I 2.96 Penetration Body Metal Loss Body Page 8 ~~ PDS Report Cross Sections Well: 1J-03 Survey Date: December 11, 2008 Field: Kuparuk Tool Type: UW MFC 24 No. 211387 Company: ConocoPhillips Alaska, Inc. Tool Size: 1.69 Country: USA No, of Fingers: 24 Tubin 3.5 ins 9.3 f L-80 EU MOD _ Analyst: C. Waldrop Cross Section for Joint 350.3 at depth 11038.33 ft Tool speed = 43 Nominal ID = 2.992 Nominal OD = 3.500 Remaining wall area = 95 Tool deviation = 60 ° finger 19 Penetration = 0.064 ins Isolated pitting 0.06 ins = 25% Wall Penetration HIGH SIDE = UP • Cross Sections page 1 ~~ y ~+~ , PDS Report Cross Sections Well: 1J-03 Survey Date: December 11, 2008 Field: Kuparuk Tool Type: UW MFC 24 No. 211387 Company: ConocoPhillips Alaska, Inc. Tool Size: 1.69 Country: USA No. of Fingers: 24 Tubin 3.5 ins 9.3 f L-80 EU MOD Anal st: C. Waldro Cross Section for Joint 352.1 at depth 11121.03 ft Tool speed = 43 Nominal ID = 2.992 Nominal OD = 3.500 Remaining wall area = 99 Tool deviation = 57 ° Finger 23 Penetration = 0.06 ins Isolated pitting 0.06 ins = 24% Wall Penetration HIGH SIDE = UP • Cross Sections page 2 KUP ~ 1J-03 ,~ ConocoPhillips wen Attributes ~ wdmare ARNYeI Rldd name web Status Proton) wex type Inef 1°I ~ 1~1 TD ImaD Irt- al''~'.," p' _ 5002923(X1261 KUPARUK RIVER UNR PROD 102.50 13,585.99 13,585.0 Comment n IP on End a KB 8 die Osle SSSV: NIPPLE 85 7/12008 Las[ WO: 9!G/2005 39.51 3!72001 on ) b Arcot Date Last Tag 11.992.0 7/112005 Rev Reason: SET CAT SV. GLV C/O 11/72008 Casin 3trin p11110 Sd DeP~ 8d 1 ~~~ CONWCTOR, 12o Dex*Won I„1 Itil Top 1EK6) ptKW pal {ms44 o~ade MtMgT llyd CONDUCTOR 2 0 19.020 0.0 120.0 120.0 91.50 H40 WELDED NIPPLE, 539 SURFACE 8 8 8.697 0.0 7, 84.0 4,269.8 40.00 L-80 BTCM PRODUC ION 7 6.16 0.0 11,255.0 6,2 2.3 26.00 L-80 B CM UN 312 .992 11,101.0 12,214.0 6,815.4 9.30 1-80 SLHT GASLIFr. 3,534 LINER TOP Lt 231 8 .992 1,591.0 11,597.0 6,473.3 4.60 E 0 STL Tubi 9Mn s GAS LIFT. i Tung Descdptlon (r4 0n1 T sd mKel 1 P~Ei >~ pbsilry ~1tw Drede Top Thrd e.e1o ° ~ TUBING 31 2.992 0.0 11,161.0 6.21 .4 9.30 L-80 EU MOD Other In Hole A N Jewel : Tu Run d. Retr Fish etc. SURFACE. 1,]el (ND1 Top Top ~) (~) YwJ fl Dea4rlP8on Comment Run Doh D MI GAS uFr, s o91 ~ - 539.0 538.3 5.82 NIPPLE CAMCO'DS' nPPk w!h NO GO profile 3l 1 2.8 5 , 3.534.0 2,509.2 66.17 GAS LIFT CA /KBUGl1/GLV/BK/.125l13181 Conanerd: STA 1 1/112008 2.920 6,910.0 3.908.8 85.80 GAS UFf CAMCO/KBUGl1/GLV/BK/.15&1326/Co~mlenT. STA 2 1/16/2008 2.920 GAS uF], 9 091 0 4 959 9 5 59 GAS U 156/13021 Carrnnent STA 3 CAMCO/KBU 1IGLV/BK/ 1/1 920 2 10,119 , . . . . . . 10,229.0 2.3 52.38 GAS LIFT CAMCO/KBUGItlG V/BKI.188l13071Coenment STA 4 10/1312008 2.920 11,028.0 6.135.9 53.46 GAS LIFT CAMCO/MMGl1.5/OV/RKl.2 /Comment: STA 5 10/30/2008 2.920 Gnsu s ° 11 078 0 165 8 53 30 NIPPLE CAMCO'DS'rlip w/NO GO profile 3/82001 2.812 1° , . , . . 11,078.0 6,165.8 53.30 VALVE AT/SV - SERO @ NO G0 14/292008 0.000 NIPPLE. 11 o]a 11 101 6 179 5 53 23 TlE BA K LI LINE TIE CKSLEEVE 3182001 5.250 , VPLVE, 11,078 , . , . . 11,109.0 6,184.3 3.21 PA KER LINER BAKER 5'7( 'ZXP UNERT PACK K 3182001 4.438 COUPU NG nE BACK, 11,115.0 6,187.9 53.19 HANG L1 UN R BAKER 5'x 7" FLEX-L LINER HANGER 3/ 2001 4. 11,1at ~ 11,122.0 6,192.1 53.17 LOCATOR BAKER NO GO LOCATOR 3!82001 3.000 11.124.0 6,193.3 63.16 SEAL BAKER GBH-22 35' Seal Assembly 3/8/2001 3.000 11 129 0 6 196 3 14 53 SB L1 LINER SBE 8040 82001 4.000 PACKER, . . , . . 11 too 11,161.0 6,215.4 52.75 SHOE BAKER muk shoe 3/81'2001 3.000 11,187.0 6,231.2 52.76 NIP LE LI LINER HOWCO XN NIPPLE w2.75"NO GO 3182001 2.750 RANGER. 1 ,582.0 6,464.7 54.85 L7 PACKER L1 LINER WEATHERFORD SS-WSR-BB LINER TOP 8!222005 1.250 11 ~1s PACKER 11.597.0 6,473.3 54.93 WINDOW L7 L1 WINDOW &2212005 2.992 LocAroR. 11 122 12,146.0 6. 8.4 57.05 COLLAR LIN KER LANDING COLLAR, LJi'f 31812001 . 12,179.0 6,7 4 57.05 COLLAR LINER BAKER FLOAT COLLAR, SLHT 3782001 12.214.0 6.815.4 57.05 SHOE NER BAKER FLOAT SHOE. SLHT 37&2001 SEPL. 11.124 PeAOfBtlOf14 Top l11'W RKE ebn (~) ~B Dare {sh t Top pncei Bhn ( i ( ) ione Date - Cantnet seE.11.1zs 11,606.0 11.616.0 6.478.4 6.484.2 C4, 1J-03 6272001 6.0 APE F 2.5' HSD 60 deg BH-0P chgs sROE, iti61 NIPPLE, 71, 187 11,833.0 11,843.0 6,806.4 6,612.0 A3, 1J-03 523/2001 6.0 IPERF .5" HSD, 60 deg ph, BH-DP Charges PROOUCrIO 5 $~Iryrylg ~pns d~ TrsBtnlB llts Li PACKER, 11,582 1rn lyp ~gbn Tpp peppl De1Ih LINER TOP, 11 590 O•pttl ~ m~ fiVq L1 oeRlor s~o. IpW Idol P~~ IRKW Date comment n ss° 11 592.0 13,967.0 470.4 6 CSAND FRAC 127292007 C-SAND FRA , 147,222p CARB U E, 8 PPA ON uNER roP u' 11.59] , , PERFS °~^NOOw u, 11.606.0 11.616.0 6,478.4 6,484.2 F C 6282001 GSAND FRAC, 58,000N, 16/20 CARBO E, 7 ppe 11.58] APERF, ON PERFS FRAC, 11,806 Notes: Oenanl & IPERF. 11 3311 4 End Dde Annotatlall ,8 8 3 co R 5232001 NOTE: 30 min of SIBHP of 3486 PSI at mid ped uA , 12 14 . . 6 couAR. 11179 916/2005 NOTE: MULTI-LATERAL WELL 1J-03, 1J-03L7, 1J-03L2 LINER, 12T16 TD (1 J03), 12,214 SROE. 17 21d GSANO fRAC . 11591 LINER Li SLOTS. 11 811 I • Maunder, Thomas E (DOA) From: Schwartz, Guy L [Guy.L.Schwartz@conocophilNps.com} Sent: Thursday, February 28, 2008 10:05 AM To: Maunder, Thomas E (DOA) Subject: RE: 1J-03L2 (205-121) Stimulation Attachments: 1J-03L18~L2 final CTD completion.pdf Page 1 of 1 Tom, My apologies... we should be sending these visio sketches with the more complicated wells. I will talk with Sharon and make sure we start doing this to make it easier for everyone!!! The strategy was to stimulate only the upper L2 lateral on 1 J-03. We stung into the Weatherford BB packer just below the L2 junction with the diverter and this hydraulically isolated the lateral. Incidentally ,the L1 lateral is a C sand too. Have a good day!!! Call me if you need further clarification. Guy Schwartz Drilling and Wells Engineer ~~~ FEB f ~ 2~~~ office: 907-265-6958 Cell: 240-5696 ATO-1512 guy.l. schwariz@conocophillips.com From: Maunder, Thomas E (DOA) {mailtoaom.maunder@alaska.gov] Sent: Wednesday, February 27, 2~8 7:45 PM To; Schwartz, Guy L Subject: 1J-03L2 (205-121} Stimulation Hi Guy, Working late trying to clean some stuff out. On the stimulation on this weN, did you really stimulate only 1J-03L2? I can't access the electronic well files right now to get more familiar with the well. Later, Tom 2/29/2008 KRU 1 J-03L1 & L2 Producer Final CTD Completion ~c~r~occ~P~~~ ,alaska, iti~:_. 3-1 /2" Camco DS nipple, 2.875" min ID at 538' MD 3-1/2" 9.3# L-80 EUE 8rd Mod Tubing 3-'/~' Camco KBUG GLM @ 3534', 6910', 9091', & 10229' MD 9-5/8" 40# 3-'/" Camco MMG GLM @ 11028' MD • L-80 7784' Baker ZXP Packer w/SBE @ 11109' MD 7" 26# J-55 11255' MD 3-'/" Halliburton XN nipple, 2.75" min ID @ 11187' MD 2-3/8" Baker deployment sub @ OH sidetrack @ 122 20' and 11590' MD 1 J-03 L2PB1, L2 KOP 11574' MD 3" openhole TD @ 13588' and Window in 3-1/2" - \ ~\ 3-'/" Weatherford SS-WS-R-BB Packer @ 2-3/8" slotted liner ' " \ ~' • 11582 MD, 1.25 minimum ID 1 J-03 L2, " ' shoe @ 13490' and 3/8 Baker deployment sub @ 11592 and L1 KOP 11597' MD Window in 3-1 /2" 3" openhole 1 J-03 L1 shoe @ 12923' and C4 Sand erfs P 3-%2' LSX WS 2-318" slotted liner 3-1/2" 9.3# L-80 FIII 12146' PBTD 08-06-07 • STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION ~ ~~ . 'FHB ~ 7 L(Jll~ REPORT OF SUNDRY WELL OPERAT10111~Ska ~~~ ~ ~~c ~~~~• ~°'~'~"~~`'~'~ 1. Operations Performed: Abandon ^ Repair Well ^ Plug Perforations (~ Stimulate Q ~ ..-....Other Alter Casing ^ Pull Tubing ^ Perforate New Pool [~ Waiver ^ Time Extension ^ Change Approved Program ^ Operat. Shutdown^ Perforate ^ Re-enter Suspended Well ^ 2. Operator Name: 4. Well Class Before Work: 5. Permit to Drill Number: ConOCOPhillips Alaska, InC. Development 0 Exploratory ^ 205-121 / ' 3. Address: Stratigraphic ^ Service ^ 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-029-23002-61 7. KB Elevation (ft): 9. Well Name and Number: RKB 116' 1J-03L2 " 8. Property Designation: L ~6! D ' ~D o ~ 10. Field/Pool(s): ~ Z ~ /~ y.Z7 U ADL 028248 Kuparuk River Field /Kuparuk Oil Pool ' 11. Present Well Condition Summary: Total Depth measured 13586' feet true vertical 6415' feet Plugs (measured) Effective Depth measured feet Junk (measured) true vertical feet Casing Length Size MD TVD Burst Collapse Structural CONDUCTOR 80' 16" 120' 120' SURFACE 7744' 9-5/8" 7784' 4269' PRODUCTION 11215' 7" 11255' 6272' LINER 489' 3-1/2" 11574' 6460' L2 LINER 1900' 2-3/8" 13490' 6423' Perforation depth: Measured depth: 11592'-11655', 11781'-12319', 12414'-12730', 12981'-13457' true vertical depth: 6470'-6492', 6490'-6484', 6484'-6467', 6439'-6424' ~~YY q , ~B~~G.~ ~~~ ~ 7~~J~ Tubing (size, grade, and measured depth) 3-1/2" , L-80, 11161' MD. Packers & SSSV (type & measured depth) Baker ZXP liner top packer ~ 11109' Camco'DS' nipple @ 539' 12. Stimulation or cement squeeze summary: Intervals treated (measured) 11592'-13957' MD Treatment descriptions including volumes used and final pressure: 147,222# carbolite, 8 ppa on perfs 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casin Pressure Tubin Pressure Prior to well operation 159 765 123 -- 196 Subsequent to operation 206 ~ 415 200 - 181 14. Attachments 15. Well Class after work: Copies of Logs and Surveys run _ Exploratory ^ Development ^~ 'Service ^ Daily Report of Weil Operations _X 16. Well Status after work: Oi10 Gas^ WAG^ GINJ^ WINJ ^ WDSPL^ 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: none Contact Guy Schwartz @ 265-6958 Printed Name Guy Schwartz Title Wells Group Engineer ~-y Signature / Phone '~~Y ,~ . ~i`l ,, ~ Date ~ - ~ ` ~~ ~~'- c '' P red b Karon Allsu Drake 263-4612 -- ~~ Form 10-404 evised 04/2006 ~a l~1 Sub Original Only ~~~- 1J-03 Well Events Summary DATE Summary 12/23/07 SET WEATHERFORD COIL DIVERTER (OAL=11'2",2 7/8" G F.N.).SET 2.81" CS-AZ PLUG @ 11078' RKB.PERFORMED NEGATIVE AND POSITIVE TBG TEST.GOOD.SET BAITED 2 1/2" PULLING TOOL ON PLUG FOR CATHERSUB.IN PROGRESS 12/24/07 REPLACED STA #1,2,3,4 1" GLV'S WITH 1" DUMMY'S @ 3534',6910',9091' AND 10229' RKB.IN PROGRESS 12/25/07 PULL 1.5" OV FROM STA #5 @ 11028' RKB.CIRCULATE 65 BBL'S DIESEL FOLLOWED BY 290 BBL'S SEAWATER,THEN 30 BBL DIESEL.SET 1.5" DV @STA #5.PT TBG 3500# WITH 1500# ON lA AND 3500# IA WITH 1500# ON TBG=GOOD.IN PROGRESS 12/26/07 PULLED CATCHERSUB ASSY.PULLED 2.81" CS-A2 PLUG FROM 11078' RKB.DRIFT FOR TREE SAVER TO 10' SLM WITH 2.90" GAUGERING. 12/29/07 PUMP C SAND FRACTURE TREATMENT USING 50# X-LINKED GEL @ 20 BPM. PUMPED A TOTAL OF 165,115# OF 16/20 CARBOLITE PLACING 147,222 # BEHIND PIPE, 72% OF DESIGN. SCREENED OUT INSTANTLY WHEN THE 10 PPA STAGE HIT PERFS. LEFT APPROX. 17,870# OF SAND IN WELLBORE. PUMPED TOTAL OF 1880 BBLS OF SW @ AN AVERAGE TREATING PRESSURE OF 4950 PSI. WELL NOT FREEZE PROTECTED. 12/31/07 INSTALL 1.5" COIL ON UNIT FOR A POST FRAC FCO. 1/4/08 PERFORM POST FRAC FCO DOWN TO TOP OF DIVERTER SET @ 11560' SLM.MADE SEVERAL ATTEMPTS TO GAIN ENTRY THROUGH DIVERTER WITH NO SUCCESS.POOH JETTING TUBING, GLM AND JEWELRY.HAD HEAVY FRAC SAND WITH UNBROKEN GEL DURING FCO.LEFT WELL SHUT IN AND FREEZE PROTECTED 1/6/08 SET 2.79" CATCHER SUB @ 11,187' RKB, ATTEMPT TO PULL 1.5" DV, SET DOWN @ 2400' SLM, CARBOLITE IN KOT, IN PROGRESS. 1/7/08 BAILED FRAC SAND, IN PROGRESS. 1/10/08 BAILED BRIDGE FROM 2413' - 2442' SLM. TAGGED CATCHER SU8 AT 11187' RKB. ATTEMPTED KICKOVER TOOL, UNABLE TO WORK PAST 2480' SLM. ATTEMPTED 2.805" G/R, UNABLE TO WORK PAST 2487' SLM. IN PROGRESS. 1/11/08 BAILED AND BRUSHED FRAC SAND FROM 2400' TO 2900' SLM. PULLED DVs FROM 11208' AND 10229' RKB. SET 1/4" OV AT 11208' RKB. IN PROGRESS. 1/16/08 PULL DGLV'S FROM 9091' RKB AND 6910' RKB. SET 1" LGLV'S AT 10,229' RKB, 9091' RKB AND 6910' RKB. IN PROGRESS. 1/17/08 BAIL FRAC SAND FROM 3541' SLM TO 3559' SLM. BRUSH MANDERAL AT 3534' RKB. PART WIRE LEAVING 28' OF TOOL STRING AND +/- 80' OF WIRE IN HOLE. TAG TOP OF FISH AT 11,154' SLM. BREAK WIRE OFF OF FISH'S ROPE SOCKET W/ BLIND BOX. JOB IN PROGRESS. 1/18/08 RECOVER ALL WIRE AND LOST TOOL STRING FROM WELL. IN PROGRESS. 1/19/08 SET 1" LGLV/BK LATCH AT 3534' RKB. PULL CATCHER SUB. CONFIRM GOOD SET ON NEW GL DESIGN. TURN WELL OVER TO DSO. 1/22/08 DRIFT TBG. W/ 2.66" CENT & 2.5" SAMPLE BAILER TO 2977' SLM-WORK TO 3376' SLM. STILL MAKING HOLE BUT DECIDED TO ABORT TAG DUE TO JARS LOCKING UP. NO SAMPLE OBTAINED. • ~----~ ~I ~onacoPhillips Alaska, tnc, ....~ ... 1 J-03L2 API: 500: TUBING SSSVType: NIP 1a111s1, OD:3.500, iD:2.ssz) Annular Fluid: Reference Lo : 30' E 'i Last Ta -- -- _ Last Tag Date: Casing String - L2 Description Window L2 11574-11575, OD:3.000) 6 .11592-11 55) ICI CAAND ICI FRAC '11592-13957) Pert I y l ,12414-12730) r~~ Perf 12981-13457) • KRU 1 J-03L2 12300261 Well T e: PROD An le TS: d _E Orig 9/6/2006 Angie @ TD: 103 deg @ 13586 Com letion: Last W/O: Rev Reason: C-SAND FRAC <B Ref Lo Date: Last U date: 12/30/2007 TD: 13586 ftK^B _ Max Hole Angle: 103 deg I,W 13586 _ __ SLOTTED LINER {Alternating slotted/solid pipe liner) Size Top Bottom TVD Wt Grade Thread LL JLV 1 ICU LIIVCR L.3/J I IJ`JV IJ-V`U O-iLJ -I.OV L-GU J I L ~ Casih~ String - C©~M(JN STRINGS - - -- --- Descrf lion Size To Bottom TVD Wt Grade Thread SURFACE 9.625 0 7784 4269 40.00 L-80 BTCM PRODUCTION 7.000 0 11255 6272 26.00 L-80 BTCM CONDUCTOR 20.000 0 120 120 91.50 H-40 WELDED LINER -Main Leg Top Portion 3.500 11101 11590 6469 9.30 I-80 SLHT Tubing Stt7nq -TUBING _ _ Size Top Bottom TVD Wt - Grade Thread ~_ 3.500 ~ 0 ~ _11761 ~ 6216 9_._30 ~ L-~0 ~ EU MOD ____ Perforations Summary Interval TVD Zone Status Ft SPF Date T e Comment 11592 - 11655 6470 - 6492 63 40 9/4/2006 SLOTS Alternating Slotted/Bank Pi 11781 - 12319 6490- 6484 538 40 9/4/2005 SLOTS Alternating Slotted/Bank Pi 12414 - 12730 6484 -6467 316 40 9/4/2005 SLOTS Alternating Slotted/Bank Pi 12981 - 13457 6439 - 6424 476 40 9/4/2006 SLOTS Alternating, Slotted/Bank __ _ __ Pipe Stimulations & Treatments Interval Date Type Comment 1159 - 13957 1 J29/2007 C-SAND FRAC --- - C-SAN D FRAC. 147.222# CARBOLITE 2 PPA ON PERFS - - Gas Lift MandrelsNalves --- __ _ St MD TVD Man Mfr Man Type V Mfr __ V Type V OD Latch PoR TRO Date Run Vlv Cmnt 1 3534 2509 CAMCO KBUG DMY 1.0 BK 0.000 0 12/24/200 2 6910 3909 CAMCO KBUG DMY 1.0 BK 0.000 0 12!24/200 3 9091 4960 CAMCO KBUG DMY 1.0 BK 0.000 0 12/24/200 4 10229 5652 CAMCO KBUG DMY 1.0 BK 0.000 0 12124/200 5 11028 6136 CAMCO KBUG DMY t5 RK 0.000 0 12/25/200 Other (Dluas. eauiD.. etc.! -LINER -MAIN LEG De h TVD T e Descn lion ID 11101 6180 TIE BACK LINER TIE BACK SLEEVE 5.250 11109 6184 PACKER LINER BAKER 5" x 7" ZXP LINER TOP PACKER 4.438 11115 6188 HANGER LINER BAKER 5" x 7"FLEX LOCK LINER HANGER w/RS NIPPLE 4.250 11129 6196 SBE LINER BAKER SBE 80-40 4.000 11187 6231 NIP LINER HOWCO XN NIPPLEw/2.75" NO GO 2.750 11574 6460 Window L2 L2 WINDOW 2.992 Other lugs, equip., etc.) - L2 LINER ept I TVD __ Type Description ID 11590 ~ 6469 L2 Dcpl l/ L2 LINER F3TT SEAL BORE DEPLOYMENT SLEEVE wl3" GS PROFLE 1.920 Sub _ _ --- ~Other plugs, - equuu~~ etc. - COMMQN_J_EWELRY DB h TVD T e Descri lion ID 539 538 NIP CAMCO'DS' NIPPLE wlNO GO PROFILE 2.865 11078 6166 NIP CAMCO'DS' NIPPLE w/NO GO PROFILE 2.812 11122 6192 LOCATOR BAKER NO GO LOCATOR 3.000 11124 6193 SEAL BAKER GBH-22 35' SEAL ASSEMBLY 3.000 11161 6216 SHOE BAKER MULE SHOE 3.000 r~eneral Notes DATA SUBMITTAL COMPLIANCE REPORT 10/29/2007 Permit to Drill MD 13586 2051210 Well Name/No. KUPARUK RIV UNIT 1J-03L2 Operator CONOCOPHILLIPS ALASKA INC API No. 50-029-23002-61-00 TVD 6415 Completion Date 9/6/2005 Completion Status 1-OIL Current Status 1-OIL UIC N REQUIRED INFORMATION Mud Log No Samples No Directional Survey Yes DATA INFORMATION Types Electric or Other Logs Run: MWD, GR (data taken from Logs Portio n of Master Well Data Maint Well Log Information: Log/ Electr Data Digital Dataset Log Log Run Interval OH / Type Med/Frmt Number Name Scale Media No Start Stop CH Received Comments f•')=D D Asc Directional Survey 12220 13586 Open 10/4/2005 IIFR Rpt Directional Survey 12220 13586 Open 10/4/2005 IIFR D D Asc Directional Survey 11560 13589 Open 10/4/2005 IIFR Rpt Directional Survey 11560 13589 Open 10/4/2005 IIFR ~I Rpt Las 14207/Induction/Resistivity 11566 13585 Open 11/8/2006 LASGRw/Graphics Log 14207 Gamma Ray 25 Blu 11574 13586 Open 11/8/2006 MD GR 5-Sep-2005 Log 14207 Gamma Ray 25 Blu 11574 13586 Open 11/8!2006 ND GR 5-Sep-2005 Rpt Las 14208E Induction/Resistivity 11579 13589 Open 11/8/2006 PB 1 LAS GR w/Graphics ', Log 14208 Gamma Ray 2 Blu 11574 13589 Open 11/8/2006 P61 TVD GR 30-Aug-2005 Log 14208 Gamma Ray 25 Blu 11574 13589 Open 11/8/2006 P61 MD GR 30-Aug-2005 ~, Rpt 14255 ~°LIS Verification 11579 13589 Open 11/29/2006 PB1 LIS Veri ROP, GR I w/Graphics Rpt 14263 ..~(S Verification 11579 13586 Open 11/29/2006 LIS Veri, ROP, GR ~, w/Graphics Well Cores/Samples Information: Sample Interval Set Name Start Stop Sent Received N umber Comme nts DATA SUBMITTAL COMPLIANCE REPORT 10/29/2007 Permit to Drill 2051210 Well Name/No. KUPARUK RIV UNIT 1J-03L2 Operator CONOCOPHILLIPS ALASKA INC MD 13586 TVD 6415 Completion Date 9/6/2005 Completion Status 1-OIL Current Status 1-OIL ADDITIONAL INFORMATION Well Cored? Y ! N Daily History Received? Y f' Chips Received? "~'~`N-~ Formation Tops Y// N Analysis ~`t1d'- Received? Comments: Compliance Reviewed By: Date: API No. 50-029-23002-61-00 UIC N ~1 ~ J Transmittal Form INTEQ '~ BAKER HUGHES Anchorage GEOScience Center To: AOGCC 333 West 7th Ave, Suite 100 _ ~~~~j Anchorage, Alaska ~_~ ~ ~ ~~ ~ ' 99501 i Attention: Helen Warman _ =~., Reference: 1 J-03L2PB 1 Contains the following: I RE`IIS~D 1 LDWG Compact Disc (Includes Graphic Image files) i 1 LDWG lister summary LAC Job#: 958647 Sent By: Deepa Joglekar Received By: ~ ~~~ , 0 Date: Nov.l7, 2006 Date: PLEASE ACKNOWLEDGE RECEIPT BY SIGNING & RETURNING OR FAXING YOUR COPY FAX: (907) 267-6623 Baker Hughes INTEQ ~aJ "~ ~ ~ ( 7260 Homer Drive Anchorage, Alaska ~ ~~l~j SJ 9918 Direct: (907) 267-6612 FAX: (907) 267-6623 i i ~~ ~~o-~o~~~ ~,..,K , __.~., ~' ~_, F> ~;; ~: ~- , ~:1 I'~` f r'_ ,;~ ~ ~_ -~r.~ - ~, ~' -~-- - - -- -- ~ ~:. _. ` _ ~ ___. ____ ~~ • • Transmittal Form ~i<, BAKER HUGHES INTEQ To: AOGCC 333 West 7th Ave, Suite 100 Anchorage, Alaska 99501 Attention: Helen Warman Reference: 1J-03L2 Anchorage GEOScience Center Contains the following: RE~IISLI~ 1 LDWG Compact Disc (Includes Graphic Image files) 1 LDWG lister summary LAC Job#: 958647 SJ ~ -, - :. - _. 88 ~ Sent By: Deepa Jo lekar Date: Ao~~ 1 ,2006 , Received By: ~, 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 ~3 FAX: (907) 267-6623 -. an i...,., ~ _ --°-- - ,., . _:- I ,,, ~' ~~'3- - 1 ~~;-_ T E ,~ -- ~5 _ ..~ -. 1 t' _:', ~. ,,.. - -- ~~:~__ f: ,: P -, i • • Transmittal Form ~~® gwtna irosona r~ sAKER NU~HES ~ ,~zC INTEQ To: AOGCC 333 West 7`h Ave, Suite 100 Anchorage, Alaska 99501 Attention: Helen Warman Reference: 1 J-03L2PB1 Contains the following: 1 LDWG Compact Disc (Includes Graphic Image files) 1 LDWG lister summary 1 blueline - GR Measured Depth Log 1 blueline - GR TVD Log LAC Job#: 958647 Sent By: Deepa Joglekar Received By: ''~~--- Anchorage GEOScience Center ~ ',=• f. PLEASE ACKNOWLEDGE RECEIPT BY SIGNING & RETURNING OR FAXING YOUR COPY FAX: (907) 267-6623 #. ~ Baker Hughes INTEQ ~~5 - J~ ~ ~ ' ~~~ 7260 Homer Drive Anchorage, Alaska 99518 Direct: (907) 267-6612 FAX: (907) 267-6623 ~~~ '~- r----: - ,, __ i' -_ ~- - ~; ~~ ~~ r.__ ~~ ~~ ~~'~ `,i - - -~ - ~~ - ~~- E G--, -:- ~ -- ~~ . ~,, _- - ', .. • • Transmittal Form ~~-~® @If1 K9 I(bS0 CM1U i Y~0 :,. sAKE~ ~~_ - - ---.~. NU6HES ~r ~ ,~ r `~ INTEQ To: AOGCC 333 West 7th Ave, Suite 100 Anchorage, Alaska 99501 Attention: Helen Warman Reference: 1J-03L2 Anchorage GEOScience Center Contains the following: k~',_ -~ Sent By: Deepa Joglekar Date: ~a~ ~..-~46 ~~ ~'- ~ ~~ ~ rr; - - ~ 1 Received By: ~ Date: ~~ ~ - - - E~_ ,. PLEASE ACKNOWLEDGE RECEIPT BY SIGNING & RETURNING ~`-~~- - ' OR FAKING YOUR COPY ~ FAX: (907) 267-6623 Baker Hughes INTEQ 7260 Homer Drive ~- -- "'` r~ ,~ Anchorage, Alaska ~ =- d ~tJr' 9 ~ , ~ ~f ~0~- 99518 ~ Direct: (947} 267-6612 ~ FAX: (907) 267-6623 j" ` STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMION WELL COMPLETION OR RECOMPLETION REPORT AND LOG Alaska Oil & Gas Cons. Commission Anchorage 1a. Well Status: ®Oil ^ Gas ^ Plugged ^ Abandoned ^ Suspended ^ WAG 20AAC 25.105 20AAC 25.110 ^ GINJ ^ WINJ ^ WDSPL No. of Com letions One p Other 1b. Well Class: ®Development ^ Exploratory ^ Stratigraphic ^ Service 2. Operator Name: Conoco Phillips Alaska Inc. 5. Date Comp., Susp., or Aband. 9!6/2005 12. Permit to Drill Number 205-121 3. Address: c/o P.O. Box 196612, Anchorage, Alaska 99519-6612 6. Date Spudded 8/24/2005 13. API Number 50-029-23002-61-00 4a. Location of Well (Governmental Section): Surface: `2107 FSL 2419' FEL S C 7. Date T.D. Reached , 9/4/2005 14. Well Name and Number: 1J-03L2 , , E . 35, T11 N, R10E, UM Top of Productive Horizon: 4046 FSL, 322' FWL, SEC. 31, T11N, R10E, UM g. KB Elevation (ft): 116.12' 15. Field /Pool(s): Kuparuk River Field /Pool Total Depth: ~ 2236 FSL, 369' FWL, SEC. 31, T11N, R11E, UM 9. Plug Back Depth (MD+TVD) 13586 + 6415 Ft 4b. Location of We11(State Base Plane Coordinates): Surface: x- 558790 ~ y- 5945920 ' Zone- ASP4 10. Total Depth (MD+TVD) 13586 + 6415 Ft 16. Property Designation: ADL 028248 _ TPI: x-^566792 y- 5947925 Zone- ASP4 Total Depth: x- 566855 ~ Y- 5946116 'Zone- ggp4 11. Depth where SSSV set NlA MD 17. Land Use Permit: 18. Directional Survey ®Yes ^ No 19. Water depth, if offshore N/A MSL 20. Thickness of Permafrost 1473 (Approx.) 21. Logs Run: MW D, GR "~~~+~.d•~,,~ f7 S-~'~ ~~~'~ ~~~~' ~'~ ma`y' y y/~' ~~ Lir ~~i 22. ASING, LINER AND CEMENTING RECORD CASING ETTING EPTH MD ETTING EPTH TVD HOLE " AMOUNT SIZE WT. PER FT. GRADE OP OTTOM OP OTTOM SIZE CEMENTING RECORD PULLED 16" 62.5# H-40 Surface 120' Surface 120' 24" 400 sx Arcticset I 9-5/8" 40# L-80 Surface 7784' Surface 4269' 12-1/4" 770 sx AS Lite, 486 sx LiteCrete 7" 26# L-80 Surface 11255' Surface 6272' 8-1/2" 170 sx Class 'G' 3-1/2" 9.3# L-80 11101' 11574' 6180' 6460' 6-1/8" 256 sx Class 'G' 2-3/8" 4.6# L-80 11590' 13490' 6469' 6423' 3" Uncemented Slotted Liner 23. Perforations open to Produc tion (MD +TV D of Top and " " 24. TUBING RECORD Bottom Interval, Size and Number; if none, state none ): SIZE DEPTH SET (MD) PACKER SET (MD) 2-318" Slotted Section 3-1/2", 9.3#, L-80 11161' 11109' MD TVD MD TVD 11592' - 11655' 6470' -6492' 11781' - 12319' 6490' - 6484' 2~j, 14CID, FRACTURE, CEMENT SQUEEZE, ETC. 12414' - 12730' 6484' - 6467' 12981' - 13457' 6439' - 6424' DEPTH INTERVAL MD AMOUNT 8c KIND OF MATERIAL USED 2500' Freeze Protect with Diesel 26. PRODUCTION TEST Date First Production: September 14, 2005 Method of Operation (Flowing, Gas Lift, etc.): Gas Lift Date of Test 9/15/2005 Hours Tested 8.5 PRODUCTION FOR TEST PERIOD OIL-BBL 319 GAS-MCF 898 WATER-BBL 95 CHOKE SIZE 100 GAS-OIL RATIO 2815 Flow Tubing Press. 1 g Casing Pressure CALCULATED 24-HOUR RATE OIL-BBL 900 GAS-MCF 2536 WATER-BBL 267 OIL GRAVITY-API (CORK) 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". None ~ ~~ ~_ ~~ ` , ~. ~s 10D5 ~_.. ~~__b ~-~~,,,. ~~_= Form 10-407 Revised 12/2003 CONTINUED ON REVERSE SIDE r~ 28. GEOLOGIC MARKERS 29' FORMATION 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". Kuparuk B 11653' 6492' None Kuparuk B /Base C4 11722' 6493` Kuparuk B 12747' 6464' Kuparuk B /Base C4 12964' 6441' Top C4 13560' 6420' 30. List of Attachments: Summary of Daily Drilling Reports, Well Schematic Diagram, Surveys 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed Terrie Hubb-e~ ~ Title Technical Assistant Date '~ • ~~'dS 1 J-03L2 205-121 Prepared By Name/Number: Terrie Hubble, 564-4628 Well Number Dolling Engineer: Sean McLaughlin, 564-4387 Permit No. / A royal No. INSTRUCTIONS GeNeaAL: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. IreM 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. IreM 4b: TPI (Top of Producing Interval). IreM 8: The Kelly Bushing elevation in feet above mean low low water. Use same as reference for depth measurements given in other spaces on this form and in any attachments. IreM 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). IreM 20: True vertical thickness. IreM 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. IreM 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). IreM 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, or Other (explain). IreM 27: If no cores taken, indicate "None". IreM 29: List all test information. If none, state "None". Form 10-407 Revised 12/2003 Submit Original Only BP EXPLORATION Page 1 of 19 Operations Summary Report Legal Well Name: 1J-03 Common Well Name: 1J-03 Spud Date: 8/13/2005 Event Name: REENTER+COMPLETE Start: 8/11/2005 End: Contractor Name: NORDIC CALISTA Rig Release: 9/6/2005 Rig Name: NORDIC 2 Rig Number: Date From - To Hours Task Code NPT Phase Description of Operations 8/14/2005 00:00 - 09:00 9.00 MOB P PRE Rig Maintenance finished and ready to move. Presently waiting for Doyon 141 to move onto iJ pad ahead of us. This is a planned event. Rig is on "Stand-by" until Doyon 141, including the Camp is on location at iJ pad and water is delivered to ~ rig/camp facilities. At 09:00 hrs, Doyon rig 141 is on location. Small amount of rigging up before accepting water. 09:00 - 18:30 9.50 MOB P PRE Setting rig mats from Spine RD thru S curves around D pad. Pulled rig off Herculite and cleaned up area. Wait. 18:30 - 19:00 0.50 MOB P PRE PJSM with Toolpusher, SLB Team Leader, BP WSL, rig crew about rig move. 19:00 - 22:00 3.00 MOB P PRE Move rig from Kuparuk iB pad to 1J pad access road turn off at the spine road. 22:00 - 23:00 1.00 MOB P PRE Wait while the drilling tool house shuffles rig mats around for us. 23:00 - 00:00 1.00 MOB P I PRE Move rig from spine road down the 1J pad access road. On rig 8/15/2005 00:00 - 00:40 0.67 MOB P ~ i ~ PRE mats for first 1/4 mile around the S turn. Continue moving down 1J pad access road. Not using rig mats except at culverts and pipeline crossings. 00:40 - 01:00 0.33 MOB P I PRE Arrive at 1J pad with the rig. Avery fast move with surprisingly ' tittle problems on the 1J pad access road. It is a much deeper road than the ones to 1 C pad and 1 F pad that gave us problems last year. Call for trucks to bring camps over. Call for pad operator to do pre rig inspection of well. 01:00 - 03:45 2.75 MOB P i PRE Move in rig camps. Position rig mats around well. Accept rig at 02:00. (Make up some time not counted earlier) 03:45 - 04:00 0.25 MOB P PRE Position rig in front of well. 04:00 -04:15 0.25 MOB P PRE PJSM prior to moving over well. 04:15 - 04:30 0.25 MOB P PRE Position rig over well. 04:30 - 10:00 5.50 BOPSU P PRE Start rigging up and NU BOPE stack. Hoist and secure 2" coil reel. MU inner reel hardline. 10:00 - 14:00 4.00 BOPSU P PRE PT 7-1/16" BOP stack 250psi low / 3500psi high. Test Koomey unit. AOGCC rep Chuck Sheve wavied witnessing. 14:00 - 16:30 2.50 RIGU P PRE RU to pull coil into injector. 16:30 - 16:45 0.25 RIGU P PRE PJSM review stabbing procedures and hazards. 16:45 - 18:00 1.25 RIGU P PRE Stab coil into injector. 18:00 - 19:15 1.25 RIGU P PRE Seal end of eline. 19:15 - 19:20 0.08 RIGU P PRE Reverse circulate mud into coil to fluid pack coil. Shut down pumping to repair leak on pump #1. 19:20 - 19:50 0.50 RIGU N RREP PRE Repair leak on pump #1. Leak repaired. Try to come on line with pump, blew braker. Line up on different charge pump. (Using mixing pump in pits as charge pump). 19:50 - 20:50 1.00 RIGU P PRE Reverse circulate mud into coil. 20:50 - 21:00 0.17 BOPSU P PRE Pressure test inner reel valve to 4000 psi. Passed ok. 21:00 - 21:30 0.50 RIGU P PRE Pump mud reverse circulation to get slack in coil. 21:30 - 21:50 0.33 RIGU P PRE Unstab injector. Cut coil to find end of wire. Cut off 25' of coil. 21:50 - 22:40 0.83 RIGU P PRE Attach Kendel coil connector. Pull test to 35 klbs. 22:40 -00:00 1.33 RIGU P PRE Make up BHI UOC. 8/16/2005 00:00 - 01:20 1.33 RIGU P PRE Finish MU BHI UOC. PT to 3500 psi. Stab on well. Pump forward to finish slack management. 01:20 - 01:40 0.33 STWHIP P WEXIT PJSM. Review deployment proceedure. Assign tasks and review critical areas. Call for pad operator to pump open SSV. Printed: 9M 2/2005 10:06:03 AM BP EXPLORATION Page 2 of 19 Operations Summary Report Legal Well Name: 1J-03 Common Well Name: 1J-03 Spud Date: 8/13/2005 Event Name: REENTER+COMPLETE Start: 8/11/2005 End: Contractor Name: NORDIC CALISTA Rig Release: 9/6/2005 Rig Name: NORDIC 2 Rig Number: Date `From - To, Hours Task Code I NPT I Phase ` Description of Operations 18/16/2005 101:40 - 05:15 I 3.58 ~ STWHIPI P 05:15 - 05:20 I 0.081 STWHIPI P 05:20 - 07:00 f 1.671 STWHIPI P 07:00 - 09:30 I 2.501 STWHIPI P 09:30- 10:20 I 0.831 STWHIPIP 10:20 - 10:40 I 0.33 ~ STWHIPI P 10:40 - 12:30 1.83 STWHIP P 12:30 - 13:00 0.50 STWHIP P 13:00- 15:45 2.75 STWHIP P 15:45 - 17:15 I 1.501 STWHIPI P 17:15 - 19:15 2.00 STWHIP P 19:15 - 19:30 0.25 STWHIP P 19:30 - 00:00 4.50 STWHIP P X8/17/2005 100:00 - 02:30 I 2.501 STWHIPIP 02:30 - 03:45 1.25 STWHIP P 03:45 -04:15 0.50 STWHIP P Q4:15 - 06:15 2.00 STWHIP P 06:15 -06:30 0.25 STWHIP P 06:30 - 08:30 2.00 STWHIP P 08:30 - 09:00 0.50 DRILL P 09:00 - 10:30 1.50 DRILL P 10:30 - 12:30 2.00 DRILL P 12:30 - 13:00 0.50 DRILL P 13:00 - 13:30 0.50 DRILL P WEXIT Pressure deploy BHA #1 to set whipstock for L1 lateral. Pressure on well = 980 psi. ,WEXIT RIH with BHA #1. Have open EDC on tool. Bullheading down the backside to kill the well. WEXIT BHI depth encoder not working. Wait at 200' until they get ~~ them sorted out. Come on line with pumps, pumping down the ', backside to kill the well ~ 3bpm 2200psi. Pumped 150 bbls. WEXIT RIH with open EDC pumping min rate holding 1000psi on well. (Found broken surface wire on BHI equipment. SLB depth counter working after re-booting computer.) WEXIT Log tiein f/ 11500'. Seen good GR spike at 11450' corrected -13'. RIH log CCL to 11620'. See good collars correlations. PU to 11500'. Up weight 30k WEXIT RIH to 11603'. Place TOWS at 11594' and TF at 30deg LOHS. Close EDC. String wt 12500. Pressure up to 3500psi Fury Tool fired. Setdown to 610016s. WS set and in place. SLB previously placed 3 RA tags in WS. WEXIT TOH open EDC. WEXIT PJSM while POOH re: undeployment. WEXIT Undeploy BHA #1, whipstock setting BHA. Note -confirmed with WF hand. The RA tag is 5.7' down from the top of whipstock. WEXIT Deploy BHA #2 to mill window for the L1 lateral. 280 psi on wellhead during deployment. WEXIT RIH with BHA #2, following pressure schedule. WEXIT Log gr tie in from 11,500'. Subtract 14' correction. WEXIT Tag ws at 11597'. Paint flag. Begin to time mill window at 1' per hour. 3990 psi fs at 1.4 in/1.22 out. DPSI: 100-200. DHWOB: 0.8 - 1.5k#. WHP/BHP/ECD: 15/4030/12.3 ppg. IA/OA/PVT: 675/408/437 bbls. Mill to 11600'. WEXIT Continue to mill window. Estimated top: 11597, estimated bottom: 11603'. WEXIT Drill open hole to 11613'. Continue to lose +/- 6 bbls of mud per hour. WEXIT Dress window in up and down directions. Make three complete passes. Drift dry. Appears to be smooth. WEXIT Putl out of hole with milling assembly. Maintain BHP using choke schedule. WEXIT PJSM re: undeployment of BHA #2, window milling BHA. WEXIT Undeploy BHA #2. PROD1 Check MWD toot on catwalk configured for drilling the build section. PROD1 Pressure deploy BHA #3 to drill L1 build section. PROD1 RIH with BHA #3 following pressure schedule with the drilling choke. PROD1 Log tie in pass over GR marker at 11436'. Make -14' correction. PROD1 Begin drilling build section. Free spin 3750 psi at 1.55 bpm. ECD=12.06 ppg. BHP = 3963 psi. 1.55/1.06/3830 psi. Losing 30 bbls an hour at this time. ROP=60 fph. Printed: 9/12/2005 10:06:03 AM BP EXPLORATION Page 3 of 19 Operations Summary Report Legal Well Name: 1J-03 Common Well Name: 1J-03 Spud Date: 8/13/2005 Event Name: REENTER+COMPLETE Start: 8/11/2005 End: Contractor Name: NORDIC CALISTA Rig Release: 9/6/2005 Rig Name: NORDIC 2 Rig Number: Date From - To Hours Task Code NPT Phase Description of Operations 8/17/2005 13:30 - 14:30 1.00 DRILL P PROD1 Losses slowly healing up. 1.55/1.2/4100 psi. 14:30 - 15:30 1.00 DRILL P PROD1 Losses healing, now at 1.58/1.38/3900 psi. 15:30 - 16:30 1.00 DRILL P PROD1 Losses now at 1.5811.45!3944 psi. {AP=707 psi, OAP=495 psi. 16:30 - 18:00 1.50 DRILL P PROD1 Losses pretty good now. 1.57/1.55/3770 psi. 18:00 - 20:15 2.25 DRILL P PROD1 Drill ahead from 11,690'. 4000 psi fs ~ 1.67 in/1.61 out. DPSI: 100-250 DHWOB: 1.Sk - 2.5k#. WHP/BHP/ECD: 22/4050112.22 ppg. IA/OA/PVT: 730/581/480 bbls. ROP varying from 30 to 50 fph. 20:15 - 20:45 0.50 DRILL P PROD1 Putl into casing. Log main wellbore tie in. Add 3' correction. Log RA tag at 11603'. Final TOW: 11,597.6', BOW: 11,603.3, RA tag: 11,603' . Test mud pump #2 while inside casing. Repair minor leak. 20:45 - 00:00 3.25 DRILL P PROD1 Drill ahead to 11,855'. Directional, ROP, WOB all looking good. 8/18/2005 00:00 - 01:00 1.00 DRILL P PROD1 Drill build and turn to 11864'. Have enough turn and angle. 01:00 - 03:00 2.00 DRILL P PROD1 ~ Circulate out of hole. 03:00 - 05:15 ~ 2.25 DRILL P PROD1 'Hold PJSM. Undeploy build BHA (3). MU and deploy L1 lateral BHA (#4). Stab coil. Test MWD. Get on well. 05:15 - 07:20 2.08 DRILL P PROD1 Run in hole. 07:20 - 07:35 0.25 DRILL P PROD1 Log tie in pass accross the RA tag. Make -14'. 07:35 - 10:00 2.42 DRILL P PROD1 Tag bottom 11860'. Begin drilling lateral section. Free spin 3620 psi at 1.57 bpm. Drilling at 1.58/1.43/3800 psi. ECD=12.19 ppg. BHP=4036 psi. Pit vo1=410 bbls. IAP=720 psi, OAP=508 psi. ROP slow and ratty. 10:00 - 10:30 0.50 DRILL P PROD1 11889', lost some returns. 1.5511.0/3700 psi. Little stickey for a moment. Possibly differentially stuck for a moment. Returns slowly healing up. Now at 1.55/1.32/3650 psi. 10:30 - 12:00 1.50 DRILL N HMAN PRODi Surveys are coming in 10 deg different on this run than on run #3 when we drilled the build section. This is the same DGS tool run previously. Resurvey in the build section. Confirms that we are 10 degrees different. Let MW D guys sort out the problem to see if it is on surface. They can't find anything. Take check shots over the entire build section. Check shots show gradually increasing divergence as we get deeper. Log tie in pass to be sure we are on depth. Make +3' correction. Run back to repeat a survey in the build section. Make a flow off survey this time. Found surveys to be in agreement this time. Difference appears to be flow on vs flow off surveys. DD used to working on Nordic 1. Resume drilling. 12:00 - 15:30 3.50 DRILL P PROD1 Resume drilling lateral section. 1.56/1.41/3770 psi. ECD=12.15 ppg, BHP=4012 psi. IAP=730 psi, OAP=576 psi. PVT=367 bbls. Slow drilling. Geo's samples show lots of siderite and gtoconite. That would explain the ROP. 15:30 - 18:00 2.50 DRILL P PROD1 Hit a brick wall. ROP = 0. Sit here and grind away on it for a while. Finally chewed our way thru, and back to making 10 fph. 18:00 - 21:30 3.50 DRILL P PROD1 Drill ahead from 11,951'. 3600 psi fs ~ 1.6 in/1.5 out. DPSI: 200-300. DHWOB: 1k-2k# WHP/BHP/ECD: 25/4033112.22 ppg. IA/OA/PVT: 755/634/297 bbls. INC/AZ1TF: 94.1/6.4/60L. ROP continues to be slow: 15-30 fpm. 21:30 - 22:15 0.75 DRILL P PROD1 Short trip to window. Hole smooth in both directions. Printed: 9/12/2005 10:06:03 AM BP EXPLORATION Page 4 of 19 Operations. Summary Report. Legal Well Name: 1J-03 Common Well Name: 1J-03 Spud Date: 8/13/2005 Event Name: REENTER+COMPLETE Start: 8/11/2005 End: Contractor Name: NORDIC CALISTA Rig Release: 9/6/2005 Rig Name: NORDIC 2 Rig Number: Date From - To Hours Task Code NPT Phase Description of Operations 8/18/2005 22:15 - 00:00 1.75 DRILL P PROD1 Drill ahead from 12,020'. Take on additional mud into pits. Add 4 ppb klagard to new mud. Continue to lose approx 12 bbls per hour of mud. 8/19/2005 00:00 - 03:00 3.00 DRILL P PROD1 Drill ahead from 12,050'. 3600 psi fs ~ 1.62 in/1.55 out. DPSI: 200-300. DHWOB: 1k-3k# WHP/BHP/ECD: 25/3877/11.78 ppg. IA/OA/PVT: 627/181/439 bbls. INC/AZlTF: 95.4/341.0/1208. ROP continues to be slow: 15-30 fpm. Weight transfer good. New mud added to system reduce ECD from 12.2 to 11.8 ppg. 03:00 - 05:00 2.00 DRILL P PROD1 Drill ahead from 12,115'. Fairly consistent ROP of 25 fph. Continue to lose about 10 bbls per hr of mud. ~ 05:00 - 06:00 1.00 DRILL P PRODi Wiper trip to window. 06:00 - 10:30 4.50 DRILL P PROD1 Resume drilling lateral section of hole. ROP=25 fph. 1.62/1.53/3750 psi. IAP=634 psi, OAP=215 psi. PVT=407 bbls. ECD=12.1 ppg. BHP=3990 psi. 10:30 - 10:50 0.33 DRILL P PROD1 Wiper trip to window. Clean off bottom, and clean in open hole. ' 10:50 - 11:10 0.33 DRILL P PROD1 Log tie in pass over RA tag. Make +2 correction. 11:10 - 11:30 0.33 DRILL P PROD1 Continue back in hole. No problems. 11:30 - 15:30 4.00 DRILL P PROD1 Resume drilling. Free spin 3725 psi at 1.6 bpm. Drilling at 1.6/1.54/3900 psi. WOB=2500 psi. PVT=363 bbls. Lost 44 bbls in past 5.5 hours. IAP=640 psi, OAP=233 psi. ECD=12.2 ppg, BHP=4020 psi. ROP = 30-45 fph. 15:30 - 16:30 1.00 DRILL P PROD1 Clean pickup off bottom at 24 klbs. Clean to window and back in hole. 16:30 - 18:00 1.50 DRILL P PROD1 Resume drilling. 1.58/1.52/3904 psi. 18:00 - 20:30 2.50 DRILL P PROD1 Drill ahead from 12,250'. 3999 psi fs ~ 1.57 iM1.48 out. DPSI: 100-200. DHW06:1.75k#. WHP/BHP/ECD: 37/4117/12.46 ppg. IA/OA/PVT: 650/290/304 bbls. INC/AZM/TF: 86.3/0.0/85L. ROP 40-50 fph. Wt transfer good, but ECD high, probably due to mud properties. Call for trucks to swap to new mud system. 20:30 - 22:00 1.50 DRILL P PROD1 Drill ahead from 12,600'. Begin new flo-pro down coil. 4000 psi ~ 1.57 bpm / 12.49 ppg ECD before displacement. 3400 psi ~ 1.54 bpm / 11.8 ppg after mud swap. 22:00 - 23:15 1.25 DRILL P PROD1 Wiper trip to below window. Hole smooth in both directions except for one "bounce" at 12,602' while RIH.. 23:15 - 00:00 0.75 DRILL P PROD1 Drill ahead from 12,620'. 3480 psi fs ~ 1.56 in/1.46 out. 200-400 DPSI. DHWOB as high as 3.3k#. PVT: 473 bbls. BHP/ECD: 3939/11.93 ppg. 8/20/2005 00:00 - 03:00 3.00 DRILL P PROD1 Drill ahead from 12,637'. PVT: 475 bbls. 03:00 - 05:00 2.00 DRILL P PROD1 Drill ahead from 12,720'. 3400 psi fs ~ 1.57 in/1.55out. DPSI: 200-300. DHWOB:1.75k#. WHPlBHPfECD:37/3920111.9 ppg. IA/OA/PVT: 647/278/461 bbls. INC/AZM/TF:86.5/349/908. ROP 25 to 35 fph. 05:00 - 05:50 0.83 DRILL P PROD1 Clean to window, no problems. 05:50 -06:10 0.33 DRILL P PROD1 Make tie in pass over RA tag. Make +6' correction. 06:10 - 11:00 4.83 DRILL P PROD1 Resume drilling lateral section of hole. Free spin 3730 psi at 1.67 bpm. Drilling at 1.67/1.63/3750 psi. WOB=2300 lbs. ECD=11.91 ppg. BHP=3940 psi. IAP=650 psi, OAP=280 psi. PVT=452 bbls. 11:00 - 11:40 0.67 DRILL P PROD1 Slow drilling. 1.60/1.55/3700 psi. PVT=440 bbls. Free spin 3670 psi at 1.6 bpm. Not getting much motor work. WOB=2300 lbs. String wt = -7000 lbs. Stacking max weight at Printed: 9/12/2005 10:06:03 AM BP EXPLORATION Page 5 of 19 Operations Summary Report Legal Well Name: 1J-03 Common Well Name: 1J-03 Spud Date: 8/13/2005 Event Name: REENTER+COMPLETE Start: 8/11/2005 End: Contractor Name: NORDIC CALISTA Rig Release: 9/6/2005 Rig Name: NORDIC 2 Rig Number: Date From - To Hours Task Code NPT Phase Description of Operations 8/20/2005 11:00 - 11:40 0.67 DRILL P PROD1 surface without not much more on WOB sensor. Would like to try getting more weight on bit to see if it will drill better. Mix some Alpine beads and see if it gives us more WOB and the ability to drill a little better. Only averaging 10 fph so far today. 11:40 - 12:05 0.42 DRILL P PROD1 Start pumping 47 bbls of Alpine glass beads (Coarse size). Mixed at 6#/bbl. 12:05 - 12:25 0.33 DRILL N STUC PROD1 Beads to the bit. Pump 20 bbls out, got an additional 10001bs WOB now at 3300 lbs. Make a pickup to check free spin. Can't pick up, and starting to pack off. Returns getting worse the more we pump. Motor and orienter won't turn. BHP =3418 psi. Possibly packed off below the annular pressure sensor. 65 bbls since starting to pump glass beads. 24 bbls out the bit. Pumping more beads below the packed off interval will make ~ it worse. We are about 5' off bottom. 12:25 - 13:10 0.75 DRILL N STUC PROD1 Open EDC. PLF to get remainer of beads above BHA, and to prevent further packing off. Pumping 1.97 bpm, 3800 psi thru ~ an open EDC. Annular pressure transducer = 4080 psi. ~ Transducer is 32' above bit. Probably packed off below pressure transducer. Pump beads out of EDC plus 7 bbls of neat mud behind. Try to shut EDC. It won't close all the way, and is 12% open. Try pumping 2 bbls to flush it clear. Can't pump. Still packed off. At least the EDC is holding. Cycle coil pressure up and down. Can't establish circulation. Try to open EDC. EDC is out of calibration and won't open. A downhole calibration must be done, and there is the risk of disconnecting. Need to establish circulation, so will take the chance. Recalibrate and open the EDC. 13:10 - 15:00 1.83 DRILL N STUC PROD1 EDC open. Circulate bottoms up to get the remainder of the beads OOH, and allow us to work pipe without packing off further up hole. Pumping 2.0/1.56/3900 psi. Holding pipe with maximum stack surface weight. WOB sensor is reacting to the stacked weight we have on it. WOB sensor is 31' off bottom. We are likely stuck on the bottom 31' of BHA. Got bottoms up, but are still getting lots of beads over the shaker. Continue to circulate thru an open EDC until the returns are clean. 15:00 - 15:30 0.50 DRILL N STUC PROD1 Hold PJSM to discuss plan forward. Returns have mostly cleaned up. Still getting a few beads, but not bad. Total of 230 bbls since starting to circulate. Bottoms up volume = 60 bbls. SD pumps. Shut EDC. Pressure up on the backside to 1000 psi. Drop the backside to zero thru the Baker choke while holding 4000 psi an the coil. Repeat while trying to turn the HOT. Try 3 times. No luck. Try 1500 psi on the WHP then dumping thru the Baker choke. Holding maximum stacked weight at surface. Might be making a small amount in the hole as we cycle pressure. 10 klbs on WOB sensor. Start depth 12840.1'. 15:30 - 16:00 0.50 DRILL N STUC PROD1 Continue to cycle WHP to 1500 psi, while holding maximum stacked weight, and 4000 psi on coil. Depth now 12842.4'. Possibly just helic'ing the pipe in the hole. WOB now 11400 lbs. Have cycled WHP 20 times with no improvement. Line up to use a 1/4 turn valve instead of the Baker choke. Continue to surge WHP from 1500 psi to 0. Surge it 10 more times. No Printed: 9/12/2005 10:06:03 AM BP EXPLORATION Page 6 of 19 Operations Summary Report Legal We11 Name: 1J-03 Common Well Name: 1J-03 Spud Date: 8/13/2005 Event Name: REENTER+COMPLETE Start: 8/11!2005 End: Contractor Name: NORDIC CALISTA Rig Release: 9/6/2005 Rig Name: NORDIC 2 Rig Number: Date From - To Hours Task Code NPT Phase Description of Operations 8/20!2005 15:30 - 16:00 0.50 DRILL N STUC PRODi luck. Coil pressure holding steady. Can't get flow pass the packed off interval. Still seeing pressure on BHP sensor, and WOB on DH WOB sensor. Packed off interval is below these sensors. 16:00 - 16:45 0.75 DRILL N STUC PROD1 Bleed coil and WHP off. Pull to maximum sate pull of 60 klbs. DH WOB went from 8500 Ibs compression to 5700 Ibs tension. Continue working pipe up and down to maximum overpull. Work 5 times. Slacking off quickly to maximum stacked wt. Seeing overpull and slackoff on WOB sensor. Pull to 60 klbs. Hold for 5 minutes. Unable to pull free. Consult with town. ~ Give EDC the order to disconnect. Note - It may not mean anything, but the drilling choke plugged off at one point during the previous 4 hours operations. When the choke was cycled a lot of paint chips came over the shaker. ~ The mud pits were painted during summer shutdown. 16:45 - 19:30 2.75 FISH N STUC PROD1 PU at 30 klbs. (Pumps off). Confirmed free. Kick on pumps. POH pumping at 2 bpm. PU weight with pumps on is 24 klbs. No problems in open hole, or in the B shale interval. 19:30 - 19:45 0.25 FISH N STUC PROD1 At surface. Close master with 650 psi on well. Flow check well. Repair loose control panel valve on Swaco choke. Get off well. Unstab coil. LD mwd tools. Check and clean high pressure filters on pumps and in reel house. 19:45 - 22:00 2.25 FISH N STUC PROD1 Hold PJSM to discuss deployment. MU Fishing BHA #1 (2-1/2" GS spear w/jars etc) with EDC & Power Comms. Deploy BHA. WHP: 615 psi. 22:00 - 00:00 2.00 FISH N STUC PROD1 RIH maintaining BHP schedule. Circ at min rate while RIH. Full rtns. 8/21/2005 00:00 - 01:00 1.00 FISH N STUC PROD1 RIH with GS spear fishing assembly. Subtract 14' correction. Run in open hole at 35 fpm. 1750 psi ~ 0.57 in. Continue full rtns. Continue RIH. 01:00 - 01:15 0.25 FISH N STUC PROD1 RIH thru B shale ok. Check weight above fish. Up wt =25 klbs, down wt = 8 klbs. Lost 12 bbls of mud while RIH. pumping 0.58 bpm, 1800 psi. Tagged top of fish at 12,794'. Stack 3000 Ibs down. WHP=650 psi, 0 bpm. Jar #1. Came free on first lick. POOH to 12735', pick up clean. RIH, set back down on fish. Pulled out of GS the first time. Tag again at 12,794'. PU to 35 klbs. Jar #2 35 klbs. No jar action. Set down to -2000 lbs. Jar #3 PU to 40 klbs no jar action. Set down to cock jars again. Jar #4 PU to 60 klbs. Jar lick, fish came free. Pull up hole 5-8 klbs drag, with erratic wt. Looks like pulling BHA thru fill. Run back in hole set down at 12,788'. Work fish up hole again. 39 klbs up wt. then 30 klbs up wt. 25 klbs normal up wt with 5 klbs drag. POOH to 12697' 01:15 -04:15 3.00 FISH N STUC PROD1 Release from fish with GS. Pump 1.1 bpm ~ 2300 Ibs. 25 klbs up wt. Line up KWF in pits and trucks. Circ ~ minimum rate with 1700 psi ~ 0.36 inl0.16 out. Pump 10 bbls high vis sweep. Pump 10.3 ppg KWF at 3780 psi at 1.44 bpm. Slow rate to 1.0/0.75 as KWF comes up back side. Final rate: 0.5 in/0.3 out. Printed: 9/12/2005 10:06:03 AM BP EXPLORATION Page 7 of 19 Operations Summary Report Legal Well Name: 1J-03 Common Well Name: 1 J-03 Spud Date: 8/13/2005 Event Name: REENTER+COMPLETE Start: 8/11/2005 End: Contractor Name: NORDIC CALISTA Rig Release: 9/6/2005 Rig Name: NORDIC 2 Rig Number: Date From - To Hours Task Code NPT Phase I Description of Operations 8/21/2005 04:15 - 04:30 0.25 FISH N STUC PROD1 RIH at 0.5 bpm ~ 1400 psi. Tag and latch fish at 12,697'. ' 7200 Ibs down wt, 28 klbs up wt. 04:30 - 07:15 2.75 FISH N STUC PROD1 Pull out of open hole and window at 30 fpm. Holding 500-600 psi on WHP pumping down the backside to keep the hole full and maintain 10.8 to 11.0 ppg BHP. 07:15 - 07:45 0.50 FISH N STUC PROD1 PJSM Re: Laying down fishing BHA. Perform flow check while holding PJSM. 07:45 - 09:50 ~ 2.08 FISH N STUC PRODi No flow observed. Stand back injector. lay down BHA. j Recovered fish. All recovered, nothing left in hole. Bit ~ recovered graded 1,1. Motor locked up and won't tum. BHI i MWD tools above motor full of mud with beads in suspension. After breaking MWD off of motor got 2 gallons of mud with beads out of MW D tools. Top of motor had beads. Bit had clay balls on bit. Geo examined sample from bit. See remarks ~ section of this report for detailed analysis of sample from bit. 09:50 - 10:25 i 0.58 FISH P PROD1 Hold pad evacuation drill in conjunction with Doyon 141, Construction crews on pad, and with pad operator. The well was secured. All hands responded to drill including Vac truck drivers on location supporting rig. All hands accounted for. Rig evacuated, pad operator notified, and drill was concluded with 10:25 - 10:45 ~I 0.33 FISH N STUC PROD1 no significant action items. Make up new BHI MWD tool and check on the catwalk. 10:45 - 11:45 j 1.00 DRILL N STUC PROD1 MU BHA. Using same bit as last run, new motor, and Agitator. Took BHI checks out of the UOC, and did not run the DFV. Using dart style check vavles from Baker TT. 11:45 - 12:00 0.25 DRILL N STUC PROD1 Stab tools, stab injector. Perform shallow hole test at surface of BHI eq. Passed ok. 12:00 - 12:15 0.25 DRILL N STUC PROD1 RIH to 500'. Kick on pumps. Pump thru the motor to test Agitator tool. Got good responce on horses head. I'm picking up good vibrations. 12:15 - 14:25 2.17 DRILL N STUC PRODi RIH with BHA #6 to finish drilling the lateral section. 14:25 - 14:55 0.50 DRILL N STUC PROD1 Log tie in pass over RA tag. Make -17' correction. 14:55 - 15:50 0.92 DRILL N STUC PROD1 RIH to resume drilling lateral section. Pumps to full rate with the EDC closed. 1.57/1.31/4025 psi. Displacing KWF OOH and pumping 8.7 ppg mud. No problems down thru the B shale. No problems in open hole. Make frequent pickups and ease down slow the fast 150' to flush debris uphole. Wt check at 12700' = 23 klbs. 15:50 - 18:00 2.17 DRILL P PROD1 Free spin = 4000 psi at 1.57 bpm. Begin drilling at 12844'. 1.58/1.53/4300 psi. Good motor work. We weren't getting much motor work on the last run, thats why we pumped the glass beads. String wt = 0. We have improved 7000 Ibs over last lateral run. DH WOB is 2500 Ibs, virtually identical to the last run. Drilling at 30-50 fph. There is a definite and significant difference in our ability to drill now compared to the last lateral run. W e have good and consistent motor work, and we have much better string wt. at surface. 18:00 - 23:15 5.25 DRILL P PROD1 Drill ahead from 12,890'. 3800 psi fs ~ 1.53 iN1.48 out. OPSI: 100-200. DHWOB: 1.5 - 2.25k#. WHP/BHP/ECD: 51/4038!12.20 ppg. WOA/PVT: 657/276/331 bbls. INC/AZMlfF: 83.7/27.9/1208. ROP fairly consistent at +/- 25 fph. Weight transfer adequate. Printed: 9/12/2005 10:06:03 AM BP EXPLORATION Page 8 of 19 Operations Summary Report Legal Well Name: 1J-03 Common Well Name: 1J-03 Spud Date: 8/13/2005 Event Name: REENTER+COMPLETE Start: 8/11/2005 End: Contractor Name: NORDIC CALISTA Rig Release: 9/6/2005 Rig Name: NORDIC 2 Rig Number: Date From - To Hours Task Code NPT Phase Description of Operations 8/21/2005 23:15 - 00:00 0.75 DRILL P PROD1 Wiper trip to window while town evaluates logs for TD. Hole smooth except for one weight bobble and slight motor work at +/-11,705'. 8/22/2005 00:00 - 00:15 0.25 DRILL P PROD1 Log gr tie in across RA tag. Add 1' correction. 00:15 - 01:00 0.75 DRILL P PROD1 Wiper trip back to btm. Several minor weight bobbles between 12,500' and 12,590'. Otherwise hole smooth. 01:00 - 03:45 2.75 DRILL P PROD1 Drill ahead from 13,000'. Planned TD is to drill to 13,050'. 3875 psi fs ~ 1.48 in/1.38 out. DPSI: 100-200. DHWOB: 1.22k#. PVT: 297 bbls. ROP very slow from 13030'. Hofe getting sticky too. Drill to 13035'. Call TD. 37k# pick up off btm. 23k# normal up wt. 03:45 - 05:15 1.50 DRILL P PROD1 Wiper trip to window. Mix 30 bbl 10.3 ppg pill with 6 ppb coarse Afpine beads while tripping. Hole smooth out. Wiper trip in hole to 12,950'. 05:15 - 05:45 0.50 DRILL P PROD1 Open EDC. Displace KWF bead pil down coil while moving pipe near btm. 05:45 - 08:30 2.75 DRILL P PROD1 Pull out of hole laying in bead pill. 2450 psi ~ 1.1 bpm. No weight bobbles, no problems pumping 48 bbls of bead pill thru an open EDC. 08:30 - 08:50 0.33 DRILL P PROD1 Tag up at surface. Hold PJSM prior to laying down BHA. Flow check well. No flow observed. 08:50 - 09:45 0.92 DRILL P PROD1 Lay down BHA #6. Bit recovered graded same as last run, 1,1. 09:45 - 10:30 0.75 CASE P RUNPRD Configure BHI MW D tools for running with liner. Check out electrically. All checks ok. Rig crew performed weekly function test of ROPE. 10:30 - 10:50 0.33 CASE P RUNPRD PJSM prior to running liner. All hands on rig in attendence. Topics discussed: Well has been flow checked and is static. Safety joint is ready. Use lifting nubbins and dog collar when making up liner with no cementralizers or upsets. Watch out for overhead loads and pinchpoints. Take your time and operate safely. Keep the hole full. 10:50 - 13:00 2.17 CASE P RUNPRD Pick up 2-3/8" liner string as per proceedure and Geo's instructions from town. Liner run as follows; BTT deployment sleeve 2-3/8" Solid Tubing (250.97') 2-3/8" Slotted Tubing (443.68') 2-3/8" Solid Tubing (62.77') 2-3/8" Slotted Tubing (539.42') BTT O-Ring sub 2-3/8" Solid Tubing (31.23') BTT Unique Biased Edge Guide Shoe Overall Liner length = 1331.45' Top of liner to be at 11590' Bottom of liner to be at 12921.45' 13:00 - 13:30 0.50 CASE P RUNPRD PU BHI MWD tools. Stab coil. Stab injector. 13:30 - 16:25 2.92 CASE P RUNPRD RIH with liner on coil tubing. Wt check with bottom of liner at window. Up wt = 24500 Ibs, down wt=7500 lbs. Check window flag at 11573.3' (10200' EOP). Make -24' correction. RIH. Smooth thru the window. Smooth thru the B shale interval. Smooth in open hole. Log down from 12750' to see GR marker Printed: 9/12/2005 70:06:03 AM BP EXPLORATION Page 9 of 19 ~ Operations Summary Report Legal Well Name: 1J-03 Common Well Name: 1 J-03 Spud Date: 8/13/2005 Event Name: REENTER+COMPLETE Start: 8/11/2005 End: Contractor Name: NORDIC CALISTA Rig Release: 9/6/2005 Rig Name: NORDIC 2 Rig Number: Date From - To Hours Task Code NPT Phase Description of Operations 8/22/2005 13:30 - 16:25 2.92 CASE P RUNPRD on BHI GR tool. Logging down at 150 fph, 6400 Ibs string wt. Make +9' correction. Total correction now is -15', comparable i to previous runs (-14' typically). RIH. Position guide shoe at 12921.45'. WOB sensor reads 3700 Ibs, String wt RIH is 6000 lbs. Bring pumps to 1.5 bpm, 4200 psi. PU at 22 klbs. Liner free. Slickest liner I have ever run in Kuparuk. We only lost 1500 Ibs of RIH wt from the window to TD. Due to Alpine beads? 16:25 - 16:50 0.42 CASE P RUNPRD Pull back up above GR marker. Log down from 12750' to verify i top of liner. Tagged top of liner at 11592'. 16:50 - 18:30 1.67 CASE P RUNPRD POH to pick up L2 whipstock anchor. 18:30 - 19:00 0.50 CASE P RUNPRD At surface. Hold PJSM to discuss BHA handling while flow i i checking well. I Get off well. Unstab coil. LD liner running BHA. 19:00 - 20:30 1.50 WHIP P j WEXIT ~ MU MWD tools on catwalk. Check Weatherford tools. PU ~ ~ ~ {toots. Orient packer slot to 0 deg on HOT orienter. 20:30 - 22:00 , 1.50 WHIP P I !WEXIT Stab coil. Check MWD tools. Get on well. Run in hole. 22:00 - 23:30 ~ 1.50 WHIP N j DFAL ~ WEXIT , MWD tools acting up. First drawing too much current, now unable to power up tools at all. Pull out of hole to check out MWD. 23:30 -00:00 0.50 WHIP N DFAL WEXIT At surface. Get off well. Unstab coil. Begin testing MWD. 8/23/2005 00:00 - 01:30 1.50 WHIP N DFAL WEXIT Continue to trouble shoot MWD tools at surface. Found shorts in UOC and LOC, but still experiencing problems after repaving shorts. 2nd problem found to be surface softwear. Correct same. Stab coil. Get on well. 01:30 -04:30 3.00 WHIP P WEXIT Run in hole at reduced rate due to packer slips & element. 04:30 -04:45 0.25 WHIP P WEXIT Log GR tie in from 11,450'. Subtract 15' correction. 04:45 - 05:15 0.50 WHIP P WEXIT RIH to setting depth. 8.5k# dn, 27.5k# up wt. Packer btm at 11,585'. Pull 20k# up wt. Close EDC. Pressure up down coil to 4400 psi. Set WS anchor. Set down on Ws with 3000 Ibs. Confirmed set. 05:15 - 07:00 1.75 WHIP P WEXIT POH with WS anchor setting BHA. 07:00 - 07:15 0.25 WHIP P WEXIT Hold PJSM while POOH with setting BHA to discuss swapping BHA's. 07:15 - 08:30 1.25 WHIP P WEXIT Tag up at surface. Lay down WF whipstock anchor setting BHA (BHA #9). Pick up hollow tray and jars, BHA #10. 08:30 - 12:00 3.50 WHIP P WEXIT RIH with WF whipstock 12:00 - 12:25 0.42 WHIP P WEXIT Tie in 11450' Correct -16' , 25,600# up wt, 6300# do wt 12:25 - 12:45 0.33 WHIP P WEXIT Tag top of WF anchor packer 11584', Set 4K dn, Pick up to 29,500#, Pick up to 33,000# Jar went off WS released, PT to 500# then 1000# hold 5 minutes 12:45 - 14:30 1.75 WHIP P WEXIT POOH Pump 1.25BPM 3200# CP run trip sheet 14:30 - 15:15 0.75 STWHIP P WEXIT At surface. Get off well. Unstab coil. LD Weatherford tools. Remove orienter from MWD. 15:15 - 16:00 0.75 STWHIP P WEXIT MU window milling assy (Baker motor w/ DSM and string reamer.) Stab coil. Test MWD. Get on well. 16:00 - 18:30 2.50 STWHIP P WEXIT Run in hole. Load 8.7 ppg flo pro into pits to prep for mud change. Install softwear mods in SLB Ops Cab computer. 18:30 - 18:45 0.25 STWHIP P WEXIT Log gr tie in from 11,450'. Subtract 16' correction. Continue displacing 10.3 to 8.7 ppg mud. Printed: 9/12/2005 10:06:03 AM BP EXPLORATION Page 10 of 19 Operations Summary Report Legal Well Name: 1J-03 Common Well Name: 1 J-03 Spud Date: 8/13/2005 Event Name: REENTER+COMPLETE Start: 8/11/2005 End: Contractor Name: NORDIC CALISTA Rig Release: 9/6/2005 Rig Name: NORDIC 2 Rig Number: Date From - To Hours Task Code NPT Phase Description of Operations 8/23/2005 18:45 - 22:20 3.58 STWHIP P WEXIT Tag whipstock at 11,574'. Paint flag at 11,573.8'. 3600 psi fs ~ 1.51 bpm. Begin time milling at 1.0' per hour. Finish displace 10.3 to 8.7 ppg mud. PVT: 329 bbls 22:20 - 23:00 0.67 STWHIP P WEXIT Mill window from 11577.7' 1.5/3450 w/ 150 psi dill, 1-2k wob, ECD 12.07 PVT 327 23:00 - 00:00 1.00 STWHIP P WEXIT 11578.5' had MW, then str wt incr, plus started losing fluid 1.5/1.38 Drill to 11579.5' and losses stopped PVT 323 8/24/2005 00:00 - 01:40 1.67 STWHIP P WEXIT Drill formation 11579.5' to 11590' 1.6711.58 w/ 400# dill, 2-3k wob, 12.2 ECD PVT 316 01:40 - 02:15 0.58 STWHIP P WEXIT Ream and backream window three times and clean. Dry tag, clean PVT 315 02:15 - 04:10 1.92 STWHIP P WEXIT POOH following pressure schedule PVT 270 04:10 - 05:00 0.83 STWHIP P WEXIT Pressure undeploy w/ 435 psi WHP 05:00 - 05:30 0.50 STWHIP P WEXIT LD, load out milling tools. Mills were 2.74" no-go, 2.73" go 05:30 - 07:30 2.00 DRILL P PROD2 MU build assy. Pressure deploy BHA. Stab coil. Test MWD. Get on well. 07:30 - 10:00 2.50 DRILL P PROD2 Run in hole following pressure schedule. 10:00 - 10:15 0.25 DRILL P PROD2 Log gr tie in from 11450'. Subtract 16' correction. RIH. 10:15 - 10:30 0.25 DRILL P PROD2 RIH through window ok. Close EDC. 10:30 - 15:15 4.75 DRILL P PROD2 Drill ahead from 11590'. 3850 psi fs C~1 1.63 iN 1.48 out. DPSI:100-250. DHW06:2-3k#. WHP/BHP/ECD: 25/3970/12.1. IA/OA/PVT: 634/232/309 bbls. INC/AZM/TF: 56/ /30R. ROP variable: 10 to 40 fph. Getting +/- 40 deg avg dog legs. One accelerometer has failed in DGS tool. Cannot get good surveys. 15:15 - 17:15 2.00 DRILL N DFAL PROD2 POOH to change out MWD DGS tool. 17:15 - 19:00 1.75 DRILL N DFAL PROD2 At surface. Hold PJSM. Undeploy BHA w/ 420 psi WHP. 19:00 - 20:00 1.00 DRILL P PROD2 Cut off CTC. Stab onto lubricator. Reverse circ slack back into coil 20:00 - 21:30 1.50 DRILL P PROD2 RU cutter on rig floor. Cut off 75' to find end of wire. Cut off additional pipe for wear management (cut a total of 500'). 21:30 - 23:00 1.50 DRILL P PROD2 Install Kendal connector. PUII test to 37k#. Meg test good. Head up BHI. Pressure test to 4000 psi. 23:00 - 00:00 1.00 DRILL N DFAL PROD2 Pressure deploy build assembly. SIWHP: 200 psi. 8/25/2005 00:00 - 00:40 0.67 DRILL N DFAL PROD2 Continue to pressure deploy build assy (BHA #13, 2.4 mtr w/ HYC bi cent). PVT: 220 bbls 00:40 - 02:40 2.00 DRiLt N DFAL PROD2 Run in hole following BHP pressure schedule. 02:40 - 02:55 0.25 DRILL N DFAL PROD2 Log gr tie in. Subtract 14' correction. RIH. Tag TD at 11,666'. 02:55 -04:00 1.08 DRILL P PROD2 Drill ahead f/ 11,666'. 1.6/1.4/3900. 100-300 psi dill. 2-4k# WOB. 12.46 ECD. PVT: 231 bbls 04:00 -04:10 0.17 DRILL P PROD2 Wiper trip through window. Open EDC. 04:10 -06:15 2.08 DRILL P PROD2 Pull out of hole for BHA change. Follow BHP schedule. PVT: 190 bbls at surface. 06:15 - 07:15 1.00 DRILL P PROD2 Hold PJSM. Undeploy build assy. LD motor and bit. 07:15 - 09:00 1.75 DRILL P PROD2 Re head coil and test same. 09:00 - 10:00 1.00 DRILL P PROD2 Pressure deploy BHA #14 (0.8 deg mfr w/ HCC bicent) 10:00 - 12:45 2.75 DRILL P PROD2 Stab coil. Test MWD. Get on well. RIH following BHP schedule. 12:45 - 13:00 0.25 DRILL P PROD2 Log gr tie in f/ 11450'. Subtract 15' correction. RIH to TD at 11,690' 13:00 - 16:30 3.50 DRILL P PROD2 Drill ahead f/ 11,690'. 3800 psi fs ~ 1.56 iN1.41 out. DPSI: 100-250. DHW06:1.5-2.5k#. WHP/BHP/ECD: 30/4132/12.5 Printed: 9/12/2005 10:06:03 AM BP EXPLORATION Page 11 of 19 Operations Summary Report Legal Well Name: 1J-03 Common Well Name: 1 J-03 Spud Date: 8/13/2005 Event Name: REENTER+COMPLETE Start: 8/11/2005 End: Contractor Name: NORDIC CALISTA Rig Release: 9/6/2005 Rig Name: NORDIC 2 Rig Number: Date From - To Hours Task Code NPT Phase Description of Operations 8/25/2005 13:00 - 16:30 3.50 DRILL P PROD2 ppg. IA/OA/PVT: 640/256/252 bbls. INC/AZM/TF: 93.7/137/958. ROP: 40-50 fph. PVT 231 16:30 - 17:55 1.42 DRILL P I PROD2 Drill ahead f/ 11,815'. Hitting some hard spots. Drill to 11850'. PVT 215 17:55 - 18:20 0.42 DRILL P PROD2 Wiper to window PVT 209 18:20 - 22:10 3.83 DRILL P PROD2 Drill from 11850' 1.57/1.42/3830/758 w/ 100-300 psi dill, 1.5-2.5k wob, 12.5 ECD with frequent sharp stalls to 12000'. Had penetration rate incr last 50'. Start new mud-recip while fin circ fresh mud to bit 22:10 - 22:40 0.50 DRILL P ~ PROD2 Wiper to window while fin displace wellbore to fresh mud w/ 12 ppb KG/3% LT 22:40 - 00:00 1.33 DRILL P PROD2 Drill from 12000' 1.6/3600/908 with full returns at 11.8 ECD w/ 100-200 psi dill, 1-3k wob. Drill to 12050' and start losing 0.3 bpm w/ ECD ~ 11.53. Retum rate gradually improved to 1.54/1.36 by 12078' 8/26/2005 00:00 - 01:40 1.67 DRILL P ~ PROD2 Continue drilling from 12078' 1.52/1.40/3350/608 w/ 100-200 psi dill, 1-2k wob, ECD 11.75 C~3 3876 psi DHP at 92 deg and 01:40 - 02:10 0 50 DRILL ~ P ~ ~ ~ 6365' TVD. Drill to 12150' PVT 452 ' . ~ PROD2 Wiper thru window, clean. Wiper to 11300 02:10 - 02:25 0.25 DRILL ~ P PROD2 Log tie-in down from 11450'. Add +3' 02:25 - 02:50 0.42 DRILL P PROD2 RIH thru window, clean. Wiper to TD, clean PVT 442 02:50 - 05:40 2.83 DRILL P i PROD2 Drill from 12152' 1.56/1.46/3430!708 w/ 100-250 psi dill, 1-2k wob, 11.77 ECD at 89 deg C~3 6365' TVD in 90 api rock 05:40 - 06:15 0.58 DRILL P PROD2 Drill on a hard spot from 12254' and losses slowly increasing 1.56/1.3 06:15 - 07:15 1.00 DRILL P PROD2 Drill ahead from 12,268'. 3300 psi fs ~ 1.58 inl1.41 out. DPSI: 150-250. DHWOB: 0.8 - 2.Ok#. WHP/BHP/ECD: 18/3872/11.74 ppg. IA/OA/PVT: 660/360/410 bbls. INC/AZMlTF: 91.3/190.2/358. ROP continues to avg 40-50 fph. 07:15 - 08:15 1.00 DRILL P PROD2 Wiper trip to window. Hole smooth. 08:15 - 15:00 6.75 DRILL P PROD2 Drill ahead from 12,300'. ROP slowed to 15-20 fph. Drilling lots of hard spots. 3500 psi fs ~ 1.58 in/1.35 out PVT: 358 bbls. 15:00 - 16:00 1.00 DRILL P PROD2 Drill ahead from 12,425'. 3500 psi fs ~ 1.57 in/1.36 out. PVT: 295 bbls. WHP/BHP/ECD: 26/3968112.04 ppg. 16:00 - 17:00 1.00 DRILL P PROD2 Wiper trip to window. Hole smooth. 17:00 - 20:00 3.00 DRILL P PROD2 Drill ahead from 12,450' 1.56/1.43/3500/160L w/ 100-200 psi dill, 1-3k wob w/ 11.6 ECD at 88 deg at 6360' TVD. Add fresh mud to system after PVT at 250 bbls 20:00 - 23:15 3.25 DRILL P PROD2 Drill from 12500' 1.56/1.50/3300/708 w/ 100-200 psi dill, 2-3k wob w/ 11.33 ECD while continue adding fresh mud unfit PVT 477. Drill to 12600' 1.56/1.25 w/ 12.0 ECD w/ used mud PVT 446 23:15 - 00:00 0.75 DRILL P PROD2 Wiper thru window was clean 8/27/2005 00:00 - 00:15 0.25 DRILL P PROD2 Log down from 11450', add 3.0' 00:15 - 01:05 0.83 DRILL P PROD2 Wiper to TD, clean except for set down and stall at 12502' w/ TF 90 deg out 01:05 - 02:25 1.33 DRILL P PROD2 Drill from 12601' 1.58/1.29/3750/758 w/ 100-200 psi dill, 1-2.Sk wob w/ 11.98 ECD at 3946 psi DHP at 87 deg and 6368' TVD with stow progress due to stacking, then stalls. Numerous stalls at 12608'. Acts like rubble zone-are also near a projected fault Printed: 9M 2/2005 10:06:03 AM BP EXPLORATION Page 12 of 19 Operations Summary Report Legal Well Name: 1J-03 Common Well Name: 1J-03 Spud Date: 8/13/2005 Event Name: REENTER+COMPLETE Start: 8/11/2005 End: Contractor Name: NORDIC CALISTA Rig Release: 9/6/2005 Rig Name: NORDIC 2 Rig Number: Date From - To Hours Task Code NPT Phase Description of Operations 8/27/2005 02:25 -04:30 2.08 DRILL P PROD2 Drill from 12609' and back to good drilling for a while 1.57/1.3/3650/808 at 91 deg at 6368' TVD, ECD 12.0, to 12680' PVT 363 04:30 - 06:00 1.50 DRILL P PROD2 Drill from 12680' in a multiple stall area 06:00 - 07:00 1.00 DRILL P PROD2 Drill ahead f/ 12,730'. 3500 psi fs C~ 1.52 in/1.25 out. DPSI: 200-350. DHWOB: 2.0 - 3.Ok#. WHP/BHP/ECD: 26/3983/12.07 ppb. IA/OA/PVT: 657/353/331 bbls. INC/AZM/TF: 91.5/189.0/958. ROP 35-55 fph. Losing +/- 15 bph mud to formation. 07:00 - 08:15 1.25 DRILL P PROD2 Wiper trip to window. Hole smooth. 08:15 - 11:00 2.75 DRILL P PROD2 Drill ahead from 12,750'. 3700 psi fs C~3 1.57 in/1.34 out. ~ PVT:305 bbls. Take on mud from uprights.: PVT: 460 bbls. ROP varying from 30 to 50 fph. Wt transfer good. 11:00 - 13:30 2.50 DRILL P PROD2 Drill ahead from 12,850'. PVT: 405 bbls. 13:30 - 15:00 1.50 DRILL P ~ PROD2 Wiper trip to window. Hole smooth. 15:00 - 17:30 2.50 DRILL ~ P I PROD2 Drill ahead from 12,900'. 3600 psi fs ~ 1.52 in/1.32 out. PVT: 314 bbls. 17:30 - 20:20 2.83 i DRILL P PROD2 Drill from 12955' 1.51/1.30/3850/85L w/ 50-200 psi dill, 1-2k wob, ECD 12.27 at 93 deg at 6368' TVD. Drill to 13054' PVT 1 262 20:20 - 21:15 0.92 DRILL P PROD2 Wiper thru window was clean 21:15 - 21:30 0.25 DRILL P PROD2 Log tie-in down from 11445', Corr +3' 21:30 - 22:25 0.92 DRILL P PROD2 Wiper back to TD was clean except for wt loss at 13005' PVT 223 22:25 - 00:00 1.58 DRILL P PROD2 Drill from 13051' 1.46/1.25/3600/85L w/ 100-200 psi dill, 0.75-2k wob w/ 12.4 ECD at 92 deg at 6358' TVD. Drill to 13100' PVT 199 8/28/2005 00:00 - 00:50 0.83 DRILL P PROD2 Continue drilling from 13100' at 93 deg to right side 1.45f 1.25/3650/858 w! 100-200 psi dill, 1-2k wob w! 12.34 ECD (4060 psi DHP) at 6351' TVD. Slow drilling due to stacking from TF change. Geo reports shale too. Drill to 13118' PVT 180 00:50 - 01:05 0.25 DRILL P PROD2 Wiper to 13000', clean 01:05 -04:00 2.92 DRILL P PROD2 Resume drilling from 13118' w/ slow steady progress and increase angle toward 96 deg since may be scraping the B Shale. Drill to 13200' (6341' TVD) PVT 110 04:00 - 05:00 1.00 DRILL P PROD2 Wiper to window w/ 5k overpulls and MW at 12990', 12460' PVT 74 05:00 - 06:15 1.25. DRILL P PROD2 Wiper back to TD. Start'poorboy' mud swap. Set downs at 12980-13010'. Work several times and end up drilling it. Finish wiper to TD 06:15 - 12:00 5.75 DRILL P PROD2 Drill ahead from 13,200'. New mud all the way around. Continue loading pits. 3500 psi fs ~ 1.57 in/1.46 out. DPSI: 200-300. DHWOB: 1.5 - 2.5k#. WHP/BHP/ECD: 18/3980/12.12 ppg. IA/OA/PVT: 657/343/248 bbls. INC/AZM/TF: 98.6/169.1/1008. ROP avg: 30 fph. Trying to climb out of B shale as fast as possible. 12:00 - 14:00 2.00 DRILL P PROD2 Wiper trip to window. No overpulls while POH. Several set downs and motor work at 12,965'. Reduce pump rate from 1.35 to 1.0 bpm and get through. Same problem and solution at 12,990'. Rest of trip to TD fairly smooth. 14:00 - 17:30 3.50 DRILL P PROD2 Drill ahead from 13,352'. 3500 psi fs ~ 1.50 in/1.41 out. Printed: 9/12/2005 10:06:03 AM BP EXPLORATION Operations Summary Report Legal Well Name: 1 J-03 Common Well Name: 1J-03 Event Name: REENTER+COMPLETE Contractor Name: NORDIC CALISTA Rig Name: NORDIC 2 Date From - To Hours Task Code ~ NPT 18!28(2005 114:00 - 17:30 I 3.504 DRILL {P 17:30 - 20:15 I 2.751 DRILL I P 20:15 - 21:20 1.08 ~ DRILL P 21:20 - 21:35 0.25 DRILL P 21:35 - 21:55 I 0.331 DRILL I P 21:55 - 22:40 0.75 ~ DRILL P I 22:40 - 23:05 ~ 0.42 ~ DRILL P 23:05 - 23:35 0.501 DRILL ~ P 23:35 - 00:00 I 0.421 DRILL I P 18/29/2005 100:00 - 00:25 I 0.421 DRILL I P 00:25 - 00:50 I 0.421 DRILL I P 00:50 - 01:45 I 0.921 DRILL I P 01:45-02:451 1.oolDRILL IP 02:45 - 04:55 I 2.171 DRILL I P 04:55 - 06:00 I 1.081 DRILL I P Start: 8/11 /2005 Rig Release: 9!6/2005 Rig Number: Page 13 of 19 ~ Spud Date: 8/13/2005 End: Phase Description of Operations PROD2 Take on additional mud. PVT: 554 bbls. Having trouble building angle and drilling w/ neg surface wt PROD2 Drill from 13432' 1.58/1.49/3550/208 w/ 100-200 psi dill, 1-2.4k wob w/ 12.12 ECD at 94.5 deg at 6319' TVD. Drill to 13500' (6310' TVD) PVT 520 PROD2 Wipes thru window w! 5k overpuli at 12990' PROD2 Log tie-in down from 11445', corr +4'. Attempted to hold 200 psi WHP, but well was flowing. SI ~ choke and watch WHP build to 600 psi while logging. PUH to 11400'. Bleed off WHP to 400 psi PROD2 Monitor WHP parked at 11400' (6253' TVD SS, 6369' TVD RKB). Pressure built to 612 psi over 20 min which is 10.4 ppg EMW w/ 8.55 ppg mud. BHI showed 10.92 ppg at 3500 psi DHP due to assumed LSRV PVT 517 PROD2 Hold 700 psi WHP while RIH thru window. Wiper to TD at normal pump rate 1.55/1.47/3500 ECD 11.9 PROD2 Set down at 12876' and drill thru on third try, but set down at 12910' and spud to get thru on fourth try. RIH until clean to 12962'. Wiper back to 12870' to orient around, and fairly clean. All pickups were about 5k over PVT 500 PROD2 Wiper back in hole from 12870' and clean until 12958' set down. Lose ground to 12952' w/ 8k overpulls. Wiper back to 12870'. Red pump rate to 1.0 bpm and hold 600 psi whp for 12.7 ECD. RIH ~ 50'/min and fairly clean to 13050'. Open choke and wiper back to 12870' 1.56/1.52/3680 w/ 5-8k overpulls. Continue wiper up hole while reboot SWS PC PROD2 Wiper back in hole and set down at 13000', then 13090'. Reapply 600 psi whp at 1.0 bpm to get thru both spots w/ 12.65 ECD at 1.0/0.25. Continue RIH. Get to 13157', but set down. Work to 13232' and set down, and 13238'. Gradually open choke and drill thru both and wiper in hole to 13391' set down. Appears B shale is falling apart PROD2 Lose ground from 13391' back to 13332' while wiper at normal conditions. Backream to 12870' to test the water. 5-8k overpulls occasionally, but not bad PVT 460 PROD2 Apply initial 600 psi whp and red rate to 1.0 to maintain ECD at 12.7 ppg while RIH from 12870' while gradually reduce whp to 400 psi 1.0/0.5 and was clean until set down at 13439'. Work thru 10' of set downs, then RIH to TD tagged at 13502' PVT 438 PROD2 Open choke and resume drilling from 13502' 1.48/1.45/3600/258 w/ 200-300 psi dill, 1-2.5k wob, 12.6 ECD at 92 deg at 6310' TVD PVT 428 PROD2 Drilling break at 13520' 1.48/1.39/3600/158 w/ ECD 12.44 Still having trouble building angle-last survey shows 90 deg at 13508' (6312' TVD), TF has been nearly straight up. NB incl shows 92 deg at 13537' PROD2 Drill from 13550' attempting to build angle 1.47l1.31l3600/10R w/ 12.47 ECD. Also, starting to run out of push. Stacking max surface wt and getting 800# wob w/ little MW. Finally showing build on surveys at 93 deg w/ NB incl at 95 deg PVT 409 PROD2 Drill from 13583' 1.45/1.32/3600 w/ 12.49 ECD and having to do mini wipers to get wt to bit to drill. Printed: 9/12/2005 10:06:03 AM BP EXPLORATION Page 14 of 19 Operations Summary Report Legal Well Name: 1J-03 Common Well Name: 1J-03 Spud Date: 8/13/2005 Event Name: REENTER+COMPLETE Start: 8!11/2005 End: Contractor Name: NORDIC CALISTA Rig Release: 9/6/2005 Rig Name: NORDIC 2 Rig Number: Date From - To Hours Task Code NPT Phase Description of Operations 8/29/2005 06:00 - 08:15 2.25 DRILL P PROD2 Drill ahead from 13,588'. 3750 psi fs ~ 1.57 iN1.44 out. DPSI:50-100. DHWOB:1.0-1.75k#. WHP/BHP/ECD: 26!4100/12.54 ppg. IA/OA/PVT: 680/394/394 bbls. INC/AZM/TF: 96.7/196.3/HS. Very slow drilling, difficult to get weight to bit. Unable to make any progress. Discuss with Town team. 08:15 - 09:15 1.00 DRILL P PROD2 Wiper trip to window. Overpulls and mtr work (5k max) from 12,940' to 12,900'. Rest of open hole was smooth. PVT: 362 bbls. 09:15 - 11:30 2.25 DRILL P PROD2 Circulate out of hole. 11:30 - 13:30 2.00 DRILL P PROD2 At surface. Hold PJSM to review undeployment. Get off well. Unstab coil. Undeploy. LD BHA. 13:30 - 18:00 4.50 BOPSU P PROD2 Perform bi-weekly BOP equipment test. Witness waived by ~ AOGCC J. Jones. 18:00 - 18:20 0.33 DRILL P PROD2 MU new 1.1 deg motor and used bi bit 18:20 - 18:35 0.25 DRILL P PROD2 Safety mtg re: pressure deploy 18:35 - 20:20 1.75 DRILL P PROD2 Pressure deploy BHA #15 w/ agitator w/ 400 psi SIWHP. Meg ~ ( test line, PT CTC ~ 4000 PVT 271 20:20 - 22:30 2.17 ~ DRILL P j FROD2 RIH w/ BHA #15 0.38/1800 following pressure schedule. Test ~ agitator and open EDC PVT 300 22:30 - 22:45 0.25 DRILL P PROD2 Log tie-in down from 11450', corr -13'. Close EDC 22:45 - 23:25 0.67 DRILL P PROD2 Wiper thru window and head to TD 1.511.34/3800 PVT 290 23:25 - 23:55 0.50 DRILL P PROD2 First set dawn at 12787'! Red rate to 1.26/1.20/3330 w/ 12.17 ECD and get to 12848'. Apply 200 psi whp at 1.0/0.65 w/ 12.2 ECD to get to 12858' after several tries. All set downs had MW and all pickups were either clean or up to 5k max overpull. Get past 12858' w/ no pump holding 400 psi whp and set down at 12900'. PUH 20k over and temporarily immobile twice while bring pump back on line and bleed off whp. PUH, sticky to 12770' and start over 23:55 -00:00 0.08 DRILL P PROD2 Wiper back in hole 1.25/1.1513350 8/30/2005 00:00 -00:45 0.75 DRILL P PROD2 Fin ream back in hole 1.25/1.15/3450 w/ 11.9 ECD to set down at 12848' and have 15k overpull. RIH and apply 200 psi whp w/ 0.8 bpm/0.7 bpm and get to 12853' w/ 12.2 ECD. Apply 500 psi at 0.5 bpm and get to 12,848' w/ 12.6 ECD. Do various combinations of the above and work to 12892'. Start losing ground back to 12848' and becoming increasingly sticky. Wiper to clean up cuttings to 12,750' and started packing off at 12,770' and had 15k overpull. Need wiper to belly at 11,675' to check cuttings bed too. Discuss 00:45 - 01:40 0.92 DRILL P PROD2 Wiper to window 1.46/1.2/3770 12.0 ECD was clean PVT 252 Receive orders to OH sidetrack to avoid the B Shale and redrill to the targets given in the 8/29/05 Plan Forward email from Voorhees. Initial planned KO point will be at 12220' 01:40 - 03:50 2.17 DRILL C PROD2 POOH following pressure schedule for sidetrack BHA Add additional mud to pits PVT 414 Safety mtg re: undeploy 03:50 -04:50 1.00 DRILL C PROD2 Undeploy w/ 435 psi Rehead slickline rope socket 04:50 -06:00 1.17 DRILL C PROD2 LD agitator assy. MU sidetrack assy 06:00 -08:30 2.50 STKOH C PROD2 Hold PJSM in dog house to review deployment procedure. Pressure deploy side track BHA. (1.9 deg mtr w/ R-60ST brass nose cone bit) Printed: 9/12/2005 10:06:03 AM BP EXPLORATION Page 15 of 19 Operations Summary Report Legal Well Name: 1J-03 Common Well Name: 1J-03 Spud Date: 8/13/2005 Event Name: REENTER+COMPLETE Start: 8/11/2005 End: Contractor Name: NORDIC CALISTA Rig Release: 9/6/2005 Rig Name: NORDIC 2 Rig Number: Date From - To Hours Task Code NPT Phase Description of Operations 8/30/2005 06:00 - 08:30 2.50 STKOH C PROD2 Stab coil. Test MWD. Get on well. 08:30 - 11:15 2.75 STKOH C PROD2 Run in hole following pressure schedule. 11:15 - 11:30 0.25 STKOH C PROD2 Log gr tie in. Subtract 15' correction. RIH through window ok. 11:30 - 16:00 4.50 STKOH C PROD2 Trough open hole from 12,200' to 12,220'. 1 fpm in up direction. 20 fpm down. Make three passes. 3615 psi fs ~ 1.57 in/1.45 out. WHP/BHP/ECD: 18/3920/11.89 ppg. IA/OA/PVT: 614/201/432 bbls. Low side TF. 16:00 - 17:00 1.00 STKOH C PROD2 Lock brake at 12,219' for 30 minutes. Drill 1' per hour for 2' (2 hrs). Drill 2' per hour for 2' (1 hr) Drill 3' per hour for 3' (1 hr) 17:00 - 17:40 0.67 STKOH C PROD2 Set brake ~ 12219' for 30 minutes 17:40 - 00:00 6,33 STKOH C PROD2 Time drill sidetrack at 1'/hr from 12219' to 12225'. No weight transfer to bit. Back ream ST to 12200' at 1'lhr. Work trough. Time drill ST at 1'/hr. 8/31/2005 00:00 - 05:00 5.00 ; STKOH C i PROD2 Time drill ST at 1'1hr. Work trough and ST as needed to clear hole. Stacking out on bottom, attmept to drill ahead with slow ~ ROP. 05:00 - 06:30 1.50 STKOH C PROD2 Drill ahead with ST interval from 12219' to 12240'. 0=1.58 (1.51 out), 3650 BHP, 3K WOB, 12.1 ECD, 15'/hr. 06:30 - 08:30 2.00 STKOH C PROD2 Backream trough, ST several times. Wipe hole clean. No problems. All indications show 5 degree change from original hole. 08:30 - 10:00 1.50 STKOH C PROD2 POOH w/ ST assy and CT. 10:00 - 10:15 0.25 STKOH C PROD2 Conduct safety meeting for Undeployment. 10:15 - 11:30 1.25 STKOH C PROD2 Undeploy ST BHA. 11:30 - 12:00 O.SO STKOH C PROD2 Inspect and rebuild BHA assy. Bit looks good- 1 plugged jet, otherwise 1/1 12:00 - 14:30 2.50 DRILL P PROD2 PU new BHA, deploy into hole. 14:30 - 16:00 1.50 DRILL P PROD2 RIH w/ Lateral assy. 16:00 - 16:30 0.50 DRILL P PROD2 Tie in. -14' correction. 16:30 - 17:00 0.50 DRILL P PROD2 Continue RIH to bot. 17:00 - 21:15 4.25 DRILL P PROD2 Drill ahead from 12240' to 12400'. 0=1.5511.3, 3650 BHP, 2450 WOB, 11.95 ECD, 75'/hr. TF at 60L. 21:15 - 22:15 1.00 DRILL P PROD2 Conduct wiper trip to window. 22:15 - 00:00 1.75 DRILL P PROD2 Drill ahead from 12400' to 12510'. 0= 1.5/1.38, 3600 BHP, 1700 WOB, 11.93 ECD, 58'/hr, TF at 0 9/1/2005 00:00 - 03:15 3.25 DRILL P PROD2 Drill ahead from 12477' to 12550'. 0=1.5/1.4, 3600 BHP, 1700 WOB, 11.93 ECD, 58'/hr 03:15 -04:30 1.25 DRILL P PROD2 Conduct wiper trip to window. Hole acting good. 04:30 - 11:15 6.75 DRILL P PROD2 Drill ahead from 12550' to. 0= 1.5/1.25 bpm, 3650 BHP, 1700-2450 WOB, 11.93 ECD, 10-58'/hr, TF at 0. Swap mud on the fly, fill pits back to full. -Intermittant siderite streaks -X0700, changed TF to 60R 11:15 - 13:00 1.75 DRILL P PROD2 Conduct wiper trip to window. Tie in. +5' Correction. RIH to bottom. No problem re-entering ST. 13:00 - 19:30 6.50 DRILL P PROD2 Drill ahead from 12700' to . 0=1.53/1.41, 3550 press (3200 FS), 1500 WOB, 12.0 ECD, 20-77'/hr, hold 90R TF to correct turning problem. -Continual stacking out starting at 12727' to 12745'. Sticky when pulling through as well- 10K overpull. Work through Printed: 9/12/2005 10:06:03 AM BP EXPLORATION Page 16 of 19 Operations Summary Report Legal Well Name: 1J-03 Common Well Name: 1J-03 Spud Date: 8/13/2005 Event Name: REENTER+COMPLETE Start: 8/11/2005 End: Contractor Name: NORDIC CALISTA Rig Release: 9/6/2005 Rig Name: NORDIC 2 Rig Number: Date From - To Hours Task Code NPT Phase Description of Operations 9/1/2005 13:00 - 19:30 6.50 DRILL P PROD2 sticky spots as needed. Overall tough drilling. -~ 1700 hrs, change TF to 150R -Continue to have stacking problems and stalling problems. Make short trip. 19:30 - 21:00 1.50 DRILL P PROD2 Conduct wiper trip to window. 21:00 - 23:30 2.50 DRILL P PROD2 Attempt to drill ahead from 12840'- will not drill. 0=1.52/1.42, 3500 press {3450 FS), 2500 WOB, 11.97 ECD, 8'lhr, TF at 90R. -Appx. 15% chert coming in returns 23:30 - 00:00 0.50 DRILL P PROD2 POOH w/ BHA and CT 9/2/2005 00:00 - 02:30 2.50 DRILL P PROD2 POOH w/ BHA and CT 02:30 - 02:45 0.25 DRILL P PROD2 Conduct safety meeting for undeployment 02:45 -04:00 1.25 DRILL P PROD2 Undeploy and LD BHA 04:00 - 05:15 1.25 DRILL P PROD2 C/O new components on BHA, PU new bit. Old bit graded 2/4/RGS/XI/BU/PR 05:15 - 05:30 0.25 DRILL P PROD2 Conduct safety meeting for deployment 05:30 - 06:15 0.75 DRILL P PROD2 Deploy BHA 06:15 - 06:30 i 0.25 DRILL P PROD2 Conduct new safety meeting for deployment with new crew 06:30 - 07:00 ! 0.50 DRILL P PROD2 Deploy BHA 07:00 - 10:30 3.50 DRILL P PROD2 RIH w/ BHA and CT. Tagged up at 12350'. Worked through tight spot several times. RIH and tagged up at 12580'. Worked through tight spot several times. R1H and tagged again at 12750'. Worked through tight spot several times. Overpull on all tight spots around 15K. 10:30 - 17:00 6.50 DRILL P PROD2 Drill ahead from 12840' to 12925'. 0=1.55/1.45, 3500 press (3350 FS), 2200 WOB, 11.75 ECD, 10'/hr, TF at 100R. Negative coil wt. at surface. -~ 1530, Change TF to 97. Cuttings entirely shale, no chert remaining 17:00 - 19:30 2.50 DRILL P PROD2 Conduct wiper trip to window. Tie in. +4' correction 19:30 -00:00 4.50 DRILL P PROD2 Drill ahead from 12925' to . 0=1.6/1.5, 3550 press, 1500 WOB, 12.04 ECD, 25'/hr, TF at 75R. 9/3/2005 00:00 -04:45 4.75 DRILL P PROD2 Drill ahead to 13230'. 0=1.6/1/45, 3600 press (3500 FS), 1800 WOB, 11.86 ECD, 25-50'lhr. 04:45 - 06:30 1.75 DRILL P PROD2 Conduct Wiper trip to window. Conduct mud swap on the fly 06:30 - 09:15 2.75 DRILL P PROD2 Drill ahead from 13230' to 13380'. 0=1.55/1.5, 3500 press, 2450 WOB, 12.21 ECD, 50-110'/hr, TF at 90L -X0830, dropped TF to 120E 09:15 - 11:30 2.25 DRILL P PROD2 Conduct wiper trip to window 11:30 - 15:00 3.50 DRILL P PROD2 Drill ahead from 13380' to 13480'. 0=1.55/1.45, 3700 press, 1400 WOB, 12.33 ECD, 10-50'/hr. TF at 90L. -~ 1230 hrs, ROP dropped from 100'/hr to 10'/hr, ECD at 12.64. Mud problems. 15:00 - 16:30 1.50 DRILL P PROD2 Conduct wiper trip. Start diluting new mud to drop ECD. 16:30 -00:00 7.50 DRILL P PROD2 Drill ahead from 13480' to 13540'. 0=1.4/1.3, 3500 press, 1500-2400 WOB, 12.38 ECD, 10'/hr ROP. TF held at 0 deg HS -Modify pump rates (1.2-1.4 BPM) to drop ECD (lowest attained is 12.08) -10% Siderite in returns 9/4/2005 00:00 -04:30 4.50 DRILL P PROD2 Drill ahead from 13480' to 13566'. Q=1.4/1.3, 3500 press, 1500-2400 WOB, 12.38 ECD, 10'/hr ROP. TF held at 0 deg HS -Modify pump rates (1.2-1.4 BPM) to drop ECD (lowest attained is 12.08) Printed: 9/12/2005 10:06:03 AM BP EXPLORATION Page 17 of 19 Operations Summary Report Legal Well Name: 1J-03 Common Well Name: 1J-03 Spud Date: 8/13/2005 Event Name: REENTER+COMPLETE Start: 8/11/2005 End: Contractor Name: NORDIC CALISTA Rig Release: 9/6/2005 Rig Name: NORDIC 2 Rig Number: Date From - To Hours Task Code NPT Phase Description of Operations 9/4/2005 00:00 -04:30 4.50 DRILL P PROD2 -10% Siderite in returns 04:30 - 07:30 3.00 DRILL P PROD2 Conduct wiper to window 07:30 - 11:30 4.00 DRILL P PROD2 Drill ahead from 13566' to 13577'. 0=1.35!1.25, 3400 press ~ (3400 FS), 2700 WOB, 12.41 ECD, 5'/hr, TF at 30R i -Returns: 2-3% Siderite, 15% Shale 11:30 - 12:00 0.50 DRILL P ~ PROD2 Shale sloughed and packed around bit. Cannot turn motor, returns nil. Work pipe up and down, increase-pump rate to 1.9 ~ ~ (max) and pull tension on pipe. Came free, PU with pipe. 12:00 - 18:30 6.50 DRILL P PROD2 TD called at 13577'. Begin final wiper and tie in at window. +9 correction. Corrected TD at 13585'. RIH to 13520'. lay in 30 ~ bbl 11.1 ppg liner pill (includes 20 bbls of beads). Chase liner 18:30 - 20:00 1.50 j DRILL i ~ N ~ FLUD j ~ PROD2 i pill with 10.7 KWF. POOH. ~ Check for flow at surface- well flowing. Continues to flow- put ~ I 250 psi backpressure on well, bleeds to 75 psi, order out I weighting material. Start back in hole, circulating to keep gas ~ ~i ~ i out of mud column. KWM needed-11.3 ppg (includes 100 psi differential °safety factor"). 120:00 - 22:00 2.00 i DRILL i N ~ FLUD PROD2 RIH circulating at .5 BPM to circ. out gas. RIH to window. ECD j at 14.3, SD pumps. At 7200' lose returns. 22:00 - 00:00 2.00 DRILL ~ N FLUD ~ PROD2 Circulate mud while waiting for mud spike to arrive on location 9/5/2005 00:00 - 02:15 2.25 DRILL ~ N ; FLUD ~ PROD2 Circulate hole to keep gas out of column while waiting on mud ~ i to arrive 02:15 - 03:30 1.25 DRILL N FLUD PROD2 Mix 100 bbls 12.4 ppg spike fluid with 300 bbl in system- puts KW at 11.3 i 03:30 -04:00 0.50 DRILL N FLUD PROD2 Fill reel volume with 11.3 mud. Start POOH when mud turns corner 04:00 - 06:15 2.25 DRILL N FLUD PROD2 Circulate 11.3 KWF at 1.25 BPM while POOH. Losing .25 BPM. Have 200 bbls of 11.3 KWF made at plant. ECD at 14.5 06:15 - 06:30 0.25 DRILL P PROD2 Conduct safety meeting for liner running- hole full 06:30 -06:45 0.25 DRILL P PROD2 Check for flow- well dead. 06:45 - 07:15 0.50 DRILL P PROD2 LD drilling assy- bit junked- 4/4/BT/WC 07:15 - 07:30 0.25 DRILL P PROD2 Conducted safety meeting for BOPE function test 07:30 - 08:00 0.50 BOPSU P PROD2 Stab BOPE test joint, function test BOPE. Works fine. 08:00 - 10:00 2.00 CASE P RUNPRD RIH w/ 60 jts 2 3/8" (4.43# L80) Liner and liner jewelry: Indexing Shoe Solid 1 Jt- 31.5' BTT O-Ring Sub Slotted 15 Jts- 475.21' Solid 8 jts- 240.96' Slotted 10 jts- 316.92' Solid 3 jts- 94.37' Slotted 17 jts- 538.47' Solid 4 jts- 125.36' Slotted 2 jts- 63.51' TOTAL LENGTH- 1896.3' 10:00 - 10:30 0.50 CASE P RUNPRD PU liner BHA, attach coil, RU injector 10:30 - 13:15 2.75 CASE P RUNPRD RIH w/ Liner and CT to 13450' -No problem at window (11579') -No problem at ST KOP (12219') -No problem through shales 13:15 - 13:30 0.25 CASE P RUNPRD Log up from 13450 to 13350'. -15' correction. 13:30 - 15:15 1.75 CASE N DFAL RUNPRD RIH w/ liner and CT to 13490' (Bottom of Liner). Total wt. at +/- 32k. Bring pumps to full rate- 1.6 at 4500 psi. No retums. Work Printed: 9/12/2005 10:06:03 AM LJ BP EXPLORATION Page 18 of 19 Operations Summary Report Legal Well Name: 1J-03 Common Well Name: 1J-03 Spud Date: 8/13/2005 Event Name: REENTER+COMPLETE Start: 8/11/2005 End: Contractor Name: NORDIC CALISTA Rig Release: 9/6/2005 Rig Name: NORDIC 2 Rig Number: Date From - To Hours Task Code NPT Phase Description of Operations 9/5/2005 13:30 - 15:15 1.75 CASE N DFAL RUNPRD pipe several times- don't lose liner wt (+/- 20001bs)- not disconnected. PU to 13000'- disengage from liner. Push liner to desired depth- cannot disconnect. Work liner several times at ~ various speeds and pump rates- cannot disconnect. PU at 120 fpm and disconnect from liner (Bottom of liner at 13478'- top of liner possibly in cased hole). Short distance from landing point and window is putting a bind on the spear and liner connection (cannot disconnect). Leave liner as is and POOH to modify spear. 15:15 - 18:30 3.25 CASE N DFAL RUNPRD POOH w/ Liner BHA and CT. Filling hole from top. 18:30 - 19:00 0.50 CASE N DFAL RUNPRD Remove Collett sheath off of spear 19:00 - 20:30 1.50 CASE N DFAL RUNPRD RIH to 4300'- tool shorted out. Cannot tell depth. POOH. 20:30 - 21:30 1.00 CASE N DFAL RUNPRD Test BHA- UOC and LOC malfunctioning. Change both out. ~ 1 Test BHA- good. 21:30 - 23:30 2.00 CASE N DFAL RUNPRD RIH w/ BHA and CT 1 23:30 - 23:45 1 025 CASE N DFAL RUNPRD Log down from 11425' to 14450'. Tie in. -14' correction. ' 23:45 - 00:00 0.25 CASE N DFAL !RUNPRD RIH w/ Liner BHA and CT. Tag Liner top at 11582 . Push liner to 11590'. Liner dragging with bare spear uphole as POOH. ~ Push liner back down to 11590'- stays. Top of liner- 11590', Bottom of liner- 13490'. POOH. 9/6/2005 ~ 00:00 - 01:45 1.75 CASE P RUNPRD POOH with liner BHA and CT 01:45 - 02:00 0.25 CASE P RUNPRD Conduct safety meeting 02:00 - 02:30 0.50 CASE P RUNPRD LD Liner BHA and PU WS Pulling BHA 02:30 -04:30 2.00 CASE P RUNPRD RIH w/ WS BHA to11430' 04:30 - 05:00 0.50 CASE P RUNPRD Log down at 2.6 fpm from 11430' to .Tie in. -14' correction. 05:00 - 05:45 0.75 CASE P RUNPRD RIH to Top of WS (11574') at 2 fpm. Engage top of WS until motor stalls. -PU to neutral wt, stall motor for maximum torque. SD pump. -String Wt. is 25K, pull 30K, jars unintentionally go off (stroked wt. 35K). Pull 30K, jars unintentionally go off (stroked wt- 35K). Pull 34K, jars went off (stroked wt. at 34K). Pull 32K, lose circ. press but no movement. Slowly pull to 36K, no movement. Re-pull 36K, jars going off. Repeat the 36K cycle 5 more times with same result- jars going off every time. Pull 38K, no movement, jars stroking. -Ramp pump to 1.5 bpm and stall motor to ensure box tap still tight. -Pu1139K, no movement, jars stroking. Repeat twice more- ~ second time pull free. -Free weight 25K. Open EDC, POH. 05:45 - 07:30 1.75 CASE P RUNPRD POOH w/ WS Pulling BHA and WS. Circulating at .75 bpm. 07:30 - 07:45 0.25 CASE P RUNPRD Conduct safety meeting 07:45 - 09:00 1.25 CASE P RUNPRD LD WS BHA and WS, PU jet to circulate weN 09:00 - 11:00 2.00 CASE P RUNPRD RIH w/jet 11:00 - 13:45 2.75 CASE P RUNPRD POH displacing well with seawater from 11500' to 2500', diesel from 2500' to 400'. At 400', developed pinhole in coil. Finished freeze protecting to surface. 13:45 - 15:45 2.00 CASE P RUNPRD Drain coil. Cut connector off of coil. Cut 400' of coil off reel. Re-attach connector to coil. 15:45 - 18:00 2.25 CASE P RUNPRD RU to BD coil with N2, BD coil, RD N2 unit 18:00 - 20:00 2.00 CASE P RUNPRD RD coil, change out. Clean pits. Rig down stack. 20:00 - 20:30 0.50 RIGD N SFAL POST During rig down of BOP stack the chains centering the stack were released. At this point the flange connection between the Printed: 9/12/2005 10:06:03 AM BP EXPLORATION Page 19 of 19 Operations Summary Report Legal Well Name: 1J-03 Common Well Name: 1J-03 Spud Date: 8/13/2005 Event Name: REENTER+COMPLETE Start: 8/11/2005 End: Contractor Name: NORDIC CALISTA Rig Release: 9/6/2005 Rig Name: NORDIC 2 Rig Number: Date From - To Hours Task Code NPT Phase ~ Description of Operations 19/6/2005 ~ 20:00 - 20:30 ~ 0.50I RIGD I N I SFAL I POST 20:30 - 21:25 ~ 0.92 ~ RIGD ~ N ~ SFAL ~ POST 21:25 - 21:40 0.25 RIGD N SFAL I POST 21:40 - 23:00 1.33 RIGD I N SFAL POST 23:00 - 00:00 1.00 RIGD P I POST i I tubing hanger adapter and master valve started to leak diesel. There was 500 psi on the wellhead. The chains were retightened, and the leak stopped. The bolts at this connection were checked and found to be loose. They were tightened by hand, then hammered up. Called CPAI Wells Coordination Supervisor, Mark Chaney, and discussed. The plan forward is to set a BPV, move rig off well and let CPAI resolve the issue with the rig off location. CaII for BPV. Notify town engineer. Notify Kuparuk spill reporting hotline of leak and repair, with no diesel getting off the tree. Wait on BPV crew. Hold PJSM with CPAI valve crew Re: situation with tree, and setting BPV. Set BPV in tubing hanger profile. Bleed pressure off lubricator, BPV held. RD Valve crew equipment. Continue prep for rig move. Rig released at 23:45. Further telex entries carried on 1 D-34 DIMS report. Printed: 9/12/2005 10:06:03 AM ~~~~ V >~ p' Conoc~hillips ~aker Hughes INTEQ •OCT 0 ~ 2005 ~ Baker Hughes INTEQ Survey Reports Oil & Gas Core Compauy: ConocoPhillips Alaska, Inc Date: 9/21/2005 Time: 11:20:59 Page: I Field: Kuparuk River Unit Co-ordiuate(NE) Reference: Well: 3, True North Site: Pad 1J Vertical (TVD) Reference: Wellhead(116') 116.0 Well: 3 Section (VS) Reference: Well (O.OON,O.OOE,180.OOAzi) Wellpath: 1J-03L2PB1 Survey Calculation Method: Minimum Curvature Db: Oracle Field: Kuparuk River Unit North Slope, Alaska USA Map System:US State Plane Coordinate System 1927 Map Zone: Alaska, Zone 4 Geo Datum: NAD27 (Clarke 1866) Coordinate System: Well Centre Sys Datum: Mean Sea Level Geomagnetic Model : bggm2004 Site: Pad 1 J Site Position: Northing: 5943831.65 ft Latitude: 70 15 25.530 N From: Map Easting: 561226.77 ft Longitude: 149 30 18.584 W Position Uncertainty: 0.00 ft North Reference: True Ground Level: 0.00 ft Grid Convergence: 0.47 deg Well: 3 Slot Name: Well Position: +N/-S 2107.93 ft Northing: 5945919.64 ft Latitude: 70 15 46.258 N +E/-W -2419.99 ft Easting : 558789.96 ft Longitude: 149 31 29.006 W Position Uncertainty: 0.00 ft Wellpath: 1J-03L2P81 Drilled From: 1J-03 50-029-23002-60-70 Tie-on Depth: 11560.66 ft Current Datum: Wellhead(116') Height 116.00 ft Above System Datum: Mean Sea Level Magnetic Data: 7/29/2005 Declination: 24.24 deg Field Strength: 57605 nT Mag Dip Angle: 80.73 deg Vertical SeMion: Depth From (TVD) +N/-S +E/-W Direction ft ft ft deg 0.00 0.00 0.00 180.00 Survey Program for Definitive Wellpath Date: 7/29/2005 Validated: No Version: 1 Actual From To Survey Toolcode Tool Name ft ft 201.29 11560.66 MWD w/IFR<0-12214'> (20 1.29-12214.00) (pl)/VD+SAG+IFR MWD+SAG+IFR (AK) 11574.00 13589.00 MWD (11574.00-13589.00) MWD MWD -Standard Annotation MD TVD ft ft 11560.66 6452.52 TIP 11574.00 6460.22 KOP 13589.00 6424.84 TD Survey: MWD Start Date: 8/25/2005 Company: Baker Hughes INTEQ Engineer: Tool: MWD;MWD -Standard Tied-to: From: Definitive Path Survey MD ft Incl deg Azim deg TVD ft SS TVD ft N/S ft E/W ft MspN ft MapE ft VS ft DLS Tool deg/100ft 11560.66 54.74 118.61 6452 .52 6336.52 1983. 05 7952.01 5947964 .52 566725.48 -1983. 05 0.00 MWD 11574.00 54.81 118.58 6460 .22 6344.22 1977. 83 7961.58 5947959 .38 566735.09 -1977. 83 0.56 MWD 11592.07 56.56 120.91 6470 .40 6354.40 1970. 43 7974.53 5947952 .08 566748.10 -1970. 43 14.39 MWD 11620.01 67.89 124.03 6483 .41 6367.41 1957. 15 7995.33 5947938 .96 566769.00 -1957. 15 41.73 MWD 11649.65 79.93 126.96 6491 .61 6375.61 1940. 63 8018.46 5947922 .62 566792.25 -1940. 63 41.71 MWD 11680.16 91.00 129.80 6494 .02 6378.02 1921. 77 8042.26 5947903 .95 566816.20 -1921. 77 37.45 MWD 11716.47 91.15 137.10 6493 .33 6377.33 1896. 82 8068.60 5947879 .21 566842.73 -1896. 82 20.11 MWD 11750.90 93.89 143.03 6491 .82 6375.82 1870. 46 8090.67 5947853 .03 566865.00 -1870. 46 18.96 MWD 11779.49 94.04 ~ 147.28 6489 .84 6373.84 ~ 1847. 06 8106.96 5947829 .76 566881.47 -1847. 06 '14.84 MWD • 11824.11 90.72 152.51 6487 .99 6371.99 1808. 51' •8129.34 5947791 .39 566904.12 -1808. 51 13.87 MWD 11858.13 89.62 156.54 6487 .89 6371.89 1777. 80 8143.94 5947760 .80 566918.99 -1777. 80 12.28 MWD ~~~ -/,Z( ~' ConocoPhillips ~aker Hughes INTEQ ~ ~ ~'~ Baker Hughes INTEQ Survey Report ~~.~~~ Company: ConocoPhillips Alaska, Inc Date: 9/21/2005 Time: 11:20:59 Page: 2 Field: Kuparuk River Unit Co-ordinate(NE) Reference: Well: 3, True North Site: Pad 1J Vertical (TVD) Reference:. Wellhead(116') 116.0 Well: 3 Section (VS) Reference: Wel! (O.OON,O.OOE,180.OOAz!) Wellpath: 1J-03L2P61 Survey Calculation Method: Minimum Curvature Db: Oracle Survey MD Incl Azim TVD SS TVD N/S ft deg deg ft ft ft 11886.12 90.35 160.22 6487.89 6371.89 1751.79 11929.24 91.06 163.92 6487.36 6371.36 1710.77 11962.91 92.01 167.00 6486.46 6370.46 1678.20 11993.18 92.93 170.15 6485.16 6369.16 1648.56 12029.16 93.61 175.28 6483.10 6367.10 1612.94 12061.52 92.17 178.83 6481.47 6365.47 1580.67 12099.35 88.60 183.72 6481.22 6365.22 1542.87 12129.64 89.86 185.07 6481.62 6365.62 1512.67 12159.44. 89.52 188.57 6481.78 6365.78 1483.09 12190.24 90.14 190.19 6481.88 6365.88 1452.70 12220.07 91.83 190.29 6481.36 6365.36 1423.35 12249.17 93.02 192.16 6480.13 6364.13 1394.83 12280.01 93.95 192.36 6478.26 6362.26 1364.75 12310.38 93.46 190.99 6476.29 6360.29 1335.07 12340.79 91.70 186.42 6474.92 6358.92 1305.05 12370.47 87.37 182.53 6475.17 6359.17 1275.48 12401.54 90.02 182.52 6475.87 6359.87 1244.45 12434.65 88.57 177.77 6476.28 6360.28 1211.35 12464.35 86.18 175.71 6477.64 6361.64 1181.74 12506.66 85.22 172.88 6480.81 6364.81 1139.76 12536.89 87.Q4 177.24 6482.86 6366.86 1109.72 12566.72 87.47 180.64 6484.28 6368.28 1079.93 12598.04 88.57 184.77 6485.37 6369.37 1048.67 12626.66 91.93 187.70 6485.24 6369.24 1020.23 12657.67 91.92 189.16 6484.20 6368.20 989.57 12688.14 91.15 193.43 6483.38 6367.38 959.71 12719.72 90.38 196.53 6482.96 6366.96 929.21 12754.84 92.81 200.93 6481.98 6365.98 895.97 12784.54 91.61 201.13 6480.84 6364.84 868.27 12836.00 91.27 193.60 6479.54 6363.54 819.21 12869.42 93.27 189.78 6478.22 6362.22 786.52 12913.04 93.80 185.10 6475.53 6359.53 743.36 12944.47 93.30 182.67 6473.58 6357.58 712.06 12980.78 92.38 178.51 6471.78 6355.78 675.81 13011.60 94.17 174.86 6470.02 6354.02 645.10 13054.66 93.39 169.10 6467.18 6351.18 602.57 13086.42 94.56 165.17 6464.98 6348.98 571.69 13115.18 96.32 166.60 6462.25 6346.25 543.92 13156.23 97.74 171.59 6457.22 6341.22 503.93 13199.37 98.95 175.68 6450.96 6334.96 461.52 13237.29 98.15 180.40 6445.32 6329.32 424.06 13268.70 96.10 182.13 6441.42 6325.42 392.90 13299.11 94.46 183.92. 6438.62 6322.62 362.66 13336.73 91.46 184.44 6436.68 6320.68 325.20 13369.92 94.53 187.52 6434.95 6318.95 292.24 13396.99 94.87 190.17 6432.73 6316.73 265.59 13442.52 92.38 194.00 6429.85 6313.85 221.17 13471.13 92.26 196.61 6428.69 6312.69 193.60 13508.01 90.26 196.95 8427.88 6311.88 158.30 13543.89 92.69 196.34 •6426.96 6310.96 123.93 13589.00 .92.69 196.34 .6424.84 6308.84 80.69 E/W MapN MapE ft ft ft 8154.25 5947734.87 566929.50 8167.52 5947693.96 566943.09 8175.97 5947661.46 566951.79 8181.96 5947631.87 566958.01 8186.51 5947596.29 566962.84 8188.17 5947564.04 566964.75 8187.33 5947526.23 566964.21 8185.01 5947496.02 566962.12 8181.47 5947466.41 566958.82 8176.45 5947435.99 566954.03 8171.15 5947406.60 566948.96 8165.49 5947378.05 566943.53 8158.95 5947347.92 566937.23 8152.82 5947318.20 566931.33 8148.23 5947288.14 566926.97 8145.91 5947258.55 566924.88 8144.54 5947227.52 566923.76 8144.46 5947194.42 566923.93 8146.14 5947164.82 566925.85 8150.34 5947122.89 566930.37 8152.93 5947092.87 566933.20 8153.48 5947063.09 566933.98 8152.01 5947031.82 566932.75 8148.90 5947003.36 566929.86 8144.36 5946972.67 566925.56 8138.39 5946942.77 566919.83 8130.23 5946912.21 566911.91 8118.96 5946878.89 566900.90 8108.31 5946851.11 566890.47 8092.97 5946801.93 566875.51 8086.20 5946769.19 566869.00 8080.57 5946725.99 566863.70 8078.44 5946694.68 566861.82 8078.07 5946658.43 566861.73 8079.85 5946627.73 566863.75 8085.84 5946585.26 566870.07 8092.89 5946554.44 566877.36 8099.87 5946526.73 566884.56 8107.58 5946486.80 566892.58 8112.32 5946444.44 566897.65 8113.60 5946406.99 566899.22 8112.91 5946375.83 566898.77 8111.31 5946345.58 566897.41 8108.57 5946308.10 566894.96 8105.12 5946275.12 566891.77 8100.97 5946248.44 566887.83 8091.46 5946203.95 566878.67 8083.91 5946176.32 566871.34 8073.27 5946140.95 566860.97 8063.00 5946106.51 •566850:97 8050.32 .5946063.17 566838.63 VS DLS Tool ft deg/100ft -1751.79 13.40 MWD -1710.77 8.74 MWD -1678.20 9:57 MWD -1648.56 10.83 MWD -1612.94 14.36 MWD -1580.67 11.83 MWD -1542.87 16.00 MWD -1512.67 6.10 MWD -1483.09 11.80 MWD -1452.70 5.63 MWD -1423.35 5.68 MWD -1394.83 7.61 MWD -1364.75 3.08 MWD -1335.07 4.78 MWD -1305.05 16.09 MWD -1275.48 19.61 MWD -1244.45 8.53 MWD -1211.35 15.00 MWD -1181.74 10.62 MWD -1139.76 7.05 MWD -1109.72 15.60 MWD -1079.93 11.48 MWD -1048.67 13.64 MWD -1020.23 15.58 MWD -989.57 4.71 MWD -959.71 14.23 MWD -929.21 10.11 MWD -895.97 14.31 MWD -868.27 4.10 MWD -819.21 14.64 MWD -786.52 12.89 MWD -743.36 10.78 MWD -712.06 7.88 MWD -675.81 11.72 MWD -645.10 13.17 MWD -602.57 13.47 MWD -571.69 12.88 MWD -543.92 7.87 MWD -503.93 12.55 MWD -461.52 9.79 MWD -424.06 12.49 MWD -392.90 8.51 MWD -362.66 7.96 M W D -325.20 8.09 MWD -292.24 13.09 MWD -265.59 9.84 M W D -221.17 10.02 MWD -193.60 9.12 MWD -158.30 5.50 MWD =123.93 6.98 MWD .-80.69 . 0.00 MWD ~ ~ ~ ~ ~~ t ~' !~`t~ Conoc~illips Baker Hughes INTEQ Baker Hughes INTEQ Survey Report ~~~- ,~ Conoc Phillips aker Hughes INTEQ Baker Hughes INTEQ Survey Report ~~ li:vx~t~ Company: ConocoPhillips Alaska, Inc Dste: 9!21/2005 Time: 11:22:26 Pager 2 Field: Kuparu k River Unit Co-ordinate(NE) Reference: Well: 3, True North Site: Pad 1J Vertical (TVD) Reference: Wellhead(116') 116.0 Well: 3 Section (VS) Reference: Well (O.OON,O. OOE,180.OOAzi) Wellpatb: 1J-03L2 Survey Calculation Method: Minimum Curvature Db: Orate Survey MD Inc! Azim TVD SS TVD N/S E/W MapN MapE VS DLS Tool ft deg deg ft ft ft ft ft ft ft degl100ft 12220.07 91 .83 190.29 6481.36 6365.36 1423.35 8171.15 5947406. 60 566948.96 -1423.35 0 .00 MWD 12251.50 87 .31 187.24 6481.60 6365.60 1392.30 8166.36 5947375. 52 566944.42 -1392.30 17 .35 MWD 12283.07 89 .06 181.00 6482.60 6366.60 1360.84 8164.10 5947344. 05 566942.40 -1360.84 20 .52 MWD 12314.90 86 .57 172.57 6483.82 6367.82 1329.12 8165.88 5947312. 34 566944.43 -1329.12 27 .60 MWD 12348.78 88 .91 169.14 6485.15 6369.15 1295.70 8171.26 5947278. 97 566950.07 -1295.70 12. 25 MWD 12377.73 90 .78 170.33 6485.23 6369.23 1267.22 8176.41 5947250. 53 566955.45 -1267.22 7 .66 MWD 12406.31 92 .48 175.60 6484.42 6368.42 1238.88 8179.91 5947222. 22 566959.17 -1238.88 19. 37 MWD 12436.49 93. 49 180.14 6482.84 6366.84 1208.77 8181.03 5947192. 12 566960.52 -1208.77 15 .39 MWD 12466.39 93 .61 175.93 6480.99 6364.99 1178.95 8182.06 5947162. 32 566961.78 -1178.95 14 .06 MWD 12494.61 90 .94 169.29 6479.87 6363.87 1151.00 8185.68 5947134. 40 566965.62 -1151.00 25 .34 MWD 12545.45 89. 80 158.93 6479.54 6363.54 1102.17 8199.58 5947085. 69 566979.90 -1102.17 20 .50 MWD 12575.36 89 .03 161.69 6479.85 6363.85 1074.02 8209.66 5947057. 61 566990.19 -1074.02 9 .58 MWD 12611.74 92 .41 157.36 6479.39 6363.39 1039.95 8222.38 5947023. 65 567003.18 -1039.95 15. 10 MWD 12641.65 95. 23 162.25 6477.40 6361.40 1011.95 8232.68 5946995. 74 567013.70 -1011.95 18. 84 MWD 12674.82 97 .83 167.41 6473.62 6357.62 980.16 8241.30 5946964. 02 567022.57 -980.16 17 .33 MWD 12705.46 96 .30 170.28 6469.85 6353.85 950.33 8247.18 5946934. 24 567028.68 -950.33 10. 55 MWD 12736.82 98. 55 176.75 6465.80 6349.80 919.45 8250.70 5946903. 39 567032.43 -919.45 21. 68 MWD 12771.30 99 .51 180.08 6460.38 6344.38 885.42 8251.64 5946669. 37 567033.64 -885.42 9. 94 MWD 12803.79 96 .85 181.99 6455.76 6339.76 853.27 8251:06 5946837. 22 567033.31 -853.27 10. 04 MWD 12833.81 93. 46 183.83 6453.06 6337.06 823.42 8249.54 5946807. 36 567032.03 -823.42 12. 84 MWD 12864.79 94 .17 189.30 6451.00 6335.00 792.72 6246.01 5946776. 64 567028.73 -792.72 17. 77 MWD 12895.84 95 .77 193.03 6448.31 6332.31 762.38 8240.02 5946746. 25 567022.98 -762.38 13. 03 MWD 12925.08 96. 69 197.44 6445.13 6329.13 734.34 8232.38 5946718. 16 567015.57 -734.34 15. 32 MWD 12956.16 96. 72 202.14 6441.50 6325.50 705.30 8221.94 5946689. 04 567005.35 -705.30 15. 02 MWD 12986.83 95 .64 206.76 6438.20 6322.20 677.55 8209.32 5946661. 20 566992.95 -677.55 15. 38 MWD 13022.76 96. 66 212.28 6434.35 6318.35 646.48 8191.73 5946629. 99 566975.60 -646.48 15. 54 MWD 13065.94 93. 70 217.92 6430.45 6314.45 611.32 8167.01 5946594. 64 566951.16 -611.32 14. 70 MWD 13093.88 90 .17 219.20 6429.50 6313.50 589.49 8149.60 5946572. 68 566933.93 -589.49 13. 44 MWD 13128.42 91. 62 215.61 6428.96 6312.96 562.06 8128.63 5946545. 09 566913.17 -562.06 11. 21 MWD 13163.11 91. 61 211.86 6427.99 6311.99 533.23 8109.37 5946516. 11 566894.15 -533.23 10. 81 MWD 13202.42 92 .01 208.80 6426.74 6310.74 499.32 8089.54 5946482. 05 566874.57 -499.32 7. 85 MWD 13227.52 91. 43 202.31 6425.99 6309.99 476.70 8078.72 5946459. 35 566863.94 -476.70 25. 95 MWD 13259.42 91. 27 197.56 6425.24 6309.24 446.72 8067.85 5946429. 29 566853.30 -446.72 14. 89 MWD 13292.84 92. 20 194.07 6424.23 6308.23 414.59 8058.75 5946397. 09 566844.45 -414.59 10. 80 MWD 13320.84 91 .58 191.66 6423.30 6307.30 387.31 8052.52 5946369. 77 566838.43 -387.31 8. 88 MWD 13350.74 89. 37 190.94 6423.05 6307.05 357.99 8046.66 5946340. 41 566832.81 -357.99 7. 77 MWD 13378.94 88. 02 187.35 6423.70 6307.70 330.16 8042.18 5946312. 55 566828.54 -330.16 13. 60 MWD 13413.47 91 .58 187.12 6423.82 6307.82 295.91 8037.83 5946278. 27 566824.46 -295.91 10. 33 MWD 13446.36 89. 25 179.98 6423.58 6307.58 263.11 8035.80 5946245. 45 566822.68 -263.11 22. 83 MWD 13475.51 91. 46 173.05 6423.40 6307.40 234.03 8037.57 5946216. 40 566824.68 -234.03 24. 95 MWD 13507.72 89 .56 166.01 6423.11 6307.11 202.38 8043.42 5946184. 79 566830.78 -202.38 22 .64 MWD 13536.33 93. 95 159.93 6422.23 6306.23 175.06 8051.78 5946157. 54 566839.36 -175.06 26. 20 MWD 13586.00 102. 50 161.00 6415.13 6299.13 128.78 8068.21 5946111. 39 566856.14 -128.78 17. 34 MWD • ~II~P~~~+~"' ~` ConocoPhillips Alaska, Inc. KRU 1J-03L2 1J-03L2 API: 500292300261 Well T : PROD An le TS: d TusiNC 1o-11161, 00:3.5oa, SSSV Type: NIPPLE Orig Com letion: Angle @ TD: deg @ io:2.992) Annular Fluid: Last W/O: Rev Reason: NEW WELL Reference L 30' RKB Ref L Date: Last U ate: 10/3/2005 Last Ta TD: 11591 ftKB -- Last Ta Date: Max Hole An le: 0 de Casin Strin - L2 SLOTTED LI NER Alternatin slotted/solid i e liner Descri lion Size To Bottom TVD Wt Grade Thread L2 SLOTTED LINER 2.375 11590 13490 13490 4.60 L-80 STL Casin Strin -COMMON STRINGS Descri lion Size To Bottom TVD Wt Grade Thread SURFACE 9.625 0 7784 7784 40.00 L-80 BTCM PRODUCTION 7.000 0 11255 11255 26.00 L-80 BTCM CONDUCTOR 20.000 0 120 120 91.50 H-40 WELDED LINER - Main L To Portion 3.500 11101 11590 11590 9.30 I-80 SLHT I~ Tubin Strin -TUBING 1 Size To Bottom TVD Wt Grade Thread IiC; ; 3.500 0 11161 11161 9.30 L-80 EU MOD ~ ' Pertorations Summa Interval TVD Zone Status Ft SPF Date T e Comment - 1 i• 11592 - 11655 11592 - 11655 63 40 9/4/2005 SLOTS Alternating Slotted/Blank Pi 11781 - 12319 11781 - 12319 538 40 9/4/2005 SLOTS Alternating Slotted/Blank Pi 12414 - 12730 12414 - 12730 316 40 9/4/2005 SLOTS Alternating Slotted/Blank Pi 12981 - 13457 12981 - 13457 476 40 9/4/2005 SLOTS Alternating Slotted/Blank Pi Gas Lift MandrelsNalves St MD TYD Man Mfr Man Type V Mfr V Type V OD Latch Port TRO Date Run Viv Cmnt 1 3534 3534 CAMCO KBUG GLV 1.0 BK 0.156 1320 9/11/2005 ~ ~' L ' 2 6910 6910 CAMCO KBUG GLV 1.0 BK 0.188 1350 9/11/2005 I ,~ 3 9091 9091 CAMCO KBUG GLV 1.0 BK 0.188 1340 9/11/2005 4 10229 10229 CAMCO KBUG GLV 1.0 BK 0.188 1340 9/11/2005 5 11028 11028 CAMCO KBUG OV 1.5 RK 0.188 0 9/11/2005 Other lu s e ui .etc. -LINER -MAIN LEG Depth TVD Type__ _ _ Descri lion ID 11101 11101 TIE BACK TIE BACK SLEEVE 5.250 11109 11109 PACKER BAKER 5" x 7" ZXP LINER TOP PACKER 4.438 11115 11115. HANGER BAKER 5" x 7" FLEX LOCK LINER HANGER w/RS NIPPLE 4.250 11129 111291 SBE BAKER SBE 80-40 4.000 11187 11187 ~ NIP HOWCO XN NIPPLE w/2.75" NO GO 2.750 11574 11574 ! Window L2 2.gg2 Other lu s e ui .etc. - L2 LINER De th TVD ' T e Descri ion ID 11590 11590 L2 Deploy Sub BTT SEAL BORE DEPLOYMENT SLEEVE w/3" GS PROFILE 1.920 Other lu s e ui .etc. -COMMON JEWELRY De th TVD T e Descri lion ID 539 539 NIP CAMCO 'DS' NIPPLE w/NO GO PROFILE 2.865 11078 11078 NIP CAMCO 'DS' NIPPLE w/NO GO P ROFILE 2.812 11122 11122 LOCATOR _ _ BAKER NO GO LOCATOR 3.000 window ~2 11124 11124 SEAL BAKER GBH-22 35' SEAL ASSEMBLY 3.000 ;11574-11575, 11161 11161 SHOE BAKER MULE SHOE 3.000 00:3.000> General Notes Date Note 9/4/2005 MULTI-LATERAL WELL: 1J-03 PARENT BORE 1J-03L1 1J-03L2 Perf = ;11592-11655) Ped - ;11781-12319) -_ Perf - ;12414-12730) - Perf ;12981-13457) - I I I I ~ ~ I ~ ~ I I = - -_ = - • 11 /09/04 STATE O F ALASKA OIL AND GAS CONSERVATION COMMISSION BOPE Test Report Submit to: .E~E'3.. rE~g~ ~~rt'i~t,s~~~ f__~~c.u i~ti~.~~'E; ~%~~EJE~?'~E~£? i3r.',~'{r``~..c'.EE~'B`(li(~.:~~i~:F'.c~---: E_e~a 1:~~~i•~ E~~E?+:~E`(1S~£?(1~,,xJ;~C~(~'Ei(9 St~'~~3.~?t.(.1~4 .............................k.N___.........................___..._...... ._ ....... Contractor: Nordic .. Rig No.: 2 DATE: 8/29/05 Rig Rep.: Mckeiman / Dowell Rig Phone: 659-4398 Rig Fax: 659-4356 Operator: BPX Op. Phone: 659-4393 Op. Fax: 659-4356 Rep.: Goodrich / Sevcik E-Mail ss~~c~~~~~rl~,rE~~~ie~tc?~If?~s~€~E~~~~?_~_tr3 Well Name: 1J-03L2 PTD # 205-121 Operation: Drlg: XXX Workover: Explor.: Test: Initial: Weekly: Bi-Weekly XXX Test Pressure: Rams: 250-3500 Annular: 250-3500 Valves: 250-3500 MISC. INSPECTIONS: TEST DATA FLOOR SAFETY VALVES: Test Result Test Result Quantity Test Result Location Gen.: P Well Sign P Upper Kelly NT Housekeeping: P Drl. Rig P Lower Kelly NT PTD On Location P Hazard Sec. P Ball Type 2 P Standing Order Posted P Inside BOP NT BOP STACK: Quantity Size/Type Test Result MUD SYSTEM: Visual Alarm Stripper 1 2" P Trip Tank P P Annular Preventer 1 7 1/16" P Pit Level Indicators P P #1 Rams 1 Blind /Shear P Flow Indicator P P #2 Rams 1 2" Combi P Meth Gas Detector P P #3 Rams 1 2 3/8" Combi P H2S Gas Detector P P #4 Rams 1 2" Combi P #5 Rams N/A NA Quantity Test Result Choke Ln. Valves 1 3 1/8" P Inside Reel valves NA HCR Valves 2 3 1/8" P Kill Line Valves 1 3 1/8" P ACCUMULATOR SYSTEM: Check Valve N/A NA Time/Pressure Test Result System Pressure 3000 P CHOKE MANIFOLD: Pressure After Closure 2250 P Quantity Test Result 200 psi Attained 15 sec P No. Valves 14 P Full Pressure Attained 78 sec P Manual Chokes 1 P Blind Switch Covers: All stations Y Hydraulic Chokes 1 P Nitgn. Bottles (avg): 4 2000 Test Results Number of Failures: 0 Test Time: 4_5 Hours Components tested 29 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: ,~~E~3_.rE}g~~~~r~'i~3.s~~~kf_~>t:us Remarks: Distribution: 24 HOUR NOTICE GIVEN orig-Well File YES XXX NO c - Oper./Rig Waived By Jeff Jones c -Database Date 8/28/05 Time 07:00 c -Trip Rpt File Witness Tyler Mconnell c -Inspector Test start 13:00 Finish 17:30 Coil Tubing BFL 11/09/04 Nordic 2 80P 8-29-05p.xls Sean McLaughlin CT Drilling Engineer ConocoPhillips Alaska Inc. P.O. Box 196612 Anchorage, Alaska 99519-6612 Re: Kuparuk 1J-03L2 ConocoPhillips Alaska Inc. Permit No: 205-121 FRANK H. MURKOWSK/, GOVERNOR 333 W. 7TM AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Surface Location: 2107' FSL, 2419' FEL, SEC. 35, T11N, R10E, UM Bottomhole Location: 2136' FSL, 109' FWL, SEC. 31, T11N, R11E, UM Dear Mr. McLaughlin: Enclosed is the approved application for permit to redrill the above development well. The permit is for a new well branch of existing well KRU 1J-03, Permit No. 201-024, API No. 50-029-23002-00. 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 revoc on r suspension of the permit. Please provide at least twenty-four (24) hours otice r a representative of the Commission to witness any required test. Con . ct thg C mmission's petroleum field inspector at (907) 659-3607 (pager). Norman DATED this day of August, 2005 cc: Department of Fish 8~ Game, Habitat Section wJ o encl. Department of Environmental Conservation w/o encl. STATE OF ALASKA ALAS~L AND GAS CONSERVATION CO I ~,IISSIO~ Aug o ~ ~~o~~ ~ls PERMIT TO DRILL 20 AAC 25.005 1t~.,r~,., n.~ b w ,~ ia. Type of work ^ Drill ®Redrill ^ Re-Entry ib. Current Well Class ^ Exploratory ®Developmeer~t O~ fvlul ip e o ^ Stratigraphic Test ^ Service ^ Developm HI~C~ f~8iingle Zone 2. Operator Name: Conoco Phillips Alaska Inc. 5. Bond: ®Blanket ^ Single Well Bond No. 59-52-180 11. Well Name and Number: 1J-03L2 3. Address: c/o P.O. Box 196612, Anchorage, Alaska 99519-6612 6. Proposed Depth: MD 13625 TVD 6360 12. Field /Pool(s): Kuparuk River Field /Pool 4a. Location of We11 (Governmental Section): Surtace: 2107 FSL 2419' FEL SEC T11 N R10E 35 UM ~ 7. Property Designation: ~~'~' ~ ADL 028248 =~~ ~s ~ `~ ~'~' 1 ~' V'~ , , . , , , Top of Productive Horizon: 4175 FSL, 1455' FWL, SEC. 36, Ti 1 N, R10E, UM 8. Land Use Permit: 13. Approximate Spud Date: August 20, 2005 Total Depth: 2136 FSL, 109' FW L, SEC. 31, T11 N, R11 E, UM 9. Acres in Property: 1920 14. Distance to Nearest Property: 2060' 4b. Location of Weii (State Base Plane Coordinates): Surface: x- 558790 - 5945920 Zone- ASP4 10. KB Elevation (Height above GL): 116.12 feet t5. Distance to Nearest well Within Pool 1 D-34 is offset by 1225' 16. Deviated Wells: Kickoff Depth: 11572 feet Maximum Hole Angle: 94 de rees 17. Maximum Anticipated Pressures in psig (see 20 AAC 25.035) ,$D Downhole: 2839" ,~SZ~' Surtace: 3690'' Z s~.3 ~ ~' `/~ 18. as ng rogram: Size Specifications Setting Depth To Bottom uant~ty o errrent c.f. or sacks Hole Casin Wei ht Grade Cou lin Len th MD TVD MD ND includin sta a data 3" 2-3/8" 4.6# L-80 STL 2048' 11577' 6462' 13625' 6360' Uncemented Slotted Liner 19. PRESENT WELL CONDITION SUMMARY (To be completed for Redrill AND Re-entry Operations) Total Depth MD (ft): 12214 Total Depth TVD (ft): 6816 Plugs (measured): None Effective Depth MD (ft): 12146 Effective Depth TVD (ft): 6778 Junk (measured): None Casin Len th Size Cement Volume MD TVD r r n r 120' 16" 00 sx Arcticset I 120' 120' 7784' 9-518" 70 sx AS Lite, 486 sx Lite Crete 7784' 4269' 11255' 7" 170 sx Class 'G' 11255' 6272' o ci n 1113' 3-1/2" 56 sx Class 'G' 11101' - 12214' 6180' - 6816' L1 Liner 1455' 2-3/8" Uncemented Slotted Liner 11595' - 13050' 6356' - 6395' Pertoration Depth MD (ft): 11606' - 11843' Perforation Depth TVD (ft): 6479' - 6612' 20. Attachments ^ Filing Fee, $100 ®BOP Sketch ®Drilling Program ^ Time vs Depth Plot ^ Shallow Hazard Analysis ^ Property Plat ^ Diverter Sketch ^ Seabed Report ®Drilling Fluid Program ®20 AAC 25.050 Requirements 21. Verbal Approval: Commission Representative: Date: 22. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Sean McLaughlin, 564-4387 Printed Name Sean McLaughlin Title CT Drilling Engineer Prepared By Name/Number: Si nature /`' ~ Phone 564-4387 Date $ 3 vS Terrie Hubble, 56a-4628 Commission Use Only Permit To Drill _ Number: :-a~'"l~.l AP1 Number: 50- 029-23002-61-00 Permit Approv Date: ~ See cover letter for other requirements Conditions of Approval: Samples fired ^ Yes No Mud Log Require ^ Yes ~ No ydro fide Measures ~ Yes ^ No Directional Survey Required Yes ^ No Other: ~S,~.~ ~ rti. ~OQ ~r,~..~n.°~ ~~~'~. Vur-tc~,. ~ S.o3to C~~ C.`tl cue +~~.c~. ~ac~ i~~~'"~' 1'ro~.c~,~~o rn~t~1~.S'~3C7~ uS APPROVED BY C7~~/~I A roved B THE COMMISSION Date v c. ~ Form 10-401 Revised 0 /2~ 00~}/ "" ` ' " ' ` "" "' rryf `/ - u / n up icate I_ KR~J-03L1 and iJ-03L2 Sidetracks - C~d Tubing Drilling Summary of Operations: A coiled tubing drilling unit will drill 2 laterals in producer KRU 1J-03 using the managed pressure drilling technique (MPD, see description below). These horizontal laterals will target Kuparuk C sand reserves for production. CTD Drill and Complete 1,T-03L1 & l,T-03L2 program: Planned for August 20, 2005 Pre-Rig Work I. Positive pressure and drawdown tests on MV and SV 2. Test Packoffs - T&IC 3. Dummy GLV's 4. MIT-IA, MIT-OA 5. Caliper 3-1/2" liner, memory GR/CCL log 6. Drift tubinglliner with dummy whipstock Rig Work 7. MIRU Nordic 2. NU 7-1/16" BOPS, test. 8. Set 3-1/2" LSX whipstock @ 11600' md. 9. Mill 2.74" window and 10' of open hole. 10. Drill 3" bicenter hole horizontal lateral from window to 13050' TD targeting Kuparuk C sands. 11. Kill well w/ brine & Complete with 2 318" slotted liner from TD up into the 3-1/2" liner to 11595' md. 12. Set Weatherford SS-WSRBB packer at 1.1582' md. 13. Stab into packer with retrievable 3-1/2" hollow whipstock, targeting top of whipstock at 11572 md. 14. Mill 2.74" window and 10' of open hole. 15. Drill 3" bicenter hole horizontal lateral from window to 13625' TD targeting Kuparuk C sands. 16. Ki11 well w/ brine & Complete with 2 3/8" slotted liner from TD, to 5'-l0' outside the 3-1/2" casing exit. 17. Retrieve hollow whipstock from L2. ~ ~ ~~_ , l 8. ND BOPE. RDMO Nordic 2. ` ~~~ ~~~ ~ Post Rig work 19. Post CTD rig -Run GLVs. Mud Program: • Step 9: chloride-based biozan brine (8.6 ppg) • Steps 10, 12-15: chloride-based Flo-Pro (8.6 ppg) • Steps 11 & 16: Potasium Formate KWF (10.8 ppg) Disposal: • No annular injection on this well. `r • Class II liquids to KRU 1R Pad Class II disposal well • Class II drill solids to Grind & Inject at PBU Drill site 4 • Class I wastes will go to Pad 3 for disposal. Casing Program: • 1J-03L1: 2 3/8", 4.6#, L-80, STL slotted liner from 11,595' and to 13,050' and • 1J-03L2: 2 318", 4.6#, L-80, STL slotted liner from 11,577' and to 13,625' and Casing/Liner Information 9 5/8", L-80, 40#, Burst 5750; collapse 3090 psi. 7", L-80, 26#, Burst 7240; collapse 5410 psi 3'h", L-80, 9.3#, Burst 10159; collapse 10533 psi Well Control: • Two well bore volumes (-238 bbls) of KWF will be location during drilling operations. KR~J-03L1 and 1J-03L2 Sidetracks - !~d Tubing Drilling BOP diagram is attached. Pipe rams, blind rams and the CT pack off will be pressure tested to 250 psi and to 3500 psi. The annular preventer will be tested to 400 psi and 2500 psi. Directional • See attached directional plans for 1J-03L1 & 1J-03L2 • Magnetic and inclination surveys will be taken every 30 ft. No gyro will be run. • The nearest well to 1J-03L1 is ID-34 which is offset by 1020'. KPA boundary is 1975' away. • The nearest well to 1J-03L2 is 1D-34 which is offset by 1225'. KPA boundary is 2060' away. Logging • MWD directional and Gamma Ray will be run over all of the open hole section. Hazards L1 & L2 will both cross one mapped fault. Lost circulation risk is moderate. Expect to encounter increasing pressure as lateral is drilled away from the mother well. Well 1J-03 has a H2S reading of 58 ppm. Well 1D-39 has a close BHL to 1J-03 and has recorded 110 ppm H2S. All H2S monitoring equipment will be operational. Reservoir Pressure • The most recent SBHP survey (Feb 2004) was gauged at 2,976 psi after having been SI for 9 days. Expect to encounter increasing pressure as lateral is drilled away from mother well. Max. expected pressure of 3500 psi. The EMW is 10.6 ppg at 6343' TVD (L2 KOP). Max. surface pressure with gas (0.1 psi/ft) to surface is 2839 psi. Variance request • BPXA requests a variance to the provisions of 20 AAC 25.036 (d)(4) THROUGH TUBING DRILLING AND COMPLETION. This is regarding the function pressure test requirement after the use of BOP ram ~r type equipment for other than well control or equivalent purposes. The variance will not apply when the / ' routine use of BOP ram type equipment may have compromised their effectiveness. (Example would be when pipe rams are inadvertently closed on a tool joint during routine operations.) While drilling 1J-03 it will be routine to close the 2-3/8" combi rams (pipe/slip) on the BHA during deployment and undeployment. These activities will not compromise the integrity of the BOP equipment. Managed Pressure Drilling Managed pressure drilling techniques will be employed to provide constant bottom hole pressure by using 8.6 ppg drilling fluid in combination with annular friction losses and applied surface pressure. Constant BHP will be utilized to reduce pressure fluctuations to help with hole stability Applying annular friction and choke pressure also allow use of less expensive drilling fluid and minimizes fluid losses and/or fracturing at the end of the long well bores. A hydraulic choke for regulating surface pressure will be installed between the BOPS choke manifolding and the mud pits and will be independent of the BOPS 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 (2-3/8" 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. Operating parameters and fluid densities will be adjusted based on real-time bottom hole pressure measurements while drilling and shale behavior. The following scenario is expected at TD: • Estimated reservoir pressure: 3500 psi at 6343' TVD, 10.6 ppg EMW. • Expected annular friction losses while circulating: 1090 psi (based on 80 psi/100 ft) • Planned mud density: 8.6 ppg equates to 2837 psi hydrostatic bottom hole pressure. KR~J-03L1 and 1J-03L2 Sidetracks - ~d Tubing Drilling • While circulating 8.6 ppg fluid, bottom hole circulating pressure is estimated to be 3927 psi or 11.9 ppg ECD • When circulation is stopped, a minimum of 663 psi surface pressure will be applied to maintain constant BHP. ' ! C~anocc~Philli Baker Hu hes INTE to g Q Baker Hughes INTEQ Planning Report ~~~ ~N~r~~~ .. ____ i Company: ConocoPhillips Alaska, Inc Field: Kuparuk RiverUnit Site: Pad 1J Well: 3 Wellpath: PIanS, 1J-03L2 ~.-- --- Date: 8/1/2005 Time: 14:36:06 Page: 1 Co-ordinate(NE) Reference: We1i: 3, True North Vertical (TVll) Reference: Wellhead(116') 116.0 Section (VS) Reference: Weil (O.OON;O.OOE,180.OOAzi) Survey Calculation Method: Minimum Curvature I)bc Oracle Field: Kuparuk River Unit North Slope, Alaska USA Map System:US State Plane Coordinate System 1927 Map Zone: Alaska, Zone 4 Geo Datum: NAD27 (Clarke 1866) Coordinate System: Well Centre Sys Datum: Mean Sea Level Geomagnetic Model: bggm2004 Site: Pad 1 J Site Position: Northing: 5943831.65 ft Latitude: 70 15 25.530 N From: Map Easting: 561226.77 ft Longitude: 149 30 18.584 W Position Uncertainty: 0.00 ft North Reference: True Ground Level: 0.00 ft Grid Convergence: 0.47 deg Well: 3 Slot Name: Well Position: +N/-S 2107.93 ft Northing: 5945919.64 ft Latitude: 70 15 46.258 N +E/-W -2419.99 ft Easting : 558789.96 ft Longitude: 149 31 29.006 W Position Uncertainty: 0.00 ft Wellpath: PIan5, 1J-03L2 Drilled From: 1J-03 Tie-on Depth: 11560.66 ft Current Datum: Wellhead(116') Height 116.00 ft Above System Datum: Mean Sea Level Magnetic Data: 7/29/2005 Declination: 24.24 deg Field Strength: 57605 nT Mag Dip Angle: 80.73 deg Vertical Section: Depth From (TVD) +N/-S +E/-W Direction ft ft ft deg 0.00 0.00 0.00 180.00 Plan: Plan #5 Date Composed: 7/29/2005 copy Lamar's plan 1J-03 s plans Version: 1 Principal: Yes Tied-to: From: Definitive Path Targets Name Description Dip. Dir. TVD ft +N/-S ft +E/-W ft Map Northing ft Map Easting ft <_-- Deg Latitude --> Min Sec <-- Deg Longitude --> '~ Min Sec 1J-03L2 Polygon 116 .00 1963.18 7998. 37 5947945. 01 566771.99 70 16 5.524 N 149 27 36. 190 W -Polygon 1 116. 00 1963.18 7998. 37 5947945. 01 566771.99 70 16 5.524 N 149 27 36. 190 W -Polygon 2 116 .00 1807.87 8291. 20 5947792. 01 567065.99 70 16 3.993 N 149 27 27. 672 W -Polygon 3 116 .00 542.94 8261. 32 5946527. 01 567045.99 70 15 51.553 N 149 27 28. 582 W -Polygon 4 116 .00 -104.12 8131. 25 5945879. 01 566920.99 70 15 45.190 N 149 27 32. 388 W -Polygon 5 116 .00 -22.15 7879. 86 5945959. 01 566668.99 70 15 45.999 N 149 27 39. 701 W -Polygon 6 116 .00 1691.74 8050. 26 5947674. 01 566825.99 70 16 2.854 N 149 27 34. 689 W 1J-03L2 Target 6 6438 .00 29.23 8088. 29 5946012. 01 566877.00 70 15 46.502 N 149 27 33. 634 W 1J-03L2 Target 5 6457 .00 419.27 8089. 33 5946402. 01 566875.00 70 15 50.338 N 149 27 33. 591 W 1J-03L1 Target 2 6460 .00 2621.43 8104. 52 5948604. 01 566872.99 70 16 11.996 N 149 27 33. 080 W 1J-03L1 Target 3 6483 .00 2179.01 8151. 08 5948162. 01 566922.99 70 16 7.645 N 149 27 31. 739 W 1J-03L2 Target 1 6491 .00 1665.84 7909. 04 5947647. 01 566684.99 70 16 2.600 N 149 27 38. 800 W 1J-03L1 Target4 6510 .00 3117.46 8236. 41 5949101. 01 567000.99 70 16 16.874 N 149 27 29. 225 W Annotation -- r- MD TVD ft ft 11560.66 6452.52 TIP ~ 11572.00 6459.06 KOP 11592.00 6470.37 End 9°/100' DLS `~ ' ' ~ Baker Hu h s I TE ~ ~~~~ ConocoPF~~Il~ps g e N Q ~~ Baker Hughes INTEQ Planning Report ~~1 ~{~, --~~~~~--- Company: ConocoPhillips Alaska, Inc Date: 8/1/2005 Time: 14:36: 06 Page: 2 Field: K uparuk Rive r Unit Co-ordinate(NE) Re ference: Well: 3, T rue North Site: Pad 1J Vertical (TVD) Refe rence: Wellhead(116') 116.0 ~ Well: 3 Section (VSO Reference: Well (0'.OON,O.OOE,180.OOAzi) Wrllpath: PIanS, 1J-03L 2 Survey Calculation ' Method: Minimum Curvature Db: ~ Oracle Annotation Nl ll TVD --- -- - -- - ft ft 11680.29 6494.25 End 45°/100' DLS 12055.29 6482.46 5 12155.29 6477.32 6 12305.29 6471.45 7 12455.29 6474.77 8 12630.29 6478.33 9 12730.29 6477.66 10 12930.29 6475.66 11 13030.29 6471.67 12 13230.29 6457.36 13 13400.00 6447.32 14 13425.00 6447.54 15 13625.00 6476.28 TD Plan Section Information MD [ncl Azim TVD +N/-S +F./-W DLS Bu ild Turn TF O Target ~, I ft ~_.-_ deg -__ deg -- - ft _ _ ft -_ __- ft - _ - deg/100ft deg/100ft deg/100ft deg _ _ - _ _... _- _ - 11560.66 54.74 118.61 6452.52 1983.05 7952.01 0.00 0 .00 0.00 0 .00 11572.00 54.80 118.60 6459.06 1978.61 7960.14 0.53 0 .53 -0.09 352 .24 11592.00 56.36 119.68 6470.37 1970.58 7974.55 9.00 7 .82 5.40 30 .00 11680.29 92.00 138.33 6494.25 1917.27 8038.39 45.00 40 .36 21.12 30 .00 12055.29 91.41 183.35 6482.46 1572.25 8158.25 12.00 -0 .16 12.00 90 .00 12155.29 94.47 194.97 6477.31 1473.83 8142.39 12.00 3 .06 11.62 75 .00 12305.29 89.98 177.52 6471.45 1325.44 8126.19 12.00 -3 .00 -11.63 256 .00 12455.29 87.51 195.36 6474.77 1177.04 8109.45 12.00 -1 .64 11.89 98 .00 12630.29 90.18 174.52 6478.33 1003.70 8094.48 12.00 1 .52 -11.91 277 .00 12730.29 90.59 162.53 6477.66 905.88 8114.33 12.00 0 .41 -11.99 272 .00 12930.29 90.54 186.53 6475.66 708.25 8133.26 12.00 -0 .03 12.00 90 .00 13030.29 94.01 198.03 6471.67 610.79 8112.06 12.00 3 .47 11.50 73 .00 13230.29 94.07 173.97 6457.36 413.85 8091.37 12.00 0 .03 -12.03 271 .00 13400.00 92.64 194.32 6447.32 245.77 8079.18 12.00 -0 .85 11.99 93 .40 13425.00 86.39 194.32 6447.54 221.56 8073.00 25.00 -25 .00 0.00 180 .00 13625.00 78.11 144.47 6476.29 33.11 8107.39 25.00 -4 .14 -24.92 257 .50 Survey Mll Incl Azim SS TVD N/S E/yV MapN vlapN: DLS VS TFO 'fool ft deg deg ft ft ft ft ft deg/100 ft ft deg 11560.66 54.74 118.61 6336.52 1983.05 7952.01 5947964.52 566725.48 0.00 -1983.05 0.00 MWD 11568.42 54.78 118.60 6341.00 1980.01 7957.57 5947961.53 566731.07 0.53 -1980.01 352.24 1J-03L2 11572.00 54.80 118.60 6343.06 1978.61 7960.14 5947960.15 566733.65 0.53 -1978.61 352.25 MWD 11573.63 54.93 118.69 6344.00 1977.98 7961.31 5947959.52 566734.82 9.00 -1977.98 30.00 1J-03L1 11575.00 55.03 118.76 6344.79 1977.44 7962.30 5947958.99 566735.81 9.00 -1977.44 29.95 MWD 11592.00 56.36 119.68 6354.37 1970.58 7974.55 5947952.23 566748.12 9.00 -1970.58 29.91 MWD 11600.00 59.50 121.77 6358.62 1967.11 7980.38 5947948.81 566753.97 45.00 -1967.11 30.00 MWD 11618.60 66.90 126.15 6367.00 1957.83 7994.12 5947939.64 566767.78 45.00 -1957.83 28.89 1 J-031.1 11625.00 69.47 127.55 6369.38 1954.27 7998.87 5947936.11 566772.56 45.00 -1954.27 26.91 MWD 11644.78 77.49 131.59 6375.00 1942.19 8013.47 5947924.15 566787.25 45.00 -1942.19 26.39 1J-03L2 11650.00 79.62 132.60 6376.04 1938.76 8017.26 5947920.75 566791.07 45.00 -1938.76 25.24 MWD 11675.00 89.83 137.34 6378.33 1921.19 8034.84 5947903.32 566808.79 45.00 -1921.19 25.04 MWD 11680.29 92.00 138.33 6378.25 1917.27 8038.39 5947899.42 566812.37 45.00 -1917.27 24.60 MWD 11700.00 92.00 140.70 6377.56 1902.29 8051.18 5947884.55 566825.27 12.00 -1902.29 90.00 MWD 11725.00 91.99 143.70 6376.69 1882.55 8066.49 5947864.93 566840.73 12.00 -1882.55 90.08 MWD 11750.00 91.98 146.70 6375.82 1862.04 8080.75 5947844.53 566855.15 12.00 -1862.04 90.19 MWD 11775.00 91.96 149.70 6374.96 1840.80 8093.91 5947823.40 566868.48 12.00 -1840.80 90.29 MWD 11800.00 91.94 152.70 6374.11 1818.91 8105.95 5947801.60 566880.68 12.00 -1818.91 90.39 MWD 11825.00 91.91 155.71 6373.27 1796.42 8116.82 5947779.20 566891.73 12.00 -1796.42 90.50 MWD 11850.00 91.87 158.71 6372.45 1773.38 8126.50 5947756.24 566901.58 12.00 -1773.38 90.60 MWD 11875.00 91.84 161.71 6371.64 1749.88 8134.96 5947732.80 566910.23 12.00 -1749.88 90.70 MWD '`~ ' ' ~ Baker Hu hes INTE Conc~oPhillEps g Q Baker Hughes INTEQ Planning Report ~~~~ ~~.r~~=t~ __ ~- ~~ ~ - Company : Con ocoPhill ips Alaska, Inc Date: 8/1/20 05 T ime : 14:36: 06 Pa gec 3 Field: Kup aruk River Unit Co- ordinate(1VE) Reference: Wel{`. 3, T rueNorth Sitc: Pad 1J ver tical (Y'VD) Reference: Wellhead (116') 116.0 j Nell: 3 Sec tion (VS)Refere nce: Well (O.OON,O.OOE,180 .OOAzi) ~i'ellpath: PIanS, iJ-03L2 Sur vey Calculation 1Viethod: Minimum Curvature Db: Oracle i Survey ViD Incl Azim SS TVD N/S E/W NIapN N1apE DL S VS TFO Tool ft deg deg ft ft ft ft ft deg/100ft ft deg 11900. 00 91. 79 164.71 6370. 85 1725 .96 8142 .17 5947708 .94 566917 .63 12. 00 -1725.96 90. 79 MWD 11925. 00 91. 74 167.71 6370. 08 1701 .69 8148 .13 5947684 .73 566923 .77 12. 00 -1701.69 90. 89 MWD 11950. 00 91. 69 170.71 6369. 33 1677 .15 8152 .81 5947660 .22 566928 .64 12. 00 -1677.15 90. 98 MWD 11975. 00 91. 63 173.71 6368. 60 1652 .39 8156 .19 5947635 .50 566932 .22 12 .00 -1652.39 91. 07 MWD 12000. 00 91. 57 176.71 6367. 90 1627 .49 8158 .28 5947610 .62 566934 .50 12. 00 -1627.49 91. 16 MWD 12025. 00 91. 50 179.71 6367. 23 1602 .51 8159 .06 5947585 .65 566935 .47 12. 00 -1602.51 91. 24 MWD 12050. 00 91. 43 182.71 6366. 60 1577 .53 8158 .53 5947560 .67 566935 .14 12. 00 -1577.53 91. 32 MWD 12055. 29 91. 41 183.35 6366. 46 1572 .25 8158 .25 5947555 .38 566934 .90 12. 00 -1572.25 91. 40 MWD 12075. 00 92. 02 185.63 6365. 87 1552 .61 8156 .71 5947535 .73 566933 .51 12. 00 -1552.61 75. 00 MWD 12100. 00 92. 79 188.54 6364. 82 1527 .83 8153 .62 5947510 .93 566930 .63 12. 00 -1527.83 75. 07 MWD 12125. 00 93. 56 191.44 6363. 44 1503 .25 8149 .30 5947486 .32 566926 .49 12. 00 -1503.25 75. 19 MWD 12150. 00 94. 31 194.35 6361. 72 1478 .94 8143 .73 5947461 .97 566921 .11 12. 00 -1478.94 75. 35 MWD 12155. 29 94. 47 194.97 6361. 31 1473 .83 8142 .39 5947456 .85 566919 .82 12. 00 -1473.83 75. 55 MWD 12175. 00 93. 89 192.67 6359. 88 1454 .75 8137 .70 5947437 .74 566915 .27 12. 00 -1454.75 256. 00 MWD 12200. 00 93. 16 189.76 6358. 34 1430 .27 8132 .85 5947413 .23 566910 .61 12. 00 -1430.27 255. 83 MWD 12225. 00 92. 41 186.85 6357. 13 1405 .57 8129 .24 5947388 .50 566907 .20 12. 00 -1405.57 255. 65 MWD 12250. 00 91. 65 183.94 6356. 24 1380 .70 8126 .89 5947363 .61 566905 .05 12. 00 -1380.70 255. 51 MWD 12275. 00 90. 90 181.04 6355. 68 1355 .73 8125 .81 5947338 .64 566904 .15 12. 00 -1355.73 255. 41 MWD 12300. 00 90. 14 178.14 6355. 46 1330 .73 8125 .99 5947313 .65 566904 .53 12. 00 -1330.73 255. 34 MWD 12305. 29 89. 98 177.52 6355. 45 1325 .44 8126 .19 5947308 .36 566904 .77 12. 00 -1325.44 255. 32 MWD 12325. 00 89. 65 179.86 6355. 52 1305 .74 8126 .64 5947288 .67 566905 .37 12. 00 -1305.74 98. 00 MWD 12350. 00 89. 23 182.84 6355. 76 1280 .76 8126 .05 5947263 .67 566904 .98 12. 00 -1280.76 97. 99 MWD 12375. 00 88. 82 185.81 6356. 19 1255 .83 8124 .16 5947238 .74 566903 .29 12. 00 -1255.83 97. 96 MWD 12400. 00 88. 41 188.78 6356. 79 1231 .05 8120 .99 5947213 .93 566900 .31 12. 00 -1231.05 97. 91 MWD 12425. 00 88. 00 191.75 6357. 58 1206 .46 8116 .54 5947189 .31 566896 .05 12. 00 -1206.46 97. 84 MWD 12450. 00 87. 60 194:73 6358. 54 1182 .15 8110 .82 5947164. 96 566890 .52 12. 00 -1182.15 97. 75 MWD 12455. 29 87. 51 195.36 6358. 77 1177 .04 8109 .45 5947159 .84 566889 .19 12. 00 -1177.04 97. 63 MWD 12475. 00 87. 80 193.01 6359. 57 1157 .95 8104 .62 5947140 .72 566884 .52 12. 00 -1157.95 277. 00 MWD 12500. 00 88. 18 190.03 6360. 45 1133 .47 8099 .63 5947116 .20 566879 .72 12. 00 -1133.47 277. 10 MWD 12525. 00 88. 55 187.05 6361. 16 1108 .76 8095 .92 5947091. 47 566876 .20 12. 00 -1108.76 277. 20 MWD 12550. 00 88. 94 184.08 6361. 71 1083 .89 8093 .50 5947066 .58 566873 .97 12. 00 -1083.89 277. 29 MWD 12575. 00 89. 32 181.10 6362. 09 1058 .92 8092 .37 5947041 .60 566873 .04 12. 00 -1058.92 277. 35 MWD 12600. 00 89. 71 178.13 6362. 30 1033 .92 8092 .54 5947016. 61 566873 .40 12. 00 -1033.92 277.40 MWD 12625. 00 90. 10 175.15 6362. 34 1008 .97 8094 .00 5946991 .67 566875 .06 12. 00 -1008.97 277. 42 MWD 12630. 29 90. 18 174.52 6362. 33 1003 .70 8094 .48 5946986 .40 566875 .58 12. 00 -1003.70 277. 43 MWD 12650. 00 90. 26 172.16 6362. 25 984 .13 8096 .76 5946966. 85 566878 .01 12. 00 -984.13 272. 00 MWD 12675. 00 90. 36 169.16 6362. 12 959 .46 8100 .82 5946942. 22 566882 .26 12. 00 -959.48 271. 99 MWD 12700. 00 90. 47 166.16 6361. 94 935 .04 8106 .16 5946917 .85 566887 .79 12. 00 -935.04 271. 97 MWD 12725. 00 90. 57 163.16 6361. 71 910 .94 8112 .77 5946893. 80 566894 .59 12. 00 -910.94 271. 95 MWD 12730. 29 90. 59 162.53 6361. 66 905 .88 8114 .33 5946888. 75 566896 .19 12. 00 -905.88 271. 93 MWD 12750. 00 90. 59 164.89 6361. 45 886 .96 8119 .86 5946869. 89 566901 .87 12. 00 -886.96 90. 00 MWD 12775. 00 90. 59 167.89 6361. 20 862 .67 8125 .74 5946845. 64 566907 .94 12. 00 -862.67 90. 02 MWD 12800. 00 90. 58 170.89 6360. 94 838 .10 8130 .34 5946821. 11 566912 .73 12. 00 -838.10 90. 06 MWD 12825. 00 90. 58 173.89 6360. 69 813 .33 8133 .65 5946796. 36 566916 .23 12. 00 -813.33 90. 09 MWD 12850. 00 90. 57 176.89 6360. 44 788 .41 8135 .66 5946771. 47 566918 .43 12. 00 -788.41 90. 12 MWD 12875. 00 90. 56 179.89 6360. 19 763 .42 8136 .36 5946746. 49 566919 .33 12. 00 -763.42 90. 15 MWD 12900. 00 90. 55 182.89 6359. 94 738 .44 8135 .75 5946721. 50 566918 .91 12. 00 -738.44 90. 18 MWD 12925. 00 90. 54 185.89 6359. 70 713 .51 8133 .83 5946696. 56 566917 .19 12. 00 -713.51 90. 21 MWD 12930. 29 90. 54 186.53 6359. 66 708 .25 8133 .26 5946691. 30 566916 .66 12. 00 -708.25 90. 23 MWD 12950. 00 91. 23 188.79 6359. 35 688 .72 8130 .63 5946671. 75 566914 .19 12. 00 -688.72 73. 00 MWD 12975. 00 92. 10 191.66 6358. 62 664 .13 8126 .20 5946647. 13 566909 .94 12. 00 -664.13 73. 03 MWD 13000. 00 92. 97 194.54 6357. 52 639 .81 8120 .54 5946622. 77 566904 .47 12. 00 -639.81 73. 12 MWD 13025. 00 93. 83 197.42 6356. 03 615 .82 8113 .67 5946598. 73 566897 .79 12. 00 -615.82 73. 25 MWD '''~ ' ' ~ Baker Hu hes INTE ConocaF'hifl~ps g Q Baker Hughes INTEQ Planning Report MapIv MapE DLS VS ft ft deg/100ft ft 5946593.69 566896.22 12.00 -610.79 5946574.83 566890.68 12.00 -591.98 5946550.61 566884.77 12.00 -567.80 5946526.11 566880.14 12.00 -543.34 5946501.41 566876.81 12.00 -518.66 5946476.56 566874.77 12.00 -493.83 5946451.64 566874.04 12.00 -468.91 5946426.72 566874.62 12.00 -443.98 5946401.86 566876.51 12.00 -419.11 5946396.61 566877.07 12.00 -413.85 5946377.04 566878.89 12.00 -394.26 5946352.13 566880.03 12.00 -369.34 5946327.18 566879.86 12.00 -344.40 5946302.28 566878.39 12.00 -319.50 5946277.47 566875.61 12.00 -294.72 5946252.85 566871.55 12.00 -270.12 5946228.46 566866.20 12.00 -245.78 5946204.21 566860.21 25.00 -221.57 5946179.73 566855.53 25.00 -197.13 5946154.95 566853.51 25.00 -172.36 5946130.15 566854.15 25.00 -147.55 5946105.63 566857.46 25.00 -123.00 5946081.68 566863.39 25.00 -99.01 5946058.58 566871.87 25.00 -75.84 5946036.62 566882.81 25.00 -53.79 5946016.04 566896.06 25.00 -33.11 Company: ConocoPhillips Alaska, Inc Field: Kuparuk River Unit Site: Pad 1J i WeII: 3 V1'ellpath: PIan5, 1J-03L2 Survcv Date: 8/1!2005 Time: 14:36:06 Page: 4 Co-ordinate(NE) Reference: Well: 3,True North Vertical (TVD) Reference: Wellhead(116') 116.0 Section. (VS) Reference: Well (O.OON,O.OOE,180.OOAzi) Survey Calculation Method: Minimum Curvature llb: Oracle Mll lncl Azim SS TVD ]SlS ft deg .deg ft ft 13030 .29 94.01 198.03 6355 .67 610. 79 13050 .00 94.05 195.66 6354 .28 591. 98 13075 .00 94.09 192.65 6352 .51 567. 80 13100 .00 94.12 189.64 6350 .72 543. 34 13125 .00 94.13 186.63 6348 .92 518. 66 13150 .00 94.14 183.63 6347 .12 493. 83 13175 .00 94.13 180.62 6345 .32 468. 91 13200 .00 94.11 177.61 6343 .52 443. 98 13225 .00 94.08 174.60 6341 .73 419. 11 13230 .29 94.07 173.97 6341. 36 413. 85 13250 .00 93.93 176.33 6339 .98 394. 26 13275 .00 93.74 179.33 6338 .31 369. 34 13300 .00 93.54 182.33 6336 .73 344. 40 13325 .00 93.32 185.33 6335 .23 319. 50 13350 .00 93.10 188.33 6333 .83 294. 72 13375 .00 92.87 191.32 6332 .53 270. 12 13400 .00 92.64 194.32 6331 .32 245. 78 13425 .00 86.39 194.32 6331 .54 221. 57 13450 .00 85.06 188.19 6333 .40 197. 13 13475 .00 83.78 182.05 6335 .84 172. 36 13500 .00 82.58 175.87 6338 .81 147. 55 13525 .00 81.47 169.66 6342 .28 123. 00 13550 .00 80.45 163.41 6346 .21 -99. 01 13575 .00 79.54 157.13 6350 .56 75. 84 13600 .00 78.76 150.82 6355 .27 53. 79 13625 .00 78.11 144.48 6360 .28 33. 11 E/W ft 8112.06 8106.36 8100.27 8095.45 8091,92 8089.69 8088.77 8089.15 8090.84 8091.37 8093.03 8093.97 8093.61 8091.94 8088.98 8084.72 8079.18 8073.00 8068.13 8065.91 8066.36 8oss.as 8075.22 8083.53 8094.29 8107.39 73.42 MWD 271.00 MWD 270.83 MWD 270.62 MWD 270.40 MWD 270.19 MWD 269.97 M W D 269.75 MWD 269.54 MWD 269.32 MWD 93.40 MWD 93.57 MWD 93.77 MWD 93.96 M W D 94.14 MWD 94.30 MWD 94.46 MWD 180.00 MWD 257.49 MWD 257.96 MWD 258.56 MWD 259.29 MWD 260.15 MWD 261.13 MWD 262.23 MWD 263.42 M W D TFO Tool deg BP Amoco WEL~P~rx oaruu PNns, l,aau P.mxYWVP.M~ 1J-0] iN en W~ 115aO.w µ~ AM.MWU WNVw~111 °') 11aLgl V.t.elbn O In iNM~y YyN • i YI Frvrn TVD lwm• om o.w o.w REFERENCE INFORMATION co-oroinate (N/E) Relerence'. Well Centre: 3, True North Vertical (TVD Relerence: System: Mean Sea Level Section (VS Relerence: Slot- (O.OON,O.OOE) Measureo Depth Relerence: Wellhead(116') 116.00 Calwlation Methoo: Minimum Curvature ... .n ... .. r ,.. ... ..... w ..... ~,... r_... C O V r~`^ 7~ i3Ai~iR LEGEND 3`1J-03) 3 (PIan4, 1J-03L7) PIanS 1J-03L2 T Azimuths to True North M Magnetic North: 24.24° Plan: Plan #5 (3/PIanS, 1103L2) Created By Bill Michaelson Date: 8/12005 - - ~~!` Ri - hsy ~,J~.,J , - Plan#s Magnetic Field Strengthe 57605nT ------ .,:.,tact i^'o~nat cn B~II Michaelson ~~~~~ Dip Angle: 80.73° Date: 7/29/2005 ortect (907) 2671,624 CeIC (907)301-735 70 Model: bggm2004 E-mall: bi11_michaelson@;nteq cum 2100_: _ _ 3 Plano 1J-03L1 .-,... - - I- -, i - 2000 ~ I ~ it . PP _ . '.. I KOP _ }II -,_ ..1 ~ - _ '?. I ~~. ) i I 1800 _~ _ -' :- - - -- ~~t -- _. ~ . ~_ _ ... __. I - - •i •I d 2 -50 PM Vertical Section at 180.00° [50ft/in] ConocoPhillips Alaska, Inc. KRU 1 J-03 11-03 API: 500292300200 Well T : PROD An le TS: 55 11569 TuewG 1x11161, SSSV Type: Nipple Orig Com lion: 3/7/2001 Angle @ TD: 57 deg @ 12214 00.3'SOO' io:z.ssz) Annular Fluid: Last W/O: Rev Reason: Ad ust TBG to to 1 P 0' Reference L Ref L Date: Last U ate: 9/51'1004 Last T : 12005 TD: 12214 ftK6 Last Ta Date: 2/4/2004 Max Hole le: 67 d 5088 Casin SVI - ALL STRING S Descri on Size To Bottom TVD Wt Grede Thread J CONDUCTOR 20.000 0 120 120 91.50 H-40 WELDED J PRODUCTION 7.000 32 11255 6272 26.00 L-80 BTCM - SURFACE 9.625 35 7784 4269 40.00 L$0 BTCM LINER 3.500 11101 12214 12214 9.30 L-80 SLHT Tubin SMn -ALL Size T Bottom TVD Wt Grade Thread 3.500 0 11161 6216 9.30 EU-MOD Pertoretions Summa Interval TVD Zone Status Ft SPF Date T Comment 11606 - 11616 6478 -6484 C-4 10 6 6/27/2001 APERF 2.5" HSD 60 deg BH-DP ch s 11833 - 11843 6606 - 6612 A-5 10 6 5/23/2001 IPERF 2.5" HSD, 60 deg ph, BH-DP char s Stimulations $ Treatments ~ Interval Date T Comment _ 11606 - 11616 6/28/2001 FRAC C- SAND FRAC, 58,000#, 16/20 CARBOLITE, 7 ppa ON PERFS Gas Lift MandrelsNalves St MD TVD Man Mfr Man Type V Mfr V Type V OD Latch Port TRO Date Run Viv Cmnt 1 3534 2509 CAMCO KBUG CAMCO GLV 1.0 BK 0.156 1270 7/2/2001 2 6910 3909 CAMCO KBUG CAMCO GLV 1.0 BK 0.188 1303 7/2/2001 3 9091 4960 CAMCO KBUG CAMCO GLV 1.0 BK 0.188 1298 7/2/2001 TIE BACK 4 10229 5652 CAMCO KBUG CAMCO GLV 1.0 BK 0.250 1394 7/2/2001 ;11101-n1oz, ~so) oD:s 5 11028 6136 CAMCO MMG CAMCO OV 1.5 RK 0.250 0 7/2/2001 . Oth er s ui .etc. -LINER De th TVD T e Descri lion ID 11101 6180 TIE BACK TIE BACK SLEEVE 5.250 11109 6184 PKR BAKER 5"X7" ZXP LINER TOP PACKER TKC COUPLING 4.438 11115 6188 HANGER BAKER 5" X 7" FLEX-LOCK LINER HANGER W/RS NIPPLE &TKC COUPLING 4.250 11129 6196 SBE BAKER SBE 80-40 wlfCK cou li s & XO 4.000 11187 6231 NIP HOWCO XN NIIPLE WITH 2.75" NO GO SLHT BOX X PIN 2.750 11650 6504 PLUG SAND PLUG 0.000 12146 6778 COLLAR BAKER LANDING COLLAR SLHT 0.000 12179 6796 COLLAR BAKER FLOAT COLLAR SLHT 0.000 12214 12214 SHOE BAKER FLOAT SHOE SLHT 0.000 SEAL Other s ui .etc. -JEWELRY ,111za-11125, oo:a.ooo) De ND T Desch ion ID 539 538 NIP CAMCO'DS' ni le with NO GO file 2.875 11078 6166 NIP CAMCO 'DS' ni le w/NO GO le 2.812 11122 6192 LOCATOR BAKER NO GO LOCATOR 3.000 11124 6193 SEAL BAKER GBH-22 35' Seal Assemb 3.000 11161 6216 SHOE BAKER mule shoe 3.000 General Notes Date Note 5/23/2001 30 min. of SIBHP of 3486 PSI at mid rt. FRAC 11606-11616) Perf '11606-11616) PLUG ;11650-17214, Perf '11833.11843) KRU 1J-03L1 & L2 Producer -Proposed Completion 3-1/2" Camco DS nipple, 2.875" min ID at 538' MD 9S/8" 4f9# L-80 (a3 7784' 3-1/2" 9.3# L-80 EUE 8rd Mod Tubing 3-'/2" Camco KBUG GLM @ 3534', 6910', 9091', & 10229' MD 3-'/z" Camco MMG GLM @ 11028' MD Baker ZXP Packer w/SBE @ 11109' MD 7" 28# J-55 (d3 11255' MD " Iliburton XN nipple, 2.75" min ID @ 11187' MD 2-3/8" liner top @ +/-11577' MD ~ / 3" openhole L2 P 11572' MD Win win 3-1/2" `. ,_ ., trievable hollow whipstock @ 11572' and ~~ SS-WSRB a +/-11582' IVD ~ 2-3/8" Baker deployment sub @ 11595' and L1 KOP 11600' MD Window in 3-1/2" 3" openhole C4 Sand perfs I I ~ 3-'/Z" LSX WS 3-112" 9.3# L-80 Fill (tD 12146' PBTD ads- ~a- \ " liner ~ ~..`.` ~ \ n oPhilli Co oc ps Alaska, Inc. • TD @ 13630' and 2-3/8" slotted liner 1 J-03 L1, TD @ 13050' and 05-24-05 h ' ~ Kuparuk DOBCTD BOP configuration 2" CT KB Elevation Well 1 J-03L1,L Rig Floor ........ .................. >x i_~br~caTa~.lf3:~ 6.375 W[th;.6 Ups :. .: s:<:•::<: ::: ~:::=:> :<~: ~= l+J ~ r.Y .. :::: 71/T~':t~(3 PEE ~F"s. fb ~ 7.C>G" i ~ .........:>:;:ii:~>:~::>:;::;:: :;:.;:.;:;:;;;;:;;:~:. 7176` ~UO~.A~~; ~'3'1~.4fi._ '' '' # ~h~«i 'ii iii?iii ... ~: v. ..... •: \j •~ 1:l~ '~UI77.: ~'~' Y1~V~ i max:' •••• :i•:ii ............ .~' ~ x ::. ........ . r. r..... .... .. :::..:::...:. iiiiiiiii .::i>i>ii:::iii:is .: .... ~... 11 }} ~~aa~~ ppyy ~ 7(1F~. N: ,.7,V0~ $f..r,{~~46 .......:: ... ::::. :...:.. i: .: ::.:...: :: ........ . .;:.;:.;:.;:.;:.:;.: :.:..:.~:::::::: :....i:::.;;::;::;:.i:.i: Ktll>Line .;:.i:.;:.;:.;:.i;:.;: .:. :~: ~ :.:.; ;:.:: ~:: ..:...:...: . °~ 2 1/'f 6" SQOd ~Si ; f~X-24 4:::. :;5 .:: y.: v:::. ":•: 7 T/l6° 5000 i3s1 ~RX-46) Of f- :>:; - 4 1lTB" 5400 p$i(RX-39) Swab Valve Tree Size '~~''~='::r~ri< • 1t>~' SSV Master Valve {r. ~.-.,,,~::,i: _yrr : o ~ 1.":. .......Y... "'"''`'~ ~` `~ Base Flan e .f.-..-~;~~ :,:.r~r::: . rfrr . /}}'' Page 1 ~1" ;r f~ rt~ -- - • ...-,q {~,ltir :'j~ti M'H ~-. ,~ t ; _ _ ~ .- .~.,-!~ ~~ t, ~~- .:..,~ ,~~ -~ K RU 1 J-03 L2 /~! i t~ - ~ i ,o-,zs ,o- - - ~.~ '' ''` ~~ Proposed 1-Oil ~ ~ d ~- a ~~•~ ~ t E-.v3P~~ ~ 25 ~' 3~1~~ ~ t 3Pt .' ~,j ~ ~~, ~ ~ : •~~-' 3.~ ~ ,~~ Kuparuk Oil Pool ~~ ,Ei$M ~'~ -''`' ;- ,~ , ~~ ~` '~~ ~ - 2051210 II~ ,~ ~~ ,:- , I -i ,,~~ ~' ~' ~,' w %~1 ,~ ~; 1 ' " ~ Confidential wells shown as red i. ,.. `. ,F s S F D 8/4/2005 ~ _ I ~ s~-iosPa~ ~, -. - _ _ -, -- - - - . _... r,,D v~L,-.. -i iC ~iq, ~~ :~_- i ® ~ ~~ '' j I ! ~ io-4ni, 1 ie~-+oasua ~ ~ ,~ I '~~' - ,.~' . 4 y,,o-~eu • ~ ~1 _,,,, ~ - ,,; i , r-,eau ~ ° 1 I ~~ ~ J _ I 1 __ _ , r _. 1D~0 c - _,.k. I t ... ..~ ~ f i L7 ', " ~ ,o-4e ~ c; j ' O rn ~~ - O° n~~ , ,_.,,,~. „~. ~5~ o .. o ~ i O ~? i ~ ,_ -,- _ - ~, ~~: 1-2000T ~~ ~' °~- Slotted Liner ~: 0 0 7 Jo - o, n 1E-117L3 1 E-170L.Y ~`~,~,~~;~;~ 111 N, R10E, U.N NSP-14 T11 N, R11 E~ u. Feet 0 1,000 2,040 3~~00 4,000 • . TRANSMITAL LETTER CHECK LIST CIRCLE APPROPRIATE LETTER/PARAGRAPHS TO BE INCLUDED IN TRANSMITTAL LETTER WELL NAME 1C ~ ~~ / ~ ~~'~ L' CHECK WHAT ADD-ONS "CLUE" APPLIES (OPTIONS MULTI The permit is for a new wellbore segment of LATERAL ~ -~~~ existing well ~~ S~~ ~~.~-Z-- 1.~/-c;z API No. Y Permit No, (If API number Production should continue to be reported as last two (2) digits a function of the original API number stated are between 60-69) above. PILOT HOLE In accordance with 20 AAC 25.005(f), all (per records, data and togs acquired for the pilot hole must be clearly differentiated in both name (name on permit plus PH) and API number (50 - 70/80) from records, data and togs acquired for well (name on permit). SPACING The permit is approved subject to full EXCEPTION compliance with 20 AAC 25.055. Approval to perforate and produce/infect is contingent upon issuance of a conservation order approving a spacing exception. (Company Name) assumes the liability of any protest to the spacing exception that may occur. DRY DITCH All dry ditch sample sets submitted to the SAMPLE Commission must be in no greater than 30' sample intervals from below the permafrost or from where samples are first caught and 10' sample intervals through target zones. ~2- Rev: 04/01/05 C\jody\transmittal_checklist WELL PERMIT CHECKLIST Field & Pool KUPARUK RIVER, KUPARUK RV OIL • 490100 __WeII Name: KUPARUK RIV UNIT 1J-03L2 Program DEV WeII bore see ^ PTD#: 2051210 Company CONOCOPHILLIPS ALASKA INC Initial ClasslType DEV / PEND GeoArea 890 Unit 11160 OnlOff Shore On Annular Disposal ^ Administration 1 Permitfeeattached___________________________________ _______--NA__ ______Multilate[alwellbor_e;feewaiyed_per20_AAC25.005(e)_______-----_-_________-._ 2 Lease number apprgpriate_ _ - - _ _ _ - . _ - - - . Yes - _ _ - - -Corrected omission on-407 form; topproductive interval.is in ADL 025661, TD_ in AOL 028248.. 3 Uniquewell_nameandnumber_____________________________ _________ Yes. -...-______._-___-__- ---------------------------------------------------- 4 Well located in a_defined-pggl._________________________ _________Yes_ ___--_KuparukRiver Oil Pool,ggvernedbyConseryati_onOrderNo.4320--_________---__--_____--__ 5 WeII located Proper distance.from drilling unitboundary_ - _ - - Yes Conservation Order No. 4320 ~ntains rig spacing restrictions with respegt_tg drilling unit boundaries. - - 6 WeII located proper distance from ether wells_ _ - - _ _ - - - - Yes - _ _ - _ - Cgn_servation Older No. 4320 has no in_terwell_spacing_rest[ictigns_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ 7 Sufficient acreage available in-drilling un~_ - - _ _ _ - _ _ Yes Conservation Order No. 4320 has no interwell_spacing_restriclions, Wellbore will be-more than 500' from - _ _ - 8 If_deviated, is-we_Ilbore plat_inelutled - - - - _ _ _ - _ - _ _ _ _ _ Yes an-external property line where_ownership gr_lan_dgwnership changes. - _ - _ - - _ _ _ - - 9 Operator gnly affected party- - - - - -Yes - - - - - - - 10 Operator has.appr9prlate.bondinfgrce ------ ----- -------- -- -- --Yes- ..- -- -- -------- ------------- - ------ --..... -- -- --- -- -- 11 Permit-can be issued withoutconserva#igngrder__________________ __--_--_-Yes_ _____---_-_____ ----------------------------------------------------------- pr Date 12 Permit-can be issued withou# administrative_appr_oyal _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes _ _ _ - - - _ _ _ _ _ _ - _ _ _ _ _ _ -- -- 81412005 13 Can permit be approved before 15-day wait Yes 14 Well located within area and strata authorized by-Injection Order # (put 10# in_comments)-(For_ NA_ - _ _ - _ - _ _ - - _ 15 All wells within1l4_mileareaofreyiewidentified(Forservicewellgnly)______ _________NA__ _,__-__--__-________-_--__-___________.---__________-_.-.-_-___-___--_---_ 16 Pre-produced injector duration-of pr_e production less than_ 3 mgnths_(Fgr_service well only) . NA_ ---------------------------------------------------------------- 17 ACMP_FindingofCgnsistency_hasbeenissued_fgr_thisproject___________ _________ NA__- ________------_______-.__-_____---__--________-_------________- Engineering 18 Conductorstring_provided_______________________ ________ _______NA_- -__-_Conductorset_in mot_herbore,-1J,03(201-024),__--_-.--________-_--_-_-______-_-_- 19 Surface casing-protects all kngwn- USDWs _ _ _ - NA_ _ _ _ All aquifers exempted, 40 CFR-147.102 (b~(3).- _ _ - - - - --------------------------------- 20 CMT_v_oladequate-tg circul_ate_on cgnductor_& surf-csg _ _ - - _ NA_ - Surface casing set in_motherbore. ------------------------------------------------ 21 CMT-vol-adequate_to tie-in long string tosurf csg- - - - .. - - - - NA- _ - - _ Pr_oducti4n. casing set in_motherbore. All hydrocarbon zones covered._ 22 CMT-willcoyer-allkno_w_n_productive horizon_s_---_.______ - - No-__ ____-Slgttedlinercgmpletionpl_anned____________________________________________ 23 Casing desgns adequate for C, T B &_permafrost- - NA_ Motherbore meets design requirements, NA fgr_slotted line[.. - - . - - - - - 24 Atlequat_e iankage_or reserve pit - . - - . _ _ - - Yes _ - - Rig is.equippe_d with steel-pits. -No reserve_pitplanned, All waste to approved annulus or disposal well. 25 Ifa_re-drill,has-a_1.0-403forabandonmentbeenapp_roved__-_---_---- ----------N_A___ _---.--_________-__-___ __,-_-__________-.-_-_________------ _______ _-__ 26 Adequate wepbore separation_propgsed_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes _ . _ _ - -Proximity analysis performed, Nearest well segment-is motherbore with lateral moving away. _ _ _ _ _ - _ _ _ _ _ _ _ 27 Ifdiverterrequired,doesitmeetregu_la_lions_____--_____________ _________ NA___ ____BOPstack_willalready_beinplace,___-___-_-_______-----________---__--______. pr Date 28 Drilling fluid_program schematic & equip list adequate. - - . - Yes Maximum expected formation pressure 10.6 EMW._ Plan to drill with.8.6 ppg fluid and frictionlapplied pressure, . . 8!5/2005 29 BOPEs,_do they meet regulation Yes _ - - _ _ - 2 volumes of kill_weight fluid will be kept at location as contingency. _ . - 30 BOPE-press rating appropriate; test to (put prig m comments) _ - _ Yes _ _ MASP calculated at 2839 psi 3500_psi BOP testproposed._ _ 31 Choke-manifold complies wlAPl_RP-5$ (M_ay 84) _ Yes - BHA will be deployed underpressure using pipelshp rams. Well does not have_SSSV. 32 Work will occur without operation shutdown_ _ _ - - _ _ - - Yes - _ - - Variance requested to 20 AAC 25.036_ (d)-(4) regarding routine use of BOP not cgmpromising i_ntegrity._ 33 Is presence. of H2Seas-probable _ - . Yes _ _ - - H2S has heen_reported in_1J-03.- Mod should preclude H2S on-rig, Rig_has sensors and alarms._ _ - - 34 Mechanical condition of wells withinAORyerified(Forservicewellonlya--___ ____.--_ NA___ ___-.-_____________________-____________-________--_--_-___-___---. Geology 35 Petmit_can be issued wlo hydrogen_sulfide measures _ . _N_o_ KRU 1J-03 hasprodueed 58 ppm of H2S, H2S monitoring_equipmentwill be used. - - - - . 36 Data_presented on potential overpressure zgnes Yes - _ - - _ Expected reserovirpressure i_s 35Q0-psi (10.6 ppg EMW). -WeII. will be drilled withcoiled tubing 8_ Appr Date 37 Seismic analysis of shallow gas_zones... - NA_ - _ - - -pressure drillingtechniques, Mmultilaleral branch drilled-from an_existing well.- _ . - - - ----- -------- SFD 8!412005 38 Seabed condition survey_(ifoff-shore) - - - - _ _ - _ ----- --------- 39 Contact name/phone fgr weekly progress_reports [exploratory only - - _ _ _ - NA- Geologic Engineering Pu i Commissioner: Date: Commissioner: Date C © r Date • 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 simpl'rfy t^inding infom~ation, 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 06/11/17 BHI 01 LIS Customer Format Tape **** TAPE HEADER **** MWD 05/08130 958647 01 2.375" CTK *** LIS COMMENT RECORD *** !!!!!!!!!!!!!!!!!!! Remark File Version 1.000 !!!!!!!!!!!!!!!!!!! Extract File: ldwg.las Version Information VERS. 1.20: CWLS log ASCII Standard -VERSION 1.20 WRAP. N0: One line per frame Well Information Block #MNEM.UNIT Data Tyne Information. STRT.FT 11579.0000: Starting Depth STOP.FT 13589.0000: Ending Depth STEP.FT 0.5000: Level Spacing NULL. -99,.2500: Absent Value COMP. COMPANY: ConocoPhillips Alaska, Inc. WELL. WELL: 1J-03L2PB1 FLD FIELD: Kuparuk River Unit LOC LOCATION: 70 deg 15' 46.258"N 149 deg 31' 29.006"W CNTY. COUNTY: North Slope Borough STAT. STATE: Alaska SRVC. SERVICE COMPANY: Baker Hughes INTEQ TOOL. TOOL NAME & TYPE: 2.375" CTK DATE. LOG DATE: 30-Aug-05 API API NYUMBER: 500292300270 Parameter Information Block #MNEM.UNIT Value Description SECT. 35 Section TOWN.N 11N Township RANG. 10E Range PDAT. MSL Permanent Datum EPD .F 0 Elevation Of Perm. Datum LMF RKB Log Measured from FAPD.F 106 Feet Above Perm. Datum DMF KB Drilling Measured From EKB .F 106 Elevation of Kelly Bushing EDF .F N/A Elevation of Derrick Floor EGL .F 0 Elevation of Ground Level CASE.F N/A Casing Depth OS1 DIRECTIONAL Other Services Line 1 Remarks aps- Icy) ~ l~f~S C (1) All depths are Measured Depths (MD) unless otherwise noted. (2) All depths are Bit Depths unless otherwise noted. (3) All Gamma Ray data (GRAX) presented is realtime data. (4) Baker Hughes INTEQ utilized CoilTrak downhole tools and the advantage surface system to log this well. (5) Tools ran in the string included Casing Collar Locator, an Electrical Disconnect and Circulating Sub, a Drilling Performance Sub (Inner and Outer Downhole Pressure and Downhole Weight on Bit), a Directional and Gamma Sub, Ultra Slim Resistivity Sub and a Hydraulic Orienting Sub with a Near Bit Inclination Sensor. (6) Data presented here is final and has not been depth adjusted to a PDC (Primary Depth Control)log. The INTEQ MWD Gamma Ray is the PDC for this wellbore. (7) The sidetrack was drilled from 1J-03 through a milled window in 3 1/2" liner. Top of Window 11574.0 ft.MD (6344.2 ft.SSTVD) Bottom of Window 11579.0 ft.MD (6347.1 ft.SSTVD) (8) The interval from 13565 ft.to 13589 ft.MD (6309.9 ft.to 6308.7 ft.SSTVD) was not logged due to sensor bit offset. (9) Tied to 1J-03 at 11433 ft.MD (6262.5 ft.SSTVD) (10) The well 1J-03L2 was kicked off this wellbore 1J-03L2PB1 at 12220 ft.MD (6365.37 ft.SSTVD) MNEMONICS: GRAX -> Gamma Ray MWD-AAPI [MWD] (MWD-API units) ROPS -> Rate of Penetration, feet/hour TVD -> Subsea True Vertical Depth, feet Tape Subfile: 1 Minimum record length: Maximum record length: **** FILE HEADER **** MWD .001 1024 64 records... 14 bytes 132 bytes *** INFORMATION TABLE: CONS MNEM VALU WDFN 1J-03L2PB1 5.xtf LCC 150 CN ConocoPhillips Alaska Inc. WN 1J-03L2PB1 FN Kuparuk River Unit COUN North Slope STAT Alaska *** LIS COMMENT RECORD *** !!!!!!!!!!!!!!!!!!! Remark File Version 1.000 The data presented here is final and has not been depth shifted • *** INFORMATION TABLE: CIFO MNEM CHAN DIMT CNAM ODEP ---------------------------------------------------- GR GR GRAX 0.0 ROP ROP ROPA 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: 0.500000 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 GR MWD 68 1 AAPI 4 4 2 ROP MWD 68 1 FfxR 4 4 8 Total Data Records: 48 Tape File Start Depth = 11579.000000 Tape File End Depth = 13589.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = feet **** FILE TRAILER **** Tape Subfile: 2 57 records... Minimum record length: 54 bytes Maximum record length: 4124 bytes **** FILE HEADER **** MWD .002 1024 *** INFORMATION TABLE: CONS MNEM VALU -------------------------------- WDFN 1J-03L2PB1.xtf LCC 150 CN ConocoPhillips Alaska In • • WN 1J-03L2PB1 FN Kuparuk River Unit COUN North Slope STAT 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 GRAX GRAX 0.0 ROP ROP ROPA 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 GRAX MWD 68 1 AAPI 4 4 2 ROP MWD 68 1 F/HR 4 4 8 Total Data Records: 97 Tape File Start Depth = 11566.500000 Tape File End Depth = 13588.750000 Tape File Level Spacing = 0.250000 Tape File Depth Units = feet **** FILE TRAILER **** Tape Subfile: 3 106 records... Minimum record length: 54 bytes Maximum record length: 4124 bytes **** TAPE TRAILER **** MWD 05/08/30 958647 O1 • **** REEL TRAILER **** MWD 06/11/17 BHI O1 Tape Subfile: 4 2 records... • Minimum record length: 132 bytes Maximum record length: 132 bytes • • Tape Subfile 1 is type: LIS • • Tape Subfile 2 is type: LIS DEPTH GR ROP 11579.0000 76.5500 -999.2500 11579.5000 77.6000 -999.2500 11600.0000 107.8500 18.8200 11700.0000 102.0600 39.9000 11800.0000 80.7600 25.1500 11900.0000 87.8600 43.9900 12000.0000 98.7750 77.3100 12100.0000 88.6500 43.4800 12200.0000 83.1200 40.4500 12300.0000 99.4300 26.9600 12400.0000 138.3500 46.9900 12500.0000 114.9500 26.1600 12600.0000 65.2400 11.8700 12700.0000 118.3600 43.6700 12800.0000 127.8300 23.1900 12900.0000 139.4000 37.5900 13000.0000 140.1900 22.4500 13100.0000 130.2000 26.5800 13200.0000 123.8900 47.5200 13300.0000 114.9500 21.5800 13400.0000 97.5900 45.0200 13500.0000 96.0100 52.7700 13589.0000 -999.2500 -999.2500 Tape File Start Depth = 11579.000000 Tape File End Depth = 13589.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = feet Tape Subfile 3 is type: LIS DEPTH GRAX ROP 11566.5000 128.6200 -999.2500 11566.7500 127.7780 -999.2500 11600.0000 107.8500 18.8200 11700.0000 102.0600 39.9000 11800.0000 80.7600 25.1500 11900.0000 87.8600 43.9900 12000.0000 98.7750 77.3100 12100.0000 88.6500 43.4800 12200.0000 83.1200 40.4500 12300.0000 99.4300 26.9600 12400.0000 138.3500 46.9900 12500.0000 114.9500 26.1600 12600.0000 65.2400 11.8700 12700.0000 118.3600 43.6700 12800.0000 127.8300 23.1900 12900.0000 139.4000 37.5900 13000.0000 140.1900 22.4500 13100.0000 130.2000 26.5800 13200.0000 123.8900 47.5200 13300.0000 114.9500 21.5800 13400.0000 97.5900 45.0200 13500.0000 96.0100 52.7700 13588.7500 -999.2500 -999.2500 Tape File Start Depth = 11566.500000 Tape File End Depth = 13588.750000 Tape File Level Spacing = 0.250000 Tape File Depth Units = feet • • ~ Tape Subfile 4 is type: LIS • ~ ~ :~- ~ • . , ,_ ~~ 3 ~~ U. **** REEL HEADER **** MWD 06/11/21 BHI 01 LIS Customer Format Tape **** TAPE HEADER **** MWD 05/09/05 958647 O1 2.375" CTK *** LIS COMMENT RECORD *** !!!!!!!!!!!!!!!!!!! Remark File Version 1.000 !!!!!!!!!!!!!!!!!!! Extract File: ldwg.las Version Information VERS. 1.20: CWLS log ASCII Standard -VERSION 1.20 WRAP. NO: One line per frame Well Information Block #MNEM.UNIT Data Type Information STRT.FT 11579.0000: Starting Depth STOP.FT 13586.0000: Ending Depth STEP.FT 0.5000: Level Spacing NULL. -999.2500: Absent Value COMP. COMPANY: ConocoPhillips Alaska, Inc. WELL. WELL: 1J-03L2 FLD FIELD: Kuparuk River Unit. LOC LOCATION: 70 deg 15' 46.258"N 149 deg 31' 29.006"W CNTY. COUNTY: North Slope Borough STAT. STATE: Alaska SRVC. SERVICE COMPANY: Baker Hughes INTEQ TOOL. TOOL NAME & TYPE: 2.375" CTK DATE. LOG DATE: 05-Sep-05 API API NYUMBER: 500292300261 Parameter Information Block #MNEM.UNIT Value Description #--------- --------------- ---------- SECT. 35 Section TOWN.N 11N Township RANG. 10E Range PDAT. MSL Permanent Datum EPD .F 0 Elevation Of Perm. Datum LMF RKB Log Measured from FAPD.F 106 Feet Above Perm. Datum DMF KB Drilling Measured From EKB .F 106 Elevation of Kelly Bushing EDF .F N/A Elevation of Derrick Floor EGL .F 0 Elevation of Ground Level CASE.F N/A Casing Depth OS1 DIRECTIONAL Other Services Line 1 Remarks ~~-- ~a ~ 'f ~ va~3 • (1) All depths are Measured Depths (MD) unless otherwise noted. (2) All depths are Bit Depths unless otherwise noted. (3) All Gamma Ray data (GRAX) presented is realtime data. (4) Baker Hughes INTEQ utilized CoilTrak downhole tools and the advantage surface system to log this well. (5) Tools ran in the string included Casing Collar Locator, an Electrical Disconnect and Circulating Sub, a Drilling Performance Sub (Inner and Outer Downhole Pressure and Downhole Weight on Bit), a Directional and Gamma Sub, Ultra Slim Resistivity Sub and a Hydraulic Orienting Sub with a Near Bit Inclination Sensor. (6) Data presented here is final and has not been depth adjusted to a PDC (Primary Depth Control)log. The INTEQ MWD Gamma Ray is the PDC for this wellbore. (7) The sidetrack was drilled from 1J-03 through a milled window in 3 1/2" liner. Top of Window 11574.0 ft.MD (6344.2 ft.SSTVD) Bottom of Window 11579.0 ft.MD (6347.1 ft.SSTVD) (8) The interval from 13562 ft.to 13586 ft.MD (6303.5 ft.to 6299.1 ft.SSTVD) was not logged due to sensor bit offset. (9) Tied to 1J-03 at 11433 ft.MD (6262.5 ft.SSTVD) (10) This wellbore 1J-03L2 was kicked off the wellbore 1J-03L2PB1 at 12220 ft.MD (6365.37 ft.SSTVD) MNEMONICS: GRAX -> Gamma Ray MWD-AAPI [MWD] (MWD-API units) ROPS -> Rate of Penetration, feet/hour TVD -> Subsea True Vertical Depth, feet Tape Subfile: 1 Minimum record length: Maximum record length: **** FILE HEADER **** MWD .001 1024 64 records... 14 bytes 132 bytes *** INFORMATION TABLE: CONS MNEM VALU ---------------------------------- WDFN 1J-03L2 5.xtf LCC 150 CN ConocoPhillips Alaska Inc. WN 1J-03L2 FN Kuparuk River Unit COUN North Slope STAT Alaska *** LIS COMMENT RECORD *** !!!!!!!!!!!!!!!!!!! Remark File Version 1.000 The data presented here is final and has not been depth shifted • *** INFORMATION TABLE: CIFO MNEM CHAN DIMT CNAM ODEP GR GR GRAX 0.0 ROP ROP ROPA 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: 0.500000 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 GR MWD 68 1 AAPI 4 4 2 ROP MWD 68 1 F/HR 4 4 8 Total Data Records: 48 Tape File Start Depth = 11579.000000 Tape File End Depth = 13586.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = feet **** FILE TRAILER **** Tape Subfile: 2 57 records... Minimum record length: 54 bytes Maximum record length: 4124 bytes **** FILE HEADER **** MWD .002 1024 *** INFORMATION TABLE: CONS MNEM VALU -------------------------------- WDFN 1J-03L2.xtf LCC 150 CN ConocoPhillips Alaska In • • WN 1J-03L2 FN Kuparuk River Unit COUN North Slope STAT 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 GRAX GRAX 0.0 ROP ROP ROPA 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: FRAME SPACE = 0.250 * F ONE DEPTH PER. FRAME Tape depth ID: F 2 Curves: Name Tool Code Samples Units 1 GRAX MVTD 6 8 1 AAP I 2 ROP MWD 68 1 F/HR Total Data Records: 97 1 Size Length 4 4 4 4 8 Tape File Start Depth = 11566.500000 Tape File End Depth = 13585.750000 Tape File Level Spacing = 0.250000 Tape File Depth Units = feet **** FILE TRAILER **** Tape Subfile: 3 106 records... Minimum record length: 54 bytes Maximum record length: 4124 bytes **** TAPE TRAILER **** MWD 05/09/05 • 958647 O1 **** REEL TRAILER **** MWD 06/11/21 BHI 01 Tape Subfile: 4 2 records... LJ Minimum record length: 132 bytes Maximum record length: 132 bytes • Tape Subfile 1 is type: LIS • Tape Subfile 2 is type: LIS DEPTH GR ROP 11579.0000 76.5500 -999.2500 11579.5000 77.6000 -999.2500 11600.0000 107.8500 18.8200 11700.0000 102.0600 39.9000 11800.0000 80.7600 25.1500 11900.0000 87.8600 43.9900 12000.0000 98.7750 77.3100 12100.0000 88.6500 43.4800 12200.0000 83.1200 40.4500 12300.0000 115.4700 62.0800 12400.0000 110.7400 54.0100 12500.0000 100.4800 33.6800 12600.0000 104.4300 49.1100 12700.0000 123.8900 44.0700 12800.0000 120.7300 25.7300 12900.0000 98.1100 69.0700 13000.0000 127.0400 29.2500 13100.0000 120.4700 76.2400 13200.0000 141.2500 98.4500 13300.0000 127.8300 124.3500 13400.0000 113.3700 104.7000 13500.0000 94.4300 23.7400 13586.0000 -999.2500 -999.2500 Tape File Start Depth = 11579.000000 Tape File End Depth = 13586.000000 Tape File Level Spacing = 0.500000 • Tape File Depth Units = feet • Tape Subfile 3 is type: LIS DEPTH GRAX ROP 11566.5000 128.6200 -999.2500 11566.7500 127.7780 -999.2500 11600.0000 107.8500 18.8200 11700.0000 102.0600 39.9000 11800.0000 80.7600 25.1500 11900.0000 87.8600 43.9900 12000.0000 98.7750 77.3100 12100.0000 88.6500 43.4800 12200.0000 83.1200 40.4500 12300.0000 115.4700 62.0800 12400.0000 110.7400 54.0100 12500.0000 100.4800 33.6800 12600.0000 104.4300 49.1100 12700.0000 123.8900 44.0700 12800.0000 120.7300 25.7300 12900.0000 98.1100 69.0700 13000.0000 127.0400 29.2500 13100.0000 120.4700 76.2400 13200.0000 141.2500 98.4500 13300.0000 127.8300 124.3500 13400.0000 113.3700 104.7000 13500.0000 94.4300 23.7400 13585.7500 -999.2500 -999.2500 Tape File Start Depth = 11566.500000 Tape File End Depth = 13585.750000 Tape File Level Spacing = 0.250000 Tape File Depth Units = feet • Tape Subfile 4 is type: LI5 • **** REEL HEADER **** MWD 06/10/31 BHI 01 LIS Customer Format Tape **** TAPE HEADER **** MWD 05/08/30 958647 O1 2.375" CTK *** LIS COMMENT RECORD *** • !!!!!!!!!!!!!!!!!!! Remark File Version 1.000 !!!!!!!!!! !!!!!!!!! Extract File: ldwg.las Version Information VERS. 1.20: CWLS log ASCII Standard -VERSION 1.20 WRAP. NO: One line per frame Well Info rmation Block #MNEM.UNIT Data Type Information STRT.FT 11579.0000: Starting Depth 5TOP.FT 13589.0000: Ending Depth STEP.FT 0.5000: Level Spacing NULL. -999.2500: Absent Value COMP. COMPANY: ConocoPhillips Alaska, Inc. WELL. WELL: 1J-03L2PB1 FLD FIELD: Kuparuk River Unit LOC LOCATION: 70 deg 15' 46.258"N 149 deg 31' 29.006"W CNTY. COUNTY: North Slope Borough STAT. STATE: Alaska SRVC. SERVICE COMPANY: Baker Hughes INTEQ TOOL. TOOL NAME & TYPE: 2.375" CTK DATE. LOG DATE: 30-Aug-05 API API NYUMBER: 500292300270 Parameter Information Block #MNEM.UNIT Value Description ----------------- SECT. -------------- 35 Section TOWN.N 11N Township RANG. 10E Range PDAT. MSL Permanent Datum EPD .F 0 Elevation Of Perm. Datum LMF RKB Log Measured from FAPD.F 106 Feet Above Perm. Datum DMF KB Drilling Measured From EKB .F 106 Elevation of Kelly Bushing EDF .F N/A Elevation of Derrick Floor EGL .F 0 Elevation of Ground Level CASE.F N/A Casing Depth OS1 DIRECTIONAL Other Services Line 1 Remarks 205 = ~2 i ~t~iaa~r • • (1) All depths are Measured Depths (MD) unless otherwise noted. (2) All depths are Bit Depths unless otherwise noted. (3) All Gamma Ray data (GRAX) presented is realtime data. (4) Baker Hughes INTEQ utilized CoilTrak downhole tools and the advantage surface system to log this well. (5) Tools ran in the string included Casing Collar Locator, an Electrical Disconnect and Circulating Sub, a Drilling Performance Sub (Inner and Outer Downhole Pressure and Downhole Weight on Bit), a Directional and Gamma Sub, Ultra Slim Resistivity Sub and a Hydraulic Orienting Sub with a Near Bit Inclination Sensor. (6) Data presented here is final and has not been depth adjusted to a PDC (Primary Depth Control)log. The INTEQ MWD Gamma Ray is the PDC for this wellbore. (7) The sidetrack was drilled from 1J-03 through a milled window in 3 1/2" liner. Top of Window 11574.0 ft.MD (6344.2 ft.S5TVD) Bottom of Window 11579.0 ft.MD (6347.1 ft.SSTVD) (8) The interval from 13565 ft.to 13589 ft.MD (6309.9 ft.to 6308.7 ft.SSTVD) was not logged due to sensor bit offset. (9) Tied to 1J-03 at 11433 ft.MD (6262.5 ft.SSTVD) (10) The well 1J-03L2 was kicked off this wellbore 1J-03L2PB1 at 12220 ft.MD (6365.37 ft.$STVD) MNEMONICS: GRAX -> Gamma Ray MWD-AAPI [MWD] (MWD-API units) ROPS -> Rate of Penetration, feet/hour TVD -> Subsea True Vertical Depth, feet Tape Subfile: 1 64 records... Minimum record length: 14 bytes Maximum record length: 132 bytes **** FILE HEADER **** MWD .001 1024 *** INFORMATION TABLE: CONS MNEM VALU ---------------------------------- WDFN 1J-03L2PB1 5.xtf LCC 150 CN ConocoPhillips Alaska Inc. WN 1J-03L2PB1 FN Kuparuk River Unit COUN North Slope STAT Alaska *** LIS COMMENT RECORD *** !!!!!!!!!!!!!!!!!!! Remark File Version 1.000 The data presented here is final and has not been depth shifted • • *** INFORMATION TABLE: CIFO MNEM CHAN DIMT CNAM ODEP ---------------------------------------------------- GR GR GRAX 0.0 * FORMAT RECORD (TYPE# 64) Data record type is: 0 Datum Frame Size is: 8 bytes Logging direction is down (value= 255) Optical Log Depth Scale Units: Feet Frame spacing: 0.500000 Frame spacing units: [F ] Number of frames per record is: 127 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 1 Curves: Name Tool Code Samples Units Size Length 1 GR MWD 68 1 AAPI 4 4 4 Total Data Records: 32 Tape File Start Depth = 11579.000000 Tape File End Depth = 13589.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = feet **** FILE TRAILER **** Tape Subfile: 2 40 records... Minimum record length: 54 bytes Maximum record length: 4124 bytes **** FILE HEADER **** MWD .002 1024 *** INFORMATION TABLE: CONS MNEM VALU -------------------------------- WDFN 1J-03L2PB1.xtf LCC 150 CN ConocoPhillips Alaska In WN 1J-03L2PB1 FN Kuparuk River Unit COUN North Slope STAT 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 GRAX GRAX 0.0 * FORMAT RECORD (TYPE# 64) Data record type is: 0 Datum Frame Size is: 8 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: 127 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 1 Curves: Name Tool Code Samples Units Size Length 1 GRAX MWD 68 1 AAPI 4 4 4 Total Data Records: 64 Tape File Start Depth = Tape File End Depth = Tape File Level Spacing = Tape File Depth Units = **** FILE TRAILER **** Tape Subfile: 3 72 Minimum record length: 54 Maximum record length: 4124 **** TAPE TRAILER **** MWD 05/08/30 958647 O1 11566.500000 13588.750000 .0.250000 feet records... bytes bytes r 1 ~J • **** REEL TRAILER **** MWD 06/10/31 BHI 01 Tape Subfile: 4 2 records... • Minimum record length: 132 bytes Maximum record length: 132 bytes • • Tape Subfile 1 is type: LIS .7 Tape Subfile 2 is type: LIS DEPTH GR 11579.0000 76.5500 11579.5000 77.6000 11600.0000 107.8500 11700.0000 102.0600 11800.0000 80.7600 11900.0000 87.8600 12000.0000 98.7750 12100.0000 88.6500 12200.0000 83.1200 12300.0000 99.4300 12400.0000 138.3500 12500.0000 114.9500 12600.0000 65.2400 12700.0000 118.3600 12800.0000 127.8300 12900.0000 139.4000 13000.0000 140.1900 13100.0000 130.2000 13200.0000 123.8900 13300.0000 114.9500 13400.0000 97.5900 13500.0000 96.0100 13589.0000 -999.2500 Tape File Start Depth = 11579.000000 Tape File End Depth = 13589.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = feet • LJ Tape Subfile 3 is type: LIS DEPTH GRAX 11566.5000 128.6200 11566.7500 127.7780 11600.0000 107.8500 11700.0000 102.0600 11800.0000 80.7600 11900.0000 87.8600 12000.0000 98.7750 12100.0000 88.6500 12200.0000 83.1200 12300.0000 99.4300 12400.0000 138.3500 12500.0000 114.9500 12600.0000 65.2400 12700.0000 118.3600 12800.0000 127.8300 12900.0000 139.4000 13000.0000 140.1900 13100.0000 130.2000 13200.0000 123.8900 13300.0000 114.9500 13400.0000 97.5900 13500.0000 96.0100 13588.7500 -999.2500 Tape File Start Depth = 11566.500000 Tape File End Depth = 13588.750000 Tape File Level Spacing = 0.250000 Tape File Depth Units = feet • • C7 Tape Su3~file 4 is type: LIS • **** REEL HEADER **** MWD 06/10/30 BHI O1 LIS Customer Format Tape **** TAPE HEADER **** MWD 05/09/05 958647 O1 2.375" CTK *** LIS COMMENT RECORD *** !!!!!!!!!!!!!!!!!!! Remark File Version 1.000 !!!!!!!!!!!!!!!!!!! Extract File: ldwg.las Version Information VERS. 1.20: CWLS log ASCII Standard -VERSION 1.20 WRAP. NO: One line per frame Well Information Block #MNEM.UNIT Data Type Information STRT.FT 11579.0000: Starting Depth STOP.FT 13586.0000: Ending Depth STEP.FT 0.5000: Level Spacing NULL. -999.2500: Absent Value COMP. COMPANY: ConocoPhillips Alaska, Inc. WELL. WELL: 1J-03L2 FLD FIELD: Kuparuk River Unit LOC LOCATION: 70 deg 15' 46.258"N 149 deg 31' 29.006"W CNTY. COUNTY: North Slope Borough STAT. STATE: Alaska SRVC. SERVICE COMPANY: Baker Hughes INTEQ TOOL. TOOL NAME & TYPE: 2.375" CTK DATE. LOG DATE: 05-Sep-05 API API NYUMBER: 500292300261 Parameter Information Block #MNEM.UNIT Value Description ----------------- -------------- SECT. 35 Section TOWN.N 11N Township RANG. l0E Range PDAT. M5L Permanent Datum EPD .F 0 Elevation Of Perm. Datum LMF RKB Log Measured from FAPD.F 106 Feet Above Perm. Datum DMF KB Drilling Measured From EKB .F 106 Elevation of Kelly Bushing EDF .F N/A Elevation of Derrick Floor EGL .F 0 Elevation of Ground Level CASE.F N/A Casing Depth OS1 DIRECTIONAL Other Services Line 1 Remarks 2oS - ~~ - ~ I'`lao~- • (1) All depths are Measured Depths (MD) unless otherwise noted. (2) All depths are Bit Depths unless otherwise noted. (3) All Gamma Ray data (GRAX) presented is realtime data. (4) Baker Hughes INTEQ utilized CoilTrak downhole tools and the advantage surface system to log this well. (5) Tools ran in the string included Casing Collar Locator, an Electrical Disconnect and Circulating Sub, a Drilling Performance Sub (Inner and Outer Downhole Pressure and Downhole Weight on Bit), a Directional and Gamma Sub, Ultra Slim Resistivity Sub and a Hydraulic Orienting Sub with a Near Bit Inclination Sensor. (6) Data presented here is final and has not been depth adjusted to a PDC (Primary Depth Control)log. The INTEQ MWD Gamma Ray is the PDC for this wellbore. (7) The sidetrack was drilled from 1J-03 through a milled window in 3 1/2" liner. Top of Window 11574.0 ft.MD (6344.2 ft.SSTVD) Bottom of Window 11579.0 ft.MD (6347.1 ft.SSTVD) (8) The interval from 13562 ft.to 13586 ft.MD (6303.5 ft.to 6299.1 ft.SSTVD) was not logged due to sensor bit offset. (9) Tied to 1J-03 at 11433 ft.MD (6262.5 ft.SSTVD) (10) This wellbore 1J-03L2 was kicked off the wellbore 1J-03L2PB1 at 12220 ft.MD (6365.37 ft.SSTVD) MNEMONICS: GRAX -> Gamma Ray MWD-AAPI [MWD] (MWD-API units) ROPS -> Rate of Penetration, feet/hour TVD -> Subsea True Vertical Depth, feet Tape Subfile: 1 64 records... Minimum record length: 14 bytes Maximum record length: 132 bytes **** FILE HEADER **** MWD .001 1024 *** INFORMATION TABLE: CONS MNEM VALU WDFN 1J-03L2 5.xtf LCC 150 CN ConocoPhillips Alaska Inc. WN 1J-03L2 FN Kuparuk River Unit COUN North Slope STAT Alaska *** LIS COMMENT RECORD *** !!!!!!!!!!!!!!!!!!! Remark File Version 1.000 The data presented here is final and has not been depth shifted • *** INFORMATION TABLE: CIFO MNEM CHAN DIMT CNAM ODEP GR GR GRAX 0.0 * FORMAT RECORD (TYPE# 64) Data record type is: 0 Datum Frame Size is: 8 bytes Logging direction is down (value= 255) Optical Log Depth Scale Units: Feet Frame spacing: 0.500000 Frame spacing units: [F ] Number of frames per record is: 127 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 1 Curves: Name Tool Code Samples Units Size Length 1 GR MWD 68 1 AAPI 4 4 4 Total Data Records: 32 Tape File Start Depth = 11579.000000 Tape File End Depth = 13586.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = feet **** FILE TRAILER **** Tape Subfile: 2 40 records... Minimum record length: 54 bytes Maximum record length: 4124 bytes **** FILE HEADER **** MWD .002 1024 *** INFORMATION TABLE: CONS MNEM VALU -------------------------------- WDFN 1J-03L2.xtf LCC 150 CN ConocoPhillips Alaska In WN 1J-03L2 FN Kuparuk River Unit • _ • COUN North Slope STAT 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 GRAX GRAX 0.0 * FORMAT RECORD (TYPE# 64) Data record type is: 0 Datum Frame Size is: 8 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: 127 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 1 Curves: Name Tool Code Samples Units Size Length 1 GRAX MWD 68 1 AAPI 4 4 4 Total Data Records: 64 Tape File Start Depth = Tape File End Depth = Tape File Level Spacing = Tape File Depth Units = **** FILE TRAILER **** Tape Subfile: 3 72 Minimum record length: 54 Maximum record length: 4124 **** TAPE TRAILER **** MWD 05/09/05 958647 O1 11566.500000 13585.750000 0.250000 feet records... bytes bytes • • **** REEL TRAILER **** MWU 06/10/30 BHI O1 Tape Subfile: 4 2 records... • Minimum record length: 132 bytes Maximum record length: 132 bytes • • Tape Subfile 1 is type: LIS • Tape Subfile 2 is type: LIS DEPTH GR 11579.0000 76.5500 11579.5000 77.6000 11600.0000 107.8500 11700.0000 102.0600 11800.0000 80.7600 11900.0000 87.8600 12000.0000 98.7750 12100.0000 88.6500 12200.0000 83.1200 12300.0000 115.4700 12400.0000 110.7400 12500.0000 100.9800 12600.0000 104.4300 12700.0000 123.8900 12800.0000 120.7300 12900.0000 98.1100 13000.0000 127.0400 13100.0000 120.4700 13200.0000 141.2500 13300.0000 127.8300 13400.0000 113.3700 13500.0000 94.4300 13586.0000 -999.2500 Tape File Start Depth = 11579.000000 Tape File End Depth = 13586.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = feet • • Tape Subfile 3 is type: LIS DEPTH GRAX 11566.5000 128.6200 11566.7500 127.7780 11600.0000 107.8500 11700.0000 102.0600 11800.0000 80.7600 11900.0000 87.8600 12000.0000 98.7750 12100.0000 88.6500 12200.0000 83.1200 12300.0000 115.4700 12400.0000 110.7400 12500.0000 100.4800 12600.0000 104.4300 12700.0000 123.8900 12800.0000 120.7300 12900.0000 98.1100 13000.0000 127.0400 13100.0000 120.4700 13200.0000 141.2500 13300.0000 127.8300 13400.0000 113.3700 13500.0000 94.4300 13585.7500 -999.2500 Tape File Start Depth = 11566.500000 Tape File End Depth = 13585.750000 Tape File Level Spacing = 0.250000 Tape File Depth Units = feet • • Tape Subfile 4 is type: LIS