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DATA.VG017 M.K.BENDER To: AOGCC RECEIVED Makana Bender 333 West 7th Avenue Suite 100 JUN 13 2017 Anchorage, Alaska 99501 (907) 793-1225 AOGCC 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 Anchorage, AK 99518 Fax: (907) 245-8952 WOOD .!UN 2 2 t01?, 1) Caliper Report 30-May-17 3G-06 1 Report /CD 50-103-20130-00 2) Signed : m,94,,,,,4,44.4.) 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:\AchivesNasteTemplateFi les\Templates\Di stribution\Transmittals heets\ConocoPhillips_Transm it.docx RECEIVED • 2$292, 1116 L JUN 13 2017 Memory Multi-Finger Caliper AOGCC Log Results Summary Company: ConocoPhillips Alaska, Inc. Well: 3G-06 Log Date: May 30, 2017 Field: Kuparuk Log No.: 12783 State: Alaska Run No.: 1 API No. 50-103-20130-00 Pipe Description: 3.5 inch 9.3 lb. L-80 ABM EUE Top Log Interval: Surface Pipe Use: Tubing Bottom Log Interval: 7,408 Ft. (MD) Pipe Description: 2.875 inch 6.5 lb. L-80 ABM EUE Top Log Interval: 7,408 Ft. (MD) Pipe Use: Tubing Bottom Log Interval: 7,431 Ft. (MD) Pipe Description: 7 inch 26 lb. J-55 Top Log Interval: 7,431 Ft. (MD) Pi•e Use: Casin• Bottom Lo• Interval: 7,599 Ft. MD Inspection Type : Corrosive and Mechanical Damage Inspection COMMENTS : This caliper data is correlated to the tubing tally dated March 1, 1997. This log was run to assess the condition of the tubing and casing with respect to internal corrosive and mechanical damage. The caliper recordings indicate the 3.5 inch and 2.875 inch tubing appear to be in good condition, with no significant wall penetrations, areas of cross-sectional wall loss or I.D. restrictions recorded. The body region analysis and joint tabulation data for the 3.5 inch and 2.875 inch tubing are combined. Although no significant I.D. restrictions were recorded throughout the tubing, the caliper recordings indicate cork-screwed tubing from —2,000 feet to 7,431 feet (end of tubing). The caliper recordings indicate the 7 inch casing logged appears to be in good condition with respect to internal corrosive and mechanical damage outside of the perforation intervals, with no significant wall penetrations or areas of cross-sectional wall loss recorded. Intermittent light deposits are recorded throughout the casing logged, restricting the I.D. to 5.86 inches in joint 1 (7,432 ft). No other significant I.D. restrictions are recorded throughout the casing logged. A graph illustrating the minimum recorded diameters on a joint-by-joint basis across the casing logged is included in this report. 3.5 INCH AND 2.875 INCH TUBING - MAXIMUM RECORDED WALL PENETRATIONS : No significant wall penetrations (> 18%) are recorded. 3.5 INCH AND 2.875 INCH TUBING - MAXIMUM RECORDED CROSS-SECTIONAL METAL LOSS : No significant areas of cross-sectional wall loss (> 5%) are recorded. 3.5 INCH AND 2.875 INCH TUBING - MAXIMUM RECORDED ID RESTRICTIONS : No significant I.D. restrictions are recorded. 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 • • 7 INCH CASING - MAXIMUM RECORDED WALL PENETRATIONS : Outside of the perforation intervals, no significant wall penetrations (> 15%) are recorded throughout the casing logged. 7 INCH CASING - MAXIMUM RECORDED CROSS-SECTIONAL METAL LOSS : Outside of the perforation intervals, no significant areas of cross-sectional wall loss (> 4%) are recorded throughout the casing logged. 7 INCH CASING - MAXIMUM RECORDED ID RESTRICTIONS : Description Minimum Recorded Diameter Deposits 5.86 in. 1 7,432 Ft. (MD) No other significant I.D. restrictions are recorded throughout the casing logged. R. Holden C. Waldrop J. Fama 'nalyst(s) 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 • • Correlation of Recorded Damage to Borehole Profile Pipe 1 3.5 in (54.8'-7,408.1') Well: 3G-06 Pipe 2 2.875 in (7,408.1'- 7,431.0') Field: Kuparuk Pipe 3 7. in (7,431.0'-7,599.0') Company: ConocoPhillips Alaska,Inc. Country: USA Survey Date: May 30, 2017 ■ Approx.Tool Deviation ■ Approx.Borehole Profile 1 58 a 25 790 4 50 I 11,535 75 2,288 GLM 1 100 3,049 0 L � t 125 3,809 GLM 2 a. cu 150 1 4,582 GLM 3 5,348 GLM 4 !! 6,129 GLM 5 225 6,918 GLM 6 NMI 1 7,431 6 7,561 0 50 100 Damage Profile(%wall)/Tool Deviation (degrees) Bottom of Survey=6 0 Perforations • • PDS Report Overview �,\ S Body Region Analysis Well: 3G-06 Survey Date: May 30,2017 Field: Kuparuk Tool Type: UW MFC 24 Ext. No.218183 Company: ConocoPhillips Alaska,Inc. Tool Size: 1.69 inches Country: USA No. of Fingers: 24 Analyst: C.Waldrop Pipe Nom.OD Weight Grade&Thread Nom.ID Top Depth Bottom Depth 3.5 in. 9.3 ppf L-80 ABM EUE 2.992 in. 55 ft. 7,408 ft. 2.875 in. 6.5 ppf L-80 ABM EUE 2.441 in. 7,408 ft. 7,441 ft. Penetration(%wall) Damage Profile(%wall) 250 mINI Penetration body Metal loss body 0 50 100 0.1 200 3 150 100 47 M 50 g 0 0 to 20 to 40 to over 20% 40% 85% 85% wa _ Number of joints analyzed(total=247) GLM 1 (10:00) 96 111 247 0 0 0 Ara 7 Damage Configuration(body) _ 20 GLM 2 (7:00) I a 145 -."-- i _i 15 ja 10 GLM 3 (10:30) i 194 5 GLM 4 (2:00) 0 GLM 5 (3:30) a Isolated General Line Other Hole/ Pitting Corrosion Corrosion Damage Pos.Hole GLM 6(3:00) 235 T' Number of joints damaged(total= 18) 5 0 13 0 0 Bottom of Survey=238.9 • • IIII PDS Report Joint Tabulation Sheet Well: 3G-06 Survey Date: May 30,2017 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 L-80 ABM EUE Tubing 2.992 in. 0.254 in. 55 ft. 7,408 ft. 2.875 in. 6.5 ppf L-80 ABM EUE Tubing 2.441 in. 0.217 in. 7,408 ft. 7,441 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 55 0 0.04 15 0 2.90 Pup Shallow Line of Pits.Lt. Deposits. • 1 58 0 0.04 14 3 2.90 Lt.Deposits. 1.1 87 0 0.02 9 2 2.93 Pup Lt. Deposits. 1.2 93 0 0.02 8 2 2.89 Pup Lt. Deposits. 3 2 103 0 0.03 10 1 2.92 Lt.Deposits. 3 132 0 0.02 9 2 2.90 Lt.Deposits. 3 4 162 0 0.02 8 2 2.90 Lt.Deposits. 5 193 0 0.02 9 2 2.92 Lt.Deposits. 6 221 0 0.02 7 2 2.91 Lt.Deposits. 7 250 0 0.02 8 2 2.91 Lt.Deposits. 8 280 0 0.03 11 2 2.92 Lt.Deposits. ■ 9 309 0 0.03 10 2 2.92 Lt.Deposits. ■ 10 339 0 0.03 10 2 2.92 Lt.Deposits. 11 369 0 0.02 7 2 2.90 Lt.Deposits. 12 399 0 0.02 9 2 2.91 Lt.Deposits. 3 13 429 0 0.03 11 4 2.90 Lt.Deposits. ■ 14 460 0 0.03 10 2 2.91 Lt.Deposits. ■ 15 488 0 0.03 10 2 2.90 Lt.Deposits. 15.1 518 0 0 0 0 2.80 CAMCO DS NIPPLE NO GO 16 519 0 0.03 10 2 2.92 Lt.Deposits. 17 549 0 0.02 9 2 2.92 Lt.Deposits. 18 580 0 0.02 . 7 2 2.92 Lt.Deposits. 19 609 0 0.02 7 1 , 2.91 Lt.Deposits. 20 639 0 0.03 11 3 2.91 Lt.Deposits. 21 669 0 0.02 8 2 2.90 Lt.Deposits. 3 22 700 0 0.02 8 2 2.91 Lt.Deposits. 23 730 0 0.02 9 2 2.90 Lt.Deposits. r 24 760 0 0.03 12 2 2.91 Lt.Deposits. • 25 790 0 0.03 11 2 2.90 Lt.Deposits. 26 820 0 0.02 8 2 2.91 Lt.Deposits. 27 850 0 0.03 . 11 3 2.91 Lt.Deposits. ■ 28 880 0 0.03 10 2 2.91 Lt.Deposits. 29 910 0 0.02 9 2 2.91 Lt.Deposits. 30 940 0 0.04 14 2 2.91 Lt.Deposits. ■ 31 969 0 0.03 10 3 2.91 Lt.Deposits. 32 999 0 0.03 10 2 2.91 Lt.Deposits. 33 1028 0 0.02 9 2 2.91 Lt.Deposits. 34 1058 0 0.02 9 2 2.91 Lt.Deposits. 35 1088 0 0.02 9 2 2.91 Lt.Deposits. 36 1118 0 0.02 8 3 2.91 Lt.Deposits. 37 1147 0 0.02 8 2 2.91 Lt.Deposits. 38 1178 0 0.03 12 3 2.90 Lt.Deposits. ■ 39 1208 0 0.03 13 3 2.90 Lt.Deposits. ■ 40 1239 0 0.03 13 2 2.92 Lt.Deposits. 41 1268 0 0.02 9 2 2.91 Lt.Deposits. 42 1296 0 0.02 9 2 2.92 Lt.Deposits. 43 1326 0 0.02 9 2 2.90 Lt.Deposits. 44 1356 0 0.02 8 3 2.92 Lt.Deposits. 45 1384 0 0.02 8 2 2.91 Lt.Deposits. 46 1415 0 0.02 8 2 2.92 Lt.Deposits. IPenetration Body Metal Loss Body Page 1 0 • (1144.S. PDS Report Joint Tabulation Sheet Well: 3G-06 Survey Date: May 30, 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 L-80 ABM EUE Tubing 2.992 in. 0.254 in. 55 ft. 7,408 ft. 2.875 in. 6.5 ppf L-80 ABM EUE Tubing 2.441 in. 0.217 in. 7,408 ft. 7,441 ft. Joint Jt.Depth Pen. Pen. Pen. Metal Min. Damage Profile No. (Ft.) Upset Body % Loss I.D. Comments (%wall) (in.) (in.) % (in.) 0 50 100 47 1445 0 0,03 11 3 2.90 Lt.Deposits. ■ 48 1476 0 0.03 11 2 2.91 Lt.Deposits. 49 1504 0 0.03 10 2 2.91 Lt.Deposits. 50 1535 0 0.02 9 2 2.91 Lt.Deposits. 51 1565 0 0.02 9 2 2.91 Lt.Deposits. 52 1595 0 0.02 9 1 2.91 Lt.Deposits. 53 1625 0 0.03 11 3 2.90 Lt.Deposits. 54 1656 0 0.02 9 2 2.92 Lt.Deposits. 55 1685 0 0.03 11 2 2.88 Lt.Deposits. 56 1714 0 0.02 9 2 2.89 Lt.Deposits. 57 1745 0 0.02 9 2 2.90 Lt.Deposits. 58 1775 0 0.04 15 3 2.91 Shallow Line of Pits.Lt. Deposits. ■ 59 1805 0 0.03 13 3 2.91 Lt.Deposits. w 60 1835 0 0.03 12 3 2.89 Lt.Deposits. ■ 61 1866 0 0.03 12 2 2.91 Lt.Deposits. ■ 62 1896 0 0.03 11 2 2.91 Lt.Deposits. 63 1926 0 0.02 9 2 2.91 Lt.Deposits. 64 1957 0 0.03 11 2 2.91 Lt.Deposits. 65 1986 0 0.02 9 2 2.91 Lt.Deposits. 66 2016 0 0.03 13 2 2.91 Lt.Deposits. 67 2046 0 0.03 . 10 2 2.89 Lt.Deposits. 68 2077 0 0.04 14 3 2.89 Lt.Deposits. ■ 69 2107 0 0.03 10 2 2.87 Lt.Deposits. ■ 70 2137 0 0.03 12 3 2.89 Lt.Deposits. ■ 71 2168 0 0.03 11 2 2.89 Lt.Deposits. ■ 72 2198 0 0.03 10 2 2.88 Lt.Deposits. a 73 2228 0 0.03 11 2 2.88 Lt.Deposits. ■ 74 2257 0 0.03 11 3 2.88 Lt.Deposits. ■ 75 2288 0 0.03 12 2 2.88 Lt.Deposits. ■ 76 2318 0 0.03 12 3 2.89 Lt.Deposits. 77 2348 0 0.03 10 2 2.89 Lt.Deposits. 78 2379 0 0.03 12 2 2.90 Lt.Deposits. 79 2409 0 0.03 10 2 2.88 Lt.Deposits. 80 2439 0 0.03 11 3 2.90 Lt.Deposits. ■ 81 2470 0 0.03 10 2 2.90 Lt.Deposits. ■ 82 2499 0 0.03 10 2 2.88 Lt.Deposits. ■ 83 2529 0 0.03 12 2 2.88 Lt.Deposits. ■ 84 2558 0 0.03 10 2 2.90 Lt.Deposits. ■ 85 2589 0 0.03 11 2 2.89 Lt.Deposits. ■ 86 2619 0 0.03 12 2 2.89 Lt.Deposits. ■ 87 2649 0 0.03 10 2 2.89 Lt.Deposits. ■ 88 2680 0 0.03 11 2 2.89 Lt.Deposits. ■ 89 2710 0 0.04 15 3 2.89 Shallow Pitting. Lt Deposits. ■ 90 2740 0 0.03 11 3 2.88 Lt.Deposits. ■ 91 2770 0 0.03 11 2 2.88 Lt.Deposits. ■ 92 2801 0 0.03 10 3 2.88 Lt.Deposits. 92.1 2831 0 0 0 0 2.89 GLM 1 (LATCH @ 10:00) II 93 2837 0 0.03 10 3 2.89 Lt.Deposits. • 94 2866 0 0.03 11 3 2.87 Lt.Deposits. ■ 95 2897 0 0.03 10 2 2.90 Lt.Deposits. - IPenetration Body Metal Loss Body Paget 0 • ill PDS Report joint Tabulation Sheet Well: 3G-06 Survey Date: May 30,2017 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 L-80 ABM EUE Tubing 2.992 in. 0.254 in. 55 ft. 7,408 ft. 2.875 in. 6.5 ppf L-80 ABM EUE Tubing 2.441 in. 0.217 in. 7,408 ft. 7,441 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 96 2927 0 0.03 13 4 2.89 Lt.Deposits. ■ 97 2958 0 0.03 12 2 2.89 Lt.Deposits. ■ 98 2988 0 0.03 12 2 2.88 Lt.Deposits. ■ 99 3018 0 0.03 11 3 2.88 Lt.Deposits. ■ 100 3049 0 0.03 12 4 2.90 Lt.Deposits. • 101 3079 0 0.03 13 3 2.89 Lt.Deposits. ■ 102 3109 0 0.03 12 3 2.89 Lt.Deposits. ■ 103 3139 0 0.03 11 3 2.89 Lt.Deposits. ■ 104 3169 0 0.04 14 3 2.90 Lt.Deposits. ■ 105 3200 0 0.03 11 2 2.89 Lt.Deposits. ■ 106 3231 0 0.03 12 2 2.89 Lt.Deposits. ■ 107 3261 0 0.03 10 3 2.89 Lt.Deposits. ■ 108 3292 0 0.03 13 3 2.87 Lt.Deposits. ■ 109 3322 0 0.03 13 2 2.89 Lt.Deposits. ■ 110 3353 0 0.03 10 2 2.88 Lt.Deposits. ■ 111 3384 0 0.03 12 2 2.86 Lt.De posits. ■ 112 3414 0 0.03 11 2 2.90 Lt.Deposits. 113 3445 0 0.03 10 3 2.88 Lt.Deposits. 114 3475 0 0.03 11 3 2.90 Lt.De•'sits. ■ 115 3506 0 0.03 12 2 2.89 Lt.Deposits. ■ 116 3536 0 0.03 12 2 2.86 Lt.Deposits. ■ 117 3566 0 0.03 13 4 2.87 Lt.Deposits. ■ 118 3597 0 0.03 11 3 2.90 Lt.Deposits. 119 3625 0 0.03 10 2 2.90 Lt.Deposits. J 120 3656 0 0.03 13 3 2.87 Lt.Deposits. ■ 121 3687 0 0.03 10 2 2.87 Lt.Deposits. ■ 122 3718 0 0.03 11 2 2.87 Lt.Deposits. ■ 123 3748 0 0.03 11 2 2.88 Lt.Deposits. 124 3779 0 0.03 10 2 2.88 Lt.Deposits. 125 3809 0 0.03 10 2 2.88 Lt.Deposits. 2 126 3838 0 0.04 14 3 2.87 Lt.Deposits. ■ 127 3869 0 0.03 11 3 2.88 Lt.Deposits. 128 3900 0 0.02 9 3 2.89 Lt.Deposits. 129 3930 0 0.03 11 1 2.89 Lt.Dep•sits. ■ 130 3962 0 0.03 10 2 2.88 Lt.Deposits. ■ 131 3992 0 0.03 11 2 2.87 Lt.Deposits. ■ 132 4022 0 0.03 11 2 2.89 Lt.Deposits. ■ 133 4052 0 0.04 14 2 2.88 Lt.Deposits. • 134 4082 0 0.04 14 2 2.88 Lt.Deposits. ■ 135 4112 0 0.0 12 2 2.87 Lt.Deposits. 136 4143 0 0.02 9 2 2.87 Lt.Deposits. 137 4173 0 0.03 12 2 2.88 Lt.Deposits. ■ 138 4203 0 0.04 15 2 2.82 Shallow Pitting. Lt Deposits. 138.1 4234 0 0 0 0 2.89 GLM 2(LATCH @ 7:00) I 139 4241 0 0.03 10 3 2.91 Lt.Deposits. ■ 140 4270 0 0.03 11 3 2.89 Lt.Deposits. 141 4301 0 0.02 9 1 2.88 Lt.Deposits. 142 4332 0 0.02 8 2 2.87 Lt.Deposits. i 1 143 4363 0 0.03 11 2 2.89 Lt.Deposits. a 144 4394 0 0.03 12 2 2.90 Lt.Deposits. IPenetration Body Metal Loss Body Page 3 1110 • 1111 PDS Report Joint Tabulation Sheet Well: 3G-06 Survey Date: May 30,2017 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 L-80 ABM EUE Tubing 2.992 in. 0.254 in. 55 ft. 7,408 ft. 2.875 in. 6.5 ppf L-80 ABM EUE Tubing 2.441 in. 0.217 in. 7,408 ft. 7,441 ft. Joint Jt.Depth Pen. Pen. Pen. Metal Min. Damage Profile No. (Ft.) Upset Body % Loss I.D. Comments (%wall) (in.) (in.) % (in.) 0 50 100 145 4425 0 0.03 10 2 2.90 Lt.Deposits. ■ 146 4456 0 0.04 14 3 2.90 Lt.Deposits. ■ 147 4488 0 0.03 10 2 2.89 Lt.Deposits, 148 4519 0 0.02 9 1 2.88 Lt.Deposits. 149 4551 0 0.02 9 2 2.88 Lt.Deposits. 150 4582 0 0.02 9 1 2.88 Lt.Deposits. 151 4612 0 0.02 9 2 2.87 Lt.Deposits. 152 4643 0 0.02 8 2 2.89 Lt.Deposits. 153 4674 0 0.03 10 2 2.88 Lt.Deposits. 154 4705 0 0.02 9 2 2.88 Lt.Deposits. 155 4736 0 0.04 14 2 2.88 Lt.Deposits. ■ 156 4765 0 0.03 10 2 2.88 Lt.Deposits. ■l 157 4793 0 0.03 10 3 2.88 Lt.Deposits. ■j 158 4825 0 0.03 10 2 2.88 Lt.Deposits. ■I 159 4856 0 0.03 11 3 2.87 Lt.Deposits. ■ 160 4887 0 0.03 12 2 2.89 Lt.Deposits. ■ 161 4916 0 0.03 12 2 2.89 Lt.Deposits. ■ 162 4947 0 0.03 12 2 2.88 Lt.Deposits. ■ 163 4976 0 0.03 13 3 2.91 Lt.Deposits. ■ 164 5006 0 0.03 11 2 2.87 Lt.Deposits, ■ 165 5038 0 0.03 11 2 2.91 Lt.Deposits. ■ 166 5069 0 0.03 13 1 2.88 Lt.Deposits. ■ 167 5100 0 0.03 12 2 2.92 Lt.Deposits. 168 5131 0 0.02 9 2 2.90 Lt.Deposits. 169 5162 0 0.03 12 2 2.87 Lt.Deposits. ■ 170 5193 0 0.04 15 2 2.91 Shallow Line of Pits.Lt. Deposits. ■ 171 5224 0 0.03 13 2 2.87 Lt.Deposits. 172 5254 0 0.03 10 2 2.88 Lt.Deposits. 173 5285 0 0.03 13 1 2.87 Lt.Deposits. ■ 174 5317 0 0.03 11 1 2.88 Lt.Deposits. 175 5348 0 0.02 9 2 2.89 Lt.Deposits. 176 5379 0 0.03 12 2 2.90 Lt.Deposits. ■ 177 5409 0 0.03 11 2 2.90 Lt.Deposits. ' 177,1 5440 0 0 0 0 2.87 GLM 3(LATCH @ 10:30) 178 5446 0 0.03 11 2 2.89 Lt.Deposits. ■ 179 5476 0 0.04 14 3 2.89 Lt.Deposits. 180 5505 0 0.02 7 2 2.89 Lt.Deposits. 181 5537 0 0.03 11 4 2.90 Lt.Deposits. ■ 182 5568 0 0.03 11 2 2.88 Lt.Deposits. ■ 183 5599 0 0.03 13 2 2.88 Lt.Deposits. ■ 184 5631 0 0.03 12 2 2.90 Lt.Deposits. ■ 185 5662 0 0.04 14 3 2.90 Lt.Deposits. ■ 186 5693 0 0.04 15 2 2.89 Shallow Line of Pits.Lt. Deposits. ■ 187 5724 0 0.04 15 3 2.92 Shallow Line of Pits.Lt. Deposits. ■ 188 5756 0 0.04 15 4 2.91 Shallow Line of Pits.Lt. Deposits. ■ 189 5787 0 0.03 13 3 2.91 Lt.Deposits. ■ 190 5818 0 0.03 11 2 2.90 Lt.Deposits. ■ 191 5849 0.04 0.03 13 3 2.90 Lt.Deposits. ■ 192 5880 0 0.04 14 3 2.91 Lt.Deposits. ■ 193 5911 0 0.03 13 4 2.92 Lt.Deposits. IPenetration Body Metal Loss Body Page 4 • • Pil PDS Report Joint Tabulation Sheet Well: 3G-06 Survey Date: May 30, 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 L-80 ABM EUE Tubing 2.992 in. 0.254 in. 55 ft. 7,408 ft. 2.875 in. 6.5 ppf L-80 ABM EUE Tubing 2.441 in. 0.217 in. 7,408 ft. 7,441 ft. Joint Jt.Depth Pen. Pen. Pen. Metal Min. Damage Profile No. (Ft.) Upset Body % Loss I.D. Comments (%wall) (in.) (in.) % (in.) 0 50 100 194 5942 0 0.03 11 2 2.91 Lt.Deposits. • 195 5974 0 0.03 12 2 2.91 Lt.Deposits. ■ 196 6005 0 0.04 15 4 2.90 Shallow Line of Pits.Lt. Deposits. ■ 197 6036 0 0.04 16 4 2.90 Shallow Line of Pits.Lt. Deposits. ■ 198 6067 0 0.04 14 2 2.90 Lt.Deposits. ■ 199 6098 0 0.03 13 3 2.90 Lt.Deposits. 200 6129 0 0.02 9 2 2.91 Lt.Deposits. 201 6160 0 0.03 11 2 2.91 Lt.Deposits. 201.1 6192 0 0 0 0 2.86 GLM 4(LATCH C 2:00) I 202 6198 0.07 0.03 13 4 2.90 Lt.Deposits. ■ 203 6230 0 0.03 13 3 2.90 Lt.Deposits. ■ 204 6259 0 0.03 13 4 2.91 Lt.Deposits. ■ 205 6291 0 0.04 15 4 2.88 Shallow Line of Pits.Lt. Deposits. ■ 206 6322 0 0.04 15 4 2.91 Shallow Line of Pits.Lt. Deposits. ■ 207 6353 0 0.03 11 2 2.90 Lt.Deposits. ■ 208 6384 0 0.03 12 2 2.90 Lt.Deposits. ■ 209 6415 0 0.03 12 3 2.90 Lt.Deposits. ■ 210 6446 0 0.03 11 2 2.90 Lt.De posits. 211 6475 0 0.02 8 2 2.89 Lt.Deposits. 212 6504 0 0.03 11 3 2.91 Lt.Deposits. ■ 213 6536 0 0.04 14 4 2.90 Lt.Deposits. ■ 214 6567 0 0.05 18 5 2.88 Shallow Line Corrosion. Lt. Deposits. ■ 215 6599 0 0.03 13 2 2.89 Lt.Deposits. ■ 216 6630 0 0.04 15 4 2.89 Shallow Pitting. Lt Deposits. ■ 217 6661 0 0.03 11 4 2.88 Lt.Deposits. • 218 6693 0 0.03 11 3 2.89 Lt.Deposits. ■ 219 6724 0 0.04 15 3 2.89 Shallow Pitting. Lt Deposits. 219.1 6756 0 0 0 0 2.81 GLM 5(LATCH 3:30) I 220 6762 0 0.03 13 2 2.91 Lt.Deposits. ■ 221 6793 0 0.03 12 3 2.91 Lt.Deposits. ■ 222 6825 0 0.04 15 3 2.90 Shallow Pitting. Lt Deposits. ■ 223 6856 0 0.03 12 2 2.91 Lt.Deposits. ■ 224 6886 0 0.03 11 2 2.91 Lt.Deposits. ■ 225 6918 0 0.03 12 4 2.90 Lt.Deposits. ■ 226 6947 0 0.03 11 4 2.87 Lt.Deposits. ■ 227 6977 0 0.03 13 3 2.91 Lt.Deposits. 228 7008 0 0.02 9 4 2.91 Lt.Deposits. 3 , 229 7039 0 0.02 7 1 2.90 Lt.Deposits. 230 7071 0 0.0 11 3 2.91 Lt.Deposits. ■ 231 7102 0 0.03 13 3 2.90 Lt.Deposits. ■ 232 7133 0 0.03 11 2 2.91 Lt.Deposits. 232.1 7164 0 0.02 7 4 2.92 Pup Lt. Deposits. 232.2 7170 0 0 0 0 2.83 GLM 6(LATCH C 3:00) 232.3 7180 0 0.04 14 1 2.91 Pup Lt. Deposits. • 233 7186 0 0.04 15 3 2.92 Shallow Line of Pits.Lt. Deposits. 233.1 7217 0 0 0 0 2.79 CAMCO W NIPPLE NO GO 234 7219 0 0.03 11 4 2.91 Lt.Deposits. 234.1 7250 0 0.02 9 1 2.87 Pup Lt. Deposits. 234.2 7256 0 0 0 0 2.96 BAKER PBR SEAL ASSEMBLY 234.3 7270 0 0 0 0 2.87 BAKER DB PERMANENT PACKER IPenetration Body Metal Loss Body Page 5 • • illl CIO`. PDS Report Joint Tabulation Sheet Well: 3G-06 Survey Date: May 30, 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 L-80 ABM EUE Tubing 2.992 in. 0.254 in. 55 ft. 7,408 ft. 2.875 in. 6.5 ppf L-80 ABM EUE Tubing 2.441 in. 0.217 in. 7,408 ft. 7,441 ft. Joint Jt.Depth Pen. Pen. Pen. Metal Min. Damage Profile No. (Ft.) Upset Body % Loss I.D. Comments (%wall) (in.) (in.) % (in.) 0 50 100 235 7277 0 0.03 13 3 2.91 Lt.Deposits. C 236 7308 0 0.03 13 2 2.91 Lt.Deposits. 237 7339 0 0.05 18 3 2.90 Shallow Line of Pit.Lt. Deposits. C 238 7371 0 0.04 14 2 2.92 Lt.Deposits. 238.1 7402 0 0.03 12 2 2.87 Pup Lt. Deposits. • 238.2 7408 0 0 0 0 2.41 5.5"X 2.875"CROSS-OVER 238.3 7409 0 0 0 0 2.37 BAKER GBH LOCATOR SEAL ASSEMBLY 238.4 7416 0 0 0 0 2.89 BAKER SEAL BORE EXTENSION 238.5 7418 0 0 0 0 2.42 BAKER DB PERMANENT PACKER 238.6 7419 0 0.01 2 0 2.37 Pup Lt. Deposits. 238.7 7424 0 0 0 0 2.22 CAMCO D NIPPLE NO GO 238.8 7424 0 0.02 11 2 2.38 Pup Lt. Deposits. 1111 238.9 7431 0 0 0 0 2.34 BAKER SHEAR OUT SUB Penetration Body Metal Loss Body Page 6 • • Minimum Diameter Profile Well: 3G-06 Survey Date: May 30,2017 Field: Kuparuk Tool Type: UW MFC 24 Ext. No. 218183 Company: ConocoPhillips Alaska, Inc. Tool Size: 1.69 inches Country: USA Tubing I.D.: 6.276 inches Minimum Measured Diameters(in.) 1.75 2 3 4 5 6 7,431 . 7,439 2 7,480 3 G.) 0 7 Z 7,500 = a O 4 7,520 5 7,561 6 i 1 • • PDS Report Overview V___S Body Region Analysis Well: 3G-06 Survey Date: May 30,2017 Field: Kuparuk Tool Type: UW MFC 24 Ext. No.218183 Company: ConocoPhillips Alaska, Inc. Tool Size: 1.69 inches Country: USA No. of Fingers: 24 Pipe 7 in. 26 ppf J-55 Analyst: C.Waldrop Pipe Nom.OD Weight Grade&Thread Nom.ID Top Depth Bottom Depth 7 in. 26 ppf J-55 6.276 in. 7,431 ft. 7,599 ft. Penetration (%wall) Damage Profile(%wall) 10 110.1 Penetration body i Metal loss body 0 50 100 1 8 6 4 2 2 0 1 0 to 20 to 40 to over 3 20% 40% 85% 85% Number of joints analyzed(total=6) 2 0 0 0 I 4 Damage Configuration(body) 1 10 8 5 6 4 2 6 0 ■ Isolated General Line Other Hole/ Pitting Corrosion Corrosion Damage Pos.Hole Number of joints damaged(total=2) 0 0 2 0 0 Bottom of Survey=6 = Perforations • • PI tit 0 PDS Report Joint Tabulation Sheet Well: 3G-06 Survey Date: May 30, 2017 Field: Kuparuk Analyst: C.Waldrop Company: ConocoPhillips Alaska,Inc. Pipe Description Nom. ID Body Wall Top Depth Bottom Depth 7 in. 26 ppf J-55 Casing 6.276 in. 0.362 in. 7,431 ft. 7,599 ft. Joint It.Depth Pen. Pen. Pen. Metal Min. Damage Profile No. (Ft.) Upset Body % Loss I.D. Comments (%wall) (in.) (in.) % (in.) 0 50 100 1 7431 0 0.05 15 4 5.86 Shallow Line of Pits.Deposits. ■ 2 7439 0.08 0.40 100 9 5.95 Perforations Lt.Deposits. ...... 3 7480 0 0.28 78 5 6.14 Perforations Lt.Deposits. ■siommom 4 7500 0.36 0.50 100 16 6.03 Perforations Lt.Deposits. Immo 5 7520 0.17 0.43 100 16 5.90 Perforations Lt.Deposits. 6 7561 0 0.06 15 4 6.03 Shallow Line of Pits.Lt. Deposits. I Penetration Perforations Body Metal Loss Perforations 'Penetration Metal Loss Body Page 1 0 (i . PDS Report Cross Sections Well: 3G-06 Survey Date: May 30,2017 Field: Kuparuk Tool Type: UW MFC 24 Ext. No. 218183 Company: ConocoPhillips Alaska,Inc. Tool Size: 1.69 Country: USA No. of Fingers: 24 Tubing: 7 in. 26 ppf J-55 Analyst: C.Waldrop Cross Section for Joint 1 at depth 7,431 .930 ft. Tool speed=53 Nominal ID=6.276 Nominal OD= 7 Remaining wall area= 100% ,' Tool deviation=33° ,, A 11 / ,. , 1 Minimum I.D.=5.858 in. Deposits Minimum I.D.=5.86 in. HIGH SIDE= UP • • TUBING SINGLE PRODUCER STRADDLE PACK R 3G-06 ARCO Alaska, Inc. DATE: 3/1/97 Subsidiary of Atlantic Richfield Company 1 OF 1 PAGES #ITEMS COMPLETE DESCRIPTION OF EQUIPMENT RUN LENGTH DEPTH TOPS RKB TO TBG HEAD LOCK DOWN SCREWS DOYON RIG#14 31.35 WKM Gen IV 3-1/8" 5M TBG hgr WI 3-1/2" EUE 8rd Pup 3.05 31.35 jt's# 238 3-1/2" 9.3#J-55 ABM-EUE 8rd TBG 30.50 34.40 SPACE OUT PUPS (10,06,6.13') 16.19 64.90 224-237 3-1/2" 9.3#J-55 ABM-EUE 8rd TBG 427.65 81.09 3 112"<CAMCO IOS1 NIPPLE WI;'2 812 'tJo•Gb-Prta`fiki:4:416401 0D','; ...? 8.74- #147.223 3-112"9.3#J-55 ABM-EUE 8rd TBG 2354.89 509.71 .11dfisvD'KBUG'W/ V� 3)�'LATCf-i- 1D 2f92 5`_39 OD't3LIi4##1 6-45 N,,...2 € 8'6:4.60-: #101-146 3-1/2"9.3#J-55 ABM-EUE 8rd TBG 1389.19 2871.05 3-1/2"''X 1"'Camco'KBUG'W/DV, BK`LATCH,-2:92 ID.'5;39 OtJGLM#2',: 6 4.0` 4280-24'.' #62-100 3-1/2" 9.3# J-55 ABM-EUE 8rd TBG 1165.96 4266.64 3-112"X 1"Cameo'KBUG' W/DV, BK LATCH,2:92.ID, 5:39 CD:GLM#3' #38-61 3-1/2" 9.3# L-80 ABM-EUE 8rd TBG 750.62 5439.03 3.1/'2"X 1":Qamco'KBUG' W/DV; BKLATCH,2492•ID,.500'GLM#4 #20-37 3-1/2" 9.3# L-80 ABM-EUE 8rd TBG 557.97 6196.11 31/2"::X 1:t amco'KBUG'W/DV,:BK IATCH,2 92`lD;'S 39 OD`GLM#5 6.63;' ",&75'4:08. #7-19 3-1/2" 9.3# L-80 ABM-EUE 8rd TBG 403.39 6760.71 3-1/2" 9.3# L-80 ABM-EUE 8rd Pup 6.09 7164.10 31/2"t)( 1-1/2"Oils `LBX' W/DGR 1;di inp kil€valve #iii' 3.112" 9.3# L-80 ABM-EUE 8rd Pup 6.13 7179.32 _ jt #6 3.112" 9.3# L-80 ABM-EUE 8rd TBG 31.36 7185.45 1;1/2" Cameo 'W Nipple WI 2:81.2" Select€ve°:Profile, 544 :_O:D 1.94.': "`72,1.6,81 jt #5 3-1/2" 9.3# L-80 ABM-EUE 8rd TBG 31.38 7218.75 3-1/2" 9.3# L-80 ABM-EUE 8rd Pup 6.10 7250.13 3-1/2"!80-40'PBR (SHEARED OUT), ., qg256.23 3-1/2"'X.7,Baker'FHU Retri PKR'60M'LB STRIGH't'PULLzr Rik Rales 7:05< 7269.94` JT'S #1-4 3.1/2"9.311 L-80 ABM-EUE 8rd TBG 125.54 7276.99 3-1/2" 9.3# L-80 ABM-EUE 8rd Pup 6.01 7402.53 2-7/8" Baker `GBH-22 locator Seal Assy W/5' stroke. 2-7/8" x 3.5" 1.46 7408.54 X/over on top 7410.00 Permanent Packer Set on 3-1/2" TBG 311/97 @ 7410' SWS LOGGED AND LOCATED TO CBL DATED 2/12/91 CONTINUED ON NEXT PAGE Remarks: String Weights with Blocks: 70K# Up,35K#On,6K# Blocks. Ran 238 joints of tubing. 60 Joints new L-80& Rerun 178 Joints of J-55 pulled fron Well Drifted tubing, GLMs, & hanger with 2.867"plastic rabbit. Used Arctic Grade API Modified No Lead thread compound on all connections. Tubing is non-coated. Nordic Rig#1 Drilling Supervisor: DON L.WESTER • 410 KUP PROD 3G-06 COtIOCOPh1IIips name Attributes ---_---- Max Angle&MD TD Alaska,IDC. Wellbore APliUWI Field ame Wellbore Stahl, ncl(0) MD(KKB) Act 813 IItKel 501032013000 KUPARUK RIVER UNIT PROD I 48.16 4.100.00 7.910.0 ••• Comment 1(25(ppm) Date Annotation End Date KB.Grd 01 Rig Release Dais nG-00.12/302015 2n1 eo PM --- SSSV:NIPPLE Last WO: 3/1/1997 36.00 5/14/1990 woes.*(auusl) Annotation I Depth(81(131st I I End Date Annotation LaMod By End Date Last Tag:SUM 7.5060 12/28/2015 Rev Reason:TAG (ehalif 12/30/2015 {{_ Casing Strings WINGER:31.3 I Casing vesception OD(in) ID(in) Top(ftKB) Set Depth BOB)( Set Depth(TVD)...WI/Len(I...Grade Top Thread CONDUCTOR 16 15.062 36.0 1150 1150 62.5811-40 WELDED ' Casing Description 00(in) ID(In) Top(BOB) Set Depth(560) Set Depth(TVD)...WI/Len(I...Grade Tap Thread 1 SURFACE 95/8 8.921 350 3.741.9 3.109.3 36.00 J-55 BTC Casing Description OD(in) ID(in) 'Top(ftKB) Set Depth Pike Set Depth(TVD)...WI/Len(I...Grade Top Thread 'aa'E PRODUCTION TIE- 7 6.276 23.7 2007.0 1.9024 26.00 J-55 Bu8AMOD BACK Casing Description OD(in) ID lin) Top(5081 Set Depth 81681 Set Depth(TVD)...WVLen(I...Grade Top Thread PRODUCTION 7 5.276 2.007.0 7.9620 26.00 J-55 Tubing Strings t-- Tubing Description Senn,/Ma...ID(in) Top(568) Set Depth(5..1 Set Depth(TVDI(...Wt(iWRM) Grade Top Connection TUBING 3 1/2 '992 31.3 7.430.9 5.7991 9.30 L-80 ABM-EUE 3.5'62.875'@ 7418' j/�^^�J',�� Completion Details Cd46lKTOR:x.o-,ta.pJ1 Nominal ID Top 1568) Top(TVD)(INKS) Top Incl I') hem Des Com (int NIPPLE;501.7 31.3 31.3 0.10 HANGER WKM GEN IV HANGER 3.000 5087 508.7 0.53 NIPPLE CAMCO OS NIPPLE NO GO 2.812 7.216.8 5.624.9 3721 NIPPLE CAMCO W NIPPLE NO G0 2 812 7.2562 5.656.5 36.41 PER BAKER PSR 3.000 - z 7269.9 5.667.6 36.14 PACKER BAKER FHL RETRIEVABLE PACKER 3.000 eacouc-nou nsawciu 23.7- s; 7.408.5 5.780.7 34.72BAKER GBH-2,"LOCATOR SEAL ASSEMBLY 2441 2.007 0 .1 . 1 AG BAKER DDS PERMANENT PACKER 3.250 OAS LIFT;2.1104.11 7.413.6 5.784.9 34.69 SBE BAKER SEAL BORE EXTENSION 3.250 7.418.0 5.788.5 34.67 X0 Reducing CROSSOVER REDUCING 3.5'K2.875" 2.441 7,424.7 6.794.0 34.64 NIPPLE -CAMCO D NIPPLE NO GO 2250 74302 5.798.5 3461 SOS BAKEnHEAR OUT SUB 2441 Perforations&Slots Snot SURFACE 35D3.741.n-• Dene Top(TVD) BM(TVD) (nhobS Top 1568) Men(8681 (111188) MKS) Zone Date t) Type Cons GAS OFT:4.2.0.27.394.0 7.404.0 5.768.8 5.777.0 C'4 !P .3G-06 8/16/1991 4.0 ERE 2.5"Titan.: g 180 de .phasing III 7.460.0 7.490.0 5,823,1 5.847.9 A4.A-3.30- 8/19/ 2 1991 4.0 APERF 2.5"Titan:180 deg. GAS uFr:55,4..85,4..81111 7.502.0 /.532.006 5.85/.8 5.882.6 A-2,3G-06 21phasing 19/1991 4.0 APERF 4.5"Csg Gun:180 deg III Ph DAs LIFT;ariaoe L. Cement Squeezes Top(TVD) Ban(TOD) II Top(0001 Bier(RKS) OMB) (MB) Des Start Date Com 7.395.0 7.405.0 5.769.6 5.777.8 Cement Squeeze 9/29/1996 OAS LIFT.8.754.1 ' Mandrel Inserts on It ar all Top(TVD) Valve Latch Part Side TRO Ian S M Tap(18(8) 1566) Make Mosel OD In) Sen Type Type (b) (psi) Run Date Com G.LIFT;7.no.z---.-- !i f 2.864.6 24875 CAMCO KBUG 1 GAS LIFT GLV OK 0.156 1.291.0 914r009 I 2 4260.2 3.463.3 CAMCO KBUG 1 GAS LIFT GLV BK 0156 1282.0 9/4/2009 3 5.432,6 4.294.9 CAMCO KBUG 1 GAS LIFT GLV BK 0.156-T272.0 9/3/2009 4 6.189.7 4648.8 CAMCO KBUG 1 GAS LIFT GLV BK 0.188 1.2970 9/3/2009 RIPPLE;7,21e.e ----Tr 5 6.754.1 5.268.6 CAMCO KBUG 1 GAS LIFT OV BK 0.250 0.0 9/24/2009 6 7.1702 5.588.0 OTIS LBX 1 1/2 GAS LIFT DMY MA0.000 0.0 9/3/2009 Riotes:General&Safety End Date Annotation 8/30/2010 NOTE:View Schematic w/Alaska Shcematic9.0 Pan:7,2383 -- 11110 1019/2012 NOTE;RKSs FROM 3 RIGS ACCOUNT FOR CASING/MG TOPS PACKER.72e0n IPE.F:7.344.0.7404.0- SEAL 255Y:7.408.1 PACKER: SPE:7.4136AS i I RIPPLE:7.421.7 I SOS:7,430.2 it APERF:7.460.1.4W.0 - APENF;71020.7.5020 PRODUCTION:2.007.0.7.552.0 A Pages NOT Scanned in this Well History File XHVZE This page identifies those items that were not scanned during the initial scanning project. They are available in the original file and viewable by direct inspection. PAGES TO DELETE RESCAN [] Color items - Pages: Grayscale, halftones, pictures, graphs, charts - Pages: [] Poor Quality Original - Pages: [] Other- Pages: DIGITAL DATA [] Diskettes, No. [] Other, No/Type OVERSIZED [] Logs of various kinds [] Other Complete COMMENTS: Scanned by: Beverly/~ncent TO RE-SCAN Notes: Nathan Lowell Re-Scanned by: Bevedy Bren Vincent Nathan Lowell Date: Is~ NOTScanned.wpd KRU 3G-06 (PTD# 190-069) R~ Of TxIA Communication • Page 1 of 1 Regg, James B (DOA) From: NSK Problem Well Supv [n1617@conocophillips.com] /4I ~ Sent: Saturday, September 12, 2009 2:52 PM ~~~~ i~ To: Regg, James B(DOA); Maunder, Thomas E(DOA); Schwartz, Guy L(DOA) Cc: NSK Problem Well Supv; NSK Well Integrity Proj; CPF3 Prod Engrs; CPF3 DS Lead Techs Subject: KRU 3G-06 (PTD# 190-069) Report Of TxIA Communication Attachments: 3G-06 Wellbore Schematic.pdf; 3G-06 TIO Plot.pdf ~ Jim/Tom/Guy, .~ Kuparuk gaslifted producer 3G-06 (PTD#190-069) is suspected of having TxIA communication base upon a failed diagnostic TIFL on 9/9/09. A gaslift valve is the likely source of communication so slickline will troubleshoot and repair~"~possible. The well will be added to the SCP report and will be repaired or shut in by 10/7/09. Attached is a 90 day TIO plot and wellbore schematic. «3G-06 Wellbore Schematic.pdf» «3G-06 TIO Plot.pdf» Please contact me at your convenience if you have questions or comments. Martin Martin Walters / Brent Rogers Problem Wells Supervisor ConocoPhillips Alaska Inc. Office 907-659-7224 Cell 907-943-1720 / 1999 Pager 907-659-7000 #909 ~~ ,-~~_ 4 n,~ `~ ~~: ~t~u"J .a~'i~~fdti`1b'k~t.:./ t `" " 11 /4/2009 ~~ ~ ~~~~~-~ ~ Name 3G-06 Notes: AOGCC Report of TxIA Commun Date 10/1 /2009 ; 120 ; Date 6/3/2009 isoo 1400 1200 1000 ~Q 800 soo 400 200 0 Jun-09 ,~ ~DGI I eoo eoo ~MGI ~, o ~oo ~PWI , m s°°' SWI ~ LL soo.~BLPD ~ aoo ~~, -- - ---- - ~ 300 _ ___ _ . _ . .-. - 200 - - 100 --... ___. _.. __. . _ _ _ 0 Annular Communication Surveillance ,20 100 80 LL 60 d 'a 40 20 0 u • Jun-09 Jul-09 Aug-09 Sep-09 Date Jul-09 Aug-09 Sep-09 u ConocoPhillips ~~~ P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 March 12, 2009 Mr. Tom Maunder Alaska Oil & Gas Commission 333 West 7~' Avenue, Suite 100 Anchorage, AK 99501 ~~° Dear Mr. Maunder: C~ ~1 ~~ .ob Enclosed please find a spreadsheet with a list of wells from the Kuparuk field (KRU). Each of these wells was found to have a void in the conductor. These voids were filled with cement if needed and corrosion inhibitor, engineered to prevent water from entering the annular space. As per previous agreement with the AOGCC, this letter and spreadsheet serves as notification that the treatments took place and meets the requirements of form 10-404, Report of Sundry Operations. The cement was pumped February 15~` 2009. The corrosion inhibitor/sealant was pumped March 10~' and 11 a', 2009. The attached spreadsheet presents the well name, top of cement depth prior to filling, and volumes used on each conductor. Please call MJ Loveland or Perry Klein at 907-659-7043, if you have any questions. Sincerely, t / '. ~ /~ t M.J. Ioveland i` 1~ r~~~~ ~ fY_~~- ConocoPhillips Well Integrity Projects Supervisor ConocoPhillips Alaska Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10-404) Kuparuk Field Date 3/12/2009 Well Name PTD # Initial top of cement Vol. of cement um ed Final top of cement Cement top off date Corrosion inhibitor Corrosion inhibitor/ sealant date ft bbls ft al 3G-02 190-137 SF NA 16" NA 1.7 3/11/2009 3G-03 196-122 SF NA 16" NA 1.7 3/11/2009 3G-05 190-075 12'6" 1.80 19" 2/15/2009 4.25 3/10/2009 3G-06 190-069 8'4" 1.20 18" 2/15/2009 3.5 3/10/2009 3G-07A 190-085 25'6" 3.40 18" 2/15/2009 3.4 3/10/2009 3G-11 190-076 22" NA 22" NA 4.25 3/10/2009 3G-14A 197-251 SF NA 17" NA 3.4 3/10/2009 3G-17 190-122 5' 0.80 16" 2/15/2009 2.55 3/10/2009 3G-18 190-125 18" NA 18" NA 4.25 3/10/2009 3G-19A 201-106 18" NA 18" NA 2.55 3/10/2009 3G-21A 198-052 21' 2.80 2'10" 2/15/2009 12.75 3/10/2009 3G-25X 196-136 SF NA 7" NA 2.55 3/10/2009 THE MATERIAL UNDER THIS COVER HAS BEEN MICROFILMED ON OR BEFORE OCTO. BER 27, 2000 P M C:LORRMFILM. DOC L A T E R IA L THIS MA E E E W UNDER R K E R STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Operation Shutdown__ Pull tubing Alter casing Stimulate X Plugging Perforate Repair well Other 2. Name of Operator ARCO Alaska, Inc. 3. Address P. O. Box 100360, Anchorage, AK 4. Location of well at surface 99510 5. Type of Well: Development ,X Exploratory _ Stratigraphic _ Service 2538' FNL, 245' FWL, Sec. 24, T12N, R8E, UM At top of productive interval 1538' FSL, 1044' FEL, Sec. 24, T12N, R8E, UM At effective depth 1445' FSL, 837' FEL, Sec. 24, T12N, R8E, UM At total depth 1423' FSL, 791' FEL, Sec. 24, T12N, RSE, UM 12. Present well condition summary Total Depth: measured true vertical 6. Datum elevation (DF or KB) RKB 90 feet 7. Unit or Property name Kuparuk River Unit 8. Well number 3G-06 9. Permit number/approval number 90-69 10. APl number 5o-103-20130-00 11. Field/Pool Kuparuk River Field/Oil Pool 791 0 feet Plugs (measured) None 6203 feet Effective depth: measured 7812 feet Junk (measured) None true vertical 6 1 1 9 feet Casing Length Size Cemented Measured depth Structural Conductor 8 0' 1 6" 220 Sx AS I 1 1 5' Surface 3707' 9-.5/8" 875 Sx AS III & 3742' Intermediate 485 Sx Class G Production 7855' 7" 381 Sx Class G & 7892' Liner 265 Sx Class G tail Perforation depth: measured True vertical depth 115' 3006' 6188' . ,. 7394'-7404', 7460'-7490', 7502'-7532' _ true vertical I I I I I L 5769-5777, 5823-5848, 5858-588;:~ Tubing (size, grade, and measured depth) 3.5, 9.3#/ft., J-55 @ 7431 Packers and SSSV (type and meas,ured depth) , , Pkrs: Baker ECL @ 1998, Baker FHL @ 7270 & Baker DB @ 7410; SSSV: None, nipple 13. Stimulation or cement squeeze summary Fracture Stimulate 'A' Sands on 3/16/97. ~~.-~...~~I~ I ~'~'~\&L ..,. --. , ~,~, ~ ~ ~. i!- Intervals treated (measured) i''~ i ~ 7460'-7490', 7502'-7532' i, '~.,i ~' ...... ~ :, .... Treatment description including volumes used and final pressure Pumped 127.8 Mlbs of 20/40 and 12/18 of ceramic proppant into formation, fp was 2975 psi 14. Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 3 1 5 172 0 875 185 Subsequent to operation 1299 1 2 2 3 0 900 192 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations 16. Status of well classification as: Oil X Gas Suspended Service 17o I hereby certify that the foregoing is true and correct to the best of my knowledge. Si~InedForm 10~8 ~'~"'' Title Wells Superintendent SUBMIT IN DUPLICATE ARCO Alaska, Inc. KUPARUK RIVER UNIT '' WELL SERVICE REPORT '~ K1(3G-06(W4-6)) WELL JOB SCOPE JOB NUMBER 3G-06 FRAC, FRAC SUPPORT 0312970834.2 DATE DAILY WORK UNIT NUMBER 03/16/97 REFRAC A SAND DAY OPERATION COMPLETE ] SUCCESSFUL KEY PERSON SUPERVISOR © No (~) Yes O No DS-GALLEGOS JORDAN I I Yes FIELD AFC,~ CC.4f DAILY COST ACCUM COST Signed ESTIMATE KD1664 23ODS36GG $69,800 $73,777 Initial Tb.q Press Final Tb.cl Press Initial Inner Ann Final Inner Ann I Initial Outer Ann I Final Outer Ann 1130 PSI 0 PSI 800 PSI 0 PSII 0 PSII 0 PSI DAILY SUMMARY I REFRAC A SAND WITH 127800 LBS PROPPANT IN PERFS AND 659 LBS PROPPAND LEFT IN PIPE AFTER FLUSH TIME 07:00 09:27 09:51 10:36 10:48 11:02 12:09 16:30 LOG ENTRY MIRU DOWELL FRAC UNIT. TGSM PT TO SWAB VALVE 10800 PSI OK. SET TREE SAVER AND TEST. PUMP BREAKDOWN. CHECK ISIP 1656 PULSE ACTION / SD PULSEACTION/SD DATAFRAC. CHECK ISIP 1794 PUMP FRAC THROUGH FLUSH. TOTAL PROPPANT PUMPED 128459 LBS/10892 LBS 20/40, 117567 LBS 12/18. FLUSH AS DESIGNED/LEFT 659 LBS PROPPANT IN PIPE AFTER FLUSH. RDMO SERVICE COMPANY - SERVICE DAILY COST ACCUM TOTAL .,, APC $7,000.00 $7,000.00 DOWELL $61,000.00 $61,000.00 HALLIDUI=iTON $0.00 $3,458.00 LITTLE RED $1,800.00 ' $2,320.00 TOTAL FIELD ESTIMATE $69,800.00 .$73,778.00 ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 March 27, 1997 RECEIV b APR 1 1997 ~it & Gas Cons. C0mmis~,'. ~chorage Mr. David J. Johnston Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Subject: 3G-06 (Permit No. 90-69) Well Completion Report Dear Mr. Commissioner: Enclosed is the well completion report to cover any changes made to the completion during the recent workover operations on KRU 3G-06. If there are any questions, please call 263-4622. Sincerely, W. S. Isaacson Drilling Engineer Kuparuk Drill Site Development WSUskad ALASK~ OIL AND GAS CONSERVATION C,..,,vIMISSION.z.1/~.~__ WELL COMPLETION OR RECOMPLETION REPOR~'~.~_NU" EU~ ClasSificati~)'R 1. Status of Well ClasSificati~)'~r {~Y/~e,r, yiCe ~ej~.q';, [] Oil [] Gas [] Suspended [] Abandoned [] Service .,'"' ~a$ !2. Name of Operator 7. Permit Numbe"~';'C/~0/'E~;- ARCO Alaska Inc. 90-69 3. Address ................................ 8'. APi'Number P. O. Box 100360 Anchorage, Alaska 99510-0360 50-103-20130 4. Location of well at surface 9. Unit or Lease Name 2538' FNL, 245' FWL, Sec 24, T12N, RSE, UM ~"%;~~ Kuparuk River Unit At top of productive interval .~ ~.,-,~'~;;~.~?! 110. Well Number 1538' FSL, 1044' FEL, Sec. 24, T12N, R8E, UM ~ ~ i; 3G-06 At total depth ~ 1433 FSL, 791' FEL, Sec. 24, T12N, RSE, UM ~ 111 Field and P°0i .................................. ~' ...... ~ -~"-~-: Kuparuk River 5. Elevation in feet (indicate KB, DF, etc.) 16. Lease Designation and Serial No; RKB 90', Pad 54' GL i ADL 25547, ALK 2661 112. Date Spudded6/8/90 ,i13' Date I'D' Reached i 14' Date C°mp" Susp" °r Aband'i15' Water depth' if °fish°re I 16' N°' °f C°mpleti°ns6/13/90 ......... 3/2/97 N/A MSLI Two '17. Total Depth (MD+TVD)118. Plug Back Depth (MD+TVD)119~ Directional Survey l20. Depth where SSSV set~21. Thickness of Permafrost 7910 6203 FT~ 7682 6009 Pr] []Yes [] No I . N/A MD! 1650' (Approx.) 22. Type Electric or Other Logs Run ... 23. CASING, LINER AND CEMENTING RECORD CASING ......... SETTING DEPTH HOLE " , ..... _S___!_Z_~_ ~__.VVT. PER FT. .GRADE~ __ TOP ~BOTT'OM , SIZE ~ CEMENTIN_~_REC_ORD ........ ..A.M...o,U..N~'..' ,.P,?LL..ED ..... 16" 62.5# H-40 Surf. 115' 24" 220 sx AS I 9.625" 36# J-55 Surf. 3742' 12.25" 1875 sx AS III, 485 sx Class G ·~ .... ?--- ! ....... -~6_~ -_-.. J-_5_5 ..... S~rf-:--_--i 7892' , 8:5~ 381 SX CI__a__S~S ~-_,_~26-~--S~--ol-a_~ss--(~--~ail ............ i~ ....... ~ ...... ~--~ ........ i~-.-.--i ....... .-~.~ ...... . '24. Perforations'open to ProduCtion' (MD+TVD of Top and Bottom' '25. TUBING RECORD ..... and interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 3.5" x'2.875" 7431' 7270' & 7410' MD TVD MD TVD 7394'-7404' 7460'-7490' 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. 7502'-7532' , , 4 spf DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL UsED "27. PRODUCTION TEsT ......... Date First Produ~tion IMeth0d'°f Operation (Flowing, gas lift, etc.) ......... ~ Gas Lift Date of Test iHours TeSted I PRODUCTION FoR OIL-BBL GAS-MCF =.WATER-BBL CHOKE S~ZE I GAs-O~L RATIO ] TEST PERIOD ' I Flow TubingiCasing Pressur~ CALCULATED · OIL-BBL !GAs-MCF WATER-BBL !OIL GRAWTY-API (CORR) Press. ! ~4-HouR RATE 128. CORE DATA Brief description of lithology, porosity, fraCtures, apparent dips and presence of oil, gas or water. Submit core'~hips. Form 10-407 Rev. 07-01-80 Submit In Duplicate 29. Geologic Marl,~-'' 30. '-" Formation Tests I Measured True Vertical Include interval tested, pressure data, all fluids recovered Marker Name Depth Depth and gravity, GOR, and time of each phase. RECE!V D APR '! 1997 A:as.~.0il .& Gas Cons. C0mmiSS' ch0rage r'3E' List' of Attachment~ ......... Summary of Daily Drilling Reports 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed /j,,~. ~, ~ ................................. ~ _:_'- 'a .... Title I'~l~.l.~.r.~. E,4~,~¢,. Date ~'~'- Z 7' °l Prepared By Name/Number; INSTRUCTIONS GENERAL: This form is designed for submitting a complete and correct well completion report and Icg 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 ,~: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. ITEM 16 AND 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. ITEM 21: Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). ITEM 23: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. ITEM 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, Other-explain. ITEM 28: If no cores taken, indicate 'none'. Form 10-407 Rev. 07-01-80 Date: 3/6/97 ARCO ALASKA INC. WELL SUMMARY REPORT REMEDIAL AND COMPLETION OPERATIONS RE EIVbg: APR '1 1997 .Oil A Gas Cons..Co~l~t~-' , ~nc~Qr.aget WELL:3G-06 RIG:NORDIC WELL ID: 998731 TYPE: AFC:--998731 AFC EST/UL:$ 388M/ 485M STATE:ALASKA AREA/CNTY: NORTH SLOPE WEST FIELD: KUPARUK RIVER UNIT BLOCK: SPUD: START C0MP:02/22/97 FINAL: WI: 0% SECURITY:0 API NUMBER: 50-103-20130-00 02/22/97 (C1) TD: 7910' PB: 7682' SUPV: DLW DAILY: $ 02/23/97 (C2) TD: 7910' PB: 7682' SUPV: DLW DAILY: $ 02/24/97 (C3) TD: 7910' PB: 7682' SUPV: DLW DAILY: $ 02/25/97 (C4) TD: 7910' PB: 7682' SUPV:DLW DAILY:$ 02/26/97 (C5) TD: 7910' PB: 7682' SUPV: DLW DAILY: $ 02/27/97 (C6) TD: 7910' PB: 7682' SUPV:DLW DAILY:$ 02/28/97 (C7) TD: 7910' PB: 7682' SUPV:DLW DAILY:$ RIG UP MW: 8.5 SW Turn key pad to pad rig move from 3F pad to 3G pad. Accept rig @ 1800 hrs. 2/22/97. Rig up. 27, 796 CUM:$ 27,796 ETD:$ 0 EFC:$ 415,796 PULL 3.5" TBG STAND BACK MW: 8.5 SW Kill well. Freeze protect production flowline with diesel. Test BOPE 250/3500 psi. Pull tubing. 34,300 CUM:$ 62,096 ETD:$ 0 EFC:$ 450,096 M/U OVERSHOT TO CATCH TBG MW: 8.5 SW Continue POOH with 3.5" tubing. Held rig floor safety meeting. RIH with BHA %1. Work spear into Baker 'PBR', jar on PKR, jarred free. POOH with Baker "FHL" PKR. 31,700 CUM:$ 93,796 ETD:$ 0 EFC:$ 481,796 C/O CEMENT AND CTU JUNK @ MW:10.3 LSND POOH and recover Baker PBR, packer. Top of fish @ 7280' . RIH with BHA #2. POOH with 3.5" tubing cut off. Recover cut off 3.5" tubing. Clean out CTU squeeze from 7291' to 7342' junk from CTU under reamer. 66,110 CUM:$ 159,906 ETD:$ 0 EFC:$ 547,906 RAISE MUD WEIGHT TO 10.6 MW:10.4 LSND Continue to clean out CTU squeeze and junk from 7342' to 7410' Test 'C' perfs 7394' - 7404' MD. Continue to clean out cement from 7410' to 7682' PBTD. 42,200 CUM:$ 202,106 ETD:$ 0 EFC:$ 590,106 RUN BAKER 7" X 2-7/8" PER MW:10.6 LSND Circulate gas cut mud to 8.3 ppg. Gas coming from 'C' sand. Raise mud weight from 10.3 ppg to 10.7 ppg. Monitor well. Well dead. Run 7" x 2-7/8" permanent packer assembly, stopped at 7368' try to work past tight spot. Unable to get below 7368' POOH. -- 33,389 CUM:$ 235,495 ETD:$ 0 EFC:$ 623,495 RERUN 7" PKR (IV) TIME MW:10.6 LSND Continue running Baker 7" x 2-7/8" permanent packer. Stopped at 7368' Re-run gauge ring junk basket. RIH with Baker setting tool on 3.5" tubing. Run permanent packer on 3.5" tubing to 7424' . No tight spot at 7368' Run logging too1. 51,190 CUM:$ 286,685 ETD:$ 0 EFC:$ 674,685 RE E V U Date: 3/6/97 03/01/97 (C8) TD: 7910' PB: 7682' SUPV: DLW DAILY: $ ARCO ALASKA INC. APR 1 1997 Page: 2 WELL SUMMARY REPORT AI~s/~ ~ii & Gas Cons. com~' ~nchoraga ND BOPE MW:10.7 LSND Continue to POOH w/ Baker model 'D' permanent packer. Setting failed shift all the way. Re-run 7" x 2-7/8" permanent packer to 7410' RIH with 3.5" tubing and jewelry. 55,559 CUM:$ 342,244 ETD:$ 0 EFC:$ 730,244 03/02/97 (C9) TD: 7910' PB: 7682' SUPV: DLW DAILY: $ PREPARE RIG FOR RIG MOVE MW: 0.0 SW Continue to run 3.5" tubing. Freeze protect well with diesel. Secure well. 58,345 CUM:$ 400,589 ETD'$ 0 EFC:$ 788,589 03/03/97 (Ci0) TD: 7910' PB: 7682' SUPV:DLW DAILY:$ RELEASE RIG MW: 0.0 SW Continue to rig down. Move rig off 3G-06. Release rig at 0500 hrs. 3/3/97. 15,600 CUM:$ 416,189 ETD:$ 0 EFC:$ 804,189 End of WellSummary for We11:998731 ARCO Alaska, Inc. Date: April 25, 1991 Transmittal #: 8075 RETURN TO: ARCO Alaska, Inc. ATTN: Maria Trevithick Kuparuk Operations File Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted here with are the following items. signed copy of this transmittal. Acoustic Cement Bond Log Pulse Echo Cement Evaluation Log Cement Evaluation Log Cement Bond Log Cement Evaluation Log Cement Evaluation Log Receipt Please acknowledge receipt and return one Acknowledge' 2-12-91 6928-7675 2-12-91 1817-7692 4-18-91 5995-7836 4-18-91 5995-7816 4-19-91 6795-8554 4-19-91 6795-8534 Date' Drilling State of Alaska NSK ARCO Alaska, Inc. Date: Juen 22, 1990 Traflb~#: 7795 ARCO Alaska, Inc. Attn' Jenny Gamage Clerk Kuparuk Operations File 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. 3G-06 Dual Gamma Ray Elecromagnetic Wave 6-1 3-90 3762-791 0 Resistivity Formation Exposure Time 3 G - 06 Dual Gamma Ray Compensated Neutron 6 - 1 3 - 9 0 3 7 6 2 - 7 91 0 Porosity Simultaneous Formation Density Receipt Acknowledged: ..... ~.._~L~ .......... Date' DISTRIBUTION: D&M Drilling Franzen Vendor Package(Johnston) NSK State of Alaska(+Sepia) Todd Salat ARCO Alaska, Inc. Date: June 22, 1990 RETURN TO: ARCO Alaska, Inc. Attn: Jenny Gamage Kuparuk Operations File Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmittal #' 7794 ',~a~ Cof)$. ~'o , Transmitted herewith are the following items. Please acknowledge receipt and return one signed copy of this transmittal. 3G-06 LIS Tape and Listing 6-18-90 #90-06-022 Receipt Acknowledged: --- -,~~:-:--" .......... Date' DISTRIBUTION: Lynn Goettinger State of Alaska STATE OF ALASKA WELL COMPLETION OR RECOMPLETION REPORT AND LO , 1 Status of Well Classification of Service Well OIL ~ GAS ~ SUSPENDED ~ ABANDONED [~] SERVICE [~] 2 Name of Operator 7 Permit Number ARCO Alaska, Inc 90-69 3 Address 8 APl Numbe~ P.O. Box 100360, Anchorage, AK 99510-0360_~ _ 50-103-20130 4 Location ofwell atsurface ~ ~:~.~ ii C~7~:~'i i-:Tli)~ ~~-- i :~t~~ 9 Unitor Lease Name 2538' FNL, 245' FWL, SEC 24, T12N, RBE, UM ~ KUPARUK RIVER I~' J V~'I~tPJ)" 10 WellNumber - At Top Producing Interval 1538' F SL, 1044' FEL, SEC 24, T12N, RBE, U M At Total Depth ! ;~- H~ 11 Field and Pool 1423' FLS, 791' FEL, SEC 24, T12N, RBE, UM KUPARUK RIVER FIELD 5 Elevation in feet (indicate KB, DF, etc.) [ 6 Lease Designation and Serial No. KUPARUK RIVER OIL POOL RKB 90', PAD 54' GLI ADL 25547 ALK 2661 12 Date Spudded 13 Date T.D. Reached 14 Date Comp., Susp. or Aband. 15 Water Depth, if offshore 116 No. of Completions 6/05/90. 6/13/90. 2/20/91. NA feet MSLI 1 17 Total Depth (MD+TVD) 18 Plug Back Depth (MD+TVD) 19 Directional Survey 20 Depth where SSSV set 21 Thickness of permafrost 7910' MD, 6203' TVD 7812' MD, 6119' TVD YES r~ NO [~] 1808' feet MD 1600' APPROX 22 Type Electric or Other Logs Run EWR/C N/S F D/C ET/DG R/CB L/GYRO 23 CASING, LINER AND CEMENTING RECORD SE'I-rING DEPTH MD CASING SIZE . WT. PER FT. GRADE TOP Be'I-rOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 16" 62.5# H-40 SURF 115' 24" 220 SX ASl 9-5/$" 36# J-55 SURF 3742' 12-1/4" 875 SX ASIII, 485 SX CLASS G 7" 26# J-55 SURF 7892' 8-1/2" 381 SX CLASS G, 265 SX CLASS G TAIL I 24 Perforations open to Production (MD+-I-VD of Top and Bottom and 25 TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 3-1/2" 7314' 7325' 7502'-7532' W/4-1/2" CSG GUN @ 4SPF MD 5858'-5883' TVD 26 ACID, FRACTURE, CEMENT SQUEEZE, ETC DEPTH INTERVAL (MD) [ AMOUNT & KIND OF MATERIAL USED SEE ATTACHED ADDENDUM 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 GAS-OIL RATIO TEST PERIOD ,~- Flow Tubing 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. RECEIVED JUN 1 2 !991 A/aska Oil & Gas Cons. Commission Anchorage Form 10-407 Submit in duplicate Rev. 7-1-80 ~INUED ON REVERSE SIDE NAME Include interval tested, pressure data, all fluids recoverd and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. KUPARUK C TOP 7395' 5769' NA KUPARUK C Be'I-rOM 7403' 5776' KUPARUK A TOP 7447' 5812' KUPARUK A BOTTOM 17600' 5939' 31. LiST OF ATTACHMENTS GYRO , ~ I~C..) ~-t~ ~:~L~r~ 32. I hereby certify that the foregoing is true andJcorrect to the best of my knowledge [ ,~ned ~',~' ,~~--~//~,~· ~ Title AREA DRILLING ENGINEER Date ~.-.-'//~ ~/~;7// , /~ INSTRUCTIONS General' This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1' Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- ing and the location of the cementing toolo Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". Form 10-407 ADDENDUM WELL: ~/~ ~/91 3G-06 Frac KRU "A" sand perfs from 7502'-7532' @ 4spf in 11 stages as follows: Stage 1. Pmp Stage 2 Pmp Stage 3 Pmp Stage 4 Pmp Stage 5 Pmp Stage 6 Pmp Stage 7 Pmp Stage 8 Pmp Stage 9 Pmp Stage 10 Pmp Stage 11 Pmp Pmp Pmp Average Pressure: Fluid to recover: Sand in zone: Sand in casing: 130 bbls Surf XL GW Pre Pad @ 25 bpm 6500-4400 psi 30 bbls Non XL GW@ 25 bpm 4300 psi 40 bbls Slick Diesel @ 25 bpm 4100 psi 150bbls Surf XL GW @ 25 bpm 4800-4300 psi 15 bbls Surf XL GW w/2ppg @ 25 bpm 4300 psi 20 bbls Surf XL GW w/4ppg @ 25 bpm 4300 psi 20 bbls Surf XL GW w/6ppg @ 25 bpm 4050 psi 20 bbls Surf XL GW w/7ppg @ 25 bpm 3950 psi 15 bbls Surf XL GW w/8ppg @ 25 bpm 3940 psi 10 bbls Surf XL GW w/10ppg @ 25 bpm 6500 psi 20 bbls Surf XL GW 0 bbls Non XL GW 4.6 bbls Slick Diesel @ 1.5 bpm 4500 psi 393 4915 14,348 # Date RECEIVED JUN ^Jaska OiI& Gas Cons. ComrDiSstOh Anchorage ARCO ALASKA INC. DAILY OPERATIONS WELL: 3G-06 PAGE: 1 BOROUGH: FIELD: UNIT: LEASE: API: PERMIT APPROVAL: AFE: WI: NORTH SLOPE KUPARUK RIVER FIELD KUPARUK RIVER UNIT ADL 25547 ALK 2661 50-103-20130 90-69 AK4931 55.252072 ACCEPT: 02/06/91 21:000 SPUD: RELEASE: 02/20/91 OPERATION: COMPLETION RIG: NORDIC 02/07/91 (9) TD: 0 PB: 0 SUPV:RWS 02/08/91 (10) TD: 0 PB: 7812 SUPV:GB/SK 02/09/91 (11) TD: 0 PB: 7812 SUPV:GB/SK 02/10/91 (12) TD: 0 PB: 7812 SUPV:GB/SK NORDIC 1 RU FLOOR TO RIH W/ WASH PIPE MW:ll.1 NaC1/Br RIG MOVE F/ 3G-10 TO 3G-06. DIFFICULT DUE TO SNOW CONDITIONS. SPOT RIG OVER WELL-ACCEPT RIG @ 21:00 HR LEVEL RIG, ND TREE,REPAIR CELLAR BRIDGE CRANE, NU BOPS, TST BOPE TO 3500 PSI,REPAIR VALUE ON CHOKE, RU FLOOR TO RIH W/ WASH OVER PIPE DAILY:S21,064 CUM:$885,342 ETD:S921,214 EFC:$1,384,328 LAY DOWN 7" CASING MW:10.4 NaC1/Br SERVICE RIG, MU WASH PIPE ON 3-1/2" DP AND RIH AND TAG FISH AT 527', CIRC HEATED BRINE TO THAW ICE PLUG, NO GAIN IN FOOTAGE, TOH AND LAY DOWN WASH PIPE, PU OVERSHOT ASSY, TIH AND TAG FISH AT 524' LATCH AND POH WITH FISH, MU 6-1/8" BIT, RIH AND TAG OBSTRUCTION AT 535', CIRC HEATED BRINE, UNABLE TO MAKE ANY FOOTAGE, POH, MU 1 JOINT OF 3-1/2" TUBING ON 3-1/2" DP, RIH AND TAG UP, UNABLE TO WORK THROUGH, POH, PRESS TEST 7" CSG, ND 11" BOP STACK, CHANGE OUT SPOOL, PULL PACKOFF, TACK WELD SLIPS TO 7" CSG, NU 11" BOPS AND TEST, MU 7" TRI-STATE CASING CUTTER ON 3-1/2" DRILL PIPE, TIH, CUT 7" CSG AT 537', DISPLACE OUT ARCTIC PACK FLUID, TOH, MU 7" CSG SPEAR, RIH AND LATCH CSG STUB AND POH W/ CSG STUB AND SPEAR, REMOVE SLIPS AND LAY DOWN 11 AND 1/2 JOINTS 7" CSG DAILY:S31,187 CUM:$916,529 ETD:S952,401 EFC:$1,384,328 POH TO CLEAN PACKED BIT MW:10.4 NaCl/Br CLEAN UP 3 BBL BRINE SPILL, NULOAD 7" CSG FROM PIPE SHED, RACK AND TALLY 5" DP, RU AND RUN 8-3/4" MILL ON 5" DP, RIH TAG 7" CSG AT 537', MILL TO 554', CIRC BTMS UP, POH W/ MILL, MU AND RUN 6-1/8" BIT ON 3-1/2" DP, ROTATE INTO 7" CSG, CONT TO RIH, TAG OBSTRUCTION AT 572', ATTEMPT TO CIRC BUT BIT PACKED OFF, POH AND CLEAN BIT DAILY:S32,347 CUM:$948,876 ETD:S984,748 EFC:$1,384,328 TEST 9-5/8" CASING MW: 9.9 NaCl/Br SERVICE RIG, TOH W/ BIT, UNPLUG BIT AND RIH, TAG TOP OF 7" CSG AT 554, ROTATE INTO 7" CSG, TAG OBSTRUCTION AT 572' PUSH METAL CUTTINGS DOWN TO 675', WOULD NOT GO MORE, POH W/ 6-1/8" BIT, MU 7" CSG SPEAR, TIH LATCH 7" CSG, BLIND BACKOFF POH, RECOVERED 8 JTS, LD CSG AND 2 DAMAGED JOINTS, RIH WITH 7" CSG SPEAR LATCH CSG AT 949', BLIND BACK OFF, TEST 9-5/8" CSG TO 1950 PSI, CONT POH WITH 7" CSG, RECOVER 24 JTS TOP OF 7" CSG AT 2006', MU 8-1/2" BIT AND 9-5/8" SCRAPER, RIH, CIRC DAILY:S31,314 CUM:$980,190 ETD:S1,016,062 EFC:$1,384,328 ARCO ALASKA INC. DAILY OPERATIONS WELL: 3G-06 OPERATION: COMPLETION RIG: NORDIC PAGE: 2 02/11/91 (13) TD: 0 PB: 7812 SUPV:GB/SK 02/12/91 (14) TD: 0 PB: 7812 SUPV:GB/SK 02/13/91 (15) TD: 0 PB: 7812 SUPV:GB/SK 02/14/91 (16) TD: 0 PB: 7812 SUPV:GB/SK 02/15/91 (17) TD: 0 PB: 7812 SUPV:GB/SK 02/16/91 (18) TD: 0 PB: 7812 SUPV:GB/SK RU TO ARCTIC PACK MW:10.9 NaCl/Br SERVICE RIG, REMOVE 7" CSG FORM PIPE SHED, SEND CSG TO BE INSPECTED, LOAD NEW 15 JTS NEW CSG IN PIPE SHED, DIPLACE CONTAMINATED BRINE FROM WELL, PUMP 40 BBL DIESEL SPACER FOLLOWED BY 200 BBLS BRINE, PRESS TEST 9-5/8" CSG TO 2500 PSI, DIRC WELL CLEAN, POH W/ 8-3/4" BIT AND 9-5/8" CSG SCRAPER, MU TRI-STATE SCREW IN CSG GUIDE AND BAKER OPEN HOLE PACKER ON BOTTOM JT OF 7", RIH W/ 47 JTS OF 7" CSG, INSTALL STAND OFF BANDS EVERY OTHER JOINT, RU TO ARCTIC PACK WELL DAILY:S36,242 CUM:$1,016,432 ETD:S1,052,304 EFC:$1,384,328 TIH TO FILTER BRINE MW:ll.1 NaCl/Br ARCTIC PACK WELL, SCREW INTO 7" CSG AT 2007', PRESS 7" CSG TO 1550 PSI, LOST 50 BBLS, BLEED OFF, PULL 120K# ON CSG AND PRESS TO 3500 PSI, SET OPEN HOLE PACKER, TEST FOR 30 MIN, LOST 25 PSI, RU TO ND BOPS, SET SLIPS AT 95K#, CUT CSG TO SET PACKOFF, ND ADAPTER FLANGE, DRESS CSG FOR PACKOFF AND SET PACKOFF, TEST, NU 7" SPOOL ADAPTER FLANGE AND BOP, TEST, RIH WITH 6-1/8" BIT ON 3-1/2" DRILL PIPE AND CIRC OUT DIESEL W/ 11.1 PPG BRINE, CONT TO RIH IN PREPERATION TO FILTER BRINE DAILY:S56,862 CUM:$1,073,294 ETD:S1,109,166 EFC:$1,384,328 MU 6.059" GAUGE RING AND JUNKT MW:ll.1 NaC1/B~ SERVICE RIG, CONT RIH W/ 6-1/8" BIT AND 7" CSG SCRAPER, TAG UP AT 7683', CIRC AND FILTER BRINE, SLIP AND CUT 50 DRLG LINE, POH W/ BIT, RU HLS AND LOG (CBL, PET, AND GYRO), CBL/PET SHOWED POOR CEMENT BOND, RIH W/ SQUEEZE PERF GUN: PERF 7434'-7436' AND 7310'-7312', POH AND ALL SHOTS FIRED, MU 6.059" GAUGE RING AND JUNK BASKET AND CCL, RIH DAILY:S39,539 CUM:$1,112,833 ETD:S1,148,705 EFC:$1,384,328 WOC MW:ll.1 NaC1/Br RIH W/ GAUGE RING, SERVICE RIG, RIH W/ BRIDGE PLUG AND SET AT 7470', POH, RIH WITH EZSV AND SET AT 7330', RD HLS, MU BAKER STINGER AND RIH AND TAG EZSV AT 7314', RU CEMENT HEAD AND ESTABLISH INJECTION RATE, SQUEEZE BOTTOM SET OF PERFS W/ 20 BBLS CMT, UNSTING FROM EZSV AND REVERSE OUT, ESTABLISH INJECTION RATE IN TOP PERFS, POH W/ 10 STDS DP, SQUEEZE TOP SET OF PERFS W/ 15 BBLS CMT, CIP AT 02:05 HRS, RD DOWELL, WOC DAILY:S103,464 CUM:$1,216,297 ETD:S1,252,169 EFC:$1,384,328 TESTING LOWER SQZ PERFS MW:ll.1 NaC1/Br SERVICE RIG, POH WITH DP, RIH W/ BIT, TAG TOP OF CMT STRINGERS AT 7057', CIRC AND WOC FOR 1.5 HRS, DRLG CMT . STRINGERS TO 7245', FIRM CMT AT 7245'-7283', TEST CSG AT 2000 PSI FOR 15 MIN, LOST 75 PSI, DRILL TO 7314', TAG EZSV, TEST AT 2000 PSI FOR 15 MIN, LOST 125 PSI, DRILL EZSV AND CMT TO 7449', CIRC AND TEST LOWER SQZ PERFS DAILY:S54,702 CUM:$1,270,999 ETD:S1,306,871 EFC:$1,384,328 TIH W/ HOMCO EZSV MW:ll.1 NaC1/Br RU TO TEST CSG AT 2000 PSI, LOST 900 PSI IN 7 MIN, RIH AND CIRC AND ESTABLISH INJECTION RATE, POH, TEST BOPE, RIH W/ BIT AND CASING SCRAPER TO 7449', RU AND CIRC, POH, MU HOMCO EZSV AND SETTING TOOL AND PLUG CATCHER ON 3-1/2" DP, RIH DAILY:S28,832 CUM:$1,299,831 ETD:S1,335,703 EFC:$1,384,328 JUN 1 2 AJaska Oil & Gas Cons. Commis$io~ Anr:.hnmnn WELL: 3G-06 OPERATION: COMPLETION RIG: NORDIC PAGE: 3 02/17/91 (19) TD: 0 PB: 7812 SUPV:GB/SK .02/18/91 ( 20) TD: 0 PB: 7812 SUPV:GB/SK 02/19/91 (21) TD: 0 PB: 7812 SUPV:GB/SK 02/20/91 (22) TD: 0 PB: 7812 SUPV:GB/SK POH W/ BHA MW:ll.1 NaC1/Br SERVICE RIG, CONT RIH W/ EZSV, ATTEMPT TO ESTABLISH INJ RATE NO RATE, PULL OUT OF RETAINER, TEST ABOVE, OK, POH W/ STINGER, BREAK DOWN HOMCO TOOLS, RIH W/ DRILL BIT AND DRILL EZSV AT 7320', RIH 2 STDS DP AND TAG BP AT 7448', RU TO CIRC AND CIRC 15 MIN, TEST CSG AND PERFS, LOWTS 100 PSI IN 30 MIN DRILL CMT AND BP, RIH TO 7683', CIRC, TEST CSG TO 2000 PSI LOST 700 PSI IN 30 MIN, TETEST TO 200 PSI, LOST 450 PSI IN 10 MIN, CIRC, POH DAILY:S50,618 CUM:$1,350,449 ETD:S1,386,321 EFC:$1,384,328 CIRC AND FILTER BRINE MW:ll.1 NaC1/Br CONT POH W/ DP, MU BAKER RETRIEVE-O-MATIC/BRIDGE PLUG, PLUG CATCHER SUB, RIH W/ DP, SET PKR AT 7435' PRESS TEST BELOW PKR (OK) AND PRESS TEST ABOVE PKR (OK), PU PKR AND SET AT 7400', TEST ABOVE AND BELOW PKR (OK), TEST CSG WITH PKR UNSET (OK), POH W/ PKR, RIH WIHT DP AND DRILL BIT TO 7682', CIRC, FILTER BRINE DAILY:S41,201 CUM:$1,391,650 ETD:S1,427,522 EFC:$1,384,328 PERFING A SANDS MW:ll.1 NaCl/Br CONT TO CIRC AND FILTER BRINE, PUMPED 200 BBLS AND MI FILTER UNIT BROKE DOWN, RD FILTER UNIT, TRANSFER BRINE AND CLEAN PITS, WAIT ON CLEAN BRINE, TAKE ON 200 BBLS OF CLEAN BRINE, CIRC CLEAN BRINE AND POH W/ DP, RU HLS, RIH WITH PERF GUN #1 ' AND PERF 7512'-7532', POH RIH WITH PERF GUN #2 AND PERF 7502'-7512' DAILY:S69,919 CUM:$1,461,569 ETD:S1,497,441 EFC:$1,384,32 RELEASED RIG MW:ll.1 NaCl/Br POH W/ GUN#2, RU AND RUN 3-1/2" COMPL ASSEMBLY, TEST CONTROL LINE, MU TBG HNGR AND ATTACH CONTROL LINE, TEST CONTROL LINE LAND TBG AND RILDS, DROP SHEAR OUT BALL, SET PKR, TEST ANNULUS AND TBG, SOS SHEARED W/ 2500 PSI, PU AND SHEAR PBR, RELAND TUBING AND RILDS, TEST SSSV, ND BOP, NU TREE, TEST TREE, DISPLACE WELL WITH 12 BBLS DIESEL IN AANULUS AND 4 BBLS IN TUBING, RELEASE RIG DAILY:S69,459 CUM:$1,531,028 ETD:S1,566,900 EFC:$1,384,328 SIGNATURE: DRILLING~~ DATE: VICIN/Yy M&P I'*~ ~ MI. /0 ~'~ ~0~ 40.4 ~4.0 ~8'~ /~' 48.~ ~538'~ I?0' 47.8 d~$O'-- 4~' 4~.1 53.8 R~38'~ 70' 46.9 ~3.1 e~30'-- ~5' 46.0 ~3.0 ~'~ /~0' 4~.~ ~.9 R~O'~ 14~' 4g,~ ~3,0 I HEREBY CERTIFY THAY I AM NgOIS?~O AND LI~gNS[D ~ P~ACTIC~ ~NO SU~V~YIN~ IN ?H~ 9TAT~ OF M~D~ ~ M~ ~ UN~ MV OIN~T ( ~ T~T ALL OI~NM~ AND ~r~/~s An~ COn~C~ ~S O~ ~MRIL Re, 1~90. dtfO0 ~ASKA,/NO. OW~. NO. ' NSOK. $$00. CRA. 05 GX. ARCO laska, Inc' ORIL l. $1 ?g $. $ CONDUC?'Ot?$ ~-~ BOlL ? LOCATION ARCO !:'~LASi(A ~C~ 5u~'~'~vn~.~ STODDARD RECEIVED JUN 12 · aska OiI& Gas Cons. Commission ~:):::,. 0 ,72 77. :000. O 8.28 120.27 .',7~'x'a o i7.70 : l& 48 ! 403'x ,:': 2!, 07 2900, 0 42, 51 i07, 2? 2200, 0 47.97 ::"'"'" ?'8,15 ........ 47,,:.i . . o~,:,' ,' 4% 87 102, 71 VERT DEPTH ......... !7 E 200, 0 , ~9 N ,5~ E 700:0 2.59 H 4.79 F 899.9 2, 25 N 8- 8: F .... 2 37 S 17,27 E i097.4 1!,60 S P4,81 E SECTION 3.8 7.7 i7,2 36.7 i5i..'3 248.0 :,00, :: 36%0 425.7 564, Z 6~7,8 711.7 · 14 2, 30 5, 50 6.35 1.52 3..:9 :~ 77 3,71 6,15 3. 4~ 03 ~: Gyrodat a 250(L 0 48, C:5 1 { 2.96 224.3.4 2500, 0 48.05 lc, x, 7 i 23i O. 2 X:OCh ~':.. 43, 71 i05,, 98 2654, 3200.0 43= 93 i07,48 2726, ]500.0 45, 50 i 98, 20 2797, 3400, 0 45, 44 10~, 7~ 2867. 3500, 0 4~, 07 -~,',~ 7,: 2938. 5700.0 44,79 fOE., 49 3079. 5900, ( 46.77 ! 07., 95 3219, ...... , .... 3287.7 42(0. (: 46.99 109.09 5422. i 4400, 0 46.34 108.07 ~559.5 4500,0 46, i6 !07, 91 3628, 7 4600, 0 45. ~.5 ',' .... ~ ~ 478(':.', f! 45,~-,~-"'q ., ,.,, , ,','~, ,':r,.... 7767,9 :onn,, ...,,, .,'"44.22 i07.60 79io. 4 308, ~-~. S %0, 6S £ ~93.28 S 271. _.~.4' E 735,33 S 2327,25 E ,'~,.~,~ S 2393,77 E 785, 934, i:::,81.7 1!52,7 1222,0 i27i:2 136!,4 1503,6 i574.5 1644,9 !7!5,6 1787,5 i860. ? '.;935, 2 2009, 0 2081,8 2!54,3 2226.5 22~.,'=,. 4 2370.0 244.0,6 ":'~ '; J': 4 DO~-LES SE:,.'"EF.:i TV 1,06 1.46 1.23 ,5i ARC8 ALASffA INC~ KUPARUK RZVER UNZT, ~ELL ~ 36.-6 Job Numbs¢= AKO291G207 x Gyrodata Oirectiana! S u P v -~ y BEAS i NCL ~ 7 ? ~,~ ,mu ...... ~EPTH ~EPTH 5500,0 a3, ¥~ ici% 92 4345.9 5700.0 43, 25 i07.55 4489, 5 Avnr ,h ':~2,57 s r,a, 74 4856, 5 6:;00, 0 42, 48 10% ~4 4%1.2 .':'.700:0 40= 7~ in-? ~ ~ 68(0, 0 40, .3~ i 02, 15 5505.5 7200.0 .37,55 ~r,~., ~. ~.,,~ '., ~;~_~., .~. 6 7fAF A ~a 7~ IiZ.7E ~7~ ~ Z 0 i~ T ~ L feet 777,03 S ..... ' · ~'~9, ::.'. S 2526, 944,55 S 2656, ,~, ,'= S 2722, ~o .... S 2787.50 E 907.72 S 2852,79 E 548.83 S 29~5,35 F 1070,87 S ~4.4!,.[! F ii00, i? S 3570,30 ~ !i27.89 S 3696,94 E 3993.86 E SECTDN ft 2580.1 ."d~q"¢,~ 27!8,6 2993, 7 3,.'}62, 2 7 ~ r"','-' 7 3266~4 ~4~ ~ 3536,5 3~,:)L'-L 8 3670, 3 380), 5 3~6'!. 8 3928,8 3992,3 4054,5 4~13,7 4i7!,2 D0~-LES ~UU~TTV de~,"100' 2,52 ~L ~ 33 ,29 2.32 ...... ! N~L AZ ~ ~!UTR VEET ...... DEPTH H~E I ZOXTA, ,~RD iNATES SECT!O~,~ 4227, 5 SEVEF:iT¥' ,64 2.48 ARCO ALASKA,_ ZNC. i i i HaPker Zdentiftcatton 14D N/S A) KB 0 0 N BI 9 5/B" CASZNG 3742 496 S C] PBTD 7682 i267 S DJ 7' CASZNG 7892 t3t5 S E} EXTRAPOLATED TD 79t0 t3t9 S /V ii OE t599 E 4t37 E 4235 E 4244 E ------ ii 11,_ i ii i i i i 36-6 API50-103-20130 PLAN VIEN .... ] _ _ , __,ti CLOSURE · 4444 ft S 72.73 E DECLINATION · 0.00 E SCALE .......: ! inch = 800 feet DRANN. '05/08/9! ..... I __ __ I Il ~J.& I nil StentL~n# Directional Drilling 2400- 1600 ...... 800- ...................... ~ .......................... . .............................. . .......... t6oo 2400 0 800 ~600 2400 3200 4000 <- NEST · EAST -> T V [3 4000- 5000~ 6000~- 7000= 8000- ..... ARCO~_ ALASKA, INC. 3G-6 API50-~03-20~30 VERTICAL SECTION VIEN Section at: S 72.23 E TVD Scale.: ! inch = lO00 feet Dep Scale.: 1 inch = lO00 feet Drawn .... '05/08/9~ Harker Identification Al KB B1 9 5/8' CASING C) PBTD .... D} 7" CASING E) EXTRAPOLATED TD MD TVD SECTN INCLN 0 0 0 0.00 3742 3t09 t675 44.94 7682 6009 4326 3t.48 7892 6tBB 4434 3t.33 79t0 6203 4444 3t.33 iO00 2000 3000 Section Departure 4000 §000 by GREAT LAND DIRECTIONAL DRILLING, INC. for GyroData Incorporated .05/08/91 Client .... : ARCO ALASKA, INC. Field ..... : KUPARUK RIVER UNIT Well ...... : 3G-6 API50-103-20130 Section at: S,72.23,E Engineer..: TOM STODDARD Computation...: RADIUS OF CURVATURE Survey Date...: 02/13/91 RKB Elevation.: 90.00 ft Reference ..... : 0291G209 MARKER IDENTIFICATION INTERPOLATED MARKERS REPORT Surface Location: 2538 FNL 245 FWL S24 T12N R8E MEAS INCLN DEPTH ANGLE VERT-DEPTHS SECT BKB SUB-S DIST DIRECTION REL-COORDINATES BEARING FROM-WELLHEAD KB 9 5/8" CASING TOP KUPARUK C BASE KUPARUK C TOP KUPARUKA 0 0.00 3742 44.94 7395 34.80 7403 34.74 7447 34.52 0 -90 3109 3019 5769 5679 5776 5686 5812 5722 0 N 0.00 E. 1675 S 73.13 E 4168 S 66.47 E 4173 S 66.27 E 4198 S 66.58 E ON 0 E 496 S 1599 E 1204 S 3991 E 1206 S 3996 E 1216 S 4019 E BASE KUPARUKA PBTD 7" CASING EXTRAPOLATED TD 7600 33.02 7682 31.48 7892 31.33 7910 31.33 5939 5849 6009 5919 6188 6098 6203 6113 4283 S 66.84 E 4326 S 64.34 E 4434 S 64.10 E 4444 S 64.10 E 1249 S 4097 E 1267 S 4137 E 1315 S 4235 E 1319 S 4244 E GREAT LAND Client · · · · · · Field · Well ...... : Section at: Engineer.... DIRECTIONAL DRILLING, ARCO ALASKA, INC. KUPARUK RIVER UNIT 3G-6 API50-103-20130 S,72.23,E TOM STODDARD MEAS INCLN DEPTH ANGLE VERTICAL-DEPTHS BKB SUB-SEA 100 0.31 100.0 . 10.0 200 0.40 200.0 110.0 300 0.50 300.0 210.0 400 0.42 400.0 310.0 500 0.51 500.0 410.0 7 600 0.72 600.0 510.0 7 700 0.68 700.0 610.0 7 800 0.76 800.0 710.0 7 900 2.80 899.9 809.9 7 1000 8.28 999.4 909.4 7 1100 14.58 1097.4 1007.4 7 1200 16.19 1193.8 1103.8 7 1300 17.70 1289.4 1199.4 7 1400 21.07 1383.8 1293.8 7 1500 22.83 1476.5 1386.5 1600 25.06 1567.9 1477.9 1700 30.09 1656.5 1566.5 1800 33.46 1741.5 1651.5 1900 39.60 1821.8 1731.8 2000 42.51 1897.2 1807.2 2100 42.99 1970.7 1880.7 'Survey Codes: 7/GYRO 13G6 B1.21) INC. SECTION DISTNCE 0.1 0.3 0.8 1.4 1.9 2.8 3.7 4.7 7.7 17.2 36.6 62.8 91.6 124.5 161.5 RECORD OF SURVEY DIRECTION BEARING N 37.82 E N 40.54 E N 69.79 E N 56.68 E N 63.09 E Computation...: Survey Date...: RKB Elevation.: Reference ..... : RELATIVE-COORDINATES FROM-WELL-HEAD 0.2N 0.2E 0.7N 0.6E 1.1N 1.2E 1.5N 1.9E 1.9N 2.6E N 77.15 E 2.3 N 3.6 E N 66.55 E 2.6 N 4.8 E N 71.42 E 3.1 N 6.0 E S 66.01 E 3.0 N 9.0 E S 59.73 E 1.4 S 17.6 E 05/08/91 S 63.64 E 10.8 S 35.0 E S 62.78 E 22.8 S 58.7 E S 63.52 E 36.0 S 84.7 E S 64.71 E 50.4 S 114.5 E S 64.36 E 66.5 S 148.3 E RADIUS OF CURVATURE 02/13/91 90.00 ft 0291G209 201.8 S 65.63 E 83.7 S 185.1 E 247.9 S 71.28 E 100.7 S 228.1 E 300.6 S 74.22 E 116.3 S 278.4 E 360.0 S 74.78 E 132.2 S 335.7 E 425.7 S 72.76 E 150.5 S 398.8 E 493.5 S 71.53 E 171.3 S 463.4 E CLOSURE DL DISTNCE BEARING / 100 0.3 N 37.82 E 0.31 0.9 N .38.76 E 0.09 1.6 N 46.40 E 0.10 2.4 N 51.88 E 0.08 3.2 N 53.88 E 0.09 4.3 N 57.90 E 0.21 5.5 N 60.98 E 0.04 6.7 N 62.48 E 0.08 9.5 N 71.77 E 2.04 17.6 S 85.30 E 5.48 36.6 S 72.79 E 6.30 63.0 S 68.77 E 1.61 92.0 S 66.99 E 1.51 125.2 S 66.22 E 3.37 162.5 S 65.83 E 1.76 203.1 S 65.67 E 2.24 249.3 S 66.18 E 5.23 301.7 S 67.32 E 3.49 360.8 S 68.50 E 6.14 426.2 S 69.31 E 3.05 494.0 S 69.70 E 0.75 3G-6 API50-103-20130 S MEAS INCLN C DEPTH ANGLE 7 2200 47.07 7 2300 47.61 7 2400 47.87 7 2500 48.05 7 2600 48.05 VERTICAL-DEPTHS BKB SUB-SEA SECTION DISTNCE 2041.3 1951.3 564.3 2109.1 2019.1 637.8 2176.3 2086.3 711.7 2243.3 2153.3 785.7 2310.1 2220.1 859.9 7 2700 48.10 2377.0 2287.0 7 2800 48.09 2443.7 2353.7 7 2900 46.41 2511.6 2421.6 7 3000 44.14 2582.0 2492.0 7 3100 43.71 2654.0 2564.0 7 3200 43.93 2726.2 2636.2 7 3300 45.30 2797.4 2707.4 7 3400 45.44 2867.6 2777.6 7 3500 45.02 2938.0 2848.0 7 3600 45.04 3008.7 2918.7 7 3700 44.79 3079.5 2989.5 7 3800 45.16 3150.3 3060.3 7 3900 46.77 3219.8 3129.8 7 4000 47.78 3287.6 3197.6 7 4100 48.16 3354.6 3264.6 7 4200 46.99 3422.0 3332.0 7 4300 46.55 3490.5 3400.5 7 4400 46.34 3559.4 3469.4 7 4500 46.16 3628.6 3538.6 7 4600 45.85 3698.0 3608.0 7 4700 45.58 3767.9 3677.9 RECORD OF SURVEY ~Survey Codes: 7/GYRO 934.1 1008.4 1081.7 1152.7 1222.0 1291.2 1361.5 1432.6 1503.6 1574.4 1644.9 1715.6 1787.5 1860.9 1935.2 2009.0 2081.8 2154.3 2226.5 2298.5 2370.1 DIRECTION BEARING RELATIVE-COORDINATES FROM-WELL-HEAD S 71.81 E 193.6 S 530.5 E S 71.85 E 216.5 S 600.4 E S 77.29 E 236.2 S 671.7 E S 77.04 E 252.7 S 744.1 E S 76.29 E 269.8 S 816.5 E S 76.10 E S 75.28 E S 75.23 E S 74.32 E S 74.02 E Page 2 05/08/91 CLOSURE DiSTNCE BEARING 564.7 S 69.95 E 638.2 S 70.16 E 712.0 S 70.62 E 785.8 S 71.24 E 859.9 S 71.70 E /lOO 4.08 0.54 3.00 0.23 0.41 287.6 S 888.7 E 934.1 S 72.06 E 0.12 306.0 S 960.8 E 1008.4. S 72.33 E 0.45 324.7 S 1031.9 E 1081.7 S 72.53 E 1.68 343.3 S 1100.4 E 1152.7 S 72.66 E 2.31 362.3 S 1167.1 E 1222.1 S 72.75 E 0.45 S 72.52 E 382.2 S 1233.4 E 1291.3 S 72.78 E S 71.80 E 403.7 S 1300.3 E 1361.5 S 72.74 E S 71.27 E 426.3 S 1367.8 E 1432.7 S 72.68 E S 73.24 E 447.9 S 1435.4 E 1503.7 S 72.66 E S 74.06 E 467.8 S 1503.3 E 1574.4 S 72.71 E 487.5 S 1571.1 E 1645.0 S 72.75 E 508.1 S 1638.7 E 1715.7 S 72.77 E 529.9 S 1707.2 E 1787.6 S 72.75 E 553.2 S 1776.9 E 1861.0 S 72.70 E 577.8 S 1847.0 E 1935.2 S 72.62 E S 73.51 E S 72.62 E S 72.05 E S 70.97 E S 70.40 E S 70.91 E 602.2 S 1916.6 E 2009.0 S 72.55 E S 71.26 E 625.9 S 1985.6 E 2081.9 S 72.50 E S 71.93 E 648.7 S 2054.3 E 2154.3 S 72.47 E S 72.09 E 671.0 S 2123.0 E 2226.6 S 72.45 E S 72.72 E 692.8 S 2191.6 E 2298.5 S 72.45 E 713.9 S 2260.0 E 2370.1 S 72.46 E S 73.00 E 0.75 1.42 0.30 1.07 0.41 0.37 0.58 1.64 1.17 0.49 1 ..20 0.48 0.41 0.20 0.45 0.31 3G-6 API50-103-20130 S MEAS ~NCLN C DEPTH ANGLE 7 4800 44.27 7 4900 44.22 7 5000 44.16 7 5100 43.88 7 5200 43.54 VERTICAL-DEPTHS BKB SUB-SEA RECORD OF SURVEY SECTION DIRECTION DISTNCE BEARING 3838.7 3748.7 2440.7 S 72.47 E 3910.3 3820.3 2510.4 S 72.40 E 3982.0 3892.0 2580.1 S 73.14 E 4053.9 3963.9 2649.6 S 69.82 E 4126.2 4036.2 2718.7 S 70.97 E 7 5300 43.62 4198.6 4108.6 7 5400 43.49 4271.1 · 4181.1 7 5500 43.31 4343.8 4253.8 7 5600 43.21 4416.6 4326.6 7 5700 43.26 4489.4 4399.4 7 5800 43.04 4562.4 4472.4 7 5900 42.77 4635.6 4545.6 7 6000 42.51 4709.2 4619.2 7 6100 42.72 4782.8 4692.8 7 6200 42.57 4856.4 4766.4 7 6300 42.46 4930.1 4840.1 7 6400 42.43 5003.9 4913.9 7 6500 42.52 5077.6 4987.6 7 6600 41.31 5152.0 5062.0 7 6700 40.78 5227.5 5137.5 7 6800 40.31 5303.4 5213.4 7 6900 40.23 5379.7 5289.7 7 7000 39.90 5456.3 5366.3 7 7100 39.47 5533.2 5443.2 ? 7200 37.55 5611.5 5521.5 2787.6 .S 71.68 E 2856.5 S 72.11 E 2925.2 S 72.08 E 2993.8 S 72.53 E 3062.3 S 72.45 E 3130.6 S 72.66 E 3198.7 S 73.55 E 3266.4 S 74.46 E 3334.1 S 74.95 E 3401.7 S 75.26 E 3469.2 S 75.66 E 3536.5 S 76.84 E 3603.8 S 76.92 E 3670.4 S 77.31 E 3735.8 S 77.35 E 3800.5 S 77.85 E 3864.8 S 77.61 E 3928.9 S 78.23 E 3992.4 S 78.67 E 4054.4 S 76.60 E ? 7300 35.53 5691.8 5601.8 4113.8 S 70.65 E 'Survey Codes: 7/GYRO RELATIVE-COORDINATES FROM-WELL-HEAD Page 3 o5/o8/91 CLOSURE DISTNCE BEARING /lOO 1113.7 S 3634.0 E 1127.4 S 3697.1 E 1140.9 S 3760.1 E 1153.7 S 3822.7 E 1167.0 S 3883.5 E 1183.8 S 3940.6 E 1039.1 S 3310.0 E 1055.1 S 3375.5 E 1070.4 S 3441.3 E 1085.3 S 3506.4 E 1099.7 S 3570.5 E 948.4 S 2983.6 E 968.1 S 3048.7 E 986.8 S 3113.8 E 1004.7 S 3179.1 E 1022.1 S 3244.6 E 843.9 S 2656.8 E 865.3 S 2722.3 E 886.4 S 2787.7 E 907.2 S 2853.0 E 927.9 S 2918.3 E 2787.6 S 72.37 E 0.35 2856.5 S 72.36 E 0.24 2925.2 S 72.35 E 0.18 2993.8 S 72.35 E 0.23 3062.3 S 72.35 E 0.06 3130.6 S 72.36 E 0.24 3198.7 S 72.37 E 0.49 3266.4 S 72.41 E 0.49 3334.1 S 72.45 E 0.31 3401.8 S 72.51 E 0.21 3469.3 S 72.56 E 0.21 3536.6 S 72.63 E 0.54 3603.9 S 72.71 E 0.10 3670.6 S 72.79 E 1.22 3736.0 S 72.87 E 0.53 3800.8 S 72.95 E 0.51 3865.2 S 73.03 E 0.13 3929.4 S 73.11 E 0.42 3992.9 S 73.20 E 0.47 4055.0 S 73.27 E 2.07 4114.5 S 73.27 E 2.85 734.9 S 2327.4 E 2440.7 S 72.47 E 1.34 755.9 S 2394.0 E 2510.5 S 72.47 E 0.06 776.6 S 2460.5 E 2580.2 S 72.48 E 0.36 798.6 S 2526.4 E 2649.6 S 72.45 E 1.62 821.8 S 2591.5 E 2718.7 S 72.40 E 0.64 3G-6 API50-103-20130 RECORD OF SURVEY Page 4 05/08/91' S MEAS INCLN C DEPTH ANGLE 7 7400 34.76 7 7500 34.26 7 7600 33.02 7 7690 31.33 X 7910 31.33 VERTICAL-DEPTHS BKB SUB-SEA SECTION DISTNCE 5773.6 5683.6 4171.3 5856.0 5766.0 4227.7 5939.2 5849.2 4282.8 6015.4 5925.4 4330.4 6203.3 6113.3 4443.6 DIRECTION BEARING S 66.25 E S 66.96 E S 66.84 E S 64.10 E S 64.10 E RELATIVE-COORDINATES FROM-WELL-HEAD 1204.9 S 3994.1 E 1227.4 S 4046.1 E 1249.1 S 4097.0 E 1269.0 S 4140.6 E 1319.0 S 4243.5 E CLOSURE DiSTNCE BEARING 4171.9 S 73.20 E 4228.2 S 73.12 E 4283.2 S 73.04 E 4330.7 S 72.95 E 4443.8 S 72.73 E DL /loo 1.62 0.55 1.24 2.05 0.00 ^Survey Codes: 7/GYRO X/EXTRAPOLATED 3G-6 API50-103-20130 Page 5 DATA INTERPOLATED FOR 100 FT SUBSEA INTERVAL 05/08/91 SUBSEA MEAS INCLN TVD DEPTH DEPTH ANGLE BKB MD-TVD VERT DIRECTION RELATIVE COORDINATES DIFF CRRT BEARING FROM WELL HEAD 100 190 0.39 190 200 290 0.49 290 300 390 0.43 390 400 490 0.50 490 500 590 0.70 590 0 0 N 40.27 E 0.64 N 0.51 E 0 0 N 66.86 E 1.10 N 1.12 E 0 0 N 57.99 E 1.46 N 1.85 E 0 0 N 62.45 E 1.86 N 2.53 E 0 0 N 75.74 E 2.24 N 3.50 E 600 690 0.68 690 700 790 0.75 790 800 890 2.60 890 900 990 7.76 990 1000 1092 14.10 1090 0 0 N 67.60 E 2.60 N 4.67 E 0 0 N 70.93 E 3.06 N 5.83 E 0 0 N 34.51 W 5.26 N 6.67 E 0 0 S 60.32 E 0.80 S 16.41 E 2 2 S 63.34 E 9.98 S 33.32 E 1100 1196 16.13 1190 1200 1301 17.72 1290 1300 1407 21.19 1390 1400 1515 23.16 1490 1500 1625 26.29 1590 6 4 S 62.81 E 22.29 S 57.71 E 11 5 S 63.52 E 36.03 S 84.84 E 17 6 S 64.68 E 51.47 S 116.72 E 25 8 S 64.54 E 68.98 S 153.45 E 35 10 S 67.01 E 87.94 S 194.80 E 1600 1739 31.40 1690 1700 1859 37.11 1790 1800 1990 42.22 1890 1900 2127 44.08 1990 2000 2272 47.45 2090 49 14 S 72.42 E 106.86 S 247.02 E 69 20 S 74.55 E 125.50 S 311.42 E 100 31 S 72.95 E 148.58 S 392.45 E 137 36 S 71.60 E 177.14 S 480.80 E 182 45 S 71.83 E 210.01 S 580.57 E 2100 2420 47.90 2190 2200 2570 48.05 2290 2300 2720 48.10 2390 2400 2868 46.94 2490 2500 3011 44.09 2590 230 49 S 77.23 E 239.53 S 686.44 E 280 49 S 76.51 E 264.58 S 794.69 E 330 50 S 75.94 E 291.11 S 902.83 E 378 49 S 75.24 E 318.84 S 1009.68 E 421 43 S 74.28 E 345.44 S 1107.88 E 2600 3150 43.82 2690 460 39 S 73.27 E 371.97 S 1200.21 E 3G-6 API50-103-20130 Page 6 DATA INTERPOLATED FOR 100 FT SUBSEA INTERVAL o5/o8/91 SUBSEA MEAS INCLN TVD DEPTH DEPTH ANGLE BKB MD-TVD VERT DIRECTION RELATIVE COORDINATES DIFF CRRT BEARING FROM WELL HEAD 2700 3290 45.15 2790 500 40 S 71.87 E 401.40 S 2800 3432 45.30 2890 542 42 S 71.89 E 433.42 S 2900 3574 45.03 2990 584 42 S 73.84 E 462.62 S 3000 3715 44.84 3090 625 41 S 73.37 E 490.49 S 3100 3857 46.07 3190 667 42 S 72.29 E 520.34 S 3200 4004 47.79 3290 714 47 S 70.95 E 554.08 S 3300 4153 47.54 3390 763 49 S 70.67 E 590.83 S 3400 4299 46.55 3490 809 46 S 71.25 E 625.68 S 3500 4444 46.26 3590 854 45 S 72.00 E 658.64 S 3600 4588 45.88 3690 898 44 S 72.64 E 690.33 S 3700 4732 45.16 3790 942 43 S 72.83 E 720.48 S 3800 4872 44.23 3890 982 40 S 72.42 E 749.94 S 3900 5011 44.13 3990 1021 39 S 72.77 E 778.83 S 4000 5150 43.71 4090 1060 39 S 70.39 E 810.40 S 4100 5288 43.61 4190 1098 38 S 71.59 E 841.29 S 4200 5426 43.44 4290 1136 38 S 72.10 E 870.80 S 4300 5564 43.24 4390 1174 37 S 72.36 E 899.71 S 4400 5701 43.26 4490 1211 37 S 72.45 E 928.02 S 4500 5838 42.94 4590 1248 37 S 72.99 E 955.96 S 4600 5974 42.58 4690 1284 36 S 74.22 E 982.05 S 4700 6110 42.70 4790 1320 36 S 74.98 E 1006.39 S 4800 6246 42.52 4890 1356 36 S 75.44 E 1029.89 S 4900 6381 42.43 4990 1391 36 S 76.61 E 1052.18 S 5000 6517 42.31 5090 1427 36 S 76.98 E 1072.97 S 5100 6650 41.04 5190 1460 34 S 77.33 E 1092.61 S 1293.26 E 1389.33 E 1485.31 E 1581.08 E 1677.43 E 1779.37 E 1883.89 E 1985.03 E 2084.74 E 2183.69 E 2281.45 E 2375.12 E 2467.96 E 2558.95 E 2649.01 E 2739.35 E 2829.15 E 2918.80 E 3008.13 E 3096.83 E 3185.53 E 3274.45 E 3363.21 E 3452.33 E 3538.83 E 5200 6782 40.39 5290 1492 32 S 77.76 E 1111.27 S 3622.82 E 3G-6 API50-103-20130 Page 7 DATA INTERPOLATED FOR 100 FT SUBSEA INTERVAL 05/08/91 SUBSEA MEAS INCLN DEPTH DEPTH ANGLE TVD BKB 5300 6913 40.18 5390 5400 7044 39.71 5490 5500 7173 38.07 5590 5600 7298 35.57 5690 5700 7420 34.66 5790 5800 7541 33.75 5890 5900 7660 31.89 5990 6000 7777 31.33 6090 6100 7894 31.33 6190 MD-TVD VERT DIRECTION RELATIVE COORDINATES DIFF CRRT BEARING FROM WELL HEAD 1523 31 S 77.69 E 1129.27 S 3705.62 E 1554 30 S 78.42 E 1146.57 S 3787.61 E 1583 29 S 77.16 E 1163.22 S 3867.24 E 1608 25 S 70.78 E 1183.35 S 3939.34 E 1630 22 S 66.39 E 1209.48 S 4004.50 E 1651 21 S 66.91 E 1236.40 S 4067.20 E 1670 19 S 65.00 E 1262.32 S 4126.51 E 1687 17 S 64.10 E 1288.87 S 4181.48 E 1704 17 S 64.10 E 1315.46 S 4236.23 E 3G-6 API50-103-20130 Page 8 DATA INTERPOLATED FOR 1000 FT MEASURED DEPTH INTERVAL 05/08/91 MEAS INCLN VERT-DEPTHS SECT DIRECTION REL-COORDINATES DEPTH ANGLE BKB SUB-S DIST BEARING 1000 8.28 999 909 17 S 59.73 E 1 S 2000 42.51 1897 1807 426 S 72.76 E 151 S 3'000 44.14 2582 2492 1153 S 74.32 E 343 S 4000 47.78 3288 3198 1861 S 70.97 E 553 S 5000 44.16 3982 3892 2580 S 73.14 E 777 S 6000 42.51 4709 4619 3266 S 74.46 E 987 S 7000 39.90 5456 5366 3929 S 78.23 E 1141 S CLOSURE FROM-WELLHEAD DIST BEARING DL/ 100 18 E 18 S 85.30 E 5.5 399 E 426 S 69.31 E 3.1 1100 E 1153 S 72.66 E 2.3 1777 E 1861 S 72.70 E 1.2 2461 E 2580 S 72.48 E 0.4 3114 E 3266 S 72.41 E 0.5 3760 E 3929 S 73.11 E 0.4 AOGCC GEOLOGICAL MATERIALS iNYENTORY LiST PERMIT # ~ - ~°1 WELL NAME ~'~ ~ . ...~_~-- ~ COMPLETION DATE .~ t.~ t ~ ~ CO. CONTACT ~~ ~ ~ check off or lis~'"d~ta a~ i~' i~ rcC~ived.'list reccived d~e '~or 4'0i: if n~' rc.~i~cd list as ER _~ cored intervals core analysis ditch intervals digital data ,,~~ ,, '" ,i, , .............~t%2_..% , . IIII I IIII I I Il III I I II I III I , I I I , , , I LOG 'rrna, , ,--,_ ...... I RUN " ,,~lI!TI;rl'~'/l'°, Li'i. II/'IL~.) SCALE ........ NO. ~, ,, It, 0 thc n,carest footl [inchll00'] ~I ~~, I c~ ~ / ~0 .... \ ...... '6-/~ ;~ - ?qt, o~ .... 2 ~ 5 bm.. i ....... I -,,, ~} t~~'T ....................... ~, I\~t-/-- '7~qZ ,5 ......... ~ ~ .... ,., . ,,, ,,., IU L_ . I 11 ~1 , I111 II III I I III IIIII I I I III iii I 71 ,, ,, . ,, ., I~IlU[ I I II I I I I II I I I i ':fl ................. ,,, ,,,,,,, ,, ~ ~ , . ,,. ,,, . ~ ~?~ ..... , ........ ,"ll LII log ~pc" received *fcc date run # Comnmnts DlUSFL 'yes- no .... DLL yes no ,,, IJHCISL yes no 'BHCIA~- yes no .......... LSS yes no SSS yes no CNFD yes no , CNL yes no SHOT - yes ..... no ...... CYBER yes no LOOK .... FMS yes no ML yes no cBL~.~ ,~s' '<~ no RF[ y'--~s n o ' / GYRO ~ IlO ,, t~L~ ¢~ yes no MUD yes no -SA~" yes ' no .(~/~ .... "CORE yes no .... CORED INTERVALS RECOVERED COMMENTS TO: THRU: MEMORANUUM Sta e of Alaska ALASKA OIL AND GAS CONSERVATION COMMISSION Lonnie C. Sm DATE: March 15, 1991 Commies loner - v FILE NO: HH315 - 7 TELEPHONE NO: SUBJECT: RTG/BOPE Inspection AAI KRU 3G-6/% Kuparuk Rv Field FROM: Harold R. Hawkins Petroleum Inspector~/~ Wednesdav Feb. 13 .... 1991: I performed a RIG/BOPE Inspection on AAI KRU 3G-6 well. The rig I inspected was Nordic #1. I informed GE Bean, AAI Co. man, and Lance Johnson, that when they complete the initial BOP test on a well, that all the BOP equipment tested should be listed on their BOP report FAXed into AOGCC. I also checked with George Bean about the blowdown lines. The new blowdown lines are built and are on location and will be connected on the first well that they may have to kill. I filled out an AOGCC BOPE walk-thru inspection report attached. In summary: I performed a RIG/BOPE inspection and talked to both the co. man for AAI and toolpusher for Nordic rig #1. They said the BOP test report would be filled out completely from now on and the blowdown lines will be nippled up on a well they may have to kill. Attachment. 02-00lA (Rev. 6/89) 20/ll/MEMOI.PM3 A. pass fail n/a ~.() () 2.() () 3.() () 4. ( ) ( ) 5.() () 6.() () 7.() () DIVERTER (') line sz & length () line conn& anchored (?~) bifurcated & dwn wind i/~) 90° targeted turns (,~t) vlvs: auto & simultaneous (.?) annul ar pack-off (~) condition B, 1. (,~) ( > 2. C~) ( ) 3.(~ () s.(I/) () 6.() () 7. (2) ( ) 9. (,:) ( ) ~o. ()0 () 11. g/) () 12. (~) ( ) ~3. C~') () 14. (~[) ( ) lS. ~! ( ) ,.. fail n/a BOP STACK ( ) wellhead flg wkg press ( ) stack wkg press ( ) annular preventer ( ) pipe rams ( ) blind rams ~ stack anchored ( ) chke/kill line sz ~ ( ) 90° turns t~eted (chke & kill In) ( ) manual vl~s (chke & kill) ( ) connections (flgd, whd, clmpd) ( ) drl spool ( ) flow nipple ( ) flow monitor ( ) control lines fire protected C. pass fail n/a ~. (_]i~~) 2. C:~:) 3. s. (?~) 6. 10. (~) ( ) CLOSING UNITS ( ) ( ) wkg press ( ) ( ) fluid level ( ) ( ) oprtg press ( ) ( ) press gauges ( ) ( ) sufficient vlvs ( ) ( ) regulator bypass ( ) ( ) 4-way vlvs (actuators) ( ) blind handle cover ( ) driller control panel ( ) remote control panel (if applc) RECORDS STATE OF ALASKA ALASKA 01L AND ~AS CON~ERVAT I ON COMM I SS I ON BOPE Walk-Thru Inspection Report 12. 13. ~ DATE: W% //~/~ / Representative ~ ~ ~ r, Permit # ~..2 ~ Representative /, ~ ,~,r~ ...... Rig (gen'l) n A'A ~ / ( ) ( ) firewall ( ) ( ) nitrogen po.er source (back-up) ( ) ( ) condition (leaks, hoses, D. pass fail n/a MUD SYSTEM 1. ( ) ( ) (~) pit level floats installed 2. ~ ( ) ( ] flow rate sensors 3-~) ( ) ( ) mud gas separator 4. ~) ( ) ( ) degasser 5. ~) ( ) ( ) separator bypass 6. (~) ( ) ( ) gas sensor 7. () ( ) ~[) chke In conn 8. ~ ( ) ( ) trip tank E. pass fail n/a RIG FLOOR 1. ~) ( ) ( ) kelly cocks (upper,lower,IBOP) 2. (~ ( ) ( ) floor vlvs (dart vlv, ball vlv) 3. (=]~, ( ) ( ) kelly & floor vlv wrenches (flow monitor flow rate indicator) 4. ( ) 7. (~,) driller's console (pit level indicators, gauges) ( ) ( ) kill sheet up-to-date ( ) ( ) gas ~etection monitors (H-S & methane) ( ) ( ) hydr chke panel ( ) ( ) chke manifold F. pass fail n/a 1.() 2. (~') 3.() ~.-() s.~/) 7. 8. ~X) MISC EQUIPMENT ( ) ~)[) flare line ( ) (~ vent line (). ( ) 90~ turns targeted ( ) ( ) (dwn strm choke lns) (.) ( ) reserve pit tankage ( ) ( ) personnel protective equip avail ( ) ( ) all drl site suprvs trained for procedures ( ) ( ) H2S probes ( ) ( ) rig housekeeping Date of last BOP inspection:~ ...... :' /-.~//(.. Date of last BOP test: : ) '" Resulting failures: BOP test & results properly entered on daily Peeo~d? ]':[~:' Kill sheet current? C.0013 (rev 01/17/91) STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon 2. Name of Operator Suspend _ Operation Shutdown X Re-enter suspended well _ Repair well _ Plugging _ Time extension _ Stimulate _ Pull tubing _ Variance _ Perforate _ Other _ 5. Type of Well' 6. Datum elevation (DF or KB) Development X.~ Exploratory _ Stratigraphic _ Service Alter casing _ Change approved program _ ARCO Alaska, Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510 (approx) 4. Location of well at surface 2538' FNL, 245' FWL, Sec. 24, T12N, R8E, UM At top of productive interval 1425' FSL, 925' FEL, Sec. 24, T12N, R8E, UM At effective depth NA At total depth 1355' FSL, 707' FEL, Sec. 24, T12N, R8E, UM 12. Present well condition summary Total Depth: Effective depth: (approx) measured 7910' feet Plugs (measured) (approx) true vertical 6204' feet None measured NA feet Junk (measured) (approx) true vertical NA feet None RKB 90' 7. Unit or Property name Kuparuk River Unit Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: Length Size 80' 16" 3707' 9 5/8" 7855' 7" measured None true vertical None Tubing (size, grade, and measured depth None Packers and SSSV (type and measured depth) None 13. Attachments Description summary of proposal_ 8. Well Number 3G-6 9. Permit number 90-69 10. APl number ~0-103-2~130 11. Field/Pool Kuparuk River Field Kuparuk River Oil Pool Cemented Measured depth 115' 875 Sx AS III & 3742' 485 Sx Class G 381 Sx Class G 7892' & 265 Sx Clas ~ ~ta[t' ' ~ Detailed operation program Status of well classification as:, Oil ;K Gas __ 15. Service 14. Estimated date for commencing operation November. 1990 16. If proposal was verbally approved Name of approver True vertical depth (approx) 115' 3105' 6188' Date approved 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ~ ~. ~~~. Title Area Drilling Engineer - ! FOR COMMISSION USE ONLY BOP sketch Conditions of approval: Notify Commission so representative may witness Plug integrity_ BOP Test_ Location clearance ~ Mechanical Integrity Test ~ Subsequent form require 10- Z/oZ-/ Suspended Date IApproval No. Commissioner Date SUBMIT IN TRIPLICATE Approvea Copy Returned ORIGINAL SIGNED 8Y LONNIE C. SMITH Approved by the order of the Commission Form 10-403 Rev 06/15/88 ARCO Oil a,.. Gas Company Well History - Initial Report - Daily Instructions: Prepare and submit the "Initial Report" on the first Wednesday after a well is spudded or workover operations ere started. Daily work prior to spudding should be summarized on the form giving inclusive dates only. District I County, parish or borough ARCO ALASKA INC. I~ NORTH SLOPE Field Lease or Unit KUPARUK RIVER ' J ADL: 25547 ALK: 2661 Auth. or W.O, no. ~Title AK4931 J DRILLING lState AK I Well no, KR~ 3G-06 Operator ARCO Spudded or W.O. begun SPUD I ARCO w i IDate IH°ur JJ 55.8533status if a w.o. 06/08/90 01: 30 iPri°r Date and depth as of 8:00 a.m. 06/08/90 (1) TD: 574' ( 574) SUPV:TAB 06/09/90 (2) TD: 3040' (2466) SUPV:TAB 06/10/90 (3) TD: 3762'( 722) SUPV:TAB 06/11/90 (4) TD: 4083' ( 321) SUPV:TAB 06/12/90 (5) TD: 6870'(2787) SUPV:TAB 06/13/90 (6) TD: 7617'( 747) SUPV:TAB 06/14/90 (7) TD: 7910' ( 293) SUPV: RWS Complete record for each day reported DOYON 14 DRLG MW: 9.2 VIS: 45 MOVE FROM 3G-09 TO 3G-06,NU DIVERTER, PU BHA, TEST DIVERTER, DRLG. MOVE RIG FROM 3G-09,NU DIVERTER, INSTALL MOUSE HOLE,MU BHA, TEST DIVERTER DRLG FROMli5 TO 574 DAILY:S48,793 CUM:$48,793 ETD:S48,793 EFC:$1,420,200 DRLG MW: 9.5 VIS: 59 DRLG FROM574 T/3040,REPAIR ELECT. PROBLEM ON CONVEYOR. DAILY:S62,416 CUM:$111,209 ETD:S111,209 EFC:$1,420,200 RD CMTR MW: 0.0 VIS: 0 DRLG F/3040 T/3762,CIRC, SHORT TRIP,CIRC, DROP SS,POH, LD BHA, RUN CSG, CIRC,CMT. DAILY:S132,692 CUM:$243,901 ETD:S243,901 EFC:$1,420,200 RIH MW: 9.5 VIS: 40 LD LANDING JT, INSTALL BRADEN HEAD,NU BOPE,TEST BOPE,PU BHA, CUT DRLG LINE, DRL FC AND 10' NEW FORMATION, TEST TO 13.8,OK, DRLG FROM 3772 TO 4083,CIRC AND COND,POH, STAND BACK BHA, PU TURBINE,RIH. DAILY:S141,833 CUM:$385,734 ETD:S385,734 EFC:$1,420,200 DRLG FINISH RIH,DRLG F/4083 T/6870 MW: 9.6 VIS: 37 DAILY:S56,284 CUM:$442,018 ETD:S442,018 EFC:$1,420,200 DRLG MW:11.0 VIS: 42 DRLG F/6870 T/7109,CBU, POH, TEST FORMATION TO 11.6,OK, POH TO CHANGE BHA, PICK UP ROTARY ASSY, RIH, BREAK CIRC,WT UP TO 11PPG, DRLG F/7109 T/7617. DAILY:S76,116 CUM:$518,134 ETD:S518,134 EFC:$1,420,200 CIRC @ 6500' MW:11.0 VIS: 46 DRLG F/ 7617 T/7910,SHORT TRIP,CIRC HOLE CLEAN, DROP SS,POH, LDDP,DUMP RLL, PULL WEAR RING, RUN 7" CSG, LOST RETURNS AT 6500' WHILE RIH, BREAK CIRC. The abov, e,,is Signature For form ~preparation a ~istribution, s.. ,o.' Drilling, Pages 86 and 87. ' / d ! ' AR3B-459-1-D INumber all daily well history forms consecutively as they are prepared for each well. Page no, · ARCO O,..nd Gas company Daily Well History-Final Report Instructions: Prepare and submit the "Final Report" on the first Wednesday after allowable has been assigned or well is Plugged, Abandoned, or Sold. "Final Report" should be submitted also when operations are suspended for an indefinite or appreciable length of time. On workovers when an official test is not required upon completion, report completion end representative test data in blocks provided. The "Final Report" form may be used for reporting the entire operation if space is available. District ARCO ALASKA INC. IAccounting cost center code State AK Field County or Parish NORTH SLOPE ]Lease or Unit KUPARUK RIVER I ADL: 25547 ALK: 2661 ! ]Title I DRILLING ]Well no, KR~ 3G-06 Auth, or W.O. no. AK4931 Operator A.R.Co. W.l. ARCO 55. 8533 Spudded or W.O. begun Date06/08 SPUD /90 Date and depth Complete record for each day reported as of 8:00 a.m. DoYoN 14 06/15/90 (8) TD: 7910 PB: 0 SUPV:RWS Old TD I New TD I Released rig J Date I Classifications (oil, gas, etc.) Producing method Potential test data Iotal number of wells (active or inactive) on this oat center prior to plugging and I bandonment of this well 1 our I Prior status if a W.O. 01:30 RIG RELEASED MW:ll.1 NaCl RIH WITH CASING, LOST CIRC WHILE RIH,CONT. RIH,RIG UP AND CMT 7" PROD.CASING, ND BOPE,CLEAR ANN. WITH DIESEL, RIG RELEASED 14-JUN-90 20:00. DAILY:S279,972 CUM:$864,278 ETD:S864,278 EFC:$1,420,200 IPB Depth IKind of rig IType completion (single, dual, etc.) Official reservoir name(s) 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 Effec!ive date corrected T. he above~.s correct For form preparat~-"and distribution, see Procedures Manual, Section 10, Drilling, Pages 86 and 87. AR3B-459-3-C Number all daily well history forms consecutively as they are prepared for each well. Page no. Dlvl~lon of AllanllcRIchfleldCompeny TO: M'EMOR ol Lonnie C. Smith Commissioner DATE: FILE NO: June 13, 1990 JT.HH.613.3 THRU: TELEPHONE NO: SUBJECT: BOP Test AAI KRU DS 3G-6 Permit No. 90-69 Kuparuk Rv Field FROM: Harold R. Hawkins Petroleum Inspector Sunday June 10, 1990: I witnessed a BOP tests for AAI KRU DS 3G-6. ~here were no fa'ilu~es. I filled out an AOGCC field report which is attached. In summary, the BOP Test on AAI KRU DS 3G-6 was performed satisfactorily. Attachment 02-00lA (Rev. 6/89) 20/ll/MEMOI.PM3 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION BOPE Inspection Report DATE Inspector Location: Sec ~2 ~ T TtZ . d. Location (general) ~}~ Well sign General housekeeping Rig # Rig Reserve pit 0/~ MUD SYSTEMS: Visual Trip tank Pit gauge Flow monitor Gas detectors Audio BOPE STACK: Test Pressure Annular preventer Pipe rams Blind rams Choke line valves HCR valve Kill line valves Check valve /~, Representative Tf/~ ~ ~ Casing set / ~ Rep ~1~ ACCUMULATOR SYSTEM: Full charge pressure 3~'~~) Press after closure /~ ~ Pump incr clos press 200 psig ~ Full charge press attained ~ Control s: Master ~/~ Remote ~ Blind switch cover KELLY AND FLOOR SAFETY VALVES: Upper Kelly Lower Kelly Ball type Inside BOP Choke manifold Number valves /~ Number flanges ,~ Adjustable chokes ~~ Hydraulically operated choke Test pressure Test pressure Test pressure Test pressure Test pressure mi n t~ . min 3~ ft psig psig sec sec TEST RESULTS: Failures /~/~/~*' Test time /,~/~ Repair or replacement of failed equipment to be made within ~-----days and Inspector/Commission office notified. Distribution: orig - AOGCC c - Operator c - Supervisor C.004 (rev 03/17/89) Inspector: June 1, !990 Telecopy: (907)276-7542 P. J. Archey Area Drilling Engineer ARCO Alaska, Inc. P. O. Box 100360 Anchorage, Alaska 99510-0360 Re: Kuparuk River Unit 3G-06 ARCO Alaska, Inc. Permit No. 90-69 Sur. Loc. 2538'FNL, 245'F%.~, Sec. 24, T12N, RSE, UM. Btmhole Loc. !355'FSL, 707'FEL, Sec. 24, T12N, RgE, Mr. Archly: Enclosed is the approved application for permit to drill the above referenced well. The permit to drill does not exempt you from obtaining additional permits required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permitting determinations are made. The Commission will advise you of those BOPE tests that it wishes to witness. ....V-.e~ry truly yours, Chai~n of Alaska Oil and Gas Conservation C~ission BY ORDER OF ~E CO~flSSION d!f Enclosure cc: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. STATE OF ALASKA AI_~,.,KA OIL AND GAS CONSERVATION COMMI~x.~,ON PERMIT TO DRILL 20 AAC 25.005 I la. Type of Work Drill X.. Redrill -- J lb. Type of Well Exploratory__ Stratigraphic Test _ Development Oil .~X Re-Entry _ Deepen --I Service _ Development Gas __ Single Zone ~X Multiple Zone _ 2.. Name of Operator 5.Datum Elevation (DF or KB) 10. Field and Pool ARCO Alaska1 Inc. RKB 90'1 Pad 54' GL feet Kuparuk River Field 3. Address 6. Property Designation Kuparuk River Oil Pool P. O. Box 100360, Anchorage, AK 99510-0360 ADL 25547 ALK 2661 4. Location of well at surface 7. Unit or property Name 11. Type Bond (see 20 AAC 25.025) 2538' FNL, 245' FWL, Sec. 24, T12N, R8E, UM KuDarpk River Unit At top of productive interval (TARGET) 8. Well number Number 1425' FSL, 925' FEL, Sec. 24 , T12N, R8E, UM 3G-00 #U630610 At total depth 9. Approximate spud date Amount 1355' FSL, 707' FEL, Sec 24, T12N, RSE, UM 06-4-90 $200,000 12. Distance to nearest 13. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and TVD) property line 3G-08 7906MD 707' @ TD feet 25' at surface feet 2560 6093VD feet 16. To be completed for deviated wells 17. Anticipated pressure (see 20 AAC 25.035(e)(2)) kickoff depth 800 feet Maximum hole angle 45° Maximum surface 1 81 1 psig At total depth (-rVD) 5700' 3500 psig 18. Casing program Setting Depth size Specification Top Bottom Quantity of cement Hole Casing Weight Grade Coupling Length ND TVD ~ TVD (include sta~le data/ 24 16" 62.5# H-40 Weld 80' 35' 35' 115' 115' _+200 Cu. Ft. 12.25 9.625 36.0# J-55 BTC 3593' 35' 35' 3593' 3060 1698 Cu. Ft. AS III & ~-~,~ 560 Cu. Ft. Class G 8.5 7" 26.0# J-55 BTC 7906' 35' 35' 7906' 6093' 235Cu. Ft. ClassG HF-ERW Top 500' above Kuparuk 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured feet Plugs (measured) true vertical feet Effective depth: measured feet Junk (measured true vertical feet Casing Length Size Cemented Measured depth True Vertical depth Structural sOu%U: RECEiVEil,. Intermediate Production Liner ~' ~ ' '3 '.:) Perforation depth: measured ~% ~ . ~ ~,.~sk~ .0il & Gas Cons. Commissior~ true vertical · '" ' ~nch0rage 20. Attachments Filing fee ~ Property plat __ BOP Sketch ~ Diverter Sketch ~ Drilling program ~ Drilling fluid program ~ Time vs depth plot __ Refraction analysis _ Seabed report _20 AAC 25.050 requirements ~ 21. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed ~~ .'~.//~~ Title Area Drilling Engineer Date ,-~'/2~?/~ Commission Use Only Permit Number J APl number I Appr°val date 06 / 01/90 I See cover letter for ~'~c~ --~'~ ~' 50-/'~ ~-- ~__,(~),~,~ ~ other rec{uirements Conditions of al~proval Samples required ~Y e s ~ N o Mud Icg requi~ed ~ Y e s ,,~ N o Hydrogen sulfide measures~ Yes ~"N o Directional survey required ,,~'Yes ~ N o Required working pressure for BOPE ~2M; ~ 3 M' ~ 5M' ~ 1 0 M' ~ 1 5 M by order of Approved by __ Commissioner the commission Date Form 10-401 R, / / / n triplicate GENERAL DRILLING PROCEDURE KUPARUK RIVER FIELD 3G PAD I , . . . . . 7, Si , 10. 11. 12. 13. 14. 15. 16. 17. 18. 19. 20. 21. Move in and rig up Doyon 14. Install diverter system. Drill 12-1/4" hole to 9-5/8" surface casing point according to directional plan. Run and cement 9-5/8" casing. Install and test BOPE. Test casing to 2000 psi. Drill out cement and 10' of new hole. Perform leak off test. Drill 8-1/2" hole to logging point according to directional plan. Run open hole evaluation logs or RLL as needed. Run and cement 7" casing. Pressure test to 3500 psi. ND BOPE and install temporary production tree. Secure well and release rig. Run cased hole cement evaluation and gyro logs Move in and rig up Nordic #1. Install and test BOPE. Perforate and run completion assembly, set and test packer. ND BOPE and install production tree. Change over to diesel Shut in and secure well. Clean location and release rig. Fracture stimulate well. Reperforate and add additional perfs. .ARCO ALASKA, !ne, Pe~I 30, Well No8 6 Propoeed Kuparuk Field, North Slope, Aleeke 0 'Il -RK-B-KoP'EL--EVT ^--~-TVDI=,O~N8 -'OO9°--'TMD=,800 DEP=O 1 000 2000 m 3000 m o 4000 rtl 3 BUILD 3 DEO g PER 100 FT B/ PERMAFROST TVD=1605 TMD=1631 DEP=I?8 27 T/ UONU SNDS TVD=1795 TMD=1847 DEP=280 39 45 EOC TVD=2158 TMD=2310 DEP=567 T! W SAK SNDS TVD=2400 TMD=2655 DEP=812 B/ W SAK SNDS TVD=2860 TMD=3309 DEP=1277 9 5/8' CSO PT TVD=3060 TMD=;Ssg3 DEP=1479 K-lO TVD-3325 TMD-3970 DEP-1747 5000 AVERAGE ANGLE 45 DEG 19 HI N K-5 TVD=4710 TMD=5g40 DEP=3147 6000 (LO0 PT) 7000 I I ZONE C TVD=5780 THD=7461 DEP=4229 ZONE A TVD=5835 TMD=7537 DEP=4282 CNTR TVD=5866 THD=7584 DEP=4316 TVD=5952 TMD=7706 DEP=4403 TVD=6093 TMD=7906 DEP=4545 Oil a {las Cons. Comraissio;~ Anchora~ I I I I 1000 2000 ;~000 4000 5000 VERTICAL SECTION 1000 SURFACE LOCAT [ ON, 2538' FNL. 245' FWL SEC. 24. TI2N. RSE z ~ 1 000 _ 2000 _ :3OO0 _ HORI ZONT^L PROJECT I ON SCALE 1 IN. = 1000 FEET ARt~D ALASKA. I.~. Paci :3G. Wel I No' 6 Proposed Kupmruk Field. Nor~:h Slope. Alaska 10C~O WEST-EAST 0 1 000 2000 :3000 4000 I I I I I Y~ TVD=5866 TIID-?584 DEP-,k316 5000 I SOUTH 1317 EAST 4110 TAROET LOCAT ! ON, 1425' FSL. 925' FEL SEC. 24. T12N. RSE S 72 DEO 14 MI N £ 4316' (TO TARGET) TD LOCAT ! ON, 135'5' FSL. 7'07' FEL SEC. 24. TI2N. R"SE 50 1 O0 ~ 50 200 250 300 350 1400 450 2400 2450 2500 2550 2600 2650 270O j, , ',~00 i 100 '"%,3700 *.300 '~\$00 roo \ \ \ \ ',. ~9~o~oo I 150 I 2OO / / "1 $00 / / 1100 !31:!~ "~00..~11~0 1300 1500 1700 O0 / ,,,, ,,"1700 250 1900 300 i 350 ,500 I 400 i I - I I 450 2400 _ 2450 2550 2600 26.=,- 2700 .JF~RUK RIVER UN 20" DIVERTER SCHEMATIC 5 6 4 3 ( ' C~ 0 ' 2 DO NOT SHUT IN WELL UNDER ANY CIRCUMSTANCES MAINTENANCE & OPERATION . , . UPON INITIAL INSTALLATION, CLOSE PREVENTER AND VERIFY THAT VALVE OPENS PROPERLY. CLOSE ANNULAR PREVENTER AND BLOW AIR THROUGH DIVERTER LINES EVERY 12 HOURS. CLOSE ANNULAR PREVENTER IN THE EVENT THAT AN INFLUX OF WELLBORE FLUIDS OR GAS IS DETECTED. OPEN APPROPRIATE VALVE TO ACHIEVE DOWNWIND DIVERSION. ARCO ALASKA, INC., REQUEST S APPROVAL OF THIS DIVERTER SYSTEM AS A VARIANCE FROM 20AAC25.035(B) 1. 16" CONDUCTOR 2. SLIP-ON WELD STARTING HEAD 3. FMC DIVERTER ASSEMBLY WITH TWO 2-1/16"- 2000 PSI BALL VALVES 4. 20" - 2000 PSI DRILLING SPOOL WITH TWO 10" OUTLETS. 5. 10" HCR BALL VALVES WITH 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 SRE 2/6/ 7 6 5 4 I3 13 5/8" 5000 , .51 bOP STACK ACCUMULATOR CAPACITY TEST 1. CHECK AND FILL ACCUMULATOR RESERVOIR TO PROPER LEVEL W1TH HYDRAUUC FLUID. 2. ASSURE THAT ACCUMULATOR PRESSURE IS 3000 PSI WITH 1500 PSI DOWNSTREAM OF THE REGULATOR. 3. OBSERVE TIME, THEN CLOSE ALL UNITS SIMULTANEOUSLY AND RECORD THE TIME AND PRESSURE REMAINING AFTER ALL UNITS ARE CLOSED WITH CHARGING PUMP OFF. 4. RECORD ON THE IADC REPORT. THE ACCEPTABLE LOWER LIMIT IS 45 SECONDS CLOSING TIME AND 1200 PSI REMAINING PRESSURE. BOP STACK TEST 1. FILL BOP STACK AND MANIFOLD WITH ARCTIC DIESEL. 2. CHECK THAT ALL HOLI~DOWN SCREWS ARE FULLY RETRACTED. PREDETERMINE DEPTH THAT TEST PLUG WILL SEAT AND SEAT IN WELLHEAD. RUN IN LOCK-DOWN SCREWS IN HEAD. 3. CLOSE ANNULAR PREVENTER AND CHOKES AND BYPASS VALVES ON THE MANIFOLD. ALL OTHERS OPEN. 4. TEST ALL COMPONENTS TO 250 PSI AND HOLD FOR 10 MINUTES. INCREASE PRESSURE TO 3(X)O PSI AND HOLD FOR 10 MINUTES. BLEED TO ZERO PSI. 5. OPEN ANNULAR PREVENTOR AND MANUAL KILL AND CHOKE LINE VALVES. CLOSE TOP PIPE RAMS AND HCR VALVES ON KILL AND CHOKE LINES. 6. TEST TO 250 PSI AND 3000 PSI AS IN STEP 4. 7. CONTINUE TESTING AL VALVES, LINES, AND CHOKES WITH A 250 PSI LOW AND 3(X)O PSI HIGH. TEST AS IN STEP 4. DO NOT PRESSURE TEST ANY CHOKE THAT IS NOT A FULL CLOSING POSITIVE SEAL CHOKE. 8. OPEN TOP PIPE RAMS AND CLOSE BOTFOM PIPE RAMS. TEST BOTTOM RAMS TO 250 PSI AND 3000 PSI. 9. OPEN PIPE RAMS. BACKOFF RUNNING JT AND PULL OUT OF HOLE. CLOSE BLIND RAMS AND TEST TO 3000 PSI FOR 10 MINUTES. BLEED TO ZERO PSI. 10 OPEN BLIND RAMSAND RECOVER TEST PLUG. MAKE SURE MANIFOLD AND UNES ARE FULL OF ARCTIC DIESEL AND ALL VALVES ARE SET IN THE DRILLING POSITION. 11. TEST STANDPIPE VALVES TO 3000 PSI. 12. TEST KELLY COCKS AND INSIDE BOP TO 3000 PSI WITH KOOMEY PUMP. 13. RECORD TEST INFORMATION ON BLOWOUT PREVENTER TEST FORM. SIGN AND SEND TO DRILLING SUPERVISOR. 14. PERFORM COMPLETE BOPE TEST ONCE A WEEK AND FUNCTIONALLY OPERATE BOPE DAILY. 1. 16" - 2000 PSI STARTING HEAD 2. 11" - 3000 PSI CASING HEAD 3. 11" - 3000 PSI X 13-5/8" - 5(XX) PSI SPACER SPOOL '4. 1;~5/8" - 5000 PSI PIPE RAMS 5. 13~5/8" - 5000 PSI DRLG SP(:X3L W/ CHOKE AND KILL LINES 6. 1:~5/8" - 5000 PSI DOUBLE RAM W/ PIPE RAMS ON TOP, BLIND RAMS ON BTM 7. 1:~5/8" - 5000 PSI ANNULAR SRE 8/22/8g DOYON 14 DRILLING FLUID PROGRAM (3G-06) Spud to 9-5/8" Drill out to surface casino weioht UO Density 8.6-10.0 8.6-9.3 PV 15-35 5-15 YP 15-35 5-8 Viscosity 50-100' 30-40 Initial Gel 5-15 2-4 10 Minute Gel 1 5-4 0 4- 8 APl Filtrate 1 0-1 2 8-1 0 pH 9-10 8.5-9 % Solids 10 +/- 4- 7 Weight up 11.3 10-18 8-12 35-50 2-4 4-8 4-5 9.0-9.5 10-12 Drillin(] Fluid System: -- - Triple Tandem Shale Shaker - (2) Mud Cleaners - Centrifuge - Degasser - Pit Level Indicator (Visual and 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 0.11 psi/ft. This shows that formation breakdown would occur before a surface pressure of 1825 psi could be reached. Therefore, ARCO Alaska, Inc. will test the BOP equipment to 3000 psi. - The nearest well to 3G-06 is 3G-08. As designed, the minimum distance between the two wells would be 50' at surface. The wells would diverge from that point. 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 shut down in pumping operations. The annulus will be sealed with 175 sx of cement followed by arctic pack upon completion of fluid pumping. * Spud mud should be adjusted to a funnel viscosity between 100-120 to drill gravel beds. CHECK LIST FOR NEW WELL PERMITS ITEM APPROVE DATE (8) (3) Admin/~ .//'~,n/"g;~-) 9. (9-thru f3) ' ' 10. (10 and 13): '' 12. 13. (5) BOPE (23 thru ~8)' Company Lease & Well No. YES NO P~,S Is the permit fee attached .......................................... 2. Is well td be located in a defined pool ............................. 3. Is well located proper distance from property line .................. 4. Is well located proper distance from other wells .................... 5. Is sufficient undedicated acreage available in this pool ............ 6. Is well. to be deviated and is wellbore plat included ................ 7. Is operator the only affected party ................................. 8. Can permit be approved before fifteen-day wait ...................... Does operator have a bond in force .................................. Is a conservation order needed ...................................... Is administrative approval needed ................................... Is the lease number appropriate ..................................... Does the well have a unique name and number ......................... 14. 15. 16. 17. 18. 19. 20. 21. 22. 23. 24. 25. 26. 27. 28. Is conductor string provided ........................................ Will surface casing protect all zones reasonably expected to serve as an underground source of drinking water ..................... Is enough cement used to circulate on conductor and surface ......... ~_ Will cement tie in surface and intermediate or production strings ... Will cement cover all known productive horizons ..................... Will all casing give adequate safety in collapse, tension and burst.. Is this well to be kicked off from an existing wellbore ............. Is old wellbore abandonment procedure included on 10-403 ............ Is adequate wellbore separation proposed ............................ -~ Is a diverter system required ....................................... Is the drilling fluid program~-a~and list of equipment adequate-~ Are necessary diagrams and descriptions of diverter and BOPE attached. Does BOPE have sufficient pressure rating - Test to_~~ psig .. Does the choke manifold comply w/API RP-53 (May 84) .................. _~ Is the presence of H2S gas probable ................................. (6) o~ ~(2'~ tn~ 3-~) Geology: EngSneering: D;,u M- LCS : rev: 6.011 · 01/30/89 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 ............................................. ~ Additional Remarks~ INITIAL GEO. UNIT ON/OFF POOL CLASS STATUS AREA NO. SHORE ,,, C ~ C Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information, of this nature is accumulated at the end of the file under APPENDIX. ,. No special 'effort has been made to chronologically organize this category of information. .o ** FILE HEADER ** FILE NAME: 3G6.MWD SERVICE NAME: RLL VERSION #: V 2.40 DATE: 90 / 06 / 18 MAX. RECORD LENGTH: FILE TYPE: EO PREVIOUS FILE NAME: ** COMMENTS ** FILE SEQUENCE # 1 COMPANY: ARCO ALASKA INC.// WELL: 3G-06// API#: 50-103-20130// DATE: 6/13/99 LOCATION: 2538' FNL & 245' FEL, SEC. 24, TWP. 12N, RANGE 8E, NORTH SLOPE BOROUGH, ALASKA, USA.// RIG: DOYON 14// CO. REP.: T. BILLINGSLEY// RLL ENG.: GALVIN & BROWN// COMMENTS **>> NEUTRON AND DENSITY LOGS ARE CALIPER CORRECTED AND PROCESSED ASSUMING A SANDSTONE MATRIX @ 2.65 GM/CC, FORMATION WATER @ 14,545 PPM CL, FLUID DENSITY = 1.0 GM/CC AND MUD SALINITY = 1,200 PPM. DATA IN NON-ROTATING (SLIDING) INTERVALS IS NOT QUANTITATIVE (SEE BLUELINE LABELS). ** DATA FORMAT SPECIFICATION ** ENTRY BLOCKS TYPE SIZE REP CODE ENTRY 4 1 66 255 0 1 66 DESCRIPTION LOG DIRECTION, DOWN TERMINATOR (NO MORE ENTRIES) DATUM SPECIFICATION BLOCKS NAME SERVICE SERVICE UNIT API API API API FILE SZE PROC SPL REPR ID ORDER# DEPT FT 0 RHOB MWD G/C3 0 NPSC MWD P.U. 0 NFO MWD CTS 0 NFl MWD CTS 0 NN0 MWD CTS 0 NN1 MWD CTS 0 EWR MWD OHMM 0 ROP MWD FT/H 0 FXE MWD HOUR 0 GRC MWD API 0 CAL MWD INCH 0 DP. NO MWD G/C3 0 LOG TYP CLS MOD NO. LVL CODE 0 0 0 1 4 0 1 %68 0 0 0 1 4 0 1 68 0 0 0 1 4 0 1 68 0 0 0 1 4 0 1 68 0 0 0 1 4 0 1 68 0 0 0 1 4 0 1 68 0 0 0 1 4 0 1 68 0 0 0 1 4 0 1 68 0 0 0 1 4 0 1 68 0 0 0 1 4 0 1 68 0 0 0 1 4 0 1 68 0 0 0 1 4 0 1 68 0 0 0 1 4 0 1 68 ** DATA FORMAT SPECIFICATION ** (NOTE: **** LIS READ **** MAXIMUM RECORD LENGTH - 8192 BYTES) ** REEL HEADER ** REEL SEQUENCE # 1 SERVICE NAME: SSDS DATE: 90/06/18 ORIGIN OF DATA: RLL REEL NAME: ARCO CONTINUATION #: 01 PREVIOUS REEL NAME: COMMENTS: PETROLEUM COMPUTING INC.- LIS FORMAT ** TAPE HEADER ** SERVICE NAME: RLL DATE: 90/06/18 ORIGIN OF DATA: 3G-6 TAPE NAME: KUPARUK CONTINUATION #: 01 PREVIOUS TAPE NAME: COMMENTS: PETROLEUM COMPUTING INC.- LIS FORMAT ********** END OF FILE (EOF # 1) ********** TYPE SIZE REP CODE 4 1 66 0 1 66 ENTRY 255 DESCRIPTION LOG DIRECTION, DOWN TERMINATOR (NO MORE ENTRIES) DATUM SPECIFICATION BLOCKS NAME SERVICE SERVICE UNIT API API API API FILE SZE PROC SPL REPR ID DEPT RHOB MWD NPSC MWD NFO MWD NFl MWD NN0 MWD NN1 MWD EWR MWD ROP MWD FXE MWD GRC MWD CAL MWD DRHO MWD ORDER# LOG TYP CLS MOD NO. LVL CODE FT 0 0 0 0 1 4 0 1 68 G/C3 0 0 0 0 1 4 0 1 68 P.U. 0 0 0 0 1 4 0 1 68 CTS 0 0 0 0 1 4 0 1 68 CTS 0 0 0 0 1 4 0 1 68 CTS 0 0 0 0 1 4 0 1 68 CTS 0 0 0 0 1 4 0 1 68 OHMM 0 0 0 0 1 4 0 1 68 FT/H 0 0 0 0 1 4 0 1 68 HOUR 0 0 0 0 1 4 0 1 68 API 0 0 0 0 1 4 0 1 68 INCH 0 0 0 0 1 4 0 1 68 G/C3 0 0 0 0 1 4 0 1 68 ** DATA DEPT EWR VERIFICATION (every 500 FT) RHOB NPSC NFO ROP FXE GRC 3600.000 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 4000.000 4.484 2.250 37.854 611.000 109.597 1.237 87.520 4500.000 3.583 2.290 35.931 647.000 300.315 .413 98.478 5000.000 3.144 2.360 35.020 624.832 335.363 .746 86.332 5500.000 2.248 6000.000 3.703 NFl NN0 CA/5 DRHO 6500.000 3.991 -999.250 -999.250 -999.250 -999.250 7000.000 3.361 611.000 2536.000 8.760 .001 7500.000 4.585 599.000 2616.000 8.950 .007 602.335 2737.330 8.730 .000 2.380 36.775 639.000 647.000 2552.000 332.373 .649 127.162 8.770 .000 2.400 39.216 663.000 226.538 .473 125.143 2.240 32.648 674.927 181.230 .908 89.910 2.410 37.601 605.170 66.094 1.009 139.689 2.450 32.659 692.171 98.295 .695 80.543 ** 461 DATA RECORDS ** FROM ** FILE TRAILER** FILE NAME: 3G6.MWD SERVICE NAME: RLL VERSION #: V 2.40 DATE: 90/06/18 MAX. RECORD LENGTH: FILE TYPE: EO NEXT FILE NAME: 1024 543.000 2520.000 8.620 -.006 679.088 2746.897 8.730 -.002 586.744 2581.532 9.070 .011 665.520 2825.981 8.790 .003 3600.00 TO 7975.00 FT NN1 -999.250 2568.000 2664.000 2666.661 2568.000 2472.000 2749.085 2604.936 2733.277 ********** END OF FILE (EOF # 2) ********** ** TAPE TRAILER** SERVICE NAME: RLL DATE: 90/06/18 ORIGIN OF DATA: 3G-6 TAPE NAME: KUPARUK CONTINUATION #: 01 NEXT TAPE NAME: COMMENTS: PETROLEUM COMPUTING INC.- LIS FORMAT ** REEL TRAILER ** SERVICE NAME: DATE: 90 / 06 / 18 ORIGIN OF DATA: REEL NAME: ARCO CONTINUATION #: NEXT REEL NAME: COMMENTS: ssDs RLL O1 PETROLEUM COMPUTING INC.- LIS FORMAT
