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Home My WebLink About200-119 Imag~roject Well History File Coverage 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. _~_~_~ ] L(~_ Well History File Identifier RESCAN DIGITAL DATA OVERSIZED ~Scannable) [] Color items: [] Diskettes, No. [] Maps: [] Grayscale items: [] Poor Quality Originals: [] Other: NOTES: [] Other, No/Type [] BY: BEVERLY ROBIN VINCENT SHER~~INDY Project Proofing BY: BEVERLY F~OBIN VINCENT SHERY~'~INDY Scanning Preparation ~_ x 30 = ~ ~) BEVERLY ROBIN VINCENT SHER~WINDY BY: Other items scannable by large scanner OVERSIZED (Non-Scannable) [] Logs of various kinds . q Other DATE: / DATE: '~~/S/ [4/1 -I-..~ = TOTAL PAGES ~___ Production Scanning Stage 1 PAGE COUNT FROM SCANNED FILE: Stage 2 (SCANNING IS COMPLETE AT THIS POINT UNLESS SPECIAL ATTENTION IS REQUIRED ON AN INDIVIDUAL PAGE BASIS DUE TO QUALITY, GRAYSCALE OR COLOR IMAGES) PAGE COUNT MATCHES NUMBER IN SCANNING PREPARATION: YES X NO IF NO IN STAGE 1, PAGE(S) DISCREP E FOUND: BEVERLY ROBIN VINCENT SHERYL MARIA~ DATE: % RESCANNEDBY; BEVERLY ROBIN VINCENT SHERYL MARIA WINDY DATE: Isl General Notes or Comments about this file: Quality Checked la~ PROACTIVE DIACNOSi1C SERVICES INC. ~G~L ~~4~ 7"I~,4N~~1/T"TT 4L To: AOGCC Christine Mahnken 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 (907j 659-5102 RE : Cased Hole/Open Hole/Mechanical Logs and/or Tubing Inspection(Cafiper/ M1Tj The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the following ProActive Diagnostic Services, Inc. Attn: Robert A. Richey 130 West International Airport Road Suite C Anchorage, AK 99518 Fax: (907 245.8952 1 j Caliper Report 12-Octr09 1 D-40A 1 Report / EDE 50-029-2296800 2j ~®D~L ~ ~ ZOOS uT ~ ~bU - I t ~ ~ ~~~9 ~_, Signed : ! Date : ,, :,.. . Print Name: PROACTNE DIAGNOSTIC SERVICES, INC., 130 W. INTERNATIONAL AIRPORT RD SUITE C, ANCHORAGE, AK 99518 PHONE: (907)245-8951 Fax: (907)245-88952 E-MAIL ._-_._._ __._~ ~ ?__ .__~.~:~ wET35ITE : ; ___:~.~ C:`.Decumen~ and Settings)Owner\Desktap\Transmit_Conoco.docx i • Memory Mu~tNFinger Caliper ~ L.og Re~ults Summary ~~~ Company: ConocoPhillipsAlaska, Inc. Well: 1b-4QA , Log Date: Octaber 12, 2009 Field: Kupacuk ' Log No. : 90598 State: Alaska ' Run No.: 1 API No.: 50-029-22969-OQ Pipe1 Desc.: 3.5" 9.31b. L-80 $RD EUE Top Log intvl1.: Surface ' Pipe1 Use: 'fubing Bot. Log Intvl1_: 10,438 Ft. ~MD) lnspection Type : Corrosive & Mechanicat Dama~e /nspection COMMENTS : This ca(Iper data is tfed into the X-Nipp/e @ ~0,369.4' (Driller`s Depthj. This log was run to assess the condition of the tubing with respect to corrosive and mechanical damage. The caliper reeordings indicate the 3.5" tubing Iogged is in good #o poor condition, with a possible hole recorded in joint 283 (8,922'). Wall penetrations ranging from 40% to 72°/a wall thickness are recorded in 81 of the 340 joints logged. Recorded damage appears as scattered pitting from ~740' to ~8,350' and a line of pits from -8,350' to 10,438' (EOL). No significant areas of cross-sectiona( wall loss or I.D. restrictions are recorded fhroughout the tubing iogged. MAXIMUM RECORDED WALL PENETRATIONS: Possible Hole ( 88%) Jt. 243 ~ 8,922 Ft. (MD) Line of pits ( 72%) Jt. 301 ~ 9,470 Ft. (MD) Isola#ed pitting { 68%) Jt. 261 ~ 8,240 Ft. (MD) Isolated pitting ( 66%) Jt. 241 (c~ 7,603 Ft. (MD) Line of pits ( 65°~) Jt. 282 @ 8,902 Ft, tMD) MAXIMUM REGORDED CROSS-SECTIONAL METAL LQSS: No significant areas of cross-sectional wall loss (> 7%) are recorded throughout the tubing togged. MAXIMUM RECORDED ID RESTRICTIONS: No sign~cant I.D. restrictions are recorded throughout the tubing logged. ~~'~~~~~1;~s ~ ,r ~ ~ ~.0(~~ Field Engineer. G. Etherton Analyst: C. Waldrop Witness: C. Fitzpatrick ProAckfve Diagnostic Services, Inc. / P,~J. Bax 1369, Stafford, TX 77497 Phone: (2&i} or (888) 565-9085 Fax: (281} 505-1369 E-mail; PDS~c~memorylog.com Pr~udhoe Bay Field Office Phone: (907) 659-2307 Fax: (907) 659-2314 v~c aoo - ~ ~ ~ ~ ~ ~~~ • • Correlation of Recorded Damage to Borehole Profile ~ Pipe 1 3.5 in (10.4' - 10408.5') Well: 1 D-4()A Field: Kuparuk Company: ConocoPhillips Alaska, Inc. Country: USA Survey Date: October 12, 2009 ^ Approx. Tool Devia6on ^ Approx. Borehole Profile 1 14 5O < -; 1573 GLM 1 10U ~ ,a 3185 150 ,. 4749 0 ` ~ w ~ E ~ ~ ~ . Z c 20t1 . s 6313 Q ~o __ v ~ 2 5c ~ - 7874 3~O f 9435 GLM 2 3 29.2 10409 U 50 100 Damage Profile (% wall) / Tool Deviation (degrees) Bottom of Survey = 329.2 • ~ PDS Report Overview ~ s._ Body Region Analysis Well: 1 Q40A Survey Date: October 12, 2009 field: Kuparuk Tool Type: UW MFC 24 No. 212330 Company: ConocoPhillips Alaska, Inc. Tool Size: 1.69 Country: USA No. of Rngers: 24 Anal st: C. Waldro I Tubing: Nom.OD Weight Grade & Thread Nom.iD Nom. Upset Upper len. Lower len. 3.5 ins 93 ppf L-80 8RD EUE 2 992 ins 3 5 ins 6 0 ins 6 0 ins Penetration and Metal ~oss (°~ wall) ~ penetration body ~gp metal loss body 400 300 200 100 ~ 0 to 1 to 10 to 20 to 40 to over 1% 10% 2Q% 40% 85"/~ 85% Number of ~oints anal sed total = 340 pene. 0 59 68 131 81 1 loss 9 331 0 0 0 0 Damage Configuration ( body ) 3~0 25(1 200 150 100 i0 U isulatcsl gr.~neml line nng hole/poss pitting corrosion mrrosion corrosion ible hole Number of ~oints dama ed total = 267 266 0 0 0 1 Damage Profile (% wall) ~ penetration body :_;~-, metal loss body 0 SO 100 n GLM 1 GLM 2 Bottom of Survey = 329.2 Analysis Overview page 2 • PDS REPORT JOINT TABI. Nipe: 3.5 in 9.3 ppf L-80 8KD EUE 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 D-40A Kuparuk ConocoPhillips Alaska, Inc USA October 12, 2009 Joint No. Jt. Depth (R.) I'~~n. IJF,.c~t Itnt.) Pen. Body (Ins.) Pen. °„ ~lct,il In~s ~ Min. I.D. (Ins.) Comments Damage Profile (%wall) 0 50 100 .1 10 i~ 0.01 _' I 2.97 PUP 1 14 ~~ 0.01 6 2.94 1.1 45 ~~ 0.02 7 I 2. 2 PUP 1.2 55 ~~ 0.02 9 I 292 PUP 1.3 66 ~~ 0.0 9 -~ 2.94 PUP 2 74 ~) 0.02 9 ' 2.94 3 105 ~~ 0.02 9 I 2.94 4 136 ~~ 0,03 1 U 2.95 5 167 ~~ 0.02 ~) 2.94 6 199 ~~ 0.01 ~~ 2.94 7 230 u 0.02 '~ 2.93 8 261 ~~ OA2 9 _' 2.94 9 292 ~~ 0. 2 ' ' 2.95 10 324 n 0.02 ' 2. 4 1 1 355 !~ 0.02 i ' 2.93 1 386 ~~ 0.02 ~> ; 2.94 13 418 t~ 0.03 i I 2.93 14 449 ~ ~ 0.02 ~i -~ 2.94 15 480 ~~ 0.02 7 ' 2.95 16 S11 !? 0.03 11 2.94 17 543 ~~ 0.02 E~ ~' 2.95 18 574 ~ i Q03 1 1 _' 2.94 19 605 t) 0.03 1 l~ 2.94 20 636 l~ 0.01 6 _' 2.95 1 668 ~~ 0 02 ~i 2 95 22 699 U 0.01 (~ ' 2.94 23 730 U 0.01 i _' 2.94 24 761 (1 0.03 13 2.95 Shallow ittin . 25 792 ~~ 0.02 7 2 93 26 823 i~ 0.03 11 2.92 27 855 u 0.03 11 2.93 28 886 n 0.02 ~? 2.93 29 916 t? 0.02 tj _' 2.93 30 948 ! ~ 0.02 ~? ' 2.93 31 979 ~ ~ 0.02 ~? > 2.95 32 101 1 i~ 0.02 ~~ _' 2.94 33 1042 ~~ 0.05 19 ~' 2.94 Shallow it6n . 34 1073 t` 0.03 11 ' 2.94 35 1104 i~ 0.02 9 ? .95 36 1136 ~ ~ 0.02 ~) ~' 2.94 37 1167 U 0.02 ~) ' .95 38 1198 U 0.02 9 s 2.94 39 12 9 ~~ 0.02 ~~ _' 2.94 40 1260 l1 0.03 13 I 2.94 Shallow ittin . 41 1292 t) 0.05 Zt) 2.94 Shallow itti 42 1323 ~~ 0.03 I' 2.94 43 1354 l~ 0.05 1~i ~ 2.95 Shallow ~ittin . 44 1385 ~~ 0.05 lE3 ~ 2.93 Shallow ittin . 45 1417 u 0.03 I_' ~ 2.93 46 1448 u 0.05 ~'U 3 2.94 Shallow ittin . Penetration Body ! Metal Loss Body Page 1 . ~ PDS REPORT JOINT TABULATION SHEEf Pipe: 3.5 in 9.3 ppf L-80 8RD EUE Well: t D-40A Body Wall: 0.254 in Field: Kuparuk Upset Wall: 0.254 in Company: ConocoPhillips Alaska, Inc Nominal I.D.: 2.992 in Country: USA Survey Date: October 12, 2009 Joint No. Jt. Depth (Ft.) I'e~n. ~?~nf~i (I~:~.) Pen. Body (Ins.) I'<_~n. `i<, ~i~lc~tal Ioss °/ Min. I.D. (Ins.) Comments Damage Profile (%wall) 0 50 100 47 1479 ~ ~ 0.02 ' ~ 2.93 48 1511 i? 0.05 2ll ? 2.95 Isol ted ittin . 49 1542 !~ 0.03 1 t1 ~1 2.93 50 1573 ~~ 0.06 '~? t 2.93 Isolated ittin . 51 1604 ~l 0.02 9 _' 2.95 52 1636 U 0.07 Zt3 _' 2.95 Isolated ittin . 53 1667 t) 0. 3 1I > 2.94 54 1697 ~~ 0.01 ~ ; 2.94 55 1728 t~ 0.02 ~~ _' 2.94 56 1760 ~t 0.03 I t ' 2.94 Shallow ittin . 57 1790 ~~ 0.06 ~4 ~' 2.9 Isolated ittin . 58 1822 ~~ 0.05 Z~~ ! 2.91 Shallow ittin . Lt. De osits. 59 1853 ~1 0.06 _'.; .9 Isolated ittin . Lt De osits. 60 1884 ~ ~ 0.02 ~) _' 2.94 61 1915 ~ i 0.03 1_> 2.91 I.t De o its. 62 1947 ~) 0.02 ~) 2.94 63 1978 U 0.03 t l) ~t 2.94 64 2009 (~ 0.03 1ll ~> 2.95 65 2040 t? 0.02 ~~ _' .93 65.1 2072 t~ 0.05 211 ' 2.95 PUP Shallow itti . 65.2 2081 ~~ 0 i) u 2.81 3.5" TRM-4E Safe Valve 653 2085 t~ 0.01 ~,' I 2.91 NUN 6 2094 t~ 0. 6 'S ..' 2.94 Isolated ittin Lt. De its. 67 2125 U 0.05 19 ~ 2.94 Shallow ittin . 68 1 6 U OA 9 I . 1 Lt. osits. 69 2188 i? 0.01 6 i 2.95 70 2219 i) 0.06 ~Z ~_' 2.94 Isolated ittin . 71 2250 U 0.06 ?-1 ~' 2.93 Isolated ittin . 72 2282 !~ 0.04 li~ 2.93 Shallow ittin . 73 2313 ~~ 0.06 ~'-1 2.93 lsolated ittin . 74 2344 (1 0.04 1 i ? 2.94 S~Ilow ittin . 75 2375 U 0.05 19 ~' 2.91 Shallow ittin . Lt. De sits. 76 406 ~f 0.05 1U _' .93 Isolated ittin . 77 2437 ta 0.07 2(~ 2.94 Isolated ittin . 78 24b9 O 0.03 12 ~' 2.94 Lt. De osits. 79 2500 U 0.02 9 _' 2.95 80 2531 U 0.06 ~5 ' 2.94 Isolated ittin . 81 2562 !? 0.03 l~ .90 Shallow ittin . Lt. De osits. 82 2594 u 0.05 I~) 2.95 Shallow ittin . 83 2625 U 0.04 1-3 2.94 Shallow ~ittin . 84 2656 u 0.05 1') ' 2.91 Shallow ittin . Lt. e sits. 85 2687 l) 0.03 12 2.94 Shallow ittin . Lt. De osits. 86 2719 ~) 0.05 19 s 2.94 Shallow ittin . Lt. De osits. 86.1 2750 ~1 0.02 9 I 2.91 PUN Lt Ue sits. 86.2 2760 U 0 0 U N A GLM 1 Latch ~ 9:00 863 2767 t? 0.03 1I 2 2.92 PUP 87 2777 U 0.02 9 _' .95 88 2809 i~ 0.01 5 2.94 89 2840 0.02 ~1 2.90 De osits. 90 2871 0.02 ~~ 2.95 PeneUation Body Metal Loss Body Page 2 ~ PDS REPORT JOINT TABI Pipe: 3.5 in 9.3 ppf L-80 8KD EUC Well: Body Wall: 0.254 in Field: Upset Wall: 0.254 in Company: Nominal I.D.: 2.992 in Country: Survey Date: • JLATION SHEET 1 D-40A Kuparuk ConocoPhillips Alaska, Inc. USA October 12, 2009 Joint No. Jt. Depth (Ft.) Pc~n. ~1F»~•i IIn..1 Pen. Body (InsJ Pen. °i~ tit~~i,~l I~~~ti ~ Min. I.D. (Ins.) Comments Damage Profile (%wall) 0 50 100 91 2903 i~ 0.03 12 ! 2.94 Shallow ittin . Lt. De sits. 92 2934 ~~ 0.07 26 4 2.9 I lated ittin . Lt. De sits. 3 2966 ~~ 0.05 2U 2.87 Isolated ittin . Lt. De sits. 94 2997 ~~ 0.05 I~? ' 2.91 Shallow ittin . t.De sits. 95 3 8 ~~ 0 05 1 ts 2.88 Shallow ittin . c De sits. 96 060 t~ 0.0 _'_' 2.93 Is lated itti . L~ De sits. 97 3091 ~~ 0.06 2.93 Isolated ittin . 98 3123 u 0. 6 _' S -1 .88 Isolated ittin . Lt. De sits. 99 3154 ~~ 0.0 _'t9 i .93 Isolated i tin . L. its. 100 3185 ~~ 0.06 ~> s 2.90 Isolated ittin . Lt. De sits. 101 3217 U 0.04 1~ _' 2.91 Shallow ittin . 102 3248 t) OA I ti •~ 2.93 Shallow ittin . Lt. e sits. 103 3 80 O 0.05 ~ 1 t 2.88 Isolated ittin . Lt Ue sits. 104 3 11 U 0.08 S I i 2.90 Isolated ittin . Lt. e sits. 1 5 334 U 0.07 1(, ~' 2.87 Isolatecl ~ittin . Lt. D its. 106 3374 ct 0.05 !~) Z 2.91 Isolated itti . Lt De sits. 107 3405 U 0.04 l E> _' 2.90 Shallow itbn . Lt. De sits. 108 3435 ~~ 0.07 Z(, ; .90 I late ittin . Lt. De osits. 109 3467 ~> 0.05 ~1U ~~ 2.90 Shal ow itbn . Lt. De sits. 110 3498 c~ 0. 6 Z5 1 2.92 Isolated ittin . Lt. De sits. 111 35 9 ~~ 0.05 21 ~~ .91 Isolated ittin . Lt. De sits. 11 3561 ~~.1~; 0.05 2(1 _' 2.85 Isolated ~ittin . Lt. De osits. 113 3592 U 0.05 ~U 2.92 hallow ittin . L. De sits. 114 3623 ~~ 0.05 _' 1 _' 2.90 Isolated it6 . Lt. De sits. 15 3 ~~ _' ~ -4 7 I I ted it ~ 116 3686 U 0.07 ~'t3 ' 2.86 Isolated ittin . Lt De sits. 117 3717 U 0.07 2' ~' 2.86 Isol- ted ittin . Lt. De sits. 118 3749 ll 0.08 t 1 ~' 2.81 Isolated itti . Lt. De sits. 119 3780 l~ 0.05 2(~ ! 2.88 Isolated ittin . Lk De sits. 120 3811 l~ 0.07 _'(> Z 2.91 Isolated ittin . Lt. pe sits. 1 384 U 0.07 Z') ; .89 Isolated ittin L. De si . 122 3874 l) 0.07 l6 ~3 2.92 Isolated ittin . Lt. De sits. 123 3905 U 0.07 Z9 ' .94 Isolated ittin . LC De sits. 124 3936 ~~ 0.04 I i _' 2.94 Shallow ittin . Lt. De sits. 125 3968 ~~ 0.0 1~~ 2.89 Shallow ittin . Lt. De si . 126 3999 ~? 0.08 ~ I ~ 2.89 Isolated ittin . Lt De sits. 127 4030 U 0.08 ;l) _' ".92 Isolated ittin . Lt. De sits. 128 4061 n 0.07 Z6 _' 2.86 Isolated ittin . Lt. De sits. 1 9 4092 t~ 0.04 14 _' 2.95 Shallow ittin . 130 4124 t~ 0.05 1f3 _' 2.93 Shallow iuin . Lt. De osits. 131 4155 (~ 0.06 24 Z 2.94 Isolated ittin . 132 4186 ~~ 0.01 5 ~? 2.94 133 42 7 (> 0.08 i 1 2.91 Iso) ted it4 . Lt. D its. 134 4249 U 0.01 (~ ' 2.94 35 280 U 0.07 _" ~ 2.90 so ated itUn . t e its. 136 4312 U 0.07 _'tc 2.91 Isolated ittin . Lt De sits. 137 4343 U 0.07 _'(~ ' 2.94 Isolated ittin . 138 4374 U 0.05 I ts 2.93 Shallow ittin . 139 4405 U 0.03 I u 2.94 140 4436 ~) 0.06 Z4 s 2.92 Isolated ittin . Penetration Body Metal Loss Body Page 3 ~ PDS REPORT )OINT TABI. Pipe: 3.5 in 9.3 ppf L-80 SRD EUE Well: Body Wall: 0.254 in Field: Upset Wall: 0.254 in Company: Nominal I.D.: 2.992 in Country: Survey Date: • ~LATION SHEET t D-40A Kuparuk ConocoPhillips Alaska, Inc USA October 12, 2009 Joint No. Jt. Depth (Ft.) I'c~n. ~~~~•~~i !trn.l Pen. Body (Ins.) Pc~n. % ~1~•t,~l I u~s °~ Min. I.D. (Ins.) Comments Damage Profile (%wall) 0 50 100 141 4468 u 0.06 '~ 2.94 Isolated ittin . Lt. De sits. 142 4499 ~~ 0.05 lti .92 Shallow ittin . LtDe sits. 143 453 u 0.07 ~'' _' . 1 Isolated itti . Lt. De si . 144 4561 0.07 ?b _' .94 Isolated itti 145 4593 ~~ 0.07 Z(> ; 2.94 Isolated ittin . Lt. Ue sits. 146 4624 ~? 0.04 1 ~ 2 1 Shallow ~ittin . Lt. De sits. 147 4655 t~ 0.10 ~') l 2.95 Isolated ittin . 148 4687 i? 0.07 "i 2.87 Isolated ~ittin . Lt De its. 149 4718 U 0.10 ;9 ~ .95 Isolated ittin . 150 4749 t1 0.06 ~? ' 2.94 Isolated ittin . 15 4780 i~ 0.06 _' i 2.94 Isolated ittin . 152 4812 l1 0.07 _'t9 1 2.90 Isolated ittin . Lt. De s~ts. 153 4843 t) 0.05 I'i 95 Shallo ittin . 154 4874 u 0.06 ~'_' s 2.90 Isolated ittin . Lt. e sits. 155 4906 u 0.07 <£3 ~ 2.92 Isolated ittin . t. De sits. 156 4937 U 0.07 2' _' 2.88 Isolated ittin . Lt. De sits. 157 4968 ll 0. S ?U t .94 solated itti . 158 5000 U 0.06 ~'4 _' 2.94 Isolated ittin . 159 5031 t~ 0.05 2U ' 2.90 Isolated ittin . lt. De si . 160 5062 ~~ 0.07 Z(, Z 2.90 Isolate ittin . L. De sits. 161 5094 u 0.07 ~ti a 2.90 Isolat d ittin . Lt. De sits. 162 5125 ~~ 0. 7 Zti _' 2.93 Isolated ittin . 163 5156 i~ 0.08 3< ~' 2.92 Isolated ittin . Lt. De sits. 164 5188 ~~ 0.08 3~) ~' 2.95 Isolated ittin . Lt De sits. 165 5219 u 0.08 31 ~ 2.93 Isolated itti . LL De sits. 166 5250 u 0.11 -13 _' 2.94 Isolated ittin . Lt. De sits. 167 52 2 ~1 0.08 il ..' 2.93 Isolated ittin . Lt. De sils. 168 5313 ~~ 0.08 32 4 2.94 Isolated ittin . 169 5344 ~~ 0.07 ~it) _' 2.94 Isolated ittin . 170 5376 ~~ 0.07 Z~) 2.94 Isolated ittin . 171 5407 t~ .09 ;~ ; .93 I olated ittin . 172 5438 u 0.08 i~' ~' 2.87 Isolated ittin . Lt. De sits. 173 5470 U 0.04 1' ~' .95 Shallow ittin . 174 5501 U 0.06 ~~-~ _' 2.94 Isolated ittin . 175 532 u 0.08 31 _' 2.95 Isolated ittin . 176 5563 t~ 0.10 3tf t 2.94 Isolated ittin . 177 5595 U 0. 5 5f3 ~t 2.95 Isolated ittin . 178 5626 ll 0.10 41 2.95 Isolated ittin . 179 5657 !~ .06 ..'~' ' 2.88 Isolated ittin . De si . 180 5689 ~~ 0.13 5U 2.95 Isolated ittin . 181 5721 ~ ~ 0.07 'Ei ~ .94 Is (ated ittin . 182 5752 ~~ 0.06 1 ~ Z 2.93 Isolated itti . 183 5783 U 0.07 2~1 t 2.87 Isolated 'tti . Lt. e sits. 184 5814 l~ 0.02 ~) 2.91 185 5846 U 0_06 ? 3 ' 2.94 Isol ted ittin . 186 5877 ~~ 0.10 -31 2.94 Isolated ittin . 87 5908 c~ 0.10 4t1 2.94 Isolated ittin . 188 5939 l~ 0.13 52 ~ 2.92 Isolated ittin . Lt. De sits. 189 5971 (~ 0.12 -1(> + 2.91 Isolated >ittin . Lt. De si . 190 6002 c? 0.07 _"~ 2.93 I~lated ittin=. Penetration Body ~ Metal Loss Body Page 4 • PDS REPORT JOINT TABI, Pipe: 3.5 in 9.3 ppf L-80 SRD EUE 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 D-40A Kuparuk ConocoPhillips Alaska, Inc USA October 12, 2009 )oint No. )t. Depth (Ft.) P~~ri. l I~~.E~i (Ins.) Pen. Body (Ins.) Nen. °i~ ~tf~i,~l I~~~~ ~- Min. I.D. (Ins.) Comments Damage Profile (°/a wall) 0 50 100 191 033 U 0.07 26 ~ 2.93 Isolat d ittin . 192 6064 tl .0 35 2.94 Isolated ittin . 193 60 6 U 0.07 28 ~ 2.93 Is la ed ittin . 194 6127 !? 0.06 2:~ ~ 2.91 Isolated ittin . Lt De sits. 195 6158 i) 0.12 4!, ~, 2.93 Isolated ittin _ 196 6189 ~~ 0.03 1; 2.94 Shal o ittin . 197 6221 ~? 0.04 17 S 2.94 Shallow ittin . 98 6 51 t~ 0.05 ~~t~ 2.93 Shallow ittin . 199 6 8 ~~ .0 1 1 _' 2.94 200 6313 U 0.0 'S ~ 2.94 Isolate itti . O1 6344 t~ 0.03 1~ _' 2.94 Shallow ittin . 202 637 U 0.09 i~ _' 2.94 Isolated i bn . 203 6 7 U 0.07 ~<<) ' 2.93 Isolated ictin . 04 643 ~> 0.07 2(, ~ .94 Isolated ittin . 205 6469 i~ 0.0 1~ ' 2 4 06 6500 ~~ 0.06 ~' j 2.94 olated ittin . 207 6532 i) 0.11 ~ I t 2.94 Isolated 'ttin . 208 65F,3 U 0.08 32 t 2.93 Is lated it 'n . 209 59 c~ 0.11 45 i .94 Isolated it6n . Lt. e si . 10 6626 U 0.06 23 Z 2.95 Isol~ ted ittin . 211 6 5 U 0.12 4E3 4 2.94 Isolated itti . 212 6688 U 0.07 2(~ 2.94 Isolated ittin . 21 67 8 0 0.05 ?~) _' 2.94 Shallow ittin . 274 6750 0 0.05 _'~? _' 2.95 Shallow ittin . 215 6782 U .11 -l~ 94 Is la ed ittin . 216 6813 l) 0.08 31 s 2.94 Isolated ittin . 17 6 (? 0.15 5~) ~ .93 I lated ittin . 18 6875 ~) 0.06 Z ~i 2.94 Isolated ittin . 219 06 t~ 0.07 16 ~ 2.95 Iso ted it6n . 220 6938 ~~ 0.12 4t3 ~ 2.93 Isolated ittin . 21 6967 ~~ 0.1~ 4U Z 2.94 Isolated ittin . 222 6998 ~) 0.11 45 ~ 2.93 Isolated ittin . 223 7029 O 0.10 ~~3 ' 2.94 I olated ittin . 24 7061 (~ 0.10 ~1 -4 2.94 Isolated ittin . 225 7092 ~1 0.06 Z2 2.94 Isolated ittin . 226 7123 U 0.08 ~3~, ~ 2.94 Isolated ittin . 227 7154 (1 0.1 3~~ 3 .91 Isola d ittin . 228 7186 U 0.05 1 f1 ~' 2.94 Shallow itti . 229 7217 u 0.08 ;1 1 2 93 la e ittin 230 7248 U 0.02 ~~ ~' 2.94 2 1 7279 ~1 0.09 ~i -] 2.93 Isolated i~n . 232 7310 t1 0.11 4, > 2.92 Isolated itti . Corrosion. 233 7342 t) 0.10 3t~ ' 2.93 Isol ted it'n . 234 7373 ~~ 0.15 5t9 ~ 2.93 Isolated ittin . 23 7404 ~~ 0.10 t~~ .9 Isolated i ti 236 7436 ~~ 0.06 2 i ' 2.93 Isolated it6n . 237 7467 i~ 0.14 5 M1 t .94 Isolated ittin . 238 7498 U 0.14 54 -3 2.94 Isolated ittin . 39 7 30 l~ 0.11 44 ~ 2.92 Isolated i ti . 240 7561 ~~ 0.16 63 2.94 Isolated ittin . Penetration Body Metal Loss Body Page 5 ~ PDS REPORT JOINT TABI. Pipe: 3.5 in 9.3 ppf L-80 SRD EUE Well: (3ody Wall: 0.254 in Field: Upset Wall: 0.254 in Company: Nominai I.D.: 2.992 in Country: Survey Date: • iLATION SHEET 1 D-40A Kuparuk ConocoPhillips Alaska, Inc. USA October 12, 2009 Joint No. JL Depth (Ft.) I'c~n. ~~~,~~~i Iln, ) Pen. Body (Ins.) Pen. % M~~I~il Loss `%~ Min. I.D. (Ins.) Comments Damage Profile (%wall) 0 SO 100 241 7593 ~~ 0.17 (,(> i .93 Isolated ittin . 242 7623 u 0.10 4(1 i, 2.94 Isolated ittin . 243 7655 i~ 0.04 15 ' 2.94 Shallow ittin . 244 7686 ~~ 0.10 i8 3 2.94 Isolated it6n . 45 7717 U .14 5i ~~ 2.90 Isolated ittin 246 7748 U 0.10 3~) ~ 2.94 Isolated ittin . 247 7780 ~ 1 0.11 45 t 2.93 Isolated ittin . 248 7811 u 0.03 l t 2.94 Shallow ittin . 249 7842 U 0.10 i~) 2.94 Isolated ittin . 250 7874 U 0.13 5U 5 2.93 isolated ittin . 251 7905 ~~ 0.11 4 i -1 2.93 Isolated ittin . 252 7937 i! 0.16 (i_' S 2.94 I olated itti . 253 7968 ~! 0.09 35 Z 2.93 Isolated ittin . de si . 254 7998 ~~ 0.09 34 _' 2.94 Isolated itbn . 255 8030 ~~ 0.11 43 ~ 2.93 ~solated ittin . 256 8061 U 0.12 46 -I 2.94 Isolated ittin . 257 8092 U 0.12 4~ ! 2.94 Isolated ittin . 258 8123 l~ 0.12 46 2.94 Isolated ittin . 259 8154 i~ 0.07 2~) 3 2.94 Isolate ittin . ~ 260 8186 ~~ 0.11 4~ ~ 2.94 Isolated it6n . 261 8217 ~? 0.17 b8 d 2.94 Isolated ittin . 262 8249 i 1 0.10 41 -! 2.94 Isolated iltin . 263 8280 U 0.09 35 -} 2.95 Isolated ittin . 264 8311 U 0.12 45 ~ 2.94 Isolated ittin . 265 8342 ~~ 0.12 45 t, .93 Line of its. 266 8372 ~~ ~.11 42 ~ 2.94 Line of its. 267 8403 U 0.12 4i -1 .94 Line of its. 268 8435 t~ 0.07 ~?7 2.94 Line of its. 269 8466 ~~ 0.16 63 -1 2.93 Line of its. 270 8497 ~~ 0.12 =1b -t 2.94 Line of its. 71 8528 i~ 0.09 ;5 -t 2.95 Line of its. 272 8560 ~~ 0.09 ~3 ~ s 2.93 Line of its. 273 8591 ~i 0.09 >7 -1 2.93 Line of its. 274 8623 U 0.11 ~4 ~ 2.93 Line of its. 275 8654 ~~ 0.12 -1i 2.94 Lineof its. 276 8685 ~~ 0.11 4a a 2.93 Line of its. 277 8717 t~ 0.1 ~it3 ~ 2.94 Lin of its. 278 8748 ~~ 0.15 i,~~ ! 2.95 Line of its. 279 8779 ~~ 0.12 -1tS ! 2.93 Line of its. 280 8810 u 0.13 -~`~ - 2.94 Line of its. 281 8842 t) 0.12 4~, ~1 2.95 Line of its. 282 8873 U 0.16 E>5 s 2.94 Line of its. 283 8904 l) 0.2 t9t3 •J 2.93 Po sible ole. 284 8935 t~ 0.11 43 ~ 2.93 Line of its. 285 8966 U 0.11 ~5 -1 2.95 Lin of its. 286 8998 t) 0.11 ~Z -1 2.94 Line of its. 287 9029 l1 0.12 ~~) -1 2.94 Line of its. 288 9060 t) 0.12 -~9 '~ 2.94 Line of its. 289 9092 (~ 0.12 47 i 2.93 Line of its. 290 9123 t) 0.10 4I a 2.95 line of its. Penetration Body Metal Loss Body Page 6 • PDS REPORT JOINT TABI. Pipe: 3.5 in 9.3 ppf L-80 8RD EUE Well: Body Wall: 0.254 in Field: Upset Wall: 0.254 in Company: (~lominal I.D.: 2.992 in Country: Survey Date: • ~LATION SHEET 1 D-40A Kuparuk ConocoPhiliips Alaska, Inc USA October 12, 2009 Joint No. )t. Depth (Ft.) I'c~n. l 1~ „c~i (Irn.) Pen. Body (Ins.) Pen. 3~, Ntc~t~il I c~s~ "~, Min. I.D. (Ins.) Comments Damage Profile (% wall) 0 50 100 291 9154 ~~ 0.12 4i 4 2.94 Line of its. 292 9185 ~) 0.14 54 -3 2.94 Line of its. 293 9216 ~~ 0.11 42 -1 2.93 Line of its. 294 9247 ~? 0.11 4 3 4 2.93 Line of its. 295 9279 l? 0.13 51 t .94 Line of i. 296 9310 l) 0.09 35 ~l 2.94 Line of its. 297 9341 ~~ 0.14 54 -1 2.94 Line of its. 298 9372 t> 0.10 ~3~) d 2.94 Line o( its. 299 9404 U 0.12 4t3 ~ 2.93 Line of i. 300 9435 u 0.09 i4 (, 2.91 Line of its. 301 9466 (~ 0.18 72 ~1 2.94 Line of its. 302 9498 U 0.12 48 -! 2.89 ine of i. 303 9529 U 0.10 4tt ~ 2.94 Line of its. 304 9560 ~~ 0.09 ~7 .93 ine of its. 305 9592 t) 0.12 4Fi -t 2.95 I.ine of its. 306 9623 l) 0.14 5~ ~ 2.94 Line of its. 307 9654 U 0.0 2£3 -t 2.94 Line of its. 308 9686 l~ 0.11 ~1 •~ 2.93 Line of its. 309 9717 U 0.10 >8 -1 2.94 Line of its. 310 9748 u 0.10 t<) ~1 2.94 ine of its. 311 9779 ~~ 0.12 4~? ~ 2.93 Line of its. 312 9810 U 0.10 ~~~> ~ 2.94 Line of its. 313 9842 ~~ 0.10 ~ll ~1 2.94 ine of its. 314 9873 ~~ 0.09 ~ 5 ~ 2.93 Line of its. 315 9904 ~ 1 0.11 dl t, 2.94 Lin of i. 316 9936 u 0.11 43 ~ 2.94 Line of its. 317 9967 t1 0.12 ~39 5 2.94 Line of its. 318 9998 ~) 0.11 43 -~ 2.94 Line of its. 319 10029 ~) 0.11 44 i 2.94 Line of its. 320 10061 ~~ 0.10 41 -1 2.94 Line of its. 321 10092 1 ~ 0.11 d I (, 2.93 L~ e f its. 322 10123 ~i 0.09 >4 4 2.94 Line of its. 323 10155 t~.Utf 0.09 i5 -l 2.95 Line of its. 324 10186 l1 0.13 52 7 2.94 Line of its. 325 10217 (1 0.09 37 4 2.94 Line of its. 326 10248 (1 0.13 50 i 2.9~ Line of its. 327 10280 t) 0.09 ~5 -1 2.93 Line of its. 327.1 10311 ~~.t~ t 0.11 -13 2.93 PUP Line of its. 327.2 10320 t~ 0 (~ ~? N A CLM 2 Latch ~ 2:30 327.3 10328 t~. li> 0.06 ~~ 2.90 PUP Line o( its. 328 10338 ~~ 0.07 ~'ti ~1 2.93 Line of its. 328.1 10369 ~~ 0 ~? t: 2.81 3.5" X-Ni le 329 10371 ~? 0.11 ~? ~ ; 2.87 Line of its. Lt. De osits. 329.1 10403 0.09 ~ 2.93 PUP Line of its. i 329.2 1040~) _ _ (1 3.00 Seal Assernbl ~Nenetration Body Metal Loss Body Page 7 ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ PDS Report Cross Sections -~u - -~ ,. ~Nell: 1 D-40A Survey Date: October 12, 2009 Field: Kuparuk Tool Type: UW MFC 24 No. 212330 Company: ConocoPhillips Alaska, Inc. Tool 5ize: 1.69 Country: USA No. of Fingers: 24 Tubin : 3.5 ins 93 f L-80 8RD EUE Anal st: C. Waldro Cross Section for Joint 283 at depth 8922.08 ft Tool speed = 43 Nominal ID = 2.992 Nominal OD = 3.500 Remaining wall area = 96 % Tool devia6on = 61 ° Finger 13 Penetratian = 0.223 ins Pocsible Hole 0.22 ins = 88% Wall Penetration HIGH SIDE = UP i • Cross Sections page 1 ~ i ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~~U ~~ PDS Report Cross Sections Well: 1D-40A Survey Date: October 12, 2009 Field: Kuparuk Tool Type: UW MFC 24 No. 212330 Company: ConocoPhillips Ataska, Inc. Tool Size: 1.69 Country: USA No. of Fingers: 14 Tubing: 3.5 ins 9.3 ppf L-80 8RD EUE Analvst: C. Waldrop Cross Section for Joint 301 at depth 9470.31 ft Tool speed = 43 Nominal ID = 2.992 Nominal OD = 3.500 Remaining wall area = 97 % Tool deviation = 63 ° Finger 8 Penetration = 0.182 ins Line of pits 0.18 ins = 72% Wall Penetration HIGH SIDE = UP • • Cross Sections page 2 . ConocoPhillips .a~,:.., ~~,. - . . i :, I'. ; __~=is~-~ . , : 51.~ . _ 1 1::1 . ."~ 1 '.IIF~~, ' i ~~_'. 1 ~ . . .1 , !~`.,~. 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FLE MJ- Tu:~ ~ ~~~~, ' - ;!~'~~i~pbHt~237?"F~v~l~ ` ~ 2.81e 159 1 Cther .~ ~~ Y~ ~ iYiYr ~. • t~ i ~h h :F~.9.3~,I~ND.3~jEJE•M(.I~'~bvti•~ ~lI? ~5~i 330_~90 31.~~ l I~~~c, ~tidF~-:= ~~(~~ , ~ 8 :~i E'_ _ ~ ~ 'i,w, ~ ±'t'' .~i' . 9.371. I Q0 er~ F I lE•~+JO.~ :~.b~»' ? t/~ z y3~ 5. =~ :_ 3C i~7 1 lutir~, . ~ ~ 'v i.3~; ~ , ~ '3.~•:~r51?~ x '1~•Go1 ?catc~ : 2950 I.Gj ' Othe! . 5~a~:a ,.~:I 3~Id 3Q0) 2.7~ " llthe~ .• r~~~ ~ .t 3.;171 391~ 1 Uc~rr .. ~~Ii~ `:aa ~~ukty, .:j i..-.-.. ".r~v JeHU""" ~"Ul"1i'--U.rL-'''' Cl'> YY"ll e e Tom, I have reviewed the records. The details from the operations summaries and cement reports indicate that both 1D-40 and 1D-134 had good returns throughout the cement jobs and cement to surface. I have compiled the reports and highlighted the information related to the cement jobs. I have edited the documents to remove proprietary contractor data. My schedule for this afternoon is full. I will follow up on Monday with electronic or hard copies of the documents. Pat Reilly ConocoPhillips (907) 265-6048 (907) 244-5558 (907) 265-1535 Alaska Drilling WORK CELLULAR FAX & Wells ~'8¿;\\-\c>~ \ '\ ~~"''-'G.. ~'\t::) '\'-- \ "'" \Q:- ":> ~<-c-:-\-~~<è ~Cc \ \.. .ç\.\~ c:::. L l ~-- \ .~'-\ \,<r'\~"1 ¢: \ "'> ~Ü 'S.~..~c;:...(:: ~~V\. \-\,' ~ Ù'P~S-(;bo~ CJ..<:....~~\?~ \ \f , h0- <lJt11 Lt{ \0 -'0(.:, Thanks again for your help. Patrick.J.Reilly@conccophillips.com -----Original Message----- From - Thomas Maunder ['11'~ l' ., >-,-. . ... Om "l-'lI-clO~('j~'+"'l'" ~ ¡"' at' '" a'f .. '" 1 . . l'A .L .._-,. '. hC, "D., ". '--~ "-,.'.,",,, "-. ð ,- ., -,-. ''.'(''I;:~~\lir,;;r''1 Sent : Thursday, April 06, 2006 10: 13 AM \]',,,.1' ."\,.,=>,, To: Reilly, Patrick J Subject: Re: 1D-40 Surface Cement--1D-134 as well 4JOO-\\~ (Ci" ( ~\S~-\\\ Pat, Could you also provide information on 1D-134 as well? about as thin as for 1D-40. Thanks much. Tom The summary is Thomas Maunder wrote, On 4/6/2006 10:06 AM: Pat, I am reviewing the close wells to 1J-127. Would it be possible to get some "detailed" information on the surface cementing operations for 1D-40. That is the casing that would be across the West Sak. The information submitted with the completion report is pretty brief. No problems are indicated, but interpretation is difficult when all that the summary says is , "Run 9-5/8" casing. Break circ @ 2300' & 4300', good returns. Finish running 9-5/8" casing with shoe @ 6978', FC @ 6897'. Circulate and condition mud for cement job. Held PJSM. Cement 9-5/8" casing. N/D diverter system." It is noted that they drilled soft cement and wound up running a RTTS to test the casing. Formation test once out of the shoe looks OK at 13.8 EMW. Thanks for your help on this matter. Tom Maunder, PE AOGCC > .. e e Tom, Here are the details ofthe lD-40 and lD-134 cement jobs. Our color scan capability is still impaired. I will deliver hard copies after I send this email. Please refer to those documents. ID-40 Package: Page 1: I have highlighted the operational details that indicate relatively good hole conditions during several trips. Also, good returns were seen throughout the cement job with 96 bbls of cement to surface. Page 2: Details indicate a successful casing test with the test packer. Page 3: This is the planned cement program. TOC of tail slurry was planned to reach 800' above the top ofthe West Sak. Page 3a: These are my calculations using the actual volumes pumped. My calculated hole volume was 753 bbls. The actual volume pumped was 850 bbls. Assuming the hole washout was as expected, we should have returned 97 bbls to surface. The actual return was 96 bbls. Obviously the numbers are not usually that close, but in this case that is the way it worked out. Pages 4-5: The Dowell report indicates the pipe was reciprocated and cement was circulated to surface. Page 6: Pump Graph. Pages 7-8: Dowell Cement Test Report: Mike Martin (Dowell Representative) indicated that the tail density of 12.0 ppg. was probably lower than 15.8 ppg for ECD reasons. It will also achieve its compressive strength more slowly than the 15.8 ppg mix, but will eventually get to 2000 psi strength. Page 9: Our cement report indicates full circulation throughout the job and reciprocation until the top plug was dropped. This would have been after most of the lead cement was around the shoe. We displaced the theoretical plus Y2 of the shoe track. I think the data indicates that we likely have a competent barrier on the surface casing of 1 D-40. I ~ / eoo -\L~ Page 1 of 5 GonocoPhillips Alaska Operations Summary Report legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date 8/14/2000 8/15/2000 8/16/2000 8/17/2000 8/18/2000 8/19/2000 8/20/2000 1 D-40 1D-40 ROT - DRilLING Nabors Alaska Drilling Nabors 16E I Sub Code Code Phase 00:00 - 01 :00 1.00 DRILL SURFAC 01 :00·01 :30 0.50 DRILL SURFAC 01 :30·02:30 1.00 DRILL DRLG SURFAC 02:30 - 03:00 0.50 DRILL SURFAC 03:00 - 04:00 1.00 DRILL SURFAC 04:00 - 06:00 2.00 DRILL SURFAC 06:00 - 08:30 2.50 DRILL SURFAC 08:30 - 00:00 15.50 DRILL DRLG SURFAC 00:00 - 15:30 15.50 DRILL DRLG SURFAC 15:30 -16:30 1.00 CIRC SURFAC 16:30 - 20:30 4.00 DRILL WIPR SURFAC 20:30·21 :30 1.00 RIGMNT RSRV SURFAC 21 :30 - 22:30 1.00 DRILL WIPR SURFAC 22:30 - 00:00 1.50 CIRC SURFAC 00:00 - 14:00 14.00 DRILL DRLG SURFAC 14:00 - 15:00 1.00 CIRC SURFAC 15:00 -18:30 3.50 TRIP SURFAC 18:30 - 21 :00 2.50 PULD SURFAC 21 :00 - 23:00 2.00 TRIP SURFAC 23:00 - 00:00 1.00 CIRC SURFAC 00:00 - 21 :30 21.50 DRILL DRLG SURFAC 21:30-23:00 1.50 CIRC SURFAC 23:00 - 00:00 1.00 DRILL WIPR SURFAC 00:00·01 :00 1.00 DRILL WIPR SURFAC 01 :00 - 02:00 1.00 CIRC SURFAC 02:00 - 02:30 0.50 DRILL DRLG SURFAC 02:30·03:00 0.50 RIGMNT RSRV SURFAC 03:00 - 16:00 13.00 DRILL DRLG SURFAC 16:00· 18:30 2.50 CIRC SURFAC 18:30·23:30 5.00 DRILL WIPR SURFAC 23:30 - 00:00 0.50 DRILL WIPR SURFAC 00:00 - 02:30 2.50 DRILL WIPR SURFAC 02:30 - 06:00 3.50 CIRC SURFAC 06:00 - 10:30 4.50 TRIP SURFAC 10:30 - 13:00 2.50 PULD SURFAC 13:00 - 14:00 1.00 RIGMNT RSRV SURFAC 14:00 - 16:00 2.00 SURFAC 16:00·00:00 8.00 SURFAC 00:00·01 :00 1.00 SURFAC 01 :00 - 06:30 5.50 CIRC SURFAC 06:30 - 10:30 4.00 CEMENli PLUG SURFAC I I 10:30 . 12:30 2.00 CEMENlj PLUG SURFAC 12:30 - 14:30 2.00 :NUND SURFAC 14:30 - 16:30 2.00 WELCTLi BOPE INTRM1 I Sta rt: Rig Release: Rig Number: Spud Date: 8/13/2000 End: 9/2/2000 Group: 8/13/2000 9/2/2000 16E Description of Operations I Attempt to get MWD survey - no good See above See above i Replace 0 ring for transducer on stand pipe See above See above I Drill 12 1/4" hole f/431' to 469' I Attempt MWD survey - still having problem with tool- circ See above ! See above Pull out, LID MWD, ck motor & bit See above See above Wait on MWD tool See above See above P/U new MWD, Pony DC,XO· orient tool,RIH , ck shots @ 265',355,&446' See above See above Drill 12 1/4" hole fl 469' to 1847' Drill 12 1/4" hole f/1847' to 3255' Pump hi vis, hi wt. pill, circ up Wiper trip f/3255, to 906' - hole swabbing pumped out f/2972, to 1564' I Service TO & DW (circ while servicing) RIH f/906 to 3255' . no problems Circulate bottoms up Drill 12 1/4" hole f/3255, to 4378' Pump sweep and circ hole clean for bit trip Trip for bit - pulled 15stds. wet - no swabbing, pump dry jub, continue trip for bit Handle BHA , change bit and stab. service MWD RIH to 4378' - no problems Circulate btms up Drill 12 1/4" hole f/4378' to 5975' ADT 15.5 hrs. AST4.75 hrs. Pump sweep, circ hole clean - monitor well Wiper trip f/ 5975' to 4378' - no problems RIH fl 4378' to 5975' - no próblems Circ btms up Drill 12 1/4" hole f/5975' to 6020' Replace swab in # 2 pump Drill 12 1/4" hole fl 6020' to 6988' TD 12 141" hole ADT 8 .75 hrs- AST 1 hr. pump sweep - circ hole clean Wiper trip f/ 6988' to 906' (SLM), No problems RIH f/906' Continue RIH to 6988' - No problem QoinQ in hole. Circulate and condition mud and hole for casing monitor well, pump dry job Pull out to run 9 5/8" casing, hole in good condition Handle BHA stand back HWDP, LID jars, std. back DC's, Down laod MWD, LID mwd,motor and bit PJSM - cut drill line 184' R/U to run 9 5/8" casing· Held PJSM Ran168 jts. 95/8" 40# L-80 BTC· break circ @ 2300' & 4300' ~ ~od ,&turns - 181 jts. total to run -' Fínísh running 9 5/8" csg. 181jts.,csg hanger & landing jt. w/ shoe @ 6978' FC@ 6897' - RID casing tongs R/U cmt head & lines Circulate and condition mud for cmt job - Held PJSM Cmt. 9 5/8" csg - 645 bbls lead, 202 bbls tail, full returns, 96 bbls emt returns to surface, CIP @ 10:30 hrs. 8/20/2000 LID landing jt., Cmt head, clean up fl cmt job N/D diverter system Install & test FMC GenV wellhead Printed: 417/2006 10: 16:39 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date From - To 8/20/2000 16:30 - 21:00 21 :00 - 00:00 8/21/2000 00:00 - 00:30 00:30 - 01 :30 01 :30 - 04:30 04:30 - 05:00 05:00 - 06:00 06:00 - 11 :00 11 :00 - 12:30 12:30 - 13:30 13:30 - 15:00 15:00 - 19:00 19:00 - 20:30 20:30 - 21:30 21 :30 - 23:00 23:00 - 00:00 8/22/2000 00:00 - 02:30 02:30 - 04:00 04:00 - 08:30 I 08:30 - 09:30 09:30 - 13:30 13:30 - 14:30 14:30 - 16:00 16:00 - 17:00 17:00 - 20:00 20:00 - 20:30 - 22:00 22:00 - 23:30 23:30 - 00:00 8/23/2000 00:00 - 01 :30 01 :30 - 06:00 06:00 - 07:30 07:30 - 00:00 8/24/2000 00:00 - 04:00 04:00 - 05:00 05:00 - 06:30 06:30 - 08:00 08:00 - 09:00 09:00 - 10:00 e e 2. Page 2 of 5 ConocoPhillips"Alaska Operations Summary Report Phase 4.50 WELCTU BOPE INTRM1 3.00 WELCTLI BOPE INTRM1 0.50 ! INTRM1 1.00 jPULD INTRM1 3.00 !PULD INTRM1 0.50 I TRIP INTRM1 1.00 RIGMNTj RSRV INTRM1 5.00 ,TRIP INTRM1 1.50 [CIRC INTRM1 1.00 CASE DEQT INTRM1 i 1.50 CEMEN~ INTRM1 I I I I I I 4.00 CEMENli INTRM1 I 1.50 CEMEN~ INTRM1 1.00 I INTRM1 I 1.50 :CIRC INTRM1 1.00 CEMENi INTRM1 2.50 PROD 1.50 PROD 4.50 PROD 1.00 PROD 4.00 PROD 1.00 PROD 1.50 PROD 1.00 PROD 3.00 PROD 0.50 DRILL DRLG PROD 1.50 CIRC PROD 1.50 PROD 0.50 CIRC PROD 1.50 CIRC PROD 4.50 DRILL DRLG PROD 1.50 CIRC PROD 16.50 DRILL DRLG PROD 4.00 DRILL DRLG PROD 1.00 CIRC PROD 1.50 DRILL WIPR PROD 1.50 RIGMNT RSRV PROD 1.00 DRILL WIPR PROD 1.00 CIRC PROD Start: Rig Release: Rig Number: 8/13/2000 9/2/2000 16E Spud Date: 8/13/2000 End: 9/2/2000 Group: Description of Operations N/U 11" 5K BOPE P/U test jt. - Test BOPE _ Witnessing of test waived by Lou Grimaldi Set wear bushing, Blow down lines, UD test jt. UD 8" DC's fl derrick M/U 8-1/2" BHA, orient tools RIH wI 8-1/2" BHA - P/U 5" DP Service top drive & drws Continue RIH wI 8-1/2" BHA - P/U 5"DP - tag top of cmt @ 6876' Circulate btms up Pressure test 9 5/8" casing - pressure bleed off to 2775 psi in 10 mins. - check surface equip. - bleed off pressure - circ.- retest to 3000 psi - bleed off to 2650 psi in 5 mins. - bleed off pressure C/o soft cmt to FC - circulate btms up - soft cmt @ shakers - circ. hole clean Did not bump the plug and overdisplaced by 1/2 the annlus volume to the float collar. Casing would not pressure test -lost 1900 psi in 30 min. Dowell pumping charts showed changes in flowrate and cement density at the end of the tail cement column Drill out soft cement, float equipment and rathole. Circulate hole clean and pooh. RIH to just above float collar with Baker retrieve-o-matic packer. Set packer and pressure test casing. If test is good, POOH and pick up drilling assembly. RIH and perform LOT and then drill ahead WOC See above See above Retest 9 5/8" casing to 3000 psi - bleed down to 1100 psi in 30 mins. See above See above Drill FC and soft cmt to shoe - drill out shoe & clo rat hole to 6988' Circ hole clean - obtain SPR - monitor well - pump dry job Pull out wI 8 -1/2" bit & BHA to run test packer See above See above POOH (SLM) to P/U packer See above See above Work BHA Plug into MWD/LWD. Remove batteries. See above See above RIH wI Baker Retrieve-O-Matic to 695 ' See above See above Set packer & test casing to 3000/30 min See above See above POOH wI pa same. ee a ove See above Service Rig & Top Drive See above See above P/U BHA Orient tools, Program MWD/LWD. Install batteries. See above See above M/U rest of BHA See above See above RIH wI Drilling Assy. See above See above Drilling 8.5" hole fl 6988' to 7008' Circ & Cond for LOT. Mud weight 9.5 ppg. Rig up equip. & perform LOT. 7008' MD. 4268' TVD. 9.5 ppg MW. 950 psi. 13.8 EMW. RID equip. Blow down kill line. Circ & dispace well wI LSND mud. Displace wI LSND mud. PJSM. Clean pits & shakers. Drilling 8.5" hole fl 7008' to 7365'. ART=3.75 hrs AST=.25 hr Circ Sweep to clean hole for PWD baseline test. Perform Test. Drilling 8.5" hole fl 7365' to 8900'. ART=10.75 hrs AST=1.5 hrs Drilling 8.5" Hole fl 8900' to 9247' ART=3 hrs AST=O hrs Circ Weighted Sweep around, Monitor well. Pump slug & POOH to shoe. No problems. Service Rig & Top Drive. Cut drilling line 91'. RIH to 9247'. No problems. Circ Weighted sweep around. ECD's to calculated values after sweep Printed: 4/7/2006 10:16:39 AM II e I 1) L /1 . \ 0 ~ (1 Ç! Iv1 t2i;'-J T I í-'- fJ I t5' L) V I v '\"""QÌ> '-..J L::::' e -s \ ID-40 Kuparuk Well Surface Cement loads and CemCADE* summary. Use 45% excess below the Permafrost and 250% above. Drilled with 12 1/4" bit. 9 5/8", 47 #casing TMD 6960', Single Stage Design. Tail Slurry TOC is @ 4575' MD (800' above the West Sak top). No Port Collar Contingency Base of the Permafrost at 1630' MD Volume Cales: Pump 20 bbls Arco Preflush, 50 bbls Arco Spacer @ 10.5ppg w/ 0.1 #/bbl C359. Cement from MD to 4575' with LiteCRETE @12.0 ppg and from 4575' to surface with ASLite @1O.7 ppg Lead Slurry Requirements: ASLite @ 10.7ppg, Class G + 50%DI24, 9%D44, 0.4%D46, 30%D53, 1.5%SI, 1.5%D79 - 4.44 ft3/sk (4575'-1630') x 0.3132 ft3/ft x 1.45 (45% excess) = (1630') x 0.3132 ft3/ft x 3.50 (250% excess) = 1337.4 ft3+ 1786.8 ft3 = 3124.2 f13/ 4.44 ft3/sk = 1337.4 ft3 1786.8 ft3 3124.2 ft3 703.6 sks - Round up to 710 sks Have 260 sks of additional Lead on location for Top Outl2od stage, if necessary Tail Slurry Requirements: LiteCRETE @ 12.0 ppg - 2.46 ft3/sk (6960'-4575') x 0.3132 ft3/ft x 1.45 (45% excess) = Shoe Joints: (80') x 0.4110 ft3/ft = 1083.1 ft3 + 32.9 ft3 = 1116 ft3/ 2.46 ft3/sk = BHST = 80 deg F 1083.1 ft3 32.9 ft3 1116 ft3 453.7 sks - Round up to 460 sks CemCADE* Summary: Fluid sequence: Establish circulation using FW, 20 bbl Arco Preflush, 50 bbls 10.5ppg Arco Spacer wlO.I#/bbl C359, 710 sks (561 bbl) AS Lite Lead, 460 sks (202 bbl) LiteCRETE Tail. Displacement is approximately 504 bbls. Circulation: Circulation and cementing at or less than 8 bpm is within the safe ECD to avoid breaking down the formation. Recommend dropping the rate below 3 bpm for the last 20 bbls of displacement for bumping the plug as well as maintaining returns. Run dye marker in the spacer to provide insight into the decision to open the port collar or performing a top job. Expected pressure to bump the plug is 700 psi. At 7 bpm, expect 30 minutes ofu-tubing after dropping the top plug. Recommended Conditioned Mud Properties: 10.0 ppg, Pv = 20 or under, Ty = 20 or under. e e 3ø.. 1 D-40 Surface Cement Hole Section LENGTH Cap. (bbl/ft) Cap. (Bbl) Cap. With Excess lead above pf 1630 0.0558 91 318 lead below pf 2948 0.0558 164 238 tail 2400 0.0558 134 194 tail below shoe 10 0.1458 1 2 Calculated Volumes TOTAL 391 753 Sacks ft^3/sack ft^3 bbl ILead 818 4.44 3,632 647 ITail 477 2.38 1,135 202 Actual Pumped Total Calculated Excess to Surface = (850-753) Actual to Surface 850 97 96 .... Ie Cementing Service Report ,e \_- Lf Dowell I Customer I Job Number ARCO ALASKA INC 20174038 Well I Location (legal) Dowell Location Job Start 1D 40 Prudhoe Bay, AK 8/20/00 Field Formation NamelType Deviation I Bit Size WellMD Well TVD WEST SAK 66 0 12.3in 6,978 ft 4,256 ft County State/Province BHP BHST I BHCT OaF I Pore Press. Gradient Beechey Point AK o psi 80°F 0 psi/ft Rig Name Drilled For I Service Via Casing/liner ! Oil Land Depth, ft Size, in Weight, Iblft Grade Thread Offshore Zone Well Class I Well Type 6978 9.63 40 New Workover 0 0 0 Drilling Fluid Type I Max. Density II Plastic Viscosity 1\. ......... < .'. TUbing/Drill Pipe .. . o Ib/gal 0 Cp Depth, Size, in Weight, Ib/ft Grade Thread Service Line Job Type 0 0 0 Cementing Cem Surface Casing 0 0 0 Max. Allowed Tubing Pressure Max. Allowed Ann. Pressure I WellHead Connection Perforations/Open Hole 3500 psi o psi Double cement hea Top, ft Bottom, ft I spf I No. of Shots T otallnterval 0 0 0 0 0 ft ,.,. r 0 0 0 0 Diameter 0 0 0 0 0 in ,All Fe Treat Down Displacement Packer Type Packer Depth Casing 523 bbl 0 ft Tubing Vol. Casing Vol. Annular Vol. OpenHole Vol 0 bbl 523 bbl 390 bbl o bbl CasinglTubing Secured ~ 1 Hole Volume Circulated prior to cementingD Casing Tools Squeeze Job Lift Pressure: psi Shoe Type: Float Squeeze Type Pipe Rotated 0 Pipe Reciproc:atelQ1 Shoe Depth: 6976.5 ft ToolType: No. Centralizers: 0 Top Flugs: 1 IBottom Plugs: 1 Stage Tool Type: Tool Depth: Oft Cement Head Type: Double Stage Tool Depth: Oft Tail. Pipe Size: Oin Job Scheduled For: I Arrived on Location: I Leave Location: Collar Type: Diff-FiII Tail Pipe Depth: Oft 8/19/00 13:00 8/19/00 22:00 8/20/00 10:30 Collar Depth: 6897.5 ft Sqz Total Vol: Obbl T¡lrit¡ CiimVol Density ¡Pressure U1 Sl:ageVoI I T otfIowiaté I Message 24hr . bbí I ¡ I clock ppg , . psi bbI bpm . 6:29 0.014 8.39 4.58 ; 0.D14 O. 0 0 Start Pumping Water 6:35 5.45 8.37 3306 5.45 O. 0 0 Pressure Test Lines 6:37 5.45 8.4 27.47 5.45 O. 0 0 Stal1 Prefl u s h 6:37 5.45 8.4 27.47 5.45 O. 0 0 ResetVolume 6:37 5.45 8.4 27.47 5.45 O. 0 0 [Stage Vol]=5.45 bbl 6:41 26.44 8.26 215.2 20.99 4.34 0 0 Drop Bottom Plug 6:41 26.81 8.06 36.63 21.36 O. 0 0 Reset Volume 6:41 26.81 8.06 36.63 21.36 O. 0 0 [Stage Vol]=21.36 bbl 6:55 7256 10.58 41.21 45.75 O. 0 0 Start Lead Cement 6:56 7256 10.58 41.21 45.75 O. 0 0 [Stage Vol]=45.83 bbl 6:56 7256 10.58 41.21 45.75 O. 0 0 Reset Volume 8:28 717.8 10.77 631.9 645, 6.93 0 0 Start Mixing Tail Slurry 8:28 720.1 10.6 572.3 O. 6.99 0 0 ResetVolume 8:28 720.1 10.6 572.3 O. 6.99 0 0 [Stage Vol]=646.8 bbl 9:01 I 921.9 12.18 54.95 201.8 0.272 0 0 Drop Top Plug 9:01 921.9 12.18 54.95 20få 0.272 0 0 [Stô.ge Vol]=201.8 bbl 9:01 921.9 12.18 54.95 201.8 I 0.272 0 0 Reset Volume 9:06 932.2 8.75 27.47 10.26 O. 0 0 --. Start Mud Displacement 11:10 End Job RIGS 97 v2.1a-SR Page 1 of 2 Well Time 24hr clack Slurry Maximum 1 D #40 Average Pump Rates, N2 Mud 5 o Treating Pressure Summary, psi Final Average Bump Plug to Breakdown e Field bpm WEST SAK Service Date Maximum Rate Post Job Summary Total Slurry o o 12 bbl Customer or Authorized Representative RIGS 97 v2.1a·SR Don Mickey Dowell Supervisor 10 6 847 Type Mix Water Temp 75 of Steven Doughten e Job Number ARCO ALASKA INC 20174038 Message Volume of Fluid Injected, bbl Mud Spacer o Breakdown Fluid 50 Volume Density L o bbl L ~ o Cement Circulated to Surface? Volume Washed Thru Perfs To o o CirculationLost N2 o Ib/gaf o bbl ft ~ Job Completed Page 2 of 2 5 o 06:28:48 06:43: 12 06:57:36 07:12:00 07:26:24 07:40:48 07:55:12 08:09:36 08:24:00 08:38:24 0 " u '~J 08:52:48 ill Cementing Job Report PRISM* V2.23 Pressure Ui psi Client Phillips Petroleum SIR No. Job Date 8/20/20006:25:02 AM ,rJ. 4000 Messages J<StartPumping Water bb! þbl Fluid No : PAK Icrt001 Date : 17-08-2000 Job Type BHST' Starting Temp. Starting Pressure Ie e SCblulllbørgep Laboratory Cement Test Report surface 80 degF 80 degF 348 psi Client : Phiilips Well Name : 1 D-40 Depth BHCT Time to Temp. Time to Pressure Rig ': Nabors 16E Field : Kuparuk 6960.0 ft 65 degF 00:24 hr:mn 00:24 hr:mn TVD BHP Heating Rate API Schedule Fld Blend LiteCRETE Tail 3906.0 ft 2248 psi -0.61 degF/min 1- Composition G Fresh water 8.097 gallsk Rheology 300 200 100 60 30 6 3 Pv (cP) Ty (lbf/100ft2) I Temperature 96 72 42 29 19 10 .8 85.932 12.10 70 degF Density Yield Mix Fluid Porosity ~ t b 0 ..;) <2/[( í ......ts Results Thickening Time 1\ í Ii r,~~ fo ,,---.---.-.--....._ VJ r (J \~2.00 Ib/gal ¿t:>I:JÞO P So :. 2~k--- Co >Ie r ,..~. 1>$ I ¡J ~ 8.097 gal/sk Sf" ~'I,3f1,... 45.4% rnl:lr~ ;)Iov-ll,: ;-~~ IS Ie f'ófÞ' tr kþ (;" 5 e' ~.tz-.¿f1·· in 2 hrs at 0 deg None 124 95 57 40 26 12 10 108.946 18.32 65 degF .VI..'" Free Water 0.0 mU250mL At 72 degF and 0 deg incl. Sedimentation -- Comments ie ,e Laboratory Cement Test Report Fluid No : PAK surl143 Date : 23-07-2000 Job Type Surface BHST 70 degF Starting Temp. Starting Pressure Blend Base Fluid 1 Rheology G Fresh water Client : Phillips Well Name : 10-40 Depth BHCT Time to Temp. Time to Pres~ure Rig : Nabors 16e Field : Kuparuk 4500.0 ft TVD BHP Heating Rate API Schedule Composition 20.135 t . Fld Blend Lead Slurry 4500.0 ft Density Yield Mix Fluid Porosity 10.701b/gal 4.44 ft3/sk 20.704 gal/sk 62.4 % ~þ9~( p ¡I" Jt"l)JL. ~.c..l"uf 1 ests Results Thickening Time ¡Gõn"$lstem:Yl~~1;':d!~~'tiii:1~Tim~:t~þl' 104 74 BC'- .. . .., ..'....··06:00 hr:mn' 81 70 58 54 49 35 20 27.839 50.04 65 degF 600 300 200 100 60 30 6 3 J:'v (cP) fy (lbf/100ft2) r Temperature 70 degF :><"'" Comments ie ,e Phillips Alaska Drilling Cementing Details Well Name: 1D·40 Report Date: 0812012000 Report Number: 8 Rig Name: Nabors 16E AFC No.: AIŒ097 Field: KUP Casing Size Hole Diameter: Angle thru I<RU, Shoe Depth: I LC Depth: % washout: 9518" 12114" 66 6978 6897 93 Centralizers State type used, intervals covered and spacing Comments.: Weatherford SpiraGlider jts. 2, 4-13, Bow spring onJts.1,J & everythirdjt fl # 16·# 172 Mud Weight: PV(prior cond): PV{after cond): I YP{prior cond): YP(after cond): Comments.: 9.7 31 20 56 17 Gels before: Gels after: Total Volume Circulated: 23148 719 2 pipe & annuluar volumes Wash 0 Type: Volume: Weight: COOIma¡ls: ARCD Wash 20 bbls 8.3 PP9 Sp.acer 0 Comments: Type: Volume: Weight ARCD 845 50 bbls 10.5 ppg lead Cemen.t 0 Comments: Type: Mixwtrtemp: No. of Sacks: I Weight: Yield: AS IIIlW 75 818 10.7 4.44 '-Þ :7 ~ e- I I -¡-r fJ,-f}...£. l.- T a¡l Cemeßt 0 Comments: 1',"0 I No. of Sacks: A Weight: Yield: 75 477 12.0 2.38 l,¡,CRETE 'V Disp.litcement [J Comments: Rate(before tail at shoe}: Str. WI. Up: 6.5 bpm 6.5 bpm 3201{ Reciprocation length: Reciprocation speed: Str. Wt. Down: 15' 160 K Theoretical Displacement: Actual Displacement: Str. Wt.inmud: 523 bbls 526 bbls Calculated top ot cement: CP: Bumped plug: I Floats held: Surface - 96 bbls cmt returns Date:0812012000 No Yes Time:10:3[J hrs. Remarks:Full circ through out the job· Reciprocated pipe until dropping top plug· Didn't bump plug displaced theoretical plus 112 shoe track Cement Company: Rig CDntractDr: I ~PPrDVed By: DDwell NABDRS DDn Mickey ,-or 1 ~ MICROFILMED 04/01/05 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE F:\LaserFiche\CvrPgs _ Inserts\Microfilm _ Marker.doc Permitto Drill 2001190 MD 12225 ~ TVD DATA SUBMITTAL COMPLIANCE REPORT 9/912002 Well Name/No. KUPARUK RIV UNIT 1D-40 Operator PHILLIPS ALASKA INC. 6376 J Completion Dat 9/2/2000 ~ Completion Statu P&A Current Status APl No. 50-029-22969-00-00 P&A UIC Y REQUIRED INFORMATION Mud Log N__.~o Sample No Directional Survey ~ \,/,~.~, DATA INFORMATION Types Electric or Other Logs Run: Well Log Information: Log/ Data Digital Digital Type Media Fmt (data taken from Logs Portion of Master Well Data Maint) Log Log Run Name Scale Media No Interval OH I Dataset Start Stop CH Received Number Comments 6945 12172 Case 2/22/2001 09835 '6945-12172 L L L L L L L L D D R R R R R R D D R R z~D GP,/DEN/NEU 2/5 FI. NAL ~/ROP/GPJRES 2/5 FINAL ~7~D G'P,/RI~S 2/5 FINAL , ~D GP,/NEU/DEN 2/5 FINAL , ~ ~ FINAL ~ s~l~Verification FINAL ~'~VY RPT FINAL ~-/VY RPT FINAL ~--E~G LIS 110 12225 CH 2/22/2001 110 12225 CH 2/22/2001 110 12225 CH 2/22/2001 110 12225 CH 2/22/2001 2/22/2001 2/22/2001 0 12225 OH 9/19/2000 0 12225 OH 9/19/2000 6945 12172 1/9/2001 1/9/2001 9835 110-12225 BL, Sepia 110-12225 BL, Sepia 110-12225 BL, Sepia 110-12225 BL, Sepia LIS Verification Digital Data LIS Verification Paper Copy SPERRY 0-12225. SPERRY 0-12225 MWD 6945-12172 Digital Data Lis Verification Well Cores/Samples Information: Name Interval Start Stop Sent Dataset Received Number Comments ADDITIONAL INFORMATION Well Cored? Y Chips Rece ved? Analysis R ~.c.~.iv~.cl '~ Daily History Received? {~/N Formation Tops ~/N Comments: Permit to Drill 2001190 MD 12225 TVD DATA SUBMITTAL COMPLIANCE REPORT 91912002 Well Name/No. KUPARUK RIV UNIT ID-40 Operator PHILLIPS ALASKA INC. 6376 Completion Dat 9/2/2000 Completion Statu P&A Current Status P&A APl No. 50-029-22969-00-00 UIC Y Compliance Reviewed By: Date: PLUGGI_~G & LOCATION CLEA~,gCM REPORT State of Alaska Review the well file, and. c=mmen: on plugging, well head Well head .. 3.3.05 Code WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Lisa Weepie 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 MWD Formation Evaluation Logs 1D-40, AK-MM-00146 February 08, 2001 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Jim Galvin, Sperry-Sun Drilling Services, 6900 Arctic Blvd., Anchorage, AK 99518 1D-40: 2" x 5" MD Resistivity & Gamma Ray Logs: 50-029-22969-00 2" x 5" TVD Resistivity & Gamma Ray Logs' 50-029-22969-00 2" x 5" MD Neutron & Density Logs: 50-029-22969-00 2" x 5" TVD Neutron & Density Logs' 50-029-22969-00 1 Blueline 1 Folded Sepia 1 Blueline 1 Folded Sepia 1 Blueline 1 Folded Sepia 1 Blueline 1 Folded Sepia To: WELL LOG TRANSMITTAL State of Alaska Alaska Oil and Gas Conservation Comm. Attn.' Lori Taylor 3001 Porcupine Dr. Anchorage, Alaska 99501 January 09, 2001 MWD Formation Evaluation Logs 1D-40, AK-MM-00146 1 LDWG formatted Disc with verification listing. API#: 50-029-22969-00 PLEASE ACKNOWLEDGE RECEIFr BY SIGNING TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Service Attn: Jim Galvin 6900 Arctic Blvd. Anchorage, Alaska 99518 RETURNING A COPY OF THE Date: PHILLIPS Alaska, Inc. A Subsidiary of PHILLIPS PETROLEUM COMPANY Post Office Box 100360 Anchorage, Alaska 99510-0360 J. Trantham Phone (907) 265-6434 Fax: (907) 265-6224 November 15, 2000 Mr. Daniel T. Seamount, Jr. Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Subject: Completion Report for 1D-40 (200-119/300-231) Dear Mr. Commissioner: Phillips Alaska, Inc. submits the attached Completion Report for the drilling operations on 1D-40. If you have any questions regarding this matter, please contact me at 265-6434 or Tom Brockway at 263-4135. Sincerely, J. Trantham Drilling Engineering Supervisor PA1 Drilling JT/skad RECE X/ED Gas cons. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of well Classilication of Service Well Oi, D ~ D Suspended D Abandoned r~ Service D 2. Name of Operator 7. Permit Number Phillips Alaska, Inc. 200-119 / 300-231 3. Address 8. APl Number P. O. Box 100360, Anchorage, AK 99510-0360 50-029-22969-00 4. Location of well at surface ' 9. Unit or Lease Name 537' FNL, 421' FEL, Sec. 23, TllN, R10E, UM (ASP 560671,5959129) i ~ li Kuparuk River Unit At Top Producing Interval .[. ~_~-'~-. I1 i10. Well Number 951' FSL, 627' FEL, Sec. 26, T11 N, R10E, UM (ASP: 560544, 5950058) '.[~ 1D-40 At Total Depth ~ 11. Field and Pool 646' FSL, 749' FEL, Sec. 26, T11 N, R10E, UM (ASP: 560424, 5949752) Kuparuk River Field 5. Elevation in feet (indicate KB, DF, etc.) 16. Lease Designation and Serial No. RKB 35' feetI ADL 25661 & 25650, ADL 471 Kuparuk River Oil Pool 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. Or Aband. 115. Water Depth, if offshore 16. No. of Completions August 13, 2000 August 30, 2000 September 2, 2000 (P&A'd) I N/A. fee{ MSL 1 17. Total Depth (MD + TVD) 18. Plug Back Depth (MD + TVD) 19. Directional Survey 120. Depth where SSSV set 21. Thickness of Permafrost lP~25' MD/6376' TVD 11137' MD/5957' TVD YES r~ No r-]I N/A feet MD 1511' 22. Type Electric or Other Logs Run MWD/GR/RES/PWD 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 20" 91.5# H-40 Surface 137' 30" 503 sx ASLite 9.625" 40# L-80 Surface 6978' 12-1/4" 818 sx AS III LW, 477 sx LiteCRETE 7" 26# L-80 Surface 11593' 8-1/2" 180 sx Class G Plu~l #1: 11610'-12225' Plug ~2:11137'-11610' 24. Perlorations open to Production (MD + TVD of Top and Bottom and 25. TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 3-1/2" tubing kill string 2150' N/A No Perforations 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED Plug #1: 11610'-12225' 29 bbls 15.8 cement Plug ~2:11137'-11610' 19 bbls 15.8 cement 27. PRODUCT~ONTEST i ! !~ i t~l i\i Date First Production Method o! Operation (Flowing, gas lilt, etc.) v ~ ~ i N/A Plugged & Abandoned Date of Test Hours Tested Production for OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE I GAS-OIL RATIO I N/A Test Period > Flow Tubing Casing Pressure Calculated OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY - APl (con') Press. 24-Hour Rate · 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and pressence of oil, gas or water. Submit core chips. RECEIVED N/A NOV Alaska 0it & Gas Cons. Commission Anchorage Form 10-407 Rev, 7-1-80 CONTINUED ON REVERSE SIDE Submit in duplicate GEOLOGIC MARKERS FORMATION TESTS NAME Include interval tested, pressure data, all fluids recovered and gravity. MEAS. DEPTH TRUE VERT. DEPTH CE)R, and time of each phase. Top of Kuparuk C 12015' 6296' Base of Kuparuk C 12052' 6310' Top of Kuparuk A 12225' 6376' N/A Base of Kuparuk A 12225' 6376' 31. LIST OF ATTACHMENTS Summary of Drilling Operations, Directional Survey 32. I hereby certify that the following is true and correct to the best of my knowledge. Questions? Call Tom Brockway 263-4135 Signed Title Ddllin,q E n,q neerin,q Supervisor Date ~ J. Trantharn Prepared by Sharon Al~sup-Drake INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1: Classification of Service wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. 'Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21: Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool, Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". Form 10-407 Date: 10/05/00 ARCO ALASKA INC. WELL SUMMARY REPORT Page: 1 WELL:iD-40 STATE:ALASKA COUNTY: NORTH SLOPE EAST FIELD: KUPARUK RIVER UNIT SPUD:08/13/00 START COMP: RIG:NABORS 16E BLOCK: FINAL: WI: 0% SECURITY:0 API NUMBER: 50-029-22969-00 08/13/00 (D1) TD/TVD: 431/0 SUPV: MW: 9.3 VISC: 235 PV/YP: 28/47 ( 431) P/U NEW SPERRY SUN MWD APIWL: 7.2 Move from 1D-30 to 1D-40. Accept rig @ 1000 hrs. 8/13/00. NU diverter system. Held pre-spud meeting. Function test 20" diverter system. Performed shallow gas kick drill. RIH, tag bttm of conductor @ 137', Spud in @ 1900 hrs. Drill 12.25" hole from 137' to 431' 08/14/00 (D2) MW: 9.6 VISC: 255 PV/YP: 42/57 TD/TVD: 1847/1819 (1416) DRILLING 12 1/4" @ 2385 SUPV:DON MICKEY APIWL: 6.4 Attempt to get MWD survey, no good. Replace O ring for transducer on stand pipe. Drill 12.25" hole from 431' to 469'. Attempt MWD survey, still having problem with tool, circ. Pull out. Replace with new MWD. Drill 12.25" hole from 469'- 1847' 08/15/00 (D3) MW: 9.5 VISC: 235 PV/YP: 39/57 APIWL: 6.2 TD/TVD: 3255/2773 (1408) DRILLING 12 1/4" HOLE @ 3732 SUPV:DON MICKEY Drill 12.25" hole from 1847' to 3255' Pump hi vis, hi weight pill, circ up. Wiper trip from 3255' to 906', hole swabbing pumped out from 2972' to 1564'. RIH. No problems. Circulate bottoms up. 08/16/00 (D4) MW: 9.6 VISC: 205 PV/YP: 37/53 APIWL: 5.8 TD/TVD: 4378/3193 (1123) DRILLING 12 1/4" HOLE @ 4865' SUPV:DON MICKEY Drill 12.25" hole from 3255' to 4378' Pump sweep and circ hole clean for bit trip. Trip for bit. Change bit. RIH to 4378', no problems. Circulate bottoms up. 08/17/00 (D5) MW: 9.8 VISC: 202 PV/YP: 32/53 APIWL: 5.5 TD/TVD: 5975/3850 (1597) DRILLING 12 1/4" HOLE @ 6250' SUPV:DON MICKEY Drill 12.25" hole from 4378' to 5975'. Pump sweep, circ hole clean, monitor well. Wiper trip from 5975' to 4378', no problems. RECEIVED NOV 0 2000 Alaska 0tl & Gas Cons. Commission Anchorage Date: 10/05/00 ARCO ALASKA INC. WELL SUMMARY REPORT Page: 2 08/18/00 (D6) MW: 9.7 VISC: 175 PV/YP: 28/46 APIWL: 5.0 TD/TVD: 6988/4260 (1013) CIRCULATE AND CONDITION HOLE FOR 9 5/8" CSG SUPV:DON MICKEY RIH from 4378' to 5975', no problems. Circ bttms up. Drill 12.25" hole from 5975' to 6020'. Replace swab in #2 pump. Drill 12.25" hole from 6020' to 6988'. Pump sweep. Circ hole clean. Wiper trip from 6988' to 906'. No problems. RIH from 906' 08/19/00 (D7) MW: 9.7 VISC: 180 PV/YP: 31/56 APIWL: 5.0 TD/TVD: 6988/4260 ( 0) CEMENTING 9 5/8" CASING SUPV:DON MICKEY Continue RIH to 6988'. Circulate and condition mud and hole. Pump dry job. PJSM. R/U to run 9-5/8" casing. PJSM. Ran 9-5/8" casing. Break circ @ 2300' & 4300', good returns. 08/20/00 (D8) TD/TVD: 6988/4260 ( SUPV:DON MICKEY MW: 9.6 VISC: 44 PV/YP: 17/15 0) RIH W/ 8 1/2" BIT & BHA APIWL: 6.6 Finish running 9-5/8" casing w/shoe @ 6978', FC @ 6897' Circulate and condition mud for cement job. Held PJSM. Cement 9-5/8" casing. N/D diverter system. N/U BOPE and test. 08/21/00 (D9) TD/TVD: 6988/4260 ( SUPV:DON MICKEY MW: 9.3 VISC: 39 PV/YP: 11/ 9 0) RIH W/ PACKER TO TEST CSG APIWL: 10.2 RIH w/8.5" BHA. Tag top of cement @ 6876'. Circulate bottoms up. Pressure test 9-5/8"casing. C/O soft cement to FC, circulate bottoms up, soft cement @ shakers, circ hole clean. Retest 9-5/8" casing. Drill FC and soft cement to shoe, drill out shoe & c/o rat hole to 6988'. Circ hole clean. Pull out w/8.5" bit & BHA to run test packer. 08/22/00 (D10) MW: 9.5 VISC: 46 PV/YP: 11/12 APIWL: 11.0 TD/TVD: 7008/4268 ( 20) CIRC & COND FOR PWD BASELINE TEST. 7365' DEPTH SUPV:FRED HERBERT POOH. RIH w/Baker retrieve-o-matic to 6950'. Set packer and test casing to 3000 psi. POOH w/packer. RIH w/drilling assy. Drilling 8.5" hole from 6988' to 7008'. Circ and cond for LOT. Perform LOT, 13.8 EMW. Circ and displace well w/LSND mud. 08/23/00 (Dll) MW: 9.0 VISC: 43 PV/YP: 10/ 9 TD/TVD: 8900/5019 (1892) WIPER TRIP TO SHOE. DEPTH 9279' SUPV:FRED HERBERT APIWL: 7.2 Displace w/LSND mud. PJSM. Drilling 8.5" hole from 7008' to 7365'. Circ sweep to clean hole for PWD baseline test. Perform test. Drilling 8.5" hole from 7365' to 8900' RECEIVED NOV 2, 0 2000 Alaska Oil & Gas Cons. Commission Anchorage Date: 10/05/00 ARCO ALASKA INC. WELL SUMMARY REPORT Page: 3 08/24/00 (D12) MW: 9.3 VISC: 48 PV/YP: 18/23 APIWL: 4.6 TD/TVD:10403/5624 (1503) DRILLING AHEAD @ 10948' SUPV:FRED HERBERT Drilling 8.5" hole from 8900' to 9247'. Circ weighted sweeD around, monitor well. Pump slug & POOH to shoe. No problems. RIH to 9247' Circ weighted sweep around. Drilling 8.5" hole from 9247' to 10403' 08/25/00 (D13) MW: 10.0 VISC: 53 PV/YP: 18/20 TD/TVD:l1390/6021 (987) RIH TO BOTTOM AFTER LOT SUPV:FRED HERBERT APIWL: 3.6 Drilling 8.5" hole from 10403' to 11390'. Pump densified sweep around. POOH w/ 10 stds. RIH to bottom w/ no problems. Circ bttms up. Small amount of gas on bttms up. Mud weight cut to 9.4 ppg. Continue circ & raise mud weight to 10 ppg. POOH w/15 stds. No tight spots. Monitor well (static). RIH. Circ bttms up. No gas cut mud on bttms up. 08/26/00 (D14) TD/TVD:l1390/6021 ( SUPV:FRED HERBERT MW: 10.1 VISC: 48 PV/YP: 17/13 APIWL: 3.4 0) L/D BHA. NOTE; RIG ON HIGH LINE POWER @ 15:00 HRS. POOH to shoe @ 6978'. Monitor well. Circ out dry job for LOT. Perform deep LOT, 12.6 EMW. RIH to bttm. Circ bttms up. Drilling 8.5" hole from 11390' to 11605'. Circ densified sweep, monitor well. POOH w/ 10 stds. RIH to bttm. Pump sweep. Circ and cond for casing. Monitor well. Pump dry job. POOH. 08/27/00 (D15) TD/TVD:l1390/6021 ( SUPV:FRED HERBERT MW: 10.0 VISC: 45 PV/YP: 18/14 0) INSTALL PACK OFF APIWL: 3.5 POOH to run 7" casing. PJSM. Run 7" casing. PJSM. Run 7" casing. Circ bttms up @ 9430'. Run 7" casing. Circ and cond for cement job. 08/28/00 (D16) MW: 11.2 VISC: 55 PV/YP: 20/19 APIWL: 3.2 TD/TVD:l1390/6021 ( 0) RIH W/ 6 .125" DRILLING ASSY. P/U 4" DP SUPV:FRED HERBERT Circ and cond for cement job. PJSM. Pump cement. Bump plug. Check float equipment (OK). Install packoff and test to 5000. Test BOPE to 250/5000. 08/29/00 (D17) MW: 11.3 VISC: 58 PV/YP: 22/21 APIWL: 3.4 TD/TVD:l1728/6150 (338) DRILLING AHEAD SUPV:FRED HERBERT PJSM. RIH. Tag cement stringers @ 11480' Circ out cement cont. mud. Test 7" casing to 3500 psi. Drill out cement, float equipment and 20' new hole. Pump sweep. Perform FIT to 16 EMW. drilling 6.125" hole from 11625' to 11728' RECEIVED NOV Z 0 ZOO{} Alaska Oil & Gas Cons. Commission Anchorage Date: 10/05/00 ARCO ALASKA INC. WELL SUMMARY REPORT Page: 4 08/30/00 (D18) MW: 11.5 VISC: 63 PV/YP: 33/32 TD/TVD:12225/6338 (497) READ LOGS SUPV:FRED HERBERT APIWL: 4.9 Circ bttms up. Perform PWD baseline test. Drilling 6.125" hole from 11728' to 11924'. Circ out gas cut mud. Circ bttms up for ECD's. Drilling 6.125" hole from 11924' to 12225'. Circ and cond mud. Circ densified sweep around. Raise mud weight to 11.5 ppg. Monitor well Pump out to shoe. RIH to bttm. No problems. Circ & cond mud for liner. No gas cut mud on bottoms up. Monitor well (OK). 08/31/00 (D19) TD/TVD:12225/6338 ( SUPV:FRED HERBERT MW: 11.5 VISC: 52 PV/YP: 22/30 0) CIRC. W.O.C. APIWL: 6.8 Monitor well. POOH. PJSM. Rig maintenance and cleaning. RIH to plug well. Tag bttm @ 12225'. Circ and condition mud for cement plug. PJSM. Lay cement plug. POOH slow to 11329'. Circ out cement cont. mud. No cement back to surface. RIH tag cement @ 11610'. Circ out cement and cement contaminated mud. Cond for 2nd plug. 09/01/00 (D20) TD/TVD:12225/6338 ( SUPV:FRED HERBERT MW: 0.0 VISC: 52 PV/YP: 0/ 0 0) NIPPLE DOWN. APIWL: 0.0 Lay cement plug. Pump cement. POOH 10 stds (slow) to 10625'. WOC. Circ & cond. mud. RIH tag cement @ 11137'. Set down firm cement. Circ out contaminated mud. POOH. Rig up to run tubing. PJSM. Run 3.5" tubing. 09/02/00 (D21) MW: 0.0 VISC: 52 PV/YP: 0/ 0 APIWL: 0.0 TD/TVD:12225/6338 ( 0) RIG RELEASED @ 0800 HRS F/ 1D-40 SUPV:FRED HERBERT Run 3.5" tubing kill string to 2150'. Freeze protect. ND BOPE stack. Rig released from 1D-40 @ 0800 hrs. to move to 1D-36. North Slope Alaska Alaska State Plane 4 Kuparuk 1D 1D-40 Job No. AKMMO0146, SURVEY REPORT 13 September, 2000 Your Ref: API-500292296900 Surface Coordinates: 5959128.85 N, 560670.87 E (70° 17' 56.0313" N, Kelly Bushing: 105.30ft above Mean Sea Level m I:tR I L. L.. 1 N Cll S IIIRVI C: i~e A Halliburton Company 210° 29' 28.8357" E) Survey Ref: svy9290 RECEIVED NOV 2, 0 ZOOO Alaska 0it & Gas Cons. Commission Anchorage North Slope Alaska Measured Sub-Sea Depth Incl. Azim. Depth (~) (~) 0.00 0.000 0.000 -105.30 137.00 0.000 0.000 31.70 207.23 0.140 337.920 101.93 298.28 0.390 53.230 192.98 386.23 0.300 58.880 280.93 476.21 0.630 41.360 370.90 570.56 0.560 348.400 465.25 657.41 0.510 297.330 552.10 745.23 0.340 278.450 639.91 838.99 0.860 192.050 733.67 Sperry-Sun Drilling Services Vertical Depth (ft) 0.00 137.00 207.23 298.28 386.23 476.20 570.55 657.40 745.21 838.97 932.80 3.150 144.440 827.42 932.72 1026.58 4.880 136.720 920.97 1026.27 1120.58 6.150 138.720 1014.53 1119.83 1210.14 7.060 157.110 1103.51 1208.81 1310.27 9.130 168.560 1202.64 1307.94 1403,78 12.590 167.200 1294.46 1399.76 1497.51 15,130 166.910 1385.45 1490.75 1593.28 16.920 167.720 1477.50 1582.80 1686.61 19.550 167.640 1566.13 1671.43 1780.10 23.160 166.740 1653.19 1758.49 Survey Report for 1D-40 Your Ref: API.500292296900 Job No. AKMMO0146, 1877.72 27.780 166.510 1741.30 1846.60 1973.31 30.760 169.260 1824.68 1929.98 2065.85 31.810 173.740 1903.77 2009.07 2159.75 34.920 176,860 1982.19 2087.49 2250.50 36.210 176.540 2056.01 2161.31 Local Coordinates Northings (ft) 0.00 N 0.00 N 0.08 N 0.37 N 0.67 N 1.16N 2.00 N 2.59 N 2.81 N 2.16N Eastings (ft) Global Coordinates Northings Eastings (fi) (ft) 0~00 E 5959128.85 N 560670.87 0.00 E 5959128.85 N 560670.87 0.03W 5959128.93 N 560670.84 0.17 E 5959129.22 N 560671.04 0.61 E 5959129.52 N 560671.48 0.62 S 5.62 S 12.32 S 20.99 S 34.45 S 51.67 $ 73.55 S 99.34 S 127.87 S 161.05 S 1.14 E 5959130.02N 560672.00 1.39 E 5959130.86 N 560672.24 0.96 E 5959131.45 N 560671;81 0.36 E 5959131.66 N 560671.20 0.07W 5959131.01N 560670;79 1.29 E 5959128.24 N 560672.16 5.52 E 5959123.27N 560676.43 11.58 E 5959116.63N 560682.55 16.89 E 5959107.99 N 560687.93 20.86 E 5959094.57N 560692.01 201.88 S 247.57 S 295.07 S 346.53 S 399.22 S 24.59 E 5959077.38 N 560695.88 29.62 E 5959055.55 N 560701.09 35.42 E 5959029.80 N 560707.09 41.65 E 5959001.32 N 560713.55 49.22 E 5958968.20N 560721.39 58.93 E 5958927.45 N 560731.43 68.69 E 5958881.84 N 560741.56 75.76E 5958834.40N 560749.01 79.93 E 5958782.98N 560753.60 82.97E 5958730.31N 560757.06 Dogleg Rate (°/100fi) 0.00 0.20 0.42 0.11 0.40 0.57 0.53 0.25 0.96 2.82 1.93 1.37 2.56 2.61 3.71 2.71 1.88 2.82 3.88 4.73 3.42 2.76 3.78 1.44 Alaska State Plane 4 Kuparuk tD Vertical Section Comment 0.00 o.oo -0.08 -0.37 -0.69 -1.20 -2.05 -2.62 -2.82 -2.16 0.58 5.43 11.91 20.40 33.72 50.79 72.49 98.O7 126.37 159.28 199.75 245.08 292.31 343.59 396.15 Continued... 13 September, 2000 - 8:42 -2- DrillQuest 2.00.02 RECEIVED NOV ~ 0 2000 Alaska Oil & Gas Cons. ~ Anchorage North Slope Alaska Measured Depth (it) Incl. Azim. Sub-Sea Depth (it) 2348.12 39.020 173.710 2133.34 2442.96 41.140 174.230 2205.90 2537.41 44.300 174.100 2275.28 2632.27 47.390 171.470 2341.36 2726.93 48.590 171.960 2404.71 Sperry-Sun Drilling Services Vertical Depth (it) 2238.64 2311.20 2380.58 2446.66 2510.01 2820.06 52.210 173,130 2464.07 2569.37 2910.60 57.680 172.800 2516.05 2621.35 3004.37 61.130 170.650 2563.77 2669.07 3194.35 67.550 171.500 2646.00 2751.30 3289.27 68.320 171.300 2681.65 2786.95 3384.89 67.910 171,460 2717.30 2822.60 3479.20 66.140 173.710 2754.1! 2859.41 3570,31 66.530 175.350 2790.68 2895.98 3665.74 66.250 175,620 2828.90 2934,20 3758.94 66.870 178.170 2865,98 2971,28 3850.17 66.570 3944.43 67.050 4038.23 66.850 4128,67 65.590 4221.14 65.780 Survey Report for 1D-40 Your Reft API.500292296900 Job No. AKMMO0146, 4315,77 66.740 4413.51 66.130 4508,38 65.510 4600.92 65.470 4695.15 66.920 2902.04 2939.16 2975.89 3012.36 3050.44 3088.54 3127.61 3166.47 3204.86 3242.89 177.730 180.510 180.530 183.590 184.380 184.560 184.200 184.360 185.150 184.860 3007.34 3044.46 3081.19 3117.66 3155.74 3193.84 3232.91 3271.77 3310.16 3348.19 Local Coordinates Northings Eastings (ft) (ft) 458.56 S 88,08 E 519.29 S 94.49 E 583,02 S 101,00 E 650.52 S 109.59 E 720.12 S ' 119.72 E 791.25 S 129.01E 864.78 S 138.09 E 944.64 S 149.73 E 1113.72 S 176.25 E 1200.70 S 189.41 E 1288.43 S 202.71E 1374.52 S 213.92 E 1457.58 S 221.87 E 1544.75 S 228.76 E 1630.13 S 233.38 E 1713.87 S 236.38 E 1800.50 S 237.71E 1886.80 S 236.92 E 1969.50 S 233.96 E 2053.56 S 228.10 E 2139.92 S 221.35 E 2229.25 $ 214.51 E 2315.55 S 208.05 E 2399.46 S' 201.07 E 2485.34 S 193.55E Global Coordinates Northings Eastings (ft) (it) 5958671.01 N 560762.65 E 5958610.34 N 560769.55 E 5958546.66 N 560776.58 E 5958479.24 N 560785.71 E 5958409.72 N 560796.40 E 5958338.66 N 560806.27 E 5958265.21N 560815.94 E 5958185.45 N 560828.23 E 5958016.59 N 560856.11 E 5957929.72 N 560869.96 E 5957842.10 N 5957756.10 N 5957673.11N 5957586.00N 5957500,66 N 560883.97 E 560895.88 E 560904.50 E 560912.09 E 560917.41E 5957416.94 N 5957330.33 N 5957244.02N 5957161.30 N 5957077.20 N 560921.08 E 560923.11E 560923.02 E 560920.72 E 560915.55 E 5956990.79 N 5956901.41N 5956815.O5 N 5956731.09 N 5956645.15 N 560909.49 E 560903.37E 560897.61E 560891.31E 560884.48 E Dogleg Rate (°/lOOft) 3.38 2.26 3.35 3.82 1.32 4.01 6.05 4.17 3.40 0.83 0.46 2.89 1.70 0.39 2.60 0.55 2.76 0.21 3.40 0.81 1.03 0.71 0.67 0.78 1.56 Alaska State Plane 4 Kuparuk 1D Vertical Section Comment 455.28 515.75 579.23 646.39 715.60 786.38 859.56 938.96 1107.04 1193.52 1280.74 1366.40 1449.14 1536.02 1621.19 1704.79 1791.31 1877.60 1960.34 2044.56 2131.10 2220.61 2307.08 2391.18 2477.27 Continued... -3- DrillQuest ZOO.02 13 septembe~ 2000-8:42 'RECEIVED NOV Alaska O~ & 6as Cons. ¢om~ss~on Sperry-Sun Drilling Services Survey Report for 1D-40 Your Ref: API-500292296900 Job No. AKMMO0146, North Slope Alaska Measured Depth (ft) Incl. Azim. Sub-Sea Depth (~t) Vertical Depth (ft) 4789.26 66.190 185.450 3280.34 3385.64 4883.29 67.610 185.320 3317.23 3422.53 4977.68 67.760 184.760 3353.07 3458.37 5071.99 67.720 183.880 3388.79 3494.09 5167.03 67.070 183.900 3425.32 3530.62 5256.50 67.520 184.810 3459.86 3565.16 5351.04 67.280 183.100 3496.19 3601.49 5444,35 66.160 184,250 3533.07 3638.37 5537.39 66.180 184.890 3570.66 3675,96 5634.55 66.800 182.800 3609.42 3714.72 5724.73 66.310 182.170 3645.30 3750.60 5821.10 66.400 183.410 3683.96 3789.26 5912.76 66.940 183.110 3720.26 3825.56 6010.74 66.680 183.510 3758.84 3864.14 6103.54 66.980 183.850 3795.35 3900.65 6195.38 66.320 183,220 3831.75 3937.05 6290.29 65.800 182.960 3870.26 3975.56 6383.30 65.420 183.250 3908.67 4013.97 6478.72 65.150 183,610 3948.57 4053,87 6571:51 66.620 184,450 3986,48 4091.78 6665.13 65.930 183.510 4024.15 4129.45 6759.61 65.340 183.570 4063.12 4168.42 6854.42 66.670 184.270 4101.68 4206.98 6921.50 66.400 184.440 4128.39 4233.69 7106.01 65,940 183.750 4202.94 4308.24 Local Coordinates Northings Eastings (ft) (ft) Global Coordinates Dogleg Northings Eastings Rate (ft) (fi) (°/lOOft) 2571.33 S 185.80 E 5956559.10 N 560877.42 E 2657.44 S 177.68 E 5956472.93 N 560870.00 E 2744.42 S 170.01 E 5956385.89 N 560863.03 E 2831.46 S 163.43 E 5956298.81N 560857.16 E 2918.99 S 157.48 E 5956211.22 N 560851.91E 3001.29 S 151.21 E 5956128.88 N 560846.31 E 3088.36 S 145.19 E 5956041.77 N 560840.99 E 3173.89 S 139.70 E 5955956.19 N 560836.19 E 3258.73 S 132.92 E 5955871.30 N 560830.10 E 3347.62 S 126.95 E 5955782.37N 560824.84 E 3430.27S 123.36 E 5955699.69 N 560821.92 E 3518.44 S 119.07E 5955611.48 N 560818.34 E 3602.47 S 114.28 E 5955527.42 N 560814.23 E 3692.39 S 109.08 E 5955437.46 N 560809.76 E 3777.53 S 103.60 E 5955352.28 N 560804.97 E 3861.68 S 98.40 E 3948.30 S 93.73 E 4032.89 S 89.14 E 4119.41S 83.95 E 4203.89 S 78.00E 4289.39 S 72.05 E 4375.29 S 66.73 E 4461.70 S 60.81E 4523.05 S 56.14 E 4691.40 S 44.08 E 5955268.09N 560800.45 E 5955181.43N 560796.47 E 5955096.82 N 560792.57 E 5955010.25 N 560788.08 E 5954925.73N 560782.81 E 5954840.18 N 560777.55 E 5954754.24N 560772.93 E 5954667.79 N 560767.70E 5954606.40 N 560763.52 E 5954437.96 N 560752.83 E 0.97 1.52 0.57 0.86 0.68 1.06 1.69 1.65 0.63 2.07 0.84 1.18 0.66 0.46 0.47 0.96 0.60 0.50 0.44 1.79 1.18 0.63 1.56 0.46 0.42 Alaska State Plane 4 Kuparuk 1D Vertical Section Comment 2563.48 2649.81 2737.00 2824.21 2911.90 2994.36 3081.58 3167.26 3252.28 3341.32 3424.05 3512.31 3596.46 3686.5O 3771.77 3856.06 3942.79 4027.48 4114.13 4198.76 4284.41 4370.45 4457.01 4518.49 4687.15 Continued... DrillQuest 2.00.02 13 September, 2000 - 8:42 - 4 - RECEIVED NOV 2 '0 ZOO0 Alaska Oil & Gas Cons. Commission Anchorage North Slope Alaska Measured Depth (fi) Incl. Azim. Sub-Sea Depth (ft) 7195.38 65.180 182.890 4239.91 7290.46 65.970 184,830 4279.23 7385.29 66.070 185.470 4317.77 7481.62 65.850 185.060 4357.01 7574.69 67.410 185.550 4393.93 7668.45 67.190 185.140 4430.11 7759.45 66.520 185,780 4465,88 7853.49 65.990 185.700 4503.75 7949.37 67.270 186.340 4541.78 8043.11 67.020 186.300 4578.19 8137.58 66.660 186.240 4615.35 8231.07 67.590 185.590 4651.69 8329.63 67.490 184.610 4689.34 8419.48 66.950 184.050 4724.13 8515.67 66.510 184.360 4762.13 8609.78 66.280 183.900 4799.82 8702.13 65.860 57.380 4855.25 8795.59 67.250 183,740 4910.53 8889.72 68.410 183.480 4946.05 8984.06 68.240 183.360 4980.89 Sperry-Sun Drilling Services Survey Report for 1D-40 Your Ref: AP1-$00292296900 Job No, AKMMO0146, 9076.67 67.650 183.320 5015.66 9172.24 67.150 183.550 5052.39 9261.13 66,560 183,400 5087.33 9355.38 66.020 184.140 5125.23 9449.18 65,650 183.880 5163.63 Vertical Local Coordinates Global Coordinates Depth Northings Eastings Northings Eastings (ft) (ft) (ft) (ft) (ft) 4345.21 4772.63 S 39.37 E 5954356.70 N 560748.77 E 4384.53 4858.99 S 33.54 E 5954270.29 N 560743.64 E 4423.07 4945.29 S 25.76 E 5954183.93 N 560736.55 E 4462.31 5032.89 S 17.69 E 5954096.27 N 560729.19 E 4499.23 5117.96 $ 9.79 E 5954011.14 N 560721.98 E 4535.41 5204.08 S 1.73 E 5953924.96 N 560714.61 E 4571.18 5287.37 S 6.23W 5953841.60 N 560707.33 E 4609.05 5373.02S 14.84W 5953755.89 N 560699.41E 4647.08 5460.55 S 24.07W 5953668.29 N 560690.88 E 4683.49 5546.40 S 33.58W 5953582.36 N 560682.07 E 4720.65 5632.74S 43.07W 5953495.95 N 560673.28 E 4756.99 5718.42 S 51.94W 5953410.20 N 560665.10 E 4794.64 5809.14 S 60.04W 5953319.42 N 560657.73 E 4829.43 5891.74S 66.30W 5953236.76 N 560652.14 E 4867.43 5979.87 S 72.78W 5953148.59 N 560646.38 E 4905.12 6065.88 S 78;99W 5953062.53 N 560640.86 E 4960.55 6094.68 S 30.72W 5953034.12 N 560689.35 E 5015.83 6124.44 S 18.50 E 5953004.76 N 560738.81E 5051.35 6211.43 $ 13.01 E 5952917.72 N 560734.03 E 5086.19 6298.95 S 7.78 E 5952830.17 N 560729.50 E 5120.96 6384.63 S 2.78 E 5952744.45 N 560725.19 E 5157.69 6472.71S 2.51W 5952656.34N 560720.62 E 5192.63 6554.29 S 7.46W 5952574.71 N 560716.32 E 5230.53 6640.40 S 13.14W 5952488.56 N 560711.35 E 5268.93 6725.77 S 19.12W 5952403.15 N 560706.05 E Dogleg Rate (°/lOOft) 1.22 2.04 0.63 0.45 1.74 0.47 0.98 0.57 1.47 0.27 0.39 1.18 0.92 0.83 0.54 0.51 118.50 117.62 1.26 0.22 0.64 0.57 0.68 0.92 0.47 Alaska State Plane 4 Kuparuk 1D Vertical Section Comment 4768.49 4855.00 4941.51 5029.34 5114.63 5200.97 5284.49 5370.38 5458.17 5544.31 5630.92 5716.85 5807.79 5890.56 5978.86 6o65.03 6092.17 6120.22 6207.35 6294.99 6380.80 6469.00 6550.71 6636.96 6722.49 Continued... DrillQuest 2.00,02 13 September, 2000 - 8:42 - 5 - Sperry-Sun Drilling Services Survey Report for 1D-40 Your Ref: API.500292296900 Job No. AKMMO0146, North Slope Alaska Measured .Depth (~t) Incl. Azim. Sub*Sea Depth (~t) Vertical Local Coordinates Global Coordinates Depth Northings Eastings Northings Easfings (ft) (ft) (fi) (ft) (ft) 9548.27 65.180 183.790 5204.85 5310.15 9644.17 66.590 184.410 5244.03 5349.33 9735.54 66.760 184.290 5280.21 5385,51 9828.02 66.620 184.520 5316.81 5422.11 9923.20 66.130 184.690 5354.95 5460,25 10017.86 65.740 183.690 5393.55 5498.85 10111.46 65.250 183.950 5432.37 5537.67 10206.31 66.010 184.310 5471.51 5576,81 10298.90 65.840 184.490 5509.28 5614.58 10393.73 66.680 184.360 5547.46 5652.76 10487,78 66.540 183.930 5584.79 5690.09 10583.66 66,280 183,640 5623,17 5728.47 10679.29 66.030 183.570 5661.82 5767.12 10769.24 65.670 184.460 5698.63 5803.93 10866.48 65.440 184.690 5738.87 5844.17 10957.57 64.950 183.370 5777.08 5882.38 11052.08 65.440 184.400 5816.73 5922.03 11143.60 66.780 186.660 5853.80 5959.10 11241.94 66.620 186.460 5892.70 5998.00 11304.46 66.190 186.760 5917.72 6023.02 11331.70 66,100 186.150 5928.74 6034.04 11426.93 68.090 185.470 5965.80 6071.10 11523.53 67.490 185.370 6002.32 6107.62 11658.14 67.480 183.910 6053.86 6159.16 11753.09 67.220 183.500 6090.43 6195.73 6815.67 S 25.15W 6902.98 S 31.41W 6986.64S 37.77W 7071.32S 44.30W 7158.24S 51.30W 7244.44 S 57.61W 7329.42 S 63.29W 7415.59 S 69.51W 7499.88 $ 75.99W 7586.42S 82.69W 7672.52 S 88.93W 7760.19 S 94.73W 7847.49 S 100.23W 7929.36 S 105.98W 8017.60 S 113.04W 8100.08 S' 118.85W 8185.68 S 124.66W 8268.95 S 132.74W 8358.68 S 143.06W 8415.60 S 149.65W 8440.35 S 152.45 W 8527.62 S 161.33 W 8616.65 S 169.77 W 8740.59 S 179.83 W 8828.03 S 185.50 W 5952313.20 N 560700.75 E 5952225.85 N 560695.19 E 5952142.14 N 560689.51E 5952057.41N 560683.67 E 5951970.43 N 560677.37E 5951884.18 N 560671.75E 5951799.16 N 560666.76 E 5951712.94N 560661.23 E 5951628.60N 560655.43 E 5951542.01N 560649.43 E 5951455.86 N 560643.89 E 5951368.14 N 560638.79 E 5951280.81N 560634.00 E 5951198.89 N 560628.91E 5951110.59 N 560622.57 E 5951028.07 N 560617.42 E 5950942.44 N 560612.30 E 5950859.09 N 560604.90 E 5950769.28 N 560595.30 E , 5950712.32N 560589.17 E 5950687.54 N 560586.57 E 5950600.21N 560578.40 E 5950511.11N 560570.67E 5950387.10 N 560561.61E 5950299.61N 560556.65 E Dogleg Rate (°/lOOft) 0.48 1.58 0.22 0.27 0.54 1.05 0.58 0.87 0.26 0.89 0.45 0.39 0.27 0.99 0.32 1.42 1.12 2.69 0.25 0.82 2.07 2.19 0.63 1.00 0.48 Alaska State Plane 4 Kuparuk 1D Vertical Section Comment 6812.55 69o0.01 6983.84 7068.70 7155.8o 7242.17 7327.29 7413.63 7498.09 7584.81 7671.07 7758.89 7846.33 7928.35 8016.78 8099.41 8185.15 8268.66 8358.69 8415.79 8440.63 8528.14 8617.41 8741.62 8829.21 Continued... 13 September, 2000,8:42 - 6- DrillQuest 2.00.02 Sperry-Sun Drilling Services Survey Report for 1D-40 Your Ref: API-500292296900 Job No. AKMMO0146, North Slope Alaska Measured Sub-Sea Vertical Local Coordinates Depth Incl. Azim. Depth Depth Northings Easflngs (~) (~) (~) (~) (~) 11850.06 67.480 183.500 6127.77 6233.07 8917.35 S 190.96W 11946.27 67.670 183.900 6164.48 6269.78 9006.10 S 196.70W 12042.82 67,830 182.980 6201,03 6306.33 9095.30 S 202.06W 12138.83 67.410 182,830 6237.59 6342.89 9183.97 S 206.56W 12155.61 67.220 182.280 6244.06 6349.36 9199.43 S 207.25W 12225.00 67.220 182.280 6270.93 6376.23 9263.36 S 209.79W Global Coordinates Dogleg Northings Eastings Rate (fi) (ft) (°/lOOft) 5950210.24 N 560551.91E 5950121.45 N 560546.89 E 5950032.21N 560542.25 E 5949943.52 N 560538.46 E 5949928.04N 560537.90 E 5949864.10 N 560535.87 E All data is in feet unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to 1 D-M WPs. Northings and Eastings are relative to 1D-M WPs. The Dogleg Severity is in Degrees per 100 feet. Vertical Section is from 1D-M WPs and calculated along an Azimuth of 181.960° (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 12225.00ft., The Bottom Hole Displacement is 9265.73ft., in the Direction of 181.2970 (True). 0.27 0.43 o.90 0.46 3.23 0.00 Alaska State Plane 4 Kuparuk 1D Vertical Section Comment 8918.67 9007.56 9096.89 9185.66 9201.14 9265.12 Projected Survey Continued... 13 September, 2000 - 8:42 -7- DrillQuest 2.00.02 Sperry-Sun Drilling Services Survey Report for 1D-40 Your Ref: API-500292296900 Job No. AKMMO0146, North Slope Alaska Alaska State Plane 4 Kuparuk 1D Comments Measured Depth (ft) 12225,00 Station Coordinates TVD Northings Eastings (h) (ft) (it) 6376.23 9263.36 S 209.79 W Comment · Projected Survey 'Survey tool program From To Measured Vertical Measured Depth Depth Depth (~t) (/t) (/t) 0.00 0.00 12225.00 Vertical Depth (ft) 6376.23 Survey Tool Description AK-6 BP_IFR-AK DrillQuest 2.00.02 13 September, 2000 - 8:42 - 8 - 13-Sep-00 AOGCC Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 1D-40 MWD Tool Type (Not Definitive) Re: Distribution of Survey Data for Well 1D-40 MWD Dear Lori Taylor: Enclosed are two survey hard copies. Tie-on Survey: Window / Kickoff Survey Projected Survey: 0.00' MD 'MD 12,225.00' MD (if applicable) Please call me at 273-3545 if you have any questions or concerns. Regards, Kenneth W. Allen Survey Manager Attachment(s) RECEIVED SEP 19 2.000 Anchorage 13-Sep-00 AOGCC Lori Taylor 3001 Pomupine Drive Anchorage, AK 99501 1D-40 MWD+IIFR Tool Type (Definitive) Re: Distribution of Survey Data for Well 1D-40 Dear Lori Taylor: Enclosed are two survey hard copies. Tie-on Survey: Window / Kickoff Survey Projected Survey: 0.00' MD 'MD 12,225.00' MD RECEIVED SEP 19 .000 AI~ Oil & Gas Cons. Commission Anchorage (if applicable) Please call me at 273-3545 if you have any questions or concerns. Regards, Kenneth W. Allen Survey Manager Attachment(s) 8-1~- 0 ';11:21A1~1 ; PHILLIPS Al( INC~ 907 276 7542;g 2/ 7 PHILLIPS Alaska, Inc. ^ Subsidiary of PHILLIP.~ PETFIOI F!..IM COMPANY September 12, 2000 Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 (907) 279-1433 Re: Application for Suspension of Drilling Operations; KRU 1D-40 Surface Location: Target Location: Bottom Hole Loca§on: 537' FNL, 421' FEL, Se(; 23, T11N, R10E, UM 848' FSI., 742' FEL, Sec. 26, T11 N, R10E, UM 571' FSL, 764' FEL, Sec. 26, T11N, R10E, UM Dear Sirs: Phillips Alaska, Inc. hereby applies for permission to perform a temporary shutdown of drill and complete operations on KRU well 1D-40 (APD# 200-119). After drilling to the target specified in the original APD and reviewing the LWD logs obtained across the Kuparuk producing interval, it was found that the Kuparuk sands in this area exhibited virtually no porosity, making the well unsuitable for completion as an injector. In addition, as a result of the extremely poor porosity response obtained on 1D-40, the reservoir quality in the area of the planned contingency sidetrack location was alSo called into question. This well has been suspended as shown in the attached wellbore schematic by laying 15.8 ppg . 'Class G' cement across the entire open hole interval below the 7" intermediate casing shoe and running a 3-1/2" tubing kill string to 2150' MD. The competency and location of the top of the plug was mechanically confirmed at 11137' by tagging the cement with the BHA and then applying 20 klbs of sustained downweight. A 5000 psi tree has been installed on the well and a back pressure valve (BPV) has been set in the wellhead. The well has been freeze protected by displacing with diesel to below the base of the permafrost. Phillips Alaska is requesting this temporary shutdown in order to allow time to properly identify an alternative sidetrack target and prepare the appropriate directional plans and permits. Current rig scheduling plans call for sidetrack and complete operations on well 1D-40 to resume sometime around January 15, 2001. This is towards the end of the current KRU EBA drilling program on 1D pad. If you have any questions or require further information, please contact Tom Brockway at (907) 263-4135 or James Trantham at (907) 265-6434. Thomas A. Brockway Operations Drilling Engineer - Phillips Alaska, Inc. ECE VED SEP 1 5 ?.000 Gas C0~s. C0mmiss'~ STATE OF ALASKA (' ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of request: Abandon _ Suspend _ Operational shutdown _X Re-enter suspended well _ Alter casing _ Repair well _ Plugging _ Time extension _ Stimulate _ Change approved program _ Pull tubing _ Variance _ Perforate _ Other_ 2. Name of Operator Phillips Alaska, Inc. 3. Address P. O. Box 100360 Anchorage, AK 99510-0360 5. Type of Well: Development __ Exploratory _ Stratigraphic _ Service __X 4. Location of well at surface 537' FNL, 421' FEL, Sec. 23, T11N, R10E, UM (ASP 560671,5959099) At top of productive interval 848' FSL, 742' FEL, Sec. 26, T11N, R10E, UM (per APD) ^' ORIGINAL At total depth 571' FSL, 764' FEL, Sec. 26, T11 N, R10E, UM (per APD) 6. Datum elevation (DF or KB feet) RKB 35' feet 7. Unit or Property name Kuparuk River Unit 8. Well number 1 D-40 9. Permit number / approval number 200-119 10. APl number 50-029-22969-00 11. Field / Pool Kuparuk River Field / Kuparuk River Pool 12. Present well condition summary Total depth: measured 12225' feet Plugs (measured) true vertical 6338' feet Effective depth: measured 12225' feet Junk (measured) true vertical 6338' feet Casing Length Size Cemented Conductor 102' 20" 230 sx ASl Surface 6943' 9.625" 818 sx AS III LW, 477 sx LiteCRETE Production 11558' 7" 180 sx Class G Liner Plug #1' 11610'-12225' Plug #2:11137'-11610' Measured Depth True vertical Depth 137' 137' 6978' 4250' 11593' 6098' Perforation depth: measured not perforated true vertical Tubing (size, grade, and measured depth 3.5" tubing kill string to 2150' Packers & SSSV (type & measured depth) N/A RECEIVED SEP 0 7 000 Alaska 0it & Gas Cons, Cemm~ 13. Attachments Description summary of proposal _ Detailed operations program m BOP sketch __ Refer to attached morning drilling report for LOT test, surface cement details and casing detail sheets, schematic 14. Estimated date for commencing operation August 31,2000 16. If proposal was verbally approved 8/31/00 Oil__ Name of approver Blair Wondzell Date approved Service wX 17. I hereby~certify that the foregoing is true and correct to the best of my knowledge. Signed ~ O~~, ~ ~ Title: Drilling Engineering Supervisor J. 'Trantham 15. Status of well classification as: FOR COMMISSION USE ONLY Gas __ Suspended __ Questions? Call Tom Brockway 265-4135 Prepared by Sharon AIIsup-Drake Conditions of approval: Notify Commi~ion so representative may witness Plug integrity __~ BOP Test _ Location clearance __ Mechanical Integrity Test__ Subsequent form required 10- Approval Approved by order of the Commission ,.,.-,~{:~,¢¢,~L SIGNED BY Taylor Seamount Commissioner Date Form 10-403 Rev 06/15/88 · SUBMIT IN TRIPLICATE KRU 1D-40 Inject( Plug and Suspend Schematic PHIfL[.IPS Alaska, Inc. A Subsidiary of PHILLIPS PETROLEUM COMPANY 20" 91.5# H-40 137' MD Depths are based on Nabors 16E RKB Surface csg. 9-5/8" 40.0# L-80 BTCM (+/- 6978' MD / 4250' TVD) Intermediate csg. 7" 26.0# L-80 BTCM (+/- 11593' MD / 6098' TVD) 6-1/8" Open Hole TD (+/- 12225' MD / 6338' TVD) 3-1/2' FMC Gen V Tubing Hanger, 3-1/2' L-80 EUE8RD pin down 3-1/2" 9.3# L-80 EUE8RD tubing kill string 2150' MD / 2080' TVD to surface RECEIVED SEP 0 7 ;~000 Alaska Oii & Gas Cons. Commission Cement Plug #2 15.8 ppg Class 'G' w/GasBIok (11610' MD to 11137' MD) Cement Plug #1 15.8 ppg Class 'G' w/GasBIok (12225' MDto 11610' MD) TAB, 8/1/00, vl SENT BY: 9-13- 0 ';ll:21AM ; PHILLIPS AK INC~ 907 276 7542;# 4/ 7 Date: 09/13/00 ARCO ALASKA INC. WELL SUMMARY REPORT Paqe: 1 ___ WELL:iD-40 STATE:ALASKA COUNTY: NORTH SLOPE EAST FIELD: KUPARUK RIVER D'NIT SPUD:08/13/00 START COMP: EIG:NABORS BLOCK: FINAL: WI: 0% SECURITY:0 API NUMBER: 50-029-22969-00 08/13/00 (D1) TD/TVD: 431/0 SUPV: MW: 9.3 VISC: 235 PV/YP: 28/47 (431) P/U NEW SPERRY SUN MWD APIWL: 7.2 Move from 1D-30 to 1D-40. Accept rig @ 1000 hrs. 8/13/00. NU diverter system, Held pre-,spud meeting. Function test 20" diverter ~y~em. Performed ~hallow gas k~ck drill, RIH, tag bttm of conductor ~ 137', Spud in @ 1900 hfs, Drill 12.25" hole from 137' to 431' 08/14/00 (D2) MW: 9.6 VISC: 255 PV/YP: 42/57 APIWL: 6.4 TD/TVD: 1847/1819 (1416) DRILLING 12 1/4" ~ 2385 SUPV:DON MICKE¥ Attex~t to ~et MWD ~uz'v~y, no good, Replace O ring for transducer on s~and D~D~- Dri].] 12.25" hoq~ f'~om ~31' tO 469', Attempt MWD survey, still having problem with tool, circ. Pull out_ Replace with new MWD. Drill 1.2.25" hole from 469'., 1847'. 08/15/00 (D3) MW: 9.5 vise: 235 PV/YP: 39/57 APIWL: 6.2 TD/TVD: 3255/2773 (1408) DRILLING 12 1/4" HOLE @ 3'732 SUPV:DON MICKEY Drill 12.25" hole from 1847' to 3255' Pump hi. v~.s, hi weight pill, circ up, Wiper trip from 3255' to 906', hole swabbing puanped out trom 2972' to 1564'. RIH. No problems, Circulate bottoms up. 08/16/00 (D4) MW: 9.6 VISC: 205 PV/YP: 37/53 APIWL: 5.8 TD/TVD: 4378/3193 (1123) DRILLIN~ 12 1/4" HOLE @ 4865' SUPV:DON ~ICKEY Drill %~,25" hole from 3255' to 4378'. Pump sweep and circ hole clean for bit trip, Trip for bit. Change bit. RI~ to 4378', no problems, circulate bottoms up. 08/17/00 (DS) 1~: 9.8 VISC: 202 PV/YP: 32/53 APIWL: 5,5 TD/TVD: 5975/3850 (3.597) DRILLING 12 1/4" HOLE @ 6250' SUPV:DON MICKEY Drill 12.25" hole from ~378' to 5975', Pump sweep, circ hole clean, monitor well, Wiper trip from 5975' to 4378', no problems, SE~IT BY: 9-13- 0 :ll:21A~l ; ( PHILLIPS AK INC~ 907 276 7542:# $/ 7 Date: 09/13/00 ARCO ALASKA INC. WELL SUP~ARY REPORT Page: 2 08/18/00 (D6) MW: 9.7 VISC: 175 PV/YP: 28/46 APIWL: 5.0 TD/TVD: 6988/4260 (1013) CIRCULATE AND CONDITION HOLE FOR 9 5/8" CSG SUPV:DON MICKEY Rill from 4378' to 5975', no problems. Circ bttms up, Drill 12.25" hole from 5975' to 6020'. Replace swab in %2 pump, DriLl 12.25" hole from 6020' to 6988'. Pumt~ sweep. Circ hole clean. Wiper trip from 6988' to 906'. No problems. RIH from 906' 08/19/00 (D7) MW: 9.7 VISC: 180 PV/YP: 31/56 APIWL: 5.0 TD/TVD: 6988/4260 ( 0) CEMENTING 9 5/8" CASING SUPV:DON MICKEY Continue RIH to 6988'. Circulate and condition mud and hole. Pump dry job. PJSM, R/U to run 9-5/8" casing. PJSM, Ran 9-5/8" casing. Break clrc ~ 2300' ~ 4300', good returns. 08/20/00 (DS) MW: 9.6 VISC: 44 PV/YP: 17/15 APIWL: 6.6 TD/TVD: 6988/4260 ( 0) RIH W/ 8 1/2" BIT & BHA SUPV:DON MICKEY Finish running 9-5/8" casing w/shoe ~ 6978', FC @ 6897', Circulate and condition mud for cement job. Held PJSM, Cement 9-5/8" casing. N/D diverter system, N/U BOPE and test. 08/21/00 TD/TVD: 6988/4260 ( SUPV:DON MICKEY MW: 9.3 VISC: 39 PV/YP: 11/ 9 0) RIH W/ PACKER TO TEST CSG APIWL: 10.2 RIH w/8.5" BHA. Tag top Of cement @ 6876'. Circulate bottoms up. P~ssure test 9-5/8"casing. C/O soft c~ment to FO, circulate bottoms up, soft cement ~ shakers, circ hole clean. Retest 9-5/8" casing. Drill FC and soft cement to shoe, drill out shoe & c/o rat hole to 6988'. Circ hole clean. Pull out w/8.5" bit & BHA to run test packer. 08/22/00 (D10) FIN: 9.5 VISC: 46 PV/YP: 11/12 APIWL: 11.0 TD/TVD: 7008/4268 (~0) CIRC & COND FOR FWD BASELINE TEST, 7365' DEPTH SUPV~FRED HERBERT POO~. R!H w/Baker retrieve-o-marie to 6950'. S~t packer and test casing to 3000 psi. POOH w/packer, RIH w/drilling assy. Drilling 8.5" hole from 6988' to 7008' Circ and cond w/LSND mud. 08123/00 (Dll) TD/TVD: 8900/5019 (1892) WIPER TRIP TO SHOE. DEPTH 9279' SUPV:FRED HERBERT Displaca w/LSND mud. PJSM. Drilling 8.5" hol~ from 7008' to 7365'. Circ sweep to clean hole for PWD baseline test. P~rform test. Drilling ~.5" hola from 7365' to 8900'. 'SENT BY: 9-13- 0';H:22AM ; PHILLIPS AK INC+ 907 276 7842;# 6/ 7 Date: 09/13/00 ARCO ALASKA INC. WELL SUMMARY REPORT Page: 3 08/24/00 (D12) MW: 9.3 VISC: 48 PV/YP: 18/23 APIWL: 4.6 TD/TVD;10403/5624 (1503) DRILLING AIIEAD @ 10948' SUPV:FRED HERBERT Drilling 8,5" hole from 8900' to 9247' Circ weighted sweep around, monitor well. Pump slug & POOH to shoe. No problems_ RIM to 9247' Circ w~i~hUed sweep ilround_ Drilling 8.5TM hole from 92~7' to 10403' 08/25/00 (D13} MW: 10_0 VI~C: 53 PV/YP: 18/20 TD/TVD:l1390/6021 ( 987) RIH TO BOTTOM AFTER LOT SUPV:FRED HERBERT APIWL: 3.6 Drilling 8.5" hole from 10403' to 11390', Pump densified sweep around, POOH w/ 10 stds. RIH go bottom w/ no problems, Circ bttms up. Small amount of gas on bttms up, Mud weight cut to 9,4 ppg, Con5inue circ& raise mud weighg to 10 ppg. POOH w/15 stds, No tight spots, Monitor well (static), RIM, Circ brims up, No ~as cut mud. on bttms up. 08/26/00 (D14) TD/TVD:l1390/6021 ( SUPV:FRED HERBERT MW: 10,1 VISC: 48 PV/YP: 17/13 APIWL: 3.~ 0) L/D BI~. NOTE; RIG ON HIGH LINE POWER @ 15:00 }{RS, POOH to sho~ @ 6978', Monitor well, Circ out dry job for LOT, Perform deep LOT, 12,6 EMW. RIH to bttm. Circ bttms up. Drilling 8.5" hole from 11390' to 11605'. Circ d~nsifi~d sweep, monitor w~ll. POOH w/ ~0 stds, RIH to bttm. Pump sweep, Circ and cend for casing. Monitor well. Pump dry job, POOH, 08/27/00 (D15} MW: 10,0 VISC: 45 PV/¥P: 18/~,.4 APIWb: 3,5 TD/TVD:l1390/6021 ( 0) INSTALL PACK OFF SUPV:FRED HERBERT POOH to run 7" casing, PJSM, Run 7" casing. PJSM, Run casin~_ Cizc bttm~ up @ 9430', Run 7- casing. C~,rc and cond for cement job. 08/28/00 (D16} I~W: 11.2 VISC: 55 PV/YP: 20/19 APIWL: 3.2 TD/TVD:l1390/6021 ( 0) RIH W/ 6 ,125" DRILLING ASSY. P/U 4" DP SUPV:FRED ~ERBERT Uirc and cond for cement job. PJSM. Pump cement, Bump plu~. Ch~ck float equipment (OK), Install packof~ and test to 5000, Test BOPE to 250/5000. 08/29/00 (D17) MW: 11,3 VISC: 58 PV/'YP: 22/21 APIWL: 3.4 TD/TVD:l1728/6150 ( 338} DRILLING AHEAD SUPV:FRED HERBERT PJSM, KIII, Tag cement stringers @ 11480', Circ out cement cont, mud, Test 7' casin~ to 3500 psi, Drill out cement, float equipment and 20' new hole. Pump sweep. Perform FIT to 16 EMW. drilling 6,125" hole from 11625' to 11728'. 8-13- 0";1'1'-'22A.~1 ; PHILLIPS AK INC~ 007 276 7.542 ;/t 7/ 7 Date: 09/13/00 ARCO ALASKA INC. WELL SUMMARY REPORT Page: 4 08/30/00 (D18) MW: 11.5 VISC: 63 PV/YP: 33/32 TD/TVD:12225/6338 (497) RE~ LOGS SUPV:FRED HERBERT APIWL: 4_9 Circ bttms up, Perform PWD baseline test, Drilling 6.125" hole from 11728' to 11924', Circ out gas cut mud, Circ bttms up for ECD's, Drilling 6,125" hole from 11924' to 12225', Circ and cond mud, Circ densified sweep around, Raise mud weight to 11,5 ppg, Monitor well Pump out to shoe. RIH to bttm, No problems, Circ & cond mud for liner, NO gas cut mud on bottom~ up. Monitor w~ll (OK). 08/31/00 (D19) TD/TVD:12225/6338 SUPV:FRED HERBERT MW: 11,5 VISC: 52 PV/YP: 22/30 0) CIRC, W,O,C, APIWL: 6,8 Monitor well. POOH. PJSM. Rig maintenance and cleaning, RIH to plug well, Tag bttm@ 12225', circ and condition mud for cement plug. PJSM, Lay cemen= plug, POOH slow to 11329'. Circ out cement cont, mud, No cement back to surface, RIH tag cement @ 11610', Circ out cement and cement contaminated mud, Cond for 2nd plug, 09/01/00 (D20) TD/TVD=12225/633g ( SUPV:FRED HERBERT MW: 0,0 VISC: 52 PV/YP: 0/ 0 0) NIBBLE DOWN. APIWL: 0,0 Lay cement plug, Pump cement, POOIt l0 stds (slow) Ko 10625', WOC, Circ & cond, nmd, RIH tau cement ~ 11137', Set down firm cement_ Circ out contaminated mud, P00M, Rig up tO run %ubing, PJSM, Run 3,5" tubing, 09/02/00 (D21) MW: 0,0 VISC: 52 PV/YP: 0/ 0 APIWL: 0,0 TD/TVD:12225/6338 ( 0) RIG RELEASED @ 0800 ~RS F/ 1D-40 SUPV:FRED HERBERT Run 3,5" tubing kill string to 2150', Freeze protect, ND BOPE stack, Rig released from 1D-40 ~ 0800 hrs, to move to 1D-36, MEMORANDUM TO: Dan Seamount Commissioner THRU: Blair Wondzell P.I. Supervisor FROM: John CdsP~' ,J ~[-,,,~ (~. Petroleum Inspector State of Alaska Alaska Oil and Gas Conservation Commission DATE: 08/28/2000 SUBJECT: Blowout Preventer Test Nabors 16E Phillips Alaska Inc. 1D Pad KRU 1D-40 200-119 Kuparuk River Field NON- CONFIDENTIAL Operator Rep.: Fred Herbert Contractor Rep.' Jimmy Greco Op. phone: 659-7562 Rig phone: 659-7075 Op. E-Mail: Rig E-Mail: Test Pressures MISC. INSPECTIONS: P/F Location Gen.: Good Housekeeping: Good PTD On Location Yes Standing Order: Yes Rams: 5000 Annular: 3500 Choke: 5000 TEST DATA FLOOR VALVES: P/F Quantity P/F Sign: Yes Upper Kelly 1 P Rig cond: Good Lower Kelly 1 P Hazard: Yes . Ball Type 1 P Inside BOP 1 P BOP STACK: Quantity Size P/F Annular Preventer 1 13 5/8" P Pipe Rams 1 3 1/2X6" P Lower Pipe Rams 1 4" P Blind Rams 1 13 5~8" P Choke Ln. Valves 1 4" P HCR Valves 2 4" P Kill Line Valves 1 4" P Check Valve CHOKE MANIFOLD: Quantity P/F No. Valves 16 P Man. Chokes 1 Functioned Hyd. Chokes 1 Functioned MUD SYSTEM: Visual Alarm Trip Tank Yes Yes Pit Level Indicators Yes Yes Flow Indicator Yes Yes Meth Gas Detector Tested Tested H2S Gas Detector Tested Tested ACCU M ULATOR SYSTEM: Time/Psi P/F System Pressure 3000 After Closure 1500 200 psi Attained 22 sec. Full Pressure 2 min. 45 sec. Blind Covers (All Stations): Yes N2 Bottles (avg): 6 btls.2100 ave. Test's Details I traveled to Phillip's Kuparuk River Field to witness the weekly BOP test on Nabors 16E on well 1D-40. Testing vent well with no BOP equipment failures. The isolation valve on the test pump had to be replaced. Total Test Time: 6.5 hrs. Number of failures: 0 cc'. Attatchments: _0 V03gr3h2.xls 8/30/00 ALASI~A OIL AND GAS CONSERVATION COPl~IISSION James Trantham Drilling engineering Supervisor Phillips Alaska, Inc. P O Box 100360 Anchorage, AK 99510-0360 TONY KNOWLES, GOVERNOR 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 Kuparuk River Unit 1D-40 Phillips Alaska, Inc. Permit No: 200-119 Sur. Loc. 537'FNL, 421'FEL, Sec. 23, T11N, R10E, UM Btmhole Loc. 571'FSL, 764'FEL, Sec. 26, T11N, R10E, UM Dear Mr. Trantham: Enclosed is the approved application for permit to drill the above referenced well. The permit to drill does not exempt .you from obtaining additional permits required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permitting determinations are made. Please note that any disposal of fluids generated from this drilling operation which are pumped down the surface/production casing annulus of a well approved for annular disposal on Drill Site 1D must comply with the requirements and limitations of 20 AAC 25.080. Approval of this permit to drill does not authorize disposal of drilling waste in a volume greater than 35,000 barrels through the annular space of a single well or to use that well for disposal purposes fOr a period longer than one year. The blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25.035; and the mechanical integrity (MI) of the injection wells must be demonstrated under 20 AAC 25.412 and 20 AAC 25.030(g)(3). Sufficient notice (approximately 24 hours) of the MI test before operation, and of the BOPE test performed before drilling below the surface casing shoe, must be given so that a representative of the Commission may witness the tests. Notice may be given by contacting the Commission petroleum field inspector on the North Slope pager at 659-3607. Daniel T. Seamount, Jr. Commissioner BY ORDER OF THE COMMISSION 'DATED this ~ day of August, 2000 dlf/Enclosures DePartment of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. Re: Doghouse Hazards N,,te 1D-40 (PTD 200-119) Subject: Re: Doghouse Hazards Note 1D-40 (PTD 200-119) Date: Fri, 04 Aug 2000 13:30:26 -0800 From: Tom Maunder <tom_maunder@admin.state.ak. us> To: Thomas A Brockway <tbrockw@ppco.com> I don't believe I'll need anything else. Thanks for you reply. Tom Thomas A Brockway wrote: As per our conversation, I mil revise the well plan to include a 3500 psi pressure test on the 7" casing - do you need anything else from me for your records on this? I also forwarded your request for a Doghouse Hazards Note on to James Trantham who is going to put it on the agenda for the ne~t Drilling Team Leaders 'meeting. With everyone out of the office today, we would like to make sure that anything we implement is SOP for all of the Kuparuk rigs. Either James or myself will follow up with you on this. Thanks, Tom Brockway Operations Drilling Engineer 263-4135 tbrockw@ppco, com Tom Maunder <tom_maunder@admin. state, ak. us> on 08/04/2000 11:34:24 AM To: Thomas A Brockway/PPCO@Phillips cc: Subject: Doghouse Hazards Note 1D-40 (PTD 200-119) Tom, I have finished reviewing the subject permit application. There are a couple of items !,; would like you to address. Since you indicated it is likely that you will topset, the listed 7" casing test pressure is less than the calculated MASP. When we discussed this you indicated you would likely change the test pressure to 3500 psi. The other item is a Doghouse Hazards note. Based on the investigations of the blowouts at Endicott and Cirque, a common thread was that those on the rig were not aware of the potential to drill into gas You do have that information in the drilling area risks section, but that is several pages into the packet. Blair has repeatedly indicated to me that he desires to see a one page "note" that can be prominently posted in the doghouse. Below is an example I have for the other side of the world. Bill Lloyd might have an example. He and I had emailed each other on the subject. Have a look at it and get back to me. I veil plan to have the permit on Blair's desk on Monday which should allow review by the commissioners later that day or Tuesday. 1 of 2 8/7/00 12:26 PM Re: Doghouse Hazards Note 1D-.40 (PTD 200-119) Other Tom POST THIS NOTICE IN THE DOGHOUSE High formation pressures are present both in and sometimes above the Kuparuk reservoir ' zone. Expected formation pressure below the permafrost is 9.0 ppg EMVV. Mud weights in excess of 10. 4 ppg can be expected. Hydrates have occasionally been encountered at XX pad. No other shallow gas has been reported. Lost circulation is unlike/y, however lost circulation potential increases when crossing faults. Stuck pipe is possible if the HRZ shale gives problems. XX pad is not a designated H2S pad. Consult the XX pad data sheet (if applicable) and well plan for more information. (See attached file: tom_maunder, vcf) Tom Maunder <tom maunder~admin.state.ak, us> Petroleum Engineer Alaska Oil and Gas Conservation Commission 2 of 2 8/7/00 12:26 PM STATE OF ALASKA( ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 AAC 25.005 la. Type ofwork: '~)'ri'll [~] Redrill r--] "1 ...... ~.b. Type ofwell. Exploratory r-] Stratigraphic Test g] I~;;vel0pment Oil [~ '" Re-ently D Deepen r-~ I Service r~ Development Gas [--] Single Zone r~ Multiple Zone r-] 2. Name of Operator 5. Datum elevation (DF or KB) 10. Field and Pool Phillips Alaska, Inc. RKB 35 feet 3. Address 6. Property Designation ;7_.~,~-~ ~, Kuparuk River Field P.O. Box 100360 Anchorage, AK 99510-0360 ADL 25661 ALK 471/'~ Kuparuk River Pool 4. Location of well at surface 7. Unit or property Name 11. Type Bond (see 2O AAC 25.0251) 537' FNL, 421' FEL, Sec. 23, T11 N, R10E, UM Kuparuk River Unit Statewide At top of productive interval 8. Well number Number 848' FSL, 742' FEL, Sec. 26, T11 N, R10E, UM 1D-40 #U-630610 At total depth 9. Approximate spud date Amount 571' FSL, 764' FEL, Sec. 26, T11 N, R10E, UM August 7, 2000 $200,000 12. Distance to_nearest property line I 13. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and TVD) ~J"(~¢~/~/~4-~ TD feet~l 1D-38 28.8' @ 520' feet 2560 12314 ' MD/6383'TVD · 16. To be completed for deviated wells 17. Anticipated pressure (see 20 AAC 25.035 (e)(2)) Kickoff depth: 850 MD Maximum hole angle 66.5° Maximum surface 3379 psig At total depth (TVD) 4067 psig 18. Casing program Settin,cj Depth size Specifications Top Bottom Quantit~ of Cement Hole Casinc, I Wei~lht Grade Coupling Len~lth MD TVD MD TVD (include sta~le data) 30" 20" 91.5# H-40 Weld 85' 35' 35' 120' 120' 230 sx ASI 12.25" 9.625" 40# L-80 BTCM 6924' 35' 35' 6959' 4244' 760 sx AS III & 750 sx LiteCrete 8.5" 7" 26# L-80 BTCM 11526' 35' 35' 11561' 6082' 180 sx Class G 6.125" 3.5# 9.3# L-80 SLHT 903' 11411' 6022' 12314' 6383' 180 sx Class G w/Gssblock 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total Depth: measured feet Plugs (measured) :, ,;.~ true vertical feet Effective Depth: measured feet Junk (measured) true vertical feet Casing Length Size Cemented Measured depth True Vertical depth Conductor Surface ProductionRECEIVED LinerORIGINAL Perforation depth: measured AJask~ Oi'~ & Gas Cons. An~0rage true vertical 20. Attachments Filing fee ~] Property Plat [~ BOP Sketch r~ Diverter Sketch [~] Drilling program [~] Drilling fluid program ~ Time vs depth plot E~Refraction analysis E] Seabed report r-] 20 AAc 25.050 requirements r-] 21. I hereby I~rtify that ~ng is true and correct to the best of my knowledge Ouestions?Ca/ITomBrockway~J~-413~. SignedU ~ ~~ Title: Od/ling EngineedngSuporvisor Date Pret3~red hv ~h~ron AIl.~un-Dr~k¢ Commission Use Onl) Permit Number ~,_//?IAPI50n'um~e~-"'~::~''''' ~?~;:;~?"' {~)~'~IAppro~)d?.~.)/oO Ieee cover letter , Ifor other requirements Conditions of approval Samples required D Yes J~ No Mud log required D Yes [~ No Hydrogen sulfldemeasures r-~ Yes D No Directionalsurveyrequired [~ Yes D No Required working pressure for BOPE D2M; D 3M; ~ 5~ r"'] lOM;D ~C..,~.~ Q¥.~ b~]~,~.~~,'t --__ SIGNED BY by order of Other: Approved by D Taylor Seamount Commissioner the commission Date '~lg/00 Form 10-401 Rev. 12/1/85 · Submit in triplicate PHILLIPS Alaska, Inc. Subsidiary of PHILLIPS PETROLEUM COMPANY July 26, 2000 Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 (907) 279-1433 RECEIVED A~aska Oi'; & Gas Co~$. C~m~i~i~i~ Anchorage Re: Application for Permit to Drill: Surface Location: Target Location: Bottom Hole Location: KRU 1D-40 537' FNL, 421' FEL, Sec 23, T11N, R10E, UM 848' FSL, 742' FEL, Sec. 26, T11N, R10E, UM 571' FSL, 764' FEL, Sec. 26, T11N, R10E, UM Dear Sirs: Phillips Alaska, Inc. hereby applies for a Permit to Drill an onshore development well to the Kuparuk interval from 1D Pad in the Kuparuk River Unit ("KRU"). The well is designed to penetrate and further develop the production potential of the Kuparuk sands in the vicinity of 1D pad. The well is designated as a conventional injector and is planned for a 9-5/8" surface casing string, a 7" intermediate casing string, and a 3-1/2" production liner to penetrate the Kuparuk sands. The well will be drilled and completed using Nabors 16E. Completion plans call for running a 3-1/2" injection tubing string. Please find attached information as required by 20 AAC 25.005 (a) and (c) for your review. Pertinent information attached to this application includes the following: 1) Form 10-401 Application for Permit to Drill per 20 AAC 25.005 (a). 2) Fee of $100 payable to the State of Alaska per 20 AAC 25.005 (c) (1). 3) A directional plat showing the surface and bottomhole locations proposed for the well per 20 AAC 25.005 (c) (2). 4) Directional plots and proximity calculations in accordance with the requirements of 20 AAC 25.050. 5) Diagrams and descriptions of the BOP and diverter equipment to be used as required by 20 AAC 25.035 (a) (1) and (b). 6) A complete proposed casing and cementing program is attached as per 20 AAC 25.030. A wellbore schematic is also attached visually depicting the proposed well and completion design. 7) The drilling fluid program, in addition to the requirements set forth in 20 AAC 25.033 are attached in this APD package. PHILLIPS Alaska, Inc. A Subsidiary of PHILLIPS PETROLEUM COMPANY 8) 9) 10) 11) A copy of the proposed drilling program, including a request for approval of annular pumping operations is attached. A description of the procedure for conducting formation integrity tests, as required under 20 AAC 25.030(f). Also note that Phillips does not anticipate the presence of H2S in the formations to be encountered in this well. However, there will be H2S and combustible gas monitoring equipment functioning on the rig as is the standard operating procedure in the Kuparuk River Unit drilling operation. Please note that because of the large volume of regional information available in this area, Phillips considers this well to be a development well, and as such, no mudlogging operations such as type log generation and sample catching are planned. The following are the Phillips designated contacts for reporting responsibilities to the Commission: A) Completion Report (20 AAC 25.070) Sharon AIIsup-Drake, Drilling Technologist 263-4612 B) Geologic Data and Logs Bill Raatz, Geologist (20 AAC 25.071) 263-4952 Please note that the anticipated spud date for this well is Auqust 7, 2000 If you have any questions or require further information, please contact Tom Brockway at (907) 263-4135 or James Trantham at (907) 265-6434. Thomas A. Brockway ~ Operations Drilling Engineer Attachments: CC: KRU 1D-40 Well File Tom Brockway ATO-1040 RECEIVED GENERAL DRILL AND COMPLETE PROCEDURE EBA INJECTOR KRU 1 D-40 General Procedure: R CEiVED Alaska O?i & Gas Oo~s. Anchorage 1. Excavate cellar, install cellar box, set and cement 20" conductor to +/- 150' RKB. Weld landing ring on conductor. 2. Move in / rig up Nabors Rig 16E Install diverter & function test same. 3. Spud and directionally drill 12-1/4" hole to 9-5/8" surface casing point (+/- 6960 MD') according to directional plan. Run MWD / LWD logging tools in drill string as required for directional monitoring and formation data gathering. 4. Run and cement 9-5/8" 40.0# L-80 BTCM casing to surface using lightweight permafrost cement lead slurry to assure cement returns to the surface. Adequate excess cement will be pumped to ensure cement reaches the surface during the first stage cement job. Displace cement with mud. 5. Nipple down diverter and install wellhead. Nipple up BOPE and test to 5000 psi. Record results. 6. Shut in BOP's and pressure test casing to 3000 psi for 30 minutes per AOGCC regulations. Record results. 7. Drill out cement and 20' of new hole. Perform formation integrity test not to exceed 16.0 ppg EMW. This establishes a maximum allowed drilling mud weight below the casing shoe per 20 AAC 25.030 (0.5 ppg less than the FIT or LOT EMW). 8. Directionally drill 8-1/2" hole to mid-point of the HRZ (+/- 11375' MD) according to directional plan. Run MWD / LWD logging tools in drill string as required for directional monitoring and formation data gathering. Perform second LOT at to evaluate long string option. If LOT is adequate to long string, drill to well total depth (+/- 12314' MD), run 7" 26.0# L-80 BTCM casing to surface and cement, and continue with step #17. Note: If significant hydrocarbon zones are present above the Kuparuk, sufficient cement will be pumped for isolation in accordance with Rule 20 AAC 25.030 9. If LOT is inadequate to long string, drill to 7" intermediate casing point (+/- 11561' MD). &'~['1 ¥~\'1 '~\\ 10. Run 7" 26.0# L-80 BTCM casing to surface and cement. ~:~s~'~'-, ~ Note: If significant hydrocarbon zones are present above the Kuparuk, sufficient cement -"' "~f"~ will be pumped for isolation in accordance with Rule 20 AAC 25.030 11. Nipple up BOPE and test to 5000 psi. Record results. 12. Shut in BOP's and pressure test casing to 3000 psi for 30 minutes per AOGCC regulations. Record results. 13. Drill out cement and 20' of new hole. Perform formation integrity test not to exceed 16.0 ppg EMW. This establishes a maximum allowed drilling mud weight below the casing shoe per 20 AAC 25.030 (0.5 ppg less than the FIT or LOT EMW). 14. Drill 6-1/8" hole to well total depth (+/- 12314' MD) according to directional plan, running LWD logging equipment as needed. Circulate and condition hole. POOH 15. Run open hole e-line or drill pipe conveyed logs as needed. 16. Run and cement 3-1/2" 9.3# L-80 EUE8RD liner and Baker SAB-3 packer assembly. Set packer +/- 150' above intermediate casing shoe to provide appropriate liner lap. 17. RIH with clean out BHA. Scrape casing. Displace well to completion brine. 18. Run and land 3-1/2" tubing with gas lift completion. TAB, 07/25/00, vl 19. Pull landing joint. Install BPV. Nipple down BOP stack, and nipple up production tree. Pull BPV. Install test plug. Pressure test production tree. Pull test plug. Secure well. 20. Freeze protect well. Set BPV. Release rig and turn well over to production. 21. Clean location and RDMO in preparation for coiled tubing cieanout and perforating Note: As a dedicated injector, cased hole cement bond logs (SLT-J or CBT) will be run to establish isolation after the cleanout is completed, but prior to perforating. RECEIVED Alaska Oil & Gas Cons. Commissior~ ~chomge TAB, 07/25/00, vl DRILLING FLUID PROGRAM, PRESSURE CALCULATIONS, & DRILLING AREA RISKS KRU 1 D-40 Drilling Fluid Properties: Density PV YP Viscosity Initial Gel 10 Minute Gel APl Filtrate pH % Solids Spud to 9-5/8" Sudace Casing 8.5-10.2 16-26 25-50 100-200* 10-20 15-40 7-15 9.5-10 6-8% Drill out to 7" Intermediate Casin[I 8.8-9.8 5-25 8-25 35-55 3-10 10-15 5-15 8.5-9.5 6-8% Drill Out to TD 11.3-13.0 25-35 20-30 50-65 4-7 4-8 8-10 8.0-8.5 4-7% Drilling Fluid System - Nabors 16E 3 - Derrick Shale Shakers Desander Desilter Mud Cleaner Centrifuge Degasser Pit Level Indicator (w/visual and audible alarms) Trip Tank Fluid Flow Sensor Fluid Agitators *Spud mud should be adjusted to a FV between 180-250 sec/qt to drill gravel beds Notes: Drilling fluid practices will be in accordance with the appropriate regulations stated in 20 AAC 25.033. Maximum Anticipated Surface Pressure: Three possibilities exist for the possible maximum anticipated surface pressure (MASP) seen by the surface casing string along the 1 D-40 well path. 1) MASP can be calculated using an expected leak-off of 13.7 ppg EMW (0.71 psi/ft) and a gas gradient of 0.11 psi/ft. This shows that formation breakdown would occur at a surface pressure of 2503 psi. The leak off EMW was chosen based on an open hole LOT on well, 1 D-38, taken to 13.5 ppg at 4279' TVD (0.70 psi/fi). MASP = (4244 ft)(0.70 - 0.11) = 2503 psi RECEIVED AUG 0 2 . A!aska 0[4 & Gas uo,~s. Commissio~ Anchorage 2) 3) If the well is drilled out of surface casing to TD as planned and surface shoe LOT is higher than expected, the MASP can be calculated based on a reservoir pressure of 3500 psi at 6262' TVD (0.56 psi/ft) and a gas gradient of 0.11 psi/ft. In this case, MASP would occur at 2818 psi. MASP = (6262 ft)(0.56 - 0.11) = 2818 psi Some prior EBA and GSA wells in this area have experienced gas charged sands in the D-shale as a result of historic Gas Storage Area injection. These sands are located above the Kuparuk reservoir and are expected to occur at +/- 6257' TVD along the proposed well path in the 1D-40 target area. There is a strong possibility that gas charging will be encountered in this well and if this occurs, MASP would be based on a 12.5 ppg equivalent pressure (0.65 psi/ft). Based on this pressure gradient and a gas gradient of 0.11 psi/ft, MASP would occur at 3379 psi. MASP = (6257 ft)(0.65 - 0.11 ) - 3379 psi Therefore, based on the possibility of a MASP greater than 3000 psi, Phillips Alaska, Inc. will test the BOP equipment to 5000 psi prior to drilling out of surface casing. In the event that the well must be topset above the Kuparuk, the maximum anticipated pressure for the intermediate casing string would continue to be the pressure exerted by the gas charged D-shale sands at the surface and would remain at 3379 psi as calculated previously. Therefore, based on the possibility of a MASP greater than 3000 psi, Phillips Alaska, Inc. will test the BOP equipment to 5000 psi prior to drilling out of intermediate casing if an intermediate string is needed. Based the anticipated pressures shown, a maximum mud weight requirement for this well is established based on the potential charging of the D-shale sands. Assuming a 150 psi overbalance is required to safely drill and trip in this formation, then a required mud weight of 13.0 ppg can be predicted as the maximum mud weight needed to safely conduct rig operations, assuming a TVD of 6257'. MW = [(6257 ft)(0.65)+150]/6257/.052 - 13.0 ppg In order to allow for a long string design, the minimum LOT in the Mid-HRZ or surface casing shoe must be greater than ECD (equivalent circulating density) with a 13.0 ppg drilling fluid as modeled or as measured with the Pressure While Drilling (PWD) sub, plus adequate safety margin. Well Proximity Risks: The nearest existing well to 1D-40 is 1D-38. As designed, the minimum distance between the two wells would be 28.8' at 520' MD. Drilling Area Risks: Risks in the 1D-40 drilling area include surface interval hydrates, lost circulation, and potential borehole instability in and below the permafrost zone as well as through the intermediate shales. Hydrate risks will be minimized by the use of sufficient mud weights to allow for tripping of pipe, controlled drilling rates, and rheological properties which safely appropriate gas breakout. Lost circulation will be addressed with lost circulation material (LCM), reduced circulating rates, and reduced mud weights as needed. Shale instability will be controlled primarily with the planned fluid densities. Additional risk exists with unpredictable charging of the D-shale sands during historic gas injection. These gas pressure risks are mitigated with mid-HRZ LOT's and a top set option above the D- shale based upon those results. RECEIVED /-U 02 .... ' A aska & Gas Col s. Anchorage Annular Pumping Operations: Incidental fluids developed from drilling operations will be either injected into an approved annulus on the same pad or hauled to the nearest permitted Class II disposal well. (Note that cement rinseate will not be injected down the dedicated disposal well but will be recycled or held for an open annulus.) The open annulus will be left with a non-freezing fluid during any extended shut down (> 4 hr) in pumping operations. The 1D-40 surface/production casing annulus will be filled with diesel after setting production casing and prior to the drilling rig moving off of the well. If isolation is required per regulations over significant hydrocarbons, then sufficient cement volume will be pumped during the production cement job to cover those formations. At the end of drilling operations, a request for 1D-40 to be permitted for annular pumping of fluids occurring as a result of future drilling operations on 1D pad, per regulation 20 AAC 25.080, will be submitted. Any zones containing significant hydrocarbons will be isolated prior to initiating annular pumping. There will be no USDW's open below the shoe or potable/industrial water wells within one mile of the receiving zone. Reference the enclosed directional drilling plan for other formation markers in this well. Surface casing will be set in the Cretaceous shales below the base of the West Sak Sands. These 300-500' thick shales are part of the Colville Group and are known to provide vertical barriers to fluid flow. The surface casing shoe will be set a minimum of 200' vertically below the base of the West Sak into the heart of the shales. The surface and production casing strings exposed to the annular pumping operations have sufficient strength by using the 85% collapse and burst ratings listed in the following table: Wt :Connection 85% of 85% of OD (ppf) Grade Range Type Collapse Collapse Burst Burst 9-5/8" 40 L-80 3 BTC 3,090 psi NA 5,750 psi 4,888 psi 7" 26 L-80 3 LTC-Mod 5,410 psi 4,599 psi 7,240 psi 6,154 psi 3W'* 9.3 L-80 2 8rd EUE Mod 10,530 psi 8,951 psi 10,160 psi 8,636 psi *ifneeded Fluids to be disposed of in the annulus will be limited to drilling wastes associated with drilling a well as defined in 20 AAC 25.080 (h). RECEIVED AJaska 0~; & Gas Cons. Commis=ior~ Anchorage KRU 1D-40 Inject( Proposed Completion Schematic Topset Base Case PHIl. LIPS Alaska, Inc. A Subsidiary of PHILLIPS PETROLEUM COMPANY 20" 91.5# H-40 @ +/- 120' MD Depths are based on Nabors 16E RKB Surface csg. 9-5/8" 40.0# L-80 BTCM (+/- 6959' MD / 4244' TVD) 3-1/2" FMC Gen V Tubing Hanger, 3-1/2" L-80 EUE8RD pin down 3-1/2" 9.3# L-80 EUE8RD Spaceout Pups as Required 3-1/2" 9.3# L-80 EUE8RD Tubing to Surface 3-1/2" Camco 'DS' nipple w/2.875" No-Go Profile. 3-1/2" x 6' L-80 pup installed above. 3-1/2" x 6' L-80 flow coupling installed below, EUE8RD set at +/- 500' MD 3-1/2" 9.3# L-80 EUE8RD tubing to landing nipple Intermediate csg. 7" 26.0# L-80 BTCM (+/- 11561' MD / 6082' TVD) Future Perforations Production Liner 3-1/2" 9.3# L-80 EUE8RD (+/- 12314' MD / 6383' TVD) 3-1/2" x 1-1/2" Camco 'MMG' mandrel w/shear valve and latch (Max. OD 5.968", ID 2.92"), pinned for 3000 psi shear (casing to tubing differential), 6' L-80 handling pups installed above and below. 1 jt 3-1/2" 9.3# L-80 EUE8RD tubing 3-1/2" Camco 'DS' nipple w/2.813" No-Go profile. 3-1/2" x 6' L-80 EUE8RD handling pups installed above and below 1 jt 3-1/2" 9.3# L-80 EUE8RD tubing 5.125" x 3" Baker Iocator sub 4-1/2" Baker GBH-22 casing seal assembly w/12' stroke, 3-1/2" L-80 EUE8RD box up Liner Assembly (run on drillpipe)l set @ +/- 11411' MD Baker 7" x 3-1/2" 'SLZXP' Liner Top Isolation Packer Baker 7" x 3-1/2" 'HMC' Hydraulic Liner Hanger Baker 17' Seal Bore Extension 1 jt 3-1/2" 9.3# L-80 SLHT tubing 3-1/2" Camco 'D' nipple w/2.75" No-Go Profile. 3-1/2" x 6' L-80 EUE8RD handling pups installed above and below 3-1/2" 9.3# L-80 SLHT liner run to TD F ECE VED TAB, 7/25~00, vl KRU 1D-40 Inject(.' Proposed Completion Schematic Long String Contingency Case PHI(LLIPS Alaska, Inc. A Subsidiary of PHILLIPS PETROLEUM COMPANY 20" 91.5# H-40 @ +/- 120' MD Depths are based on Nabors 16E RKB Surface csg. 9-5/8" 40.0# L-80 BTCM (+/- 6959' MD / 4244' TVD) Future Perforations Production csg. 7" 26.0# L-80 BTCM (+/- 12314' MD / 6383' TVD) 3-1/2" FMC Gen V Tubing Hanger, 3-1/2" L-80 EUE8RD pin down 3-1/2" 9.3# L-80 EUE8RD Spaceout Pups as Required 3-1/2" 9.3# L-80 EUE8RD Tubing to Surface 3-1/2" Camco 'DS' nipple w/2.875" No-Go Profile. 3-1/2" x 6' L-80 pup installed above. 3-1/2" x 6' L-80 flow coupling installed below, EUE8RD set at +/- 500' MD 3-1/2" 9.3# L-80 EUE8RD tubing to landing nipple RECEIVED 3-1/2" x 1-1/2" Camco 'MMG' Mandrel w/shear valve and latch (Max. OD 5.968", ID 2.92"), pinned for 3000 psi shear (casing to tubing differential), 6' L-80 handling pups installed above and below. 1 jt 3-1/2" 9.3# L-80 EUE8RD tubing 3-1/2" Camco 'DS' nipple w/2.813" No-Go profile. 3-1/2" x 6' L-80 EUE8RD handling pups installed above and below 1 jt 3-1/2" 9.3# L'80 EUE8RD tubing 7" x 3-1/2" Baker 'SAB-3' permanent packer w/KBH-22 seal assembly, 3-1/2" x 6' L-80 EUE8RD handling pup on top 1 jt 3-1/2" 9.3# L-80 EUE8RD tubing 3-1/2" Camco 'D' nipple w/2.75" No-Go Profile. 3-1/2" x 6' L-80 EUE8RD handling pups installed above and below 3-1/2" x 10' L-80 EUE8RD pup joint 3-1/2" Baker Shear Out Ball Seat Sub. Tubing tail +/- 50' above top of proposed perforations TAB, 7/25/00, vl 5OO 1000 150O 2OOO ~- 2500 ..+- 3000 '~ 3500 (D 4000 I 4500 V Created b~ rix~e FOR: BROCKWAY Date plotted: 25-Jul-2000 Plot Reference is 40 Version ~1 . Coordinates ore in feet reference slat ~40 . [rue Vertical Oepths o_r~_~ce RKB(Nabors 16E). PHILLIPS Alaska, Inc. Structure : Pad 1D Well : 40 Field : Kuparuk River Unit Location : North Slope, Alaska 50OO 55O0 6000 65OO KOP 0.75 4.11 Begin Build & Turn 15.51 Base of Permafrost 21.27 27.15 33.14 39.13 DLS: 3.00 deg per 100 ft 45.12 51.12 57.1 1 66.1 1 EOC 66.41 Begin Right Turn 66.35 DLS: 1.50 dog per 100 ft 66.44 EOC Top of West Sok TANGENT ANGLE 66.45 DEG Point KOP Begin Build & Turn Base of Permafrost EOC Begin Right Turn EOC Top of West Sok Base of West Sak 9-5/8 Casing Pt C80 (KIO) C50 c4o <K-5) Top HRZ C30 (K-2) PROFILE COMMENT DATA MD Inc Dir TVD North East V. Sect Dog/lO0 850.00 0.00 0.00 850.00 0.00 0.00 0.00 0.00 1000.00 2.25 90.00 999.96 0.00 2.94 -0.10 1.50 1629.54 19.22 165.92 1617.00 -100.92 45.86 99.29 3.00 3211.48 66.45 175.00 2745.82 -1133.41 195.90 1126.05 3.00 3525.02 66.45 17`3.00 2870.29 -1416.88 230.71 1408.16 0.00 4225.00 66.45 184.49 3151.54 -2058.82 244.77 2049.25 1.50 5375.13 66.45 184.49 3611.00 -3109.96 162.24 3102.59 0.00 6459.02 66.45 184.49 4044.00 -4100.56 84.47 4095.27 0.00 6959.67 66.45 184.49 4244.00 -4558.11 48.55 4555.78 0.00 7362.69 66.45 184.49 4405.00 -4926.44 19.63 4922.89 0.00 9685.67 66.45 184.49 5333.00 -7049.48 -147.06 7050.38 0.00 10268.92 66.45 184.49 5566.00 -7582.53 -188.91 7584.55 O.OC 11009.87 66.45 184.49 5862.00 -8259.70 -242.08 8263.15 O.OC 11014.88 66.45 184.49 5864.00 -8264.28 -242.43 8267.74 flOC C20-HRZ Midpoint 11375.34 66.45 184.49 6008.00 -8593.72 -268.30 8597.67 O.OC 7 Csg Pt-Bose HRZ 11560.58 66,45 184,49 6082.00 -8763,01 -281,59 8767.51 0.0£ K-1 Marker 11788.38 66.45 184,49 6173.00 -8971,20 -297.94 8976.14 O,OC Top Kuporuk D 11998.65 66.45 184,49 6257,00 -9163.37 -313.02 9168.71 O.OC Target-Top C4 12011.16 66,45 184.49 6262.00 -9174,81 -313,92 9180,18 0.00 Top C3 12048.71 66.45 164.49 6277.00 -9209,12 -316.62 9214,56 0.00i Top C2 12078.75 66.45 184.49 6289,00 -9236,58 -318,77 9242,08 0.00I Top C1 12116,30 66,45 184,49 6304,00 -9270.89 -321,47 9276.46 0,00I Top B Shale 12126,31 66.45 184,49 6308,00 -9280,04 -322,19 9285.63 0,00 TD -Cosing Pt 12314.05 ~6.45 1~4,49 6383.00 -9451.63 -335.66 9457.58 0.00 Base of West Sok 9-5/8 Casing Pt C80 (KIO) 181.96 AZIMUTH 9180' (TO TARGET) ***Plane of Proposal*** C50 c~-o (K-5) C30 (K-2) C20-HRZ Mid 7 Csg Pt K- 1 Marker Top Kuporuk D Target-Top C4 Top C2 Top B Shale Anchorage Top .C3 Top C 1 TD - Casing Pt · I I I I I I I I I I I I I I I I I I I I II I II I I I I I I I I I I I I I I I I 500 0 500 1000 1500 2000 ' 2500 3000 ,3500 4000 4500 5000 5500 6000 6500 7000 7500 8000 8500 9000 9500 Vertical Section (feet) -> Azimuth 181.96 with reference 0.00 N, 0.00 E from slot #40 . Creat~l by rix~e FOR: BROCKWAY Date plotted; 2¢-Jul-2000 P~ot Reference is 40 Version ~1 . Coordinates are in feet ~eference slot ~40 . True Vertical Depths ore reference RKB(Nabors 16£ PHILLIPS Alaska, Inc. Structure : Pad 1D Well : 40 Field : Kuparuk River Unit Location : North Slope, Alaska 2400 I 81.96 AZIMUTH ***Plane of Proposal*** <- West (feet) 1800 1200 600 0 600 1200 B~ogin Build & :l'urn se of Permofrost EOC Begin Right Turf EOC Top of West Sok Base of West Sok 9-5/8 Casing Pt c8o (K~O) C50 c4o (K-5) C30 (K-2) Top HRZ C20-HRZ Midpoint z~, L 7 casing (KBaSe HRZ - 1 Marker Target-Top C4 Top Kuparuk D Top C5 Top C2 Top C1 Top B Shale TD - Casing Pt 600 6OO 200 1800 24OO 5000 3600 4200 4800 5400 6OOO 6600 72OO 78OO 84OO 9000 9600 0 SURFACE LOCATION: 537' FNL, 421' FEL SEC. 25, Tll N, RIOE .:CEI 7ED TARGET LOCATION: 84-8' FSL, 7,~2' FEL SEC. 26, T11N, RIOE TD LOCATION: 571' FSL, 764' FEL SEC. 26, T11N, RIOE Creot~:l by H~FOR: BROCI(WAY Doto plotted : 24-J~-2~ Coordin~ are ;n feet ~e PHILLIPS Alaska, Inc. Structure : Pad 1D Well : 40 Field : Kuparuk River Unit Location : North Slope, Alaska 20 20 40 60 80 100 120 I V t40 160 180 / 200 ~ 220 E o st ( f e e t ) - > Anchorage 140 120 1 O0 80 60 40 20 0 20 40 60 80 1 O0 120 140 160 180 I I I I I I I I I I I e I I I I I I I I I I I I 60 200 900 /1800 / 1100 1800 300 9OO ,/'1700 1000 1900 100(, ,/1600 1400 1100 O0 1000 1200 1100 1200 /~)"'- 900 900 300 1400 15~'h'-.,.__ 1000 40 500 '-,.-~-...~ "~ . '",.110 1700 20 ~'~~~oo -. "',%] 200 . '~ 1200 '",, ~ ~00 ~500 '",h ~ 300 '"', 20 ~ ~00 "~, ~ 300 ~ 700 ',,,,,,, "'~ 1400 40 x 1800 ~ '""' 60 ~ 1500 'A 1~00 11 O0 , "',,,,,, 80 ', 1600 1~00 100 120 1300 · ~1700 ~ 2100 ~4o ~ 1800. .180 200 2200 220 13OO 800 1201 240 240 1400 , 260 ~ 700 260 1300 28O 28O 140 120 1 O0 80 60 4.0 20 0 20 40 60 80 1 O0 120 140 160 180 East (feet) -> c,-,.te~ ,.~, ,~., FOR: BROCKWAY Dote plotted: 25-~-2~ ~ot Ref~ence ia ~ Va~ion CaordinGt~ ore in feet ~e~e T~* V~c~ ~ths ~ce PHILLIPS Alaska, Inc. Structure : Pad 1D Well: 40 Field : Kuparuk River Unit Location : North Slope, Alaska Eost (feet) -> 200 160 120 80 40 0 40 80 120 REC. Ei AUG 0 Anchorage, 60 200 240 280 320 ,360 400 2OO 240 28O 320 360 400 440 -4-- ~ 480 '-,- 520 0 56O I v 600 640 680 720 760 800 840 2100 / / I ! I 2300 ~5oo I I ; I I I I ! I / I 2300 ! 2500 1100 150 2700 1300 ~3oq i1900 210(: 1700 iiO0 1~00 1900 2100 200 ~ 1700 ""\\\ 240 '\'\\, \\ 280 '\, '"\'x ,32o 1900 ~. 1 @00 \ ,\ aso '\, 400 1700 i2300 21300 130 50O i i t i I / i i i t i i i i i i i i 2700 "~ 440 2100 0 48O E 520 560 I v 6O0 640 68O 72O I i I I I i i i i i I 200 160 120 80 40 0 40 80 t20 160 200 240 280 320 360 400 Eosf (feet) -> u~ r~ FOR: BROCKWAY DOte plotted: 2§--Jul-2000 PIo~ Raf~ance ~a ~ Ve~io~ ~I . Caordin~ are ~n leek ~e~e sl~ fi40 . 500 400 500 200 100 0 700 21 O0 800 / I / / / go0 / 2go0 1000 / ! / / 230( / / 1100 I / 1200 / 31 O0 I / / ; / 1300 i ! ! / 2500 1400 1500 1600 1700 1800 1900 2000 2100 2200 2300 PHILLIPS Alaska, Inc. Structure : Pad 1D Well : 40 Field : Kuparuk River Unit Location : North Slope, Alaska RECEIFED 17OO 19O0 2700 AUG 0 2 G; & Gas Ca?,s.~mm~ss~on""' ' ' E a s f ( f e e t) - > /~c~orage 1 O0 200 300 40; 500 600 700 800 900 1000 I I I I I ,! '\ "~ 2500 1, 3 lOO -- ',~ 2~o "~-- 2300 3100 2900 t2100 ,.,~ 3100 I1 L_~ ~3700 , ~'~ 500 400 300 200 100 0 100 200 300 400 500 600 700 800 900 1000 Eosf (feet) -> 7OO 800 - 900 -1000 -1100 -1200 -1300 - 1400 -1500 -1600 1700 1800 1900 '2000 - 2100 ~ 2200 2300 c.~t~ u~ ,{.e FOR: BROCKWAY Dete plotled : 25-Jul-2000 P{ot Reference ;e ~ V~{on ~1 . Cao~in~ are ;n feet ~e~e sl~ {~ . PHILLIPS Alaska, Inc. Structure : Pad 1D Well : 40 Field : Kuparuk River Unit Location : North Slope, Alaska 1800 E o s f ( f e e f) - > Af~Ciora~e 1200 1000 800 600 400 200 0 200 400 600 800 1000 1200 1400 1600 1800 ~ 1800 2000 2200 2400 26OO 2800 3OOO x-~ 3200 .-I-- ~ 3400 0 3600 I v 38oo 4000 4200 4400 4600 4800 5OOO 5200 25OO 27O0 ' 4700 , I 4900 / / ! 5100 ,, / 3100 , i 2,00 ! / 2900 ~ 3900 4100 4300 4500 23OO 2500, 2700 2900 3100 3300 3500 3700 3go0 4100 3100 3300 3500 3700 3900 4100 350( 4300 29OO ~330( 3100 ' 3500 3700 3300 500 700 3900 O0 3700 '\ ; 350~ '~ 37c '""k,,, 3900 00 5100 ~00 55OO 5700 3900 4100 f 4300 4100 ) 6500 1200 lO00 800 600 400 200 0 200 400 600 800 1000 1200 14oo 16oo 1800 2O0O 2200 2400 26OO 2800 3000 3200 (J3 0 c' 3400 .3600 _.~ I 38oo V 4000 '4200 4400 -- - 4600 4800 5OOO 5200 East (feet) -> PHILLIPS Alaska, Inc. Sfructure: Pad 1D Well : 40 Field : Kuparuk River Unit Location : North Slope, Alaska 3600 4000 4400 4800 5200 5600 6000 /'~ 6400 ~'~ 6800 0 7200 I V 7600 East (feet) -> 2800 2400 2000 1600 1200 800 400 0 400 800 1200 1600 2000 2400 2800 ,.3200 3600 I I I I¢ I I I I t I ~jI I I ~ 5500 /5700 ! ~ 5900 /'61oo 6300 4100 i i4300 i 4500 4700 '4900 1 51oo 5300 5500 6700 4300~\ ~00 ~ ¢500 4300 \, ~ 4700 ~ ¢900 4500 ~ 51oo \, ~ 5300 4700 ~ 5500 5700 4900 , 530O "~ 4100 X 3600 4000 5100 4400 4800 - 5200 5600 60O0 900 6400 0 61oo ', 6800 ~ 6300 ~ 6500 7200 _.+. '\ 7600 V I ~5700 5500 8000 !' 8000 '5900 8400 5700 6100 6300 84oo 8800 8800 5900 9200 9200 9600 6100 9600 1OOOO 1000O 10400 10400 2800 2400 2000 1600 1200 800 400 0 400 800 1200 1600 2000 2400 2800 3200 3600 East (feet) -> c~,~t~ u~ ~,e FOR: BROCI~AY Dote plotte<J: 25-Jul-2~ ~ot Reliance is 4D Ve~ion ~1 . I Coordinot~ ore in f~ ~e~e sl~ ~40 . I rme Ve~col ~ths 700 500 330 PHILLIPS Alaska, Inc. Structure : Pad 10 Well : 40 Field : Kuparuk River Unit Location : North Slope, Alaska 540 TRUE NORTH 350 0 10 2O 9O0 1100 290 7O 280 8O 270 + ~oo 9O 260 100 250 9OO 110 20 · 1500 0 1700 210 o 1 1 200 190 1300 3900 41 O0 ¢300 170 160 150 150 Normal Plane Travelling Cylinder- Feet All depths shown are Measured depths on Reference Well PHILLIPS Alaska, Inc. Pad 1D 40 slot~40 Kuparuk River Unit North Slope, Alaska PROPOSAL LISTING INCLUDING POSITION UNCERTAINTIES by Baker Hughes INTEQ Your ref: 40 Version #1 Our ref: prop1837 License : Date printed : 25-Jul-2000 Date created : 15-0ct-1996 Last revised : 25-Jul-2000 Field is centred on n70 16 18.576,w150 5 56.536 Structure is centred on n70 18 1.316,w149 30 18.908 Slot location is n70 17 56.035,w149 30 31.181 Slot Grid coordinates are N 5959129.177, E 560670.303 Slot local coordinates are 537.00 S 421.00 W Projection type: alaska - Zone 4, Spheroid: Clarke - 1866 Reference North is True North RECE V..D PHILLIPS Alaska, Inc. Pad 1D,40 Kuparuk River Unit,North Slope, Alaska Measured Inclin. Azimuth True Vert R E C T A N G U L A R Depth Degrees Degrees Depth C 0 0 R D I N A T E S PROPOSAL LISTING Page 1 Your ref : 40 Version#1 Last revised : 25-Jul-2000 Dogleg Vert Deg/lOOft Sect 0.00 0.00 0.00 0.00 0.00 N 0.00 E 0.00 500.00 0.00 0.00 500.00 0.00 N 0.00 E 0.00 850.00 0.00 0.00 850.00 0.00 N 0.00 E 0.00 900.00 0.75 90.00 900,00 0.00 N 0,33 E 1.50 1000.00 2.25 90.00 999.96 0.00 N 2.94 E 1.50 0.00 0.00 0.00 KOP -0.01 -0.10 Begin Build & Turn 1100.00 4.11 135.61 1099.82 2.56 S 7.41 E 3.00 2.30 1200.00 6.83 149.26 1199.36 10.23 S 12.96 E 3.00 9.78 1300.00 9.72 155.00 1298.31 23.00 S 19.57 E 3.00 22.31 1400.00 12,63 158.71 1396.40 40.84 S 27.11 E 3.00 39,89 1450.00 14.10 160.00 1445.04 51.66 S 31.18 E 3.00 50.56 1500.00 15.51 162.03 1493.38 63.75 S 35.32 E 3.00 1600.00 18.37 165.16 1589.04 91.70 S 43.49 E 3.00 1629.54 19.22 165.92 1617.00 100,92 S 45.86 E 3.00. 1700.00 21.27 167.48 1683.11 124.65 S 51.45 E 3.00 1800.00 24.19 169.25 1775.33 162.48 S 59.21 E 3.00 62.50 90.16 99.29 Base of Permafrost 122.81 160.36 1850.00 25.65 170.00 1820.68 183.21 S 63.00 E 3.00 180.95 1900.00 27.15 170.24 1865.46 205.11 S 66.81 E 3,00 202.70 2000.00 30.14 170.66 1953.21 252.38 S 74.76 E 3.00 249.68 2100.00 33.14 171.00 2038.34 304.16 S 83.11 E 3.00 301.14 2200.00 36.13 171.30 2120.61 360.32 S 91.84 E 3.00 356.96 2300.00 39.13 171.56 2199.79 420.68 S 100.94 E 3.00 416.99 2400.00 42.13 171.78 2275.68 485.10 S 110.37 E 3.00 481.05 2500.00 45.12 171.98 2348.06 553.40 S 120.11 E 3.00 548.96 2600.00 48.12 172.16 2416.74 625.37 S 130.13 E 3,00 620.56 2700.00 51.12 172.33 2481.52 700.84 S 140.41 E 3.00 695.63 2800.00 54.11 172.48 2542.23 779.59 S 150.92 E 3.00 773.98 2900.00 57.11 172.62 2598.70 861.41 S 161.62 E 3.00 855.38 3000.00 60.11 172.75 2650.78 946.07 S 172.49 E 3.00 939.62 3100.00 63.11 172.87 2698.32 1033.34 S 183.50 E 3.00 1026.46 3200.00 66.11 172.99 2741.20 1122.98 S 194,62 E 3.00 1115.67 3211.48 66.45 173.00 2745.82 1133.41 S 195.90 E 3.00 1126.05 EOC 3500.00 66.45 173.00 2861.10 1395.93 S 228.13 E 0.00 1387.32 3523.02 66.45 173.00 2870.29 1416.88 S 230.71 E 0.00 1408.16 Begin Right Turn 3600.00 66.41 174.26 2901.08 1487.00 S 238.53 E 1.50 1477.97 3700.00 66.37 175.90 2941.13 1578.29 S 246.40 E 1.50 1568.94 3800.00 66.35 177.53 2981.23 1669.74 S 251.65 E 1.50 1660.16 3900.00 66.35 179.17 3021.35 1761.30 S 254.28 E 1.50 1751.57 4000.00 66.36 180.81 3061.46 1852.90 S 254.30 E 1.50 1843.12 4100.00 66.39 182.44 3101.54 1944.48 S 251.70 E 1.50 1934.73 4200.00 66.44 184.08 3141.55 2035.97 S 246.48 E 1.50 2026.35 4225.00 66.45 184.49 3151.54 2058.82 S 244.77 E 1.50 2049.25 EOC 4500,00 66.45 184.49 3261.40 2310.15 S 225.04 E 0.00 2301.11 5000.00 66,45 184.49 3461,14 2767.12 S 189.16 E 0.00 2759.03 5375.13 66.45 184.49 3611,00 3109.96 S 162.24 E 0.00 3102.59 Top of West Sak 5500.00 66.45 184.49 3660.88 3224.08 S 153.28 E 0.00 3216.95 6000.00 66.45 '184.49 3860.63 3681.04 S 117.41 E 0.00 3674.88 6459.02 66.45 184.49 4044.00 4100.56 S 84.47 E 0.00 4095.27 Base of West Sak 6500.00 66.45 184,49 4060.37 4138.01 S 81.53 E 0.00 4132.80 , 6959.67 66.45 184.49 4244.00 4558.11 S 48.55 E 0.00 4553.78 9-5/8" Casing Pt 7000.00 66.45 184.49 4260.11 4594.97 S 45.65 E 0.00 4590.72 RECEWED All data is in feet unless otherwise stated. Coordinates from slot #40 and TVD from RKB(Nabors 16E) (106.00 Ft above mean sea level). Bottom hole distance is 9457.58 on azimuth 182.03 degrees from wellhead. Total Dogleg for wellpath is 79.12 degrees. Vertical section is from wellhead on azimuth 181.96 degrees. Calculation uses the minimum curvature method. Presented by Baker Hughes INTEQ PHILLIPS Alaska, Inc. Pad 1D,40 Kuparuk River Unit,North Slope, Alaska Measured Inclin. Azimuth True Vert R E C T A N G U L A R Depth Degrees Degrees Depth C 0 0 R D I N A T E S 7362.69 66.45 184.49 4405.00 4926.44 S 19.63 7500.00 66.45 184.49 4459.86 5051.93 S 9.78 8000.00 66.45 184.49 4659.60 5508.90 S 26.10 8500.00 66.45 184.49 4859.34 5965.86 S 61.98 9000.00 66.45 184.49 5059.08 6422.82 S 97.86 9500.00 66.45 184.49 5258.83 6879.79 S 133.73 9685.67 66.45 184.49 5333.00 7049.48 S 147.06 10000.00 66.45 184.49 5458.57 7336.75 S 169.61 10268.92 66.45 184.49 5566.00 7582.53 S 188.91 10500.00 66.45 184.49 5658.31 7793.72 S 205.49 11000.00 66.45 184.49 5858.06 8250.68 S 241.37 11009.87 66.45 184.49 5862.00 8259.70 S 242.08 11014.88 66.45 184.49 5864.00 8264.28 S 242.43 11375.34 66.45 184.49' 6008.00 8593.72 S 268.30 11500.00 66.45 184.49 6057.80 8707.64 S 277.24 11560.58 66.45 184.49 6082.00 8763.01S 281.59 11788.38 66.45 184.49 6173.00 8971.20 S 297.94 11998.65 66.45 184.49 6257.00 9163.37 S 313.02 12000.00 66.45 184.49 6257.54 9164.61 S 313.12 12011.16 66.45 184.49 6262.00 9174.81 S 313.92 12048.71 66.45 184.49 6277.00 9209.12 S 316.62 12078.75 66.45 184.49 6289.00 9236.58 S 318.77 12116.30 66.45 184.49 6304.00 9270.89 S 321.47 12126.31 66.45 184.49 6308.00 9280.04 S 322:19 12314.05 66.45 184.49 6383.00 9451.63 S 335.66 PROPOSAL LISTING Page 2 Your ref : 40 Version #1 Last revised : 25-Jul-2000 Dogleg Vert Deg/lOOft Sect 0.00 0.00 0.00 0.00 0.00 4922.89 C80 (KIO) 5048.65 5506.57 5964.49 6422.41 0.00 0.00 0.00 0.00 0.00 6880.34 7050.38 C50 7338.26 7584.55 C40 (K-5) 7796.18 0.00 0.00 0.00- 0.00 0.00 8254.11 8263.15 Top HRZ 8267.74 C30 (K-2) 8597.87 C20-HRZ Midpoint 8712.03 0.00 0.00 0.00 0.00 0.00 8767.51 7" Csg Pt-Base HRZ 8976.14 K-1 Marker 9168.71 Top Kuparuk D 9169.95 9180.18 Target-Top C4 0.00 0.00 0.00 0.00 0.00 9214.56 Top C3 9242.08Top C2 9276.46 Top C1 9285.63 Top B Shale 9457.58TD - Casing Pt A~$ka O, ii & Ga~ ~' Anoh,.omge All data is in feet unless otherwise stated. Coordinates from slot#40 and TVD from RKB(Nabors 16E) (106,00 Ft above mean sea level). Bottom hole distance is 9457.58 on azimuth 182.03 degrees from wellhead. Total Dogleg for wellpath is 79.12 degrees. Vertical section is from wellhead on azimuth 181.96 degrees. Calculation uses the minimum curvature method. Presented by Baker Hughes INTEQ f PHILLIPS Alaska, Inc. Pad 1D.40 Kuparuk River Unit.North Slope, Alaska PROPOSAL LISTING Page 3 Your ref : 40 Version #1 Last revised : 25-Jul-2000 Comments in wellpath MD TVD Rectangular Coords. Comment 850.00 850.00 0.00 N 0.00 E KOP 1000.00 999.96 0.00 N 2.94 E Begin Build & Turn 1629.54 1617.00 100.92 S 45.86 E Base of Permafrost 3211.48 2745.82 1133.41 S 195.90 E EOC 3523.02 2870.29 1416.88 S 230.71E Begin Right Turn 4225.00 3151.54 2058.82 S 244.77 EEOC 5375.13 3611.00 3109.96 S 162.24 E Top of West Sak 6459.02 4044.00 4100.56 S 84.47 E Base of West Sak 6959.67 4244.00 4558.11 S 48.55 E 9-5/8" Casing Pt 7362.69 4405.00 4926.44 S 19.63 E C80 (KIO) 9685.67 5333.00 7049.48 S 147.06 W C50 10268.92 5566.00 7582.53 S 188.91W C40 (K-5) 11009.87 5862.00 8259.70 S 242.08 W Top HRZ 11014.88 5864.00 8264.28 S 242.43 W C30 (K-2) 11375.34 6008.00 8593.72 S 268.30 W C20-HRZ Midpoint 11560.58 6082.00 8763.01 S 281.59 W 7" Csg Pt-Base HRZ 11788.38 6173.00 8971.20 S 297.94 W K-1 Marker 11998.65 6257.00 9163.37 S 313.02 W Top Kuparuk D 12011.16 6262.00 9174.81S 313.92 W Target-Top C4 12048.71 6277.00 9209.12 S 316.62 W Top C3 12078.75 6289.00 9236.58 S 318.77 W Top C2 12116.30 6304.00 9270.89 S 321.47 W Top C1 12126.31 6308.00 9280.04 S 322.19 W Top B Shale 12314.05 6383.00 9451.63 S 335.66 W TD - Casing Pt Casing positions in string 'A' Top MD Top TVD Rectangular Coords. Bot MD Bot TVD Rectangular Coords. Casing 0.00 0.00 O.OON O.OOE 6959.67 4244.00 4558.11S 48.55E 9 5/8" Casing. 0.00 0.00 O.OON O.OOE 11560.58 6082.00 8763.01S 281.59W 7" Casing 0.00 0.00 O.OON O.OOE 12314.00 6382.98 9451.58S 335.65W 3 1/2" Liner Targets associated with this wel 1 path Target name Geographic Locati on T.V.D. Rectangul ar Coordi nates Revised RECEWuD PHILLIPS Alaska. Inc. Pad 1D,40 Kuparuk River Unit. North Slope, Alaska Measured Inclin Azimuth True Vert Depth Degrees Degrees Depth 0.00 0.00 0.00 0.00 500.00 0.00 0.00 500.00 850.00 0.00 0.00 850.00 900.00 0.75 90.00 900.00 1000.00 2.25 90.00 999.96 1100.00 4.11 135.61 1099.82 1200.00 6.83 149.26 1199.36 1300.00 9.72 155.00 1298.31 1400.00 12.63 158.71 1396.40 1450.00 14.10 160.00 1445.04 1500.00 15.51 162.03 1493.38 1600.00 18.37 165.16 1589.04 1629.54 19.22 165.92 1617.00 1700.00 21,27 167.48' 1683.11 1800.00 24.19 169.25 1775.33 1850.00 25.65 170.00 1820.68 1900.00 27.15 170.24 1865.46 2000.00 30.14 170.66 1953.21 2100.00 33.14 171.00 2038.34 2200.00 36.13 171.30 2120.61 2300.00 39.13 171.56 2199.79 2400.00 42.13 171.78 2275.68 2500.00 45.12 171.98 2348.06 2600.00 48.12 172.16 2416.74 2700.00 51.12 172.33 2481.52 2800.00 54.11 172.48 2542.23 2900.00 57.11 172.62 2598.70 3000.00 60.11 172.75 2650.78 3100.00 63.11 172.87 2698.32 3200.00 66.11 172.99 2741.20 3211.48 66.45 173.00 ' 2745.82 3500.00 66.45 173.00 2861.10 3523.02 66.45 173.00 2870.29 3600.00 66.41 174.26 2901.08 3700.00 66.37 175.90 2941.13 3800.00 66.35 177.53 2981.23 3900,00 66.35 179.17 3021.35 4000.00 66.36 180.81 3061.46 4100.00 66.39 182,44 3101.54 4200.00 66.44 184.08 3141.55 4225.00 66.45 184.49 3151.54 4500.00 66.45 184.49 3261.40 5000.00 66.45 184.49 3461.14 5375.13 66.45 184.49 3611.00 5500.00 66.45 184.49 3660.88 .' 6000.00 66.45 184.49 3860.63 6459.02 66.45 184.49 4044.00 6500.00 66.45 184.49 4060.37 6959.67 66.45 184.49 4244.00 7000.00 66.45 184.49 4260.11 R E C TAN G U L A R Dogleg Vert C 0 0 R D I N AT E S Deg/lOOft Sect PROPOSAL LISTING Page Your ref : 40 Version,~6K~ Last revised : 25-Jul-2000 GRID COORDS Easti ng Northi ng O.OON O.OOE 0.00 0.00 560670.30 5959129.18 O.OON O.OOE 0.00 0.00 560670.30 5959129.18 O.OON O.OOE 0.00 0.00 560670.30 5959129.18 O.OON 0.33E 1.50 -0,01 560670.63 5959129.18 O.OON 2.94E 1.50 -0.10 560673.25 5959129.20 2.56S 7.41E 3.00 2.30 560677.74 5959126.68 10.23S 12.96E 3.00 9.78 560683.34 5959119.05 23.00S 19.57E 3.00 22.31 560690.06 5959106.34 40.84S 27.11E 3.00 39.89 560697.74 5959088.56 51.66S 31.18E 3.00 50.56 560701.90 5959077.78 63.75S 35.32E 3.00 62.50 560706.14 5959065.73 91.70S 43.49E 3.00 90.16 560714.53 5959037.84 100.92S 45.86E 3.00 - 99.29 560716.98 5959028.64 124.65S 51.45E 3.00 122.81 560722.76 5959004.97 162.48S 59.21E 3.00 160.36 560730.82 5958967.20 183.21S 63.00E 3.00 180.95 560734.78 5958946.51 205.11S 66.81E 3.00 202.70 560738.77 5958924.64 252.38S 74.76E 3.00 249.68 560747.10 5958877.44 304.16S 83.11E 3.00 301.14 560755.87 5958825.73 360.32S 91.84E 3.00 356.96 560765.06 5958769.65 420.68S 100.94E 3.00 416.99 560774.65 5958709.37 485.10S 110.37E 3.00 481.05 560784.60 5958645.03 553.40S 120.11E 3.00 548.96 560794.90 5958576.83 625.37S 130.13E 3.00 620.56 560805.50 5958504.94 700.84S 140.41E 3.00 695.63 560816.39 5958429.57 779.59S 150.92E 3.00 773.98 560827.54 5958350,91 861.41S 161.62E 3.00 855,38 560838.90 5958269.19 946.07S 172.49E 3.00 939.62 560850.46 5958184.63 1033.34S 183.50E 3.00 1026.46 560862.18 5958097.46 1122.98S 194.62E 3.00 1115.67 560874.03 5958007.92 1133.41S 195.90E 3.00 1126.05 560875.39 5957997.50 1395.93S 228.13E 0.00 1387,32 560909.75 5957735.28 1416.88S 230.71E 0.00 1408.16 560912.50 5957714.36 1487.00S 238.53E 1.50 1477.97 560920.89 5957644.31 1578.29S 246.40E 1.50 1568.94 560929.50 5957553.10 1669.74S 251.65E 1.50 1660,16 560935.49 5957461.70 1761.30S 254.28E 1.50 1751.57 560938.87 5957370.17 1852.90S 254.30E 1,50 1843.12 560939.63 5957278.59 1944.48S 251.70E 1.50 1934,73 560937.78 5957187.00 2035.97S 246.48E 1.50 2026.35 560933.31 5957095.47 2058.82S 244.77E 1.50 2049.25 560931.78 5957072.61 2310.15S 225.04E 0.00 2301.11 560914.09' 5956821.15 2767.12S 189.16E 0.00 2759.03 560881.93 5956363.95 3109.96S 162.24E 0.00 3102.59 560857.81 5956020.94 3224.08S 153.28E 0.00 3216.95 560849.78 5955906.76 3681.04S 117.41E 0.00 3674.88 560817.62 5955449.56 4100.56S 84.47E 0.00 4095.27 560788.09 5955029.83 4138.01S 81.53E 0.00 4132.80 560785.46'5954992.37 4558.11S 48.55E 0.00 4553.78 560755,89 5954572.05 4594.97S 45.65E 0.00 4590.72 560753.30 5954535.17 All data in feet unless otherwise stated. Calculation uses minimum curvature method. Coordinates from slot ~40 and TVD from RKB(Nabors 16E) (106.00 Ft above mean sea level). Bottom hole distance is 9457.58 on azimuth 182.03 degrees from wellhead. Total Dogleg for wellpath is 79.12 degrees. Vertical section is from wellhead on azimuth 181.96 degrees. Grid is alaSka - Zone 4. Grid coordinates in FEET and computed using the Clarke - 1866 spheroid Presented by Baker Hughes INTEQ PHILLIPS Alaska, Inc. Pad 1D,40 Kuparuk River Unit,North Slope, A1 aska Measured Inclin Azimuth True Vert R E C TAN G U L A R Depth Degrees Degrees Depth C 0 0 R D I N AT E S 7362,69 66,45 184,49 4405,00 4926,44S 19,63E 7500.00 66.45 184,49 4459.86 5051.93S 9.78E 8000,00 66,45 184,49 4659,60 5508,90S 26,10W 8500.00 66,45 184,49 4859.34 5965,86S 61,98W 9000,00 66,45 184,49 5059,08 6422,82S 97.86W 9500,00 66,45 184,49 5258,83 6879,79S 133,73W 9685,67 66,45 184,49 5333,00 7049,48S 147.06W 10000,00 66.45 184.49 5458,57 7336,75S 169.61W 10268.92 66.45 184,49 5566,00 7582,53S 188.91W 10500,00 66.45 184,49 5658,31 7793,72S 205,49W 11000,00 66,45 184,49 5858,06 8250,68S 241,37W 11009.87 66,45 184,49 5862,00 8259,70S 242,08W 11014,88 66,45 184,49 5864,00 8264,28S 242,43W 11375,34 66,45 184,49. 6008,00 8593,72S 268,30W 11500,00 66,45 184,49 6057,80 8707,64S 277.24W 11560,58 66,45 184,49 6082,00 8763,01S 281,59W 11788,38 66,45 184,49 6173,00 8971,20S 297,94W 11998,65 66,45 184,49 6257,00 9163,37S 313,02W 12000,00 66,45 184,49 6257,54 9164,61S 313,12W 12011,16 66,45 184,49 6262,00 9174,81S 313,92W 12048,71 66,45 184,49 6277,00 9209,12S 316,62W 12078,75 66,45 184,49 6289,00 9236,58S 318.77W 12116,30 66,45 184.49 6304,00 9270,89S 321,47W 12126,31 66,45 184,49 6308,00 9280,04S 322,19W 12314,05 66,45 184,49 6383,00 9451,63S 335,66W PROPOSAL LISTING Page 2 Your ref : 40 Version #1 Last revised : 25-Jul-2000 Dogleg Vert G R I D C 0 0 R D S Deg/lOOft Sect Easting Northing 0,00 4922,89 560729,97 5954203,53 0.00 5048.65 560721.14 5954077.97 0,00 5506.57 560688,98 5953620,78 0,00 5964,49 560656,83 5953163,58 0,00 6422,41 560624,67 5952706,38 0,00 6880,34 560592,51 5952249,19 0.00 7050,38 560580,57 5952079,41 0.00 7338.26 560560,35 5951791,99 0.00 7584.55 560543,05 5951546.09 0,00 7796,18 560528,19 5951334,80 0,00 8254,11 560496,03 5950877,60 0,00 8263,15 560495.40 5950868.57 0.00.8267,74 560495,08 5950863,99 0,00 8597,87 560471,89 5950534,39 0.00 8712,03 560463,88 5950420,40 0,00 8767.51 560459,98 5950365,01 0,00 8976.14 560445,33 5950156,71 0,00 9168,71 560431,80 5949964,44 0,00 9169,95 560431,72 5949963,21 0,00 9180,18 560431,00 5949953,00 0,00 9214,56 560428,58 5949918,67 0.00 9242.08 560426,65 5949891.20 0,00 9276,46 560424,24 5949856,87 0,00 9285,63 560423,59 5949847,71 0.00 9457.58 560411.52 5949676,04 .RECEIVED All data in feet unless otherwise stated, Calculation uses minimum curvature method, Coordinates from slot~O and TVD from RKB(Nabors 16E) (106,00 Ft above mean sea level), Bottom hole distance is 9457.58 on azimuth 182,03 degrees from wellhead, Total Dogleg for wellpath is 79,12 degrees. Vertical section is from wellhead on azimuth 181.96 degrees, Grid is alaska - Zone 4, Grid coordinates in FEET and computed using the Clarke - 1866 spheroid Presented by Baker Hughes INTEQ PHILLIPS Alaska, Inc. Pad 1D,40 Kuparuk River Unit,North Slope, Alaska PROPOSAL LISTING Page 3 Your ref : 40 Version #1 Last revised : 25-Jul-2000 Comments i n wel 1 path MD TVD Rectangul ar Coords. Comment ........ ........ ........................................................... 1000.00 999.96 O.OON 2.94E Begin Build & Turn 1629.54 1617.00 100.92S 45.86E Base of Permafrost 3211.48 2745.82 1133.41S 195.90E EOC 3523.02 2870.29 1416.88S 230.71E Begin Right Turn 4225.00 3151.54 2058.82S 244.77E EOC 5375.13 3611.00 3109.96S 162.24E Top of West Sak 6459.02 4044.00 4100.56S 84.47E Base of West Sak 6959.67 4244.00 4558.11S 48.55E 9-5/8" Casing Pt 7362.69 4405.00 4926.44S 19.63E C80 (KiO) 9685.67 5333.00 7049.48S 147.06W C50 10268.92 5566.00 7582.53S 188.91W C40 (K-5) 11009.87 5862.00 8259.70S 242.08W Top HRZ 11014.88 5864.00 8264.28S 242.43W C30 (K-2) 11375.34 6008.00 8593.72S 268.30W C20-HRZ Midpoint 11560.58 6082.00 8763.01S 281.59W 7" Csg Pt-Base HRZ 11788.38 6173.00 8971.20S 297.94W K-1 Marker 11998.65 6257.00 9163.37S 313.02W Top Kuparuk D 12011.16 6262.00 9174.81S 313.92W Target-Top C4 12048.71 6277.00 9209.12S 316.62W Top C3 12078.75 6289.00 9236.58S 318.77W Top C2 12116.30 6304.00 9270.89S 321.47W Top C1 12126.31 6308.00 9280.04S 322.19W Top B Shale 12314.05 6383.00 9451.63S 335.66W TD - Casing Pt Casing positions in string 'A' Top MD Top TVD RectangUlar Coords. Bot MD Bot TVD Rectangular Coords. Casing 0.00 0.00 O.OON O.OOE 6959.67 4244.00 4558.11S 48.55E 9 5/8" Casing. 0.00 0.00 O.OON O.OOE 11560.58 6082.00 8763.01S 281.59W 7" Casing 0.00 0.00 O.OON O.OOE 12314.00 6382.98 9451.58S 335.65W 3 1/2" Liner Targets associated with this wellpath Target name Geographic Location T.V.D. Rectangul ar Coordinates Revised ........ ...... ...... ....... RE ,E VED PHILLIPS Alaska, Inc. Pad 1D,40 Kuparuk River Unit,North Slope. Alaska Measured Inclin. Azimuth True Vert R E C T Depth Degrees Degrees Depth C 0 0 R PROPOSAL LISTING Page 1 Your ref : 40 Version#1 Last revised : 25-Jul-2000 A N G U L A R Vert Ellipse Semi Axes Minor D I N A T E S Sect Major Minor Vert. Azi. 0.00 0.00 0.00 0.00 0.00 N 0.00 E 0.00 0.00 0.00 0.00 N/A 500.00 0.00 0.00 500.00 0.00 N 0.00 E 0.00 1.31 1.31 0.75 N/A 850.00 0.00 0.00 850.00 0.00 N 0.00 E 0.00 2.22 2.22 1.28 N/A 900.00 0.75 90.00 900.00 0.00 N 0.33 E -0.01 2.35 2.35 1.35 N/A 1000.00 2.25 90.00 999.96 0.00 N 2.94 E -0.10 2.62 2.61 1.50 N/A 1100.00 4.11 135.61 1099.82 2.56 S 7.41 E 2.30 2.90 2.87 1.65 298.11 1200.00 6.83 149.26 1199.36 10.23 S 12.96 E 9.78 3.23 3.14 1.80 314.45 1300.00 9.72 155.00 1298.31 23.00 S 19.57 E 22.31 3.65 3.42 1.95 323.42 1400.00 12.63 158.71 1396.40 40.84 S 27.11E 39.89 4.22 3.71 2.11 329.02 1450.00 14.10 160.00 1445.04 51.66 S 31.18 E 50.56 4.56 3.86 2.19 330.89 1500.00 15.51 162.03 1493.38 63.75 S 35.32 E 62.50 4.94 4.01 2.27 332.65' 1600.00 18.37 165.16 1589.04 91.70 S 43.49 E 90.16 5.86 4.34 2.45 336.05 1629.54 19.22 165.92 1617.00 100.92 S 45.86 E 99.29 6.19 4.44 2.50 336.86 1700.00 21.27 167.48' 1683.11 124.65 S 51.45 E 122.81 6.97 4.69 2.63 338.78 1800.00 24.19 169.25 1775.33 162.48 S 59.21 E 160.36 8.28 5.06 2.83 341.01 1850.00 25.65 170.00 1820.68 183.21S 63.00 E 180.95 8.98 5.26 2.94 341.93 1900.00 27.15 170.24 1865.46 205.11 S 66.81 E 202.70 9.74 5.46 3.05 342.73 2000.00 30.14 170.66 1953.21 252.38 S 74.76 E 249.68 11.42 5.89 3.30 344.13 2100.00 33.14 171.00 2038.34 304.16 S 83.11E 301.14 13.28 6.34 3.59 345.25 2200.00 36.13 171.30 2120.61 360.32 S 91.84 E 356.96 15.31 6.81 3.92 346.15 2300.00 39.13 171.56 2199.79 420.68 S 100.94 E 416.99 17.50 7.31 4.30 346.90 2400.00 42.13 171.78 2275.68 485.10 S 110.37 E 481.05 19.85 7.81 4.73 '347.53 2500.00 45.12 171.98 2348.06 553.40 S 120.11 E 548.96 22.35 8.32 5.22 348.06 2600.00 48.12 172.16 2416.74 625.37 S 130.13 E 620.56 24.99 8.84 5.76 348.52 2700.00 51.12 172.33 2481.52 700.84 S 140.41 E 695.63 27.76 9.35 6.36 348.93 2800.00 54.11 172.48 2542.23 779.59 S 150.92 E 773.98 30.65 9.86 7.02 349.28 2900.00 57.11 172.62 2598.70 861.41 S 161.62 E 855.38 33.66 10.35 7.73 349.59 3000.00 60.11 172.75 2650.78 946.07 S 172.49 E 939.62 36.77 10.83 8.50 349.87 3100.00 63.11 172.87 2698.32 1033.34 S 183.50 E 1026.46 39.98 11.29 9.32 350.12 3200.00 66.11 172.99 2741.20 1122.98 S 194.62 E 1115.67 43.27 11.72 10.19 350.35 3211.48 66.45 173.00 2745.82 1133.41S 195.90 E 1126.05 43.65 11.77 10.29 350.37 3500.00 66.45 173.00 2861.10 1395.93 S 228.13 E 1387.32 53.20 12.99 12.85 350.86 3523.02 66.45 173.00 2870.29 1416.88 S 230.71 E 1408.16 53.96 13.09 13.05 350.89 3600.00 66.41 174.26 2901.08 1487.00 S 238.53 E 1477.97 56.48 13.42 13.74 351.04 3700.00 66.37 175.90 2941.13 1578.29 S 246.40 E 1568.94 59.70 13.84 14.64 351.31 3800.00 66.35 177.53 2981.23 1669.74 S 251.65 E 1660.16 62.86 14.26 15.54 351.63 3900.00 66.35 179.17 3021.35 1761.30 S 254.28 E 1751.57 65.98 14.69 16.43 351.99 4000.00 66.36 180.81 3061.46 1852.90 S 254.30 E 1843.12 69.05 15.11 17,33 352.40 4100.00 66.39 182.44 3101.54 1944.48 S 251.70 E 1934.73 72.07 15.53 18.24 352.83 4200.00 66.44 184.08 3141.55 2035.97 S 246.48 E 2026.35 75.07 15.95 19.14 353.30 4225.00 66.45 184.49 3151.54 2058.82 S 244.77 E 2049.25 75.82 16.06 19.37 353.41 4500.00 66.45 184.49 3261.40 2310.15 S 225.04 E 2301.11 84.13 17.23 21.86 354.56 5000.00 66.45 184.49 3461.14 2767.12 S 189.16 E 2759.03 99.53 19.37 26.40 356.17 5375.13 66.45 184.49 2611.00 2109.96 S 162.24 E 3102.59 111,27 20.98 29.81 357.06 5500,00 66.45 184.49 3660.88 3224.08 S 153.28 E 3216.95 115.18 21.51 30.95 357.36 6000.00 66.45 '184.49 3860.63 3681.04 S 117.41 E 3674.88 130.99 23.64 35.50 358.26 6459.02 66.45 184.49 4044.00 4100.56 S 84.47 E 4095.27 145.61 25.58 39.68 358.91 6500.00 66.45 184.49 4060.37 4138.01S 81.53 E 4132.80 146,91 25.75 40.06 358.97 6959.67 66.45 184.49 4244.00 4558.11S 48.55 E 4553.78 161.62 27.69 44.25 359.49 7000.00 66.45 184.49 4260.11 4594.97 S 45.65 E 4590.72 162.91 27.86 44.62 359.54 · All data is in feet unless otherwise stated. Coordinates from slot/~40 and TVD from RKB(Nabors 16E) (106.00 Ft above mean sea Bottom hole distance is 9457.58 on azimuth 182.03 degrees from wellhead. Vertical section is from wellhead on azimuth 181.96 degrees. Calculation uses the minimum curvature method. Presented by Baker Hughes INTEQ PHILLIPS Alaska, Inc, Pad 1D,40 Kuparuk River Unit,North Slope, Alaska Measured Inclin. Azimuth True Vert R E C T Depth Degrees Degrees Depth C 0 0 R 7362,69 66,45 184,49 4405,00 4926,44 7500.00 66,45 184.49 4459,86 5051,93 8000.00 66,45 184,49 4659.60 5508.90 8500,00 66.45 184,49 4859,34 5965.86 9000,00 66,45 184.49 5059,08 6422,82 9500.00 66.45 184.49 5258.83 6879,79 9685,67 66.45 184,49 5333,00 7049,48 10000.00 66.45 184,49 5458,57 7336,75 10268.92 66.45 184,49 5566.00 7582,53 10500,00 66,45 184,49 5658,31 7793,72 11000,00 66,45 184,49 5858,06 8250,68 11009,87 66,45 184,49 5862,00 8259,70 11014.88 66.45 184.49 5864,00 8264,28 11375,34 66,45 184,49. 6008,00 8593,72 11500,00 66.45 184,49 6057,80 8707,64 -- 11560,58 66,45 184,49 6082,00 8763,01 11788,38 66,45 184,49 6173,00 8971,20 11998,65 66,45 184,49 6257,00 9163,37 12000,00 66.45 184,49 6257,54 9164,61 12011,16 66,45 184,49 6262,00 9174,81 12048,71 66,45 184,49 6277,00 9209,12 12078,75 66.45 184,49 6289,00 9236,58 12116,30 66,45 184,49 6304,00 9270,89 12126,31 66,45 184,49 6308,00 9280,04 12314,05 66,45 184,49 6383,00 9451,63 ANGULAR DINATES PROPOSAL LISTING Page 2 Your ref : 40 Version#1 Last revised : 25-Jul-2000 Vert Ellipse Semi Axes Minor Sect Major Minor Vert. Azi. S 19,63 E 4922,89 S 9,78 E 5048.65 S 26.10 W 5506.57 S 61,98 W 5964,49 S 97.86 W 6422.41 S 133,73 W 6880,34 S 147.06 W 7050,38 S 169.61W 7338,26 S 188.91 W 7584.55 S 205,49 W 7796,18 S 241,37 W 8254,11 S 242,08 W 8263,15 S 242,43 W 8267,7~ S 268,30 W 8597.87 S 277,24 W 8712,03 S 281,59 W 8767,51 S 297,94 W 8976,14 S 313,02 W 9168,71 S 313.12 W 9169,95 S 313,92 W 9180,18 S 316.62 W 9214,56 S 318,77 W 9242.08 S 321,47 W 9276,46 S 322,19 W 9285,63 S 335,66 W 9457,58 174,55 29,39 47,92 359,87 178,96 29.97 49,18 0,00 195.06 32,08 53.74 0.39 211,18 34,18 58,30 0,71 227.34 36,28 62,87 0,99 243.51 38.37 67.43 1.23 249.52 39,15 69,13 1,31 259.70 40,47 72,00 1,44 268,41 41.60 74.45 1,54 275,90 42,57 76.56 1,63 292,12 44,67 81,13 1,79 292,44 44.71 81,22 1,79 292,60 44.73 81.27 1,80 304,30 46,24 84,56 1,90 308,34 46,76 85,70 1.94 310,31 47.02 86,25 1.95 317,70 47,97 88.33 2.01 324.53 48,86 90,25 2,07 324,57 48,86 90,26 2.07 324,94 48.91 90,36 2,07 326.15 49,07 90,71 2,08 327,13 49,19 90.98 2,09 328,35 49,35 91,32 2,10 328,67 49,39 91.42 2,10 334,77 50,18 93,13 2,15 POSITION UNCERTAINTY SUMMARY Depth Position Uncertainty From To Survey Tool Error Model Major Minor Vert, 0 12314 ARCO (H,A, Mag) User specified 334,77 50,18 93,13 1. Ellipse dimensions are half axis. 2. Casing dimensions are not included. 3. Ellipses are calculated on 2.58 standard deviations. 4. Uncertainty calculations start at drill depth zero. 5. Surface position uncertainty is not included. 6. Where two surveys are tied together the errors of one are considered to have a systematic relationship to the corresponding errors of the other. 7. Detailed description of the INTEQ error models can be found in the Ec*Trak manual. Anchorage All data is in feet unless otherwise stated. Coordinates from slot~40 and TVD from RKB(Nabors 16E) (106,00 Ft above mean sea level), Bottom hole distance is 9457,58 on azimuth 182.03 degrees from wellhead. Vertical section is from wellhead on azimuth 181,96 degrees, Calculation uses the minimum curvature method, Presented by Baker Hughes INTEQ PHILLIPS Alaska. Inc. Pad 1D.40 Kuparuk River Unit,North Slope. Alaska PROPOSAL LISTING Page 3 Your ref : 40 Version #1 Last revised : 25-Jul-2000 Comments i n wel 1 path MD TVD Rectangul ar Coords. Comment ....... ....... ........................................................... 1000.00 999.96 0.00 N 2.94 E Begin Build & Turn 1629.54 1617.00 100.92 S 45.86 E Base of Permafrost 3211.48 2745.82 1133.41 S 195.90 EEOC 3523.02 2870.29 1416.88 S 230.71E Begin Right Turn 4225.00 3151.54 2058.82 S 244.77 E EOC 5375.13 3611.00 3109.96 S 162.24 E Top of West Sak 6459.02 4044.00 4100.56 S 84.47 E Base of West Sak 6959.67 4244.00 4558.11S 48.55 E 9-5/8" Casing Pt 7362.69 4405.00 4926.44 S 19.63 E C80 (KiO) 9685.67 5333.00 7049.48 S 147.06 W C50 10268.92 5566.00 7582.53 S 188.91W C40 (K-5) 11009.87 5862.00 8259.70 S 242.08 W Top HRZ 11014.88 5864.00' 8264.28 S 242.43 W C30 (K-2) 11375.34 6008.00 8593.72 S 268.30 W C20-HRZ Midpoint 11560.58 6082.00 8763.01S 281.59 W 7" Csg Pt-Base HRZ 11788.38 6173.00 8971.20 S 297.94 W K-1 Marker 11998.65 6257.00 9163.37 S 313.02 W Top Kuparuk D 12011.16 6262.00 9174.81S 313.92 W Target-Top C4 12048,71 6277.00 9209.12 S 316.62 W Top C3 12078.75 6289.00 9236.58 S 318.77 W Top C2 12116.30 6304.00 9270.89 S 321.47 W Top C1 12126.31 6308.00 9280.04 S 322.19 W Top B Shale 12314.05 6383.00 9451.63 S 335.66 W TD - Casing Pt Casing positions in string 'A' Top MD Top TVD Rectangular Coords. Bot MD Bot TVD Rectangular Coords. Casing 0.00 0.00 O.OON O.OOE 6959.67 4244.00 4558.11S 48.55E 9 5/8" Casing. 0.00 0.00 O.OON O.OOE 11560.58 6082.00 8763.01S 281.59W 7" Casing 0.00 0.00 O.OON O.OOE 12314.00 6382.98 9451.58S 335.65W 3 1/2" Liner Targets associated with this wel 1 path Target name Geographic Location T.V.D. Rectangular Coordinates Revised PHILLIPS Alaska, Inc. Pad 1D 40 slot ~0 Kuparuk River Unit North Slope, Alaska SUMMARY CLEARANCE REPORT by Baker Hughes INTEQ Your ref : 40 Version #1 Our ref : prop1837 License : Date printed : 25-Jul-2000 Date created : 15-0ct-1996 Last revised : 24-Jul-2000 Field is centred on n70 16 18.576,w150 5 56.536 Structure is centred on n70 18 1.316,w149 30 18.908 Slot location is n70 17 56.035,w149 30 31.181 Slot Grid coordinates are N 5959129.177, E 560670.303 Slot local coordinates are 537.00 S 421.00 W Projection type: alaska - Zone 4, Spheroid: Clarke - 1866 Reference North is True North Object wellpath PMSS<245-5962'>DepthShifted,,110,Pad 1D PMSS <5155'- 5905'>,,110A,Pad 1D PMSS <O-4590'>,,118,Pad 1D 139 <PMSS 515 - 4838'>,,139,Pad 1D 139 <GSS 0 - 475'>,,139,Pad 1D PGMS <0-8930'>,,5,Pad ID PMSS <0-5126'>,,106,Pad 1D PMSS <381-6092'>,,105,Pad 1D PGMS <O-9783'>,,2,Pad 1D PMSS <1957-5265'>,,133,Pad 1D PMSS <O-3252'>,,133,Pad 1D PMSS <467 - 5802'>,,132,Pad 1D PMSS <0 - 6472'>,,131,Pad 1D PMSS <0-4778'>,,130,Pad 1D MSS <3311-8200'>,,7,Pad 1D PMSS <0-5462'>,,129,Pad 1D PMSS <O-4515'>,,119,Pad 1D PGMS <O-8070'>,,3,Pad 1D PMSS <0-4530'>,,120,Pad 1D PMSS <0 - 6716'>,,126,Pad 1D PMSS <0 - 7432'>,,127,Pad 1D PMSS <0 - 6580'>,,128,Pad 1D PMSS <0 - 5445'>,,122,Pad 1D GSS <O-173'>,,123,Pad 1D PMSS <287-6055'>,,123,Pad 1D GSS <O-175'>,,116,Pad 1D PMSS <290-6245'>,,116,Pad 1D Closest approach with 3-D Last revised Distance 17-May-2000 17-May-2000 2-Jun-1998 18-May-2000 18-May-2000 13-Nov-1997 2-Jun-1998 2-Jun-1998 4-Aug-1992 2-Jun-1998 2-Jun-1998 6-Aug-1998 23-Ju1-1998 2-Jun-1998 6-Nov-1997 2-Jun-1998 2-Jun-1998 13-Aug-1998 2-Jun-1998 1-Ju1-1998 6-Ju1-1998 17-Aug-1998 29-Aug-1998 4-Sep-1998 13-Sep-1998 8-Sep-1998 17-Sep-1998 606.8 606.8 462.7 219.0 219.0 343.0 664.2 692.5 678.1 198.6 198.6 205.5 213.3 220.4 187.9 231.0 424.6 563 2 411 1 295 6 283 8 272 2 384 2 370 7 369 8 493.5 493.5 Minimum Distance method M.D, 100.0 100.0 875.0 120.0 120.0 640.0 100 0 300 0 420 0 100 0 100 0 100 0 100.0 580.0 440.0 100.0 380.0 862.5 100.0 100.0 100.0 100.0 100.0 160.0 280.0 100.0 100.0 Diverging from M.D. 100.0 100.0 875.0 1669.8 120.0 640.0 875.0 300.0 420.0 4320.0 3380.0 5180.0 100.0 580.0 440.0 100.0 380.0 862.5 1011 100 100 100 lO0 160 28O lO0 100.0 PMSS <0-5047'>,,124,P( ~D PMSS <291 - 5795'>,,125,Pad 1D PGMS <O-8365'>,,1,Pad 1D PMSS <0 - 7150'>,,108,Pad 1D PMSS <O-4850'>,,109,Pad 1D PMSS<O-7045'>,,111,Pad 1D PMSS <0-9250'>,,12,Pad 1D PMSS <O-8702'>,,14,Pad 1D PMSS <556-7024'>,,9,Pad 1D PMSS <294 - 8250'>,,112,Pad 1D PMSS <293 - 6866'>,,113,Pad 1D PMSS <0 - 6270'>,,114,Pad 1D PMSS <O-5142'>,,115,Pad 1D 2-Jun-1998 19-Aug-1998 10-Dec-1997 28-0ct-1998 2-Jun-1998 3-Sep-1998 21-Jan-2000 6-0ct-1999 29-Apr-1998 21-Sep-1998 22-Sep-1998 2-Sep-1998 2-Jun-1998 PGMS <0-8850'> 28-May-81,,MP I 17-ii-Ii,Pad 1D 23-Apr-1999 PMSS <4674'-5639'>,,125A,Pad 1D PMSS <O-5205'>,,117,Pad 1D PMSS <256 - 5973'>,,1lO,Pad 1D PMSS <0 - 7340'>,,lO,Pad 1D PGMS <0 - 6400'>,,WS-8,Pad 1D PGMS <O-7502'>,,4,Pad 1D PMSS <O-1288'>,,138PB1,Pad 1D PMSS <0-6543'>,,138,Pad 1D 136 PMSS <519 - 5680'>,,136,Pad 1D 137 PMSS <0 - 5615'>,,137,Pad 1D PGMS <0-8610'>,,6,Pad 1D PMSS <0-5015'>,,135,Pad 1D PMSS <0-11234'>,,11,Pad 1D PMSS <0-7378'> Sperry,,lO2,Pad 1D L1PMSS <4338-7400'> Sperry,,lO2L1,Pad 1D PMSS <O-4414'>,,121,Pad 1D PMSS <377 - 6224'>,,134,Pad 1D PMSS <0-14324'>,,38,Pad 1D PMSS <O-????'>,,30,Pad 1D 24-Apr-2000 2-2un-1998 24-Apr-2000 28-Apr-1998 27-Apr-2000 4-Aug-1992 18-May-2000 18-May-2000 5-Jun-2000 2-Jun-2000 13-Nov-1997 2-~un-1998 30-Dec-1999 26-~un-2000 27-~un-2000 2-~un-1998 3-Aug-1998 24-Jul-2000 25-~ul-2000 320.1 307.7 793.7 635.6 621.2 592.4 770.4 766.0 438.3 549.6 535.7 519.9 507.5 8364.9 307.7 479.5 606.8 80.3 185.7 450.1 208.0 202.3 125.2 203.8 163.0 52.1 150.8 651.3 651.3 397.6 181.7 28.8 148.2 100.~ 100.0 640.0 100.0 100.0 100.0 1044.4 100.0 100.0 100.0 100.0 640.0 160.0 3066.7 100.0 100.0 100.0 1055.6 862.5 760.0 875.0 840.0 1700.0 240.0 2333.3 1522.2 942.9 2377.8 2377.8 100.0 260.0 520.0 660.0 100.0 100.0 900.0 100.0 100.0 300.0 1044.4 100.0 914.3 100.0 100.0 640.0 160.0 3066.7 100.0 100.0 100.0 1055.6 862.5 760.0 1300.0 840.0 1700.0 4240.0 2333.3 1522.2 942.9 4940.0 5440.0 1011.1 6000.0 520.0 660.0 LEAK OFF TEST PROCEDURE( Kuparuk River Unit (KRU) Operations . After cementing casing and nippling up BOPE, RIH to top of cement and pressure test the casing to 3000 psi for 30 minutes and record on chart (AOGCC required casing integrity test). Record the information on the AAI LOT form (you can locate on the drilling web page). Plot Casing Pressure Test (volume vs. pressure and time holding pressure on casing). Verify that the test indicates a linear line and that there is no air entrained in the mud. Repeat Casing pressure test if needed. 2. Drill 20' of new hole below the casing shoe. . Circulate the hole to establish a uniform mud density throughout the system (required for a good FIT or LOT). PU into the shoe. 4. Close the blowout preventer (ram or annular). 5. Pump down the drill stem at 1/4 to 1/2 bpm. . On the LOT form, plot the fluid pumped (volume or strokes) vs. drill pipe pressure until the formation begins to take fluid; at this point the pressure will continue to rise, but at a slower rate. Note: If 16.0 ppg EMW is reached, shut down and hold the pressure there. This becomes the data for a formation integrity test (FIT) instead of a LOT 7. At leak off pump 3 bbls of mud into formation prior to shutting down the pump. Shut down when the leak-off point is clearly seen and 3 bbls of mud has been pumped into the formation. Record initial shut-in pressure. With the pump shut down monitor, record and report the shut -in pressures for a minimum of 10 minutes or until the shut -in pressure stabilizes. Record time vs. pressure in 1-minute intervals and plot information. Bleed the pressure off and record the fluid volume recovered. Forward the data to the Drilling Engineer in Anchorage. The Drilling Engineer will forward the information to the Agencies. R :CL TAB, 7/7/00 PHILLIPS Alaska, Inc. Subsidiary of PHILLIPS PETROLEUM COMPANY Diverter Schematic Nabors 16E Flowline 21 lA" 2,000 psi WP DRILLING SPOOL w/16" Outlet 211,4" HYDRIL MSP 2,000 psi WP ANNULAR PREVENTER 16" 200 psi WP HYDRAULIC KNIFE VALVE 16" OD DIVERTER LINE 16" 62 ppf PEB CONDUCTOR PIPE set at 80' (GL) ~,ECE~VED PHILLIPS Alaska, Inc. A Subsidiary of PHILLIPS PETROLEUM COMPANY Nabors #16E 13-5/8" 5,000 PSI BOP COMPONENTS I I 3" 5,000 psi WP OCT r-j MANUAL GATE V KILL LINE 3" 5,000 psi WP Shaffer GATE VALVE 1 w/hydraulic actuator / J / DSA 13-5/8" 5,000 psi WP '"'~L x 11" 3,000 psi WP 13-5/8" 5,000 psi WP, HYDRIL Type GK ANNULAR PREVENTER w/companion flange to bell nipple CHOKE LINE A~ch0ra§e -. ! I NOTES / ~ ~_y ' I. COORDINATES SHOWN ARE A.S.P. ZONE 4, N.A.D. 27. ELEVATiONS SHO~ A~ ~iTI~ ~TR~EUM MEAN ~ d SEA LEAL. ALL DISTilS ~0~ ARE ~UE. ~ ~ ~-~ MONUMEN~ ~R LH~ ANO ASS~iA ~ 4. CONDUCTUS ARE LO~ ~IN P~AC~D ~CTI~ ~/~z/ee. Fa L~-r~ P~ ~3. ~/~-~/~. ~. L~e-Z~ I~5, I~6, I~9,115. l ~7-121,124,129.1~, 13J · 135; 22 y CEA-DIDX-61~4DIJ F~ C~DUCT~S 9 · I~ ~-o~ox-~o,~ ~ CONOUCrORS ~8. ~-~. ,~. WCINI~ MAP FOR CONOUCT~S 1~ ANO 18-21. Sec. 23, ~ 11 N., R. 1~ E. No. Y X Lotitude Longitude FN.L. F.E.L. Pod O.G. ,,, 28 5,959,3~9.2~ 568,67~.72 7~ ~7' 5Z8~5' 749" 3~' 3~.I26' 357" 4~9' 7~.9' 6Z2" 3~ 5,959,279.~ 56B, 67~.9~ 7~" I~ 5Z5~8' 149" 3~* 31.~28' ~ 419' 7~.9" 6~.~ 32 5,959,249.~9 56~,67~.66 7~" 17' 57.214' 149" 3~ 3~.142" 4~ 42~ 7~.9' 68.9' 34 5,959,2~8.83 56~,67~.62 7~ l~ 56.916' 149" 3~' 31.~5~" 44~ 42~ 7~.9' 69.6' 36 5,959,188.94 56~,67~.73 7~" ~ 56.622' 149" 3~' 38 5,959,~59.~4 ~,67~.82 7~" I~ 56.328' 749" 3~' 4~ 5,959, I28.85 56~,67~.87 7~" 17' 56.83~' ~49" 3~" 3~.164~ 537' 421' 7~.9' 64.~ ', 42 5,959,~99.2~ 56~,67~'81 7~" 17' 55.74~' ~49" 3~' 3~.173' 567' 42~' 7~.9" 64.6' .~ ~ ~'%~ SUR~YOR'S CERTIFICATE ~x~ ~ ~" ........~~'-'~ I HEREBY CERTIFY THAT I AM PROPERLY REGISTEREO ~ND ~g~h~ ~ ........... ~ OIMENSIONS AND OTHER DETAILS ~RE CORRECT AS OF JUNE ~ 2000. LOUNSBURY .......... " ~ ASSOCIATES. INC. AREA: 1D XXXX UNIT: ~ DS1D ' ASBUlLT LOCA~ONS Rood - i r -- ---"' , 12 14 ~ 1~2 2 DS-1E 1 ,--, ~~ U~ ~ ~ DS-lO ~u ~ 14.13 ~2~ o 23~2~ ~ ,,~ "~ ~ VICINITY MAP 117 ~ 4 I SCALE: ~' = I MILE Ilg 122~ 121 123 , 125~ 124 · u?:,~8~26 N ~ ~? ' ~ 28 ~ 129 · ~e ~ ~ ,~ ~32 ~ 34 133~ 2! ~ u ~ 42 . . LEGEND SEE SHEET ~ 2 [OR NOTES ~0 LOC~T~ON INFOR~TIOH , o ~x/sr,~ co~oucro~s ~~. LOUNSBURy · "~5'8o;~ r' CONDUCTOR LOCATION~[~ a ASSOCIATES, INC. ~ENGINEE~ P~NNE~ '~E[A: 10 XXXX UNI~: ARCO Alaska, Inc ASSUILT LOCA~ONS CADD FILE NO. [ "' [ DRAWING .0: m ! ~EET,: iREV~ LK~e.02~ ~/~7/2eee ..... CEA-D1DX-61e4D28 , ~ o~ 2 e.' CASH ADVANCE DRAFT 116 D FOR AlqOUNT OVER $ 1000 BROWN WELL PERMIT CHECKLIST COMPANY .~'//, ~o.5 WELL NAME /.Z) -~/'4~) PROGRAM: exp ~ FIELD & POOL 47'/('~)/~--.)i~) INIT CLASS (/ ,~'/-~,/.4/'~' GEOL AREA ADMINISTRATION A~ DATE 1. Permit fee attached ....................... 2. Lease number appropriate ................... 3. Unique well name and'number .................. 4. Well located in a defined pool .................. 5. Well located proper distance from drilling unit boundary .... 6. Well located proper distance from other wells .......... 7. Sufficient acreage available in drilling unit ............ 8. If deviated, is wellbore plat included ............... 9. Operator only affected party ................... 10. Operator has appropriate bond in force ............. 11. Permit can be issued without conservation order ........ 12. Permit can be issued without administrative approval ...... 13. Can permit be approved before 15-day wait ........... ENGINEERING 14. Conductor string provided ................... 15. Surface casing protects all known USDWs ........... 16. CMT vol adequate to circulate on conductor & surf csg ..... 17. CMT vol adequate to tie-in long string to surf csg ........ 18. CMT will cover all known productive horizons .......... 19. Casing designs adequate for C, T, B & permafrost ....... 20. Adequate tankage or reserve pit ................. dev redrll serv v/ wellbore seg. ann. disposal para req ,,"~ _~4~ UNIT# (~ / //~z:>(~) ON/OFF SHORE ~ 21. 22. 23. 24. 25. DATE 26. */,.% 27. 28. 29. GEOLOGY 30. 31. 32. ;~R DATE 33. ~, .~ ,(~C) 34. re-drill, has a 10-403 for abandonment been approved... .Y ~daequate wellbore separation proposed ............. If diverter required, does it meet regulations .......... ~ ) N ' ' Drilling fluid program schematic & equip list adequate ..... BOPEs, do they meet'regulation ................ ~ ) N _ ' BOPE press rating appropriate; test to ..~;~C3~ psig. Choke manifold complies w/APl RP-53 (May 84) ..... (~) N ' ~ ~ ' Work will occur without operation shutdown ........ ~ Is presence of H2S gas probable ................. ~:r, ami t rCeasne nbtt ~lSoS X e ,do~VJnOt ,ha lYdorvtgne rnet~lufirCleez omneeasS u re s ..... Seismic analysis of shallow gas zones ........... '...l~l~ Y N Seabed condition survey (if. off-shore) ......... .~'~...~ Y N ~ ' Contact name/phone for weekly progress reports ~e,~7oratory only] Y N ANNULAR DISPOSAL35. With proper cementing records, this plan (A) will contain waste in a suitable receiving zone; ....... APPR DATE (B) will not contaminate freshwater; or cause drilling waste... to surface; ~ ~ %1 ~) o,o (C) will not impair mechanical integrity of the well used for dis posal; ' ~ (D) will'not damage producing formation or impair recovery from a pool; and (E) will not circumvent 20 AAC 25.252 or 20 AAC 25.412. (~N ®N ENGINEERING: UlC/Annular COMMISSION: Comments/Instructions: c:~msoffiCe\wordian\diana\checklist (rev. 02/17/00) Z -4 mm organize this category of information. Sperry-Sun Drilling Services LIS Scan Utility SRevision: 3 $ LisLib SRevision: 4 $ Fri Jan 05 15:30:51 2001 Reel Header Service name ............. LISTPE Date ..................... 01/01/05 Origin ................... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Previous Reel Name ....... UNKNOWN Comments ................. STS LIS Writing Library. Scientific Technical Services Tape Header Service name ............. LISTPE Date ..................... 01/01/05 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Previous Tape Name ....... UNKNOWN Comments ................. STS LIS Writing Library. Scientific Technical Services Physical EOF Comment Record TAPE HEADER KUPARUK RIVER UNIT MWD/MAD LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: # JOB DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD MWD RUN 5 AKMM00146 T. MCGUIRE F. HERBERT 1ST STRING 1D-40 500292296900 PHILLIPS ALASKA, INC. Sperry Sun 05-JAN-01 MWD RUN 6 AKMM00146 T. MCGUIRE F. HERBERT 23 lin 10E 5373 421 .00 105.30 70.90 OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT 8.500 9.625 6978.0 2ND STRING 6.125 7.000 11593.0 3RD STRING PRODUCTION STRING REMARKS: 1. ALL DEPTHS ARE MEASURED DEPTHS UNLESS OTHERWISE NOTED. 2. MWD RUNS 1-3 ARE DIRECTIONAL ONLY AND NOT PRESENTED. 3. MWD RUN 4 MADE NO FOOTAGE AND IS NOT PRESENTED. 4. MWD RUN 5 IS DIRECTIONAL WITH DUAL GAMMA RAY (DGR) UTILIZING GEIGER-MUELLER TUBE DETECTORS AND ELECTRO- MAGNETIC WAVE RESISTIVITY PHASE-4 (EWR4). 5. MWD RUN 6 IS DIRECTIONAL WITH DGR, EWR4, COMPEN- SATED THERMAL NEUTRON POROSITY (CTN), AND STABILIZED LITHO-DENSITY (SLD) . 6. MWD DATA IS CONSIDERED PDC PER THE E-MAIL FROM D. SCHWARTZ OF PHILLIPS ALASKA, INC. ON 10/02/00. 7. MWD RUNS 1-6 REPRESENT WELL 1D-40 WITH API#: 50-029-22969-00. THIS WELL REACHED A TOTAL DEPTH (TD) OF 12225'MD, 6340'TVD. SROP = SMOOTHED RATE OF PENETRATION WHILE DRILLING. SGRC = SMOOTHED GAMMA RAY COMBINED. SEXP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (EXTRA SHALLOW SPACING). SESP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVIT (SHALLOW SPACING). SEMP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (MEDIUM SPACING). SEDP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (DEEP SPACING). SFXE = SMOOTHED FORMATION EXPOSURE TIME. TNPS = SMOOTHED THERMAL NEUTRON POROSITY (SANDSTONE MATRIX, FIXED HOLE SIZE). CTFA = SMOOTHED AVERAGE OF FAR DETECTOR'S COUNT RATE. CTNA = SMOOTHED AVERAGE OF NEAR DETECTOR'S COUNT RATE. SBD2 = SMOOTHED BULK DENSITY-COMPENSATED (LOW-COUNT BIN). SCO2 = SMOOTHED STANDOFF CORRECTION (LOW-COUNT BIN). SNP2 = SMOOTHED NEAR DETECTOR ONLY PHOTOELECTRIC ABSORPTION FACTOR (LOW-COUNT BIN). PARAMETERS USED IN POROSITY LOG PROCESSING: HOLE SIZES: 6.125" MUD WEIGHT: 11.3 PPG MUD SALINITY: 550 PPM CHLORIDES FORMATION WATER SALINITY: 13000 PPM CHLORIDES FLUID DENSITY: 1.0 G/CC MATRIX DENS.ITY: 2.65 G/CC LITHOLOGY: SANDSTONE $ File Header Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 01/01/05 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.000 Comment Record FILE HEADER FILE NUMBER: 1 EDITED MERGED MWD Depth shifted and clipped curves; all bit runs merged. DEPTH INCREMENT: .5000 # FILE SUMMARY PBU TOOL CODE GR RPX RPS RPM RPD FET ROP PEF NCNT FCNT NPHI RHOB SCO2 $ START DEPTH 6945.5 6962.0 6962.0 6962.0 6962.0 6962.0 6988.5 11577 0 11583 0 11583 0 11583 0 11586 5 11586 5 BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA {MEASURED DEPTH) BASELINE DEPTH $ # MERGED DATA SOURCE PBU TOOL CODE MWD MWD $ # REMARKS: STOP DEPTH 12172.0 12178.5 12178.5 12178.5 12178.5 12178 5 12225 0 12150 0 12135 0 12135 0 12135 0 12150 0 12150 0 EQUIVALENT UNSHIFTED DEPTH # Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .lin Max frames per record ............. Undefined Absent value ...................... -999 MERGED MAIN PASS. $ BIT RUN NO MERGE TOP MERGE BASE 5 6945.5 11605.0 6 11605.0 12225.0 Name DEPT ROP GR RPX RPS RPM RPD FET NPHI FCNT NCNT RHOB DRHO PEF Depth Units ....................... Datum Specification Block sub-type...0 Service Order Units Size Nsam FT 4 1 MWD FT/H 4 1 MWD API 4 1 MWD OHMM 4 1 MWD OHMM 4 1 MWD OHMM 4 1 MWD OHMM 4 1 MWD HOUR 4 1 MWD PU-S 4 1 MWD CNTS 4 1 MWD CNTS 4 1 MWD G/CM 4 1 MWD G/CM 4 1 MWD BARN 4 1 Rep Code Offset Channel 68 0 1 68 4 2 68 8 3 68 12 4 68 16 5 68 20 6 68 24 7 68 28 8 68 32 9 68 36 10 68 40 11 68 44 12 68 48 13 68 52 14 Name Service Unit Min Max DEPT FT 6945.5 12225 ROP MWD FT/H 0 472.29 GR MWD API 37.12 426.96 RPX MWD OHMM 0.4 967.58 RPS MWD OHMM 0.45 1625.27 RPM MWD OHMM 0.57 2000 RPD MWD OHMM 0.56 2000 FET MWD HOUR 0.26 81.73 NPHI MWD PU-S 17.33 54.37 FCNT MWD CNTS 137 934.6 NCNT MWD CNTS 15665.7 37530.9 RHOB MWD G/CM 2.101 3.29 DRHO MWD G/CM -0.361 0.472 PEF MWD BARN 3.25 16.28 Mean Nsam 9585.25 10560 121.178 10474 140.756 10454 3.92548 10434 4.67343 10434 12.2731 10434 14.9208 10434 1.79986 10434 39.5232 1105 270.161 1105 20510.6 .1105 2.45308 1128 0.0724131 1128 6.49805 1147 First Reading 6945.5 6988.5 6945.5 6962 6962 6962 6962 6962 11583 11583 11583 11586.5 11586.5 11577 Last Reading 12225 12225 12172 12178.5 12178.5 12178.5 12178.5 12178.5 12135 12135 12135 12150 12150 12150 First Reading For Entire File .......... 6945.5 Last Reading For Entire File ........... 12225 File Trailer Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 01/01/05 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.002 Physical EOF File Header Service name ............. STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 01/01/05 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.001 Comment Record FILE HEADER FILE NUMBER: 2 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 5 DEPTH INCREMENT: .5000 # FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 6945.5 11561 5 RPX 6962.0 11554 0 RPS 6962.0 11554 0 FET 6962.0 11554 0 RPD 6962.0 11554 0 RPM 6962.0 11554 0 ROP 6988.5 11605 5 $ # LOG HEADER DATA DATE LOGGED: 26-AUG-00 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 65.41 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT): 11605.0 TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 65.2 MAXIMUM ANGLE: 68.4 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 1614HWGRV6 EWR4 ELECTROMAG. RESIS. 4 1614HWGRV6 $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN) : EWR FREQUENCY (HZ) : 8.500 6978.0 Water Based 9.50 46.0 11.1 500 11.0 1. 950 1.043 1.920 1.940 68.0 133.0 68.0 68.0 # Dat Name DEPT ROP GR RPX RPS RPM RPD FET REMARKS: $ a Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999 Depth Units ....................... Datum Specification Block sub-type...0 Service Order Units Size Nsam Rep FT 4 1 68 MWD050 FT/H 4 1 68 MWD050 API 4 1 68 MWD050 OHMM 4 1 68 MWD050 OHMM 4 1 68 MWD050 OHMM 4 1 68 MWD050 OHMM 4 1 68 MWD050 HOUR 4 1 68 Code Offset Channel 0 1 4 2 8 3 12 4 16 5 20 6 24 7 28 8 Name Service Unit Min Max DEPT FT 6945.5 11605.5 ROP MWD050 FT/H 0 472.29 GR MWD050 API 37.12 426.96 RPX MWD050 OHMM 1 967.58 RPS MWD050 OHMM 1.16 1625.27 RPM MWD050 OHMM 1.24 1700.97 RPD MWD050 OHMM 1.29 2000 FET MWD050 HOUR 0.26 20.53 Mean 9275.5 127.988 140.891 3.81325 4.50757 6.12304 8.64691 0.978644 Nsam 9321 9235 9233 9185 9185 9185 9185 9185 First Reading 6945.5 6988.5 6945.5 6962 6962 6962 6962 6962 Last Reading 11605.5 11605.5 11561.5 11554 11554 11554 11554 11554 First Reading For Entire File .......... 6945.5 Last Reading For Entire File ........... 11605.5 File Trailer Service name ............. STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 01/01/05 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.003 Physical EOF File Header Service name ............. STSLIB.003 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 01/01/05 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.002 Comment Record FILE HEADER FILE NUMBER: 3 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 6 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH RPD 11554.5 RPX 11554.5 RPM 11554.5 FET 11554.5 RPS 11554.5 GR 11562.0 PEF 11577.0 NPHI 11583.0 FCNT 11583.0 NCNT 11583.0 RHOB 11586.5 DRHO 11586.5 ROP 11606.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT): TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: STOP DEPTH 12178.5 12178.5 12178.5 12178.5 12178.5 12172.0 12150.0 12135 0 12135 0 12135 0 12150 0 12150 0 12225 0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY EWR4 ELECTROMAG. RESIS. 4 CTN COMP THERMAL NEUTRON SLD STABILIZED LITHO DEN $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: 30-AUG-00 Insite 0.41 Memory 12225.0 67.2 67.8 TOOL NUMBER PBO1626FGR4 PBO1626FGR4 PBO1626FGR4 PBO1626FGR4 6.125 11593.0 LSND 11.30 58.0 9.6 550 3.4 1.300 .593 .950 62.0 144.1 62.0 MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: $ # Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .lin Max frames per record ............. Undefined Absent value ...................... -999 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep DEPT FT 4 1 68 ROP MWD060 FT/H 4 1 68 GR MWD060 API 4 1 68 RPX MWD060 OHMM 4 1 68 RPS MWD060 OHMM 4 1 68 RPM MWD060 OHMM 4 1 68 RPD MWD060 OHMM 4 1 68 FET MWD060 HOUR 4 1 68 NPHI MWD060 PU-S 4 1 68 FCNT MWD060 CNTS 4 1 68 NCNT MWD060 CNTS 4 1 68 RHOB MWD060 G/CM 4 1 68 DRHO MWD060 G/CM 4 1 68 PEF MWD060 BARN 4 1 68 1.600 Code Offset Channel 0 1 4 2 8 3 12 4 16 5 20 6 24 7 28 8 32 9 36 10 40 11 44 12 48 13 52 14 62.0 Name Service Unit Min Max DEPT FT 11554.5 12225 ROP MWD060 FT/H 0.66 150.27 GR MWD060 API 46.67 296.96 RPX MWD060 OHMM 0.4 48.9 RPS MWD060 OHMM 0.45 662.09 RPM MWD060 OHMM 0.57 2000 RPD MWD060 OHMM 0.56 2000 FET MWD060 HOUR 0.52 81.73 NPHI MWD060 PU-S 17.33 54.37 FCNT MWD060 CNTS 137 934.6 NCNT MWD060 CNTS 15665.7 37530.9 RHOB MWD060 G/CM 2.101 3.29 DRHO MWD060 G/CM -0.361 0.472 PEF MWD060 BARN 3.25 16.28 Mean Nsam 11889.8 1342 70.4199 1239 139.738 1221 4.75083 1249 5.89316 1249 57.4999 1249 61.0585 1249 7.83896 1249 39.5232 1105 270.161 1105 20510.6 1105 2.45308 1128 0.0724131 1128 6.49805 1147 First Reading 11554.5 11606 11562 11554.5 11554.5 11554.5 11554.5 11554.5 11583 11583 11583 11586.5 11586.5 11577 Last Reading 12225 12225 12172 12178.5 12178.5 12178.5 12178.5 12178.5 12135 12135 12135 12150 12150 12150 First Reading For Entire File .......... 11554.5 Last Reading For Entire File ........... 12225 File Trailer Service name ............. STSLIB.003 Service Sub Level Name... Ver'sion Number ........... 1.0.0 Date of Generation ....... 01/01/05 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.004 Physical EOF Tape Trailer Service name ............. LISTPE Date ..................... 01/01/05 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Next Tape Name ........... UNKNOWN Comments ................. STS LIS Writing Reel Trailer Service name ............. LISTPE Date ..................... 01/01/05 Origin ................... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Next Reel Name ........... UNKNOWN Comments ................. STS LIS Writing Library. Library. Scientific Scientific Technical Technical Services Services Physical EOF Physical EOF End Of LIS File