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• WELL LOG TRANSMITTAL IT /-L DATA LOGGED /►3/2017 I� iv1.K.BENDER PROACTIVE DIAGNOSTIC SERVICES, INC. To: AOGCC RECEIVED ED Makana Bender 333 West 7th Avenue APR 12 2017 Suite 100 Anchorage, Alaska 99501 AOGCC (907) 793-1225 RE : Cased Hole/Open Hole/Mechanical Logs and /or Tubing Inspection(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 MAY 0 12Q17 Anchorage, AK 99518 SCANNE° Fax: (907) 245-8952 1) Caliper Report 09-Apr-17 2Z-29 1 Report /CD 50-09-21881-00 2) Signed : 4) 65. e4C4%. Date : 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\ConocoPhillipsTransmit.docx VCEfVE® APR 12 2011 Memory Multi-Finger Caliper ILA rillACCCC Log Results Summary Company: ConocoPhillips Alaska, Inc. Well: 2Z-29 Log Date: April 9, 2017 Field: Kuparuk Log No.: 12431 State: Alaska Run No.: 1 API No. 50-029-21881-00 Pipe Description: 3.5 inch 9.3 lb. J-55 EUE 8RD Top Log Interval: Surface Pipe Use: Tubing Bottom Log Interval: 9,967 Ft. (MD) Inspection Type : Corrosion & Mechanical Damage Inspection COMMENTS : This caliper data is tied into the AVA Shear Out Sub at 9,967 feet(Driller's Depth). This log was run to assess the condition of the tubing with respect to internal corrosive and mechanical damage. The caliper recordings indicate the 3.5 inch tubing appears to be in good condition with the exception of a hole recorded in joint 301 (9,899 ft). A 3-D log plot of the caliper recordings across the recorded hole is included in this report. No other significant wall penetrations, areas of cross-sectional wall loss or I.D. restrictions are recorded. MAXIMUM RECORDED WALL PENETRATIONS : sciotion ;'eicent V`J<',13 Penetration n etrat c n ,iI 11. r t .., . Hole 100 301 9,899 Ft. (MD) No other significant wall penetrations (> 19%)are recorded. MAXIMUM RECORDED CROSS-SECTIONAL METAL LOSS: No significant areas of cross-sectional wall loss (> 8%)are recorded. MAXIMUM RECORDED ID RESTRICTIONS : No significant I.D. restrictions are recorded. SCANNED g : 2.f 1 i, D. Sparks &T. Leckband C. Waldrop E. Zemba 1=iekti:aurie.er(s) Analyst(s wVitiu 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 0 • is PDS Multifinger Caliper 3D Log Plot Company : ConocoPhillips Alaska, Inc. Field : Kuparuk Well : 2Z-29 Date : April 9, 2017 Description : Detail of Caliper Recordings Across Hole Recorded in 3.5 Inch Tubing. Comments Depth Maximum Penetration 1 Nominal LD. 3-D Log Image Map 1ft.240ft1 0 100 2 5 3.5 28° 0° 90° 180° 270° 0° Maximum I.D. I I 2.5 3.5 Minimum I.D. I I 2.5 3.5 uumm -- - _ z 9850 Joint 300 I — 00 i 9860 IF Pup Joint 9870 lc Nipple 9880 - ...._ 9890 Joint 301 Hole 1,..m—....— _ (9,899') 9900 9910 Pup Joint it 9920 : Packer Nipple 9930 t„,—,-. , SI - .•-. Pup Joint i . \ / 3.5"AVA SOS 9940 -116 Avii... eineff - • Correlation of Recorded Damage to Borehole Profile I. Pipe 1 3.5 in (11.4'-9,967.2') Well: 2Z-29 Field: Kuparuk Company: ConocoPhillips Alaska,Inc. Country: USA Survey Date: April 9,2017 ■ Approx.Tool Deviation ■ Approx.Borehole Profile 1 15 50 1,611 GLM 1 3,265 150 4,890 E GLM2 E 200 6,522 GLM 3—� o � GLM 4 GLM 5 250 8,163 GLM6 GLMLMgg7 8LM 9 300 9,838 301.6 9,939 0 50 100 Damage Profile(%wall)/Tool Deviation (degrees) Bottom of Survey=301.6 • • 116 PDS Report Overview IABody Region Analysis Well: 2Z-29 Survey Date: April 9,2017 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 Analyst: C.Waldrop Pipe Nom.OD Weight Grade&Thread Nom.ID Top Depth Bottom Depth 3.5 in. 9.3 ppf 1-55 EUE 8RD 2.992 in. 11 ft. 9,967 ft. Penetration (%wall) Damage Profile(%wall) 400 Penetration body mom Metal loss body 0 50 100 0.1 300 200 48 100 0 95 0 to 20 to 40 to over GLM 1 (4:00) 20% 40% 85% 85% Number of joints analyzed(total=315) 314 0 0 1 143 Damage Configuration(body) 10 I GLM 2 (8:00) 8 191 GLM 3 (11:30) 6 GLM 4(11:00) 4 238 GLM 5 (6:00) 2 GLM 6(11:00) _ 0 Isolated General Line Other Hole/ 286 Pitting Corrosion Corrosion Damage Pos.Hole GGILMM gg7(5:00)80 Number of joints damaged(total=4) 1 0 2 0 1 Bottom of Survey=301.6 • 0 1111 1 PDS Report Joint Tabulation Sheet Well: 2Z-29 Survey Date: April 9,2017 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 Tubing 2.992 in. 0.254 in. 11 ft 9,967 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 0.1 11 0 0.01 5 2 2.95 Pup t 1 15 0 0.03 10 2 2.91 Lt. Deposits. 1.1 48 0 0.02 7 3 2.92 Pup Lt. Deposits. 1.2 50 0 0.02 6 2 2.92 Pup Lt. Deposits. 2 60 0 0.03 10 2 2.89 Lt. Deposits. ■ 3 93 0 0.03 11 2 2.91 Lt. Deposits. r• 4 125 0 0.02 9 2 2.92 Lt. Deposits. • 5 158 0 0.02 7 2 2.92 Lt. Deposits. C 6 190 0 0.02 8 2 2.91 Lt. Deposits. 7 223 0 0.02 7 1 2.92 Lt. Deposits. 8 255 0 0.02 7 2 2.92 Lt. Deposits. • 9 288 0 0.02 7 2 2.91 Lt. Deposits. 1 10 320 0 0.02 7 2 2.89 Lt. Deposits. • 11 353 0 0.01 6 1 2.91 Lt. Deposits. 1 12 385 0 0.01 6 1 2.90 Lt. Deposits. 13 419 0 0.02 6 1 2.92 Lt. Deposits. 14 451 0 0.02 9 2 2.91 Lt. Deposits. 15 484 0 0.02 6 2 2.90 Lt. Deposits. M 16 516 0 0.02 6 2 2.89 Lt. Deposits. 17 547 0 0.02 7 2 2.91 Lt. Deposits. 18 580 0 0.02 6 1 2.91 Lt. Deposits. 19 612 0 0.02 7 1 2.89 Lt. Deposits. • 20 644 0 0.01 6 1 2.88 Lt. Deposits. 21 676 0 0.02 7 2 2.91 Lt. Deposits. • 22 708 0 0.02 7 2 2.91 Lt. Deposits. ` 23 741 0 0.02 6 1 2.89 Lt. Deposits. 24 773 0 0.02 6 2 2.90 Lt. Deposits. I 25 806 0 0.01 5 1 2.89 Lt. Deposits. 26 838 0 0.02 6 2 2.89 Lt. Deposits. ii 27 871 0 0.02 7 2 2.89 Lt. Deposits. it 28 903 0 0.02 7 1 2.92 Lt. Deposits. It 29 936 0 0.02 6 1 2.89 Lt. Deposits. II 30 968 0 0.01 5 1 2.91 Lt. Deposits. 31 1001 0 0.01 5 1 2.91 Lt. Deposits. 1 32 1033 0 0.02 6 1 2.92 Lt. Deposits. 33 1066 0 0.02 6 1 2.89 Lt. Deposits. 1 34 1098 0 0.02 6 1 2.89 Lt. Deposits. 1 35 1131 0 0.01 6 1 2.89 Lt. Deposits. 36 1163 0 0.02 7 1 2.89 Lt. Deposits. • 37 1195 0 0.02 6 1 2.90 Lt. Deposits. iii 38 1228 0 0.02 7 2 2.90 Lt. Deposits. • 39 1259 0 0.02 6 1 2.90 Lt. Deposits. 40 1291 0 0.02 8 2 2.92 Lt. Deposits. • 41 1324 0 0.02 7 1 2.91 Lt. Deposits. • 42 1356 0 0.02 8 1 2.88 Lt. Deposits. • 43 1389 0 0.01 6 1 2.89 Lt. Deposits. II 44 1420 0 0.02 8 1 2.89 Lt. Deposits. • 45 1452 0 0.02 7 3 2.89 Lt. Deposits. C 46 1485 0 0.02 8 2 2.93 Lt. Deposits. 47 1514 0 0.02 6 2 2.90 Lt. Deposits. i IPenetration Body Metal Loss Body Page 1 • • 11111 PDS Report Joint Tabulation Sheet Well: 2Z-29 Survey Date: April 9,2017 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 Tubing 2.992 in. 0.254 in. 11 ft 9,967 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 48 1546 0 0.02 6 1 2.90 Lt. Deposits. 49 1579 0 0.01 5 1 2.90 Lt. Deposits. 50 161 1 0 0.02 9 2 2.90 Lt. Deposits. 51 1644 0 0.02 6 2 2.93 Lt. Deposits. 52 1676 0 0.02 7 1 2.91 Lt. Deposits. 53 1709 0 0.02 8 1 2.93 Lt. Deposits. 54 1741 0 0.02 9 1 2.93 Lt. Deposits. 54.1 1771 0 0.03 11 3 2.91 Pup Lt. Deposits. 54.2 1776 0 0 0 0 2.80 3.5"CAMCO TRDP-1A SSSV 54.3 1789 0 0.01 5 1 2.93 Pup Lt. Deposits. 55 1791 0 0.02 8 1 2.89 Lt. Deposits. 56 1823 0 0.02 7 1 2.89 Lt. Deposits. 57 1855 0 0.02 6 1 2.90 Lt. Deposits. 58 1888 0 0.03 10 2 2.93 Lt. Deposits. 59 1921 0 0.02 8 3 2.92 Lt. Deposits. 60 1954 0 0.02 7 1 2.93 61 1986 0 0.03 11 1 2.90 Lt. Deposits. 62 2018 0 0.01 6 1 2.93 Lt. Deposits. 63 2051 0 0.02 6 1 2.90 Lt. Deposits. 64 2083 0 0.02 6 1 2.94 65 2116 0 0.03 10 2 2.93 Lt. Deposits. 66 2148 0 0.02 7 1 2.92 Lt. Deposits. 67 2180 0 0.02 9 1 2.91 Lt. Deposits. 68 2213 0 0.02 7 2 2.91 Lt. Deposits. 69 2245 0 0.02 8 2 2.90 Lt. Deposits. 70 2278 0 0.02 7 2 2.90 Lt. Deposits. 71 2311 0 0.02 9 3 2.95 72 2343 0 • 0.02 9 1 2.89 Lt. Deposits. 73 2375 0 0.02 8 1 2.90 Lt. Deposits. 74 2408 0 0.02 8 2 2.92 Lt. Deposits. 75 2441 0 0.02 9 2 2.90 Lt. Deposits. 76 2471 0 0.02 9 2 2.90 Lt. Deposits. 77 2504 0 0.02 9 1 2.90 Lt. Deposits. 78 2536 0 0.03 12 2 2.91 Lt. Deposits. 79 2569 0 0.02 7 2 2.91 Lt. Deposits. 80 2601 0 0.03 13 2 2.93 Lt. Deposits. 81 2633 0 0.02 7 2 2.91 Lt. Deposits. 82 2666 0 0.02 9 2 2.90 Lt. Deposits. 83 2698 0.05 0.03 11 3 2.90 Lt. Deposits. 84 2731 0 0.02 6 2 2.91 Lt. Deposits. 85 2764 0 0.02 8 2 2.93 Lt. Deposits. 86 2796 0 0.02 6 2 2.94 87 2829 0 0.03 11 2 2.90 Lt. Deposits. 88 2861 0 0.02 7 2 2.93 Lt. Deposits. 89 2894 0 0.03 11 2 2.92 Lt. Deposits. 90 292 5 0 0.02 9 2 2.93 Lt. Deposits. 91 2958 0 0.02 9 2 2.90 Lt. Deposits. 92 2991 0 0.02 8 2 2.92 Lt. Deposits. 93 302 4 0 0.03 11 1 2.95 94 3056 0 0.03 13 2 2.90 Lt. Deposits. Penetration Body Metal Loss Body Page 2 • • .....4:3,_ PDS Report Joint Tabulation Sheet Well: 2Z-29 Survey Date: April 9,2017 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 Tubing 2.992 in. 0.254 in. 11 ft 9,967 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 • 95 3088 0 0.02 6 2 2.92 Lt. Deposits. 96 3121 0 0.03 10 2 2.90 Lt. Deposits. • • 97 3153 0 0.02 7 2 2.92 Lt. Deposits. • 98 3186 0 0.02 8 1 2.92 Lt. Deposits. • 98.1 3216 0 0.03 11 3 2.93 Pup Lt. Deposits. 98.2 3224 0 0 0 0 2.88 GLM 1 (LATCH @ 4:00) • 99 3233 0 0.02 9 1 2.93 Lt. Deposits. 100 3265 0 0.02 7 2 2.94 101 3298 0 0.02 8 1 2.92 Lt. Deposits. • 102 3330 0 0.02 6 2 2.93 Lt. Deposits. li 103 3362 0 0.03 11 2 2.90 Lt. Deposits. • 104 3395 0 0.02 7 1 2.90 Lt. Deposits. • 105 3428 0 0.02 8 2 2.94 • 106 3461 0 0.03 11 1 2.94 • 107 3493 0 0.02 7 1 2.93 i 108 3525 0 0.03 11 1 2.94 IIII 109 3557 0 0.02 7 2 2.95 110 3590 0 0.02 8 2 2.89 Lt. Deposits. 111 3623 0 0.02 9 2 2.94 112 3655 0 0.02 8 2 2.90 Lt. Deposits. C 113 3688 0 0.02 7 2 2.93 Lt. Deposits. ii 114 3720 0 0.02 7 2 2.92 Lt. Deposits. 115 3752 0 0.02 8 2 2.95 I 116 3785 0 0.02 7 3 2.92 Lt. Deposits. C 117 3818 0 0.02 8 1 2.94 118 3850 0 0.02 9 2 2.90 Lt. Deposits. 119 3883 0 0.02 7 2 2.94 120 3915 0 0.02 6 2 2.89 Lt. Deposits. li 121 3948 0 0.03 12 2 2.94 a 122 3981 0 0.02 8 2 2.94 • 123 4012 0 0.02 7 2 2.93 Lt. Deposits. • 124 4044 0 0.02 7 2 2.90 Lt. Deposits. • 125 4078 0 0.02 7 1 2.92 Lt. Deposits. • 126 4110 0 0.03 11 2 2.93 Lt. Deposits. • 127 4142 0 0.02 7 2 2.89 Lt. Deposits. • 128 4174 0 0.02 9 3 2.90 Lt. Deposits. • 129 4208 0 0.02 7 3 2.92 Lt. Deposits. 1 130 4240 0 0.02 7 2 2.95 • 131 4272 0 0.02 7 2 2.93 Lt. Deposits. • 132 4304 0 0.02 7 1 2.90 Lt. Deposits. • 133 4338 0 0.02 9 5 2.89 Lt. Deposits. C 134 4370 0 0.02 9 2 2.89 Lt. Deposits. 135 4402 0 0.02 7 2 2.92 Lt. Deposits. • 136 443 5 0 0.02 8 2 2.93 Lt. Deposits. • 137 4467 0 0.03 11 4 2.93 Lt. Deposits. C 138 4500 0 0.02 9 1 2.88 Lt. Deposits. 139 453 3 0 0.02 8 4 2.93 140 4564 0 0.02 6 2 2.89 Lt. Deposits. 141 459 7 0 0.02 8 2 2.93 • 142 4630 0 0.02 7 2 2.93 Lt. Deposits. • IPenetration Body Metal Loss Body Page 3 • • lib 11, PDS Report Joint Tabulation Sheet Well: 2Z-29 Survey Date: April 9,2017 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 Tubing 2.992 in. 0.254 in. 11 ft 9,967 ft. Joint Jt.Depth Pen. Pen. Pen. Metal Min. Damage Profile No. (Ft.) Upset Body % Loss I.D. Comments (%wall) (in.) (in.) % (in.) 0 50 100 143 4663 0 0.02 7 2 2.93 144 4695 0 0.02 7 3 2.93 Lt. Deposits. 145 472 7 0 0.02 8 3 2.91 Lt. Deposits. 146 4760 0 0.02 6 1 2.93 147 4792 0 0.02 7 2 2.92 Lt. Deposits. 148 4824 0 0.02 9 2 2.89 Lt. Deposits. 149 4856 0 0.02 7 2 2.90 Lt. Deposits. 150 4890 0 0.02 7 2 2.93 151 4922 0 0.02 8 2 2.93 Lt. Deposits. 152 4954 0 0.03 12 2 2.89 Lt. Deposits. 153 4988 0 0.02 7 2 2.93 154 5020 0 0.02 7 2 2.93 Lt. Deposits. 155 5051 0 0.02 7 2 2.91 Lt. Deposits. 156 5085 0 0.02 8 2 2.93 Lt. Deposits. 157 5116 0 0.02 8 2 2.92 Lt. Deposits. 158 5149 0 0.02 7 2 2.92 Lt. Deposits. 159 5181 0 0.02 8 2 2.88 Lt. Deposits. 160 5214 0 0.02 7 2 2.92 Lt. Deposits. 161 5246 0 0.02 7 2 2.88 Lt. Deposits. 162 5279 0 0.02 8 2 2.92 Lt. Deposits. 163 531 1 0 0.02 7 2 2.92 Lt. Deposits. 164 5344 0 0.02 6 2 2.92 Lt. Deposits. 165 5376 0 0.03 11 2 2.90 Lt. Deposits. 166 5408 0 0.02 7 2 2.93 Lt. Deposits. 167 5440 0 0.02 8 2 2.89 Lt. Deposits. 168 5474 0 0.02 6 2 2.94 169 5506 0 0.02 6 2 2.91 Lt. Deposits. 170 5538 0 0.02 8 2 2.93 171 5570 0 0.02 7 2 2.91 Lt. Deposits. 172 5598 0 0.02 6 2 2.89 Lt. Deposits. 173 5631 0 0.02 8 2 2.92 Lt. Deposits. 174 5663 0 0.02 7 2 2.90 Lt. Deposits. 174.1 5696 0 0.02 8 3 2.94 Pup 174.2 5703 0 0 0 0 2.84 GLM 2(LATCH @ 8:00) 175 5712 0 0.02 8 2 2.92 Lt. Deposits. 176 5743 0 0.02 9 2 2.91 Lt. Deposits. 177 5776 0 0.02 7 2 2.92 Lt. Deposits. 178 5808 0 0.02 9 2 2.88 Lt. Deposits. 179 5840 0 0.02 9 3 2.89 Lt. Deposits. 180 5873 0 0.02 9 2 2.94 181 5906 0 0.02 8 2 2.93 182 5938 0 0.02 8 2 , 2.88 Lt. Deposits. 183 5971 0 0.03 11 2 2.92 Lt. Deposits. 184 6002 0 0.02 7 2 2.92 Lt. Deposits. 185 603 6 0 0.02 8 2 2.94 186 6067 0 0.02 8 3 2.92 Lt. Deposits. 187 6101 0 0.02 8 2 2.88 Lt. Deposits. 188 6133 0 0.02 7 2 2.91 Lt. Deposits. 189 6165 0 0.02 7 2 2.92 Lt. Deposits. 190 6197 0 0.03 12 3 2.88 Lt. Deposits. IPenetration Body Metal Loss Body Page 4 • • 114 PDS Report Joint Tabulation Sheet Well: 2Z-29 Survey Date: April 9,2017 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 Tubing 2.992 in. 0.254 in. 11 ft 9,967 ft. Joint Jt.Depth Pen. Pen. Pen. Metal Min. Damage Profile No. (Ft.) Upset Body % Loss I.D. Comments (%wall) (in.) (in.) % (in.) 0 50 100 191 6231 0 0.04 14 2 2.92 Lt. Deposits. 192 6262 0 0.03 12 2 2.92 Lt. Deposits. 193 6295 0 0.02 7 2 2.87 Lt. Deposits. 194 6329 0 0.02 9 2 2.87 Lt. Deposits. • 195 6361 0 0.02 9 2 2.91 Lt. Deposits. U 196 6393 0 0.02 7 2 2.91 Lt. Deposits. • 197 6425 0 0.03 11 2 2.92 Lt. Deposits. • 198 6457 0 0.03 11 2 2.88 Lt. Deposits. • 199 6490 0 0.02 7 2 2.92 Lt. Deposits. 200 6522 0 0.02 8 4 2.87 Lt. Deposits. C 201 6556 0 0.02 9 1 2.92 Lt. Deposits. • 202 6588 0 0.02 9 2 2.87 Lt. Deposits. 203 6621 0 0.02 8 2 2.92 Lt. Deposits. C 204 6651 Q 0.02 7 2 2.90 Lt. Deposits. 205 6684 0 0.02 9 2 2.91 Lt. Deposits. • • 205.1 6715 0 0.03 11 2 2.92 Pup Lt. Deposits. 205.2 6724 0 0 0 0 2.88 GLM 3 (LATCH @ 11:30) 206 6731 0 0.02 9 2 2.88 Lt. Deposits. • 207 6763 0 0.02 9 3 2.93 Lt. Deposits. • 208 6794 0 0.02 9 2 2.91 Lt. Deposits. • 209 6825 0 0.03 11 3 2.88 Lt. Deposits. C 210 6859 0 0.03 11 3 2.87 Lt. Deposits. 211 6891 0 0.02 7 2 2.92 Lt. Deposits. • 212 6923 0 0.02 8 2 2.88 Lt. Deposits. • 213 6956 0 0.02 7 2 2.92 Lt. Deposits. • 214 6989 0 0.02 8 2 2.90 Lt. Deposits. r 215 7021 0 0.03 10 2 2.90 Lt. Deposits. • 216 7052 0 0.02 9 2 2.87 Lt. Deposits. s 217 7085 0 0.02 8 1 2.90 Lt. Deposits. • 218 7118 0 0.02 9 2 2.92 Lt. Deposits. 219 7150 0 0.02 7 1 2.92 Lt. Deposits. 220 7181 0 0.02 8 2 2.88 Lt. Deposits. • 221 7215 0 0.02 7 2 2.92 Lt. Deposits. • 222 7246 0 0.02 9 3 2.88 Lt. Deposits: e 223 7278 0 0.03 11 2 2.87 Lt. Deposits. 224 7312 0 0.02 7 1 2.93 Lt. Deposits. • 225 7343 0 0.02 9 3 2.88 Lt. Deposits. 226 7372 0 0.02 8 2 2.91 Lt. Deposits. 226.1 7405 0 0 0 0 2.88 GLM 4(LATCH @ 11:00) 227 7411 0 0.03 11 2 2.92 Lt. Deposits. • 228 7440 0 0.02 9 1 2.92 Lt. Deposits. • 229 7473 0 0.02 7 1 2.91 Lt. Deposits. • 230 7505 0 0.02 8 4 2.91 Lt. Deposits. C 231 7538 0 0.03 12 2 2.89 Lt. Deposits. 232 7572 0 0.02 6 1 2.89 Lt. Deposits. 1 233 7603 0 0.02 9 2 2.88 Lt. Deposits. Im 234 7636 0 0.02 9 2 2.89 Lt. Deposits. • 235 7668 0 0.02 7 2 2.89 Lt. Deposits. 236 7701 0 0.02 8 1 2.86 Lt. Deposits. _ • 237 7734 0 0.02 7 2 2.91 Lt. Deposits. In IPenetration Body Metal Loss Body Page 5 • • ILA W/P,Sw S PDS Report Joint Tabulation Sheet Well: 2Z-29 Survey Date: April 9,2017 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 Tubing 2.992 in. 0.254 in. 11 ft 9,967 ft. Joint Jt.Depth Pen. Pen. Pen. Metal Min. Damage Profile No. (Ft.) Upset Body % Loss I.D. Comments (%wall) (in.) (in.) % (in.) 0 50 100 238 7766 0 0.02 6 1 2.90 Lt. Deposits. 239 7799 0 0.02 7 2 2.93 Lt. Deposits. 240 7831 0 0.02 9 2 2.91 Lt. Deposits. ` 241 7863 0 0.02 9 2 2.86 Lt. Deposits. • 242 7897 0 0.02 8 2 2.85 Lt. Deposits. I 243 7928 0 0.02 7 2 2.86 Lt. Deposits. 244 7961 0 0.03 11 2 2.88 Lt. Deposits. C 245 7993 0 0.02 8 2 2.91 Lt. Deposits. 245.1 8025 0 0 0 0 2.82 GLM 5(LATCH cc, 6:00) 246 8032 0 0.03 10 2 2.90 Lt. Deposits. U • 247 8063 0 0.03 10 2 2.88 Lt. Deposits. 248 8097 0 0.03 11 2 2.87 Lt. Deposits. 249 8129 0 0.02 6 2 2.90 Lt. Deposits. 250 8163 0 0.04 17 4 2.94 Shallow Line of Pits. r 251 8194 0 0.02 7 2 2.90 Lt. Deposits. 252 8227 0 0.03 11 1 2.91 Lt. Deposits. • 253 8260 0 0.03 10 2 2.93 Lt. Deposits. • 254 8292 0 0.03 11 1 2.91 Lt. Deposits. r 255 8324 0 0.02 8 3 2.90 Lt. Deposits. • 256 8358 0 0.02 9 2 2.93 Lt. Deposits. • 257 8390 0 0.02 7 2 2.92 Lt. Deposits. III 258 8423 0 0.03 12 4 2.91 Lt. Deposits. C 259 8455 0 0.02 8 2 2.93 Lt. Deposits. 260 8486 0 0.02 7 2 2.88 Lt. Deposits. • 261 8520 0 0.03 12 2 2.91 Lt. Deposits. • 262 8553 0 0.02 7 2 2.88 Lt. Deposits. • 263 8585 0 0.02 6 1 2.91 Lt. Deposits. II 264 861 7 0 0.02 9 2 2.87 Lt. Deposits. U 265 8650 0 0.02 7 2 2.87 Lt. Deposits. la 266 8680 0 0.03 10 2 2.87 Lt. Deposits. C 267 8712 0 0.02 8 2 2.93 267.1 8744 0 0 0 0 2.88 GLM 6(LATCH @ 11:00) 268 8751 0 0.03 11 2 2.93 Lt. Deposits. im 269 8783 0 0.03 11 2 2.86 Lt. Deposits. • 270 8816 0 0.02 8 2 2.89 Lt. Deposits. • 271 8848 0 0.02 7 1 2.85 Lt. Deposits. • 272 8880 0 0.03 11 2 2.87 Lt. Deposits. • 273 8913 0 0.03 11 2 2.87 Lt. Deposits. • 274 8946 0 0.03 12 2 2.86 Lt. Deposits. • 275 8978 0 0.02 7 1 2.87 Lt. Deposits. U 276 9011 0 0.02 8 2 2.90 Lt. Deposits. • 277 9043 0 0.02 7 1 2.91 Lt. Deposits. U 278 9075 0 0.02 7 1 2.87 Lt. Deposits. 279 9108 0 0.02 7 2 2.89 Lt. Deposits. • 280 9141 0 0.02 7 1 2.86 Lt. Deposits. • 281 9173 0 0.02 7 2 2.88 Lt. Deposits. • 282 9206 0 0.03 11 1 2.90 Lt. Deposits. '■I 283 9238 0 0.02 7 1 2.90 Lt. Deposits. • 284 9270 0 0.04 15 2 2.90 Shallow Pitting. Lt.Deposits. No 285 9305 0 0.02 9 2 2.90 Lt. Deposits. U Penetration Body Metal Loss Body Page 6 • • tiji et~ PDS Report Joint Tabulation Sheet Well: 2Z-29 Survey Date: April 9,2017 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 Tubing 2.992 in. 0.254 in. 11 ft 9,967 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 lo 286 933 7 0 0.04 14 2 2.90 Lt. Deposits. • 287 9368 0 0.02 7 2 2.90 Lt. Deposits. 288 9401 0 0.03 13 2 2.88 Lt. Deposits. r 288.1 9434 0 0 0 0 2.85 GLM 7(LATCH @ 5:00) 289 9440 0 0.02 8 2 2.88 Lt. Deposits. C 290 9472 0 0.02 8 2 2.86 Lt. Deposits. 291 9502 0 0.02 9 2 2.89 Lt. Deposits. • 292 9535 0 0.02 9 2 2.92 Lt. Deposits. l 293 9566 0 0.02 7 1 2.87 Lt. Deposits. • 294 9599 0 0.02 8 2 2.91 Lt. Deposits. • 294.1 9632 0 0.03 10 3 2.90 Pup Lt. Deposits. r 294.2 9637 0 0 0 0 2.88 GLM 8(LATCH @ 4:30) 295 9644 0 0.02 8 2 2.91 Lt. Deposits. • 295.1 9677 0 0.02 7 1 2.89 Pup Lt. Deposits. I 295.2 9686 0 0 0 0 2.88 3.5"AVA PBR 295.3 9698 0 0 0 0 2.92 3.5"AVA RHS XL RETRIEVABLE PACKER 296 , 9706 0 0.03 11 2 , 2.92 Lt. Deposits. A 296.1 9738 0 0 0 0 2.88 GLM 9(LATCH @ 1:30) 297 9743 0 0.02 8 1 2.90 Lt. Deposits. • 298 9776 0 0.03 10 4 2.93 299 9807 0 0.02 9 2 2.91 Lt. Deposits. r 300 9838 0 0.02 8 2 2,93 Lt. Deposits. 300.1 9866 0 0.02 7 2 2.90 Pup Lt. Deposits. 1 300.2 9876 0 0 0 0 2.71 3.5"OTIS PORTED LANDING NIPPLE 301 9879 0 0.27 100 8 2.90 Hole! Lt. Deposits. FIN•IIII 301.1 9913 0 0.03 10 4 2.85 Pup Lt. Deposits. 301.2 9922 0 0 0 0 2.94 3.5"TIW SS-BB PERMINENT PACKER 301.3 9922 0.04 0.05 19 7 2.97 Pup Shallow Line of Pits. P 301.4 9929 0 0 0 0 2.73 3.5"OTIS XN NIPPLE 301.5 9932 0 0.02 8 2 2.90 Pup Lt. Deposits. l• 301.6 9939 0 0 0 0 2.94 3.5"AVA SOS IPenetration Body Metal Loss Body Page 7 • (IRS. PDS Report Cross Sections Well: 2Z-29 Survey Date: April 9,2017 Field: Kuparuk Tool Type: UW MFC 24 No.218370 Company: ConocoPhillips Alaska, Inc. Tool Size: 1.69 Country: USA No. of Fingers: 24 Tubing: 3.5 in. 9.3 ppf J-55 EUE 8RD Analyst: C.Waldrop Cross Section for Joint 301 at depth 9,898.770 ft. Tool speed=52 Nominal ID=2.992 Nominal OD=3.5 Remaining wall area=92% Tool deviation=47° 1 I d Finger= 11 Penetration=0.274 in. g Hole 0.27 in.= 100%Wall Penetration HIGH SIDE=UP > ® KUP PROD • 2Z-29 COnOCOPhillips Well Attributes Max Angle&MD TD Alaska,Inc. Wellbore APIIUWI Field Name Wellbore Status tel(°t MD(ftKB) Act Btm(ftKB) ,_,,c cec Vlupt 500292188100 KUPARUK RIVER UNIT PROD 61.88 4,600.00 10,457.0 ••• Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) -Rig Release Date 2Z-29,2/8201710:39:35 AM SSSV:TRDP Last WO: 41.71 2/20/1989 Vertical schematic(actual) Annotation Depth(ftKB) End Date Annotation Last Mod By End Date -- --- ,� ---- Last Tag:SLM 10,068.0 1/22/2016 Rev Reason:REPLACE SLEEVE pproven 2/8/2017 HANGER 31.1 °�� S 0i Casing Strings Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread y CONDUCTOR 16 15.062 41.0 115.0 115,0 62.50 H-40 WELDED aaa„,a,,,,„aa,"aa,"ac",ma"„"a,"a,a,aa.,ar° a„, '• Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread ISURFACE 95/8 8.921 40.1 5,184.0 3,551.3 36.00 J-55 BTC Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TOO)...Wt/Len(I...Grade Top Thread PRODUCTION 7 6.276 33.0 10,382.9 6,288.9. 26.00 J-55 BTC 'M/CONDucTOR;4i.0-1iso^-'^-^"` Tubing Strings --- Tubing Description I String Ma...I ID(in) 'Top(ftKB) I Set Depth(ft...I Set Depth(TVD)(...I Wt(Ib/t) 'Grade 'Top Connection TUBING 31/2 2.992 311 9,93971 6,0071 9.30 J-55 EUEBrd Completion Details SAFETY VLV,1,796.0 PIs 1i Nominal ID Top(ftKB) Top(ND)(ftKB) Top Incl(°) Item Des Com (in) 31.1 31.1 0.08 HANGER FMC GEN 4 TUBING HANGER 3.500 1,796.0 1,700.8 37.02 SAFETY VLV CAMCO TRDP-1A SAFETY VALVE 2.812 OAS LIFT;3,235.0 9,684.4 5,853.6 55.04 PBR AVA PBR 3.900 • 9,698.0 5,861.4 54.74 PACKER AVA RHS-XL RETRIEVABLE PACKER 3.000 • 9,774.0 5,906.2 53.06 BLAST RINGS CARBIDE BLAST RINGS(3) 3.867 I.. 9,876.3 5,968.4 52.48 NIPPLE OTIS PORTED LANDING NIPPLE 2.310 SURFACE;40.1-5,184.0- # l 9,911.1 5,989.6 52.42 LOCATOR TIW LOCATOR 3.000 9,913.1 5,990.8 52.40 PACKER TIW SS-BB PERMANENT PACKER 4.000 GAS LIFT;5,709.4 9,916.8 5,993.1 52.38 SBE 'SEAL BORE EXTENSION 4.000 9,929.7 6,001.0 52.31 NIPPLE OTIS XN NIPPLE w/NO GO PROFILE 2.635 9,939.1 6,006.7 52.25 SOS AVA SHEAR OUT SUB 2.992 r Other In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.) GAS LIFT;6,727.3 . Top(ND) Top Incl • Top(ftKB) (ftKB) (-) Des Com , Run Date ID(in) 9,876.3 5,968.4' 52.48 SLEEVE OTIS COMMINGLING SLEEVE 12/22/2016 2.310 GAS LIFT;7,407.7-1;. Perforations&Slots Shot GAS LIFT;8,027.1 . Dens Top(ND) Btm(TVD) Dens Top(ftKB) Btm(ftKB) (ftKB) (ftKB) Zone Date t) Type Com GAS LIFT.8.743.1 1. 9,792.0 9,850.0- 5,917.0 5,952.4 C-4,UNIT B, 2/18/1989 12.0 IPERF 120 deg.phase;5' 22-29 Sequential Omni K 10,002.0 10,022.0 6,045.4 6,057.7 A-5,2Z-29 1/25/1990 8.0 APERF .60 deg.phasing;2 1/8" GAS LIFT;9,430.5 Dyna Stdp 10,034.0 10,051.0 6,065.1 6,075.7 A-4,2Z-29 10/23/1992 4.0 RPERF 180 deg.phasing;2 1/8" Bi Were GAS LIFT;9,633.6 i. 10,034.0 10,080.0 6,065.1 6,093.7 A-4,2Z-29 12/18/1989 8.0 APERF 60 deg.phasing;2 1/8" Atlas Silver 10,051.0 10,085.0 6,075.7 6,096.9 A-4,2Z-29 10/22/1992 4.0 RPERF 180 deg.phasing;2 1/8" PBR;9,684.4 1 it Bi Wire PACKER;9,698.0 10,080.0 10,090.0 6,093.7 6,100.0 A-4,22-29 2/18/1989 8.0 IPERF 120 deg.phase;5" Sequential Omni K 10,134.0 10,146.0 6,127.5 6,135.1 A-3,2Z-29 2/18/1989 8.0 IPERF 120 deg.phase;5" Sequential Omni K PRODUCTION;9,735.2 4 1 ? 10,154.0 10,166.0 6,140.1 6,147.6 A-3,2Z-29 2/18/1989 8.0 IPERF 120 deg.phase;5" Sequential Omni K Stimulations&Treatments FRAC;9,792.0 Proppant Designed(Ib) I Proppant In Formation(Ib) (Date IPERF;9,792.0-9,850.0_ 1 2/8/2001 Stimulations&Treatments Min Top Max Btm f Top(111/01 Btm(TVD) T Vol Clean Vol Slurry NIPPLE;9,876.3Depth(ftKB) Depth(ftKB) (ftKB) (ftKB) Stg S Date Stim/Treat Fluid Pump(bbl) (bbl) SLEEVE;9,876.3 - 9,792.0 9,850.0 5,917.0 5,952.4 1 2/8/2001 II° Mandrel Inserts St LOCATOR;9,911.1 r atl • on Top(ND) Valve Latch Port Size TRO Run N Top(ftKB) (ftKB) Make Model 00(in) Sery Type Type (in) (psi) Run Date Com PACKER;9,913.1 - 'r 3,235.0 2,548.0 CAMCO KBUG 1 GAS LIFT GLV BK 0.156 1,350.0 3/9/2001 SOD;9.910.8 Q- 2 5,709.4 3,826.5 CAMCO KBUG 1 GAS LIFT GLV BK 0.188'1,332.0 3/9/2001 0 3 6,727.3 4,337.5 CAMCO KBUG 1 GAS LIFT OV BK 0.188 0.0 12/20/2007 NIPPLE;9,929.7 4 7,407.7 4,675.3 CAMCO KBUG 1 GAS LIFT DMY BK 0.000 0.0 1/26/2001 5 8,027.1 4,999.5 CAMCO 'KBUG 1 GAS LIFT DMY BK 0.000 0.0 2/21/1989 505;9,939.1 [A 6 8,743.1 5,371.4 CAMCO KBUG 1 GAS LIFT DMY BK 0.000 0.0 1/24/2001 7 9,430.5 5,716.0 CAMCO KBUG 1 GAS LIFT DMY BK 0.000 0.0 2/21/1989 8 9,633.6 5,824.9 CAMCO MMG-2 1 1/2 GAS LIFT DMY RK 0.000 0.0 1/18/2001 9 9,735.2 5,883.1 CAMCO KBUG 1 PROD EQUA BK 0.000 0.0 4/23/1994 Close --4 L DMY d APERF;10,002.0-10,022.0-i Notes:General&Safety RPERF;10.034.0.10,051.0.-- End Date Annotation APERF;10,034.0-10,080.0 1/28/2001 NOTE:LEAK DETECTED IN FIRST JOINT ABOVE LOWER PACKER RPERF;10.051.0-10,0135.0 .... 1/14/2011 NOTE:View Schematic w/Alaska Schematic9.0 IPERF;10.080.0-10,090.0 IPERF;10.1340-10,146.0- IPERF;10,154.0-10,166.0 PRODUCTION;33.0.10.382.9 Z1- 1�. � WELL LOG TRANSMITTAL To: Alaska Oil and Gas Conservation Comm. July 13, 2012 Attn.: Howard Okland 333 West 7th Avenue, Suite 100 Anchorage,Alaska 99501 RE: Bottom Hole Pressure Survey : 2Z-29 Run Date: 7/7/2012 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Klinton Wood, Halliburton Wireline&Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 2Z-29 Digital Data in LAS format, Digital Log Image file 1 CD Rom 50-029-21881-00 Bottom Hole Pressure Survey Log 1 Color Log 50-029-21881-00 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline & Perforating Attn: Klinton Wood 6900 Arctic Blvd. Anchorage, Alaska 99518 sameOffice: 907-273-3527 JON 92,01 Fax: 907-273-3535 klinton.wood@halliburton.com Date: ro L Signed: I�'1� D1 7 Ima ect Well History File' Cover e XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. Z Z(~''/- / ,~ ¢ Well History File Identifier RESCAN DIGITAL DATA OVERSIZED (Scannable) D Color items: [] Diskettes, No. D Maps: [] Grayscale items: [] Other, No/-rype [] Other items scannable by large scanner [3 Poor Quality Originals: ~, OVERSIZED (Non-Scannable) [] Other: , NOTES: [] Logs of various kinds [] Other BY: BEVERLY BREN VINCENT SHERYL MARIA LOWELL DATE: /S! Project Proofing BY: BEVERLY BREN VINCENT SHERYL MARIA LOWELl_ DATE: IS/ Scanning Preparation J~ X 30 = ?O + ~'~ = TOTAL PAGES BY: BEVERLY BREN VINCENT SHERYL MARIA LOWELL DATE: Is! Production Scanning . Stage 1 PAGE COUNT FROM SCANNED FILE: '~"~ PAGE COUNT MATCHES NUMBER IN SCANNING PREPARATION: ~YES Stage 2 IF NO IN STAGE 1, PAGE(S) DISCREPANCIES WERE FOUND: YES BY: BEVERLY BREN VINCENT SHERYL MARIA LOWELL DATE: IS/ (SCANNING IS COMPLETE AT THIS POINt' UNLESS SPECIAl. ATTENTION IS REQUIRED ON AN INDIVIDUAL PAGE BASIS DUE TO QUALITY, GRAYSCALE OR COLOR IMAGES) NO NO ReScanned (individual page [special attention] scanning completed) RESCANNEDBY; BEVERLY BR~ SHERYL MARIA LOWELL General Notes or Comments about this file: Quality Checked (done) 10/25/02Rev3NOTScanned.wpd ~ ~ y~ . • ConocoPh i I I i ps Ala -ska P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 October 12~', 2009 Mr. Tom Maunder Alaska Oil & Gas Commission 333 West 7~' Avenue, Suite 100 Anchorage, AK 99501 ~~~G~ V ~~ OCT ~ ~ 2.Q(l9 Alaska Oil & Gas Cons. ~ommission Ancharape ~ ~g ` ~ ~,2 " ~ r,, , E~ , ~ `r; ~: ~~~4 ~ ~;~~~,~~~ i ~ ' . Dear Mr. Maunder: Enclosed please find a spreadsheet with a list of wells from the Kuparuk field (KRi~. 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 cement was pumped September 2"d, 2009 and the corrosion inhibitor/sealant was pumped September 4~`, and September 5~', 2009. The atta.ched spreadsheet presents the well name, top of cement depth prior to filling, and volumes used on each conductor. Please call Perry Klein or MJ Loveland at 907-659-7043, if you have any questions. ely, Perry ConocoPhillips Well Integrity Projects Supervisor ` ~ ~ . ConocoPhil{ips Alaska Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-ofF Report of Sundry Operations (10-404) Kuparuk Field 10/5/2009 ~~ ~ a ~~ own I Well Name API # PTD # Initial top o cement Vol. of cement um ed Final top of cement Cement top off date Corrosion inhibitor Corrosion inhibitor/ sealant date ft bbls ft al ~ 2U-04 50029212700000 1850070 10'5" 1.5 6" 9/2/2009 1.27 9/5/2009 2U-11 50029213030000 1850400 6' 1.00 9" 9!2/2009 1.9 9/5/2009 2Z-08 50029209240000 1830380 5' 1.50 24" 9/2/2009 2.5 9/4/2009 2Z-09 50029213770000 1851360 4'6" 0.70 22" 9!2/2009 6.3 9/4/2009 2Z-20 50029218760000 1881240 6' 0.80 30" 9/2/2009 8.9 9/4/2009 2Z-29 50029218810000 1881290 26'5" 3.50 24" 9/2/2009 8.9 9/4/2009 2Z-29 (PTD 1881290) Failed TI ~ ~ Page 1 of 1 Regg, James B (DOA) From: NSK Problem Well Supv [n1617@conocophillips.com] Sent: Wednesday, November 28, 2007 2:05 PM To: Maunder, Thomas E (DOA); Regg, James B (DOA) ~ ~ ~~ ~ 12~~~ ~~ Cc: NSK Problem Well Supv; NSK Well Integrity Proj ~' Subject: 2Z-29 (PTD 1881290) Failed TIFL Attachments: 2Z-29 schematic.pdf; 2Z-29 90 day TIO pfot.jpg Tom & Jim, Kuparuk gas lifted producer 2Z-29 (PTD 1881290) failed a diagnostic TIFL on 11/27/07 and has been added to the weekly SCP report. The TIO prior to the TIFL were 2100/2050/780. A leaking GLV is suspected. Slickline will troubleshoot the tubing leak and repair if possible. Attached is a 90 day TIO plot and schematic. Please let me know if you have any questions. «2Z-29 schematic.pdf» «2Z-29 90 day TIO plot.jpg» Brent Rogers Problem Wells Supervisor ConocoPhillips Alaska, Inc. Desk Phone (907) 659-7224 Cell Phone (907) 943-1999 Pager (907) 659-7000 pgr. 909 '~!~~ DEC ~ 6 ZOfl7 12/3/2007 • • • f'~ ~ ~ ~ ~ C ~ ph~lii Cn ~ s Al s~ KRU 2Z-29 ca- ~ x nt p C~f, c. a ---_ i 2Z-~9 ~ API: bU0z9Z1881UU Well T e: PRUD An le a) r5: 53 de o7 9792 F SSSV i (1796-1797 T , ~ 00:3.500) '~ y N Lact Tart Date' Fr?0r?nn7 Max Hnlo 4nnla R2 dart n 4600 I;~- ~ ~? Casing String -ALL STRINGS ['- t' (Description I Size I Too I Bottom I ND I Wt I Grade I Thread f PBR (9684-9665, 00:3.500) PKR (9698-9699, 00:6.151) Pert (9792-9850) NIP (9876-9877, 00:3.500) PKR (9913-9914, 00:6.151} NIP (9930-9931, 00:3.500) TUBING (0.9940, 00:3.500, fD:2.992) Pert ;10002-10022) Perf ;10034-10051) PeA ;10034-10080) Perf ;10051-10085) Perf ;10134-10146) Perf ;10154-10166) SSSV T e. TRDP Ori Com Ietion: 2/20/1989 An le TD: 49 de 10457 Annular Fluid: Last W/0: Rev Reason: TAG FILL Reference Lo Ref Lo Date: Last U date: 6/17/2007 Last Ta : 10084' RKB TD: 10457 ftKB PRnDI_Ir;TION I 7 nf>n 1 n I 10~R3 t R2RQ f 2F t1n i .1.._55 1 I Tubing String -TUBING Size Top 8nttom T`JD VJt Grade 7hre~d 9,7. ~. .,.tip ~ i -- r . [- i ~ i. i Perforations Summary Interval TVD Zone Status Ft SPF Date T Gomment 9792 - 9850 5917 - 5952 C-4,UNIT B 58 12 2/18/1989 IPERF 120 deg. phase; 5" Sequential Omni K 10002 - 10022 6045 - 6058 A-5 20 8 1/25/1990 APERF 60 deg. phasing; 2 1/8" Dyna Stri 10034 - 10051 6065 - 6076 A-4 17 12 10!23!1992 RPERF 180 deg. phasing; 2 118" Bi Wire 10051 - 10085 6076 - 6097 A-4 34 12 10/22/1992 RPERF 180 deg. phasing; 2 1/8" Bi Wire 10085 - 10090 6097 - 6100 A-4 5 8 2/18/1989 IPERF 120 deg. phase; 5" Sequential Omni K 10134 - 10146 6128 - 6135 A-3 12 8 2!1811989 IPERF 120 deg. phase; 5" Sequential Omni K 10154 - 10766 6140 - 6148 A-3 12 8 2/18/1989 IPERF 120 deg. phase; 5" Sequential Omni K Stimulations & Treatments Inte^/al Date Type Comment -~ r~r~ - , i _ i_ 1 - _, i r,~i_Il~ ~'r7 ~fl .Gas 1_ift Mandrels,Nalves _ _. . St MD TVD Man Mfr Man Type V Mfr V Type V OD Latch Port TRO Date Run Viv Cmnt 1 3235 2548 Camco KBUG GLV 1.0 BK 0.156 1305 3/9!2001 2 5709 3826 Camco KBUG GLV 1.0 BK 0.188 1332 3/9/2001 3 6727 4337 Camco KBUG OV 1.0 BK 0.188 0 3/9/2001 4 7408 4675 Camco KBUG DMY 1.0 BK 0.000 0 1/26/2001 5 8027 4999 Camco KBUG DMY 1.0 BK 0.000 0 2/21!1989 6 8743 5371 Camco KBUG DMY 1.0 BK 0.000 0 1/24!2001 7 9431 5716 Camco KBUG DMY 1.0 BK 0.000 0 2/21/1989 8 9634 5825 Camco MMG-2 DMY 1.5 RK 0.000 0 1/18!2001 Pro ductio n Man drels/Va lves St MD 7VD Man Mfr Man Type v Mfr v Type V OD Latch Port TRO Date Run Vlv Cmnt 9 9735 5883 Camco KBUG EQUAL. 1.0 BK 0.000 0 4!2311994 (1) DMY ?. CLOSF_C3 ,. _._ _ Other (plugs, equip., etc.) - J_,EW_ __~L_RY ua to TVD T e Desert-lion ID 1796 1701 SSSV Camco TRDP-1A 2.812 9684 5854 PBR AVA 3.900 9698 5861 PKR AVA'RHS-XL' 3.000 9876 5968 NIP Otis PORTED LANDING NIPPLE; OTIS CMU sleeve set 3!15(01 2.310 9913 5991 PKR TIW'SS-BB' 4.000 9930 6001 NIP Otis'XN' Ni le w/ NO GO Profile 2.635 9939 6007 SOS AVA 2.992 944n anrn TTI 7 QQ9 1 ~ Flsh -FISH -I ~j ~ r?apUt G; cr(pti~.,n ~:omm?n[ 1 ~ . `' General Notes Scblullbel'gel' (jJJ NO. 4384 Schlumberger -DCS 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth 2, '7 Z007 C;Oí1\mission Company: I) (Y. 1\UG ?, 11\\\11 SCA~t\\;.O Field: Well Job# Log Description Date BL 1 R-27 11850425 FPIT ¡q / -/0;) 08/18/07 1 31-08 11839638 LDL )-"¡rIA - fY.IÀ 07/28/07 1 2M-19 11813070 INJECTION PROFILE I l-r" ,0, I - r.::t-:) 07/29/07 1 3G-26 11813071 LDL J~l1-^~:.ç- 07/30/07 1 1R-18 11837482 SBHP/DDL )t:>¡, ~ 1'\1S-':/ 07/31/07 1 1Y-01 11813072 INJECTION PROFILE U"1J'. - J~3 ~ó 07/31/07 1 2C-08 11813073 INJECTION PROFILE' I 1-rf\ J'fr'Z. -r-A<"' 08/01/07 1 3H-32 11837483 LDL .!),v-, _ Ñ., I 08/01/07 1 1Y-10 11837485 INJECTION PROFILE . U:tL' I 'Jf~ - r&""' ì 08/03/07 1 3G-08 11813075 PRODUCTION PROFILE' 1~ - () ç;,~ 08/04/07 1 1A-06 11837486 INJECTION PROFILE i rrl' 1->r1-11l.... 08/04/07 1 2N-337B 11837489 PRODUCTION PROFILE ·.QN _ - II A' 08/06/07 1 2U-08 11813076 LDL W't't *<' - N=). ( 08/06/07 1 1G-12 11837490 PRODUCTION PROFILE Iff?" - .~;:). 08/07/07 1 2N-343 11745232 MEM INJECTION PROFILE . ()-rt" 1C1~- r'A.:J 08/08/07 1 2N-327 11837491 SONIC SCANNER ;Sh -g. -(J(,.., ~ 08/08/07 2N-327 11837491 SONIC SCANNER-FMI ',",,,,~ ~F~ 08/08/07 3K-01 11632749 PRODUCTION PROFILE . J1sCo - ''';1 08/12/07 1 2X-04 11846430 INJECTION PROFILE ( 1"T..t' I~~ -II*' 08/13/07 1 2Z-29 11850419 SBHP SURVEY 1'7Ýlr ..:.. )::JCJ 08/13/07 1 2X-19 11850420 SBHP SURVEY IC¡é- r;kÇ 08/13/07 1 1A-20 11850421 SBHP SURVEY l~/') - II,':) 08/14/07 1 1 F-13 11850422 SBHPSURVEY {)Jù0 J~~~~~~ 08/14/07 1 1H-10 11846432 SBHP SURVEY )0}::,\ - ^-:q-..., 08/14/07 1 1 Q-1 0 11846431 SBHP SURVEY 1 '$r4 - lC1 'Sr 08/14/07 1 2U-05 11846433 INJECTION PROFILE ( ~ ï:f\ _ /lir.¿;;;- - rv.:K 08/15/07 1 2D-12 11846434 PRODUCTION PROFILE Hri./ - rl?l../ 08/16/07 1 2H-06 11846435 LDL J'k~ -II...C{ 08117/07 1 Alaska Oil & Gas Cons Comm AUn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Kuparuk Color CD 1 1 ';)7f' Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. 08/22/07 . . 06/08/07 Schlumberger NO. 4286 Schlumberger -DCS 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 A TTN: Beth Company: Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 1 20m ~NED JUN 1 4 2007 GOI1!!,. C{)mmls~!oíl ~v 1151f - Jé1l Field: Kuparuk Well Job# Log Description Date BL Color CD 2L-321 11629010 MULTI-FINGER CASING INSPECTION 05/12/07 1 2C-16 11629008 PPROF/LDL 05/10107 1 2G-11 11638863 PRODUCTION PROFILE 05/05107 1 1C-125 N/A MEM INJECTION PROFILE 05/05/07 1 2D-13 11638861 PRODUCTION PROFILE 05/03/07 1 2D-08 11638862 PRODUCTION PROFILE 05/04/07 1 2G-09 11638864 PRODUCTION PROFILE 05/06/07 1 2N-349A 11629004 RST/ WFL 05/04/07 1 3H-19 11638867 PRODUCTION PROFILE 05/09/07 1 1Q-10 11628771 MEM PRODUCTION PROFILE 05/03/07 1 1E-11 11629012 INJECTION PROFILE 05/14/07 1 2L-321 11665439 USIT OS/25/07 1 2V-08A 11629013 PMIT 05/15/07 1 1J-160 11632704 PRODUCTION PROFILE 03/19/07 1 1 H-07 11665436 SBHP SURVEY OS/20/07 1 2F-11 11665434 PRODUCTION PROFILE 05/19/07 1 2X-07 11665433 INJECTION PROFILE 05/18/07 1 1 B-01 11665432 PRODUCTION PROFILE 05/17/07 1 2X-01 11637338 INJECTION PROFILE 05/15/07 1 2Z-29 11665438 PRODUCTION PROFILE OS/22/07 1 1 H-22 11637339 INJECTION PROFILE 05/16/07 1 1Y -11 11632708 INJECTION PROFILE OS/23/07 1 1G-03 11637336 INJECTION PROFILE 05/14/07 1 1A-23 11665443 MEM PRODUCTION PROFILE OS/29/07 1 1F-08 11665435 SBHP SURVEY OS/20/07 1 1J-170 11632709 INJECTION PROFILE OS/24/07 1 10-109 N/A INJECTION PROFILE 05/13/07 1 2M-24 11665440 SBHP SURVEY OS/28/07 1 I Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. . . 10/31/05 Schlumbergep NO. 3513 Schlumberger -DCS 2525 Gambell Street, Suite 400 Company: Alaska Oil &. Gas Cons Comm Anchorage, AK 99503-2838 SCANNED \\Iü\! 23 {,nos AUn: Helen Warman A TTN: Beth 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Kuparuk - Well Job# Log Description Date BL Color CD 1 R-16 11015756 PRODUCTION PROFILE 10/24/05 1 2X-10 11015758 PRODUCTION PROFILE 10/26/05 1 1 D-128 11015759 INJECTION PROFILE 10/27/05 1 3J-06 11072927 SBHP SURVEY 10/30/05 1 3J-07 A 11072926 SBHP SURVEY 10/30/05 1 t/2Z-29 11072924 PRODUCTION PROFILE 10/28/05 1 1A-02 11022938 INJECTION PROFILE 10/18/05 1 1 Q-26 11022937 PRODUCTION PROFILE 10/17/05 1 1G-16 11015753 INJECTION PROFILE 10/21/05 1 2A-08 11015755 INJECTION PROFILE 10/23/05 1 2G-15 11072919 PRODUCTION PROFILE 10/23/05 1 2N-329 11022935 PRODUCTION PROFILE 10/15/05 1 2Z-07 11022936 PRODUCTION PROFILE 10/16/05 1 3G-02 11056697 PRODUCTION PROFILE 09/20/05 1 2B-03A 11015749 PRODUCTION PROFILE 10/05/05 1 3N-09 (REDO) 11015722 PRODUCTION PROFILE 08/29/05 1 .~ 2C-04 11022934 INJECTION PROFILE 10/14/05 1 1M-07 (REDO) 11015737 INJECTION PROFILE 09/26/05 1 2A-01A 11072922 INJECTION PROFILE 10/26/05 1 1 R-1 0 11015757 INJECTION PROFILE 10/25/05 1 2Z-08 11072920 INJECTION PROFILE 10/24/05 1 1 E-170 11015750 USIT 1 0/19/05 1 1J-154 11022931 US IT 10/12/05 1 2F-03 11015763 INJECTION PROFILE 10/31/05 1 SIGNED: iJ . ()itLJ DATE: 1& NtV' ~)- Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. (J(~_c 1'\ d STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION 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 Phillips Alaska, Inc. 3. Address P. O. Box 100360 Anchorage, AK 99510-0360 4. Location of well at surface 1158' FSL, 258' FEL, Sec.11, T11N, R9E, UM At top of productive interval 1475' FSL, 388' FEL, Sec.13, T11N, R9E, UM At effective depth At total depth 1102' FSL, 35' FEL, Sec. 13, T11N, R9E, UM 5. Type of Well: Development _X Explorato~__ Stratigraphic_ Service__ (asp's 529451, 5965918) (asp's 534625, 5960977) (asp' s 534980, 5960606) 6. Datum elevation (DF or KB feet) RKB 109 feet 7. Unit or Property name Kuparuk Unit 8. Well number 2Z-29 9. Permit number / approval number 188-129 10. APl number 50-029-21881 11. Field / Pool Kuparuk Oil Pool 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Length CONDUCTOR 115' SURFACE 5075' PRODUCTION 10274' 10457 feet Plugs (measured) 6338 feet 10084 feet Junk (measured) 6096 feet Tagged PBTD (3/14/01) @ 10084' MD. Size Cemented Measured Depth True vertical Depth 16" 182 Sx AS III 115' 115' 9-5/8" 1100 SxAS III & 500 G 5184' 3551' 7" 485 Sx Class G 10383' 6289' Perforation depth: Tubing (size, grade, and measured depth) measured 9792 -9850'; 10002- 10022'; 10034- 10090'; 10134- 10146'; 10154- APR O9 2001 true vertical 5917 - 5952'; 6045 - 6058' 6065 - 6100'; 6128 - 6135'; 6140 - 6148' ¢\,!aska Oil & Gas Cons. Commissior 3-1/2", 9.3#, J-55 Tubing @ 9940' MD. Aqchorage Packers & SSSV (type & measured depth) AVA 'RHS-XL' Packer @ 9698' MD; TIW 'SS-BB' Packer @ 9913' MD. Camco TRDP-1A @ 1796' MD. 13. Stimulation or cement squeeze summary Intervals treated (measured) (see attached) Treatment description including volumes used and final pressure 14. Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mc/ Water-Bbl Prior to well operation 199 887 501 Subsequent to operation 347 1276 648 Casing Pressure Tubing Pressure 211 2O5 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. Signed , _~~,.i~_~ ~~/¢_,/~,¢v~ Title: Form 10-404 Rev 06/15/88 · Prepe~e¢t I:~John Peirce 265-64~~. SUBMIT IN D PLICATE 2Z-29 DESCRIPTION OF WORK COMPLETED HYDRAULIC FRACTURE TREATMENT 1/24/01' RIH & tagged Fill at 10050' MD. 2/4/01: RU & pumped gelled sand slurry containing 2020 lbs of 20/40 mesh sand, to place an isolation sand plug across the open 'A' sand perforation intervals located at: 10002-10022' MD 10034-10090' MD 10134-10146' MD 10154-10166' MD 2/5/01: RIH & tagged sand plug at 9956' MD. 2/8/01' MIRU & PT equipment. Pumped a Hydraulic Fracture Treatment using 16/20 & 12/18 mesh proppants, through the 'C' sand perforation interval located above the sand plug at: 9792- 9850' MD Pumped Breakdown w/209 bbls of 20# Linear Gel @ 25 bpm, followed by Shutdown. Resumed pumping Scour stage w/250 bbls of 50# Crosslinked Gel, followed by 50 bbls of Scour slurry w/lppa proppant @ 15 25 bpm, followed by 150 bbls Flush, followed by Shutdown. Resumed pumping Data Frac stage w/100 bbls of 50# Crosslinked Gel, followed by 88 bbls of 20# Flush, followed by Shutdown. ISIP @ 2392. Resumed pumping Frac Treatment w/150 bbls Crosslinked Pad stage, followed by Crosslinked Slurry stages w/proppant ramped in stages from 2 to 8 ppa, followed by Flush, followed by Shutdown. Placed 78,000 lbs of proppant in the formation. RD. 2/10/01' RIH w/CT & jetted a proppant & sand plug fill cleanout to 9970' MD. 3/8/01' RIH & tagged fill at 10034' MD. 3/12/01' RIH w/CT & jetted a fill cleanout to 10182' MD. 3/14/O 1' RIH & tagged fill at 10084' MD. Returned the well to production w/gas lift & obtained a valid well test. MEMORANDUM TO: Julie Huesser, Commissioner State of Alaska Alaska Oil and Gas Conservation Commission DATE: December 1, 2000 THRU: Tom Maunder, ,,,,,- ' ' f ,-,,, P. I. Supervisor FROM' Chuck Scheve; SUBJECT: Petroleum Inspector Safety Valve Tests Kuparuk River Unit 2Z Pad Friday, December !, 2000' I traveled to the Kuparuk River Field and witnessed the semi annual safety valve system testing on 2Z Pad. As the attached AOGCC Safety Valve System Test Report indicates I witnessed the testing of 12 wells and 24 components with two failures observed. The surface safety .valve on wells 2Z-7 and 2Z-10 had slow leaks when pressure tested. These two valves will be serviced and retested by the operator. ' Earnie Barndt conducted the testing today he demonstrated good test procedure and was a pleasure to work with Summary: I witnessed the semi annual SVS testing at 2Z Pad in the Kuparuk River Field. KRU 2Z Pad, 12 wells, 24 components, 2 failures 8.3% failure rate Attachment: SVS KRU 2Z Pad 12-1-00 CS X Unclassified Confidential (Unclassified if doc. Removed) SVS KRU 2Z Pad 12-1-00 CS.doc Alaska Oil and Gas ConserVation Commission Safety Valve SYstem Test Report Operator: Phillips Operator Rep: Emie Barndt AOGCC Rep: Chuck Scheve - Submitted By: Chuck Scheve Date: Field/Unit/Pad: Kupauk / KRU / 2Z Pad ~ Separator Psi: LPS 100 HPS 12/1/00 Well Permit Separ Set L/P Test Test Test Date Oil, WAG, G~J, Number Number PSI PSI Trip Code Code Code Passed aAS or CYCLE 2Z-01 1830730 100 70 70~ P P OIL 2Z-02 1830800 2Z~03 1830850 " 2Z-04 1830860 2Z-05 1830760 100' · 70 70 ,P, P OIL 2Z-06 1830770 3700 2000 2000 P P WAG 2Z-07 '1830640 100 70 65 P 4 OIL 2Z-08 1830380 2Z-09 1851360 , 2Z-10 1851370 100 70! 70 P 4 OIL , 2Z-11 1851380 . 2Z212A 1951480 100 70 50 P P 0IL , ,, 2Z-13 1851060 2Z-14 1851070! 2Z-15 1851080, 3700 2000 1700 P P '' WAG 2Z-16 1851090 ' 2Z-18 1881330 100~ 70 65 P P OIL 2Z-19 1881300 100! 70 65 P P OIL 2Z-20 1881246 100 70 100 P P OIL 2Z-21 1881250' 100 70 70 P e OIL 2Z-22 1941470~ 2Z-23 1950100! , , 2Z-29 1881290 100 70 70 P P OIL 2z-ws 85 58o " ,,. I Wells: 12 Components: 24 Failures: 2 Failure Rate: 8.3% [390 Day Remarks: .Surface Safety Valves On wells 7 & 10 had slow leaks when pressure tested. They ar serviced and retested by the operator. '"'*"'" Paee 1 ofl SVS KRU 2Z Pad 12-1-00 CS.xls THE MATERIAL UNDER THIS COVER HAS BEEN MICROFILMED ON OR BEFORE OCTO.BER 24, 2000 E E C:LORIuMFILM.DOc PL E W M A T E R IA L U N D ER II II TH IS M A R K ER i LARRY GRANT Attn. ALASKA OIL + GAS CONSERVATION 3001 PORCUPINE DRIVE ANCHORAGE AK, 99501. Date: RE: 28 December 1994 Transmittal of Data ECC #: 5906.04 Sent by: MAIL Data: PDK Dear Sir/Madam, Reference: ENDICOTT NORTH SLOPE, AK Enclosed, please find the data as described below: Prints/Films: 1 PDK/GR FINAL BL+RF Run # 1 Please sign and retu~Rodney D.~Paulson~ / Suite 201 Anchorage, AK 99518 ~ O~X to (907) 563-7803 Received b~~~z, ~//~ ~ ~te: STATE OF ALASKA ALA::::CKA OIL AND GAS CONSERVATION COMMI,b,51ON REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Operation Shutdown Pull tubing . . Alter casing 2. Name of Operator ARCO Alaska. Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510 4. Location of well at surface 1158' FSL, 258' FEL, Sec. 11, T11N, R9E, UM At top of productive interval 1475' FSL, 388'; FEL, Sec. 13, T11N, R9E, UM At effective depth 1195' FSL, 107' FEL, Sec. 13, T11N, R9E, UM At total depth 1102' FSL, 35' FEL, Sec. 13, T11N, R9E, UM Stimulate X Repair well 12. Present well condition summary Total Depth' measured true vertical 1 0457' 6337' 5. Type of Well: Development X Exploratory _ Stratigraphic _ Service _ Plugging .. Perforate Other 6. Datum elevation (DF or KB) RKB 107' feet .. 7. Unit or Property name Kuparuk River Unit 8. Well number 2Z-29 9. Permit number/approval number 88-129/8-900 & 9-039 10. APl number 50-029-21881 11. Field/Pool Kupal'~,kCRj~¢-¢, Q~ ?o_o± Effective depth' measured 1 0 3 0 0' true vertical 6233' Length Size Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: feet Plugs (measured) feet NONE JU~... 2 ,~ 199, feet Junk (measured) Alaska 0il & Gas C,~~''' feet NONE . .,,o. Commissiou Anchorage Cemented Measured depth True vertical depth 80' 1 6" 185 sxASII 115 115 51 49' 9 5/8" 1100 sxAS III & 51 84' 3551' 5 0 0 SX CLASS G 10350' 7" 485 sxClassG 10383' 6288' measured 9792'-9850', 10080'-10090', 10134' 10146', 10154'-10166' true verdcal 5916'-5952', 6093' 6099', 6126'-6134', 6139'-6147' Tubing (size, grade, and measured depth) 3 1/2", J-55, tbg w/tail @ 9940' Packers and SSSV (type and measured depth) AVA 'RHS-XL' PKR @ 9698', TIW 'SS-BB' PKR @ 79913'366', CAMCO 'TRDP-1A' SSSV @ 1828' 13. Stimulation or cement squeeze summary 'A' SAND FRACTURE STIMULATION Intervals treated (measured) 1 0 0 8 0'-1 0 0 9 0', 1 0 1 34'-1 0 1 4 6', 1 0 1 5 4'-1 0 1 6 6' Treatment description including volumes used and final pressure SEE ATI'ACHEDSUMMARY 14. Pre ssure Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Prior to well operation 249 15. i7. Signed Form Subsequent to operation 7 7 Attachments 16. Copies of Logs and Surveys run Daily Report of Well Operations X I hereby certify that the foregoing is true and correct to the best of my knowledge. Title 10-404 Rev 06/15/88 65 3 1 78 271 104 303 Status of well classification as: Water Injector __ Oil X Gas Suspended Service Date SUBMIT IN DUPLICATE cc; UJELL: 2~-2q rUO 3) PERFS: ~Oq3 ' ~OLE ~I~GLE 3) PERFS: Y/ ~ EFF. PflO: /20 ~ PHRSINIt PRESSURE Elrlr. SLUR#Y: //0 ~i~ PROP. PROP. HNN. IJOLU.'~tE LUHTPII: g3oo / ISIP: 2(~ I FR#C GigO: TII.FNIC: PER/' FIIC: /220 LOS INTERURL: % ~ IQ MIN. NOTES: , STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMI~,51ON REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed' Operation Shutdown Stimulate X Pull tubing Alter casing Repair well 2. Name of Operator ARCO Alaska. Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510 5. Type of Well: Development X Exploratory _ Stratigraphic _ Service 4. Location of well at surface 1158' FSL, 258' FEL, Sec. 11, T11N, R9E, UM At top of productive interval 1475' FSL, 388'; FEL, Sec. 13, TllN, R9E, UM At effective depth 1195' FSL, 107' FEL, Sec. 13, T11N, R9E, UM At total depth 1102' FSL, 35' FEL, Sec. 13, T11N, R9E, UM 12. Present well condition summary Total Depth: measured true vertical 1 0457' feet 6337' feet Plugs (measured) NONE Plugging Perforate m Other 6. Datum elevation (DF or KB) RKB 107' 7. Unit or Property name Kuparuk River Unit feet 8. Well number 2Z-2~) 9. Permit number/approval number 88-129/8-900 & 9-039 10. APl number 5o-029-21881 11. Field/Pool Kuparuk River Oil Pool Effective depth: measured true vertical Casing Length Structural Conductor 8 0 ' Surface 51 4 9' Intermediate Production 1 03 5 O' Liner Perforation depth: measured true vertical 1 0300' feet 6233' feet Size Cemented 16" 185 9 5/8" 11 00 500 7" 485 9792'-9850', 5916'-5952', Junk (measured) NONE Measured depth True vertical depth sx AS II 1 1 5 1 1 5 sxAS III & 51 84' 3551' SXCLASSG sx Class G 1 0383' 6288' 10080'-10090', 10134'-10146', 10154'-10166' 6093'-6099', 6126'-6134', 6139'-6147' Tubing (size, grade, and measured depth) 3 1/2", J-55, tbg w/tail @ 9940' Packers and SSSV (type and measured depth) AVA 'RHS-XL' PKR @ 9698', TIW 'SS-BB' PKR @ 79913'366', CAMCO 'TRDP-1A' SSSV @ 1828' 13. Stimulation or cement squeeze summary Intervals treated (measured) 9792' 9850' Treatment description including volumes used and final pressure 5BBLS XYLENE, 65 BBLS 12% HCL, FINAL WHTP 14. Pre 15. ssure Prior to well operation . _ Production or Injection Data Representative Daily Avera(~e OiI-Bbl Gas-Mcr Water-Bbl ., Tubing 71 32 0 200 JUL 2 7993 348 1 59 4 Abo[,., r,.~, 200 16. Status of well classifica-ti~'r~a"f¥ (~ Gb~$ I~O.,n.S. Corfii'~iSgi01~ Water Injector__ Anchorage Oil X Gas Suspended Service Subsequent to operation Attachments Copies of Logs and Surveys run Daily Report of Well Operations 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Si~tned C' ~k'~ ' '~ Title ...~ Y'. E.,~ ;'~ ~ ~v" Date Form 10-404 Rev 06/15/88 SUBMIT IN DUPLICATE WELL ARCO Alaska, Inc. Subsidiary of Atlantic Richfield Company .)NTRACTOR REMARKS WELL SERVICE REPORT FIELD- DISTRICT- STATE OPERATION AT REPORT TIME DAYS l DATE Anchorage CHECK THIS BLOCK IF SUMMARY CONTINUED ON BACK 1.' Operation Performed: Pull tubing . 2. Name of Operator ~ OIL AND GAS ~ATION COMMI~.~ON REPORT OF SUNDRY WELL OPERATIONS .Z] Plugging Perforate ._ Other 6. Datum elevation (DF or KB) Stimulate ~[ Repair well Service Operation Shutdown ~ Alter casing 5. Type of Well: Development Exploratory Stratigraphic Plugs (measured) ARCO Alaska. Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510 14. Location of well at surface 1158' FSL, 258' FEL, Sec. 11, T11N, R9E, UM At top of productive interval 1475' FSL, 388' FEL, Sec. 13, T11N, R9E, UM At effective depth 1195' FSL, 107' FEL, Sec. 13, T11N, R9E, UM At total depth 1102' FSL~ 35' FEL~ Sec. 13~ T11N~ R9E~ UM 12. Present well condition summary Total Depth: measured 1 0457' feet true vertical 6337' feet 107' RKB feet 7, Unit or Property name Kuparuk River Unit 8. Well number 2Z-29 9. Permit number/approval number 88-129/8-900 & 9-039 10. APl number 50-029-21881 11. Field/Pool KuJ3aruk River Oil Po01 . Effective depth: measured I 0 3 0 O' feet true vertical 6233' feet Junk (measured) Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: Length Size 80' 16" 5149' 9-5/8" I O35O' 7" measured 9792-9850, true vertical 5916-5952, Cemented Measured depth True vertical depth 185 Sx AS II 1 1 5' 1 1 5' 1100 Sx AS III & 5184' 3551' 500 Sx Class G 485 Sx Class G 1 0383' 6288' 10034-10085, 10080-10090, 10134-10146, 10154-10166 6064-6096, 6093-6099, 6126-6134, 6139-6147 Tubing (size, grade, and measured depth) 3.5", 9.3#, J55 tbg w/ tail @ 9940' Packers and SSSV (type and measured depth) AVA 'RHS-XL' pkr @ 9698', TIW 'ss-aB' pkr @ 9913' & Camco TRDP-1AJ~[~i~I 13. Stimulation or cement squeeze summary ' Fracture Stimulation Intervals treated (measured) 2 2 993 Kuparuk 'A' Sands Treatment description including volumes used and final pressure Alaska Oil & Gas Cons ~;0rnrnissi0n 1606 bbls water/28 bbls Diesel/24 bbls Additives/250~359# of proppant/FTP=55~;khl~i~ 14. Reoresentative Daily Average Production or In!ection Data ........ ~' OiI-Bbl Gas4Vld Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 511 353 0 800 176 Subsequent to operation 1768 2306 34 800 170 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. Form 10-404 Rev 09/12/§0 Date SUBMIT IN DUPLICATE "ARCO Alaska, In( Subsidiary of Atlantic I:lichfleld Company I PBDT . WELL ZZ.-Zq ;ONTRACTOR WELL SERVICE REPORT FIELD-DISTRICT-STATE rDAYS DATE K~J ~ "/,~/'~ OPERATION AT REPORT TIME c.c~PLea~ REMARKS o~3o P/r ?'6 (o,:~o rs; . c~qo ~F;nj ~T'~. 1005 Pu~PlN ~l SI.K. ~JTE. 20 e~ ' t. Ifl~4~l's ql$O PS~ 5 ~,~.T P-..~u,~ ['"] CHECK THIS BLOCK IF SUMMARY CONTINUED ON BACK Report eF *F mile~ knote ~ ADbffl, dE$: Z~.r,, e~s STATE OF ALASKA 0 g 16 I N A A.ASKA OIL AND GAS CONSERVATION COMMIssION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1 Status of Well Classification of Service Well OIL r-~ GAS r'-"] SUSPENDED ~ ABANDONED ['"-] SERVICE r'-"] 2 Name of Operator 7 Permit Number ARCO Alaska, Inc 88-129 ... 3 Address 8 APl Number P.O. Box 100360, Anchorage, AK 99510-0360 50-029-21881 4 Location of well at surface 9 Unit or Lease Name t KUPARUK RIVER UNIT ' -'~"/'2--'- ~'?~ Su~/~'~i~J'ED~ 10 Well Number At Top Producing Interval ~ 1475' FSL, 388' FEL, SEC 13, T11N, R9E UM ~ .i!z~.,~ ..?~ ..... ........ ..ii I'd..-~' 11 Field2Z'29and At Total Depth Pool 1102' FSL, 35' FEL, SEC 13, T11N, R9E UM .......................... '~ KUPARUK RIVER FIELD 5 Elevation in feet (indicate KB, DF, etc.) 6 Lease Designation and Serial No. KUPARUK RIVER OIL POOL RKB 107' ADL: 25653 12 Date Spudded 13 Date T.D. Reached 14 Date Comp., Susp. or Aband. 15 Water Depth, if offshore 116 No. of Completions DEC 14 1988 DEC 20 1988 FEB 21 1989 NA feet MSLJ 1 17 Total Depth (MD+TVD) 18 Plug Back Depth (MD+TVD) 19 Directional Survey 120 Depth where SSSV set I 21 Thickness of permafrost 10,457' MD & 6337' TVD 10,300' MD & 6233' TVD YES r~ NO E~I 1796, feet MDI 1400' (approximate) 22 Type Electric or Other Logs Run DIL,SFL,GR,CAL,SP,FDC,CNL, PET, GYRO 23 CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BO'I-rOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 16" 62.5# H-40 SURF 115' 24" ,182 SX AS III 9 5/8" 36# J-55 SURF 5184' 12-1/4" !1100 SX AS III & 500 SX CLASS G 7" 26# J-55 SURF 10,383' 8-1/2" 485 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) 9792'-9850' MD, 5" W/12 SPF 5916' - 5952' TVD 3-1/2", J-55 9940' 9913' 10080' - 10090' MD, 5" W/8 SPF 6093' - 6099' TVD 10134' - 10146' MD, 5" W/8 SPF 6126' - 6134' TVD 26 ACID, FRACTURE, CEMENT SQUEEZE, ETC 10154' - 10166' MD, 5" W/12 SPF 6139' - 6147' TVD DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 10034' - 10080' MD, 2-1/8" W/8 SPF 6064' - 6093' TVD 10,080' - 10,166 30,660 lbs 16/20 CARBOLITE 10002' - 10022' MD, 2-1/8" W/8 SPF 6044' - 6057' TVD 9890'- 9892' 150 SX CLASS G 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 FIowTubing Casing Pressure CALCULATED OIL-BBL GAS-MCF 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 29. ' '--';': .. 30. ... 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. iTOP KUPARUK C 9791' 5915' NA BOTTOM KUPARUK C 9844' 5948' TOP KUPARUK A 9988' 6036' BO'I-rOM KUPARUK A 10169' 6148' , ,, 31. LIST OF ATTACHMENTS 32. I hereby certify that the foregoing is true and correct to the best of my knowledge 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 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 12/22/89 12/16/89 12/18/89 1/26/90 2Z-29 Iniect diesel. Unsuccessful attempt to frac well. Well pressured out when XL fluid hit peris; unable to rock fluid and start downhole. RU DA, tst iubr to 3000 psi; OK. RIH w/2.5" gauge ring, set down on /8" & tag isolation sleeve @ 9870' WLM, POOH. RIH w/2-1 gauge ring btm @ 10,289', POOH. RIH w/strip gun; unable to get past 7000', POOH. PU add'l wt bar, RIH & pert A-4 sands from 10,034'-10,080' in 2 runs @ 4 spt, POOH, RD DA. RU CTU & cln out well. o ,002'-10,022' @ -30 · as follows. RIH, peri 10 , o Perform post frac pert RIH w/2nd gun, pert '" n'~°"10'022 ® -30,... POH, gun did not fire. POH. RIH w/3rd gun, pert 10,002'-10,022' @ +30°' POH; ti caught La) tbg tail. Increace In pull in 100# increments & pulled out of rope socket. POH w/wire. Fsh in hole = 39' w/top of tool @ 9921' WLM. Signed: ADDENDUM WELL 2Z-29 12/31/89 Frac Kuparuk "A" sand perfs 10034'-10380 @ 4 spf; 10080'-10090', 100134'-100146', and 100154'-10166' @ 8 spf in eleven stages as follows. Stage Stage Stage Stage Stage Stage Stage Stage Stage Stage Stage Fluid to recover: Sand in zone: Sand in csg: Avg pressure: 1: Prop 40 bbls 145 deg Diesel w/5% Musol @ 4-7.75 bpm 3300-3460 psi 2: Pmp 200 bbls Gel Water prepad @ 4.5-20 bpm 3460-4900 psi 3:Pmp 90 bbls Slick Diesel 20 bbm 4900-5290 psi 4:Pmp 120 bbls Gel Water pad @ 10-20 bbl 4175-5520-5090 psi 5:Pmp 14 bbls Gel Water pad w/2 ppg 16/20 Carbolite @ 20-14 bpm 5090-4070 psi 6:Pmp 17 bbls Gel Water w/4 ppg 16/20 Carbolite @ 14-20 bpm 4070-5120 psi 7: Prop 16 bbls Gel Water w/6 ppg 16/20 Carbolite @ 20 bpm 5120-4970 psi 8: Pmp 19 bbls Gel Water w/8 ppg 16/20 Carbolite @ 20-19.5 bpm 4970-4770 psi 9: Pmp 18 bbls Gel Water w/10 ppg 16/20 Carbolite @ 19.5-20 bpm 4770-4950 psi 10: Prop 10 bbls Gel Water w/12 ppg 16/20 Carbolite @ 20 bpm 4950 psi 11: Pmp 90 bbls Slick Diesel flush @ 20.5-16-20 bpm 4950-5600 psi 632 bbls 30,660 lbs 840 lbs 4,850 psi l! Date ARCO ALASKA, INC. ~l~ II~r I ~ I'I II ~ AN,-:H,-,RAGE ALASKA 2Z-2:.-] . ,-:,-,HpI_ITATIC, N =,ATE [::U'~'RLi~.i-FI-~i-D ........ t)~ L _ ~ _ _ FEBRUARY 1 ALASKA VERTICAE-~$-~CTION-C:ALI:iULATED ALONG CL,:,F:URE 'D~q"[',E':O'i~"$.~:Y3'Rg'E"C~WEBRLIARY 14., 1989 '~E'~¢~~S'-_.'OF" IC F:URVEY.. ,_IEIB NUMBER AK-BI:I-gC:015 KELLY BI_I'.::HING ELEV. = 1(])7.()C~ FT. OF'ERATFIR-HARGER TRUE SUB-SEA MEASURED VERT I CAL VERT I CAL nEPTH DEPTH DEF'TH ............... o ....... 0 ~ qo' ' 1 o7. Po 100 100.00 -7.00 200 '-'' 9. ?o. 00 ~0(. 00 '- '=' ~ (') 0 300.00 1 o..._,':'. 0 C) 400 '-"-'- ' - . · $00 4'~0.99 392.99 COLIRSE INCLINATION BEG MIN 0 0 0 15 0 24 0 19 0 37 0 30 600 5:.~. 94 492.94 2 19 700 699.72 5~2.72 5 15 '~'(')'" . . o. ,., 79:--:. 91 6'..-:/1 ';~1 6 .~(.)0 :E:97. :31 790. :31 1 i 19 F. 1000 994. ,:, 4 ,_,-] ,_,,:, _v. ,_,-] 4 14 7 .......................1 louZ__'. ..................... lu~1:.': .............. ! (-.:. .................... ':,,,'.-..:.4.. 16 17 1 ! 200 1 ~ 85. ,.,6 107o. 5/-. ~. 1 .,-._ ! 300 :!. 277.76 ! 170.76 24 6 !_,¢!.~',0 ............. 1 ~...~.,.., 74 1~15.74 ..'7 40 ._ / -.=., ,-} _l 400 :1 ~:~_, :,. 69 1.,-'=' F, '=~._ ... 69 .. ! ._.~ 15 0 0 ! 4.~, o '" '~' . _. . .:,~ 1 o 46 32 3C) 5:9 1600 !=''-'''' '-= ..... :31 · ..::=t.:~.:. ~..~., .............. !..4:=: 1 '=L~ ::-: 1 1700 1 '-'"' '-'c 6~..-. 79 1515.79 :::4 .:, J 1800 1707-:. '-'° 596. ' - o,=, 1 ~:=: :=:7 7 1900 1781 '~'" 41 31 · ..'-z 1674...~.'"":' 200C) 1854.96 1747.9/=, 4::: 2/=, 2100 1 '-"-'= '" '=: '- .:- ....:,.._-4 1C-: 18 · ._ 4 47 .=: '--"-'-=(') 2026 9(') 1,.~1,-.- 9(3 48 ~(') · ." .~: .._1 . · .... · .... 2:300 ~.'='r' ~,=,..... ,.,. 61 1951.6.1 ._~:.=:':' 26 .) - .:, ,=: . ~'-' .:, 4C 0 211 ,-, · ,, 1 2011 F"~ ~ ._ .= ..... 1 2500 2175 · 06 2068.06 58 1 "M ' ' F,':' 24 · -'- ~.00 2227 · 7:3 2120 7:3 · _ 1 217:3 51 ._7 52 270(:) 22F-';0..=, . -'-] C:OURSE DOG-LEG Et I RECT I ON :SEVER I TV DEGREE'.=-; DEG/100 N 0. 0 E N 7.69 W N 4.10 W N 10.19 E N 13.60 E N 29.50 E S 50.30 E S 45.10 E S 43. 0 E S 4.2.6':.? E S 4C). 5C) E S 40.10 E S 40.8'.;~ E S 39.60 E S 38.39 E S 37.89 E S :38.60 E S 38.89 E S 39.89 E S 39.60 E S 39. :39 E S :::8.89 E S 40.19 E TOTAL RECTANGULAR COORD I NATES NORTH/:E;OLITH EAST/WEST O. 00 0. O0 O. 00 0.25 0.22 N 0.03 0. 16 0.79 N 0.0:3 0.12 1.43 N 0.C) 6 '-"= '2 24 N 0.12 C).., ./ · 2.46 2.25 N 2.24 · =' 95 2.28 S ':' 87 11 30 ':' ._l, , . I ':~ 1 24.30 S ,:,{-} ,=- ? o.=, 4{.'}., ...... · -, 90 61., '-' - 4.40 86.._.'-'FJ '='._, '='. 73 115. ,:, 4 7.24 1 '~'~ :~ ~ ':' 20 151 ='/ .., · . .-I 7.04 15.68 27.74 42..~-~ C, .~ .59.69 81.09 :=, 106.06 S ...... 11 'P. 79 S 13:4.51 VERT I CAL SECT I C"' 0.0C) W -0. 17 W -0.61 W - 1.04 E -1.47 E :. !. ...:3/,', E 0.0.5 E 6.64 E ........... 19.1:3 E :36 '"':' E .~':' 79 · _ l__lI E E:.5,.51 E 118.29 E 156.78 E 178.4.5 E 2 C) 2. ( I ' 1.44 190.77 O. 88 ....... 23L....04 3.02 273.13 2.63 318. 11 4.40 ...... 367, O0 1.96 419. ::-:7 :3.7:3 474.11 S 165.43 E 251.5~.' S 232.35 E 356.94 S 269.75 E 415.11 S 310.04 E ......... 478.06~ · :'F,'-. 545.1:3 S ..... ...67 E S 397.91 E 615.70 S 39.39 E 3.61 558.64 S S 39.50 E 7.20 588.49 S S 3'.9. :39 E 1' 0 8 I 650. 14 S S 4.2. 0 E 4.9? 712.76 S '.F.; 42. C) E 0 . :::_ 9. 775 .9. :-.-:,_ ._.':' S 42. C) E 0.54 83'?.0,5 $ 468· 8:3 E 725.50 493.44 E 763.91 544.17. E 596:1 .56 /-,54.98 E 1010.36 711.81 E 1095.10 ARCO ALASKA· INC. ........ 2Z-_27_ KUPARUK FIELD ALASKA SF'ERRY-SLIN WELL SLIRVEYING C:OMPANY ANC:HORAGE ALAF;KA C:OMF'UTATION DATE FEBRUARY I VERTICAL SEC:TION E:ALCLIL~]~E[' ALONG CLO~--;LIRE _ PAGE '--" DATE OF SURVEY FEBRUARY I4, 1989 BOSS GYROSCOPIC: SLIRVEY ,_lOB NUMBER AK-BC~-90015 KELLY BUSHING ELEV. = 107.00 FT. .... OPERATOR-HARGER ........... TRUE .... SUB-SEA COURSE MEASURED VERTICAL VERTICAL INCLINATION "EF"TH DEPTH DEPTH DEG M I N · ?~ --., "D 28C)0 2333, ._ 1 '-"--"?/- '-~ ' ' ='-' 2~00 2383.27 2276.27 61 38 3000 2431 · 24 2324 . 24 61 1 3100 ~ 4 o 0 19 2373.19 60 ":' 1 :3200 25:30.06 2423.06 59 49 3300 2580.93 2473.93 59 1 3400 26:32.59 2525.59 58 46 3500 2684.71 2577.71 58 24 3600 2736.96 2629.96 58 35 3700 2789.06 2682.06 58 36 3800 2841.47 2734.47 58 10 · =, ?/00 2894.20 2787 . .-"L'-' ') 58 4000 2.946.77 2839.77 41 O0 299.9.58 2892.58 4200 3051 . 38 2944.38 ~ 10~. 05 2'.~J'P/.,. o..' F, 4400 3156.61 3049.61 4._,o0 oz( )7.7A .~ 1 ( )(). 7/-, 4600 o'-.,F,= c~4 '-' , ._1 _.._ ..,. o_l ,ii · '-, 148 ._ 4 4700 3302. ~"-' .... ,=,.~ :3195, 48Cx] '-"-'= *. 40 3244.40 . . ._',..%,._1 .L 4900 :Z-:401.2:=: ::-:294.28 5000 '-' ='-' '-'"' ~ = · -",4._, ..', 57 . o..:,4 ....,7 5100 '-'= ' = ..... "-'":~'-' 28 · z,._,O..,. ~.: ..................... · -',..D; ,--, · 5200 '~=.~'--.~ 59 ---,zi.=;.-, .=;,,._-~ 5'",'),', 3614.42 3507, 42 ._ .,..%i ~,. 5400 '-' '--' · -',66,=,. 29 7:561.29 55cx:) :i:720.21 3613 '-'1 · _,600 3770.41 :36/=,:3. 40 5700 '-"-"-' ':' .--,,_-,..' 1. 1 ._, :3714 . 1:3 11 58 22 57 51 59 43 58 :3 57 10 61 17 61 5:3 /_-,1 25 /.,0 :2/., 59 41 58 35 57 46 56 25 57 4 57 43 · 5'.-? 4::: 60 1 59 0 C:C~I_IR~--;E D I R E C T I 0 N DEGREER '.--; 41. 0 E S 40. :_--:9 E S 40.10 E '.--; :39.60 E ':' '::'--? /-,':P E S :3'.~. :--:'P E S 3'::-~. 10 E S 38.60 E ':' 40 :::':) E :3 41. :39 E S 4.1.50 E :--;42.10 E '=' 42 80 E S 42./.,9 E '-" 41 ."4,'-? E '.=;40.80 E '=' :::'-.? :=:':.? E '=' 40 :(') E · =,41. 10 E S 41,10 E S 41. 0 E S 40.80 E S 41. 0 E S 41. 0 E S 41 · :30 E · =,41. 10 E S 41. :39 E S 4.:2:. 50 E S 44. tO E S 45. 10 E DOG-LEG :SEVER I TY DEG/100 1.00 3.28 O. 66 0.81 0.54 0.84 0. :36 0. ~/- 1. '.-77 ('). 4'= 0.51 0.6:3 0..~':' 2 1'-' 1.7/_-, TOTAL REE:TANGULAR COORD I NATES - VERT I CAL NORTH/SOUTH EAST/WEST '.:;ECT I ~_-~ .. '.-?,)2.65 '.-. 76~, 0]~ E- .............. 11'79~-78 ' 9/.,8 · :--:2 '._=; 824.55 E 1 2/.,6.03 10:~5 '~'-? '--' 881 24 E 1 '~"' 35 . -- · a-....., · ._ ._1 ..%I i 1102·23 S 9:37. 12 E 1440.06 F,'-' '-'- ']' 11/-° '-?A '.S '-?'~'-:' 4:2 E 1._..'6 .. .... --' ~-~ · . -- .' .. a-. · · . ',"IS ...... '=' . 1...=,._, :34 ._, 1047: '_2~,.. E: ............!611.79 I3C)1.65 S 1101.42 E 16'P6.:E:4 1o-, ,q o/.,~. 11 .$; 11~4.~ 95 E 1781.54 1433.65 ._, ¢' 1209.. .46 E 1866.3£) · '-'./- ~. . · 1497.93 S 1. .... 63 E l'.PS1 37 1 ~_/-,_ 1 . 76. S 1 ._'-~ ~... '~' '~' . C) 0 E 2_ 0 :'~_/-,_. 27 1'-,~.~,. 10 :--: 1378 64 E 2121.C) 3 1687.87~,'--' 14.=,~ . 06 E 2205.94 ~ ' '--' 493. 17._ 0.22._, 1 70 E 2290· 73 181 o,, 73 ':' 1 ~(') 9A E '-"-' -, ....... ..~._-, 7/.. ('~.~ 1878.24 S 1607.24 E 2461·$'" · 942. F,,=, ."~ '-'F; F, ........ =, 1/.,/-,1 92 E _ . .--._4~.4~ 2c)('):::. 19 ::; 1717 '~7 E 2/.,:~C). 89 ~ ~',-- ....... t r' ,·,2~ .............................. .,--, ................ 0. ~('.) 2074 77 0.47 2141.09 0 97 '-' '-~'0'~ 00" ·. ..'z2. ~. '._-, 0 77 2272. · .., 1 :=: I 12 '-"-"~ · ..'..:.._7.4¢) S 0.81 ...... 2401. , :~.~ ._.,':'. S 1 · :37 24/_,4 · 75 S 0.66 2527.67 S O. 71 25'.-.71. O! S 2./-,8 2654.05 S 0.60 2716.48 S 1.3:3 2777. L--.::3 S 1774· 84 E 2718,._,=('.) 1'="::'-'. 70 E 2806. ~C 1 o,:~0 10 E '-'A'-? ''~ 29 . ~-~ .... ~ 17/46.84 E 2979.63 '2003.05 E 3065. 15 '?05:~ 79 E :314'9.82 114 04 E ~,.~.po . ._*~ .....49 2169. 12 E 3316.84 2224.67 E :~400.81 --,o,-,.-, 36 E o4,_,=,. 11 · ~.~ .-, .O.], ~._4~.~ E :~7'?'__ ~.54 ARCO ALASKA, INC. 2Z-29 KUPARUK FIELD ALASKA SF'ERRY-'SUN WELl.. SURVEYING COMPANY A N F: H 0 R A r'.~ E A L A S K A COMF'LITATION DATE FEBRLIARY 16., 1 ':.-,'8'.-T.' VERTICAL SECTILN CALE. ULATED ALuNG F:LOSURE PAGE :':; DATE OF '.=;URVEY FEBRUARY 14, 1787 BOSS; GYROSCOF'IC: SLIRVEY dOB NUMBER AK-BO-90015 KELLY BUSHING ELEV. = 107.0(') FT. OPERATOR-HARGER TRUE '.=;UB-SEA -'C --' u jLIR.:,E MEASURED VERTIcAL ...... VERTICAL INCLINATION (" "EPTH DEPTH DEF'TH DEG MIN · '=,,'-q ....'-' '":-' 92 '-4 '=', 9 '2 5 :--: · _ ,~ O0 ._4,_-, 7 z. ._ 76o :36 · _%~, O0 .... ,o'-,=' .06 C-::-]: 18.06 :,58 '-"-' 60C)0 :39.076,57 :_:::7.:69, 57 59 27 · . '-'/ ':'": ":' ' 5-5 .................. ~l'lll(}o .....4027 ..:,:, ....,..,'..o. :2:6 _'.-.-.' 30 6200 4077 :=:':: 3970 A":' .~'---, 52 6o00 4127.72 4020.72 /_-,0 16 .................. 6406 .......... 4177.08 4070, (.),=,"-' 60 '-'".:,._-: 6500 '-"-'-,. . . 4.-J: 11 4119 11 60 4:7.: 6600 4274 75 4167 75 61 ":-' 6700 4.:,.' ~ = ._, 1 4216.51 60 6ooo 4372 61 4../:,._, 61 60 6900 4421.72 4314.72 60 35 7000 4470.81 4363.81 60 36 7100 4519.95 4412.95 60 31 7200 4569.66 4462.66 59 50 ~.:,.],~ ~ ~ ~ ,~ ,~ ~ ~ '~ ..... 7400 4670.60 4563.60 59 21 S 7500 4721.87 4/_-, 14.? :_.=:7 7600 4773.83 466/-, :~P, .=;':' 7700 '-"-' 4o~6, '-'= · _-,,., 4719. ':, N % ,-, 7800 4879. z._, 4772 . ;.J o7 54 ~ ' ' ~'~'> ~ 95 '-"-' 7. O0 29 __ ....m ~ I i .' ._ 8000 4984 2o 4o Z7.39 5:3 15 ,:, 100 5027. 12 4930 1 '-' -- -- m ~ ... ~, ._ ~l(j)(.),=, '-, ' ' .. ~ ,. r) o '~' o~, 50 . ~..~ Q ,>~ o .-, · 5(]) .- ~ ,-'~ 46 8300 5141 75 MO'='" ~'-' . ._ ~ ~. 75 ._ o 13 8400 ._, 194.61 · _,,. o,. 61 o7 .-7 :R5(')O %'-'~ ~ '. 58 ..... z~..49 ._140 49 11 :3600 5299.56 5192.56 59 3 87 0 0 P]'-'" = M'$' ~.s, ~ .:,4 F._, 1 1 61 0 .......... i ._ ~ ~ ~...I . C: 0 LI R :--; E D I RECT I ON DEGREES S 45,50 E :--'; 47.10 E '._--; 50.50 E ::; 5c). 60 E S 50. :--:0 E S 5(:). 8(.-) E 'S 51.1(:) E S %(') '-'(' _ . . o ~) E ':' Sl 1(:) E S 5'2. 0 E :":; 5';.'. 50 E S :5'2. ::-:9 E :':; 5:3, :39 E S 54, (:) E S 54, 69 E S %":' 19 E 5:3. :-5-.:0 E 54. :'::0 E. · =, ...,4.60E S._.,:...%":' ._"::9. E c..~.':, 10 E S 51.69 E S 52.30 E S 52.50 E · _,'--' 48.10 E :--: 48.19 E o 49 19 E S 4,_--:. 60 E :--: 49. 19 E ..,'--' 4.9.50 El [lOG-LEG TOTAL . SEVERITY RECTANGULAR C:CIORDINATES ...... VERTICAL DEG/100 NORTH/SOUTH EAST/WEST SEC:TIOga:,, (')._._,.=i '":" Z :=: 3 :d. (') 0 :.:; .,.__'.':" 4 A_ ._,':'. 5:3 E 3744 '""'-' . . . ..'~, 1 2:7 '::-'8 ¢;/-,. m · " 0/-, 2953.39 S · /'m - 0 10 '-" ' '-' ~ '- · oL)¢),_-,. 13._,'--' ~';'/-,%/-, ..... . ~z E 400('). .... 'T~'-.-/ 0.41 :3(362.81 S :272:3.03 E 4087.02 o. 41 0. :3:--.: :3172. :37 S 2857, 7:3 E 4259.99 0 ':' 1 -:,oo-~ .-., ---, 292%. 41 E 4346.81 ....... .~..,=,...M L:; . ,. 0, 41 :']2F:2.32 S 299:3,26 E ................ 4433.84 0. '? 1 33:--:6.61 S :3C)61.64 E 4 52('). 71 0 44 -~.:, o,:-¢ 94 '=' 5:130 .~ 2 E 4607 '.~ 9 ._t ._m i_t ... . ~m , ._1 . .m... 0, 3:5 ......L--.!4427 Zi~: .S. 3199, !E_:.I 0.44 3494.9:R ....... S 3269..~:R E 478o.°1 0. ~':' "::F, 4/- . ._,=4 ¢-._, .-, .... ,,r,, 72 . .... _ ..... :,.:,.:,.': .E 48/_',6 49 0, '~'":' ::d=o'''' '=' 34 .-,...s, .-,( .,;.. ..... .......,.. - 11 ._, 10, E 4952 .:, ) 1.5:0 3647 .97 ._, '=' :_--:4:7.:0.10 E 50:37. :? - ' 0 67 :':: /-, 9 '--,, '-'/. '-] '-' '=''' c,, ._ - ' ........ ,c :..-, ._ .: .... .-,..-: . 41 E .=,, 1 '.-':'-:. :5:',.,. C, ('). ?]'T¢ :':,'74'r~. ~,/.;, S :.361,.,. "? - , .............. ~. ..... ,...:. .' 0 -~"-'" :2799 ,-4 :-5 ~..'-,.O--., .... > "q ":,/. ;q O ....... ,_,, 42 E 1.89. 3,~49_ . ,95 S 37~&. 8!_ _ E ...~,'>'~-~..,.-. 14 0 67 390!.3! S '~'~ '~ * '--' i '":' '":' '~"'"-; =''-' '=' · _, ~. .:, r....,.:, 17 3:_::91 69 E · ._. , .... ,~._ · ,'_-'-:2 0 4005. F,'-? S · 56 '-"=' =''-' 7 :.'3 E 56:30.4:7.: , ._ .. ._', ..._h:,, 0.2 ::: 4 ¢').=,7.4 ? :-] 402/-,, ! 0E .....7_-~, 14 :::9 3.81 4111.84 S 0.56 4168.72 S 0.8? 4224. Z¢ S 0.56 4280.54 S 1.00 43:36.65 S 1.98 4393.07 S 4091.62 E 5799,81 4155,12 E 5885.00 4218.89, E .................. N969,78 4282,85 E 6054.54 4347.18 E 6139.79 4412.90 E 6226.2~ ARCO ALASKA, INC. 2Z-29 KUPARLIK FIELD ALASKA SPERRY-SLIN WEL. L SURVEYING COMF'ANY ANCHORAGE ALAE;KA COMPLITATION DATE FEBRUARY 16, I'F/89 ...... -VER-I:~'E-:'~-L-'s-E~T-i-;3-~4 ' E:AL-E:OEATED ALON'3 CLO:--;URE ..... PAGE 4_ - DATE OF SURVEY FEBRUARY 14, 1989 BOSS GYROSCOPIC SLIRVEY JOB NUMBER AK-BO-90015 KELLY BLISHING ELEV. = 107.00 FT. OPERATOR-HARGER TRUE MEASURED VERT I CAL SUB-SEA COLIRSE VERTICAL INCLINATION DEPTH DEG M I N "EPTH DEPTH -"-' ' . 5~:.~ 1 6.0 4o ~oo0 5398 24 .24 8900 5447.22 5::-:40.22 60 40 9000 5496 45 ~"-"-":~ . ._, ._",,:, ~. 45 A_ 0 .."-' 1 ~ --,,~ .-,. 9100 .=,, .=,, 4 A_ _ _. 12._ 4o .. . I .' 60 ._ '~'-' ' ' 5489 '--'~ Y.z.¢.)(.) .=;,.=;'T//-, '":'.=; .=,':','4:--: =/ '7-'/-, .~,H z~ r"~ 26 ='-' .~.~ 9300 ._, :,47 ............... .-,,:, ::.;' 4 C) (.) ._, 6 ~ :./. (') 6 ='.=, '-_-~ '--' .~'R · _,._ .~ -". 06 ._,_ 40 9500 ._,7._ 1.52 ._, _,44..'-]'--'_ .,.. ._ ,~, 2 ~ 6 (..) 0 ._ o,,. .... ..s.,,:,, ._,6 :.,',:,, 29. .~/-,_ _._.=;":'._, ........ 51 9700 ._,o61 51 . ._ 4 42 9800 ._, .':..,::.., ='--,"-, p. :::/-,_ _ ._ F,'-',:, 1._,":', ,_,':'/- _, .:;,2 _ 29 . :~900 5981.7.5 ~,.=,74.7.5 5Z .s,.-7~ 10000 604o. 04 5936, 04 51 .54 10100 6105.1'-'c~ ?,cxg::: ..... 13 F,._I 1 9 10 ~ 00 6168.0~' ''~' 6061, ¢'J '~'.:, 50 4:3 10300 '" '~ '-' © '=:"' ":' 5 6~ ~ 61 '-'~'-- o._, 4 30 10400 /--,_ 29. ':;~.. 11 61 '~.....'-'" i 1 48 :2:0 1 o4._,7 ii: Cl I_1R ~--; E D I RECT I ON DEGREES S 49. E:O S 50.39 S 51. 10 S 52. 19 S 52.89 S .:,4.. 0 S 54.89 S 55.50 S 54.30 S 50.8':.-~ S 47.8(} S 47. :3(") S 46 '-":',' . .', :: S 45.50 S 4:3.10 S 37. :30 F:; :'::'7. :=:0 S 37.80 · DOG-LEG :_--;EVER I TY DE G / 100 TOTAL REE:TANGLILAR COORD I NATES NORTH/.SCIUTH EAAT/WEST E 0.43 4449.61 8 E 0 =;":' 4 ~(')~ 54 S i.-.~ -- E 0. E,'P 4560.61 S E 0. '.-.'~9 46,14.46 E; E 0.70 4667.07 S :7 1·24 4718.30 S .-~ ~/.,,'", -).~ ,=. _-- 0 . ,.~,'--' 1 ~/_ o. C o ._, - (3. ':"--' 4816 62 c; -_- 1.5:3 4:365.09 S -~ '-' 56 4915 '-"=' S -- 'l'I · I ~ .-. o, :-_: 4 4'--~/-, 7 68 '--' E 0.40 5021.21 S ...... =' 0. '-:,'2 507F, '-,'=' S ..... · ~ .~! =' 0. o2 --.,,:~ c- 51 75 ~ m . . i.... · E 4 61 .=, ":, zt ':, 2'4 S · ,~ .~--r ~.1 · E VERT I CAL E;ECT I C'..~" .. 4479.45 E 4546.34 E 4613.74 E 4681.80 E 4750.49 E 4819.58 E 631:3.38 6400.32 6487.05 6573.41 6659.34 6744.60 4889. 18 E 6829 II19 4959.08 E 6913.20 5028.05 E 6996.45 5093.76 E 7078.56 5154.83 E 7158· 8:3 5213.36 E 7238.17 5271.00 E 7317.17 5327.34 E 7395.55 5Oql 62 E 747:3.24., ..~l i~. · ......... 54'31.05 E 7549.( ' HORIZONTAL DISPLACEMENT = 7665.43 FEET AT :~FIIITH 4._=;, DEG '='"' ...... ,.,:. MIN. EAST AT MD = 10457 ................. -~'H~-'"~,i'~'E'i~ULATION' ";'-: , ' '" ' CiN USE OF THREE DIMENSIoNnL"R~£iILIS 'CfF CURVATURE METHO1] F RUL. ED_IRE._-, ARE BASED THE . ARCO ALASKA, INC:. 2Z-29 ....... 1<I21p-~RLIK 'F l EE£i ALASKA SF'ERRY-SUN WELL. SURVEY INO COMF'ANY ANF:HCiRAAE ALARKA C:OMF'UTATIF~N I]ATE FEBRUARY 16, i'P:::'? ,~!.?.-~ -. .._ PAGE 5 D~TE',Q~*~!;~Y _~BRI I~RY t4, tgR9 . d 0 B N U M B E R A K - B O- 9 0 015 KELLY BLISHING ELEV. = 107.00 FT. OF'ERATOR-HARGER INTERPOLATED VALUE:=; FOR EVEN lO00 FEET OF MEASURED DEPTH TRUE SUB-SEA 'EASURED VERT I CAL VERT I IS:AL ~ _,EPTH DEPTH DEPTH TOTAL REE:TANGULAR E:OORD I NATES MDiTVD VERT I E:AL NORTH/SOUTH EAST/WEST D I FFERENCE E:ORREE:T I ON 0 0.00 - 107.00 0, 0 (] 0.00 0.00 e-i · · · *- · . . 1000 994.84 887.o4 4(:) 80 .'_=; 42:33 E 5 16 F, 16 · .-, 000 1 :_4'- ._, ~ 4. '-~ 6 1747 .96 41 '9. ::: 7 c. '~'.=,'.:' 67 E 145 04 1 '::9 :=: 9 4.,.... · '--~ '--~ '-- '~' · · '-- ' "-- ' . ..' 4.. 1 ..- 4 --). ':,'-.,n ... 4 1 C)5:.~ '.:"-? :5; c,,:, 3000 '-' ':: '-' '-' - - - · ,.,..,~. ............... 1.24 E .=,,/-.:=; · 7/_- 42:3.72 · -., ,2 . '-' '-' '-' '-") '-" '--' 4000 ,.y46 77 ~-- · .......... · ..' ,:,._-, .~, 77 1687, 87 '.F.; 1436, 06 E 10.~ :::, ..._, 484 47 0._ E 1._47.43 494 20 5000 ':'45'-, 57 --"-'"F, F, '-"-"-' 2003 'F, .... · _-,o~ .... 7 ..',:,..:,7 40 ~q '--"~' A'--, .-,: ,-, c, 7 (] E 4 .:3 47.5 'P"-'~ 6000 3976 57 .... =,,-,.. 57 ' .', '9 7, ':: .'~,-v,=- ...._,,=,.. '.-.'0'~':' · · ~. . ... .... ._i · · " -', .~':' 2m29 19 =c'.=, 77 7000 4470 °1 4._-,/_-,._-, 81 34'.-.?498 S ::;26? .... E ,-,.,.-. '--'0 ' ' ~'--¢'--'~ '-";~ '-"-'='-' 78 E :s:O ! 5.6 ! 4:=:/-, 42 ,~. 00 4 :=: 77 ::: 9 4 ('~ 0.=, ~ 9 S :, ':-._,,-, -r.'. fi-r..",.~ · ...... ,, - . - · - - # 4o6o.61 F; 461 74 E 487. 9000 5496.45 ='-"-'"-~ ':" ' ':' .... · _, ._- ,:, .-.. 45 ._,. .'::.=, 0 ::: .55 ':.? 4. 4...z,, 4.1 ...... I OOAO 6043 · 04 .~ ' .P ::: /-, 04 .'-]07.~ '-'=' ="-' , . ...-._, F; .2...'71 0(')E ':-:'--cF, l-, ?6 5'-' /_',oo6 · o,-, ~'.-..-./. .,. /. --, ...... -"¢ 1 '7, 1 ::,.:,. 15 10457 ':'"' /- '-"-'"? '-'"' o,:, o z.,..., . ,:,,:, ._,..~ c .... 1 F, F; ::; 50 ::: 11E 41 '" ]. " " L.=, OF C:URVATLIRE METHOD THE CALULILATION PROCEDLIRE'S ARE BASED ON THE USE OF THREE DIMENSIONAL RADI I'-' . ARCO ALASKA, INC. '2Z-29 ~ .... ;FARUK FIELD ALASKA SF'ERRY-::.~;I. JN WELL L:;URVEYING L..LMFANY ANE:HORAGE ALA'._--;KA F:OMPUTATICmN DATE FEBRUARY 16, 19:--:9 F'AGE 6 DATE OF SURVEY FEBRUARY 14, 1989 ,_lOB NUMBER AK-BO-'"'-}i)O 15 KELLY BUSHING ELEV· = 1':)7·00 FT. OF'ERATOR-HARGER INTERPOLATED VALLE.:, FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE "~EASURED VERT I L:AL ( EPTH I]EPTH SLIB-SEA TOTAL VERT I CAL RECTANGLILAR COORD I NATE:--: MD-TVD DEPTH NORTH/.SOLITH EAST / WEST D I FFERENCE .. VERT I CAL CORREC:T I ON 0 O. O0 -107. O0 O. 00 107 107.00 0.00 0.25 N · 207 207.00 100.00 0. :..':4 N 307 307· 00 200· 00 i. 47 N 407 407.00 300.00 2.31 N 507 507.00 400.00 3.21 N 607 607.00 500.00 2.04 N 707 707.00 600.00 2.79 S 808 807.00 700.00 1:2.25 S 909 907. O0 800. O0 25.77 S 1012 1116 1223 1207.00 1100.00 .................... ~ ::!.~ ........... 1 oo7. oo ...... 1200.00 1446 1407 00 1300 00 1562 1507.00 1400.00 16o0 1607. O0 .............................................................. 1 ._,00..)0 ..... o0~ 1707.00 1600.00 1934 1807. O0 1700.00 1107.00 1000 .00 65 . o'-?.. '-"._. '-72 79 '-' · · ."""~ 126.59 :.=.: 169.44 S 215· 79 .'_:; 2A 4 88 ':' · 31 ':?. '.~6 S '---"-' 6:2, "" o,:, 4. 4:, 0.00 0.00 0.03 W 0.00 0.00 0.09 W 0.00 0.00 0.05 W 0.00 0.00 0. 14 E 0.0I 0.00 0.50 E 0.01 0.00 '-' 49 E 0 0/-, 0 o~ 7.55 E 0.32 0.26 · _ 7 E 1 19 0 87 16. R' . . . 29 0::: E -o :=:9 i 70 44 :~l E ~ ~ - ...... , Z. AA /.o 91 E 9.61 4 06 ,:,~. 6'7 E 16.09 6.48 114 81 E '~'~ '~- .... c,~. 9.27 t48.45 E 39.25 t3.89 ~ ':'~. 55.52 ,;,._ 44 E ~6.27 '?'~' ~. 47 E Z :3, 9 t '" ~,:,, 3'9 27~ '~'~ E ':M, 94 '-":' 03 324.._ .._,~]':' E 127.4:3 ~'~6).. 49 ARCO ALASKA, INF':. ..... 2Z..-_27 I-:,L F ARUK F I ELD ALASKA '$F'ERRY--SUN WE:'.LL '.:;~ ~RVEY I NO L,L MFANY ANCHnRAGE ALASKA CnMPUTATION DATE FEBRUARY 16, 1 '.--./ :_:: 'F~ DATE OF._,':'~RVFY .... FEBRUARY ,_lOB NLIMBER AK-BO-'PC)C)15 KELLY BU::-;HING ELEV. = OF'ERATOR-HARGER PAGE 7 14, 1987 107. o0 FT · INTERF'OLATED VALUE::; FOR EVEN 100 FEET OF SLIB-SEA DEPTH ( EASURED VERT I CAL dEPTH DEPTH SUB-SEA TOTAL VERT I CAL RECTANGLILAR F:OORD I NATES MD-TVD DEPTH NORTH/SOLITH EAST/WE::;T D I FFERENCE . VERT I CAL CORRECT I ON 2073 1907.00 1800.00 45'P. 29 2219 2007.00 1 '.-.-/00. 00 ._41~. 26 ~'-"~;:'-:._ :, U 2107.00 20C}C)'' 00 637.7? 2560 2207.00 2100.00 750.88 2749 2307.00 2200.00 870.50 2949 2407.00 ""-' ' . ~ ._~ 00.00 1001 73 3154 2507.00 2400.00 3350 2607. O0 2500. O0 3542 2707· 00 2600.00 3734 2807. O0 2700· 00 3924 2907.00 2800.00 4113 3007.00 2900.00 4307 3107.00 3000.00 44 ~,:, oz07.00 .:, 100.00 ................ 4'~'()8 ............. 3307' 4911 3407, O0 :3300. O0 2279.92 5103 :~ ~ 07. (') (') 24 (') ('). 0 (') 240:3. ~'-' 5286 3607. O0 3500. O0 2519.04 5474 3707.00 3600.00 2637.75 1138.41 1268.87 13'.-.-~6 · 42 1519.98 1640.41 1758.90 1883.0:3 2007.15 2146.88 S ':":'~ 47 E ..., i_* .~ · S 4._ 4 E .: ..... .:, 4. C)::-: E :::; 632.42 E '.:; 740.0:3 E S.' '='.=,'-:' 95 E .:,'-' '~. A_ '7.06 E ':' 1074 75 E S 1_ 177.60 E '.:; 1 '.--":'F, 07 E ..,... I_~ ._ i . S 1:3'P :2.48 E :--; 1 ~" E oo I · 70 · :, 1611.:38 E · _,':' 1716, 48 E '.3 1':""~7 7.5 E F:; 1 ':~ =-'-' 24 ., ._1.:,. E S 2C) 60.5:3 c. °161 60 '"' '-.'"':'. A 7 0,S ._--", ~...,:. _ -- · 166. :34 :3:3.92 ":' 12 273 I ":' /_-,0 2(-) ':'F,c' 4 · _~-_ -.., · 442, .!S'_.7 ,'-::9,45 .~ .-, ,-~ ... ~ 4...' 99. ~'";' 647 L o 104 '-"'-' · · 743 60 ':"--'F, m_l ._i ,_ · - -- . · 927. ~4 9!. 88 017, 2 106 '-= 200.47 9:'-:. 52 29~, 43 ..... 90.96 ~401 · 74 11(.'). ~1 .. 5¢)4.34 102.59 E 1677.26 :BE:. 13 E 1767.0:3 87.68 ARCO ALASKA, INC:. · -,7 ""¢7 -.' z.._--~ --' , I<UPARUi< FIELIq ALASKA ::i;F'ERRY-SUN WELL S;IJRVEYING L, LMFANY ANCHORAGE ALA'.SKA C:OMF'LITATION DATE FEBRUARY 16, 1 '.-.-J :=-: 'P F'~OE 8 [lATE OF :=;URVEY FEBRUARY 14, 1'P8'~ ,_lOB NUMBER AK-BO-?0015 KELLY BUSHING ELEV. = 107.00 FT. OPERATOR.HARGER ..... INTERPOLATED VALUE:=; FOR EVEN 100 FEET OF SUB-SEA DEPTH ................................ TRuE SUB-SEA ( 'EASURED VERTICAL VERTICAL _.EPTH DEPTH DEF'TH TOTAL RECTANGULAR C:00RD I NATE:=; NORTH/SOLITH EAST/WEST MD-TVD DIFFERENCE VERTIE:AL C:ORRECTION 567'2 3807.00 3700.00 =-~" =' 3'.--/07. 00 ~:E:('x'~ 00 · ~h--,O,,_l _ . . . 6'".=;,--~ ..... ,.,,.; 4007.00 :--:gCx] '-'F.'--' --',. ~ 4107. ex} 4000. 6,460 4207.00 4 lC~0.00 6666 4:_::07.00 4200. O0 .-.., - ~- 6870 4407. O0 4._,0 J. 00 7073 4507.00 4400.00 7274 4607.00 4500. 7471 4707. AO 4600.00 7663 4807.00 4700.00 7852 4907.00 4800.00 8042 5007.00 4~00.00 823~ 5107.00 5000.00 8423 5207.00 5100.00 8614 5307.00 5200.00 8817 5407.00 5300.00 ~021 9221 ' ._,5o7. O0 ._ 4oo 00 ._,6o7.00 5._,0o. 00 2761.22 S 2876.86 S 2'~:_=:6. 1 ?.) S 30'.-.74. 6,5 S · _~zU .... 74 '._=; 3318.58 S :_--:426. '=.78 S 3533.0:=: S 3634.66 S '-' '-'~'l '-.'.~, · :,7.: .... .~.._ S 38:=:0. '.~0 S 3928.05 S 4027.9:'-: S 4131.1;.,2 S 4237.6.:-3, S 4344.76 S 445:-.?. 68 S 4572.25 S 4678.18 S 2:~:::A. 06 E 2503.5'.-.-~ E 2627.5'2 E 2762.07 E 287'?~. 00 E 3038.56 E 3178. ?8 E 3321.18 E 3462.27? E 35'.-.-/L=:. 85 E 3732.08 E 385':.?. 77 E 3?.)87.70 E 4113.11 E 42:33. :_:8 E 4356,. 57 E 44'.-.? 1.36 E 4628. 17 E 4765. 18 E 1 ?58. '2052. :=-:'P 21.~1 ':'1 .-:,.5, ~-"=, ,.=,, .' .~. *_ ._!, . - 2359. :38 246:3.02 '"~'~ / /-,9 266,7.27 27/_-,4. 17 '.?856.27 · -,,.-/ 5 .-~ ~;4-_ .,:,4 30 :-': 5, 97 3126, 76 :=::'216 :3:307.46 3410. ~'? ':'.=, 14 '-"--" · _,._ . 3614.32 '.-.78.52 'P2.85 78.32 .. 102:71 105.4.5 1 ~..=,. 64 103.66 100.5'.-.-~ '~2.10 89.07 "c 6.'_--: ~.). 90.79 8 ,..-~ =,.- '.-.71. 11 i ex_'-,:. 43 103.44 ARCO ALASKA, INC. 2Z-29 KUPARUK FIELD ALASKA SF'ERRY-'.:;UN WELL '.:;URVEYING COMF'ANY ANE:HORAGE ALASKA COMF'LITATION DATE FEBRUARY 16, 1'P:=:9 PAGE 'P DATE OF SURVEY FEBRUARY 14, 1989 JOB NUMBER AK-BO-gC)c)I:._, KELLY BI_k=;HING ELEV. = 107.0o FT. OF'ERATOR-HARGER ............. INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-'.=;EA DEPTH ......... TRUE ' sLiB_.SE 'EASURED VERT I CAL VERT I CAL ~ _.EPTH DEPTH DEPTH TOTAL RECTANGULAR COORD INA TE'.=: MD-TVD NORTH /:SOUTH EAST / WEF;T D I FFERENCE VERT I CAL C 0 R R E C T I 0 N 9415 5707.00 o60 }. O0 9603 ?,oo~ O0 ?,70o. oO 9777 ~,~=o")~,. ~. C)C) ~:::C)O ..... 00 9941 6007.00 5900.00 0102 6107.00 6000.00 0260 6207.00 6100.00 0411 6307.00 6200. O0 0457~/ 6~o6.""-' ~.o .-,o- 4775.54 S 4866.61 S 4955.53 S 504::-:. 53 .':; 5131.38 S 5220.16 S 530'). 46 S 5336.15 ~=; 4897.86 E 5030.15 E 5141.24 E ~; ...., ~ '~, · _~o7 E 5329.01E 5412.43 E 5482.41E 5503.11E ::: 7 C) :-q ",':' '-} ::: 9 A -- . -- · u:.,,'~_* . - ii :=-:796. 11 6:7.8'2 :=:870. 10 74. C)C) :2:9:2:4.46 /_-,4. :_'-:6 5: 9'-.-~ 5 '-.",":,' /-, 1 ~ ::: -- · _ ". ':. ~ -' '%.~..'_-t ............................................................ 405:3.66 57.66 4104 90 · 51 '" =' 41 '-' ') '-' · .'¢ , 1.. 15, °l ........ THE CALCULATION PROCEDURES USE A LINEAR INTERPOLATION BETWEEN THE NEAREST 20 FOOT MD (FROM RADILI.'=; OF CLIRVATURE) POINTS ARCO ALASKA, INC. 2Z--' ~ ALASKA :~f;F'ERRY""?:I,,.IN WELl. SURVEYINO COMF'ANY ANCHORAGE ALA'.E;KA CnMF'LITATION DATE FEBRUARY 16, I'FJS'F~ F'AOE 10 DATE OF SLIRVEY FEBRUARY 14, 1989 _ . KELLY BUSHING ELEV. = 107. A0 FT. OPERATOR-HARGER INTERPOLATED VALLIES FOR :S:F'ECIAL SLIRVEY PAINTS TRUE SLIB-SEA ~EASLIRED VERT I CAL VERT I CAL ~ ~PTH DEPTH DEPTH TOTAL REF:TANGLILAR COORD I NATE:$; NORTH/SOL, TH EAST/WEST MARKER 97~1 5915.39 5808.3? 9844 5947.65 5840.65 9988 6035.63 5928.63 10169 6148.41 6041.41 10300 6232.85 6125.85 10300 6232.85 6125.85 10457 6336.88 6229.88 4962.87 S 5149.52 4991.12 S 5180.68 5068.74 S 5264.17 5167.84 S 5365.23 5243.24 S 5431.05 5243.24 S 5431.05 5336.15 S 5503.11 TOP KUPARUK C BASE KUPARUK C TOP KUPARUK A BASE KUPARLIK A SLIRVE .Y__DEP TH PBTB TB ARCO ALA.SKA, INC:. 2Z-29 STRAT I GRAF'H I C SLIMMARY DERIVED USING B IL DEF'THS AND '.:-;PERRY SI_IN SURVEY DATA MARKER--'22222 ........ MEASURED DEPTH TV[, TH I CKNESS BKB BKB SLIB-SEA VERT I CAL COORDINATES WITH REF. TO WELLHEAD (ORIGIN-1158FSL 258FEL) SEC 11 TllN RO?E TOP KUPARUK C 97'~I BASE KUPARUK C 9844 TOP KUPARUK A 9988 BASE KUPARUK A 10169 PBTD 10300 TD 10457 5915.39 5947.65 60:35.63 6148.41 6232.85 6:3E:6.88 5:--:0:--:. :39 5:--:40.65 5928.63 6041.41 6125.85 6229.88 4962.89S 5149.52~ 4991.12S ........ 5180.682 ' 5068.74S 5264.17E 5167.84S 5365.23E 5243.24S .... 5431.05E 5336.15S 5503.11E ................. i-')--~'6'N L~'~E~R' E"XTRAp°LATIbN" BELCiN DEEF'EST STATION. ,.-) COMPUTER PROGRAM - SPERRY SUN THREE [I IMENSIONAI_ RADIUS OF CLIRVATURE. DATA. CALCULATION AND INTERPOLATION BY RADIU:;; OF CURVATURE _.uMFUTA] ION DATE FEBRUARY 16, 1'F~89 DATE OF ._-,..IRVEY FEBRUARY 14 19:::9 ,JOB NUMBER AK-BO-90015 KEI_LY BLISHING EI_EV. = 107.00 FT. SPERRY -SUN KUPRRUK F]ELO 2Z-29 AK-80-900~5 TRUE NORTH --~500.00 --SOOO. O0 --4500.00 --6000.00 HOBIZONTflL SCALE :- 1 INCH TO 1500.00 / 1500.0 ARCO ALASKA, !NC. FERRUART 14, 1989 i '1 8000. OO 4500. O0 PROJECTION 10457 SPERRY -,SUN 0.00 ISOO. O0 5CRLE :- 1 INCH 78 1500.00 / 1500.0 KUPRRUK F]ELO RRCO RLRSKR. 2Z-29 FEBRURR~ 14. RK-BO-9001S ]NC. 1989 3000.00 450C. O0 8000.00 7500.00 i 8~6.88 10457 ,sbo. oo a°bo. oo 4sbo. oo ~obo. oo ~s~o. oo ~o'oo. ~:. VEB T I CflL PROJE C T I ON STATE OF ~ ALASKA OIL AND GAS CONSERVATION COMMISSION A~i_~ APPLICATION FOR SUNDRY APPROV IGINAL 1. Type of Request: Abandon _ Suspend _ Alter casing _ Repair well Change approved program _ 2. Name of Operator ARCO Alaska. Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510 4. Location of well at surface Operation Shutdown _ Re-enter suspended well _ _ Plugging _ Time extension _ Stimulate X Pull tubing _ Variance _ Perforate _ Other 5. Type of Well: Development X Exploratory _ Stratigraphic _ Service _ 1158' FSL, 258' FEL, Sec. 11, T11N, R9E, UM At top of productive interval 1475' FSL, 388' FEL, Sec. 13, T11N, R9E, UM At effective depth 1195' FSL, 107' FEL, Sec. 13, T11N, R9E, UM At total depth 1102' FSL, 35' FEL, Sec. 13, T11N, R9E, UM 12. Present well condition summary measured true vertical measured true vertical Total Depth: Effective depth: 6. Datum elevation (DF or KB) Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: RKB 107' 7. Unit or Property name Kuparuk River Unit feet 8. Well number 2Z-29 //,_ 9. Permit number 88-129/8-900 & 9-039 10. APl number ~(~-029-21881 11. Field/Pool Kuparuk River Field Kuparuk River Oil Pool 10457'MD feet Plugs (measured) 6337' feet None 10300'MD 6233'TVD feet Junk (measured) Length Size Cemented Measured depth ~":TrU~' vef{ical depth 80' 16" 185 sx AS II 115'MD 115'TVD 5149 9 5/8 1100SxAS III& 5184' 3551' " 500 sx Class G ' 1 03 5 0 7" 485 Sx Class G 1 0383'M D 6288'TVD measured 9792'-9850'MD, 10080'-10090'MD, 10134'-10146', 10154'-10166'MD true vertical 5916'-5952'TVD. 6093'-6099', TVD, 6126'-6134' TVD, 6139'-6147' TVD Tubing (size, grade, and measured depth 3-1/2" J-55 tbj w/tail @ 9940' Packers and SSSV (type and measured depth) AVA 'RHS-XL' pkr @ 9698', TIW 'SS-BB', pkr @ 9913', & CAMCO 'TRDP-1A' SSSV @ 1796' 13. Attachments Description summary of proposal X Detailed operation program _ BOP sketch ~ Fracture A Sand. 14. 16. 17. Estimated date for commencing operation 15. Status of well classification as: July, 1989 Oil X . Gas__ If proposal was verbally approved Name of approver Date approved Service I hereby certify that the foregoing is true and correct to the best of my knowledge. Title Sr. Operations Engineer FOR COMMISSION USE ONLY Suspended _ Conditions of approval: Notify Commission so representative may witness Plug integrity ~ BOP Test~ Location clearance ~ Mechanical Integrity Test ~ Subsequent form require ORIGINAL SIGNED BY LONNIE C. SMITH Approved by the order of the Commission Commissioner IIAppr°val No~_ Approved Copy Returned Date Form 10-403 Rev 5/03/89 SUBMIT IN TRIPLICATE KUPARUK RIVER WELL 2Z-29 FRACTURE STIMULATE THE A SAND . . . . No workover fluids will be used during the fracture treatment. No BOP's will be used during the fracture treatment. The estimated maximum surface treating pressure is 6,500 psi. The estimated A Sand bottom hole pressure is 2,600 psi. ARCO Alaska Inc. is a subsidiary of Atlantic Richfield Company AR3B-6001-A A Kuparuk Well 2Z-29 Sand Fracture Stimulation AFE #AK3447 May 12, 1989 pre-Frac , , . . . . Fracture 7. Slickline Work MIRU Slickline Unit. Tag bottom. (If applicable) Replace GLV's with dummy valves. Pull Otis commingling sleeve with blanking plug from Otis ported landing nipple at 9876' RKB and replace with isolation sleeve. RIH with standing valve and set in Otis ported landing nipple at 9876' RKB. Pressure test tubing to ensure DV's are set. Pull standing valve. RDMO Slickline unit. o . 10. 11. 12. 13. 14. 15. Stimulation MIRU fracturing equipment and related flowback equipment. Record the total weight of the proppant. Perform all standard quality control procedures (On-site Operations Engineering). Install largest diameter 'tree saver' available for 3 1/2", 9.3# tubing. Pressure test lines. Pressure up the annulus to prevent tubing buckling and maintain throughout job. Pump the 150 BBL pre-pad at 20 BPM. Shut down and record ISIP and 10 minute pressure decline. If treating pressure is excessive (greater than approximately 5,500 psi), ball out the perfs. (Halliburton should come prepared for a ball out). Perf size is approximately 0.4" and the total number is 262. Pump the fracture stimulation as per the attached pump schedule. Ra. mp between stages. Obtain representative fluid samples of the pad, slurry, and flush stages during the treatment. Place frac fluid samples in 140° water bath. the estimated treating conditions are as follows: WHTPE: Fracture Gradient: Tubing Friction' Recommended maximum treating pressure 4,500 psi 0.72 psi/ft 220 psi / 1000' (3.5") 6,500 psi Record ISIP and 5 minute, 10 minute and 15 minute shut-in pressures. SI well, bleed down annulus, and rig down frac equipment. Record the weight of proppant not pumped. Flowback Schedule 16. Begin flowback at the designed break time after verifying that gelled water samples in the water bath have broken. Contact Operations Engineering in Anchorage and do not begin flowback if gelled water samples have not broken. 17. Flowback the well at 5 to 10 BPH. At bottoms up verify that the gel has broken. Record tanks straps, choke settings and WHP's during flowback period. Inspect samples for proppant. If excessive proppant is produced, reduce rate and contact Operations Engineering. 18. 19. After 24 hours of fiowback at 5 to 10 BPH, decrease the wellhead pressure in 50 psi increaments every two hours until the well is producing at header pressure. Continue to monitor for unbroken gel or excessive proppant throughout flowback. Once well has completed flowback, obtain a 24 hour well test. KUPARUK WELL 2Z-29 A SAND FRACTURE PUMPING SCHEDULE 5/12/89 ST,Z~GE FLUID DESCRIPTION CLEAN VOLUME PUMP RATE PROP. ~. PROPPANT PROPPANT WT DIRTY VOLUME HIT PERFS BBLS BPM PPG DESCRIPTIChN LBS STG/CUM ,@ BELLS 1 GW PRE-PAD 150.0 20 .................................................. SHUT DOWN 0 ~ 0 FOR ISIP AND LEAKOFF CALCULAT~IONS I 5O/ 1 50 92 2 GWPAD 120.0 20 0 0 1 2O/ 27O 242 3 GW w/2 PPG 13.8 20 16/20 M CARBO-LITE 1158 1 5/ 285 362 4 GW w/4 PPG 17.0 20 16/20 M CARBO-LITE 2856 2O/ 3O5 377 5 GW wi6 PPG 15.8 2 0 16/20 M CARBO-LITE 3986 201325 397 6 GW w/8 PPG 18.5 2 0 16/20 M CARBO-LITE 6210 25/350 417 7 GW w/10 PPG 17.4 20 1 0 16/20 M CARBO-LITE 7288 25/375 442 8 GW w/12 PPG 9.8 2 0 1 2 16/20 M CARBO-LITE 4945 15/390 467 9 SLICK DIESEL FLUSH 88.0 +SV 20 · , , 88/478 467 TOTAL GELLED WATER = TOTAL DIESEL -- TOTAL FRAC FLUID = TOTAL DIESEL FOR FLUSH = 347.2 BBLS 15.0 BBLS 362.3 BBLS 88.0 BBLS + SV 16/20 M CARBO-LITE = 26444 LBS NOTES: 1. All fluids should be maintained between 85 F and 90 F on the surface. 2. Stages 1 and 4 are crosslinked 40~/1,000 gal gelled water with 2% KCL by weight and 5% diesel by volume and enough breaker lor an 8 hour bre~,. 3. Stages 5 through 9 are the same as above but without diesel. 4. Reduce pump rate to 15 BPM if treating pressure rises to 6,000 psi. Shut down at 6,500 psi, 5. Stage 9 (flush) should include a volume adjustment for sudace equipment between the wellhead and densimeter. 6. This job is intentionally underflushed by 4.0 bbls. The blender tub should be bypassed at flush, ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 June 5, 1989 Mr. C. V. Chatterton, Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Chatterton: Attached in triplicate are multiple Applications for Sundry Approvals on the following Kuparuk wells. Well Action Anticipated Start Date 3 H- 1 0 Conversion June, 1989 2Z-04 Storm Ck. March, 1989 2F-07 Refracture July, 1989 3H-04 Acidize June, 1989 2Z-07 Acidize May, 1989 3 B - 0 2 Tbg. Leak June, 1989 3K-1 5 Stimulate June, 1989 2Z-29 Acidize June, 1989 If you have any questions, please call me at 265-6840. Sincerely, G. B. Smallwood Senior Operations Engineer RECEIVED ;~laska 0il & 6as Cons. C0mr~issi0~ Anchorage ARCO .~iasxa. Inc. is a Subsidiary of At anticRichfieidComoany 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 X 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 X Exploratory _ Stratigraphic _ Service _ 4. Location of well at surface 1158' FSL, 258' FEL, Sec. 11, T11N, R9E, UM At top of productive interval 1475' FSL, 388' FEL, Sec. 13, T11N, R9E, UM At effective depth 1195' FSL, 107' FEL, Sec. 13, T11N, R9E, UM At total depth 1102' FSL, 35' FEL, Sec. 13, T11N, R9E, UM 12. Present well condition summary Total Depth: measured true vertical Effective depth: measured true vertical 1 0457'M D feet 6337' feet 10300'MD 6233'TVD feet feet Casing Length Structural 8 0' Conductor 51 4 9 Surface Intermediate 1 0 3 5 0 Production Liner Perforation depth: measured Plugs (measured) None 6. Datum elevation (DF or KB) RKB 107' 7. Unit or Property name Kuparuk River Unit feet 8. Well number 2Z-29 9. Permit number ~8-129/8-900 & 9-039 10. APl number 50-029-21 881 11. Field/Pool Kuparuk River Field Kuparuk River Oil Pool Junk (measured) None Size Cemented I 6" 185 sx AS II 9 5/8 1100SxAS III & " 500 sx Class G 7" 485 Sx Class G RECEIVED ,(~laska Oil & Gas Cons. Commissk Measured depth True vertj, cal, aep~ 11 5'M D 1 ¢~!~r¢~ge 5184' 3551' , 1 0383'M D 6288'TVD 9792'-9850'MD, true vertical 5916'-5952'TVD. Tubing (size, grade, and measured depth 3-1/2" J-55 tbj w/tail @ 9940' Packers and SSSV (type and measured depth) AVA 'RHS-XL' pkr @ 9698', TIW 'SS-BB', pkr @ 9913', & CAMCO 'TRDP-1A' SSSV @ 1796' 13. Attachments Description summary of proposal X Detailed operation program _ BOP sketch X' Acidize C Sand. 10080'-10090'MD, 10134'-10146', 10154'-10166'MD 6093'-6099', TVD, 6126'-6134' TVD, 6139'-6147' TVD 14. Estimated date for commencing operation June, 1988 oi~ X 16. If proposal was verbally approved Name of approver Date approved Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ,//,~(..~,~.,~ ¢~' .~,t,.1,~t.,,,~J¢ .~...~,..,,.r~,~ TitleFoR COMMISSIoNSr' OperatiOnSuSE ONLyEngineer 15. Status of well classification as: Gas __ Suspended _ Date Conditions of approval: Notify Commission so representative may witness Plug integrity m BOP Test_ Location clearance__ Mecha'nical Integrity Test m Subsequent form require Approved by the order of the Commission ORIGINAL SIGNED BY LONNIE C. SMITH [~lAppr°val No.¢_. '~ '~4~ 10- Cr_.)/-j &pomved Copy Commissioner Date '" Form 10-403 Rev 5/03/89 SUBMIT IN TRIPLICATE C Kuparuk Well 2Z-29 Sand Matrix Acid Stimulation AFE #AK3447 . , . 10. Obtain a C Sand production test a few days before acid treatment. Obtain a wellhead fluid sample and perform an emulsion/sludge test. Shut-in well. MIRU CTU, Transports, Nitrogen, and Pumps. Pressure test equipment. Titrate 12% HCL. RIH with CT to 9878' MD-RKB and pump 5 BBLS xylene, 5 BBLS straight 12% HCL acid, and 60 BBLS nitrified 12% HCL acid at 0.5 to 1.0 BPM. NOTE: Nitrify with 200 SCF per BBL. Displace with 5 BBLS diesel and purge coiled tubing with nitrogen. Immediately return well to production. Nitrogen lift until approximately 200 barrels of fluid are recovered. POOH with CT. NOTE: A. Operation Engineering should take the following flowback samples: (1) After first spent acid passes sample point. (2) At midpoint of spent acid passing sample point. (3) After final spent acid passes sample point. B. Samples should be analyzed for concentration of Fe+3, Fe+2, and PH. Send results to Jay Stratton, ATO-1136. RDMO CTU, Transports, Nitrogen, and Pumps. After well stabilizes, obtain a 24 hour C Sand only test. ARCO Alaska Inc. is a subsidiary of Atlantic Richfield Company AR3B-6001-A 5 4 3 2 I. 5000 PSI ?" WELLHEAD CONNECTOR FLANGE 2. 5000 PSI 4 1/16" PiPE RAMS 3. 5000 PSI 4 1/6" HYDRAULIC SLIPS 4. 5000 PSI 4 1/6" SHEAR RAMS 5. 5000 PSI 4 1/6" BLIND RAMS 6. 5000 PSI 4 1/16" STUIrFINO BOX (;OILED TUBINg UNIT BOP E8UIPHEIMT ,, STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COM MISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown __ Stimulate __ Plugging Pull tubing ~ Alter casing __ Repair well m 2. NameofOper~or ARCO Alaska; Inc... 3. Address P.O. Box 100360 Anchorage, AK 99510-0360 4. Location of well at surface 1158' FSL, 258' FEL, Sec.11, TllN, R9E, UM At top of productive interval 1475' FSL, 388' FEL, Sec.13, T11N, R9E, UM At effective depth 1195' FSL, 107' FEL, Sec.13, T11N, RgE, UM Attplt1~lLCel~, 35' FEL, Sec.13, T11N, R9E, UM 5. Type of Well: Development Exploratory Stratigraphic Service 12. Present well condition summary Total depth: measured 10457'MD feet Plugs(measured) None true vertical 6337'TVD feet 10300 ' MD Effective depth: measured 6233 'TVD feet Junk (measured) true vertical feet Perforate None Casing Length Size Cemented Measured depth Structural 80' 16" 182 sx AS I I 115 ' MD Conductor 5149' 9-5/8" 1100 sx AS III & 5184'MD Surface 500 sx Class G Intermediate 10350' 7" 485 sx Class G 10383'MD Production Liner Perforation depth: measured 9792'-9850'MD, 10080'-10090'MD, 10134'-10146'MD, 10154'-10166'MD true vertical 5916'-5952'TVD, 6093'-6099'TVD, 6126'-6134'TVD, 6139'-6147'TVD Tubing (size. grade, and measured depth) Other ~ Workover 6. Datum elevation (DF or KB) RKB 107' 7. Unit or Property name Kuparuk River Unit 8. Well number 2Z-29 9. Permit number/approval number 88-129/8-900 & 9-039 10. APl number 50-- 029-21881 11. Field/Pool Kuparuk River Oil Pool ~ueverticaldepth 115'TVD 3551'TVD 6288'TVD feet Packers and SSSV (type and measured depth) 13. Stimulation or cement squeeze summary 3-1/2", J-55, tbg w/tail ~ 9940' AVA 'RHS-XL' pkr @ 9698', TIW 'SS-BB', pkr ~ 9913', & CAMCO 'TRDP-1A' 14. Intervals treated (measured) ?' ~ ~:' '~ "'~ ''~' c. r, :~t~-~!'",, U ~'i~, :.:~,, 9890'-9892' Treatment de~ription including ~lumes used and final pressure :::'~Jaska 0il & Gas Cons, 60mn~issior~ 150 sx Cl ass O ":'~'~ ~Ch0/~Oe ,, _ Representative Daily Average Production or Injection Data N/A Oil-Bbl Gas-Md 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 ,/' . 16. Status of well classification as: Oil ~ Gas m Suspended 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Service Form 10-404 Rev 06/15/88 Title Area Drilling Engr. * Completion Well History (059/SA4) Date ~/5'-,/~.,~ SUBMIT IN DUPLICATE ARCO Oil and Gas Company Daily Well History--Interim I~lstructions: This form is used during drilling or workover operations. If testing, coring, or perforaling, show formation r~ame in describing work performed. Number all drill stem tests sequentially. Attach description of all cores. Work performed by Producing Secllon will be reoorted on "Interim" sheets until final completion. Report official or representative test on "Final" form. f} Submit "lnlerlm" sheets when filled out bur not less frequently than ovary 30 days. or (2) On Wednesday pi the week in which oil string is set. Submi! weekly for. workovers and following setting of oil string until completion. District Field KUPARUK Date and deptl~ aa of 8:00 a.m. The above is correct jCounly or Parish ARCO ALASKA INC. I NORTH SLOPE Itease or Unit 2Z-29 Complete record for each day while d~rilling or workover in progress NORDIC RIG ! 02/18/89 ( TD:10457 PB:10300 SUPV:DL 02/19/89 ( TD:10457 PB:10300 SUPV:DL 02/20/89 ( TD:10457 PB:10300 SUPV:DL 02/21/89 ( TD:10457 PB:10300 SUPV:DL Signalur~,~ ~ For form preparatiq6 ,~nd distribulior---~ see Procedures Mah1~al Seclion tO. Drilling, Pages 86 and 87 ISta~eAK P/U PERF GUNS 7"@10383' MW:10.8 NACL/BR SERV RIG. POOH W/ DP AND BHA. MU BHA t2. RIH TO 10295'. FILTER FLUID. POOH. ND BELL NIPPLE. NU LUBRICATOR. TEST TO 1000 PSI. PU PERF GUNS. DAILY:S29,734 CUM:$1,325,398 ETD:S1,325,156 EFC:$1,668,742 RUNNING COMPLETION 7"@10383' MW:10.8 NACL/BR PERF W/ DREESER ATLAS. M/U AND RUN 6.125 GAUGE RING AND JUNK BASKET. TIGHT IN SEVERAL PLACES. RUN TO 9770. POOH RUBBER FROM CEMENT WIPER PLUG IN BASKET ...RUN 6.00" GAUGE RING-OK. (PKR OD 5.912"). M/U AND RUN TIW 7 X 3-1/2 SS-BB PERM PKR. SET @ 9904 WLM, 9913 PIPE. POH R/D DRESSER. RUN COMPLETION. DAILY:S99,805 CUM:$1,425,203 ETD:SI,424,961 EFC:$1,668,742 RET. STD'G VALVE E 7"@10383' MW:10.8 NACL/BR SERV RIG. CONT TO RUN COMP. TEST SSSV TO 5000 PSI. TEST FMC GEN IV HGR TO 5000 PS8. TEST TBG TO 2500 PSI. PKR SET AT 2300 PSI. TEST ANN TO 1500 PSI. RELEASE PBR. UNLOCK HGR. PU AND RELAND HGR - PBR FREE. SHEAR OUT CHECK VALVE. TEST TBG AND ANN. NO TEST. WO OTIS. RU OTIS. SET PLUG IN ISOLATION SLEEVE AT 7873'. TEST TBG AND ANN TO 2500 PSI. OK. PULL OUT W/ PLUG. STUCK AT SSSV AT 1794'. DROP LINE CUTTER. CUT AND PULL LINE. REHEAD AMD RETRIEVE CUTTER. GO IN HOLE TO RETRIEVE STANDING VALVE. DAILY:S240,204 CUM:$1,665,407 ETD:S1,665,165 EFC:$1,668,742 NIPPLE UP TREE 7"~10383' MW:I0.8 NACL/BR ATTEMPT TO FISH CIRC PLUG F/ SSSV W/O SUCCESS. R/D OTIS. P/U LDG JT AND PULL TBG TO SSSV. TEST SSSV TO 5000-OK. RIH W/ COMPL STRING. CONTROL LINE FOR SSSV WOULD NOT TEST. POH AND LAY DOWN SSSV. WAIT ON SSSV. M/U NEW SSSV AND TEST TO 5000PSI-OK. RIH AND LAND TBG. TEST TBG AND ANNULUS TO 2500 PSI. PRESS UP TO 3600PSI TO SHEAR SUB. WOULD NOT SHEAR OUT. TBG HOLDING 3600PSI. PRESS UP TO 3975, SHEAR SUB SHEARED OUT. BACK OUT LANDING JT. SET BPV. NIPPLE DOWN BOP'S AND NIPPLE UP TREE. (CAMCO 'TRDP-1A' SSSV @ 1796', AVA 'RHS-XL' PKR ~ 9698', TIW 'SS-BB' PKR @ 9913 & TT @ 9940'.) DAILY:S34,387 CUM:$1,699,794 ETD:S1,699,552 EFC:$1,668,742 : /uJch0rage IT'''e Odlling Supt, IWell no. AR3B-459-2-B Number all daily well hislory forms conseculively as they are prepared for each well. IPage no ARCO Oil and Gas Company Well History - Initial Report - Daily Instructions: Prepare and submit the "Initial Report" on the first Wednesday alta! a well is spudded or v~orkovef operations are started. Daily work prior to spudding should be summarized on the form giving inclusive dates only. District ARCO ALASKA INC. Field County. parish or borough NORTH SLOPE Lease or unit APL: 25653 Title CO[~[PLETE KUPARUK 2Z-29 IWell no. Auth. or W.O, no. AK3447 50-029-21881 Operator ARCO Spudded or W.O. begun ]Date I ACCEPT Date end depth as of 8:00 a.m. 02/12/89 TD:10457 PB:10300 SUPV:CD 02/13/89 ( 1; TD:10457 PB=10300 SUPV:CD 02/14/89 ( 1: TD:10457 PB:10300 SUPV:CD 02/15/89 ( 1, TD=10457 PB:10300 SUPV=CD 02/16/89 TD:10457 PB:10300 SUPV:DL 02/17/89 TD:10457 PB=10300 SUPV:DL Complete record for each day reported NORDIC RIG I 02/11/89 ARCO W I Hour 1600 [ 56'0000 W,O, Prior stalus if a DRILLING CEMENT 7"~10383' MW:10.8 NACL/BR DRILL HARD CEMENT FROM 9613' TO FC AT 10294'. REVERSE CIRCULATE HOLE VOL. POOH TO PU CASING SCRAPER. (ACCEPT RIG @ 1600 HRS, 2/11/89) DAILY:S28,022 CUM=$1,081,598 ETD:S1,081,598 EFC:$1,668,500 POOH TO PU SCRAPER 7"~10383' MW:10.8 NACL/BR FINISH POOH. RIH WITH BIT AND SCI~APER TO PBTD AT 10294', CIRC AND FILTER BRINE TEST CASING TO 3000 PSI, POOH LD DP. RU WL RIH WITH 6.125" GAUGE RING AND JUNK BASKET. DAILY:S27,842 CUM:$1,109,440 ETD:S1,109,440 EFC:$1,668,500 RIH W/ 6.125" GR/JB 7"~10383' MW:10.8 NACL/BR SERVICE RIG. CONT. POOH. CHNG BHA. TIH TO PBTD AT 10294' REVERSE CIRC. FILTER BRINE. MAINTAIN WEIGHT AT 10.8 PPG. TEST CSG TO 3000 PSI. POOH. LD PARKER DP. RU GEARHART W/L. RIH W/ 6.125 GR/JB. DAILY:S37,612 CUM:$1,147,052 ETD:S1,147,052 EFC:$1,668,500 TIH W/ RTTS TO SQUEEZE 7"@10383' MW=10.8 NACL/BR FINISH RUNNING GR/JB TO 10285'. RU WL RUN PET LOG FROM 10298-8800'. POOR CMT BOND. RUN GYRO FROM 10300' TO SURFACE. RIH WITH SQUEEZE PERF GUN AND PERF 9890-9892, 4 SPF. WITH EZSV BRIDGE PLUG AND SET AT 9915. MU RTTS WITH BY-PASS TIH WITH 3.5" DRILL PIPE TO SQUEEZE BETWEEN 'A' AND 'C' SANDS. DAILY:S63,684 CUM:$1,210,736 ETDt$1,210,736 EFC=$1,668,500 REPAIRING SHIEVE IN CROWN 7"~10383' MW=10.8 NACL/BR RIH W/ RTTS AND SET AT 9640'. EST INJ RATE OF .5 BPM ~ 1400 PSI, i BPM @ 2000 BATCH MIXED 150 SX 'G' W/ .47% FL-28, .3% CD-31, .3% A2, 15.8 PPG, 1.15 CU. FT/SX. PUMP CEMENT INTO PERFS AT 2.6 BPM, 2200 PSI. FINAL PRESS 1200 PSI. L HESITATE AND SQUEEZE 4 BBL CMT INTO PERFS AT 5-10 MINUTE INTERVALS. FINAL SQUEEZE PRESSURE 1750 PSI. PUMPED 27 BBLS CEMENT INTO PERFS, LEFT 4 BBLS IN THE 7" CSG. WOC 4 HRS. REV CIRC 100 BBLS. SWI. RIG REPAIR. REPLACE FAST LINE SHIEVE AND BEARINGS. ( 13 }IRS RIG REPAIR ). DAILY=S56,528 CUM:$1,267,264 ETD=S1,267,264 EFC:$1,668,500 POOH WITH BIT 7"~10383' MW:10.8 NACL/BR POOH WITH DP AND SQUEEZE PKR. MU BIT, 2 JB. RIH TAG TOC AT 9713, DRILL CEMENT TO 9911. TEST SQUEEZE PERFS TO 1500 PSI. DRILL OUT BP AND CLEAN OUT TO 10294. CIRC BTM UP, POOH WITH 6-1/8" BIT. DAILY:S28,400 CUM:$1,295,664 ETD:S1,295,664 EFC:$1,668,500 The above tS correct For form prel;l~r~tlon' and distri~, see Procedu e~,.~4anueI. Section t0, Drilling, Pages 86 and 87'. INumber ,,11 dally well history forms consecutively es they are prepared for each well. Page no. ARCO Oil and Gas Company Daily Well History-Final Report Instruclion$: 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 Ior an indefinite or appreciable length of time On workove~s when an official te~t is not required upon completiom report completion and representative test d.ata in blocks provided The "Final Reporl" Iorm may be used for reporting the entire operation ~t space is available. District JCounty or Parish Field ILease or Unit Auth. or W.O.'~' ...... Title AK? 447 nnl~4'D T,R TF, IAccounting cost center code IWell no. Operator Spudded or W.O. begun Date and depth as of 8:00 a.m. 02/22/89 ( 2] TD=10457 PB:10300 SUPV:DL IA.R.Co. W.I. ~otal number of wells (aclive or inactive) on this ~cost center prior to plugging and I ~jabandonment of this well ~ nncln[i n~/11/89 / 1600 Complete record for each day reported NO,nTt RT~ I , RIG RELEASED @ 1030 7"@10383' MW:10.8 NACL/BR SERV RIG. SET TEST PLUG. TEST TREE AND PACK OFF TO 250 AND 5000 PSI. DISPL WELL W/ 345 BBLS OF DIESEL. SITP 850 PSI. TEST CV TO 1000 PSI. SET B?V. SECURE WELL. RELEASE RIG TO 2Z-21 COMPLETION @ 1030 HR 2/21/89. DAILY:S28,705 CUM:$1,728,499 ETD:S1,728,257 EFC:$1,668,742 Old TI) Released rig Classifications (oil, gas. etc.) rNew TD I PB Depth Date rKind pi rig Type completion (single, dual, otc,) Producing method Official reservoir name(s) Potential test data Well no. Date Reservoir Producing Interval Oil or gasTest lime Production OII on test (~aa Der day ..... Pump size, SPM X length Choke size T.P, C.P. Water % GOR Gravity Allowable Effective date corrected The above ia correct Drilling, Pages 86 and AR3B-459-3-C I Number all dally well hlatory forms consecutively aa they are f3repared Ior each well. iPage no. Dlvll~on of AtlantlcRIchfleldComf3any ARCO Alaska, Inc. Date: December 30, 1988 Transmittal #: 7390* RETURN TO: Transmitted herewith are the following items. one signed copy of this transmittal. ARCO Alaska, Inc. Attn: Brenda K. Miernyk Kuparuk Records Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Please acknowledge receipt and return 2 Z- 29 5" Dual Induction I 2 - 21 - 88 51 82-1 0438 2 Z- 29 2" Dual Induction 1 2 - 21 - 8 8 51 82 - 1 0438 2Z-29 Cyberlook' I 2-21 -88 9600-1 0250 2Z-29 2" & 5" Raw FDC I 2-21 -88 5500-1 0409 2Z-29 2" & 5" Porosity FDC 1 2-21 -88 5500-1 0409 This transmittal was sent out with the wrong well number. The original transmittal #7390 had the well number 1Y-29 instead of 2Z-29 that corresponded with the well logs. Please accept my apologies on this mistake. Receipt Acknowledged: .& (]as Cons, . DISTRIBUTION: NSK Franzen State of Alaska(+sepia) Drilling D&M L. Johnston(vendor package) STATE OF ALASKA .... AL. . ~A OIL AND GAS CONSERVATION COM M~_ .,ON 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 99510-0360 4. Location of well at surface 1158' FSL, 257' FEL, Sec.11, T11N, R9E, UM At top of productive interval 1360' FSL, 810' FEL, Sec.13, T11N, RgE, UN (approx) At effective depth 1138' FSL, 131' FEL, Sec.13, T11N, RgE, UN (approx) At total depth 1049' FSL, 50' FEL, Sec.13, T11N, R9E, UN (approx) 5. Type of Well: Development ,.' Exploratory ~ Stratigraphic __ Service __ 6. Datum elevation (DF or KB) RKB 109' 7. Unit or Property name Kuparuk River Unit 8. Well number 2Z-29 9. Permit number 88-129 10. APl number 50-- 029-21881 11. Field/Pool Kuparuk River Oil Pool 12. Present well condition summary Total depth: measured true vertical 10457 'MD feet 6333 ' T VD feet Plugs (measured) None Effective depth: measured true vertical 10300 'MD feet 6234 'TVD feet Junk (measured) None Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: Length 80' 5149' 10350' measured None true vertical None Tubing (size, grade, and measured depth) None Packers and SSSV (type and measured depth) None Size 16" 9-5/8" 7" Cemented 182 sx AS I I 1100 sx AS Ill & 500 sx Class G 485 sx Class G Measured depth ll5'MD 5184 'MD 10383 'MD RECEIVED JAN 1 8 t9R9 DJl & Gas Cons. Coll Jtlll True vertical depth 115'TVD 3557 ' TVD 6286'~ rVD 13. Attachments Well Hi story Description summary of proposal __ Detailed operations program __ BOP sketch __ 14. Estimated date for commencing oPeration February , 1989 16. If proposal was verbally approved Name of approver Date approved 15. Status of well classification as: Oil_,.~' Gas__ Suspended__ Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. -._....~..¢- . -..,..--~(/'~C/L ,, -- Title Area Drill i ng Engi neer Signed / FOR COMMISSION USE ONLY Conditions of approval: Notify Commission so representative may witness Plug integrity __ BOP Test ~ Location clearance __ Mechanical Integrity Test __ Subsequent form required 10- ~//' c:, ~ Date ///~ / ~ ? Approved by order of the Commissioner 0R!GIN~ .~CNED BY LONNtF C : ~ !b",,, ~1 ! Approved Copy Retu. j'n¢d ,-:~. ¢.~. 1---- z:z C~h~miss~oner /~Date feet Form 10-403 Rev 06/15/88 044/SA4 SUBMIT IN TRIPLICATE ARCO Oil and Gas Company Well History - Initial Report- Daily Inetructionn: Prepare and submit the "Initial Report" on the first Wednesday after a wail is spudded or workover operations are starled. Daily work prior to spudding should be summarized on the form giving inclusive dates only. District Field ARCO ALASKA INC. I NORTH SLOPE J AK ILeaseOr Unit no, I I ADL: 25653 2Z-29 ITitle I DRILL KUPARUK Auth. or W.O. no. AK3447 API: 50-029-21881 Operator ARCO Spudded or W.O, begun SPUD Date and depth as of 8:00 a.m, I ARCO W.l. [Date 12/14/88 IH°ur 1000 HRS I 56'0000 I Prlor status if a W.O. Complete record for each day reported DOYON 14 12/15/88 ( ') DRILLING SURFACE HOLE 16"% 115' MW: 9.4 VIS: 60 TD: 3589' ( 3! 89) FINISH NU DIVERTER, PU BHA, FUNCTION TEST DIVERTER, SPUD % 1000 SUPV:EV HRS, 12/14/88. DRILL 115 TO 1288, WIRE- LINE SURVEY, DRILL 1288 TO 3589. DAILY: $59,116 CUM: $59,116 ETD:S59,116 EFC:$1,668,500 12/16/88 ( ) TOH TO RUN CASING 16"% 115' MW: 9.6 VIS: 92 TD: 5210' ( 1 ~21) DRILL 3539 TO 5210, CIRC & COND HOLE, TOH FOR CLEAN OUT RUN, SUPV:EV TITE AT 1940 AND FROM 940 TO 550, TIH TO CLEAN OUT, CIRC & COND, SURVEY, TOH TO RUN 9-5/8" SURFACE CASING. DAILY: $73,084 CUM: $132,200 ETD: $132,200 EFC:$1,668,500 12/17/88 ( ~) TESTING CASING 9-5/8"% 5184' MW: 8.3 VIS: TD: 5210'( 0) FINISH TOH, RUN 134 JTS 9-5/8" CSG TO 5184, CEMENT CSG W/ SUPV:EV 1100 SX AS III AND 500 SX G, DISPLACE W/ WATER, BUMP PLUG, FULL RETURNS, CEMENT TO SURFACE, ND DIVERTER, NU BOP'S, TEST BOP'S, pU BHA, TIH TO FLOAT COLLAR, CIRC AND TEST CSG TO 2000 PSI. DAILY: $239,583 CUM: $371,783 ETD:S371,783 EFC: $1,668,500 12/18/88 ( i) TOH FOR PLUGGED BIT 9-5/8"% 5184' MW: 8.9 VIS: 32 TD: 6629'( ,19) DRILL OUT FLOATS, TEST SHOE TO 12.4 EMW, DRILL 5220 TO 6629, SUPV:EV TOH FOR PLUGGED BIT, BIT WAS BALLED UP EXTERNALLY IN FLOW COURSES. DAILY: $49,024 CUM.' $420,807 ETD: $420,807 EFC:$1,668,500 12/19/88 ( ,) DRILLING 9-5/8"% 5184' MW.' 9.5 VIS'. 41 TD: 9200'( 2 ~71) STAND BACK BHA, BIT BALLED UP, PU NEW BIT, TIH, DRILL 6629 SUPV: EV TO 9200. DAILY: $48,573 CUM: $469,380 ETD:S469, 380 EFC:$1,668,500 12/20/88 ( ;) DRILLING 9-5/8"% 5184' MW.'10.7 VIS: 49 TD: 9875' ( ~75) DRILL W/ TURBINE AND PCP BIT 9200 TO 9569, TOH ABOVE KUPARUK SUPV:EV AND LD BIT AND TURBINE, PU CONVENTIONAL BHA W/ S84F AND LARGE JETS, TIH, DRILL 9569 TO 9875. DAILY:S84,349 CUM: $553,729 ETD:S553, 729 EFC:$1,668,500 12/21/88 ( ~) POOH ON SHORT TRIP 9-5/8"% 5184' MW:10.7 VIS: 43 TD:10457' ( i82) DRILL 9875-10457. START SHORT TRIP TO SHOE. HOLE TIGHT. SUPV: EV DAILY:S81,960 CUM: $635,689 ETD :$635,689 EFC: $1,668,500 12/22/S8 ( ~) POOH LD DP 9-5/8"% 5184' M~:10.7 VIS: 45 TD:10457' ( 0) SLIP AND CUT DRILL LINE AND TIH. CIRC AND CONDITION HOLE. SUPV:EV DROP SURVEY, SPOT PILL AND TOH FOR LOGS. RU SCHLUMBERGER AND LOG W/ TRIPLE COMBO F/ 10448-9600, DIL/SFL/CAL/SP 10446-SHOE, FDC/CNL10446-9600,5900-5500, GR The above is correct 10446-- [U00. Signature DAILY: $122, ~81 CUM: $758,67q ETD:S758, 670 EFC: $1,668,500 For form l)roparation and distribution, ~,=~)~[~)/ . ~.~ j~.~ //~/~ see Procedures Manual, Section 10, Drilling, Pages 86 and 87. AR3B--459-1-D INumber all daily well history forms consecutively as they are prepared for each well. jPage 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 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. IAccounting cost center code ARCO ALASKA INC. District KUPARUK I ADL: 25653 [ ~_~ Field Lease or Unit .... IWell no. AK3447 DRILL Auth. or W.O. no. ITitle 50-029-3_1R81 ARCO 56. QQ00 Operator IA'R'C°' W'I' Icost[T°ta' number °f wells (active °r inactive) °n thisIcenter prior to plugging and SPUD 12/14/88 Jabando~% o~ well Spudded or W.O. begun DOYON 14 IDate IH°ur - ..... IPrl°r status if a W'O' Complete record for each day reported Date and depth as of 8:00 a.m. 12/23/88 ( TD:10457 SUPV:ZR 12/24/88 ( 1 TD:10457 SUPV:ZR PREPARE TO SET SLIPS 7"~]O~R~' __NW.:!0.~ N~.CL FINISH POH LDDP. RU AND RUN 7" 269 J-55 BUTT CASING. RU DOWELL AND ATTEMPT TO CIRCULATE, WITHOUT SUCCESS. CEMENTED AS FOLLOWS: 10 BBL CW100, 40 BBL SPACER 3000, 485 SX CLASS G CEMENT, TOP PLUG, 31BBL CEMENT, 2ND TOP PLUG, DISPLACED W/ 348 BBL 10.8 BRINE. NO RETURNS WHILE CEMENTING. AT 346 BBL DISPLACEMENT PRESSURE CLIMBED FROM 1000-1860 PSI. LOWER PLUG HAD NOT YET BUMPED. PRESSURE UP TO 2200 AND SD. PRESSURE BLED TO 1460 INDICATING ECP FILLING WITH CEMENT. PRESSURED TO 1600 AND IT BLED TO 1480 AS PACKER CONTINUED TO FILL. PRESSURED TO 1700 AND HELD. PACKER TOOK I 1/8 BBL EQUIVALENT TO 11.25" HOLE AGREEING WITH CALIPER. RD DOWELL AND BREAK OFF BOP. PREPARING TO CUT OFF CASING. DAILY:S242,448 CUM:$1,296,016 ETD:$1,001,118 EFC=$1,963,398 RR 7"~ 10383' MW: 00.0 SET SLIPS, CUT CSG, INSTALLED TBG HEAD, PRESS TSTD PACK OFF SECURED WELL & RR @ 1200 HRS, 12/23/88. Old TD I New TD Released rig I Date I Classifications (oil, gas, etc.) Producing method PB Depth Kind of rig Type completion (single, dual, etc.) Official reservoir name(s) 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 Gravity Allowable Effective date corrected The above is correct sFeO;fl~/~oPdrue, pe~ral~iaOnu~/a~l,ds*~[~u~i0o,n, ~ ~' '" / Drilling, Pages 86 and 87. AR3B-459-3-C Number all daily well history forms consecutively I Page no. as they are prepared for each well. I Dlvl~on of AtienflcRIchfleldCompsny ARCO Alaska, Inc. Date: January 6, 1989 Transmittal #: 7394 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. 2 Z - 2 9 OH Edit Tape and Listing 1 2 - 2 8 - 8 8 # 7 3 0 7 9 Receipt Acknowledged: DISTRIBUTION: ~ ~ska Oil & Gas Cons. '' Anchorage State of Alaska Lynn Goettinger MEMORANDbM State of Alaska ALASKA OIL AND GAS CONSERVATION COMMISSION TO: Lonnie C Smi Commissioner DAYE: January 9, 1989 mtENO: D.BDF.158 THRU: FROM: Sr Petroleum Engineer Bobby D ¥ost:er Petroleum Inspector TELEPHONE NO: SUBJECT: BOP Test AAI KRU 2Z-29 Permit ~88-129 Kuparuk Rv Field Frid~y.,_December .!6,_1988: The test began at 10:00 p.m. and was concluded at '12:00 p.m. As the attached BOP test report shows, there were no failures. In summary, I witnessed the BOP test on AAI 2Z-29. At tachment 02-001A (Revl 8~85) STATE OF ALASKA ALASKA OIL & GAS CONSERVATION COMMISSION B.O.P.E, Inspection Report Location, General ~ Well Sign ~'/ ACCUMULATOR SYSTEM General ltousekeeping ~-- Ri~ ~ Reserve Pit Mud Systems Visual Trip Tank Pit Gauge Flow Monitor Gas Detectors Audio BOPE S tack Annular Preventer , Pipe Rams · Blind Rams Choke Line Valves It.C.R. Valve · Kill Line Valves Check Valve Full Charge Pressure ~O psig. _ Pressure After Closure_/~O psig ,. Pump incr. clos. pres. 200 psi~ -- miCa.see. Full Charge Pressure Attained: ~ min~ sec. Controls: Master c-f~ ~ RemOte ~, ~ Blinds switch cover ~.~ , ; Kelly and Floor Safety Valves . Test Pressure "· Upper Kelly , 3~ o Test Results: Failures Lower Kelly Ball Type Inside BOP Test Pressure Test Pressure Test Pressure ~.~/o Test Pressure ~'~ ,.. Choke Manifold ~ Test Pressure..~z>~~ No. Valves ) No. flanges ,~,~ Adjustable Chokes ) Hydrauically operated choke / Test Time ~ hrs. Repair or Replacement of failed equipment to be made within .___' day~ and Inspector/ Commission office notified. Remarks: Distribution orig. - AO&GCC cc -Operator CC - Supervisor M EMORAN DU M State of Alaska ALASKA OIL AND GAS CONSERVATION COMMISSION To: Lonnie C Smith-- ;~/-~d~'6 DATE: January 9, 1989 Commissioner mLENO: D.BDF.156 THRU: FROM: Michael T Minder ~"~-'---'"'~'"~'. Sr Petroleum Engineer Bobby D Foster/~' Petroleum Inspector TELEPHONE NO: SUBJECT: Diverter Inspection AAI KRU 2Z-29 Permit #88-129 Kuparuk Rv Fie ld Wednesday, December 14, 1988: I inspected the diverter on Doyon Rig 14" ~nd found it ~tc~-e installed in a manner acceptable to the AOGCC. I requested that a tie-down be installed on one of the lines, and the crew was in the process of complying when I departed the location. In summary, I inspected the diverter installation on ARCO 2Z-29. 02-00 lA (Rev. 8~85) · ARCO Alaska, Inc. Date: December 30, 1988 Transmittal #: 7390 RETURN TO: ARCO Alaska, Inc. Attn: Brenda K. Miernyk Kuparuk Records Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 -29 -29 -29 Transmitted herewith are the following items. one signed copy of this transmittal. 5" Dual Induction 2" Dual Induction Cyberlook 2" & 5" Raw FDC 2" & 5" Porosity FDC Please acknowledge receipt and return 12-21-88 12-21-88 12-21-88 12-21-88 12-21-88 5182-10438 5182-10438 9600-10250 5500-10409 5500-1O4O9 Receipt Acknowledged: DISTRIBUTION: NSK Franzen State of Alaska(+sepia) Drilling D&M L. Johnston(vendro package) STATE OF ALASKA ...... AL, .,;A OIL AND GAS CONSERVATION COMM,_ ,,,ON APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon __ Suspend __ Operation shutdown __ Re-enter suspended well __ Alter casing __ Repair we,~ll __ Plugging __ Time extension __ Stimulate __ Change approved program _~' Pull tubing __ Variance __ Perforate __ Other __ 2. Name of Operator / 5. Type of Well: 6. Datum elevation (DF or KB) ARC0 Alaska, Inc. i- Development__v~ RKB 109' Exploratory __ 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 1158' FSL, 257' FEL, Sec.11, T11N, R9E, UN At top of productive interval 1360'FSL, 450' FEL Sec. 13, T11N, R9E, UM At effective depth At total depth 958' FSL, 48' FEL, Sec. 13, TllN, R9E, UM feet 8. Well number 2Z-29 9. Permit number 88-1 29 10. APl number 50-- 029-21881 11. Field/Pool Kuparuk River Oil Pool 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Well has not spudded. feet Plugs (measured) feet feet Junk (measured) feet Casing Length Structural Conductor Surface Intermediate Production Liner Perforation depth: measured true vertical 'Tubing (size, grade, and measured depth) Size Cemented Measured depth True vertical depth RECEIVED · ;~:;;ka ~OJl & Gas Cows. C0mmissi0~:~ This Sundry Request revises the target for subject well resultin in a revised directional program Packers and SSSV (type and measured depth) 13. Attachments Description summary of proposal __ Revised Directional Plan 14. Estimated date for commencing operation December 10, 1988 16. If proposal was verbally approved Name of approver Date approved Detailed operations program __ BOP sketch 15. Status of well classification as: · Oil ~ Gas__ Suspended __ Service 17. I he,by certify that the fore~oi ng is true and correct to the best of my knowledge. Signed · Title n e e r · ~ /,/ FOR COMMISSION USE ONLy' T WM ) SA4/032 Conditions of approval: Notify Corrb~ission so representative may witness Plug integrity __ BOP Test __ Location clearance __ ~,~ Mechanical Integrity Test ~ Subsequent form required 10- ~ Approved Copy ORIGINAL SIGNED BY Returned ~¢_¢~ Approved by order of the Commissioner ! 0r'.!'~JIF ~ SMITH / ~ - ~ -- '-- - uommlssioner lApp'ova'No. Date Form !0-403 Rev 06/15/88 SUBMIT IN TRIPLICATE '600C ARCO ALASKA, Ins. Psd 2Z, Well No' 29 Revised Proposml Kuparuk Field, North Slope, Alaska 0 _ RKB ELEVAT'[ON~ 109' 1000 _ 2000_ 3000_ 4000 5000_ 6000_ ?000 0 KOP TVD=550 TMD=550 DEP=O 3 9 i5 BUILD 3 DEO PER 1 O0 Fl' 21 33 B/ PERMAFROST TVD=1609 TMD=1673 DEP=320 39 51 sT EOC TVD=2193 TMD=2528 DEP=936 T/ UGNU SNDS TVD=2269 TMD=2677 DEP=1064 T/ W SAK SNDS TVD=2839 TMD=3795 DEP=2026 AVERAGE ANGLE 59 DEG 20 MI N K-12 TVD=3349 TMD=4795 DEP=2886 9 5/8" CSG PT TVD=3549 TMD=5187 DEP=3224 K-5 TVD=4949 TMD=7933 DEP=5585 , . TARGET TVD=5899 TMD=9796 DEP=7188 T/ ZONE C TVD=5904 TMD=9806 DEP=7196 T/ ZONE A TVD=6024 TMD=IO041 DEP=7399 B/ KUP SNDS TVD=6134 TMD=I0257 DEP=7584 TD (LOG PT) TVD=6236 TMD=10457 DEP=7756 I 1000 i 2000 3000 4000 VERTICAL SECTION ! ! m I 5000 6000 7000 8000 100 50 0 50 100 150 200 250 ~00 I I I I I I I I I 100 5O 5O lO0 150 2OO 250 300 350 400 /~ 500 I .~oo .__._., ,,/" '~ 500 r o ,O,°° I loo \ %,13OO \ \ \ \ \ 5OO \ 300 500 t S05591 100 50 1 100 1 150 J. I \ %1700 J 100 _ 5O _0 _ 5O 100 150 _ 200 _ 25O 2OO 25O 3OO 350 400 1000 1050 - 1100 _ 1150 _ 1200 _ 1250 1300 _ 1350 _ 1400 _ 1450 _ 1500 _ 1050 I I \ \ \ \ \ \ 1100 I 1150 1200 1250 1300 1350 1400 1450 I I I I I I I \ \ \ .................. _.~ _ 1000 · _ 1050 1100 '~ '" ,, ~ ; ' ' , .J. . 1200 '- X I _ ,250 ~, ~. ~820 "~,~o ~ I xxx ~ j _ 1350 ~ ~o I 1 450 11 50 1200 1250 1300 1350 1400 1450 _ 1500 1050 1100 October 31, 1988 Telecopy: (907)276-7542 Mr. J. B. Kewin P~gional Drilling Engineer ARCO Alaska, Inc. P. O. Box 100360 Anchorage, Alaska 99510-0360 Re: Kuparuk River Unit 2Z-29 ARCO Alaska, Inc. Permit No. 88-129 Sur. Loc. 1158' FSL, Btmhole Loc. 957'FSL, ~57' Sec 11 TllN RgE UM ~ FEL, . , , , · 435'FEL, Sec. 13, TllN, RgE, UM. Dear Mr. Kewin: ~Enclosed is the approved application for permit to drill the above referenced w~ll. The permit to drill does not indemnify you from the probable need to obtain additional permits required by law from other governmental agencies prior to commencing operations at the well site. To aid us in scheduling field work, please notify this office 24 hours prior to commencing installation of the blowout prevention equipment so that a representative of the Commission may be present to witness testing of the equipment before the surface casing shoe is drilled. ~There a diverter system is required, please also notify this office 24 hours prior to commencing equipment installation so that the Commission may witness testing before drilling below the shoe of the conductor pipe. Ve~-~ truly yours, ? I 7/ Il "- ' - ' Chair~n of Alaska Oil and Gas Conservation Co~ission BY ORDER OF THE COMMISSION dlf Enclosure cc: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. ------. STATE OF ALASKA ALASK,_)IL AND GAS CONSERVATION . .,MMISSION PERMIT TO DRILL 20 AAC 25.005 la. Type of work Drill J~ Redrill lb. Type of well. Exploratory [] Stratigraphic Test [] Development Oil Re-Entry [] Deepen Service [] Developement Gas ~ Single Zone ~ Multiple Zone 2. Name of Operator " 5. Datum Elevation (DF or KB) 10. Field and Pool ARCO Alaska, Inc. RKB 109', PAD 73'GLfeet Kuparuk River Field ,,i 3. Add'ress 6. Property Designation Kuparuk River Oil Po P.O. Box 100360 Anchorage, AK 99510-0360 ADL 25653 ALK 2579 '4. Location of well at surface 7. Unit or property Name 11. Type Bond(see 2o AAC 25.0251 l158'FSL, 257'FEL,Sec.ll,T11N,R9E,UM Kuparuk River Unit Statewide At top of productive i nterval(~ target) "8. Well nu.mber Number 1360'FSL, 81 O' FEL,Sec. 1 3,T11N,R9E,UM 2Z-29 #8088-26-27 At total depth "9. Approximate spud date Amount 957'FSL, 435' FEL,Sec. 13,T11N,RgE,UH 11/23/88 $500,000 "12. Distance to nearest 13. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and TVO) property line 2Z-13, 2Z-14 10229'MD 43~5' ~ TD feet 30' ~ surface feet 2560 6239'TVD feet "16. To be completed for deviated wells 17. Anticipated pressure (see 20 AAC 25.035 (e)(2)) Kickoff depth 550 feet Maximum hole angle 580 Maximum surface 2101 psig At total depth (TVD) 3374 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) ?/~" 1R" i~,9 c.~ H-Z~(~ W,~IH R{3' ~.~; '~;, !!r-, 11~' ~-~00 CF 12-1/4" 9-5/8".36# J-55 BT£ 5073' .~6 _~6' .~lClC~ ~.c~b,O. 11~30 _~× A~ II I & F-ER~ 500 sx Class G 8-1/2"I 7" 26# J-55 BTC 10194'I 35~ 35' 10229 6239.' 200 sx Class G tail F-ER~ Top of G 500' above 19. To be completed for Redrill, Re-entry, and Deepen Operations. Kuparuk 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 Intermediate Production ¢".¢".. ;',. Liner Perforation depth: measured · . true vertical 20. Attachments Filing fee ~ Property plat ~ BOP Sketch j~ Diverter Sketch ~'~ Drilling program [] Drilling fluid program ~ Time vs depth plot [] Refraction analysis [] Seabed report [] 20 AAC 25.050 requirements 21. I hereby certify/fh-"~ the foregoing is true and correct to the best of my knowledge Signed / ////~,~/,~,<z~, ~;~~~ Title R eo'i r,n~l n,--i'l'l ,i,~, F~ "~ '/ ' ~' / '- ' Commission Us~ Only.~l~)M (TEI~) P~3;;;; 'Date-/a Permit Number / '1 APl number I Approval date ' ! See cover letter I 50- z - I10/31/88/ forother requirements Conditions of approval Samples required [] Yes ,,~ No Mud log required ~ Yes ~' No Hydrogen sulfide measures ~ Yes ~ No Directional survey required ,,~"Yes ~ No Other: ~___~~~. ~~/.,~/ e//~/ by order of Approved by Commissioner the commission Dat Form 10-401 Rev. 12-1-85 f ' Submit in' triplicate ' HORIZ£ TAL ...... PROJECT. IO ~ : SCALE ! IN. = 1000 FEET ~cO ~^s~. ~o. P"d 2Z. Well No' 29 Propo,ed Kuperuk Field. North Slope. Aleeke 000 0 1000 :3000 4000 , I I i 100.0.. ~ 1000 200.0_ 30.00 ,4000 ..... 5000. TN~,T L.O~TIOM, - 13e0' FgL~ 810' FEL SECt. 13. T11N. ~ TD LOCATION' S=JT' FSL. 435' FEL 600.0 ...... SEC,. 13, T11N. Rg~ WEST-EAST 2000 I SURFACE; LOCtATION. 115~" FSI.. 2~' FEL SEC. 11. TII#. RgE 5000 I 6000 I $ 42. D.EG 57 M[N E 6938, (TIO TARGET) TARGET TVD-511~ T~=9~2 EASTI 4?2? i ~RGGIALASKA, ]]ne, . ~ Pedi2Z~iWell Ho, 2g Pr. opoeed Kup_:e_~.pk._F'leld,i_North Slope, Alaeka 0 ~ .ELEVAT[OIi, .ll)9, 1 OOO 2000 KOP TVD-550 THD-550 DEP-O 3 15 BU['LD 3 DEO PER I00 FT 27 33 BASE PERIIAFROST TVD-16:09 TIID-1673 DEP-320 45 EOC TMD"212'5 TPID"2.494 DEp-9.06 T/ UGINU SND$ TYD 226(3 THD 2672 DEP"IO$9 3001 .... AVERAGE ^NOLE 58 DE G 18 MI N T/ W SAK SNDS TVD-283g THD-3?$? DEP-11982 K-12 TVD"3349 TIID-4728 DEP-2$08 9 5/8' C$~ PT TVD-35,V3 TIID~5109 DEP-3132 K-5 TVD-4949 TIID-?Z74 DEP-5399 TARGET TVD-8899 THD-9582 DEP-6938 T/'-~ZONE "C- ..... TVD- $G0~4'- THD"' 959 i- DEP"8946- T/ ~ZONE A TVD-,G.O~g4 TMD.9820 DEP-?140 B/KUP SNDS TVD 6,134 THD-10029 DEP-7318 TD ~ CL~- 'PT) ~TVD-G,239- Tt'lD-10229--'DEP ?488 0 1000 2OOO i i m I 3000 4000 5000 6000 VERTICAL SECT[ON 7000 i 8000 1250 1200 1150 1100 1050 1000_ 950 _ 900 _ 850 _ 8OO 750 I fi' ~°¢'a' _ ~ ~oo N~! / " ~ /700 9OO 300 I I 350 300 250 350 300 250 200 150 100 50 0 50 I I I I I I I I I 0 \ '"'q ~ oo \ \ \ 300 \ \ \ \ \ \ \ \ *,,~ 500 \ \ \ \ \ N \ \ \ \ \ \ %17oo \ \ \ ! 200 I 150 ! 100 _ 1250 _ 1200 1150 _ 1100 _ 1050 _ 1000 _ 95O _ 900 85O _ 800 _ 750 75O 8OO 850 9OO 95O 1000 _ 1050 - 1100_ 1150 1200 1250_ 1550 1600 1650 1700 1750 1800 1850 I I I I I I I 1900 I 1950 I \ \\\ ~00 'k?6oo ~ "~soo %3700 \\\ 3800 I I I I I I I I \ \ 1550 1600 1650 1700 1750 1800 1850 1900 1950 750 80O _ 85O _ 9O0 950 1000 1050 1100 1150 1200 1250 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 logging 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" casing. 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. 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. Circulate hole with MUD I SHALE SHAKERS STIR STIR MUD CLEANER 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 10.7 PV 15-30 5-15 11-16 YP 20-40 8-12 8-12 Viscosity 50-100 35-40 35-50 Initial Gel 5-15 2-4 3-5 10 Minute Gel 15-30 4-8 5-12 Filtrate API 20 10-20 pH 9-10 9.5-10.5 9.0-10.5 % 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 13.5 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. After 2396' of departure, there are no well bores within 200' of this proposed well. TWM/ih 10/12/88 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. KUPARUK RIVER UNIT 20'° DIVERTER SCHEMATIC 6 DESCRIPTION 1. 16" CONDUCTOR 2. FMC SLIP~:)N WELD STARTING HEAD 3. FMC DIVERTER ASSEMBLY WITH TWO 2-1/16' 2000 PSI BALL VALVES 4. 20" 2000 PSI DRILLING SPOOL W/10' OUTLETS 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 4 ARCO ALASK~ INC., REQUESTS APPR(:)VAL OF THIS DIVERTER SYSTEM AS A VARIANCE FROM 20AAC25.035(b) MAINTENANCE & OPERATION 3 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 $,HUT IN WELL UNDER ANY . CIRCUMSTANCES JG 4/26/88 7 DIAGRAM el 13-5/8" 50CX) PSI RSI;ag, A ~ STACK 6 ACO.,M.LATC~ O.~ACITY TEST i, O.E~ JlAD F3LL AO::t,M. LATC~ I:~~IR TO ~ LEVEL WITH ~IC FLUID, 2,. ~ THAT A(X1Jll,I. ATCR ~ IS ~ PSI WITH 1500 PSI ~TRF. AM CIF TI'~ REGLLATClt'. 3. (3BSERV~ Tlkf., TI-EN C:UJSE ALL UNITS SIMJLTA~OUSLY AI~ RECI:RD TIE TII~ AI~ PRF. S:Ig.I~ REI~INII~ AFTER ALL UNITS AI~ CL(ZSED WITH OqARGING PLM:} CFF. 4. RE(II]ltD CIN ~ I:lffia(~T,, TI~ ACaiP'TABI.E LOIM~ LIMIT IS 45 SE~ CLCISII~ TIM: AI~ 1200 PSI 1llg~INING I 3 2 13-5/8" B(~ STACK TEST I. FILL BCP ST,Od3( ~ ~ ~F(::U3 W~TH AI~TIC DIESEL. 2. CI4~CK THAT ALL LOCK ~ ~ IN N~I. Li..EAD AI~ FULLY I:~T~ED. ~r. AT TEST PLUG IN PELLI-EAD WITH RI.N~ING JT ~ RLN IN LCXiI(IiI3~N SCRE~. 3. CLOSE ~ P;aLrVENTER ~ M~IJAL KILL LIllE VALVES ADJACENT TO BCP STAOC ~ OTI..ER VALVES ~ O.#3(ES ~ BE CPEN. 4. F~E~ UP TO 250 PSI ~ 14iD FC~ I0 MIN. IN~ CREA~ PRESSLR~ TO ~ PSI AM) H~LD FCR I0 MIN. BLEED la:E~ TO 0 PSI. 5. CPEN a6N. LAI~ PRLrvENTE~ AM) ~ KILL LI~E VALVES. CLOSE TCP PlI:~ RAM~ ~ WCR VALVES Oq KILL ~ ~ LII~5. 6, TEST TO 250 PSI ~ ~ PSI AS IN STEP 4. '7. CCI~IN,E TESTING ALL VALVE..~ LII~,~ ~ O.IDKES WITH A 250 PSI LOW ~ ~ PSI HIGIL TEST A,5 IN STEP 4. m ~37 p~ar_~a~ T~'S-'I' aNY ~ THRT NOT A FULL CLOSIN3 POSITIVE SEAL CHCKE. Cei. Y 8. ~ TCP PIPE ~ AI~ CLOSE BOTTCM PIPE RAI~. TEST BOTTCM PIPE ~ TO 250 PSI ~ ~ PSI. 9. CI:~N BOTTOM PIPE RAb~ BACX OUT ~NG JT AM) ICL CLCIIIE BLIM) ~ AM) TEST TO 250 PSI ~ PSI. ~FCLD ~ LIltS ARE FLLL Cl' NCI~I-FI~EZlNG FLUID. 5ET ALL VALVES IN CRILLING PCISITI~ 12. TEST STAN:PIPE VALVES, Kln/yo KELLY CCX]C~ DRILL PIPE SAFETY VALVE, AN) II~IDE BOP TO 250 PSI ~ PSI. I~, R~CI]aD TEST I~:'~TICN CN BLOaOt~ PR~'VENTER TEST FQRM. SIGN, AM) 5EM) TO DRILLING 14. PERFCRM a:M:LETE ~ TEST AFTER ~IPPLING UP AN) ~EKL.Y TI49~AFTER FUNL'TI~LY OPERATE ~ DRILY. ~ i ~4oo I ARCO Alaska, Inc. ~e?,~pi-i©i~e 9C~Y October 4, 1988 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 SUBJECT: Conductor As-Built Location Plat - 2Z Pad (Wells 18 - 21, 29) 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 GRU13/1.2 ii z I0 N.T.S. , 13 o O_ 18 V I CIN ITY MAP Imi. II o 16 ,\ o I~ ol5 ~ ~ NOTES: A~L WEL~S IN THIS ~ I COORDINATES A~E ~S.~ ZONE ~S'BUILT ~CATED ' SECTION II, ~ I I N., ~.9 E., ~ ~ 2. ALL DISTANCES SHOWN A~E T~UE. UMIAT ~E~IDIAN. ~ ~. ELEVATIONS A~E ~. ~EFE~ENCE FIELD BOOKS~ L-88-34, pg. Z-3 , L-88-36, pg. 3-4. I 2 5. O.G. ELEVATIONS FROM NSK'3.23.6-Z, rev. I PROTRACTED SECTION CORNER 14113 6. HORIZONTAL POSITION B~ED ON 2-Z CONTROL I MONUMENTS PER LHD end ASSOCIATES. WellJ , , ASP's , , I J I Dist. I DiSt. O.G. J Pad : N~ Y X LATITUDE LONGITUDE F.E.L. ES.L Elev. Elev. 18 ·5,966,552.92 529,117.01 70° 19' 10.907" J 149°45'50.~50'' 591' 1796' 65.0' 72.6' 19 5~966,605.96 I 529~088.86 70°19'11.4~0" ~ 149°45'51.065'' 619' ~ 1849' 67.8' 72.5' 20 5~966~658.89 529~060.86 70°19'! 1.952" 149°45'51.877'' 647' ! 1902' 68.0' 72.6' 21 5~966~827.08 529~79.34 i 70019' 1~.594" 149°45'42.563" 327' z069' 66.5' 71.6' ~ 29 5~965~916.38 529~45~.15 70Ol9'04.6~" 149o45'40.51~" i 258' 1158' 67.3' 71.1' I I I I I I,, I I HEREBY CERTI~ THAT I AM PROPERLY ~ OF ~(= REGISTERED AND LICENSED TO PRACTICE ~~...~e~,ee:~, LAND SURVEYING IN THE STATE OF ~..- ~-~ ~ '$ ALASKA AND THAT THIS PLAT Ii MADE BY ME OR UNDER MY ~~~~~e..- ~ ..... SUPERVISION, AND THAT ALL ~.~~~~ D.S. 2-Z DIMENSIONS AND OTHER DETAILS ~,~CRAIG L. S*VAGE~ ARE CO~.ECT AS OF 8/~9/88. '~------~X ~~~~ WELL CONDUCTOR AS-BUILT · 4538-5 .. ' t { ~ ''" M'O' O' ' ¢-'"~¢' '''', NellI , , ASP's , , I j Dist' Joist' O'G' I Pad No Y X LATITUDE LONGITUDE F.E.L. ES.l_ Elev. Elev. · 18 5,966,552.92 529,117.01 70° 19' 10.907" 149045'50.250'' 591' 1796' 65.0' 72.6' 19 5,966,605.96 529,088.86 70°19'11.430" 149°45'51.065'' 619' 1849' 67.8' 72.5' 2_0 5,966,658.89 529,060.86 70°19' ! 1.952" 149°45'51.877" 647' 1902' 68.0' 72.6' 21 5,966,827.08 529,379.34 70°19' I 3.594" 149°45'42.565" 327' 2069' 66.5' 71.6' 29 5,965,916.:38 529,453.15 70°19' 04.635" 149°45'40.515'' 258' 1158' 67.3' 71.1' ,' ,, , CHECK LIST FOR NEW WELL PERMITS ITEM APPROVE DATE (2't~ru 8) ' " (3) Admin ~ Z'd~/p____~/f'~' (9 thru 13) (10 and 13) (14 thru 22) (5) BOPE /~~?'~"I~ ,;f ~' (23 thru 28) Company ~f~_O ~. '"~~ Lease & Well No. ' " YES NO Is the permit fee attached · ~ ~" eeeeleee®eeeeeeeeeee~eeee~eeeeeeeeeeeeeeee 2. Is well to be located in a defined pool ............................. ~/~ 3. Is well located proper distance from property line .................. ~.p~. -__ 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 .... ~ ...... ~-AJ_G-- __ 7. Is operator the only affected party ................................. ~Rf. __ 8. Can permit be approved before fifteen-day.wait ...................... 9. Does operator have a bond in force .................................. 10. Is a conservation order needed ...................................... 11. Is administrative approval needed ................................... 12. Is the lease number appropriate ..................................... 13. Does the well have a unique name and number ......................... 14. Is conductor string provided ........................................ 15. Will surface casing protect all zones reasonably expected to serve as an underground source of drinking water ..................... 16. Is enough cement used to circulate on conductor and surface ......... 17. Will cement tie in surface and intermediate or production strings ... 18. Will cement cover all known productive horizons ..................... 19. Will all casing give adequate safety in collapse, tension and burst.. 20. Is this well to be kicked off from an existing wellbore ............. 21. Is old wellbore abandonment.procedure included on 10-403 ............ 22. Is adequate wellbore separation proposed ........................... 23. Is a diverter system required ....................................... 24. Is the drilling fluid program schematic and list of equipment adequate~,~ 25. Are necessary diagrams and descriptions of diverter and BOPE attached. 26. Does BOPE have sufficient pressure rating - Test to ~~ psig .. 27. Does the choke manifold comply w/API RP-53 (May 84) .................. 28. Is the presence of H2S gas probable ................................. (6) O'iI:IF, R t~fd_. /,~/~/~f (29 thru 3i) (6) Add: ~.t~ / ~' f~' Geology: Engineering rev: 08/11/88 6.011 For 29. 30. 31. 32. 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 presented Additional requirements ............................................. POOL Additional Remarks: INITIAL GEO. UNIT ON/OFF CLASS STATUS AREA NO. SHORE t- o,'/ 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. ,o COMPANY NAmE : ~RCO ALASKA INC. YELL NA~E : FIEbD NAME : S ' TAlE : ALASKA BOROUGH :NORTH SLOPE API NIJMO~R :: 50-029-21881,-00 REFERENCE NO : 73079 ALASKA COMPUTING CENTER ~mmmmmm~m~mmm~mmmmmmmmmm~mmm$ WELLDNAME STATE BOROUGH API NUMBER ~;FERENC~ 50-029~21881-00 73079 LIS ?aLe Ver.tficetiom l, lstino Schlumberqer Alaska ComUutino Center 28-DE~C-1. 988 17:04 DATF : O~IClN : ~biC REEL ~A~E : 73079 CONTI~UATIO~ ~ ~ COM~E~T : bis TAPE, ARCO KUPARUK 2Z-29, API~50-029-2~8~1 **** TAPE H~;ADER **** ORIGIN : FbIC T~P~ NA~E : 7]079 CONTIMUATION ~ : 1 P~EVIOUS T~PE : COMM~Z~T ~ LIS TAPE, ~RC[~ KUPA~[.~N 2Z-~9, API~50-029-21881 FILF NAME :FDIT ,001 SMRVICE : FbIC VERSION : O0~AO~ D.&TF ~ 88/12 ~8 M~X ~C STZ~ : 1096 FIS~ TYPE : LO L~ST FILE : PAGEt NA~E: ARC() ALASKA INC. ~Z - 29 ~TATE~ . ALASKA LOCATION: 1158' ~S...,, & ~57' ~'~5 ~ECI~IOi'~: 1I TOWD~SHIP: lin RAN'GE: 9E Schlumberger AlasKa Computlno (:enter 28-DEC-.~ 98g 17:n4 PAGE: Ef!EVLT1ONM K~: OF: 108, GL: 68. DATE 50GG~O: 21-DgC-88 TD DRILLER: 10457. DRILLER DEPTH ()F 5184 TYPE IN HOLE: 5S POLYMER DENSI'~YI 10,7 VISCOSITY; 41, P~: 9.5 ~i!D RESISTIVITY~ 3.2 ~ 77, FILTRATE ~ESISTI~I?Y: 3,37 ~ 77, ~tID CAKE ~ESISTTVTTY: 2.86 ~ 77. T?~E CIWCtJLaTION ENOED: T~E LOGGER ON BOfYQM: M~XIM{IM TE~P RECORD~DI 1030 17-21 1816 12-21 152, LOGGING OISTR!CT: I, OGG~NG ENGIt~EE~: PRUDHOE BAY G, SARBER ~. VAUG~N/Z.RUNJ~/P. F[,ETCMER IOOL SGC,,j¢ 2479 P (; C '" ',~ g ' ! 0 5 PG8"50 ~ SIX! 1/2" TEFhON .... STANDOFF~ AN;) A 2" HC)L,E FINDER UBED. AN T~LIt~E WEIGHT ALSO USED DUE TO HOLE ANG[~E (61.4 DEG) CNL ~A~RIX - SAND, M C '" 'm' ' ' ' ' XOki~ .,RE': ~ODAY ~t~,AS D, D~TE gOO ~TARTED; 28,,DEC 88 JOB RMFER~N'CE N.O: 73079 LDP/ANA~ R. ~INES ********************************************************************************* . ' w INCLUDED WITH THIS FILE LiS Tape Verification !,!.stin~ Scblumber~;ler AlasKa Co~o~lti,~g Center <,qEF ~"I{~E ~D[T.002 FOR 1.2" SA~PLFD FDC/CNL i){~AL ]NDUCT{(]~:~ SPHERICALLY F~C~S~D FIRST TO LA6T READING: 10478' FOR~ATIO~ ~ENSITY CO~PENS~TFD LOG C~FDC) FIRST TO LAST ~E~DING: !0478'-9590 CO~PENSAT~D NfUTRO{~ LOG (,CNL) FIRST TO LAST RSADING: 10476'-g590'/59~0' - 5490' FIRST TO LAST READiN ;G 5180' PAGE: TABLE TYPE { CONS TUNI VALU DEFI CN ARCO ALASKA INC' Company Name FN KUPARUK Fle~d Name WN 2Z - 29 Well Name NaT! USA Nation STAT ~6ASKA State or COUN NORTH SLOPE County ii Sectl6n ilN Township 115~ FSb, & 257' FEb Province 54 8730 API~! 50-~029-21881-00 APl Serial Number . TABLE TYPE : CURV DEFI DEPTH CHAN~EL NAME Tension IL ~edlu. m IL-Deep ~esistivit Spontaneous Potential Gamma Rag ~enSiOn DPBI Density Poroslt~ D~HO Delta rbo LIS Ta~e Verificetion Listinc.l 8chlumberoer AlasKa Compt!tinq Cent, er TNRA CAbIBEATED THgRMAb ~'~EUTRON RAT~) RCFT RCFT RCNT RCNT CFTC CFTC CNTC CNTC G~ Gamma Rev GR ~emma Ray PAGE: ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EM ** TYPE REPR CODE VALUE ! 66 O 2 66 0 3 7~ 96 4 66 1 5 6~ 6 7 65 ~ 68 0~5 9 65 F ~1 66 1~ 6B 13 66 0 14 65 FT 6 65 66 0 ** SET TYPE - CHAN ** UNIT SERVICE AP1 APl AP1 API FILE NUMB NUMB SIZE S ORD~,,R ~ LOG TYPE CheSS NOD NUmB SAMP ~LEM O0 000 O0 0 1 1 ! 4 68 0000000000 07 I LN DIL OHM~ 548730 07 LD DIL 0~ 5487~0 07 SP OIb MV 548730 07 GR OIL GAPi 548730 07 ~P'H,TFOC ~U 07 2O O! 20 46 ]10 01 I 4 i 4 65 6:8 IS Tame refill, cation Listing cblumberger AlasKa Computing Center 28-DEC-lQ88 17:O4 RHGB FDC G/C3 548730 07 310 O1 0 1 I 1 4 68 CAL? FDC IN 548730 07 310 O1 0 1 ! 1 4 68 GR FDC GAPI 548730 07 310 Ol 0 I 1 1 4 68 TFNS CNL LB ~4873o 07 310 Ol 0 I 1 I 4 68 NPH! CNL PU 548730 07 310 O1 0 1 1 I 4 68 TNRA CNL 5487]0 07 3~0 O{ 0 i ! 1 4 68 RTNR CNL 548730 07 310 O1 0 1 1 ! 4 68 RCFT CNG CPS 548730 07 310 O1 0 1 I I 4 68 RCNT CNG CPS 548730 07 310 01 0 ~ 1 ! 4 68 CFTC CNG CPS 5487~0 07 ]10 O! ~ 1 I 1 4 68 CNTC CNL CPS 548730 07 ]10 Ol 0 ! I 1 4 68 G~ C~L G~P! 54873O ~7 3~0 O~ 0 ! ~ I 4 68 T~NS CHL LB 548730 O7 635 21 u I I 1 4 68 ~m CML G~PI 548'730 07 310 Ol 9 1 1 1 4 68 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 DATA D~PT. DPH?.FDC TGR,FDC R.N~,CNL C~!TC,CNL L~ DC DC C~L C N L D~PT, DP?ii~FDC GR,FDC C,TC;C~h DE'PT, 10478 000 I.~ 838 86O ~ 813 373 1806 954 10400,000 2,411 !.71750 10300. ooo 778 1'451 1020'~,000 ,354 103,259 79438-8 TENS.DIG DRHO,FDC T~,CNL ~C.,,T,CNG GR, TEN$.~IL DRHO,~DC RCFT,CNL .ENS Si: DID DRHO FDC CN h CNG TENS,DIG DRHO;FDC R. CVT,CNL 1550 000 -40 344 0 04O 1550 OOO 517 676 82 813 SFLU GR RHOB N~H~ RCN'~' TENS DIG ~,DIh ~FDC CNG CNb 78~48 34 0 7848 025 000 RHOB;FDC NPHI;CNG RC~I,CN5 7560,000 SF!LUi -lg,719 ;:082 7560,000 NPHI 434,554 RCNT 92,750 TEN6 CHh ,C 0 SFbU 73~ '0 ' :'~219 GR,DI.h ,f~c 0;023 1308~000 ,N~ ,CNL 417,932 RC ~,CN5 103'~50 3.233 8~,813 .471 3~,586 176:,i39 -999,250 ILS DIL TENS FDC CAb! FDC CNG GR CHI.,, 9'9 .945 IbM,DIG ;750 TENS~:FDC ,42! CAbI,FDC ;967 TNRR;CNL ~994 CF~C,CND ;250 GR;:C~ 2.080 ILM,Dlb 9 .750 TEN$,FDC ~;060 TNRA,CN[ CrTC C. 999,250 GR~C~L 611 tLM.,DI.L ~50 TENS;FDC 2~464 CALI,FDC 44i87! T~RA,CNL !798,645 CS.TC,C~L 99q'~5.0 GR2C:HL 71 756' -999 250 7 30~. I~I$ Ta~e VerIflcati. on ~.istipc= $c61umberqer Alaska Computin~ Center DFPT, 10100,000 TENS,b~L Ib0.~Ib 5,377 SP,DI6 DPHT.~C ~3.325 DRHO.F'~C G",FOC 86.313 T~N!iC~b R~.C~L J,l~! PCF C~TC,C!~L 2,~38.051 G C~ DEPT, lO000,O00 TENS,OIL ~LD,DIL 4,293 8P,DXL OP~. FDC 10.911 DRHO FDC ,FDC lOl,5OO ~ENS~C~L CNTC.CNL 1994.353 GR h D~PT, IbD,D1L DPM~.FDC G~,FDC RTN~;CNL CNTC.C~L 9900,000 5 3~6 14 743 78 000 3 151 2248,5]8 TE~S,DIL DRHO,FOC ~£N$,CNb RCFT.C~ GR.CNb D~PT DPH! G~ RTNR C~TC r)IL FDC FDC ~CNb 9800 34 '4 66 ~1~I ,000 ,361 ,529 65 DRHO GR DIL DIL rDC CNb D~PT D~hD GR CNTC ,Dlb .FDC ,FOC ,CML .CNI. qTO0 4 1691 000 917 9~ 39 246 TENS,DIb DRMO,FDC TEN$,C~b RCFT.C~L GR.CML D~PT DPH! 'D , IL , FDC , C~L oo0 3 ? 0 610 80O TENS,OIL SP.DIb ~o,~uc ~ENS,CNL RC~T,C~L GR~CNL OFP'T, Ib~,Dlb DPH~,FDC "GR,FDC C~TC.CNL 9500, 4, '999. '999, -999. 000 250 TENS SP DRHO GR DTL ¢¢. C~IL CNL .C~ib D~PT DPHI DI L FDC FDC CN [, 940 0 5 -999 -999 000 2~0 2SO ~0 'E ' SP.DIb ORHO ~DC RC R.CML 28-D~:C-!988 i7:04 "1068.000 SFLU.DIL '17,766 GR,Olb 0.007 RHOB.FDC 70mS,0UO NPHI.C~L 63~.239 RCNT,CNb B6,31] TENS,CHh 7400 0 7400 513 101 000 SFLU,OIL Ob3 GR;DIL 0~3 RHOB,FDC 000 NPH1,CNL 936 RCNT'CNL 500 7120,000 SFLU,DIL -~,406 GR,DIL .002 RHOB,FDC 7~,000 NPHI,CN~ .824 RCNT'CNL 78.000 TENS.CML 624 66 7180 -32 0 71.80 429 110 7 512 -35 751~ 000 SFLU 313 GR 003 RHOB 000 NPHI 4'74 RCNT 813 TENS OIL FOC CNb CNL C H L 000 SFbO,DIb 313 GR,DIL 014 RHOB~FDC 000 NPHI'CNb 152 RCN.T;CNb 188 TENS,CH~ 7208,000 SFLU 75O GR 250 RHOB :999, 50 NPHI 999e 50 RENT -999,250 TENS NPHI.CL 50 'C~L TENS PAGE{ 2088. -999, 56"] 313 430 971 464 250 TENS,FDC CALI.FDC TNRA,CNL C~TC,C~L GR,ChL ILM,DIL TEN$.FDC CAL~.FDC TNR ,CNL CFTC~CNL GR,CHL ILM,DIL TENS,FDC CALI~FDC TNRA,C~ CFTC.CNL GR,CHL , 101' 1895. 999. 324 5O0 470 832 8';5 25O 5 78 2 32 2200 -999 609 000 4O7 474 260 25O 78 66 .2031 999 181 IbM,DIL 81 TMNS.FDC 725 CALI,FDC 761 TNRA,CNL 849 CFTC;CNL 250 GR'CHI, 999, 188 TE~S 305 TNRA,CNb I7~ CFTC;CN5 250 .174g 99, 4 538 !b:~ P!b 5.462 7068,000 9,680 999,250 4,138 7400,000 8,945 3,297 .608,511 999,250 5,399 ?t20,O00 999,2~.0 00~ 950 718 -999 ~0 .,999 250 GR.:CML '1.7, ,. .15::$' , .99~, ,FDC 99:{. * '999,250 CFTC,CNb '999~ ~5:0 G~'CHL LIS Tape verification Listlna Schlumberger AlasKa ComPutf. no Cemter DF-PT, T1, D.DIL DPHI,FDC GR,FDC C~TC. CN L DFPT ILD DPH 7 FDC G~ FDC DEPT DP~] FDC G~ FDC CNTC C~L DFPT ILD DIL DPt% FDC GR FD~ C~ TC ,C~ L D~PT, DP{~I ,FDC GR ,FDC RTNR C~L ~IL FDC G~ FDC CNTC G~ FDC C~TC FDC GR 9300.000 4,3{5 '999,250 '999,250 '999,250 '999;250 9200,000 3,750 '999,250 '999'250 '999,~50 '999'250 9100 000 3 507 '999 250 '999 250 '999 250 '999 250 9000 000 6 439 -999 250 -999 250 -999 250 -999 250 8900 OOO 4 314 -999 -999 -999 2 0 3, 54 '999 250 ~9'99' 999® .250 @70~,~00 '999,250 '999,250 '999,259 '999i250 ~60:0 OO0 4 -999 50 -999 250 -999 256 TENS,D]L SP,glh DRMO,FDC TENS,CNL ~b RCFT,C~ GR,C~I~ TENS,DIh SP,DIL RCFT,C~[, GR,C~L TENS DIL ORMO FDC TENS CNL RCFT CML GR CML TENS.DIL SP DIL DRMO FDC TENS CNL RCFT C~L GR TEN$,DIh SP'DYh o~.o.~'~C TENS,CNb 'F .,C~ DRHO,FDC 'N T~.,~.C~ nCF.t,C~L GR'CNb TEN$,DIL SP,DIL D~HO'FDC RC'~T,C~L ~R.CMh SP.DIL PCF'.C. C 2B-DEC-Iq88 1.7:04 6604,000 -43.688 ~999 250 -999 250 -999 250 -999 250 SFLU,OIL GR,DIb RHOB,FDC NPMI,CNL ~CNT,CNL TENS.C~L °°° 44,5b~ q99;250 999,250 999.~50 -999,250 SFLU,DIL ~HOB,FDC NPHI,CNL RCNT,CNL TENS,CHh - 594 -999 250 -999 -999 -999 50 ~HOB,FDC ~P~I,CNh RCNT,CNL TENS,CML 6392 000 -50 ~63 -999 50 -999 -~99 -999 250 SFbU,DIL GR,DIh RHOB,FDC NPHI,CN6 ~CNT'CNh TENS,CHh 6432,000 SFLO,DIL -41;875 ~GR;D:IL -999,250 RHOB,FDC -999~2'50 NPHI;CNL -999,250 RCN~'CNL -999'~50 TMNS~CHL 6260,000 "42'3~3 GR;DIb -999,2:~0 NPHI~CNB -999;2'0 -999,250 TENS,CHh 6304,000 8FLU,DIt~ --44 , 969 ~ ~ 999 250 RHOB; -99:9,250 N:P'}~ I '999,250 RCNT,CP '999~ ~50 TENS 4 693 226 875 TENS,FDC -999 250 CALI,FDC -g99 250 TNR~*CNL -999 ~bO CFTC,CNL -999 250 G~,CML 4,119 IL~,D]5 .178.625 TENS,FDC ~999,250 C~5I,FDC .999,250 TNR~,CNL 999.250 CFTC,C~L -999.250 GR,CHL 4,754 ILM,DXL 116,]75 TEN$,FDC -999, TNRA,CNL .999.250 CFTC*CNL 999,250 GR,CHL 9 543 IL~,DI~ 101 188 TENS,FDC '999 250 CALI,FDC CNL -999 250 G CML ~' 5 T~NS'FDC 250 CALI,FDC :999 999 250 2 800 4,38 250 250 2150 CFTC~C~ -999 250 GR,CHL 700 IL~,DIL I2S T~NS,FU:C :999 250 C[DI,FDC 999 25=0 TMR~,CNL -999 250 CFTC,CNL -99:9 250 GR,CHL 4.274 750 TEh$,FDC 250 C~LY*FDC 250 TNRA'CN~ ~50 CFTC~CN[! '999, '999,~50 '999, 90 '999.I~0 '999, 0 . 3,862 999, 999,250 -999;250 ,,999,250 999, "'999 · -999 -999 ,0 mC I~ Tame Veriflcatio~ !.,isti~ chlUmbe~qer AlasKa Computin~ Cent.r" e CfJTC. CN[, -999,25a GR, C~'iL DFPT, ~500.000 TENS.DIL 945 SP,DIL TLB.DIL 3t'250 DRHO,FDC DPHT, F[';C '999'250 TENS,CML GR,FDC '999, RTNR,CNL -999,250 RcF'r.c~L C~'I/C,C~'~L -999. 250 GR,C~b DFPT. DPHI 400,000 TENS.DIL DIL 4,584 SP.DI~ FDC 999']50 DRHO,FDC FDC 999. 50 TENS;CML CML -999,250 RCFT'CNL CN!,, -999.250 CR,CFL DFPT ILD DPHT GR RTN~ CNTC 8300,000 TENS,DIL DIb 3~352 SP OIL FOC -999.250 ORHO FDC FDC -999,250 TENS CML CNI, -999,250 RCFT CML CML -999.2~0 GR,C~b DEPT, 820~,000 TENS,DI.b !L~iDIb ,~46 SP;DIL DPHI FDC -999,2~0 ~RHO,~DC G~,F. C -999,250 TE~S~CN[, T~ ~ -999 RCFT,CNL R.~ C,~b .250 (..NT.~.CN[, -999'250 GR~CNL 28-D~:C-198~ 17:04 ILD,DIL DP~I,FDC -999.2b0 TE~'.!S. CML D I L FDC FDC 5888.000 SFLU DIL ~6,0t3 GR Di~ - 99,~50 R~iOB MDC -999.250 NFHI CNb -999'250 RCNT CML -999'250 TENS CH~ PT DPH T 6040.000 SFbU,D{L -59.188 GR,Dih -999,2b0 ~HOB,FDC -999,250 NPHI,CNL -999,250 RC~T,CNL -999,250 TENS,CHL 6112,000 8FLU 48,875 GR -q99'250 ~HOB -999,250 NPHI -999'250 RCNT -999;250 TENS biB4 -40 8100.000 TENS.DIL 6332 1,982 SP, DIL ',999'250 DRMO; FDC -99:9 -999'~50 TE ~999; 50 RCFT; C~3~L -999,250 GR,ChL -999 800~:000 TENS,OIL ~6 SP~Olb -999,250 DRHO'FDC ~999,~50 TENS.CML '999, 50 G~,CNB 790~,000 TEN$.DIL .999,959 ~P,DIL .250 DRJ!O~FDC -9~.250 TENS,~ML -99 ,250 RCFT, -999,250 DIL , 780~,,00U TENS,DIL , DI5 ,630 , FDC -99~, 250 )3RMO, FDC ,FDC -999,250 TENS*CML 000 SFLU,DI5 031, GR,DIb RHO~ 20 NPHi;C~b 250 RCN~,C~L 250 TEMS~C~L 000 8FLU, GR'DIL RHOB~FDC 250 5168,000 SFLU,OIb '54~594 GR;DIL '999,2~0 REOO,FDC -~99,250 R~NT~CNG DIL C~b C H b PAGE: -999.~50 3.817 113.750 -999'250 -999'250 -999'250 -999.250 5.245 139.500 :999,250 ~999,250 ~99'250 3 898 -999,250 -999,~50 -999,~50 -999.250 -999 -999 '9:99 GR.CHL IL~.DIL TE~$,FDC CALI,FDC TN~A,CNL CFTC;CN~ GR,CHI ILM,Dib TMN$,FDC CALI,FOC TNRi,CNL 'CHL IL~,DIL TENS FDC CALI FDC TNRA CML CFTC CML GR.CHL Ib~ TENS FDC CAbi FDC T~R tnb CFTC I 900 IL~ 250 GR FDC CN5 CHL 082 IL~,OIb 500 250 CAbI,FDC 5o: 2 855 I L ~ D I b :999 250 TNRA,CNL '999 ~50 CFTC,CNL -999 250 GR,CHL ,493 ILM,DIL 9~,750 TENS;.FD.C -999,250 CALI,FDC -999.~50 TNRA~CNL -999,250 . 3,890 ~999,250 .999,250 999~250 -999,250 . .999,250 .999,250 .99 ,2~0 3.484 -,,, '999 '999 2~0 2.50 t,I$ ~ane Verification!( Llst!n~ SchlUmberger AlasKa omputinq CeDter RT~P.C~,~L -999,250 PCFT.C?JL CNTC,C~L -999,250 GP,CNb DEPT, 7700,000 TENS,~Ib IL~,DII.. 3.761 SP,DIL G~,FDC -9~9,250 TEN CNL R%NP,CNL ~999,250 RCFT,CNL CNTC,CNL '999,250 GR,CML DKPT. 7600 TLD.DIL 4 DPHI.FDC -999 GP FDC -999 RTM~:CNL -999 CNTC.CNL -999 ,0oo TE~S,DIL 093 SP,DI~ 250 DRHO.FDC 250 TEN$,CNL ~50 RCFT.CNL 250 GR.CNL DEPT DPMI GR C~TC 7500 ooo TEN8 ~Ib 3 402 SP FDC -999 250 DRHO FDC -999 250 TENS CNL -999,~50 RCFI C~L -999. 50 GR OIL DIL FDC CML DFPT DPMT GR C~TC . 7400,000 TENS. ,DIL 3,169 · FDC -999~250 DRMO~ ,FDC -999'250 TENS, 'CML -999;250 RCFT. ,CNL -999.250 D I L FDC CNL CN b D~PT, '730~,000 TENS, I,D,OIL DPHI,FDC -999;~50 DRHO, G~,:FDff -,999&250 TEM$, ~TNR,CNL -999,250 CNTC,CNL -999'250 "D ~ C CN L DFPT C~TC N L C N L 7200,000 -999,250 rENS.D'IL DRHO;FDC TEN~,CMb RCF~,CNL ~ ,, GR,CNL 710~,000 '999,~ '9'g9~5050 '999,250 '999.250 TENS,DIL DRHO,FDC TENS~CNI,, RC~T,CNL 17:04 -999,250 RCNT,CML -999,2b0 TENS,CHh 5700 000 -51 969 -999 250 -999 250 -999 ~$0 -999 50 5668 oo0 -49 563 -999 ~50 -999 250 -999 ~50 -999 250 5532 000 -52 9O6 -999 50 -999 ~50 "999 250 '999 250 SFLU,OIL GR,DIb RHOB,FDC NPHI,CNL RCNT,CNb TEN$.CNL SFLU. GR, NPH~, RCNT, TENS. SFLU, G'R, RHOB, NPMI, RCNT, TEN$~ 5~92,000 SFLU 49,906 G~ ~999,250 ~HOB -999~ -999,250 TE~S OIL FDC CHL C CNL OIL OI b 5120 DIL ,46 OI b 50RCNT 50 YENS 5984 000 SFbU OIL '4~ -99 '999 250 5~80,000 SFLU,DIL '999,2b0 RHOB,FDC -999~50 ~CNT,CNb -999.;~50 :~ENS;CHL -999.250 CFTC.CNL -999.250 GR'cHb 3 441 97 813 -999 250 -999 250 -999 250 -999 250 IbM TENS TNRA CFTC G~ DIL FDC FDC CNL CNL CHL 4 Iii -999 -999 -999 -999 125 ] TENS 250 CFTC 250 GR DIL FDC FDC CNL CNL CHL 96 -999 -999 -999 -999 282 ILM 625 50 CALI 50 TNRA DIL FDC FDC CNL CNL CHL 2 682 ILM,DIL 97 TEN$,FDC -999 CALl, FDC -999 iO GR,CHL -999 ,,~9.9 258 ,D!L ,FDC ,FOC CFTC,CNL ~99g,250 TNRA, ':99:'9~ CNL 38 250 CALI,FDC PAGE{ -999,250 -999,250 3 740 -999 250 -999 -999 4 126 -,,, tloo -999 -999 250 :999 -999 ;0 959 "'999 LIS Tame Veri~lcattoD T.j. StlD~ Schlumber(~er AlasKa Co,nDt]tinq Center DF:PT, 6900.000 TENS.DIL SP.DIb ~LD.DIL 2.~56 DRNO.FDC DPHI,FDC '999,250 G~,FDC '999.250 ~ENS'CNG R~'NR,CNL '999'250 RCFT,CNL CNTC.CNb '999,~5t) GR,CNL DFpT, 6800 IL~,DII, 2 DPH~.PDC -999 GR,FDC -999 RTNR.CN'L -999 C~TC.C~L -999 000 TE~S,DIL 871 SP DIG 250 ORMO FDC 50 TENS CNG 50 RCFT CNb ,250 GR,CNL DfPT ! LD G~ 700,000 Tf, NS,DIL DIL 2,845 SP.DIb FDC 999,250 DRHO,FDC FDC -999' ~50 TENS.CI~5 iCNL -999,250 GR.CNL DFPT D~H ! FDC CNL 660O 2 -999 -999 17:(74 D~PT, LD'DIL DP ,FDC RT~P,CNb 2 5020.0(,0 SFI,U.OYL -50'156 GR.DIb -999j250 RHOB.FDC -999,250 NPHI'CNL -999,250 RCNT,C~L -999,250 TENS,CM~ 4864 000 -56 281 -999 -999 250 -999 -999 50 -52, 6 999, 0 999. 50 '999.250 4944 '48 '99 '999 '999 000 50 F)RHO~FDC TEN$,CNL -999 RCFT~C~ '999 ,250 GR,CNL -999 000 TENS 954 SP DRHO TM~$ 50 ~CFT 50 GR D I L FDC CNL DFPT, 6400,~00 TENS ]LD,DI'L -99~'- 41 DPHI:.'FDC 4250 DRHO _GR,~C '999;250 RTN~,CML '999'250 CNTC,CNL '999,250 GR FDC CN.L TE~JS, DI b SP, DIL TENS;CML ~C C GR,CNL GR'D~L ~HOB,FDC NP~I,CNG RCNT,CNL TE~S;CHL SFLU,DIL GR RHOB FDC NPHI RCNT Nb TENS,CHG 00 SFLU,OI~ 56 GR;DIL 250 RHOB,FDC 250 NPHI~CNb 250 RCNT,CND 250 TENS~CHb 000 SFbU 50 RHOB FDC 50 50 CN:G 250 TENS.CHL SF~U,DIG RHOB,FDC NPHI,CNb 4484 000 SFbU DIG -99~ CI..L '99 CNb '999 250 TENS CHh -4~;2:50 .:GR,jDI5 "999~ '999'~0 2~ 96. -999. -999, -999, -999, 999. '999' '999, '999 * 2 '999. '999, '999. '999. 656 625 250 250 ~50 250 '999 -999 -999 -999 89 -999 -999 -999 '999 PAGE~ 10 712 25O 25O 25O 25O 692 81:{ 250 250 IL~ TENS CIbI CFTC OR TFN$ CFTC TENS CaLl TNRA CFTC GR CFTC .DIL ,FDC ,FDC ,CNL ,CNI, ,CHL FDC FDC ,CN~ ,CH[ FDC FDC C~5 CHL FDC, FDC CNL ,C.NI~ CHL 2,778 999,250 999'250 999,250 . 2,774 .999;2~0 999,250 -999,250 -999~250 -999 250 GR,C~b 674 ! b M, D'! ; ~ r:D,C 250 TNRA,CNL 250 CFTC; 250 GR,CML :125 TENS ~:F:DC 250 ~A~I,FDC ~0 25 CFIC -999 2:50 Schlumberger Alaska Comuutino Center 2R-DEC-1988 17:04 PAGE~ it DEPT, TLD.DIL DPHT.FDC G~,FPC ~TNR.C~b CNTC,CML DFPT, DPM?,FDC GR,~DC C~TC,CML DEP~, ~LD.DIL DPNI,FDC GP.FDC RTN~,CI~b CNTC.CNL DFPT ILD DIL DPH! FDC CNL CNTC C~L DPHI,FDC Ct~b DEPT C ~;C ~ D'FPT. ILD,DIL DPHT':FDC G~,FDC 'g' bib 6200,000 r.:~$, 3.586 SP.PlL '999.250 DRHO,FDC -999.250 ?E~S,C~'L -999,250 RCFT,CNL -999,250 GR,CNL 6100.000 TENS.DIL 4,566 SP,DIL -999.250 tJRHO,FDC -999,250 TEN$.CNL -999,250 RCFT.CNL -999,250 GR.CNL 6000 -999 -999 -999 -999 5900 4 23 74 3 1925 5800 4 5700 1802 ~ 3 2:159 5500 42~8 -46 -999 -999 -999 -999 Ot/O SFLO,DIL 406 GR.DXL 50 RhOB,FDC 50 ~PHI,CNL 250 RCN'~,CNL 250 TENS,CML 44~2 000 -52 250 -999 25O -999 -999 ~00 -999 250 000 TENS.OIL 4260 072 SP.DIL -56 250 DRMO,FDC -999 250 TENS,CN£. -999 250 RCFT,CNL -999 250 GR.CNb '999 000 TENS.DIb ]7.60 84 SP,DIL -4~ 1'7 DRHO+FDC 88 *EN$,ChL 3760 80 RCFTiCNL 5]4 036 GR.CNb 74 00o 357 323 563 TE~S,OIL [)R~O,FDC TEN$~CNL RCFT,C~L GR.CNb TMNS,DTL SP,DIb DR~O,FDC TE~$.,CN~ RCFT,CML GR,CNL TENS,OIL SP~DIb O~O,FDC TENS~CNb RCFT,C~L GR~C~b ,000 ,730 &464 ,531 .918 ,000 ,796 ,141 ,313 ,686 ,373 .000 ,384' '406 ,750 SFLU.D~L GR,DIL RHOB.FOC NPHI,CNL ~CNT,CNL ~ENS.CH~ O0 g SF ,~Ib 94 GR,DIL NPHI,C~b 250 RCN ~50 ?E~I L ;CHL 000 SFLO 719 OR 017 RHOB RC'NT 188 TEN8 DIL, FDC CHL 3944,000 "48~094 0,004 RHOB 3944,000 NP'HI 6~1,893 RCNT ,563 CNL CML 37O4 000 8FLU, ~313 GR~ ,004 ~HOB. 49 31 tENS, D :I b 3560,000 -,49,344 CNL CML 3504,000 '49,844 GR,DIL 0,017 RHOB,FOC 3504,0P0 555,471 RCNT~CN~ 9O -999 -999 -999 -999 229 313 250 250 250 250 TE~S FDC CALl FDC TNRA CNL CFTC CNL GR CHL 4 96 -999 ..999 -999 -999 225 250 ~50 25O ENS,FDC ALI;FOC TNRA,CNL CFTC.CNL GR.CHL -999 -999 -999 -999 758 625 0 TENS CA CFTC FDC 4,034 71,188 ..~2'55 999.250 932 .IL~,DIL 5 ' 2 CAbI,.FDC 920 CFTC,CNL ~50 GR~CHL 2,338 46,453 26 i 048 999Z250 IL~ GR CHL 2 096 999 4.97:9 247 ClbI;FD'C 938 . _3,441 999,250 :999~250 .999,250 999;250 :999, "999,250 "" '999 '99:9 4, 3760, 999'250 4 1t'5. AlaSKa Compurlnq Center C,~;TC o Ct,: [,,, 2212 o 74 q Ga o Ch DFPT, 5400,0()0 !LP,PtL 3,643 SP,DIL D¢[,iT,FDC -gq9°250 ~HO,FDC G~.FDC -~99.25L) PTNR.CNL -999.250 C[TC.C~L -999,250 DFP~", 5300,000 'tENS,OIL ILB.DIt. 3.879 SP.DI[, RTNR,CNL 999 250 RCFT,CND C~TC.CNL :999,250' GR;CNL. DFPT. 5200.000 TENS,OIL, ILD,DIL 5,~94 SP,DIL DPHT.FDC '999.250 DRHO.FDC GR,FDC '999,250 TEN$,CNL ~TN~,CN[. '999,250 RCFT;CNb C~:TC,CNL '999.250 GR,CNL LD'DIL 999"250 SP;DIL DPH!,FDC '999' 50 DRHO G~,FDC -999~50 ,FDC T~NS;C'NL R?~R;C~L -999~250 RCF?~CNb CNTC~C~L -999~250 GR.CNL DFP?. ,DIS .FDC GR,FDC 999,250 SP,I)IL -999,~50 TENS,CN~ '999,250 RCFT;CNb -999,250 GR,CNL '~OlL FD.C C 1'; b 4900,000 -999;2:50 SP.DIL -999'250 DRHO,FDC '999~50 T~N$ CNL '999.250 '999;~50 ,CNL DFPT. GR CNTC DIL FDC FDC 99 250 -999 250 T~ .ENS r)R HO RC~'T GR D I b F DC N b CN L D~PT, ;LD,DIb DPHI,FDC .4700,000 999;250 '999,250 -999 ~ 250 TENS, DRHO, FDC CNL 28-r~EC-I ~88 17:04 -47,031 GR,OIL '999.250 ~HO~.FOC '999.250 NPHI,CN5 '999,250 RCNT,CN[ '999,250 TENS,CHh 3614 '46 '999 "999 "999 "999 -999. 86 '999 '999 '999 '999. 250 250 250 000 SFLU,Dlfi 3 029 93~ GR,OI~ 106 063 ~ RHOB.FDC -999 250 NPHI,CN5 -999 250 250 RC~T,CN~ -999 250 ~50 TEN$;CHL -999 ~50 3820.000 SFLU -46,7b0 GR -999.~50 RHOB -999,~50 NPHI '999, 50 RCNT -999,250 TENS 999,250 SFLU 999,~50 GR '999,2~0 RHOB -999;2 0 NP:H! ~999,2~0 RCN~, DIG FDC CN~ CHh FDC CN h -999 ~50 S:FBU,DI5 :999 50 GR,OI~ 999 50 ~HOB,FDC NPHI,CNb ~CNT,CNb -999~250 TEM$,CHb OI& CHh -999 -999 . J -99:9 ~50 S'FLL TEN ~50 5:0 -999 250 5 . 76 999 -999 -999 -999 -999 -999 -999 -999 ~999 3354 -999 3210 ~999, '.999 ~ ~'999, '999, PAGE: 12 O I 'b CNL CNb ~ CHh "999, ' SFbU,OIL ~999' "~50 RBO ,FDC .999. !50 NPH~,CMG 849 813 25O S0 250 50 50 IL~,DIL IENS,FDC CALI'FDC TNRA'CNL CrlC.CNb GR,CHL ILN,DIL TEN$,FDC CALI,FDC TNRA,CNL GR HL TENS,,FDC C~LI,FDC TNRA,CNL CFTC,CNL GR,CML CALl TNR~ CNL 250 Ib~,'Olh 250 TEN$,FDC 250 TNRA,CNB ~50 CFTC~CNb 000 GR~CMb '999,250 3 454 -999 250 "999 2~0 :9,9 ,o -999 250 3,705 '999,250 -999, 999, 0 -999, 0 '999 50 25 C~:C CNL 0:00: !!G!R CHL 250 ILM,DIL 250 TEN$,FDC 2~0, ?NRA'CNL ,000 250 I~,DIL 9i50 TENS,FDC 250 CABI,FDC ~50 TNRA,CNL 999,2§0 9 9~ . ' 44 Tare Verification l, lstin~ Schlumberger AlasKa Computing Center RTNR,Ct,~[, ..... -999.250 Rcm~.CNG CNTC,C~L -999,250 GR,C{~L DEPT, 4600,000 TENS,DIL YL~.mI}. -999.250 { SP~DIL GP,FDC -9~9 250 TEN$'CNL RTN~.CN[, -999 25(] RCFT,CNL C~tTC.CNL -9~9 250 GR.CNL DEPT. 4500.000 ?EN$.DIL ILD,DIL -999,250 SP OIL DPM?.FDC -999.~50 DRWO:FDC G~,FDC -999,~50 TE~S,CNL RTN~,CNL '999.250 ~CFT.CML CNTC.CNL '999,250 GR.CNL DEPT, 4400 ]LD.~IL '999 DP~],FDC '999 GR.FDC '999 RTNR,CNL '999 C~TC.CNL -999 000 TENS,OIL 250 SP.DIL 250 DR~O,FDC 250 TENS.CNL 50 RCFT,C~b DEPT CNTC · 4300 OIL '999 FDC -999 FDC -999 CNL -999 CML -999 0o0 TENS 25O SP 25O [)RMO 250 T~N$ 250 GR ~b CN r)IL 9 ~oC -999 FDC '999 g N [, 000 250 250 250 SP O~HO TENS RCFT GR FDC CNb C~ h DEPT CNTC D CN L 4100 -999 000 ~0 250 Sp DRHO RCFT GR ,Din ;FVC 40O0 -999 -999 -999 -999 -999 000 250 50 50 SP DRH. O RCFT FDC %.. , . ~ 17:04 -999.250 RCNT C~L -999,250 TEN$'CHL -999,250 SFbU,OI~ -999,250 GR,DTb -999,250 ~HO!!FDC -999'250 NPM CML -999,250 RCN CMb -999~50 TEN$.C~L -999,250 -999,250 GR,OIb -999.250 -999 ~50 NPH~,CN~ -999 50 RCN .CNL -999 250 TEN$,CHL -999,250 =999.250 -999,250 -999,250 -999. SFLU RHOB FDC TENS 250 SFLU.DIb 50 G 50 .~FDC -999 250 '999 ~50 RCNT~C~L -999 ~50 TENS,CHh :999 5 ' ' · ,250 $~LiJ,DIL 9'9:9~0 GR,DI~ -999'250 ~HOB,FDC .'999-;~50 NPHI~CN5 ~999,2~0 RCNT,CNb ~990:;~50 T~:NS~CML '999 250 8FLU DI.5 999 250 "~'' ~ 999'250 RHO~iFDC '999,250 RCNT,C,.L '999~50 '999 250 CFTC,CNL 3164:000 GP.CHL -999 -999 -999 -999 -999 3054 50 Ib~,Dlb ~50 TMNS'FDC 250 CAbI,FDC 250 TNRA,CNL 250 CFTC,CNL 000 G~,CHL -999.250 -999 250 -999 250 -999 250 -999 250 2980 000 TENS FDC CAb! FDC CFTC CNL G~ CHh -999,250 -999.250 -999,~50 -999. 50 -999,~50 3050.000 TENS CALl FDC FDC CNL CNL -999 250 2'50 2954 000 ILM,DIL IEN$,FD~ C~LX;FD.. TNR~,CNL CFT:CiCNb GR,CHL -999,250 ~999~250 ~999,250 CALI,FDC .999'250 CFTC,CNL 2894~000 GR~CHL -9:99.250 Ib~,DIb -999;~50 TEN$'FOC ~99!9~250 C~LX~FDC -999.;250 T~RA.,CNL ':999,25'0 CFTC~CNL 2880.00C CNL CHL PAGEI '999,250 62,?19 -999 -999 '999,25'0 ~3;063 -999 54 -999 ~999 2'~0 *,999 62¸ 13 LIS Tace VeriIication Listfr'~o Schlumberqer AlasKa Computinq Center D F P'T. 3900.00 O T E hi S. ~ I L ILD.D![. -999. 256 SF.OIL F~PH I, F{.)~ -999,250 DRBO,FDC GR.FDC -999.250 TENS.CNb RT~7~.C~L -999.250 ~CFT'CNL CNTC, CNL -999. 250 GR.CNL DEPT, 3800,000 TEN$,DIL ?LD,mlI, '999,250 SP,DIL DPHI,FDC '999 250 DRMO,FDC G~.FDC -999 250 TE~S,CNL RTN~'C~i~L~ -999 250 RCFT,CNL C~TC,CNL -999 250 GR,C~L O~P~. 3700 lb~,DIb '999 DPH~,FDC -999 _?G~.FDC -999 C TC.CNL -999 000 TENS.DIL 250 SP.DIL 250 DRMO,F~C 250 TENS,CNL 250 RCFT.CNL 250 GR.CNL DEPT DPH! ~600 DIb -999 FDC -999 FDC -999 N L 000 TENS 250 SP 50 t)RBO 50 TENS 25O ~CFT 250 ~R FDC CNL CNL CN L ,DIL .FDC G~,FDC CMTC,CNb 3500, '999 ~999 '999 000 TENS SP DRMO ~ 0 25 TE~$ 250 RC~T 250 GE, OIL DIL FDC CNL C ~ L CNL C~b ~400 999 -999 -999 -999 -999 ,000 .250 .250 .250 250 :2'50 TENS sP I L FDC C~L CNL FDC G~ F~C CNTC,C.N[, 3300 -999 -999 -999 -999 -999 .000 ,2~0 ,250 .250 TE~N$., RCFT, FDC CNL C~L OEPT, DPMI,FDC C~-TC,CNL -999~ -999 -999 0 O0 25O 250 250 25O 25O TENS DRHO TENS DC ~L CNL CN L, 28-r)Ec-1988 .17:04 -q99.250 8FI, U,D!L -999'250 GR,DIb -99~1250 RHOB.FDC '999,~50 '999. 50 ~CNT.C~[. '999.250 TEN6,CH~ -999 250 Sf"LU,OIL -999 250 GR'DIb '999 250 RHOB,,FDC -999 250 NPHI,CNb -999,250 RCNT,CNb -999.250 TENS'CHL -999 -999 -999 -999 -999 -999 -099.250 -999,250 -999.250 -999.250 -999.~50 2780.000 -999 -999 -999 -999 -999 2740 250 SFLU.DIL '999 250 GR,DXL -999 250 RHOB,FDC -999 ~0 NP,I,CN~ -999 0 RCNT.CNL -999 250 TEN~.CHL 2620 -999,250 SFLU,DIL -999;250 GR,DIL '999,~50 RHO ,FDC '999~ 50 NPH~,CNL Nb 'q99~ TENS. -999,250 SFLU -999,250 OR -999;250 ;2:0 -999,250 TENS C N ~ C N P IL ~D C'NL GR,DIb NPHI,CNL ~CNT~CNL TEN$:,CHL .'999 -99:9 -999 PAGe]", 14 -999 250 -999, ~0 SFbU '99:9,~ ,OIh 50 5O 0 o0o IL~ TENS FDC CALI FDC TNR~ CNL g~ HL 250 250 250 000 IL~ TEN FDC CALX FDC TNNA CFTC ~NL GR,CHL 250 I, LP 250 TENS 250 CALI 250 TNRA 250 CFTC 000 GR FDC CNL CfiL~ -999 2510 ~999,250 999, '999, 41,$94 999 9~ -999 iQ 60 -99~ 250 -9 -9 47, $6 -:999: "999 2430 CN CH[ [:IS Ta~e Verif~catlo~ Schlomber~er AlasKa Computino Center DEPT. 3.100,,000 TENS 99 25O GP DC 999.250 TENS C~TC ~L 9o9,250 DFPT, 3000.000 TENS, ILD.DIL -999 250 DPHT,FDC -999 250 DRHO. GR,FDC -999 250 TENS, RTN~,CNL -999 250 RCFT. CNTC.CNL '999 250 GR, DEPT 2900 0(')0 1'gMS, ILD:DIL '999 250 DPHI,FDC '~99 250 DRHO, G~,FDC -999 250 TENS~ RTNR C~L -999,250 RCFT, CNTC' ~'~ .C.~L '999.250 D~PT. 2800 I~D,DIL '999 DPH~.FDC -999 G~,FDC -999 RTN~CNL -999 CNTC,CNL -999 000 TENS 50 SP 50 DRHO 250 TENS 250 RCFT 250 GR D~PT, 2'700,000 TEN& TLD~DTL '999;250 SP .:.9, 'N DPHI,FDC -99 250 DRHO G~FDC -999~250 TE .... S RTN~,C~' -999,250 RCFT CNTC.CN~ 9, -99 ~50 GR DFPT DFH? FDC CNTC.CNI, '.DiL FDC RTNR CNL CNTC CNb 2600 -999 2500 -999 -999 -9.99 -999 -999 2400 :999 999 -999 DF. PT . DPHT. GR. 000 50 50 RCFT, 25o ,000 TENS, ;2'50 ,250 TEN~' ,000 TEN8 ,250 ;250 Dado 5O ~CFT .DI.L .DIL FDC CNb CNb FDC CNL CNL OIL DI L FDC C N L CML DIL FDC CNL CNL .DIL · OIL DI h ~IL ~ DC CNL DI b DIL FDC CNL D I b DC CML 28-DFC-1 9"8 17:04 -999,250 SFLU,DIL -999.250 GR,DIL -999,250 RHOB.FDC -999.250 NPHI.CNL -999.250 RCNT.CNL '999.~50 TENS.CML -999 250 -999 250 -999 250 -999 250 -999 ~50 -999 250 ~' GR,DIL RHOO.FDC NPHI,CNh RCNT,CNL TENS,CH~ '999.250 SFLU,DIL '999.~50 GR,DIL -999,250 RHOB,FDC -999.~50 NPHI,CN5 -999,~50 RCNT.CN~ '999~ 50 TENS.CHh '9.99,250 SFLU.DIb -999'250 GR,DI~ '99:9,250 RHOB,,FDC '999,250 NPH.I,CN~ -999,250 RCNT~CNL -999,250 TENS,CML -999 250 EFSU,DIb -999 250 OR;Olb ~GB,~DC HIiCNL -999 ?~50 RCNT,CNh -ggg 50 TE~$,CHb ,250 ,250 ~NOB~FOC ,250 NP.Hi,~NG '~99'250 TENS*CHh '999,250 SFb~.OIb ,999'250 ~HOB.FDC 999,~50 NPHI,CNL -999,~50 T~NS.CHb PAGE~ i5 -999 250 '999i250 -999 250 -999,~50 -999,250 2~70.000 i99,250 99, 0 999,250 '999,250 2~90.000 -999.250 -999,250 -999 259 -999 25 -999 250 2184 000 -999 250 250 25O 2204 000 IL~.DIL TENS.FDC CALI.FDC TNRA.CNL CFTC.CNb GR'CHL Ib~,Dlb ¢~LI, C~TC NL GR,CML ILg,~IL TENS, DC CALI,FDC TNR~.CNL CFTC.CNL GP'CNL IL~,DIL TE.NS,FDC CALI,FDC TNRA.CNL CFTC;CNb GR,CHL '999,250 :999.2So 999,~$0 -999~250 -999'250 41;594 -999,250 -999, -999, 56.375 '999, -999, -9'99 35 8!3 -999 250 IL,~ DI5 2100 ',999 ~'999 000 GR CHh .! *999 '999 ':99:9 25O CFTC 000 250 250 250 C 250 C:F'I'C ¢ C~L -99'9 LIS Tav. e ver~ticatlon L1stfv,~ Schlumberger AlasKa Compt]tinO Center C~TC , C ;~a l, -9.09 . 250 C,R . CN!, DEPT, 2300.000 TEN$,DIL DPH?.FOC 09,250 ORHO.FDC GR,FDC -999.250 TE~S.CNL RT~.CNL -999,250 RCFT~CNL CNTC,CNL -999,250 GR.C~L ILD:DIL -909 250 $ DFHI,FOC -999 250 DRHO,FDC G~.FDC -999 250 TENS.CNb RTN~,C~L -999,250 RCFT,C~L CNTC.CN[. -999.250 GR.CNL DMPT. 2100 ILD,OIL -999 DPMI,FDC -999 R..NR,FDC -999 -TGR.cNL -999 'N CNL -999 C. TC, OEPT YbD ~DC Chb CNTC CNL OIL FDC C~b D~PT C~L C~TC.C~L 2000 -999 -999 -999 -999 ~999 t900 -999 -999 -999 I700 -999 ·-999 -999 '999 -999 ~999 ..999 -999 000 5O ,~50 , 50 ,250 ,000 ;250 ,250 ,250 i250 .000 ,250 ;250 ~50 i25.0 ,250 000 25 u 5O ,000 ,250 ,250 ,000 250 50 TENS,DIL SP DRHO FDC TENS CNL RCFT CNL GR,CNL TEN$,DIL SP,DIL DRMO,FDC RCFT'CNL GR.CNL SP,DIL DRMO;FDC TEN$,CNL ~CFT GR,C~Ib TENS DIL SP [DC C Nh TENS DIiL DRHO FDC C~b GR C~b TE~ ~, DI 6 MP.DIL D"'' FDC · RHO, 28-0EC-!988 17104 -990.250 -999.250 SFLU,DIL '999,250 -999.250 RHOB.FDC -999,~50 NPHI,CN5 -999. 50 RCNT.CNL -999,250 TENS,CHL =999,250 SFLU,DI6 -999.250 GR,OXL -999 250 RHO.B,FDC '999 250 NPHI.CNL -999 250 RCNT.CN~ -999 250 TENSeCML -999,250 SFI,U,DIL ~999,250 GR,OIL 999,~50 RHOB.FDC '999,250 NPHI,CN~ -999.250 TENS,CHh -999,250 SFLO,DIL -999,250 -999,250 RHOB,FDC 25O ~PHI 2999, ,999,2$0 RC~T,CNL 999~50 -999, GR~DI~ '999 RHOB FDC ' . 999,:2 0 ~CNT;CNL -999'2§0 TE~S,CHL -999,2~0 SF~U,OIb -999~i'0 GR~DIb -999,250 RMO~'FDC -999;.~5.0 N'PHi;CNh -999,250 RCNT;CNb -999"~50 ?ENS~CML ':999 250 SFLO,OIb '999 2~ RHO'B~FDC- -999 2~0 · NPEI,CNh '999 2..·0 RCNT;CNL -999, 250 TENS'CHh 999,2 50 SFLU,DI6 99:9; 250 GR ;l) l 6 2999,250 RHOB,FDC 999-.250 NPHI~CNL -999.250 -999 250 -999:250 -999'250 -999.250 2064.000 -999 250 -999 250 -999 250 -999 250 -999 250 2050 000 -999 250 99 250 99 250 2015 000 ~999.250 999.250 -999,250 -999;250 -999,250 2025;000 II~.D1L tE~S,FDC CALI,FDC TNRA,CNL CFTC;CNb GR,CHL IL~ DXL TE~S FDC CAL! FDC TNRA CNL CFtC CmL GR CHL Ib~ DIL TENS FDC CALI FDC TNRA CNL CFTC CNL GR CHL iL~ DIL TENS FDC TNR~ '999, ~9i99~ 0 -999,25 C~TC ig5'B'~O00 "999,~50 I.L~,DIL ~999~250 TENS' 999,250 ~999~250CF~C'~CNL 1945,000 GR,C~L :999,250 ILg,DIb 999,250 CA~,I'FDC -.999i250 TNRA,CNL 51.250 999,250 999,250 999,250 999,250 999~250 34;250 -999 250 -999 250 -999 '999,2'~0 '999, ? 8.1 -999 250 LIS Tare Verification LiStl, r~q Schlumber~er Alaska Computina CeDteI' RT !,~P. C~,~ [., -900,250 RCFT.C~L CNTC.CNL -999.250 GR.CNL DFPT, 1500.000 TENS.DIL ILD,DIL '999.250 .SP.DI5 DPHI.WDC -999.250 DRHO,FDC G~.FDC -999.2~0 TEN$.CNL RT~RjCNL -999.250 RCF'T.CN5 CNTC.CN[. -999'250 GR.CNL DFPT G~ CNTC . ~400 DIG -999 FDC -999 FDC -999 CNL -999 CNG -999 .000 TE~S.D~L 250 ~P,DI6 250 DRHO;FDC 250 TE~$.CNt 250 RCFT'CNL 250 GR.CNL DKPT, X300.O00 TEN$.DIb TLD,DIL -999.~50 SP~DIL DPHI,FDC -999,250 DRHO FDC G~,FDC -999.~50 TE~S CNL RTN~,CNL -999,250 REFT CNL CNT..C~[,C -999~250 GR CNL DFPT. CF~TC DIL FDC 1200 -999 -999 -999 '999 -999 28-DEC-19~8 17:04 DPHI G RTNR ~999,250 ~CNT,C~L 999,250 TENS,CHD -999 250 -999 250 -999 0 -999"~b0 -999~250 SFLU,DIL GR,DIL RHOB,FDC ~PHI.CNL TENS HL '999.~0 0 '999,~ 0 '999, ~999,250 '999.2'50 '999,250 GR,~Ih RHOB. DC NPHI,CNb RC~T,~6 TENS,.HL -999 -999 -999 -999 *999 -999 250 ~R I6 ~0 RHO~.FDC ' O NPHI'CN6 ,. CH6 000 TEaS.Df5 -999 250 BFLU,OIL 250 SP,[!I6 -999 GR,D~6 250 DRHO~DC -999 RMOB;F C TEN~,C~'5 NPHI,CNL 250 GR,CNL -999,250 TENS;CHh 1000.OO0 '999,250 '999~250 '999*250 DFPT. IhD,DI6 D'PH?'FDC CNTC,CNL iLD' .~9.4,000 .~I1, 99~250 DPHI,FDC ~999.250 G~,FDC -999,250 c~Te.c~t -~,25o mE~$ SP DRHO GR fDC CN L TENS SP DRHO ~ L C N 16 -999 0 RHOB"FDC -999 250 RCN~*CN6 -999 ~:5. O T~$:~CHL '999,250 SFLO,DIb -999~2~0 GR,DI~ '999,2~0 999;250 IEN.$.CML -999,2~0 SFLU,DI6 -999,250 RHOB,FDC 1999,2~0 RCN~;CNL 999;25'0 TE~:$~CHb PAG~I t7 -999.250 C?TC,CNI, IB70.O00 GR,CHL -999 -999 -999 -999 -999 1830 250 250 50 000 IbM TENS FDC CAbI FDC TNRA CNL CFTC CNL GR CHh -999. -999, -999; -999, -999; 1770. 250 250 250 250 000 IL~,DIL TE~S,FDC CALI,FDC ~NRA,CN~ CFTC.CNL GR,CHL -999 -999 -999 -999 -999 1700 250 250 250 50 TEN~ FDC CA6I FDC TNRA CFIC -999 1620 250 ' 0 25 250 000 IL~,DIL GR, CHL -999,250 IL~, '999~250 TENS, -999'25:0 CALl 25 CFTC :ooo o.: ,'9'99 1480 20 TE~$,FDC ~:50CALI;FDC '999,250 XL~,DIL -999,250 ?ENS~FDC -999,250 CALI,FDC ,250 CFTC;CNL ~000 g~,C~ '999,2'30 ,38 34¸ ( ( Tame Verification Iist~nm ~hlumberger AlasKa Computlnq (:enter FILF NAME : EDIT ,001 SFRVICE : FblC ~ERSIO~ : OUlA02 D~TF : MAX EEC SIZE : 1096 FILF TYPE : LO FILE NA~E ~ EDIT ,002 SERVICE ~ wLIC VERSION : O01A02 D~TF ~AX ~EC SIZE ~ 1096 FILF TYPE : LO LAST FILE 28-DEC-19~9 I7:04 PAGE: 18 ***** TMIM DATA HAS NOT BEEN DEPTB SHIFTED * SCHL!:I~BERGffR LOGS INCLUDED W!:r~ T.MIS FILE (EDIT,O02)i * <SEE FILE EDIT,O01 FOR 6" SA~FL~D DIh/FDC/CaL/GR D * * F[]R~ATI~.,N DENoITY CO~PENS~T~;D * PlRS~ TC hAST READING: TO 9589,7' * COMPENSAT~;D NEt. IRON * FIR,~T TO baST READING:t ~045!,2' TABLE TYPE TUNI VAL~ [')~EF! CN ARCO ALASKA INC, F~ KUPA~UK LIS TaCe ver,i~1catton Listinq Schlumberqer AlasKa Computinq Center 28-D~,~C-1988 17104. TY}~2.T VaLb DEF! ...................... .... ..............................................,,.,......................... 2Z ~9 W a~e~ NATI USA Nation STAT ALASgA State or Province COu~ NORTH SLOPE County TOWN 11~ Township R~N~ 9E Range ENGI G $ ~BER Engi e s Name SON 5~8730 Se~ ice order Number ~PIN 50-029 21881-00 APIv - Serial Number TYPE ~ CbRV D~PT TENS ~CFT FTC DEPTH CHaNNEl, NA~E Tension Density Porosity Delta tho BulR Density Tension C.AI, IB~A~ED IHERM .[, NEUTRON R~TIO RAW T'HER~AL ~!EUTRON RATIO Gam~na m,~wm,mm,~mem~m'm m . mmmmmmm~m~'~m~m~memmmmmmmmmmm ** D ' ~ECORD AT A FORMAT SPECI, FICAT[ON ** SET T'¥PE - 64ES ** TYPE REPR CODE V AL, L)E i 66 ~ 2 66 3 73 64 4 66 t 5 66 6 73 7 65 8 6~ 0,090 LIS TaPe VerlticatloD [.isti. nn SchlUmberger AlasKa Comuutinq Center 17:04 2O ,,mm ~m m, m, ,mm m .,{m # ,m m m ,m M, m mmm m wm mm mm m m m m # m m m m m m TYPE ~ ,PR CUDE VALUE 9 65 FT ~! 66 17 14 65 FT 15 66 68 16 66 ~ 0 66 1 NAMF DFPT T~N$ FDH LB DPHI FD~ DR~O FD~ G/C3 R~O~ FDR G/C3 C~LI PDH Ih) G~ FDH (IAPI PHI CNH PU T~RA CNH RiN~ ** SET TYPE - CHAN SEDV UNIT SERVICE AP1 AP1 APl AP1 FILE NUMB NUMU SIZE REPR PROCESS IO ORDER ) LOG TYPE CLASS MOD NUMB SAMP EL~ CODE (HEX) '''''"''"';"'"'''''''"''''''''"'"'"''''''"''i''''i"'''X'""""''"';;''''''''"F? 48730 O0 000 O0 0 2 68 00000000 01 O 2 1 I 4 68 0000000000 54873(; 07 548730 07 3 0 0 548 0 548730 07 548730 07 3 548730 07 310 54,730 07 310 48730 07 ~I0 48730 07 0 5~8730 07 548730 07 5487]0 O~ lit) 548730 07 0000000000 000000 000 0000008000 0000000000 000000'0000 0000000000 0000000000 ** DATA D~PT, RHO'B,FDH C~T'CNH HOBPH~' ,CNH NDHI,CN~ RCN~,CNh TWN~ FDH CALI;~DH TNRA,CN~ 1840 10400,000 TENS,FDH 2 ~,092 C.G , 1775,[38 ~5~C C~H i030~,000 TENS 2,506 CALl 48, 7 T~RA 04 !649, 2 ..F~C CNh 000 DPHi,FDH 012 GR ;FDH 2~8 R NR,CNH 385 CNTC,CNH 7708 ,000 DPHI .~ lU2 G~ 310 RTNR 568 030 CN~C'T" FDH F D H CNH CNH 760~,000 ,t80 3,8~5 49t,549 TNR, CN H I~:842 DRHO,F'DH 000 TEN$~CNH 3,442 ~CFT,CNH i881,:2875 33,808 DRHO,FDH ~9 ,'692 RCF ~C~ 18832770 ~0~ 000 875 ~CF?,cNH ~50 GR~CNH 770 , SO~, t29, 0-99 SChlu~berqer AlasKa Computin~ <;enter 28-D~C-~988 21 D~PT, 10200,¢)0~ . E~S,FDh R"OB.FDM 2,553 CALI,FD~ NPHI.CNH 42,431 TNRA'CN~t RC~q~.C~'H 17~6.53! CFTC;CN~I DFPT, 9900.000 TENS,FDH RHOB.FDH 2.393 CALI,FDH NPHT,C~H 33,915 ~NRA,CNH RC~T,CNH 2290,3~8 CFTC,CNH 000 750 448 EPT, NPHI,CNH END OF DATA TENS FDH CALl FDH T~A CNH CFTC C~ T~ .~ ENS.FDH CAL!, FDh TNRA,CNH Cf'TC,CN~{ TENS ChbI TNRA CFTC TENS,FDM CFTC .CNH 7128,0{:0 DPHI,FDH 9,9~4 GR,FDH 6772,000 DPHI.FOH 9,563 GR,FDH 3.~65 RTNR.CNH 700,0~4 CNTC,CNM 7152,000 DPRI g,086 GR 256 RTNR 60 '0~2 CNTC FDH CN~ CNH 6820,000 DPHI,FDH 3, 0 PTNR,C)JH 764.960 CNTC,CNh 7040,000 DPHI,FDH 9, I41 GR,FDH 3,270 RT~R,CNH 698~897 CNTC,CNH 6664,000 DPHI.FDH 9,609 GR FDH ~:620 RTNR 48 7~9 CNTC CNH 700~,000 DPHI,FDH ,658 7~24 000 DPH! FD~ 477 5,869 DRhO,FDH 103,438 TE~S,CNN 3,]19 RCFT,C~ 1853, 09 GR,CNH 14 359 DRHO.FDH 89 313 TE~$,C~H 3 533 PCFT.CNH 2~54'600 GR.CNH 44,030 DRHO cFDH 3' ~t) TENS: N~ 2027.~02 OR'C~H 77.~88 let S,CNH 3. I1 RCFT,CNH 2261,825 GR,CNH i g62 DRMO.FDH ~ ,' O0 TENS, ,714 RCFT,CNH 22t~.227 17 438 DRHO,FDH TEN ,CNH , ~CFT,C~H 1743,207 GR,CNH !5,463 DRi{O,FDH 1. i'6,438 TEN$~CNH ,.947 RCf'T,CNH ,909 G~,CNH 17,690 ORHO FDH 12~, 1762.573 OR CNH 0,093 9t28.000 'OEO09 67~,00 569.313 O, 0.018 6820'000 0 0:4:8. 1! .000 ,002 ScblU~>erqer AlasKa Co~,~utlng Ce~teI PAGE: ORIGI~ : CO~EN'I~ : [,IS TAPE, ARCO KUPARU~ 2Z-2~, API#50-029-2~881 **** REEL TRAt!,ER **** SERVICE NA~E : EDI'~ CONTINUATION # : P~EVI~(J8 REEL : COMMENT ~ LAS TAPE, ~RCO K{iPARb~ !
