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WALL LOG TRANSMITTAL RECEI iit-bg 1 APR 2 6 2018 AOGCCPRoAclivE DiAgroosric SERVICES, INC. To: AOGCC Makana Bender 333 West 7th Avenue Suite 100 SCANNED Anchorage, Alaska 99501 (907)793-1225 RE : Cased Hole/Open Hole/Mechanical Logs and/or Tubing lnspection(Caliper/MTT) The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the attention of: ProActive Diagnostic Services, Inc. Attn: Ryan C. Rupe 130 West International Airport Road Suite C Anchorage, AK 99518 Fax: (907) 245-8952 1) Caliper Report 06-Apr-18 1Y-30 1 Report /CD 50-029-21851-00 2) Signed : Date : ' 0 1 Print Name: PROACTIVE DIAGNOSTIC SERVICES, INC., 130 W.INTERNATIONAL AIRPORT RD SUITE C, ANCHORAGE, AK 99518 PHONE: (907)245-8951 FAx: (907)245-8952 E-MAIL: PDSANCHORAGE@MEMORYLOG.COM WEBSITE:WWW.MEMORYLOG.COM D:\Achives\MasterTemplateFiles\Templates\Distribution\TransmittalSheets\ConocoPhillips_Transmit.docx 188090 29191 Memory Multi-Finger Caliper Cit Log Results Summary Company: ConocoPhillips Alaska, LLC. Well: 1Y-30 Log Date: April 6, 2018 Field: Kuparuk Log No.: 14314 State: Alaska Run No.: 1 API No. 50-029-21851-00 Pipe Description: 3.5 inch 9.3 lb. J-55 EUE 8RD ABM Top Log Interval: Surface Pipe Use: Tubing Bottom Log Interval: 8,948 Ft. (MD) Inspection Type : Corrosive & Mechanical Damage Inspection COMMENTS : This caliper data is tied into the top of GLM 4 at 8,839 feet(Driller's Depth). This log was run to assess the condition of the tubing with respect to corrosive and mechanical damage, particularly between 8,326 feet and 8,833 feet where Slickline diagnostics indicate a tubing leak. A 3-D log plot of the caliper recordings across this interval is included in this report. The caliper recordings indicate the 3.5 inch tubing logged appears to be in good condition, with no significant wall penetrations, areas of cross-sectional wall loss or I.D. restrictions recorded. MAXIMUM RECORDED WALL PENETRATIONS : No significant wall penetrations(> 19%)are recorded throughout the tubing logged. MAXIMUM RECORDED CROSS-SECTIONAL METAL LOSS: No significant areas of cross-sectional wall loss (>4%)are recorded throughout the tubing logged. MAXIMUM RECORDED ID RESTRICTIONS : No significant I.D. restrictions are recorded throughout the tubing logged. C. Goerdt C. Waldrop J. Fama Rt en Loo eerisi ;'vialys4sj ProActive Diagnostic Services, Inc. / P.O. Box 1369, Stafford, TX 77497 Phone: (281) 431-7100 or (888) 565-9085 Fax: (281) 431-7125 E-mail: PDSAnalysis@memorylog.com Prudhoe Bay Field Office Phone: (907) 659-2307 Fax: (907) 659-2314 i • ,] PDS Multifinger Caliper 3D Log Plot Company : ConocoPhillips Alaska, Inc. Field : Kuparuk Well : 1Y-30 Date : April 6, 2018 Description : Detail of Caliper Recordings From 8,320 Feet to 8,838 Feet. Comments Depth Nominal I.D. 3-D Log Image Map 141111111111111111111W IIIIIIIIMIIIIIIIIIK 1ft:440ft 2 5 inches 3.50° 0° 90° 180° 270° 0° Maximum I.D. I - I 2.5 inches 3.5 Minimum I.D. I I 2.5 inches 3.5 Joint 259 8325 Joint • • 260 8350 Joint 261 8375 8400 = Joint 262 8425 Joint 263 I 8450 Joint 264 8475 1. Z Joint 265 8500 S. L I • 8525 4 Joint 266 1 V I 8550 • 0 JCAI1t LO/ 8575 1 1. I Joint 268 1 8600 I 1 8625 Joint 269 1 4 ,, 8650 > Joint 270 1 8675 i Joint 271 IF 8700 Joint 272 8725 ' i ,,_ , 8750 Joint 273 8775 11 r i Joint 274 ■ 8800 . It Joint 275 i 8825 v am Pun Joint Minimum I.D. I I 2.5 inches 3.5 Maximum I.D. 2.5 inches 3.5 Comments Depth Nominal I.D. 3-D Log Image Map lft:440ft 2 5 inches 3.5 0° 0° 90° 180° 270° 0° • Correlation of Recorded Damage to Borehole Profile • Pipe 1 3.5 in (37.8'-8,948.5) Well: 1Y-30 Field: Kuparuk Company: ConocoPhillips Alaska,Inc. Country: USA Survey Date: April 6,2018 ■ Approx.Tool Deviation ■ Approx.Borehole Profile 1 38 25 809 50 ; 1,597 75 2,389 100 3,178 GLM 1 SEW t, 125 3,976 - LL Z • 150 3 4,775 a. o � a) 175 5,579 GLM 2 200 — 6,389 • 225 7,197 GLM 3 250 8,013 pr. GLM 4--- 275- 8,802 278 8,944 0 50 100 Damage Profile(%wall)/Tool Deviation (degrees) Bottom of Survey=278 0 r 1111 PDS Report Overview tit 0._ _ Body Region Analysis Well: 1Y-30 Survey Date: April 6,2018 Field: Kuparuk Tool Type: UW MFC 24 No.218370 Company: ConocoPhillips Alaska,Inc. Tool Size: 1.69 inches Country: USA No. of Fingers: 24 Pipe 3.5 in. 9.3 ppf J-55 EUE 8RD ABM Analyst: C.Waldrop Pipe Nom.OD Weight Grade&Thread Nom.ID Top Depth Bottom Depth 3.5 in. 9.3 ppf J-55 EUE 8RD ABM 2.992 in. 38 ft. 8,948 ft. Penetration (%wall) Damage Profile(%wall) 300mc mu--- Penetration body Imo Metal loss body 0 50 100 250 1 200 -- C ___,___ ___=.___ ... 150 mii 100 47 €> 50 E 0 0 to 20 to 40 to over 20% 40% 85% 85% 97 Number of joints analyzed(total=284) - 284 0 0 0 GLM 1 (4:00) _, Damage Configuration(body) 146 20 15 - 196 10 GLM 2 (3:00) 5 245 GLM 3 (1:00) 0 Isolated General Line Other Hole/ Pitting Corrosion Corrosion Damage Pos.Hole - Number of joints damaged(total= 16) GLM 4(2:30) 14 2 0 0 0 Bottom of Survey=278 • • pi _ cif oks PDS Report Joint Tabulation Sheet Well: 1Y-30 Survey Date: April 6,2018 Field: Kuparuk Analyst: C.Waldrop Company: ConocoPhillips Alaska,Inc. Pipe Description Nom. ID Body Wall Top Depth Bottom Depth 3.5 in. 9.3 ppf J-55 EUE 8RD ABM Tubing 2.992 in. 0.254 in. 38 ft 8,948 ft. Joint Jt.Depth Pen. Pen. Pen. Metal Min. Damage Profile No. (Ft.) Upset Body % Loss I.D. Comments (%wall) (in.) (in.) % (in.) 0 50 100 1 38 0 0.03 13 2 2.93 U 1,1 69 0 0.03 13 2 2.93 Pup Lt. Deposits. 1.2 79 0 0.02 7 2 2.92 Pup Lt. Deposits. Is 1.3 89 0 0.01 5 2 2.93 Pup 2 98 0 0.02 8 2 2.93 Lt. Deposits. IN 3 129 0 0.02 7 2 2.93 • 4 159 0 0.03 10 3 2.94 • 5 191 0 0.02 8 2 2.92 Lt. Deposits. ■ 6 220 0 0.02 6 2 2.94 I 7 251 0 0.03 11 2 2.94 r 8 282 0 0.01 5 2 2.94 9 313 0 0.02 8 1 2.93 Lt. Deposits. • 10 343 0 0.03 13 2 2.93 •I 11 374 , 0 0,02 7 1 2.95 I 12 405 0 0.03 . 10 2 2.94 • 13 436 0 0.03 11 2 2.94 I• 14 467 0 0,03 11 2 2.94 11111 14.1 499 0 0 0 0 2.81 CAMCO DS NIPPLE 15 500 0 0.03 11 2 2.93 mi 16 531 0 0.03 12 2 2.94 - 17 562 0 0.02 9 2 2.94 • 18 593 0 0.02 8 2 2.93 • 19 624 0 0.02 7 2 2,94 • 20 655 0 0.02 7 2 2.94 ■ 21 686 0 0.02 8 2 2.94 • 22 717 0 0.02 7 2 2.94 r 23 748 0 0.03 13 2 2.93 Lt. Deposits. IN 24 778 0 0.02 7 1 2.94 II 25 809 0 0.03 10 2 2.93 Lt. Deposits. • 26 840 0 0.02 9 2 2.94 • 27 871 0 0.02 9 2 2.94 C 28 903 0 0.02 9 2 2.95 29 934 0 0.02 6 2 2.94 i 30 965 0 0.03 11 1 2.94 I• 31 996 0.06 0.02 9 1 2.96 • 32 1028 0.05 0.04 14 2 2.97 IN 33 1059 0 0.03 13 2 2.93 - 34 1091 0.05 0.02 8 2 2.97 • 35 1123 0.05 0.03 11 2 2.97 114 36 1154 0.04 0.03 12 2 2.96 • 37 1186 0 0.02 9 1 2.97 • 38 1218 0.04 0.04 14 2 2.95 IN 39 1249 0.04 0.02 8 2 2.97 • 40 1281 0 0.04 14 1 2.94 No 41 1313 0.05 0.02 6 2 2,97 1 42 1344 0 0.04 14 2 2.94 NI 43 1376 0.04 0.02 7 2 2.97 • 44 1407 0 0.04 15 2 2.95 Shallow Corrosion. 45 1439 0.04 0.02 8 1 2.95 • 46 1471 0 0.03 13 2 2.95 Penetration Body Metal Loss Body Page 1 0 0 PDS Report Joint Tabulation Sheet Well: 1Y-30 Survey Date: April 6,2018 Field: Kuparuk Analyst: C.Waldrop Company: ConocoPhillipsAlaska,Inc. Pipe Description Nom. ID Body Wall Top Depth Bottom Depth 3.5 in. 9.3 ppf J-55 EUE 8RD ABM Tubing 2,992 in. 0.254 in. 38 ft 8,948 ft. Joint Jt.Depth Pen. Pen. Pen. Metal Min. Damage Profile No. (Ft.) Upset Body % Loss I.D. Comments (%wall) (in.) (in.) % (in.) 0 50 100 47 1502 0.05 0.02 8 2 2.94 48 1534 0.04 0.03 12 2 2.9511 49 1566 0 0.02 8 2 2.94 50 1597 0 0.03 10 3 2.94 51 1629 0 0.02 9 3 2.94 I 52 1661 0.05 0.03 10 3 2.94 s 53 1693 0 0.03 13 2 2.93 Lt. Deposits. 54 172 5 0 0.02 9 1 2.95 I 55 1756 0.04 0.04 14 2 2.96 r 56 1788 0 0.04 16 2 2.93 Shallow Pitting. Lt.Deposits. 57 1820 0.04 0.02 9 1 2.96 58 1851 0.06 0.03 11 2 2.95ill 59 1883 0 0.02 7 1 2.95 60 1914 0 0.02 7 2 2.93 61 1946 0 0.02 8 2 2.94 62 1978 0 0.03 13 2 2.96 • 63 2010 0 0.02 9 3 2.94 64 2041 0.04 0.04 14 2 2.94 65 2073 0.04 0.04 15 2 2.96 Shallow Pitting. 66 2105 0.04 0.02 9 2 2.96 • 67 2136 0 0.02 6 1 2.97 I 68 2168 0.04 0.02 9 1 2.97 • 69 2199 0 0.04 14 1 2.97 WI 70 2231 0 0.02 6 2 2.96 71 2262 0.05 0.04 16 1 2.96 Shallow Pitting. IIII 72 2294 0 0.02 7 1 2.93 Lt. Deposits. II 73 2326 0 0.02 9 3 2.94 74 2357 0.05 0.02 8 1 2.96 75 2389 0 0.03 12 2 2.96 • 76 2420 0 0.03 12 2 2.93 77 2452 0 0.03 10 2 2.94 f 78 2484 0.05 0.02 6 2 2.97 II 79 2515 0 0.02 7 2 2.96 I 80 2547 0.04 0.02 7 2 2.95 U 81 2579 0 0.03 13 2 2.95 • 82 2610 0 0.02 7 2 2.96 IN 83 2642 0.04 0.04 15 2 2.97 Shallow Pitting. me 84 2673 0 0.03 10 2 2.96 1 85 2705 0 0.03 13 2 2.94 a 86 2736 0.05 0.02 8 2 2.94 it 87 2768 0.04 0.05 19 1 2.97 Shallow Corrosion. r 88 2800 0 0.02 9 2 2.92 Lt. Deposits. • 89 2831 0.04 0.03 13 2 2.95 90 2863 0 0.03 12 2 2.94 • 91 2894 0 0.04 15 3 2.94 Shallow Pitting. 92 2926 0.04 0.02 9 3 2.94 93 295 7 0.04 0.02 7 1 2.97 94 2989 0 0.02 8 2 2.96 • 95 3020 0.05 0.03 11 4 2.92 Lt. Deposits. G 96 3052 0 0.02 9 2 2.94 IPenetration Body Metal Loss Body Page 2 • 0 IRS. PDS Report Joint Tabulation Sheet Well: 1Y-30 Survey Date: April 6,2018 Field: Kuparuk Analyst: C.Waldrop Company: ConocoPhillips Alaska,Inc. Pipe Description Nom. ID Body Wall Top Depth Bottom Depth 3.5 in. 9.3 ppf J-55 EUE 8RD ABM Tubing 2.992 in. 0.254 in. 38 ft 8,948 ft. joint Jt.Depth Pen. Pen. Pen. Metal Min. No. (Ft.) Upset Body % Loss I.D. Damage Profile % (in.)) Comments (°/0 wall) (in.) (in.) in. 0 50 100 97 3084 0.05 0.02 8 2 2.97 98 3115 0 0.02 9 2 2.93 Lt. Deposits. 99 3147 0 0.03 13 2 2,94 100 3178 0 0.04 15 2 2.94 Shallow Pitting. NI 101 3210 0.05 0.02 8 1 2.96 102 3242 0 0.02 9 2 2.95 103 3273 0.05 0.04 17 2 2.95 Shallow Pitting. r 104 3305 0 0.03 10 3 2.94El 105 3336 0 0.02 9 2 2.94 1 106 3368 0 0.02 9 2 2.9511. 107 3400 0 0.02 . 8 2 2.94 108 3431 0.05 0.03 12 1 2.96II 109 3463 0 0.03 11 2 2.93si 110 3494 0 0.04 14 2 2.93 Lt. Deposits. ei 111 3525 0 0.02 9 2 2.91 Lt. Deposits. 1 112 3557 0 0.03 13 2 2.88 Lt. Deposits. ■ 113 3590 0 0.02 9 2 2.90 Lt. Deposits. • 114 3620 0 0.02 9 2 2.91 It Deposits. 115 3653 0 0.03 10 2 2.91 Lt. Deposits. Eli 116 3683 0 0.02 9 2 2.86 Lt. Deposits. II 117 3715 0 0.02 8 2 2.91 Lt. Deposits. 118 3746 0 0.03 10 2 2.89 Lt. Deposits. 119 3776 0 0.02 8 2 2.91 Lt. Deposits. 120 3809 0 0.02 7 1 2.89 Lt. Deposits. 121 3841 0 0.02 9 2 2.90 Lt. Deposits. 122 3874 0 0.02 8 2 2.90 Lt. Deposits. 122.1 3906 0 0 0 0 2.83 GIM 1 (LATCH @ 4:00) 123 3913 0 0.03 11 2 2.94 125123976 4 3945 0 0.02 8 3 2.89 Lt. Deposits. 126 396 0 0.02 0 0.02 8 3 2.90 Lt. Deposits. tii 7 2 2.90 Lt. Deposits. 127 4041 0 0.02 7 2 2.90 Lt. Deposits. 129128 4074 0 0.02 9 2 2.90 Lt. Deposits. 3 2.90 Lt. Deposits. 130 413 7 0 0.02 8 2 2.90 Lt. Deposits. 131 416 8 132 4268 0 00.02 7 2 2.91 Lt. Deposits. 02 7 2 2.90 It. Deposits. 133 4232 0 0.02 , 9 2 2.90 Lt. Deposits. 134 4263 0 0.02 7 1 2.90 Lt. Deposits. 135 4296 0 0,02 9 2 2.90 Lt. Deposits. 137136 4328 0 0.02 9 2 2.90 Lt. Deposits. ii 0.03 11 3 2.89 Lt. Deposits. 138 4393 0 0,02 8 2 2.91 Lt. Deposits. 139 4426 0 0.02 9 2 2.89 . Lt. Deposits. 140 4454 0 , 0.03 13 2 2.88 Lt. Deposits. 141 142 4485 5 0 0.02 8 2 2.90 Lt. Deposits. ' 10 143 455 8 0.03 12 2 2.88 Lt. Deposits. 144 45830 0 0.02 9 2 2.90 Lt. Deposits. 145 4513 0 0.02 8 2 2.90 Lt. Deposits. 0.02 9 2 2.90 Lt. Deposits. 'Penetration Body Metal Loss Body Page 3 0 • PIO t_iii NIL PDS Report Joint Tabulation Sheet Well: 1Y-30 Survey Date: April 6,2018 Field: Kuparuk Analyst: C.Waldrop Company: ConocoPhillips Alaska,Inc Pipe Description Nom. ID Body Wall Top Depth Bottom Depth 3.5 in. 9.3 ppf J-55 EUE 8RD ABM Tubing 2.992 in. 0.254 in. 38 ft 8,948 ft. Joint Jt.Depth Pen. Pen. Pen. Metal Min. No. (Ft.) Upset Body % Loss I.D. Damage Profile % (in.)) Comments (°/0 wall) (in.) (in.) in. 0 50 100 146 4647 0 0.04 14 2 2.90 Lt. Deposits. is 147 4680 0 0.03 11 2 2.90 Lt. Deposits. 148 471 0 0 0.02 7 3 2.90 Lt. Deposits. 149 4743 0 0.02 9 2 2.90 Lt. Deposits. I 150 4775 0 0.02 9 2 2.90 Lt. Deposits. II 151 4808 0 0.02 8 2 2.90 Lt. Deposits. 152 4840 0 0.02 9 2 2.90 Lt. Deposits. 153 4872 0 0.02 6 2 2.90 Lt. Deposits. ii 154 4905 0 0.03 12 2 2.88 Lt. Deposits. 155 493 7 0 0.02 7 2 2.90 Lt. Deposits. 157156 7 8 3 2.89 Lt. Deposits. 158 5002504 0 0.02 2 2.90 Lt. Deposits. 0 0.03 10 3 2.90 Lt. Deposits. 159 5067 0 0.02 9 2 2.90 Lt. Deposits. 160 5099 0 0.02 7 2 2.90 Lt. Deposits. 161 5132 0 0.02 9 2 2.90 Lt. Deposits. 162 5164 0 0.02 9 2 2.89 Lt. Deposits. 163 5196 0 0.02 6 2 2.90 Lt. Deposits. 164 5229 0 0.02 8 2 2.90 Lt. Deposits. 165 5259 0 0.02 8 2 , 2.91 Lt. Deposits. 166 5292 0 0.03 12 2 2.90 Lt. Deposits. 167 5324 0 0.02 8 2 2.90 It. Deposits. 168 5357 0 0.02 7 2 2.90 Lt. Deposits. 169 5389 0 0.02 8 2 2.91 Lt. Deposits. 17117 542 4 542 1 0 0. 02 8 2 2.89 Lt. Deposits. 172 54864 0 0.02 8 2 2.90 Lt. Deposits. 0,03 11 2 2.90 Lt. Deposits. 1733 5519 0 0.02 7 2 2.90 Lt. Deposits. 1754 5551 0 0.02 8 2 2.90 Lt. Deposits. 176 56129 0 0.02 7 0.02 7 2 2.89 Lt. Deposits. 2 2.90 Lt. Deposits, 177 5644 0 0.02 8 2 2.90 Lt. Deposits. 178 5677 0 0.03 11 2 2.91 Lt. Deposits. 179 5709 0 0.02 8 2 2.90 Lt, Deposits, 180 5741 0 0.02 7 3 2.90 Lt. Deposits. 182 5774806 0 0.02 7 2 2.90 Lt. Deposits. 0.02 8 2 2,89 Lt. Deposits. 183 5839 0 0.02 8 2 2.90 Lt. Deposits. 185184 587103 0 0.02 7 1 2.90 . Lt. Deposits. 0.02 9 2 2.89 Lt. Deposits. 186 5936 0 0.02 7 2 2.89 Lt. Deposits. 187 5968 0 0.02 8 2 2.91 Lt. Deposits. 3 188 6000 0 0. 03 13 2 , 2.89 Lt. Deposits. 190 6065 0 .03 8 2 2 .90 Lt. Deposits. 0 13 2.88 Lt. Deposits. 191 6098 0 0.02 9 2 2.90 Lt. Deposits. 1926130 0 0.03 13 2 2.88 Lt. Deposits. 193 6162 0 0,02 7 2 2.90 Lt. Deposits. 195194 6295 0 0,03 12 2 2.89 Lt. Deposits. 0.02 6 2 2.90 Lt. Deposits. IPenetration Body Metal Loss Body Page 4 ! • ~ PDS Report Joint Tabulation Sheet Well: 1Y-30 Survey Date: April 6,2018 Field: Kuparuk Analyst: C.Waldrop Company: ConocoPhillips Alaska,Inc Pipe Description Nom. ID Body Wall Top Depth Bottom Depth 3.5 in. 9.3 ppf J-55 EUE 8RD ABM Tubing 2.992 in. 0.254 in. 38 ft 8,948 ft. Joint Jt.Depth Pen. Pen. Pen. Metal Min. Damage Profile No. (Ft.) Upset Body % Loss I.D. Comments (%wall) (in.) (in.) % (in.) 0 50 100 196 6260 0 0.03 13 2 2.90 Lt. Deposits. IN 197 6292 0 0.02 7 2 2.90 Lt. Deposits. I 198 6324 0 0.04 14 2 2.87 Lt. Deposits. r 199 6357 0 0.01 6 2 2.88 Lt. Deposits. 200 6389 0 0.02 9 3 2.89 Lt. Deposits. r• 200.1 6421 0 0 0 0 2.84 GLM 2(LATCH @ 3:00) • 201 6428 0 0,02 8 2 2.91 Lt. Deposits. 202 6461 0 0.02 9 2 2.88 Lt. Deposits. U Ii 203 6493 0 0.02 9 2 2.89 Lt. Deposits. 204 6522 0 0.02 9 1 2.90 Lt. Deposits. ■ 205 6554 0 0.02 7 2 2.90 Lt. Deposits. • 206 6587 0 0.02 8 2 2.89 Lt. Deposits. • 207 6619 0 0.02 7 2 2.89 Lt. Deposits. it 208 6652 0 0.02 7 2 2.89 Lt. Deposits. • 209 6682 0 0.02 9 2 2.89 Lt. Deposits. U 210 6714 0 0.02 9 2 2.87 Lt. Deposits. U 211 6745 0 0.02 8 2 2.89 Lt, Deposits. o 212 6776 0 0.02 7 2 2.89 Lt. Deposits. • 213 6809 0 0.02 8 2 2.89 . Lt. Deposits. • 214 6841 0 0.02 9 2 2.90 Lt. Deposits. • • 215 6874 0 0.02 7 2 2.89 Lt. Deposits. 216 6905 0 0.02 8 2 2.88 Lt. Deposits. U 217 6938 0 0.02 8 2 2.90 Lt. Deposits. le 218 6970 0 0.03 10 2 2.90 Lt. Deposits. U 219 7003 0 0.03 10 2 2.87 Lt. Deposits. • 220 7035 0 0.03 13 2 2.86 Lt. Deposits. io 221 7067 0 0.02 9 2 2.89 Lt. Deposits. • 222 7100 0 0.02 7 2 2.85 Lt. Deposits. it 223 7132 0 0.02 9 2 2,89 Lt. Deposits. C 224 7165 0 0.02 8 2 2.89 Lt. Deposits. 225 7197 0 0.03 11 2 2.88 Lt. Deposits. 226 7229 0 0,02 9 2 2.89 Lt. Deposits. • 227 7262 0 0.02 7 2 2.89 Lt. Deposits. o 228 7294 0 0.02 9 2 2.92 Lt. Deposits. • 229 7326 0 0.02 8 2 2.89 Lt. Deposits. • 230 7359 0 0.02 9 2 2.89 Lt. Deposits. w 231 7391 0 0.02 9 2 2.89 Lt. Deposits. • 232 7424 0 0.02 8 2 2.88 Lt. Deposits. r I 233 7456 0 0.02 8 2 2.88 Lt. Deposits. 234 7489 0 0.02 8 2 2.89 Lt. Deposits. • 235 7521 0 0.02 8 2 2.88 Lt. Deposits. • 236 7553 0 0.02 6 1 2.89 Lt. Deposits. 237 7586 0 0.02 9 2 2.89 Lt, Deposits. U 238 7618 0 0,03 11 2 2.89 Lt. Deposits. U 239 7650 0 0.02 7 2 2.88 Lt, Deposits. • 240 7683 0 0.02 9 2 2.89 Lt. Deposits. • 241 7715 0 0.02 9 2 2.91 Lt. Deposits. • 242 7747 0 0.02 8 2 2.89 Lt. Deposits. 1 243 7780 0 0.02 7 1 2.88 Lt. Deposits. C 244 7812 0 0.02 9 3 2.87 Lt. Deposits. IPenetration Body Metal Loss Body Page 5 • • Li PDS Report joint Tabulation Sheet Well: 1Y-30 Survey Date: April 6,2018 Field: Kuparuk Analyst: C.Waldrop Company: ConocoPhillips Alaska,Inc. Pipe Description Nom. ID Body Wall Top Depth Bottom Depth 3.5 in. 9.3 ppf J-55 EUE 8RD ABM Tubing 2.992 in. 0.254 in. 38 ft 8,948 ft. Joint Jt.Depth Pen. Pen. Pen. Metal Min. Damage Profile No. (Ft.) Upset Body % Loss I.D. Comments (%wall) (in.) (in.) % (in.) 0 50 100 245 7845 0 0.03 10 2 2.89 Lt. Deposits. 246 7877 0 0.02 8 2 2.89 Lt. Deposits. 111 247 7909 0 0.02 9 2 2.90 Lt. Deposits. ■ 248 7942 0 0.02 7 2 2.92 Lt. Deposits. 1 248.1 7974 0 0 0 0 2.88 GLM 3(LATCH @ 1:00) 249 7981 0 0.04 14 2 2.93 Lt. Deposits. 250 8013 0 0.03 11 2 2.94 251 8044 0 0.03 13 3 2.94 252 8076 0 0.02 8 2 2.91 Lt. Deposits. 253 8107 0 0.03 13 2 2.93 Lt. Deposits. 254 8139 0 0.04 15 3 2.93 Shallow Pitting. Lt.Deposits. 255 8170 0 0,04 17 1 2.95 Shallow Pitting. 256 8202 0 0.03 13 2 2,93 Lt. Deposits. 257 8234 0 0.04 14 2 2.92 Lt. Deposits. 258 8265 0 0.02 9 2 2.91 Lt. Deposits. • 259 8296 0 0.04 14 2 2.91 Lt. Deposits. 260 8328 0.04 . 0,04 15 3 2.93 Shallow Pitting. Lt.Deposits. 261 8359 0 0.03 13 3 2.93 262 8391 0 0.03 10 2 2.92 Lt. Deposits. • 263 8422 0 0.03 12 2 2.95 264 8454 0 0.02 9 2 2.92 It Deposits. 265 8485 0.04 0.03 12 3 2.92 Lt. Deposits. 266 8517 0.05 0.05 18 2 2.94 Shallow Pitting. 267 8548 0 0,04 17 1 2.91 Shallow Pitting. It Deposits, 268 8580 0.04 0.04 15 2 2.95 Shallow Pitting. 269 8612 0 0.03 13 2 2.92 Lt. Deposits. r■ 270 8643 0.04 0.02 8 2 2.94 ■ 271 8675 0.04 0.03 13 2 2.92 Lt. Deposits. • 272 8707 0.05 0.04 14 2 2.92 Lt. Deposits. 273 8738 0.04 0.04 14 2 2.93 Lt. Deposits. 274 8770 0 0.03 12 2 2.95 l 275 8802 0.04 0.03 10 2 2.92 Lt. Deposits. 275.1 8833 0 0.02 6 1 2,92 Pup Lt, Deposits. 275.2 8839 0 0 0 0 2.87 GLM 4(LATCH @ 2:30) 275.3 8847 0 0.01 5 0 2.91 Pup Lt. Deposits. 276 8853 0 0.03 11 2 2.90 Lt. Deposits. 277 8884 0 0,04 15 2 2.92 Shallow Pitting. Lt.Deposits. 277.1 8917 0 0.02 9 0 2.93 Pup Lt. Deposits. 277.2 8922 0 0 0 0 2.94 BAKER 80-40 PBR 277.3 8936 0 0 0 0 2.88 BAKER FHL PACKER 278 8944 0 0.02 7 0 2.95I U Penetration Body Metal Loss Body Page 6 • • KUP 9Y-30 ConocOPhilli p5 3 Well Attributes Max Angle&MD TD q'..n:ka.Int!. WeMore 0)9/618 Field Plan WW Status 8i('i WOMB) A.B.IRKS) ca,pa}1MIps 500292185100 KUPARUK RIVER UNIT PROD 58.08 360000 9.5950 ... Comment 1025(ppm) DaleAnnotaion End Date KB-0r4(5) Rip Rebase Dae flits Orm S���w SSSV:NIPPLE 160 9/4/2011 Last WO: 422/1995 39.99 10/18,1988 Mnoabn Depth(W(8) End Oa* Amohcon Last Mtn...EM Dab Last Tag:S'.M 9 341.0 1512011 Rev Reason:WELL REVIEW osoo/: 6!26/2012 .,, Citing'$111,1g5 CasNDDesu12P1ia1 91(1600_ S15 5_Top 380 Bet Depth get Depth(TVD)...Shing WL..Ship...String Tp Thrd --� CONDUCTOR 16 15250 360 1150 1150 65.00 1140 WELDED Casing Description String O._ Wing ID...Top(*88) Set Depth{r-.SN Depth(TVD)._Snip WI-$Kp_Ship Twlhtl SURFACE 950 8.921 35.0 5,157.5 3,553.0 36.00 .1.55 BIC ,,.,_, !� casing Deaerpliee 55ag 0... seine D...Top IeKBI Set 8040 H--.Set Depth(ND)-..String VR..Minna..."Strina Tug and PRODUCTION 7 6276 330 9.572.8 6.346.8 26.00 355 arc Tubing Safngs .. Tudnp Dea Tptioe s,,,..37.0_. uhp O_.'tiring D._lop (1ddIB) 5elbpte...5aITVD)...5526.04...6ekp._85hp Top llvd TUBING 3.5'(.2875' 3 / 2.992 21.5 9,178.1 6.0530355 EUEBRDABM Completion Details Top Depth Ssn (190) Top hna xm8... 1IRPL✓GO Topp) MD) (9 a.„,,,,,,,,,„a.„,,,,,,,,,„ CammM Den) r21.5 21.5 0.21 SANGER FMC GEN IV TUBING HANGER3.500 488,3 487.0 6.44 NIPPLE CAMC005N9WLE 2912 8,822.6 5.877.9 47.84 PBR BAKER 8040 PBR w!10'STROKE 3.000 GlSae�'TBd 8,936.3 5,887.2 47.70 PACKER BAKER FHL PACKER 2.992 _- 8,975.0 5,913.3 47.31 BLAST JTS BLAST JOINTS{OAL=138.18') 3.000 9,152.7 6,035.7 45.53 00 Reducing CROSSOVER 3.5 x 2.875 2.875 9,154.4 6,036.8 4551 LOCATOR TIW LOCATOR SEAL ASSEMBLY 2.507 9,156.0 6,038.0 45.48 PACKER TM SS PERMANENT PACKER 3260 SURFAl 9,170.2 8,347.8 45.27 NIPPLE OTS kW LANDING NIPPLE 2.31'*2.25'NO GO 2.250 330.1110 E. • 9,177.4 6,052.9 45.16 SOS BAKER SHEAR OUT SUB.ELMO TTL 0 9178 during Packer/07 Sal 3.003 Record on 42211995 Pts UFT °415 Other In Hole Wireline retrievable plugs.valves,pumps,fish.etc.) Tap Depth [ iiIII (1YDI Tapbd GIS77Wl TOP/)160) ( ) (7 D.OvOprion Comment Rut Dale ID(in) P3ti6 1 6,181.7 41.83 FISH DROPPED 7.S CV IN RATHOLE 118)2011 0.000 Perforations&Slots Shot PIS LIFT. Top(1VD)600(190) Dass 8.870 I. Top mice)96s99931 (h1 1 ®) MD) Zmu Dab hat- TY" Camera 8.985.0 9,070.0 5.920.0 5.978.3 UNIT 4.C.4,C•3.1020/1990 12.0 APERF 2100 Atles Silver:60 deg.pH 10.30 9.080.0 9,110.0 5,985.1 6,005.8 C-1.UNIT B, 10)2801990 12.0 APERF 2 I/O'Atlas Silver:60 deg.pH 1Y-30 r I 9248-0 9.254.0 6,103.6 6,107.8 AS,111.30 1/31/1989 4.0 IPERF 2 5/8'Atlas SlintKoo;180 deg.pH PeR 5�7 ii 9254.0 9,320.0 6,107.8 8,155.4 AS,A4,M3, '8/24/1990 8.0 APERF 21!11 Titan guns:100 deg pH; PACI08.8.030 10.30 dawning so.25 deg if 9.320,0 9,340.0 6,155.4 6,170.4 A-3.10-30 1131/1989 4.0 IPERF 250'Atlas S6o8on:180 deg.pH 98740 9.399.0 6.195.5 6,207.5 A2,10.30 1/31/1989 4.0)PERF l2 50"Atlas SliinKon.180 deg.pH 8A944.898 MII., M Notes:General&Safety End Dae Annotation 7.8'2002 NOTE:WAIVERED WELL IA X OA COMMUNICATION 102912010 NOTE:View Schematic rK Alaska Sdwnlegc9.0 I PRCOUCTXMI6 I ;.. I t LCCATP4 III 0,114 PACKER 0.165 ...... II NIPPLE,0.1711 IE 1 509.9.177 r ° a M 22540 M Mandrel Details Top Depth TopPort 0.3x110.310 (tvD) Ind CD Vatw Lams Eine TRO Rut On Top INKED 116®) I') Male Meet (M inn Type Type tW (103 Rus Dale Cm. 1 3,8862 2.839.9 56.95 CARCO KBUG 1 GAS UFT GLV 8145 0.125 1,304.0 2/172010 0.300 ! 2 6,4182 4,291.1 52.94 CARCO KBUG 1 GAS LIFT GLV 8145 0.156 1332.0 6+52005 3 7,973.1 5,257.3 5027 CARCO KBUG 1.GAS LIFT OV 8145 0.250 0.0 2/122006 4 8,838.9 5,822.4 48.70 CARCO MING 7 12.GAS UFT OW RK 0.000 0.0 2/022006 0,374-0,300� III 5 9,120.3' 6,012.9 46.01 CARCO 1814G1 12 PROD DMY RK 0.000 0.0 14/2011 PRODUCTION, o 00: � Ta • STATE OF ALASKA R&.. 1 SKA OIL AND GAS CONSERVATION C SSION R ORT OF SUNDRY WELL OPE TIONS APR 1 ; 2018 1.Operations Abandon U Plug Perforations LI Fracture Stimulate Li Pull Tubing U mpritretirrolveKown LI Performed: Suspend ElPerforate ElOther Stimulate ElAlter Casing H C rV"^{►' ram Plug for Redrill ❑ Perforate New Pool ❑ Repair Well El Re-enter Susp Well ❑ Other: Tbq patchesn 2.Operator 4.Well Class Before Work: 5.Permit to Drill Number: Name: ConoCoPhllllps Alaska, Inc Development E Exploratory ❑ 188-090 3.Address: P.O.Box 100360 Stratigraphic ❑ Service ❑ 6.API Number: Anchorage AK 99510 50-029-21851-00 7.Property Designation(Lease Number): 8.Well Name and Number: ADL 25641 KRU 1Y-30 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): N/A Kuparuk River Field/Kuparuk River Oil Pool 11.Present Well Condition Summary: Total Depth measured 9573 feet Plugs measured N/A feet true vertical 6347 feet Junk measured 9368 feet Effective Depth measured 9359 feet Packer measured 8936,9156 feet true vertical 6184 feet true vertical 5887,6038 feet Casing Length Size MD TVD Burst Collapse Conductor 80 16" 115 115 Surface 5123 9-5/8" 5158 3553 Production 9540 7" 9573 6347 Perforation depth Measured depth 8985-9110,9248-9390 feet True Vertical depth 5920-6107,6103-6208 feet Tubing(size,grade,measured and true vertical depth) 3.5" J-55 9178'MD 6053'TVD Packers and SSSV(type,measured and true vertical depth) Packer Baker FHL 8936'MD 5887'TVD Packer TIW SS Permanent 9156'MD 6038'TVD No SSSV Camco DS nipple 488'MD 488'TVD 12.Stimulation or cement squeeze summary: N/A Intervals treated(measured): Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: N/A N/A N/A N/A N/A Subsequent to operation: N/A N/A N/A N/A N/A 14.Attachments(required per 20 AAC 25.070,25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations 0 Exploratory ❑ Development Service ❑ Stratigraphic ❑ Copies of Logs and Surveys Run ❑ 16.Well Status after work: Oil 10 Gas H WDSPL H Printed and Electronic Fracture Stimulation Data ❑ GSTOR ❑ WINJ H WAG ❑ GINJ H SUSP❑ SPLUG❑ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: Authorized Name: Kelly Lyons Contact Name: Kelly Lyons/Jan Byrne Authorized Title: Well Integrity Su ervisor Contact Email: n1617@cop.com Authorized Signature: ��� Date:4/15/18 Contact Phone: 659-7224 vrt_ 4J27/l V *11/2-74( Form 10-404 Revised 4/2017 R�� APR 12 M Submit Original Only • y/ • • ConocoPh i l l i ps Alaska P.O. BOX 100360 ANCHORAGE,ALASKA 99510-0360 April 15, 2018 Commissioner Hollis French Alaska Oil & Gas Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 Dear Commissioner French, Enclosed please find the 10-404 Report of Sundry Well Operations for ConocoPhillips Alaska, Inc. Development KRU well 1Y-30 (PTD 188-090). The report is for two tubing patches that were set to repair leaks above the packer. Please call Jan Byrne or myself at 659-7224 if you have any questions. Sincerely, Kelly Lyons Well Integrity Supervisor Attachments • • Date Event Summary 03/10/18 (WC) MIT-OA(PASS TO 1800 PSI) TIFL (FAIL DUE TO PRESSURE INCREASE AND INFLOW) Initial T/I/O = 205/1340/1325. IA FL @ 6935' (1038' above St#3 OV) . OA FL NS Bled the OA to 970 psi in 30 sec(gas). Pressured up the OA to 1800 psi with 0.48 bbl of diesel Start T/I/O = 205/1340/1800 15 min T/I/O = 205/1340/1765 (-35) 30 min T/I/O =205/1340/1755 (-10) Bled the OA to 600 psi in 3 min (charged fluid). SI the WV and double blocked the AL line. Stacked out the T x IA to T/I/O = SI 1250/1240/635 in 40 min. IA FL @ 6563' ( inflowed 372') Bled the AL line. Bled the IA to 725 psi in 45 min. IA FL @ 5504' (inflowed 1059'). T FL @ 6077' Start T/I/O = SI 1255/725/615 15 min T/I/O = SI 1255/780/610 (+55). IA FL @ 5139' (Inflowed 365'). T FL @ 6163' (Out flowed 86') 30 min T/I/O = SI 1255/820/605 (+40). IA FL @ 4824' (Inflowed 315'). T FL @ Same location Final T/I/O = SI 1255/820/605 03/18/18 DISPLACE TBG w/DIESEL AND SET BAITED HOLE FINDER @ 9153' RKB. PULLED OV (CHECK STUCK OPEN) @ 6418' RKB AND REPLACED IN KIND. SET HOLE FINDER @ 9095" RKB. TESTED TBG; FAILED. IN PROGRESS. 04/05/18 PERFORM BASELINE TEMPERATURE PASS FROM SURFACE TO RBP @ 8960' RKB. IDENTIFY TBG LEAK @ APPROX 8533' RKB, PERFORM UP/DOWN PASSES ACROSS LEAK AND STATION STOPS @ 8540' &8525' RKB. LOG MAIN PASS FROM RBP @ 8960' RKB TO SURFACE, LOG CORRELATED TO TBG TALLY 4/22/95. SET CATCHER ON RBP & PULLED DV @ 8839' RKB. LRS ON LOCATION TO LOAD TBG x IA w/CISW& DIESEL FREEZE PROTECT. IN PROGRESS. PUMP 226 BBLS OF INHIBITED SEAWATER FOLLOWED BY 88 BBLS OF DIESEL DOWN TUBING UP THE IA TAKING RETURNS TO WELL 1Y-15 U-TUBE CMIT T X IA TO 2500 PSI JOB COMPLETE PRESSURE UP TBG/IA TO 2500 PSI 2.9 BBLS TO PRESSURE UP T/I/O/F INITAL= 750/750/500/200 PRE= 2550/2600/540/200 15M= 2550/2600/540/200 TBG LOST= OPSI IA LOST= OPSI FIRST 15M 30M=2550/2600/540/200 TBG LOST-= OPSI IA LOST= OPSI 04/06/18 SET EXTENDED PKG DV @ 8839' RKB. IDENTIFY LEAK @ APPROX 8820' RKB PUMPING 2 BPM. LOG UP/DOWN PASS ACROSS LEAK AND PERFORM STATION STOPS @ 8850' & 8815' RKB. U-TUBE T x IA. LOG PDS CALIPER FROM 8955' RKB TO SURFACE; OBTAIN GOOD DATA. IN PROGRESS. • S 04/13/18 SET 2.72" P2P w/AGGRESSIVE SLIPS (#CPP35165) MID ELEMENT @ 8828' RKB. CMIT T x IA TO 2500 (PASS) WITH TEST TOOL SET IN P2P. SET 2.72" P2P (#CPP35166), SPACER PIPE, ANCHOR LATCH (#CPAL35081) MID ELEM @ 8810' RKB. CMIT T x IA TO 2500 (PASS)WITH TEST TOOL SET IN P2P. IN PROGRESS. **CMIT against lower packer pass: preTIO=600/450/440, initial=2500/2300/440, 15min=2475/2275/440, 30min=2475/2275/440 CMIT against top packer pass: preTIO=350/225/420, initial=2500/2275/430, 15min=2450/2225/430, 30min=2450/2225/430** 04/14/18 SET 2.72" P2P w/AGGRESSIVE SLIPS (#CPP35163) MID ELEM @ 8542' RKB. SET TEST TOOL IN P2P & CMIT TO 2500 (PASS). SET 2.72" P2P (#CPP35164), SPACER PIPE, ANCHOR LATCH (#CPAL35080) MID ELEM @ 8524' RKB. SET TEST TOOL IN P2P @ 8524' RKB. MITT TO 2500 (PASS), CMIT IA x TBG TO 2500 (PASS). JOB COMPLETE. CMIT TO 2500. PRE T/I/O= 300/250/380. PSI UP w/7.8 BBLS. START=2500/2350/390 15 MIN=2400/2300/390 30 MIN=2400/2300/390 ***PASS*** against lower packer of 2nd patch MITT TO 2500. PRE T/I/O= 300/275/370. PSI UP w/0.9 BBLS. START= 2500/275/370 15 MIN=2400/275/370 30 MIN=2375/275/370***PASS***against top packer of 2nd patch CMIT IA x TBG TO 2500. PRE T/1/O=2500/150/275. PSI UP w/7.8 BBLS. START= 2750/2500/380 15 MIN=2750/2425/380 30 MIN= 2750/2425/380 ***PASS***against top packer of 2nd patch Executive Set two retrievable TTS tubing patches to repair leaks at 8820' and 8533'. Both patches are Summary 18' long. Integrity of the patches was confirmed with a series of pressure tests (CMITs and MITT). KUP PROD • 1Y-30 O. Well Attributes Max Angle&MD TD ConocoPhillips Wellbore API/UWI Field Name Wellbore Status ncl(1 MD(ftKB) Act Btm(ftKB) Alaska,Inc. :' 500292185100 KUPARUK RIVER UNIT PROD 58.08 3,600.00 9,595.0 r- r Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date ... SSSV:NIPPLE Last WO: 4/22/1995 39.99 10/18/1988 1Y-30,4/1520188:44:51 AM Last Tag Vesical schematic(actuap Annotation Depth(ftKB) End Date Last Mod By ............................................................... Last Tag:RKB-EST.31'OF FILL 9,353.0 3/17/2018 pproven HANGER;215 Last Rev Reason Annotation (End Date (Last Mjod By Rev Reason:Patches,GLV C/O 4/1572018 fama Casing Strings t 1' Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ft88) Set Depth(TVD(... Wt/Len(I...Grade Top Thread • CONDUCTOR 16 15.250 36.0 115.0 115.0 65.00 H-40 WELDED aur Casing Description OD(in) ID lin) Top(ftKB) Set Depth(ftKB) Set Depth(ND)...Wt/Len(I...Grade Top Thread SURFACE 95/8 8.921 35.0 5,157.5 3,553.1 36.00 J-55 BTC hit, I s Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)... Wt/Len(I...Grade Top Thread CONDUCTOR;36.0-1150 1"-/11/ PRODUCTION 7 6.276 33.0 9,572.8 6,346.8 26.00 J-55 BTC Tubing Strings NIPPLE;488.3 Mr Tubing Description 'String Ma...IID(n) 'Top(118131ISet Depth(ft..Set Depth(TVD)(...I Wt(lb/ft) (Grade 'Top MR Connection IIITUBING 3.5"x2.875" 31/2 2.992 21.5 9,178.1 6,053.4 9.30 J-55 EUEBRDABM GAS LIFT;3,896.2 _ Completion Details Top(ND) Top Incl Nominal Top(ftKB) (ftKB) F) Item Des Coin ID(in) , 21.5 21.5 0.04 HANGER FMC GEN IV TUBING HANGER 3.500' 488.3 487.8 6.55 NIPPLE CAMCO DS NIPPLE 2.812 8,922.6 5,877.9 47.84 PBR BAKER 80-40 PBR w/10'STROKE 3.000 SURFACE;35.0-5,157.5- a 8,936.3 5,887.1 47.70 PACKER BAKER FHL PACKER 2.992 8,975.0 5,913.2 47.31 BLAST JTS BLAST JOINTS(OAL=139.16') 3.000 GAS LIFT;6,418.2 ®A 9,152.6 6,035.5 45.53 XO Reducing CROSSOVER 3.5 x 2.875 2.875 9,154.3 6,036.6 45.51 LOCATOR 'TIW LOCATOR SEAL ASSEMBLY 2.507 GAS LIFT;7,973.1 1 j 9,156.0 6,037.8 45.48 PACKER TIW SS PERMANENT PACKER 3.260 9,170.2 6,047.8 45.27 NIPPLE OTIS XN LANDING NIPPLE 2.31"x 2.25"NO GO 2.250 PATCH;8,524.0 9,177.4 6,052.8 45.16 SOS BAKER SHEAR OUT SUB,ELMD TTL©9178'during Packer/TT 3.000 LEAK;8,5330 Set Record On 4/22/1995 Other In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.) PATCH;8,542.0 f Top(ND) Top Incl Top(ftKB) (ftKB) (°) Des Com Run Date ID(in) 8,524.0 5,614.5 48.96 PATCH P2P PACKER(#CPP35164)W/SPACER PIPE AND 4/14/2018 1.600 SNAP LATCH(#CPAL35080)SET AT8524'PACKER DEPTH.MIN ID 1.6"OAL 19'. PATCH;8,810.0 LEAK;5820.0 1tIrM 8,533.0 5,620.4 48.95 LEAK LEAK IDENTIFIED WITH SPINNERS AT 8533' 4/5/2018 2.992 8,542.0 5,626.3 48.95 PATCH P2P PACKER(#CPP35163)W/AGGRESSIVE SLIPS '4/14/2018 1.625 SET AT 8542'. MIN ID 1.625"OAL 4' PATCH;8820.0 - 11 8,810.0 5,802.9' 48.59 PATCH P2P PACKER(#CPP35166)W/SPACER PIPE AND 4/13/2018 1.600 ANCHOR LATCH(#CPAL35081)SET WITH TOP PACKER AT 8810'1.6"ID 19'OAL 8,820.0 5,809.5 48.53 LEAK LEAK IDENTIFIED WITH SPINNERS 4/6/2018 2.992 GAS LIFT;8,838.9 8,828.0 5,814.8 48.48 PATCH P2P PACKER(#CPP35165)W/AGGRESSIVE SLIPS 4/13/2018 1.625 SET AT 8828'. 1.625"ID 4'GAL. 9,368.0 6,191.0 41.63 FISH DROPPED 1.5"CV INRATHOLE 1/6/2011 0.000 Perforations&Slots PBR;8,922.6 tl Shot Dens PACKER;8,936.3 Top(ND) Btm(ND) (shots/ft 1 Top(ftKB) Btm(ftKB) (ftKB) (ftKB) Zone Date ) Type Com 8,985.0 9,070.0 5,920.0 5,978.2 UNIT 4,C-4,C- 10/20/1990 12.0 APERF 2 1/8"Atlas Silver;60 deg. 1 3,1Y-30 pH APERF;6,965.0-9,070.0_ 9,080.0 9,110.0 5,985.0 6,005.7 30,UNIT B,1Y 10/20/1990 12.0 APERF 21/8"Atlas Silver;60 deg. P H 9,248.0 9,254.0 6,103.1 6,107.4 A-5,1Y-30 1/31/1989 4.0 IPERF 25/8"Atlas SlimKon;180 APERF;9,080.0-9,110.0 deg.pH 9,254.0 9,320.0 6,107.4 6,155.4 A-5,A-4,A-3, 8/24/1990 8.0 APERF 2 1/2"Titan guns;180 deg. 1Y-30 pH;°denting to-25 deg 9,320.0 9,340.0 6,155.4 6,170.1 A-3,1Y-30 1/31/1989 4.0 IPERF 25/8"Atlas SlimKon;180 PRODUCTION;9,120.3 -11 deg.pH ■ 9,374.0 9,390.0 6,195.5 6,207.5 A-2,1Y-30 1/31/1989 4.0 IPERF 25/8"Atlas SlimKon;180 deg.pH I. Mandrel Inserts LOCATOR;9.154.3 St PACKER;9,156.0 �' ati on Top(ND) Valve Latch Port Size TRO Run NTop(ftKB) (ftKB) Make Model OD(in) Sery Type Type (in) (psi) Run Date Com NIPPLE;9,170.2 - '1' 3,896.2 2,839.9 CAMCO KBUG 1 GAS LIFT GLV BK-5 0.188 1,281.0 4/7/2018 2 6,418.2 4,291.0 CAMCO KBUG 1 GAS LIFT OV BK-5 0.250 0.0 4/7/2018 11.1 3 7,973.1 5,257.3 CAMCO KBUG 1 GAS LIFT DMY BK-5 0.000 0.0 8/19/2016 SOS;9,177.4 . . 4 8,838.9 5,822.0 CAMCO MMG 11/2 GAS LIFT DMY RK 0.000 0.0 2/12/2006 5 9,120.3 6,012.9 CAMCO MMG 11/2 PROD DMY RK 0.000 0.0 1/6/2011 Notes:General&Safety End Date Annotation 7/8/2002 NOTE:WAIVERED WELL IA X OA COMMUNICATION (PERF;9,248.0-9,254.0- 10/29/2010 NOTE:View Schematic w/Alaska Schematic9.0 APERF;9,254.0.9,320.0 (PERF;9,320.0-9,340.0-• FISH;9,368.0 IPERF;9.37d.0-9,390.0.-. PRODUCTION;33.0.9572.8 0 lin - • '� b° Ts- a) ^ u M V NI v a) z t 0 --L - U N a) �, Nz g -, O Q p_ s 0CO t�m a) a) C0 HN C a) C .0 C a ! •` N- c) ro ♦- p .. • Y p v v j EC O CI -1 CIS0 + C Lu p_ C O p H co �--, f0 T c Q ^ o C ca Q Q t` ca O E ^ m 1- U U �, t J Z > 0 p O cE co c z N N '6 - 0_ j Q .. C C a N 0 r v � -C p @ r:":1 O a) J U.1 J J J C N u 6 0. -.I 1= � L F- op C ro O O Q I... Q Q Q Q Q O C 0 CIS fT1o 0, a Z Z Z C a, o U 5 O l 2 Uco 0 } vp .... 1r ] N U C0 a E a) a) O O c a a) C O -0 C1:3RU J LA Ti, v aQ, ? m LL LL pOOO _ a, C Q v p > u u Q ' a \ A u % > j o �i o or 2 a13 0 cu co v Q Z C w - 41 0 w O, ° �t 4R (-) N °5 � � � in www ar u > > > 4 ar Z Y Y Y E > > > 1 Ci La Q Q Q v s a a a L U • > > >LLI a H Y Y Y a 0 O 0 W...'F; M O c, X In 0 co co ao 0 0 ..-- CV O o 0 0 0. - W O O O ro W D O o v 0 cc Lc) O O O N sl 1 r I I I I I 1 I I ra 0o u) t, s n r"i ago u) v E N N N N -N O O N N N C p Ol O O O L. U O O O •L N to to CO « 3 K G O C C. Z m £ _ u U Qw Li tf) < p W a) •; y N _= F- `Fc ul Pe t'!1 Q I- M o coo a) 3 C- St Z a Z e- E to •a C a Q N W - - M 1 ,0 c a) , CL i r-1 .0 ^ C Z N �C H V C 0 c N o O �e/' a tD Q O1 'L � a a Q P )°3e Regg, James B (DOA) From: NSK Fieldwide Operations Supt <n2072@conocophillips.com> Sent: Wednesday, November 23, 2016 10:19 AM To: Bixby, Brian D (DOA); Regg, James B (DOA) i1CZ Cc: NSK Prod Engr Specialist ( l Subject: RE: Kuparuk 11Y-Pad Deficiency Report follow-up Attachments: 20161123103221.pdf; 20161123103153.pdf Brian, Jim, Attached is the completed deficiency report and supporting follow up information noting the following: • 1Y-17: No active leak could be identified after cleaning the area and checking the torques. • 1Y-29 and 1Y-30ySigns have been installed. Please let us know if there are any questions. Thanks NS JUN 2 " Z01 Scott Fahrney/Larry Baker NSK Fieldwide Operations Superintendent (907) 659-7042 From: NSK Prod Engr Specialist Sent: Friday, November 18, 2016 1:44 PM To: Bixby, Brian D (DOA) <brian.bixby@alaska.gov> Cc: NSK Fieldwide Operations Supt<n2072@conocophillips.com> Subject: Kuparuk I 1Y-Pad Deficiency Report follow-up Brian, Thank you for taking the time to stop in on Wednesday, it was a pleasure meeting you. The items you identified on 1Y- Pad are currently being addressed and we'll let you know when they're resolved. In the meantime don't hesitate to contact us if you have questions or need anything additional from us. Enjoy your time off! Cheers, Matt Matthew Raiche/Darrell Humphrey Production Engineering Specialist ConocoPhillips Alaska Ph:907.659.7535 I Pg:924 I Mail: NSK 69 1 ( y:3/C' pit (e'er State of Alaska Oil and Gas Conservation Commission 93g` ,(1.0Deficiency Report Location: ���4b 1VPAQiU K Date: , PTD: Operator: 6,0ficei, i � Type Inspection: DOperator Rep: 44eldRae, Inspector d4 141 � Position: proldio4 J j4(gfi e44e1 Op.Phone: Igo7� mf, 7535 Correct by(date): Op.Email: n /134e 7 0,406v iz;.* coM Follow Up Req'd: yes Detailed Description of Deficiencies Date Corrected W Ect i 1-47 czAde)E Poma+SK I�E�.wEAA ,4 , �� (t \J L l i-Z9 dabs, w7 ' or �al�.>L iI(73[1 / 1(123[1(1) � SR - 46u. I1•30 j htt VirCt xani S1r 116(11P 51Cr • Attachments: Operator Rep Signatures: 1 /16 AOGCC Inspector *After signing,a y of this form is to be eftuo• Ir. OP y Follow-up Instructions Return a copy of this Deficiency Report to AOGCC(Attention:Inspection Supervisor)within 7 days of receipt. Include the"Date . Corrected"and attach supporting documentation for each corrective action implemented to address the deficiencies. If a follow-up inspection was performed by AOGCC,include the date and name of Inspector. Extensions for corrective actions taking longer than the"correct by"date must be requested and accompanied by justification(Attention:Inspection Supervisor).Documentation of deficiences that are outside of AOGCC regulatory jurisdiction will be forwarded to the appropriate authority for follow-up action. Revised 2/2016 • • ConocoPhillips Alaska AOGCC EXCEPTION REPORT Location: 'A-D Date: m jb /(� AOGCC Inspect Jj t^tcvt �c xi"( Instructions:All exceptions listed below must be corrected within 7 days of receipt of this notification. Documentation of the work performed is to be entered into the'Action Taken'section below. Note-Failure to comply with these instructions may constitute a violation of SOA regulations and may be subject to enforcement action under 20 AAC 25.535 EXCEPTIONS NOTED: V)elk '"� . Flat1 lexil< 04 fid if ►le-ad &C'.eo1.o - Ixec (SID1 ✓L o use �1 We. U 1Y— 2`� WPP,JS e,1�.\bu..ce 5‘.7 15 IY —011— Wel{ 1Y-30 1.1e16 a Action Taken to Correct Problem: /7 NOV to D5ewvtt aiDLAJ F(ok+wifiebt couul F,ua0'Ct1. Or*e.- Date:o2QtJoJf6 Initials: /JS (/ f 7 z.40,4A1 D () C . tcToaau0-4ICWI'AV AV St4�l QC RC' YtD ` ` Date:Zo/JO t4 Initials: Y " ` �L L L 7.9 A*►D berlN4 sciv.seule to r.),04 5 tq ti1 t2e'Ce-ni,tLi ( I2. CgtVCpDate:2.o 404 ((o Initials: A)hie— I y- .&0 is heimy sd►a-dile i +b )&) 1 S io,,•" i" ,s4a la Date: Z3 pou l6 Initials: SRF f{ -3o 5 t w 1 45-g ((t4 Date: 23 ,u),.$ /4lnitials: SPF Date: Initials: Return completed form to Prod.Engr.Specialist: n1139conocophillips.corn Distribution: CPF DSLT CPF OPS Supv Prod. Engr. Specialist C.C. CPF1&2 Ops Supt CPF3 Ops& DOT Pipelines Supt NSK Fieidwide Operations Supt 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. I ~ ~_- 0 ~ 0 Well History File Identifier Organization (done) ~ Two-Sided RESCAN [] Color items: [] Grayscale items: [] Poor Quality Originals: [] Other: DIGITAL DATA Diskettes, No. [] Other, No/Type TOTAL pAGES: /D~~,- NOTES: ORGANIZED BY: BEVERLY BREN VINCENT SHERYL MARIA LOWELL DATE: OVERSIZED (Scannable) [] Maps: [] Other items scannable by large scanner OVERSIZED (Non-Scannable) [] Logs of various kinds [] Other Isl Project Proofing [] By: Staff Proof Date: PROOFED BY: BEVERLY BREN VINCENT SHERYL MARIA LOWELL DATE: Is~ PAGES:/0~' (at the time of scanning) SCANNED BY.' BEVERLY BREN VINCENT SHERYL(~LOWELL DATE: Is~ tYlP RESCANNEDBY: BEVERLY BREN~SHERYL MARIA LOWELL General Notes or Comments about this file: Quality Checked (done) RevlNOTScanned.wpd • • WELL LOG TRANSMITTAL To: Alaska Oil and Gas Conservation Comm. January 25, 2011 Attn.: Christine Shartzer 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 AtthifiNED MAR 3 21W RE: Production Profile: 1Y -30 Run Date: 1/1/2011 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 1Y -30 Digital Data in LAS format, Digital Log Image file, Interpretation Report 1 CD Rom 50- 029 - 21851 -00 Production Profile Log 1 Color Log 50- 029 - 21851 -00 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND 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 j Fax: 907 - 273 -3535 00ga0 rafael.b ,t. rtbr ft0 E7 �' Date: FEB �% 2011 Signed: Masks Oil & Gas Cons. C -;,mm of ion roy Page 1 of 1 Regg, James B (DOA) From: NSK Problem Well Supv [n1617@conocophillips.com] ~~~ Z~t~o~l~ Sent: Saturday, February 13, 2010 2:08 PM To: Maunder, Thomas E (DOA); Regg, James B (DOA); Schwartz, Guy L (DOA) Cc: NSK Problem Well Supv Subject: 1Y-30 (PTD 188-090) Report of failed TIFL Attachments: 1Y-30 schematic.pdf ~ ~-~~~.~t~ ~~~ ~ ~y ~~ ~(' Tom, Jim, Guy Kuparuk gas lifted producer 1Y-30 (PTD 188-090) failed a diagnostic TIFL on 02/12/10. The well was SI prior to testing and the TIO was 1780/1680/1400. A leaking GLV is suspected to be the source of the leak. Slickline will troubleshoot and repair if possible. Attached is a 90 day TIO plot and schematic. '~ ~~~ ~-S I~~~~ CPT Please let me know if you have any questions. ~ ~'~-~~~ ~r .~ ko~ ~l n1,f ~,.~ ~ C°~~h Brent Rogers/Martin Walters Problem Wells Supervisor ConocoPhillips Alaska, Inc. Desk Phone (907) 659-7224 Pager (907) 659-7000 pgr. 909 C~h, J5S`~ 2~'~pF~ ~ 1~~~~; ~`~'~~` 3~~?`~~ 3 ` ~~~a~', .iSS, ~~PP~~ ~~ f~~ ~35~~; ~,'t `~~ce ~4~( o ~ p~- C,t? ~[L~- ~ 1 LPG 2/ 16/2010 KRU 1Y-30 PTD 188-090 2/13/2010 TIO Pressures 3000. SC 3000 200. 3000. 3000. 2700 3000. ;i[i00. 3000 2400 . 2100 1800 1500 1200 900 0. 0. 0. 0. 0. 0. o. 600 300 0 PLOT START TIME MINOR TIME ~:->~,rl~ ?9 ti->TifJN PLOT I'.-i7P. ~T'IME 15-NOV-09 14:10 MAJOR TIME WEEK +02160:00:00 HR513-FEB-10 14:10 PICK TI1+~: 13-F EB-10 14:05:46 ;C TAG HARE DESCRIPTION 'x,iiif( T_ATEST ~ WL1Y-30-CHORE FLOW TUBING CHOKE ?l~???'? ~ SCRATCH 47 FLOW TUBING PRESSURE ??????? SCRATCH_47 FLOW TUBING TEMP ??????? ~ AI-PIYSOD2-30 GL CASING PRESSURE ??????? ??????a ??????? ~ SCRATCH 47 iNlIF.I? h17N[JLUS PRES 777777 SCRATCH_47 OUTER ANNULUS PRES ??????? ~~ PREV WELL DRILLSITE WELL ly 30 NEXT WELL .-*~"",°' '"`"'r OPERATOR ~ OPERATOR VERIFIED ~ _;YSTEM AUTO ENTRY ~ BOTH WELL NAME WLKRUlY-30 ,~~ ~~ KU P 1 Y-30 T!"tOCOP~11~~~ f P S '~ ~ ~ Well Attnbut_es _ Max An le & MD TD~-I . ~ V Jellbore API/UWI Fleltl Name well Status lncl (°) MD (ttKB) Act Btm (ttKB) '.. ~' "`^"~ ~ "~ 00292185100 KUPARUK RIVER UNIT PROD 58.08 3,600.00 9,595.0 "' ._..__._._..__. Comment H2S (ppm) SSSV:NIPPLE 80 Date 7/2/2007 Annotation Last WO: End Date 4/22/1995 KB-0rd (ft) 39.99 Rig Relaase Date 10/18/1988 __.__._ Wall Co,nlg_~ 1Y-30 10 Sc emanc 29/009 3.3321 PM -Actual Annotation Depth (ttKB) End Date Annotation Last Mod By End Date Lasl Tag. SLM 9,358.0 10/23/2009 Rev Reason: TAG, GLV C/O, PULL CAT SV Imosbor / Casin Strin s 9 ~ ~ ~, I ~ Casing Description ~ String OD 11^I String ID 0^) - - Top IRKB) Set Depth (ttKB) Set Depth (TVD) (ttKB) Strang Wt (lbalft) String Orade String Top Thrd coNDUCroR. 115 ~ ~ CONDUCTOR 16 15.062 0.0 115.0 115.0 65.00 H-40 [j , III( ~ SURFACE 95/8 8.765 0.0 5,158.0 3,553.3 36.OO J-55 '~... ~ PRODUCTION 7 6.151 0.0 9,573.0 6,346.9 27.00 J-55 NIPPLE, 486 ~ ~ TUI)In~^Jtrin~s _-__~ __ T..__.__._._~ ~ - ~ Set Depth Set Depth (ND) String Wt String 'String OD String ID Tubing Deacrl tlon li^) 0^) Top ttKB) (ttKB) (ttKB) (lba/R) Orade Strin Top Thrd 1 TUBING 312 2.992 0.0 7,980.0 5,261.7 9.30 J-55 EUE8RDABM GnsLIFr, ~ LJ TUBING 31/2 2.992 7,980.0 9,153.0 6,035.9 9.30 E-80 EUE8RDABM 3.as6 "~ TUBING 27/8 2.441 9,153.0 9,178.0 6,053.3 6.50 J-55 EUE8RDABM Other In Poem All Jewelry: Tubin Run & Retrievable, Fish, etc.) __ ' T SURFACE, 5158 ~ (ND) Top Inc! Top IRKB) IRKB) (°) Descriptlon Comment Run Date ID (in) 486 487.5 6.43 NIPPLE Camco'DS' 4/22/1995 2.812 GnsuFr, 1 u=,~ 3,896 2,839.8 56.95 GAS LIFT CAMCOMBUG/1/GLV/BK-5/.125/1304/Comment: STA 1 6/5/2005 2.920 6,4 6 --..~+ 6,418 4,290.9 52.94 GAS LIFT CAMCO/KBUG/1/GLV/BK-5/.156/1332/Comment:STA2 6/52005 2.920 ~I 7,973 5,257.2 50.27 GAS LIFT CAMCO/KBUG/1/OVBK-5/.25// Comment: STA 3 2/122006 2.920 ~ ~~ 8,839 5,822.5 48.70 GAS LIFT CAMCO/MMG/1.5/DMY/RK/.25//Comment: STA 4 2/122006 2.920 GAS LIFT, 7,973 L ~ 8,923 5,878.2 47.84 PBR Baker 80-40 w/ 10' Stroke 4/22/1995 3.000 8,936 5,887.0 47.71 PACKER Baker'FHL' 4/22/1995 2.992 ~ ~ 9,120 6,012.7 46.02 PRODUCTION CAMCO/MMG/1.5/CV/RK///Comment: STA 5 1024/2009 2.920 I" 9,156 6,038.0 45.48 PACKER TIW'SS'Penn. 422/1995 3.250 ~ 170 9 047 7 6 45 27 NIPPLE Otis'XN' NIPPLE 2.31" x 2.25" NO GO 422/1995 2.250 ~ ~ , . , . FT GAS ~ ' - 9,177 6,052.6 45.17 SOS Baker 422/1995 2.441 B B ~ fit; g,178 6,053.3 45.15 TTL ELMD TTL @ 9178' during Packer/TT Set Record on 422/1995 2.441 422/1995 r Perforations & Slots _~! - -- -- ~_ --- - -T - -- Shot PBR, 8,923 1 Top (ND) Btm (ND) ~^a 4 To IRKB Btm (ftK8 IRKB) (ftK8) Zone Data lah••~ Type Comment 8,985 9,070 5,920.0 5,978.3 U NIT 4, C-4, C-3, 1020/1990 12.0 APERF 2 1/8" AUas Silver; 60 deg. pH 1 Y-30 r_- PACKER, 8,936 y"'yl!- yam. 9,080 9,110 5,985.1 6,005.8 C 1 -1, UNIT 8, Y 30 1020!1990 12.0 APERF 2 1/8" Atlas Silver; 60 deg. pH t '- - " 9,248 9,254 6,103.6 6,107.8 A -5, 1Y-30 1/31/1989 4.0 IPERF 2 5/8" AUas SlimKon; 180 deg. pH ~ 9,254 9,320 6,107.8 6,155.4 A -5, A-0, A-3, 824/1990 8.0 APERF 2 12"Titan guns; 180 deg. pH; APERF, 1 Y-30 Orienting to -25 deg 8.985-9,070 9,320 9,340 6,155.4 6,170.4 A -3, 1Y-30 1/31/1989 4.0 IPERF 25/8"Atlas SlimKon; 180 deg. pH ~ i 9,374 9,390 6,195.5 6,207.5 A -2, 1Y-30 1/31/1989 4.0 IPERF 25/8"Atlas SIimKOn; 180 deg. pH ' ~~ Notes: General 8 Safe ER ~ End Date Annotation s D a o ~ ~ ~ 7/8/2002 NOTE: WAIVERED WELL IA X OA COMMUNICATION PRODUCTION, 0 I I I r ~"+~ J ' 9,12 Z ~ f ~ PACKER, 9.166 ~' }~ 6_i ~..4 J w NIPPLE, 9,170 I SOS, 9,177 t TTL, 9,178 I IPERF, , 9,248-9,254 APERF, , 9,250.9,320 IPERF, , 9:32Q9,340 IPERF, . 9,374-9.390 PRODUCTION. 9,573 TD, 9,595 • ConocoP h~~lips A~ska P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 August 17, 2008 Mr. Tom Maunder Alaska Oil & Gas Commission 333 West 7~' Avenue, Suite 100 Anchorage, AK 99501 Dear Mr. Maunder: R~CE~VE® AUG 2 5 2008 Alaska Oil & Gas C ans. Co~n,;,sion Ancharage ~~ Enclosed please find a 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 cement if needed and 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 corrosion inhibitor/sealant was pumped August 2-17, 2008. The attached spreadsheet presents the well name, top of cement depth prior to filling, and volumes used on each conductor. Please call MJ Loveland or Perry Klein at 907-659-7043, if you have any questions. Sincerely, Perry Kle .~ - U ~ Z ~~C~ ~ ConocoPhillips Well Integrity Projects Supervisor g~~~~~ AU G ~ ~ 20t~8 • ConocoPhillips Alaska Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10-404) '.,,..~ n~+o Kuparuk Field ell Name TD # - ---- Initial top of cement Vol. of cement um ed Final top of cement Cement top off date air Corrosion inhibitor n~uus Corrosion inhibitor/ sealant date 2H-05 185-168 ft SF bbls N/A ft SF N/A al 5.10 8/2/2007 2H-17 200-019 6" N/A 6" N/A 1.27 8/2/2007 2K-27 201-169 10" N/A 10" N/A 8.92 8/2/2007 2M-03 191-141 16" N/A 16" N/A 2.13 8/2/2007 1 B-14 194-030 SF N/A SF N/A 1.70 8/13/2008 18-18 194-061 9" N/A 9" N/A 8.07 8/13/2008 1 B-19 194-064 SF N/A SF N/A 5.10 8/13/2008 16-20 203-115 21" N/A 21" N/A 5.95 8/13/2008 1 B-101 203-133 3" N/A 3" N/A 1.00 8/17/2008 1 B-102 203-122 4" N/A 4" N/A 1.00 8/17/2008 1 Y-05 183-087 6" N/A 6" N/A 1.27 8/13/2008 1 Y-07 183-068 6" N/A 6" N/A 1.27 8/13/2008 1Y-17 193-068 SF N/A SF N/A 1.27 8/13/2008 1Y-22 193-070 SF N/A SF N/A 2.12 8/13/2008 1Y-26a 188-116 SF N/A SF N/A 3.83 8/13/2008 1Y-30 188-090 SF N/A SF N/A 3.83 8/13/2008 1 E-112 204-091 14" N/A 14" NIA 5.95 8/17/2008 1 E-119 204-031 14" N/A 14" N/A 4.67 8/17/2008 1 E-121 204-246 6" N/A 6" N/A 1.00 8/17/2008 1 E-123 204-074 5" N/A 5" N/A 1.00 8/17/2008 MEMORANDUM State of Alaska Alaska Oil and *Gas ConserVation Commission TO: Julie Heusser, '~&x~.~k~'\ DATE: Commissioner Tom Maunder, P. I. Supervisor THRU: FROM: SUBJECT: John Crisp, Petroleum Inspector May 17-18, 2001 Safety Valve.Tests Kuparuk River Unit :I:Y Pad May 17 & 18. 2001: I traveled to Phillips Alaska's Kuparuk River Field to witness Safety Valve System tests. Ernie Barndt was Phillips Rep. in ·charge of SVS testing. Testing was conducted in a safe & efficient manner. ! witnessed one failure, the LPP failed to trip above 50% of primary separator pressure. The pilot was re-tested & passed the re-test.' The AOGCC test report is attached for reference. I conducted 25 well house insPections on 1Y Pad. The majority of the houses were in good shape wi no problems witnessed. Well houses # 30 & 22 were found w/the well house lids resting on the tree cap gauges. The VSM for the 'flow line on well # 29 looked as if it had shifted up & had the line in a slight bind. I asked Phillips Rep. Pete Nezaticky to inspect this line. Prudhoe Bay Field has had problems wi VSM's shifting up & I wanted to make sure KRU Rep's were aware of this problem. SUMMARY: I witnessed SVS testing in Kuparuk ·RiVer Field. 16 wells, 32 components tested. 1 failure witnessed. 3.13% failure rate. 25 well house inspections conducted. Attachments: SVS KRU 1Y 5-17 & 18-01jc CC; NON-CONFIDENTIA. L, SVS KRU IY 5-17 & 18-01jc A~as~ Oil and Gas Conservation Commission Safety Valve System Test Report Operator: Phillips Alaska Operator Rep: Emie Barndt AOGCC Rep: John Crisp Submitted By: J0,.hn CdS, ,p Date: 5/17 & lS/01 Field/Unit/Pad: Kupantk RD~r'Unit 1Y Pad Separator psi: LPS 85 HPS Well Permit Separ Set L/P Test Test Test Date Oil, WAG, GIN J, Number Number PSI PSI Trip Code Code Code Passed GAS or ¥-oi 3o5oO , 1Y'02 1830590 1y.03 1830610 3750 2006 " 1800 P P WAG 1Y-04 183'0660 .... 1Y-05 1830870 1y'06A 1971340 '85' 70 55 P 'P OIL 1Y-07 1830680 1Y-08 1830620 1Y-09 1830520 1Y-10 1830510 37~0 ' 2000 '1'750 P P .... W)kG 1Y-11 1830410 1Y-12 1830260 830 50 ..... , . , 1 Y- 14 1830230 1Y-15A 1981860 85 70 50 P P OIL 15"-16 1830420 " 1Y-17 1930680 85 60 60 'P P OIL 1 Y- 18 1931060 1 Y- 19 1931070 85 60 65 P P OIL 1Y-21 1931020 85 70 65 P P OIL 1Y-22 1930700 85 60 55 P P OIL 1Y.23 ' '1930710 85~ 70 28 3 P 5/18/0i OIL 1Y-24 1930720 85 70 78 P P OIL , 1Y-25 1880890 1Y-26A 1881160 85 70 50 P p OIL 1Y-27 193'0880 ~t5 70 64 P 'P OIL 1 Y-28 1930890 880'910 85 70 60 P 'P .... OiL ~ 85 70 7,0 P ,P , OIL ;1Y-31 1930900 1Y-32 '1880930 .... 85 ~ 70 70 P P " ' OIL 1Y-34 1930910 85 70 65 P P OIL Wells: 16 Components: 32 Failures: .... 1, Failure Rate: 3. ~ 3% ~ 90 ray SVS g__o~J !y 5-!?,& !8-O!j--_ ,, ~e# Permit Sep~ Set L/P Test Test Test D~te- oil, w~, ~J. Number Number PSI PSI T,rip Code Code COde Passed GAS or CYCLE RJF 1/16/01 Page 2 of 2 SVS KRU 1Y 5-17 & 18-01jc ARco Alaska, Inc. Post Office Box 100360ff"~ Anchorage, Alaska 995~, ,660 Telephone 907 276 1215 MaY 24, 1995 Mr. David J. Johnston Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Subject: 1Y-30(Permit No. 88-90) Well Recompletion Report Dear Mr. Commissioner: Enclosed is the well recompletion report for the recent workover operations on KRU iY-30. This workover was performed to recomplete the well as a selective single to isolate the 'C' sand. Sincerely, W. S. Isaacson Drilling Engineer WSI/skad STATE OF ALASKA A~SKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG I Status of Well Classification of Service Well OIL ~] GAS r'-] SUSPENDED [~ ABANDONED [] SERVICE r~ 2 Name of Operator 7 Permit Number ARCO Alaska,Inc ~.~'~ ~r:.8~e0 3 Address 8'=-.~:API Number P.O. Box 100360, Anchoracje, AK 99510-0360 50-029-21851 4 Location of well at surface ? ~ - · - · 9 Unit or Lease Name 208' FNL, 1164' FWL, Sec. 1, T11N, R9E, UM~i ¥.tr~Ft,~D ~.~.~ .~! ~,,OCA~ Kuparuk River Unit At Top Producing lnterva,! ~'/~/--~ 'i~--~i 10 WellNumber 80' FSL, 2169' FEL, Sec. 35, T12N, R9E, UM~ ~-.~;A' 1Y-30 At TotalDepth !i~..~..~ 11 Field and Poo, 253' FSL, 2419' FEL, Sec. 26, T12N, R9E, UM ~ ,.~ KUPARUK RIVER 5 Elevation in feet (indicate KB, DF, etc,) I 6 Lease Designation and Serial No, 102' RKB 67' Pad ADL 25641 ALK2572 12 Date Spudded 13 Date T.D. Reached 14 Date comp., susp. or Abend, 15 Water Depth, If offshore 116 No, of Corn plettons Oct 8 1988 Oct 15 1988 27-NoV~88 : NA feet MSLI 1 17 Total Depth (MD+TVD) 18 Plug Back Depth (MD+TVD) 19 Directional survey 120 Depth where SSSV set 21 Thickness of permafrost 19595' U D & 6363' TVD 9486' U D & 6280' TVD : 'YEs :~ NO ~I NA feet MD 1300' APPROX 22 Type Electric or Other Logs Run DIL,S FL,G R,CAL,SP, FDC,CNL,CBL, GYRO 23 CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE w'r GRADE TOP BTM HOLE SIZE CEMEN]' F~CORD 16" 62.5# H-40 SURF 115' 24" 181 SX ASll 9-5/8" 36# J-55 SURF 5158' 12.75" 1150 SX ASlII & 450 SX CLASS G 7" 26# J-55 SURF 9573' 8.5" 260 SX CLASS G 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) 3-1/2', 9.3#, J-55 9178' 8936' & 9156' 12 SPF 8985' - 9070' M D 5920' - 5978' TVD 12 S PF 9080' - 9110' M D 5985' - 6005' TVD 26 ACID, FRACTURE, CEMENT SQUEEZE, ETC 4 SPF 9248' - 9340' MD 6103' - 6170' TVD (squeezed in 1990) DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 4 SPF 9374' - 9390' M D 6195' - 6206' TVD (squeezed in 1990) 4 SPF 9254' - 9320' MD 6107' - 6155' TVD (selective repert) 27 PRODUCTION TEST Date First Production IMethod of Operation (Flowing, gas lift, etc.) I Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE I GAS-OIL RATIO I TEST PERIOD 1:3 Flow Tubing Casing Pressure CALCULATED OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press. 24-HOUR RATE 1:3 28 CORE DATA Brief description of lithology, porosity, fraclures, apparent dips and presence of oil, gas or water. Submit core chips. RECEIVEO MAY 25 1995 Alaska 0ii & Gas Cons. Commission Anchorage Form 10-407 Submit In duplicate Rev. 7-1-80 C,(]~INUEDON REVERSESlDE 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 8987' 5921' BOTTOM KUPARUK C 9107' 6003' TOP KUPARUK A 9240' 6097' BOTTOM KUPARUK A 9394' 6210' 31. LIST OF A'I-rACHMENTS 32. I hereby certify that the foregoing is true and correct to the best of my knowlege. Signed 'L~'~ h . ~'~.~.~..~,-.,-...-.- Title O~.~.t.,[.r,l(,_ ['t,,l(...[t.,,t~,[~ DATE ~'' ~ ~' c~ 5 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:05/23/95 Page: 1 ARCO Alaska Inc. DAILY DRILLING REPORT REMEDIAL AND COMPLETION OPERATIONS RECEIVED MAY 2 5 ]995 Alaska 0il & Gas Cons. Commission Anchorage WELL:iY-30 WELLID: 998398 AREA/CNTY: FIELD: SPUD: AFE: 998398 START COMP: RIG:NORDIC WI: 0% SECURITY:0 TYPE:DEV AFE EST:$ OM/ OM STATE: API NUMBER: FINAL': 04/14/95 ( 1) TD: 9595' PB: 9486' SUPV:CJF 04/15/95 (2) TD: 9595' PB: 9486' SUPV: 04/16/95 (3) TD: 9595' PB: 9486' SUPV: 04/17/95 (4) TD: 9595' PB: 9486' SUPV:CFJ 04/18/95 (5') TD: 9595' PB: 9486' SUPV:CFJ 04/19/95 (6) TD: 9595' PB: 9486' SUPV:CFJ 04/20/95 (7) TD: 9595' PB: 9486' SUPV:CJF 04/21/95 (8) TD: 9595' PB: 9486' SUPV:CJF PREP TO KILL WELL MW:12.4 VISC'D BRINE Move rig from 2Z-12. Accept rig @2100 hrs 4/14/95. Kill well and freeze protect flowline. DAILY: $65,721 CUM: $65,721 ETD: $0 EFC: $65,721 WORK TBG, ATT. PULL OUT O MW:12.4 VISC'D BRINE Kill well. Set BPV, Nipple down tree and nipple up BOPE. Test BOPE. DAILY:S62,567 CUM:$128,288 ETD:SO EFC: $128,288 KILLING WELL MW:12.4 VISC'D BRINE Work stuck pipe and RIH w/chem cutter. Cut 3-1/2" tbg. Kill well. DAILY:S83,178 CUM:$211,466 ETD:SO EFC:$211,466 POH & LD 4" TBG MW:12.4 VISC'D BRINE Spot pill to kill well. LD 4" tbg. POH w/4" tbg. DAILy: $49,959 CUM: $261,425 ETD:S0 EFC:$261,425 POH W/3-1/2" TBG MW:12.6 VISC'D BRINE POH to joint above SSSV & LDD 4" tbg. CL balling up in BOPs. Unable to work SSSV thru CL obstruction in BOP. Fish balled up control line from BOP stack. POH LD 4"tbg. DAILY:S35,365 CUM:$296,790 ETD:SO EFC:$296,790 POH W/OVERSHOT & FISH MW:12.6 VISC'D BRINE POH w/3-1/2" tbg. Chem cut tbg end clean. RIH w/fishing ass'y on 3-1/2" DP. While jarring up, fish came free. POH slowly w/fishing assembly. DAILY:S44,478 CUM:$341,268 ETD:SO EFC:$341,268 FISHING PACKER W/SPEAR MW:12.6 VISC'D BRINE POH w/O/S & fish. RIH w/ O/S fishing ass'y. Fish pulled free. POH w/ O/S ass'y and fish. DAILY:S33,614 CUM:$374,882 ETD:SO EFC:$374,882 RIH W/MILL & CSG SCRAPER MW:12.6 VISC'D BRINE Fish packer. POH w/ packer and tail pipe ass'y. DAILY: $34,563 CUM: $409,445 ETD:SO EFC: $409,445 STATE OF ALASKA OIL AND GAS CONSERVATI~ C(~M~o,~ION REPORT OF SUNDRY WELL OPERATIONS 1 Operations Performed: Operation Shutdown Stimulate X Plugging Perforate /~.~/~ Pull tubing Alter casing Repair well Other 2. Name of Operator 5. Type of Well: 6. Datum elevation (DF or KB)~//~' ARCO Alaska. Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510 Development X Exploratory _ Stratigraphic _ Service 4. Location of well at surface 208' FNL, 1164' FWL, Sec. 1, T11N, R9E, UM At top of productive interval 80' FNL, 2169' FEL, Sec. 35, T12N, R9E, UM At effective depth 196' FSL, 2378' FEL, Sec. 26, T12N, R9E, UM At total depth 253' FSL, 2419' FEL~ Sec. 26~ T12N~ R9E, UM 12. Present well condition summary Total Depth: measured 9 5 9 5 feet true vertical 6363 feet FIKB 102 7. Unit or Property name Kuparuk River Unit 8. Well number 1Y-30 9. Permit number/approval number 88-90/90-384 10. APl number 50-029-21851 ;. 11. Field/Pool Kuparuk River Field/Oil Pool Plugs (measured) None Effective depth: measured 9 4 8 6 feet true vertical 6280 feet Junk (measured) None Casing Length Structural Conductor 8 0' Surface 51 2 3' Intermediate Production 9 5 4 0' Liner Perforation depth: measured 8985'-9070', true vertical 5920'-5978', Tubing (size, grade, and measured depth) Size Cemented Measured depth True vertical depth 1 6" 9 5/8" ,1 181 SXASI 115' 115' 1150 SX AS III & 51 58' 3553' 450 SX Class G, Top job w/100 SX AS I 260 SX Class G 9 5 7 3' 6 3 4 6' g080'-9110', 9248'-9340', 9374'-9390' RECEIVED 5984'-6005', 6103'-6170', 6196'-6208' J U L 2 3 4", 11#, J-55 @ 4028'; 3.5", 9.3#, J-55 @ 4028'-8842' Packers and SSSV (type and measured depth) PKR: Baker HB ~ 8750'; SSSV: AVA @ 1786' 13. Stimulation or cement squeeze summary 14. &laska 0il & Gas Cons. Commission ncl{0ragel Refractured "A" sand on 9/26/90 and perforated "C" Sand @ 12 SPF on 10/19-20/90. Intervals treated (measured) "A" Sand @ 9240'-9394'; Perforated "C" Sand @ 8985'-9070', 9080'-9110' Treatment description including volumes used and final pressure Frac - pumped 62,660 lbs of 16/20 carbolite and 1299 Bbls of fluid; 3545 psi on 7". Reoresentative Daily Average Production or Injection Data OiI-Bbl Gas-Mcr Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 1000 550 200 1150 150 Subsequent to operation 4500 3000 2500 1 150 225 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations X 16. Status of well classification as: Oil X Gas Suspended~ Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Form 10-404 Rev 06/15/88 Title SUBMIT IN DUPLICATE ARCO Alaska, Inc~~, Subsidiary of Atlantic Richfield compan~l,i~ i~ ) WELL /Y-3O CONTRAC'I'OR IPBDT qq$O/ REMARKS ~E,q_,cO~O,q TE WELL SERVICE REPORT FIELD-DISTRICT-STATE IDAYs IDATE OPERATION AT REPORT TIME oq'vs' //dO //5*8 Iq30 ~Gl0 /4,:75- ~ST~.T POO fl. 1705 i ?,~ --/$16--' 1333 o~m~T~Y'~b ,30 o t~+=T) 7-/~ /,4/. us'ixJG [~/CHECK THIS BLOCK IF SUMMARY CONTINUED ON BACK Report °F °FI miles IWind Vel. Signed knot, ARCO Alaska, Inc SubsidiarY of Atlantic Richfield Company WELL IPBDT WELL SERVICE REPORT IFIELD - DISTRICT- STATE DAYS I DATE d~NTRACTOR //.~y, uE' IOPERAT~ON AT REPORT TIME REMARKS PGE,'/-/ 1~¢5' I ~7/'7 / ~,~C -- / ¢.~'o ~ I E;/5 I.~_ . ' e !VED J~'CHECK THIS BLOCK IF SUMMARY CONTINUED ON BACK ~i.~,~u._..,. ~il & 6as Cons. Comm'tss'to]~ ,, ~ch0rage WeatherReport J Temp. IChill Factor J Visibility OF °Fi miles JWind Vel. knots J signed ,4RCO Alaska, Inc. ~) Subsidia~, of Atlantic Richfield Compar~ WELL , ijPBDT IY- ~_ I 9¢~o' CONTRACTOR REMARKS JFIELD - DISTRICT- STATE OPERATION AT REPORT TIME · 'ELL SERVICE REPORT / ?6V R'ECEIVED J U L 2 3 199~ Alaska .0il & Gas Cons. 6ommissio~ Anchorage I--I CHECK THIS BLOCK IF SUMMARY CONTINUED ON BACK ~ knotsl ~ i:~.~ i STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation Shutdown __ Pull tubing X Alter casing Stimulate __ Plugging Perforate Repair well Other m 2. Name of Operator ARCO Alaska. Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510 4. Location of well at surface 208' FNL, 1164' FWL, Sec. 1, T11N, R9E, UM At top of productive interval 80' FSL, 2169' FEL, Sec. 35, T12N, R9E, UM At effective depth 196' FSL, 2378' FEL, Sec. 26, T12N, R9E, UM At total depth 253' FSL, 2419' FEL, Sec. 26, T12N, RgE, UM 5. Type of Well: Development Exploratory Stratigraphic Service 6. Datum elevation (DF or KB) 102' RKB 7. Unit or Property name Kuparuk River Unit 8. Well number 1Y-30 9. Permit number/approval number 88-90/9-851 10. APl number 50-029-~1 ~51 11. Field/Pool Kuparuk River Oil Pool feet 12. Present well condition summary Total Depth: measured true vertical Effective depth: measured true vertical 9595' 6363' 9486' 6280' feet Plugs (measured) feet feet Junk (measured) feet None 0 R ~perf~g!n~.~t21~ md Tubing conveyed Casing Leng~ Structural 8 0' Conductor Surface 5 72 3 Intermediate Production 9 5 4 0' Liner Perforation depth: measured Size 1 6" Cemented Measured depth True vertical depth 181 SxAS II 115' md 115' tvd 9-5/8" 11 1050 sx AS III 5158' md 3553' tvd 450 sx Class G & Top Job w/ 100 sx AS I 260 sx Class G 9573' md 6346' tvd 9254' - 9320' true vertical 6107' - 6156' Tubing (size, grade, and measured depth) 3-1/2", 9.3#, J-55 TBG W/ TAIL @ 8842' Packers and SSSV (type and measured depth) Baker "HB" Pkr @ 8768', AVA Sideguard SSSV @ 1797' 13. Stimulation or cement squeeze summary Intervals treated (measured) Treatment description including volumes used and final pressure 14. Reoresentative Daily Average Production or In!ection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation Subsequent to operation 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations X 16. Status of well classification as: Water Injector ~ Oil X Gas Suspended Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. SignedForm "1'~~404~R~~ ~/~05/17/89 Title Area Drilling Engineer Date ~1~~0 ~.~ SUB'lIT it(I DUPLICATE (~ ARCO Oil ~d Gas Company Well History - Initial Report - Daily Instructions: 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 ARCO ALASKA INC. Field KRU Icounty, parish or borough NORTH SLOPE Lease or Unit ADL: 25641 ALK: 2572 Title WORKOVER IState AK no. 1Y-30 Auth. or W.O; no. Operator ARCO Spudded or W.O. begun SPUD Date and depth . as of 8:00 a.m. 05/27/90 ( TD: 9595 PB: 9486 SUPV:DEB 05/28/90 ( TD: 9595 PB: 9486 SUPV:DEB 05/29/90 ( TD: 9595 PB: 9486 SUPV:DEB 05/30/90 ( TD: 9595 PB: 9486 SUPV:GB 05/31/90 ( TD: 9595 PB: 9486 SUPV:GB JDate10/8/88 ~4:00 2) 3) Complete record for each day reported NORDIC 1 ]ARCOW.,. 55. 8533 Prior status if a W,O, POH W/ DV - SLICKLINE MW:11.8 NaCl/Br MOVE RIG FROM 1Y-11 TO 1Y-30, LEVEL RIG, RU HARD LINE TO TANK AND KILL LINES, OPEN SSV AND SSSV, PULL BPV, RUN OTIS SLICKLINE, RIH TO PULL DV FROM GLM @ 8688', POH W/ DV DAILY:S20,709 CUM:$20,709 ETD:S20,709 EFC:$680,000 POH - LD 4" TBG MW:ll.9 NaCl/Br FINISH POH W/ DV, RU LINES TO KILL WELL, CIRC. 11.8 PPG MUD TO GLM @ 8688', PULL BPV, TST BOPE, PULL TP, MU LNDG JNT, BOLDS PULL HNGR TO FLOOR,. POH W/ 4" TBG AND AVA SSSV, CL BIRD NESTED AT TOP OF SSSV, RECOVERED ALL CL, RECOVERED 12 TO 14 OUT OF ORIGINAL 27 CL BANDS, CONT. POH, LD 4" TBG, STRAP AND DRIFT TBG DAILY:S40,058 CUM:$60,767 ETD:S60,767 EFC:$680,000 MW:11.9 NaCl/Br CONT. POH W/ 4" TBG, POH W/ 3.5" TBG, RU FLOOR TO RUN DP, MU BOT PBR/PKR RETRIEVING TOOL/JARS/BUMPER SUB. RIH ON 4.75" DC AND 3.5" DP, LATCH PBR/PKR AT 8729' DPM, RELEASE PKR, POH SLOW DAILY:S30,375 CUM:$91,142 ETD:S91,142 EFC:$680,000 RU OTIS SLICK LINE MW:12.2 NaCl/Br FINISH POH W/ PKR ASSY. ON DP, MU BIT #1RR, RIM, TAG FILL @ 9242' NORDIC RKB, DRILL 9242'-9265', CIRC., DRILL 9265'-9468', CIRC. HOLE CLEAN, POOH, RU OTIS SLICK LINE DAILY:S40,763 CUM:$131,905 ETD:S131,905 EFC:$680,000 CIRC., PREP. FOR SQUEEZE MW:11.9 NaCl/Br RU OTIS SL, MU 5.5" GR, RUN GR TO 9455' WLM, POOH LD GR, MU KINLEY CALIPER, RIH TO 9455' WLM, LOG UP TO 8400', POOH, KINLEY CALIPERS FAILED, W/O CALIPERS, RIH W/ CALIPERS, TO 9445' WLM, LOG UP TO 8400', CALIPERS FAILED, RIG DOWN OTIS SL UNIT AND KINLEY CALIPERS, RU TO RIH W/ 2-3/8" TBG STNGR ON 3.5" DP, PU HOWCO PLUG CATCHER SUB, RIH TO PBTD, CIRC., RU DOWELL FOR SQUEEZE #1 DAILY:S34,145 CUM:$166,050 ETD:S166,050 EFC:$680,000 06/01/90 ( 6) DRILLING CEMENT MW: 11.9 NaCl/Br TD: 9595 CIRC., FINISH RU DS, MIX 137 SX CMT, ESTABLISH INJ. RATE 2 PB: 9486 BPM AT 1450 PSI, PUMP 25 BBLS WATER, 28 BBLS CMT, 3 BBLS SUPV:GB H20, DROP WIPER DART, PUMP I BBL H20, 50 BBLS GEL MUD, 9 BBLS H20, LATCH DART IN PLUG CATCHER, LD HOWCO PLUG HEAD· PU ON DP, DP STUCK IN HOL~, PULL 300K#, POH 4 STDS DP, PUMP 7.5 .' .... . _,_:? .... .~ ~_N/.."'jI~IR AND SQUEEZE 4.5 BBLS TO C.'.;~', ~i' hL~ ~--~S.. SET, PULL 8 STDS DP, CLOSE ANNULAR AND SQUEEZE AWAY 10 BBLS, SHUT DOWN 15 MINUTES, SQUEEZE AWAY 18 BBLS, WOC, PUMP DRY JOB AND POOH, RECOVERED ALL STRING, TIH W/ DP, CIRC.· TST CSG TO 2000 PSI, PRESS. BLEEDS BACK TO 1000 PSI IN 5 SEC., .............. ' The above is correct c see Procedures Manua'~, Section 10, Drilling. Pages 86 and 87. Number all~atlyWell~b~m~ forms con~cutlvely as they are'P~e~a~eE'fb~ek~h well. AR3B-459-1-D IPage no. ARCO Oil an~ Gas Company Daily Well History--Interim Instructions: This form is used during drilling or workover operations. If testing, coring, or perforating, show formation name in describing work performed, Number all drill stem tests sequentially. Attach description of all cores. Work performed by Producing Section will be reported on "lnlerlm" sheets until final completion. Report official or representative test on "Final" form. 1) Submit "Interim" sheets when filled out but not less frequently than every 30 days, or (2) on Wednesday of the week in which oil string is set. Submit weekly for workovers and following setting of oil strin§ until completion. District Field Date and deptrt es of 8:00 a.m, 06/02/9O ( TD: 0 PB: 9486 SUPV:GB 06/03/90 ( TD: 0 PB: 9486 SUPV:GB I County or Parish ARCO ALASKA INC. I NORTH SLOPE I Lease or Unit KUPARUK RIVER UNIT ~ 1Y-30 Complete record for each day while drilling or workover in progress NORDIC 1 7) 8) 06/04/90 ( 9) TD: 0 PB: 9486 SUPV:GB 06/05/90 (10) TD: 0 PB: 9486 SUPV:GB JState AK CIRC., PREPARE TO SQUEEZE MW:ll.9 NaCl/Br FINISH DRLG CMT TO 9421', CIRC. HOLE CLEAN AND COND. MUD, POOH, SLIP AND CUT DRILL LINE, TIH W/ 25 JTS 2-3/8" TBG ON 3.5" DP TO 9421', MU CIRC. HEAD AND PREPARE TO SQUEEZE PRODUCTION PERFS DAILY:S30,162 CUM:$259,287 ETD:S259,287 EFC:$680,000 TIH W/ BIT f2 MW:11.9 WBM CIRC. HOLE, BATCH MIX 128 SX CMT (26.5 BBLS), TEST DOWELL LINES, pbsv/P 5 BBLS H20 FOLLOWED BY 10 BBLS DOWELL 3000 SPACER, FOLLOW SPACER W/ 26.5 BBLS CMT, PUMP 4 BBLS H20, RELEASE HOWCO WIPER DART, PUMP 1 BBL H20 FOLLOWED BY 48.5 BBLS MUD AND 8 BBLS H20, LATCH DART IN CATCHER W/ 1380 PSI, PULL 14 STDS DP, SQUEEZE 17 BBLS CMT, RD DOWELL, RELEASE DP PRES. AND CIRC. AND COND. MUD TO DP OUT HOLE, POH W/ DP, MU 6.125" BIT, TIH, BIT AT 9000' AT 0600 HRS DAILY:S49,158 CUM:$308,445 ETD:S308,445 EFC:$680,000 TEST DQWELL LINES FOR SQZ MW:ll.9 WBM FINISH TIH W/ BIT #2, TAG CMT STRINGERS AT 9166', CIRC, DRILL TO 9288', DRILL SOFT CMT F/ 9228' TO 9231', CIRC. AND COND. MUD, PRESS TST CSG TO 2000 PSI, PRES BLED TO 1150 PSI IN 10 SEC, TAG CMT AT 9236', CMT DOWN HOLE 5', RE-PRESS CSG TO 2000 PSI, PRES BLED TO 1150 PSI IN 10 SEC, RE-TAG CMT AT 9239', CMT PUMPING AWAY TO FORMATION, PUMP CMT AWAY F/ 9239' TO 9257', DRILL SOFT CMT F/ 9257' TO 9300', FIRM CMT AT 9290', CIRC., BLOW DOWN AND SET KELLY BACK, POH, PU AND TIH W/ 21 JTS 2-3/8" TBG ON BTM OF 3.5" DP, ON BTM AT 9300' AT 0400 HRS, RU DOWELL FOR SQUEEZE, TEST DOWELL LINES AT 0600 HRS DAILY:S34,064 CUM:$342,509 ETD:S342,509 EFC:$680,000 DRLG CMT STRINGERS MW:11.9 WBM DOWELL PUMP 10 BBLS WATER, 25 BBLS 15.8 PPG CLASS G CMT, FOLLOW CMT W/1 BBL WATER, RELEASE HOWCO DART, DISPLACE CMT W/52 BBLS DRILL MUD & 6 BBLS WATER, LATCH DART IN CATCHER, PULL 6 STDS DP OUT OF HOLE, PRESS UP ON DP & SHEAR DART CATCHER W/2450 PSI, PULL 5 MORE STDS DP-(TOTAL 11 STDS=696'),SHUT IN WELL & DOWELL START SQZ CMT THRU PROD PERFS @ 9247'-9300', SQZD AWAY 16.5 BBLS AWAY @ 2320 PSI, SI DP & RD DOWELL, TOC @ APPROX 9078',RU TO MONITOR PRESSURE ON DP & WOC, FINAL PRES @ 1660 PSI @ 1430 HRS, POOH & LD 21 JTS 2-3/8"TBG, MU 6.125" BIT & RIH W/DC, SLIP & CUT DRILL LINE, TIH TO 8700', PU KELLY & CIRC, WASH DOWN TO TOC W/KELLY @ 8987', DRILL CMT STRINGERS TO 9053' DAILY:S51,028 CUM:$393,537 ETD:S393,537 EFC:$680,000 JWell no. The above is correct Signature ' For form preparation ~;I distribution see Procedures Manual Section 10, Drilling, Pages 86 and 87 / / AR3B-459-2-B JNumber all daily well history forms consecutively IPage no. as they are prepared for each well. ARCO Oil an~ Gas Company Daily Well History--Interim Instructions: This form is used during drilling or workover operations. If testing, coring, or perforating, show formation name in describing work performed. Number alt drill stem-tests sequentially. Attach description of all cores. Work performed by Producing Section will be reported on "lnlerlm" sheets until final completion. Report official or representative test on "Final" form. 1) Submit "lnlerim" sheets when filled out but not less frequently than every 30 days, or (2) on Wednesday of the week in which oil string is set. Submit weekly for workovers and following setting of oil strin§ until completion. Field ARCO ALASKA INC. lLease or Unit SLOPE AK ]weu no. I I · KUPARUK RIVER UNIT I 1Y-30 Date and depttl Complete record for each day while drilling or workover in progress as of 8:00 a.m. 06/06/90 (11) TD: 0 PB: 9486 SUPV:GB 06/07/90 (12) TD: 0 PB: 9486 SUPV:GB 06/08/90 (13) TD: 0 PB: 9430 SUPV:GB 06/09/90 (14) TD: 0 PB: 9430 SUPV:GB ' The above is correct . . For form preparation and d(st~bution ~ see Procedures Manual Secffe~5 10, Drilling, Pages 86 and 87 NORDIC 1 RIH W/ HLS E-LINE (PET) MW:11.9 WBM DRILL TO 9100', CIRC., TST CSG., W/ 2000 PSI, 50 PSI LOSS IN 30 MIN, DRILL CMT 9100' TO 9430', CIRC., TST CSG W/ 500 PSI, 50 PSI LOSS IN 30 MIN., PUMP DRY JOB, POOH AND RD DP SPINNERS, RU HLs E-LINE, RIH W/ PET LOG TO 3700', TOOL NOT GOING DOWN HOLE, POOH, CHG TOOL CONFIGURATION AND RIH TO 9126', UNABLE TO GO DEEPER W/ TOOL, LOG UP HOLE 100', POOR CMT IN AREA, POOH, CHG BOW SPRING CENTRALIZERS, RIH W/ PET TOOL (3RD TIME) DAILY:S31,972 CUM:$425,509 ETD:S425,509 EFC:$680,000 PREP. TO TIH W/ 6.125" BIT MW:ll.9 WBM CONT. RIH W/ HLS E-LINE PET LOG TO 9166, UNABLE TO GO DEEPER, LOG F/ 9166' TO 8345',POH W/ PET LOG, LOG SHOWS POOR CMT BOND BTWN A AND C SAND, RD HLS E-LINE, PU 15 JTS 2-3/8" TBG, AND HOWCO PLUG CATCHER, TIH W/ 3.5" DP, RU DOWELL, PUMP 18 BBLS H20,16 BBLS CMT, 3 BBLS H20, WIPER DART, 55.5 BBLS MUD, 4.1 BBLS H20, LATCH DART IN CATCHER, POH W/ 521' DP, SHEAR DART, PRESSURE UP ON DP W/ 1400 PSI ON CMT PLUG, HOLD PRES FOR 15 MIN, NO PRESS. LOSS, REVERSE CIRC. HOLE, PUMP DRY JOB, POOH W/ DP AND TBG, PREP. TO TIH W/ 6.125" BIT DAILY:S60,877 CUM:$486,386 ETD:S486,386 EFC:$680,000 TIH TO CEMENT SQUEEZE MW:ll.9 WBM FUNCTION TST BOP, TIH W/ DS'S A/TD DP TO 8940', TAG CMT, PU KELLY AND DRILL CMT F/8940' TO 9200', SET BACK KELLY, REVERSE CIRC. HOLE CLEAN, PUMP DRY JOB, POOH, RU HLS E-LINE, RIH W/ 3-3/8" PERF GUN, TIE IN W CCL TO CET LOG DATED 6/11/88, PERF 9170'-9172' AT 4 SPF, POH, RD PERF GUN, CLOSE BLIND RAMS, PRESSURE ON 7" CSG TO CHK FOR PERFS, RU FLOW NIPPLE-AND FLOW LINE, PU 2-3/8" STINGER AND RIH ON 3-1/2" DP DAILY:S39,482 CUM:$525,868 ETD:S525,868 EFC:$680,000 CIRC. AND PREP. TO TST 7" MW:11.9 WBM FINISH TIH TO 9200', SPOT 21 BBLS CMT, FOLLOW CMT BY 3 BBLS H20 & HOWCO DART & 54 BBLS MUD AND 4.5 BBLS H20, LATCH DART, SQZ AWAY 14.5 BBLS CMT W/ 2150 PSI AT START AND 2600 PSI AT FINISH, PRES. BROKE BACK TO 1540 PSI, 7 BBLS LEFT IN 7" CSG, CIP AT 1530 HRS, SHUT IN DP W/ PRES. ON CMT SQZ, RD DOWELL, WOC AND MONITOR DP/CSG PRESS, PRES. ON DP AT 1930 HRS IS 1200 PSI, RELEASE PRES. AND PUMP DRY JOB AND POOH, LD 2-3/8" TBG STINGER, MU 6.125" BIT AND BHA AND TIH, TAG CMT STRINGERS AT 8898', LAY DOWN 12 JTS DP OUT OF DERRICK, PU KELLY AND BRK CIRC DAILY:S49.322 CUM:S575.190 ETD:S575.190 EFC~S680.000 AR3B-459-2-B I Number all daily well history forms consecutively las they are prepared for each well. IPage no. ARCO Oil an~'Gas Company Daily Well History--Interim Instructions: This form is used during drilling or workover operations. If testing, coring, or perforating, show formation name in describing work performed. Number all drill stem tests sequentially. Attach description of all cores. Work performed by Producing Section will be reported on "lnterll~" sheets until final completion. Report official or representative test on "Final" form. 1) Submit "Interim" sheets when filled out but not less frequently than every 30 days, or (2) on Wednesday of the week in which oil string is set. Submit weekly-for workovers and following setting of oil string until completion. District ~]C°unty or Parish IState ARCO ALASKA INC. I NORTH SLOPE AK Field ILease or Unit JWell no. KuPARUK RIVER UNIT I 1Y-30 Date and depth Complete record for each day while drilling or workover in progress as of 8:00 a.m. NORDIC 1 06/10/90 (15) TD: 0 PB: 9430 SUPV:GB 06/11/90 (16) TD: 0 PB: 9430 SUPV:GB 06/12/90 (17) TD: 0 PB: 9430 SUPV:GB 06/13/90 (18) TD: 0 PB: 9430 SUPV:DEB MU NEW BHA MW:ll.9 WBM TST CSG TO 2000 PSI AT 9989', CO CMT STRINGERS F/ 8898'-8915',HARD CMT AT 9200', TST CMT PERFS TO 1400 PSI, DRILL HARD CMT TO 9410' TST A SAND PROD. PERS TO 500 PSI, CONT. DRLG HARD CMT TO PBTD AT 9430', CIRC AND CLEAN HOLE, PUMP PILL, POOH, LD 15 JTS 3.5" DP, PU NEW BIT & FuLL GAGE STRING MILL & JARS & B. SUB DAILY:S32,929 CUM:$608,119 ETD:S608,119 EFC:$680,000 START DWN HOLE W/ PERF GUN MW:ll.8 WBM TIH W/ BIT & STRING MILL TO 9000', BIT/MILL TAKING WT AT 9000', PU KELLY AND START REAM/WASH AT 9000' TO 9430', TIGHT SPOTS 9220'-9224' AND 9228'-9240', SET BACK KELLY, POOH, RU HLS E-LINE, RIH W/ PET LOG TO 9444' WLM, LOG 9444'- 8300', LOG SHOWS GOOD CMT BOND BTWN A AND C SAND, POOH, MU PERF GUN W/ ORIENTATION, START RIH W/ GUN AT 0600 HRS DAILY:S29,234 CUM:$637,353 ETD:S637,353 EFC:$680,000 LAYING DOWN DP MW:11.8 WBM RUN PERF GUN #1 TO 9249' WI/W, GUN STOPPED, POOH, TAKE OF ORIENTING WHEELS, MU GUN W/ BOW SPRING CENTRALIZER, RIH TO 9249', GUN STOPPED, POOH, LD PERF GUN, MU 3-1/4" SINKER BARS ON CCL, RIH, TO PBTD AT 9444' WLM, POOH AND RD HLS E-LINE, RU FLOW NIPPLE AND FLOW LINE, MU BIT, TIH, TO 9426' DPM, PU KELLY, CIRC., BLOW DOWN LINES AND KELLY, PUMP DRY JOB, LAY DOWN KELLY AND POOH, LAY DOWN DP DAILY:S60,451 CUM:$697,804' ETD:S697,804 EFC:$680,000 RD AND STAND ASIDE SL MW:11.8 WBM FINISH POH, LD DP AND'DC'S, DLEAR DP AND DC OUT OF PIPE SHED, RUN 3.5" X 4.5" COMP., LAND TBG AND RUN IN LOCK DOWN SCREWS, RU OTIS SL, RIH TO SET STDG VALVE IN 'D' NIPPLE AT 8807',POH, RD AND STAND ASIDE OTIS SL DAILY:S29,936 CUM:$727,740 ETD:S727,740 EFC:$680,000 The above is correct "- - · - · ' ....... ' ........... Signature ~.~ ~ ,Date/. / T* . For form preparation an~:listribution ~ W' / - see Procedures Manual ~.)::tion 10, -- ',,J Drilling, Pages 86 and 87 AR3B-459-2-B Number all daily well history forms as they are prepared for each well. consecutively IPage no. ARCO Oii a'nd Gas Company Daily Well 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. District ARCO ALASKA 'INC. Field KRV Auth. or W.O. no. IAc¢ounting cost center code State AK ' Well no. 1Y-30 ICounty or Parish NORTH SLOPE Lease or Unit ADL: 25641 ALK: 2572 Title WORKOVER Operator I A.R.Co. W.I. ARCO I '55,8533 Spudded or W.O. begun lDate SPUD [ 10/8/88 Date and depth as of 8:00 a.m. Complete record for each day reported NORDIC 1 06/14/90 (19) TD: 9595 PB: 9430 SUPV:DEB Iotal number of wells (active or inactive) on this DSt center prior to plugging and bandonment of this well our I Prior status if a W,O. I 06:00 Old TO Released rig RIG RELEASED MW: 0.0 Diesel RU CIRC. LINES, SET PKR, BOLDS, PU AND SHEAR PBR AT 88K# (22K# OVERPULL), RELAND HANGER, RILDS, CLOSE SSSV, TST SSSV, OK, OPEN SSSV, RU OTIS S-LINE, RIH AND RETIEVE STANDING VALVE, POH, RD OTIS S-LINE, LD LJ, SET BPV, CLOSE SSSV, ND BOPE, NU FMC GEN iV 4-1/16" TREE, TST TREE, OK, TST PACKOFF, OK, DISPLACE MUD WITH DIESEL, SHUT IN WELL, MONITOR PRESSURE, PT=PC=650 PSI, BUILT TO 1100 PSI IN 45 MIN, ATTEMPT TO BLEED ANNULUS TO CLOSE CV, CV NOT HOLDING, SHUT IN, RU FMC LUBRICATOR AND SET BPV, SECURE WELL, PT=PC=ll00PSI, PA=1000PSI RD, RIG RELEASED AT 2400 HRS DAILY.:$54,614 CUM:$782,354 ETD:S782,354 EFC:$680,000 INew TD PB Depth Date I K nd of r g Classifications (oil, gas, etc.) Type completion (single, dual, etc.) Producing method I Off cial reservoir name(s) I Potential test data Well no. Date Reservoir Producing Interval Oil or gasTest time Production Oil on test Gas per day Pump-size, SPM X length. Choke size T,P. C.P. Water % ..... 'GOR ~~3'ravity ,' · .. AIIowebl'e ' ' Effective date" corrected The above is correct For form preparation a(~.~ distribution, see Procedures Manual, Section 10, Drilling, Pages 86 and 87. AR3B-459-3-C Number all daily well history forms consecutively as they ara prepared for each well. iPage no. Olvltlon of AtlantlcRIchfleldCompanY ARCO Alaska, Inc. Date: July 13, 1990 Transmittal #: 7814 RETURN TO: ARCO Alaska, Inc. ATTN: Jenny Gamage Kuparuk Operations File Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted herewith are the following items. PleaseaCknowledge receipt and return one. signed copy of this transmittal. 1Y'30 3G-09 Pulse Echo Cement Evaluation(PET) 6-1 I -9 0 Pulse Echo Cement Evaluation(PET) 6- 1 2- 9 0 8276-9444 ~ 4200-7889 Receipt Acknowledged: DISTRIBUTION: RECEIVED Date,~ U L 1 (~ lr'JgO Alaska 0ii & Gas Cons. uommission Anchorage Drilling NSK Sta ARCO Alaska, Inc. Date: June 22, 1990 ¢ F' .'~AnChOrage.~as Cons. Transmittal ~: 7793 RETURN TO: ARCO Alaska, Inc. ATTN: Jenny Gamage Kuparuk Operations File Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted herewith are the following items. signed copy of this transmittal. 1Y-30 1L-10 2K-10 2C-13 Pulse Echo Cement Evaluation Pulse Echo Cement Evaluation Tracer Chek Experimental NORM Tracerscan Please acknowledge receipt and return one 6-5-90 8345-9164 5-31 -90 7087-9122 6-2-90 6350-6555 5-24-90 6895-7075 Receipt Acknowledged: Date: DISTRIBUTION: Drilling NSK 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 2. Name of Operator ARCO Alaska, Inc. 3. Address P. O; Box 100360, Anchorage, AK 99510 5. Type of Well: Development Exploratory Stratigraphic Service 4. Location of well at surface 208' FNL, 1164' FWL, Sec.1, T11N, R9E, UM At top of productive interval 80' FNL, 2169' FEL, Sec. 35, T12N, R9E, UM At effective depth 196' FSL, 2378' FEL, Sec.26, T12N, R9E, UM At total depth 253' FSL, 2419' FEL, Sec. 26, T12N, R9E, UM 12.Present well condition summary Total Depth: measured 9 5 9 5' true vertical 6 3 6 3' feet feet Plugs (measured) 6. Datum elevation (DF or KB) feet RKB 102 7. Unit or Property name Kuparuk River Unit 8. Well number 1¥.30 Effective depth: measured true vertical 9486' feet Junk (measured) 6 2 8 0' feet None Casing Structural Conductor Surface Intermediate Production Liner Perforation depth Length 80' 5123' Size 16" 9 5/8" 9540' 7" measured 9248'-9340', 9374-9390 9. Permit number 88-90/8-865 & 8-879 10. APl number 5o-029-21 851 11. Field/Pool Kuparuk River Field Kuparuk River Oil Pool Cemented Measured depth True vertical depth 181 SxASII 115' 115' 1150 Sx AS III & 5158' 3553' 450 Sx Class G Top Job w/100 Sx AS I 260 Sx Class G 9 5 7 3' 6 3 4 6' @ 4 SPF 180 degree phasing RECEIVE[) .Oil & Gas Cons. Commissio[~' %L, ~,ilchoral~ true vertical 6103'-6170', 6196'-6208' TVD Tubing (size, grade, and measured depth 4" to 4017' tapered to 3.5" with tubing tail @ 8824', J-55 IPC Packers and SSSV (type and measured depth) BOT HB pkr @ 8750', AVA SSSV @ 1786' 13. Attachments Description summary of proposal _ Detailed operation program~ BOP sketch _ A Sand Re-Frac pump schedule, Annotated Log Section w/Proposed C Sand Perforations 14. Estimated date for commencing operation 15. Status of well classificatiOn as: May 1990 Oil X Gas __ Suspended _ 16. If proposal was verbally approved Name of approver Date approved Service Oil Producer Si, ned17' I here~ce~h,~e foregoing is true and correct to the best of my knowledge., ~- Title <~¢lJ;bfL ¢~~I~' L~~Date FOR COMMISSION USE ONLY Conditions of approval: Notify Commission so representative may witness Plug integrity __ BOP Test _ Location clearance __ Mechanical Integrity Test m Subsequent form require ORIGINAL SIGNED BY LONNIE C. SMITH Commissioner APproved by the order Commission Approved Copy Returned IApproval No. , Date ~ I ~-~'~~ SUBMIT IN TRIPLICATE Form 10-403 Rev 5/03/89 Well 1Y-30 Application for Sundry Approval A Sand Re-frac; C Sand Perforating May 11, 1990 It is proposed to re-frac the A Sands in well 1Y-30 following the upcoming workover to restore production. The well will be fractured with gelled water, placing roughly 45,000 lbs of 16:20 Carbo-Lite proppant in the formation at rates of 20 BPM and concentrations up to 12 ppg. No BOP is required for this work. Flowback of the frac will occur through the existing production facilities. Following flowback and testing of the A Sands, the C Sands will be perforated from 9248'-9340' and 9374'-9390' RKB @ 12 SPF using through tubing strip guns. A standard pressure control lubricator will be used for this operation. STAGE KUPARUK WELL 1Y-30 A SAND RE-FRACTURE PUMPING SCHEDULE 5/1 1/90 FLUID CLEAN VOLUME PUMP RATE PROP. CONC. PROPPANT PROPPANT WT DIFrP¢ VOLUME H IT PERFS DESCRIPTION BBLS BPM PPG DESCRIPTION LBS STG/CUM ~ BBLS 1 GW PRE-PAD (X-Linked) 125.0 20 0 0 125/ 125 104.5 2 GW PRE-PAD (Non X-Linked) 50.0 20 0 0 50/ 175 229.5 ..................................................... SHUT DOWN FOR ISIP AND LEAKOFF CALCULATIONS ................................... 3 GW PAD 285.0 20 0 0 285 / 460 279.5 4 GW w/2 PPG 18.4 20 2 16/20 M CARBO-LITE 1 544 20/ 480 564.5 5 GW w/4 PPG 21.3 20 4 16/20 M CARBO-LITE 3571 25/ 505 584.5 6 GW w/6 PPG 23.7 20 6 16/20 M CARBO-LITE 5979 30/ 535 609.5 7 GW w/7 PPG 26.7 20 7 16/20 M CARBO-LITE 7864 35/ 570 639.5 8 GW w/8 PPG 22.2 20 8 16/20 M CARBO-LITE 7452 30/ 600 674.5 9 GW w/10 PPG 20.8 20 1 0 16/20 M CARBO-LITE 8746 30/630 704.5 1 0 GW w/12 PPG 19.6 20 1 2 16/20 M CARBO-LITE 9890 30/660 734.5 11 SLICK DIESEL 102.5 +SV 20 0 - - 0 103/ 763 TOTAL GELLED WATER= 587.8 BBLS 16/20 M CARBO-LITE = 45045 LBS TOTAL DIESEL = 25.0 BBLS TOTAL FRAC FLUID = 612.7 BBLS TOTAL DIESEL FOR FLUSH = 102.5 BBLS + SV 1. All fluids should be maintained between 85 F and 90 F on the surface. 2. Stages I through 5 are: 40#/1,000 gal gelled water, surface crosslinked, with 2% KCL by weight and 5% diesel by volume and enough breaker for an 8 hour break. 3. Stages 6 through 10 are the same as above but without diesel. 4. Reduce pump rate to a minimum of 14 BPM in roughly 2 BPM increments if a significant premature rise in treating pressure is observed. If pressure continues to rise, go immediately to flush at 20 BPM 5. Stage 11 (flush) should include a volume adjustment for surface equipment between the wellhead and densimeter. 6. This job is intentionally underflushed by 2.0 bbls. The blender tub should be bypassed at flush. 9300 9400 I I 2101189 4/lO/89 4/14189 8/25/89 RECEIVED 1Y-30 ADDENDUM APR ) o 1990 Oil.& Gas Con;. Tst lubr to 3500 psi. Perf well thru tbg w/2-5/8" Atlas Slim Kone BH Hollow Carrier guns @ 4 SPF w/180° phasing as follows: 9374'-9390' 9320'-9340' 9300'-9320' 9280'-9300' 9260'-9280' 9248'-9260' Flow well to tank for 10 min. to cln up perfs. Frac Kuparuk "A" sand perfs 9248'-9340' & 9374'-9390' in eight stages per procedure dated 2/10/89 as follows: Stage #1: Pmp 175 bbls gelled diesel pre-pad w/294# silica flour @ 25 BPM, 3850 psi Stage #2:305 bbls gelled diesel pad w/512# silica flour @ 25 BPM, 4118 psi Stage #3:10 bbls gelled diesel w/2 ppg, 16/20 Carbolite @ 25 BPM, 4070 psi Stage #4:23 bbls gelled diesel w/4 ppg, 16/20 Carbolite @ 25 BPM, 3997 psi Stage #5:27 bbls gelled diesel w/6 ppg, 16/20 Carbolite @ 25 BPM, 3990 psi Stage #6:52 bbls gelled diesel w/8 ppg, 16/20 Carbolite @ 25 BPM, 4025 psi Stage #7:48 bbls gelled diesel w/10 ppg, 16/20 Carbolite @ 25 BPM, 4198 psi Stage #8:32 bbls gelled diesel w/12 ppg, 16/20 Carbolite @ 25 BPM, 6279 psi Sanded out with 27 bbls 6 ppg stage below perfs. Fluid to Recover: Sand in Zone: Sand in Csg: Avg Pressure: 627.5 bbls 25,100# 125 bbls slurry, 21,200# 4000 psi RU CTU, RIH while circ'g gelled diesel. RIH & CO well to 9470' CTM (PBTD), POOH & displ well to cln diesel. Arctic Pak well w/175 sx AS I and 63 bbls Arctic Pak. Dr~rvisor c_) WELL COMPLETION OR RECOMPLETION REPORT AND LOG 'i Status of Well ' ' ' Classification of Service Well OIL ~] GAS r~ SUSPENDED ~ ABANDONED [~ SERVICE r'-] 2 Name of Operator 7 Permit Number ARCO Alaska, Inc 88-90 ,, 3 Address 8 APl Number P.O. Box 100360,'Anchorage, AK 99510-0360 50-029-21851 4 Location of well at surface....--.__._~ ~~:~ 9 Unit or Lease Name 208' FNL, 1164' FWL, SEC 1, T11N, R9E Utv ~J~l~ !. ~! ~,~.~;~-;.>~ ..... '~ ~ KUPARUK RIVER UNIT i~ ~ ~ 10 Well Number At Top Producing Interval 80' FSL, 2169' FEL, SEC 35, T12N, RgE UM 1Y-30 At Total Depth I'1~o ~ ,~.~..~ li' Field and Pool '" 253' FSL, 2419' FEL, SEC 26, T12N, R9E UI~ KUPARUK RIVER FIELD 5 ElevatiOn in feet (indicate KB, DF, etc.) I 6 Lease Designation and Serial No. KUPARUK RIVER OIL POOL RKB 102'I ADL: 25641 12 Date Spudded ' 13 Date T.D. Reached ' 14 Date Comp., Susp. or Aband. 15 Water Depth, if offshore ' I of ComPletions OCT8 1988 OCT 15 1988 ...... ,~-~ ~nq~ NA ,16 No. ........... feet MSLI. 1 "1'~/Total Depth (MD+TVD) 18 Plug Back Depth (MD+TVD) 19 Directional Survey 20 Depth where SSSV set 21 Thickness of permafrost 9595' MD & 6363' TVD 9486' MD & 6280' TVD YES ~ NO ~ 1786' feet MD 1300' (approximate) 22 Type Electric or Other Logs Run DIL,SFL, GR,CAL,SP,FDC,CNL, CBL,GYRO 23 CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD _ CASING SIZE WT. PER FT. GRADE TOP BoTroM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 16" 62.5# H-40 SURF 115' 24" 181 SX AS II , 9 5/8" 36# J-55 SURF 5158' 12-3/4" 1150 SX AS III & 450 SX CLASS G ,,, 7" 26# J-55 SURF 9573' 8-1/2" 260 SX CLASS G 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) 4"/3-1/2", J-55 8824' 8750' 9248'-9340' MD, 2-5/8" W/4 SPF 6103' - 6170' TVD 26 ACID, FRACTURE, CEMENT SQUEEZE, ETC 9374'-9390' MD, 2-5/8" W/4 SPF 6195' - 6206' TVD DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 9248'- 9390' 25,100 lbs 16/20 CARBOLITE ,, ,, 27 PRODUCTION TEST Date First ProductiOn JMethod of Operation (Flowing, gas lift, etc.) I Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE J GAS-OIL RATIO I TEST PERIOD Flow Tubing Casing Pressure CALCULATED OIL~BBL GAs-MCF i WATER-BBL OIL GRAVITY-APl (corr) Press. 24-HOUR RATE 28 CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. ,, Form 10-407 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE GEOLOGIC MARKERS FORMATION TESTS :,~ ~ . . NAME Include interval tested, pressure data, all fluids recoverd and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase, TOP KUPARUK C 8987' 5921' NA BOTTOM KUPARUK C 9107' 6003' TOP KUPARUK A 9240' 6097' BOTTOM KUPARUK A 9394' 6210' :?- , 31. LIST OF ATTACHMENTS 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed __~----t4'~ ,-~~ Title AREA DRILLING ENGINEER Date ~//~,/~'~ INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion repod 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 pedinent 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 ~UB-$URFACE DIRECTIONAL ~UIDANCE F~'iONTINUOUS [~]OOL ~URVEY Company ARCO ALASKA, INC. Well Name' 1, Y-30 (208' FNL,1164' FWL,SEC 1,TllN,R9E,UM) F)o~d~L~at~orl KUPARUK, NORTH SLOPE, ALASKA Jol~ Reference No. 73057 SCHWARTZ Date 6-N0V-88 Computed By: KRUWELL ~ SCHLUMO:P, GERo,-"' GCT ,DIRECTIONAL SURVEY CUSTOMER LISTING FOR ARCO ALASKA, INC. 1Y-30 K, UPARUK NORTH SLOPE,~LASKA SURVEY DATE: 06-NOV-88 ENGINEER: SCHWARTZ METHODS OF CgMPUFATION TOOL LOC~TT. ON: TANGENTT.~L- ~VER~GED DEVIATION AND AZIMUTH INTERPOL&TIDN: LINEAR VERTICAL SECTION: HORIZ. gIST. PROJECTED ONTO A TARGET AZI'4UTH OF NORTH 37 DEG 20 MIN WEST ARCO ALASKA, INC. 1Y-30 KUPARUK NORTH SLOPE,ALASKA TRUE SUO- MEASURED VERTICAL VERT DEPTH DEPTH DE 0.00 0.00 -10 100.00 99.95 - 200.00 199.95 9 300.00 299.94 19 400.00 399.85 29 500.00 499.37 39 600.00 598.23 49 700.00 695.79 59 800.00 791.96 69 900.00 886.56 78 1000.00 979'21 87 1100.00 1069.32 96 1200.00 1156.69 105 1300.00 1240.74 114 1400.00 1322.14 122 1500.00 1401.40 130 1600.00 1478.05 137 1700.00 1551.41 145 1800.00 1621.60 152 1900.00 1688.95 158 2000.00 1752.57 155 ZlO0.O0 1813.09 171 2200.00 1871.51 177 2300.00 1929.90 132 2400.00 1988.40 188 2500.00 2047.50 194 2600.00 2108.37 290 2700.00 2169.80 206 2800.00 2231.22 213 Z900.00 2290.08 219 3000.00 2347.00 224 3100.00 2403.28 230 3200.00 2459.08 235 3300.00 2515.63 241 3400.00 2572.44 247 3500.00 2626.55 252 3600.00 2679.33 257 3700.00 2732.85 263 3800.00 2786.82 268 3900.00 2841.10 274 COMPUTATION DATE: 13-DEC-88 PAGE DATE OF SURVEY: KELLY 5USHING ELEVATION: 06-NOV-88 100. O0 ENGINEER: SCHWARTZ INT.,,~,RPOLATED VALUES FOR S E A ~!!!!?i C 0 U R S E I C ~1.::., iTION AZIMUTH PTH N O. 0 0 0 0.05: ~ 0 11 9.95 0 !0 9.94 I 1:0 9.B5 9.37:: 6..'53 8-23: 10' 44 5.79 14 7 1.96 17 21 6.56 20 28 EVEN VERTIC SECTI BEG MIN FEE 0 0 E O. 72 34. W -0. 64 5 W -0. 34 44 W O. 23 2)3 W 4. 2.1 28 W 14. 22 14 W 28. 25 57 W 49. 24 59 W 76. 21 47 W 107. 22 5 W 144. 21 48 W 185. Z1 49 W 232. 22 39 W 284. 35 7 W 341. 26 3,4 W 401. 27 21 W '464. Z~ 7 W 531. 30 2S W 601. 32 27 W 675. 32 37 W 752. !2 29 W 831. 30 34 W 912. 29 42 '4 992. 29 4 W 1073. 28 lg W 1152. 27 2 W 1230. 26 12 W 1308. 25 52 W 1385. 26 13 W 1465. 26 14 W 1545. lB 15 W 1627. 2q 3.~ W 1709. 28 19 W 1790. 29 38 W 1872. 30 17 W 1955. 29 41 W 2039. 29 ,6 W 2123. 28 47 W 2206. 28 33 W 2289. 9.21 23 50 9.32 27 22 6.69 30 53 0.74 34 23 2.14 36 29 1.40 38 40 H.05 41 26 1.41 44 5 1.60 46 34 8.95 48 53 2.57 51 51 3.09 53 42 1.51 54 19 9.90 54 15 8.40 54 6 7.50 53 6 8.37 52 l! 9.80 52 6 1.22 52 32 0.08 55 2 7.00 55 21 3.28 56 10 9.08 55 47 5.63 55 11 2.44 56 15 6.55 57 53 9.33 58 4 2. ~35 57 21 6.82 57 18 1.10 56 54 100 FEET OF MEASURED DEPTH AL DOGLEG RECTANGULAR ON SEVERITY NORTH/SOUTH T OEG/IO0 FEET O0 0.00 0.00 N 15 0.32 0.18 S 29 0.41 0.43 S 51 2.01 0.08 N 62 4.09 3.86 N 00 2.76 12.83 N 34 5.08 26.74 N 64 2.71 46.67 N 49 3.10 71.21 N 80 3.44 101.04 N 03 3.70 135.89 N 82 3,.58 176.06 N 61 3.62 221.22 N 87 2.96 271.36 N 32 2.27 324.51 N 08 2.54 379.33 N 25 3.13 4'36.48 N 23 2.97 496.65 N 69 2.97 558.8,~ N 24 2.97 621.75 N lO 2.13 686.78 45 3.05 753.65 16 0.86 822.98 70 0.50 893.20 02 0.60 953.87 78 2.06 1034.58 99 1.00 1104.84 51 0.70 1175.42 86 2.04 1246.38 13 1.37 1319.00 80 0.76 15 1.27 17 0.60 64 0.94 02 3.00 47 1.04 70 0.67 36 0.39 64 0.44 65 0.63 COORDINATES HORIZ. DEPARTURE EAS'T/WEST DIST. AZIMUTH FEET FEET DEC MIN 0.00 E 0.00 N 0 0 E O.OZ E 0'18 S 4 47 E 0.09 W 0.44 S 11 51 W 0.73 W 0.73 N 83 39 W -.~ 2.56 W 4.63 N 33 36 W~ 6.26 W 14-28 N 26 1 11.67 W 29.18 N 23 34 W 20.68 W 51.04 N 23 53 W 32.76 W 78.38 N 24 42 45.29 W 110.73 N 24 8 W 59.33 W 148.28 N 23 35 W '75.57 W 191.60 N 23 13 W 93.52 W 240.18 N 22 54 W 113.9'7 W 294.32 N 22 46 W 137.36 W 352.38 N 22 56 W 164.02 W 413.2~ N 23 22 W 193.27 W 477.36 N 23 53 W 224.79 W 545.18 N 24 21 W 259.43 W 616.16 N 24 54 W 298.27 W 689.59 N 25 37 W 339.75 W 766.22 N 26 19 W 382.93 W 845.35 N 26 56 W 425.12 W 926.29 N 27 19 W 465.85 W 1007.39 N 27 32 W 505.64 W 1088.45 N 27 40 W "'~ 544.46 W 1169.10 N 27 45 W'.; 5c31.30 W 1248.43 N 27 45 W 616.60 W 1327.33 N 27 40 W 651.10 W 1406.20 N 27 34 W 636.62 W 14~7.01 N 27 29 W 1392.76 N 722.92 W 1569.21 N 27 25 1466.29 N 760.67 W 1651.85 N 27 25 1539.14 N 900.40 W 1734.81 N 27 28 1611.69 N 839.62 W 1817.29 N 27 31 1683.82 N 879.23 W 1899.55 N 27 34 1756.45 N 921.62 t.~ 1983.55 N 27 41 1830.00 N 964.07 W 2068.42 N 27 46 1903.62 N 1005.51 W 2152.86 N 27 50 1977.29 N 1046.26 W 2237.03 N 27 53 2051.02 ~ 10c36.47 W 2321.01 N 27 54 ARCO ALASKA, INC. 1Y-30 KUPARUK NORTH SLOPE,ALASKA COMPUTATION DATE: 13-0EC-88 DATE OF SURVEY: 06-NOV-88 KELLY BUSHING ELEVATION: 100.00 F'T ENGINEER: SCHWARTZ INTERPOLATED VALUES FOR EVEN 100 FEET OW MEASURED DEPTH TRUE SUB-SEA COURSE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH DEPTH DEPTH DEPTH DEG MIN DEG MIN VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/WEST gIST. AZIMUTH FEET DEG/IO0 FEET mEET FEET DEG MIN 4000.00 2896.24 2796.24 5:5 59 4100.00 Z952.57 2852.57 55 49 4200.00 3008.46 2908.46 56 8 4300.00 3064.27 2964.27 55 56 4400.00 3120.22 3020'22 56 7 4500.00 3175.79 3075.79 56 21 4600.00 3231.16 3131.16 56 19 4700.00 3286.57 3186.57 56 12 4800.00 3343.38 3243.38 54 29 4900.00 3401.86 3301.86 54 11 5000°00 3460.40 3360.40 54 B 5100.00 3518.84 3418.84 54 24 5200.00 3577.29 3477.29 54 9 5300.00 3635.65 3535.65 54 23 5400.00 3693.76 359'3.76 54 31 5500.00 3751.70 3651.70 ~4 41 5600.00 3809.49 3709.49 54 40 5700.00 3867.24 3767.24 54 46 5800.00 3924.90 3824.90 54 50 5900.00 3982.35 3882.35 54 56 6000.00 4040.59 3940.59 ~3 53 6100.00 4099.85 3999.85 53 33 6200.00 4159.32 4059.32 53 23 6300.00 4219.17 4119.13' 53 3 6400.00 4279.39 4179.39 52 53 6500.00 4339.82 4239.32 52 48 6600.00 4400.36 4300.36 52 3~ 6700.00 4461.21 4361.21 52 2~ 6800.00 4522.29 4422.29 52 16 6900.00 4583.55 4483.55 :32 9 7000.00 4645.00 4545.00 51 58 7100.00 4706.75 4606.75 51 47 '7200.00 4768.74 4668.74 51 36 7300.00 4830.98 4730.98 51 28 7400.00 4893.30 4793.30 51 23 7500.00 4955.89 4855.99 51. 7600.00 5018.86 4918.86 50 47 7700.00 5082.18 4982.18 50 32 7800.00 5145.95 5045.95 50 13 7900.00 5210.03 5110.03 50 13 N 30 43 W 2372.26 N 31 43 W 2454.46 N 31 30 W 2535.97 N 31 16 W 2619.50 N 30 5~ W 2701.90 N 30 26 W 2784.48 N 29 57 W 2867.11 N 29 27 W 2949.60 N 31 59 W 3031.28 N 32 23 W 3112.11 N 31 40 W 3192.83 N 31 12 W 3Z73.55 N 31 11 W 3354.22 N 31 12 W 3434.96 N 31 14 W 3515.87 N '31 lZ W 3596.91 N 31 19 W 3678.06 N 31 39 W 3759.27 N 31 59 W 3840.60 N 32 21 W 3922.12 N 34 15 W 4003.18 N 34 53 W 4083.65 N 94 52 W 4163.97 N 34 54 W 4244.01 N 34 52 W 4323.77 N 34 49 W 4403.37 N 34 52 W 4482.88 N 35 4 W 4562.18 N 35 12 W 4641.30 N 35 19 W 4720.28 N 35 39 W 4799.12 N 35 34 W 4877.'75 N 35 34 W 4956.18 N 35 32 W 5034.41 N 35 34 W 5112.58 N 35 37 W 5190.53 N 35 41 W 5268.19 N 35 37 W 5345.54 N 35 35 W 5422.54 N 35 40 W 5499.28 2.63 0.62 0.38 0.23 0 0.49 0 1.10 2.37 0.60 0.52 0.39 0.34 0.16 0.13 0.19 0.23 0.36 0.31 0.60 1.87 0.25 0.28 0.52 0.45 0.14 0.30 0.18 0.17 0.18 0.31 0.23 0.27 0.08 0.17 0.14 0.21 0.50 0.50 0.37 2123.71 N t127.39 W 2404.40 N 27 57 W 2194.14 N 1170.57 W 2486.87 N 2!3 4 W 2264.72 N '1214.10 W 2569.63 N 28 11 W 2335.57 N 1257.29 W 2652.48 N 29 17 W 2406.49 N 13'00.19 W 2735,27 N 2,3 22 W~i~ 24?7.98 N 1342.63 W 2818.34 N 28 26 2549.94 N 1384.54 W 2901.57 N 28 30 W 2622.32 N 1425.66 . 2984.80 N 28 31 W 2693.2S N !457.35 W 3067.04 N 28 34 W 2761.65 N 1510.95 W 3147.96 N 2E)41 W 2830.39 N 1553.94 W 3228.91 N 28 46 W 2899.64 N 1596.23 W 3309.97 N 28 49 W 2969.08 N 1538.22 W 3391.04 N 28 53 W 303~.52'N 1680.31 W 3472.18 N 28 56 W 3108.12 N 1722.48 W 3553.50 N 28 59 W 3177.81 N 1764.73 W 3634.94 N 29 2 W 3247.59 N 1807.06 W 3716.50 N 29 5 W 33t7.21 N 1849.70 W 3798.06 N 29 8 W 3386.64 N 1892.77 W 3879.68 N 29 12 W 3455.94 N 1936.35 W 3961.43 N 29 15 W 3523.99 N 1990.78 W 4042.52 N 29 20 'W 3590.12 N 2026.77 W 4122.71 N 29 26 W 3656.07 N 1072.74 W 4202.75 N 29 33 W 3721.79 N 2118.56 W 4282.53 N 29 38 W 3787.27 N 2164.22 W 4362.03 N 29 44 W ~\ 3852.65 N 2209.78 W 4441.40 N 29 50 W .... 3917.99 N 2255.22 W 4520.69 N 29 55 W 3983.01 N 2300.71 W 4599.75 N 30 0 W 4047.77 N 2346.23 W 4678.51 N 30 5 W 4112.29 N 2391.91 W 4757.33 N 30 11 W 4176.58 N 2437.63 W 4835.90 N 30 16 W 4240.58 N 2483.37 W 4914.23 N 30 21 W 4304.40 N 2529.04 W 4992.38 N 30 26 W 4368.08 N 2574.54 W ~070.34 N 30 30 W 4431.70 N 2620.01 W 5148.25 N 30 35 W 4495.1~ N 2665.40 W 5225.94 N 30 39 W 4558.25 N 2710.68 W 5303.34 N 30 44 W 46~1.13 N 2755.80 W 53~0.4~ N 30 48 W 4683.78 N 2800.62 W 5457.22 N 30 52 W 4746.16 N 2845.36 W 5533.73 N 30 56 W COMPUTATION DATE: ARCO ALASKA, INC. 1Y-30 KUPARUK NORTH SLOPE,ALASKA INTERPOLATED VALUES FOR EVEN TRUE SUS-SE~ MEASURED VERTICAL VERTICAL DEPTH DEPTH OEPTH ' 8000.00 5274.00 8100.00 5338.01 8200.00 5402.66 8300.00 5467.57 8400.00 5532.67 8500.00 5598.14 8600.00 5663.79 8700.00 5729.66 8800.00 5795.77 8900.00 5862.07 9000.00 5929.71 9100.00 5998.18 9200.00 6068.09 9300.00 6140.13 9400.00 6214.14 9500.00 6290.54 9595°00 6363.23 COURSE VERTIC ,TION AZIMUTH SECTI N DEG MIN FEE 5174.00 50 16 5238.01~ 49 59 5302.66 49 34 5367.57 49 28 5432.67 49 13 5498.14 48 57 5563.79 48 57 5629.66 48 39 5695.77 48 38 5762.07 48 4 5~29.71 47 3 5595.18 46 18 5968.09 44 49 6040.13 43 11 6114.14 40 53 6190.54 40 4 6263.23 40 4 N 35 42 W 5575. N 35 47 W 5652. N 35 54 W 5729. N 36 3 W 5805. N 36 20 W 5881. N 36 32 W 5g56. N 36 46 W 6032. N 37 4 W 6107. N 37 3 W 6182. N 36 54 W 6257. N 36 48 W 6330. N 37 26 W 6403. N 37 lq W 6475. N 37 18 W 6544. N 36 38 W 6611. N 36 0 W 6676. N 36 0 W 6737. 13-0EC-88 DaTE OF SURVEY: KELLY BUSHTNG ELEVATYON: ENGINEER: 100 FEET OF MEASURED DEPTH ~,L DOGLEG RECTANGULAR COORDIN,~TES HDR!Z. ON SEVERITY NORTH/SOUTH EAST/WEST DIST. T OEG/IO0 FEET FEET FEET PAGE 3 06-NOV-88 - 100.00 FT SCHWARTZ .,,, DEPARTURE AZIMUTH DEG MIN 11 0.25 4808.5B N 2890.21 W 5610.33 N 31 0 W 91 0.45 4870.94 N 2935.09 W 5686.90 N 31 4 W 18 0.33 4932.79 N 2979.78 W 57S2.94 N 31 8 W 23 0.27 4994.35 N 3024.4T W 5838.74 N 31 11 W 69 0.16 5116.39 N 3114.21 W 5989.64 N 31 19 o.25 52 7.06 w 1 9.64 . 31 27 w 0.3 N 324 .73 W . W 90 0.64 5415.64 N 3338.91 W 6362.19 N 31 39 W 79 0.93 5473.73 N 3382.93 W 6434.75 N 31 43 W 28 1.81 5530.52 N 3426.36 W 6505.89 N 31 46 W 62 1.32 5585.70 N 3458.35 ;,~ 6574.92 N 3l 50 W 85 3.76 5639.32 N 350,~.92 W 6641.87 N 31 53 W 36 0.00 5691.40 N 3546.99 W 6706.21 N 31 55 W 51 0.00 5740.88 N 3582.9~ W 6757.22 N 31 58 W ARCO ALASKA, INC. KUPARUK NORTH SLOPE,ALASKA COMPUTATION DATE: 13-3EC-85 PAGE D~,TE OF SURVEY: 06-NOV-88 - KELLY BUSHING ELEV~.TIDN.' 100.00 FT ENGIN6ER: SCHWa. RTZ INTERPOLATED VALUES FOR EVEN 1000 FEET OF MEASURED DEPTH TRUE SUB-SEn COURSE MEASURED VERTICAL VERTICAL DEYZATION AZIMUTH DEPTH DEPTH DEPTH DEG MIN DEG MIN 0.00 O.OO -100.00. O 0 1000.00 979.21 879. :~1 2.3 50 ZO00.O0 1752.57 1652.57 51 51 3000.00 Z347.00 2247.00 55 21 4000.00 Z896.24 2796. Z4 55 59 5000.00 3460.40 3360.40 54 8 6000.00 4040.59 3940.59 53 53 7000.00 4645.00 4545.00 51 58 8000.00 5274.00 5174.00 50 16 9000.00 5929.71 5829.71 47 3 VERTICAL OOGLEG RECTANGULAR COORDiNaTES HORIZ. DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH FEET DEG/IO0 FEET CE~T ~EET DEG MIN N 0 0 E 0.00 N 22 5 W 144.03 N 32 3? W 752.10 N 26 14 W 1545.80 N .tO 43 W 2372.26 N 31 40 W 3192.83 N 34 15 W 4003.18 N 35 30 W 4799.12 N 35 42 W 5576.tl N 36 48 W 6330.90 9595,00 6363,23 6263,Z3 40 4 N ~6 0 W 673?.51 0,00 3,70 2,13 0,76 2.63 0,52 I ,87 0,31 0,25 0,64 0.00 N 0.00 E 0.00 N 0 0 E 135.89 N 59.33 W 148.28 N 23 35 W 6~6.7~ N 3'39.75 W 766.22 N 26 19 W 1392.76 N 7Z2.97 W 1569.21 N 27 25 W~- 21Z~,71 N 1127,3~ W 2404,40 N 27 57 W' 2830,39 N 1553,94 W 3228.91 N 28 46 3523.9g N 1980.T3 W 4042.52 N 29 20 W 4176.58 N Z&37.63 W G835.90 N 30 16 W 4808.58 N 2890.21 W 5610.33 N 31 0 W 5415.6.4 N 3338,91 W 6362,19 N 31 39 W 0.00 5740.88 N 3532.9,5 W 6767.22 N 31 58 W ARCO ALASKA, INC. 1Y-30 KUPARUK NORTH SLOPE,ALASKA CgMPUTATION D6T~: 13-DEC-88 PAGE 5 DATE OF SURVEY: 06-NOV-88 KELLY 3USHING EtEVATION: 100.00 FT EqGINEER: SCHWARTZ INTERPOLATED VALUES FOR EVEN 100 FEET O: SU~-SE~ DEPTH TRUE SUB-SEA COURSE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH DEPTH DEPTH OEPTH OEG MIN DEG M!N 0.00 0.00 -100.00 0 0 N 0 0 E 100.05 100.00 0.00 0 11 S 22 37 W 200.05 200.00 100.00 0 10 S 64 9 W 300.06 300.00 200.00 I 11 N 34 43 W 400.15 400.00 300.00 4 0 N 23 25 W 500.64 500.00 400.00 6 54 N 21 27 W 601.80 600.00 500.00 10 50 N 22 18 W 704.34 700.00 600.00 14 15 N 26 4 W 808.43 800.00 700.00 17 36 N 24 .37 W 914.35 900.00 300.00 20 57 N 21 46 W VER-TIC~L DOGLEG RECTANGUL4R COORDIN&TES HORIZ. DEPARTURE SECTION SEVERITY NO~TH/SOUTH E~ST/WEST DIST. AZIMUTH FEET DEG/IO0 mEr-T FEET FEET DEG MIN 1022.85 1000.00 900.00 24 39 1134.75 1100.00 1000.00 28 36 1251o04 1200.00 1100.00 32 46 1372.59 .1300.00 1200.00 95 58 1498.21 1400.00 1300.00 38 38 1629.51 1500.00 1400.00 42 16 1768.78 1600.00 1500.00 45 52 1916.89 1700.00 1600.00 49 23 2078.06 1800.00 1700.00 53 16 2248.82 1900.00 1800.00 54 16 0.00 0.00 0.00 N 0.00 E -0.15 0.32 O.1q S 0.02 E -0.29 0.41 0.43 S 0.09 W 0.51 2.01 0.09 N 0'.73 W 4.63 4.09 3.8'7 N 2.57 W 14.07 2.80 12.90 N 6.29 W 28.66 4.93 27.05 N 11.80 W 50.69 3.60 47.62 N 21.14 W 78.98 3.15 73.53 N 33.83 W 112.55 3.39 105.72 N 2419.80 2000.00 1900.00 54 2 2586.32 2100.00 2000.00 52 15 2749.16 2200.00 2100.00 52 4 2917.37 2300.00 2200.00 55 15 3094.12 2400.00 2300.00 56 7 3272.50 2500.00 2400.00 55 25 3450.34 2600.00 2500.00 57 19 3638.98 2700.00 2600.00 57 44 3824.40 2800.00 2700.00 57 13 4006.70 2900.00 2~00.00 ~5 N 22 5 W 153.19 N 21 40 W 201.52 N 22 10 W 258.65 N 24 22 W 325.55 N 26 32 W 399.98 N 27 28 W 483.67 N 29 33 W 579.35 N ~2 32 W 687.96 N 32 45 W 813.90 N 30 6 W 951.51 4184.81 3000.00 2900.00 56 6 4363.77 3100.00 3000.00 56 0 4543.78 3200.00 3100.00 56 24 4724.14 3300.00 3200.00 55 51 4896.82 3400.00 3300.00 54 11 5067.66 3500.00 3400.00 54 17 5238.84 3600.00 3500.00 54 15 5410.75 3700.00 3600.00 54 31 5583.58 3800.00 3700.00 54 40 5756.78 3900.00 3800.00 54 46 N 28 57 W 1088.89 N 27 12 W 1220.34 N 25 55 W 1346.54 N 26 16 W 14.79.12 N 28 8 W 1622.33 N 28 19 W 1768.30 N 30 23 W 1913.80 N 29 26 W 2072.44 N 28 41 W 222,5.94 N 30 54 W 2377.77 31 33 W 252~.43 31, 9 W 2672.02 30 16 W 2820.68 29 44 W 2969.66 32 25 W 3109.54 31 19 W 3~47.42 31 !~ W 3385.55 31 1~ W 3524.58 31 17 W 3.664.74 31 50 W 3805.43 0.00 N 0 0 ~ 0.18 S 4 45 E 0.44 S 11 52 W 0.73 N 83 35 W_ 4.64 N 33 34 14.35 N 26 0 29.51 N 23 33 W 52.10 N 23 56 W '80.94 N 24 42 W 47.15 W 115.76 N 24 2 W 3.5'7 3.54 3.70 2.53 2.5~ 2.56 3.04 3.20 2.31 0.72 1¢4.69 N 62.90 W 157.77 N 23 29 W 191.21 M 81.61 W 207.90 N 23 6 W 246.25 N 103.65 W 267.17 N 22 49 W 309.86 N 130.60 W 336.24 N 22 51 W 378.34 N 163.52 W 412.16 N 23 22 W 453.99 N 202.34 W 497.04 N 2~% 1 W 539.36 N 248.18 W 593.72 N 24 42 W 632.52 N 305.13 W 702.27 N 25 45 W 738.89 ,q 373.34 W ,~27.85 N 25 48 W 857.19 N 445.14 W 965.88 N 27 26 W 0.73 1.04 0.57 0.76 .1.52 0 .SO 1.52 1.43 0.60 2.32 977.89 N 513.42 W 1104.4~ N 27 42 W 1095.21 N 576.36 W 12'37.61 N 27 45 W 1,210.26 N 633.62 W 1366.10 N 27 38 W 1331.78 N 692.92 W '1501.26 N 27 29 W 1461.98 N 7'58.35 W 164,6.97 N 27 25fL~]~_ 1591.77 N 828.89 W 1794.66 N 27 30 W 1720.26 N 900.36 W t941.64 N 27 37 W 1858.74 N 980.40 W 2101.45 N 2,7 48 W 1995.29 N 1056.13 W 2257.56 N 27 53 W 2128.47 N 11,30.23 W 2409.94 N 27 58 W 0.42 0.45 0.42 2.52 0.56 0.67 0.27 O. 15 0.16 0.34 2253.98 N 1207.50 W 2557.0~ N 28 10 W 2380.75 N 1284.67 W 2705.24 N 2~ 21 W 2509.45 N 1361.06 W 2854.79 N 28 28 W 2639.79 N 1435.50 W 3004.86 N 2~ 32 W 2759.47 N 1509.56 W 31~5.39 N 2~ 40 W 2877.17 N 1582.61 W 32,93.71 N 2,~ 48 W 2996.03 N 1654.54 W 3422.53 N 28 54 W 3115.61 N 1727.02 W 3552.25 N 29 0 W 3236.14 N 1800.10 W 3703.11 N 2~ 5 W 3356.66 N 1874.10 W 3844.40 N 29 10 W ARCO ALASKA, INC. 1Y-30 KUPARUK NORTH SLOPE,ALASKA COMPUTATION DATE: 13-DEC-B8 DATE OF SURVEY: 06-NOV-85 . KELLY BUSHING ELEVATION: 100.00 FT ENGINEER: SCHWARTZ INTERPOLATEO VALUES FOR EVEN 100 .~EET OF SUB-SEA DEPTH TRUE SUB-SEA COURSE VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE . MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH DEPTH DEPTH DEPTH ,!'I)EG~:~,IN BEG M[N FEET DEG/IO0 FEET FEET FEET DEG MIN 5930.68 4000.00 3900.00 54 36 6100.25 4100.00 4000.00' 53 33 6268.05 4200.00 4100.00 53 9 6434.10 4300.00 4200.00 52 49 6599.41 4400.00 4300.00 52 38 6763.56 4500.00 4400. O0 52 19 6926.81 4600.00 4500.00 52 T 7089.09 4700.00 4600.00 51 48 7250.27 4800.00 4700. O0 51 29 7410.73 4900.00 4800.00 51 22 7570.17 5000.00 4900.00 50 54 7727.98 5100.00 5000.00 50 26 7884.30 5200.00 5100.00 50 12 8040.72 5300.00 5200.00 50 14 8195.89 5400.00 5300.00 49 34 8349.90 5500.00 5400.00 49 22 8502.83 5600.00 5500.00 ¢8 57 8655.06 5700.00 5600.00 48 46 8806.40 5800.00 5700.00 48 3=3 8956.35 5900.00 5800.00 47 21 9102.64 6000.00 5900.00 46 17 9244.69 6100.00 6000.00 43 56 9381.17 6200.00 6100.00 41 30 V' 9595.00 v~6363.23 6263.23 40 4 N 32 43 W 3947.12 N 34 53 W 4083.84 N 34 54 W 4218.47 N 34 52 W 4350.92 N 34 5~ W 4482.42 N 35 8 W 4612.49 N 35 22 W 4741.44 N 35 34 W 4569.18 N 35 32 W 4995.52 N 35 34 W 5120.96 N 35 40 W 5245.08 N 35 36 W 5367.12 N 35 4') W 5487.21 N 35 44 W 5607.43 N 35 54 W 5726.05 N 36 ll W 5543.13 N 36 32 W 5958.33 N 36 55 W 6073.59 N 37 2 W 6187.19 N 36 51 W 629,~.92 N 37 26 W 6405.69 N 37 14 W 6506.56 N 36 52 W 6599.42 N 36 0 W 6737.51 2.14 0.25 0.17 0.22 0.30 0.17 0.26 0.20 0.i0 0.23 3477.12 N 1949.80 W 3986.48 N 29 16 W 3590.28 N 2026.88 W 4122.91 N 29 26 W 3700.83 N 2103.94 W 4257.07 N Z9 37 W 3809.56 N 2179.76 W 4389.09 N 29 46..~W ~ 3917.60 N,72~4-, .95 W 4570, .22 N 29 55 W~ 4024.20 N 2329.67 W ,4649.90 N 30 4 W~,~ 4129'.56 N 2404.16 W 4778.42 N 30 12 W 4233.61 N 2478.38 W 4905.70 N 39 20 W 4336.41 N 2551.92 W 5031.58 N 30 28 W 4438.52 N 26!4.89 W 5156.60 N 30 35 W 0.66 0.32 0.49 0.42 0.34 0.39 0.16 0.45 0.34 1 .25 4539.47 N 2697.20 W ~280.31 N 30 43 W 4638.68 N ~_768.37 W 5401.96 N 30 ~+9 W 4736.36 N 2838.32 W 5521.70 N 30 55 W 4834.02 N 2998.50 W 5641.56 N 31 2 W 4930.25 N 2977.94 W 5759.82 N 31 7 W 5024.97 N 3046.82 W 5876.51 N 31 13 W 5118.11 N 3115.48 'W 5991.77 N 31 19 W 5210.09 N 31~4.]2 W 6106.04 N 31 25 W 5300.71 N 3252.63 W $219.09 N 31 32 W 5390.03 N 3~19.75 W 5330.34 N 31 37 W 0.90 5475.25 N 33~4.09 W 6436.65 N 31 43 W 2.18 5555.41 N 3445.32 W 6537.03 N 31 48 W 2.76 5629.36 N 3501.48 W 6629.48 N 31 52 W 0.00 V5740.88 N¥35,~2.96 W 6767.22 N 31 58 W ARCO ALASKA, INC. 1Y-30 KUPARUK NORTH SLOPE,~LASK~ MARKER TOP KUP~RUK C BASE KUPARUK C TOP KUPARUK A BASE KUPARUK A LAST GCT READING PBTO TD COMPUTATION D~TE: INTERPOLATED VALUES 13-DEC-88 FOR CHOSEN HORIZONS KELLY DaTE OF SURVEY: BUSHING ELEVATION: SURF ORIGIN= 208 FNL, 1164 OWL, S MEASURED DEPTH TVO ~ECTANG BELOW KB FROM KB SUB-SE~ NORTH/ 8987.00 5920. ~4 5820 . 84 5409. 9107.00 6003. O1 5903.0 1 5477. 9240. O0 6096.62 5996.6 2 5552. 9394.00 6209.64 6109.64 5636. 9435.85 6241.46 6141.46 5557. 9486.00 6279.83 6179.83 5684. 9595.00 6363.23 6263.23 5740. ENGINEER: ACE LOC AT EC. UL~R CO SOUTH 02 N 76 N $2 N 14 N 99 N 11 N 88 N PAGE 7 06-NOV-S8 100.00 FT SCHW&RTZ ATIDN TllN, RgE,uM ORDINAT6S EAST/WEST 3333.Z3 W 3386.01 W 3443.35 W f 3506.55 W 3522.71 W 3541.69 W 3582.96 W AR£O ALASKA, INC. 1Y-30 KUPARUK NORTH SLOPE~ALASK~ HARKER COMPUTATION DBTE: ~0~~ STR~TIGRAPHIC MEASURED DEPTH BELOW KB 13-0EC-88 SUMMARY FROM K B TOP KUPARUK C 8987.00 5920.8~ BASE KUPARUK C 9107.00 6003.01 TOP KUPARUK A 9240.00 6096.62 BASE KUPARUK A 9394.00 6209.54 LAST GCT READING 9435.85 6241.46 PBTO 9486.00 6279.83 TD 9595.00 6363.7_3 ORIG TVO KELLY IN= 208 FNL~ SUB-SE& 5820.8¢ 5903.01 5996.6Z 6109.64 6141o46 6179.83 6263°23 D~TE OF SURVEY: BUSHTNS EL6V~TION: ENGINEER: PAGF 8 06-NOV-88 . ~00.00 FT SCHWARTZ I 164 FW REC NO SURF L~ S TANG RTH/ 408. 477. 552, 636. 657. 684. 740. ~CE LOCATION AT Et. 1 T11N~ RgE,UM ULAR ~OORDINATES SOUTH EAST/WE ST 02 N 3333.Z3 W 76 N 3386.01 W,,,,~ 82 N 3443.35 W ( 14 N 3506.55 W '%. 99 N 3522.71 W 11 N 35~+1.69 W 88 N 358~_.96 W FINAL WELL LOCATION AT TD: T~U~ SUB-SE~ HORIZONTAL DEPARTUR~ MEASURED VERTICAL VERTTC~L DISTANCE ~ZIMUTH DEPTH DEPTH DEPTH :FIT D~G MTN 9595.00 6363.23 6263.23 676T.22 N 31 5~ W SCHLUMBERGER O I RECT I ONAL SURVEY ,, COMPANY ARCO ALASKA, INC. WELL 1 Y- SO F I ELO KUPARUK COUNTRY USA RUN ! DATE LOOOEO 06 - NOV - 88 REFERENCE 730S7 WE.~L.' ~'.-~0' ,O~ZO,~^L P~O,~ECT~O, (208' FNL, 1164' FWL,&,,..~£C 1, TllN, R9E, UM) ~ i~R'r H 7000 6OOO 4OOO 1000 ?9057 5CRL£ = 1/I000 IN/FT WE,,LL' I'Y 30:' :, VERTICAL PROJECTION (208' FNL, 1164' FWL,~EC 1, TllN, RgE, UM) ~ 14~1. -4000 -2000 0 0 2000 4000 6000 8000 ! 0000 ! 2000 -.4'..4-4...i......44...i...;... ?!..;-.;+. [+..i.-;4 ...... ;..~...;..¢...-4-~..¢4-.-: .z,¢.-.-~ :'-4-¢4..:-.~.;...~..;..~.~. ~.;.i,.:_:..4:.~.~.~_~.....~..~...~...:..~...:.~...:..:..i.:£3..:...t..:.~..~.:..~ ..~..~..,...c.....~...,...,...,.....~_.;..~...;.~.L.~_~.. c.~;~...L....X..,...iJ ....... 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T · -~i..--!-.f..-~-.f- .-i-+"~--"f"f"f?i 'd'-f'd-i-'~-~--~-+'! ....... f"f-'f'i"'~f'i-??"--f"+--f--~-'--f--~i-'?-'??f'!--"-f-?f'? -f-??f'~"d"+'i~- -?i-?h- -~4+~--~ q..~.*~.--++-+.~ -+.+++.q.-++44-..~-+-e+*-~...~--..+-+-e.+- ~-+-+-+-.-+-~+~.-,+++..~++~-~-~4 ~ ~ ~ ~ ~- ~-b~ -4..,+,.~.-T.., -~-.~.-~,--~-. ""~-T-'~'"~" ""T-'T'"T-+'~ '~"~""F-T'" '++'+'+"q "'T'-'+--~-'+'- '-7'-w"7-'w-' "'7'"7'"7"~~" -T"+"T'-?- "m'+-~-'T"+"~"~"T'"~" '-~-~-'+'"T ...... ?'~'"7-~-~ "~'7-m'm'q - ~ ..~.~.~ ... ~..~. L..T..., ~...~...~..~.. -~.~...~.~ ...... ~-.~..~ ...... ~-.~...~.-~-i .--~--~...~4.-. ~--~-~-~ ~-~4-~.... -.~..~-.~.~.-~ -+.~+..~..~....;..~-.~-~.. --~..4~-~+--~.-.~---T~-- -.~+.-~q ..~-~-. ..... .... "~'t--h' ~'~ -~'~- '-t-h'Z'~' "~-~': ~-~"" ~--r-~ ~ i ~ i ~ ~ ~-~ ~'~"T- ~"m~-m' -~m'~-'r-: r-~:::~'m~'~'F'TT' -I"'~-1"T~ ~ I ~ ~?'" ~'~'+ ~ '~'~'~ ~ .... ~ ~"+"m'~ ~ ~ ...... "~'m"~'"~'+" ~'~'~-~"" "~'~-' ~~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ i~ ~ ~ ~ ~ "~'~'~"~"""~'~-T"~-q'~'~'T"W'~ } ~i~'* ~.~~ ,~.~.~.~.~]"~'%'"T'~'-?'"T"W~'~ -T"W'T'~S "~%-%"'W'_~_~ "~"~" . .' 4.4..~..T~.. ,. ' .~. ~-.~.~- -~.-~-. ~-~. ~-- ~-. -~-~-.?~---, '--~-~-~---~" -~'~-'~' r"~-~'"~' "'?'??~ ...... ~-~-'~'~-' -'~--~-?'r- ~ ~ t ~: : : : : : : : : ' : : : ; ; ; ; : : ~ : : ' : : : q ~ :~ ~:: ~ ~.~~ [-4.4- -~.+~. ~-~-~ ~-~-.'-~.~-' ~-' ~-~-~-t-'t't4'-' -~'-~-:~ 4'm'~-~'" :'-'~"-?T--,-t"t-'~-'~ ...... ~"'rt:~'"~'~-t ~t:t ..... ~+.. ~ .... . ..... ~ .....~ ............. ~ ....................... m PROgECTION ON VERTICRL PLRNE 323. - 143. ~.J:ILED IN VERTICRL DEPTHS HORIZ SCALE = 1/2000 IN/FT AE~SKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon __ Suspend __ Alter casing __ Repair welt Change approved program __ 2. Name~Oper~or ^RC0 Alaska~ Inc, 3. Address P. 0, Box 100360, Anchorage~ AK 4. Location of well at surface 208' FNL, 1164' FWL, At top of productive interval :80' FNL, 2169' FEL, At effective depth 196' FSL, 2378' FEL, At total depth 253' FSL, 2419' FEL, Sec.1, Sec.35, Sec.26, Sec.26, Operation shutdown __ Re-enter suspended well __ Plugging __ Time extension __ Stimulate ~ Pull tubing -'X. Variance __ Perforate ~ Other I 5. Type of Well: Development Exploratory Stratigraphic 9951 0I- 03 60 Service T11N, T12N, T12N, T12N, R9E, UM RgE, UM R9E, UM RgE, UM 6. Datum elevation (DF or KB) i~KB I 02 t 7. Unit or Property name Kuparuk River Unit 8. Well number 1Y-30 feet 9. Permit number 88-90/8-8G5 & 8-77g 10. APl number 50-- 029-21 851 11. Field/Pool Kuparuk River Oil Pool 12. Present well condition summary Total depth: measured true vertical 9595'MD feet 6363 ' TVD feet Plugs (measured) None Effective depth' measured 9486' MD feet true vertical 6280 ' T V D feet Casing Length Size Structural Conductor 80 ' 1 6" Surface 5123 ' 9-5/8" Intermediate 4 50 Production 9540 ' 7" Liner Perforation depth: measured N o n e true vertical N o n e Tubing (size, grade, and measured depth) 4"/3-~", J-55, tbg w/tail ~ 8824' Packers and SSSV (type and measured depth) BOT 'HB' pkr ~ 8750', & AVA SSSV @ 1786' Junk (measured) Cemented 181 sx 1150 sx sx C1 ass AS II AS III G - Top None Measured depth True vertical depth 115'MD &5158'MD Job w/lO0 sx AS I 115'TVD 3553'TVD 260 sx Class G 9573'MD 6346'TVD REEEIVED SEP25 t9 9 Anchorage 13. Attachments Description summary of proposal Well Schematic Detailed operations program __ BOP sketch 14. Estimated date for commencing operation 115. Status of well classification as: September 30~ 1989 16. If proposal was verbally approved Oil X Gas __ Suspended __ Name of approver Date approved Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed Area Drillin.q Engineer Title FOR COMMISSION USE ONLY Date Conditions of approval: Notify Commission so representative may witness Plug integrity __ BOP Test ~ Location clearance ~ Mechanical Integrity Test __ Subsequent form required 10- Approved by order of the Commission ORIGINAL SIGNED BY LONNIE C. SMITH SAl/20 J Approval No. ~,,...,~,,~.....! Commissioner Approved Copy Returned Date Form 10-403 Rev 06/15/88' SU BM IT IN TRIPLICATE KRU 1Y-30 WORKOVER SUMMARY KRU 1Y-30 was completed as a single conventional completion in November '88. Only the 'A' sand was perforated with the intentions of opening the 'C' sand to production after the frac'ing of the 'A' sand. While frac'ing the 'A' sand the observed Iow frac treating pressures indicated that the frac possibly was in communication with the unperforated 'C' sand. Production rate and pressures further supported the suspicion that a channel may exist between the 'C' sand and 'A' sand. In May '89 a temperature survey was run that confirmed the existence of the channel. The well remained on production while a coiled tubing squeeze was being planned. While producing the well began to make a large amount of formation debris and eventually died due to 50-60' of fill above the top perforations. Due to the large size of the fill. it was decided that a coiled tubing cleanout and squeeze would be risky and that a workover would be required to clean out the well and squeeze off the channel. The planned workover procedure consists of killing the well and pulling the existing completion. After the fill is cleaned out the channel will be squeezed off through the existing 'A' sand perforations. The completion will be re-run and the well perforated through tubing. Following frac'ing of the 'A' sand the 'C' sand will be perforated. RECEIVED sEP25 . 9 Anchorage KUPARUK RIVER UNIT Well 1Y-30 WORKOVER PROCEDURE I · 1 1 4, Si J e Se , 10. 11. 12. MIRU Nordic #1. Pull Dummy Valve from GLM at 8,688' and set orifice valve in same. Circulate and kill well with 11.2 ppg mud. Set BPV. Nipple down tree. Nipple up blowout preventers. Pull BPV and set test plug. Test rams, annular, and choke manifold to 3000 psi. Pull test plug. Screw into tubing hanger (4-1/2" NU landing threads) and pull tubing string. Run in hole with Baker packer retrieving tool on 3-1/2" drill pipe and pull Baker (BOT) "HB" packer from 8,750'. Packer releases with 8 R.H. turns or 60,000# shear. POOH and lay down packer and tail pipe. Pick up 6-1/8" bit and 4-3/4" drill collars and run in hole. Clean out fill to PBTD 9,486' (Doyon 14's RKB-TBG Spool = 30.25'). POOH. Pick up 7" test packer and trip in hole to 9,225+/- (above top "A" sand perf at 9,248'). Set packer and test casing to 3,000 psi. POOH. Rig up wireline and set cement bridge plug at 9,400'. (Below bottom "A" sand perf at 9,390'). Run in hole with 1,000' 2-7/8" tubing stinger and 3-1/2" drill pipe to 9,400'. Use of a 'plug cutter' with drill pipe dart or a similar cementing aid is recommended. Establish injection rate into perforations. Batch mix cement and spot 150-200 sack cement plug on top of bridge plug. Have cement company test cement prior to job for desired pumping time of 3hrs+/- and fluid loss of 130-150 cc. Rotate and work pipe when setting cement plug in casing (Hole angle is 47 degrees). Pull out of cement 1,000' and squeeze cement into perforations. Leave a minimum of 3 BBL of cement (75') in the casing above the top perforation. After squeeze is obtained reverse out drill string keeping circulating pressures at or below final squeeze pressure. Wait on cement 8 hours. POOH. Pick up bit and BHA and run in hole. Clean out cement to bridge plug and test squeeze to 1,500 psi. If perfs test drill out bridge plug and clean out to PBTD. If perfs fail to test re-squeeze as required. 13. Displace out mud with 10 ppg filtered completion fluid. 14. Re-run completion as per completion detail. POOH. RECEIVED Anchorage 1Y-30 Workover Procedure. Page 2 15. 16. 17. 18. 19, 20. Set BPV and nipple down BOP stack. Nipple up tree. Pull BPV and set test plug. Test tree. Pull test plug and set BPV. Move off rig. Pull BPV. Re-perf "A" sand through tubing. Original top 10 to 25' of perforations will not be reshot until after the frac treatment. Frac "A" sand. Add "C" sand perfs and additional "A" sand perfs. Release rig to production. APl #: 500292185100 SPUD DATE: 10/08/88 ORIGINAL RKB: KUPARUK WELL 1Y-30 ADL LEASE: 25646 COMPLETION DATE: 11/27/88 SURFACE LOCATION: 208-FNL,1164-FWL,SEC1,T11N, R9E TOP OF KUPARUK: 80-FNL,2168-FEL,SEC35,T12N,R9E TD LOCATION: 253-FSL,2419-FEL,SEC26,T12N,R9E All depths are MD-RKB to top of equipment unless otherwise noted 102 TUBING SPOOL: 30.25 WELLTYPE: CASING and TUBING DETAILS SIZE WEIGHT GRADE DEPTH 16" 110# H-40 115 9.625" 36# J-55 5157 7" 26# J-55 9573 4" 11# J-55 IPC 4017 3.5" 9.2# J-55 IPC 8824 LINER DETAILS SIZE WEIGHT GRADE TOP BTM TUBING JEWELRY ITEM TYPE ID DEPTH SSSV AVA SIDEGUARD 3.25" 1786 SBR BAKER PBR 8737 PKR BAKER BOT HB 2.89" 8750 NOGO CAMCO 'D' NIPPLE 2.75" 8789 SHROUT BAKER 8823 PERMIT #: WORKOVER DATE: PAD ELEVATION: 62 88-90 GAS LIFT and FLOW INFORMATION VALVE PORT STN DEPTH MANDREL SIZE SIZE 1 3376 OTIS 1.0" DUMMY 2 5269 CAMCO KBUG 1.0" DUMMY 3 5870 CAMCO KBUG 1.0" DUMMY 4 6466 CAMCO KBUG 1.0" DUMMY 5 7034 CAMCO KBUG 1.0' DUMMY 6 7627 CAMCO KBUG 1.0" DUMMY 7 8163 CAMCO KBUG 1.0" DUMMY 8 8688 CAMCO MMG-2 1.5" DUMMY PERFORATION DATA INTERVAL ZONE FT SPF PHASE COMMENTS 9248-9340 A4 92 4 -+ 90° ATLAS SLIMKONE 9347-9390 A3 43 4 +- 90° ATLAS SLIMKONE MISC. DATA DESCRIPTION DEPTH KICK OFF POINT: 500 MAX HOLE ANGLE: 58 dog 3600 HOLE ANGLETHRU KUP: 47 dog LAST TAG DATE: 04/14/89 9486 RATHOLE: 96 ft FISH/OBSTRUCTION: PBTD: 9486 PBTDSS: 6178 REVISION DATE: 04/21/89 REASON: INITIAL 11 5000 PSI BOP STACK ! I I [,, 4 3 2 1. 9 5/8" CASING HEAD 11" -3000 PSI FLANGE 2. 11" - 3000 PSI X 7 1/6" - 5000 PSI TUBING HEAD 3. 7 1/6" - 5000 PSI X 11" 5000 PSI CROSS-OVER SPOOL. 4. 11" -5000 PSI BLIND RAMS 5. 11" -5000 PSI PIPE RAMS 6. 11" -5000 PSI ANNULAR 13. 14. 15. ACCUMULATOR CAPACITY TEST 1 . CHECK AND FILL ACCUMULATOR RESERVOIR TO PROPER IF:VEL WITH HYDRAULIC FLUID. 2. ASSURE THAT ACCUMULATOR PRESSURE IS 3000 PSI WITH 1500 PSI DOWNSTREAM OF THE REGULATOR. 3. OBSERVE TIME, THEN CLOSE ALL UNITS SIMULTANEOUSLY AND RECORD THE TIME AND PRESSURE REMAINING AFTER ALL UNITS ARE CLOSED WITH CHARGING PUMP OFF. 4. RECORD ON THE IADC REPORT. THE ACCEPTABLE LOWER LIMIT IS 45 SECONDS CLOSING TIME AND 1200 PSI REMAINING PRESSURE. ,,B,,,OP STACK TEST FILL BOP STACK AND MANIFOLD WITH BRINE. CHECK THAT ALL HOLD-DOWN SCREWS ARE FULLY RETRACTED. PREDETERMINE DEPTH THAT TEST PLUG WILL SEAT AND SEAT IN WELLHEAD. RUN IN LOCK-DOWN SCREWS IN HEAD. 3. CLOSE ANNULAR PREVENTER AND CHOKES AND BYPASS VALVES ON THE MANIFOLD. 4. TEST ALL COMPONENTS TO 250 PSI AND HOLD FOR 10 MINUTES. INCREASE PRESSURE TO 3000 PSI AND HOLD FOR 10 MINUTES. BLEED TO ZERO PSI. 5. OPEN ANNULAR PREVENTER AND CLOSE PIPE RAMS. 6. INCREASE PRESSURE TO 3000 PSI AND HOLD FOR 10 MINUTES. 7. CLOSE VALVES DIRECTLY UPSTREAM OF CHOKES. BLEED DOWNSTREAM PRESSURE TO ZERO PSI TO TEST VALVES. TEST REMAINING UNTESTED MANIFOLD VALVES, IF ANY, WITH 3000 PSI UPSTREAM OF VALVE AND WITH ZERO PSI DOWNSTREAM. BLEED SYSTEM TO ZERO PSI. 8. OPEN PIPE RAMS. BACKOFF RUNNING JOINT AND PULL OUT OF HOLE. 9. CLOSE BLIND RAMS AND TEST TO 3000 PSI FOR 10 MINUTES. BLEED TO ZERO PSI. 10. OPEN BLIND RAMS AND RECOVER TEST PLUG. MAKE SURE MANIFOLD AND LINES ARE FULL OF BRINE AND ALL VALVES ARE SET IN THE DRILLING POSITION. 1 1 . TEST STANDPIPE VALVES TO 3000 PSI. 12. TEST KELLY COCKS AND INSIDE BOP TO 3000 PSI WITH KOOMEY PUMP. RECORD TEST INFORMATION ON BLOWOUT PREVENTER TEST FORM. SIGN AND SEND TO DRILUNG SUPERVISOR. PERFORM COMPLETE BOPE TEST ONCE A WEEK AND FUNCTIONALLY OPERATE BOPE DAILY. RECEIVED Anchorage NORDIC SRE 9/89 STATE OFALASKA , ; A~A OIL AND GAS CONSERVATION COMMI~N REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown m Stimulate m Plugging __ Perforate m Pull tubing ..._ Alter casing ~ Repair well __ Pull tubing __ Other Comp1 et;e 2. Name of Operator ARCO A'laska~, Inc. 3. Address P.0. Box 100360, Anchorage, AK 4. Location of well at surface 208' FNL, 1164' FWL, Sec. 1, T11N, At top of productive interval 80' FNL, 2169' FEL, 5sc. 35, T12N, At effective depth 196' FSL, 2378' FEL, Sec. 26, T12N, At total depth 253' FSL, 2419' FEL, Sec. 26, T12N, 12. Present well condition summary Total depth: measured true vertical 9595 'MD 6363 ' TVD 99510-0360 R9E, UM R9E, UM RgE, UM R9E, UM 5. Type of Well: Development Exploratory Stratigraphic Service 6. Datum elevation (DF or KB) RKB 100' 7. Unit or Property name Kuparuk River Unit 8. Well number 1Y-30 9. Permit numbedapproval number 88-90/8-865& 8-779 10. APl number 50-- 029-21851 11. Field/Pool Kuparuk River Oil Pool ,, feet Plugs (measured) None feet Effective depth: measured 9486 'MD true vertical 6280 'TVD Casing Length Size Structural Conductor 80 ' 16" Surface 5123 ' 9-5/8" Intermediate Production 9540 ' 7" Liner Perforation depth: measured None true vertical None feet Junk (measured) None feet Cemented Measured depth True vertical depth 181 sx AS II 115'MD 1150 sx AS III & 5158 'MD 450 sx Class G - Top Job w/lO0 sx AS I 115'TVD 3553'TVD 260 sx Cl ass G 9573'MD 6346'TVD Tubing (size. grade, and measured depth) 4"/3-1/2", J-55, tbg w/tail @ 8824' Packers and SSSV (type and measured depth) BOT 'HB' pkr ~ 8750'~ & AVA $$$V ~ 1786' 13. Stimulation or cement squeeze summary N/A Intervals treated (measured) Treatment description including volumes used and final pressure 14. N/A Representative Daily Average Production or Injection Data OiI-Bbl GaS-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation Subsequent to operation 15. Attachments 16. Status of well classification as: Copies of Logs and Surveys run .~,,. Gyro Daily Report of Well Operations .,~.." Oil ..~ Gas __ Suspended 17. I hereby certify that the foregoing is tru~ and correct to the best of my knowledge. Signed [~)'~ ~c Title Form 10-404 Rev 06/15/88 ompl'eti on Wel 1 Hi story Area Drilling Engineer Service Date ~A)A ~/~ ~ # SUBMIT IN DUPLICATE S~03/079 feet ARCO Oil and Gas Company Well History - Initial Report- Daily Inelructione: Prepare and submit the "Initial Report" on the first Wednesday after a well is spudded or workover operations are started. Dally work prior to spudding should be summarized on the form giving inclusive dates only. District Field ~LRCO ALASKA INC. KUPARUK Auth. or W.O, no, AK33 [ 5 County, parish or borough NORTH SLOPE Lease or Unit ADL: 2564;1 ITitle ~OMPT.E'1P~ Stat:;(, 1Y-30 no. Operator ARCO Spudded or W.O. begun ACC£PT Date and depth as of 8:00 a.m. 11/26/88 ( 1: API; 50-029-21851 IDate . IHour Complete record for each day reported t~O~DIC i RIH W/ COMPLETION ARCO W,I. ~ no00 w.o. Prior status if a 7"@ 9572' MW:11.2 NACL The.above Is correct TD: 9573 PB: 9486 SUPV: TA 11/27/88 TD= 9573 PB= 9486 SUPV=TA For f~rm preparation and distribution, -- ' see Procedures Manual, Section 10, Drilling, Pagea 86 and 87. MIRU, ACCEPT RIG AT 0800 11/25/88, ND TREE, NU BOPE & TEST, LOAD PIPE SHED, RIH W/ COMPLETION ASSEMBLY DAILY:S37,257 CUM:$1,001,287 ETD:S1,001,287 EFC:$1,691,000 RIH W/SSSV PULLING TOOL 7"@ 9572' MW:11.2 NACL CONT. RIH W/ COMPLETION, LAND HGR & TEST, SET PKR, TEST TBG TO 2500 PSI, TEST SSSV, SHEAR PBR, SHEAR SOS, TEST .PKR TO 2500 PSI, SET BPV, ND BOPE, NU TREE, TEST TO 5000 PSI, UNABLE TO DISPLACE WELL, RU SLICKLINE, RIH, SSSV CLOSED, UNABLE TO PRESS SSSV OPEN, RIH W/ 4" KICKOVER TOOL TO PULL WIRELINE 'BRAIN' (AVA SSSV @ 1786', BOT 'HB' PKR @ 8750', TT @ 8824'.) DAILY=S242,820 CUM:$1,244,107 ETD:S1,244,107 EFC=$1,691,000 Oil& Gas Cons. C ' ~ ..... · ' ~ ~ch0rage AR3B-459-1-D iNumber all dally well history forms consecutively as they are prepared for each well. lPage no. ARCO Oil and Gas Company Daily Well 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 So'ld. "Final Report" should be submitted sled when operatione 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 coat center code District ~.CO ALASKA INC. IC°unty°[~l~J~ SLOPE Statable,(. Field KUPARUK ]Lease or ~l.J~iT.: 25641 1Y-30 IWell no. Auth, or W.O. J~1~3315 ITitle CO[VJ~LETE Operator Spudded or W~[~l~{~ Date and depth as of 8:00 a.m. IA.R.Co. Date Complete rec[~[~'~chlday reported API: 50-029-21851 ~.6,0000 ri'oral number of wells (active or inactive) on this ~cost center prior to plugging and labandonment of this well 11/25/88 IHour 0800 HRS IPrior status "a W.O. 11/28/88 ( 1 TD: 9573 PB: 9486 SUPV:TA RIG RELEASED 7"@ 9572' M~: 0.0 DIESEL MADE 2 ATTEMPTS TO LATCH AVA 'BRAIN', UNABLE TO LATCH, INCREASE PRESSURE ON CL TO 6500 PSI, PRESSURE TBG TO 5000 PSI, SSSV OPEN, RD SLICKLINE, DISPLACE W/DIESEL TEST ORIFICE, RIG RELEASED AT 1430 11/27/88 DAILY:S14,372 CUM:$1,258,479 ETD:S1,258,479 EFC:$1,691,000 Old TD Released rig New TD Date Classifications (oil, gas, etc.) Producing method Potential test data o Alas~ Oil '.& Gas Cons, J Kind of rig Type completion (single, dual, etc.) official reseed r name(s) Well no. Date Reservoir Producing Interval Oil or gasTest time Production Oil on test Gas per day F;ump size, SPM X length Choke size T.P. C.P. Water % GOR Gravity Allowable Effective date corrected ,. Signet _ ,q Date ITitle ~L~ / For form preparation and distribution, see Procedures Manual, Section 10, Drilling, Pages 86 and 87. AR3B-459-3-C Number all daily well history forms consecutively as they are prepared for each well. iPege no. Division of AtlantlcRIchfleldCornpany ARCO Alaska, Inc. Date: November 28, 1988 Transmittal #: 7358 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. 1Y-30 Cement Evaluation Log 1 1 -06-88 81 03-9468 1 Y- 3 2 Cement Evaluation Log 1 1 - 0 7 - 8 8 6 71 0- 6 71 6 1 Y - 2 9 Cement Evaluation Log 1 I - 0 6 - 8 8 6 3 8 0 - 7 4 6 0 Receipt Acknowledged: DISTRIBUTION: NSK Drilling State of Alaska(+sepia) ARCO Alaska, Inc. Date: November 28, 1988 Transmittal #: 7354 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. one signed copy of this transmittal. 1Y-25 1Y-29 1Y-30 1Y-32 LIS Open Hole Tape LIS Open Hole Tape LIS Open Hole Tape LIS Open Hole Tape Please acknowledge receipt and return 11-11-88 #72953 11-11-88 #72983 11-11-88 #72973 11-11-88 #72953 Receipt Acknowledged: -ua~e: ............ DISTRIBUTION: State of Alaska ~ STATE OF ALASKA ~ ' ALASKA OIL AND GAS CONSERVATION COMMISolON APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon __ Suspend_ Operation shutdownS_.._ Re-enter suspended well __ Alter casing m Repair well Plugging m Time extension m Stimulate m Change approved program ~ Pull tubing m Variance Perforate m Other __ 2. Name of Operator ! 5. Type of Well: \ 6. Datum elevation (DF or KB) Development ~v A R C (3 A 1 a s k a _. I n c · Exploratory R K R I (3 ? t 3. Address Stratigraphic 7. Unit or Property name P. 0 Box 100360~ Anchorage.~ AK 99510 0360 Service~ Kuparuk River Unit 4. Location of well at surface 208' FNL, 1164' FWL, Sec.1, TllN, RgE, UN At top of productive interval 250' FNL, 2450' FWL, Sec.35, T12N, RgE, UM (Approx) At effective depth 75' FSL, 2568' FEL, Sec.26, T12N, PgE, UM (Approx) At total depth 135' FSL, 2611' FEL, Sec.26, T12N, PgE, UM (Approx) 12. PresentWell condition summary Total depth: measured 9595 ' M D feet Plugs (measured) N o n e true vertical '6369 ' T¥]:) feet 8. Well number 1Y-30 9. Permit number RR-qfl 10. APl number 50-- 029-21~51 11. Field/Pool Kuparuk River Oil Pool Effective depth: measured 94 8 6 ' M D feet Junk (measured) N o n e true vertical feet 6291 ' TVD Casing Length Size Cemented Measured depth True vertical depth Structural Conductor 80 ' Surface 51 23 ' Intermediate Production 9540 ' Liner Perforation depth: measured 16" 181 sx AS II 115'MD 9-5/8" 1150 sx AS II I & 5158'MD 450 sx Class G - Top Job w/lO0 sx AS 7" 260 sx Class G 9573'MD None true vertical N o n e Tubing (size, grade, and measured depth) Packers and SSSV (type and measure~'depth); None RECEIVED NOV Alaska .Oil .& Gas Cons· Commission ch0rage 115'TVD 3570'TVD 6353'TVD 13. Attachments Description summary of proposal Well Hi story 14. Estimated date for commencing operation April~ 1989 16. If proposal was verbally approved Name of approver Date approved Detailed operations program __ BOP sketch __ i15. Oil~ · Service Status of well classification as: Gas __ Suspended 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ~,._~~..~,~z.~ Title Ar~.a Dril,,nn Engineer t FOR COMMISSION'USE ONLY Date ,, , feet Conditions of approval: Notify Commission so representative may witness (Dani) $A4/01 81 Approval No. ,¢~_ ~::),/~ ,_5'- Plug integrity __ BOP Test __ Location clearance ./~/~ ~.~ I ,, Mechanical Integrity Test __ Subsequent form required 10- Approved Copy Return_ed -- // L;orar~iSsloner ORIGINAL SIGNED BY Approved byorder of the Commissioner LONNIE C, SMITH Form 10-403 Rev 06/15/88 SUBMIT IN TRIPLICATE ARCO Oil and Gas Company Well History - Initial Report - Daily Instructions: Prepare and submit the "Initial Report" on the first Wednesday after a well is spudded or workover operations ere started. Daily work prior to spudding should be summarized on the form giving inclusive dates only. District ARCO Alaska, Inc. Field KUPARUK Auth. or W.O.A~33 15 Lease o~1~: 25641 Tttle DRILL ]Sta~K 1Y-30 no. API: 50-029-21851 Operator ARCO Spudded or WA~Cb~ Date and depth as of 8:00 a.m. 10/09/88 ( ' TD: 2749'( 22 SUPV:EEV 10/10/88 ( ~ TD: 5180'( 2~ SUPV:EEV 10/11/88 ( TD: 5180'( SUPV:EEV Date 10/08/88 IHOur Complete re~(~l~%.eaelh4day reported 0600 HRS IAR¥~.*I0000 Prior status if a W.O. · ) 49) DRILLING 16"@ 115' MW: 9.6 VIS: 91 FINISH MOVING RIG. ACCEPT RIG @ 0030 HRS 10-8-88, NU DIVERTER AND FUNCTION TEST SAME. PU BHA AND SPUD WELL @ 0600 HRS 10-8-88. DRILL 115'-251'. WORK ON CONVEYOR CHAIN. CONTINUE DRILLING AND SURVEY 251'-2149'. CIRC BOTTOMS UP, DROP SS AND TOH. RETRIEVE SURVEY, CHANGE BHA AND TIH. DRILL AND SURVEY 2149'-2749'. DAILY:S71,790 CUM:$71,790 ETD:S71,790 EFC~$1,691,000 ) 31) POOH TO RUN CSG 16"@ 115' MW: 9.4 VIS: 56 DRLD F/ 2749' TO 5180'. CBU. SURVEY. SHORT TRIP TO HWDP. RIH. CIRC AND COND MUD. POOH TO RUN CSG. DAILY:S43,390 CUM:'$115,180 ETD:S115,180 EFC:$1,691,000 CUT DRILL LINE 9-5/8"@ 5158' MW: 0.0 VIS: FINISH TOH, LD BHA. RU AND RUN 131JTS 9-5/8", 36#, J-55 BUTT CASING, SHOE @ 5157', COLLAR @ 5074'. RU CEMENT HEAD AND CIRC AND ~%C%~..^~ CONDITION WELL AND CEMENT AS FOLLOW PUMP 80 BBLS WATER, 1150 9 SX AS III @ 12.1 PPG AND 450 SX CLASS G W/ ADDITIVES @ 15.8. DISPLACED CEMENT W/ 392 BBLS WATER. LOST ALL RETURNS AFTER 155 BBLS. PUMPED PLUG TO 2000 PSI OK. FLOATS HELD OK. CIP · ~O~Ul , .-1815 HRS, 10-10-88. BACK OUT LANDING JOINT AND SET BACK _ _~A~,~'~ ...... HEAD AND BOPE. TEST BOP EQUIPMENT TO 3000 PSI. PO BHA, SLIP ""- --------; ,~%~ '/ DAILY: $216,035 CUM: $331,215 ETD :$331,215 EFC: $1,691,000 10/12/88 ( ') DRILLING 9-5/8"@ 5158' MW: 9.3 VIS: 34 TD: 8064'(2184) FINISH CUTTTING DRILL LINE AND TIH. DRILL OUT TO 15' ABOVE SUPV:EEV SHOE AND TEST CASING TO 2000 PSI, OK. CONTINUE DRILL OUT TO 5190'. DISPLACE TO POLYMER MUD AND TEST FORMATION. LEAKED OFF AT 11.6 EMW. DRILL AND SURVEY 5190'-8064'. DAILY:S42,168 CUM:$373,383 ETD:S373,383 EFC:$1,691,000 10/13/88 ( ) TIH 9-5/8"@ 5158' MW:11.0 VIS: 43 TD: 9029'( ~65) DRILL AND SURVEY 8064'-9029'. TOH FOR BIT, HOLE SWABBED WITH SUPV:DL SMALL FLOW. RIH. CIRC BOTTOMS UP MUD GAS CUT. RIASE WEIGHT TO 10.9 PPG. MONITOR WELL, SLIGHT FLOW SHUT WELL IN DP PRESS 0 PSI, CSG PRESS 0 PSI. RAISE WEIGHT TO 11.0 PPG. PUMP PILL AND POH SLOW. AT 60 STANDS HAD 3 BBL GAIN AND SMALL FLOW, RIH. DAILY:S62,742 CUM:$436,125 ETD:S436,125 EFC:$1,691,000 10/14/88 ( TD: 9340'( SUPV:DL ;) ,11) DRLG 9-5/8"@ 5158' MW:11.2 VIS: 48 RIH. CIRC OUT GAS. RAISE MUD WT TO 11.2 PPG. POOH. LD BHA AND MU NEW BHA. RIH AND REAM F/ 8979' TO 9029'. CBU. DRLD F/ 9029' TO 9340'. DAILY:S51,695 CUM:$487,820 ETD:S487,820 EFC:$1,691,000 The above is correct For form preparation and distribution, see Procedures Manual, Section 10, Drilling, Pages 86 and 87. IDate ITitle //l _ ARCO Oil and Gas comPany Daily Well History--Interim Instructions: This form is used during drilling Or workover operations. If testing, coring, or perforating, show formation name In describing work performed. Number all drill stem tests sequentially. Attach description of all cores. Work performed by Producing Section will be reported on "Interim" sheets until final completion. Report official or representative test on "Final" form. 1) Submit "Interim" sheets when filled out but not less frequently than every 30 days, or (2) on Wednesday of the week in which oil string is set. Submit weekly for workovers and following setting of oil strin§ until completion. District Field KUPARUK Date and depth as of 8:00 a.m. Alaska, Inc. ]County or~l~l~H SLOPE ARCO i=,,,, or U~%_30 I Complete reco;d f~'d~Ofl~a[~jhile drilling or workover in progress 10/15/88 ( TD: 9595'( SUPV:DL 10/16/88 ( TD: 9595'( SUPV:DL 10/17/88 ( TD:' 9595' ( SUPV:DL 7) 255) 8) 0) 9) 0) steteAK LOGGING 9-5/8"@ 5158' MW:11.2 VIS: 47 DRLG 9340' TO 9595', SHORT TRIP, TOH, RU SCHLUMBERGER, TIE W/ TRIPLE COMBO LOGS DAILY:S45,084 CUM:$532,904 ETD:S532,904 .EFC:$1,691,000 TIH W/ MICROLOG 9-5/8"@ 5158' MW:11.2 VIS: 46 TIH W/ TRIPLE COMBO LOGS, UNABLE TO GET BELOW 7678', AFTER 3 ATTEMPTS LOG UP FROM 7200', MAKE WIPER TRIP, SPOT DIESEL PILL, RU SOS, RUN TRIPLE COMBO (DIL/SFL/GR/FDC/CNL/CAL) TO TD, LOG, RU AND RUN MICROLOG IN HOLE. DAILY:S44,419 CUM:$577,323 ETD:S577,323 EFC:$1,691,000 RIH W/ 7" CSG 7"@ 9573' MW:11.2 VIS: 49 RUN ML/GR F/ 9578' TO 8800'. POOH. RD SOS. RIH. CIRC AND COND MUD. SPOT pILL. POOH. DAILY:S132,310 CUM:$709,633 ETD:S709,633 no.. MU BHA AND RIM W/ 7" CSG. EFC:$1,691,000 The above is correct For forth preparation and distribution see Procedures Manual Section 10, Drilling, Pages 86 and 87 ARCO Oil and Gas Company Daily Well History-Final Report District AA~O Alaska, .[nc. Field K~'~'~ ~- Auth. or W.O. ~.'33 15 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 subm tted also when operations are suspended for an indefinite or albpreciable 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 I County orl~'~'H ~¢JL-'~ State~K iLease or t~L; ~5~ m '[~-~U IWel, no. ITitleDR[T'L 'APi- 50-029-21551 Operator Spudded or W.~. ~e~l~'r~ Date and depth as of 8:00 a.m. Old TD Date Complete rec~r~-.~ao~'~aY reported otal number of wells (active or inactive) on thisj ost center prior to plugging and I bandqn_m_e_nt o__f_th_is well I0/1~/~ TD: 9595 PB: 9485 SUPV:DL RiG RELEASED T"~ 9573: m~:i~.2 Nau~ FINISH RUNNING 7" CASING, SHOE @ 9573', COLLAR @ 9486' CIRC .AND CONDITION WELL,· RETURNS WERE 5 - 10%. RECIPROCATED WHILE PUMPING. CEMENT WELL WITH 260 SX CLASS G CEMENT AND ADDITIVES. DISPLACED WITH 11.2 PPG BRINE. BUMPED PLUG TO 3500 PSI, OK. FLOATS HELD OK. HAD SLIGHT FLOW FROM ANNULUS, OBSERVED FOR 1.5 HR, NO PRESSURE BUILDUP, NO FURTHER FLOW. RAISE STACK, SET SLIPS AND CUT OFF CASING. INSTALL PACKOFF AND NU WELL HEAD. TEST TO 3000 PSI OK. FREEZE PROTECT ANNULUS AND RELEASE RIG @ 1900 HRS 10-17-88. DAILY:S254,397 CUM:$964,030 ETD:S964,030 EFC:$1,691,000 New TD Released rig Date Classifications (oil, gas, etc.) IPB Depth Kind of rig' IType complet, lon (sin. gle, dual, etc.) Official rese~oir name(s) . Producing method Potential test data 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 Theabove is correct For form preparation and distribution, see Procedures Manual, Section 10, Drilling, Pages 86 and 87. IDate ARCO Alaska, Inc. Date: October 21, 1988 Transmittal #: 7328 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. 1Y-30 Cyberlook 1 0-1 6-88 8850-9450 1Y-30 Microlog-GR 1 0- 1 6-88 8800-9578 1Y-30 5" Dual Induction 10-16-88 1000-9576 1Y-30 2" & 5" Raw FDC 10-16-88 8750-9550 1Y-30 2" & 5" Porosity FDC 1 0-1 6-88 8750-9550 1Y-30 2" Dual Induction 10-16-88 1000-9576 Receipt Acknowledged: DISTRIBUTION: NSK Franzen D&M Drilling State of Alasla(+sePia) ~ STATE OF ALASKA ' AI'~ OIL AND GAS cONSERVATION COMMI;~,.,;0N APPLICATION FOR SUNDRY APPROVALS 3. Address P. 0. Box 100360~ Anchorage, AK 4. Location of well at surface 1. Type of Request: Abandon __ Suspend ~ Alter casing __ Repair well __ Change approved Program ~ Pull tubing m · Variance m 2. Name of Operator ! 5. TyPe of Well: l Development Exploratory Stratigraphic 9951 0 03 6 0 Service Operation shutdown m Re-enter suspended well ~ Plugging ~ Time extension ~ Stimulate ~ Perforate __ Other 208' FNL, 1164' FWL, SEC.1, T11N, R9E, UM (Approx) At top of productwe interval 250' FNL, 2380' FEL, Sec.35, T12N, RgE, UM (Approx) At effective depth At total depth 211' FSL, 2588' FWL, Sec.26, T12N, R9E, UM (-Approx) 6. Datum elevation (DF or KB) EKB 1 02 ' 7. Unit or PropertY name Kuparuk River Unit feet 8. Well number 1Y-30 9. Permit number 88-90 10, APl number 50-- 029-21 851 11. Field/Pool Kuparuk River Oil Pool 12. Present well condition summary Total depth: measured true vertical Wel 1 p de . hasfeet not sPlu (u-d(gsdmeasured) feet None Effective depth: measured true vertiCal feet feet Junk (measured) None Casing Structural Conductor Length Size Cemented Measured depth True vertical depth Surface Intermediate Production Liner Perforation depth: measured true vertical Tubing (size, grade, and measured depth) Packers and SSSV (type and measured depth) This sundry request is for a change in bottomhole location for the subject well. This new BHL is 450'E of that previously permitted. A new form 401 is attached with relevant changes made. The change was approved by Mike Mi nder to Tom Maunder 10/7/88. ~'~ ~ ~ '~ ~( ? ~ '~',~. . .. ~ . 13. Attachments 14. Estimated date for commencing oPeration Description summary of prOpoSal Detailed oPerations program ~ BOP sketch ctober 7 1988 16.1fproposalwasverballyapproved Mike Minder to T. E, Maunder Nameofapprover Form 401 & Attachments ' !15' 10/07/88 Date approved I" service' Status of well classification as: Oil ~ Gas Suspended 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. signed ' Title ~;r, Dr'~llinq Enqin~er FOR COMMISSION USE ONLY --./" ' Conditions of approval: Notify Commission so representative'may witness ( T EM ) S A 4 / 0 01 J Approval No. Plug integrity ~ BOP Test ~ Location clearance __ I Mechanical Integrity Test ~ Subsequent form required 10- Date//~ -/,,.~ --~ SUBMIT IN TRIPLICATE :':'tRk;INAL SIGNED BY IE SMITH Approved by order of the Commiss~l~ C. .~,pproved Copy Returned /o Commissioner Form 10-403 Rev 06/15/88 l__j_l-.,,,, .... t.o~.,~Ion: sec _2~_ :T.t~ ~ q~ _~ .... Drillfn retract r L~c~ti~n, General ~ Well Sign ~ Gener~I Hbusekeeping~Rig. ~ Reserve Pit ..... ~ ~st'ems Visual Trip Tank ~-" Pit Gauge .______~ _ Fl~w Monitor Gas Detectors -:: Inspection Report ,BOPE Stack Annular Preventer ~L_ Pipe Rams Blind Rams______J.__. Choke Line Valves. H.C.~. Kill Line Waives_ ~__ Check Valve~._~/~ Test Pzessure equipment Test Results: Failures ~,,/~~ Repair or Replacement of failed Commission office notified. Remarks: " w~ii entmtive ACCU~LATOR SYSTEM Full Cha~ge Pressure___~~. psig Pressure After Closure_~~; ps~g Pump ~.ncr. c]os. pres. 200 p~ig~ min_~_sec. Full Charge Pressure Attained Controls: Master ~ Remote ~ Bl~Dds sw~tch cover~ ~/oor Saf_~tj. Valves Upper Kelly___~___Test Pressure ~ Lower Kelly__~L~Test Pressure Ball Type____~_Test Pressure .... ~~ ............ 'Inside BOP__~~ffest Pressure .... ~~O .......... Choke Manifold__~__Test Pressure~~O No. Valves_~~ ~ No. flanges.~ Adjustable Chokes_~ ~ ,dra~icai!~perat'ed choke ~~ Te~t T~e~ hrs. to-be made within days and Inspector/ Distribution orig. - AO&CCC cc - Operator cc - Supervisor RECEIVED ARCO Alaska, Inc. Post Office Box 100360 Anchorage. Alaska 99510-0360 Telephone 907 276 1215 October 4, 1988 Mr. C. V. Chatterton Commi s s i one r State of Alaska Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 SUBJECT: Conductor As-Built Location Plat- 1Y Pad (Wells 25, 26, 29, 30, 32) Dear Mr. Chatterton- Enclosed is an as-built location plat for the subject wells. any questions, please call me at 263-4944. Sincerely, d. Gruber Associate Engineer JG'hf Enclosure If you have RECEIVED OCT O 6 '/ao Oil & 8as Cons. Com,'~ission · ~ .~nchorsg~ GRU13/1.1 ARCO Alaska. Inc. is a Subsidiary of AtlanticRichfieldComc3n¥ iiii ALL WELLS LOCATED IN SEC'I'ION i, T. II N., R. g E., UMIAT MERIDIAN. PROTRACT'ED SECTION CORNER NOTES I. COORDINATES ARE ~-:~P. ZONE 4. 2. ALL DISTANCES SHOWN ARE TRUE. 5. ELEVATIONS ARE B.P.M.S.L. 4. REFERENCE FIELD BOOK: L-88-54, pgs. 76-78 AND L-88-55, I:~S. :55,:58-59. 5. O.G. ELEVATIONS FROM CED-7Y00-:5001, rev. 7. 6. HORIZONTAL POSITION BASED ON i-Y CONTROL MONUMENTS PER LHD (]nd Ass0ci(]tes. Well y, ASP's 'X' LATITUDE LONGITUDE N(~ - · E N.L. EW£, E lev. Elev: 25 5,974,755.59 5:50,951.49 700 20' :51 .5.15" 149044'55.7?_5" 568~ 1282_' 60.9' 66.1' 26 5,974,755.59 530,891.45 700 20' :5l .517" 1490 44' 57.479'' 568' 12.22' 60.6' 66.0' 29 5,975,115.51 5:50,771.76 70020' :55.062:" 149°45'0Q.933'' 208' 1104' 59.2' 65.2_' :50 5,975,115.51 5:50,8:51.66 70o20':55.060'' 149°44'59.18:3" 2:08' 1164' 59.4' 65.4' ::52 5,975,115'.:58 5:50,951.51 70020' :55.054" 149°44'55.681'' 2:08' 1284' 59.6' 65.5' · I HEREBY CERTIFY THAT I AM PROPERLY REGISTERED AND LICENSED TO PRACTICE LAND SURVEYING IN THE STATE OF ALASKA AND THAT THIS PLAT REPRESENTS A LOCATION SURVEY MADE BY ME OR UNDER MY SUPERVISION, AND THAT ALL DIMENSIONS AND OTHER DETAILS ARE CORRECT AS OF 8/Z:5/88. "ARCo Alaska, Inc. ii ii ii D.S. I-Y WELL CONDUCTOR AS-BUILT b/,.' M.O'D. A.J.R. ~$,ef. I of I ~fe.' 8- 2-~ ~. ~Vo..' NSK 6.125. d 6 August 18, 1988 J B Kewin Regional Drilling Engineer ARCO Alaska, Inc P 0 Box 100360 Anchorage, AK 99510-0360 Telecopy~No. (907) 276, 7542 Re: Kuparuk River Unit 1Y-30 ARCO Alaska, Inc Permit ~ 88-90 Surf Loc 208'FNL, I164'FWL, See. 1, Ti1N,. R9E, UM Btmhole Loc 210'FSL, 2099'FWL, Seu. 26, T12N, RqE, UM Dear Mr Kewin~ Enclosed is th~ approved application for permit~ to drill the above referenced well. The permit to drill does not inde.mnlfy you from the probable need to obtain additional permits required by law from other govern- mental 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 comm equipment installation so that the Commission may witness testing before drilling below the shoe of the conductor pipe. /3m~Y trDly/ypu~rs, ~ Chairman Alaska Oil and Gas Conservation C~ission BY ORDER OF THE COMMISSION jo Enclosure c: Department of Fish & Game, Habitat Section- w/o en¢l Department of EnVironmental Conservation - w/o encl STATE OF ALASKA ALASKA 0't,~AND GAS CONSERVATION CO~ISSION PERMIT TO DRILL 20 AAC 25.005 la. Type of work Drill I~ Redrill E;]I lb. Type of well. Exploratory [] Stratigraphic Test [] Development Oil I~ Re-Entry [] Deepen[]1 Service [] Developement Gas [] Single Zone ~ Multiple Zone [] 2. Name of Operator 5. Datum Elevation (DF or KB) 101 Field and Pool ARCO Alaska, Inc. RKB 102', PAD 67'GLfeet Kuparuk River Field Kuparuk River Oil Po 3. Address 6. Property De,s~nation P.0. Box 100360 Anchorage, AK 99510-0360 ADL 25641K ALK 2572 4. Location of well at surface 7. Unit or property Name 11. Type Bond (see 20 AAC 25.025) 208'FNL,1164'FWL,Sec.l,T11N,RDE,UM (approx) Kuparuk River Unit 5tatewide At top of productiveinterval(~ target) 8. Well nu.mber Number 250 ' FNL, ~ ' F~i~'L,Sec. 35, T1 2N, RDE, UM 1Y-30 #8088- 26-27 21~t~tsLa~8~r~FWL,Seo{26,T1~N,RDE,UM ,'/~'/~ 9.0Ac~,plr~x/J~n~te spud date A~)~)t,000 12. Distance to nearest 13. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and TVD) property line DS 1Y-14, 1Y-15 9884'MD 208' @ Surface feet 30' (~ surface feet 2560 6307'TVD feet 16. To be completed for deviated wells _~4~ 17. Anticipated pressure (see 20 AAC 25.035 (e)(2)) Kickoff depth 300 feet Maximum hole angle~o Maximum surface 211 ~ psig At total depth CVD) 3 296 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) Z~" 16" 6Z.5~ H-~O Weld 80 35 35' 115 115' ,200 ~ cf i2-i/4:; 9-5/6" ~b. UF J-~ U'i'C ~U/U 5~ 5~' .~;3~ 55/Z' I'I~U sx Ab III G F-ER~ - 450 sx c~ass G 8-1/2" 7" 26.0~ J-55 BTC 9850 34 34' ~ ~' 100 sx 50/50 Poz Lea F-ER~ ~&~E &~[O 200 sx Class G tail 19. To be completed for Redrill, Re-entry, and Deepen Operations. ~a~kG 500' above 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 ~':~. ~, .... ' ~ '~',7;~ Intermediate Liner Perforation depth: measured ~ ~L~;';~:::. {~ ~:~ ~;~ {' ;;?~" ~;~:;%~¥~5~.~,~;;;~ true vertical 20. Attachments Filing fee ~ Property plat ~ BOP Sketch ~ Diverter Sketch ~ Drilling program ~ Drilling fluid program ~ Time vs depth plot ~ Refraction analysis ~ Seabed report ~ 20 AAC 25.050 requirements ~ 21.1 hereby~i~ that the~~ is true and correct to the best of my knowledge / , / / Signed~ /~~//~~ Title Re~ional.,Drillinq Enqineer Date PD3/O 5 (~ '~/'- ~ ' / ~ ~ Commission Us~ Only~~(TEM) 1 Permit Number -- ~ APl number ~ Approval dat' -'e ~ See cover letter ~-9o ~ 50--oZ9 -~[~1 ~ 08/18/88I for other requirements Conditions of approval Samples required ~ Yes ~ No Mud Icg required ~ Yes ~ No Hydrogen sulfide measures ~ Yes ~ No Directional survey required ~Yes ~ No Required wo~~fo~~~ 5M; ~ 10M; ~ 15M ~t:~~, Other: by order of Approved by~ ~/ ~ k -¢~~~ Commissioner the commission , ~ 31 Fnrm 10-401Re~Z'~-1-85 Sul: plicate STATE OF ALASKA ALASKA ,~ AND GAS CONSERVATION C(7'~VIlSSION PERMIT TO DRILL 20 AAC 25.005 la. Type of work Drill [] Redrill I-]I lb. Type of well. Exploratory [] Stratigraphic Test [] Development Oil Re-Entry [] DeepenE]I 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 102', PAD 67'GLfeet Kuparuk River Field 3. Address 6. Property Designation Kuparuk River 0i 1 Po P.0. Box 100360 Anchorage, AK 99510-0360 APL 25641 ALK 2572 4. Location of well at surface 7. Unit or property Name 11. Type Bond(see 20 AAC 25.025) 208'FNL,1164'FWL,Sec.1,T11N,R9E,UM (approx) Kuparuk River Unit 5tatewide At top of productive interval(~ target) 8. Well nurpber Number 250, FNL,2380' FEL,Sec.35,T1 2N,RgE,UM 1 y - 3~0~.~...~ ~.4,~,_ ~.~.~,\ #8088-26-27 ~ Approximate spud dat~ Amount total depth 9'10]07/88 $500 ~000 21 FSL~2588 ~ FWL~Sec,26~T1 2N~RgE~UH 12. Distance to nearest 13. Distance to nearest well 14. Number of acres in prOperty 15. Proposed depth(Mo and TVD) property line D5 1Y-1~ 1Y-15 9655~ND 208~ ~ Surface feet ~0~ ~ surface feetl 2560 6310~TVD feet 16. To be completed for deviated wells 17. Anticipated pressure (see 20 AAC 25.035 (e)(2)) Kickoff depth 300 feet Maximum hole angle 5~° Maximum surface 211 ~ psig At total depth CVD) 3 296 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 4987 35 35' 5022 3572' 1150 sx A5 III & t~-~V ~U SX ~lasS 8-1/2" 7" 26,0~ J-55 BTC 9621 3~ 3~* 9655 6310' 100 5x 50/50 Poz Lea 1F-ERr 200 sx Class G tail o o G 500' above 19. To be completed for Redrill, Re-entry, and Deepen Operations. ~u~a r~k 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 Perforation depth: measured ?:-: :.' t: :': ';: true vertical 20. Attachments Filing fee ~ Property plat ~ BOP Sketch ~ Diverter Sketch ~ Drilling program ~ Drilling fluid program ~ Time vs depth plot ~ Refraction analysis ~ Seabed report ~ 20 AAC 25,050 requirements 21. I hereby ce~at the foreg~g i~t~e and correct to the best of my knowledge / / Signed ( ~~ ~~~~ Title R.ninnal Drilling Fnnin..~ Date/o¢~. '~'~ / ~ ~ Commission Us~ Only~~ (TEN) P~3/015 , PermitNumb$~ ~ ~ I~number ~ IApprovalda{e ISeecoverletter ~ for other requirements Conditions of approval Samples required ~ Yes ~ No Mud log required ~ Yes ~ No Hydrogen sulfide measures ~ Yes ~ No Directional survey required ~ Yes ~ No Required working pressure for BOPE ~2M; ~ 3M; ~ 5M; ~ 10M; ~ 15M Other: by order of Approved by Commissioner the commission Date ......... ,-,A...,.,., o,- R~Jhmit in triplicate ARCO iALASKA. Eno. ~- Pe.d.'IIY, 1,/ell Not 30 Rev[,ed Pr:oposel Kupeduk: Field,. North SI:ope, Alaeika 0.- ~![~...ELEV&T[rOHI 102.'. - . T KOP TVD-300 THD-300 DEP-O 3 9 · BUILD 3 DEO ~ll 15 PER IOOFT 1000._ '~r ........ ::-' i ................... ' ........................... ~133 B/ PERHAFROE~T TVD- 1 34~2 TPID-1402! DEP-309 .2000 ~EOC TVD-1841 THD*2092'DEP"~'81 : ~ ·: ~.. ~~-~ ..... 9 s/8~. c~.-~? ~) ' ~' ~~ ~ ~VD~35Z2 THD-~22 DEP-31~4 : ~= AVERAGE ANGLE ~ ~ : ' ~ ,' ..... ZOO0 0 ....... B000. TARGET TVD=$g02 TMD-8964 DEP-6324 T/'ZONE C'TVD='Sg'TZ:'TI'~8990-DEP-b"345' T/ ZONE A TVD-60?O THD-9248 DEP-6554 B/ KUP SNDS TVD-6192 THD-9455 DEP-6?20 TD (LOG PT) TVD-.63] 0 TI"ID-9655 DEP-6881 ~1000 2000 3000 4000 : - ..... YERT[CAL'-SECT[ON- ! 5000 I 6000 I 7000 :' ~ E 1 IN. "1000 FEET _ '?000_ 6.000 5000_ 4000 iZ , ;5.000 .--'1 2.00.0 1000 O. ' LASKA. x... ~ed 1Y, ~ell~o~ 30' Revleed Propoeel Kuperuk Field North Slope, Aleeke · WEST-EAST 4000 3000 2000 1 000 0 1000 I TD"'LOCATIOtt~ 211' ;FSL. 2~' FlilL ~EC. i2~. T12N. RgI[ 850 900 950 1 000 1 050 11 O0 11 50 1 200 1250 1300 1 350 , I I I I I I I I , I I I ~oo. _ I ',, ..... ~ 50. .I xx,, ~ ,I " X~°° ,, . 5o '1 ......... ~ soo ~ ............ -- X¥~oo .... _ o x -- ~ ...... ~ - ~ .................... ~ ..... ~00 ! -- 250 . 300 ' .100 I I I I I [ I [ I I I 850 900 950 1000 1050 1100 1150 1200 1250 1300 1350 50 _0 _ 50 .100 1 50 200 -. 250 300 GENERAL DRILLING PROCEDURE KUPARUK RIVER FIELD DEVELOPMENT WELLS 1 ) MIRU. 2) Install FMC diverter system. 3) Drill 12-1/4" hole to 9-5/8" surface casing point according to directional plan. 4) Run and Cement 9-5/8" casing. 5) Install and test BOPE. Test casing to 2000 psig. 6) Drill out cement and 10' new hole. Perform leak off test. 7) Drill 8-1/2" hole to loggi'ng point according to directional plan. 8) Run open hole logs. 9) Continue drilling 8-1/2" hole to provide 100' between PBTD and bottom of Kuparuk sands. 10) Run and cement 7" casin~ Pressure test to 3500 psig. 11) Downsqueeze Arctic pack"and cement in 7" x 9-5/8" annulus. 12) ND BOPE and install temporary Xmas tree. 13) Secure well and release rig. 14) Run cased hole logs. 15) Move in Workover rig. NU BOPE. 16) PU 7" casing scraper and tubing, TIH to PBTD. CirCulate hole with clean brine and TOH standing tubing back. 17) Perforate and run completion assembly, set and test packer. 18) ND BOPE and install Xmas tree. 19) Change over to diesel. 20) Flow well to tanks. Shut in. 21) Secure well and release rig. 22) Fracture stimulate. SER MUD CLEANER SHALE SHAKERS STiR,~.-- .-~, STIR MUD CLEANER STIR CENTRIFUGE TYPICAL MUD SYSTEM SCHEMATIC 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 11.4 PV 15-30 5-15 11-16 YP 20-40 8-12 8-12 Viscosity 50-100 35-40 Initial Gel 5-15 2-4 3-5 10 Minute Gel 15-30 4-8 5-12 Filtrate AP1 20 10-20 pH 9-10 9.5-10.5 9.0-10.5 % Solids 10± 4-7 12-15 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.f ppg EMW 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. - ,i~:~ After 51U' 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. TEM6/ih KUPARUK RIVER UNIT 20" DIVERTER SCHEMATIC .I DESCRIPTION 1. 16" CONDUCTOR 2. FMC SLIP~I WELD STARTING HEAD 3. FMC D IVERTER ASSEMBLY WITH TWO 2-1/16" 2000 PSI BALL VALVES 4. 20" 2000 PSI DRILLING SPOOL W/10" OUTLETS 5. 10" HCR BALL VALVES W/10" 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., REQUESTS APPROVAL OF THIS DIVERTER SYSTEM AS A VARIANCE FROM 20AAC25.035(b) MAINTENANCE ~ OPERATION I ! 1. UPON INITIAL INSTALLATION, CLOSE PREVENTER AND VERIFY THAT VALVE OPENS PROPERLY. 2. CLOSE ANNULAR PREVENTER AND BLOW AIR THROUGH DIVERTER LINES EVERY 12 HOURS. 3. 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 JG 4/26/88 '6 5 AC~AT(~R ~APACZTY T~$T I, O-ECK At~ FILL /ICCt.M,I.ATCR RESERVOIR TO PROPER LEVEL WITH HYDP. ALLIC FLUID, 2. ASStJ~ THAT ACCLMJLAT~ ~ IS ~(X) PSI W/TH 1500 PSI ~TREAM (~F TIE REGLLATt~R. :5. OBSERVE TI~E, TFEN CLC~ ALi. UNITS SIMJI. TAI~OUSLY ALL UNITS ARE CLC~ED WITH O-IARGING ~ CFF. 4. RECORD C~¢ ~ REPORT,, TIE ACCEFTABLE LOVER LTI~T IS 45 SECCN~ CL(ZtIN~ TII~ AI~ 1200 PSI REM~I~N~ · . 15-5/8" BOP STACK T[ST 4 e. ~o. I. FILL ~ STACK N~D ~ IVlN~FCLD WITH AR~IC DIESEL. 2. a-ECK THAT ALL LOCI( ~ SCREt~ IN VE1.LI-F_AD AI~ FLLLY RETRACT~ SEAT TEST PLUG IN It~ELL~ WITH RULING JT ~ RI.N IN L~ SCRE~ 5. O..OSE ~ ~EVENTER ~ ~ KILL LII~ VALVES AD,J~ TO ~ STACK. ALL. OTI-ER VALVES AI~ ~ SHOLLD BE OPE:N, 4. PRE~ UP TO 2~) PSI ~ Fa..D F~R I0 MIN, IN-. CREASE F~E~ TO ~ PSI A~D Fa.D FlOR I0 ~N. BLEED PRE~ TO 0 P~I. 5, CPEN AN~ULA~ F~'VENTE~ ~ ~ KILL. LIF~ VALVES. CLOSE TC~ PIPE ~ ~ HCR VALVES ON KILL. ~ ~ LIltS. 6. T~ST TO ~0 PSI /~D-5(~00 PSI AS IN STEP 4. 7. CCNTIr~E TESTING ALL VALVF..~ LII~.~ ~ CHOKES NTH A ~ PSI LC~ ~ 30(X) PS! HIGH, TEST STEP 4. DO I~T PI~I~IK TF~ ~ ~ T~T ~ A ~L ~~ ~IT[~ ~ ~. ~Y ~TI~ IESI ~E~ ~T ~ ~ F~Y ~, ~N T~ P[~ ~ ~ ~ ~~'pI~ ~T ~T~PI~ ~ TO ~ ~[ ~~~I, ~N~TT~PI~ ~ ~ ~T ~~ ~L ~ ~ ~E.. ~~I~~ ~TEST TOPAZ ~ 2000. ~ooo ~ooo ARCO ALASKA. Inc. ~ Pad 1Y. ~ell No~ ~0 Propoeed Kuparuk Field, North Slope, Alaeka 0 ~ RKB ELEYA~T~O# ~ ! 02' g Bu[~ a OEo 15 PERVO FT 1000. 212~~27 AFR~ 9 B/ PERH TVD=1342 THD=I 402 DEP-309 4251 EOC TVD-16'~ T~D=2134 DEP-8!5 5000_ 6000_ 15 21 2? ~ K-I~ TVD'~3Z2 T.O'4764 DEp'29ZO CSG PT TVD'3572 THD'5] 13 DEP"3256 AVERAOE ANGLE 55 DEO 2 H[N K-5 TVD-5052 T~D-Z695 / TARGET TVD'Sg02 THD'glZ8 OEP'BS8 / T/ ZONE C TVD"SglZ THD'9204 DEP"6608 T/ ZONE A TVD'6OZO THD"g4z1 DEP"682Z B/ KUP SNDS TVD=6192 THD'9684 DEP=ZO02 TD (LO~ PT) TVD"630Z THD=g884 DEP=Z166 ZOO0,.. I I I I I I I 0 1000 2000 3000 4000 5000 6000 ?000 VERTICAL SECT[ON I 8000 HORI~-~dNTAL PROJECT ION SCALE 1 IN. = 1000 FEET ARCO ALASKA. Ine. P.d 1Y. Well No' :50 Prop°ced Kuparuk Field. Nori:h Slope. Alaska 6000 5000 4000 3000 _ 2000 _ 1 000 _ O ,mi 1000 . WEST-EAST 5000 4000 3000 2000 1000 I I I NORTH $238 WEST 3994 TD LOCATION, 21 O' FSL. 2099' FWL SEC- 26. T12N. RgE / TARGET .LOCAT I ON ' 250' FNL. 2450' FWL SEC. ,35. T12N, ROlE N ~ DEO.2-O' M!N W 6587' .CTO TARGET) 1 O00 I SURFACE LOCATION' 208' FNL. 1164' FWL SEC. I. TIIN. RgE CHECK LIST FOR NEW WELL PERMITS Company /~{~C~) Lease & Well No. ITEM APPROVE DATE YES NO (1) Fe.e ~ ~/~86 1. Is the permit fee attached .......................................... ~ (2 thru 8) (3) Admin ~ ~/~/88 9. (9 th.ru 13) 10. (10 and 13) 12. 13. (4) Cas (14 thru 22) (23 thru 28) 14. 15. 16. 17. 18. 19. 20. 21. 22. 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 ............ 6. Is well to be deviated and is wellbore plat included ................ 7. Is operator the only. affected party ................................. 8. Can permit be approved before fifteen-day wait ...................... ~__ 23. 24. 25. 26. 27. 28. Does operator have a bond in force .................................. ~ Is a conservation order needed ...................................... Is administrative approval needed ................................... Is the lease number appropriate ..................................... ~ Does the well have a unique name and number ......................... ~ Is conductor string provided ........................................ ~ Will surface casing protect all zones reasonably expected to serve as an underground source of drinking water ..................... ,~ Is enough cement used to circulate on conductor and surface ......... Will cement tie in surface and intermediate or production strings ... Will cement cover all knownproduc~ive horizons .... ' ................. Will all casing give adequate safety in collapse, tension and burst.. Is this well to be kicked off from an existing wellbore '. ............ Is old wellbore abandonment procedure included on 10-403 ............ 'Is adequate wellbore separation proposed eeeeeeeeeeeeee~eeeeeeee~eee Is a div~rter system required ....................................... Is the drilling fluid program schematic and list of equipment adequate~/~.._ Are necessary diagrams and descriptions of diverter and BOPE attached. Does BOPE have sufficient pressure rating - Test to ~OOO psig .. ~,.' Does the choke ~anifold comply w/API RP-53 (May 84) .................. Is the presence of H2S gas probable ................................. ~~S C6) OTHER ~~ (29 thru 31) For 29. 30. 31 Add: Geolog~: Eng~rin~: LCS 32. rev: 6,011 exploratory and Stratigraphic wells: Are data presented on potential overpressure zones? ......... Are seismic analysis data presented on shallow gas zones .... If an offshore loc., are survey results of seabed conditions Additional requirements ............................................. 07/22/88 INITIAL' GEO. UNIT ON/OFF POOL CLASS STATUS AREA NO. SHORE ' gco[eo 5 Eu- /-o(a 89c 11[(:,o ,, , . .,, Additional Remarks: o ~o Well Histo.ry 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. oo · X~n. t ~- jO RECEIVED 0il & Gas Cons. Co_m~is_~l~ ~nchorage, ....... AbAGKA COMPUTING CENTER Wgbb NAME = 1¥~30 FI. EbD NAME I KUPAR'UK STATE ~ AbASKA BOROUGH I NORTH ~hOPE API NU~BE~ I 50-029-21851-00 REF'ERE~CE NO ~ 72973 Tape Verlficatlon Listing cblumberger AlasKa ComputiDg Center lO-NOV-1988 14543 **** REEL HEADER **** SERVICE NAME : EDIT DATE : 88/11/10 ORIGIN I FLIC REEL NAME I 72973 CONTINUATIBN # PREVIOUS REEL COMMENT : LIS TAPE, ARCO KUPARUK I Y-30v APl #50-029-21851 **** TAPE HEADER SERVICE NAME I EDIT DATE ~ 88/11/10 O~IGIN : rblC TAPE NAME I 72973 CONTINUATION # I PREVIOUS TAPE COMMENT **** FILE HEADER FlEE NAME ~ EDIT ,001 SERVICE ~ FLIC VERSION ~ O01A02 DATE : 88/11/10 MAX REC SIZE : 1096 FILE TYPE : LO bAST FILE PAGE: SCHLUMBERGER WEbb SERVICES COMPANY NAME: ARCO ALASKA, INC, FIEbDI KUPARUK BOROUGHI NORTH SLOPE STATE: ALASKA API NUMBER: 50-029-2~85~-00 RANGE] gE PERMANENT DATUM: MBL ELEVATION: 0 LOG MEASURED FROM RKO 102, ABOVE PERMA~gNT DATUM IS Tape verification Listing chlumberger AlasKa ComPutin~ Center lO-NOV-1988 1,4:43 ELEVATIONS KB: 102, DF: 101. GL: 62. DATE LOGGED: 14'0CT'$8 RUN NUMBER: ONE TD DRILLER: 9595, TD LOGGER~ 9582, CASING 9 5/8" 36,: LB ~ 5157, DRILLER/ 5156, LOGGER BIT SIZE 8 1/2" ~ 9595, TYPE FLUID IN HOLE{ LSND POLYMER DENSITY: 11,2 VISCOSITY{ 46, PH: 9, LOSS{ 4, MUD RESISTIVITY: FILTRATE RESISTIVITY: MUD CAKE RESISTIVITY: 2,02 8 75, 2,52 ~ 68, TIME CIRCULATION ENDEDI 19,30 TIME LOGGER ON BOTTOM:03:15 MAXI~U~ TEMP RECORDED~ 135 D, I0/15 10/16 b GGING ENGINEER: WITNESS { PRUDHOE BAY TINKHAM BEAL/PICKERING/bUTRICK TOOL NUMBERS: DIS :2140 PGS 508 SGC ~3533 Nb~ 1312 DIC 2191 CNC } 449 IEM 448 FIELD REMARKS: 1 I/2" STANDOFFS AND ACORN BTg, NOSE USED ON TOOL, gATRIX DENSITY = 2,65 G/C3 . F~UID DENSITY ~ 1,00 G/C3 C~b MATRIX = SAND , HOLE CORRECTION : CALIPER' 6PERATORS - F. FOSTER AND R, WILLIAMS DATE JOB STARTED: 9-NOV-SE jOB REFERENCE NO: 72973 LDP/ANA: R, SINES THIS DATA HAS NOT BEEN DEPTH SHIFTED - OVERLAYS FIELD PRINTS IS Tape Yerlfication Listing chlumberger AlasKa Computin~ Center lO"NOV'f988 1'4=43 .PAGEI * SCHLUMBERGER LUGS INCLUDED W~TH THIS f'ILE * <SEE FILE EDXT,OO2 FOR 1,2 SAMPLED FDC/CNb DATA> * FIRST TO LAST READ~NG~ 9610 * FORMATION DENSITY COMPENSATED bOG ~ FIRST TO LAST READfNG~ 9610TO 8750 , COMPENSATED NEUTRON LOG (.C~) ~ EIRST TO LAST ~EADINGI 9610' TO 8750' * MICROLOG * FIRST TOLAST READING~ 8796 * G~M~ RAY IN CASING * FIRST TO LAST REA"D1NGI 5280' TO 993' TABLE TYPE ) CONS TUNI VALO DEFI ARCO A~ASKA, INC, CN FN KUPARUK NATX STAT ALASKA OUN NORTH SLOPE ECT TOwN RANG FB 208' FNb & 1164' FWb APIN 50 -0 29.2~85~ 0 Compound. Name Flex Name Well Name Nat&on State or Province Township TABLE TYPE = CURV DEF! DEPT DEPTH CHANNEL NAME TENS TenSion SFLU SFL Unaveraged XL~ lb-Medlum Resistivity ILD Xb-Deep ReSlstivlt¥ ' SP ~pontaDeous Potential GE Gamma~ay TENS Tension IS Tape Verification Listing chlumberger Alas~a Computin~ Center IO-NOV-1988 14543 DEF! ~HI Density DRHO Delta rho RHOB Bulk Density CA~I Caliper GR Gam~a Ray NPH! NEUTRON POROSITY TNRA CALIBRATED THERNAb NEUTRON RATfO RTNR RAW THERNAL NEUTRON RATfO R~FT RCFT RCNT RCNT CFTC CFTC C~TC CNTC GR Gamma Ray TENS Tension' GR Gamma Ray TENS Tension ~bI Gamma Ray CaliPer PAGEI DATA FOR~'AT SPECIFICATION RECORD SET TYPE - 64EB ** TYPE REPR CODE VAbUE ~ 66 o 2 66 0 3 73 104 4 66 I 5 66 6 73 7 65 I1 ' 10 12 68 65 FT ~5 66 68 ~6 66 ~ 66 IS Tape Verification Listlng chlumDerger Alaska Computin~ Center lO-NOV-1988 14:43 DEPT FT 548406 TENS DIL LB 548406 SFLU DIL OHMM 548406 ibm DIL OHMM 548406 ibD DIb OHMM 548406 SP DI M DI~L V 548406 GAPI 548406 TENS FDC LB 548406 DPHI roe PU 548406 DRHO rDC G/C3 548406 RHOB FDC G/C3 548406 CALI FDC IN 548406 GR FDC GAPI 548406 TNRA 548406 RTNR CML 548406 RCr? CNG CPS 548406 RCNT Nb 54 C C~L CPS 8406 CFTC CPS 548406 CPS 548406 GAPI 548406 LB 548406 GAPI 548406 bB 548406 ** SET TYPE NAME SERV UNIT SERVICE API API API APl FIbE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP EbEM CODE CHEX) ooooo ooo, , , ~ ~ oooooooooo oo ooo oo o oo ooo oo o , , , ~ ~,oooooooooo oo ooo oo o , , , , ~.oooooooooo oo ooo oo o , , , , ~,oooooooooo oo ooo oo o ~ ~ ~ ~ .,oooooooooo oo ooo oo o , , , , ,,oooooooooo oo ooo oo o , , , . ~ oooooooooo oo ooo oo o , , ~ , ~ oooooooooo oo ooo oo o , , ~ 4 .~oooooooooo c..~ ~.~ oo ooo oo o , , . ~,oooooooooo ~ ~ oo ooo oo o , , , ~ ~ oooooooooo '~N~ CH~ O0 000 O0 0 ' ' ~ ' ~r' 0000000000 ~.~.~ oo ooo oo o , , · ~ ~ oooooooooo ?SNS ~bb~oo oo0 O0 o X 1 ~ 4 680000000000 GRMbb GAeI ~8406 O0 000 O0 0 ~ I ~ 4 680000000000 Ck~I Mbb IN _~8406 O0 000 O0 0 I I I 4 68 0000000000 DPHi;F.DC RC~ 'FDc ,CNb OR.CML GRjMbL DEPT IbD:DIb ;FDC ;CNb ,CNb 961~ 500 -99 250 -999 250 -999 250 ~9 250 81 563 9600 000 4 142 34 621 92 75O 48~ 756 9 750 76 750 TENS.DIL -9~9 SP.DIL DRHO,FDC NPHI,CNL -99~ RCNT.CNb ~99 TENS'CHL -999 CALI.MLL 4 TEN$.DIb 4~ SP.DIL DRHO,FDC NPHI,CNb 4 RCNT;CNL 166 TENS.CHh -999 CALI;MLL 7 250 SFLU,DIb 250 GR,DZb i 50 RHOB*FDC , 50 TNRA,CNb 50 CFTC;CML 250 GR;CHL 695 000 SFLU,DIL 031 GR, IL 072 R~Oa,iDC TNRA; Nb 496 '999,250 I'LM,DIL -999,250 TENS,.FDC -999,250 CAbI,FDC -9~.250 R?NR;CNb -9 ,.250 CNTC,CNb -999,-250 TEN$,~bb 4 92 027 IbM 750 .TENS 079 CALI 78 RTNR 95 CNTC 50 TENS Dlb ,FDC FDC CNI, CNb PAGEI IS Tape Verification Listing cblummerger AlasKa Computing Center DEPT RCFT FDC FDC CNL 9500 000 2 657 13 205 97 438 577 324 97 438 92 125 DRHO FDC RCNT CNL TENS CHL DPHX OIL FDC FDC CNL 9400 2 489 ~2 o0o 479 324 500 583 500 000 TENS,DXL DRHO,FDC NPHi,CNb RCNT,CNb TENS,CHh CAbI,Mhb DEPT ZLD DPH! GR DIL FDC FDC CNb ,~CNb 9300,000 26,814 23,356 57,594 758,754 57,594 59,375 TEN$,DIb SP,DXb DRHO,FDC NPHI,CNb RCNT~CHL TENS,CHh CALI,~bL DEPT DPH! GR eOF? GR DIL FDC FDC CNL CNL 9200 000 5 197 188 737 466 83 188 91 625 TENS DRHO FDC NPHI CNL RCNT CNL TENS CHL CALX DEPT XLD DPHI' OXb 'FDC FDC CNL CNb 9100 000 14 861 9 698 62 969 785 922 62 969 66,000 TENS O~HO rDC NPHI CNb RCNT CNb TENS CHL CALX OPhi GR RCF~ GR OR DXL FDC FDC CNL CNL MLL 9O0O 000 1~ 950 49 156 70~ 494 4 156 55 344 TENS'DXb SP,DXL DRHO;FDC RCNT'CNb TENS,CUb CALX,~Lb DEP~ DPH! RCGR GR G~ FDC FDC CNL 8900 000 732 2~ 638 95 688 384 404 95 688 i05 375 TEN$,DIL DRHO,FDC NPHI,CNL RCNT~CNL TENS,CHL CALi;~LL lO-NOV-Ig88 14:43 88,000 6241,594. 0,040 36'525 ~953,791 -'9999'250 ,8~ o ,o 4215 1892 ° 9 469 5940 0 -48 3 4 2313 "'999 0 8 0 5960 000 '42 781 0 000 007 g99 2~0 946 5948 000 -57 563 912 SFLU,DIL GR,DXL RHOB,FDC TNRA,CNL CFTC,CNb GR,CHb RHOB,~DC TNRA, Nb · , Hb SFLU DXL GR RHOB FDC TNRA CNL CFTC CNb GR CHh 8FLU OIL GR DXL RHOB FDC TNRA CNL SFbU GR DXL RHOB FDC TNRA CNL CFTCOR 6304,000 SFbU,DIL 313 OIL '"~2, GR, · 0~'4 RHOB, 0 0 ~TNRA~CNL 2129,063 CF~:CNb 0 47 1562 -999 10 ~0o 31 SFLU GR DXb RHOB FDC TNRA CNL CFTC CNb G~ C~b 2,807 ILM,DIL 97,438 TENSeFDC ,432 CALI,FDC ~,234 RTNR,¢NL 61~0467 CNTC,CNL 99 TENSeMLL - ,250 2,660 IbM 92,500 TENS 2,430 CALX 3;476 RTNR '56~,665 CNTC -99 i~50 TENS FD FDC CNL CNL Nbb 284 XLM DIL 594 TENS FDC 65 RTNR CNL ~ ~96 CALX FDC 854 586 CNTC CN -999 .250 TENS 5 667 IbM, 83 188 TENS, 390 CALX 851 RTNR 80. :TENS DIL FDC CNL CN 87 -999 969 TENS 490 C1 2,50 TI 13 73 ,,,99~ 579 IbM,OIL 156 TENSeFDC 498 CALX,FDC RTNR,CNL TEN$,MLL 8 2 09 2 44O3 1.66 -999 250 TENS,FDC CALI,FOC RTNR,CNL CNT~,CNL TEN ,MLL PAGE 73 5804, . 2,589 608~,000 .ol;oh 3;~e6 ~2520,671 5963 !7 9 5948 :t 0, .7 t i 4 5,86 3 4*0?8 68,000 Tape Verification Listing chlumberger AlasKa Computing Center D~PT I~D DI~ DPHI FDC GR FDC RCFT CNb GR CNb bO,D~b DPHI,FDC ,tNb GR~CNE GR,MLL IbP OIL DPHI FDC GR FDC GR tnb DEPT lb~ DIL DPH FDC OR FDC RCFT CNL DEPT DPH! FDC GR CNb GR Mbb DEPT, DPH1,FDC ~GR~FDC RCFT,CNL GR,Mbb DEPT "ILO DPHI FDC RCGR FDC FT CN~ GR CNL 8800 000 2 387 12 929 102 875 416 549 102 875 110 750 8700,000 ,370 '99 ,250 "999,250 '999,250 '999,250 '999,250 8600 000 3 283 -999 250 -999 250 -999 250 -999 250 -999 250 8500 000 -99~ 351 25O -999 250 '999 250 -999 ~50 -999 8400 000 -99~ 973 50 -999 -999 250 -999 250 -999 250 8300 000 4 773 -999 250 :999 999 999 i50 - 8200 000 3 345 999 250 -999 250 -999 250 TENS DIb SP DRHO FDC NPHI CNb RCNT CNb TENS CHh CAbI MLb TENS.DIb SP,DIb DRHO,FDC NPHI;CNb RCNT,CNL TENS,CHh CALI,MLb TENS SP DRHO FDC NPHI CNL RCNT CNb TENS CHh CAbI TEN$,DIb DRHO,FDC NPHI,CNb RCNT,CNb TENS*CHh CAbI,NLb TENS,DIL SP,DIb DRHD,FDC NPHI.CNL RCNT,CNL TEN CAb~,'CHh .Mbb TEN$,DIL SP,DIL DRHO,FDC NPHI,CNL RCNT,CNL TENS,~HL CALI, Lb TENS DIb DRHO FDC NPBI CN5 RCNT CN5 TENS. CHh lO-NOV-1988 14143 5568 000 =54 563 0 037 49 118 1774 193 -999 250 ~0 375 5904 000 -4 13 "999 0 -999 0 5672 000 "52 063 -999 250 -999 250 '999 '50 -999 !50 '999 50 5668,000 -55,094 ~999,2~0 -999,250 -999,250 -999,250 5384 000 '67 3~3 "999 2 0 ~999 2~0 -999 2 0 -999 2~0 "999 2 0 5344 O0 -7~ 75 -99 50 -999 50 -999 50 "999 50 "999 50 5480 000 -75 88 -999 ~50 "999 ~0 -999 2 0 SFLU,DIb GR.DIb RHOB.FDC TNRA,CNb CFTC,CNb GR.CHb GR,DIb RHOB,~DC ?NRA,CNb CFTC,CNb GR,CHb SFEU DIG GR RHOB FDC TNRA CNb CFTC CNb GR CHh SFbU DIb GR DIb RHOB FDC TNRA CNb CFTC CNG GR CHh SFLU DIG GR DIG RHOB FDC TNRA. Nb CFTCi~Nb GR CHh GR,DIb RHOa*FDC TmRA,CNb CFTC,CNb SFLU DIG GR RHOB FDC TNRA CNG CFTC CNG GR CHL 2 673 IbM,DIb 102 875 TENS,FDC 437 CAbI,FDC 844 RTNR,CNb 463 529 CNTC,CNb -999 250 ?EN$,Hb~ FO .141, TENS FD~ 999,250 CAb! '999,250 RTNR NE 999.250 TENS 4 089 ILM,DIL 148 [2~ TEN$,FOC -999 ~5 CAbI.FD~ -9 9 ~50 RTNR,CNb 9~9 CNTi.CNb -999 250 TEN ,MbL ,250 CAb! 999,250 RTNR :999;2~o CNTC 999,250 TEN& ~CNb ~CNb 790 'I ' RTNR.CNb -999~: ~ .FDC -999, CNTC,CNG 4,649 IbM,OIL 88,813 TEN$.FDC -999.250 CAbI;rOC -999,250 RTNR;.CNL -999,250 CNTC*CNL -999'250 3 525 IbM DIb 109 063 TENS roc -999 250 CAb! FDC -999 250 -999 250 CTNR R CNb NTC CNb -999 250 TENS Nbb PAGEI 20, 0999 0999 '999 0999 "999 ~999 3 '999 *999 '999 '999' *999 "999 ~999 ~999 "'999 iO -999 Tape verification Listing Chlum~erger AlasKa Computing Center lO-NOV-1988 14:43 -999.250 CALI.ML5 -999.250 FDC FDC CNb CNL MLI` 8100 000 2 349 -999 250 -999 250 -999 250 -999 25O -999 250 TENS DIh DRHO FDC NPHI CNL RCNT CNL TENS CHh CALl MLL DEPT DPH! RCGR GR GR FDC FDC 8000 000 ] 5!8 -999 250 -999 250 -999 250 -999 250 -999 250 TENS.OIL SP,DI~ DRHO.FDC NPHI,CNb RCNT,CNb TENS,CHh CALI,Mbb DEPT IbD DPHI 7900,000 -99 250 -999,250 '999,'0 -999,250 TENS DIb SP DIL, DRHO FDC NPHI CNb RCNT CNb TENS CHh CALl Mbb D~FT, 'IbDeDIL DPHI,FDC :GR'FDC GR,~NbNb GR,MLb 7800,000 4,173 '999,250 '999,250 '999.250 '999.250 '999.250 TENS SP DRHO NPHI RCNT TENS CALl ,FDC ,CNb 'CNL ,CHh ,Mbb DEPT ibD:Olb DPHI,FDC GR;FDC GR;CNb FDC FDC CNb 7700 000 -999 250 -999 5O 0999 ~50 -999 250 TENS 'SP DIb DRHO FDC NPHI CNb RCNT CNL TENS CHh DEPT DPHI GR GR GR OIL FDC rD(: CNL 7600,000 2,187 -999,250 '999'250 '999;250 '999,250 '999,~50 TENS DIb DRHO FDC NPHI CNb ~CNT TENS CHh DPHI .GR GR OIL. FDC FDC CN5 7500 000 2 ~95 -999 50 -999 ~50 -999 50 TENS SP DRHO NPHI RCNT DII` FDC CNb CNb DEPT DPHI RCFT ooo - -99~ 250 '99 250 '999 250 '999 250 '999 250 'Ill ooo 500 '999 50 '999 50 0999 50 -999 50 -999 50 5044 0 0 '999 '999 2 0 '99'9 250 '999 250 ~999 250 -48 ~5 '999 ~50 -999 50 -999 -999 isO$O -999 250 5208,0 -41 0999'2 '999 '999 5120 000 ''24 "999 2 0 0999 250 '999 4968 00 '28 ~50 '999 o -999 250 SFLU DII` GR OIL RHOB FDC TNRA CNb CFTC CNA` GR CH5 OFbU Dlb GR DIb RHOB FDC TNRA CNb CFTC CNL GR CHI` SFLU DIb GR OIL RHOB FDC TNRA CNb SFbU,DIb GR.Dib RHOB;FDC TNRA,CNb CFTC,CNb GReCHb SFI`U Dlb GR DIb RHOB FDC TNRA CNb CFTC tnb GR CHI` OFbU.DIb OR,DIb RHOB.rDC TNRA~CNb CF~C,CNb 2 444 IbM DIb 115 813 TENS FDC -999 250 CALl FDC -999 250 RTNR CNb -999 250 CN?C -999 250 TENS Mbb 127 TENS FDC -999 250 CAbI FDC -999 250 RTNR CN~ CN '"' .d -999 TENS -999 -999 -999 -999 4 142 '999 '999 '999 '999 ~t0 TEN~ CAb 50 RTNR 50 CNTC 50 TENS FDC FDC tnb CNL HI, I, 382 IbM,DIL 875 TENS,FDC 250 CAbI,FDC 250 RTNR,CNb 250 CNTC.CNb 250 TENSeMbL .15;,767 ,250 TENS 999,250 CAb! -999.250 RTNR -999,250 MT -999.250 tnb CNb Nbb 7~ 598 ILM,DIb 625 TENS,FDC '999 250 CA~I.FDC -999 250 RTNReCNb -999 250 CNTC,:CNL -999 250 TEN$;MbL OR;OIL RHOB;FDC .-999 ?NRA,CNL 999 CFTC,CNL, -999 226 Ib~ CALl 250 RTNR 25O CNTC DIb FDC FDC CNL tnb PAGEt '999 "999 -999 . 3 ,999 09 ,,99~ 0999 "999 ~'999 5 4 250 I$ Tape Verification Listing chlumberger AlasKa Computing Center lO-NOV-1988 14~43 GR,CNL '999,250 TENS.CHL :999, CHi., ° - 0 7400 000 2 463 -999 250 -999 250 -999 250 -999 250 -999 25O TENS DIL DRHO FDC NPH! CNL RCNT CNL TENS CHE CALf MLL DEPT, ILD,DIL DPHI,FDC GR,FDC RCFT,CNL GR,CNL FDC FDC CNL CNb MbL 7300,000 . 2,424 999,250 '999,250 '999,250 '999,250 '999,250 TENS SP DIL DRHO FDC NPHI CNL RCNT ENS CHL ALI DEPT DPH! RCFT 7200,000 3;004 '999,250 '999,250 '999,250 '999,250 '999,250 TEN$,DIL SP,DIL DRHO,FDC RCNT,CNb CAbI,~Lb DEPT, IbD,.DIb DPHI,FDC GR,FDC RCFT,CNb GR,CNL GReMbb FDC FDC 7100 000 2 580 -999 250 -999 250 -999 250 -999 250 -999 25O TENS DRHO NPH! RCNT TENS DIb FDC CNL CNL DF. PT FDC FDC CNL CNL MLb 7000,000 3;522 -999,250 -999,250 -999'250 '999,250 '999,.250 TENS,DIL SP,DIL D.RHO,FDC NPHI,CNb R'CNT,CNL TENS,CHL DEPT DPH! OIL FDC FDC CNL CNI., Mbb 6900,000 , 2,584 999,250 '999e250 -999'250 -999,250 -999'250 TENS DIL SP DRHO FDC NPH! CNL RCNT CNb TENS CHL CALI MLL DEPT IbD DPH! GR RCFT GR 6800 000 2 641 -999 250 -999 250 4892 ~00 -25 50 -99' ~50 -99~ 50 -99 250 .999 ~50 '999 50 DEPT DPHI FDC GR FDC 4784 000 999 250 -99~ 250 '99 250 -99~ 250 4792 000 -33 125 0 -999 ~0 '999 '999 '999 '999 0 4680,000 '34;906 '999,250 '999'2~0 '999,2,0 "999 4604 000 -36 750 -999 250 -999 250 -999 -999 250 250 -9999 250 '99 250 SFLU,DIL GR DZL RHOB FDC TNRA CNL CFTC CNL GR CHL SFLU DIL GR OIL RHOB FDC TNRA CNL CFTC GR CHh SFbU DIb GR Dfb RHOB FDC TNRA CNL CFTC CNL GR, CHh OR OIL RHOB FDC TNRA CNb CFtC CNL GR CHh SFLU,DIL GR,DIL RHOB,FDC TNRA,CNb CFTC,CNb GReCHL SFLU GR RHOB FDC CFTC OR CHh TEN$,DIL i~468,000 SFLU,DIb SP,DIb 9,000 GR,DIb DRHOeFDC 9999:250 RHOB,FDC NPHI,CNb -99 250 TNRA,CN~ -999,250 TENS,MbL 2 533 IbN,DIb ~ 6,88 TENS.FDC -9 250 CALI,FDC -999 ~50 R~NR,CNb -999: 50 CN~C,CNb -999 250 TEN$,Mbb 12 414 -999 -999:250 ILM,DIL ~ENS,FDC~ CALI,FDC R~NR,CNb CNTC,,CNb TENS'NLL 3 609 -999 0 -999 250 PAGE{ '999,250 9~ '999, "999; "999, '999* TIN$'FDC C LX,FDC -, iO RTNR~CNL ."~ CNTC,CNL TENS,NLL '"999 2 693 7-7 063 TENt -999 250 CAb -999 ,250 RTNI -999 250 CNTt -999 250 TEN{ 3 81 -999 -999 -999 -999 :202 DXL ,]{oo ..., CNT.i ~NL 250 -9 50 -999 250 -999 250 -999 250 2,614 IL~,DXL 85,, 375 TENS'FDC -999,250 CALI,FDC -999,250 RTNR'CNL . ~2,,6{4 999'250 '999'250 '999'250 chlUm~e c on Ala ~ Computin Center rger s a GR NL -999,250 GF~,NLL -999,250 DEPT ILO DPHI FDC GR FDC RCFT CNE R CNb DEPT, ILD,DIL DPHI,FDC GR,FDC RCFT,CNb GR,,CNL GR,MLL DEPT,~ DPH~'FDC ,GR,FDC RCFT,CNL GR,CNb I:b ,DZL DPHX,FDC GR,FDC RCFT~=CN5 GR,CNL DEPT, !LO,OIL CG ;FDC RFT,'CNb GR,CNL DEPT, ILO,OIL DPHI4FDC GR,FDC RCFT~:CNL GR;CNb GR,Mbb 6700,000 2,725 '999 250 '999 250 '999 250 '999 250 -999 250 6600,000 . 3'7~0 999,250 -999'250 -999'250 ~999,250 999,250 6500'000 3,047 -999'250 -999,250 '999,250 '999,250 -999,250 6400,000 ' 2'984 .999,250 999;250 -999,250 ~999'250 999,250 6 oo'ooo 4,103 -999,250 -999.250 -999;250 -999,250 6200'000 3,230 -999,250 '999,250 -999;250 ~999,250 ~999,2§0 RCNT,CN5 TENS'CAb CAbI,~Lb TENS OIL SPDIb DRHO FDC NPHI CNb RCNT CNL TENS CHL CALI MbL TENS,OIL SP'DIL DRHO,FDC NPHI4CNb RCNTeCNL TE~$',CHb CAlI:,~bb TENS,OIL BP'OiL DR~O,FDC NPHi.CNL RCNT,CN~ TENS;CHL TENS,OIL SP.DiL DRHO.FDC NPHI,CN5 RCNT'CNL TENS,C'HL TEN$.DI~ DRHO,FDC NPHI,CNL RCNT;,CNb TENS'CHh TENS,OIL SP,Di.L DRNO'FDC RCN~,CNL TEN$~HL CALI'~L~ IO-NOV-1988 14:43 -999 250 -999!250 -999 250 4]~4,000 -39,250 '999,250 '999,2~0 '999'250 '999'250 '999,250 '44,35 '999,2;0 '999'~i0 -9~9,2 0 -999,2 0 4268,000 '-43'875 -9~9.250 -999'2)0 '999,2)0 '999,~50 CFTC,CNL GR,CHL SFLU,DIL GR,DIL RHOB,FDC TNRA,CNb CFTC,CNb GR,CHb SFLU,DIb · GR;Dib RHOBtFDC TNRA,CNL CFTCeCNL GE,CML SFLU,DIb GR-DZL R OB;FDC TNRA,CNb 4180,000 SFbU.DIL '46,7~1 GR'DIb "999.:250 R~OB,FDC '999~250 TNRA.CNb '9~9i,:2~0 CFTC,CNb '999,250 GR,'CHb '999,250 45,1~5 GReDIL -999;.2~0 RHOB;FDC -999:i~2~0 TNRA'CNL "999'250 CFTC,CNL '999:'250 GR;CHL -999e250 3980'000 SFLUeDIb -39,406 GR'DIb -999e:250 RHOB*FDC -999,2~0 :TNRA,CN~ '999~:2~0 CFTCJ;CN~ -999~250 -999,250 CNTC,CNL '999,250 TEN$,HbL ,813 TENS, ?~99.250 CAbI, 99;250 RTNR, 999;250 CNTC~: -999,250 tENS OIL FDC FDC CNL 81:596 188 TEN$,FDC :50 -999.{50 CAL~,FDC -999, RTN 'CNL "999~?'50 -999,150 TENS,NLL -999,:250 TN~'CNL -999 ~2'856 IbM,OIL 119,..125 ,250 RTNR,CNb -'999~250 CNTC,CNL -999;250 -99 CA;bi RTNR I L 3 ,040 9 ;250 '"999 PAGE= 10 '999,250 '999,250 2'668 .999,2S0 999,2S0 '999'2S0 '9,, Tape Verification Listing chlumberger AlasKa ComPuting Center DEPT. 6100.000 TENS,DIL ILD,DIL 2'969 SP,DIL DPHI.FDC -999,250 DR.HO'FDC GR'FDC -999,250 NPHI,CNL RCFT;CN5 -999,250 RCNT,CNL GR,CNE -999,250 TEN$,CHL DEPT, 6000,000 TEN$,DXL IbD;PIb . 2,400 DPHIeFDC .999~250 DRHO,FDC GR;FDC .999.250 NPHI,CNb RCFTeCN5 .999'250 RCNT;CNb GR~CNb .999,250 TENS,CHh GR,NSL '999,250 DEPT, 5900,000 TEN$,D~5 'ILD,DIL .3'368 SP,DIL DPHZ;FDC '999,250 DRHO,FDC GReFDC '999'250 NPHI,CN5 RCFT~CNb -999,250 RCNT,CN~ G~,CNb -999;250 TENS,CHL GR,~Sb '-999;250 CALI,MS~ DEPT, 5800,000 TENS,DIb I:~D.DI5 . 4,065 '$P,DI5 DPH~;FDC 999e250 DRHOeFDC OR~F.DC -999,250 NPH~,CN5 RCFT,CN~ -999;250 RCNT,CNL GR,:CN5 -999'250 TEN$'CHL DEPT, 5700,000 TEN$,DXU XbD,DX5 . 2,762 .DPHI::,FDC 999,250 DRHO;~DC GR,FDC -999,,250 NPH.I,CN~ RCFT,CNb '999;250 RCNT,CNL GR'NSG -999,250 5600,000 TEN$,DI~ 2,882 SP,DIL DPHI;FDC -999,250 DRHO,FDC CG~.;FDC '999,250 NPHI,CNL R F..':CNL -999;250 RCNT'CNL ~R,CN~ '~99~250 TEN$,CHL DEPT 5500,000 TENS'DIL DPHI'FDC '999e250 DRHO;FDC GR,.FDC '999,250 NPHi,CNb RCFT,CN~ "999;250 RCNT'CNL GR,.CNL :999,250 TENS.,CH~ GE,~LL 999,250 CALI,~LL lO-NOV-1988 14~43 ooo 25O -999 250 -999 2~0 -999 0 -999 ~50 -999 250 3754 000 '-41 750 '999 250 -999 250 -999 -999 ~50 ooo , 750 -999 250 -999 250 '999 25~ '999 25 '999 250 3584 09o -48 375 "999 250 ~999 '999 250 '999 ~50 35~,000 - ,500 '999,2~0 '999'2~0 -99 ~.2~0 -99~,.2 0 -999,250 3634 000 -47 625 -999 250 -999 250 -999 250 999 250 3334 000 '44 906 -999 250 -999 250 "999 250 '999 250 -999 250 SFLU GR,DIU RHOB,FDC TNRA CNb CFTC GR CHh DI~ RHOB FDC TNRA CNL CFTC CN~ GR CHU RHOB FDC TNRA .CN6 CFTC CN~ GR CH~ GR DIh RHOB FDC TNRA INh ~Hb SFSU DIh GR DI5 RHOB FDC TNRA CN~ GR SFbU GR DIb RHOB FDC TNRA CNb GE RHOB FDC TNRA CNb CFTC CH~ GR -999 -999 -999 -999 910 Ib~ 063 TEN~ 250 CALl 250 RTNR 250 CNTC 250 TENS PAGEI -999 -999 -999 -999 FDC '999e 0 '999 -9{9,250 Mbb -999 -999 -999 -999 194 ILN,DIL 438 TENSeFD¢ ~5~ CAbI.FDC i~0 R~NR,CN~ 50 CNTC,CN~ TENS,Nbb TENS ~50 CAb~oFDC ~50 RTNR,CNb aS'O ZSO ~ENS,~bb 3 6)9 'ZbM,,DIb 90 ~ 5 TENS,FDC '999 !50 CA~i,FDC '99950 ETNR,CN~ -999 ~0 CNXC,CN~ -999 250 TENSmMb~ 250 CA~I"FDC 250 RTNR,CNb 250 CNTC~CNb 250 TENS,Mb~ 3 1.04 -999 -999 -999 -999 RTNR : CN~C 250 TENS CNI~ -99~ -99 -9 383 lb~,Dib 75O 250 ~EN$,FDC 250 .250 ~TNR,C~b NTC,CNb 250 TENS,Mbb 3 93 999 -999 -99~ iO -999 .I IS ,Tape Verification bistlng chlUmDerger AlasKa Computing Center 10-N0¥-1988 14:43 PAGEI 12 DEPT, IbP,Plb DPHI,FDC cGR,FDC R FT,CNE GR,CNb GR.MbL I~P DPH! rDC RC~T C~ DEFT*: DPH!:,rDC GR,.FDC GR,Mbb DE1 ! DC DEPT .DPHI,FDC GR..FDC RCF?,CNb DEPT, DPHI,FDC OR,rue GR,CNh 5400,000 3,201 =999.250 999'250 "999t250 '999,250 -999,250 5300'000 3.644 '999,250 "ggg'250 '999.250 "999.250 "999,250 520i'000 ,064 "99 .250 -999,250 '999'250 '999 0 ~1:o0'0oo .999,250 -999~250 -999;250 -999,250 -999,250 ~999,250 5000,000 -999;250 -999'250 '999;:2.50 -999;~250 .~999;250 -999,250 ~800'000 999,,i250 -999,250 -999;250 -999,250 TENSDIb SP DIL DRHO FDC NPHI CNb RCNT CNL TENS TEN$,DIb SP,DIb DRHO.FDC NPHI.CNb RCNT.CNL TEN$.CH~ TEN$'DIL SP,DIb DRHO'FDC NPHI,,CNL RCNT~CNb TEN$;CH~ CAb:I,Mbb TENS'DI~ DRHO,FDC NPHI,CNL RCNT~CNL TENS,CHh CALI.MLL TEN$,DI~ SP,D!L DRHO.,FDC RCNT,CNL TEN~.'CML CALI,,MLL TENSeDIb 8P,Olb DRHO;FDC NPHI,;CNL RCNT;CNL TENS,CHh 'CAbI.~bb DRHO,FDC NPHI,CNb ~c~,c~ 3324 000 -47 000 -999 250 "999 250 ~999 250 '999 250 "999 250 SFLU DIL GR Dib RHOB FDC TNRR CNb CFTC CNb GR CHh 3~84,000 SFbU,DIb 47;625 GR,DIb -999;250 RHOB;rDC -999..250 TNRA'CNb "999,250 C~TC.CN~ "999,250 GR;CHb "999,.250 3234,000 BFLU,DIb ~50, O0 GR,D~b -999~, 50 RHOB,FDC -999, ~0 TNRA-CNL "999. 50 CFTC'CN~ 4624;: GR.CHL .999.~0 0 -999,250 -999,250 -999,.2:50 -999i250 ~999.2.50 GR,DIb RHOB,FDC ,TNRA,CNL cr~c,¢Nb GR,CHb 250 :SFbU.DIb -999, _ -999,2b0 :GR:,Dib - 99'250 RHOB;FDC -~99,250 TNRA,CN~ !;99,250 584~0~0 CFTC,C~b 99;,2 0 GR,CHb "9! ~0 "9 iO 4580 ~0 "999 -999.250 -999,250 "999'250 '999,2~0 "999,250 4520;000 sFGU,DIb G'R.:,DIb RHOB,FDC ,T~RA,CNb C~C,CNb GRiCHb GR,DIb RHOB'FDC CFTC'CNb GR.CH~. 2 896 IbM,DIb 93 15 -999 '210 TENSeFDC CAbI..FDC -999 250 RTNR,CNb -999,250 CNTC.,CNb -999,250 TEN$,~ 3,559 IbM,DIb 104,813 TENS;rD -999.250 CAbl.~D~ .999.25 999;250 250 TENSerDC 999,250 -999.250 '~999.250 CNTC,CN~ 104,313 TEN$,MbL -999:250 IbM, -999 :DC - DC -99! :Nb --9,! CN "99 63:531~ -999,250 '999,250 '999':250 -999,250 ~999,250 54"313 RTNi CNTi Nb '999 ~0 I$ Ta · Verification Listing chlue~erger Alaska Comput n~ Center lO'NOV't988 t4:43 GR,MbE -999,250 CALI,MLb 47 0 0 -999 250 -999 250 -999 250 '999 250 '999 250 TENS DIG SP DRHO FDC NPH! CNG RCNT TENS CHh D~PT, ILD,DIE DPHI,FDC _GR,FDC RCFT, GR,MbE DIG FDC FDC 4600 000 -999 250 -999 250 -999 250 -999 ~50 -999 50 -999 250 TENS,DIG DRHO,FDC NPNI,CNb RCNT,CNb TEN~,CHb IbP DPHI GR RCFT GR GR 450 -999 -999 -999 -999 -999 000 250 250 250 250 250 250 TENS,DIG SP,DIG DRHO'FDC NPHI.CNb RCNT~C~b TE~SeC~b CAbI,Mbb DEPT IED:DIb DPHI,FDC GR,FDC RCFT ,CNG ,Mbb 4400 000 -999 250 "999 '~50 '999 50 '999 '999 50 -999 250 TENS DIG SP DIG DRHO FDC NPH! RCNT CNG TE~S CHh CA. bi DEPT DPH~ GR RCFT GR DIG FDC Mbb 4300 -99 -999 ~999 ~999 ~999 000 250 250 250 2.50 250 250 SP DIG RCN~ DEPT DPHI FDC 4200 000 ~999 2~0 -999 50 -999 I'50 -999 250 -999 250 -999 250 TENS. DRHO ReNT TENS CAb! DiG FDC DEPT DPH! DIG FDC FDC 4100,000 "999;250 -999;250 '999,250 -999 · 250 TENS,DIG DRHO'FDC NPHI,CNL RCNT.CNL DPHI G RCFT -999 250 -999 250 -999 250 -999 250 -99~ 250 446 000 -999 250 -999 ~0 2 0 '999 **999 ~0 "'999 32a '999 -999 -999 ~0 0 -999 I 0 '999 ~0 "999 50 ~264 O0 999 50 -999 25 -999 -999 25 -999 25~ '999 250 4184 000 '999 250 "99 99~ 250 ' 250 99 2~0 9~9 2~0 "999 250 399~ 000 '99 250 -99:~ 250 -99 250 250 250 -999 250 SFbU DIE GR OIL RHOB FDC TURk CNG CFTC CUb GR CHh SFGU,D~b GR.DIb RHOB,FDC TNRA,CNb CFTC,CNG GR,CHb SFGU.DIE GReDIb TNRA,~u CFTC,CUb SFGU DIG GR DIG RHOB FOC TNRA CNG CFTC CNG GR CHG SFbU DIE GR R~OB FOe TNRA CNG CFTC CNG GR CHh SFbU DI'b GR DIG RHOB roc CF3C GR CHh SFbU DIG R FDC TNRA CNG CFTC CNG -999 -999 -999 -999 -999 58 ,250 IbN.Olb ,250 TEN&.:FD~ ,250 C&bI,FDC ,250 R~NR,¢Nb ,250 CNTC,CNb ,344 TENS,MGb -999,250 IbM,DIb -999,250 TEN$,FD¢ -999,;250 R,NR.:CNb '999,{Z~ CNTC.CNb 44, TENSeMLG :999,250 Ib~,OZb 999~250 TENS,FDC ~999;250 .CNG 59,21, TENSeMbG '99! "9! "9! '9! 4 625 CAb! -999 -9! "'9 -99~ ~C ~CNb -999 '999 62 'CNG :999,250 Ib~,DIb 999,250 CAGI -.999~250 RTNR;CNb -999'250 CNTC,:CNb ' 99 ,.99 13 ~0 IS T8 · Yeri~i tion chlum~e ca ~is~inq A1 sKa Computin~ Center rger a GR.CN~ IbD DPHI FDC _CGR FDC R FT CN~ GR CNG DEPT, !LD;DIG DPHZ,FDC GR'FDC DEPT. ILD,DIL DPHI,FDC ~C~T~CNb !,bD~DIL DPHI,FDC GR~FDC ~C:FT~CNG D~PT, ILD,DIL DPHI,FDC D£PT, DPHI,FDC ~*FDC RCFT*CN5 DEPT,. DPHI;FDC GR.FDC -999.250 -999,250 ~000,000 .999,250 999,250 -999,250 -999,250 -999.250 -999'250 3900 000 '999 250 "999 250 '999 250 '999 250 '999 250 -999 250 3800,000 '999 250 '999,250 "999,250 "999'250 "999'250 3700,000 "999;250 ~999'250 '"999~250 "999'250 "999,2 0 '999,2~0 3600,000 "999'250 "999'250 999,~50 ~999~250 '999~250 lO-NOV-1988 14:43 PAGE~ 14 TENS.CHh 3900,000 G~.CHL 59.375 TEN$,Mbb -999,250 CALI,MbL -999,250 -999 250 -999 250 -999 250 ~999 250 -999 250 ~894 000 ~999 250 SFLU GR DIL RHOB FDC TNRA CNL CFTC CNL GR CHL DRHO,FDC NPHI;CNG RCNT,CNb TENS,CHh CALI,MbL TENS,DIb "999,250 SFLU,DIb SP,DIb -999,:250 GR,DIb DRHO,FDC "999,:250 RHOB,FDC NPHI,CNb "999,250 TNRA,CNL RCNT,CN~ -999,~50 CFTC, Nb TEN$,CHL 3664,000 GR'~HL CAbI,Mbb '999,250 TENS,DIS "999,25 SP'DIb '999~.25~ DRHO,FDC '999,.250 NPHI,CNb '999'250 RCNT,CNb 7999,~250 TENS,CHh 3610,000 CAbI,Mb~ -999'250 TEN$,DI5 ~999.,.250 SP,DI~ -999.~250 DEHO,FDC -999):250 NPHI,CNb "999'250 RCNT'CN~ ~-999,250 TENS..,CHb 3480,000 CALI,~Lb "999,250 -999,250 -999;2)0 -999,250 -999.,2)0 ~9~9'.250 424'000 -999'250 TEN$,DIL DRHO'FDC ~CNT,CNL TEN$,CH~ CALI,ML5 SFLU DIG GR RHOB FDC TNRA CNb CFTC CNL GR CHL SFLU DIL GR OIL RHOB FDC TNRA CNL CFtC tnb OR CHh SFbU.DIL GR,DIL RHOB*FDC TNRA,CNb CFTC.,CNb OR,CHh SFbU DIL GR PIb RHOB FDC TNRA CNL CFTC CNG GR CHh ~,250 ILM,DIL ,250 TENS,FDC -999'250 CALI,FDC ~999,250 RTNR.CNb 999,250 CNTC,CNL 5~,53~ TEN&,MLb -999.250 ILM,DIL -9990250 TENSeFDC -999,250 CALZ;FDC '999,250 RTNR,CN~ '999,250 CNTC'CN~ 46,469 T£N$,MGb ~999,250 IbM .999~250 TENS .999,250 CALl :999,250 RTNR 999,250 CHiC 36.,81) TENS CNb -999 -999 -999 -999 -999 45 :250 250 TENS 250 CAb! ,,"$0 RTNR TENS rD CNb CNb -999 ,,999 -999 -999 "999 41 ,250 _Ibl $0 ~ 50 CNT! t9 -999, ;FDC -999~. ,CNL 999.,250 CNTC,CN~ 43~500 TENS,'HLL TENS,D)b SP,DIL DRHO,FDC NP~I;CNb RCNT,CNL CAbI,~bb 3400,000 TENS, DIL "999,250 SFLU OIL -999 250 -999,250 SP,DIL -999,2.50 GR DIG -999 250 · -999.250 DRHO,FDC -999,250 RHOB FDC -999 250 CA~I,FDC -999,250 NPHI,CNh -999~250 TNRA CNL -999 250 RTNR,CNL -,,, '999 0999 -999 -999 -999 ,. 1 9'! "999 "999 "999 ,2,0 IS Tape Verification Llsti chlum~erger AlasKa Computi~ lO-NOV-1988 14{43 PAGE{ Center 3300 FDC -999 FDC -999 CNG -999 CNG -999 MbL -999 ,000 25O 25O 25O 25O 25o 25O DEPT DPH! GR RCFT GR 3200 -999 -999 CNL -999 CNG -999 000 25O 25O 25O 250 25O 25O DEPT DPHI GR GR 3100 OIL -ggg FDC -999 rDC CNG -999 000 250 250 250 250 25O 250 DEPT DPH! GR RCFT GR GR 300O DIL -999 FDC -999 ~FDC -999 CNL -999 CNG -999 Mbb -999 000 25O 250 25O 5O 25O DEPT DPH! G~ RCrT 2900 -999 -999 -999 -999 -999 -999 000 25O 25O 25O 25O 25O 25O IbD,DI5 DPHI.FDC RCFT,CN5 GR,CNb GR,MLL 2800 DIG '999 FDC '999 FDC -999 CNG -999 CNG '999 ~bG -999 00o 25O 25O 25O 25O 25O 250 DEPT DPHI RCFT TENS DIE SP DRHO FDC NPH! CNG RCNT CNL TENS CHL TENS DRHO FDC NPH! CNG RCNT CNL TENS CHL CAb! TENS,DIG SP,DIL DRHOeFDC NPHI,CNL RCNT,CN4 TEN$,CHL DRH~ DIL FDC NPHI CN5 RCN TEN~ CNL CHL CALI ~bb TE~$,DIG SP.,DIb DRHO,FDC NPHi,CNG RCNTeCNL TENS.;CHL CALI;MLL TENS SP DIL DRHO FDC RCN TEN~ CHL CALI MLL ~999 290 999 250 99~ 250 250 0o0 -999 250 '999,250 -999;250 ~999, ~999,250 3240,000 "999'2~0 '999,250 '999'150 so )0 '999'250 , :ooo 250 -999,2~0 -999,2 0 -999,250 -999,250 -999~:250 3100,000 '999~250 -999 50 -999 :)50 -999 !50 '99~ 50 '999 50 2984 00 -999 250 -999 -999 50 -999 )56 ~999 250 3030 000 -999 250 SFbU DIL GR DIG RHOB FDC TNRA CNL CFTC CNG GR CHh GR,DIG RHOB,FDC TNRA,CNL CFTC, Nb 8FLU DIL GR DIG RHOB FDC TNRA CNG CFTC. CNG GR CHb SFbU,DIL GR,DIb RHOBmFDC TNRA;.CNb CFTC,CNG GR,CHG 8FLU,DIL GR', DI'b TNRTAeCNb SFLU,DIh OR,DIG RHOB*FDC TNRAeCN CFT'C,CN~ GR,CHG -999 250 -999 250 -999 250 -999 250 ,50 "II -999 2 0 tlo° -999 -999 -999 :999 ,250 999 250 -999 '999,250 ~999, -999, 45, -99 ~ ,'0 '99 '250 '9 ~ 688 IbM,DIb TENS,FDC CALt,FD¢ RTNR,CNb CNTC,CNb TEN~INbL IbM DIL TENS FDC CALX iDC CNTC TENS ~bb IbM DIL TENS iDCD CNXC TENS MLL IbM TENS Nb 0 Tape Verification bisting Chlumberger AlasKa Computing Center DEPT, 2700,000 IDD,DID -999,250 DPHI,FDC -999,250 GR,FDC '999,250 RCFT,CND -999,250 GR,CNE '999,250 GR,MEL '999,250 TENS DID SP DIE DRHO FDC NPHI Ckb RCNT CNL TENS CHL DEPT DPH! GR RCFT GR OIL FDC FDC 2600 000 -999 250 -999 250 -999 250 -999 250 -999 250 -999 250 TENS SP DRHO FDC NPH! CNb RCNT CML TENS CHh CALI ~P~! RCFT GR GR FDC FDC CNE CNI, 2500 '999 -999 -999 -999 -999 -999 000 250 250 250 250 250 250 TENS,DIE DRHD'FDC NPHI,CNL ?ENS,CHL CALI,MLL DEPT ILD DPH! eR ReFT CNb MLL ~40~,000 .99 ,250 999 '999 TENS, DRHO,FDC NPHI'CNb RCNT'C.~b TENS,CHL CALI,MLE DEPT DPHI DIL FDC FDC NL 3~,000 -999,250 -999'250 -999;250 -999,250 -999.250 TENS, DIE SP DRHO FDC NPH! CNb RCNT CML TENS CME CAbI NLL DEPT DPH! DIE FDC FDC 2200,000 -999,250 -999,250 -999,250 '999~250 ~999,250 '999~250 SP, IL DRHO,FDC NPHI,CNE TENS.,CHL CALI;~bL DEPT DPH! GR RCFT GR DC CNL 2100 000 -999 250 -999 250 -999 250 -999 250 -999 250 -999 250 TENS DID SP DIG DRHO FDC NPHI CNL RCNT CNL TENS CHh lO-NOV-1988 14:43 -999 250 -999 250 -999 250 -999 250 1~ 000 '999 250 -999 250 -999 250 -999 250 -999 250 -999 250 2820 000 -999 250 '999,250 '999'150 '999, 50 '999, 50 '999,250 2780, 00 '999'~ 5O -999 250 -99g 250 *999 2~0 'gg9 -999 250 '999,250 '999,250 '999,250 '999'250 ~5 4 '999,250 '999,250 '999'250 '999~250 ~999~250 2500;000 '999'250 -999 250 -999 250 -999 250 -999 250 -99 250 251~ 000 "999 250 SFLU,DIb GR.DIL RHOB,FDC TNRA,CNb CFTC,CNE GR,CHb SFLU GR DID RHO8 FDC TNRA CNb CFTC CNb GR CHh SFLU.DIL GR,DIb RHOB,FDC TNRA,CNb CFTC,CNL GR,CHb SFLU,DIb RHOB,FDC TNRA,CNb ~, HL OIL RH6B FDC TNRA CNb C~ SFbU DI~ GR DID RHOB TNRA CNb CFTC CNb GR,CHb SFLU GR R~OB roC TNRA tnb CFTC CNb GR CHL -999 250 IbM,DID -999 250 TENSeFDC -999 250 CAbX,FOC -999 250 RTNR,CN~ -999 250 CNTC'CN~ 30 172 TENS,NEb -999 250 ILM.DIL -999 250 TENS,FDC -999 250 CAbZ,FDC -999 CNTCeCNL 30 TENS,MDb -999 -999 -999 -999 50 I[~,OlL 50 TENS~FDC RTNR.,!Nb TENS, "999, 50 '999, ILM,DIL TEN$',FDC RTNR TENS,MLL -999 -999 -999 -999 ,¸ 50 ~50 '999 ' 50 ,~Ib 'ggg t~0 ILa '999 RTNR~C L '999 CNTC,CNL 51 TENS,MLL -999 -999 -999 -999 -999 34 250 ILN,DXL 250 TENS,FDC 2 0 RTNR;CNL 2:~0 CALI,FDC 250 CNTC'CN'L 9138 TENS,MDb PAGEI "ggg,~{O ~999, '999, °999, 0999, '999, '999, .t - 0 Tape Verification Ltstlno chlumberger Alaska Computing Center 10-N0¥-1988 14:43- P AGE: I -I. ? DEPT, 2000.000 TENS,OIL ILO,OIL -999,250 SP;DIL DPHI,FDC '999,250 DRHO,FDC GR,FDC '999,250 NPHI,CNb RCFT,CNL '999,250 RCNT,CNL GE;CNG :999,250 TENS,CML GR,HLL 999.250 CALI.MLL DEPTo IbD DIG DPHI FDC GR CNG GE MLL DEPT ILO DPHI FDC CNG GR CNG GE MEG DEPT DPH! FDC C~L GE GR NL.L DEPT 'ibD DIL DPM! FDC GR CNG DEPT DPH! FDC C~L DEPT !LO OIL DPH! FDC GR FDC RCFT CNL GR CNG 1900 000 -999 250 -999 250 -999 250 -999 250 -999 250 -999 250 ~800,000 999,250 -999,250 ~999,250 '999,250 ~999,250 999,250 1700 000 -999 250 -999 250 -999 -999 25O -999 25O 1600 000 -999 250 -999 250 -999 250 -999 250 -999 250 -999 250 1500 000 -999 250 -999 250 -999 -999 250 -999 250 1400 000 -999 250 -999 250 -999 250 -999 250 -999 250 TENS,DIG DRHO FDC NPHI CNG RCNT CNL TENS CHL CALf ~bb TENS SP DRHO FDC NPH[ CNG RCNT CNG TENS CHh CALI ~LL TENS OIL DEMO FDC NPMI CNG RCNT CNG TENS CHh CALf MLL TENS DIG SP DIG DRHO FDC NPHI RCNT .Nb TENS CHL CALl MLL TENS SP DRHO FDC RCNT CNG TENS CHh CALI ~6b TENS DIL S DRM~ OIL FDC NPM CNG RCN~ CNG TENS CHL -999 250 -999 0 -999 250 -999 250 2400 000 -999 250 -999 250 '999 250 "999 250 -999 2~0 -999 250 ooo ~9 250 -999 250 -999 250 -999 '999 ~0 '"999 500 §oo 999 250 -999 250 -999 ~50 -999 ~50 -999 2280 000 -999 250 -999,250 ~999 250 -999 250 -999 250 -999 250 21~4 000 '999 250 -99 250 -99~ 2 0 -99 250 ~999 250 080 000 "999 250 -999 250 -999 250 -999 250 -999 250 -999 250 2030 000 SFLU,DIL GR DIG RHOB FDC TNRA CNG CFTC CNL GR CHh SFbU DIG GR DIG RHOB ~DC TNBA CNG CFTC CNG GR CHh SFLU,DIb RHOB, FDC TNRAeCNL CFTC,CNG SFLU OIL GR TNRA CNG CFTC CNG GR CHL GE'DIG RHOB,FDC TNEA.'C~ CF~C,C~b GE,CHh SFGU DIb GR RHOB FDC TNRA CNG CFTC CNG GR CHh SFLU,DIL R~DB,~OC TNRA,CNb CFTC,CNG GR~CH5 ~999,250 IbM.OIL ,999,250 XENS,FDC .999,250 CALXeFDC 999,250 RTNR,CN~ -999,250 CNTC,CN5 51,000 TENS,Mbb -999 -999 -999 26 50 ILM.DIL 50 TEN$,FD¢ 250 CAbI~FDC t~ RTNR.CNL CNTCeCNb 203 TENSeMbL ~999,250 ILN :9990250 TENS FD 9990250 CALX ~D~ -999,' CNTC ~ 52,656 -999 -999 -999 -999 ~999 ~0 .250 IbM 250 250 CAb CNTC 4~0 TENS FDC FDC -999 4O 250 Ib~,Olb 250 TENS,/FDC 250 CALI,FDC ~ RTNR.CNL CNTC~CNL 094 -999 250 'IbM -999 250 '999 250 C bX. '999 50 R~NR -999 )~0 CNTC 51 063 TENS FDC FDC CN -999 250 -999 250 -999 250 -999 250 -999 250 31 734 Ib~ DIL ~ENS FDC CALI FDC RTNR CNG CNTC CNG TENS.MLL -999! '999, '999~ "999 -9 -99 IS Tape Yerification bisti chlu~er~er Alaske Compu~i~ Cen~er IO'NOV'I988 14~43 GR.MLL '999.250 CAhI.Mhb -999,250 FDC FDC CNn CNL MLL 1300 000 -999 250 -999 250 -999 250 -999 250 -999 250 -999 250 TENS OIL SP DRMO FDC NPHI CNh RCNT CNb TENS CHh CALI MLh DEPT ILD DPHI GR RCFT GR DIL FDC FDC CNL CNL MLL 1200 -999 -999 -999 -999 -999 -999 O0 250 250 250 250 250 TENS SP OIL DRHO FD NPHI CN~ RCNT CNL TENS CHh CALl MLL DEPT DPHI GR 1100 000 -999 250 -999 250 -999 250 -999 250 -999 250 -999 250 TENS DIL SP DIL DRHO FDC NPHI CNL RCNT CNL TENS CHh CALI MLL DEPT, ILD,DIL DPHI FDC GR FDC RCFT CNL GR CNL DIL FDC FDC CNL CNL 1000 000 -999 250 -999 250 -999 250 -999 250 -999 250 -999 250 ~ N ~E S,DIL DRHO'FDC NPHI,CN5 RCNT,CNL TENS,CHh CALi;MLL ILD DPH1 G~ RC:FT 99 DIL FDC -999 FDC -999 CNL -999 CNL -999 MLL -999 00 5O 250 25O 5O 250 TENS.DIL SP,DIL DRHO,FDC .NPHI,CNL RCNT,CNh TENS,CHh CALI'MLL DPHI ~CFT -999 ~0 -999 0 -999 ~0 -999 0 -999 ~0 1975 0 -999 50 -99~ 250 -99 250 -999 250 -999 250 ~999 250 875 000 -999 250 250 -9 9 250 250 -99 181~ 000 -999 250 -999,250 -999,2~0 -999,20 -999,250 -999,250 ~775,000 '999,250 -999 50 -999 i50 -999 50 '999 ~50 '999 50 1770 O0 -999 25.0 SFLU DIL RHOB FDC TNRA CNL CFTC CNL GR CHh SFLU DIL GR DIL RHOB FDC CFTC OR CHh SFLU Plb GR RHOB FDC TNRA CNL , CHh SFLU DIL GR Dlb RHOB FDC TNRA CNL C XC CNL OR CHh SFLU OIL OR DXL RHOB FDC TNRA CNL -999 250 IbM DIL -999 250 TENS FDC -999 250 CALl FDC -999 250 RTNR CNL -999 250 CNTC 47 344 TENS MLL -999 -999 -999 -999 -999 49 50 5O TENS 250 CALl 250 RTNR 25~ CNTC 56 TENS CNL CNL Mbb -999 -999 -9999 -99 -999 {0 5 0 ILM,DIL 50 TEN$,FDC 50 CALI,FDC 250 RTNR,CNL 250 CNTC,CNL 859 TENSiMLL -999 -999 -999 -999 -999 40 250 .50 50 CNTC,, :Nb TENS~ ILL '99 ,250 '99~,250 '999,250 '999,250 '999,~50 45, 63 ~C -999 50 -999 ~50 '999 ~ '999 '999 '999, '999,' '999, '999, · " 0 END OF DATA IS Tape Verification Listing Chlom.ergerb AlasKa Computtn~ Center **** FILE TRAILER ***~ FILE NAME : EDIT ,OOi SERVICE : FLIC YERSION : 001A02 DATE : 88/11/10 HAX REC SIZE : 1096 FILE TYPE : LO L~ST FILE ~ ~* FILE HEADER FI~E NAME ~ EDIT ,002 SERVICE : FbIC VERSION : 001A02 DATE : 88/11/I0 MAX EEC SIZE : 1096 FXEE TYPE : ~0 LAST FILE lO-NOV-1988 14:43 19 THIS DATA HAS NOT BEEN DEPTH SHIFTED - OVERLAYS FIELD PRINTS SCHLUMBERGER bOGS INCLUDED ~IT~ THIS FILE (EDIT,O0 <SEE FILE EDI, T,O01 FOR 6 SAMPLED DIb/FDC/CNb/GR~DATA> FOR~ATIO DENSITY COMPENSATED LO .FDH) FIRST TO LAST READING~ O',TO 8798' CO~PENSATED,~EUTRON ~OG. FIRST TO ~AST READING: 9610' TO 8798' TABLE TYPE' : CONS TUNI VALU DEFI CN ARCO A~ASKA, INC, Company Name F~ K'UPARUK Field ~ame Tape Verification Listing chlumberger AlasKa Computing Center lO-NOV-1988 14:43 PAGE{ :20 WN NATI COUN NORTH SLOPE TOWN FL 8' FNb & 1164' ENGI TINKHAM SON 548406 APIN 50'029'21851-00 TUNI VAbU DEFI 1Y-30 Well Name FW6 Nation State or Province County section Township Ran · Fie~d Lo~ation ~nqipeet $ Nam~ ~etvice Order Number AP[ Serial Number TABLE TYPE I CURV DEFI DEPT DEPTH CHANNEL NAME TENS Tension DPH! DensitY Porosity DRHO Delta tho NFDC Neat FDC unt Rate FFD~ Far FDC Count Rate CALI Caliper G~ Gamma Ray NPHI NEUTRON POROSITY TNRA CALIBRATED THERMAL NEUTRON RATIO RTNR RAW THERMAL NEUTRON RATIO R~FT RCFT RCNT RCNT CNTC CNTC DR Gamma Ray DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VAhUE I 66 0 2 66 0 3 73 64 4 66 5 66 6 73 7 65 8 68 0,099 IS Tape Verification Listing chlumberger AlasKa ComPuting Center lO-NOV-1988 14{43 TYPE REPR CODE VALUE 9 65 11 66 17 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 I DPH! FDH PU 548406 DRHO FDH G/C3 548406 G/C3 548406 RHOB FDH N~DC FDH CPS 548406 .,.~ ~. .. ~4.~o. .~. c.. ~.~o~ .~,. c~. c.~ ~,~o. $* SET TYPE - CHAN ** NAME SERV UNiT SERVICE API AP! APl AFl FZbE NUMS NUMB SIZE REPR PROCESS ID ORDER # bOG TYPE CLA88 MOD NUMB SAMP EbEM CODE (HEX) DEPT FT 548406 O0 000 O0 0 2 I I 4 68 0000000000 TENS FOH LB 548406 O0 000 O0 0 ~ ~ I 4 68 0000000000 oo ooo oo o . , I 4 68 oooooooooo oo oo0 oo o 2 t I 4 68 000o000000 oo ooo oO o 2 ~ 4 68 0000000000 oo 000 oo 0 2 ~ 4 68 0000000000 oo 000 oo 0 2, t 4 68 0000000000 oo 000 oo 0 2 x 4 68 0000000000 O0 O0 o oo o 2 1 i 4 68 oooooooooo O0 ~ 1 O0 O0 0 4 68 0000000000 O0 000 O0 0 I I 4 68 O~ O0 000 O0 0 2 1 I 4 68 O~ oo ooo ~o o ~ ~ ~ ~ ~ ,ooooo O0 000 00, 0 2 ! ' 4 68 ~00000 ~,~ ¢.. ~. ~o~ oo ooo ooo_~, ~ , ~0ooooo~ CNH GAP! 548406 O0 000 O0 0 1 I 4 68 O0000v PAGEl DEPT, RHOB,FDH 'GR,FDH RCFT,CNH DEPT, RHOB,FDH RC~'FDH ,CNH DEPT, RHOB,FDH GR,FDH RCFT.CNH 9607.000 i24 9600,000 1,924 lO' 88 9500 000 2 4O 52 517 TEN$.FDH NFDC,FDH .NPHI.CNH RCNT.CNB TENS FDH NFDC FDH NPHI CNH RCNT CNH TENS FDH NFDC FDH NPHI CNH RCNT CNH 4292,i00 DPHI,FDH 88 , O0 FFDC'FDH 4~,~68 ~NRA,CNH 1758, 68 CNTC.CNH 4448,000 DPHI,FDH 881,500 FFDC,FDH 45,368 TNRA,CNH 1758,668 CNTC,CNH 6220,000 DPHI,FDH 64~,000 FFDC.FDH 19~9,766 TNRA,CNH .55! CNTC.CNB 44,026 DRHO,.rDH ,,o~,~ c,,,~l''~°" mTN 1820;926 GR,CNH 44,.0~0 DRHO, 0 6 FDH CA~I., FDH 180~,436 RTNR, NH 1820,926 GR,~NH 5,093 DRHO,FDH 5 8,500 CAbI,FDH 1 ,043 GR,CNH ,o IS Tape Verification Listing chlumberger AlasKa Computing Center IO-NOV-lgSB 14:43 22 DEPT, 9400.000 RHOB.FDH GR,FDH 89'375 RCFT,CNH 497,730 DEPT, 9300 000 RNOB,FDH 2 316 ~.FDH 57 563 RC ,C~H 865 3s5 DEPT, 9200,000 RHOB,FDH ~:367 GR,FDH 7 063 RCFT.CNH 708,659 DEPT, 9i00,000 RHOB,FDH 2,747 ,CNH 880,929 DEPT 9000,000 GR,FDH 54,031 RCFT,CNH 688,600 DEPT, 8900,000 RHOB,FDH 2,328 GR,FDH i!0~500 RCFT,CNH DEPT.. 8800,000 RHOB'fDH 2,558 ,GR;'FDH 102,188 RCFT,CNH 490;306 DEPT. 8797~199 RHOB,FDH 2,330 GR,FD~ !0 ~CFT,CNH 42~:'!'25'186 END OF DATA TENS FDH NFDC FDH NPHI CNH RCNT CNH TENS.FDH NFDC,FDH NPHI;CNH RCNT,CNH TENS,FDH NFDC, FDH NPHI'CNH RCNT'CNH TEN$,FDH NFDC,FDH NPHI 'CNH RCNT,CNH TENS, FDH NFDC,FDH N'PHI'CNH TEN$.FDH NFDC FDH NPHI CNH RCNT CNH TENS.FDH NFDC,FDH NPHI,CNH RCNT,CNH TENS,FDM NFDC,FDH NPMi ~; CNH RCNT'CNH 5928,000 00,500 643.063 1774,808 598 O0 61 :° O9 5852,O00 591'000 32 ;'/29 2357,812 5784,000 453'000 30,000 2581,81.9 5864,000 424,000 31,883 2281,518 5694,000 638,500 48,762 1506,015 5484,000 629,000 47;!34 179X,892 5532,000 610,500 46;567 1642,67 i DPHI,FDH FFDC,FDH TNRA~CNH CNTC,CNH OPM! FDH FFDC FDH TNRA CNH .CNTC CNH DPHZ,FDH FFDC,FDH TNRA,CNH CNTC,CNH DPHI,FDH FFDC,FDH TNRA.CNH CNTC~CNH DPHI,FDH FFDC,FDH TNRA'CNH C~TC'CN~ DpHI,FDH' 'FFOC*FDH TNRA,CNH CNTC,CNH DPHI.FDH FFDC'FDH TNRA,CNH CNTC,CNH DPHI,FDH FFDC;FD~ TNRA,CNH CNTC,CNH 13,282 DRHO,FDH 50~750 CAL,I,FDH i898,530 RTNR.CNH ,354 GR,CNH 5 2'7781 2520, 30 DRHO,FDH CAL, I.,FDH RTNR,CNH GR;CNH 2349 {.58 DRHO,FDH 000 CAL,I,FDH 96I RTN *,CNH 588 GR*:CNH - ,898 DRHO,FDH ,125 CAL,I,FDH 222,764 RTNR*CNH 2588,355 GR,CNH 8,477 DRHO.FDH 342,250 CAb!,FDH :2242~,009 R~NR,CNH ,32X GR,CNH 19'526 DRHO,FDH 648;.000 CAL,I,;FDH 3~974 RTNR,,CNH 1637,98:1 'GR;CNH 5 440 1,800 581. DRHO,FDH 500 CAbI'~DH :845 RTN ,CNH GR,CNH 19':392 DRH¥*FDH 618,000 CAb *FDH 3;811 RTNR.'CNH 1809,804 GR,CN:H 0,024 96 0,0!~ 0'000 75 ~0~ 10,1 8 ~008 ~0 8 :o..oOz ~0'05~ FIL,E NAHE : EDIT ,002 SERVICE ~ F5IC ERSION : O01A02 AT~ : 88/11/10 FIbE TYPE ~ l~O L,AST FIbE : IS Tape Verification Listing chlumBerger AlasKa Computing Center **** FILE HEADER FILE NAME = EDIT ,003 ERVICE = FLIC ERSION : O01A02 DATE : 88/11/10 MAX REC SIZE : 1096 FILE TYPE : LO lO-NOV-1988 i4:4] ¸23 THIS DATA HAS NOT BEEN DEPTH SHIFTED - OVERLAYS FIELD PRINTS SCHLUMBERGER LOGS INCLUDED WITH THIS FILE FILE NAME = EDIT,O03 = <i,2" SAMPLE RATE> MICROLOG DATA AVAIbABbgl 8796' TO 9624" TYPE : CONS TUNI V'ALU DEFI CN ARCO ALASKA, INC, Company Name FN KUPARUK Field Name WN IY-30 Well Name STAT ALASKA State or Province COUN NORTH SLOPE Countyn 8ECT I Sectlo TOWN Township RAnG E Ri FL 208' FNL & 1164' F~L Fi ENGI T!NKHA~ En~ me SON 548406 S rder Number APIN 50-029-2~851-00 APl IS Ta e ti n Listing cblum~e Verlfica o rger AlasKa Computing Center lO-NOV-I. 988 14:43 TABLE TYPE : cuRv DEFI DEPT DEPTH CHANNEL NAME MINV Micro-Inverse Resistivity MNOR ~lcro-Normal Resistivity HTEN HEAD TENSION ¸24 DATA FORMAT 8PKC!rlCATION RECORD ** ~ SET TYPE - 64EB ay TYPE REPR CODE VALUE I 66 0 2 66 0 3 73 16 4 66 5 66 6 73 7 65 Il 66 0 1~ 65 FI 16 66 0 66 ** SET TYPE - CHAN ** NAAE SERV UNIT SERVICE APl API APl APl FILE NUmB NUMB SIZE REPR PROCESS ID ORDER # bOG TYPE CBA$$ MOD NUMB SAM~ EbEM CODE (HEX) DEPT FT 548406 O0 000 O0 0 ~ 1 1 4 68 O000gO0000 MIN¥ MLL O.M~ 54B406 O0 000 O0 0 % 1 4 6B 0000 00000 ~o~ .bt~ o,.. s~4o~ oo ooo oo o ~ ~ ~ 4 o~ oooo~oo.ooo HTEN MLL 'LB 548406 O0 000 O0 0 3 1 I 4 68 0000 00000 ** DATA ** DEPT. 96II.832 MIN~V,ML5 1,156 MNOR,MbL i,591 HTEN.Mbb -'194'000 Tape Verification Listing chlum~erger Alaska Computin.g Center DEPT, 9500,000 MINV,~LL DEpT, 9500,000 MINV,~Lb DEPT, 9400.000 IINV,~Lb DEPT, 9300,000 ~INV,~LL DEPT, 9200,000 ~INV,~LL DEPT, 9100,000 ~INV,MLb DEPT, 9000,000 MINV,MLb DEPT, 8900,000 MINV,MbL DEPT, 8800,000 MINV,MLL DEPT, 8795,000 MINV,MLL END OF DATA lO-NOV-1988 14:43 4,46! MNOR,MbL 1,663 MNOR,MLb 2,383 MNOR,MLL 3,838 MNOR,MbL 5,012 MNOR,Mbb 4,316 MNOR,Mbb 2,369 MNOR,~bb ~,583 MNOR,Mbb 2,037 MNOReMbb 1,771 MNOR,Mbb 3.920 1.916 1.898 6,301 4,750 ?.566 3,920 1,41! 2,023 1,682 HTENeMbb HTEN,~bb HTEN,~bb HTEN,MbL HTEN,Mbb HTEN,Hbb HTEN,Mbb HTENeNbb HTENeNbb HTEN,Mbb PAGEI 25 -163,500 587,250 567,000 541,250 605,250 574,500 636,000 5~9,500 552,625 :'999,250 FILE NA~E : EDIT ,003 SERVICE : FLIC VERSION t 001A02 DATE ~ 88/11/10 MAX REC SIZE ~ ~096 FIbE TYPE : bO **** TAPE TRAILER SERVICE NAME : EDIT DRTE O~IGIN I FLIC T'PE NA~E = 72973 C~NTXNUATION # : 1 PREVIOUS TAPE COMMENT : **** REEL TRAILER **** SERVICE NAME : EDIT D- TEA : 88/11/.10 ORIGIN : FLIC REEL NA~E : 72973 C~NTINUATION # : P EVIOUS REEL : COMMENT : [,IS TAPE, ARCO KUPARUK I ¥-30, AP1 #50~029"21851
