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XHVZE Pages NOT Scanned in this Well History File This page identifies those items that were not scanned during the initial scanning project. They are available in the original file and viewable by direct inspection. 19~-/c~ 7 File Number of Well History File PAGES TO DELETE RESCAN Complete [] Color items - Pages: Grayscale, halftones, pictures, graphs, charts- Pages: Poor Quality Original- Pages: [] Other- Pages: DIGITAL DATA [] Diskettes, No. [] Other, No/Type OVERSIZED [] Logs of various kinds [] Other COMMENTS: Scanned by: Beverly Mildred Dareth N~Lowell [] TO RE-SCAN Notes: Re-Scanned by: Beverly Mildred Daretha Nathan Lowell Date: /si WELL LOG TRANSMITTAL To: Alaska Oil and Gas Conservation Comm. November 4, 2009 Attn.: Christine Mahnken 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: Water Flow Log: 2N -319 Run Date: 8/28/2009 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Rafael Barreto, Halliburton Wireline Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 2N -319 Digital Data in DLIS format, Digital Log Image file, Interpretation Report 1 CD Rom 50 -103- 20271 -00 Spectra Flow Log 4, r 1 Color p g �'M ���W o Log 50 -103- 20271 -00 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline Perforating 9�- Attn: Rafael Barreto 6900 Arctic Blvd. l Anchorage, Alaska 99518 Office: 907 273 -3527 Fax: 907 273 -353 rafael. barreto .jlihaxrtori. corhF NOV 0 s 70` Date: ,k Signed: l ~ ~ WELL LOG TRANSMITTAL To: Alaska Oil and Gas Conservation Comm. Attn.: Christine Mahnken 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: Leak Detection Log: 2N-319 Run Date: 8/21 /2009 September 9, 2009 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention o£ Rafael Barreto, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Ancharage, AK 99518 2N-319 Digital Data in LAS format, Digital Log Image file 1 CD Rom 50-103-20271-00 . t. °: A,~ ~.. . _l1~''`~ PLEASE ACKNOWLEDGE RECEIPT BY SIGMNG AT1D RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline & Perforating Attn: Rafael Barreto 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907-273-3527 Fax: 907-273-3535 rafael.barreto@halliburton.com Date: - ~ ~~~` - ~~ ~ . ,~. ~ ~~ ~ ~~ ~ ~' ; \ ~ ~~~ Signed: ~ ~~,.,.~ ~L L ProActive Diagnostic Services, Inc. To: AOGCC Christine Mahnken 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 (907) 659-5102 RE : Cased Hole/Open Hole/Mechanical Logs and/or Tubing Inspection(Caliper/ MTl') 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 ~ ,jU~ ~ ~ ~~~$ Suite C Anchorage, AK 99518 Pa~c (907] 2458952 ,;:, 1) Caliper Report 06,JuE08 28406 1 Report / EDE 50-103-2048400 2) Caliper Report 04,JuE0S 2N-319 1 Report/ EDE 50-103-20271-00 ~~ t,g--1~7 `~s~~ ~ ` Signed : ' ~__ Date Print Name: („~ ~~ lG`~ ~ ~~a ~~~ PROACTNE DIAGNOSTIC SERVICES, INC., 130 W. INTERNATIONAL AIRPORT RD SUITE C, ANCHORAGE, AK 99518 PHONE: (907245-8951 FAX: (907)2458952 E-MAIL - _~_ ~.~` ~ _ ~ WEB$fFE ~ ~~~; ~~s a C:\Doemnenls and Settin~s\Owcier\Desktop\Transmit_Comco.doc • • Memory Multi-Finger Caliper Log Results mmary Company: ConocoPhillips Alaska, Inc. Well; 2N-319 Log Date: July 4, 2008 Field: Kuparuk Log No.: 8130 State: Alaska Run No.: 1 API No.: 50-103-20271-00 Pipet Desc.: 3.5" 9.3 Ib. L-80 EUE 8RD Top Log intvl: Surface Pipet Use: Tubing & Liner Bot. Log Intvl: 6,606 Ft. (MD) Inspection Type : Corrosive 8 Mechanical Damage Inspection COMMENTS: This caliper data is tied into the D Nipple @ 6,311' (Driller's Depth). This log was run to assess the condition of the tubing and liner with respect to corrosive and mechanical damage. The caliper recordings indicate the 3.5" tubing and liner logged are in good to fair condition with respect to corrosive damage. Wall penetrations from 2096 to 28% are recorded from 4,800' to 5,700'. Recorded damage appears in the forms of isolated pitting, at times in a line, and areas of shallow general corrosion. No significant areas of crass-sectional wall loss (> 10°~) or LD. restrictions are recorded throughout the tubing and liner logged. MAXIMUM RECORDED WALL PENETRATIONS Isolated Pitting (28%) Jt. 162 ~ 5,170 Ft. (MD) Isolated Pitting (26%) Jt. 161 @ 5,123 Ft. (MD) Isolated Pitting (26%) Jt. 167 ~ 5,319 Ft. (MD) Isolated Pitting (24%) Jt. 160 ~ 5,096 Ft. (MD) Isolated Pitting (24%) Jt. 169 ~ 5,373 Ft. (MD) MAXIMUM RECORDED CROSS-SECTIONAL METAL LOSS : No significant areas of cross-sectional wall loss (> 10%) are recorded throughout the tubing and liner logged. MAXIMUM RECORDED ID RESTRICTIONS : No significant I.D. restrictions are recorded throughout the tubing and liner logged. ~C~i~+ii 1uL ~ ~ 2no8 Field Engineer: R.A. Richey/E. Dustin Analyst: M. Lawrence Witness: J. Hansen ProActive Diagnostic Services, Inc. / P.O. Box 1369, Stafford, TX 77497 Phone: (281) or {888) 565-9085 Fax: (281) 565-1369 E-mail: PDSiamemorylog.com Prudhoe Bay Field Office Phone: {907} 659-2307 Fax: {907) 659-2314 • • Correlation of Recorded Damage to Borehole Profile Pipe 1 3.5 in (19.9'-.~~.~ fn.5') Well: 2N-319 Field: Kuparuk Company: ConocoPhillips Alaska, Inc. Country: USA Survey Date: July 4, 2 8 ^ Approx. Tool De viation ^ A pprox. Borehol e Profil e 25 795 158 2378 GLM 1 ~ 3195 Y {.L ~_ Y ~. 3987 ~ 477 554 GLM 2 X414 2 `; 5 1 Dam age Pr ofile (% wall) / Tool D eviatio n (degr ees) Bottom of Survey = 2 1 25 5 75 v 1 I_ Z .0 125 15 175 2 PDS Report Overview ~. ~~ Body Region Analysis Well: 2N-319 Survey Date: July 4, 2008 Field: Kuparuk Tool Type: UW MFC 24 No. 211387 Company: Conoco('hillips Alaska, Inc. Tool Size: 1.69 Country: USA No. of Frngers: 24 Anal st: M. Lawrence Tubing: Nom.OD Weight Grade & Thread Nom.ID Nom. Upset Upper len. Lower len. 3.5 ins 9.3 f L-80 EUE 8RD 2.992 ins 3.5 ins 6.0 ins 6.0 ins Penetration and Metal Loss (°k wall) ~ penetration body metal loss body 200 - - 150 100 50 0 0 to 1 to 10 to 20 ro 40 ro over 1% 10% 20% 40% 85% 85% Number of'oints anal sed rotal = 215 pene. 1 66 140 8 0 0 loss 25 190 0 0 0 0 Damage Configuration (body ) 60 40 20 0 ix~latecl general line ring hole /post pitting corrosion corrosion corrosion ible hole Number of 'oints dama ed total = 92 53 39 0 0 0 Damage Profile (% wall) ~ penetration body ~w metal loss body 0 50 100 0 48 GLM 1 96 146 GLM 2 196 Bottom of Survey = 206 Analysis Overview page 2 • PDS REPORT JOINT TABI. Pipe: 3.5 in 9.3 ppf L-80 EUE 8RD Well: Body Wall: 0.254 in Field: Upset Wall: 0.254 in Company: Nominal I.D.: 2.992 in Country: Survey Date: • iLATION SHEET 2 N-319 Kuparuk ConocoPhillips Alaska, Inc USA July 4, 2008 Joint No. Jt. Depth (Ft.) I'~•n. 111 ~.r•+ Iln,.) Pen. Body (Ins.) PE~n. % ~Ic•),~I I vs~ ~> Min. LD• (Ins.) Comments Damage Profile (% wall) 0 50 100 1 20 n 0.03 11 a 2.91 PUP 1 25 t~ .04 17 -1 2.8 Shall w ittin . 1.1 57 +) 0.03 11 .92 PUP 1.2 7 l) 0.04 15 a .89 PU Shaf ow corr Sion. 2 9 l) 0.03 13 ~ 2.92 Sha low corrosion. 101 tl 0.0 I.1 2.91 Shallow ittin t. De sits. 4 13 a 0.03 1 3 .91 Shallow "tti 5 164 U 0.04 l i -l .91 a l w 'tti 6 196 U 0.03 12 1 .89 227 U 0.04 15 5 91 all w corrosion 8 25 O .03 11 -1 .90 9 29 O 0.03 11 ~ .91 10 322 t ~ 0.03 12 s 2.90 Lt. si 11 354 t) 0.03 I1 2.92 12 386 t) 0.0 ~~ -1 .9 13 417 t) .03 1 ~ -1 2.90 S Ilow corrosion. 14 449 U 0.04 17 i .91 Sh Ilow co ro ion. 1 48 U 0. 4 14 5 .91 Sh Ilow ittin Lt. a sits. 16 51 U 0.03 13 .90 Shallow itUn . 17 544 U 0.04 15 2 0 II w itti 18 575 t) .0 11 -t .90 19 606 +) 0.03 1 ? ~ 2.9 20 638 +) 0.03 12 ~ .90 21 670 U 0.03 1.? 4 2.91 2 7 1 t~ 03 1 -~ 2.9 23 733 U 0.02 7 -1 2.90 4 765 l) 0.04 14 2. 9 h Ilo co r lion 25 795 t) 0.02 ~) (~ 2.90 26 7 t) 0.0 12 { 2.89 27 859 +) 0.03 12 2.91 8 890 t) 0.03 11 4 .90 Lt. osits. 29 922 U 0.03 tt) ~ 2.91 9 4 +) 0.0 15 ~~ 2.88 $ Ilo corr s'o . De osi 31 985 t) 0.03 1 1 1 2.90 3 1017 U 0.03 11 s 2.89 33 1049 U 0.03 12 ~ 2.91 34 1080 U 0.04 14 9 Sha o orr io . 35 1112 a 0.02 ~> 2.90 36 11 U 0.03 12 ~~ .90 Lt. a osits. 37 1176 t) 0.03 13 i 2.92 Shallow ittin . 38 1 07 a 0.0 1 1 1 2.91 39 1239 U 0.04 14 3 2.90 Sh Ilow it'n . 40 1270 U 0.03 I 1 4 2.91 Lt. D osi . 41 1302 +) 0.03 1 ~ 4 2.91 1334 a 0.04 1 7 -1 1 Sh I w itti t De sits. 43 1365 +) 0.04 1.1 -1 2.9 Shallow c rrosion. 1397 t) 0.03 13 ~ 2.91 Shall ittin . 45 1428 a 0.04 14 4 2.91 Shallow ittin . 46 460 +) 0.04 15 -1 2. 1 h low it'n 47 1491 +? 0.03 11 ~1 2.92 _ Penetration Body Metal Loss Body Page 1 • PDS REPORT )DINT TABI, Pipe: 3.5 in 9.3 ppf L-80 EUE 8RD Well: Body Wall: 0.254 in Field: Upset Wall: 0.254 in Company: Nominal I.D.: 2.992 in Country: Survey Date: • -LATION SHEET 2 N-319 Kuparuk ConocoPhillips Alaska, Inc USA July 4, 2008 Joint No. Jt. Depth (Ft.} Nt~n. U~sc~t (Ins.) Pen. Body (Ins.) I'~~n. "/> ~k~t,~l I use `%~ Min. LD• (Ins.) Comments Damage Profile (% wall) 0 SO 100 47.1 1522 U 0 U O 2.88 DS Ni le 48 1524 O 0.03 13 4 2. 1 Shallow ittin . 49 155 U 0.03 I :~ i 2.92 Shallow corrosion. 50 1586 U 0.04 14 4 2.9 Shallow corrosi n. 51 1618 U 0.04 1 tf 2.93 hallow corrosion. 5 1 5 O 0.0 13 -1 91 Shallow corrosion. 53 1681 t) 0.0 12 ~ 2.92 54 1713 U 0.04 15 -! 2.91 Shallow corrosion. 55 1745 t) .03 13 -1 2.87 Shallow ~ttin t. De sits. 56 1775 U 0.03 13 2. 1 Shallow ittin . 57 1807 t~ 0.03 1.; ~ 2.92 Sallow ittin . 58 1839 t) 0.04 14 ~J 2.91 Shallow corrosion. 9 1870 t~ 0.03 12 -t 2.90 L . De osits. 6 1902 tt 0.03 1:1 ~ 2.91 hallow itti 61 1934 U 0.03 I _' 2.91 t. De osi 62 1965 t) 0.03 1I -1 2.91 63 1997 U 0.03 12 ~ .91 64 02 9 ! ? 0.03 1 ~ -1 2.90 65 061 a 0.03 11 i, 2.91 66 2092 a 0.02 -i 2.91 67 2124 I 0.0 `~ t 2.91 68 2156 U 0. 3 1 U -1 .91 69 2188 U .03 11 ~ 2.91 70 2219 ~1 0.04 14 =1 2.91 Shallow ittin . 71 2251 U .03 t l) a 2.91 72 2283 tl 0.03 11 I 2.92 73 2314 t I 0.04 l d -i 2.91 Shallow orrosion. 74 2346 tl 0.05 1 ~) -l 2.90 Shallow corrosion. 75 2378 U 0.03 1:, -~ 2.92 Shallow corrosion. 76 2410 t) 0.03 1 U -i 2 90 77 2441 tl 0. 3 11 S .91 78 2473 t~ 0.04 17 i 2.91 Shallow corrosion. Lt. De osits. 79 2503 U .0 ~> 2 92 80 2534 it 0.04 17 2.90 Shallow ittin . 8 2567 ti 0.04 14 -t 2.92 Shallow itti 82 2598 U 0.02 `) a 2.92 3 2630 U .03 1 1 a .88 Lt. De osits. 84 2662 11 0.03 11 -1 2.90 85 2693 l) 0.03 11 -t 2.9 86 2725 O 0.03 11 -1 2.90 86.1 2757 O 0.02 9 t) .9 PUP 86.2 2772 l~ 0 O (1 N A GLM 1 atch ~ 5:00 86.3 2778 U 0.0 7 ~' .9 P P 87 2793 ti 0.03 I:S '~ 2.91 Shallow corrosion. 88 823 c~ 0.04 17 _1 .90 hallow cor osion. Lt. De o its. 89 2855 t ~ 0.02 ~> 2.93 0 2886 i~ 0.03 1 -' S .91 91 2918 i? 0.03 1 i ~ 2.91 Shallow corrosion. 9 2948 tI 0.03 1tl 1 2.91 93 297 t~ 0.02 `) ~~ 2.93 _ Penetration Body Metal Loss Body Page 2 • • PDS REPORT JOINT TABULATION SHEET Pipe: 3.5 in 9.3 ppf L-80 EUE 8RD Well: 2N-319 Body Wall: 0.254 in Field: Kuparuk Upset Wall: 0.254 in Company: Cons Alaska, Inc Nominal I.D.: 2.992 in Country: USA Survey Date: )uly 4, 2008 Joint No. Jt. Depth (Ft.) I'~~n. Ulxet (Ins.) Pen. Body (Ins.) Pen. % Mc~t.il loss °4, Min. LD. (Ins.) Comments Damage Profile (%wall) 0 50 100 94 3009 O 0.03 1 U 5 .89 Lt. a osits. 95 3041 t ~ 0.03 10 .3 2.90 96 3072 a 0.03 I:S i 2. 8 h II w ittin . Lt. De sits. 97 3104 U 0.03 11 4 2.91 98 3135 U 0.03 11 v .93 99 3163 U 0.0 ~) ~ .93 100 31 5 u 0.0 9 -1 2.90 Lt. De osits. 101 32 7 u 0.04 1 ~1 -1 2.90 Shallow ittin . 102 3258 i? 0.05 1 ~3 1 2. 3 Shallow corro ion. 103 3290 (t 0.04 1 £~ -t .92 Shallo corro ion. 104 33 U 0. 5 I ~3 -1 .91 Shallow or osion. 105 3353 U 0.02 '~ 5 2.90 106 3385 U 0.03 1 t7 ~ 2.93 107 3417 U 0.03 11 -1 .92 108 3 tl 0. 4 14 ~ 4 Sh I ow i tin . 109 3480 t) 0.03 1 I ~ 2.91 110 3511 (1 0.03 13 -i 2.92 Shallow ittin . 111 3543 l1 0.03 1 _; r, 2.9 Shallow it in . 112 3575 t t .04 14 -1 2.9 Shallow corrosion. 113 3607 U 0.04 1 5 -t .91 Shallow co rosion. 114 3638 t) 0.03 13 ~ 2.91 Shallow ittin . 115 670 t 1 4 17 (i .91 Sh Ilow c rrosion. 116 3701 U 0.0 £3 5 .96 117 3733 t1 0.04 15 t~ 2.92 Shallow corrosion. 1 3 t1 4 ~ 91 I w r' 119 3796 l~ 0.03 11 5 2.93 1 0 3 28 (~ 0.04 17 -l 2.91 Sh w Corr Sion. 121 3860 t~ 0.03 10 '~ 2.91 12 89 U .04 4 a 2.9 Sal ow corrosi n. 123 3923 tt 0.03 12 ~ 2.91 124 955 t ~ 0.03 1 1 ? .9 125 3987 t~ 0.02 8 2.95 1 6 4018 tt 0.0 9 2.9 127 4050 t? 0.03 1 ' 2.94 1 8 4081 t7 0.04 15 2.90 Shallow it 'n . 129 4113 a 0.02 £3 2.95 130 4144 t ~ 0.03 1 1 2.92 131 4177 tt 0.02 £3 ~ 2.96 132 208 tt .05 2l) _' 2.91 Shallow corro 'on. 133 4240 t) 0.0 9 l 2.94 Pittin . 134 42 71 U 0.02 8 ? 2 135 4303 It 0.02 £3 2.94 Pittin . 136 4335 U 0. 2 t3 5 137 4366 U 0.02 £i 2.94 138 398 t) 0. 3 13 2.90 S allo rosion. 139 4429 a 0.02 7 2.90 140 4461 t) 0.03 11 t .89 141 4492 (1 0.03 12 ~? 2.91 142 4524 t ~ 0. ; 3 2.93 143 4556 0.02 2.94 _ Penetration Body Metal Loss Body Page 3 • PDS REPORT JOINT TABI. Pipe: 3.5 in 9.3 ppf L-80 EUE 8RD Well: Body Wall: 0.254 in Field: Upset Wall: 0.254 in Company: Nominal I.D.: 2.992 in Country: Survey Date: • ELATION SHEET 2N-319 Kuparuk ConocoPhillips Alaska, Inc USA July 4, 2008 Joint No. Jt. Depth (Ft.) I'~~n. Uh,e~t (lns.) Pen. Body (Ins.) Pc°n. % ti1ct,~l I cuss `~'~~ Min. LD• (Ins.) Comments Damage Profile (%wall) 0 50 100 144 4587 t) 0.03 11 1 .91 Shall w ittin . 145 461 O .02 ~) .96 146 4651 U 0. 2 t3 2.95 147 4681 O 0.02 13 1 2.95 148 4712 t) 0.03 I.1 _' 2.91 Shallow ittin . 149 4744 l) 0.04 15 .88 Shallow corrosion. 150 4776 U 0.03 11 4 2.89 151 4808 O.O4 0.0 ~~ 2.97 De sits. 152 4839 O 0.04 14 ~ 2.90 Shallow itti 153 4872 a 0.04 15 4 2.93 Shallow itti 154 4904 O 0.04 17 i 2.96 Shallow it 'n . 155 4935 U 0.02 (f 1 .92 156 4964 t) 0.04 14 i .90 Shallow it in . 157 4997 O 0.03 I1 ~ 2.90 158 5029 U 0.02 ~) 2.95 159 5054 O 0.02 ti ~ 2.96 160 5081 t) 0.06 ~4 1 2.93 Isolated itCn . 161 5111 a 0.07 ~(~ 1 2.92 Isolate itti 162 140 U.U; 0.07 28 O 2.92 Isolated ittin . 163 5170 U 0.04 15 1 2.93 Shallow ittin . 164 5202 O 0.03 13 2.93 Shallow ittin . 165 5234 O 0.06 11 I .94 Isolated ittin . 166 5265 U 0.02 ~) I 2.93 167 5297 (1 .07 2G 2.91 Isolated ittin . 1 8 l) .06 ' ' 1 I lat it 169 5359 O 0.06 24 1 2.93 Isolated ittin . 170 5390 (1 0.06 24 I .90 Isolated ittin . 171 5421 l1 0.04 15 I 2.94 Shallow ittin . 17 5453 t) 0.05 19 1 2.92 Shallow ittin . 173 5485 U 0.05 1 ~) I 2.93 Shallow itti 174 5515 t) 0.04 15 1 2.94 Shallow ittin . 175 5546 U 0.02 ~+ 1 2.94 176 5577 U 0.04 14 O 2.9 Shallow it6n . 177 5610 t) 0.02 ti a 2.93 178 5641 O 0.03 12 t I .9 179 5671 O 0.02 ~) ,' 2.95 180 5703 a 0.02 8 ~ 2.96 181 5734 U.U[) 0.02 8 ~ 2.97 182 5766 O 0.0 ~) s 2 95 183 5798 O 0.02 i ~1 2.96 184 5829 t) 0.02 t3 3 2.96 185 5861 (> 0.04 14 2 2.90 Shallow corrosion. 186 5893 U 0.02 t3 ? 2.98 187 5925 U 0.02 8 ~' 2.96 1$8 59 5 O 0.03 12 ~' .91 189 5988 I) 0.02 Fl ~' 2.96 190 6019 n .02 8 ~ 2.97 191 6050 U 0.03 I1 2.91 1 2 6083 !~ 0.04 14 Iu 2.96 Shallow ittin . 193 6114 0.04 15 ~ 2.88 Shall w ~itti _ Penetration Body Metal Loss Body Page 4 PDS REPORT JOINT TABI. Pipe: 3.5 in 9.3 ppf L-80 EUE 8RD Well: Body Wall: 0.254 in Field: Upset Wall: 0.254 in Company: Nominal I.D.: 2.992 in Country: Survey Date: -LATION SHEET 2N-319 Kuparuk ConocoPhillips Alaska, Inc. USA July 4, 2008 Joint No. Jt. Depth (Ft.) I'c~n. tllsc~t (Ins.) Pen. Body (Ins.) Pen. % ~1ct,~l Ius °-~, Min. LD• (Ins.) Comments Damage Profile (%wall) 0 50 100 194 6146 t ~ 0.02 8 t ~ 2.94 195 6177 tr 0.04 16 2.93 Shallow ittin . 195.1 6209 t~ 0 0 r~ 2.81 Slidin Sleeve 196 6213 t ? .02 - ' ~ 2.95 196.1 6244 tt 002 '~ I 2.93 PUP 196.2 6258 t) 0 U r ~ N A CLM 2 Latch @ 6:30 196.3 6263 tt 0.0 1u t 2.96 PUP 197 6279 t) 0.03 13 -1 2.91 Shallow corrosion. 197.1 6311 t) 0 O n 2.75 D Ni le 197.2 6319 U 0 U t r 2.97 eal Ass mbl 97.3 6336 tt 0 U U N A Cro Over to finer 197.4 6340 a 0.03 1 'I 2.92 PUP 198 6350 t) 0.02 £~ t ~ 2.96 199 638 t~.UU 0.02 £~ t~ 2.98 200 6414 U.(u) 0.02 i3 5 .96 201 6445 U 0.02 f3 ~ 2.96 201.1 477 c) 0 05 I £i Z 2.90 P P Shallow corrosion. 202 6482 U 0.03 11 (~ 2.97 203 6513 U 0.04 1 ~ 5 2.93 Shallow corrosion. 204 6545 t) 0.04 15 I 2.92 S Ilow it6n . 205 6577 a 0.03 1 U I 2.97 206 6606 u 0 (? tr 0.00 _ Penetration Body Metal Loss Body Page 5 PDS Report Cross Sections ~~ ~. Well: 2N•319 Survey Date: July 4, 2008 Field: Kuparuk Tool Type: UW MFC 24 No. 211387 Company: ConocoPhillips Alaska, Inc. Tool Size: 1.69 Country: USA No. of Fingers: 24 Tubin 3.5 ins 9.3 f L-80 EUE 8RD _______ _ _ Analyst: M. Lawrence Cross Section for Joint 162 at depth 5170.063 ft Tool speed = 44 Nominal ID = 2.992 Upset OD = 3.500 Remaining wall area = 99 In upset region Tool deviation = 46 ° Finger 15 Penetration = 0.072 ins Isolated Pitting HIGH 51DE = UP • • Cross Sections page 1 0.07 ins = 28% Wall Penetration PDS Report Cross Sections 4 Well: 2N-319 Survey Date: July 4, 2008 Field: Kuparuk Tool Type: UW MFC 24 No. 211387 Company: ConocoPhillips Alaska, Inc. Tool Size: 1.69 Country: USA No. of Fingers: Z4 Tubin~_ 3.5 ins 9.3 ppf L-80_EUE SRD _ _ _ _ Analyst: M. Lawrence Cross Section for Joint 167 at depth 5318.717 ft Tool speed = 43 Nominal ID = 2.992 Nominal OD = 3.500 Remaining wall area = 99 °~ Tool deviation = 48 ° Finger 15 Penetration = 0.065 ins Isolated Pitting 0.07 ins = 26% Wall Penetration HIGH SIDE = UP • Cross Sections page 2 • ConocoPhillips ~s~ P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 October 4, 2007 Mr. Tom Maunder Alaska Oil & Gas Commission 333 West 7~' Avenue, Suite 100 Anchorage, AK 99501 Dear Mr. Maunder: \~w~~~~ Enclosed please find a (revised 10/3/07)spreadsheet with a list of wells from the Kuparuk field (KRU). Each of these wells was found to have a void in the conductor. These voids were filled with a corrosion inhibitor, engineered to prevent water from entering the annular space. As per previous agreement with the AOGCC, this letter and spreadsheet serves as notification that the treatments took place and meets the requirements of form 10-404, Report of Sundry Operations. The cement top jobs were pumped on September 9, 2007 and the corrosion inhibitor/sealant was pumped on September 16-27, 2007. The attached spreadsheet presents the well name, top of cement depth prior to filling, and volumes used on each conductor. This spreadsheet is a revised format for the original submitted on 9/28107 Please call myself at 907-659-7506, or M.J. Loveland at 659-7043 if you have any questions. Sincerely, ---~_ ~ _ ~~ on Arend • .~:~~ IdGV t~ ~ 20U7 ConocoPhillips Well Integrity Field Supervisor • • ConocoPhillips Alaska Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10-404) Date Kuparuk F{e{d 9/28/2007 Weil Name Pl"D # Initial top of cement Vol. of cement um ed Final top of cement Cement top off date Corrosion inhibitor Corrosion inhibitor/ sealant date ft bbls ft al 2L-303 201-239 7' 7" 1.2 18" 9/9/2007 7.5 9/16/2007 2L-309 205-210 13' 3" 2 18" 9/9/2007 7.5 9/16/2007 2N-302 201-115 5' 11" na 5" 11" na 39.5 9/16!2007 2N-313 198-091 5' 0.75 18" 9/9!2007 2N-335 198-204 20" na 20" na 13 9/16/2007 2N-347 200-063 21' 4 18" 9/9/2007 6 9/16/2007 2N-348 201-142 4' 8" 1.5 12" 9/9/2007 4.5 9/16/2007 2N-303 200-169 5" n/a 5" n/a 1 9/27/2007 2N-304 201-130 10" n/a 10" n/a 4.5 9/27/2007 2N-305 200-135 12" n/a 12" n/a 7.5 9/27/2007 2N-307 199-017 14" n/a 14" n/a 4.5 9/27/2007 2N-308 199-010 5" n/a 5" n/a 1 9/27/2007 2N-309 199-021 9" n/a 9" n/a 2 9/27/2007 2N-311 206-179 12" n/a 12" n/a 10 9/27/2007 2N-313 198-091 18" n/a 18" n/a 2 9/27/2007 2N-314 200-193 26" n/a 26" n/a 7 9/27/2007 2N-315 198-190 6" n/a 6" n/a 3 9/27/2007 2N-317 198-143 5" n/a 5" n/a 1 9/27/2007 2N-318 200-100 10" n/a 10" n/a 1 9/27/2007 2N-319 198-197 5" n/a 5" n/a 9.5 9/27/2007 • Conoco~iilips P.O. BOX 100360 ANCHORA6E,ALASKA 99510-0360 September 28, 2007 Mr. Tom Maunder Alaska Oil & Gas Commission 333 West 7~' Avenue, Suite 100 Anchorage, AK 99501 • ~~C~ 4~'T 'VFW A/ask° ©i/~ De ~ 2 2DD~ A°eh0 age C°'~'ss; Op \~,~°~~1 Dear Mr. Maunder: Enclosed please find a spreadsheet with a list of wells from the Kuparuk field (KRin. Each of these wells was found to have a void in the conductor. These voids were filled with a corrosion inhibitor, engineered to prevent water from entering the annular space. As per previous agreement with the AOGCC, this letter and spreadsheet serves as notification that the treatments took place and meets the requirements of form 10-404, Report of Sundry Operations. The cement top jobs were pumped on September 9, 2007 and the corrosion inhibitor/sealant was pumped on September 16-27, 2007. The attached spreadsheet presents the well name, top of cement depth prior to filling, and volumes used on each conductor. Please call myself at 907-659-7043, if you have any questions. Sincerely, ~- M.J. vel d ConocoPhillips Well Integrity Projects Supervisor • • ConocoPhillips Alaska Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10-404) Date Kuparuk Field 8!28/2007 Well Name PTD # Initial top of cement Vot. of cement um ed Final top of cement Cement top off date Corrosion inhibitor Corrosion inhibitor/ sealant date ft bbls ft al 2L-f03 201-239 7' 7" 1.2 18" 9/9/2007 7.5 9/16/2007 2L-309 205-210 13' 3" 2 18" 9/9/2007 7.5 9/16/2007 2N-302 201-115 5' 11" na 5" 11" na 39.5 9/16/2007 2N-313 198-091 5' 0.75 18" 9/9/2007 2N-335 198-204 9" na 20" na 13 9/16/2007 2N-347 200-063 21` 4 18" 9/9/2007 6 9/16/2007 2N-348 201-142 4' 8" 1.5 12" 9/9/2007 4.5 9/16/2007 2N-303 200-169 5" n/a 5" n/a 1 9/27/2007 2N-304 201-130 10" n/a 10" n/a 4.5 9/27/2007 2N-305 200-135 12" n/a 12" n/a 7.5 9/27/2007 2N-307 199-017 14" n/a 14" n/a 4.5 9/27/2007 2N-308 199-010 5" n/a 5" n/a 1 9/27/2007 2N-309 199-021 9" n/a 9" n/a 2 9/27/2007 2N-311 206-179 12" n/a 12" n/a 10 9/27/2007 2N-313 198-091 5" n/a 5" n/a 2 9/27/2007 2N-314 200-193 26" n/a 26" n/a 7 9/27/2007 2N-315 19&190 6" n/a 6" n/a 3 9/27/2007 2N-317 19&143 5" n/a 5" n/a 1 9/27/2007 2N-318 200-100 10" n/a 10" n/a 1 9/27/2007 2N-319 198-197 5" n/a 5" n/a 9.5 9/27/2007 05/28/03 Schlumberger Schlumberger Technology Corporation, by and through is Geoquest Division 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 ATTN: Beth NO. 2860 Company: Alaska Oil & Gas Cons Corem Attn: Lisa Weepie 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Kuparuk Well Job # Log Description Date BL Color CD 3S-23 ¢~"Z3'~L'~ PERF & SBHP W/JEWELRY LOG 04~29~03 2N-319 -~ (~;~-I~ ~. PRESS/TEMP SURVEY 04127/03 2N-343 ~ ~ ~-~ ~ INJECTION PROFILE 05102103 2N-348 ~C ~' ~t-~ iNJECTION PROFILE 05101/03 2P-429 ~C~ ~ ' ~C~ MEM PSP INJECTION PROFILE 05106/03 2P-420 ~ '~ ~ ~ MEM PSP INJECTION PROFILE 05/06/03 3J.17 ,"~ ~ 0~1 ~ L~'MEMORY LDL 05~08~03 DATE: RECEIVED MAY 30 200~ Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. Alaska O~i & (~as Cons. CamaJeei0n Re: Jet Pumped Wells Subject: Re: Jet Pumped \Vells From: "NSK Problem Well Supv" <n 1617@~conocophillips.com> Date: Sat. 7Dec200214:07:01-0900 To: Tom .rYlaunder <tonl_nlaunder@admin.state.ak.us> CC: "n161 7" <nI617@~conocophillips.com> Tom: I requested a list of surface powered jet pump wells from our PEls. The following should be the current total for the Kuparuk area: West Sak wells: lC-123 (PTD 2010840) was recently SI for high watercut 1C-135 (PTD 2012200) is a huff and puff well and was recently put on water injection cycle CPF 2 are as follows: 2L-307 (PTD 1982560) 2 L - 3 13 (PTD 1 98 2 1 9 0 ) 2L-315 (PTD 1982180) 2L-321 (PTD 1982620) 2L-325 (PTD 1982090) 2N-303 (PTD 2001690) 2N-304 (PTD 2011300) 2N-305 (PTD 2001350) 2N-318 (PTD 2001000) ~ 2N-319 (PTD 1981970) 2N-332 (PTD 2000790) 2N-337 (PTD 1981220) 2N-339 (PTD 1981000) 2P-415 (PTD 2012260) There are no surface powered jet pump wells at CPF3. I hope this answers your question. Let me know if you need more information. Jerry Dethlefs ConocoPhillips Problem Well Supervisor Tom Maunder <'. t Corn mall ndep;;'admin . s tatE. ak . us> 12/06/2002 09:00 AM To: NSK Problem Well Supv/PPCO@Phillips cc: Subject: Jet Pumped Wells Pete and or Jerry, I have some emails fro h'l b k maw l e ac regarding the wells out there on jet pumps. Would you please provide an updated listing of the wells presently on jet pumps in greater KRU?? Thanks in advance. To w¢ i Com nan i port File on Left side of folder 198-197-0 KUPARUK RIV U TARN 2N-319 50- 103-20271-00 PHILLIPS ALASKAINC Roll #1: Start: Stop Roll #2: Start Stop MD 07039 TVD 05600 Completion Date: 10/8/98 Completed Status: 1-OIL Current: Name Interval D 9110 2,3 SPERRY MPT/GR/EWR4/CNP/SLD OH L DGR/CNP/SLD-MD FINAL 2466-7039 OH L DGR/CNP/SLD-TVD FINAL 2317-5600 OH L DGR/EWR4-MD FINAL 2466-7039 OH L DGR/EWR4-TVD FINAL 2317-5600 OH R SRVY CALC. BHI 108.-7039. OH Daily WellOps _ __ -- Was the well cored? yes no Comments: Sent Received T/C/D . 3/30/99 3/30/99 3/30/99 3/30/99 D 3/30/99 3/30/99 3/30/99 3/30/99 D 3/30/99 3/30/99 10/30/98 11/2/98 Are Dry Ditch Samples Required? ye And Received? ye Analysis Description Received? yes no Sample Set # Wednesday, November 08, 2000 Page 1 of 1 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation Shutdown _ Stimulate__ Plugging _ Perforate _ Pull tubing _ Alter casing _ Repair well _ Other _X 2. Name of Operator: 5. Type of Well: 6. Datum of elavation (DF or KB feet): ARCO Alaska, Inc. Development X__. 28' RKB 3. Address: Exploratory ~17. Unit or Property: P.O. Box 100360 Stratagrapic__ Anchorage, AK 99510-0360 Service _~. Kuparuk River Unit 4. Location of well at surface: 8. Well number: 54' FNL, 734' FEL, Sec 3, T9N, R7E, UM 2N-319 At top of productive interval: 9. Permit number/approval number: 1909' FSL, 1797' FWL, Sec 34, T10N, R7E, UM 98-197/399-14zl At effective depth: 10. APl number: 2116' FSL, 1537' FWL, Sec 34, T10N, RTE, UM 50-029-20169-00 At total depth: 11. Field/Pool: 2126' FSL, 1523' FWL, Sec 34, T10N, R7E, UM Kuparuk River Field/Tarn Oil Pool 12. Present well condition summary Total Depth: measured 7039 feet Plugs (measured) None true vertical 5600 feet Effective Deptl measured 6889 feet Junk (measured) None true vertical 5493 feet Casing Length Size Cemented Measured depth True vertical depth Conductor 80' 16" 9 cu yds High Early 108' 108' Surface 2410' 7.625" 260 Sx AS III & 2439' 2308' 240 Sx Class G w/60 Sx AS I top job Production 6291' 5.5" 208 Sx Class G 6317' 5077' Liner 702' 3.5" Included in above 7019' 5586' Perforation Depth measured 6605'-6625' true vertical 5288'-5303' 3.5", 9.3 lb/fi, L-80 EUE @ 6336' Packers and SSSV (type and measured depth) Pkr: Baker CSR @ 6317'; SSSV: None, nipple @ 513' 13. Stimulation or cement squeeze summary N/A Intervals treated (measured) N/A Treatment description including volumes used and final pressure Installed jet pump in production well from 7/30/99 to 10/9/99. 14. Representitive Daily Average Production or Injection Data OiI-Bbl Gas-Mcr Water-Bbl Casing Pressure Tubing Pressure Oil rate varies from 11 to 2000 depending on amount of paraffin in wellbore Prior to well operation 284 230 0 863 309 Approximate average, water is power fluid used Subsequent to operation 396 609 1281 1519 372 15. Attachments 16. Status of well classification as: Copies of Logs and Surveys run _ Daily Report of Well Operations Oil X Gas _ Suspended _ Service _ 17. I hereby, cej'tify that the foregoing is true and correct to th@best of my knowledge. Signed ~~'-~ Title'. Production Engineering Supervisor Date F(~rm 1 ¢1-4134 Rc.v I~t5/'1 ,~,~ P,,B SUBMIT IN DUPLICATb~ STATE OF ALASKA '.~ .... , ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of request: Abandon __ Alter casing __ Change approved program __ Suspend __ Repair well __ Pull tubing __ Operation Shutdown__ Reenter suspended well__ Plugging __ Time extension__ Variance X Perforate__ Stimulate __ Other__ 2. Name of Operator: ARCO Alaska, Inc. 3. Address: P.O. Box 100360 Anchorage, AK 99510-0360 4. Location of well at surface: 54' FNL, 734' FEL, Sec 3, T9N, R7E, UM At top of productive interval: 1909' FSL, 1797' RNL, Sec 34, T10N, R7E, UM At effective depth: 2116' FSL, 1537' RNL, Sec 34, T10N, R7E, UM At total depth: 2126' FSL, 1523' FWL, Sec 34, T10N, R7E, UM Type of Well: Development X. Exploratory ~ Stratagrapic ~ Service ~ 6. Datum of elavation (DF or KB) 28' RKB 7. Unit or Property: Kuparuk River Unit 8. Well number: 2N-319 9. Permit number: 98-197 10. APInumber: 50-103-20271-00 11. Field/Pool: Kuparuk River Field/Tarn Oil Pool feet 12. Present well condition summary Total Depth: measured true vertical Effective Depth: measured true vertical Casing Length Size Conductor 80' 16" Sudace 2410' 7-5/8" Production 6291' 5.5" Liner 702' 3.5" 7039 feet Plugs (measured) none 5600 feet 6889 feet Junk (measured) none 5493 feet Cemented Measured depth 9 cu yds High Early 108' 260sxAS III, 240sx CG, 60sxASI 2439' 220 Sx Class G 6317' True verticaldepth 108' 2308' 5077' Included above 7019' 5586' Perforation Depth measured 6605'-6625' true vertical 5288'-5303' Tubing (size, grade, and measured depth) 3-1/2", 9.3#, L-80, EUE tubing @ 6336' MD. Packers and SSSV (type and measured depth) Pkr: Baker CSR @ 6317' MD; SSSV: None, nipple @ 513' MD. 1999 ~,,~ -~''.-~[ -- ~j~sKa 0~ &_ Gas Cons, OomrCssio~ Anchorag8 13. Attachments Description summary of proposal _X Detailed operations program__ BOP sketch _ 14. Estimated date for commencing operation Install jet pump in well - July, 1999 16. If proposal was verbally approved Blair Wondzell Name of approver 15. Status of well classification as: J Oil _X Gas __ 7/15/99I Date approvedI Service Suspended__ 17. I hereby certify that the forgoing is true and correct to the best of my knowledge. FOR COMMISSION USE ONLY l Condition~roval: Notify Comission so representitive may witness ~,O~/e_,~ ~v',u Plug integrety __ BOP test __ Location clearance __ ,J:k~) ~e~g~t,~.~ _- Mechanical integrety test__ Subsequent form required 10- ~ ~ ...)RIGINAL SIGNEDBY 'F~rn 01 ' '3Hev ~ 15'881Appr°ved4boV°rder°f/theC°mmissi°n Robert N. Chdstensorl Commissioner SUBMII IN IHIPLICAIE Xe: .... mp Approval Request Subject: Re: Jet Pump Approval Request Date: Thu, 15 Jul 1999 15:58:48-0800 From: Blair Wondzell <Blair_Wondzell@admin.state.ak.us> To: Erickson&Versteeg <N 1177~mail.aai.arco.com> CC: Dobson&Sloan <N1127@mail.aai.arco.com>, Beck&Zuspan <N1052~mail.aai.arco.com>, Ryan L Stramp <RSTRAMP@mail.aai.arco.com>, Goldmann&Hill <N 1297~mail.aai.arco.com> Hans, Thanks for visiting with me this afternoon on this situation. As I understand that you have only two pipelines to Tarn, one for production and the other for lift gas or injection. Since you will need the line for injection, if the for four subject wells are to be lifted during the test it will have to be with the jet pumps, powered by water. We agree this is a reasonable approach and that your efforts should reduce casing corrision to an acceptable level. Therefore testing jet pumps powered by injection water during the Tarn water injection test is acceptable. Blair Wondzell, 7/15/99 Erickson&Versteeg wrote: Blair, Per our phone conversation 7/12/99, verbal approval is requested to proceed with the planned jet pump installations at Tarn. Verbal approval is requested since the opportunity to test the jet pumps is limited to the duration of the Tarn water injection test,. Sundry requirements for the jet pump test were not anticipated, and the issues outlined in the sundry request were only recently recognized. Approval is requested to install jet pumps in wells 2N-319, 2N-335, 2N-337A and 2N-345 during the ~ 90 day period ending October 15, 1999. Water from the Tarn Mt header will be injected down the 5-1/2" X 3-1/2" production annulus as power fluid for the "reverse circulation" TRICO jet pump. The jet pump will be installed in the 3-1/2" tubing sliding sleeve, which will allow water entry from the annulus to the tubing. This will result in tubing by. annulus communication. A variance is requested for the duration of the test. Due to the existing practice of chemical treating injected water, the short duration of the jet pump test (- 90 days), and the Iow annulus injection rate 2,000 bwpd), the existing schedule for chemical treating of injection water is expected to be sufficient for the 90 day jet pump test. Produced water used for injection is currently treated with RU 275 at the Kuparuk production wells. In general, pitting and wall loss corrosion in flow lines typically can not be detected by inspection until a coupon indicates a wall loss of greater than ~ 10 mils~year for at least 2 years. The 1999 coupon data for Kuparuk CPF2 injectors indicates that the average coupon wall loss or pitting corrosion is - 1-2 mils~year. Based on this information, wall loss and pitting in the production annulus is not anticipated for the duration of the 90 day test. Joe Versteeg (907) 659-7687 1 of 1 7/15/99 4:00 PM .Jet Pump Approval Request Subject: Jet Pump Approval Request Date: Tue, 13 Jul 1999 16:27:19-0900 From: "Erickson&Versteeg" <N1177@mail.aai.arco.com> To: blair wondzell~admin.state.ak.us CC: "Dobson&Sloan" <N 1127~mail.aai.arco.com>, "Beck&Zuspan" <N 1052@mail. aai.arco.com>, "Ryan L Stramp" <RSTRAMP~mail.aai.arco.com>, "Goldmann&Hill" <N 1297~mail.aai.arco.com> Blair, Per our phone conversation 7/12/99, verbal approval is requested to proceed with the planned jet pump installations at Tarn. Verbal approval is requested since the opportunity to test the jet pumps is limited to the duration of the Tarn water injection test,. Sundry requirements for the jet pump test were not anticipated, and the issues outlined in the sundry request were only recently recognized. Approval is requested to install jet pumps in wells 2N-319, 2N-335, 2N-337A, and 2N-345 during the ~ 90 day period ending October 15, 1999. Water from the Tarn MI header will be injected down the 5-1/2" X 3-1/2" production annulus as power fluid for the "reverse circulation" TRICO jet pump. The jet pump will be installed in the 3-1/2" tubing sliding sleeve, which will allow water entry from the annulus to the tubing. This will result in tubing by annulus communication. A variance is requested for the duration of the test. Due to the existing practice of chemical treating injected water, the short duration of the jet pump test (~ 90 days), and the low annulus injection rate (~ 2,000 bwpd), the existing schedule for chemical treating of injection water is expected to be sufficient for the 90 day jet pump test. Produced water used for injection is currently treated with RU 275 at the Kuparuk production wells. In general, pitting and wall loss corrosion in flow lines typically can not be detected by inspection until a coupon indicates a wall loss of greater than - 10 mils/year for at least 2 years. The 1999 coupon data for Kuparuk CPF2 injectors indicates that the average coupon wall loss or pitting corrosion is - 1-2 mils/year. Based on this information, wall loss and pitting in the production annulus is not anticipated for the duration of the 90 day test. Joe Versteeg (907) 659-7687 1 of 1 7/13/99 4:52 PM WELL LOG TRANSMITTAL To~ RE] State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Lori Taylor 3001 Porcupine Dr. Anchorage, Alaska 99501 MWD Formation Evaluation Logs 2N-319, March 30, 1999 ~1~_MM_80396 1 LDWG formatted Disc with verification listing. API#: 50-103-20271-00 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING THE ATTACHED COPY OF THE TRANSMITTAL LETTER TO THE ATrENTION OF: Sperry-Sun Drilling Service Attn: Jim Galvin 5631 Silverado Way, Suite G. Anchorage, Alaska 99518 Date:--~R .... ., .... , SlgI1 ":!~V,a L~ &Gas Con.'-:,. ~.~,:~.rmss~cn ? \ ~ . ,n n0ra.q.e LD 5631 Silverado Way, Suite G · Anchorage, Alaska 99518 · (907) 273-3500 · Fax (907) 273-3535 A Halliburton Company WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Loft Taylor 3001 Porcupine Dr. Anchorage, Alaska 99501 March 30, 1999 RE: MWD Formation Evaluation Logs 2N-319, AK-MM-80396 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of] Ali Turker. Sperry-Sun Drilling Services, 5631 Silverado Way, #G, Anchorage, AK 99518 2N-319: 2" x 5" MD Resistivity & Gamma Ray Logs: 50-103-20271-00 2" x 5" TVD Resistivity & Gamma Ray Logs: 50-103-20271-00 2" x 5" MD Neutron & Density Logs: 50-103-20271-00 2" x 5" TVD Neutron & Density Logs: 50-103-20271-00 1 Blueline 1 Folded Sepia 1 Blueline 1 Folded Sepia 1 Blueline 1 Folded Sepia 1 Blueline ,l~lded Sepia 5631 Silverado Way, Suite G · Anchorage, Alaska 99518 · (907) 273-3500 · Fax (907) 273-3535 A Halliburton Company ber of _ ]~'~ ages (Cover +): Kuparuk Development P. O. BOX 100360 ANCHORAGE, AK 99510-0360 ' FAX # g07 265-622.4 ATO-1279 ' Subject: Comments: i iiii ~ .~ .... III i ii --. ii . I ii.. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION ' APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon __ Suspend _ Alter casing __ Repair well _ Change approved program __ Operation Shutdown __ Re-enter suspended well_ Plugging__ Time extension_ Stimulate_ Pull tubing__ Variance_ Perforate_ Other X Annular Injection 2. Name of Operator ARCO Alaska, Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510 5. Type of Well: Development X_ Exploratory __ Stratigraphic __ Service 4. Location of well at surface 54' FNL, 734' FEL, Sec. 3, T9N, R7E, UM At top of productive interval 1909' FSL, 1797' FWL, Sec. 34, T10N, R7E, UM At effective depth At total depth 2126' FSL, 1523' FWL, Sec.34, T10N, RTE, UM 6. Datum elevation (DF or KB) 28' RKB 7. Unit or Property name Kuparuk River Field/Tarn Oil Pool 8. Well number 2N-319 - 9. Permit number 98-197 - 10. APl number 50-103-20271 11. Field/Pool Kuparuk River Field/Tarn Oil Po°l 12. Present well condition summary Total Depth: measured 7039' feet (approx) true vertical 5600' feet Effective depth: measured 6889' (approx) true vertical 5493' Casing Length Size Structural Conductor 80' 16" Surface 2411' 7.625" Intermediate Production 6289' 5.5" x Liner 702' 3.5" Plugs (measured) feet Junk (measured) feet None Cemented Measured depth 9 Cu Yds High Early 108' 260 sx ASlll LW & 2439' 240 sx Class G & 60 sx ASl True vertical depth 108' 2308' 220 sx Class G 6317' 5077' 7019' 5586' Pedoration depth: measured 6605'-6625' true vertical 5288'-5303' Tubing (size, grade, and measured depth) 3.5", 9.3#, L-80 @ 6336' Packers and SSSV (type and measured depth) Baker CSR @ 6317', No SSSV ORIGINAL RECEIVED NOV 1998 Naska 0ii & 8as Cons, 00mmissio~ Anchorage 13. Attachments Description summary of proposal__ Detailed operation program BOP sketch __ Contact Paul Mazzolini at 265-4603 with any questions. LOT test, surface cement details and Casing detail sheets X 14. Estimated date for commencing operation November 1998 Oil X i6. If proposal was verbally approved Name of approver Date approved Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ~-'~.4,~/~~ Title Tarn Drilling Team Leader FOR COMMISSION USE ONLY 15. Status of well classification as: Gas __ Suspended __ Conditions of approval: Notify Commission so representative may witness j~'f"r"' ~_ ~.~.~f"' ~vt,~Y~/~'~ ?prove, Plug integrity_ BOP Test_ Location clearance__ Mechanical Integrity Test_ Subsequent form require~0- Approved by the order of the Commission -' issioner Date '¥'~"- ¢~.~:~ ',~/I~ SUBMIT IN TRIPLICATE Form 10-403 Rev 06/15/88 ORIGINAL SIGNED BY - ,~/(,,..~- Robert N. Chdstenson Casing Detail . 7.5/8" Surface Casin~l WELL: TARN 2N-319 ARCO Alaska, Inc. DATE: 10/1/98 Subsidiary of Atlantic Richfield Company '~ OF I PAGES # ITEMS COMPLETE DESCRIPTION OF EQUIPMENT RUN LENGTH DEPTH TOPS Doyon 141 RT to LR = 29.00 7 5/8" Landing Joint 34' OA. 29.00 FMC GEN V- Prudhoe 7 5/8" Csg Hgr - 2.00 29.00 its. 24-55 7 5/8", 29.7#, L-80 BTC-MOD 1357.33 31.00 Jt #63 7 5/8", 29.7#, L-80 BTC-MOD (Thread Locked Collar) 42.22 1388.33 . .. Gemeco 7 5/8" Stage Collar (BAKERLOK) 2.75 1430.55 Jt. ~62 7 5/8", 29.7#, L-80 BTC-MOD (Thread Locked Collar) 38.22 1433.30 its. 3-23 7 5/8";29.7#, L-80 B-rC-MOD (shutoff baffle on lop of jt #3, BAKERLO/ 878.29 1471.52 Gemeco Float Collar 1.32 2349.81 . its 1-2 7 5/8", 29.7#, L-80 BTC-MOD . 86.12 2351.13 Gemeco Float Shoe - 1.51 2437.25 2438.76 Insert baffle ~. 2306.30% · T.D @ 2450' leaving 11.24' of rathole ' 28 Gemeco Bow Spring CENTRALIZERS Run centralizers over stop collars on Jts. 1, 2, 62, & 63. Run centralizers over collars on Jts 3-13, 16, 19, 22, 25, 28, 31, · 34, 37, 40, 43, 46, 49, 55 ; · ,= Remarks String Weights with Blocks: 75K# Up,75K# Dn,12k# Blocks. Ran 57 joints of casing. Drifted casing with 6.750 plastic rabbit. Used Arctic Grade APl Modified No Lead thread compound on all connections. Casing is non-coated.- Doyon 141 Drilling Supervisor: G.R. Whitlock ARCO Alaska, Inc. Cementing Details Well Name: 2N-319 Report Date: 10/02/98 Report Number: 3 Rig Name: DOYON 141 AFC No.: AK9445 Field: Casing Size Hole Diameter: Angle thru KRU: I Shoe Depth: LC Depth: I % washout: 7.625 9.875I 2438.76 2306.30 I Centralizers : State type used, intervals covered and spacing Comments: 28 bowsprings: l~t on first 13 its. 1 every 3 its to surface + 1 on each lock jt above/below DV tool. Mud Weight: PV(prior cond): PV(after cond): YP(prior cond): . YP(after cond): · Comments: 10.2 15 12 21 17 Gels before: Gels after: Total Volume Circulated: : 8/11 4/6 660/330 Wash 0 Type: Volume: Weight: Comments: Water 5/5 8.33 Spacer ' 0 Type: Volume: Weight: Comments: ARCO 30/30 10.5 Lead Cement 0 Type: Mix wtr tamp: No. of Sacks: Weight: Yield: Comments: ASIII 70 20/240 10.5 4.42 Additives: ASlII w/50%D124,3.5%D44,.4% D46,30%D53,1.6%S1,1.5% D79/A Comments: G 70 240160 15.8/15.7 1.15/.93 Stage 1-G Stage 2-AS1 Additives: G w/1%S1,.2%D46,.3%D65 / AS1 Displacement 0 Rate(before tail at shoe): Rate(tail around shoe): Str. Wt. Up: Comments: 5.5 5.5 75 Reciprocation length: Reciprocation speed: Str. Wt. Down: 10 5 fpm 75 Theoretical Displacement: Actual Displacement: Str. Wt. in mud: 105.9/65.7 106.5/66.4 Calculated t°P °f cement: ICP: Bumped plug: I Fl°ats held: Surface Date:1012/98 Yes/yes Yes/yes Time:l 9:38/21:40 Remarks:Had good returns throughout job. Opened DV tool w/2820 psi and closed w/1530 psi Cement Company: Rig Contractor: Approved By: DS DOYON G.R. Wh t ock CASING TEST and FORMATION INTEGRITY TEST Well Name: 2N-319 Supervisor: G.R. Whitlock Date: 10/3/98 Casing Size and Description: Casing Setting Depth: Mud Weight: 9.1 ppg Hole Depth: 2,331' TVD 840 psi LOT = (0.052 × 2,331') Fluid Pumped = 7 5/8", 29.7 ppf, L-80, BTC 2,438' TMD 2,310' TVD EMW = Leak-off Press. + MW 0.052 x TVD + 9.1 ppg EMW =.16.0 ppg Pump output = 0.1000 bps TIME LINE 2°300 pd .... ' 2,100 psi , , , , , , =.ooo,,, ~ ..... ~' ' ';' '~' ' ';' ': .............. ~ ....... 1,700 psi ~,~oo.,~ ~r " -- 1,500 psi 1,400 psi ' ' 1,~o0,,~ ~ ---~-- t,200 psi ......... ~CASING TEST eoo..I -- --LOT SHUT 1N TIME 700 psi J ...... --~' CAS lNG TEST SHUT IN TIME ' 't¢t ~TIMELINE 600 p~l. , I soo p,,. ~ I I il ...i ..... .. a00 psi · ' 300p~ ' "'~;''':'' :'':''!''''' ~oo,,~ .~ I I I I . .I ~"'~ ~rl I I I I ". . O 2 4 6 8 10 12 14 16 18 ~ ~ 24 ~ ~ ~ 32 ~ 36 38 40 42 ~ 48 48 ~ $2 ~ 5e ~ ~ 82 ~ ~ ~ 70 72 74 STROKES NOTE: STROKES'TURN TO MINUTES DURING "SHUT IN TIME":see time line above · LEAK-OFF DATA MINUTES FOR FIT STROKES PRESSURE r r : 1 stks ! 60 psi ' 2 stks : 280 psi : ................... f .................. ~ .................. -{ : 3 stks : 500 psi · . .................. L ................. J .................. J .* [ 4stks ! 850 psi ~HUT II~1 TiMEi SHUT IH PRESSURE 2.0 rain ; 350 psi 4.0 min : 340 psi ; 6.0rain : , 340 psi : 8.0mm : : 330 psi NOTE: TO CLEAR DATA, HIGHLIGHT AND CASING TEST DATA MINUTES FOR CSG TEST STROKES PRESSURE J .J- ............ ! 0 stks - 0 psi ....... : .....~"~'t'~ ........ '~ ~"l~'~i ..... ................... J ..... :.??.~ ........ !o..o.__.~! ..... ! 4 stks 160 psi ................... ~ ..... ~--ut-~ ........ -~'-~ ..... .................. i ..... ~--~-t-~ ......... -~"Fa .... ................... ! ..... Y'~'t-(~ ........ '~;~d"6'~i .... ' ............. i. 8 stks 840 psi : ', 10 stks 1,200 psi , .................. a .................. u... ................ ; 11 stks 1,400 psi : ................... i .... ¥ff'~'~' ...... ~';,~'~'~;~'~'": ................... : .... ¥~-'~i'~' ....... : 14stks ! 2,000psi i .................. a .................. ~ .................. , .................. J ................. _' .................. SHUT IH TIMEi SHUT IN PRESSURE ..... b',-6"~;~ .... : ................. T'"~:66tTF~i'"i .... ¥.-6--~[~ .... !, ......... ~ ....... T"T;ff~iF~i'''~ .... ::o--~:~ .... ! .................. ?"¥;~'~'i~'~ .... ..... ~:d"~::~'"': .................. T"¥;~'~'i~a'" ::::::::::::::::::::::::::::::::::::::::::::::::::: .... :...o..:~:..j .............. i..i:..,j.,..~.~!.., 6.0 ~i~ : ,_: ~,930 .... ~:~"F4i'~'"'; ......... : ...... ;"¥;ff~iF~ .... ..... ~-:(Y'r~i'~ .... : ............. ' .... T-T/ff~i:i'~'~i'" ............. : ..... -I .............. + .................. I 9.0mm : : 1,910 psi : .... '~'~';o"~:~"'! ................. T"¥;~'~'i~a"" .... -~'s"o"~r~'''~, ................ T"Y;~:~-i~a'-' ....... L .....:. .... 4 ............... ~- .......~ ...... -.--- 20.0 rain : : 1,880 ps~ .... .2.s.:.o....m_.~.-.,,. ............... i...%~Z.o..p..~£.. .... .3..o:.9...m.?....j ................. ,_~ ...J.,..s.e..o._p...si.... PRESS THE DELETE KEY CASING TEST and FORMATION INTEGRITY TEST Well Name: Supervisor: 2N-319 G.R. Whitlock 7 518", 29.7 ppf, L-80, BTC Date: 10/5198 Casing Size and Description: Casing Setting Depth: Mud Weight: 9.1 ppg Hole Depth: 3,910' TVD 650 psi LOT = (0.052 x 3,910') Fluid Pumped = 2,438' TM D 2,310' TVD EMW= Leak-off Press. + MW 0.052 x TVD + 9.1 ppg EMW = 12.3 ppg Pump output = 0.1000 bps 2,300 psi 2,0001,900 pSlpsi j 1,800 psi 1,700 psi 1,600 psi 1,500 psi 1,400 psi t 1,300 psi · 1,200 psi 1.100 psi I 1,ooo P'~ ~ "~;"~ L-~ ,~ ~<-- ~ ~ ~--~ S T eo0 ps~ "e-'CASING TEST 800 psi ..-:.:... LOT SHUT IN TIME 700 ps~ j -~- CASING TEST SHUT IN TIME soo ps~ .~. ---+--- TIME LINE 500 psi 400 psi 100 psi 0psil ~ I 0 2 4 6 8 10121416 lB 202224262~ 303234363840424445465052545658606264666870727476768082 ~tk ark stk ark ~k ark ark sik elk elk ark ~k elk slk a~k elk ~k elk elk elk stk slk elk elk slk elk elk elk elk stk elk ~tk .~tk elk slk elk ell~ stk elk elk ~k elk STROKES LEAK-OFF DATA MINUTES FOR FIT STROKES PRESSURE 0 stks i 0 psi ........................ -~--a~- .... i .... ......................... ~--a~- .... ! .... ........................ -y-a~- .... i .... ........................ -~--a~- .... :, .... ~-~-~-~r---~ ....................... -~-~- .... I .... z~-~-~F--1 ....................... -~-~i~- .... I .... ~-~-~%-r--I , 8stks i 500 psi ~ ...................................... I .................. I .................. ~ .................. i .................. i ................... : .................. i .................. L .................. : .................. 1 .................. CASING TEST DATA MINUTES FOR CSG TEST STROKES PRESSURE ......................... O--~i'~' ........... b--~-~i ..... ......................... ¥-~i-~- .......... ~-a--~i .... i ......................... ~--~- .......... ~-a--~i .... i ......................... ~--~i~;- ........ ~ .................. ; .... ',i"~i'~' .... , .... :1-~'6'~i"'! ~ ........................ ~"~i-~i- ......... i~-~--~ii'"1" 7 stks 540 psi i 8 stks 840 psi : 9 stks 1,040 psi ! ....................... Ya--,ii~- ....... .f',-aia'-i,-~i"i r ....................... ¥.iqiiiii- ....... .i-,-,iiia-¥,-~Fi :' ....................... :f~,'~iiii~' ....... 'i',~a"i:,-~i"i ~. .................. ? .................. i .................. l , ' SHUT IN TIME! S~UT IN PRESSURE SHUT IN TIME SHUT IN PRESSURE ..... ~'.~'~;'~i-r~ .... : ...................... ~;~I1~i''~ .... 'O:~ ' ~--i~f .... ....................... [~a'~--i'l'l] [ ~[--Ol~{i--F~ i.... .... ...................... f,-~o--~-~i--' ..... 'i i-C~' ~'~-J-~ .... T ....................... ~-~-~' '~[''-i i ' ' ' -5'76' ~- [~ .... ~ ...................... ~;~ 6' '~]l--] 2.0 min : 370 )si : 3.0min : : 360 )si : 4.0 rain : : 360 )si 5.0min , , 350 )si : ..... 6'.-~'~-i~'"'[ .............. :-'-17---~-~-I}-:~,-i'-"i ..... %.'6'hhT~ .... ! .................. 1 .... 7.0mm , , 1,920 ......................... : ............ j___!_,~_l__O_..P_S. !__] lO.Omin [ [ 1,910psi i ~ .................. J .................. J .................. J 15.0 rain , , 1,890 psi , Z]ie;E~ZZZZZZZZZii}'.~YE~FLE] ZZ.i°:iEiinZZZZZZZZi];.'~.~EECi] NOTE: STROKES TURN TO MINUTES DURING "SHUT IN TIME":see time line above NOTE: TO CLEAR DATA, HIGHLIGHT AND PRESS THE DELETE KEY 6~N'I' l~Y' ll-2U-:oU ' ~'ZU[-'~] ' AKUU AL,A31tA-'~ uu / ZFo /o~x,m o/ o , Daily Drilling Report ~' ARCO Alaska, Inc. Weft ~-~1~ Ii Dep~ (MOIleD) ~50~16 Pr~ ~Dln MD: 8~ 1~,~: i~ Contre~: ~YON ~' S ~ Z3~2 C~m Co~ ~ 337e24 I Es~ C~ To Date ~ Rig ~ .... ~YON 141 ;Las[ C~ 7-5~ ~ 24~ ~Ne~ ~9: S-1/2" x 3-t/2" ~ 7023' ~Sh~ Te~[: Opmet~ At US~: HIU DOPE ~p~mJ~ ~al~8: Test DOPE. Cleano~ ca,no wi ~ll I~lh bit, ~H and ddll w/~mctianal BHA MUD ~TA ~ILLING DATA ~T DATA E~ D~L~/BOP DATA ~OD ~"~' DEP 1H BIT NO. BIT NO. INCIDE~ LAST BOP/DI~RT LAST BOP/OR!LL -' 1 ~ ND Z45~ : 1 N TRT I~D~ '~IOHT ROT ~ ~IZE 31~ ~EMPLUYER L~'r H~5 DRILL LAST FIRE DRILL VISCO~ I~ PU ~ MA~ , M~E 5 P[L ~5T CONFINED LAST 5P[L DRILL 63aqc 78 S~ N 5PACE PV~P SO ~ TYPE ~PE T~E F~L & WATER JB 121 73 F~HCL GELS AVG D~G SER~I. NO SER~I. N0 VOLUME FI)EL USED API~ M~D~G ~P~[ .... ~'~0'~ ....... ~ST S~E~ MTG DRILL WATER UGED- HTHP ~ T~Q BTM DEP~ ~ DEP~ IN ~TABLE WATEE m~30 m~ ,la~ lOS INJ~ON USED - BBLS SOLIQS TRQ OFF FOOTAGE FOOTAGE INJECTION WE~ W~ER & 8.0% 2342 2N~13 PB~NN~L DATA HOLE VOLUME PUMP PRES ADT/AST ADTtAST SOURC~ ~LL TFMP 'K TTbbl 2300 ~ ~ ] 1%2 I~S ~ 'MBT .PUMP NO ~ Z ~B 2 ~TE (bom) WINO SPEED lB tl2/} 30-4o 3.5 ~ ..... :L~E~SZ R~ t RPM t PRFS~E (ps,) WIN~ DIRFCTION LGS SPM I TFA TFA INJE~TI~ FLUIDS CHILL FACTOR 'F 25~9 703 PIT VOL G~ 2 JE I'S J~ I ~ Freen Water ANCO PERSONNEL ~0 DAILY MUD ~PS 1 O~ COST BIT COST CO~RACTOR 2~ I ~ III 80~ 0 PERSONNel 0 TOTAL MUD SPP i DULL DULL TOT~ VOl {bb ) MI~ PERSONNEL COMPANY MUD ~ GRAOE GRADE TOT FO~ W~U. ~.,) S~"V'CE TOT~ ~ m TI~E } END HOURS [ Op~ CODE ~ HOLE SECT ]PHA~E Dp5 I OI'E~TJON~ F'R~ 00~ - OD00 t3:~ AM 0~:3~ AM ~.~ DRIL SUR~ Making Hole Dr~ to ~0' o5:30 AM 07:00 AM 1 ,~ CIRC SU~ Maklnfl Hole Pu~ s~eo CBU 07:~ AM 0~:00 AM 1.~ ~PBR~P SURF Making Hole ~h~ *rlp lo 1744' 08:~ AM 09:00 AM ~.~ WIPER~P SURF Casing a~ Pu~ ~ao, CBU Cementln9 09:~ AM 10:00 AM 1.~ ~IP.OUT SURF Caging a~ THp out ol ~o)e ~ BHA Come,lnG 10:~ AM 12:OQ PM 2.~ BHA SURF Casing and UD BHA and do~la~ ~O Cem~flng q2:O0 PM 04:3~ PM 4.~0 CASG SURF Ca~ng a~ Run 7.~a" c~=in9 ~ ' C=m~fln9 04:30 PM 0~:30 PM 2.00 CIRC SURF Casing a~ Cim ~ c~on mud Cem~lng 86:30 PM 01:3~ PM 1.~ CEMENT SURF C=~n9 a~ C~nt ~ ~e ~ q~ bbl Laad and 80 bbl ~il. Cem~g wi 26 ~1 H20 12 ~ ~a ~2 ~ spacer 36,8 ~l mu~ ~F ~ 19:38 10.2.~. Op~ DV tool ~ 2820 07:30 PM 08:30 PM 1,00 CI~ SURF C~lR~ a~ Cite ~ ~. ~Ot ~ DDI ~Ua contamlnat~ Cem~tln~ sp~er aha 10 ~1 ¢~ c~mln~ed ~d back. 08:30 PM 11:~ PM 2.~0 CEMENT SURF C~i.~ ~ C~n~ 2~ =la~ 1~1 lead ~d ~ bbl~l. ~ !~.~ Ce~flng p~ ¢~ In ~ume b~e awi~l~l~ I~ tall. Dl~l~e 56,~ ~ mua. ~P ~ Zl~ ~. MOflllor well 11:00 PM 12:~ AM 1 .OB OTHER SURF Casing a~ ~D =~ ha~ and ~ng jL Ce~n~g 24,0U Daily Drilling Report: 2N-319 10/02298 Page 1 SENT BY' l 1-23-58 ' 3' 2~t~t ' .~t:O :~L~K~-~ uu f z sa fo~z, ~ z~ u 'qF' ARCO Alaska, Inc. Cementing Details Well Name: 2N-3t9 Reoort Date: tO/02/g8 D.~p. nr~ Numhnr' Rig N~me: DOYEN 141 AFC Nu: AKg44B Field: Contrallzer~ C~mmo~Is: 28 buw~prir~s: t/j[ on f~st ~3 J~. I ~ 3 its Io ~ce * I on .ach IocK~ ~bove/~l~V ~. Mud We~ghl: PV{pnor Ccmments: 10.2 16 ~ 1Z 21 17 ~ ........... Wmmh 0 TY~: Volmne ~: Com~e~s; Water ~5 8.33 8pacer 0 Type: Vol~e ~igh~ Comments: ARCO Comm~m: A~III T0 ZW2~] 10.5 4,4~ ..~ .... ~itN~: A~III wi ~01 ~,3,S% ~4,,4%D~,30%~3,1,5%S1,1.5%DT~A T.~ Cement O T~: M~wlr t~p'. No. al ~Os: We~t Yle~d: Corn me~s: 70 S~e 1 .G G .... . S~e 2.AS1 ~it~. G w/1%Sl,.2%04G. 3%~S I A6t DIsplacer 0 R~n(h~ tail at ~oe)' Sir ~. Up: C~menls: &,8 15.5 15 .~ ,, R~ip~c~mn le~t~ R~ipru~iun spued: StC ~. Do'~'n~ 10 5 f~ 7S ~. , ,. 1os.g/ss.7 108.~a.4 . r,-- Cal~t~ tod ~ ceme~: R~s'H~ good mtur~ ~roug~oul )ob. Opened DV ~ol wi 2820 psi a~d ~.d wi t B~O psi __~.. , . .... Cement Company: Rig Contractor: [Approved By: OS DOYEN IG,R. Whitlock ARCO Alaska, Inc. -' Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 October 30, 1998 Mr. David J. Johnston Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Subject: 2N-319 (Permit No. 98-197) Well Completion Report Dear Mr. Commissioner: Enclosed is the well completion report for the completion on Tarn 2N-319. If there are any questions, please call 263-4603. Sincerely, P. Mazzolini Tarn Drilling Team Leader PM/skad STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR REOOMPLETION REPORT AND LOG 1 Status of Well Classification of Service Well OIL [] GAS E~ SUSPENDED E~] ABANDONED~ SERVICE [~] 2 Name of Operator 7 Permit Number ARCO Alaska, Inc 98-197 3 Address 8 APl Number P.O. Box 100360, Anchorage, AK 99510-0360 50-103-20271 4 Location of well at surface ~ ". - - 9 Unit or Lease Name 54' FNL, 734' FEL, Sec, 3, T9N, R7E, UM //~~_~/ Kuparuk River Unit At Top Producing Interval . i 10 Well Number 1909' FSL, 1797' FWL, Sec. 34, T10N, R7E, UM i ~-:... !j ~, ~.~._~ ' ~ 2N-319 2126' FSL, 1523' FWL, Sec. 34, T10N, R7E, UM Kuparuk River Field 5 Elevation in feet (indicate KB, DF, etc.) I 6 Lease Designation and Serial No. Tarn Oil Pool RKB 28', Pad 121'I ADL 380054 ALK 4602 12 Date Spudded 13 Date T.D. Reached 14 Date Comp., Susp. or Aband. 115 Water Depth, if offshore 16 No. of Completions 01-Oct-98 06-Oct-98 08-Oct-98I NA feet MSL 1 17 Total Depth (MD+TVD) 18 Plug Back Depth (MD+TVD) 19 Directional Survey 20 Depth where SSSV set 21 Thickness of permafrost 7039' MD & 5600' TVD 6889' MD & 5493' TVD YES M NO U NA feet MD 1050 APPROX 22 Type Electric or Other Logs Run GPJRes, Neutron/Density, GR/CCL 23 CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT GRADE TOP BTM HOLE SIZE CEMENT I~ECOI~D 16" 62.58t/ H-40 SURF. 108' 24" 9 cu. yds High Early 7.625" 29.7# L-80 SURF. 2439' 9.875" 260 sx ASlIILW, 240 sx Class G, 60 sx ASl 5.5" x 15.5# L-80 SURF. 6317' 6.75" 220 sx Class G 3.5" 9.3# L-80 6317' 7019' 6.75" (included above) 24 Perforations open to Production (MD+TVD of Top and Bottom and 25 TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 3.5" 6336' 6317' (CSR) 6605'-6625' MD 5288'-5303' TVD 4 spf 26 ACID, FRACTURE, CEMENT SQUEEZE, ETC DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 6605'-6625' 211,662# prop w/211,263# in formation and 399# in pipe @ 10 ppa in perfs 27 PRODUCTION TEST Date First Production10/23/98 IMeth°d °f Operati°n (Fl°wing' gas lift' etc')Gas Lift 0F IG[NAL Date of Test Hours Tested PRODUCTION FO OIL-BBL GAS-MCF WATER-BBt CHOKE SIZE I GAS-OIL RATIO 10/23/98 8.00 TEST PERIOI: 824 329 0 176I 424 Flow Tubing Casing Pressure CALCULATED OIL-BBL GAS-MCF WATER-BDt OIL GRAVITY-APl (corr) Press. 307 0 24-HOUR RATE: 906 422 0 36.9° 28 CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. N/A Form 10-407 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE 29. 30. GEOLOGIC MARKERS FORMATION TESTS NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS DEPTH TRUE VERT. DEPTH GOR, and time of each phase. Top Reservoir 03) 6530' 5233' Base Reservoir 02) 6673' 5338' Annulus left open - freeze protected with diesel. 31. LIST OF ATrACHMENTS Summary of Daily Drilling Reports, Directional Survey 32. I hereby certify that the foregoing is true and correct to the best of my knowledge. ~- 0 ~ Prepared by Name/Number Sharon AIIsup-Drake/263-4612 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 only 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 cement- ing and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". Form 10-407 Date: 10/19/98 ARCO ALASKA INC. WELL SUMMARY REPORT Page: 1 WELL:2N-319 WELL_ID: AK9445 TYPE: AFC: AK9445 STATE:ALASKA AREA/CNTY: NORTH SLOPE WEST FIELD: KUPARUK RIVER UNIT SPUD:10/01/98 START COMP: RIG:RIG # 141 BLOCK: FINAL: WI: 0% SECURITY:0 API NUMBER: 50-103-20271-00 09/30/98 (D1) TD: 108'(108) SUPV:G.R. WHITLOCK 10/01/98 (D2) TD: 1886'(1778) SUPV:G.R. WHITLOCK 10/02/98 (D3) TD: 3450' (1564) SUPV:G.R. WHITLOCK 10/03/98 (D4) TD: 3450' 0) SUPV:G.R. WHITLOCK 10/04/98 D5) TD: 4690' 1240) SUPV:G.R. WHITLOCK 10/05/98 D6) TD: 6202' 1512) SUPV:G.R. WHITLOCK 10/06/98 (D7) TD: 7039' (837) SUPV:G.R. WHITLOCK MW: 10.0 VISC: 115 PV/YP: 0/ 0 DRILLING ~ 225' APIWL: 0.0 Move rig from 2N-315 to 2N-319. Accept rig ~ 1700 hrs. 9/30/98. N/U diverter. MW: 10.2 VISC: 57 PV/YP: 17/25 CIRC AT CASING PT. APIWL: 8.5 Clean out ice in conductor to 108' Drill to 1886' Pump hi-vis sweep. MW: 10.2 VISC: 53 PV/YP: 15/21 APIWL: 4.4 N/U BOPE Drill to 2450'. Run 7-5/8" casing to 2438' Pump first and 2nd stage cement. MW: 9.1 VISC: 44 PV/YP: 0/ 0 APIWL: 7.6 DRILLING ND diverter system. NU casing head and test to 1000 psi, OK. NU BOPE and test to 300/3000 psi. BHA MW: 9.1 VISC: 46 PV/YP: 10/18 APIWL: 5.8 Clean out float collar, shoe and 20' of new hole. Displace contaminated mud w/ new 9.1 ppg mud. Run FIT to 16.0 ppg EMW. Drill from 2470' to 4690' MW: 9.9 VISC: 49 PV/YP: 11/19 DRILLING AT 6750' APIWL: 4.6 Drill from 4690' to 6202' MW: 10.0 VISC: 46 PV/YP: 11/20 LAYING DOWN DRILLPIPE AP IWL: 4.4 Drill from 6202' to 7039' Date: 10/19/98 ARCO ALASKA INC. WELL SIIMMARY REPORT Page: 2 10/07/98 (D8) TD: 7039' ( 0) SUPV:G.R. WHITLOCK 10/08/98 (D9) TD: 7039'( 0) SUPV:G.R. WHITLOCK 10/09/98 (D10) TD: 7039'( 0) SUPV:G.R. WHITLOCK MW: 10.0 VISC: 45 PV/YP: 17/15 APIWL: 4.4 PREPPING TO RUN TUBING. Run 5.5" x 3.5" casing string. Pump cement. MW: 8.3 VISC: 28 PV/YP: 1/ 0 APIWL: 0.0 MOVING RIG ON HIGHL Run 3.5" tubing. Freeze protect well. N/D BOPE. N/U tubing adapter and test to 5000 psi. Release rig ~ 2100 hrs. 10/8/98. MW: 0.0 VISC: 28 PV/YP: 0/ 0 APIWL: 0.0 RIG RELEASED Ran LOT on 7-5/8" x 5.5" annulus. ARCO Alaska, Inc. KUPARUK RIVER UNIT ,, WELL SERVICE REPORT '~, Kl(2N-319(W4-6)) .. WELL JOB SCOPE JOB NUMBER 2N-319 PERFORATE, PERF SUPPORT 1009981523.6 DATE DAILY WORK UNIT NUMBER 10/12/98 INITIAL PERFORATIONS DAY OPERATION COMPLETE I SUCCESSFUL KEY PERSON SUPERVISOR 1 YESI YES SWS-D ECKERT C HAN EY FIELD AFC# CC# Signed ESTIMATE K85104 180KN U2TN Initial Tbg Press Final Tbg Press Initial Inner Ann Final Inner Ann I Initial Outer Ann Final Outer Ann 250 PSI 50 PSI 250 PSI 50 PSII 0 PSI 0 PSI DAILY SUMMARY ISHOT INITIAL PERFORATIONS 6605' - 6625' RKB (20'). W/2-1/2" HC, BH CHGS, 4 SPF, 180 DEG PHASING, 2 SPF 155 DEG CCW I FROM HIGH SIDE, & 2 SPF 25 DEG CW FROM HIGH SIDE.[Perf] I TIME 14:30 16:00 16:30 17:00 17:30 17:45 18:30 19:30 LOG ENTRY MIRU SWS E/LINE UNIT. HELD SAFETY MEETING (4 ON LOCATION) PT'D EQUIP TO 3000 PSI. (OK). RIH W/1-3/8" HEAD, 1-11/16" SWIVEL, 2-1/8" SINKER BAR (6'), 1-11/16" GR, 1-11/16" SPRING TOOL SAVER, & 20' OF 2-1/2" HC GUN - BH CHGS- 4JSPF- 180 DEGREE PHASING- ORIENTATED 2 JSPF 155 DEGREES CCW FROM THE HIGH SIDE & 2 JSPF 25 DEGREES CW FROM THE HIGH SIDE. TAGGED BTM @ 6774' RKB AND TIED IN TO MWD GAMMA RAY LOG DATED 10/06/98. DEPRESSURED WHTPTO200PSI. SHOT PERFORATIONS FROM 6605' - 6625' RKB. WHTP DROPPED 20 PSI. STARTED OOH. ON SURFACE. ALL SHOTS FIRED. RDMO SWS. WELL SECURED AND NOTIFIED DSO OF STATUS. WELL JOB SCOPE JOB NUMBER 2N-319 FRAC, FRAC SUPPORT 1009981527.7 DATE DAILY WORK UNIT NUMBER 10/16/98 TARN SAN D FRAC DAY OPERATION COMPLETE I SUCCESSFUL KEY PERSON SUPERVISOR 2 YESI YES DS-YOKUM KRALICK FIELD AFC# CC# Signed ESTIMATE K85104 180KN U2TN InitialTbgPress FinalTbgPress Initial lnner Ann Final lnner Ann IlnitialOuterAnn I Final Outer Ann 70 PSI 0 PSI 500 PSI 500 PSIII0 PSI 0 PSI DAILY SUMMARY FRAC TARN SAND W/BRACKET FRAC (316 BBLS OF LITE FILL AND 20/40 SAND) AS A BARRIER - PUMPED 211,662# TOTAL PROP W/211,263# IN FORMATION AND 399# IN PIPE @ 10 PPA IN PERFS - ISlP 774 PSI (DATAFRAC) - MAX PRESS 6345 PSI DURING BREAKDOWN - FILL DEPTH APPROX. 6687'- 2250 PSI BHP [Frac-Refrac] TIME LOG ENTRY 06:00 MIRU DS AND LRS 08:00 SAFETY MEETING - CONGESTED PAD AND WINDY TODAY - RIG INFORMED 09:00 P/T HARD LINE AND SURFACE EQUIPMENT TO 9000 PSI - PRESS UP 7" TO 3500 PSI 09:10 BREAKDOWN AND STEP DOWN - 6250 MAX PRESS DURING BREAKDOWN - ISIP 740 PSI - PUMP PULSES 09:54 SCOUR STAGE XLINKED 50# GEL - 75 BBLS W/1 PPA - FLUSH 50 BBLS - 75 BBLS W/2 PPA - FLUSH 50 BBLS - FLUSH 124 BBLS STRAIGHT SW W/3% KCL 10:24 STEP DOWN @ 4 DIFFERENT RATES - 774 ISIP 11:49 DATAFRAC 64 BBLS/DISPLACE AND 86 BBL DATAFRAC XLINK GEL @ 15 BPM - FLUSH W/69 BBLS SW AND SHUTDOWN - ISlP 905 13:08 13:25 14:45 14:55 15:15 15:35 16:50 PULSE TO VERIFY CLOSURE (681 PSI) - PULSE AGAIN (714 PSI) - REDESIGN JOB BRACKET FRAC W/20/40 SAND AND GLASS BEADS (316 BBLS) W/20# LINEAR GEL - SHUTDOWN ISlP 733 PSI PUMP PULSE- 1 BBL PUMP PRE PAD 15 BPM 20# LINEAR GEL - 400 BBLS PUMP PAD 15 BPM 50# DELAYED XLINK GEL - 300 BBLS PUMP SAND STAGES, 2 PPA TO 10 PPA PER SCHEDULE USING 50# XL GEL FLUSH W/11 BBLS SW AND 43 BBLS DIESEL - SHUT DOWN - 2877 PSI FINAL - 10 PPA IN PERFS - PUMPED 211,662# W/#211,263 OF 10 PPA 12/18 CARBO IN PERFS - 399# IN PIPE WITH FILL DEPTH APPROX. 6687' TIME 17:30 20:30 LOG ENTRY BLEED ANNULUS TO 500 PSI - INFORMED OPERATOR OF WELL STATUS - ALL TREESAVER RUBBERS RETURNED RDMO DS AND LRS r SURVEY CALCULATION AND FIELD WORKSHEET i ~ Job No. 0450-01488 Sidetrack No.__ Page 1 of 4 I~ [l[t-] ~1 :(,--"l Company ARCO ALASKA, INC. Rig Contractor & No.DOYON - 141 Field TARN DEVELOPMENT FIELD Well Name & No.TARN DRILLSITE 2N/319 Survey Section Name p-1 BHI Rep. I~~ WELL DATA Target TVD (FT) Target Coord. N/S Slot Coord. N/S -53.65 Orid Correction 0.000 Depths Measured From:RKl3~ MSL[~ SS[- Target Description Target Coord. E/W Slot Coord. E/W -733.82 Magn. Declination 26.810 Calculation MethodMINIMUM CURVATUI Target Direction (DD) Build\Walk\DL peltl0ft[~ 30m[-] 10m[~ Vevt. Sec. Azim. 306.34 Magn. to Map Corr. 26.810 Map North to: OTHER SURVEY DATA ' Total Coordinate Build Rate Walk Rate Survey Survey Incl. Hole Course Vertical Date Tool Depth Angle Direction n~nl~[t TVD Section N(+)/ S(-) E(+2F/T~N(-' DE Build (+) Right (+) Comment _ Type (FT) (D-D) (DD)- . (FT) (FT)-- -- (Per 10~3 F~lB)rop (-) Left (-) MWD 108.00 0.00 0.00 108.00 0.00 0.00 0.00 TIE IN POINT . 01-OCT-91 MWD 245.29 0.40 219.75 137.29 245.29 0.03 -0.37 -0.31 0.29 0.29 01-OCT-91 MWD' 333.75 0.70 187.60 88.46 333.74 -0.21 -1.14 -0.58 0.47 0.34 01-OCT-9~ MWD 424.02 0.61 196.26 90.27 424.01 -0.64 -2.15 -0.78 0.15 -0.10 01-OCT-9~ MWD 521.04 0.38 166.03 97.02 521.03 -1.07 -2.96 -0.85 0.35 -0.24 01-OCT-9t MWD 612.13 0.33 185.72 91.09 612.11 -1.43 -3.51 -0.80 0.14 -0.05 01-OCT-98 MWD 704.28 0.53 167.25 92.15 704.26 -1.89 -4.19 -0.74 0.26 0.22 01-OCT-9~ MWD 794.22 0.49 173.23 89.94 794.20 -2.47 -4.98 -0.60 0.07 -0.04 01-OCT-98 MWD 883.85 0.62 167.33 89.63 883.82 -3.10 -5.83 -0.45 0.16 0.15 01-OCT-98 MWD 975.20 0.42 247.07 91.35 975.17 -3.30 -6.45 -0.65 0.75 -0.22 01-OCT-98 MWD 1064.29 2.59 295.54 89.09 1064.23 -1.15 -5.70 -2.76 2.62 2.44 60'--305M 01-OCT-9~ MWD 1153.14 4.99 299.98 88.85 1152.88 4.66 -2.91 -7.92 2.72 2.70 60'-- 305M .. 01-OCT-9~ MWD 1245.04 7.66 301.41 91.90 1244.21 14.74 2.28 -16.61 2.91 2.91 1.56 60'--305M .,. 01-OCT-9~ MWD 1337.87 10.53 302.37 92.83 1335.86 29.36 10.05 -29.06 3.10 3.09 1.03 60'--10R 01-OCT-9~ MWD 1432.24 13.89 304.94 94.37 1428.08 49.30 21.16 -45.63 3.61 3.56 2.72 60--10R 01-OCT-9~ MWD 1525.68 17.68 305.73 93.44 1517.98 74.71 35.87 -66.35 4.06 4.06 0.85 45'--10R 01-OCT-9~ MWD 1619.38 20.16 307.72 93.70 1606.62 105.08 54.06 -90.68 2.73 2.65 2.12 45'--10R 01-OCT-9~ MWD 1713.92 22.56 307.11 94.54 1694.66 139.51 74.97 -118.03 2.55 2.54 -0.65 45'--10R 01-OCT-9~ MWD 1808.54 25.03 307.77 94.62 1781.23 177.67 98.19 -148.34 2.63 2.61 0.70 30'--HS 02-OCT-9~ MWD 1902.96 27.72 308.35 94.42 1865.81 219.59 124.05 -181.35 2.86 2.85 0.61 30'--HS 02-OCT-9~ MWD 1996.85 30.28 308.96 93.89 1947.92 265.07 152.49 -216.89 2.74 2.73 0.65 30'--HS 02-OCT-9~ MWD 2091.22 32.22 306.95 94.37 2028.60 314.00 182.58 -255.50 2.33 2.06 -2.13 30'--HS 02-OCT-9~ MWD: 2187.14 34.18 307.39 95.92 2108.86 366.51 214.31 -297.35 2.06 2.04 0.46 45'--HS 02-OCT-9~ MWD 2280.33 36.84 307.38 93.19 2184.71 420.63 247.17 -340.35 2.85 2.85 -0.01 45' HS i i I SURVEY CALCULATION AND FIELD WORKSHEET Job No. 0450-01488 Sidetrack No. ?age 2 of 4 i._[l[~ll::~l. Company ARCO ALASKA, INC. Rig Contractor & No.DOYON - 141 Field TARN DEVELOPMENT FIELD ! Well Name & No.TARN DRILLSITE 2N/319 Survey Section Name p-1 BHI Rep. WELL DATA Target TVD (FT) Target Coord. N/S __ Slot Coord. N/S -53.65 Grid Correction 0.000 Depths Measured From:RKl~ MSL[~ SS[- Target Description Target Coord. E/W Slot Coord. E/W -733.82 Magn. Declination 26.810 Calculation MethodMINIMUM CURVATUI Target Direction (DD) Build\Walk\DL pO[10ft~ 30m[~ 10m[~ Vert. Sec. Azim. 306.34 Magn. to Map Corr. 26.810 Map North to: OTHER SURVEY DATA Survey Survey Incl. Hole Course Vertical Total Coordinate Build Rate Walk Rate Date Tool Build (+) Right (+) Comment Depth Angle Direction Le(nl~~ TVD Section N('~T/)S(-) E(+(}F/T?(-' (peDrL100 F~l~rop (_) (.) Type (FT) (D-D) (DD) (FT) Left 02-OCT-98 MWD' 2376.43 39.38 305.44 96.10 2260.32 479.93 282.35 -388.09 2.92 2.64 -2.02 45'--HS 04-OCT-98 MWD 2489.93 41.68 305.90 113.50 2346.58 553.67 325.36 -448.00 2.04 2.03 0.41 · 04-OCT-98 MWD 2585.89 43.54 306.67 95.96 2417.20 618.64 363.81 -500.36 2.01 1.94 0.80 30'--HS 04-OCT-98 MWD 2679.57 44.04 308.12 93.68 2484.83 683.45 403.18 -551.86 1.20 0.53 1.55 04-OCT-9fi MWD 2772.66 43.84 306.08 93.09 2551.86 748.03 442.14 -603.38 1.54 -0.21 -2.19 04-OCT-9fi MWD 2867.18 43.97 307.34 94.52 2619.97 813.57 481.32 -655.92 0.93 0.14 1.33 04-OCT-9fi MWD 2962.99 44.09 307.24 95.81 2688.85 880.16 521.67 -708.90 0.14 0.13 -0.10 04-OCT-9~ MWD 3056.61 44.20 306.01 93.62 2756.03 945.36 560.57 -761.23 0.92 0.12 -1.31 04-OCT-9~ MWD 3149.66 44.32 304.71 93.05 2822.67 1010.29 598.15 -814.19 0.98 0.13 -1.40 04-OCT-9~ MWD 3245.26 44.49 305.78 95.60 2890.97 1077.17 636.75 -868.82 0.80 0.18 1.12 04-OCT-9~ MWD 3337.05 44.44 306.49 91.79 2956.48 1141.46 674.66 -920.74 0.54 -0.05 0.77 04-OCT-9~ MWD 3432.37 44.50 307.78 95.32 3024.50 1208.23 714.97 -973.98 0.95 0.06 1.35 04-OCT-9~ MWD 3525.89 44.55 308.24 93.52 3091.18 1273.78 755.36 -1025.64 0.35 0.05 0.49 04-OCT-9~ MWD 3620.43 44.49 307.51 94.54 3158.59 1340.04 796.05 -1077.97 0.55 -0.06 -0.77 04-OCT-9~ MWD 3709.84 44.52 307.89 89.41 3222.35 1402.70 834.38 -1127.56 0.30 0.03 0.43 -- 04-OCT-9~ MWD 3804.06 44.67 306.52 94.22 3289.45 1468.84 874.37 -1180.24 1.03 0.16 -1.45 04-OCT-9~ MWD 3899.15 44.74 306.11 95.09 3357.03 1535.73 913.99 -1234.14 0.31 0.07 -0.43 04-OCT-9~ MWD 3994.82 44.77 306.20 95.67 3424.97 1603.09 953.73 - 1288.53 0.07 0.03 0.09 04- OCT-9~ MWD 4086.96 45.24 306.49 92.14 3490.12 1668.24 992.35 -1341.01 0.56 0.51 0.31 04-OCT-91 MWD 4180.55 45.41 307.41 93.59 3555.92 1734.79 1032.35 -1394.20 0.72 0.18 0.98 04-OCT-91 MWD 4274.26 45.38 307.96 93.71 3621.72 1801.49 1073.14 -1446.99 0.42 -0.03 0.59 04-OCT-91 MWD 4368.34 45.56 307.65 94.08 3687.70 1868.54 1114.25 -1499.99 0.30 0.19 -0.33 04-OCT-9t MWD 4461.86 46.01 307.78 93.52 3752.92 1935.55 1155.25 -1553.01 0.49 0.48 0.14 04-OCT-98 MWD 4555.03 46.70 307.23 93.17 3817.22 2002.95 1196.30 ~ 1606.49 0.85 0.74, -0.59 I i I SURVEY CALCULATION AND FIELD WORKSHEET Job No. 0450-01488$idctrack No.__ Page3 of 4 1-'LlJ~:l=(-~"! Company ARCO ALASKA, INC. Rig Contractor & No. DOYON - 141 Field TARN DEVELOPMENT FIELD I I Well Name & No.TARN DRILLSITE 2N/319 Survey Section Name p-1 ___ BHI Rep. I~"~ WELL DATA Target TVD__ (FT) Target Coord. N/S Slot Coord. N/S -53.65 Grid Correction 0.000 Depths Measured From:RKI~ MSLu SS[~ Target Description Target Coord. E/W Slot Coord. E/W -733.82 Magn. Declination 26.810 Calculation Method MINIMUM CURVATU] Target Direction (DD) _ Build\Walk\DL pdgl0ft[~ 30m[~ 10m[~ Vert. Sec. Azim. 306.34 Magn. to Map Corr. 26.810 Map North to:OTHER SURVEY DATA Survey Survey Incl. Hole Course Vertical Total Coordinate Build Rate Walk Rate Date Tool Depth Angle Direction L~nl~~ TVD Section N(-~T/~(-) E(+0F/T~W(- DL Build (+) Right (+) Comment Type (FT) (D-D) (DD)- - (FT), -- -- -- (Per 100 F2t~rop (-) Left (-) 05-OCT-9~ MWD 4654.03 45.03 302.95 99.00 3886.17 2073.95 1237.15 -1664.58 3.53 -1.69 -4.32 30'--140L 05-OCT-9~ MWD 4747.66 45.20 305.15 93.63 3952.25 2140.23 1274.29 -1719.54 1.67 0.18 2.35 05-OCT-9~ MWD 4839.98 44.90 303.22 92.32 4017.48 2205.51 1311.00 -1773.58 1.51 -0.32 -2.09 05-OCT-9~ MWD 4929.65 45.03 303.02 89.67 4080.92 2268.78 1345.63 -1826.65 0.21 0.14 -0.22 05-OCT-9~ MWD 5023.67 44.96 303.45 94.02 4147.41 2335.16 1382.06 -1882.26 0.33 -0.07 0.46 05-OCT-9~ MWD 5119.17 45.42 304.37 95.50 4214.72 2402.85 1419.86 -1938.48 0.84 0.48 0.96 05-OCT-9~ MWD 5212.24 45.74 303.38 93.07 4279.86 2469.26 1456.91 -1993.67 0.83 0.34 -1.06 05-OCT-9~ MWD 5306.74 45.86 304.06 94.50 4345.74 2536.94 1494.52 -2050.02 0.53 0.13 0.72 05-OCT-9~ MWD 5401.45 46.47 304.60 94.71 4411.34 2605.21 1533.05 -2106.44 0.76 0.64 0.57 05-OCT-9~ MWD 5496.47 45.27 304.12 95.02 4477.50 2673.37 1571.54 -2162.73 1.31 -1.26 -0.51 30'--160R 05-OCT-91 MWD 5590.28 44.86 305.18 93.81 4543.75 2739.75 1609.30 -2217.36 0.91 -0.44 1.13 05-OCT-91 MWD 5684.05 43.37 305.02 93.77 4611.07 2805.01 1646.83 -2270.77 1.59 -1.59 -0.17 30'--150R 05-OCT-91 MWD 5778.23 42.42 306.08 94.18 4680.07 2869.10 1684.09 -2322.92 1.27 -1.01 1.13 ,. 05-OCT-91 MWD 5872.05 42.55 305.52 93.82 4749.26 2932.46 1721.16 -2374.32 0.43 0.14 -0.60 '.. 05-OCT-91 MWD 5965.02 42.85 305.48 92.97 4817.58 2995.50 1757.77 -2425.64 0.32 0.32 -0.04 05-OCT-98 MWD 6058.24 42.53 305.47 93.22 4886.10 3058.70 1794.45 -2477.12 0.34 -0.34 -0.01 06-OCT-9E MWD 6157.85 42.73 305.04 99.61 4959.39 3126.15 1833.39 -2532.21 0.35 0.20 -0.43 06-OCT-9~ MWD 6249.40 42.51 305.14 91.55 5026.76 3.188.13 1869.03 -2582.93 0.25 -0.24 0.11 06-OCT-9~ MWD 6344.22 42.61 304.60 94.82 5096.60 3252.24 1905.69 -2635.55 0.40 0.11 -0.57 06-OCT-9~ MWD 6439.53 42.47 305.59 95.31 5166.83 3316.66 1942.74 -2688.27 0.72 -0.15 1.04 06-OCT-9~ MWD 6533.39 42.63 305.51 93.86 5235.97 3380.13 1979.64 -2739.91 0.18 0.17 -0.09 06-OCT-9~ MWD 6627.97 43.50 305.89 94.58 5305.07 3444.71 2017.33 -2792.36 0.96 0.92 0.40 ., 06-OCT-9E MWD 6724.00 43.97 305.62 96.03 5374.46 3511.09 2056.12 -2846.23 0.53 0.49 -0.28 __ 06-OCT-9~ MWD 6817.10 44.01 304.70 93.10 5441.44 3575.74 2093.36 -2899.09 0.69 0.04 -0.99 I Ill II SURVEY CALCULATION AND FIELD WORKSHEET ~ob No. 0450-01488 Sidetrack No. ,, Page 4 of 4 Company ARCO ALASKA, INC. Rig Contractor & No.DOYON - 141 Field TARN DEVELOPMENT FIELD Well Name & No.TARN DRILLSITE 2N/319 Survey Section Name p-1 BHI Rep. I~"~ WELL DATA -- Target TVD (FT) Target Coord. N/S Slot Coord. N/S -53.65 Grid Correction 0.000 Depths Measured From: RKI~ MSL[~ SS[- Target Description Target Coord. E/W Slot Coord. E/W -733.82 Magn. Declination 26.810 Calculation MethodMINIMUM CURVATUl Target Direction (DD) Build\Walk\DL pdt00ft[~ 30m~ 10m[~ Vert. Sec. Azim. 306.34 Magn. to Map Corr. 26.810 Map North to: OTHER SURVEY DATA -- I Survey Survey Incl. Hole Course Vertical Total Coordinate Build Rate Walk Rate: ~,~ _[~T/)S +OF/T? F~I~r°pBuild (+)(_) Right (-)(+) Comment Date Tool Depth Angle Direction L TVD Section N( (-) E( (-'. (peDrh 00 Type (FT) (D-D) (DD) (FT) Left 06-OCT-9~ MWD 6912.97 44.42 303.72 95.87 5510.15 3642.54 2130.94 -2954.38 0.83 0.43 -1.02 06-OCT-9[ MWD 6963.07 44.69 302.84 50.10 5545.85 3677.64 2150.23 -2983.77 1.35 0.54 -1.76 06-OCT-9~ MWD 7039.00 44.69 302.84 75.93 5599.83 3730.94 2179.19 -3028.63 0.00 0.00 0.00 PROJ @ TD , __ -- TONY KNOWLE$, GOVERNOR A~AS~& OIL AND GAS CONSERVATION COMMISSION September 25. 1998 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 Paul Mazzolini Tam Drilhng Team Leader ARCO Alaska. Inc. PO Box 100360 Anchorage, AK 99510-0360 Re: Kupamk River Unit 2N-319 ARCO Alaska. Inc. Permit No: 98-197 Sur Loc: 54'FNL, 734'FEL SEC 03. T09N, R07E. UM Btmhole Loc. 215YFSL 1546'FWL, SEC 34, T10N, R07E, UM Dear Mr. Mazzolini: Enclosed is the approved application for permit to drill fire above referenced well. The per]nit to drill docs not exempt you from obtaining additional permits rcquircd by lax,,' from other governmental agencies, and does not authorize conducting drilling operations until all other required permitting determinations are made. Annular disposal of drilling wastes will not be approved until sufficient data is submitted to ensure that the requirements of 20 AAC 25.080 are met. Annular disposal of drilling waste '.'.411 be contingent on obtaining a well cemented surface casing confirmed by a valid Formation Integrity Test (FIT). Cementing records. FIT data. and any CQLs must be submitted to the Commission on form 10403 prior to the start of disposal operations. Annular disposal must comply with thc rcquircmcnts and limitations of 20 AAC 25.080. If approved for annular disposal, drilling waste ]nay no_A bc disposed in fl~c well in a volume greater than 35.000 barrels nor may thc well be usc for annular disposal for a period longer than one ,,'ear. Blowout prc'.'cntion equipment (BOPE) must bc tcstcd in accordance with 20 AAC 25 035· Sufficient notice {approximately 24 hours) must be given to allow a representative of the Commission to v,-imess a test of BOPE installed prior to drilling new hole. Notice ]rmv be given bv contacting the Commission 59-3607. · David W. Johta{ton Clmirman BY ORDER OF THE COMMISSION dll)'Enclosures l)epartment or' Fish & Game. ttabitat Section w;o encl. Department or' F. nvironmental Conservation w,o encl. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 AAC 25.005 la. Type of Work Drill X Redrill F' / lb Type of Well Exploratory F~ StratigraphicTest r- Development Oil X . Re-Entry [] Deepen F service F Development Gas F' singleZone X Multiple Zone 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool ARCO Alaska, Inc. RKB 28', Pad 121' feet Kuparuk River Field 3. Address 6. Property Designation Tarn Oil Pool P. O. Box 100360, Anchorage, AK 99510-0360 ADL 380054, ALK 4602 4. Location of well at surface 7. Unit or property Name 11. Type Bond (see 20 AAC 25.025) 54' FNL, 734' FEL, Sec. 3, T9N, R7E, UM Kuparuk River Unit Statewide At top of productive interval (@ TARGET ) 8. Well number Number 1987' FSL, 1775' FWL, Sec. 34, T10N, R7E, UM 2N-319 #U-630610 At total depth 9. Approximate spud date Amount 2153' FSL, 1546' FWL, Sec. 34, T10N, RTE, UM 9/28/98 $200,000 12. Distance to nearest 13. Distance to nearest well 14. Number of acres ~n property 15. Proposed depth (MD and TVD) property line 2N-317 7023' MD 1546' @ TD feet 28.7' (~ 700' feet 2560 5582' TVD feet 16. To be completed for deviated wells 17. Anticipated pressure (see 20 AAC 25.035(e)(2)) Kickoff depth 1 000' feet Maximum hole angle 44° Maximum surraoe 1357 psig At total depth (TVD) 2300 psig 18. Casing program Setting Depth size Specifications Top Bottom Quantity of cement Hole Casing Weight Grade Coupling Length MD TVD MD TVD (include stage data) 20" 16" 62.5# H-40 Weld 90' 28' 28' 118' 118' +200 CF 9.875" 7.625" 29.7# L-80 BTC MOE 2402' 28' 28' 2430' 2300' 1) 20 Sx Arcticset III L & 240 Sx Class G 2) 240 sx AS IIIL & 60 sx AS I 6.75" 5.5" 15.5# L-80 LTC-M 6270' 28' 28' 6298' 5350' 150 sx Class G 6.75" 3.5" 9.3# L-80 8rd EUE 725' 6298' 5350' 7023' 5582' (included above) 19. To be completed for Redrill. Re-entry. and .)eepen Opera ions. Present well condition summary Total depth: measured feet Plugs (measured) true vedical feet Effective depth: measured feet Junk (measured) true vertical feet Casing Length Size Cemented Measured depth True Vertical depth Structural Conductor Surface Intermediate Production Perforatio~:~th: measured ORIG!I' AL true vertical 20. Attachments Filing fee X Property plat F BOP Sketch X Diverter Sketch X Drilling program X Drilling fluid program X Time vs depth plot F' Refraction analysis r- Seabed report ~- 20 AAC 25.050 requirements X 21. I hereby cedify that the foregoing is true and correct to the best of my knowledge Signed ~"~4..J~ ',~¢~,~.,f_~~.~ Title Tarn Drilling Team Leader Date ~'/~,4' / ~ ~ ~PCr~umber Commission UseOnly ~/-'1/~ Perm~__.b,,~,~.,~_ I50- //O,.~'-- ,~O ~-, '~// I Approval date 42~), ~E~ I soo c°ver letter f°r°ther requirements Conclitionsotapproval Samples required [] Yes J~ No Mud ldgreqU'//red Yes l~ No Hydrogen sulfide measures ~E Yes _']~ No ~ Directional survey required ~ Yes r- No Required w°rkingpressuref°rBOr~/J.H} I-- 2M r' 3M E~ 5M F- 1OM [~ 15M Other: ~r~u~'P'C-'J--~)~'~')'-~'$'--'l~--Co'-q-'/' l~(:~g ~P--.--~O p-6,,¢-__ 'Z-o ~(~, by order of Approved by ,~ Commissioner the commission Date Form 10-401 Rev. 7-24-89 UiI~,,. -_ ":ii5 ' ~cate David ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 September 23, 1998 David W. Johnston, Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501-3192 Re: Application for Permit to Drill KRU 2N-319 Surface Location: 54' FNI- 734' FEI_ Sec 3 TgN RTE, tiM Target Location: 1987' FSI_, 177'5' FWL Sec. 34, T10N, RTE, UM Bottom Hole Location: 2153' FSI_, 1546' FWL Sec. 34, T10N, RTE, UM Dear Commissioner Johnston, ARCO Alaska, Inc. hereby files this Application for Permit to Drill a development well in the Tarn area, KRU 2N-319, located approximately seven miles southwest of the Kuparuk River Unit's 2M Drillsite. The well is accessed via a new gravel road originating at 2M Pad. Doyon Rig 141 will drill the well. If commercial, the well will completed with Doyon 141 also. Attached is the information required by 20 AAC 25.005(c). There will be no reserve pit for this well. Waste drilling mud will be disposed of down the annulus of an existing well on Drillsite 2N (subject to AOGCC approval), or hauled to a KRU Class II disposal well. All cuttings generated will be either stored temporarily onsite or hauled to the Prudhoe Bay Field for temporary storage and eventual processing for injection down an approved disposal well. The TD of this well will be in the Tarn formation. H2S has not been encountered in this region in any stratum shallower than the Lisburne Formation. Therefore, ARCO has not included an H2S contingency plan with this Application, and requests an exemption from the H2S requirements. However, all drilling mud, cores and produced fluids exiting the wellbore will be monitored for detectable levels of H2S. The following are ARCO's designated contacts for reporting responsibilities to the Commission: ARCO Alaska, Inc. is a Subsidiary. of AtlanficRichfieldCompany .. David W. Johnston Application for Permit to Drill Page 2 KRU 2N-319 1) Completion Report (20 AAC 25.070) Sharon AIIsup-Drake, Drilling Technologist 263-4612 2) Geologic Data and Logs Doug Hastings, Geologist (20 AAC 25.071) 265-6967 If you have questions or require additional information, please contact Tom Brassfield at 265-6377 or me at 263-4603 in our Anchorage office. Sincerely, Paul Mazzolini Drilling Team Leader Exploration / Tarn Development Group Attachments cc: KRU 2N-319 Well File ARCO Alaska, Inc. GENERAL DRILLING AND COMPLETION PROCEDURE KUPARUK RIVER FIELD - PRODUCER KRU 2N 319 1. Move in and rig up Doyon 141. 2. Install diverter system. 3. Drill 9-7/8" hole to 7-5/8" surface casing point according to directional plan. . Run and cement 7-5/8" casing, using stage collar placed approximately 200' MD below the base of the permafrost. Use lightweight lead cement in the first stage. 5. Install and test BOPE to 3,500 psi. Test casing to 2,000 psi. , 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). 7. Drill 6-3/4" hole to TD according to directional plan. Run LWD logging equipment with density and porosity tools. Note: If significant hydrocarbon zones are present above the Tarn, sufficient cement will be pumped for isolation in accordance with 20 AAC 25.030(d)(3)(0). . Run and cement 5-1/2" L-80 LTC Csg X 3-1/2" L-80 8rd EUE-Mod tapered production casing string with Baker casing seal receptacle at crossover point. 9. Pressure test casing to 3,500 psi. 10. Run 3-1/2" L-80 8rd EUE-Mod completion assembly. Sting into polished seal bore with seal assembly and pressure test tubing and annulus to 3,500 psi. 11. ND BOPE and install production tree. 12. Secure well. Rig down and move out. ARCO Alaska, Inc. DRILLING FLUID PROGRAM, PRESSURE CALCULATIONS, AND DRILLING AREA RISKS Well KRU 2N 319 Drillinq Fluid Properties: Density PV YP Funnel Vis Initial Gel 10 Minute Gel APl Filtrate pH % Solids Spud to surface casing point 9.0-10.2 ppg 15-35 25-50 70-120' 10-25 15-40 5-7 9.5-10 +10% Drill out to TD 8.5 - 10.0 ppg 12-24 15-30 45-60 2-6 4-8 4-6 through Tarn 9.0-10 <11% Drillinq Fluid System' Triple Derrick Shale Shakers Desander, Desilter, Mud Cleaner Centrifuge Pit Level Indicator (Visual and Audio Alarm) Trip Tank Fluid Flow Sensor Degasser Fluid Agitators *Spud mud should be adjusted to a FV between 100-120 sec/qt to drill gravel beds Drilling fluid practices will be in accordance with the regulations stated in 20 AAC 25.033. Maximum Anticipated Surface Pressure: Maximum anticipated surface pressure (MASP) while drilling the production hole is calculated using a surface casing leak-off of 13.5 ppg EMW (0.70 psi/fi) and a gas gradient of 0.11 psi/ff. This shows that formation breakdown would occur at a surface pressure of 1,660 psi. Therefore ARCO will test the BOP equipment to 3,500 psi after setting surface casing. MASP = (2,300 ft)(0.70 - 0.11) = 1,357 psi Based on offset well data, reservoir pressures in the Tarn sands in the vicinity of 2N pad are expected to be -2,350 psi (0.50 psi/ft). Assuming a 150 psi overbalance is required to safely drill and trip in this formation, then a required mud weight of 9.5 ppg can be predicted as the maximum mud weight needed to safely drill in this formation, assuming a TVD of 5,100'. Well Proximity Risks: ARCO Alaska, Inc. The nearest well to 2N-319 is 2N-317. The wells are 28.7' from each other at a depth of 700'. Drillinq Area Risks: The primary risk in the 2N 319 drilling area is shallow gas below the permafrost. Therefore the surface hole will need to be drilled with weighted mud (9.8 - 10.2 ppg) to avoid underbalancing the hole. Another observed problem in the area is lost circulation at around 3,300' TVD and in the Tarn formation. Analysis of pressure data from offset wells shows that a mud weight of 9.6-10.0 ppg will provide sufficient overpressure to safely drill, trip pipe, and cement the well. The 9-5/8" casing shoe will be tested to leak-off, or to a maximum equivalent mud weight of 16.0 ppg upon drilling out of the casing. 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 iniected 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 2N 319 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. We request that 2N 319 be permitted for annular pumping of fluids occurring as a result of drilling operations, per regulation 20 AAC 25.080. 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 maximum volume of fluids to be pumped down the annulus of this well will not exceed 35,000 bbl without the specific permission of the AOGCC. Fluid densities will range from diesel to a maximum of 12.0 ppg for drilling fluid wastes. Using 12.0 ppg fluid and the rig's specified maximum pumping pressure of 1,500 psi for annular injection, the maximum pressure at the surface casing shoe is estimated by: Max Shoe Pressure = (12.0 ppg) * (0.052) * (Surf. Shoe TVD) + 1,500 psi = (12.0 ppg) * (0.052) * (2,300') + 1,500 psi Max Pressure = 2,935 psi ARCO Alaska, Inc. This pressure is conservative, since frictional losses while pumping have not been taken into consideration. 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 7-5/8" 29.7 L-80 3 BTC 4,790 psi 4,072 psi 6,450 psi 5,483 psi 5Y2" 15.5 L-80 3 LTC-Mod 4,990 psi 4,242 psi 7,000 psi 5,950 psi 3Y2" 9.3 L-80 2 8rd EUE Mod 10,530 psi 8,951 psi 10,160 psi 8,636 psi 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). Casing Options 5,798' Top of cement Plan A (95% chance) 5/~" Casing \ Top of cement 5,230' 5,730' 6,298' 3'~" Casing I ' 7,o23, ' · 7,023' ~l~n B (5% chance) 9/23/98 Drill and set Casing All Depths are RKB Doyon Rig 141 2N 319 FMC Prudhoe Gen V L~ 9-518 x 51/= x 31/= I Ma n d r'~ Ha n ge r-'"~.___~- Base of permafrost at ~ii!i?i 1,199' MD / 1,199'-I'VD 9-7/8" Hole Top of West Sak at 1,244' MD / 1,243' TVD Base of West Sak 2,052' MD / 2,000' TVD 7-5/8" 29.7 ppf L-80 BTC Mod Surf. Csg. 2,430' MID / 2,300' TVD oo 6~" Hole Weatherford Gemoco 3%" Float Collar and Float Shoe J 6" Conductor Weatherford Gemoco 7-5/8" Stage Collar Standard Grade, BTC 1,402' MD / 1,399' TVD Mud Weight in Surface hole: 10.0 ppg by 1~00' TVD 10.2 ppg by 1900' TVD Weatherford Gemoco 7-5/8' Float Collar and Float Shoe Mud Weight in Production hole 9.1 to 10.0 ppg X-Over 5% LTC Box X 5% BTC 5%" 15.5 L-80 LTC Mod Csg 6,298' MD / 5,350' TVD 9.3 L-80 8rd EUE Tbg 7,023' MD / 5,582' TVD Completion Type 2 9/23/98 Completed 2N 319 FMC Prudhoe Gen V 9-518 x 5s/~ x 3Y2 1,199' MD / 1,199' TVD 9-7/8" Hole 2.875" CAMCO DS Weatherford Gemoco nipple for SCSSV 7-5/8" Stage Collar ~ at 500' + MD Standard Grade, BTC threads . 7-5/8' 29.7 ppf L-80 BTC Surf. · 2,430' MD / 2,300' 'I-VD 3%" 9.3 ppf L-80 8rd EUE tubing Baker CMU Sliding Sleeve, Size 6~" Hi 2.813" w/3%" 8rd EUE Box x w/2.813" Camco DS profile Camco 3%" x 1" pocket GLM Baker 5%" Csg Seal Receptacle (CSR) Size 80-z CAMCO 2.75" 5%" 15.5 ppf Mod BTC box up D nipple X 3%" 9.3 ppf 8rd EUE pin down 6,298' MD / 5,350' 'I'VD 3%" 9.3 ppf L-80 EUE (tubing) Csg 7,023' MD / 5,582' TVD 3-I/2" Slimhole Monobore Completion 9/23/98 ARCO Alaska, Inc. Tarn Drill Site 2N 319 slot #319 Tarn Development Field North Slope, Alaska SUMMARY CLEARANCE REPORT Baker Hughes INTEQ Your ref : 319 Version Our ref : prop2843 License = Date printed : 23-Sep-98 Date created : 24-Feb-98 Last revised : 22-Sep-98 Field is centred on n70 12 49.742,w150 18 33.414 Structurs is centred on nT0 10 13.955,w150 18 32.772 Slot location is nT0 10 13.427,w150 18 54.031 Slot Grid coordinates are N 5911953.404, E 460859.302 Slot local coordinates are 53.65 S 733.82 W Projection type: alaska - Zone 4, Spheroid: Clerks - 1866 Reference North is True North Object wellpath PMSS <0-8500'),,317,Tarn Drill SAte 2N PMSS <0-9134'>,,313,Tarn Drill Site 2N PMSS <0-7431'>,,345,Tarn Drill Sits 2N PMSS <0~12339'>,,341,Tarn Drill Site 2N PMSS <O-9553'>,,323,Tarn Drill Site 2N PMSS <0-8239'>,,339,Tarn Drill Site 2N PMSS <0-9690'>,,329,Tarn Drill Site 2N PMSS <0-9631'>,,343,Tarn Drill Site 2N PMSS <0-10655'>,,337,Tarn Drill Site 2N PMSS <7090-10245'~,,337A,Tarn Drill Site 2N PMSS <0-11526'>,,321,Tarn Drill Site 2N PMSS <5286-10028'>,,321A,Tarn Drill Site 2N PMSS <0-11225'>,,331,Tarn Drill Sits 2N PMSS <0-8182'>,,325,Tarn Drill Site 2N PMSS <0-???>,,315,Tarn Drill Site 2N Closest approach with 3-D Last revised Distance 14-Aug-98 28.7 4-Aug-98 79.4 21-Jul-98 389.9 15-Jul-98 330.4 23-Jul-98 60.1 1-juz~-98 297.7 28-May-98 149.1 28-May-98 359.3 18-Jsu:~98 269.3 29-Ju1~98 269.3 25-Aug-98 30.3 31-Aug~98 30.3 15-Sep-98 179.9 22-Sep-98 90.0 22-Sep-98 49.8 Minimum Distance met. hod M.D. Diverging from M.D. 700.0 700.0 600.0 600.0 100.0 100.0 100.0 100.0 0.0 0.0 300.0 300.0 400.0 400.0 300.0 300.0 300.0 300.0 300.0 300.0 100.0 100.0 100.0 100.0 200.0 200.0 100.0 6OO.O 600.0 600.0 C~eoted ~ ~,.oe,~on For: BRASSFIELD Oote plotted : 2~-Sep-98 P!et Ratarenc~ ~ 519 Var~ ~5. C~o;nates ore m feet reference slot ~319. True V~icol Clothe are reference R~ (~yan 141). :. Structure :Tcrn Drill SHe 2N Well : Field : Tarn Davelopmenf Field Locafion: Not'ih $1cpe, Alaska <- West (feet) 5J00 5000 2700 2400 2100 1800 ~500 1200 900 600 Z00 0 JO0 I I I ! ~ ' ' I I i I ' ' I I I I ' ' ~ ' ' I i 2400 TO - Cosin~ Pt TARGET LOCATION: C55' 1988' FSL, 1771' FWL I TD LOCATION: ,T2 - i3ese Bermuda SEC. 54., TION, R7E 2100 2155' FSL, 1.546' FWL JTARCET - Mid Bermuda fT5 TARGET SEC. 54, TION, R7E T4 TV0=5297 TMD=6624 , 0EP=5445 j- 1800 NORTH 2042 . 1 WEST 2775 F C4O Z 0 RKFI ELEVATION: 149' C50 ~- !200 O 400 ' F CD 800 600 ~ KOP TVD=IO00 T~D=IO00 DEP=O t ~'0~0nBASE PERMAFROST TV0=1199 TMD=1199 DEP=10 L ~200 ~ ~'~}TOP WEST SAK SANDS TVD=1243 TMD=1243 OEP=!6 7 5/8" Cosing Pt F · ~:~ I ~ 12.00 Base West Sek ~Gnds ~ 1.5.00 DLS' 5 O0 deg per 100 ft Too Wes~ Sck ~nc_ - 0 1600 ~t 18.00 ' ' , ~ ¢ 2~.oo ' I ~ x, 26.00 t, 27.00 i ~--(D 2000 . 0BASE WEST SAK SANDS TVD=2000 TMD=2052 DEP=283 L 300 ~ _J '%. 39.00 ~CATION: ] ,,~X~. 7 5/8I' CASING PT TVD=2300 T,MO=2430 DEP=511 I 54' FNL. 734' FEL - ---~"x EocTvo=~s~ ~o=~o o~=~4~ )~ 37. -.,'¢q ~ ~ 2400 Q) % C80 TVD=2¢90 TMD=2695 DEP=696 2800 ® ~'~°°i AVERAO~ ANGLE% ~ 44.4 DEG xx 306.34 AZIMUTH '-: ;"°°t i ~ 3445' (TO TARGET) I--- -4 C50 TV0=3796 TMD=4525 DEP=1975"% I V 4000 4400 4800 ~D- 6365 OEP=3264 5200 ~7 TMD=64-98 OEP =3357",. TARGET - MID BERMUDA TVD=SZ97T2 ~'~%~, 2 -- BASE BER, UDA TV0=5387 TMD=67..O DE~ =5 ..... T MD 66 4 DEE 3440P - - 5600 6000 i i i i i i i ii i i J i i i i Ji i i i i 400 0 '~00 800 ! 200 1600 2000 2400 2800 5200 5600 4000 Vertical Section (feet) -> Azimuth 306.34 with reference 0.00 N, 0.00 E from slot #319 c~o~ ~, ,;~c~ For: BRASSFIELD ~te ~ottcd : 25-Sop-98 ~ot Reference ia 519 Ve~a~n Coord;n~te~ ~re ;n fe~ ~eference ~lot 26O 240 220 2O0 500 28O 260 240 220 2O0 180 160 140 120 IC0 80 · 6O 2O 0 2O 4O I00 Structure : Torn Drill Site 2N Well: 519 Fled : Tarn Development Field Location : North Slope, Alaska ARCO Alaska, Ind-'.' <- West (feet) 180 160 : 4.0 120 1 O0 80 60 4-0 20 0 20 40 50 ] ~'("- %x, 7 ' 1700x._ '. x ,..,,.,,,%,,.,,,,,,,%,,,~ii, ~ ~ ~\\"1,,,,\~ 1 "::'. N ~ ", ~ ~ 1200 ~',,, ~ ' 1400 [ '....... % ~...., , 1500 ~ "'"'- """ '"'~ '"", 1 000 ""'"'"'":::~"'"""-~ 11~'"'",~21 X 1400 51 ~ ~..?:.:% ~ ooo-'-...%',.~ N eoo "--~'.. :ooo '-., ",,, "L':,. '"., ' o J ~ ~ "% 900 % % '-.. ~ 8oo ~ % % ~oo ~:..:,o. "~ ~oo t "'----......,ooo o ............ '"~:... """%%%%.. ~1100 ~0 600, "..:00 "%~p:01200 70;O0 ~~--..,¢0o ~-~__ ~oo' ~ --..,.~oo ---~oo~ ~ -' .... '",, N~°°° ~ ",. aoo ~ ~oo 'x-... ~oo%~OO ~.--~ ~D~oo~ 260 700 ?-oo?~oo ~ i 600 ! ~oo ) 240 220 200 !80 I ~0 i ;0 1~0100 a'o 6'0 40 6 40 ~¢ <- Wes~ (feel) 300 280 260 240 220 200 180 150 140 20 © 2C 6O 8O io0 t -RCO Alaska i Ind[ ructure : Tarn Drill Site 2N I1:519 Id : Tarn Development Field Location : North Slope, Alaska 320 280 <- West (feet) 800 750 720 680 640 600 560 520 4.80 4-40 400 360 520 280 240 200 150 -....... '"'... ', ~ ~ ~ 640 64O "% 31 O0 2280 " 500 :ooo%,, ",,.,,.,., ',, ", , 600 600 " ' ". 1600 .~. 3000 - · .. , 560 560 '- '" ' '- ". 500 " '. 21 O0 1500 270(~'" '".. 190(~x'.. "'.. 2900 " 520 520 ! ........... ', t 260~'".. '"'.. " 4.80 480 '-, , '"-. 2800 " k 440 -, %. "". "'- 1500 ". 440 ""-. 180(~"'.. '"-. ~o~'-.. '"'-. "- ~oo i- "%. 2700 · '...... ' 400 ~- 400 4.00 1 15OO '" '"' F 380 360 2¢0¢-.... 1700~'..... 260~%. L '-.. '-.. ~ ¢oo '-. ~ 8oo i A 2200 "-. '",, 1 '"'-, Z 1400 -.. '.. 2~00 k.. ' - 280 ...... '- 2100 '"'.. '"-, 1~00 , :~- .... ...',soo 240 , ~ 0'~' 220 -.. .. 1 24-o ....... 2CO0 1300 "--........"-............. ~ ] ............. , ~ ~oo ~2oo F '~' 2100%-. k 200 200 ..... ~ 900 '- 1200 '". ........ -'---,..1600 "-. '"' , '"'"-- 1800 '"-, '"-. 1 , ~,~ ~ ........ 1800 "---. -... ,. , ou ~ ~o 1,_~__._.~oo .......... '---..] soo ~ 7oc ~ ~ co "-. '- J, ~ .......... 1700 ........ '"~ ,9t 0 I ~ .... ' ..... ---.,, ~,~oo .,, J.__..__ ~------~_]2~u ....... ---. ~ 600 -- ;~ ~20 '('3"~-2 ~ ........ 600 "-.. ~ ~ 1000 I'~ ................. ~ ..... '---. ' ..... :~oo . ~ ' -i .... ------.~_ ~ 500 -'-'------~1400 ...... ' .... ~ -~ i . -""--:~-".L._ ~ ...... ~soo ..... ~ .. , ~,~ _j ............ ~ ....... "-..J 200 '~ [- ~o -i~~ .... ~,-.oo -"""--~-~oo ........ ~,~oo ..... ~ ¢06', -' ....... '"'-.,, 1100 % l" ...... ~. ~ 300 ..... "rT~ / O0 ........ 1 ~no -...~ 00'.(~.¢,I- ,~o ..... .~.~ ~oo ~, 0 1 400 - _ ............................................ 700 ~'LCLO' ~-Mor / ~ 6oo ............................. 9 '~ ~ ~o -I .......... '~ ~'O~oo 1 .............. ' ' oo ~o I ~ -e-~o~"/5o0 / ;'(~ s'~ i 7o~ / 120 . 350 /~80 240 200 60 800 760 720 680 640 600 560 520 480 ,~40 400 320 <- West (feet) { Creo~eo :~,;.~. For: BRASSFIELD Oote !~lotted : 23-Se~-98 P'ol Re~e~ence ;s ~19 v~rs~n C~;nates are ;n f~ reference set ~319. True Ve~/c~l Oept~a ore re erence RgB (~ 141). , IAi~CO Alaska, lnc~it Structure : Tarn Drill 5ire 2N Well: ,519 Field : Tarn Development Field Location : North Slope, AlaskaI <- West (feet) 2200 2100 2000 1900 1800 1700 1600 1500 1400 ~300 1200 1!00 1000 go0 8C0 700 2000 { I I { I I I I I : ~ f : , ; I ! ~ ' { I { ~ I { i ~ I ~ ' I 2000 '",~ 2700 '",~ "~ ~ '\ ~-I 1900 1900 ,,,,,, "'",,,,,, x ', ~ '~ ' ~ 2300 ~800 / '",., '-,,. W~°° ~,oo ~ l ]700 ',,., 51 00 '.,, ~ 1700 1500-[~ "-,.. "-,, 470~x,,. ~ ',X %' ' F !500 1400 ,,, 1900 ~ 4oo _ ~'--....~ ~o '......7~ '-......~:~o, ,,oox , ,~oo- ~-... '""-... '""--..~ ..... h ~,~oo ~ 000 1000 : ",. ",. M ' '-.. '.. ~, ~500 '-. ~o ..... '"'"'---.. '-C~;'''' ..... / 7co ~oo ~- ............... -"-~- .... :~ _~ ~ .....'"'--.... 400 ~ 00 ........... ' ........ 2300 ~__ ~o .......... .~o~ ~ ......... ..~o 2o0 .... .~.~_~ 2o0 .......................... J700 ~00 ~ ~00 1700 ~ ~00 2200 2100 2000 1900 1800 1700 1600 1500 1400 1300 1200 1100 I000 900 800 700 <- West (feet) c~c~ ay ,~.~. For: BRASSF[ELD Oatc Catted : 25-$e~-~8 True Vemica~ Qe~ ore reference RK8 (~y~ 141). I Structure: Tarn Drill Site 2N Well: Field : Tarn Development Field Location : North S!ope, AlaskaI <- West (feet) 3400 3300 3200 31 O0 3000 2900 2800 2700 2600 2500 2400 2300 2200 21 O0 2000 1900 2900 z ' 2800 2700 2600 2500 2400 2300 2200 2100 I 2000 ,+.,. 1900 ,.+-. ~ 1800 © Z 1700 1600 1500 1400 1300 1200 "'"'"'"",.,., ~ I 2800 "'"'"'"'"""".,..,,,.,. ! 2500 2400 "'C '---.., l 2 -...,.... '"-,... I'~],., 3500 2000 '--. '-. '-. ~k ! 900 '.... '-... '-... "'"""'""-%4900 """'""'-,,. "'""" --,.. ,900 " " L ..,00 · 2500 '"-.. '"-. "' '"',,. ~ 1700 '-,~ 4700 ",. 4500 ? ~ 600 2900 '"-.. . 2300 '""..... F i 500 "-~. 4300 '"~!' 1400 27OO ~ ! 3CO 2900 3100 00 ....... - ....~ 5900 ...... _..~.?..o. ........ - ........ ..... .~ .... .~ ~ 250O 1100 k 1200 2300 h lO0O 900 / ~ l~ ~ , , z , , , I , ~ , , ~ ~ i I ~ , ~ i i I i , i , 3400 3300 3200 3! O0 3000 2900 2800 2700 2600 2500 2400 2300 2200 2 I00 2000 1900 <- West (feet) 1000 900 Z 0 Structure : Tarn Drill $i,~ 2N Well : 319 J Field : Tarn Development Field Location : Norih Slope, A[askaj WELL PROFILE DATA ..... P~nt ..... I~0 'nc i ooo.oo0.00 3o6.34 i ooo.ooo.oo o.oo o.oa o.oo I Tenet ~-31g ~ 22- 8624.~g ~.40 308.345297.~~041.7~ -2774.g7 3~45.~7 O.~ E~d ~ H~d ~823.05 ~.40 306.34543g. C0 212~.t7 -2887.00 3~4.25 O.~ T.9. ~ End of H~U 7023.05 ~ 40 306.345581.88 2207.10 -2ggg.72 3724.1g O.~ 1200 ~'~oo~330 520 %N TRUE NORTH 0 10 aa / 10 2O 1100 ,5O0 5O Icre~tea =y finch For: BRASSFIELDi O<~te 13~atted : 23-~-gB PIo~ Reference i~ 319 Ve~ion ~5- I I 4O 5O 6O 2go 7O 28O 270 260 2to ,5o ~oo I 8O 9i0 !20 150 180 2 0i : , I Ia0 25O 240 !20 25O 220 210 200 150 !4-0 150 160 i go i 80 170 Normai P!cne Travelling Cylinder - Feet All de~oths shown ore Measured deaths on Reference We! No bo Areas shown by double or~: o[ appropriate depth No Go = both wells major uncertainty raCii x Sofety Factor of ! ARCO Alaska, Inc. Diverter Schematic Doyon 141 Flowline ~ 211~,, 2,000 psi WP DRILLING SPOOL w/16" Outlet 21~,~" HYDRIL MSP 2,000 psi WP ANNULAR PREVENTER 16" 200 psi WP HYDRAULIC KNIFE VALVE 16" 62 ppf PEB CONDUCTOR PIPE set at 80' (GL) ARCO Alaska, Inc. DOYON 141 13-5/8" 5,000 PSI BOP COMPONENTS ! 3" 5,000 psi WP OCT [~ MANUAL GATE VALVE '~ KILL LINE ~ '~ 3" 5,000 psi WP Shaffer GATE VALVE ] w/hydraulic actuator E~ / J BSA 13-5/8" 5,000 psi WP ...~1 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 DOUBLE 13-5/8" 5,000 psi WP, HYDRIL Magnum BOP w/pipe rams on top and blind rams on bottom 3" 5,000 psi WP Shaffer GATE VALVE [__J _ __ ~/hydraulic actuator L~~ CHOKE LINE 13-5/8" 5,000 psi WP DRILLING SPOOL L]'~'--.,,,.% w/two 3" 5M psi WP outlets I J SINGLE 13-5/8" 5,000 psi WP, HYDRIL MPL BOP w/pipe rams I WELL PERMIT CHECKLIST COMPANY :IELD & POOL ......... WELL NAME .~,,~_/_..ff/ ~w'~./[_J - ~/'/? PROGRAM: exp [] dev'~'redrll [] serv [] wellbore segll ann. disposal para ADMINISTRATION 1 , 3. 4 5. 6. 7. 8 9. 10. 11 DATE / 12. · Permit fee attached ....................... Lease number appropriate ................... Unique well name and number .................. · Well located in a defined pool .................. Well located proper dislance from drilling unit boundary .... Well located proper distance from other wells .......... Sufficienl acreage available in drilling uni! ............ · If deviated, is wellbore plat included ............... Operator only affected party ................... Operator has appropriate bond in force ............. · Permit can be issued without conservation order ........ Permit can be issued without administrative approval ...... Can permit be approved before 15-day wait ........... ENGINEERING GEOL AREA ~" ? ~_~ UNIT# APPR DA'rE GEOLOGY ~NNULAR DISPOSAL 35. APPR DATE ...... 14. Conductor string provided ................... 15. Su[face casing protects all known USDWs ........... 16. CM"r vol adequate to circulate on conductor & surf csg ..... 17. CMl' vol adequate to tie-in long string to surf csg ........ 18. CM r will cover all known productive horizons ........... 19. Casing designs adequate for C, T, B & permafrost ....... 20. Adequate tankage or reserve pit ................. 21. If a re-drill, has a r10-403 for abandonment been approved... 22. Adequate wellbore separation proposed ............. 23. If diverter required, does it meet regulations .......... 24. Drilling fluid program schematic & equip list adequate ..... 25 BOPEs, do Ihey meet regulation ................ 26. BOPE press rating appropriate; test to psig. 27. Choke manifold complies w/APl RP-53 (May 84) ........ 28. Work will occur without operation shutdown ........... 29. .... ~' N Y N Y N Y N ¥ N Y N Y N Y N Y N Y N Y N Y N N ~N ON/OFF SHORE Is presence of H2S gas probable ................. 30. Permit can be issued w/o hydrogen sulfide measures ..... Y N/ 32. Seismic analysis of shallow gas zones ..... ' 33. Seabed condition su~ey (if off-shore) ............. Y N 34. Cogtacl.na~e/phone for weekly progress reports lexp~orato~ only] ~.~. A~ ~ ~,~ ~,~ ~x~'~ J3y ~P~ , CAS~,~ ~.~' ~L~o,~ ~ o~ ~. 5,~ ~ With proper cementing records, this plan (A) will contain waste in a suitable receiving zone; ....... ~ N (B) will not contaminate freshwater; or cause drilling waste... ~N (C) wiii }'lOt impak,.~echanical into~rit~ o~ the well used tot disposal; (D) will not damage producin~ formation or impair recouerV from a pool; and (E) will not circumvent 20 AAC 25.252 or 20 AAC, 25.412. (~ N GEOLOGY: ENGInEErinG: UIC/Annular coMMissioN: Commentsllnstrucfions: ...... JDH / RNC . _ CO Mchekhsl mv 0512919B Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically organize this category of information. Sperry-Sun Drilling Services LIS Scan Utility Fri Mar 26 15:21:01 1999 Reel Header Service name ............. LISTPE Date ..................... 99/03/26 Origin ................... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Previous Reel Name ....... UNKNOWN Comments ................. STS LIS Writing Library. Tape Header Service name ............. LISTPE Date ..................... 99/03/26 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Previous Tape Name ....... UNKNOWN Comments ................. STS LIS Writing Library. Scientific Technical Services Scientific Technical Services Physical EOF Comment Record TAPE HEADER KUPARUK RIVER UNIT, TARN POOL x~cs/~ ~oss 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 (ET FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: MWD RUN 2 AK-MM-80396 R. KRELL G. WHITLOCK _. RECEIVED 1999 ~ka 0ii & Gas Cons. 2N-319 And10ra~e 501032027~00 ARCO ~~z~, ~NC. SPERRY-SUN DRILLING SERVICES 26-MAR-99 MWD RUN 3 AK-MM- 80396 R. KRELL G. WHITLOCK 3 09N 07E 54 734 148.80 147.30 120.90 WELL CASING RECORD 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING REMARKS: OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 16.000 108.0 9.875 7.625 2438.0 6.750 7039.0 1. ALL DEPTHS ARE MEASURED DEPTHS (MD) UNLESS OTHERWISE NOTED. 2. MWD RUN 1 IS DIRECTIONAL ONLY AND IS NOT PRESENTED. 3. MWD RUNS 2 AND 3 ARE DIRECTIONAL WITH DUAL GAMMA RAY (DGR), ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR-4), COMPENSATED THEP24AL NEUTRON POROSITY (CTN) AND STABILIZED LITHO DENSITY (SLD). 4. DEPTH SHIFTING/CORRECTION OF MWD DATA IS WAIVED AS PER THE E-MAIL MESSAGE FROM DEDE SCHWARTZ OF ARCO ALASKA, INC ON 30 NOVEMBER, 1998. SPERRY-SUN MWD DATA IS PRIMARY DEPTH CONTROL (PDC) FOR WELL 2N-319. 5. THIS WELL REACHED A TOTAL DEPTH (TD) OF 7039'MD, 5600'TVD. SROP = SMOOTHED RATE OF PENETRATION WHILE DRILLING. SGRC = SMOOTHED GAMMA RAY COMBINED. SEXP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (EXTHA SHALLOW SPACING). SESP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (SHALLOW SPACING). SEMP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (MEDIUM SPACING). SEDP = sMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (DEEP SPACING). SFXE = SMOOTHED FORMATION EXPOSURE TIME. TNPS = COMPENSATED THERMAL NEUTRON POROSITY (SANDSTONE MATRIX-FIXED HOLE SIZE). CTNA = SMOOTHED AVERAGE OF NEAR DETECTORS' COUNT RATES. CTFA = SMOOTHED AVERAGE OF FAR DETECTORS' COUNT RATES. SBD2 = SMOOTHED BULK DENSITY - COMPENSATED. SC02 = SMOOTHED STAND-OFF CORRECTION. SNP2 = SMOOTHED NEAR DETECTOR ONLY PHOTOELECTRIC ABSORPTION FACTOR. ENVIRONMENTAL PARAMETERS USED IN PROCESSING NUCLEAR/NEUTRON LOG DATA: FIXED HOLE SIZE = MLrD WEIGHT = MUD SALINITY = FORMATION WATER SALINITY = LITHOLOGY = $ File Header Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 6.75" 9.2 - 10.0 PPG. 500 CL- PPM. 19149 CL- PPM. SANDSTONE Date of Generation ....... 99/03/26 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 START DEPTH GR 2400.0 RPD 2436.0 RPM 2436.0 RPS 2436.0 RPX 2436.0 PEF 2444.0 DRHO 2444.0 RHOB 2444.0 FCNT 2446.5 NCNT 2446.5 NPHI 2446.5 FET 2450.5 ROP 2466.0 $ BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) BASELINE DEPTH $ MERGED DATA SOURCE PBU TOOL CODE MWD MWD $ REMARKS: STOP DEPTH 6946 5 6953 0 6953 0 6953 0 6953 0 6933 5 6933 5 6933 5 6918 0 6918 0 6918 0 6953 0 7039 0 EQUIVALENT UNSHIFTED DEPTH BIT RUN NO MERGE TOP MERGE BASE 2 2466.0 4772.0 3 4772.0 7039.0 MERGED MAIN PASS. $ 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 ...................... -999.25 Depth Units~ ...................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT ROP MWD GR MWD RPX MWD RPS MWD RPM MWD RPD MWD FET MWD NPHI MWD FCNT MWD NCNT MWD RHOB MWD DRHO MWD PEF MWD FT 4 1 68 FT/H 4 1 68 API 4 1 68 OHMM 4 1 68 OHMM 4 1 68 OHMM 4 1 68 OHMM 4 1 68 HOUR 4 1 68 P.U. 4 1 68 CNTS 4 1 68 CNTS 4 1 68 G/CC 4 1 68 G/CC 4 I 68 BARN 4 1 68 0 4 8 12 16 20 24 28 32 36 4O 44 48 52 1 2 3 4 5 6 7 8 9 10 11 12 13 14 Name DEPT ROP GR RPX RPS RPM RPD FET NPHI FCNT NCNT RHOB DRHO PEF Min 2400 3 21 44 86 0 92 0 64 0 26 0 05 0 35 11 75 150 73 18832.5 1.94 -0.1 1.02 Max Mean Nsam 7039 4719.5 9279 1276.56 238.378 9147 255.7 123.322 9094 2000 4.52441 9035 25.54 4.15767 9035 2000 5.24845 9035 2000 5.86734 9035 10.81 1.09962 9006 59.9 37.7036 8944 710.39 239.754 8944 39990 25298.2 8944 2.86 2.31458 8980 0.62 0.0170312 8980 5.03 2.55649 8980 First Reading 2400 2466 2400 2436 2436 2436 2436 2450.5 2446.5 2446.5 2446.5 2444 2444 2444 Last Reading 7039 7039 6946.5 6953 6953 6953 6953 6953 6918 6918 6918 6933.5 6933.5 6933.5 First Reading For Entire File .......... 2400 Last Reading For Entire File ........... 7039 File Trailer Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 99/03/26 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.002 Physical EOF File Header Service nam~ ............. STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 99/03/26 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.001 Comment Record FILE HEADER FILE N-UMBER: 2 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 2 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR RPD RPM RPS RPX PEF DRHO RHOB FCNT NCNT NPHI FET ROP $ LOG HEADER DATA DATE LOGGED: SOFTWARE 2400.0 2436 0 2436 0 2436 0 2436 0 2444 0 2444 0 2444 0 2446 5 2446 5 2446 5 2450 5 2466 0 SURFACE SOFTWARE VERSION: DOWN-HOLE 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 4678.0 4684.5 4684.5 4684.5 4684.5 4665.0 4665.0 4665.0 4649.5 4649.5 4649.5 4684.5 4772.0 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: 05-OCT-98 INSITE 3.2.12.3 CIM 5.46,SP4 5.16,SLD 10.83 MEMORY 4772.0 2466.0 4772.0 41.7 46.7 TOOL NUMBER P1080GRM4 P1080GRM4 P1080GRM4 P1080GRM4 6.750 6.8 LSND 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) : 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 ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 9.10 46.0 10.0 500 5.8 3.100 2.130 3.900 2.400 .6 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD 2 FT/H 4 1 68 4 2 GR MWD 2 API 4 1 68 8 3 RPX MWD 2 OHMM 4 1 68 12 4 RPS MWD 2 OHMM 4 1 68 16 5 RPM MWD 2 OHMM 4 1 68 20 6 RPD MWD 2 OHMM 4 1 68 24 7 FET MWD 2 HOUR 4 1 68 28 8 NPHI MWD 2 P.U. 4 1 68 32 9 FCNT MWD 2 CNTS 4 1 68 36 10 NCNT MWD 2 CNTS 4 1 68 40 11 R}{OB MWD 2 G/CC 4 1 68 44 12 DR_HO MWD 2 G/CC 4 1 68 48 13 PEF MWD 2 BARN 4 1 68 52 14 37.9 First Name Man Max Mean Nsam Reading DEPT 2400 4772 3586 4745 2400 ROP 3.37 885.66 281.88 4613 2466 GR 44.86 201.66 114.009 4557 2400 Last Reading 4772 4772 4678 RPX 1.06 2000 4.91569 RPS 0.64 25.54 4.13552 RPM 0.26 2000 6.47199 RPD 0.05 2000 7.62719 FET 0.35 3.55 0.836039 NPHI 13.03 59.9 40.0554 FCNT 150.73 550.69 211.486 NCNT 18832.5 36060.9 24131.6 RHOB 1.94 2.86 2.2277 DRHO -0.06 0.62 0.0198447 PEF 1.02 4.96 2.23873 4498 4498 4498 4498 4469 4407 4407 4407 4443 4443 4443 2436 2436 2436 2436 2450.5 2446.5 2446.5 2446.5 2444 2444 2444 4684.5 4684.5 4684.5 4684.5 4684.5 4649.5 4649.5 4649.5 4665 4665 4665 First Reading For Entire File .......... 2400 Last Reading For Entire File ........... 4772 File Trailer Service name ............. STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 99/03/26 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 ....... 99/03/26 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.002 Comment Record FILE HEADER FILE NUMBER: 3 RgkW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: DEPTH INCREMENT: FILE SUMMARY VENDOR TOOL CODE FCNT NCNT NPHI PEF DRHO RHOB GR FET 3 .5000 START DEPTH 4650 5 4650 5 4650 5 4666 0 4666 0 4666 0 4678 5 4685 5 STOP DEPTH 6918.0 6918.0 6918.0 6933.5 6933.5 6933.5 6946.5 6953.0 RPD 4685.5 RPM 4685.5 RPS 4685.5 RPX 4685.5 ROP 4770.0 $ 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: 6953.0 6953.0 6953.0 6953.0 7039.0 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 AlgD 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 TEMPEP~ATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAI<dE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN) : EWR FREQUENCY (HZ) : REMARKS: $ 06-OCT-98 INSITE 3.2.12.3 CIM 5.46,SP4 5.16,SLD 10.83 MEMORY 7039.0 4772.0 7039.0 42.4 46.5 TOOL NUMBER P1080GRM4 P1080GRM4 P1080GRM4 P1080GRM4 6.750 6.8 LSND 10.00 45.0 10.0 500 4.6 3.500 2.068 4.400 4.000 47.8 .6 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 ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam DEPT FT 4 1 ROP MWD 3 FT/H 4 1 GR MWD 3 API 4 1 RPX MWD 3 OHMM 4 1 RPS MWD 3 OHMM 4 1 RPM MWD 3 OHMM 4 1 RPD MWD 3 OHMM 4 1 FET MWD 3 HOUR 4 1 NPHI MWD 3 P.U. 4 1 FCNT MWD 3 CNTS 4 1 NCNT MWD 3 CNTS 4 1 RHOB MWD 3 G/CC 4 1 DRHO MWD 3 G/CC 4 1 PEF MWD 3 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 Min Max Mean DEPT 4650.5 7039 5844.75 ROP 3.21 1276.56 193.934 GR 69.63 255.7 132.675 RPX 0.92 23.58 4.13695 RPS 0.99 23.33 4.18011 RPM 1 20.73 4.03587 RPD 0.97 19.67 4.12305 FET 0.45 10.81 1.35812 NPHI 11.75 58.18 35.4193 FCNT 152.7 710.39 267.215 NCNT 20962.5 39990 26431.5 RHOB 2.17 2.63 2.3997 DRHO -0.1 0.49 0.0142703 PEF 1.3 5.03 2.86783 First Last Nsam Reading Reading 4778 4650.5 7039 4539 4770 7039 4537 4678.5 6946.5 4536 4685.5 6953 4536 4685.5 6953 4536 4685.5 6953 4536 4685.5 6953 4536 4685.5 6953 4536 4650.5 6918 4536 4650.5 6918 4536 4650.5 6918 4536 4666 6933.5 4536 4666 6933.5 4536 4666 6933.5 First Reading For Entire File .......... 4650.5 Last Reading For Entire File ........... 7039 File Trailer Service name ............. STSLIB.003 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 99/03/26 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.004 Physical EOF Tape Trailer Service name ............. LISTPE Date ..................... 99/03/26 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Next Tape Name ........... UNKNOWN Comments ................. STS LIS Writing Library. Reel Trailer Service name ............. LISTPE Date ..................... 99/03/26 Origin ................... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Next Reel Name ........... UNKNOWN Comments ................. STS LIS Writing Library. Scientific Scientific Technical Technical Services Services Physical EOF Physical EOF End Of LIS File
