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QJ a Q N 2 M O M Z a O O a • s W c N 8 eD E v a � cv o 0 CL` a F- H Image Project Well History File Cover Page XHVZE This page identifies those items that were not scanned during the initial production scanning. They are available in the original file, may be scanned during the rescan activity or are viewable by direct inspection of the file. Organization (done) Well History File Identifier RESCAN Golor items: rayscale items: [] Poor Quality Originals: Other: TOTAL PAGES: NOTES: DIGITAL DATA [] Diskettes No. [] Other, No/Type OVERSIZED (Scannable) Maps: Other items scannable by large scanner OVERSIZED (Non-Scannable) rn Logs of various kinds Other ORGANIZED BY: BEVERLY BREN VINCENT SHERYL MARIA LOWELL DATE: Is/ Project Proofing [] Staff Proof By: Date: PROOFED BY: BEVERLY BREN VINCENT SHERYL MARIA LOWELL DATE: /si Scanned (done) SCANNED BY~ (at the time of scanning) BEVERLY BRE~HERYL MARIA LOWELL RESCANNED BY; BEVERLY BREN VINCEN~ARIA LOWELL General Notes or Comments about this file: PAGES: Quality Checked (done) RevlNOTScanned,wpd WELL LOG TRANSMITTAL To: Alaska Oil and Gas Conservation Comm. Attn.: Christine Mahnken 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: Plug Setting Record: 3M-18 Run Date: 2/17/2010 February 20, 2010 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 3M-18 Digital Data in LAS format, Digital Log Image file 1 CD Rom 50-029-21730-00 ,~~,`6 ~'~;"'~ VIP.!{ ri. PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNIlVG 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@halliburto~:com Date: „ l~~~`~~ ~ 9~~~ j~ ~ ,; Signed: r ~' ,, ~ ~ ~', ~` ~ c!r3SII. II.ÈLL LOG TRANSMITTAL ) (<? 7 - ô!j-S- ProActive Diagnostic Services, 'nc. ~ OCT 122004. To: State of Alaska AOGCC 333 W. 7th Street Suite 700 Anchorage. Alaska 99501 RE: Distribution - Final Print(s) The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the attention of : Joey Burton / Jeni Thompson ProActive Diagnostic ServicesJ Inc. P. O. Box 1369 Stafford. TX 77497 WELL DATE LOG TYPE DIGITAL OR CD-ROM 1 MYLAR / SEPIA FILM 1 BLUE LINE PRINT[S) REPORT OR BLUE LINE Open Hole 1 Aes. Eva!. CH 1 1 1 Meeh. CH 3M-18 9-11-04 Caliper Survey 1 Apt or 2 Color Signe~/ /I~)«~ Print Name: #J/; 'J- Zrh""~"'N Dare: It? po Þr/ PRoAcTivE DiAG~\ic ~ERviCES, INC., PO Box 1 }69 STAffoRd TX 77477 Phone:(281) 565-9085 Fax:(281) 565-1369 E-mail: pds@memorylog.com Website: www.memorylog.com ~CANNED NOV 0 8 2004 1~7-oS5 Memory Multi-Finger Caliper Log Results Summary Company: Log Date: Log No. : Run No.: Pipe1 Desc.: Pipe1 Use: ConocoPhillips Alaska, Inc. September 11, 2004 5576 1 2.875" 6.5 lb. J-55 Tubing Well: Field: State: API No.: Top Log Intvl1.: Bot. Log Intvl1.: 3M-18 Kuparuk Alaska 50-029-21730-00 Surface 8,120 Ft. (MD) Inspection Type: Corrosive & Mechanical Damage Inspection COMMENTS: This caliper data is tied into the end of the tubing @ 8,120' (Driller's Depth). This log was run to assess the condition of the tubing with respect to corrosive and mechanical damages. Six holes are recorded throughout the tubing. Wall penetrations from 20% to 76% are recorded throughout the remainder of the tubing. The damage appears in the form of general corrosion with deeper isolated pitting and lines of corrosion. Cross-sectional wall loss of 25% is recorded in an area of erosion opposite a hole recorded in joint 240 @ 7,886'. Although no significant I.D. restrictions are recorded, buckling is recorded from 6,000' - 8,100'. The distribution of maximum recorded penetrations is illustrated in the Body Region Analysis Page of this report. MAXIMUM RECORDED WALL PENETRATIONS: Multiple Holes! (100%) Jt. 240 @ 7,886 Ft. (MD) Multiple Holes! (100%) Jt. 203 @ 6,657 Ft. (MD) Multiple Holes! (100%) Jt. 241 @ 7,915 Ft. (MD) Hole! (100%) Jt. 189 @ 6,192 Ft. (MD) Hole! (100%) Jt. 234 @ 7,695 Ft. (MD) MAXIMUM RECORDED CROSS-SECTIONAL METAL LOSS: Erosion Opposite Hole Erosion Opposite Hole ( 25%) ( 17%) Jt. Jt. 240 241 @ @ 7,886 Ft. (MD) 7,922 Ft. (MD) No other significant areas of cross-sectional wall loss (> 14%) are recorded. MAXIMUM RECORDED ID RESTRICTIONS: No significant I.D. restrictions are recorded. I Field Engineer: B. McCrossan Analyst: M. Lawrence Witness: V. Yoakum ProActive Diagnostic Services, Inc. / P.O. Box 1369, Stafford, TX 77497 Phone: (281) or (888) 565-9085 Fax: (281) 565-1369 E-mail: PDS@memorylog.com Prudhoe Bay Field Office Phone: (907) 659-2307 Fax: (907) 659-2314 rc. V'rJ- (ò{rz,f 0 tf Q. Well: Field: Company: Country: 3M-18 Kuparuk ConocoPhillips Alaska, Inc. USA Tubing: Grade & Thread )-55 Nom.OD 2.875 ins Weight 6.5 f Penetration and Metal Loss (% wall) - penetration body 250 - metal loss body 200 150 100 50 0 0 to 1% 40 to over 85% 85% 6 0 Damage Configuration ( body) 100 80 60 40 20 0 isolated pitting general corrosion line ring hole / poss corrosion corrosion ¡hie hole 6 PDS Report Overview Body Region Analysis Survey Date: Tool Type: Tool Size: No. of Fingers: Analyst: Nom.lD 2.441 ins September 11, 2004 MFC 24 No. 99628 1.69 24 M. Lawrence Nom. Upset 2.875 ins Upper len. 1.2 ins Lower len. 1.2 ins Damage Profile (% wall) - penetration body 0 0 GLM 1 GLM2 GLM 3 GLM4 GLM 5 GLM6 GLM 7 GLM8 - metal loss body 50 100 GLM9 Bottom of Survey = 245.6 Analysis Overview page 2 PDS REPORT JOINT TABULATION SHEET Pipe: Body Wall: Upset Wall: NominaII.D.: 2.875 in 6.5 ppf J-55 0.217 in 0.217 in 2.441 in Well: Field: Company: Country: Survey Date: 3M-18 Kuparuk ConocoPhillips Alaska, Inc. USA September 11, 2004 Joint Jt Depth Pen. Pen. Pen. Metal Min. Damage Profile No. (Ft) Upset Body % Loss 1.0. Comments (%wall) (Ins.) (Ins.) 'Yo (Ins.) 0 50 100 .1 36 0 0.01 2 2 2.41 1 41 0 0.02 10 2 2.37 2 73 [) 0.02 10 3 2.37 Lt. Deposits. 3 106 [) 0.01 5 4 2.35 Lt. Deposits. 4 139 0 0.02 7 :3 2.36 Lt. Deposits. 5 171 () 0.02 11 :3 2.36 Lt. Deposits. 6 204 [) 0.02 11 2 2.36 Lt. Deoosits. 7 237 () 0.01 6 2 2.36 8 269 () 0.03 12 2 2.36 9 302 () 0.03 12 :3 2.36 Lt. Deposits. 10 334 [) 0.02 11 :3 2.37 11 367 () 0.03 12 :3 2.36 12 399 0 0.02 10 :3 2.36 13 432 0 0.02 10 2 2.32 14 464 0 0.01 6 :3 2.33 Lt. Deposits. 15 496 () 0.02 11 3 2.36 Lt. Deoosits. 16 529 () 0.02 11 2 2.37 Lt. Deposits. 17 561 0 0.03 14 :3 2.38 Shallowoittin\!. Lt. Deoosits. 18 594 0 0.02 10 2 2.37 Lt. Deposits. 19 626 0 0.02 10 3 2.37 Lt. Deposits. 20 659 () 0.02 11 2 2.36 21 691 0 0.01 3 2 2.35 22 724 () 0.02 11 3 2.35 - 23 756 [) 0.02 10 :3 2.35 - 24 789 () 0.01 7 :3 2.36 . 25 821 () 0.02 10 2 2.35 - 26 854 () 0.03 12 L ~ -------~----. 27 887 () 0.02 10 2 2.36 28 919 () 0.03 13 :3 2.35 - 29 952 0 0.02 11 4 2.35 Lt. Deposits. III 30 979 () 0.01 6 3 2.37 31 1011 0 0.01 7 2 2.38 . 32 1044 () 0.02 10 :3 2.38 III 33 1076 () 0.03 12 2 2.37 . 34 1109 0 0.02 10 3 2.37 Lt Deposits. 35 1142 () 0.01 6 2 2.37 . 36 1174 0 0.01 6 3 2.36 37 1207 0 0.01 5 3 2.36 38 1239 0 0.02 8 3 2.35 " 39 1272 0 0.01 6 1 2.36 40 1304 0 0.02 10 2 2.36 - 41 1337 0 0.01 6 2 2.35 Lt. Deoosits. 42 1369 0 0.02 7 2 2.37 Lt. Deposits. '" 43 1402 0 0.02 11 2 2.37 Lt. Deposits. - 44 1435 0 0.02 11 :3 2.37 Lt. Deposits. III 45 1467 0 0.03 12 2 2.38 Lt. Deposits. - 46 1500 0 0.03 13 2 2.37 - 47 1532 0 0.03 12 2 2.37 Lt. Deoosits. 48 1565 0 0.06 25 3 2.36 Line corrosion. Lt. Deposits. 18 49 1597 0 0.03 14 2 2.36 Lt. Deposits. I Penetration Body Metal Loss Body Page 1 PDS REPORT jOINT TABULATION SHEET Pipe: Body Wall: Upset Wall: NominaII.D.: 2.875 in 6.5 ppf J-55 0.217 in 0.217 in 2.441 in Well: Field: Company: Country: Survey Date: 3M-18 Kuparuk ConocoPhillips Alaska, Inc. USA September 11, 2004 Joint Jt. Depth Pen. Pen. Pen. Metal Min. Damage Profile No. (Ft.) Upset Body % Loss I.D. Comments (%wall) (Ins.) (Ins.) '}'o (Ins.) 0 50 100 50 1630 0 0.03 15 4 2.33 Shallow nittiní.!:. 51 1662 0 0.03 13 3 2.34 52 1694 0 0.04 17 3 2.35 Shallow oittinlL 8 53 1727 0 0.03 13 2 2.36 Lt. Deoosits. 54 1759 0 0.03 13 2 2.35 54.1 1792 0 0.00 2 1 2.40 PUP 54.2 1797 0 0 0 0 2.31 SSSV 55 1806 () 0.03 13 2 2.36 Lt. DeDosits. 56 1839 () 0.03 14 2 2.34 Lt. Denosits. 57 1871 0 0.03 13 4 2.34 58 1904 0 0.03 14 2 2.33 59 1937 0 0.03 13 2 2.37 Lt. Deoosits. - 60 1968 () 0.04 18 1 2.34 Shallow DittinlL Lt. DeDosits. -. 61 2001 () 0.03 13 1 2.33 Lt. DeDosits. - 62 2034 0 0.07 11 2 7.33 Lt. DeDosits. - 63 2066 0 0.04 17 3 2.33 Shallow nittin\!. _8 64 2098 0 0.02 11 2 2.33 Lt. DeDosits. - 65 2131 0 0.01 6 2 2.34 Lt. Denosits. 66 2163 () 0.03 13 2 2.33 ~ 67 2196 0 0.03 13 2 2.33 Lt. Deoosits. - 68 2228 0 0.03 12 2 2.32 Lt. Deoosits. - 69 2261 () 0.03 12 2 2.31 Lt. DeDosits. - 70 2293 0 0.02 11 2 2.34 - 71 2326 () 0.03 12 3 2.33 Lt. DeDosits. ~ 72 2359 0 0.02 11 2 2.31 Lt. DeDosits. - 73 2391 () 0.03 13 2 2.31 - ~ 2424 (2 0.03 12 2 2.31 . 75 2456 0 0.03 12 2 2.32 Lt. Denosits. ~ 76 2488 0 0.03 16 2 2.34 Shallow oittin\!. -" 77 2521 0 0.02 11 2 2.34 - 78 2553 0 0.03 12 3 2.33 .. 79 2581 0 0.03 13 1 2.34 - 80 2614 0 0.03 16 3 2.33 Shallow Ditting. Lt. DeDosits. ~ 81 2646 a 0.02 8 1 2.35 Lt. DeDosits. . 82 2679 0 0.04 17 3 2.35 Shallow nittinlL .. 83 2712 0 0.03 12 2 2.36 - 83.1 2744 0 0 0 0 N/A GLM 1 (Latch@ 10:00\ 84 2751 0 0.05 21 5 2.32 Corrosion. Lt. Deoosits. II 85 2783 0 0.04 17 2 2.31 Shallow Ditting. Lt. DeDosits. - 86 2815 0 0.03 14 2 2.30 .. 87 2848 0 0.03 14 2 2.30 Lt. Denosits. ~ 88 2881 0 0.03 15 2 2.32 Shallow nittin\!. Lt. Deoosits. 89 2914 0 0.03 14 2 2.29 Lt. Deoosits. ~ 90 2946 0 0.03 16 2 2.31 Shallow Ditting. II 91 2978 0 0.03 12 2 2.32 Lt. DeDosits. ~ 92 3011 0 0.04 19 2 2.30 Shallow Ditting. ~. 93 3044 0 0.03 16 3 2.30 Shallow Ditting. Lt. DeDosits. 94 3076 0 0.02 11 2 2.33 95 3108 0 0.03 12 3 2.30 Lt. Deoosits. 96 3141 a 0.03 16 2 2.29 Shallow Ditting. Lt. DeDosits. I Penetration Body Metal Loss Body Page 2 PDS REPORT jOINT TABULATION SHEET Pipe: Body Wall: Upset Wall: NominaII.D.: 2.875 in 6.5 ppf )-55 0.217 in 0.217 in 2.441 in Well: Field: Company: Country: Survey Date: 3M-18 Kuparuk ConocoPhillips Alaska, Inc. USA September 11, 2004 Joint Jt. Depth Pen. Pen. Pen. Metal Min. Damage Profile No. (Ft.) Upset Body % Loss I.D. Comments (%wall) (Ins.) (Ins.) 'Yo (Ins.) 0 50 100 97 3173 0 0.03 12 1 2.32 Lt. Deoosits. 98 3206 0 0.03 16 3 2.31 Shallow oittinl!:. Lt. Deoosits. " 99 3239 0 0.03 16 2 2.31 Shallow oittinl!:. Lt. Deoosits. " 100 3271 0 0.03 16 3 2.32 Shallow oittinl!:. Lt. Deoosits. " 101 3304 0 0.03 14 3 2.30 Lt. Deoosits. 102 3336 0 0.03 13 1 2.30 Lt. Deoosits. . 103 3369 0 0.03 14 2 2.32 Lt. Denosits. . 104 3401 0 0.03 15 3 2.32 Shallow nittin\!. Lt. Deposits. '" 105 3433 0 0.05 22 2 2.31 Isolated nittin\!. "' II 106 3467 0 0.03 15 2 2.31 Shallow nittin\!. Lt. Deoosits. '" 107 3499 () 0.03 15 3 2.29 Shallow oittinl!:. ~ 108 3532 () 0.03 14 2 2.33 Lt. Deoosits. 109 3564 0 0.04 17 3 2.31 Shallow oittinl!:. III,. 110 3597 () 0.03 13 2 2.31 Lt. Deoosits. . 111 3679 () 0.05 22 2 2.31 Isolated oittinl!:. Lt. Deposits. . II 112 3662 () 0.05 22 3 2.32 Isolated nittin\!. "' II 113 3694 () 0.04 16 2 2.32 Shallow oittinl!:. """ 114 3726 () 0.06 27 3 2.33 Isolated oittinl!:. II 115 3758 () 0.03 15 3 2.38 Shallow oittinl!:. Lt. Deposits. 116 3790 0 0.03 15 2 2.36 Shallow oittinl!:. 117 3823 [) 0.05 21 4 2.31 Isolated oittinl!:. Lt. Deoosits. III II 118 3856 () 0.03 15 2 2.31 Shallow oittinl!:. Lt. Deoosits. III,. 119 3887 [) 0.04 19 2 2.31 Shallow oittinl!:. "' II 120 3920 () 0.03 15 2 2.33 Shallow nittin\!. Lt. Deoosits. ..11 121 3953 () 0.03 13 2 2.31 '" 122 3985 0 0.03 13 2 2.33 Lt. Deposits. '" 123 4017 [) 0.03 12 3 2.31 124 4050 [) 0.04 18 3 2.32 Shallow oittinl!:. I'" 125 4083 () 0.03 16 2 2.31 Shallow oittinl!:. Lt. Deoosits. I 126 4116 0 0.03 12 3 2.32 Lt. Deoosits. III 127 4147 0 0.03 13 4 2.30 Lt. Deposits. .. 128 4180 [) 0.05 21 2 2.32 Isolated pittinl!:. Lt. Deoosits. III,. 129 4212 0 0.03 14 2 2.33 III 130 4245 0 0.03 14 2 2.33 Shallow pitting. Lt. Deposits. ~ 131 4278 () 0.03 14 3 2.29 Lt. Deposits. '" 132 4310 () 0.04 21 2 2.30 Isolated pittinl!:. "' II 133 4343 () 0.04 18 3 2.32 Shallow pittinl!:. Lt. Deposits. 134 4376 () 0.04 16 2 2.30 Shallow pittinl!:. Lt. Deposits. III,. 135 4407 () 0.03 15 3 2.32 Shallow pitting. Lt. Deposits. III~ 136 4439 0 0.03 13 2 2.31 . 137 4472 [) 0.04 18 3 2.33 Shallow oittinl!:. Lt. Deoosits. "',. 138 4505 0 0.04 18 3 2.32 Shallow oittin\!. Lt. Deoosits. 139 4537 () 0.04 18 3 2.30 Shallow pittinl!:. Lt. Deposits. 140 4570 0 0.03 15 3 2.31 Shallow oittinl!:. Lt. Deposits. 141 4602 0 0.04 18 3 2.32 Shallow nittin\!. Lt. Deposits. 111111 142 4635 () 0.03 15 5 2.30 Shallow nittin\!. Lt. Deposits. ..~ 142.1 4667 0 0 0 0 N/A GLM 2 (Latch @ 1 :30) 143 4674 0 0.04 17 4 2.34 Shallow oittinl!:. II 144 4706 [) 0.03 14 3 2.34 Shallow oittinl!:. 145 4739 () 0.04 18 2 2.33 Shallow oittinl!:. Lt. Deposits. II I Penetration Body Metal Loss Body Page 3 PDS REPORT jOINT TABULATION SHEET Pipe: Body Wall: Upset Wall: NominaII.D.: 2.875 in 6.5 ppf J-55 0.217 in 0.217 in 2.441 in Well: Field: Company: Country: Survey Date: 3M-18 Kuparuk ConocoPhillips Alaska, Inc. USA September 11, 2004 joint I)t. Depth Pen. Pen. Pen. Metal Min. Damage Profile No. (Ft.) Upset Body % Loss I.D. Comments (%wall) (Ins.) (Ins.) 'Yo (Ins.) 0 50 100 146 4771 () 0.03 12 3 2.32 147 4804 () 0.03 13 2 2.34 148 4836 0 0.04 19 3 2.32 Shallow nittin\!. . 149 4869 () 0.03 14 3 2.33 Lt. Denosits. 150 4902 () 0.03 13 2 2.29 Lt. Deoosits. 151 4934 () 0.04 17 3 2.31 Shallow oittin\!. Lt. Deoosits. 152 4967 () 0.03 14 2 2.30 153 4999 () 0.04 17 3 2.31 Shallow oittini!:. - 154 5032 0 0.06 26 4 2.33 Isolated pitting. Lt. Deoosits. . 155 5064 0 0.04 19 4 2.33 Line shallow corrosion. Lt. Deoosits. . 156 5096 0 0.03 13 3 2.30 Lt. Denosits. 157 5129 0 0.06 26 3 2.31 Isolated nìttin\!. Lt. Denosits. . 158 5162 0 0.04 19 5 2.31 Shallow pitting. Lt. Deposits. . 159 5194 0 0.05 24 4 2.30 Line corrosion. Lt. Denosits. . 160 5227 0 0.03 15 5 7.32 Shallow oittin\!. Lt. Deoosits. 161 5259 0 0.04 17 4 2.32 Shallow corrosion. Lt. Deoosits. 162 5292 0 0.03 14 4 2.31 Lt. Deoosits. 163 5324 0 0.05 24 4 2.31 Isolated pitting. Lt. Deoosits. .. Ib4 53J7 0 0.04 17 4 2.32 Shallow pitting. Lt. Deposits. '" 165 5389 0 0.03 15 6 2.33 Shallow nittin\!. Lt. Deposits. - 166 5422 0 0.04 16 4 2.32 Shallow nittin\!. Lt. Deposits. - 167 5454 0 0.03 12 5 2.32 Lt. Deoosits. 168 5486 () 0.04 19 4 2.34 Line shallow corrosion. Lt. Deoosits. 169 5518 0 0.04 18 6 2.32 Shallow oittim!. Lt. Deoosits. III 170 5551 () 0.05 22 5 2.33 Line corrosion. Lt. Deoosits. .. 170.1 5583 () 0 0 () N/A GLM 3 (Latch @ 10:00) 171 5590 0 0.06 26 4 2.1J- - t!¡9JfltedJ2ittill~_11J::>~osits. !III 172 5622 () 0.03 15 3 2.33 Shallow nittin\!. Lt. Denosits. ~ 173 5655 () 0.03 12 4 2.32 Lt. Denosits. 174 5688 () 0.03 15 6 2.31 Shallow oittim.!. Lt. Deoosits. 175 5719 () 0.05 23 4 2.31 Isolated oittin\!. Lt. Deoosits. !III 176 5751 0 0.04 18 5 2.33 Line shallow corrosion. Lt. Deoosits. .. 177 5783 () 0.04 18 4 2.32 Shallow oittinl.!. .. 178 5816 () 0.03 14 4 2.32 Lt. Deposits. 179 5848 0 0.06 26 4 2.34 Line corrosion. Lt. Deposits. !III 180 5880 0 0.04 18 5 2.33 Shallow pitting. III 181 5913 () 0.04 17 5 2.32 Shallow nittin\!. Lt. Denosìts. '" 182 5947 0 0.03 15 4 2.34 Shallow oittin\!. 182.1 5978 () 0 0 0 N/A GLM 4 (Latch @ 11 :30) 183 5984 () 0.04 20 5 2.35 Isolated pitting. Bucklin". 184 6017 0 0.05 25 3 2.33 Line corrosion. Buckling. III.. 185 6050 0 0.04 16 4 2.33 Shallow pitting, Lt. Deoosits. Buckling. ..'" 186 6082 () 0.06 28 3 2.35 Isolated nitting. Lt. Deposits. Buckling. ....- 187 6115 0 0.02 11 3 2.35 Lt. Denosits. Buckling. III 188 6147 0 0.14 64 3 2.35 Corrosion. Lt. Denosits. Bucklin\!. 189 6179 0 0.31 100 13 2.33 Hole! Bucklin\!. 190 6213 0 0.04 21 2 2.32 Isolated pitting. Bucklin!.!:. 191 6244 () 0.12 55 5 2.31 Line corrosion. Lt. Deoosits. Bucklin\!.. 192 6277 0 0.03 13 4 2.35 Lt. Deposits. Buckling. 193 6310 0 0.10 45 4 2.34 Isolated nittin\!. Buckling. IPenetration Body Metal Loss Body Page 4 PDS REPORT jOINT TABULATION SHEET Pipe: Body Wall: Upset Wall: NominaII.D.: 2.875 in 6.5 ppf J-55 0.217 in 0.217 in 2.441 in Well: Field: Company: Country: SUrvey Date: 3M-18 Kuparuk ConocoPhillips Alaska, Inc. USA September 11, 2004 Joint Jt. Depth Pen. Pen. Pen. Metal Min. Damage Profile No. (Ft.) Upset Body % Loss I.D. Comments (%wall) (Ins.) (Ins.) 'Yo (Ins.) 0 50 100 194 6342 0 0.01 6 2 2.33 Lt. Denosits. Buckling. " 195 6374 0 0.05 24 3 2.27 Line corrosion. Lt. Deposits. Buckling. 1""'" 195.1 6408 0 0 0 0 N/A GLM 5 (Latch @ 1 :301 196 6414 () 0.07 34 0 2.35 Line corrosion. Lt. Deoosits. Bucklin\!.. 197 6446 0 0.04 18 2 2.34 Shallow oittim!.. Lt. Deoosits. Bucklin\!.. .~ 198 6478 0 0.08 36 4 2.35 Line corrosion. Lt. Deoosits. Bucklin\!.. "" 199 6511 0 0.05 23 4 2.37 Isolated oittin\!.. Lt. Deoosits. Buckling. "" 200 6543 0 0.04 20 3 2.33 Isolated oittin\!.. Lt. Dcposits. Buckling. "" 201 6577 () 0.05 24 3 2.32 Line corrosion. Lt. Deoosits. Bucklin\!.. "" 202 6608 0 0.04 20 2 2.31 Isolated oittinl!:. Lt. Deoosits. Bucklin\!.. 203 6642 0 0.36 100 Ii 2.30 Multiole Holes! Bucklin\!.. 204 6673 om 0.05 24 4 2.31 Isolated oittin\!.. Lt. Deposits. Bucklin\!.. 205 6706 0 0.06 29 4 2.35 Isolated pitting. Lt. Deposits. Buckling. II 206 6738 () 0.09 42 5 2.34 Line corrosion. Lt. Deposits. Bucklin\!.. II 207 6771 () 0.07 34 4 2.32 Line corrosion. Lt. Deposits. Bucklin\!.. "" 208 6804 () 0.08 35 5 2.32 Line corrosion. Lt. Deposits. Bucklin\!.. II 209 6836 0 0.07 30 2 2.33 Line corrosion. Buckling. "" 210 6869 0 0.06 26 3 2.31 Isolated oittinl!:. Lt. Deoosits. Bucklin\!.. pi"" 210.1 6901 0 0 0 0 N/A GLM 6 (Latch @ 6:301 211 6907 0 0.04 20 3 2.28 Corrosion. Lt. Deposits. Bucklin\!.. I'" 212 6941 D.O2 0.07 33 4 2.26 Corrosion. Lt. Deoosits. Bucklin\!.. II 213 6972 0.02 0.07 34 5 2.32 Line corrosion. Lt. Deoosits. Bucklin\!.. 214 7006 0 0.05 23 5 2.32 Line corrosion. Lt. Deoosits. Buckling. II 215 7038 0 0.07 33 3 2.33 Line corrosion. Lt. Deposits. Buckling. II 216 7070 0.02 0.07 33 4 2.25 Line corrosion. Lt. Deposits. Bucklin\!.. II. 217 7103 0 0.07 31 5 2.32 Line corrosion. Lt. Deposits. Buckling. 218 7135 0 0.07 30 3- 2.34 Isolated pitting. Lt. Deposits. Buckling. . 219 7168 0 0.06 29 3 2.31 Line corrosion. Lt. Deoosits. Bucklin\!.. 220 7201 0 0.17 76 7 2.32 Line corrosion. Lt. Deoosits. Bucklin\!.. 220.1 7233 0 0 0 0 N/A GLM 7 (Latch @ 12:00) 221 7239 0 0.05 24 4 2.32 Isolated oittin!!.. Lt. Deposits. Bucklin!!.. . 222 7271 0 0.08 36 7 2.32 Line corrosion. Lt. Deposits. Buckling. 223 7304 () 0.08 36 6 2.32 Line corrosion. Lt. Deposits. Buckling. . 224 7336 0 0.06 29 0 2.29 Line corrosion. Lt. Deposits. Buckling. . 225 7368 () 0.10 44 0 2.33 Line corrosion. Lt. Deoosits. Bucklin\!.. . 226 7402 0 0.13 59 3 2.32 Line corrosion. Lt. Deoosits. Bucklin!!.. 227 7434 0 0.07 31 4 2.32 Isolated oittin\!.. Lt. Deposits. Bucklin\!.. 228 7466 0.04 0.05 21 3 2.32 Line corrosion. Lt. Deposits. Bucklin\!.. 229 7498 () 0.06 29 0 2.33 Line corrosion. Lt. Deposits. Buckling. 230 7531 0 0.07 34 5 2.29 Line corrosion. Lt. Deoosits. Buckling. 231 7564 0 0.08 38 7 2.28 Line corrosion. Lt. Deposits. Bucklin\!.. 232 7596 0 0.07 34 4 2.29 Line corrosion. Lt. Deoosits. Bucklin!!.. 232.1 7629 0 0 0 () N/A GLM 8 (Latch @ 8:00) 233 7635 0 0.08 35 6 2.31 Line corrosion. Lt. Deposits. Bucklin\!.. 234 7668 () 0.29 100 14 2.31 Hole! Buckling. . 235 7699 0 0.07 32 0 2.36 Line corrosion. Lt. Deposits. Buckling. 236 7732 0 0.08 35 (, 2.33 Isolated pitting. Lt. Deposits. Buckling. 237 7764 0 0.11 53 4 2.29 Corrosion. Lt. Deoosits. Buckling. 238 7798 0 0.14 65 (, 2.27 Line corrosion. Lt. Deoosits. Buckling. 239 7829 D.Oo 0.08 38 7 2.22 Line corrosion. Deoosits. Bucklin!!.. I Penetration Body Metal Loss Body Page 5 PDS REPORT jOINT TABULATION SHEET Pipe: Body Wall: Upset Wall: NominaII.D.: 2.875 in 6.5 ppf J-55 0.217 in 0.217 in 2.441 in Well: Field: Company: Country: Survey Date: 3M-18 Kuparuk ConocoPhillips Alaska, Inc. USA September 11, 2004 Joint Jt. Depth Pen. Pen. Pen. Metal Min. Damage Profile No. (Ft.) Upset Body % Loss 1.0. Comments (%wall) (Ins.) (Ins.) %, (Ins.) 0 50 100 240 7862 0 0.49 100 25 2.30 Multiole Holes! Bucklin\!:. . 241 7§~LL - -_C) ... _OJ.L 100 17 ~_.~I:!- f---_"'ilJi!iQI~ Hol~.s! Bucklin\!:. 242 7927 0 0.07 33 7 2.33 Line corrosion. Lt. Deoosits. Bucklin\!:. 243 7960 0 0.10 48 6 2.32 Line corrosion. Deoosits. Bucklin\!:. 244 7993 0 0.12 54 6 2.30 Line corrosion. Deoosits. Buckling. 244.1 8025 0 0 0 0 N/A GLM 9 (Latch @ 8:00) 245 8033 0 0.08 36 (, 2.38 Corrosion. Deoosits. Bucklin\!:. r- 1111 245.1 8066 0 0.22 100 9 2.32 PUP Hole! Bucklin\!:. 245.2 8073 0 0 0 0 2.31 SBR 245.3 8090 0 0 0 0 2.35 PACKER 245.4 8098 0 0.04 19 6 2.30 PUP Shallow oittin\!:. Lt. Deoosits. r- 245.5 8108 (J 0 0 0 2.25 D NIP "No Go" 245.6 8110 0 0.02 11 2 2.30 PUP Lt. Deoosits. III 245.6 8120 0 0 0 0 N/A WLEG I Penetration Body Metal Loss Body Page 6 cIrls. PDS Report Cross Sections Well: Field: Company: Country: Tubing: September 11, 2004 MFC 24 No. 99628 1.69 24 M. Lawrence 3M-18 Survey Date: Kuparuk Tool Type: ConocoPhj])ips Alaska, Inc. Tool Size: USA No. of Fingers: 2.875 ins 6.5 ppfl:55___- Analyst: Cross Section for joint 240 at depth 7886.18 ft Tool speed = 52 Nominal 10 = 2.441 Nominal 00 = 2.875 Remaining wall area = 80 % Tool deviation = 35 0 Finger 9 Penetration = 0.489 ins Multiple Holes 0.49 ins = 100% Wall Penetration 25% Cross-Sectional Wall Loss Cross Sections page 1 HIGH SIDE = UP <L3s. PDS Report Cross Sections Well: Field: Company: Country: Tubin~: 3M-18 Kuparuk ConocoPhillips Alaska, Inc. USA 2.875 ins 6.5 ppf )-55 Survey Date: Tool Type: Tool Size: No. of Fingers: Analyst: September 11, 2004 MFC 24 No. 99628 1.69 24 M. Lawrence - Cross Section for joint 203 at depth 6656.53 ft Tool speed = 48 NominallD = 2.441 Nominal OD = 2.875 Remaining wall area = 92 % Tool deviation = 48 0 Finger 14 Penetration = 0.358 ins Multiple Holes 0.36 ins = 100% Wall Penetration HIGH SIDE = UP Cross Sections page 2 .. -'..- ConocoPhillips Alaska, Inc. 3M-18 API: 500292173000 SSSV Type: TRDP SSSV (1798-1799. 00:2.875) SBR (8072-8073. OD:2.875) PKR (8089-8090, OD:6.151) NIP (8107-8108. OD:2.875) TIJBING (0-8120. 00:2.875. ID:2.441) Perf (8204-8238) I [] - - - - - - - - - - - - - . Well Type: PROD Orig 6/25/1987 Completion: LastW/O: Ref Log Date: TD: 8523 ftKB Max Hole Angle: 48 deg @ 2700 Size 16.000 9.625 7.000 Top 0 0 0 Bottom 115 4295 8505 Merla DMY DMY DMY DMY DMY DMY DMY DMY DMY Description Cameo'TRDP.1A-SSA' Cameo 'OEJ' Cameo 'HRp.1-SP' Cameo 'D' Nipple NO GO Cameo I I Lost in Hole - - c-- ~ ~ i--- i--- ~ i--- '-- r-- i--- i--- KRU 3M-18 Anale {(j) TS: 39 dea ((j) 8190 Angle @ TD: 39 deg @ 8523 Rev Reason: TBG LEAK NOTE Last UDdate: 9/3/2004 TVD 115 3410 6507 1.0 1.0 1.0 1.0 1.0 1.0 1.0 1.0 1.5 BK 0.000 BK 0.000 BK 0.000 BK 0.000 BK.2 0.000 BK-2 0.000 BK.2 0.000 BK.2 0.000 RM 0.000 Annular Fluid: Reference Log: LastTag: 8320' CTM Last Tag Date: 7124/2004 Casino String - ALL STRINGS Description CONDUCTOR SUR. CASING PROD. CASING Tubina Slrina - TUBING Size I Top I Bottom I TVD I Wt I Grade I Thread 2.875 1 0 .l.n .8g0- . J_~?_08 I 6.50 I J.55 I EUE 8RD AB MOD Perforations SummarY Interval I TVD I Zone I Slatus I Ft I SPF I Date I Tvpe I Comment 8204.8238 I 6273.6300 I A.1 I 134 112 18122/198711PERF 1120deo ph; 5" CsoGun Gas Uft MandrelsNalves St MD TVD Man Man Type V Mfr V Type V aD Latch Port TRO Mfr 1 2744 2330 MMH FMHO 2 4666 3675 MMH FMHO 3 5582 4336 MMH FMHO 4 5977 4621 MMH FMHO 5 6406 4931 MMH FMHO 6 6835 5243 MMH FMHO 7 7231 5531 MMH FMHO 8 7628 5831 MMH FMHO 9 8024 6134 Otis LB Other {I ,IUDs eQuip. etc,) - JEWELRY Depth TVD Tvpe 1798 1663 SSSV 8072 6171 SBR 8089 6184 PKR 8107 6198 NIP 8119 6208 SOS 8120 6208 TTL Fish - FISH Depth I Description 8228 12 KOT Springs General Notes Date I Note 1120/19951WAIVERED WELL: lAx OACOMMUNICATION 1/1312004\ TBG LEAK BE1WEEN 6045' AND 6145' WLM Comment Wt 62.50 36.00 26.00 Grade H-40 J-55 J.55 0 0 0 0 0 0 0 0 0 Date Run 1/1412004 1/14/2004 1/14/2004 211/2001 3124/1997 8122/1987 812211987 41711997 41711997 Thread Vlv Cmnt ID 2.312 2.313 2.347 2250 2.441 2.441 MICROFILMED 9/28/00 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE STATE OF ALASKA . ' v~ ALASKA OIL AND GAS CONSERVATION COMMISSION /~ ~.~ WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well OIL I~ GAS [] SUSPENDED [] ABANDONED [] SERVICE [] , 21 Name of Operator 7. Permit Number ARCO Alaska, Inc. 87-55 , 3. Address 8. APl Number P. 0. Box 100360, Anchorage, AK 99510-0360 50- 029-21730 4. Location of well at surface 9. Unit or Lease Name 858' FNL, 1559' FEL, Sec.25, T13N, R8E, UM Kuparuk River Unit At Top Producing Interval 10. Well Number 1273' FNL, 693' FEL, Sec.24, T13N, RSE, UM 3M-18 Total Depth 11. Field and Pool Alt063' FNL, 682' FEL, Sec.24, T13N, RSE, UN Kuparuk River Field 5'. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. ' ' Kuparuk River 0i 1 Pool RKB 64' ADL 25522 ALK 2558 12. Date Spudded 13, DateT.D. Reached 14. Date Comp.,Susp. orAband. 115. Water Depth, if offshore I16. No. of Completions 06/20/87 06/24/87 10/20/87'J N/A feet MSLI 1 17. Total Depth (MD+TVD) 18.Plug Back Depth (MD+TVD) 19. Directional Survey 20. Depth where SSSV set 21. Thickness of Permafrost 8523'MD, 6520'TVD 8410'MD, 6433'TVD YES ~ NO [] 1798' feet MD 1600' (approx) 22. Type Electric or Other Logs Run DIL/SP/GR/SFL, FDC/CNL, Cal, CBL, Gyro 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED i6:: hZ.5# ~-4~U Surf 115' 24" 208 sx CS II 9-5/8" 36.0# J-55 Surf 4295' 12-1/4" 1500 sx CS Ill & 500 sx Class G 7" 26.0# J-55 Surf 8505' 8-1/2" 400 sx Class G & 175 sx AS I 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) Perforated w/12 spf, 120° phasing ' '2-7/8" 8120' 8089' 8204'-8238'MD 6273'-6299'TVD 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT& KIND OF 'MATERIAL USED See attached Addendum, dated 10/21/87~ for fracture data. , 27. N/A PRODUCTION TEST .... , , Date First Production I Method of Operation (Flowing, gas lift, etc.) I Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAs-MCF wATER-BBL CHOKE SIZE IGAS-OILRATIO TEST PERIOD e , '-~'low Tubing Casing Pressure CALCULATED OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl ic0r-r) Press. 24-HOUR RATE ...... 28. CDR E DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. NoneRECEIVED NOV 161987 ' *Note: Drilled RR 6/25/87. Perforated well & ran tubing 8/22/87. Fractured well 10/20/87. Form 10-407 Rev. 7-1-80 WC3/i 02: DAN I CONTINUED ON REVERSE SIDE Submit in dupli~~// ,.~ j 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 Kuparuk C 8189' 6261' N/A Base Kuparuk C 8198' 6268' Top Kuparuk A 8198' 6268' '. · Base Kuparuk A 8267' 6321' ,, 31, LIST OF ATTACHMENTS Addendum (dated 10/21/87) · 32, I hereby certify that the foregoing is true and correct to the best of my knowledge Signed (~~ j ~~ Title Associate Engineer Date 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 ADDENDUM 10/20/87 3M-18 Frac Kuparuk A-1 zone perfs 8204'-8238' in eight stages per revised procedure dated 10/19/87 as follows: Stage 1: 100 bbls gelled diesel @ 13.1 - 20.1BPM, 6800-4200 psi Stage 2: 450 bbls gelled diesel @ 10 - 20.2 BPM, 3900-4015 psi Stage 3: 50 bbls gelled diesel 2 ppg 20/40 sand @ 20.2 BPM, 4027-4400 psi Stage 4: 50 bbls gelled diesel 4 ppg 20/40 sand @ 18.2 - 20.2 BPM, 4471 - 4550 psi Stage 5: 50 bbls gelled diesel 6 ppg 20/40 sand @ 18.5 - 19.4 BPM, 4700 - 4900 psi Stage 6: 50 bbls gelled diesel 6 ppg 20/40 sand @ 17.5 - 17 BPM, 5200-4950 psi Stage 7: 38 bbls gelled diesel 8 ppg 20/40 sand @ 8.3 - 11BPM, 4784 - 4241 psi Stage 8: 48 bbls gelled diesel flush @ 11BPM, 4570 - 3777 psi Fluid to Recover: Sand in Zone: Sand in Csg: Avg Pressure: 769 bbls 39,900# 371# 4400 psi Date Mr. Randy Ruedrich ARCO Alaska, Inc. P.O. Box 360 Anchorage, Alaska 99510 September 3, 1987 Re: Our Boss GyroSC°PiC-Su~ve¥- Job No. AK-BO-7006~'_ Survey Date: ~AU~st 21~..-198~'/ Operator: D. Harger Mr. Ruedrich: - ~ Please find enclosed the "Original" and one (1) copy of our Boss Gyroscopic Survey on the above well. Thank you for giving us this opportunity to be of service. Sincerely, NL SPERRY-SUN, INC. Ken Broussard District Manager Enclosure NL Sperry-Sun/NL Industries, Inc. P.O. Box 190207, Anchorage, Alaska 99519-0207, Tel. (907) 522-1737 JK 300 400 '70O 1000 1 1 O0 ANL FI St RL I' [ ,';::d:Z ]:T I ON SF'E:RRf-SUH WElL VF I CAL /ERTI C~L DE;F' T'I' DEPTH bULIR..,,E [NCLINA],ELIN DEG M i N 7600 : :30',::; ,, 5884 .07 6 i ?2 ~ "" 5 0 D'[REZTI[ N N ': ~ E I0. 1 ~ H_-iRT ZO SF'ERR¥..,-'.E;I, II',I WEL L, O 6000 8000 I NT E RPBb~D~ r'R F SUB-SEA TOTAL VERT I:I'P~L VEF~TI CAE I:-:E Z TAN ~ _ [ Al:;' .... Z RE I i',1¢ DiE. i--' I t~ DEF']'H I',1 "IRT,Ul/~ Z' ] t :. ,:-,6 ,, 41 ':P:2::', 4,1 .:,, ::-. '.::.~4 /,~ ..... 1 :::::0/. ,- I/4 s; ,, ::E:O 6:3 ] . '2 ? I 212, ;;::S02 -?z~ 743E';, 74 ~ :3:E:O. 7,: ~ ::76.7'7 3200 :ii,(/ :: 1:36., 5(i 203 t 5',F; ' 522. !:>8 :::i:E:50,, 98 ~ I5 N 46:}]7. :':'7 4573.07 ~40ff:.. 13 N 722. 5;_::..z, i ~/5 52?7,75 408E: ~ ,':'::,0 :Oi' F:'F:':-IZT' _RFc: ARE BA.:,EE ON THE :FERRt-.:. II t4EI..L AUGUST 24~ ;1 NTE VER '1~ 5 (h%l_ VERTICAL REC-rANGULAR CO8[ DEP!ii DFi:PTH NORTH/9;OU'[~I ~ O0 7,'5d, O0 200. O0 0,, ,?i? N 400~ 00 N 6.00; OO 700,0() .... c.,,, N ,:')i) J. S(.)(), OO 2'77~ ""'=~:...., N (')(') :l 400 ,, OO :i:37 ':)'~, N l ........ 41 i ~ '-'= N 1264,, 1464 0; i . £NTffRF'~LATEB VALLE,:, ~ 2647 '2'2,',- o.z,7 Y 3' ?, · 0~ :" 0(] P,S::7. 275.6( ' "- '1 (~7(L. - ~:25.6,3 E 2400 ,. O0 12:E:9 ~ 68 ':f ~ ~ :., :., ,, 4[4.26 E ",:'¢~ ~ ¢',,~ iA'R:, 46,~,'2'9 E ?90( ,_, ~ :!7'P5,,42 N 4 .:AOG. 00 :1. 8'P:i}. 87 bt ':M 00. O0 I 'P':P4,. 8;i~m i:400 CiO 194 07 r,: 546. k '::, u. 40 560 36/} 4. C ~ ._ ~ ,t;,,U. ©0 SPERRY-SUN WE:II ;rI'q]'ERPOLJA~E~ VALUI.,~'"" ~70~'~u~ VEl::( i I. CP, /ERT t CAL I;)ii; I:':' i i ! I] E F'T H ] ] A L RE]2TANGULAF;, ]~ d-<[ .[ ',IAT N CiI::;:T H / F,i] I IT t : A'._:i;T / g!E .:,,x,t..) ,. oO .~t 7 _~. 44, N 446,4 ~ 7,5 o..r - ,,() Fi?A, ":vi?O0. O0 ~[~;F'ERFtY--E!;I IN .dEll RED · 566z!,,<0 56()C: 00 4.,:,.:,4...:7 ~,~ ._ e:,.4 _ 5700~ ()0 4-457. :i. - Bt 79.=,..:, 6264. O0 2,200,, O0 4867 ~ 34 ~.l 6::;,i:,~I ,, f';(-~ A 300,, O0 49'48 ~ E~2 lx~ "-"=;f-q 75 E ',36 0.0:2 :I JLA]' [ ON F:'Fi':?:i-EILIRiii;.'.i I::~E A I T NEAt:R THE NE¢,~ *,~:.:, t' ', dI) FROM ~:,t~ Ei:F'IZRIR¥-:Eii IN ~EI.._L. oUR I NT _RPULAIEI) VRLUEo F JR ..~FEL IAL D VE(R] II ~ I,~ ~ ,q F F']"H 5,0'3 F;97:3 6:32 :l 424 6360.70 4997.85 N 652( ::',y :,456, 39 5074,95 N Fb':':, 6. :368.02 I DE!:?IVEO JF; ti'4u FIll DEPT 'LUG B~ KLIF'ARI. I~ DEPTH '~' 9 00 Fl: [ 9::; 8%'67 6267,, ?5 6:~:2 'I. '-' "'1'11'112 PROi3F;,'A~ - c- .... FE..~R~ SUN THREE DI N r~,TERPO ATtON BY R ti: 0 iW ALIGLI:RT 24~ 1 .. ox 3[3 3000.00 ~500.00 85~8 7500.00 ;bOO. CO 3000.00 VER~ T EIqL PROJECT ARCO Alaska, Inc. Date: February 23, 1989 Transmittal #: 7432 RETURN TO: ARCO Alaska, Inc. Attn: Brenda K. Miernyk Kuparuk Records Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted herewith are the following items. Please acknowledge receipt and return one signed copy of this transmittal. 3 F- 1 5 Kupaurk Fluid Level Report I 2- 0 3 - 8 7 3 N - 1 8 Kupaurk Fluid Level Report I 2 - 1 8 - 8 7 3 F- 0 1 Kupaurk Fluid Level Report 8-29-87 3 F- 0 2 Kupaurk Fluid Level Report 8-29-87 3 F-09 Kupaurk Fluid Level Report 8-29-87 3 F- 0 6 Kupaurk Fluid Level Report 8-29-87 3 F-1 0 Kupaurk Fluid Level Report 8-29-87 3 F-1 1 Kupaurk Fluid Level Report 8-29-87 3 F-1 5 Kupaurk Fluid Level Report 8-29-87 3 F- 1 4 Kupaurk Fluid Level Report 8-29-87 3 N- 1 0 Kupaurk Fluid Level Report 5-18-87 3N-06 Kupaurk Fluid Level Report 5-22-87 3N-09 Kupaurk Fluid Level Report 5-21-87 31-0 1 Kupaurk Fluid Level Report 4-24-87 3 N- 1 1 Kupaurk Fluid Level Report 4-15-87 3 N- 1 4 Kupaurk Fluid Level RepOrt 4-13-87 3 F- 0 8 Kupaurk Fluid Level Report 4-14-87 3 N-01 Kupaurk Fluid Level Report 4-20-87 3 N - 1 4 Kupaurk Fluid Level Report I 2 - 0 4 - 8 7 3 F-1 5 Kupaurk Fluid Level Report 2-02-89 3 F-- 1 5 Kuparuk Well Pressure Report 8-27-87 3 F- 1 3 Kuparuk Well Pressure Report 8-27-87 3 F- 1 5 Bottom-Hole Pressure Survey 8-25-87 1 B- 0 5 Kuapruk Well Pressure Report 2-20-89 I E-25 Kuparuk Fluid Level Report 2-19-89 3 B- 1 1 Kupaurk Fluid Level Report 2-20-89 3A-03 Kupaurk Fluid Level Report 2-21-89 3 H-01 Kupaurk Fluid Level Report 2-21-89 2Z-1 9 Kupaurk Fluid Level Report 2-20-89 31-1 2 Kupaurk Fluid Level Report 2-20-89 1 E-08 Kupaurk Fluid Level Report 2-19-89 3 M- 1 8 Kupaurk Fluid Level Report 2-15-89 Casing Casing Tubing Tubing Tubing Tubing Tubing Tubing Tubing Tubing Casing Casing Casing Casing Casing Casing Casing Casing Casing Tubing Sand 'C' Sand 'C' BHP Amerada Casing Casing Casing Casing Tubing Tubin~ Casinl Casin[~ . C£i '~/ /C/2orogO c'uct~7iss/b' 3H-01 Kupaurk Fluid Level Report 2-15-89 Casing 3 B- 1 3 Kupaurk Fluid Level Report 2-17-89 Casing 1 E-29 Kupaurk Fluid Level Report 2-15-89 Casing 1 C-05 Kupaurk Fluid Level Report 2-18-89 Casing/Tubing 3 M- 1 7 Kupaurk Fluid Level Report 2-16-89 Casing 2Z- 2 0 Kupaurk Fluid Level Report 2-18-89 Tubing 30-10 Kupaurk Fluid Level Report 2-16-89 Casing 31-1 2 Kupaurk Fluid Level Report 2-20-89 Tubing 3 H - 1 0 BHP Report 2-13-89 BHP Receipt Acknowledged' - .......................... Date' - ........... DISTRIBUTION: D&M State of Alaska SAPC Unocal Mobil Chevron AI~~ Ancl~orag8 C°cq[~7is$io° ARCO Alaska, Inc. Date: February 17, 1989 Transmittal #: 7429 RETURN TO: ARCO Alaska, Inc. Attn: Brenda K. Miernyk Kuparuk Records Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted herewith are the following items. Please acknowledge receipt and return one signed copy of this transmittal. 3F-11 3H-12 30-07 3F-10 3F-06 3F-02 3F-16 3F-16 3F-11 3F-04 3F-05 3F-13 3N-10 3N-10 3N-04 3N-09 30-14 30-14 3M-18 3F-16 3F-13 3F-13 3F-13 3F-13 3F-08 3F-16 3F-16 3F-13 3F-16 3F-16 3F-16 3F-14 Sub-Surface Pressure Survey Ku~aruk Well Pressure Report Ku 3aruk Ku 3aruk Ku 3aruk Ku 3aruk Ku 3aruk Ku 3aruk Ku 3aruk Ku ~aruk Ku 3aruk Ku 3aruk Ku 3aruk Ku 3aruk Ku 3aruk Kuapruk Kuparuk Kuparuk Kuparuk Kuparuk Kuparuk Kuparuk Kuparuk Kuparuk Kuparuk Kuparuk Kuparuk Kuparuk Kuparuk Kuparuk Kuparuk Kuparuk I 0-0'6-88 8-29-88 Well Pressure Report I 2- 2 0 - 8 8 Well Pressure Report 8 - 2 9 - 8 7 Well Pressure Report 8 - 2 9 - 8 7 Well Pressure Report 8 - 2 9 - 8 9 Well Pressure Report 8 - 1 7 - 8 7 Well Pressure Report 8 - 1 7 - 8 7 Well Pressure Report 8 - 2 9 - 8 7 Well Pressure Report 6 - 2 6 - 8 7 Well Pressure Report 1 2 - 1 2 - 8 8 Well Pressure Report I 2 - 31 - 8 8 Well Pressure Report 6 - 1 I - 8 7 Well Pressure Report 6 - 1 1 - 8 7 Well Pressure Report 9 - 01 - 8 7 Fluid Level Report 5 - 0 4 - 8 7 Fluid Level Report 2- 1 3 - 8 9 Fluid Level Report 2 - 1 0 - 8 9 Fluid Level Report 2 - 1 0 - 8 9 Fluid Level Report 6 - 0 5 - 8 7 Fluid Level Report 6 - 0 9 - 8 7 Fluid Level Report 6 - 1 8 - 8 7 Fluid Level Report 6 - 1 6 - 8 7 Fluid Level Report 6 - 21 - 8 7 Fluid Level Report 5 - 0 8 - 8 7 Fluid Level Report 8 - 1 8 - 8 7 Fluid Level Report 8 - 2 4 - 8 7 Fluid Level Report 6 - 0 5 - 8 7 Fluid Level Report 6 - 2/3 - 8 7 Fluid Level Report 8 - 5 - 8 7 Fluid Level Report 6 - 5 - 8 7 Fluid Level Report 9 - 8 - 8 7 #7-889 Amerada Sand 'A' Amerada Amerada Amerada Sand 'A' Sand 'A' Amerada Sand 'A' Both Sands Both Sands Sand 'A' Casing Casing Casing Casing Tubing Casing Casing Casin~'~ R ~1~. ~' ,~ Cas!n '-/- Casing ~chorage Tubing Casing Casing 3F-14 3F-06 3F-14 3F-08 3F-14 3F-09 3F-05 3F-09 3F-06 3F-05 3N-10 3N-10 3N-11 3N-10 3N-05 3N-04 3N-13 3N-11 3N-18 3N-17 3N-07 3N-15 3N-05 3N-09 3N-04 3N-14 3N-08 3N-06 3N-02 3N-10 3N-10 3N-10 3N-10 3N-10 3N-10 3N-10 3N-07 3N-01 3N-04 3N-04 3N-09 3N-10 Receipt Kuparuk Kuparuk Ku )aruk Ku 3aruk Ku 3aruk Ku 3aruk Ku 3aruk Ku3aruk Ku3aruk Kuparuk Kuparuk Kuparuk Kuparuk Kuparuk Kuparuk Kuparuk Kuparuk Kuparuk Kuparuk Kuparuk Kuparuk Kuparuk Kuparuk Kuparuk Kuparuk Kuparuk Kuparuk Kuparuk Kuparuk Kuparuk Kuparuk Kuparuk Kuparuk Kuparuk Kuparuk Kuparuk Kuparuk Kuparuk Kuparuk Kuparuk Kuparuk Kuparuk Fluid Fluid Fluid Fluid Fluid Fluid Fluid Fluid Fluid Fluid Fluid Fluid Fluid Fluid Fluid Fluid Fluid Fluid Fluid Fluid Fluid Fluid Fluid Fluid Fluid Fluid Fluid Fluid Fluid Fluid Fluid Fluid Fluid Fluid Fluid Fluid Fluid Fluid Fluid Fluid Fluid Fluid Acknowledged: Level Report 9- 1 I - 87 Level Report I 2 - 0 6 - 86 Level Report 9 - 1 I - 87 Level Report I 0 - 1 I - 87 Level Report 9 - 1 6 - 87 Level Report 4 - 1 1 - 88 Level Report 4 - 0 8 - 88 Leyel Report 4- 01 - 88 Level Report 3 - 2 6 - 88 Level Report 1 - 3 0 - 88 Level Report I 0 - 1 2 - 87 Level Report I 0 - 1 5 - 87 Level Report I 0 - 28 - 87 Level Report 1 0 - 28 - 87 Level Report I 0 - 2 8 - 87 Level Report 10 - 2 8 - 87 Level Report 3- 1 9 - 87 Level Report 9 - 1 2 - 87 Level Report 9 - 1 0 - 98 Level Report 9 - 1 0 - 87 Level Report 9 - 1 0 - 87 Level Report 9- 1 2 - 87 Level Report 9- 0 8 - 87 Level Report 9 - 01 - 87 Level Report 9 - 01 - 87 Level Report 9 - 0 6 - 87 Level Report 9 - 0 6 - 87 Level Report 9 - 0 6 - 87 Level Report 9 - 0 6 - 87 Level Report 6 - 01 - 87 Level Report 5 - 31 - 87 Level Report 6 - 03 - 87 Level Report 6 - 0 6 - 87 Level Report .6 - 0 8 - 87 Level Report 6 - 0 9 - 87 Level Report 6 - 2 5 - 87 Level Report 4 - 1 7 - 87 Level Report 4 - 1 8 - 87 Level Report 6 - 1 7 - 87 Level Report 6 - 2 0 - 87 Level Report 5 - 0 7 - 87 Level Report 8 - 24 o 87 ........................... Date: casing Tubing Casing Tubing Casing Casing Casing Casing Casing Casing Casing Casing Tubing Tubing Tubing Tubing Tubing Tubing Tubing Tubing Tubing Tubing Tubing Tubing Tubing Tubing Tubing Tubing Tubing Casing Casing Casing Casing Casing Casing Casing Casing Casing Alaska Oil & G3s Cons. Ccmm, jssJoi., ....... AwC~orage DISTRIBUTION: D&M State of Alaska - Mobil Chevron Unocal SAPC ARCO Alaska, In( Pos! Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 Date: September 22, 1987 Transmittal #: 6062 RETURN TO: ARCO Alaska, inc. Attn: Kuparuk Records Clerk ATO-1119 P.O. BoX 100360 Anchorage, AK 99510~0360 Transmitted herewith are the following items. Please acknowledge receipt and return one signed copy of this transmittal. 3C-1 31-1 1R-4 1R-6 3C-14 31-5 3M-16 3M-18 3M-19 · PBU Bottomhole Pressure Survey 'A' Sand Static BHP Bottomhole Pressure Survey Static BHP Bottomhole Pressure Survey 'A' Sand Static BHP Bottomhole Pressure Survey 'A' Sand PBU Bottomhole Pressure Survey 8-15-87 8-27-87 8-20-87 8-21-87 8-16-87 Kuparuk Well Pressure Report(Otis) 8-20-87 Kuparuk Well Pressure Report(Otis) Static 'C' Sand Kuparuk Well Pressure Report (Otis) Static Kuparuk Well Pressure Report (Otis) 50-029-21413 50-029-21407 50-029-21331 50-029-21425 9-7-87 9-14-87 9-14-87 Receipt Acknowledged: DISTRIBUTION: D&M State of Alaska BPAE Chevron Mobil SAPC Unocal ARCO Alaska, Inc. is a Subsidiary of AtlanticRIchfleldCompany ARCO Alaska, In'"' Posl Office dox 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 Date: September 10, 1987 Transmittal #6051 RETURN TO: ARCO Alaska, Inc. Attn: Kuparuk Records Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted herewith are the following items. Please acknowledge receipt and return one s~gned copy of this transmittal. 3M-15 Cement Bond Log 8-3-87 5381-7397 3M-17 Cement Bond Log 8-5-87 6200-8564 3M-19 Cement Bond Log 8-10-87 6500-8794 3M-22 Cement Bond Log 8-12-87 7890-9598 3M-18 Cement Bond Log 8-21-87 7689-8410 3M-14 Cement Bond Log 8-2-87 4903-7108 3M-13 Cement Bond Log 8-3-87 7495-9559 3M-20 Cement Bond Log 9-1-87 8700-10687 3M-11 Cement Bond'Log 8-1-87 5252-7802 3M-16 Cement Bond Log 8-4-87 -7834 3M-lO Cement Bond Log~ 8-9-87 4700-7039 3M-12 Cement Bond Log(Coiled Tubing Conveyed) 8-12, 13-87 7403-10380 Receipt~Acknowledged: DISTRIBUTION: NSK Dri State of Alaska(+sepia) Vault(film) ARCO Alaska, Inc. is a sUbsidiary of AtlanticRIchfleldCompany STATE OF ALASKA -~" ~''' AL~,,.,XA OIL AND GAS CONSERVATION CO .,SION REPORT OF SUNDRY WELL OPERATIONS 1. OperatiOns performed: Operation shutdown [] Stimulate [] Plugging ~ Perforate~l~ Pull tubing [] Alter Casing [] OtherX~ COMPLETE 2. Name of Operator 5. Datum elevation (DF or KB) ARCO Alaska, Inc. RKB 64' 3. AddreSs 6. Unit or Property name P.O. Box 100360 Anchorage, AK 99510-0360 Kuparuk River Unit 4. Location of well at surface 858' FNL, 1559' FEL, 5ec.25, T13N, R8E, UN At top of productive interval 1273' FNL, 693' FEL, 5ec.24, T13N, R8E, UN At effective depth 1134' FNL, 686' FEL, $ec.24, T13N, R8E, UN At total depth 1063' FNL~ 682' FEL~ 5ec.24~ T13N~ R8Et UN 7. Well number 3M-18 8. Approval number 7-462 9. APl number 50-- 029-21730 10. Pool Kuparuk River Oil Pool 11. Present well condition summary Total depth: measured 8523' MD true vertical 6520 ' TVD Effective depth: measured 8410 'MD true vertical 6433 ' TVD Casing Length Size Conductor 80 ' 16" Surface 4258' 9-5/8" Production 8505' 7" feet feet feet feet Plugs (measured) None Junk (measured) None Cemented 208 sx CS II 1500 sx CS Iii & 500 sx Class G 400 sx Class G & 175 sx AS I Measured depth 115'MD 4295'MD 8505'MD Feet Date Submit in Duplicat~ True Vertical depth llS'TVD 2787 ' TVD 6507'TVD 12. Perforation depth: measured 8204'-8238'MD true vertical 6273 ' -6299 ' TVD Tubing (size, grade and measured depth) 2-7/8", J-55, tubing w/tail ~ 8120' Packers and SSSV (type and measured depth) HRP pkr ~ 8089' & TRDP-1A-55A 5S5V ~ 1798' Stimulation or cement squeeze summary N/A Intervals treated (measured) Treatment description including volumes used and final pressure 13. N/A Prior to well operation Subsequent to operation Representative Daily Average Production or Iniection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure 14. Attachments (Completion Wel 1 Hi sto_~y) Daily Report of Well Operations L_~ Copies of Logs and Surveys Run ~ G,yro 15. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed Form 10-404 Rev. 12-1-85 Title Associate Engineer (Dani) SW02/78 ARCO Oil and '~sCompany ~ DailvWeiiHistory-FinaIReport Dcstnct Alaska Accountmg cos1 center code ............................ Coun:y or Parish S:ate North Slope Borough Alaska I07~,~ ..... I ...... ADL 25522 3M-18 Completion Kuparuk River Auth. or W.O no. AFE AK2181 Nordic f)l Operator ARCO Alaska, Inc. Spudded or WO. begun Complete Date and depth as of 8:O0 a.m. 8/20/87 8/21/87 8/22/87 thru 8/23/87 AP1 50-029-21730 IAR Co W I 56.24% Date 8/19/87 Iotal number of wells (active or machve) on this cst center prior to pluggmg and bandonment of this well our -- ~ Prior status if a W,O, 1200 hrs. 1 Complete record for each day reported ND tree, NU & tst BOPE. RIH , DO cmt. 7" @ 8505' 7988' PBTD, Drlg cmt 10.0 ppg NaC1/NaBr Accept rig @ 1200 hrs, 8/19/87. w/BHA on 3½" DP, tag TOC @ 7900' , CBU, TOH. PU 7" csg scrpr 7" @ 8505' 8410' PBTD, TIH w/csg scrpr 10.0 ppg NaC1/NaBr Drl cmt inside 7" csg f/7900'-8410' & TIH. 7" @ 8505' 8410' PBTD, RR 10.0 ppg NaCl/NaBr RIH w/bit & csg scrpr, tst csg to 3500 psi; OK. Displ well to cln brine, POOH. RU Gearhart, rn CBL f/8417' WLM to 7700'~,~.P¢~, gyro f/PBTD to surf. Perf @ 12 SPF, 120 phas~¢ ~ ~ ~ f/8204'-8238'. RU & rn 245 jts, 2-7/8", 6.5#, _~.~i~'*~R~ Mod tbg w/SSSV @ 1798', HRP Pkr @ 8089', TT @ 81~0~ Set pkr , Tst tbg/ann; OK. ND BOPE, NU & tst tree. Displ well. t~ d.~e~.~ RR @ 2400 hrs, 8/22/87. !;~. '~': ~ Old TD New TD PB Depth 8410' PBTD Released ng Date Kind of rig 2400 hrs. 8/22/87 Rotary C~assifications (oil, gas. etc.) 1 Type completion (stogie, dual, etc) 0il I Single Producing method ]Officia~ reservoir name(s) Flowing / Kuparuk Sands Potenda~ test data _ Well no. Date Reservoir Producing Interval Oil or gas Test time Production Oil on test -- Pump size, SPM X length Choke size T.P. C,P. Water % GOR Gravity Allowable corrected ____ The above is correct For form preparation and distribution, see Procedures Manual, Section 10, Drilling, Pages 86 and 87. Drilling Superintendent AR3B-459-3-C Number ali daily well history forms consecutively / Page no. as they are prepared for each well. Division of AllnntlcRIchfleldOompany ARCO Alaska, Inc. Post Offic( x 100360 Anchorage, ,-~aska 99510-0360 Telephone 907 276 1215 Date:July 22, 1987 Transmittal #6005 RETURN TO: ARCO Alaska, Inc. Attn: Kuparuk Records Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted herewith are the following items. Please acknowledge receipt and return, one signed copy of this transmittal. X--3M_20 7-9-87 974-11068 --~3M-20 7-9-87 10200-10670 "'3M-20 7-9-87 974-10776 '-3M-20 7-9-87 10200-10750 '-3M-20 7-9-87 10200-10750 '"3M-20 7-9-87 10200-110420 M-20 7-9-87 10200-11042 16 7-11-87 6000-7916 --3M-16 7'11-87 7350-7870 -- 3M-16 7-11-87 6000-7916 ---3M-16 7-11-87 6000-7916 ___~--3M-16,'~ 7-11-87 7350-7936 --3M-16 7-11-87 6000-7916 ---3M-16 7-11-87 1000-7942 ---3M-16 7-11-87 6000-7916 -- 3M-16 7-11-87 1000-7942 ~ 6-24-87 1000-8510 -~3M-18 6-24-87 4800-8484 -- 3M- -- 3M- --3M- --3M- -~ 3M- -i~ ~" 3M- ~- 3M- "- 3M- --3M- 18 ,~ 18 18 18 18 17 17 17 17 17 5" DIL Cyberlook 2" DIL 2" Porosity FDC 2" Raw Data FDC 5" Raw (+1.2") FDC 5" Porosity FDC 5" Porosity FDC Cyberlook 2" Raw Data FDC 5" Raw Data FDC 5" Dual Dipmeter High Resolution FDC 5" DIL 2" Porosity FDC 2" DIL 2" DIL 5" Raw Data FDC 2" Porosity FDC Cyberlook 5" DIL 5" Porosity FDC 2" Raw Data FDC Cyberlook 2" Raw Data FDC 2" Porosity FDC 5" Raw Data FDC 5" Porosity FDC 6-24-87 4800-8484 6-24-87 8000-8440 6-24-87 1000-8510 6-24-87 4800-8484. 6-24-87 4800-8484 6-30-87 6-30-87 8150-8666 Receipt Acknowledged: DISTRIBUTION: NSK 6-30-87 -~ .~.~8150- 666 6-30-87 ~.~~8Ce: a 0il & ~as ConS. Commission Anchorage Drilling Rathmell D & M State of Alaska (+sepia) Vault (film) ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany ARCO Alaska, Inc. Post OfficF'~- x 100360 Anchorage, ..,aska 99510-0360 Telephone 907 276 1215 Date: July 22, 1987 Transmittal #6005 RETURN TO: ARCO Alaska, Inc. Attn: Kuparuk Records Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted herewith are the following items. Please acknowledge receipt and return one signed copy of this transmittal. N--3M_17 A, 5" Dual Induction 6-30-87 4325-8692 ---3M-17 2" Dual Induction 6-30-87 4325-8692 ~ 2" Dual Induction 6-19-87 3488-7590 ----3M-15 2" Raw Data FDC 6-19-87 3488-7564 ~ ~ ~-3M-15 5" Raw Data FDC 6-19-87 3488-7564 -'-3M-15 ,, 5" Porosity FDC 6-19-87 3488-7564 '~-~3M-15 2" Porosity FDC 6-19-87 3488-7564 ---3M-15 5" Dual Induction 6-19-87 3488-7590 --3M-15 Cyberlook 6-19-87 Receipt Acknowledged: DISTRIBUTION: NSK Drilling State of Alaska(~ sepia) Cons. Commission "Rat~ell .D & M Vault (fi~) ARCO Alaska, Inc. is a Subsidiary of AllanlicRichfieldCompany ARCO Alaska, Inc.... Post Office- ,, 100360 Anchorage..laska 99510-0360 Telephone 907 276 1215 Date: July 22, 1987 Transmittal # 6003 RETURN TO: ARCO Alaska, Inc. Attn: Kuparuk Records Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 ~ransmitted herewith are the following items. Please acknowledge ~receipt and retur~ one signed copy of this transmittal. 3M-15 OH Lis Tapes 6-19-87 #72365 3M-16 OH Lis Tapes 6-11-87 #72361 3M-13 OH Lis Tapes 5-28=87 #72348 3M-17 OH Lis Tapes 6-30-87 #72405 3M-18 OH Lis Tapes 6-24-87 #72375 3M-14 OH Lis Tapes 6-4-87 #72353 3M-12 OH Lis Tapes 5-21-87 #72329 Receipt Acknowledged: DISTRIBUTION: M. Stanford ~"~'State of Alaska"i ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany STATE OF ALASKA '~ ALA...,A OIL AND GAS CONSERVATION CON..,~,.,,SION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon [] Suspend [] Operation Shutdown I~ Re-enter suspended well © Alter casing ~ Time extension [] Change approved program ~ Plugging [] Stimulate [] Pull tubing [] Amend order ~ Perforate i~ Other 2. Name of Operator ARCO Alaska, Inc 5. Datum elevation (DF or KB) 3. Address Po 0o Box 100:360 Anchorage, AK 99510-0360 4. Location of well at surface 858' FNL, 1559' FEL, Sec.25, At top of productive interval 1 354 ' FNL, At effective depth 1451' FNL, 721' FEL, 5ec.24, T13N, R8E, UN At total depth 1058' FNL, 703' FEL, Sec.24, T13N, R8E~ UM 8523 ' MD feet 6519' TVD feet TI:3N, R8E, UM 797' FEL, 5ec.24, T13N, R8E, UM (approx) 11. Present well condition summary Total depth: measured true vertical (approx) (approx) Plugs(measured) RKB 64 ' 6. Unit or Property name Kuparuk River Unit 7. Well number 3M-18 8. Permit number 9. APl number 50-- O29-717%0 10. Pool Kuparuk River Oil Pool None Effective depth: measured 7900 'MD feet true vertical feet 6.035 ' TVD Casing Length Size Conductor 80 ' 1 6" Surface 4258 ' 9-5/8" P roducti on 8505 ' 7" Junk (measured) None Cemented 208 sx CS II 1500 sx CS III 500 sx Class C 400 sx Class G Measured depth 115'MD 4295'MD 8505'MD True Vertical depth 115'TVD 3413'TVD 6505'TVD Perforation depth: measured None true vertical N o n e ~bing(size, grade and measured depth) None Packers and SSSV(type and measured depth) None 12.Attachments WELL HISTORY Description summary of proposal .~ Detailed operations program ~ BOP sketch 13. Estimated date for commencing operation August, 1987 14. If proposal was verbally approved Name of approver Date approved 15. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed ~ ~~].~4j~,, Title As socia te Engineer ~ Commission Use Only (Dani) ~A?/71 approval Notify commission so representative may witness I Conditions of Approval No. [] Plug integrity [] BOP Test_ [] Location clearanceI Approved b~~ ~ ~ ' ~ ..... Date by order of Commissioner the commission Date Form 10-403 Rev 12-1-85 Submit in triplicate ARCO Oil and Gas Company Well History - Initial Report- Daily Inel~'.,ctions: Prepare and submit the "Initial Report" on the first Wednesday after a well is spudded or workover operations are started. Daily work prior to spudding should be summarized on the form giving inclusive dates only. District Alaska Field Kuparuk River Auth. or W.O. no. AFE AK218i Doyon 9 Operator ARCO Alaska, Inc. Spudded or W.O. begun Spudded ICounty, parish or borough North Slope Borough Lease or Unit ADL 25522 Title Drill AP1 50-029-21730 IState IDate 6/20/87 ]Hour Complete record for each day reported 6/21187 thru 6/22/87 6/23/87 6/24/87 Alaska lWell no. 3M-18 0930 hrs. IARCO W.I. Prior status if a W.O. 56.24% 6/25/87 Date and depth as of 8:00 a.m. The above is correct Fo~ fo?~ p'~eparation and d~tribution, see Procedures Manual, Section 10, Drilling, Pages 86 and 87. 16" @ 115' - 9-5/8" @ 4295' 4315', (4200'), Prep to cmt 9-5/8" Wt. 9.5, PV 24, YP 20, PH 9.0, WL 8.8, Sol 8 Wt. 9.5, PV 24, YP 20, PH 9.0, WL 8.8, Sol 8 Accept rig @ 0800 hfs, 6/20/87. NU diverter sys. Spud well @ 0930 hfs, 6/20/87. Drl 12¼" hole to 4315', 15 std short trip, CBU, POOH. RU & rn 99 its, 9-5/8", 36#, J-55 BTC csg w/FS @ 4295'. RU & prep to cmt. 518', 4.7° 1070', 22.8° 1438', 32.0° 1877', 44.2° 2440', 45.0° 3573', 45.1° 4215', 44.8° , N23.8E, 517.85 TVD, 7.06 VS, 6.68N, 2.95E , N25.3E, 1052.09 TVD, 129.44 VS, 120.40N, 67.16E , N16.9E, 1376.72 TVD, 297.61VS, 280.32N, 132.03E , N10.4E, 1721.93 TVD, 566.44 VS, 541.68N, 200.28E , N15.2E, 2122.80 TVD, 960.91VS, 927.17N, 287.81E , N13.3E, 2905.93 TVD, 1778.07 VS, 1726.13N, 466.76E , N 7.7E, 3356.24 TVD, 2235.52 VS, 2177.83N, 539.12E 9-5/8".@ 4295' 6571', (2256'), Drlg Wt. 9.2, PV 8, YP 5, PH 9.0, WL 9.4, Sol 7 Cmt 9-5/8" w/1500 sx CS III & 500 sx C1 "G" w/2% A-7 & 2 GHS D-6L. Displ w/wtr & bump plug. ND diverter. NU & tst BOPE. RIH w/8½" BHA, tag FC @ 4207', tst csg to 2000 psi. DO flt equip, cmt & 10' new formation. Conduct formation tst to 12.5 ppg EMW. Drl 8½" hole to 6571'. 4803', 44.3°, N7.3E, 3775.27 TVD, 2647.87 VS, 2586.80N, 592.96E 5369', 43.7°, N5.SE, 4182.42 TVD, 3040.67 VS, 2977.41N, 637.81E 5933', 43.5°, N9.9E, 4590.85 TVD, 3429.53 VS, 3362.71N, 690.93E 9-5/8" 8523', Wt. 10. Drl to 6498', 7630', 8523', @ 4295' (1952'), Short trip 0, PV 15, YP 7, PH 8.5, WL 4.2, Sol 11 8523' TD, CBU, short trip to 4295'. 43.7°, N9.4E, 5000.01TVD, 3819.14 VS, 3746.83N, 756.24E 40.7°, N2.3E, 5828.47 TVD, 4588.61VS, 4514.11N, 830.88E 38.8°, N2.6E, 6518.97 TVD, 5151.24 VS, 5079.77N, 856.42E 9-5/8" @ 4295' 8523', (0'), Rn 7" csg Wt. 10.0, PV 14, YP 6, PH 8.5, WL 4.4, Sol 11 Short trip, CBU, POOH· RU Schl, rn DIL/GR/SP/SFL/FDC/CNL/CAL f/8000'-8518'. Rn FDC/CNL f/4800'-5000', RD Schl. TIH to 8300', rm to 8523', circ POOH· LD DP. RU & rn 7" csg ~. ~ 8523' 38.8° N2.6E, 6518 97 TVD, 5151 24 VS, 5079.77N, Date J Title Drilling Supervisor ARCO Oil and Gas Company Daily We,i History-Final Report Instructions: Prepare and submit the "Final Report" on the first Wednesday after allowable has been assigned or well is Plugged, Abandoned, or Sold. "Final Report" should be submitted also when operations are suspended for an indefinite or appreciable length of time. On workovers when an official test is not required upon completion, report completion and representative test data in blocks provided. The "Final Report" form may be used for reporting the entire operation if space is available. Accounting cost center code District ~County or Parish State Alaska I North Slope Borough Alaska Field ILease or Unit IWell no. Kuparuk River ADL 25522 3M-t8 Auth. or W.O. no. ~Title AFE AK2181 I Drill Doyen 9 Operator A.R.Co. ARCO Alaska, Inc. Spudded or w,O.spuddedbegun Date Date and depth Complete record for each day reported as of 8:00 a.m. 6/26/87 API 50-029-21730 W.I. [Total number of wells (active or inactive) on thisI Icost center prior to plugging and I 56.24% labandonment of this well IHour IPrlor status if a W.O, 6/20/87 / 0930 hrs. I 7" @ 8505' 8523' TD, 7900' PBTD, RR 10.0 ppg NaC1 Brine Rn 197 its, 26#, J-55 BTC csg w/FC @ 8416', FS @ 8505', Mkr Jt @ 8115', Pkr @ 8110'. Cmt w/100 sx C1 "G" w/2% A-2, 1.0% R-7 & 2 GHS FP-SL & 200 sx C1 "G" w/l% FL-19, .5% CD-31, .3% A-2, 1 GHS FP-61 & 100 sx C1 "G" w/l% FL-19, .5% CD-31, .3% A-2 & 1 GHS FP-61. ND BOPE. NU & tst tree to 5000 psi. RR @ 2230 hrs, 6/25/87. Old TD New TD Released rig Date 2230 hrs. Classifications (oil, gas, etc.) Oil J PB Depth 8523' TD IKind of rig 6/25/87 I Type completion (single, dual, etc.) Single Producing method Official reservoir name(s) Flowing Kuparuk Sands Potential test data 7900' PBTD Rotary Well no. Date Reservoir Producing Interval Oil or gas Test time Production Oil on test Gas per day Pump size, SPM X length Choke size T.P. C.P. Water % GOR Gravity Allowable Effective date corrected The above is correct For form preparation and distribution, see Procedures Manual, Section 10, Drilling, Pages 86 and 87. Date ! / ITitle I Drilling Supervisor ARCO Alaska, Inc.t Post Office Box' 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 june 29, 1987 Mr. C. V. Chatterton Commi ssi oner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT: Conductor As-Built Location Plat - 3M Pad (Wells 1-22) Dear Mr. Chatterton' Enclosed is an as-built location plat for the subject wells. you have any questions, please call me at 263-4944. If Sincerely, Gruber Associate Engineer JG/pk GRU1/31 Enclosure Al;:tsk,-:t Oil & Gas Cons. Anchor~,,fJ~ ARCO Alaska, Inc. is a subsidiary o! AilanticRichfieldC°mpanY ~. ¥1¢INI. T¥ MAP s~ ~ · ~,~s NOTES: I. ALL C~RDINATES ARE A.S~., Z~E 4. ~.~ D,smAN=s ~~ ~; TRUE. ALL WELLS LOCATED IN SEC. 25, TI:SN, R8E, UMIAT MERIDIAN. :5.EI. EVATIONS ARE B.P. Id.S.L. 4.REF. FIELD BOOK L87-$, POL 7-14 LIT-I, P.'r; LS/-$,PSI-5:5; $.0.G. ELEVAT'ONS FROM F.R. BELL · ASSOCIATES. 6.HORIZONTAL POSITIONS BASED ON :sM ~~:,. i"~: ~ ~'~ MONUMENTS PER LHD ~ ASSOCIATES. ASPs 'X' LATITUDE 70~2 6,016,225. I0 506,156.45 6,016,248.21 506,145.98 6~016,271.1:4 506,155.57 6,016,1:94.28 6,016,$17.42 506,174.6:5 6,016,$40.48 6,016,$65.49 $C)6,t95.52 6,016,$86.92 506,205.14 6,016,456-1:5 506 6 ,016 ,479.22 506,241.52 6,016 506,251.07 6,016 506,260.73 6,016,548.6Z 506,Z70.~0 6,016,571.45 $06,1:'79.?? $,016,594.T$ 6,016,617.99 506,1:99.05 6 ,016 ,641.02 506,308.?6 7' 20.459 LONGITUDE 149°5 i6'58.$16 I0 19 16 26 7002 905 97:5 1607 I.Z 26.3 ~,oo~:~3., o~ ~5o: ,~98' ~,.,: ~.4'. 70027, 23.4 I0 927, 1586 20.9, E6.4, 7~27 23.639 904, 1578' 70027'23.868 881 1569 ~0.9 ~6.S 7~7'24.094 14~56'54.647 858* 1559 20-80 ~6.6' 7~'Z7'/~. 5~ /~f'57'~.~6/' ~,,/,, ,,,.77 ,0,./,7.,, 7,',7',9.323 /'e''7'D'."t 4~ '"E~Y CERTIFY T~T' AM PROPERLY J ARCO Alaska I~. TICE L~D ~RVEYING IN ~E ~ OF AL~ta STATE OF ~KA AND T~T THIS ~ ~ .,~e~,eo- ~e . PLAT REPRESENTS A ~ATION ~x~ .0" I "~ '; ~II- · --. · M, S~/RVlS'~, AND THAT ALL ~.~~,.Z~.--'--' S WELL CONDUCTOR AS-BUILT DIM~SIONS AND O~ER ~TAIL5 ARE ~RRECT ~S OF '/8/87 [~~.~ '-- ~-- Jun~e 3, 1987 Mr. J. B. Kewin Regional Drilling Engineer ARCO Alaska, Inc. P. O. Box 100360 Anchorage, Alaska 99510-0360 Telecopy: (907) 276-7542 Re: Kuparuk River Unit 3M-!8 ARCO Alaska, Inc. Permit No. 87-55 Sur. Loc. 858'FNL, 1559'FEL, Sec. 25, T13N, R8E, U~. Btmhole Loc. l158'FNL, 766'FEL, Sec. 24, T13N, R8E, UM. Dear Mr. Kewin: Enclosed is the approved application for permit to drill the above referenced well. The permit to drill does not indemnify you from the probable need to obtain additional permits required by law from other governmental agencies prior to commencing operations at the well site. To aid us in scheduling field work, please notify this office 24 hours prior to commencing installation of the blowout prevention equipment so that a representative of the Commission may be present to witness testing of the equipment before the surface casing shoe is drilled. Where a diverter system is required, please also notify this office 24 hours prior to commencing equipment installation so that the Commission may witness testing before drilling below the shoe of the conductor pipe. Chairman of Alaska Oil and Gas Conservation Commission BY ORDER OF THE COMMISSION dlf Enclosure CC: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. Mr. Doug L. Lowery "-"'" STATE OF ALASKA ALASKA OIL/,ND GAS CONSERVATION CO,,,,v,,oSlON PERMIT TO DRILL 20 AAC 25.005 Re-Entry Deepen Service [] Developement Gas [] Single Zone/~ Multiple Zone [] 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool ARCO Alaska, Inc. RKB 64', PAD 27' feet Kuparuk River Field Kuparuk River Oil Pool 3. Address 6. Property Desiclnation P.0. Box 100360 Anchorage, AK 99510-0360 ADL 25522 ALK 2558 4. Location of well at surface 7. Unit or property Name 11. Type Bond(see 20 AAC 25.025) 858'FNL, 1559'FEL, Sec.25, T13N, R8E, UN Kuparuk River Unit Statewide At top of productive interval 8. Well number Number 1354,FNL- 797,FEL, Sec.24, T13N, R8E, UM 3M-18 . #8088.26_27 At total depth 9. Approximate spud date Amount 1158'FNL, 766'FEL, Sec.24, T13N, RSE, UM 06/21/87 $500,000 12. Distance to nearest 13. Distance to nearest well 14. Number of acres in property 15. Proposed depth(MD and TVD) property line 3M-1 7 8437 'MD 766'@ TD feet 25' ~ Surface feet 2560 (6509'TVD) feet 1'6. To be completed for deviated wells 17. Anticipated pressure (see 2o AAC 25.035 (e)(2)) Kickoff depth400 feet Maximum hole angle 44 0 Maximum surface 2023 psig At total depth 0'VD) 3180 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) 24" 16" 62.5# H-40 Weld 80' 35' 35' 115' 115' +200 cf 12-1/4' 9-5/8" 36.0# J-55 BTC 4156' 35' 35' 4191' 3418' 1500 sx AS III & HF-EFW 500 sx Class G blend 8-1/2" 7" 26.0# J-55 BTC 8403' 34' 34' 8437' 6509' 200 sx Class G(minimum HF-EFW TOC 5)0' abov., top of Kuparuk 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured feet Plugs (measured) true vertical feet Effective depth: measured feet Junk (measured) true vertical feet Casing Length Size Cemented Measured depth True Vertical depth Structural Conductor Surface Intermediate Production tV';,-'~(1 1987 Liner Perforation depth: measured Aias!(a 0ii & true vertical 20. Attachments Fill,rig fee'S' Property plat [] BOP Sketch ~ Diverter Sketch/~_ Drilling program J~ V Drilling fluid program (~ Time'vs depth plot [] Refraction analy~sis [] Seabed report [] 20 AAC25.050 requirements 21. I hereby ~'~,?that the fo~o~ true a, nd correct to the best of my knowledgesigned ---- '/ -" ' '" '~'~ Title Reg~ onal Dr~ 1 1 ~ ng E / ,,/,(Z._ .~..~_z~/~¢,/.~~" ' ' ' ngineer Dat L,/" ~ u/ ..... Commission Use Only (HRE) PD2/29 /' / Permit Number_ J APl number ,~ J Approval date J See cover letter I 50- o _ i 7 I06 / 03 / 87 I for other requirements Conditions of approval Samples required [] Yes '~No Mud log required Lq Yes Hydrogen sulfide measures [] Yes [] No Directidnal survey required ',.,~.' Yes [] No" R equiredwork~/~~___~SM; [] 5M; [] 10M; E~ 15M Other: by order of Approved by ~,,_~',,,/', f '///'~/~'~ Commissioner the commission Date Form 10-401 Rev. 12-1-85 n triplicate '- ............. ~-~'-~'?~--~-?-*-~ ................ ~'-;'~ ............~:-; ............ ; ............ ~-~" ~-~ ' ...... ;-"¥_;_~;;;-';;;.5_;.'~;;;_~z.';"7-;/';'.:.' ;~.i;~; ;.;. ;_ ........ .......... *-~__.~-~ .......... .... ~...~ ..... ........ ~--~" -~' ~ --~'-~ ................... ~ ....... ~ ......... ~ ~ ' ; = ' , ~ ~ '. i ~ ~ ' ~-'-v ~i I- = : ~ ; ~ f~; / [ ....... ~ ........ ~?~ r~ -t-+-.t .... ~_._~._~ ............... ~ .... d ~ .. ;'-~ ,,~ ; , ~.-~ ~-~ . ........... t ......... ; .......... = ' ~ ' ' ' ~ ' * ~ ~ . ~ ; .. ~_ 7-'. ...... ~ --~ -- ......... ~ ......... ._:_~:_.~ ..... ~ ..... ;_~_~ ...... ~ ..... ~_.~_:_~.__~_.~__¥_¥. ........... : , ..... ~ ~ ~ ~'.. ' . ~ ; ~ z .... ~_~_~._~ ..... ;._..~___;__~.~ ....... ~_ ', , .~-.~-.~_ ~ ...... ~..~ ~____~ ............. ~ ........ ~__~... ..... ~.~_.~.~_ ..... ~ ..... ~__~ .....~?~:~:~-~:~':'::-.:' :-:-+ :-::: , , ......... .......... ; ........ ~ ....... ~-~---~ ~ ~ -~ ........ ; ................. ~ ...... ~-~-: .... ~'-~ ......... ~ ....... i ..... ~ ......................... x ....... ~-~ ........ ~-:- ........... ~": ........................................ ~ ..... ~' ' I '~ ........ ~:'I-~-~T':": .... :--: .......... ~'-': ....... ~--~-~ ........ 777':'--;,':':..: ........................... ~ ...... ' ~ ...... . ......... . ........ ..... ............. ......... ....... '~-:~'~ '~ ~'--~--~- '-~.:~: :-::;-;-:'';'~4-:':~'-:-::-:--:'--;-'':'':-~-:'~--'~:L' :' :':' :'t j ......... , ..................... ............................................. ~ .... ~ .... ~. · i ...... -~-.-~- ..... '"' ....... , - :'-:-:-'~ ~ ..... :'"-: .................. : .... ................. ~._~_ _t~_:" ": ..... -i ' -:--:'": ......... : ............ .... ........ : ~ ............. ...-~ .............................. ~ ............................................ ~ ............ .1~'o~_~,,":.~ ............................... ~.~ ...... ~ ..... ; ....... 1 ; .................. - , i";l, ~ .... .... , -.~ .............. ' ............ ~ ...... ~..~ ......... ~ ........ I ....... ~ .... t. I ...................... ~ ....... ~ ...............- .-.:_:-": ~ ...... ' -: ::..~-:: :::'.: :' :' i:': :'::-:-,:-: :':: : :' :-: .[. ;-' : : -:: ~ i, ..... .... I, ~, ~. ;'TZ"7'7-[-;;"--;-; i:~-;-;~;:;;:t-;;;'-'t~:- -;--;-'; ;--; ~--~00 ..... :--;:-;;-i550- ;; ;; t;500 :-;:. t'450~;..- 1400] ............ ~ ................................................... ~ ................ ~ .... ' ~ .. -- -_- .... -'- ~ ' ' '" KUPARUK RI VER UNIT 20" D IVERTER SCHEMATIC j L DESCRIPTION 1. 16" CONDUCTOR 2. FMC SLIP-ON WELD STARTING HEAD 3. FMC DIVERTER ASSEMBLY WITH TWO 2-1 / 16" 2000 PSI BALL VALVES 4. 20" 2000 PSI DRILLING SPOOL W/10" OUTLETS S. 1 O" HCR BALL VALVES W/1 O" DIVERTER LINES, A SINGLE VALVE OPENS AUTOMATICALLY UPON CLOSURE OF ANNULAR PREVENTER. VALVES CAN BE REMOTELY CONTROLLED TO ACHIEVE DOWNWIND DIVERSION. 6. 20" 2000 PSI ANNULAR PREVENTER ARCO ALASKA, INC., REOUESTS APPROVAL OF THIS DIVER .~E~ ~T~mi~:.,A~ A VARIANCE FROM 20AAC2:~.~~ ~ ~]:' i;? MAI NT[NANCE $¢~O.PERAT ION i 2 i . , UPON INITIAL INSTALLATION, CLOSE PREVENTER AND VERIFY THAT VALVE OPENS PROPERLY, CLOSE ANNULAR PREVENTER AND BLOW AIR THROUGH DIVERTER LINES EVERY 12 HOURS. CLOSE ANNULAR PREVENTER IN THE EVENT THAT AN INFLUX OF WELLBORE FLUIDS OR GAS IS DETECTED, OPEN APPROPRIATE VALVE TO ACHIEVE DOWNWIND DIVERSION. DO NOT SHUT IN WELL UNDER ANY CIRCUMSTANCES J6 11-3-86 r-J L_ 6 DIAGRAM #1 13-5/8' ,5030 PSI RSRRA BOP STACK I. 16' - 2000 PSI TAI~C~ STARTINO Fred 2- II' - 3000 PSI CASING FF~,D II' - 5000 PSI X 13--5/8' - 5000 PSI SPA(CFR SPOOL 4. 13'-5/8" - ,50(X~ PSI PIPE RAMS 5. 1~-5/8" - ~ PSI DRILLING ~ W/Q~ A/~ KILL LIliES 6. 13-5/8' - 5000 P~I ~ ~ W/PIPE RAMB ON TOP, 7. 13-5/8' - 5000 PSI AN~LI. AR AC(i,M.I_ATOR CAPACZTY TEST I. Q-ECX ~ FILL ~TC~ RF_~OIR TO LEVEL WITH HYDRNi. IC FLUID. A~ THAT A(~T(:R ~ I$ 3000 PSI WITH 3. CI~ TIldE, T1-EN CLO6E ALL UNITS SII~I..TN~OUSLY AU. UNITS ARE (1.O~D WITH CI-~II~ ~ CFF. 4. RECO~ CI~ N/t~C REP(3iq', TIE ACOS~Af~.E LClII~ LIMIT IS 45 SE~ CLO6ING TII~ ~ 1200 PSI REMAINING PRESSU~. 5 4 [3-5v'8" BCP STACK TEST i. FILL BOP STAQ( N~) ~ MN~IF(i.D WITH ARCTIC DIF. SS_. 2. CHEO( THAT ALL LOC3( ~ ~ IN V~D_LI-EN3 ARE FULLY RETRACTED. SEAT TEST PLUG IN WITH RUtCCING JT ~ RIJN IN LO(](DO~N SCI~D/IS. LI~E VALVES AD,JAClD~ TO BOP STACK. NJ. OTI-ER 4. ~ UP TO 250 PSI ~ ~ F(;R I0 MIN. IN- ~ PRESGtJRE TO 3000 PSI N~) HOLD FCR I0 MIN. Bi FreD_ PRE~ TO 0 PSI. LI~E VALVES. CL__O~_ TOP PIPE RA~ A~) HCR VALVES ON KILL A~ CHC~ 6. TEST TO 250 PSI ~ 3000 PSI AS IN STEP 4. 7. COWTINLE TESTING ALL VALVES, LIr~,So ~ CHO(ES WITH A 250 PSI LOW ~ 3000 PSI HIGH. TEST AS IN STEP 4. DO NOT PRESSLR~ TF_ST~. CHO(E THAT NOT A FULL CLOSING pOSITIVE SEAL Q-Ei(E. CI~LY FUNCTICN TEST ~S THAT DO NOT FLlLY CLO~E. 8. OPEN TOP PIPE RAMS AN3 CLOSE BOT'rCM PIPE RAMS. TEST BOTTC~ PIPE RAMS TO 250 PSI ~ 3000 PSI. 9. OPEN BOI'I'CM PIPE RANBo BAQ( OUT RUNWING Jl' AN:) I0. CLOSE BLIND RAMS A~D TEST TO 250 PSI At~) 3000 PSI. II. OPEN BLI~D RAMS A~D RETRIEVE TEST PLUG. MAKE SURE MANIFOLD ~ LI~ES ARE FUU_ CF NOW-FREEZING FLUID. SET ALL VALVES IN DRILLING POSITION. 12. TEST STANDPIPE VALVES° KELLY° KELLY COCKS° DRILL PIPE SAFETY VALVE° At~) INSIDE 8CP TO 250 PSI A~D 13. RECCRD TEST IN:rORCATICN OW BLC~OUT PREVENTER TEST FORM, SIOW° A~D SE]~D TO DRILLING SUPERVISOR. 14. PERF~ CCIVPL~E BOPE TEST AFTER NIPPLING UP AND WEEKLY THEREAFTER F1JNCTIONALLY OPERATE BCI=E DALLY. si ooa4oo REV. MAY 15,. 1985 Density DRILLING FLUID PROGRAM Spud to Drill out 9-5/8" Surface Casing to Weight Up 9.6-9.8 8.7-9.2 Weight Up to TD 10.3 PV 15-30 5-15 9-13 YP 20-40 8-12 8-12 Viscosity 50-100 35-40 35-45 Initial Gel 5-15 2-4 3-5 10 Minute Gel 15-30 4-8 5-12 Filtrate API 20 10-20 pH 9-10 9.5-10.5 9.5-10.5 % Solids 10± 4-7 9-12 Drilling Fluid System: - Triple Tandem Shale Shaker - 2 Mud Cleaners - Centrifuge - Degasser - Pit Level Indicator (Visual & Audio Alarm) - Trip Tank - Fluid Flow Sensor - Fluid Agitators Notes: Drilling fluid practices will be in accordance with the appropriate regulations stated in 20 AAC 25.033. Maximum anticipated surface pressure is calculated using a surface casing leak-off of 13.5 ppg EMW (Kuparuk average) and a gas gradient of .11 psi/ft. This shows that formation breakdown would occur before a surface pressure of 3000 psi could be reached. Therefore, ARCO Alaska, Inc. will test our BOP equipment to 3000 psi. After 200' of departure, there are no well bores within 200' of this proposed well. In accordance with Area Injection Order No. 2, excess non-hazardous fluids developed from well operations and those fluids necessary to control the fluid level in reserve pits will be pumped down the surface/production casing annulus. The annulus will be left with a non-freezing fluid during any extended shutdown in disposal operations. The annulus will be sealed with 175 sx of cement followed by arctic pack upon completion of the fluid disposal. LWK5 / ih GENERAL DRILLING PROCEDURB KUPARUK RIVER FIELD DEVELOPMENT WELLS 1. Move in rig. 2. Install Tankco diverter system. 3. Drill 12¼" hole to 9-5/8" surface casing point according to directional plan. 4. Run and cement 9-5/8" casing. 5. Install and test blow out preventer. Test casing to 2000 psig. 6. Drill out cement and 10' new hole. Perform leakoff test. 7. Drill 8½" hole to logging point according to directional plan. 8. Run open hole logs. 9. Continue drilling 8½" hole to provide 100' between plug back total depth and bottom of Kuparuk sands. I0. Run and cement 7" casing. Pressure test to 3500 psig. 11. Dowmsqueeze Arctic Pack and cement in 7" x 9-5/8" annulus. 12. Nipple down blow out preventer and install temporary Xmas tree. 13. Secure well and release rig. 14. Run cased hole logs. 15. Move in workover rig. Nipple up blow out preventer. 16. Pick up 7" casing scraper and tubing, trip in hole to plug back total depth. Circulate hole with clean brine and trip out of hole standin$ tubing back. 17. Perforate and run completion assembly, set and eeoc packer. 18. Nipple down blow out preventer and install Xmas tree. 19. Change over to diesel. 20. Flow well to tanks. Shut in. 21. Secure yell and release rig. 22. Fracture stimulate. -~ OE~LSSE~! SHALE _ SHAKERS .UD STIR .~..~, STIR _~ STIR TYPICAL MUD SYSTEM :SCHEMATIC LV~<4/ih (1) Fee ~/~ -~3~-~7 1. Is the permit fee attached .......................................... ~ ( 2' llzru 8) (9'thrn 13 ) (10 and '13) - '"' (14 thr~ '22)" cs) '(23 thru 28) Lease & Well No. NO ,,, , 2. Is well to be located in a defined pool ............................. ~ 3.. Is well located proper distance from property line .................. 4. Is well located proper distance from other wells .................... 5. IS sufficient undedicated acreage available in this pool ............ ~5 6. Is well to be deviated and is wellbore plat included ................ 7. Is operator the only affected party ................................. 8. Can pennit be approved before fifteen-day wait ...................... (6) ~ (29 'thru 31) 9. Does operator have a bond in force .................................. ~ 10. Is a conservation order needed ...................................... '~ 11 Is ad~dnistrative approval-needed 12. Is the lease r~her appropriate .......... ~ 13. Does the well have a unique name ~--~'A~.~'lil..l.lllllll.i.lll .... i. . ' 14. Is conductor string prOVided ........................................ /,~ ,, 15. Will surface casing protect fresh water zones ....................... /,~ .. 16. Is enough cement used to circulate on conductor and surface ......... zw~ ...... 17. Will cement tie in surface and intermediate or production strings ... ~ 18. Will cement cover all known productive horizons ..................... ~ ,, 19. Will all casing give adequate safety in collapse, tension and burst.. ~ · 20. Is this well to be kicked off from an existing w~llbore ............ ~ ~W 21. Is old wellbore abandommmt procedure included on 10-403 ............ /y/~ 22. Is adequate wellbore separation proposed ............................ ,,~ 23 IS a diverter system required - · eleleeee®e eeee· ee~e eeeee®eeeeeeeee®eeee 24. Is ~be drill~ fluid pro~rsm schematic and list of equipms~t adequate ~ .... 25. Are necessary diagrams and descriptions of diverter and BOPE attached. 26. Does BOPE have sufficient pressure rating - Test to ~ OO~ psig .. 27. Does the choke n~uifold comply w/API RP-53 fMay 84).- ................ ' 28. Is the presence of ~S gas probable ................................. For exploratory and Stratigraphic wells: 29. Are data presented on potential overpressure zonas? ................. 30. Are seismic analysis data presented on shallow gas zones ............. 31. If an offshore loc., are survey results of seabed conditions presented (6) Add: ~~C ~'~ -8'Z 32 Additional requirements ~ Geolo~: WWB ~O rev: 01/28/87 6.011 INITIAL GEO. UNIT ON/OFF POOL CLASS STAIUS AREA NO. SHORE 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. TAPE VERIF'ICATION bISTING /P OlO,H02 V~£NIFICATION LISTING REEL HEADE~':! ** ~RVlCE MA,~ E ;EDIT %TE :87/07/ 9 ~EL ~,'~ A M E : 7'237b ~EVIO'JS REEL JNMEMTS :LIS ~['A~E, A~CO ALA&KA, I~'~C, ~-t8, AP~ 50-029-2t7~0 TAPE tiEADER ~;RVICE i?~ A lq ~f :COLT %TE :87/07/ ~V l'. OUS TAPE : DM~'~ENTg :bis ".'rAPE~ A¢CC hB~,SKA, I~C, 3~-18, A~'I 50-029-217 30 FILE ME~OER IbE SA~!E :EOIT ,001 E~$ION # : hXI~U~ LENGTH : 1,024 [i,E TYPE : REVi. OU$ FILE INFORMATION CONTEl:TS iJ~IT TYPE CATE ~IZE CODE !~ : ARCO AhASKh, INC, 000 000 018 065 % : 3~-18 OOO 000 006 0~5 ~ : KUPARUK 000 000 0~8 0~5 AMG: RSE 000 000 OO] 065 O~e!: T13i~ 0~O 000 004 0~5 iCT: &25 000 000 003 065 OiJM~ ~ORTN S60PE OOO oO0 012 T~T: ~LASKk O00 0OO 006 065 CATE SIZE CODE RgSm E 000 000 00! 0~5 *********************************************************************************** i;P ..... OlO,H02 YERIFICATIf)r~ LIS'lINt', PAGE UN #1, DATEi i,OGG~D: 24-dUN-87 9PI R, SINES ~PE FLUID ENSI.,~Y ISC05I TY LO ID LOSS ATRIX SANDSTONE 625" a ' T '" , ,~. 4298 ' BI. SiZE 10.0 LSiG R~ 4:,~ C3 R~ A.T BET 6,53 ~ 63 DF 4,58 8 ~3 Dtr 5,25 O 63 DF 2,949 8 148 DF THIS [)~fA HAS NOT bEEN D~dPTH SHIFTED ' OVERLAYS FIELD PRINTS bOGS INCLUDED ~iTH THIS ~4AGNE']]IC I~VD~JCT1OI'd SPH~RtCALL~ F~CUS~O LOG O~TA AVAILABLE: 8550' TO q270' FOR~AT~Oi~,~ DEDSITY C[)i~PENSAT6D bOG [FDN) DATA A'VAILA~[,~;~ 8550' ~'O ~000' 5000' TO 4800' i~A~ IN CASING (GR,CN~) i)ATA AVAI.'bA~L~:' 4270' TO 900' DATA FORMAT RECORD ** NTRY BLOChS TYPE SiZE REPR CODE ENTRY ~ ! 66 0 8 4 73 60 9 4 65 ,lin 16 I 66 1' O i 66 0 ATU~ SPECIFICATION BDOCRS NEE SERVICE SERVICE Writ AP1 AP1 APl AP1 FlbE SiZE SPb REPR PROCE~S ID ORDER # LOG ~P~PE CbASS ~OD NO, CODE (OCTAl) EPT ~'T O0 000 O0 0 0 ~ 1 68 OOO00OO00OO000 FLU DXb ~tiM~ O0 220 Ol 0 0 4 I 68 00000000000000 CP 010,H02 VERIFiCA~IO~ biS%I~6 L,D Bib 0 H M.~i O0 ! 20 46 0 b~ Bib OHMM O0 120 ~4 O ~ DI6 GAPi O0 ~i0 01 0 ~NS Bib ~b 00 635 21 0 ~ FDN GAPI O0 310 Ol 0 ~OB FD~ G/C3 Or) ~5t) 02 0 R~O FOa GtC] 00 356 01 0 P~I FO~ PU O0 ~90 O0 0 RAT FDN O0 ~20 01 0 ~RA FDt~ O0 O00 O0 0 , CNg FD[~ CPS O0 330 30 0 R CHL GAPI Ou 310 0i 0 ENS C~iL LB O0 ~3b 21 0 4 4 4 4 4 4 4 4 4 PAGE 4 ! 68 00000000000000 1 68 O000000000000O 1 68 O000OO00000000 t 68 O0000OO0000000 I 68 O0000OO0000000 1 68 00.000000000000 i 68 00000000000000 I 68 00000000000000 1 68 00000000000000 I 68 00000000000000 I 68 OOOOO000000000 I 68 O00OO000000000 I 68 00000000000000 1 68 00000000000000 1 68 O00OO0000OO000 1 68 00000000000000 1 68 00000000000000' 1 68 O00000000OO000 P -34 U750 GR HOB 2 40~2 DAHB PHI 3~ 9t41, NRAT P -41,b5 HOB 2,~23B PHI ]B.212~ i,~RAT CN6 621.5000 TENS EPT 8000,0000 5FLU P -qV,71~B GR HOB 2 ~7b~ ORHO '~,.~1 NRA7' CNL 519,0000 YENS EPT 8~OO,OO00 bFLU P 51.b87b GR HOB 2.~b09 DRHO PHI 43,1641 NRA'~ CNL 496,5000 TEN~ EPT 8200,O000 3FLU P -8J.1250 GR CNL 1139,0000 YghS 'EPT 8100.0000 .P -52.8750 3.1847 lbo 132.0000 TENS ()' 0425 OPHI 3'.1816 RNRA 23.34,0000 GR 2,6910 2334',0000 14.6544 3,2422 '999,2500 . ' ) 2 ~255 Iu[ 2,b9~2 132.0000 TENS BOOB,O000 13,707'i 0,059i opal 3,2598 RNRA 3,2754 8008.0000 GR -999,2500 8~,1250 TM,NS 3,0669 DPHI ,3Ib4 RNRA 7768,0000 GR 4 i201 I[,O 82~9375 TE~S 0.0479 DPHI 7860.0000 GR 149,9562 IbO ~0.4375 Tgi~$ O.Oal5 OP~I 2.2910 RNRA 7612,0000 GR 2 9213 II, D g3~43'75 TENS 2 8856 '1768 0000 10 51i4 ] 5391 -999 2500 GR CAbI ¢A6I NCNb GR CAUl NCNb TENS 7860.0000 GR 11,4583 CAbI 3.6899 I'~CNL -999,2500 TE~S 38,034i 7b12,0000 GR 2.222? -999.2500 TENS 2,15bl lb~ 7532.0000 GR 2,945t 132,0000 ~,7891 !980,0000 -999,2500 2 ??00 1]~ 0000 8 8672 2o3m oooo -99~ ~500 2,9825 8~'1250 S,7~44 1~$7,0000 -g9~,2500 1~2~,0000 -999,2500 40,4375 b 2422 999.2500 9&,4375 VP OiO,h02 VERIFiCATIO~ LISTIi~G PAGE 5 CML 461.0000 TriMS 7332" SPT 7~00,0000 8FLU ~ P 5b.$750 GR 20~ HOB -999. 2500 D}~HO -999 PHI -999 2500 NMAT -999 C ~[~ -999~ 2500 TENS -999 0210 O094 5337 O 000 (>].. 17 0000 7395 2500 2500 25O0 EPT 7800.90o0 SFLO 5.0541 ~ -61.~750 GR 174,8750 i~O~ -999,2500 Dado -999,2500 PHi '999,2500 ~:~!~h? -999,2b00 C~b -999,2500 TLM~ ~999.2500 ~PT 7?00,0000 SFLO 0.7395 FiO~ -999 2500 DRHO -999 2500 PHI -999 2500 NRAT -999 ~500 C~L -999 2500 T~J~$ -999 2500 ~O[3 -999.2500 DRi40 -999.2500 PHI -999.2500 r~AT -999.2500 CNL -999,2b00 TENS -999,2500 EPT 7500.0000 SFbU 3,9428 P -46,2g13 GR 110.1875 HOG -999.250~ DRHO '999.2500 PHI -999,2500 NKA~ 999,2500 C~[a -999,~5Q0 7'EI~$ ~999,~500 ~PT 740~.000C SFLO 2.~174 P -3~,7~15 G~ 123,0~25 !t0~ -999.2500 U~HO -999.25G0 PHI -999.2500 ~RAT -999,2500 C!~L -999,25Q0 TENb -999,25e0 ~2PT 7300, Ou~o 5Fbd .4 1522 P -bi.0625 ;AN 95;8750 HOB -999.2500 DRHO -999.2500 PHJ -999.2500 r~AT -999.250~ C'~L -999,2500 TENS -999,2500 EPT 7200,0000 SFLU 4,0047 P -50,25U{3 GM 103,5000 DP}~I TENS RNRA TENS TE~S G~ DPSI R~RA I LO DPhI RNRA lENS i5.8381 CALl '999,2500 TENS 2,4906 I~M 3,4121 NCNb '999,2500 TE~8 3,~600 ibm 7512,0000 GR :999,2500 CAbI 999,2500 N''~'r -999,2500 TEaS 3,5803 ILM 0000 GR 7252, '999,2500 CALl -999,2500 .~CNh '999,2500 EN$ 3,6239 ~984,0000 GR '999,2500 CA~i '999.2500 '999.2500 TENS 3,9212 ILM 6848,0000 GR '999,2500 CA~I -999,2500 NCNb '999,2500 TENS 3,9421 6900,0000 ~R '999,2500 CALl '999.2500 '999,2500 2,3030 Ib~ 6'i40,0000 GR -999,2500 CAhI -999,2500 NCNb -99g,2500 fENS 3,bB22 Ib~ 6628,0000 GR '999,2500 CALl -999,2500 -999.2500 3.9064 b~40,OOO0 GR 9,0859 ~'t01,0000 999,2500 2 5!33 111 0000 ~ 1797 1709 O00, O '999 2500 3,~052 '999,2500 -~99,2500 -999,2500 -99~,2500 . 3,b052 ,999,2500 999,2500 -99~,2500 -99~,2500 ,999;2500 -99~'2500 -999'2500 3 94~7 -999 2500 -99~ 2500 {,9179 -999,2500 -99~,2500 -999,2500 -99~,,2500 · 2,4850 '999,2500 -ggg,ZLOO -999,2~00 -999,25U0 ~,7485 99~,2500 99~,~500 '999,2500 VP 010, ti()2 EPT 6900.0000 P -52.2500 i!O8 -999.2500 PHI -999,2500 C~L -999.2500 a 00,000 - 47, -999,250 999, 9 2500 9 9, EPT 6700.0000 6FbO P -q6.7500 GR MO0 '999 2500 DRHO PHI '999 2500 N~Ai' C~b -999 2500 TENS 'EFT 6600,0000 SFbO P -54'750,) GR H{3$ -999,2500 DRHO PHI -999.2500 [~R~'i 'C~L -999'2500 ~g~8 6500.0000 SFbU -999,25o0 QkHO -999.2500 N~AT -999,2500 T~i~5 ~PaI -999.2b~0 NgA't 'CML -999.250U 'i'~ir45 :EPT 6300.0000 SFbO ;P -57o'75U0 GA e 72, -999, ~999, -999. 4 85 "999 '999 '999 102' -999' '999' '999, 97 -999 -999 -999 2 91 -999 -999 -999 3 98 -999 -999 -999 2 9'~ -999 -99g -999 1. 109, -999. -999, -999. 112. 250 0 2500 25 0 0 1250 ~500 25O0 2500 0047 i250 2500 2500 2500 1219 19'15 2500 2500 2500 0 25 2500 2500 2500 4460 6250 2500 2500 2500 9587 3125 2500 2500 2500 8228 750o 250O 2500 2500 9395 3125 2500 2500 2500 7415 5625 DPHI ILO G~ lbo TENS DPHi RNRA ib.G OP~I NNRA GR DPH! TENS DPHi OPHI CR iLD bPHI 3,7098 IbM '999.2500 CA~I -999,2500 NCNb -999,2500 TENS 6460,0000 Ga -999,2500 CA~I -999,2500 NCNb -999,2500 TE~$ 3,5001 £L~: -999 500 CAbI 999,2500 t,I C N b :999,2500 TENS 3,2502 · 2500 CAbI -999,250~ NCN~ -999,~50~ T~NS 2,7886 6200,0000 -999.2500 CAbI -999,2500 NCN~ -999.2500 TENS 4.0532 l[~M 5920,0000 GR -999,2500 CAbI -999,2~00 NCNb -999,2500 TENS 3.3801 AbM 872,0000 GR ~999.2500 CA4I -999,2500 ~iCNb -999,2500 TENS 580&,0000 GR 999,2500 CADI 999,2500 NCNb 999.2500 'r~NS 3.(~(~06 598~, Oo PAGE 6 '999,2500 '~99,2500 -999,2500 ~9~, O0 ~99~,2500 '~9~,~500 '99~'2500 ~99~ ZSO0 "Sg~ 2500 '999 2500 -~9~ 2500 -999 -999 2500 '999 2500 '999 ~500 ~,2254 -999,2500 '999,2500 -999,25V0 -99~'Z500 ~99 2500 -~99 2500 -~9~ 2500 -98~ 2500 3 9812 -999 2500 -999 2500 -999 2500 -999 2500 J 3902 -999 250O -999 2500 '999 2500 '999 2500 2.2794 -999,2500 '999,~500 -99~;2500 ..999,2500 J.b217 -999,2500 VP OtO,M02 VE~'.IFICATION ~Hi ..999. 256~0 i'~ R AT C N L - 999.2 5 ~J 0 T E N S EPT 6000 0000 SFbO ~{OB -999 2500 DRHO PHi -999 2500 CNL -999,2500 T~N~ EPT 5800 P ~0~ -999 PHI -999 C~:L -999 .OOOO SFDO 25 {~ 0 D k r.i 0 25 L~ 0 N ~ & T i~]. '1 5700 P HOB -999 P~I -999 C:VL, -999 EP'r 560O P -52 ~Ot~ -999 P~I -999 CNL -999 ,2M13 G~ ,2500 NEAT ,25U0 T~i~ EPT P 53 H tJ ~ 999 PHI ~999 C~'~b -999 ,2813 GR ,2500 DR H!') .25U0 TEi-;$ 5 O0, -999 -999 -999 -999 -999 -999 -999 -999 -999 139 -999 -999 -999 97 -999 -999 -999 2 101 -999 -999 '999 2 -999 -999 -999 2 1 O0 -999 -999 -999 2 93 -999 -999 -999 .2500 .2500 ,2500 .2432 ,5625 .2500 .2500 .2500 2681 zSOu 2500 2500 7463 5000 2500 25OO 2500 ~'432 0625 2500 2500 2500 !453 3125 25O0 2500 2500 5392 9375 2500 2500 2500 .54~7 ,6750 ,2500 .2500 .2500 8825 ~250 25U0 i2500 2500 . 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R~ H 1' - 999 Ci~L, -999.250o TEi~S -9B9 !'~05 -999,2500 PHI '999,2500 a~RAT C~,~b -9o9,2500.. ~]PT 5200,0009 6Ff, O P -59,8125 GR ~0[~ -999,2500 ORHD PHi -999.250U NR.AT CNL- -999'~5V0 Tg¢$ EPT 5!O0.O00O P 59.34~ HOB '999. 2500 DRHD PHI -999,2500 t.~ RAT ~ :: C~L -999,2500 g P T 500 {), 000 (~ P - 39.00 {) 0 i-,iDB 2,2832 PHI 48. 632~ CNb 423.5000 .P '40,2B1] GR PHi -99g, 2500 NRAI 'CNL -gqg,250U YENS 4500 - 45 2 106 -999 -999 -999 .2 105 -999 -999 -99~ 2 I O6 -999 -999 -999 2 103 4624 4 0 460 8 91 46~4~ 3 108 -999 -999 2 -999 99 ,2500 ,2500 .2500 9433 2500 2500 2500 682i ,4375 250O 2500 2500 9'176 8125 2500 2500 2500 ,.~250 . !.90 ,'~28 .0517 .3125 .0049 ,3672 ,0000 5705 '9375 .0371 ,55~6 '0000 .8622 .3750 .2500 ,2500 ,9'131 ,7500 ,2500 ,2500 ,2500 19~ DPHI DPHi OPHI IbD DPHI GR GR I LO DPHI E t,} R A I LO 15 D bP~tI I LO -999.2500 CAbI -999,2500 NCNb -999.2500 ?EN$ 3,1690 IbM ~032,0000 GR 999.2500 CA~I -999'2500 {~CNb '999,2500 TENS 4752.00O0 -999 2500 -999 2500 -999 2500 3,2629 '999 250o -999 2500 -999 2500 NCNb gR CAbI NCNb TENS 3.0956 IbM 4~2~*0000 GR 22,2301 CALI 3,8691 ~,ICNb -999,2500 TENS 4,586i 3,4883 NCNb -999,2500 lENS ~.0743 ibm -999.2500 CAhI -999.2500 ,~CNb -999'2500 3 1850 ~372:0000 -999.2500 -999.2500 NCNb -999.~500 3.3804 ALM 4532,0000 GR PAGg .'999,2500 999. ,2,500 -999,Z500 ,,, ~, 0698 .~9~,2500 .999e 2500 ,.999,2500 2,92 7 74 ~9~ ;, 500 . -999'Z500 -999e2500 '99~,2500 &,1~84 -999,2 O0 '99~,2500 '999,2500 '99~,2~00 2 9791 103 1250 9 5703 1639 0000 '999 2500 4 2510 102 3125 9 9219 lb62 0000 ,.999 2500 3 9501 91 9375 9 5938 i81b 0000 -999 2500 $,92~7 -999 2500 -999 2500 -999 2500 -999 2500 J 0493 -999 2500 -999 2500 -999 2500 -999 2500 &,2574 '999,2500 -999 2500 DR.~O HO~. -999,2b0o PRiqO C i~ [.., -999,25ot~ TENS -999,2500 -999.2b~0 -999. 250~ P -999,2500 GR PHX -999 2500 N 1..~ AT CNL -999' 2500 EPT 4990,000~ S~LU .HOB -999. 2500 P~II -999, CNL -999.2b0c TENS PM1 CNL -999 P -999.25~0 Ga gGB -999.2500 PHI -999,~500 C~L -999,2500 P 999.25~0 Ge PHI -999.25~U Cb~b -999,25u9 'I'Ei~ S EPT 360~,0000 Sf'LU P -999.2500 GR -999.2500 DPMI -999 2500 -999:2500 ~ 2994 .. 7500 -999 2500 -999 2500 -999 2500 I LO -999 2500 -999 250C -999 2500 -999 25OO -999 2500 -909 2500 -999 2500 -9q9 2500 -999 250O -999 2500 I L9 UPMI Ga IL 0 TE~'~8 GR -999.2500 -999,250.) TE!'~$ '909.2500 DPHI '999.2500 ~NRA -999.2590 GR -999.2500 -999'2500 -999,2500 PP~l -999,2500 -999.2500 GR -999.2500 -999.2500 tENS -999.2500 DPMI -999'2500 RNRA -999,2500 GR -999 2590 'i -999,2500 -999,2500 999,2500 lbo -'99g' 2500 'PENS -999,2500 CALl -999,2500 ~CNL -999,25o0 TENS 3,6953 IL~ 4034,$000 6R -999.~500 CabI -99~,2500 NCN~ 92,~125 TEN8 1'12,0000 GR 999,2500 CAbI -999,2500 NCNb 72,1250 TENS -999,2500 IbM -999.2500 GR -99g.2500 CAhI -999,2500 NCNL 53,4375 TEi~$ -999 2500 -999 2500 -999 250O 54 81:25 CALl NCNb TENS -999,2500 IbM -999,250o GR -999,25uu CAbI -999,25i)0 NCNb 49,8750 TENS '999,2500 IbM '999,2500 '999,2500 45,71~8 TENS '999,2500 GR '999.2509 CAbI '999.250u NCNb 56,4063 T~NS -999,2500 -999,2500 -999,2b00 CAbI -999,2500 NCNb -~99.2500 -999,2500 GR 2500 2500 2500 3 4586 -~9~ 2500 -99~ 2500 -~99 2500 400~ 0000 ~ 4585 -99~ 2500 -99~ 2500 -99~ 2500 4224 0000 -9' 2500 -999 2500 4220 0000 -999 2500 -999 2500 -999 2500 -~9~ 2500 4054 0000 -999 2500 -99~ 2500 -99~ 2500 -999 2500 3900 O000 -99~ 2500 -99~ 2500 -999 2500 -99~ 2500 3980 0000 -99~2500 -~99 2500 -999 2500 -99~ 2500 378~ 0000 -999 2500 -99~ 2500 -999 2500 -99~ 2500 3680 0000 2999,2500 999,2500 V'P OlO.t~t02 V~]~IFiCATION !.,ISTif~.~G~ PAGE -999,2500 -999 , -999 . 2500 EPT 3300,00o{) SFLU P -999.2500 HCP, -999,2500 Phi -999,2500 NRA~I CWb -999. 2500 T EP! 3090 t~ O U i.) 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';') 00 ~.; S F b ij - 9 q 9 ,,2500 ,2500 ,2500 .2500 .2500 ,2500 2500 2500 2500 2500 2500 .2500 ,2500 .2500 2500 .2500 .2500 .2500 ,2500 .2500 .2500 2500 .2500 ,2500 ,2500 2500 2500 °2500 2500 i2500 2500 ,2500 oPHi t<~RA GR TM~S DPHI RNRA GR tho GP I bO TENS OPHI R~.~ RA TENS ~PHI RNRA G~ TENS OPHI ~NRA GR TE~S G~ ILD DPHI ILO '999, '999. -999 -999 -999 '999 3~ '999, '999. '999, '999, 51t, '999, '999, '999. 1999, 34, :999, 999, 1999. -999, 39. 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