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Home My WebLink About180-081 • • WELL LOG TRANSMITTAL To: Alaska Oil and Gas Conservation Comm. January 19, 2011 Attn.: Christine Shartzer 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 I RE: Plug Setting Record: 1E-08 V'` `� F EB all Run Date: 1/11/2011 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Rafael Barreto, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 1E -08 Digital Data in LAS format, Digital Log Image file 1 CD Rom 50- 029 - 20496 -00 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline & Perforating Attn: Rafael Barreto 6900 Arctic Blvd. / [) -O / 90629 d Anchorage, Alaska 99518 Office: 907 - 273 -3527 Fax: 907- 273 -3535 rafael.barreto hallibtirton:corn = Date: Signed: �, • • WELL LOG TRANSMITTAL To: Alaska Oil and Gas Conservation Comm. December 20, 2010 Attn.: Christine Shartzer 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: Down Hole Video: 1E-08 Run Date: 12/1/2010 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Klinton Wood, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 1E -08 Digital Video File (AVI) 1 DVD Rom 50- 029 - 20496 -00 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline & Perforating Attn: Klinton Wood $ I 6900 Arctic Blvd. j7 ■ Anchorage, Alaska 99518 1) 5 Office: 907 - 273 -3527 Fax: 907 - 273 -3535 klinton.wo . 11•xg Date: Signed: • . II WELL LOG 1 __ $ TRANSMITTAL PROACTIVE Diagnomic SERVICES, INC. To: AOGCC Christine Mahnken 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 (907) 659 -5102 RE : Cased Hole /Open Hole /Mechanical Logs and /or Tubing Inspection(Caliper / MTT) The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the following : `. ProActive Diagnostic Services, Inc. Attn: Robert A. Richey 130 West International Airport Road Suite C D�d Anchorage, AK 99518 tN F Fax: (907) 245 -8952 1 Miser Resort 29-Nov-10 1R-14 1 Report / EDE 50 -029- 21386 -00 2) Caliper Report 04- Dec-10 1E-08 1 Report / EDE 50 -029- 20496-00'' 1 f o -cue l 9O - ( 2 `�5 -i 054' . 0 Signed : O Print Name: PROACTIVE DIAGNOSTIC SERVICES, INC., 130 W. INTERNATIONAL AIRPORT RD SUITE C, ANCHORAGE, AK 99518 PHONE: (907)245 -8951 FAx: (907)245 -88952 E : pdsanchoratle(C )mernortlog.corn WEBSITE : www.nternoryioq.corn C:\Documents and SettingslDiane Williams \Desktop \Transmit_Conoco.docx • I • • I r .� - iip Multi- Finger Caliper �..J Log Results Summary Company: ConocoPhillips Alaska, Inc. Well: 1E -08 Log Date: December 4, 2010 Field: Kuparuk Log No.: SO# 10292832 K200 State: Alaska I Run No.: 2 API No.: 50-029-20496-00 Pipet Desc.: 7" 26 lb. K -55 Top Log Intvll: Surface Pipet Use: Production Casing Bot. Log Intvll: 6,865 Ft. (MD) Inspection Type : Corrosive and Mechanical Damage Inspection COMMENTS : I This caliper data is correlated to the SLB BCS Log (Gamma Ray) dated October 23, 1980. This log was run to assess the condition of the production casing with respect to corrosive and mechanical I damage, particularly in the vicinity of the proposed cement retainer setting depth at — 6,770'. The caliper recordings indicate the 7" production casing appears to be in good condition in the vicinity of 6,770' with no significant wall penetrations, areas of cross - sectional wall loss or I.D. restrictions recorded. A 3 -D log plot of the caliper recordings from 6,700' to 6,865' (end of log) is included in this report. I The caliper recordings indicate the remainder of the 7" production casing logged appears to be in good to fair condition with respect to corrosive and mechanical damage, with a maximum recorded wall penetration of 33% recorded in a line of pits in joint 144 (5,673'). Additional wall penetrations ranging from 20% to 29% I wall thickness are recorded in 6 of the 174 joints logged. Recorded damage appears as a line of pits and isolated pitting. No significant areas of cross - sectional wall loss or I.D. restrictions are recorded throughout the production casing logged. I This is the second time a PDS caliper has been run in this well and the first time the 7" production casing has been logged. I This summary report is interpretation of data collected by Halliburton Well Services using a 40-arm caliper provided by Proactive Diagnostic Services, Inc. I MAXIMUM RECORDED WALL PENETRATIONS : Line of Pits ( 33 %) Jt. 144 @ 5,673 Ft. (MD) Line of Pits ( 29 %) Jt. 145 @ 5,704 Ft. (MD) I Line of Pits ( 28 %) (26 %) Jt. 149 @ 5,875 Ft. (MD) Line of Pits Jt. 147 @ 5,812 Ft. (MD) Line of Pits ( 23 %) Jt. 167 @ 6,600 Ft. (MD) 111 MAXIMUM RECORDED CROSS - SECTIONAL METAL LOSS : No significant areas of cross - sectional wall loss (> 4 %) are recorded throughout the production casing I logged. MAXIMUM RECORDED ID RESTRICTIONS : 1 No significant I.D. restrictions are recorded throughout the production casing logged. I I Field Engineer: J. Conrad Analyst: C. Waldrop Witness: D. Rowell ProActive Diagnostic Services, Inc. / P.O, Box 1369, Stafford, TX 77497 Phone: (281) or (888) 565 -9085 Fax: (281) 565 -1369 E -mail: PDS@memorylog.com Prudhoe Bay Field Office Phone: (907) 659 -2307 Fax: (907) 659 -2314 I I i to -o t ( Q0,6 I • • PDS Multifinger Caliper 3D Log Plot I Company : ConocoPhillips Alaska, Inc. Field : Kuparuk Well : 1E-08 Date : December 4, 2010 1 Description : Detail of Caliper Recordings Across Proposed Cement Retainer Setting Depth (-6,770) Comments Depth Max. Pen. ( %) Maximum I.D. 3-0 Log Image Map I i 1ft:280ft 0 100 6 inches 7 0° 0° 90° 180° 270° 0° I I Minimum I.D. I 6 inches 7 Nominal I.D. 1 6 inches 7 yr vv ■q1♦ T St II >•M�� 6710 ■ 3 a aIMIIIIIIIIIIIIIIIIM IIIIIIIIINIMINIIIIIIIIIIN 9)•111•1111111111•1111• 1 DH1111•11111111111111111MMI •a-. ..... Joint 170 6720 , =ieaIM=MINES =5 EIIMMIIIIIIIIM=I= _.INIM_____ 11111i.... 6730 =.b =i� it 6740 ail a Joint 171 I Proposed - -- Cement Retainer 6750 Setting Depth il h (- 6,770') 6760 - - - - --- — I , if III 6770 I — I 6780 --- - ---- -- i 1 Joint 172 6790 J " 6800 I - - -- , IP II it 6810 1_ - -- a 1 I 6820 — 4--6---- Joint 173 6830 I - t_ 6840 _.z..,,, " 1ILI . _ I 6850 i - - - - -- Joint 174 ' 6860 - -- I .ice I I 1 • • Correlation of Recorded Damage to Borehole Profile I ® Pipe 1 7. in (35.0' - 6864.7') Well: 1 E -08 Field: Kuparuk Company: ConocoPhillips Alaska, Inc. I Country: USA Survey Date: December 04, 2010 I I . Approx. Tool Deviation . Approx. Borehole Profile 1 38 I 25 1026 i 50 2020 75 2980 E c Z eL I 5 100 3904 CS I 125 4892 I I 150 5893 I 174.1 6865 0 50 100 I Damage Profile (% wall) / Tool Deviation (degrees) I Bottom of Survey = 174.1 I I I • 0 I PDS Report Overview � Body Region Analysis I Well: 1E-08 Survey Date: December 04, 2010 Field: Kuparuk Tool Type: UW MFC 40 Ext. No. 213120 Company: ConocoPhillips Alaska, Inc. Tool Size: 2.75 I Country: USA No. of Fingers: 40 Tubing: 7 ins 26 ppf K -55 Analyst: C. Waldrop Tubing: Nom.OD Weight Grade & Thread Nom.ID Nom.Upset Upper len. Lower len. 7 ins 26 ppf K -55 6.276 ins 7 ins 6.0 ins 6.0 ins I Penetration(% wall) Damage Profile (% wall) 200 Penetration body Metal loss body 0 50 100 0 1 150 100 I 50 0 4 I 0 to 20 to 40 to over ,- 20% 40% 85% 85% Number of joints analysed (total = 175) I 168 7 0 0 L I Damage Configuration ( body) 20 100_- I 15 10 1 5 0 150= I Isolated General Line Other Hole/ _ Pitting Corrosion Corrosion Damage Pos. Hole It I Number of joints damaged (total = 20) 20 0 0 0 0 Bottom of Survey = 174.1 I I I I 1 • • PDS REPORT JOINT TABULATION SHEET I Pipe: 7. in 26.0 ppf K -55 Well: 1 E -08 Body Wall: 0.362 in Field: Kuparuk Upset Wall: 0.362 in Company: ConocoPhillips Alaska, Inc. I Nominal I.D.: 6.276 in Country: USA Survey Date: December 04, 2010 I Joint Jt. Depth Pen. Pen. Pen. Metal Min. Damage Profile No. (Ft.) Upset Body % Loss I.D. Comments (% wall) (Ins.) (Ins.) % (Ins.) 0 50 100 I 0.1 35 0 0.02 6 2 6.28 Pup 1 38 0 0.03 8 2 6.28 2 79 0 0.03 8 2 6.27 3 119 0 0.03 7 2 6.27 4 158 0 0.02 6 2 6.29 I 5 200 0 0.02 6 1 6.29 6 243 0 0.02 6 2 6.28 7 284 0 0.03 7 2 6.25 II 8 324 0 0.02 6 1 6.29 1 I 9 366 0 0.03 8 2 6.29 s 10 408 0 0.03 7 2 6.28 IN 11 450 0 0.03 8 2 6.23 IN 12 491 0 0.03 7 2 6.26 I 13 532 0 0.02 6 1 6.27 14 571 0 0.02 7 2 6.29 15 612 0 0.02 6 1 6.29 o 16 654 0 0.03 7 2 6.28 1 17 696 0 0.03 7 1 6.29 o I 18 737 0 0.02 7 1 6.29 19 779 0 0.03 8 1 6.27 II • 20 820 0 0.03 8 1 6.27 1 21 861 0 0.03 7 1 6.28 1 I 22 903 0 0.03 8 2 6.27 U 23 943 0 0.03 7 1 6.26 24 985 0 0.03 8 2 6.27 • 25 1026 0 0.02 6 2 6.27 i I 26 1065 0 0.03 7 2 6.25 ii 27 1101 0 0.02 4 1 6.27 ii 28 1140 0 0.04 10 1 6.29 • 29 1181 0 0.02 6 1 6.25 I 30 1224 0 0.03 7 2 6.25 31 1264 0 0.02 7 2 6.25 C 32 1306 0 0.02 6 2 6.25 33 1342 0 0.03 7 2 6.27 34 1384 0 0.02 6 1 6.25 I 35 1423 0 0.02 6 1 6.28 36 1459 0 0.03 9 2 6.19 Lt. Deposits. 37 1498 0 0.03 7 2 6.25 38 1539 0 0.03 8 3 6.23 I 39 1579 0 0.03 8 2 6.24 40 1621 0 0.03 9 2 6.23 41 1660 0 0.03 7 1 6.23 • 42 1699 0 0.05 14 2 6.24 Shallow Pitting. I 43 1739 0 0.02 6 3 6.28 i 44 1780 0 0.03 8 2 6.22 45 1817 0 0.03 7 2 6.25 46 1858 0 0.02 7 2 6.25 II 47 1899 0 0.02 6 1 6.25 1 II 48 1942 49 1980 0 0.03 8 1 6.25 • 0 0.03 7 2 6.25 • t I Metal Loss ion Body 1 I I • • PDS REPORT JOINT TABULATION SHEET I Pipe: 7. in 26.0 ppf K -55 Well: 1E-08 Body Wall: 0.362 in Field: Kuparuk Upset Wall: 0.362 in Company: ConocoPhillips Alaska, Inc. I Nominal I.D.: 6.276 in Country: USA Survey Date: December 04, 2010 I Joint it. Depth Pen. Pen. Pen. Metal Min. Damage Profile No. (Ft.) Upset Body % Loss I.D. Comments ( %wall) (Ins.) (Ins.) 0 /,, (Ins.) 0 50 100 I 50 2020 0 0.03 7 4 6.27 51 2058 0 0.03 8 2 6.25 52 2097 0 0.02 6 2 6.25 53 2137 0 0.03 7 1 6.27 54 2175 0 0.02 6 1 6.25 I 55 2213 0 0.03 9 2 6.24 56 2253 0 0.02 6 2 6.27 57 2295 () 0.02 6 2 6.25 58 2328 0 0.03 9 2 6.25 I 59 2363 0 0.03 8 2 6.24 60 2398 0 0.02 7 2 6.30 61 2433 0 0.03 9 2 6.28 62 2473 0 0.03 7 2 6.26 I 63 2513 0 0.03 7 2 6.26 64 2549 0 0.03 8 2 6.25 65 2590 0 0.03 9 2 6.22 66 2629 0 0.02 5 2 6.24 67 2668 0 0.02 7 2 6.25 68 2710 0 0.03 7 2 6.25 69 2747 0 0.03 8 4 6.25 70 2786 U 0.03 7 2 6.27 71 2827 0 0.03 9 2 6.24 72 2866 0 0.03 8 2 6.24 73 2905 0 0.03 8 2 6.27 74 2941 () 0.02 6 2 6.23 75 2980 0 0.03 8 2 6.27 76 3021 0 0.03 7 2 6.24 77 3059 0 0.03 8 2 6.26 78 3098 0 0.03 9 2 6.24 79 3137 0 0.02 6 1 6.25 80 3177 0 0.03 8 2 6.29 81 3217 0 0.04 11 2 6.28 82 3256 0 0.03 8 2 6.25 83 3294 0 0.03 7 2 6.29 84 3332 0 0.03 9 2 6.24 I 85 3372 0 0.03 8 1 6.27 86 3413 0 0.03 7 2 6.28 87 3449 0 0.03 8 1 6.28 88 3491 t) 0.02 6 2 6.28 I 89 3524 90 3561 0 0.02 7 1 6.24 0 0.03 9 2 6.26 91 3603 0 0.03 8 2 6.25 92 3641 0.04 0.04 10 3 6.20 I 93 3679 0 0.04 10 3 6.26 94 3714 0 0.02 7 2 6.24 95 3752 0 0.03 7 1 6.25 Marker Joint 96 3772 0 0.03 7 1 6.26 Marker Joint 97 3790 0 0.03 8 3 6.26 I 98 3831 0 0.03 7 2 6.25 99 3866 0 0.03 9 3 6.21 Lt. Deposits. Body I Metal Loss Body Page 2 Penetration 1 I I • • PDS REPORT JOINT TABULATION SHEET Pipe: 7. in 26.0 ppf K -55 Well: 1E-08 Body Wall: 0.362 in Field: Kuparuk Upset Wall: 0.362 in Company: ConocoPhillips Alaska, Inc. I Nominal I.D.: 6.276 in Country: USA Survey Date: December 04, 2010 111 Joint Jt. Depth Pen. Pen. Pen. Metal Min. Damage Profile No. (Ft.) Upset Body % Loss I.D. Comments (% wall) (Ins.) (Ins.) % (Ins.) 0 50 100 100 3904 0 0.04 10 2 6.25 I 101 3941 0 0.02 6 1 6.27 II o 102 3979 0 0.03 9 3 6.25 II 103 4020 0 0.03 8 2 6.27 104 4061 0 0.04 10 2 6.26 I 105 4103 0 0.02 7 2 6.28 • 106 4140 0 0.03 9 2 6.28 • 107 4180 0 0.03 9 2 6.25 108 4221 0 0.03 7 2 6.25 s I 109 4262 0 0.03 7 2 6.27 C 110 4300 0 0.03 7 2 6.29 111 4337 0 0.03 7 2 6.27 112 4378 0 0.02 7 2 6.25 1 I 113 4415 0 0.03 8 2 6.25 � 114 4456 0 0.02 6 1 6.25 115 4497 0 0.02 6 2 6.27 a 116 4535 0 0.02 6 2 6.28 i 117 4573 0 0.03 7 2 6.29 I 118 4613 0 0.02 6 1 6.28 119 4649 0 0.02 6 2 6.27 120 4687 0 0.03 8 2 6.27 121 4730 0 0.02 5 1 6.26 i I 122 4769 U 0.03 7 1 6.29 123 4811 0 0.02 6 2 6.28 124 4850 0 0.03 7 1 6.27 125 4892 0 0.02 6 2 6.24 i I 126 4932 0 0.02 7 1 6.26 127 4974 0 0.03 8 2 6.25 C 128 5015 0 0.03 7 2 6.23 129 5056 0 0.03 9 2 6.27 C 130 5097 0 0.02 6 2 6.25 I 131 5138 0 0.03 8 2 6.25 C 132 5179 0 0.03 7 2 6.27 133 5218 0 0.02 7 2 6.25 II 134 5258 0 0.03 7 1 6.28 s I 135 5297 0 0.02 7 2 6.25 136 5337 0 0.03 8 2 6.24 • 137 5378 0 0.03 7 2 6.26 U 138 5412 0 0.02 6 2 6.24 i I 139 5451 140 5492 0 0.03 7 2 6.29 0 0.04 10 2 6.24 • 141 5531 0 0.03 7 2 6.27 II 142 5570 0 0.03 7 2 6.25 N 143 5612 0 0.07 18 3 6.26 Shallow Pitting. I 144 5652 0 0.12 33 2 6.24 Line of Pits. 145 5694 0 0.10 29 2 6.28 Line of Pits. INN 146 5734 0.04 0.07 19 2 6.24 Shallow Pitting. 147 5772 0 0.10 26 2 6.24 Line of Pits. I 148 5813 0 0.05 14 1 6.24 Shallow Pitting. 149 5854 0 0.10 28 2 6.26 Line of Pits. I Penetration BoBody dy I Page 3 I I • 0 PDS REPORT JOINT TABULATION SHEET I Pipe: 7. in 26.0 ppf K -55 Well: 1E-08 Body Wall: 0.362 in Field: Kuparuk Upset Wall: 0.362 in Company: ConocoPhillips Alaska, Inc. I Nominal I.D.: 6.276 in Country: USA Survey Date: December 04, 2010 I Joint Jt. Depth Pen. Pen. Pen. Metal Min. Damage Profile No. (Ft.) Upset Body % Loss I.D. Comments (% wall) (Ins.) (Ins.) % (Ins.) 0 50 100 I 150 5893 0.07 0.06 16 2 6.27 Shallow Line of Pits. C 151 5934 0 0.06 17 2 6.24 Shallow Pitting. 152 5972 0 0.03 8 1 6.26 • 153 6009 0 0.05 13 2 6.22 Shallow Line of Pits. IM 154 6048 0.07 0.05 14 2 6.24 Shallow Pitting. II 155 6088 0 0.04 12 2 6.26 Shallow Pitting. 156 6127 0 0.05 15 2 6.25 Shallow Pitting. 157 6171 0 0.03 8 2 6.24 158 6212 0 0.05 14 2 6.25 Shallow Pitting. m• I 159 6252 0 0.04 10 2 6.25 160 6294 0 0.03 8 2 6.27 • 161 6335 0 0.03 8 1 6.29 162 6377 0 0.03 8 1 6.26 • I 163 6415 0 0.04 11 2 6.23 164 6457 0 0.03 8 2 6.26 • • 165 6494 0 0.02 6 2 6.24 • 166 6535 0 0.03 8 3 6.22 E 167 6576 0 0.09 23 4 6.23 Line of Pits. I 168 6616 0 0.06 15 2 6.28 Shallow Line of Pits. 169 6658 0.11 0.08 22 3 6.23 Shallow Line of Pits. 170 6697 0 0.04 11 2 6.25 171 6736 0 0.04 10 2 6.20 Lt. Deposits. • I 172 6771 0 0.04 12 2 6.21 Lt. Deposits. 173 681 1 0 0.07 20 3 6.23 Shallow Pitting. E 174 6848 0 0.04 12 2 6.27 Shallow Pitting. 174.1 6865 0 0 0 0 N/A End of Log I Penetrat ' Metal Loss ion Body I I I I I I Page 4 1 1 • • I PDS Report Cross Sections I Well: 1E -08 Survey Date: Tool Type: December 04, 2010 Field: Kuparuk UW MFC 40 Ext. No. 213120 Company: ConocoPhillips Alaska, Inc. Tool Size: 2.75 Country: USA No. of Fingers: 40 I Tubing: 7 ins 26 ppf K -55 Analyst: C. Waldrop I I Cross Section for Joint 144 at depth 5673.060 ft Tool speed = 50 Nominal ID = 6.276 I Nominal OD = 7 Remaining wall area = 98% Tool deviation = 27° I 1 1 I ``, I Finger = 37 Penetration = 0.120 ins Line of Pits 0.12 ins = 33% Wall Penetration HIGH SIDE = UP I r I I ' • • I jj PDS Report Cross Sections M ' Well: 1E-08 Survey Date: December 04, 2010 Field: Kuparuk Tool Type: UW MFC 40 Ext. No. 213120 Company: ConocoPhillips Alaska, Inc. Tool Size: 2.75 Country: USA No. of Fingers: 40 ' Tubing: 7 ins 26 ppf K -55 Analyst: C. Waldrop Cross Section for Joint 145 at depth 5703.830 ft Tool speed = 50 Nominal ID = 6.276 ' Nominal OD = 7 Remaining wall area = 98% Tool deviation = 28° I I I Finger = 34 Penetration = 0.105 ins Line of Pits 0.10 ins = 29% Wall Penetration HIGH SIDE = UP 1 I I I I I .... KUP 1 E -08 ConocoPhillips o A ttributes Jingle & MD TD Al 1,r Ill WeIPoore APWWI Field Name Well StaWS Inc! ( °) MD MKS) Act Btm(ftKB) 500292049600 KUPARUK RIVER UNIT INJ 46.75 7,450.00 7,590.0 ccbootiOhitspx Comment H25 (ppm) Date Annotation End Date KB-GM (R) Rig Release Date I wet corlto:- 1E -oa, /593/2009 9 49 05 AM -SSSV: Locked Out 0 7/1/200 Last WO: 11/1/1984 38.99 10!28/ Schematic - Actual Annotation Depth (M(S) End Date Annotation Last Mod By End Date Last Tag: SLM 7,334.0 10/2/2009 Rev Reason: TAG Imosbor 10/4/2009 Casing Strings Wm t String OD String ID Set Depth Set Depth (TVD) String Wt String CONDUCTOR. Casing Description (in) (in) Top (BKB) (8KB) (ItKB) (Ibslft) Grade String Top Thrd CONDUCTOR 16 15.060 0.0 80.0 80.0 65.00 H-40 SURFACE 10314 9.794 0.0 2,896.0 2,693.3 45.50 K -55 VALVE 935 1 ° PRODUCTION 7 6.151 0.0 7.568.0 6,543.4 26.00 K -55 It Tubing Strings String OD wring ID Set Depth Set Depth (TVD) String Wt String I GAS LIFT, Tubing Description (in) (et) Top (MB) (MB) (5K6) (Ihe/H) Grade String Top Thrd mu 1 ' TUBING 31/2 2.992 0.0 7,176.0 6,268.2 9.20 J -55 BUTTRESS SURFACE, Other In Hole (All Jewelry: Tubing Run & Retrievable, Fish, etc.) 2,896 Top Depth (TVD) Top not - 4 Top (AKB) ( ( °) Description Comment Run Dote ID (in) i LIFT, 7 1,835 1,798.7 29.86 SAFETY VALVE CaDUn TRDP 1A (Locked Out 3117!88) Pulled WRDP on 11/1/1984 2.813 6/21/97 1,938 1,887.4 31.67 GAS LIFT MMH /3.5x1 /1 /DMY /BK// /Comment: STA 1 7/9/1990 2.859 GAS LIFT, G 3,789 3,438.2 33.28 GAS LIFT MMH/3.5x1 /1 /DMY /BK/ // Comment STA 2 6/6/1990 2.859 5,120 5,120 4,5641 3090 GAS LIFT ' MMHl3. 5x1 /1 /DMY /BK/ // Comment STA 3 6/6/1990 2.859 I Gns 5,618 5,618 4,994.4 31.39 GAS LIFT MMH /3. 5x1 /1 /DMY /BK/ // Comment: STA4 6/6/1990 2859 LIFT, 6,058 5,366.9 30.90 GAS LIFT MMH/3 .5x1 /1 /DNIY /BK/ // Comment: STA 5 5/14/1987 2.859 6,467 5,715.4 33.34 GAS LIFT MMH /3.5x1 /1/DNIY /BK! /! Comment: STA 6 11/1/1984 2.859 6,783 5,968.5 40.58 GAS LIFT MMH/3 .5x1 /1 /DMY /BK/ // Comment: STA 7 3/16/1988 2.859 GAS LIFT. 6,821 5,997.2 40.15 SBR Baker 11/1/1984 2.813 I s,oss 6,847 6,017.0' 40.02 PACKER Baker 'FHL' RETRIEVABLE PACKER 11/1/1984 3.000 6,884 6,045.3 39.83 INJECTION MMH73 .5x1 /1 /DMY /BK/ // Comment CLOSED STAB 11/ /1995 2.859 GAS LIFT, 6,952 6,097.8 39.49 INJECTION MMH / 3.5x1 /1 /DMY /BK /// Comment CLOSED STA 9 11/7/1995 2.859 e,467 7,014 6,145.3 39.93 PATCH 22' Meda Tbg Patch; Set on 11/19/95 11/19/1995 2.375 I 7,114 6,221.8 41.18 PATCH 22' Merle Tbg Patch; Set on 11/19!95 11/19/1995 2.375 GAS LIFT 6,783 7,117 6,224.1 41.21 PATCH 30' OAL TTS PATCH 7117 -7147; 2.13" OD RETRIEVABLE 9/12/2008 1.125 SEALBORE INFLATABLE PACKER ON BOTTOM; 2.225" OD TTS SIZE 287 PARAGON 2 RETRIEVABLE DUEL SEAL BORE PACKER ON TOP i SBR, 6,921 ; 7,121 6,227.1 41.26 INJECTION MMH /3.5x1 /1 /DMY /BK/ // Comment: CLOSED STA 10 11/7/1995 2.859 7,139 6,240.5 41.49 PACKER Baker'FB -l' PACKER 11/1/1984 4.000 7,160 6,256.2 41.75 NIPPLE Cameo 'D' Nipple NO GO PROFILE 11/1/1984 2.750 PACKER 6'647 7,160 6,256.2 41.75 NIPPLE AVA'D' Profile; Set on 11/17/95 11/17/1995 1.813 I I REDUCER I INJECTION, 7,176 6,268.2 41.95 SOS Baker 11/17/1995 2.992 rim 7,177 6,268.9 41.96 TTL 11/1/1984 2.992 5,886 Perforations & Slots Shot INJECTION. Top (TVD) Mtn (T /D) Dana i 5,952 Top (Po(B) Btrn (RKB) (MB) (t1KB) Zone Date (5h -- Type Comment 7,104 6,142.2 6,214.3 C-4, C-3, C-2, 8/27/1981 4.0 IPERF SOS 21/8 Ene C -1, 1E -08 7,274 7,294 6,339.9 6,354.2 A-5, 1E -08 8/27/1981 4.0 PERF Rigidjet 7,304 7,356 6,361.5 6,397.8 A-4, 1E -08 8/27/1981 4.0 PERF Rigidjet PATCH, 7,914 IPERF, 7,010-7,106 INJECTION. 21 I C PATCH. 7,117 PATCH. 7.117 I PACKER, 7,139 NIPPLE. 7,160 II S,i NIPPLE N. tr REDUCER, 7,168 i I SOS, 7,178 . TTL, 7,177 PERE, 7,274 -7,296 PERE, 7,304 -7356 PRODUCTION, 7,568 TD, 7893 . STATE OF ALASKA • ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG la. Well Status: Oil ❑ Gas ❑ SPLUG ❑ Other ❑ Abandoned ❑ Suspended Q 1b. Well Class: �I 20AAC 25.105 20AFjC 25.119 d � evelopment ❑ Exploratory LJ 2. Operator ❑ Name: El WIND WAG WDSPL No. of Completions: l�v S` r 12 Permit to Drill Number: Stratigraphic Test 5. Date Comp., Susp., ConocoPhillips Alaska, Inc. or Aband.: December 6, 2010 180 - 081 / 310 - 338, 310 - 401 3. Address: 6. Date Spudded: 13. API Number: P. O. Box 100360, Anchorage, AK 99510 - 0360 October 15, 1980 50 029 - 20496 - 00 4a. Location of Well (Governmental Section): 7. Date TD Reached: 14. Well Name and Number: Surface: 1013' FSL, 629' FEL, Sec. 16, T11 N, R10E, UM October 24, 1980 1E Top of Productive Horizon: 8. KB (ft above MSL): 24' RKB 15. Field /Pool(s): 1335' FNL, 1142' FEL, Sec. 16, T11 N, R10E, UM GL (ft above MSL): 105.7' AMSL Kuparuk River Field Total Depth: 9. Plug Back Depth (MD + TVD): 942' FNL, 1052' FEL, Sec. 16, T11 N, R10E, UM 6745 MD / 5986' TVD Kuparuk River Oil Pool 4b. Location of Well (State Base Plane Coordinates, NAD 27): 10. Total Depth (MD + TVD): 16. Property Designation: Surface: x 549890 y 5960600 Zone 4 7590' MD / 6558' TVD ADL 25651 TPI: x - 549352 y - 5963528 Zone 4 11. SSSV Depth (MD + ND): 17. Land Use Permit: Total Depth: x 549438 y - 5963921 Zone 4 543' MD / 543' TVD 469 18. Directional Survey: Yes ❑ No Q 19. Water Depth, if Offshore: 20. Thickness of Permafrost MD/TVD: (Submit electronic and printed information per 20 AAC 25.050) N/A (ft MSL) 1650' MD / 1650' TVD 21. Logs Obtained (List all logs here and submit electronic and printed information per 20 AAC 25.071): 22. Re drill /Lateral Top Window MD/TVD none not applicable 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD SETTING DEPTH ND HOLE AMOUNT CEMENTING RECORD CASING SIZE WT. PER FT. GRADE TOP BOTTOM TOP BOTTOM SIZE PULLED 16" 65# H-40 Surf. 80' _Surf. 80' 24" 200 sx Permafrost 10.75" 45.5# K -55 Surf. 2896' Surf. 2693' 13.75" 1350 sx Fondu, 250 sx AS 7" 26.0# K -55 Surf. 7568' Surf. 6543' 8.75" 530 sx Class G, 200 sx ASII 24. Open to production or injection? Yes ❑ No Ei If Yes, list each 25. TUBING RECORD Interval open (MD+TVD of Top & Bottom; Perforation Size and Number): SIZE DEPTH SET (MD) PACKER SET (MD/ND) ,,,,. , . .., ,.: , 3.5" 6667' 7139' MD / 6292' TVD perfs plugged off: 7010' - 7104' MD 6192' - 6264' TVD G, �' - fr 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. 7274' - 7294' MD 6391' - 6406' TVD DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED 7304' -7356' MD 6413' '- -6449' TVD 6655' -6753' 51 bbls 15.8 ppg Class G -r rd, iKd' e 1JEC. 8 201G 27. PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) not applicable plugged 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 - API (corr) Press. psi 24 -Hour Rate -> 28. CORE DATA Conventional Core(s) Acquired? Yes ❑ No Q Sidewall Cores Acquired? Yes ❑ No Q If Yes to either question, list formations and intervals cored (MD+TVD of top and bottom of each), and summarize lithology and presence of oil, gas or water (Submit separate sheets with this form, if needed). Submit detailed descriptions, core chips, photographs and laboratory analytical results per 20 AAC 25.071. RECEIVED NONE � 01° DEC 1 a RBDMS DEC 1 201 a c°'m 10 -- ,.0'4 &Gas Form 10-407 Revised 1 CONTINUED ON REVERSE -- Fao original only 2A__ /2„.../-7/6 o1-2//T/ 28. GEOLOGIC MARKERS (List all formations and markers - tered): 29. FORMATION TESTS NAME MD TVD Well tested? ❑ Yes is No If yes, list intervals and formations tested, Permafrost - Top ground surface ground surface briefly summarizing test results. Attach separate sheets to this form, if Permafrost - Bottom 1650' 1635' needed, and submit detailed test information per 20 AAC 25.071. not applicable N/A Formation at total depth: Kuparuk 30. LIST OF ATTACHMENTS Summary of Daily Operations, schematic 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Eh N so • ) 263 9 Printed Na ve Title: Alaska Wells Manager � Signature Phone 265 -6306 Date 1 2 7 /1 S/ f Ar Sharon aron Allsup -Drake 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. Submit a well schematic diagram with each 10 -407 well completion report and 10 -404 well sundry report when the downhole well design is changed. Item 1a: Classification of Service wells: Gas injection, water injection, Water - Alternating -Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Item 4b: TPI (Top of Producing Interval). Item 8: The Kelly Bushing and Ground level elevations in feet above mean sea level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 13: The API number reported to AOGCC must be 14 digits (ex: 50- 029 - 20123- 00 -00). Item 20: Report true vertical thickness of permafrost in Box 20. Provide MD and TVD for the top and base of permafrost in Box 28. Item 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 23: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Item 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut -in, or Other (explain). Item 27: Provide a listing of intervals cored and the corresponding formations, and a brief description in this box. Submit detailed description and analytical laboratory information required by 20 AAC 25.071. Item 29: Provide a list of intervals tested and the corresponding formation, and a brief summary of this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Form 10 -407 Revised 12/2009 t , KU P • 1 E -08 Clip§ Well Attributes Max Angle & MD _ jTD Wellbore APUU WI Field Name Well Staten fin 46 ( °) ft KB) Atablox Inc. ' 500292049600 KUPARUK RIVER UNIT INJ 46 75 1 7,450 00 MD (ftKB) Act Btrn ( 7,590 0 L t Ta NIPPLE D e 7t334 0 End I Re� Es t WO - WO End Date KB -6r3 9 Rig Release Dote (ppm) Dab w 69 8, 1; 23.25 PM S NIPPLE Last WO 12/6/2010 1 3899 1028/1980 Sch 12 /8 ACual A p ( ) tat LisalMod... E dDate Tag Reason WORKOVER Imosbor 12/8/2010 I Casing Strings dr !: Casing Description String 0... String ID ... Top (ft168) Set Depth (f... Set Depth (TVD) ... String Wt... 'String ... String Top Thrd WINGER, 29 5.: CONDUCTOR 16 15.060 32.0 80.0 80.0 65.00 H WELDED Casing Description String 0... String ID . Top (ftK6) Set Depth (f.. Set Depth (TVD) ... String Wt... String ... String Top Thrd ' SURFACE , 10 3/4 9.794 31 8 2,895 6 2,705.5 45 50 K BTC Casing Description String 0... Siring ID .. Top (fiKB) Set Depth (f... Set Depth (TVD) .. String Wt... String ... String Top Thrd PRODUCTION 7 6.151 30 9 7,568.0 6,594.8 26.00 K-55 Tubing Strings Tubing Description String 0... String ID ._ Top (ft106) Set Depth (f... Set Depth (TVD) .. String Wt... String .. 'String Top Thrd TUBING WO 31/2 2 992 I 28 -8 I 6,667.4 I 5,925.2 9.30 L80 1 EUE8RD Completion Details Top Depth (ND) Top Incl Nomi... Top OMB) (IKB) _ (3 Item Description Comment ..__ -. ID(in) CONDUCTOR,: 28.8 28.8 - 12.62 HANGER TUBING HANGER 3.125 32 542.8 542.8 0 55 NIPPLE HES'X' NIPPLE 2.813 6666.9 5 924 8 36.98 SHOE MULE SHOE 2.992 Iti Tubing Descnption String 0... String ID ... Top (ftK8) Sat Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd TUBING Original 3 1/2 2 - 992 7,020.1 7,176.4 6,319.8 9.20 J - 55 ABFL4S NIPPLE, 543 --- 3 Abandoned Completion Details Top Depth (TVD) Top Inc! NOnll..- Top (RKB) (ftK8) (^) Item Description C 10 (in) 7,020.1 6,200.1 37.93 BLAST RING BLAST RINGS (3) 2.992 7,138.7 6290.9 40.56 PACKER BAKER FB-1 PACKER 4.000 SURFACE, 7,141.2 6,292.8 40.63 SBE BAKER SEAL BORE EXTENSION 2.813 32 - 2,806 7,159.5 6.306.9 41.14 NIPPLE CAMCO D NIPPLE NO GO PROFILE 2.750 �! 7,175.6 6,319.2 41.58 SOS BAKER SHEAR OUT SUB 2.992 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top Depth (TVD) Top Inc! Top (01(0) MKS) (1 Description Comment Run Date ID (in) 6,745.0 5,986.4 39.22 Cement WORK OVER, LOWER ZONE P &A 12/5/2010 0.000 6,753.0 5992.6 39.53 Cement WORK OVER, LOWER ZONE P &A 12/5/2010 0.000 Retainer -:- 7,176.0 6,319.5 41 59 Cement I WORK OVER, LOWER ZONE P &A 12/5/2010 0.000 cement Perforations & Slots Rete nen, 6,753 -- Shot - Top (TVD) Earn (TVD) Dens Cement, 6,745 --- � 4 Top (ftK8) Btm MKS) MB) OMB) __ . Zone Date WI.- Type ...._. Comment 7,010.0 7,104.0 6,192.3 6,263.5 C -4, C -3, C -2, 8/27/1981 4.0 IPERF SOS 2 1/8 Enerjet 0 04 a C -1, 1E -08 - 7,274.0 7,294.0 6,391.2 6,405.6 A-5, 1E-08 8/27/1981 4.0 PERF Rigidjet :1 7,304.0 7,356.0 6,413.0 6,449.2 A -4, 1E -08 8/27/1981 4.0 PERF Rigidjet " � - Notes: End ote General & Safety End Rate Annotation 8242010 NOTE- View Schematic w/ Alaska Schematic9. , ,I //n /�. /') {. /� � (( //_ / //--�� 7,010 -7,106 w.:» sl t.spe/V^e " (� C O N'tr 4 e`T SL r Y G J INJECTION, - ig 7,121 1 1 PACKER,7,139 SBE, 7,141 - .1 -... _, NIPPLE,7,159 • SOS, 7,176 --' - Mandrel Details Top Depth Top Port Cement, 7,176 (TVD) 7120 6,276.9 40.07 OD Valve Latch S TRO Run 7,274-7,291 " _Stn n MKS) 3 Top (ftK8 MKS) ( °) Make Model (in) SerV 1 Typo TYM (in) (1 Run D b Cam... - MMH 3 5 x 1 1 INJ DMY BK 0.000 0.0 12/6/2010 PERF, 4" %ls`3 -,sea 7,304- 7,356 "P' �''�'+r { "-- i 1 PRODUCTION, 31- 7,566 TD, 7,590 -- • • Conoc4Phillips Time Log & Summary Wellview Web Reporting Report Well Name: 1E Rig Name: NORDIC 3 Job Type: RECOMPLETION Rig Accept: 11/19/2010 5:30:00 AM Rig Release: 12/7/2010 12:00:00 PM Time Logs Date From To ' Dur S. Depth E. Depth Phase Code Subcode < T Comment 11/16/2010 24 hr summary Move Camp from 2T Pad to !E Pad. Begin moving Nordic Rig 3 from 2T Pad to 1 E Pad. 16:00 00:00 8.00 MIRU MOVE MOB P Move Camp from 2T Pad to 1 E -Pad and spot same. Move and stage miscellaneous support equipment on 1 E -Pad. Back Nordic Rig 3 off of 2T -13 Well Slot and begin moving to 1 E -Pad. 11/17/2010 Move Rig from 2T -Pad to CPF2. Unable to continue with move due to weather conditions. Storm forecast to break Thursday Morning. 00:00 07:30 7.50 MIRU MOVE MOB P Move Nordic Rig 3 from 2T -Pad to CPF2. 07:30 00:00 16.50 MIRU MOVE MOB T Halt Rig move at CPF2 due to changing weather conditions. Blowing and drifting snow. Shortly afterwards Kuparuk Field weather condition went from Phase I to Phase 111. Secure and maintain Rig at CPF2 during weather shut -down. 11/18/2010 Continue to wait on Weather. Resume Rig Move 00:00 19:00 19.00 MIRU MOVE MOB T Continue to wait on Weather to break to be able to resume Rig move. Wait on Roads and Pads to clear snow as needed from Spine Road. 19:00 00:00 5.00 MIRU RPEQP1MOB P Resume Rig Move. Move Rig from CPF 2 to the "Y ". 11/19/2010 Resume Rig move. Rig up at 1 E -08 WEII Slot. Load Pits with 8.7 lb/gal Brine. KIII Well. 00:00 05:30 5.50 MIRU MOVE MOB P Continue to move Nordic Rig 3 from the "Y" to Location. Spot Rig over 11" x 5K BOP Stack. Accept Rig at 05:30 hrs. 05:30 13:00 7.50 COMPZ MOVE NUND P PJSM (swing path, pinch points. overhead loads). Nipple up Annular. Pick -up BOP Stack and set back on Stump. Hang Tree in Cellar. Hang Riser and install Adaptor Flange. 13:00 15:00 2.00 COMPZ MOVE RURD P PJSM (communictions, wear safety vests). Move Rig over 1 E -08 Well Slot. Center and level up Rig. 15:00 20:00 5.00 COMPZ MOVE RURD P Berm up around Cellar. Complete hardline rig up. Remove snow and re -berm Kill Tank containment due to Phase III storm. Rig up lines in Cellar. Take on Brine in Rig Pits. Circulate Pits and bring weight up to 8.7 1b /gal. Page 1 of 19 • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T " Comment 20:00 23:00 3.00 COMPZ RPEQP1 KLWL P PJSM (communications, line of fire, expect pressure). Pick -up Lubricator. Pull BPV. Lay down same. Record Wellhead pressures. Tbg = 420 psi, IA = 420 psi, OA = 40 psi. 23:00 00:00 1.00 COMPZ RPEQP1 KLWL P PJSM ( testing lines, whip checks, post signs). Pressure test all lines with air. Good. Test pump line at 250/3,500 psi. Good. Notify Security and DSO that we will be venting gas. 11/20/2010 Complete Rig move and rig -up. Load Pits with 8.7 lb/gal Brine. Pull BPV. Test lines. Kill Well. ND Tree. NU BOPE. Test BOPE. 00:00 01:00 1.00 COMPZ WELCTI KLWL P Begin Well Kill. Bring Pump on line at 1 bpm. Increase pump rate gradually up to 4.0 bpm and hold 450 psi back pressure with choke. Continue pumping a 4.0 bpm /300 psi while gradually reducing Choke pressure. After 150 bbls pumped, the Spill Champion noticed a small dribble of fluid coming down the side of the Kill Tank. The Pump was shut down and the Well was secured. 01:00 04:30 3.50 COMPZ WELCTI. KLWL T Recovered — 1/2 gal of fluid on top of the Tank due to a "washed -out" 45 deg Ell. Wipe down the side of the tank and clean -up -- 1 cup of fluid on the secondary containment line. Rig down Kill Tank. Bring in a replacement Tank. Rig up line and re -berm secondary containment Test line. 04:30 08:30 4.00 COMPZ WELCTL KLWL P Resume Well Kill Ops. Pump 8.7 lb/gal Brine at 3.0 bpm /270 psi. Total volume pumped = 300 bbls. Shut in Well and bullhead 20 bbls into perforations at 2.5 bpm. Initial pressure = 600 psi. Final pressure - 1,120 psi. Monitor Well dead. 08:30 09:30 1.00 COMPZ WELCTL KLWL P PJSM. Blow down lines. Rig down circulating hoses and secure cellar. 09:30 10:00 0.50 COMPZ RPEQP1 NUND P PJSM. Set BPV. FJI ‘11 1 � � � bajoto 10:00 11:30 1.50 COMPZ RPEQP1NUND P Nipple down Tree. 11:30 16:00 4.50 COMPZ RPEQP1NUND P Nipple up 11" x 5K BOP Stack. 16:00 22:00 6.00 COMPZ RPEQP1 BOPE P PJSM. Perform initial BOPE test per Conoco /Phillips and AOGCC requirements at 250/3,500 psi. Good test Perform Koomey draw down test. Good. Tests recorded on Zr chart. le 22:00 22:30 0.50 COMPZ RPEQP1 BOPE P Blow down lines and rig down test equipment. Page 2 of 19 • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 22:30 00:00 1.50 COMPZ RPEQPI PULL P PJSM. Drain Stack. Pull Blanking Plug. Pull BPV. Lay down same. 11/21/2010 Pull Tubing Hanger free. Circulate and condition Well. Pull Tubing Hanger to the Floor. Single down 3 1/2" Completion from 6,805 -ft. Prep for BHA #1. 00:00 02:00 2.00 COMPZ RPCOM RURD P Rig up Floor to handle 3 1/2" Tubing and pull Tubing Hanger. 02:00 02:45 0.75 COMPZ RPCOM PULL P PJSM. Make -up 3 1/2" Landing Joint (3 ea x10 -ft Pup Joints), Head Pin and Circulating Hose. Pull Hanaer free at 90K. Tubing free at 95K. 02:45 04:00 1.25 COMPZ RPCOM CIRC P Circulate and condition Well from 6,800 -ft at 4.0 bpm /220 psi. Increased rate to 6.0 bpm /450 psi. Circulated total of 365 bbls with full returns. 04:00 05:00 1.00 COMPZ RPCOM PULL P PJSM. Pull Tubing Hanger to Floor at 95K. Rig up Camco Spooling Unit. Break out Tubing Hanger. Lay down Landing Joint. 05:00 12:00 7.00 COMPZ RPCOM PULL P PJSM. Begin to single down 3 1/2" Completion from 6,805 -ft, while spooling Control Line to the SSSV. Lay down SSSV and rig down Spooling Unit. Continue to single down Completion to 3,990 -ft. 12:00 21:30 9.50 COMPZ RPCOM PULL P Finish out with the Completion from / 3,990 -ft. Completion recovered from ✓ ✓✓ 6,805 -ft total depth to the first cut = 216 Jts of 3 1/2" 9.2 lb/ft J -55 Mod Butt Tbg, SSSV, all Control Line, 31 SS Bands, 7 ea GLMs, and a 15.18 -ft 3 1/2" cut -off Tbg Stub. The Chemical Cut was aood. 21:30 00:00 2.50 COMPZ RPEQPI PULD P Clear and clean Floor. Kick out remaining Completion Tubing from Pipe Shed. Bring BHA #1 components to Floor. Continue to load and tally 3 1/2" Drill Pipe. 11/22/2010 / Make up BHA #1. Single in with 3 1/2" Drill Pipe. Engage Fish. Free SBR Seal Assy and FHL Packer Fish. �/ Circulate out gas bubble. Circulate and condition Well. Move Fish up hole to 6,738 -ft Fish hung -up. Jar to free Fish. 00:00 02:15 2.25 COMPZ RPEQPI PULD P Finish loading and tailing 3 1/2" Drill In Pipe Shed. 02:15 02:45 0.50 COMPZ RPEQPI PULD P PJSM. Pick -up an install Wear Bushing. 02:45 02:45 0.00 0 279 COMPZ RPEQP1 PULD P PJSM. Make -up BHA #1 as follows: 6" OD Drag Tooth Shoe, Wash Pipe Extension, Bushing, Overshot w/3 1/2" Grapple, Extension w /Drive Sub, Bumper Sub, Oil Jar, Pump- Out -Sub, 8 ea 4 3/4" Drill Collars. 02:45 11:00 8.25 279 6,763 COMPZ RPEQPI TRIP P Single in with BHA #1 and 3 1/2" Drill Pipe from the Pipe Shed. Stop at 6,763-ft. Page 3 of 19 • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 11:00 13:00 2.00 6,763 6,824 COMPZ RPEQP1 FISH P Establish parameters as follows: Up Weight = 135K. Down Weight = 107K. RPMs = 40. RTW = 124K. Free Torque = 4K ft/lbs. Circulate rate = 2.0 bpm /100 psi, 3.0 bpm /210 psi. Tag top of the 3 1/2" Tubing Stump at 6,812 -ft dpmd. Swallow Stump and wash down to 6,824 -ft dpmd. Plant Overshot. Pick to 180K and plant Overshot. Cycle Jars at 175K x 5 times. No movement. Cycle Jars at 190K x 3 times. No movement. Cycle Jars at 200K. Fish free. 13:00 14:00 1.00 6,824 6,792 COMPZ RPEQPI CIRC P Pull up hole to 6,792 -ft dpmd to circulate and condition Well. However, Top Drive Swivel packing began to leak. Blow down Top Drive. Make up Head Pin and Circulating Hose. 14:00 18:30 4.50 6,792 6,792 COMPZ RPEQP1 CIRC P Circulate Well with 8.7 lb/gal Brine at 3.0 bpm /550 psi. Increase rate to 5.0 bpm /1,140 psi. Circulated a gas bubble to surface with "bottoms -up ". Shut in Well with Upper Pipe Rams. Record Tubing pressure at 0 psi and IA pressure at 40 psi. Line up through Choke and circulate out the gas. Continue to circulate and condition hole. Notify AOGCC, Wells Supt, and Anch Engineer that the Well had been shut in. Follow up with an explanation E -Mail to the same people. 18:30 21:30 3.00 6,792 6,792 COMPZ RPEQP1CIRC P Continue to circulate. PJSM. Replace Top Drive Swivel Packing. Monitor Well on Trip -Tank. Well taking 4 bph (same as before the Packer was released). Bring on more fluid in Rig Pits. 21:30 22:30 1.00 6,792 6,792 COMPZ RPEQPI RGRP P Finish top Drive Swivel Packing replacement. 22:30 00:00 1.50 6,792 6,738 COMPZ RPEQP1TRIP P Start Trip out. However "Fish" hung -up at 6,738 -ft. Work Stuck Fish. Unable to come up or go down. Circulate bottoms up at 5.0 bpm /990 psi with 75% reruns. Begin to attempt to jar Fish free. Cycle Jars at 225K (90K over string weight). Pull up to 250K. 11/23/2010 Continue to Jar Fish free. POOH and recovered SBR /Seal Assembly, Test Upper Pipe Rams. MU BHA #2. Trip in hole and Fish FHL Packer. Jar free. Page 4 of 19 • Time Logs Date From To ' Dur S. Depth E. Depth Phase Code Subcode T Comment 00:00 02:00 2.00 6,738 6,477 COMPZ RPEQP1 FISH T Continue to attempt to jar Fish free. Cycle Jars ar 225K (90K over string weight). Max up weight pull = 350K Fish came free after 40 Jar cycles. Pull up hole to 6,477 -ft. Pulling weight = 140K. Park for Derrick inspection. 02:00 04:00 2.00 6,477 6,477 COMPZ RPEQP1CIRC P PJSM. Perform Derrick inspection. Circulate bottoms up at 5.0 bpm /900 psi while inspecting Derrick. Inspection good. 04:00 10:00 6.00 6,477 280 COMPZ RPEQP1 TRIP P Trip out with 3 1/2" Drill Pipe, standing back in Derrick. 10:00 12:00 2.00 280 280 COMPZ RPEQP1 PULD P Stop & Monitor Well, 2 stands before drill collar. PJSM. Lay down fish and BHA. Recover cut joint 15.54' and SBR 24.75'. Was Able to Move move Packer up hole after jarring operation. Estimated Top Of SLick Stick 6741' and FHL Packer @ 6769' feet. 12:00 15:00 3.00 280 0 COMPZ RPEQP1 BOPE P Pull Wear. Set Test Plug and Tested BOP Upper Pipe Ram with the 3 1/2" Test Joint at 250/3500 psi. Record o n Cart 9 Chart. Pulled Test Plug and Set Wear Ring. 15:00 15:45 0.75 0 280 COMPZ RPEQP1 PULD P Load Tools To Rig Floor. Make up BHA #2 as follows: 5 3/4" Overshot w/4 3/8" Spiral Grapple, Bumper Sub, Oil Jar, Pump- Out -Sub, 8 ea 4 3/4" Drill Collars, Intensifier. 15:45 20:30 4.75 280 6,700 COMPZ RPEQP1 TRIP P Trip in with BHA #2 and 3 1/2" Drill Pipe from the Derrick. 20:30 22:00 1.50 6,700 6,755 COMPZ RPEQP1 FISH P Establish parameters as follows: Up Weight = 135K. Down Weight = 110K. RPMs = 10. RTW = 120K. Free Torque = 2K. Pump Rate = 2.0 bpm /120 psi. Tagged the top of the Slick Stick/FHL Packer at 6,755 -ft dpmd. Plant Overshot. Begin to Jar on Fish to free. Work Jar cycles mostly at 225K (90K over string weight) and pull up to 325K. After one hour of steady jarring, the fish came free. 22:00 23:00 1.00 6,672 6,672 COMPZ RPEQP1 CIRC P Pull up to 6,672 -ft. Circulate bottoms -up at 5.0 bpm /580 psi. Perform Derrick inspection. Good. 23:00 00:00 1.00 6,672 5,317 COMPZ RPEQPITRIP P PJSM. Blow down Top Drive. Begin tripping out from 6,672 -ft, with Fish, standing back 3 1/2" Drill Pipe in Derrick. 11/24/2010 Trip out with FHL partial Packer Fish. Discuss options and plan forward. Trip in with BHA #3 and confirm top of FHL Packer carcass at 6,779 -ft dpmd. POOH with BHA #3. Lay down same. 00:00 03:00 3.00 5,317 280 COMPZ RPEQP1 TRIP P Finished Tripping out with 3 1/2" Drill Pipe. Page 5 of 19 s • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 03:00 04:30 1.50 280 0 COMPZ RPEQPI PULD P PJSM. BHA at surface. Lay dow BHA #2. Lay down partical FHL Packer Fish. Recovered the Slick Stick and part of the Packer Mandrel. Mandrel snapped in two. However there was some corrosion pits and holidays in the area were it separation. Total Fish Recover ( 29.97 feet ). 04:30 12:00 7.50 0 0 COMPZ RPEQPI OTHR P Discuss Plan Forward With Town Engineer, Baker Oil Tools and WO Rep. Clean and Clear Floor. Perform hazard Hunts while Waiting On Orders. 12:00 13:00 1.00 0 0 COMPZ RPEQPI PULD P PJSM. Load Tools To Floor. 13:00 15:00 2.00 0 281 COMPZ RPEQP1PULD P PJSM. MU BHA #3. Boot Basket with Magnet & 6 1/8" Bit 15:00 18:30 3.50 281 6,779 COMPZ RPEQP1TRIP P TIH w/ DP to Top of Packer for Drift & Tag. Confirmed top of FHL Packer at 6,779 -ft dpmd. (BHA, Joint 201 + 8 -ft of Joint 202). 18:30 19:30 1.00 6,779 6,779 COMPZ RPEQP1CIRC P Pump a 30 bbl Hi -vis Sweep at 10.0 bpm /1,880 psi. Chase Sweep back to surface with 8.7 lb/gal Brine. Returns clean. 19:30 22:00 2.50 6,779 282 COMPZ RPEQPI TRIP P PJSM. Trip out with BHA #3, standing 3 1/2" Drill Pipe back in Derrick. 22:00 23:00 1.00 282 0 COMPZ RPEQP1PULD P PJSM. Lay down 2 ea 4 3/4" Drill Collars. Stand back 2 stands of 4 3/4" Drill Collars in Derrick. Lay down BHA #3. Clean the normal metal particles expected from the String Magnet. Both Boot Baskets were empty. 23:00 00:00 1.00 0 239 COMPZ RPEQP1PULD P PJSM. Pick up BHA #4 as follows: PAC Muleshoe, 1 Jt 2 7/8" PAC Drill Pipe, XO, Bumper Sub, Oil Jar, Pump- Out -Sub, 6 ea 4 3/4" Drill Collars. 11/25/2010 Trip in with BHA #4. Tagged the top of the Packer at 6,779 -ft dpmd. Entered and continue through the Packer with the 2 7/8" PAC Drill Pipe Jt. Final Muleshoe depth at 6,812 -ft. Trip in with a 6" x 4 3/4" FB MM Shoe. Begin to control mill Packer Carcass 00:00 02:30 2.50 239 6,760 COMPZ RPEQP1TRIP P PJSM. Trip in with BHA #4 and 3 1/2" Drill Pipe. Pick up Jt # 202. Up Weight = 128K. Down Weight = 110K. Page 6 of 19 • • Time Logs Date From To Dur S. Depth - E. Depth Phase Code Subcode T Comment 02:30 03:15 0.75 6,760 6,812 COMPZ RPEQP1TRIP P Pick -up Jt #203 and ease in hole. Did not see Muleshoe enter the top of the Packer at 6,779 -ft. However did see "bobbles" once passed the expected entry depth. Continue in with Joint 203. End of Muleshoe depth = 6,789 -ft, —5 -ft out the end of the Packer Carcass. Pull back up hole and rotate Drill Pipe /Muleshoe 180 degs. Ease back down and tagged the top of the Packer "spot on" at 6,779 -ft. Pull back up hole and rotated the Drill Pipe/Muleshoe another 180 degs. Eased back in and entered the top of the Packer with no problem. Continue in with "bobbles" until) the XO sat down on the top of the Packer at 6,779 -ft. PAC Muleshoe now at 6,812 -ft dpmd. Findings: The bottom Box/Pin Packer Sub has parted. So that means that the remaining Completion (1 Joint, GLM, 2 Joints, GLM and the 3 1/2" Cut -off Stub has fallen back down to the Pre -RWO Chemical cut depth at 6,973 -ft elmd. Also it must be assumed that the Shear Ring and the Segment Retainer Ring have fallen down hole as well. Attempted a few light to moderate "smacks" with the Bumper Sub to move Packer Carcass downhole. No -Joy. 03:15 04:00 0.75 6,775 6,775 COMPZ RPEQP1CIRC P Circulate bottoms -up at 6.0 bpm/730 psi. 04:00 06:00 2.00 6,775 4,210 COMPZ RPEQP1TRIP P PJSM. Trip out with 3 1/2" Drill Pipe standing back in Derrick. Stop to Cut and Slip Drilling Line. 06:00 10:00 4.00 4,210 4,210 COMPZ RPEQP1SLPC P PJSM. Perform Slip /Cut On Drilling Line. 10:00 10:30 0.50 4,210 4,210 COMPZ RPEQP1SFTY P Discuss Lessons Learned during Slip /Cut. PJSM. Discuss Hazard of TOOH. 10:30 14:00 3.50 4,210 0 COMPZ RPEQP1TRIP P Continue Tripping Operations. 14:00 15:30 1.50 0 0 COMPZ RPEQP1PULD P PJSM. Lay Down BHA #4 15:30 16:30 1.00 0 231 COMPZ RPEQP1PULD P PJSM. Make Up BHA #5 as follows: 6" x 4 3/4" FB MM Shoe, Wash Pipe Extension, Top Bushing, Double Pin XO, 2 ea Boot Baskets, Bit Sub, String Magnet, Bumper Sub, Oil Jar, Pump- Out -Sub, 6 ea 4 3/4" Drill Collars. 16:30 19:30 3.00 231 6,775 COMPZ RPEQP1TRIP P PJSM. Trip in with BHA #5 and 3 1/2" Drill Pipe from the Derrick. Page 7 of 19 • • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 19:30 19:30 0.00 6,779 6,779 COMPZ RPEQPI MILL P Establish parameters as follows: Up Weight = 130K. Down Weight = 115K. Pump Rate = 6.0 bpm /650 psi. RPM range = 60 - 85. RTW = 124K. FT= 3 - 5K. Tag top of FHL Packer Carcass at 6,779 -ft dpmd. Begin control milling Packer. WOM = 2 - 3K. 19:30 00:00 4.50 6,779 6,810 COMPZ RPEQPI MILL P Continue control milling making slow steady progress. Up Weight = 130K. Down Weight = 115K. RTW = 124K. RPMs 60 - 65. Torque = 3 - 7K. WOM = 3 - 10K. Pump Rate = 3.0 bpm /330 psi. Made 2 -ft of progress. Start to torque up and stall out. Packer moving down hole. Chase down hole to 6,810 -ft dpmd. 11/26/2010 Continue to control mill Packer Carcass. Move Packer downhole to 6,810 -ft. POOH and LD BHA #5. PU BHA #6. RIH and spear Packer. POOH w BHA #6. LD Packer fish. RU S -Line 00:00 01:30 1.50 6,810 6,526 COMPZ RPEQPI CIRC P PJSM. Blow down Top Pull up hole to 6,526 -ft. Saw a couple of "bobbles" ( ?). Decided to drop Dart to open Pump- Out -Sub at 2,250 psi. Circulate bottoms up at 5.0 bpm /490 psi. 01:30 05:00 3.50 6,526 231 COMPZ RPEQP1TRIP P Continue Trip out with 3 1/2" Drill Pipe, standing back in Derrick. 05:00 06:00 1.00 231 0 COMPZ RPEQPI PULD P BHA #5 to surface. Lay down same. Recovered a "slab piece" of Packer body inside the Shoe. 06:00 08:30 2.50 0 0 COMPZ RPEQPI SVRG P PJSM. Service Top Drive. Discuss Lesson Learned After task was Perform. 08:30 09:30 1.00 0 219 COMPZ RPEQP1PULD P PJSM. MU BHA #6 ( Spear Assembly ) w/ DC. 09:30 13:00 3.50 219 6,800 COMPZ RPEQP1TRIP P TIH w/ BHA #6. Up Wt @ 6836' 135k & Down Wt =110k. 13:00 15:00 2.00 6,800 6,859 COMPZ RPEQPI FISH P Tag FHL Packer at 6,713'. Continue in hole with 2 Single joints of Drill Pipe and push Packer down hole with pump on @ 2 bpm, 210 psi. Pressure Increase to 420 psi, turn pump off, continue to push down hole to 6859' and bottom out. Set down 15k easy, pick up 10 feet and turn pump back on at 2 bpm, 240 psi, slack back down hole, and seen psi increase at 4 feet high. Turn pump off and bleed down psi. Continue down to original tag @ 6859' and bump down with 15k WOB 6k, PUH, Observe 6k bobble at 6850', set back down with 20k easy 2 more time. Pick up and seen 6k bobble again at same spot. PUH 30 feet off bottom and seen 10k bobble. Page 8 of 19 • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 15:00 15:30 0.50 6,829 6,829 COMPZ RPEQP1OTHR P Rig Blow down equipment and BD/TD. Rig down equipment. 15:30 16:15 0.75 6,829 6,829 COMPZ RPEQP1SFTY P Had PJSM on Tripping Operations. Perform Kick While Tripping Drill. 16:15 16:30 0.25 6,829 6,779 COMPZ RPEQP1TRIP P Start POOH Standing Back DP. 16:30 21:00 4.50 6,779 219 COMPZ RPEQP1TRIP P While TOOH, observed packer dragging and then tagged with packer @ 6779', same spot as before. Able to work Packer thru tight area. Continue to TOOH. Closely monitor hole fill while TOOH due to some swabbing while pulling Drill Pipe. Stop with 1 Stand of Drill Pipe before bring BHA to surface. Monitor Well static. 21:00 21:30 0.50 219 0 COMPZ RPEQPI PULD P BHA at surface. Lay down same. Recovered Packer Carcass. Hydraulic Buttons, Slip Segments, Spacer Rings, and Rubber Elements were all there. However, as expected the Shear Ring Retainer (part # 46) was left in the hole. 21:30 00:00 2.50 0 0 COMPZ RPEQP1SLKL P Call out S -Line Crew. PJSM. Nipple down Riser and Bell Nipple. Continue to prep for S -Line fishing operations while waiting for S -line Unit to rig down off of another job and arrive on Location. Spot S -Line Unit. 11/27/2010 Begin S -Line fishing operations to retrieve the Shear Ring Retainer from the Packer. Perform Weekly BOPE ✓ Test. 00:00 03:30 3.50 0 COMPZ RPEQP1SLKL P Install Shooting Flange and Riser. Continue to rig up S -Line BOPs, Pump -In -Sub, and Lubricator. Pick -up a 3.630" Super Magnet. 03:30 05:45 2.25 COMPZ RPEQP1SLKL P Rin in hole with Magnet. Set down at 6,868 -ft. Work Magnet up and down a couple of times. Pull out of hole. Magnet Showed Metal Shaving. 05:45 08:00 2.25 COMPZ RPEQPI SLKL P RIH w/ Magnet & Same BHA. Tagged same spot @ 6868' slmd. POOH and had small amount of metal shaving again. 08:00 09:00 1.00 COMPZ RPEQP1 SFTY P HES Crew Change out. Had PJSM with Rig Crew and New HES Crew. 09:00 09:15 0.25 COMPZ RPEQP1SLKL P Close BOPE on Rig & Rlh with Magnet to check top of Rams for Metal. All Clean. 09:15 11:45 2.50 COMPZ RPEQP1SLKL P MU & RIH with 3.83" CENT & 5.55" LIB. Set down a 6889' slmd. Hit 3 times Lightly without topping out spangs. POOH and inspect LIB. Picture r on LIB Look Like a section of PIPE and Half Moon of Junk. Page 9 of19 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 11:45 14:30 2.75 COMPZ RPEQP1SLKL P MU & RIH 6" Braided Fishing Brush & 2.20" Swage with Bulinose. Set down @ 6868' SLMD. Made Several Attempt to enter top of parted mandrel. No Luck. POOH. Found no marks on bullnose. 14:30 15:00 0.50 COMPZ RPEQP1SFTY P PJSM with Rig Crew & HES Crew. Discuss Hazard of Rigging down Slick -line equipment and Laying Equipment to Unit. 15:00 16:00 1.00 COMPZ RPEQP1 SLKL P Start Rigging Down Slick -Line Equipment from Well & Rig Floor. 16:00 16:30 0.50 COMPZ RPEQP1SFTY P PJSM on Rigging Down Shooting Flange and Installing Riser from Annular Bag to Floor. 16:30 18:00 1.50 COMPZ RPEQP1NUND P Nipple down Shooting Flange. Nipple up Bell Nipple and Riser. 18:00 19:30 1.50 COMPZ WELCTL BOPE P PJSM. Pull Wear Ring. Wash out BOP Stack. Rig up BOPE test equipment. 19:30 00:00 4.50 COMPZ WELCTL BOPE P PJSM. Perform weekly BOPE test per Conoco /Phillips and AOGCC requirements at 250/3,500 psi. Good tests. Record all pressure tests on /fi Chart. Also performed Gas Alarm, Choke Flow Test, Pit Level Indicator, and Koomey Draw Down Tests. All test were good. All tests were witnessed by AOGCC Rep, J. Jones. Blow down lines and rig down test equipment. 11/28/2010 Pick -up BHA #7. TIH in to retrieve the Shear Ring Retainer. No recovery. TIH w /BHA #8. No recovery. However information was gained about the Fish. TIH w /BHA #9, ITCO Soear. Work Spear to engage Fish. 00:00 00:45 0.75 0 209 COMPZ RPEQP1PULD P PJSM. Install Wear Bushing. Make up BHA #7 as follows: 5 3/4" Reverse Circulating Junk Basket, Bumper Sub, Oil Jar, Pump -Out Sub, 6 ea 4 3/4" Drill Collars. 00:45 05:00 4.25 209 6,868 COMPZ RPEQP1TRIP P PJSM. Trip in with BHA #7 and 3 1/2" Drill Pipe from the Derrick. Stop at 6,800 -ft. Drop 7/8" ball. Pick -up 3 singles from Pipe Shed. Up Weight = 137K. Down Weight = 110K. Tagged top of Fish with 1 -ft of Joint 207 in. Screw into top drive. Circulate @ 8bpm with 1730 psi on DP while working DP up and Down. 05:00 10:30 5.50 6,868 209 COMPZ RPEQP1TRIP P PJSM. Blow down TD. POOH from 6868' stopping every 5 stands and filling hole. 10:30 11:00 0.50 209 209 COMPZ RPEQP1PULD P OOH, PJSM, Remove Junk Basket and Check for Junk. Basket Was Clean. Discuss Plan Forward w/ Town Engineer. Lay Down BHA. 209 COMPZ RPEQP1SFTY SFTY P 11:00 11:15 0.25 209 09 CO Q PJSM. Discuss laying down and picking up tools to rig floor. Page10 • • 410 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 11:15 12:15 1.00 209 0 COMPZ RPEQP1 PULD P Lay Down BHA #7. 12:15 12:30 0.25 0 0 COMPZ RPEQPI SFTY P PJSM. Discuss Hazard with making BHA. 12:30 13:30 1.00 0 208 COMPZ RPEQP1PULD P PU & MU Overshot with Fishing Assembly. 13:30 17:00 3.50 208 6,793 COMPZ RPEQP1TRIP P TIH with BHA #8 to 6793'md 17:00 18:00 1.00 6,793 6,861 COMPZ RPEQPI FISH P Set Perimeter. Up Wt= 135k / Down Wt =112k with pump on @ 3 bpm with 240 psi on Drill Pipe, 10 RPM 2k torque. Set down with over -shot @ 6861' dpmd, Rotate while circulating @ 3bpm with 240 psi while stacking 10k down. Repeated same steps x3. Seen some overpull while PUH to unscrew next stand. Set 15k on last step. PUH 70 ft and blow down top drive. 18:00 21:30 3.50 6,790 208 COMPZ RPEQP1TRIP P Crew Change Out with tower opposites. PJSM. Trip out with 3 1/2" Drill Pipe to BHA #8. 21:30 22:30 1.00 208 0 COMPZ RPEQPI PULD P Pull BHA #8 from hole. No Fish recovery. However, information about the "Fsh" was obtained. Mark on the 4 1/4" Grapple Control measured a complete 4 3/4" circle. This is a good indication that the 4.750" OD Shear Ring Retainer (part #46) is centered over the parted Packer Mandrel stub and setting on top of the 4.250" OD Box/Pin Sub (part #49) which is the bottom piece of the Packer Mandrel and is screwed into the next section of the 3 1/2" Completion needed to be recovered. 22:30 23:30 1.00 0 210 COMPZ RPEQPI PULD P Clear and clean Floor. Discuss findings and the next BHA with Anchorage Engineer and Baker Fishing Tool Rep. Make up BHA #9 as follows: [too Spear w/2.938" Nom Catch Grapple, XO, Bumper Sub, Oil Jar, Pump- Out -Sub, 6 ea 4 3/4" Drill Collars. 23:30 00:00 0.50 210 210 COMPZ RPEQP1TRIP P Pick -up 27 single 3 1/2" Drill Pipe from Pipe Shed. POOH with same and stand back in Derrick to make room in Plpe Shed for Wash Pipe and Completion Pipe. 11/29/2010 ✓ Trip out with BHA #9. No recovery. Round trip BHA #10. No recovery. Trip in with BHA #11. 00:00 02:00 2.00 210 6,850 COMPZ RPEQP1TRIP P Trip in with BHA #9 and 3 1/2" Drill Pipe from the Derrick. Page 11 of 19 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 02:00 03:00 1.00 6,850 6,863 COMPZ RPEQP1FISH P Up Weight = 135K. Down Weight = 113K. RPMs = 10. RTW = 124K. FT = 2K. Pump Rate = 3.0 bpm /2,250 psi (5/16" ID through Spear). Tag top of Fish at 6,861 -ft dpmd. Work Spear to get deeper. After several attempts and bobbles Spear got down to 6,863.0 -ft. Saw a slight over pull. Worked Spear a couple more time with no further indication of deeper progress. Pull up hole with possible slight drag. 03:00 07:30 4.50 6,863 210 COMPZ RPEQP1TRIP PJSM. Blow down Top Drive. Trip out with 3 1/2" Drill Pipe, standing back in Derrick. 07:30 08:00 0.50 210 210 COMPZ RPEQP1SFTY P BHA @ Surface. PJSM. Discuss Hazard With Removing BHA. 08:00 09:00 1.00 210 0 COMPZ RPEQPI PULD P PUH and Lay Down Fishing Assembly. On Fish on spear. Spear Was Damage from fishing operation. Pictures on S- Drive. 09:00 10:00 1.00 0 0 COMPZ RPEQP1OTHR P Discuss Opitions with Town for Plan Forward. 10:00 10:15 0.25 0 0 COMPZ RPEQP1SFTY P PJSM on Loading Tools for next Tasks to rig floor. 10:15 12:00 1.75 0 207 COMPZ RPEQPI PULD P PJSM on MU BHA #10. MU BHA and RIH. 12:00 12:30 0.50 207 1,638 COMPZ RPEQP1SFTY P Crew Change Out. PJSM. Continue In Hole from 1638'md. 12:30 13:30 1.00 1,638 5,000 COMPZ RPEQPI SFTY P PJSM. Discuss Hazard for Slip & Cut Drill Line. 13:30 15:30 2.00 5,000 5,000 COMPZ RPEQP1SLPC P Slip & Cut Drill Line. 15:30 16:30 1.00 5,000 6,862 COMPZ RPEQP1TRIP P PJSM. Continue In Hole From 5000'. Set down @ 6861' up wt =135k & down wt =112k, continue to work short catch to 6862' and bottom out. Repeated Steps 3x, set down wt 10k, 15k and 17k, circulate @ 1 bpm and seen psi bump while stacking out. 16:30 17:00 0.50 6,862 6,862 COMPZ RPEQP1SFTY P PJSM, Discuss Tripping Out Hole Hazard. 17:00 19:30 2.50 6,862 207 COMPZ RPEQPITRIP P Trip out with 3 1/2" Drill Pipe, standing back in the Derrick. 19:30 19:45 0.25 207 0 COMPZ RPEQP1PULD P Lay down BHA #10. No recovery. Inspect Grapple. No conclusive marks. 19:45 20:00 0.25 0 0 COMPZ RPEQPI SFTY P PJSM. Discussed the hazards with making up the next BHA with Crew that just rotated back from days -off. 20:00 20:30 0.50 0 214 COMPZ RPEQPI PULD P Make up BHA #11 as follows: 5 3/4" x 5" Cut Lip Shoe with Wire ID (4 3/8 "), Wash Pipe Extension, Top Bushing, Bumper Sub, Oil Jar, Pump- Out -Sub, 6 ea 4 3/4" Drill Collars. Page 12 of 19 • • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 20 :30 20:30 0.00 214 4,959 COMPZ RPCOM TRIP P PJSM. Trip in with BHA #11 and 3 1/2" Drill Pipe from the Derrick. 11/30/2010 POOH with fishing BHA #11, no recovery. RIH with DP and run E -line video camera 00:00 01:00 1.00 4,959 6,799 COMPZ RPEQP1 TRIP P Continue to Ttrip in with BHA #11 and 3 1/2" Drill Pipe from 4,959.0 01:00 02:00 1.00 6,799 6,868 COMPZ RPEQPI FISH P Up Weight = 135K. Down Weight = 111K. RPMs = 15. RTW = 125K. FT = 2K. Pump Rate = 6.0 bpm/700 psi. Continue to ease in hole looking for top of fish. Tagged Fish at 6,862.8 -ft dpmd. Rotate slowly over TOF. Swallow Fish and bottom out on the Top Bushing at 6,868 -ft. Remain bottomed out. Drop Dart and wait to fall on seat. Open Pump- Out -Sub at 2,300 psi. Pull up hole slowly. Saw no over pull or pull off. Hopefully have Fish with a "friction- bite ". Blow down Top Drive. 02:00 06:00 4.00 6,868 0 COMPZ RPEQPI TRIP P PJSM. Trip out with 3 1/2" Drill Pipe, standing back in the Derrick. 06:00 06:30 0.50 0 0 COMPZ RPEQP1SFTY P OOH. PJSM, Discuss Hazard of Laying Down BHA. 06:30 07:30 1.00 0 0 COMPZ RPEQPI PULD P Lay Down BHA. Recover No Fish. Bring up more tools. Clean and Clear Floor. 07:30 09:00 1.50 0 0 COMPZ RPEQPI OTHR P Discuss Opition for Plan Forward with Town. 09:00 09:15 0.25 0 0 COMPZ RPEQP1SFTY P PJSM. On Next Tasks and Plan Forward.. 09:15 12:00 2.75 0 2,839 COMPZ RPEQP1TRIP P Load 3 1/2" Mule Shoe, RIH with DP. Up Wt =80k / down wt =75k @ 2839'md 12:00 14:00 2.00 2,839 6,856 COMPZ RPEQP1TRIP P Continue to RIH w/ DP F/2839'md to 6856'md. Space Out For E -Line Equipment. Up Wt =126k / Down Wt =107k 14:00 14:30 0.50 6,856 6,856 COMPZ RPEQP1 SFTY P PJSM, With HES E -Line Crew And Baker Personal And Rig Crew. Discuss Hazard with loading E -Line Equipment to rig floor, overhead loads and pinch point, Used good communication and any can stop the job if the task is unsafe. 14:30 19:30 5.00 6,856 6,856 COMPZ RPEQP1 RURD P Load & Rig Up E -Line Equipment. PT E -Line 3500 psi. 19:30 20:45 1.25 6,856 COMPZ RPEQP1CIRC P PJSM. Close annular, circulate well to freshwater. Pumping 4 bpm @ 580 psi, choke press 100 psi. Pumped a total of 250 bbl (hole vol = 230 bbl), 230 bbl returns. SITP= 70 psi, SICP =70 psi. Page 13 of 19 • • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 20:45 00:00 3.25 COMPZ ELOG RIH with E -line camera. Camera at DP shoe at 6856', move down into 7" casing. Scale /debris on low side piling up in front of camera while moving down hole. Unable to run in past 6860' (estimate 1' above fish) before debris covers camera lens. Attempt to pump debris downhole, bullheading down DP caused more scale to be pumped out of DP. 12/01/2010 Run E -Line with video camera to top of remaining completion. RIH with milling BHA #12. 00:00 01:00 1.00 COMPZ RPEQP1 ELOG P POOH with E -line. 01:00 03:30 2.50 COMPZ RPEQP1CIRC P PJSM. Circulate well to 8.7 ppg brine. Pumping 4 bpm at 400 psi. 03:30 05:30 2.00 COMPZ RPEQP1RURD P Blow down hard line, rig back E -line. 05:30 06:00 0.50 6,856 6,860 COMPZ RPEQPI TRIP P Re -Set Drill Pipe Depth. Tag Top OF Fish @ 6861' and + P/U 1' Off tag. 06:00 06:30 0.50 6,860 6,860 COMPZ RPEQPI SFTY P PJSM. Rig Crew Change Out. HES E -Line Crew Change Out. 06:30 09:00 2.50 6,860 6,860 COMPZ RPEQP1RURD P Re -Rig E -Line Equipment. 09:00 09:30 0.50 6,860 6,860 COMPZ RPEQP1CIRC P Reverse Circulate @ 5 bpm with 8.7 ppg Brine. 09:30 12:00 2.50 6,860 6,860 COMPZ RPEQP1CIRC P Displace Well Over To Fresh H2O.@ 2 bpm with 140 psi on DP. 12:00 15:00 3.00 6,860 6,860 COMPZ RPEQPI ELOG P RIH with E -Line video camera to top of completion. POOH 15:00 16:00 1.00 6,860 6,860 COMPZ RPEQP1RURD P PJSM. R/D E -Line equipment 16:00 17:30 1.50 6,860 6,860 COMPZ RPEQP1CIRC P Circulate well to 8.7 ppg brine, 4 bpm @ 440 psi. 17:30 18:00 0.50 6,860 6,860 COMPZ RPEQP1RURD P PJSM. Complete RD and remove from floor remaining E -line equipment. 18:00 22:00 4.00 6,860 0 COMPZ RPEQP1TRIP P POOH stand back DP workstring, up wt = 126K #, do wt = 107K #. 22:00 23:30 1.50 0 215 COMPZ RPEQP1RURD P PJSM. Load and MU Baker milling assembly BHA #12. 23:30 00:00 0.50 215 2,400 COMPZ RPEQP1TRIP P RIH with milling BHA #12 12/02/2010 RIH with milling BHA #12 and mill top of completion section. Fish and recover completion section from 6861' v to 6973'. 00:00 02:00 2.00 1,375 6,861 COMPZ RPEQP1TRIP P Contniue RIH with milling BHA# 12. 02:00 03:00 1.00 6,861 6,865 COMPZ RPEQP1TRIP P RIH to 6861', down wt = 110K, up wt = 135K. Free spin 40 rpm, 2K torque, rot wt = 125K. PJSM. 03:00 03:30 0.50 6,865 6,866 COMPZ RPEQP1 MILL P RIH to top of fish at 6865'. Pumping 3 bpm © 220 psi, sit down 1K to 2K #, 40 rpm, 3K torque. Mill down -1 ft, stopped milling off. PU 50', up wt = 135K. Blow down TD. Page 14 of 19 • • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 03:30 06:00 2.50 6,861 0 COMPZ RPEQP1TRIP P PJSM. POOH with milling BHA# 12, and Lay Down Milling Assembly. Seen Good wear pattern on nose of mill. 06:00 07:30 1.50 0 0 COMPZ RPEQP1 PULD P PJSM. CLean Out Boot Basket. Load Baker tools for next run. CLear and Clean Floor of tools. Had about Half gallon of metal shaving from boot basket. 07:30 08:30 1.00 0 221 COMPZ RPEQP1 PULD P PJSM with Baker and Rig Crew. PU & MU Fishing Assembly. 08:30 11:00 2.50 221 6,861 COMPZ RPEQP1TRIP P TIH with fishing assembly on Drill pipe. 11:00 11:30 0.50 6,861 6,860 COMPZ RPEQP1SFTY P PJSM, Discuss Hazard of Ciruclating Fluids, Fishing Operation, Flow Path, High PSI. Pinch Points. 11:30 12:15 0.75 6,860 6,867 COMPZ RPEQP1 FISH P Up Wt= 132 Down Wt= 114k , Tag top of stumb @ 6861' and Wash Over fish & No -Go out at 6867'md while pumping @ 1 bpm, 170 psi. 12:15 12:30 0.25 6,867 6,850 COMPZ RPEQP1SFTY P PUH and Monitor Well. PJSM. Discuss TOOH Hazard. 12:30 14:00 1.50 6,850 4,381 COMPZ RPEQP1TRIP P Drop Dart to open POS.TOOH standing back DP. Seen several 4K Overpulls. Continue Tripping Operation. 14:00 16:00 2.00 4,381 4,381 COMPZ RPEQP1OTHR P Stop & Secure well, while Driller and Floorhand can attend Q4 SLT Leadership Meeting. 16:00 16:15 0.25 4,381 4,381 COMPZ RPEQP1SFTY P PJSM. Discuss Hazard for TOOH. 16:15 18:30 2.25 4,381 1,485 COMPZ RPEQP1TRIP P Continue With Tripping Operation. 18:30 18:45 0.25 1,485 1,485 COMPZ RPEQP1SVRG P Crew change, service rig floor equipment 18:45 19:30 0.75 1,485 0 COMPZ RPEQP1TRIP P Continue POOH 19:30 21:30 2.00 0 0 COMPZ RPEQP1RURD P BHA #13 and completion section fish at surface. PJSM. Change out floor equipment, lay down complete section Recovered: packer sub, tbg jt, GLM #8, 2 x tbg jts, GLM #9, cut jt (14.31'). Top of remaining tubing stub above blast joints @ 6973'. *DID NOT RECOVER PACKER RING* 21:30 00:00 2.50 0 364 COMPZ RPEQP1 RURD P PJSM. Change out floor equipment. Load and MU wash over BHA #14. 12/03/2010 / POOH with washover BHA #14. RIH with milling /fishing BHA #15 to recover blast joints section. POOH with �/ BHA #15. 00:00 02:15 2.25 364 6,949 COMPZ RPEQP1TRIP P RIH with wash over BHA #14. Page 15 of 19 • • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 02:15 04:00 1.75 6,949 7,031 COMPZ RPEQP1MILL P RIH to 6949', up wt = 135K, down wt = 110. Free spin 10 rpm @ 2K torque, rot wt = 125. Start pumping 8 bpm @ 1350 psi. RIH slowly without rotating, sit down 5K# at 6980', roll over and wt dropped off. RIH slowly to 7028', sit down 10K, roll over wt drops off, work down -0.5' sit down 10K roll over wt drops off. Work this down to 7031' rolling over wt would not drop off and torque would build to 5K. PU 20', RIH with same results at same depth. Each pick up would have several 15K# over pull until pipe came up past 7028'. Circulated 10 bbl visc sweep to surface, intial BU had sand then minimal solids in returns. 04:00 08:30 4.50 7,031 1,332 COMPZ RPEQP1TRIP P PJSM. POOH w 3 1/2" DP F/ 7031' and 08:30 11:00 2.50 1,332 1,332 COMPZ RPEQPI SLPC P PJSM. Hang Blocks. Slip & Cut Dr! Line. 11:00 12:00 1.00 1,332 180 COMPZ RPEQP1SFTY P PJSM.Continue TO POOH F/ 1332'md To BHA. 12:00 12:15 0.25 180 180 COMPZ RPEQPISFTY P PJSM. Discuss Hazard of Laying Down Wash Pipe & BHA. 12:15 13:30 1.25 180 0 COMPZ RPEQPI PULD P Change Handling Equipment On Tongs & Lifting Equipment. UD Wash Pipe & BHA. 13:30 14:30 1.00 0 0 COMPZ RPEQP1PULD P PJSM. Offloard + Load (BOT) Clean & Clear Floor of Tools. 14:30 15:00 0.50 0 0 COMPZ RPEQPI SFTY P PJSM. Discuss Hazard Of Making Up Tools & Equipment. 15:00 16:30 1.50 0 225 COMPZ RPEQPI PULD P PU & MU BHA # 15 16:30 19:30 3.00 225 6,900 COMPZ RPEQPI TRIP P PJSM. TIH w/ dress off shoe and fishing assembly. 19:30 20:00 0.50 6,900 6,982 COMPZ RPEQP1MILL P BHA @ 6900', up wt = 135K, dw wt 115K, Rot 40 rpm @ 3K torque & rot wt = 125K RIH 3 bpm @ 250 psi, tag at 6980', sit down 2K and mill down to 6982' no torque increase. 20:00 20:15 0.25 6,982 6,926 COMPZ RPEQPI FISH P RIH to 6988', indication of latching onto fish, overpull 10K #. PU to 155K #(20K over), let jars fire. PU 175K #, weight starting to bleed off, PU @ 155K# pipe moving up hole to 6974' and then overpulled 195K #, jars fired and weight dropped to 145K #. PUH @ 135K# to 6926' Page 16 of 19 • Time Logs Date From To ' Dur S. Depth E. Depth Phase Code Subcode T Comment 20:15 21:15 1.00 6,926 6,926 COMPZ RPEQP1CIRC P PJSM. Circulate BU 6 bpm @ 750 psi. Perform kick drill while circulating. 21:15 00:00 2.75 6,926 1,600 COMPZ RPEQP1TRIP P PJSM. POOH with milling /fishing BHA #15. 12/04/2010 Pulled parted blast joint. Weekly BOPE test. Casing scrapper run 00:00 01:30 1.50 1,600 COMPZ RPEQP1TRIP P Continue POOH with milling /fishing BHA #15. 01:30 03:00 1.50 COMPZ RPEQPI RURD P BHA at surface. Recovered the lower 16.45' of previous cut tubing, 1 complete blast joint 31.26', and top protion of lower blast joint 4.01'. Sticking out of the blast joint was —10 ft of a tubing p atch. Below blast joint compression ring 1.05' blast rings. Below the remaining blast rings there was 15.15' of empty joint and another 4.01' of empty partial joint. Total of 19.16' of blast rings that slipped off the joints. PJSM. Breakdown fish and BHA #15. 03:00 05:00 2.00 COMPZ RPEQPI SVRG P Service TD and other rig components. Load and tally completion. 05:00 06:30 1.50 COMPZ RPEQPI MPSP P PJSM. Pull Wear Ring, Set Test Plug. R/U Testing Equipment for BOP Test. 06:30 11:30 5.00 COMPZ RPEQP1BOPE P PJSM. Weekly BOPE test. 11:30 12:15 0.75 COMPZ RPEQP1MPSP P PJSM. Pull Test Plug, Set Wear Ring. 12:15 12:30 0.25 COMPZ RPEQP1SFTY P PJSM. Discuss Hazard of Loading Baker Tools up Beaver Slide. 12:30 13:30 1.00 0 209 COMPZ RPEQP1PULD P PJSM. M/U BHA #16 13:30 16:30 3.00 209 6,880 COMPZ RPEQP1TRIP P TIH with 7" Casing Scraper. Set down With Scraper @ 6880'md made two attempts to work scraper down. NO GO. Up Wt =133k / Down Wt =115k 16:30 18:00 1.50 6,880 6,870 COMPZ RPEQP1CIRC P PUH 10' feet. Circulate 25 bbls High -vis Sweep & CBU x 2 @ 6 bpm, 830 psi 18:00 21:30 3.50 6,870 0 COMPZ RPEQP1TRIP P Blow down TD. PJSM. POOH from 6870' 21:30 00:00 2.50 0 0 COMPZ RPEQP1 RURD P BD Baker BHA an unload. ND Riser. 12/05/2010 Performed E- line /PDS casing caliper loq from 6868' ELMD to Surface. Set 7" Baker K -1 Cement Retainer at ✓✓ 6753' MD. Pumped 51 bbls 15.8opg Class G Cement, Leaving 2bbls (54') of cement on top of retainer , 00:00 00:45 0.75 0 0 COMPZ RPEQP1 RURD P NU shooting flange. 00:45 03:00 2.25 0 0 COMPZ RPEQP1 RURD P PJSM, RU E -line, PT to 1250 psi. Page 17 of 19 • • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 03:00 06:45 3.75 0 0 COMPZ RPEQP1 ELOG P 7" casing log (PDS caliper w/ Haliburton real time logging unit), logged from 6868' to surface. 06:45 10:00 3.25 0 0 COMPZ RPEQP1 RURD P PJSM. RD E -line and shooting flange, NU riser. 10:00 11:15 1.25 0 0 COMPZ RPEQPI RURD P PJSM. Load and RU Baker cement retainer. 11:15 15:30 4.25 0 6,753 COMPZ RPEQP1TRIP P RIH with Baker K -1 cement retainer on DP. 15:30 16:30 1.00 6,753 6,753 COMPZ RPEQPI PACK P 6753' MD, At set depth, rotate clockwise 12 turns to set cement retainer.PT retainer to 1500 psig, sting back into retainer, perfom injectivity test at rate.110 dwn weight,125 up weight. 1 bpm = 630 psi 1.5bpm =830 2bpm =1000 16:30 17:00 0.50 6,753 6,753 COMPZ RPEQP1SFTY P Hold PJSM with Nordic Crew,SLB,ASRC 17:00 17:45 0.75 6,753 6,753 COMPZ CEMEN CMNT P Batch Up Cement to weight 15.8ppg 17:45 17:51 0.10 6,753 6,753 COMPZ CEMEN" CMNT P Cement at weight. Pump 5 bbls clean water ahead, shut down and PT cement lines to 4000# 17:51 18:06 0.25 6,753 6,753 COMPZ CEMEN CMNT P 51 bbls cement away, follow with 5 bbls water, shut down cement pump, line up with rig pump to displace cement 18:06 18:24 0.30 6,753 6,753 COMPZ CEMEN" CMNT P RIG PUMP ON LINE 4bpm 18:24 18:36 0.20 6,753 6,655 COMPZ CEMEN" CMNT P Final circ rate and pressure was lbpm @ 1500 psig DP, PUH and breakput 3 joints of DP 18:36 20:20 1.74 6,655 6,655 COMPZ RPEQPI CIRC P Circulate around at max rate 20bbls Bio Zan followed by 2X hole volume 8.7 Brine, TOC at 6655' MD 20:20 23:59 3.66 6,655 3,465 COMPZ RPEQP1TRIP P Circulation complete, Blow Down Top Drive, TOOH laying down DP 12/06/2010 Ran 3.5" completion to 6666.93' KB consisting of 212jts 3.5" 9.3# L -80 EUE Tubing, 2.813" X- Nipple located at 542.8' KB. Circulated in 85bbls Seawater followed by 175bbIs 1% CRW -135 Inhibited Seawater. Set Type "IS" BPV and nippled down BOPE 00:00 05:30 5.50 3,465 0 COMPZ RPEQP1TRIP P Continue TOH laying down 3.5 DP 05:30 06:00 0.50 COMPZ RPEQPI RURD P Pull wear ring 06:00 08:00 2.00 0 0 COMPZ RPEQP1 PRTS P 250/3500 Pressure Test of Cement and 7" casing charted for 30 min. State witness waived by Chuck Sheve 12/5/2010 @ 10:45 08:00 17:00 9.00 0 6,745 COMPZ RPCOM RCST P PJSM. RIH with 3 -1/2" tubing string. Tag top of cement @ 6745. PUH to desired depth and prepare to circulate well to inhibited seawater. Up wt = 95K, down wt = 80K. Page 18 of 19 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 17:00 18:00 1.00 6,745 6,745 COMPZ RPCOM CIRC P Circulate in 85bbls Sea Water followed by 175bbIs 1% CRW -135 Inhibited Seawater @ 4bpm,330psi 18:00 20:00 2.00 6,745 0 COMPZ RPCOM THGR P PJSM,Drain Stack, Land Hanger, 90k up weight, 85k down weight, RI LDS 20:00 00:00 4.00 0 0 COMPZ WHDBO NUND P PJSM, Set BPV and VR Plugs, ND BOPE, NU Tree 12/07/2010 NU Tree and Charted pressure test to 250/5000 for 10min. Circulated 75bbls freeze protect and allow to U -Tube for 1 hr. Set type "IS" BPV. Prep rig and location for move. Rig Released @ 1200hrs 12 -7 -2010 00:00 03:00 3.00 0 0 COMPZ WHDBO NUND P Continue ND BOPE/NU Tree 03:00 05:00 2.00 0 0 COMPZ WHDBO PRTS P PT Tree 250/5000, chart and record for 10min 05:00 08:00 3.00 0 0 COMPZ WHDBO FRZP P Freeze Protect well with 75b1s diesel, allow to U -Tube for 1 hr 08:00 09:00 1.00 0 0 COMPZ WHDBO OTHR P Set BPV and VR plugs, Dress Tree 09:00 11:00 2.00 0 0 COMPZ MOVE MOB P Empty pits and prep for rig move, call pad ops,pull rig off well 11:00 12:00 1.00 0 0 COMPZ MOVE MOB P Off well, Rig Released Page 19 of 19 d 1 ® SEAN PARNELL, GOVERNOR ALASKA OIL AND GAS 333 W. 7th AVENUE, SUITE 100 CONSERVATION CO MhII SSIO N ANCHORAGE, ALASKA 99501 -3539 PHONE (907) 279 -1433 FAX (907) 276 -7542 Erik Nelson Wells Engineer ConocoPhillips Alaska, Inc. J� P.O. Box 100360 Anchorage, AK 995103 ( Re: Kuparuk River Field, Kuparuk River Oil Pool, 1E-08 Sundry Number: 310 -401 Dear Mr. Nelson: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Daniel T. Seamount, Jr. Chair DATED this day of December, 2010. Encl. ConocoPhillips Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510 -0360 04 December, 2010 RECE /VED DEC ® 7 2 01 0 Commissioner Dan Seamount .' aska oil & Gas Con's State of Alaska ��RMIMiSiOtt Alaska Oil & Gas Conservation Commission Ancho 333 West 7 Avenue Suite 100 Anchorage, Alaska 99501 Dear Commissioner Seamount: ConocoPhilli s Alaska, Inc. hereby applies for an Application for Sundry Approval to $vr rc�ri b P Y PP PP rY PP �Y r� .� abandeFi the Kuparuk Well 1 E -08 (PTD 180 -081). 7 !L 7• AD 1 E -08 is currently in the middle of a RWO in order to prepare it for future CTD development. The 3 -'/z" tubing selective completion has been pulled down to 7039' MD. In our last attempt to retrieve the lower section of the selective completion from the well, the blast ring section across the C -sand perforations came apart mid - joint. Taking into account our history of broken blast ring retrieval we feel it prudent to cease fishing operations and move to temporarily abandon the well. 1 E -08 will then be s idetracked with a rotary rig in order to allow for future CTD development. If you have any questions or require any further information, please contact me at 263 -4693. Z y, Erik Q. Nels Wells Engineer CPAI Drilling and Well • • 1 E -08 Capital Rig Workover (PTD #: 180 -081) Current Status 1 E -08 is currently in the middle of a RWO in order to prepare it for future CTD development. The 3 - % 2" tbg selective completion has been pulled down to 7039' MD. Remaining in the well are the lower section of blast joints, lowest injection mandrel, and the lower FB -1 packer /tailpipe assembly. As a side note 1 E- 08 had a passing MIT -IA on 24 June 2010 as witnessed by Bob Noble with AOGCC. Possible Scope of Work Attempts to fish the blast joints and the remaining packer /tailpipe assembly failed when a section of the blast rings came apart mid - joint. Due to our historical knowledge continuing fishing operations have a high likelihood of failure due to the characteristics inherent in carbide blast rings. We will move to temporarily abandon the well by placing a retainer above the selective completion remaining in the well and pump cement to isolate the A & C- sands. The cement will then be tested in order to confirm it's integrity and a kill string run to just above the top of cement. General Well info MASP: 2091 psi (utilizing 0.1 psi /ft gas gradient and SBHP listed below) Reservoir pressure /TVD: 2802 psi at 7110' MD (6270' TVD) SBHP taken on 06 February 2010 Wellhead type /pressure rating: FMC Gen I, 11" 3K btm x 7- 1/16" 5K top flange BOP configuration: Annular / Pipe Rams / Blind Rams / Mud Cross / Pipe Rams MITIA and MITOA results: MIT -IA - passed on 24 June 20010 MIT -OA - failed on 26 January 2010 Well Type: Injector Estimated Start Date: 04 December 2010 Production Engineer: David Lagerlef / Dan Bearden Workover Engineer: Erik Nelson (263 - 4693 / Erik.Nelson @conocophillips.com) Proposed Procedure 1. MU Baker cement retainer for 7 ", 26 #/ft casing and TIH to — 6750 ft MD. Set retainer with rotation. PU to test backside to 250/1500 psi for integrity of the retainer. Slack off weight to open lower flapper and perform an injectivity test. 2. Start pumping 50 bbls cmt through drillpipe follow w/ seawater. Calculate volume to retainer and pump until there are — 3 bbls left in pipe. Unsting from retainer while holding squeeze pressure and lay in remaining 3 bbls cement above retainer (— 80 ft). TOOH one stand and circulate (2X) hole volume. 3. Wait on cement until lab tests suggest 500 psi compressive strength. Test cement to 250/3500 psi. 4. TOOH sideways laying down 3 -%" DP. MU original 1 E -08 completion tubing and TIH to tag TOC. PU —50 ft and land tubing hanger. RILDS. 5. Set 2 -way check. ND BOP. NU tree and pressure test. 6. Pull 2 -way check. Freeze protect well. Set BPV. RDMO Nordic 3. — 7vf mop - Y STATE OF ALASKA ALASOIL AND GAS CONSERVATION COMMISSI18 APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 1. Type of Request: Abandon 1 { Plug for Redrill r)P Perforate New Pool Repair well Change Approved Program . Suspend f , jk* Rug Perforations 4i. Perforate Pull Tubing Time Extension .7. Is Operational Sus p. Well erational Shutdown p P � Stimulate �'", Alter casing � Other r` 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development" Exploratory > 180 -081 3. Address: 6. API Number: Stratigraphic ""` Service P. O. Box 100360, Anchorage, Alaska 99510 50- 029 - 20496 -00 7. If perforating, closest approach in pool(s) opened by this operation to nearest property line 8. Well Name and Number: where ownership or landownership changes: Spacing Exception Required? Yes No n 1 E -08 9. Property Designation: 10. Field /Pool(s): ADL 25651 Kuparuk River Field / Kuparuk River Oil Pool 11. PRESENT WELL CONDITION SUMMARY Total depth MD (ft): Total Depth TVD (ft): Effective Depth MD (fty Effective Depth TVD (ft): Plugs (measured): Junk (measured): 7590 Casing Length Size MD TVD Burst Collapse CONDUCTOR 80 16 80' 80' SURFACE 2864 10.75 2896' 2693' PRODUCTION 7568 7 7568' 6543' Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 7010'- 7104', 7274'- 7294', 7304' -7356' 6142'- 6214', 6340'- 6354', 6362' -6398' 3.5 J -55 7177 Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft) PACKER - BAKER TB -1' PACKER MD= 7139 TVD= 6292 12. Attachments: Description Summary of Proposal f 13. Well Class after proposed work: Detailed Operations Program BOP Sketch Exploratory r- Development Service r%—o r 14. Estimated Date for Commencing Operations: 15. Well Status after proposed work: 12/5/2010 Oil Gas WDSPL Suspended rv 16. Verbal Approval: YES Date: 12/4/2010 WINJ r GINJ WAG r Abandoned Commission Representative: Guy Schwartz ✓ GSTOR SPLUG 17. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Erik Nelson @ 263 -4693 Printed Name Erik Nelson Title: Wells Engineer Signature Phone: 263 -4693 Date Commission nl Sundry Number: 3►0- i o Conditions of approval: Notify Commission so that a representative may witness V Plug Integrity r BOPTest Mechanical Integrity Test r Location Clearance Other: _r Ge r1 I,& P / fit. /4.G�xej &Z ✓'011 a Ze, `� a _ t !ly 0 Zo AA C_ Z S. //o CH) DEC 2010 Subsequent Form Required: /� L/ p� 1,A & Gas ions. Gommi aion Anchorage APPROVED BY ( p A Approved by COMMISSIONER THE COMMISSION Date: / ) 2-! " d /Z7 /a Form 10 -403 Revised 01 Submit in Duplicate URIGINAL t -r � ,erF�: • KUP . 1E -08 ca m11 Well Attributes iMax Angle 4 MD Inc/ L TD r,. Wellbore APUUWI I Field Name Well Status I/ ( °) MD (ftKB) Act BUn (ftKB) 500292049600 �KUPARUK RIVER UNIT , INJ 46.75 7,450.00 7,590.0 ° C ..nt H2S (ppm) Date An otation End Date IKB - Grd (ft) Rig Release Date .1R410 7:16 M . SSSV Locked Out � .... �.. _ _ st WO: 11/1/1984 3899 10128/1980__ /�G Annotation Depth (ftKB) End Date Ann W Last Mod ... End Data Last Tag' SLM 7,334 0 10/2/2009 Rev Reason_Pull_ Patch Assy, TBG Cut Imos 1 10/31/2010 Casing Strings HANGER, 29- - -- ---- ':•" ; Casing DescriptionString 0... String ID.- Top (kK8) Set Depth (f... Set Depth (ND) ... String Wl... String ... String Top Thrd r,. CONDUCTOR 16 15.060 32.0 80.0 80.0 65.00 H40 WELDED _ w : Casing Description Sfring 0... String ID ._ Top (ftKB) Sel Depth (E.. Set Depth &VD) ... String Wt... Str g ... Strirg Top It d SURFACE 10 3/4 9.794 31.8 2 895.6 2,705.5 45.50 K -55 BTC .__ _ - -° -- -- -- Casing Description String 0... String ID ... T (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd PRODUCTION 7 6.151 30.9 7,568.0 6,594.8 26.00 K -55 Tubing Strings - - Tubing Descnpt on String ... String ID ... Top (kK6) Set Depth (t... Set Depth (TVD) .. String Wt... iStr ng .. Stang Top Thrd TUBING (QC) 3 112 0 2.992 28.6 7,176.4 6,319.8 920 J -55 MOD BUTT CONDUCTOR Completion Details To De h 32 -BO P I (ND) Top Intl NOmi... SAFETY VLV,_ To (ftK6) (ftKB) ( %_ Item Description Com _ ID (in) 1 • 28.6 28.6 -12.67 HANGER FMC HANGER 3.500 GAS uFr, _ 1,834.9 1,802.7 28.01 SAFETY VLV CAMCO TRDP -1A SAFETY VALVE (Locked Out 3/17188) 2.813 1,937 6,820.6 6,044.5 40.03 SBR (BAKER SBR 2.513 6,846.8 6,064.7 39.38 PACKER BAKER FHL RETRIEVABLE PACKER 3.000 fl 6,988.8 6175.7 3811 BLAST JT BLASTJTS 7,138.7 6290.9 40,56 PACKER (BAKER FB 1PACKER - 4.000 SURFACE, 7,141.2 6,292.8 40.63 SBE BAKER SEAL BORE EXTENSION 2.813 32 -2,896 �` 7,159.5 6,306.9 41.14 NIPPLE BAKER D NIPPLE NO GO PROFILE 2.750 - 7,175.6 6,319.2 41.58 SOS BAKER SHEAR OUT SUB 2.992 GAS LIFT,_ 3,789 Other In Hole /reline retrievable plugs, valves pumps, fish, etc. Top Depth (TVD) Top Incl 7 kK6 ( ( °) Desc'tion C omment Run Date IDlin) GAS LIFT, 6,805.0 6,032.6 40.01 TBG CUT PRE- WORKOVER TUBING CUT 10222010 2.992 5,120 6,973.0 6,163.2 38.20 TBG CUT PRE- WORKOVER TUBING CUT 10/22/2010 2.992 GASUFT,_____ -_ - -_ ' - 7,113.0 6,270.7 39,86 TBGCUT -- PRE WORKOVER TUBING CUT 10/2212010 2.992 5,618 - -___.. 07 __ ____ - ___._ - .._ _.___ - _ 7,159.5 6,30 4114 Nip Reducer AVA'D'Profle 11!17/1995 1.813 GAS LIFT. 6,058 Perforations $Slots - - _ Shot Top (rV D) Btm (TVD) Dens GAS LIFT, T ftKB Btm ji!K6 (ftKB) (sh comment 6,467 7,010.0 7,104.0 - 6,19 6,263.5 C4, C -3, C -2, &27/1981 4.0 (PERF SOS 2 1/8 Enerjet 0 C -1, 1E -08 GAS LIFT, � - 7,274.0 7,294.01 6,391.2 6,405.6 AS, 1E -08 827/7981 4.0 PERF Rigidjet 6,782 7,304.0 7,356.0 6,413.0 6,449.2 A4, tE - 08 8/27/1981 4 0 PER Rigld)et UT, TBG 6, _ j Notes: General &Safety g End Dale Annotation 8/24/2010 NOTE: View Schematic w/ Alaska Schematic9.6 SBR, 6,821 PACKER, 6,847 INJECTION, 6,884 INJECTION, 6,951 TBG CUT 6,973 i i IPERF,_ 7,01(1-7,104 TBG CUT, --_.. 7,113 + -J INJECTION, 1 7,121 t � PACKER, 7,139 - - - ' - -- - SSE, 7,141 ---- NIPPLE. ],159 I Mandrel Details. Nip Reducer, Top Depth Top Port 7,160 (TVD) Inc/ t Valve Latch Size TRO Run Sm To KB (ftKB) ( °) Nake MoAe Sefv Tj'Pe Type (in) (Psi) Run Dale Cam... SOS, 7,176 1 7,937 4 1,891.9 30.74 MMH 3.5 x 1 GAS LIFT DMY BK 0.000 0.0 7/9/1990 2 3,788.7 3,458.1 32.59 MMH 3.5 x1� GAS LIFT DMY BK 0.000 0.0 6/611990 GA PERF, 3 5,119.5 4,597.7 29.73 MMM 3 5 x 1 S LIFT DMY BK 0.000 0.0 6/617990 7.274 - 7.294 «. 4 5617.7 5031.8 30.19 MMH 3.5 x 1 GAS LIFT DMY BK 0 000 0 0 6/6/1990 PERF 57.9 5407.8 31.45 MMH 3.5 x 1 GAS LIFT DMY BK 0 i .060 0- 5/14/1987 7,304 -7.ass 6 6,467.1 5,760.3 32.47 MMH 3.5 x 1 VGAS MY BK 0000 0.0 11/1/1984 7 6,782.3 6,015.2 39.69 MMH 3.5 x 1 OPEN 0.000 0.0 10/21/2010 8 6,883.7 6,093.2 39.20 MMH 3.5 x 1 DMY BK 0.000 0.0 11/7/1995 9 6,9512 6,1462 38,32 MMH 3.5 x 1 DMY BK 0.000 0.0 11!7/1995 PRODUCTION, 31as6a 10 7,120.9 6,276.9 4007 MMH 3.5 x 7 DMY BK 0.000 0.0 11!7/1995 TD, 7,590 Page 1 of 2 Schwartz, Guy L (DOA) From: Schwartz, Guy L (DOA) Sent: Saturday, December 04, 2010 9:59 AM To: Nelson, Erik Q Subject: Re: KRU 1 E -08 P &A review Erik, You have verbal approval to proceed with plugging operations as detailed below in your attachment. A 403 sundry will be required to change well status to suspended. , GuyC�^' Sent from my iPhone On Dec 3, 2010, at 4:26 PM, "Nelson, Erik Q" < Erik .Nelson(�t)conocophillips.com> wrote: Guy, We request verbal permission to perform an abandonment of 1 E -08 (PTD #180 -081) in the event we are unable to achieve the objectives of the originally submitted sundry ( #310 -338). Attached is a detailed outline of the proposed temporary abandonment of the well. I will notify you when we move to temporarily abandon the well and will get an Application for Sundry Approval (Form 10 -403) submitted first thing Monday morning if we ultimately do this over this coming weekend. Thank you for your assistance in this matter. Q Erik Q. Nelson Workover/Wells Engineer ConocoPhillips Alaska, Inc. Office # 1590 700 G. Street Anchorage, AK 99,501 Office (907) 263 - 4693 Fax (907) 265 - I535 Cell (907) 903 - 7407 I From: Schwartz, Guy L (DOA) [mailto:guy.schwartz @alaska.gov] Sent: Friday, December 03, 2010 2:40 PM To: Nelson, Erik Q Cc: Roby, David S (DOA) Subject: FW: KRU 1E -08 P&A review <image001.gif> 12/7/2010 Page 2 of 2 Erik, Can you request verbal approval to abandon the lower part of 1 E -08. I will need detailed steps on what you plan to do also.. such as retainer depth, cement volumes etc. As we discussed this only includes setting a retainer and pumping cement and NOT initiating a sidetrack with Nordic 3. A separate PTD will be required for that. _ Although it is understood that this P & A pathway is likely to happen there is also a possibility that the planned workover operation may be successful too. However, as the operations are ongoing over the weekend this will give you some flexibility. Please notify myself when you make a decision to move forward with the P & A .... A 403 sundry will need to be generated ASAP and submitted for plugging 1 E -08 for redrill. Guy Schwartz Senior Petroleum Engineer AOGCC 793 -1226 (office) 444 -3433 (cell) From: Roby, David S (DOA) Sent: Friday, December 03, 2010 2:28 PM To: Schwartz, Guy L (DOA) Subject: KRU 1E -08 P&A review Guy, After our discussion with Jill Long regarding the possibility of having to abandon the subject well to prepare it for sidetrack I do not think we need to do a formal abandonment reserves review. The reason for this is that as she explained it the upcoming sidetrack would be planned to continue A -sand water injection in this fault block and thus continue to provide support for the wells that are supported by the current wellbore. Additionally the well would target additional fault blocks and provide support in them also. Therefore, the oil recovery in this portion of the pool should be improved by what CPAI proposes to do. Dave Roby Reservoir Engineer Alaska Oil and Gas Conservation Commission (907)793 -1232 <1E -08 _PTD# 180 -081_ Temporary Abandonment Request_03December2010.pdf5 12/7/2010 . v 1 E -08 Capital Rig Workover (PTD #: 180 -081) Current Status 1 E -08 is currently in the middle of a RWO in order to leave it setup for CTD development. The 3 - %" tbg selective completion has been pulled down to 6980' MD. Remaining in the well are the blast joints, lowest injection mandrel, and the lower FB -1 packer /tailpipe assembly. As a side note 1 E -08 had a passing MIT -IA on 24 June 2010 as witnessed by Bob Noble with AOGCC. Possible Scope of Work If attempts to fish the blast joints and /or remove the remaining packer /tailpipe assembly ultimately fail we will move to temporarily abandon the well by placing a retainer and pumping cement to isolate the A & C- sands. General Well info MASP: 2091 psi (utilizing 0.1 psi /ft gas gradient and SBHP listed below) Reservoir pressure/TVD: 2802 psi at 7110' MD (6270' TVD) SBHP taken on 06 February 2010 Wellhead type /pressure rating: FMC Gen I, 11" 3K btm x 7- 1/16" 5K top flange BOP configuration: Annular / Pipe Rams / Blind Rams / Mud Cross / Pipe Rams MITIA and MITOA results: MIT -IA - passed on 24 June 20010 MIT -OA - failed on 26 January 2010 Well Type: Injector Estimated Start Date: 04 December 2010 Production Engineer: David Lagerlef / Dan Bearden Workover Engineer: Erik Nelson (263 - 4693 / Erik.Nelson @conocophillips.com) Proposed Procedure 1. MU Baker cement retainer for 7 ", 26 #/ft casing and TIH to - 6750 ft MD. Set retainer with rotation. PU to test backside to 250/1500 psi for integrity of the retainer. Slack off weight to open lower flapper and perform an injectivity test. 2. Start pumping 50 bbls cmt through drillpipe follow w/ seawater. Calculate volume to retainer and pump until there are - 3 bbls left in pipe. Unsting from retainer while holding squeeze pressure and lay in remaining 3 bbls cement above retainer (- 80 ft). TOOH one stand and circulate (2X) hole volume. 3. Wait on cement until lab tests suggest 500 psi compressive strength. Test cement to 250/3500 psi. 4. TOOH sideways laying down 3 - %" DP. MU original 1 E-08 completion tubing and TIH to tag TOC. PU -50 ft and land tubing hanger. RILDS. 5. Set 2 -way check. ND BOP. NU tree and pressure test. 6. Pull 2 -way check. Freeze protect well. Set BPV. RDMO Nordic 3. Page 1 of 1 4 0 Subject: FW: INTENT PLUG for RE -DRILL WELLS: Corrected From: Davies, Stephen F (DOA) Sent: Monday, February 08, 2010 10:52 AM To: Foerster, Catherine P (DOA); McMains, Stephen E (DOA); Schwartz, Guy L (DOA); Saltmarsh, Arthur C (DOA); Aubert, Winton G (DOA) Subject: RE: INTENT PLUG for RE -DRILL WELLS: Corrected Revised procedure with an additional step per Cathy's comment: INTENT PLUG for RE -DRILL WELLS (IPBRD) Type Work Code in RBDMS 1. When a Form 10 -403 is submitted requesting approval to plug a well for redrill, the initial reviewer (Art or Steve D.) will check to make sure that the "Plug for Redrill" box in the upper left corner of the 403 form is checked. If the "Abandon" box is checked, we will cross that erroneous entry out and initial it on both copies of the Form 10 -403 (AOGCC's and operator's copies). 2. On the Form 10 -403 if "Abandon" is checked in Box 15 (Well Status after proposed work), Art or Steve D. will cross that erroneous entry out and initial it on both copies of the Form 10 -403 (AOGCC's and operator's copies). Instead, we will check the "Suspended" box. Guy and Winton will serve as quality control for steps 1 and 2. 3. When Steve McMains receives the Form 10 -403 with a check in the "Plug for Redrill" box, he will enter the existing code "IBPRD" into RBDMS. This code automatically generates a comment under the History tab stating "Intent: Plug for Redrill." 4. When Steve McMains receives any Form 10 -407, he will check the History tab in RBDMS for this comment. If he sees the "Intent: Plug for Redrill" code, and cannot find any evidence that a subsequent re -drill has been CO he will assign a status of SUSPENDED to the well bore in RBDMS, no matter what status is listed on the 10 -407. Steve will also change the status on the 10 -407 form to SUSPENDED, and will date and initial his change. If Steve does not see the "Intent: Plug for Redrill" comment or code, he will enter the status listed on the Form 10 -407 into RBDMS. 5. When the Form 10 -407 for the redrill is received, Steve M. will change the original well's status from suspended to abandoned. 6. The first week of every January and July, Steve M. and Steve D. will check the "Well by Type Work Outstanding" user query in RBDMS to ensure that all of the Plug for Redrill wells have been handled properly. At this same time, Steve M. and Steve D. will also review the list of suspended wells for accuracy. Thanks, Steve D. file: //F:\Daily Document Record\Procedures Instructions\FW INTENT PLUG for RE -D... 12/7/2010 . • Regg, James B (DOA) Page 1 of 1 From: Nordic 3 Company Man [n1433 @conocophillips.com] Sent: Monday, November 22, 2010 5:57 PM C� To: DOA AOGCC Prudhoe Bay �,3� C) Cc: CPA Wells Supt; Nelson, Erik Q j `1 ( 1 qo Subject: Nordic Rig 3 Well Shut -in \� John, Bob, Per our discussion, today we were making a fishing run for an SBR seal assembly. The SBR run was going to be followed by a run for the packer. It appears that the packer was released with the SBR. While circulating bottoms up after releasing the packer, we noticed an increase in returns and our shaker gas alarm sounded. We shut in the upper pipe rams. The gas has been circulated out. The max gas units value was not recorded. The Upper Pipe Rams will be tested at 250/3,500 psi just as soon as we get out of the hole. Date: 11/22/10 Rig: Nordic 3 Well: 1 E -08 Time: 14:00 hrs SI Tubing Pressure: 0 psi SI Annulus Pressure: 40 psi NO Pat Reilly / Lee Hinkel Office 659 -7446 11/23/2010 • MEMORANDUM Tai Jim Regg P.I. Supervisor 1~~~ ~ ~~1~ FROM: $Ob NOble Petroleum Inspector State of Alaska Alaska Oil and Gas Conservation Commission DATE: Wednesday, June 30, 2010 SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 1 E-08 KUPARUK RIV UNIT 1E-08 Src: Inspector NON-CONFIDENTIAL • Reviewed By: P.I. Suprvy~~ Comm Well Name: KUPARUK RIV UNIT ]E-08 API Well Number: 50-029-20496-00-00 Inspector Name: Bob Noble Insp Num: mitRCN100627072918 Permit Number: 180-08 1-0 Inspection Date: 6/24/2010 Rel Insp Num: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well ~ IE-os Type Inj N~TVD 6017 IA~ 260 ~ 2400 ~, 2360 2350 ~ I _ __ p.T t~j lsoo8lo i p Test SPT ;Test psi zaoo Op ~ so 60 ~ - 60 60 ~ 390 p~F P Tubing Interval axRTST 400 400 400 _ Notes: ~;,~ ~~, ~ .~~- ! 5`~ fr,,` ~r 4, n a. rV 1: _. Wednesday, June 30, 2010 Page 1 of 1 ConacoPhillips a~~a P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 July 16~', 2010 Commissioner Dan Seamount Alaska Oil & Gas Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 Commissioner Dan Seamount: ~~~~~~~ G~C~et,ss~a~ ~~~ka & Anc~~age D~.v~~ I~~©~. Enclosed please find a spreadsheet with a list of wells from the Kuparuk field (KRil). Each of these wells was found to have a void in the conductor. These voids were filled with 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 November 25~' 2007 & March 21 2009, the corrosion inhibitor/sealant was pumped July 6~', 7th, 8~` 2010. The attached spreadsheet presents the well name, top of cement depth prior to filling, and volumes used on each conductor. Please call Perry Klein or MJ Loveland at 907-659-7043, if you have any questions. Sincerely, Perry Klem 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 7116110 1 A. 1 C.1 E PAD 1 Well Name API # PTD # Initial top o cement Vol. of cement um ed Final top of cement Cement top off date Corrosion inhibitor Corrosion inhibitor/ sealant date ft bbis ft al 1A-11 50029206850000 1811730 10" n/a 10" n/a 3.4 7/8/2010 1A-12 50029206880000 1811780 2" Na 2" Na 1.7 7/8/2010 1A-13 50029207000000 1811950 11" Na 11" Na 3.4 7/8/2010 1A-14 50029207060000 1820100 4" Na 4" Na 2.1 7/8/2010 1 C-01 50029205260000 1801280 SF n/a 24" Na 4.3 7/6/2010 1 C-02 50029205320000 1801350 24" n/a 24" n/a 8.5 7/6/2010 1 C-03A 50029205350100 2070630 SF n/a 16" n/a 7.7 7/6/2010 1C-04 50029205470000 1801550 SF n/a 5" n/a 2.6 7/6/2010 1C-06 50029205640000 1810250 76 17.70 32" 3/21/2009 9.4 7/6/2010 1 C-09 50029208590000 1821850 38' 8.00 6" 11 /25/2007 6.8 7/6/2010 iC-10 50029208650000 1821930 37'6" 8.00 8" 11/25/2007 6.8 7/6/2010 1E-02 50029204720000 1800500 21" n/a 21" n/a 1.7 7/7/2010 1 E-03 50029204770000 1800560 4" n/a 4" Na 2.4 7/7/2010 1E-06 50029204930000 1800780 12" n/a 12" Na 13.6 7/7/2010 1 E-07 50029204950000 1800800 5" n/a 5" Na 2.6 7/7/2010 1E-08 50029204960000 1800810 5" Na 5" Na 2.B 7A2090 1E-10 50029207250000 1820360 2" n/a 2" Na 1.7 7/7/2010 1E-13 50029207500000 1820780 5" n/a 5" Na 2.6 7/7/2010 1E-19 50029209050000 1830170 1" n/a 1" Na 1.7 7/7/2010 1E-21 50029208920000 1830020 3" n/a 3" Na 2.6 7/7/2010 1E-24A 50029208570100 1971870 2" n/a 2" Na 1.7 7/7/2010 1 E-25 50029208440000 1821700 3" n/a 3" Na 1.7 7/7/2010 1E-28 50029208320000 1821580 4" n/a 4" n/a 2.5 7/8/2010 1E-29 50029208280000 1821540 7" n/a 7" Na 2.5 7/8/2010 WELL LOG TRANSMITTAL To: Alaska Oil and Gas Conservation Comm. Attn.: Christine Mahnken 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: Injection Profile: 1E-08 Run Date: 12/9/2009 • March 12, 2010 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Rafael Barreto, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 1 E-08 Digital Data in LAS format, Digital Log Image file, Interpretation Report 1 CD Rom 50-029-20496-00 Injection Profile Log 50-029-20496-00 ~~~~ ~~,~ ~K, ~ ~~1 r,~;;~ 1 Color Log PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline & Perforating Attn: Rafael Barreto %~ 6900 Arctic Blvd. /~ Anchorage, Alaska 99518 / Office: 907-273-3527 Fax:907-273-3535 rafael.barreto c~?fraliiburtork.com Date: V1~ t`6U --C~~- ~~~esa ~- Signed: • STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPE~tAT10NS 1. Operations Pertormed: Abandon ^ Repair Well ^ Plug Perforations ^ Stimulate ^ Other ~ nstall and catch , Alter Casing ^ Pull Tubing ^ Perforate New Pool ^ Waiver ^ Time Extension ^ Change Approved Program ^ Operat. Shutdown^ Perforate ^ Re-enter Suspended Well ^ 2. Operator Name: 4. Well Ciass Before Work: 5. Permit to Drill Number: ConOCOPhillips Alaska, InC. Development ^ Exploratory ^ 180-081 / 3. Address: Stratigraphic ^ Service ^/ ' 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-029-20496-00 7. KB Elevation (ft): 9. Well Name and Number: RKB 105' ~ 1 E-08 • 8. Property Designation: 10. Field/Pool(s): ADL 25651 Kuparuk River Field /Kuparuk Oil Pool 11. Present Well Condition Summary: Total Depth measured 7590' ' feet true vertical 6559' feet Plugs (measured) Effective Depth measured 7330' feet Junk (measured) true vertical 6380' feet Casing Length Size MD TVD Burst Collapse Structural CONDUCTOR 80' 16" 80' 80' ~"'~' SUR. CASING 2867' 10-3/4" 2896' 2693' B-SAND LINER 3949' 7" 7568' 6543' Perforation depth: Measured depth: , 7010'-7104', 7274'-7294', 7304'-7356' true vertical depth: 6142'-6214', 6340'-6354', 6361'-6398' Tubing (size, grade, and measured depth) 3-1/2" , J-55, 7176' MD. Packers &SSSV (type & measured depth) pkr- BAKER'FHL' RETR. ; BAKER'FB-1' pkr= 6847' ; 7139' Cameo TRDP-1A SSSV= 1835' 12. Stimulation or cement squeeze summary: Intervals treated (measured) not applicable Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casin Pressure Tubin Pressure Prior to well operation 400 -- Subsequent to operation 338 - 14. Attachments 15. Well Class after work: Copies of Logs and Surveys run _ Exploratory ^ Development ^ Service Daily Report of WeII Operations X 16. Well Status after work: ~~'~ j O ~t fJ _ Oil^ Gas^ WAG GINJ^ WINJ ~ WDSPL ^ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: 308-176 Contact John Peirce @ 26 5-6471 Printed Name John Peirce Title Wells Group Engineer ~~ ^" "" Signature ~ r-' ,~ Phone Date Z ~g LcJ Pr ared b Sharon Allsu Dra a 263-4612 Form 10-404 Revised 04/2006 ^ ~ ~ Submit Original Only ~r ~~~AL 1 E-08 Well Work DATE SUMMARY 3/12/08 RAN INJECTION PROFILE. ~ULTS: STRADDLE COMPLETION LEA~ENTIFIED AT 7120' IN 22' MERLA TBG PATCH SET FROM 7114-7136' TUBING TALLY DEPTHS. SPLITS: 36%A AND 64% C. A SAND CROSSFLOWING INTO C-SAND THROUGH LEAIS IN LOWER MERLA PATCH WITH WELL SHUT IN. BEST INDICATOR OF LEAK DEPTH SEEN IN UP/DOWN OVERLAY WITH WELL SHUT IN. 6/23/08 DRIFT THROUGH BOTH PATCHES W/ 2.28" SWAGE. BRUSH & FLUSH TBG & PATCHES. LOG f/ NIP REDUCER @ 7160' RKB TO SURFACE W/ PDS CALIPER, GOOD DATA. DRIFT TO NIP REDUCER @ 7160' RKB W/ 2.23" CENT, 15' OF 1.875" STEM & 5' OF 2.25" BLR (OAL=21.5'). JOB COMPLETE 9/12/08 SET TTS TUBING PATCH FROM 7117' TO 7147'. TOOK OVERPULLS WHILE LOGGING THROUGH EXISTING PATCH. POOH. PRESSURE UP ON TUBING TO SET INFLATABLE PACKER AND TEST PATCH. TEST WAS GOOD. CONTINUED PUMPING TO 4200 LBS TO SHEAR DISK IN PACKER. -- 1~VS aV~©('~' 1~~~~p5 ~ + KUP Well Attributes i" ,waua.:.~,,,:FUUwr FletaHa~~re ~+eusww:. m..a lo~ij ~:ao(nKSj ' ""~' • 500292049600 KUPARUK RIVER UNIT INJ 46.75 ~ 7,45f -- --- ~~-~~ Comment H2S (ppm) ;Date Annotation End Date KB-0rd (R ... - - _ _.. _ _ SSSV: TRDP 0 i 7/112008 Last WO: 1111/1984 38. _ .,.. J .~. ~~.I ~ ... - _ _- r.,,, .. „ -Annotation DepM (RKB):End Date Annotation c, vt Tag: 7,330.0 ~ 211312008 Rev Reason: SET PATCH I Casing Strings CONDUCTOR, ~ ~ ~ Casing Description ODI(1n) I Slr") ID Top IRKB) S (RKB)th 80 SAFETY VALVE, 1,835 GAS LIFT, 1,936 SURFACE, 2,896 GAS LIFT, 3,]89 GAS LIFT, 5,120 GAS LIFT, 5,616 GAS LIFT, 6.058 GAS LIFT, 6,46'7 GAS LIFT, 6,783 SBR, 8,827 SACKER, 6,847 INJECTION, 6,884 INJECTON, 8,952 PATCH, 7,014 805 21/8 Enerjel 0, 7,010.7,100 INJECTION, 7,121 PATCH, 7,114 PATCH. 7.117 SACKER, 7,139 NIPPLE, 7,160 NIPPLE REDUCER, 7,160 SOS. 7.176 TTL. 7.17] Rigitljet, 7,2]0-7,294 Repertetl t/26/&5 90, 7,300.7,358 PRODUCTION, 7,568 TD, 7,590 Snl DeyN ITL'D) SUUig 1Ji Jkuig (RK8) (1bs/ft) Gratle 1 E-08 Teal Onpth (nKB) 7,590.0 Rig Release Date 10/28/1980 d Date 921/2008 Tubing Strings 5 U 4 - LcL~lh r J q TubingC _,:ri Uticn ~ ID IinI Tcy IRKH1 (nMl:~ ~e[L!yrft l/UI InH B) (It ftl ~r le Srrin Tnp TM1rtl Other In Hole (All Jewelry: Tubing,ftun & Retrievable, Fish, etc.) Top (IIY.B) fieaeription ~ den Knl Run Gain IG iln) 1,835.0 SAFETY Camco TRDP 1A (Locked Out 3/17/88) Pulled WRDP on 6/21197 ;111111984 i 2.8131 1,938.0 GAS LIFT 3,789.0 GAS LIFT ~ 6,783.OiGAS LIFT MMH/3.5x1/1/DMYIBK//I Comment STA7 13/1611988 28591 7,014.0 PATCH 22' Meda 7bg Patch; Set on 11119/95 11/19/1995 2.375 7,114.0 PATCH 22' Meda Tbg Patch; Set on 11119/95 11/19/1995 2.375 7,117.0 PATCH 30' OAL TTS PATCH 7117-7147; 2.13" OD RETRIEVABLE SEALBORE INFLATABLE PACKER ON BOTTOM; 2.225" OD TTS SIZE 287 PARAGON 2 RETRIEVABLE DUEL SEAL BORE PACKER ON TOP 9/122008 1.125 7,727.O IINJECTION MMHl3.5x111/DMYIBK!//Comment: CLOSED STA 10 111711995 2.859 'D' Profile; Set on 7,177.0 TTL 11/1/1984 2.992 Perforat ions Top (ND) Btm (TVD) ~ snei Dens Top (RKB) Btm (1d(B) (RKB) (RKB) Type Zone (shot-~ Date Comment 7,010.0 7,104.0 6,142.2 6,214.3 SOS 2 C-0, C-3, C-2, 4.0 82711981 I ~ 1/8 C-1, 1E-08 I ~ Enerjet 0 ~ 7,274.0 7,294.0 6,339.91 6,354.2 Rigidjet A-5, 1E-OS 4.0 8127/1981 Reperfed 7,304.0 7,356.0 6,361.5 6,397.8 Reperfed A-4, tE-08 4.0 8/27/1981 ' Reperfed 126/85 90 ~~~ ~~ Ti4~4N~~ollT°T~4L ProActiwe Diagnostic Services, Inc. To: AOGCC Christine Mahnken 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 (907j 659-5102 • RE : Cased Hole/Open Hole/Mechanical Logs and /or Tubing Inspection(Caliper/ MTTj The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal fetter to the following ProActive Diagnostic Services, Inc. Attn: Robert A. Richey ~~~ ~U~~ .~, ~ 2Q~8 130 West International Airport Road Suite C Anchorage, AK 99518 Fax: [907] 245-8952 1 j Caliper Report 23-Jun-08 1 E-08 2j Signed Print Name: ;~ ;~ ~~ _ 1 // a~e/'~f - 1 Report / EDE 50-029-20496.00 Date: - PROACTIVE DIAGNOSTIC SERVICES, INC., 130 W. INTERNATIONAL AIRPORT RD SUITE C, ANCHORAGE, AK 99518 PHONE: (807)245-8951 FAX: (807)245-88952 E-NIAII.: a?~.,a?a. :3-~ ~~' ~':~':;"°ar„S: ,I~~ ^'„ i? WEBSITE ~ ,6`J,f c~. ~i''3~,~~ r"a^ ~ ~~ ~=t;~ ~f ~ .. ~ C:\Doeuments and Settings\Owner~Desktop\Transmit_BP.doc • • Memory Muni-Finger Caliper Log Results Summary Company: ConocoPhiilips Alaska, Inc. Weil: 1 E-08 Log Date: June 23, 2008 Field: Kuparuk Lag No.: 8692 State: Alaska Run No.: 1 API No.: 50-029-20496-00 Pipet Desc.: 3.5° 9.2 Ib. J-55 Buttress Top Log Intvl .: SurFace Pipet Use: Tubing Bot. Log Intvl .~ 7,142 Ft. {MDR Inspection Type : Corrosive & Mechanical Damage Inspection COMMENTS This caliper data is tied into the lower 22' Merle Tubing Patch @i 7,774' (Dril/er's Depot). This log was run to assess the condition of the tubing with respect to intemal corrosive and mechanical damage. The caliper recordings indicate that the 3.5" tubing logged is in good condition, with a 17% isolated pit in jt. 85 (2,661') being the most significant damage recorded in the tubing. No other significant wall ' penetrations (> 17%}, areas of cross sectional wall loss (> 6°~) or t.D. restrictions are recorded throughout the interval logged. An (PROF (12-Mar-08} indicated a known leak in the lower Merla tubing patch in this well (1~7 7,120'. The caliper recorded damage in the form of corrosion wikh pitting as deep as 0.05" in both Merla patch intervals in this well. A 3-D log plot of the caliper recordings across the lower Merla patch interval (7,095' - 7,143') is included in this report. MAXIMUM RECORDED WALL PENETRATIONS No significant wall penetrations (> 17°~) are recorded throughout the interval togged. i MAXIMUM RECORDED CROSS-SECTIONAL METAL LOSS No areas of significant cross-sectional wall loss (> 6°!0} are recorded throughout the interval logged. MAXIMUM RECORDED ID RESTRICTIONS : No significant l.D. restrictions are recorded throughout the interval logged. Field Engineer. K. Miller Analyst: HY. Yang Witness: S. Ferguson t ProActive Diagnostic Services, Inc. / P.O. Box 1369, Stafford, TX 77497 Phone: (281) or (888) 565-9085 Fax: (281) 565-1369 E-mail: PDS a~memorylog.com Prudhoe Bay Field Office Phone: (907) 659-2307 Fax: (907) 659-2314 U-r~ ~bU-Ofst ~ ICES-l~~ ~~~ Description Joint 226 Pup Jt 226.1 22' Merla Tubing Patch • • PDS Mu(tifinger Caliper 3D Log Plot Company : ConocoPhillips Alaska, Inc. Field : Kuparuk Well : 1 E-08 Date : June 23, 2008 Detail of Caliper Recordings Across Lower 22' Merla Tubing Patch 7100 7110 7120 7130 7140 • Correlation of Recorded Damage to Borehole Profile Pipe 1 3.5 in (5.1' - 7137.7') Well: 1 E-08 Field: Kuparuk Company: ConocoPhiAips Alaska, Inc. Country: USA Survey Date: June 23, 2008 ^ A pprox. Tool De viation ^ A pprox. Borehol e Profil e 1 25 25 773 50 1548 GLM 1 75 2333 100 3103 p L ~~ GLM 2 c Z 125 3883 s c ' a o, o 150 4653 GLM 3 175 5427 GLM 4 GLM 5 200 6218 GLM 6 7 I~ ~ 225 7050 226.3 7138 0 5 0 1 00 Dam age P rofile (% wall) / Tod D eviatio n (degr ees) Bottom of Survey = 226.3 • • PDS Report overview ~ ~. Body Region Analysis Well: tE-08 Survey Date: June 23, 2008 Field: Kuparuk Tool Type: UW MFC 24 No.212330 Company: ConocoPhillips Alaska, Inc. Tool Size: 1.69 Country: USA No. of Fingers: 24 Anal st: HY. Yan Tubing: Nom.OD Weight Grade & Thread Nom.ID Nom. Upset Upper len. Lower len. 3.5 ins 9.2 f -55 Buttress 2.992 ins 3.5 ins 6.0 ins 6.0 ins Penetration and Metal Loss (% wall) penetration body tae metal loss body 250 200 150 100 50 0 0 to 1 to 10 to 1% 10% 20% 20 to 40 to over 40% 85% 85% Number of'oints anal se d total = 230 pene. 0 226 4 loss 85 145 0 0 0 0 0 0 0 Damage Configuration (body ) 10 0 isolated general line ring hole / poss pitting corrosion corrosion corcosion ible hole Number of 'Dints dama ed total = 3 3 0 0 0 0 Damage Profile (°~ wall) ~ penetration body rt___ metal loss body 0 50 100 n GLM 1 GLM 2 GLM 3 GLM 4 GLM 5 GLM 6 IM 9 Bottom of Survey = 226.3 Analysis Overview page 2 • PDS REPORT JOINT TABULATION SHEET Pipe: 3.5 in 9.2 ppf J-55 Buttress Wep: 1E-08 Body Wall: 0.254 in Field: Kuparuk Upset Wall: 0.254 in Company: ConocoPhilips Alaska, Inc. Nominal I.D.: 2.992 in Country: USA Survey Date: June 23, 2008 Joint No. Jt. Depth (Ft.) I'rn. l)Is~~t (In>.~ Pen. Body (Ins.) Nr~n. % ~~tct,~l I~,,. °<, Min. LD• (Ins.) Comments Damage Profile (%wall) 0 50 100 1 5 l) 0.02 7 1 6 PUP 15 U 0.01 4 1 2.98 PUP .3 21 t~ 0.01 ~ I .99 PUP 1 25 U .01 5 2.96 2 57 t~ 0.0 -i .94 3 88 t ~ 0.01 d .94 4 120 a 0.01 ~' I 2.95 5 15 ~) 0.01 2.95 6 183 ~) 0.01 -t I 2.9 7 15 t l 0.01 4 I 2.9 8 246 U 0.01 I .9 9 2 78 a 0.02 t3 I 2.91 10 309 (~ 0.01 .' I 2.93 1 339 t ~ 0.01 _' I 2.95 12 370 t~ 0.01 ~' 1 2 94 13 402 t 1 0.02 ~ ' 2.93 14 4 3 t) 0.02 t3 ~' 2.94 15 464 U 0.01 -1 1 .9 16 49 t ~ 0.01 G t) 2.92 526 l1 0.01 i I 2.94 18 555 t ~ .01 4 2.95 19 586 U 0.01 5 ' .94 20 61 t) 0.01 4 ' .97 21 647 n 0.01 1 1 2.95 2 678 U 0.01 S 1 2.96 23 709 U 0.01 4 I 2.96 24 741 U 0.01 ~ ,' 2.97 25 773 t ~ 0.01 4 _' 2.98 26 804 ~) 0.01 5 ' 2. 27 834 i) 0.01 ~ 2 2.95 28 865 t ~ 0.01 5 2 .95 29 $96 t ~ 0.01 4 1 2.96 30 927 t) 001 2 1 2.93 31 958 a 0.01 4 Z 2.94 3 990 t) 0.01 4 ' 2.93 33 1021 t t 0.01 4 4 2.95 34 1051 t ~ 0.01 4 ~' 2.97 35 1082 c) 0.01 3 I 2.95 36 1113 c) 0.01 4 I 2.95 37 1142 a 0.03 t l 1 2.93 8 1174 l) .0 4 I 2.95 39 1205 t) 0.02 I 2.94 40 1237 u 0 01 -t ~ 2.96 41 1268 U 0.01 5 .96 4 1 0 c) .01 4 2.99 43 1331 t 1 0.02 t3 _' 2.94 44 1363 U 0.01 4 .99 45 1395 t 1 0.01 6 ~' 2.96 46 142 5 t ~ 0.01 ~' I 2.94 47 1456 ! ~ 0.01 ~ I 2.93 _ Penetration Body Metal Loss Body Page 1 PDS REPORT JOINT TABULATION SHEET Pipe: 3.5 in 9.2 ppf }55 Buttress Wel: 1F-08 Body Wall: 0.254 in Field: Kuparuk Upset Wall: 0.254 in Company. ConocoPhilips Alaska, Inc. Nominal I.D.: 2.992 in Country: USA Survey Date: June 23, 2008 Joint No. Jt. Depth (Ft.) I'~~n. Ul~u•I Ilrn.) Pen. Body (Ins.) Peen. %, Me~t.~l Iu" ~~~ Min. LD• (Ins.) Comments Damage Profile (%wall) 0 50 100 48 1487 t~ 0.03 12 ~ 2.94 49 1518 U 0.01 5 I .97 50 1548 t I 0.0 2 2.9 51 1579 t I 0.01 4 I 2.94 52 1609 t t .O1 5 I 2.94 53 1641 t I 0.01 S 2.96 54 1672 t t 0.01 4 I 2.94 55 1702 t ~ 0.01 2 I 2.95 56 1734 I ? 0.01 5 ' 2.95 57 765 tt 0.01 4 I 2.95 58 1796 t1 0.0 4 1 .96 58.1 1 25 11 tl ~ t 2.81 Camco TRDP 1 A SSSV Locked out 3 17 88 59 1836 t I 0.01 .1 2.95 60 1867 t t 0.01 a 2.98 61 1898 t I 0. 1 ~ I 2.96 61.1 19 7 u 0 tl t t N A GLM 1 Latch ~ 3:30 6 1934 t~ 0.0 7 I .95 63 1965 t t 0.01 4 ~ 2.98 64 1997 t t 0.01 4 _' 2.93 65 2028 t I 0.01 4 ~ 2.97 66 2058 ~~ 0.01 ~ ~~ 2.95 67 2088 tl 0.01 a ~ z.98 68 2119 i t 0.01 b I 2.95 69 2149 ~ ~ 0.01 4 I 2.94 70 217 a 0.01 ; 2.92 71 2210 it 0.01 4 I 2.94 72 2 t I 0.01 ~ 2.96 73 2271 tt 0.01 ~1 ~ 2.97 74 2302 c I 0.01 ~ ' 2. 8 75 2333 It 0.01 ~t 2.98 76 2364 tt 0.01 ~ 2.95 77 2395 tl 0.01 ~ I 2.95 78 2426 a 0.01 4 1 2.96 79 2457 U 0.01 -~ 1 2.95 2487 U 0.01 ~ 2.95 81 2518 U 0.01 5 2.98 82 2 54 t I 0.01 5 .94 83 2579 a 0.01 4 ~ ~ 2.94 4 2611 t I 0.01 -1 2.94 85 2642 U 0.04 I ; 2.96 Isolated it. 86 267 U 0 01 4 2.97 87 2702 U 0.01 4 ~ 2.97 88 733 t t 0.01 ~' t t 94 89 2 764 t ~ 0.01 ~ 2.99 90 2796 U 0.01 -1 I .94 91 2826 U 0.01 -1 I 3.00 2 858 t I 0.01 ~l 2.97 93 2889 i ~ 0.01 4 I 2.93 94 2920 0.01 2 I 2 96 95 2951 0.01 2 ~' 2.98 _ Penetration Body Metal Loss Body Page 2 • PDS REPORT J OINT TABULATION SHEEP Pipe: 3.5 in 9.2 ppf }55 Buttress Wel: 1E-08 Body Wall: 0.254 in Field: Kuparuk Upset Wall: 0.254 in Company. ConocoPhilips Alaska, lnc. Nominal I.D.: 2.992 in Country: USA Survey Date: June 23, 2008 Joint No. Jt. Depth (Ft.) I'~~n. III,.~~i (Ins.) Pen. Body (Ins.) N<n. %, ~~~t.rl Loss `;4, Min. LD• (Ins.) Comments Damage Profile (%wall) 0 50 100 96 2983 a 0.01 2 1 2.93 97 3012 ~~ 0.01 4 I 2.96 98 304 ~ ~ 0.01 I .93 99 3073 l) 0.01 Z 1 2.97 100 3103 U 0.01 2.95 101 13 (~ 0.01 -1 I .00 102 3164 ~ 1 0.01 -3 .96 103 3195 ~ ~ 0.02 2.99 104 32 6 ~) 0.01 4 .94 105 3258 ~~ 0. 1 .94 106 3288 a 0.01 4 2.97 107 33 0 ~) 0.01 5 I .96 10 3351 U 0.01 2 I 2.96 109 3382 t ~ 0.01 4 Z .96 110 3412 U 0.01 4 ~' 2.95 111 3442 ~) 0. 1 4 ! 2.93 112 3473 a 0.01 ~ I .00 11 505 U 0.01 4 I 2 94 114 3535 II 0.01 4 .'. 2.99 115 3567 U 0.01 2 _' 2.97 1 6 3598 II 0.0 4 I 2.99 117 3629 i 1 0.01 ~1 2.99 118 661 i I 0.01 _' 2.94 119 3691 ~ ~ 0.01 4 ? 2.95 1 0 3 n 0 1 ~ .9 121 3753 ~1 0.01 ~ 2.94 121.1 3784 II 0 i1 ~> N A GLM Latch ~ 9:00 122 3789 l1 0.02 ' 2.93 123 3820 ~ I 0.01 5 z .97 124 3852 (1 0.01 4 :.' 2.99 125 3883 l) 0.01 4 2.97 126 3915 I ~ 0.01 4 1 2.95 127 3945 ~) 0.0 2 I 2.98 128 3976 tI 0.02 ~) ~ 2.93 129 07 l) 0.01 2 I 2.93 130 4038 ~i 0.01 4 ~ 2.96 131 4068 U .O1 ~ 2.99 132 4100 ~ ? 0.01 4 2.95 133 4130 I ~ 0.01 i 2.92 134 4161 ~~ 0.01 ~' _' 2.97 135 4192 I ~ 0 01 4 1 2.94 136 4224 t~ 0.01 ? 1 2.94 137 4254 U 0.01 ' 6 138 4284 U 0.01 4 _' 2.98 139 431 tl .01 5 2.9 140 4345 a 0.01 4 2.96 141 4376 U .01 4 ~' 2.95 142 4406 ~) ,01 5 2 2.95 143 443 7 ~ ~ 0.01 -t 2.9 144 4467 0.01 2.96 Penetration Body Metal Loss Body Page 3 • PDS REPORT J OINT TABULATION SHEET Pipe: 3.5 in 9.2 ppf }55 Buttress Wetl: 1E-08 Body Wall: 0.254 in Field: Kuparuk Upset Wall: 0.254 in Company: ConocoPhilips Alaska, Inc. Nominal I.D.: 2.992 in Country: USA Survey Date: June 23, 2008 Joint No. Jt. Depth (Ft.) I'en. UI,>c~1 (Inti.) Pen. Body (Ins.) Pen. % ~1ci.~l Lc»s °'~~ Min. LD• (Ins.) Comments Damage Profile (%wall) 0 SO 100 145 4499 ~ ~ 0.01 5 ? 2.95 146 4530 ll 0.01 4 ~' 2.93 147 4559 ~) 0.02 Z 2.94 148 4590 ~) 0.01 5 2 2.95 149 4621 U 0.01 ~ ~ 2.98 150 4653 ~ ~ 0.01 _' I 2.95 151 4683 ~ ~ 0.01 (, 2.98 152 4714 t) 0.01 ~' 1 2.95 153 4744 U 0.01 5 _' 293 154 4775 U 0.02 f; 5 2.96 155 4806 U 0.01 4 I 2.95 156 4837 ~) 0.01 2 ~' .94 157 4868 U 0.01 2 I 2.96 158 4899 ~) 0.01 4 2.95 1 9 4929 U 0.01 b _' .95 160 4960 ~ ~ 0.02 ? 2.93 161 4992 ~ ! 0.01 ~ .93 162 5023 ~ ~ 0.01 > 2.93 163 5054 ~ ~ 0.01 5 2.96 1 5085 t ~ 0.01 S _' 2.98 Lt. De sit . 164.1 5116 U 0 ~1 a N A GLM 3 atch ®12:30 165 5122 O 0.02 i 1 2.94 166 5153 l1 0.01 4 _' 2.94 167 5184 t ~ 0.01 4 ~ 2.97 1 8 5215 a 0.01 5 ? 3 0 169 5247 ~ ~ 0.01 i I 2.91 170 5278 ~~ 0.01 -1 2.95 171 5306 a 0.01 5 2.97 1 2 5336 11 0.01 ~1 3 2.98 173 5367 U 0.01 4 1 2.97 174 539 (~ 0.01 ~ 4 2.98 175 5427 ~~ 0.01 ~ I 2.93 176 5458 a 0.01 4 1 2.94 177 5488 ~~ 0.01 2 _' 2.98 178 5519 tl 0.01 4 _' 2.95 179 5551 ~ 1 0.03 1 U (~ 2.95 180 558 ~) 0.01 ~ 4 2.93 180.1 5614 U 0 0 11 N A GLM 4 Latch ~ 12:30 181 5620 U 0.02 7 1 2.94 182 5652 t) 0.01 5 I 2.94 183 5684 ~ ~ 0.01 5 1 .94 184 5711 ~a 0.01 4 2.95 185 5744 ! ~ 0.01 (~ 2.95 186 5776 t ~ 0.01 4 I 2.94 187 5806 U 0.01 5 I 2.93 188 5838 ~~ 0.01 .5 I 2.95 189 5869 (? 0.01 6 2.95 190 5900 ~ ~ 0.02 ti 2.96 191 5931 i ~ 0.01 > 2.93 192 5963 ~ ~ 0.01 5 2.97 _ Penetration Body Metal Loss Body Page 4 • PDS REPORT J OINT TABULATION SHEET Pipe: 3.5 in 9.2 ppf J-55 Buttress Wei: 1E-08 Body Wall: 0.254 in Field: Kuparuk Upset Wall: 0.254 in Company. ConocoPhiBips Alaska, Inc. Nominal I.D.: 2.992 in Country: USA Survey Date: June 23, 2008 Joint No. )t. Depth (Ft) I'c~n. Ulsc~t (Ins.) Pen. Body (Ins.) P~~n. % Mc~t~il loss ~~ Min. LD• (Ins.) Comments Damage Profile (%wall) 0 50 100 193 5994 a 0.01 4 2.96 194 6024 U 0.01 ~ `~ 2.95 194.1 6055 t) 0 U t ~ N A GLM 5 atch ~ 7:30 195 60 1 (~ .02 F3 s 2.99 196 6093 t) 0.01 5 ~ 2.93 197 6124 t) 0.01 (~ ? 2.97 198 6156 c) 0.01 4 2.94 199 6186 U 0.01 ~ 2.97 200 6218 a 0.01 t, 2.95 201 6249 t) .01 (~ ' 2.97 202 6280 a 0.01 b 2.98 203 6312 t) 0.01 i, 2.95 204 6342 i) 0.02 2.98 205 6374 t ~ 0.01 ~i I 2.95 206 6405 t ~ 0.01 ~ 2.99 207 64 6 t) 0.01 _' -1 2.96 207.1 6465 U 0 t) U N A GLM 6 Latch @ 11:30 208 6472 a 0.01 > _' 2.95 09 6503 t ~ 0.01 4 2.98 210 6534 a 0.01 4 2.94 211 6565 t) 0.01 6 ~ 2.95 212 6595 l) 0.01 4 ~t .9 213 6626 l) 0.02 i 1 2.94 214 6657 t) 0.01 i 1 2.96 215 6688 t) 0.01 4 _' 2.95 216 6719 (~ 0.01 5 I 2.93 217 6750 a 0.01 5 2.97 217.1 6779 t) 0 U U N A GLM 7 Latch ~ 5:30 218 6787 t 1 0.02 ~) (, 2.96 218.1 6819 O 0 O U 2.81 Baker SBR 218.2 6846 U 0 t) U 300 Baker'FHL' etr. Packer 219 6853 U 0.01 4 t 2.96 219.1 6884 U 0 l) U N A I M 8 Latch @ 6:30 220 6890 O 0.03 13 ~ 2.94 Shallow itUn . 221 6921 O 0.01 -1 2 2.96 221.1 6952 t) 0 O u N A I M 9 Latch ~ 4:30 222 6957 a 0.02 i3 ? 2.9 223 6989 t ~ 0.01 5 <' 2.94 223.1 7012 U 0 U t) 2.38 2 ' MerlaTubin Patch 224 7034 (? 0.01 ~ 1 2.95 225 7050 t) 0.01 4 1 2.96 226 7080 11 0.01 6 ~' 2.93 2 6.1 7111 l) .O1 5 1 2.96 PUP 226.2 7114 U 0 (1 t) 2.38 22' Merla Tobin Patch 226.3 7138 t) 0 0 t1 N A End of atch . Penetration Body Metal Loss Body Page 5 ConocoPhillips Alaska, Inc. • KRU 1 E-08 ~ ---- -- 1 E-08 API: 500292049600 Well T INJ An le TS: 39 d 7013 sssv 18351836 SSSV Type: TRDP Orig COlrl letlon: 1028/1980 Angte @ TD: 47 deg @ 7590 ( , oD:3.5o0) Annular Fluid: Last W/O: 11/1/1984 Rev Reason: TAG BOTTOM Reference L : 29' RKB Ref L Date: Last U te: 2212008 ~ Last Ta : 7330' SLM TD: 7590 ftKB Last Ta Date: 2/13/2008 Max Hole An le: 47 de 7590 C in Sri -CONDUCTOR Deacri Uon Size To Bottom TVD Wt Grade Three CONDUCTOR 16.000 0 80 80 65.00 H-40 Casi Sin - S RFA E Deacri Uon Size T Bottom TVD Wt Grade Thread SUR. CASING 10.750 0 2896 2693 45.50 K-55 Casin Stn -PRODUCTION Descri Uon Size To Bottom TVD Wt Grade Thread PROD. CASING 7.000 0 7568 6543 26.00 K-55 Tubi Stri -TUBING Size To Bottom TVD Wt Grade Thread 3.500 0 7176 6268 9.20 J-55 BUTTRESS Perforations Summa In rval TVD Zone Status Ft SPF Date T e Comment 7010 - 7104 6142 - 6214 4,C-3,C-2, 94 4 827/1981 SOS 2 1B Enerjet 0 7274 - 7294 6340 - 6354 A-5 20 4 8/27/1981 Ri id~et Re rfed 7304 - 7356 6361 - 6398 A-4 52 4 827/1981 eperf 1 /26/85 90 Reperfed Gas ift M andr elsNalve s St MD ND Man Mfr Man Type V Mfr V Type V OD Latch Port TRO Dete Run Vlv Cmnt 1 1938 1887 MMH 3.5x1 DMY 1.0 BK 0.000 0 7/9/1990 saR (sazt-sa2z 2 3789 3438 MMH 3.5x1 DMY 1.0 BK 0.000 0 6/6/1990 oD:3.soo) 3 5120 4564 MMH 3.5x1 DMY 1.0 BK 0.000 0 6/6/1990 4 5618 4994 MMH 3.5x1 DMY 1.0 BK 0.000 0 6/6/1990 p~ 5 6058 5367 MMH 3.5x1 DMY 1.0 BK 0.000 0 5/14/1987 (ssa7-seas, 6 6467 5715 MMH 3.5x1 DMY 1.0 BK 0.000 0 11/1/1984 oD:s.15s) 7 6783 5968 MMH 3.5x1 DMY 1.0 BK 0.000 0 3/16/1988 In'ection MandrelsNalves St MD ND Man Mfr Men Type V Mfr V Type V OD Latch Port TRO Date Run Vlv Cmnt 8 6884 6045 MMH 3.5x1 DMY 1.0 BK 0.000 0 11/7/1995 Closed 9 6952 6098 MMH 3.5x1 DMY 1.0 BK 0.000 0 11!7/1995 Closed 10 7121 6227 MMH 3.5x1 DMY 1.0 BK 0.000 0 11/7!1995 Closed that u ui .etc. - J L De th TVD T Deecrf Uon ID 1835 1799 SSSV Camco TRDP 1A Locked Out 3/17/88 Pulled WRDP on 621/97 2.813 6821 5997 SBR Baker 2.813 PaTCH 6847 6017 PKR Baker'FHL' RETR. 3.000 (7o1a-7036, 7139 6240 PKR Baker'FB-1' 4.000 OD:2.765) 7160 6256 NIP Camco'D' Ni le NO GO PROFILE 2.750 7160 6256 NIPPLE AVA'D' Profile; Set on 11/17/95 1.813 REDUCER 7176 6268 SOS Baker 2.992 7177 6269 TTL 2.992 Other s ui et . -PATCH pq~H De th TVD T DeaCri Uon ID (711a-7136, 7014 6146 PATCH 22' Marla T Patch• Set on 11/19/95 2.375 oD:z.76s) 7114 6222 PATCH 22' Marla T Patch; Set on 11/19/95 2.375 PKR (7139.7140, OD:6.156) NIPPLE REDUCER (7160.7161, OD:2.750) TUBING (0.7176, OD:3.500, ID:2.992) Pert (7304-7356) c:_.._~ ~ ~__ .~ ~~ ~ ~.. ,~I,~ss~- ou, ~-l~n c~5 COI~TSFRQA'1`IO1~T COMDII5SIOI~T John Peirce Wells Group Engineer ConocoPhillips Alaska Inc. ~~ NE® MAY ~ ~ 200 PO Box 100360 Anchorage, AK 99510 SARAH PALIN, GOVERNOR 333 W. 7th AVENUE, SUITE 100 ANCHORAGE, ALASKA,~99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Re: Kuparuk River Eield, Kuparuk Oil Pool, 1 E-08 Sundry Number: 308-176 ~ a r (~ Dear Mr. Peirce: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. Sincerely, Daniel T. Seamount, Jr. Chair '~„ DATED this ~G day of May, 2008 Encl. ~(~ ~ a i... 9./ R.,, ! Y "D V Q / `~- STATE OF ALASKA `~-~'' MAY 0 9 ~ ~f '~ ALASKA OIL AND GAS CONSERVATION COMMISSION ' APPLICATION FOR SUNDRY 20 AAC 25.280 APPROV~1a Oil & Gas Cons• Commission Anchorage 1. Type of Request: Abandon ^ Suspend ^ Operational Shutdown ^ Pertorate ^ Waiver ^ Other ^/ Alter casing ^ Repair well ^ Plug Pertorations ^ Stimulate ^ Time Extension ^ Install patch Change approved program ^ Pull Tubing ^ Pertorate New Pool ^ Re-enter Suspended Well ^ ~ S~~W 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development ^ Exploratory ^ 180-081 3. Address: Stratigraphic ^ Service 0 6. API Number: P. O. Box 100360, Anchora e, Alaska 99510 50-029-20496-00 ' 7. If perforating, closest approach in pool(s) opened by this operation to nearest property line 8. Well Name and Number: where ownership o r landownership changes: Spacing Exception Requires? Y2S ^ NO ^~ 1E-08 9. Property Designation: 10. KB Elevation (ft): 11. FieldlPool(s): ADL 25651 ~ RKB 105' Kuparuk River Field !Kuparuk Oil Pool 12. PRESENT WELL CONDITION SUMMARY Total depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 7590' ~ 6559' 7330' 6380' Casing Length Size MD TVD Burst Collapse CONDUCTOR 80' 16" 80' 80' SUR. CASING 2867 10-3/4" 2896' 2693' PROD. CASING 7569' 7" 7568' 6543' Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 7010'-7104', 7274'-7294', 7304'-7356' 6142'-6214', 6340'-6354', 6361'-6398' 3-1/2" J-55 7176' Packers and SSSV Type: Packers and SSSV MD (ft) pkr= BAKER'FHL' RETR. ; BAKER'FB-1' pkr= 6847' ; 7139' Camco TRDP-1A SSSV= 1835' 13. Attachments: Description Summary of Proposal 0 14. Well Class after proposed work: Detailed Operations Program ^ BOP Sketch ^ Exploratory ^ Development ^ Service 15. Estimated Date for 16. Well Status after proposed work: Commencing Operat June 1, 2008 Oil ^ Gas ^ Plugged ^ Abandoned ^ 17. Verbal Approval: Date: WAG Q GINJ ^ WINJ ^ WDSPL ^ Commission Representative: 18. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: John Peirce @ 265-6471 Printed Name John Peirce Title: Wells Group Engineer Signature ~ Phone 265-6471 Date ~» •wQ Commission Use Onl i i witness ti e ma t th t Sundry N ber: °"~ ' ss on Conditions of approval: Notify Comm a v y a represen so a Plug Integrity ^ BOP Test ^ Mechanical Integrity Test ^ Location Clearance ^ Other: Subsequent Form Required: 1 ~ i\ ~j~ APPROVED BY /{ry ~ ~~ ~ a~/ A roved b pP Y COMMISSIONER THE COMMISSION C / 111 Date: Form 10-40 Revised 06/2006 S ~ ~iAY ~ Q ZOOS submit i Duplicate ~~ Proposed 1E-08 Tubing Patch Installation Procedure `~ An (PROF 3/12/08 showed 65% of PWI enters the C sand at a Merla Perm Patch leak. 35% of PWI enters the A sand. An expandable tubing patch will be set for injection profile mod to halt all injection to the C sand, by isolating the leak in the perm patch (set in 1995) at 7114 - 7136' RKB. The leak in the Merla patch is between 7120' and 7125' RKB. Job Objective = `A sand only' injection in 1 E-08. Slickline: Brush & flush 3-1/2" tubing and through both 2.375" ID Merla patches between 6975 - 7160' RKB (to 1.813" Nipple Reducer) where new tubing patch will be set. 2. Drift with 2.25" gauge ring to 7160' RKB (1.813" Nipple Reducer). The drift verifies both 2.375" ID Merla patches drift OK prior to running the 2.225" run OD packers for the new tubing patch. 3. Run Caliper log from the tubing tail at 7176' RKB to surface to verify condition of the tubing prior to running a tubing patch. The tubing is 24 year old 3.5" J-55. E-line: Install 30' OAL Expandable /Retrievable. Tubing Patch at 7117 - 7147' RKB: 4. RIH with patch assembly consisting from bottom to top of a 2.225" run OD Retrievable Sealbore Inflatable Packer with pump out plug, Anchor Seal assembly, ~25' Spacer Pipe, and 2.225" run OD Retrievable Dual Seal Bore Packer. Drift patch assembly slowly through the 2.375" ID Merla permanent patches at 7014 - 7036' and 7114 - 7136' RKB. Set Retrievable Dual Seal Bore Packer at +/- 7117' RKB in the upper body of the leaky Merla patch. This location sets the Packer in the leaky Merla body ~3' above the leak at 7120' RKB, and hangs the lower Packer 7147' RKB in 3.5" tubing ~11' below the leaky Merla. POOH w/running tools and RU pumping equipment to expand the lower packer. Pressure up by pumping down the tubing in 500 psi increments to final pressure of 2800 psi to inflate and set the lower TTS Packer at +/- 7147' RKB, and to shear out the pump out plug. This setting process pressure tests the tubing and new patch integrity during the setting the lower packer to complete the patch. Rig down if the shear out plug sheared out as expected. Return 1 E-08 to PWI as an `A sand only' injector and obtain a valid injection test. Note: If the tubing does not pressure up and the shear out plug does not shear, a future work procedure will be required to isolate the leak. This procedure would follow diagnostics identifying any other leaks that may exist above the Dual Seal bore Packer, and/or a possible leak in the new patch assembly itself. Either of these situations could result a setting failure of the expandable packer. .. ~„ 1 Gar~oc~a~'hiMlps Ala$ka, inc. 1 E-08 - - API: 501 SSSV Type: TR sssv (1635-1a3s, Annular Fluid: OD:3.500) SBR (6821-6822, OD:3.500) PKR (6847.6848, OD:6.156) PATCH (7014.7036, OD:2.765) PATCH (7114.7136, OD:2.765) PKR (7139-7140, OD:6.156) NIPPLE REDUCER (7160-7161, OD:2.750) TUBING (0-7176, OD:3.500, ID:2.992) KRU 1 E-08 - - -. _ _- I I Well i ype: I INJ I Angle to 15: 139 deg lg! 7013 Orig 10/28/1980 Angle @ TD: 47 deg @ 7590 Reference Lo : 29' RKB Ref Lo Date: Last u sate: uz uwtxs _ Last Ta 7330' SLM TD: 7590 ftKB Last Tag Data: 2 /1 3/2 0 013 ,Max Hole Angle: 47 deg @ 7590 _ Casing String -CONDUCTOR (.Description Size To Bottom TVD VYt Grade Thread ~ CONDUCTOR 16.000 0 80 80 65.00 H-40 .Casing String.-SURFACE p yyt i Grade I Thread IDescriptlon Size ~ To ~ Bottom i TVD I ~" SUR CASING 10.750 0 2896 '693 ~, -15.5U I<-55 Casing String- PRODUCTION ~Descrlption Size Top Bottom TVD Wi Grade Thread ~ PRfTD. CASING i 7.000 i 0 i 756H F5d3 ~ 26.H0 I KSS Tubin Strin -TUBING ~J Size To Bottom TVD VK Grade Thread - I 3.500 0 71.76 _ 6268 9.20 J-55 BUTTRESS '~ Perforations Summary interval TVO Zone Status Ft SPF Date T e Comment 7010 - 7104 6142 - 6214 4,C-3,C-2, 94 4 8/27/1981 SOS 2 >~ -~_. 1/8 Enerjet 0 7274 - 7294 6340 - 6354 A-5 20 4 8/27/1981 Ri id'et Re erfed -'f 7304 - 7356 6361- 6398 A-4 52 4 8/27/1981 eperfe Reperfed 1 /26/85 90 ' Gqs Lift Mandrels/Valves St MD TVD Man Mfr Men Type V Mfr V Type V OD Latch Port TRO Date Run Vlv Cmnt 1 1938 1887 MMH 3.5x1 DMY 1.0 BK 0.000 0 7/9/1990 2 3789 3438 MMH 3.5x1 DMY 1.0 BK 0.000 0 6/6!1990 3 5120 4564 MMH 3.5x1 DMY 1.0 BK 0.000 0 6/6!1990 4 5618 4994 MMH 3.5x1 DMY 1.0 BK 0.000 0 6/6/1990 5 5n5R 5x57 MMH 3.5x1 DMY 1.0 BK 0.000 0 5!14/1987 7 6783 5968 MMH ~ 3.5x1 ~ ~ DMY I 1.0 I BK 10.0001 0 13116119881 Injection Mandrels/Valves -- - St MD TVD Man Mfr Man Type V Mfr V Type V OD Latch ~ Port TRO Date Run Vlv Cmnt 8 6884 6045 MMH 3.5x1 DMY 1.0 BK 0.000 0 11/7/1995 Closed 9 6952 6098 MMH 3.5x1 DMY 1.0 BK 0.000 0 11/7/1995 Closed 10 7121 6227 MMH 3.5x1 DMY 1.0 BK _0.000 0 11!7/1995 Closed Other (plugs, equip., etc. -JEWELRY De lh TVD T e Descri tion ID -. I 1 R35 1799 SSSV Camco TRDP 1A (Locked Out 3/17/881 Pulled WRDP on 6/21/97 _ 2.813 6847 6017 PKR Baker'FHL' RETR. s.uuu 7139 6240 PKR Baker'FB-1' 4.000 7160 6256 NIP Camco'D' Ni le NO GO PROFILE 2.750 7160 6256 NIPPLE REDUCER AVA'D' Profile; Set on 11!17/95 1.813 7176 6268 SOS Baker 2.992 7177 O_ then ( De th fi2F9 plugs, TVD TTL equip., etc T e .) -PATCH Descn tion 2.992 iD 7014 6146 PATCH 22' Merla Tb Patch; Set on 11/19/95 2.375 7114 5222 PATCH 22' Merla Tba Patch: Set on 11/19!95 __ 2.375 Perf (73047356) ~ ~ ,,, [[ d m .~' - ~ifu~~~~~-~ ~~~',~~ `" ti~ ?~~~~r~ NO. 4639 Schlumberger -DCS 2525 Gambell Street, Suite 400 Company: Alaska Oil & Gas Cons Comm Anchorage, AK 99503-2838 Attn: Christine Mahnken ATTN: Beth 333 West 7th Ave, Suite 100 ~~~ ~A~ ~ ~ 200 Anchorage, AK 99501 Field: Kuparuk Well Job # Log Description Date BL Color CD 03/20/08 2W-11 11996609 LDL - 03/17/08 1 3J-19 11996610 PROD PROFILE - Jl( 03/18/08 1 2Z-O1A 11994631 PROD PROFILE 03/11/08 1 1E-08 11994632 INJECTION PROFILE 03/12/08 1 2U-12 11994638 PROD PROFILE 03/16/08 1 • • Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. MEMORANDUM e TO: Jim Reggre, t II P.I. Supervisor 1\' 1t[ <9: DG FROM: Chuck Scheve Petroleum Inspector Well Name: KUPARUK RIV UNIT IE-08 Insp N urn: mitCS060605100943 ReI Insp Num Packer Well i 1E-08 !TypeInj. i N I TVD P.T. I 1800810 ITypeTest I SPT I Test psi ~ Interval 4YRTST P/F P Notes Well temporarily shut in for common line repair. Wednesday, June 07, 2006 State of Alaska e Alaska Oil and Gas Conservation Commission DATE: Wednesday, June 07, 2006 SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC IE-08 KUPARUK RIV UNIT 1E-08 a\ ;01J \CòÓ Src: Inspector Reviewed By: P.I. Suprv.:::J8i2- Comm NON-CONFIDENTIAL API Well Number 50-029-20496-00-00 Inspector Name: Chuck Scheve Inspection Date: 6/4/2006 Permit Number: 180-081-0 Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. 6008 , IA 600 2250 2250 2250 i i 1502 i OA 0 0 0 0 ... ,- Tubing 650 650 650 650 ,- fj~' ¡!I¡,.~~~~E~) '.",~;¡ ~¡.,'- >.. - "1, [ "j Page I of I MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission P I. Supervisor V TO: Camille O. Taylor (j:)~\ DATE: July 11, 2002 Chair SUBJECT: Mechanical Integrity Tests Phillips Alaska 1E Pad 1E-01,1 E-04,1E-08,1E-09 FROM: John Crisp Kuparuk River Field Petroleum Inspector Kuparuk River Unit NON- CONFIDENTIAL Packer Depth Pretest Inibal 15 Min 30 MIn WellI 1E-01 I Typelnj. J S I T.VD I 5941 I Tubing I 1750 I 1750 P.T.D.I 1800390 ITypetestl P ITestpsil 1500 ICas,ngI 1650I 245O I 2425 I 2425I P/F I P I Notes: 1 bbl. pumped for test pressure. I we,I 1E-0,. [Type,n~.I S I T.V.D 15845 I Tub,ngl~0~ I~0~. I~0~. I~0~ I,n,e,va, I4 PT.DI 1800570ITypetestl P ITestpsiI 1500 I Casingl 1700I 2800 I 2725 I 27001 P/FI P Notes: 1 1/2 bbls. Pumped for test pressure. We,,I ~E-08 I Type,,jI N IT.VD. 160~7 I Tub,ngl ~50 I~ I~ I~ I,n,er~a,I 4 P.T.D.I 1800810ITypetestl P ITestpsiI 1504 I Cas,ngI 380 I 1750 I 1725 I 1725 I P/F Notes: 2 1/2 bbls. Pumped for test pressure. We,,I ~E-09 I Type,nj.I N I T.V.D. J~0~5 ~o i~ooI ~oo I ~oo J,nterva,I 4 PTD.I 1820280ITypetestl P ITestpsil 1504 I CasingI 0 1165O11625116OO1 P/FIP Notes: 5 bbl. pumped for test psi Observed test pressure for additional 15 minutes, final pressure 1590 psi WellI I Type Inj. P.T.D. I Type test Notes: Type INJ Fluid Codes F = FRESH WATER INJ G = GAS INJ S = SALT WATER INJ N = NOT INJECTING Type Test M= Annulus Momtoring P= Standard Pressure Test R= Internal Rad~oacbve Tracer Survey A= Temperature Anomaly Survey D= D~fferenbal Temperature Test 4 MIT's performed, no failures witnessed. Test's Details Interval I= Inibal Test 4= Four Year Cycle V= RequIred by Variance W= Test during Workover O= Other (describe m notes) M I.T.'s performed' 4 Attachments Number of Failures. 0 Total T~me during tests: 4 CC.' MIT report form 5/12/00 L.G MIT PAl 1Ea 07-11-02jc.xls 7/24/2002 ( ( STATE OF ALASKA (' ( L.~ ALASKA OIL AND GAS CONSERVATION COIVlMi~ON REPORT OF SUNDRY WELL OPERATIONS 1. Type of Request: Operation Shutdown Stimulate ~ Pull tubing Alter casing Repair well 2. Name of Operator ~ 5. Type of Well: Development X ARCO Alaska. Inc, Exploratory _ 3. Address Stratigraphic _ P. O. Box 100360, Anchorage, AK 99510 Service _ Plugging Perforate _ Other 6. Datum elevation (DF or KB) RKB 105' 7. Unit or Property name Kuparuk River Unit feet . Location of well at surface 1013' FSL, 629' FEL, Sec. 16, T11N, R10E, UM At top of productive interval 1335' FNL, 1142" FEL, Sec. 16, T11N, R10E, UM At effective depth 1017' FNL, 1070' FEL, Sec. 16, T11N, R10E, UM At total depth 942' FNLr 1052' FELt Sec. 16r T11N~ R10Er UM 12. Present well condition summery Total Depth: measured true vertical 7590' feet 6558' feet Plugs (measured) None 8. Well number 1 E-08 9. Permit number/approval number 80-81/90-30~t 10. APl number so-029-2049§ 11. Field/Pool Kuparuk River Oil Pool Effective depth: measured 7 4 8 5 true vertical 6486' feet Junk (measured) feet None Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: Length Size 80' 16" 2896' 10 3/4' 7568' 7" Cemented 200 Permafrost 1350 Sx Fondu & 250 Sx AS 530 Sx Class G & 200 Sx AS II measured 7304'-7356', 7272'-7294' 8 true vertical 6361'-6397', 6339'-6354', Measured depth 80 2896' True vertical depth 80' 2693' 7568' 6543' SPF, 7010'-7104' 4 SPF 6143'-6214' Tubing (size, grade, and measured depth) 3 1/2", 9.3#, J-55 at 7176' Packers and SSSV (type and measured depth) Baker FHL @ 6847', Baker FB-1 ~ 7139' Camco WRDP @ 1835' 13. Stimulation or cement squeeze summary Converted to Water Injection Intervals treated (measured) See Attachment RECEIVED NOV 2 8 1990 Treatment description including volumes used and final pressure See Attachment 14. Reoresentative Daily Averaae Production or Iniection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 300 100 900 1400 140 Subsequent to operation 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations X 16. 0 4000 340 Status of well classification as: Water Injector ~ Oil m Gas Suspended Service 230O 17. I hereb,~ certify that the foregoing is true and correct to the best of my knowledge. Form 10-404 Rev 09/12/90 SUBMIT IN DUPLICATE 'ARCOAlaska,( =~ v~ ~ubstdlan/of Atlantic Richfield Company WELL SERVICE REPORT WELL CONTJCTO~R F"' ;'MARkSw...,_ IFIEIL~DISTRICT - STATE IOPERATION AT REPORT TIME ,~1 14 NOV ?- ~ i990 Alaska 011 & Gas Cons. AnChorage, r-i CHECK THIS BLOCK IF SUMMARY CONTINUED ON BACK · ARCO AlaskR' '~ ~ ~ Subaidla~/of Atlantic Richfield ,.,~npany WELL SERVICE REPOR' Alasl~ Oil & ¢"~ Con~. r-,o~xss'~°n 'N~ohorago L'~'~ CHECK THIS BLOCK IF SUMMARY CONTINUED ON BACK WeatherReport l Temp. *F Chill Factor. FI Visibility miles I Wind Vel, ,~LASKA OILAND GAS CONSERVATION C ~ ~ON APPLICATION FOR SUNDRY APPROVAL§ 1. Type (~f Request: Abandon _ Suspend _ Alter casing _ Repair well Change approved program ~ Operation Shutdown _ Re-enter suspended well _ _ Plugging _ T~me extension _ Stimulate _ Pull tubing_ Variance _ Perforate _ Other _ 6. Datum elevation (DF or KB) 2. Name of Operator ARCO Alaska. IRK;, 3. Address P. O. Box 100360, Anchorage, AK 99510 5. Type of Well: Development X Exploratory _ Stratigraphic _ Service 4. Location of well at surface 1013' FSL, 629' FEL, Sec. 16, T11N, R10E, UM At top of productive interval 1335' FNL, 1142' FEL, Sec. 16, T11N, R10E, UM At effective depth 1017' FNL, 1070' FEL, Sec. 16, T11N, R10E, UM At total depth 942' FNL, 1052' FEL, Sec. 16, T11N, R10E~ UM RKB 105' 7. Unit or Property name Kuparuk River Unit feet 8. Well number 1E-08 9. Permit number 80-81 10. APl number 50-029-20496 11. Field/Pool Kuparuk River Field Kuparuk River Oil Pool 12. Present well condition summary Total Depth: measured true vertical 7590' 6558' Effective depth' measured 7 4 8 5' true vertical 6 4 8 6' Casing Length Structural Conductor 8 0' Surface 2 8 9 6' Intermediate Production 7 5 6 8' Liner Perforation depth: Size 16" 10 7" feet feet feet feet Plugs (measured) None Junk (measured) None Cemented Measured depth 3/4" True vertical depth 200 Permafrost 80' 80' 1350 Sx Fondu& 2896' 2693 250 Sx AS 530 Sx Class G & 7 5 6 8' 6 5 4 3' 200 Sx AS II measured 7304'-7356', 7274'-7294' 8 SPF, 7010'-7104' 4 SPF true vertical 6361'-6397', 6339'-6354', 61 43'-621 4' Tubing (size, grade, and measured depth 3 1/2", 9.3#, J-55 at 7176' Packers and SSSV (type and measured depth) Baker FHL @ 6847', Baker FB-1 @ 7139' Camco WRDP @ 1835' 13. Attachments Description summary of proposal _ Detailed operation program X Convert to Water Injection. RECEIVED Gas Cons. Commission Anch0rag~ BOP sketch X 14. Estimated date for commencing operation May 1990 16. If proposal was verbally approved Name of approver L~1~/~; ~ ~,4'~ Date approved 15. Status of well classification as: OH ~ Gas __ Service /~ /d.~ Suspended 17. I hereby certify, that the foregoing is true and correct to the best of my knowledge. Signed ' Title Senior Operations Engineer FOR COMMISSION USE ONLY Date Conditions of approval: Plug integrity m BOP Test Mechanical Integrity Test~8~ Notify Commission so representative may witness _ Location clearance M Subsequent form require Approved by the order Commission ORIGINAL $1GNE0 BY LONNIE C. SMITH IApprov_al No._ 10- ~p,.,~ro.~e(t CoPY Form 10-403 Rev 5/03/89 SUBMIT IN TRIPLICATE Well 1 E-08 Convert to Injector Charge Code 230DS10EL · · 1 · Si Gl · Pull GLV's at 1938', 3789' and 5120'. Replace with DV's. Pull GLV at 5618'. Load annulus with 150 bbls diesel. Run DY to GLM at 5618'. Perform MIT by pressuring 3 1/2" x 7" annulus to 1500 psi. minutes without changing by more than 10%. Place well on injection. This must hold for 30 1. 5000 PS1 ?" W£LLHr..AD GONN[:CTOR 2. 5000 PS1 WIR£LIN£ RAMS (VARIABLE 3. 5000 PSi 4 1/8" L UBRIGATOR 4. S000 PS~ ~ ~/~" flow TuBE PAC.-Orr 2 ,~.~¥ 0 ~, 197 ~J~sk~ Oil & ~as Cons, Commission Anchora~ HIRELINE BOP E(~JIPHEN! ARCO Alaska, Inc. Date: February 23, 1989 Transmittal #: 7432 RETURN TO: ARCO Alaska, Inc. Attn: Brenda K. Miernyk Kuparuk Records Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted herewith are the following items. Please acknowledge receipt and return one signed copy of this transmittal. 3 F- 1 5 Kupaurk Fluid Level Report I 2- 0 3 - 8 7 3 N - 1 8 Kupaurk Fluid Level Report 1 2 - 1 8 - 8 7 3 F-01 Kupaurk Fluid Level Report 8-29-87 3 F- 0 2 Kupaurk Fluid Level Report 8-29-87 3 F- 0 9 Kupaurk Fluid Level Report 8-29-87 3 F-06 Kupaurk Fluid Level Report 8-29-87 3 F-1 0 Kupaurk Fluid Level Report 8-29-87 3 F-1 I Kupaurk Fluid Level Report 8-29-87 3 F-1 5 Kupaurk Fluid Level Report 8-29-87 3 F- 1 4 Kupaurk Fluid Level Report 8-29-87 3 N- 1 0 Kupaurk Fluid Level Report 5-18-87 3 N-06 Kupaurk Fluid Level Report 5-22-87 3N-09 Kupaurk Fluid Level Report 5-21-87 31-0 1 Kupaurk Fluid Level Report 4-24-87 3 N- 1 1 Kupaurk Fluid Level Report 4-15-87 3 N- 1 4 Kupaurk Fluid Level Report 4-13-87 3 F- 0 8 Kupaurk Fluid Level Report 4-14-87 3 N-01 Kupaurk Fluid Level Report 4-20-87 3 N- 1 4 Kupaurk Fluid Level Report I 2 - 0 4 - 8 7 3 F-1 5 Kupaurk Fluid Level Report 2-02-89 3 F- 1 5 Kuparuk Well Pressure Report 8-27-87 3 F- 1 3 Kuparuk Well Pressure Report 8-27-87 3 F- 1 5 Bottom-Hole Pressure Survey 8-25-87 1 B-05 Kuapruk Well Pressure Report 2-20-89 1 E-25 Kuparuk Fluid Level Report 2-19-89 3 B-1 1 Kupaurk Fluid Level Report 2-20-89 3A-03 Kupaurk Fluid Level Report 2-21-89 3H-01 Kupaurk Fluid Level Report 2-21-89 2Z-1 9 Kupaurk Fluid Level Report 2-20-89 31-1 2 Kupaurk Fluid Level Report 2-20-89 1 E-08 Kupaurk Fluid Level Report 2-19-89 3 M - 1 8 Kupaurk Fluid Level Report 2-15-89 Casing Casing Tubing Tubing Tubing Tubing Tubing Tubing Tubing Tubing Casing Casing Casing Casing CasingCas'ngCasing Casing TubingCasing Sand'C' Sand 'C' BHP Amerada Casing Casing Casing Casing Tubing Tubin~'"'~ Casint Casin~,,~ 3 H - 01 Ku~ 3B-1 3 Kul 1 E-29 Ku 1 C-05 Ku 3M-1 7 Ku 2Z-20 Ku 30-1 0 Ku 31-1 2 Ku 3H-10 )aurk Fluid Level Report 3aurk Fluid Level Report 3aurk Fluid Level Report 3aurk Fluid Level Report 3aurk Fluid Level Report 3aurk Fluid Level Report 3aurk Fluid Level Report 3aurk Fluid Level Report BHP Report 2-15-89 Casing 2-17-89 Casing 2-15-89 Casing 2-18-89 Casing/Tubing 2-16-89 Casing 2-18-89 Tubing 2-16-89 Casing 2-20-89 Tubing 2-13-89 BHP Receipt Acknowledged: ........................... Date: ............ DISTRIBUTION: D&M State of Alaska SAPC Unocal Mobil Chevron a t tacheent Page Drill Site 1H Well No. ~1H-4 ~1H-7 ~lH-8 Log Date 8/16/82 8/13/82 6/21/82 7/20/82 7/22/82 Drill Site Well No. Log Date 1E Drill Site 1G Well No. '%1G-1 %G-~ '~1G-3 ~1G-4 %1G-5 %1G-8 Log Date 9/7/82 9125182%, 9128182/ 12/8/84/ 10/13/82 11/12/82 3/12/83 1/22/83 Drill Site Well No. Log Date 1F .'~1F-1 2/19/83 ~1F-2 2/3/83 ~F-3 1/31/83 ' ~ ~1F-4 5/29/83 %1F-5 10/25/82 '~1F-6 10/28/82 '~ 1F-7 11/19/82xx . ~ 5/7/83/ ~l~y RECEiV FEB 2 1 1985 Alaska 011 & Gas Cons. Commission Anchorage ? ARCO Alaska, Inc. Post Office B~'- ')0360 Anchorage, Ala=~a 99510-0360 Telephone 907 276 1215 December 9, 1985 Mr. C. V. Chatterton, Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Dear Mr. Chatterton: Attached in duplicate are subsequent notices following wells at the Kuparuk River Field: Well Action Date Performed 1B1 Frac 11/6/85 1E8 Frac 1 2/6/85 1E-1 9 Conversion 1 0/1 7/85 1E-21 Convers i on 8/1 / 85 1E-23 Convers i on 1 0/23/85 1G-2 Frac 12/6/85 1R1 Frac 11/5/85 1R2 Frac 11/5/85 1R4 Frac 11/6/85 1R6 Frac 11/6/85 1R1 3 Frac 11/1 /85 1R1 4 Frac 11/1/85 2D-5 Ac id i zed 51~8785 2V5 Convers i on 7/6/85 on the If you have any questions, please T. M. Drumm Kuparuk Operations Coordinator TMD/kmc Attachment (Duplicate) call me at 263-4212. ARCO Alaska, Inc is a Subsidiary of AtlanllcRichfieldCompany RECEIVED DEC ! 0 ]985 Alaska 0/I & Gas Cons. Commission Anchorag.. STATE OF ALASKA C~ ALASKA ILANDGAS CONSERVATION C ~v, MISSION SUNDRY NOTICES AND REPORTS ON WELLS 1 DRILLING WELL [] COMPLETED WELL ~ 2 Name of Operator ARCO ALASKA, INC. 3 Address P. O. BOX 100360, ANCHORAGE, ALASKA 99510 4 Locat,on of Well SURFACE LOCATION' 1013' FSL, 629' FEL, SEC. 16, T11N, R10E, tim OTHER [] 5 Elevation ~n feet (~nd~cate KB, DF, etc ) 6 Lease Designation and Serial No 105' (RKB) ADL 25651, ALK 469 7 Permit No 80-81 8 APl Number 50- 029-20496 9. Umt or Lease Name KUPARUK RIVER UN I T 10. Well Number 1E-8 11 F~eld and Pool KUPARUK RIVER F! ELD KUPARUK RIVER OIL POOL 12 Check Appropriate Box To Indicate Nature of Not~ce, Report, or Other Data NOTICE OF INTENTION TO SUBSEQUENT REPORT OF: (Submit ~n Tr~phcate) (Submit ~n Duplicate) Perforate [] Alter Casing [] Perforations [] Altering Camng Stimulate [] Abandon [] Stimulation [] Abandonment Repmr Well [] Change Plans [] Repairs Made [] Other Pull Tubing [] Other [] Pulhng Tubing [] (Note Report mult,ple completions on Form 10-407 w~th a submitted Form 10-407 for each completion ) 13 Describe Proposed or Completed Operations (Clearly state all pertinent detads and g~ve pertinent dates, ~nclud~ng estimated date of starting any proposed work, for Abandonment see 20 AAC 25 105-170) Due to higher than anticipated pre-fracture "A" sand flow rates the "A" sand of Kuparuk well 1E-8 will not be fracture stimulated. 14 I hereby certify that the foregmng ~s true and correct to the best of my knowledge S,gned ~. /~ ~C~--~-~-"--- T,tle KI JPARI IK The space below for Commission use Bate 12/6/85 OPE~TI ONS C~RD I NATOR Conditions of Approval, ~f any Approved by By Order of COMMISSIONER the Comm~ss,on Date __ Form 10-403 Rev 7-1-80 Submit "Intentions" in Tr~phcate and "Subsequent Reports" ~n Duphcate ARCO Alaska, Ir( Post Office ~ox 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 April 1, 1985 Mr. C. V. Chatterton, Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Dear Mr. Chatterton' Attached in duplicate are subsequent notices following wells at the Kuparuk River Field: on Well Action Date Performed 1E-6 Fracture 1/26/85 1E-7 Reperf 1E-7 Fracture 3/1/85 1E-8 Reperf 1/28/85 1E-11 Reperf 2/1/85 1E-11 F~acture 2/7/85 1E-18 Fracture 3/13/85 1E-20 Stress Frac 3/19/85 1E-20 Fracture 3/23/85 1E-22 Fracture 3/22/85 1E-24 Fracture 3/22/85 1L-6 Fracture 2/2/85 1L-7 Fracture 1/30/85 1Q-9 Fracture 3 / 1 8 / 85 1Q-1 0 Fracture 3/5/85 1Q-12 Fracture 3/5/85 2A-3 Conversion 3/21/85 2A-4 Conversion 3/12/85 2A-5 Conversion 3/12/85 2A-6 Conversion 3/12/85 2A-7 Conversion 3/12/85 2C-4 Reperf 2/23/85 2D-4 Reperf 2/2/85 2V-8A Conversiop 2X-8 Perforation 1/27/85 If you have any questions, please call me at 263-4253. Mike L.. Laue Kuparuk Operations Coordinator MLL ! kmc Attachment (Duplicate) the ARCO Alaska, Inc is a Subsidiary of AtlanhcRtchf~eldCompany STATE OF ALASKA ~ ALASKA OIL AND GAS CONSERVATION C ,vlMISSION SUNDRY NOTICES AND REPORTS ON WELLS 1 DRILLING WELL [] COMPLETED WELL 2 Name of Operator ARCO ALASKA, ;[NC. 3 Address P. 0. BOX 100360, ANCHORAGE, ALASKA 99510 OTHER [] 4 Location of Well SURFACE LOCATION' 1013' FSL, 629' FEL, SEC. 16, T11N, R10E, UN 5 Elevat,on m feet (,ndlcate KB, DF, etc ) 105' (RKB) 12 7 Permit No 80-81 8 APl Number 50- 029-20496 9 Umt or Lease Name KUPARUK R];VER 10 Well Number 1E-8 11 Field and Pool KUPARUK I6 Lease Desmgnatlon and Sermal No KU PARU K ADL 25651: ALK 469 PO01_ Check Appropriate Box To Indicate Nature of Not~ce, Report, or Other Data NOTICE OF INTENTION TO. SUBSEQUENT REPORT OF' (Submit ~n Tr~phcate) Perforate [] Alter Casing [] Perforations Stimulate [] Abandon [] Stimulation Repair Well [] Change Plans [] Repairs Made Pull Tubing [] Other [] Pulhng Tubing (Note Report multiple completions on Form 10-407 w~th a submitted Form 10-407 for each completion ) UNIT RIVER FIELD RIVER OIL (Submit ~n Duplicate) ~ Altering Casing [] [] Abandonment [] [] Other [] 13 Describe Proposed or Completed Operations (Clearly state all pertinent detads and g~ve pertinent dates, ~nclud~ng estimated date of starting any proposed work, for Abandonment see 20 AAC 25 105-170) On January 28 1985, the "A" sands of Kuparuk well 1E-8 were re-perforated. After testing the lubricator to 3000 psi, the was shot with a wireline conveyed gun. well Interval (MD)' 7274-7294'-(4SPF) 7304-7356' APR 1985 A~asKa OIl & Ga3 Cons. Commission Anc.~0rag,, 14 I hereby certify that the foregoing ~s true and correct to the best of my knowledge S,gneO T,t~e 0 P £ R AT I 0 N S The space below for Commission use COORDINATOR Conditions of Approval, if any 3/28/85 /-,- Approved by By Order of COMMISSIONER the Commission Date Form 10-403 Rev 7-1-80 Submit "Intentions" m Triplicate and "Subsequent Reports" in Duplicate ARCO Alaska, In~ Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 April 4, 1985 Mr. C. V. Chatterton, Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Dear Mr. Chatterton: Attached are our notices of intention to reperforate Kuparuk field wel Is 1E-lA, 1E-4, 1F-16 and fracture 1E-lA, 1E-4, 1E-8, 1E-16, and 1E-27. If you have any questions, please call me at 263-4253. · ke L. Laue ~ ~- Kuparuk Operations Coordinator MLL/kmc Attachment (In Triplicate) APR Alaska 0il & Gas Cons. commission Anchorage ARCO Alaska, Inc is a Subsidiary of AllanhcRichheldCompany ALASK IL AND GAS CONSERVATION C ~wMISSION SUNDRY NOTICES AND REPORTS ON WELLS 1 DRILLING WELL [] COMPLETED WELL OTHER [] 2 Name of Operator 7 Permit No ARCO ALASKA, I NC. 80-81 3 Address 8. APl Number P. O. BOX 100360, ANCHORAGE, ALASKA 99510 50- 029-20496 4 Location of Well SURFACE LOCATION- 1013' FSL, 629' FEL, SEC. 16, T11N, R10E, UM 5 Elevation ~n feet (~nd,cate KB, DF, etc.) I 6 Lease Des,gnat,on and Serial No 105' (RKB) I ADL 25651, ALK 469 12 9 Umt or Lease Name KUPARUK RI VER UN ! T 10 Well Number 1E-8 11 Field and Pool KUPARUK RIVER F ! ELD KUPARUK RIVER OIL POOL Check Appropriate Box To Indicate Nature of Not~ce, Report, or Other Data NOTICE OF INTENTION TO SUBSEQUENT REPORT OF (Submit ~n Tnphcate) (Submit m Duplicate) Perforate [. Alter Casing [] Perforations [] Altering Casing [] Stimulate ~, Abandon [] Stimulation [] Abandonment [] Repair Well [] Change Plans [] Repairs Made [] Other [] Pull Tubing [] Other [] Pulhng Tubing [] (Note Report multiple completions on Form 10-407 w~th a submitted Form 10-407 for each completion ) 13 Describe Proposed or Completed Operations (Clearly state all pertinent detads and g~ve pertinent dates, ~nclud~ng estimated date of starting any proposed work, for Abandonment see 20 AAC 25 105-170) It is proposed that the "A" sand in Kuparuk well 1E-8 be hydraulically fractured and propped to improve production. The treatment uses gelled water as the pad and carrying fluid and 20/40 sand as the proppant. Gelled diesel will be used as a flush. Lines and equipment will be pressure tested to 5000 psi prior to starting job. Pre-post frac logs are included in the treatment program. Fluid: Gelled water 273 BBLS Gelled diesel 69 BBLS Proppant. 20/40 sand 14,910 LBS ANTICIPATED START DATE: APRIL 12, 1985 RECEIVED APR 985 A!aska 0ii & Gas Cons. Commission Anchorage 14 I hereby certify that the foregoing ~s true and correct to the best of my knowledge S, .............. T.tle OPERATI ONS COORD ! NATOR The spac/below for Comm~ss~o/use 4/4/85 Date Conditions of Approval, ~f any Approved by Approvect Cop)~ ~, Returned .~ By Order of COMMISSIONER the Commission Form 10-403 Rev 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" ~n Duplicate ARCO Alaska, Inc. / Post Office ~ $0 Anchorage, ~..dska 99510 Telephone 907 277 5637 Date: 1~ TransmittAl ;No: 4842 RETUP. N TO: ARCO ALASKA, INC. ATTN: Records Clerk ATO-1115B P.O. Box 100360 Anchorage, AK 99510 Transmitted herewith are the following items. Please acknowledge receipt and re~urn one signed copy of ~his ~ransmit~al. PL FI~DS presser 11/05/84 Run 1 7550- 7746 ~,,~2~G-13 Collar Log "4" Perf" - /¥;~-~5 " " n/o~/~_" e55o ~o / ;j~-s " " "~/s m~;/Se~ ~e~" ~o/3o/~ ~ ~ ~ - ~V-G Sp~er ~g 8/Sl/~. ~ I 59~ - ~00 · Schl~m~berger ~ 2X-5 Dual Spacing Thermal Neutron Decay ~LE-20 Temperature' ~refrac" /1E-8 " " 2D-10 Temp "Spinner Log" "t~/FD" " " "Fluid Density" 11/02/84 Run 1 8210 - 8658 11 / 09/84 Run 1 8130 - 8500 11/09/84 Run 1 7160 - 7450 11/06/84 Run 1 3620- 6620 11/08/84_ Run I 6800- 7060 /cat Receipt Acknowledged: , B. Currier BPAE Chevron D&M ,, DISTRIBUTION Drilling W. Pasher Geology G. Phillips Mobil Phillips Oil NSK 0ps. J. Ratbmell Alaska 0ii & Sas Cons. Commission S t~h~r~gekK Sohio ~nion Well Files ARCO Alaska, Inc. ~r Post Offlc~ 360 Anchor3ge, ,.uaska 99510 Telephone 907 277 5637 Date: 2/05/85 Transmittal No: 4824 RETURN TO: ~CO ALAS~, INC. ATTN: Records Clerk ATO-1115B PA. Box 100360 ,/~chorage,~ 99510 Transmitted herewith are the following it.s. Please acknowledge receipt and retu~ one signed copy of this transmittal. PBU SURVEYS & SEQUENCE OF EVENTS --2X-7/ 8/16/84 Gearhart ----2Z-6/ 9/03/84 Otis 2X-6~ 8/16/84 Gearhart '-- 2X-4~ 8/16/84 Camco ~--2X-l~ 8/16,19/84 Camco --2V-5~/ 8/16,19/84 Dresser ~-2V-2~ 9/07/84 Otis ~2F-9~ 8/28/84 Otis --2F-8~% 10/08/84 Camco --2F-7~ 10/07/84 Otis --2B-15~ 9/03/84 Otis ~-2C-5 / 8/17/84 Otis --lY-13/ 8/16/84 Dresser ~lY-9~z 9/07/84 Camco --1Y-5/ 9/14/84 Camco 1Y-5~ 9/06/84 Otis ~lG-6~ '8/25/84 Otis ~lH-4~ 9/04/84 Otis ~1F-12¥ 9/09/84 Otis ~lF-9~ 8/17,18/84 Camco ~-lF-8z 8/16,17/84 Camco -~l,~E-8~/ 10/12/84 Otis ~-lD-5/ 10/07/84 Camco ~iA-4J~ 9/02/84 Otis --'-lA--3/ 9/02/84 Otis Receipt Acknowledged: "HP 232" "HP 233" 9/06/84 "SBHP" 9/05/84 "Static BHP" 8/17/84 "PBU"" 8/16/84 "PBU" 10/13/84 "SBHP" "E Line" 10/07/84 "Pressure Yalloff" DISTRIBUTION B. Currier Drilling W. Pasher State of AK BPAE Geology G. Phillips Sohio Chevron Mobil Phillips Oil Union D & M NSK Ops. J. Rathme!l Well Files ! ARCO Alaska, Inc. / Post Off,ce Bo%,, ,00360 Anchorage, Alaska 99510 Telephone 907 276 1215 January 29, 1985 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT: 1E-8 Dear Mr. Chatterton: Enclosed is a Well Completion Report for the subject well. you have any questions, please call me at 263-4944. Sincerely, J. Gruber Associate Engineer JG/tw GRU3/L87 Enclosures If RECEIVED FEB 0 ~ 1985 Alaska 0il & Gas Cons. Commission Anchorage ARCO Alaska, Inc ts a Substdtary of AtlanflcRtchheldCompany ( '~ STATE OF ALASKA '" ALASKA~ _ AND GAS CONSERVATION CC~ /llSSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1 Status of Well Class~hcat~on of Serwce Well OIL [~X GAS [] SUSPENDED [] ABANDONED [] SERVICE [] 2 Name of Operator 7 Permit Number ARCO Alaska, Inc. 80-81 3 Address 8 APl Number P. 0. Box 100360, Anchorage, AK 99510 50- 029-20496 4 Locat,on of well at surface 9 Umt or Lease Name 1013' FSL, 629' FEL, Sec.16, T11N, R10E, UN Kuparuk River Unit At Top Producing Interval 10 Well Number 1335' FNL, 1142' FEL, Sec.16, T11N, R10E, UN 1E-8 At Total Depth 11 F~eld and Pool 942' FNL, 1052' FEL, Sec.16, TllN, R10E, UM Kuparuk River Field 5 Elevation ~n feet (~nd,cate KB, DF, etc ) 6 Lease Designation and Serml No Kuparuk River 0i 1 Pool 105' RKB ADL 25651 12 Date Spudded 13 DateT.D Reached 14 DateComp,Susp orAband 115 Water Depth, ~f offshore 116 No of Completions 10/15/80 10/24/80 10/28/80I N/A feet MSLI 1 17 Total Depth (MD+TVD) 18 Plug Back Depth(MD+TVD) 19. D~rect~onal Survey I 20 Depth where SSSV set 21 Thickness of Permafrost 7590'ND,6558'TVD 7485'MD,6486'TVD YES [] NO []I 1835 feet MD 1500' (Approx) 22 Type Electric or Other Logs Run DIL/BHCS/GR, FDC/CNL/NGT, GR/CBL 23 CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT PER FT GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 16" 65.0# H-40 Surf 80' 24" 200 sx Permafrost 10-3/4" 45.5# K-55 Surf 2896' 13-3/4" 1350 sx Fondu & 250 sx IArctic Set 7" 26.0# K-55 Surf 7568' 8-3/4" 530 sx Class C & 200 s: AS II 24 Perforations open to Production (MD+TVD of Top and Bottom and 25 TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 7304' - 7356' 3-1/2" 7176' 7140'WLM & 6847' 7274' - 7294' 7010' - 7104' 26 ACID, FRACTURE, CEMENT SQUEEZE, ETC DEPTH INTERVAL (MD) AMOUNT& KIND OF MATERIAL USED N/A 27 N/A PRODUCTION TEST Date F~rst Production Method of Operation (Flowing, gas I,ft, etc ) Date of Test Hours Tested PRODUCTION FOR el L-BBL GAS-MCF WATER-BBL CHOKE SIZE I GAS-OIL RATIO TEST PERIOD II~ I Flow Tubing Casing Pressure CALCULATED.a~ OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press 24-HOUR RATE alF 28 CORE DATA Brmf description of I~thology, porosity, fractures, apparent d~ps and presence of o~1, gas or water Submit core ch~ps NONE - RECEIVED F E B 0 4 1985 Alaska 0il & Gas Cons, Commission Anchorage Form 10-407 GRU3/WC48 Submit ,n duphcate Rev 7-1-80 CONTINUED ON REVERSE SIDE 29 30 GEOLOGIC MARKERS FORMATION TESTS NAME Include ~nterval tested, pressure data, all fluids recovered and gravity, MEAS DEPTH TRUE VERT DEPTH GOR,and t,meof each phase Top Kuparuk 7011 ' 6143' N/A Top Upper Sand 7011' 6143' Base Upper Sand 7014' 6214' Top Lower Sand 7265' 6333' Base Lower Sand 7355' 6397' Base Kuparuk 7414' 6438' 31 LIST OF ATTACHMENTS Wnrkov~.r W~.I] Historv 32 I hereby certify that the foregoing ~s true and correct to the best of my knowledge Signed 'fYL... ~..'~L_~' T,tle Associ ate Engi neer Date /'- -c-~ ~.'~' INSTRUCTIONS General. This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases ~n Alaska Item 1 Classification of Service Wells Gas injection, water injection, steam injection, air ~njectlon, salt water d~sposal, water supply for ~nject~on, observation, injection for ~n-s~tu combustion. Item 5' Indicate which elevation Is used as reference (where not otherwise shown) for depth measurements given ~n other spaces on th~s form and ~n any attachments Item 16 and 24 If th~s well ~scompleted for separate production from more than one ~nterval (multiple completion), so state ~n ~tem 16, and in ~tem 24 show the producing ~ntervals for only the ~nterval reported ~n ~tem 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such ~nterval 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- ~ng and the location of the cementing tool. ( ( ARCO Oil and Gas Company v Well History - Initial Report- Daily ;,%&.~;~,-~. Pi~-~ end ~bmit the "~:~.&~ .';~T.~.-~' on the first Wednesday i~ii · well ~$ sDudded or workover operahons am ~t~rted Daily wo~ prior to al~dcling liquid be summarized on the form giwng ~nclu$~ve dates only District ICoun~/ 13ansh or bo~ougl~ IStata Alaska I North Slope Borough I Field ILe. or un,t ADL 2565 ITme I Recomplete Kuparuk River Auth or w o no AFE Exp 304794 NABORS 1-ES Alaska ell no 1E-8 W/O API: 50-029-20496 O~rator ARCO Alaska, Inc. 'pudd.d or W O beg,.n ID. Workover 10/26/84 iComplete record for each day reported Date and depth aa of 800 am 10/26/84 10/27/84 thru 10/29/84 10/30/84 10/31/84 300 Hrs. ARCO 56.24% Prior status ~f a W O 7" @ 7568' 7485' PBD, Tst'g lubr 10.5+ ppg Complete RU. Accept ri~ @ 0300 hfs, 10/26/84. pull btm GLV. RU Camco to 7" @ 7568' 7485' PBD, POOH w/retry BP setting tl 10.6 ppg NaC1/NaBr Pulled GLV @ 6824'. Spot 25 bbls BridgeSal pill to perfs @ 7010'-7104', circ oil & gas out of well. Set BPV. ND tree, NU BOP's. Att to MU lnd'g jt, threads zn hgr bad. Pull BPV, instl tst plug. Tst BOP's, 3000# rams, 2000# Hydrl. PU Tri-State spear. PU & shear Bkr SBR, LD hgr. Spot pill on top of pkr @ 6888'. POOH w/CA replacing butt couplings w/Mod butt couplings, oil & gas started flowing out ot tbg. Circ oil & gas out of tbg & ann. Spot 25 bbls BridgeSal pill, POOH & fin chg'g couplings & LD SBR barrel. RIH w/pkr retrv'g tl, latch onto pkr. RIH w/pkr to top of perf @ 7010', circ gas out of hole. Spot 50 bbls BridgeSal pill, POOH w/pkr & LD. RIH w/retrv BP & set same @ 6900'. Tst csg & BP to 2500 psi; no comm. POOH w/setting tl. 7" @ 7568' 7485' PBD, RIH w/Bit & Scr 10.7 ppg NaCl/NaBr ND BOP's, ND FMC 10" x 3000# tbg hd. NU FMC 10" x 3000 X 7-1/16 5000# tbg hd, NU BOP's. Tst tbg hd 3000#. Tst BOP's 5000# rams, vlvs, 2500# Hydril. Pull ret BP. POOH LD. RIH w/Bkr R-3. Tagged up @ 7030' DM. POOH w/pkr. RIH w/bit & scr. 7" @ 7568' 7485' PBD, RU to rn compl & RD DA 10.7 ppg NaCl/NaBr RIH w/bit & scrpr, tag up @ 7030', wsh dn to 7483' DPM, POOH. PU Bkr R-3 pkr, set pkr @ 6980' DPM. Tst csg to 3500 psi. RIH to 7225' DPM, set pkr. Press up on perfs @ 7274'-7294' & 7304'-7356' w/1500# press. Press would slowly bleed off; no comm on ann, POOH. RIH w/6.125" gage ring; wouldn't go below 6988' WLM. RIH w/6" gage ring to 7250', POOH. RIH w/Bkr FB-i pkr assy, set pkr @ 7140'. RECEIVED FEB 0 4 1985 The above ,s correct ~'~ Dnlhng, Pages 86 and 87 IDate 11/19/84 & Gas Cons. Commission DrA~m~, upe rin t enden ., , ( ( ARCO Oil and Gas Company Daily Well History-Final Report InsttUCtlOna Prepare and submit the "Finnl Report" on the first Wednesday after allowable has been assigned or well ~s Plugged Abandoned or Sold "Final Rel~ft" should be submitted also when operabons are suspended for an ~ndeflmte or appreciable length of hme On workovers when an official test ~s not required upon completion report complehon and representahve test data ~n blocks prowded The "Final Rel~rt" form may be used for report;ng the enhre operahon ~f space is avadahle D~stnct ICounty or Parish I Alaska F~eld ~Lease or Umt I Kuparuk River Auth or W O no ~T~tle AFE Exp 304794 North Slope Borough ADL 25651 [ Accounting cost center code State Alaska Recomplete IWel I no IR-8 W/O NABORS i-ES API: 50-029-20496 Operator ARCO Alaska, Inc. Spudded or W O begun Workover ARCo WI 56.24% Date 10/26/84 I otal number of wells (achve or ~nachve) on th~s DSt center prior to plugging and bandonment of th~s well I our I Prior status ~f a W O 0300 Hrs. I Date and depth as of 8 00 a m 11/01/84 11/02/84 Complete record for each day reported 7" @ 7568' 7485' PBD, RIH w/3½" completion 10.7 ppg NaC1/NaBr Rn 3½" compl, sting seals into FHL pkr, PU 1' above pkr, drop Bkr steel ball. Press tbg to 2500 psi & set pkr. Press ann to 2500 psi w/tbg to 2500 psi to tst pkr; OK. Shear out of SBR. MU Cut lip guide shoe on SBR barrel, RIH w/3½" completion. 7" @ 7568' 7485' PBD, RR Diesel & Crude Rn 3½" completion. MU FMC Gen III extended neck tbg hgr, tst contrl in to 5M, lnd 3½" tbg. Camco SSSV @ 1835.23', Bkr FHL pkr @ 6847.10'. Tst tbg & SBR to 2500 psi. ND BOPE, NU FMC tbg adapter & tree. Tst tree to 250/5000 psi. Displ well w/30 bbls diesel & 220 bbls crude. Close SSSV & tst to 1000 psi. Press up tbg to 3850 psi, shear out. RR @ 1400 hrs, 11/1/84. FB-1WL Pkr @ 7140', Bkr SOS @ 7176.37' Old TD New TD Released ng Date 1400 hrs. Class~hcahons (od gas etc) Oil Producing method Flowing Potenhal test data PB Depth 11/1/84 K,nd of r.g Type complehon (s~ngle. dual etc) Single Official reservoir name(s) Kuparuk Sands Well no Date Reservoir Producing Interval OH or gas Test t~me Production Od on test Gas per day Pump s~ze, SPM X length Choke s~ze T P C P Water % GOR Grawty Allowable Effech~e date corrected The above is correct p .~ ~ S,gZ~~ [Date IT,tie 11/19/84 Drilling Superintendent For form preparation a~d d~st.buhon, see Procedures Manual, Section 10, Dnlhng, Pages 86 and 87 ARCO Alaska, inc. / Post Office I~ ,0 Anchorage, · ~ka 99510 Telephone 907 ,'77 5637 RETURN TO: ARCO ALASKA, INC. ATTN: Records Clerk ATO-1115B P.O. Box 100360 Anchorage, AK 99510 Transmitted herewith are the following items. Please acknowledge receipt and return one signed copy of this transmittal. CAMCO BHP REPORI~/~3U T~ORQUE TURN PBU & TEMP SURVEYS 12/02, 03/84 ~-4 12/12, 13/84 Gauge (/64009 ~/1G-4 12/10,11/84 /lB-3 11/26/84 / ~G-2 12/08184 ~E-8 12/12,13/84 lA-6 10/21,22/84 / /lC-9 10/12,14/84 ~B-11 10/10,12/84 /1 -3 10115184 ,//2B-4 10/19/84 / 2B-3 10/19/84 1 ,/ iE-2 10/15/84 /cat Receipt Acknowledged: DISTRIBUTION B. Currier Drilling W. Pasher State of AK BPAE Geology' G. Phillips Sohio Chevron Mobil Phillips Oil Union D&M NSK Ops. J. Rathmell Well Files ARCO Alaska, Inc.~' Pos! Office Box 1479 Anchorage, Alaska 99510 Telephone 907 277 5637 January 25, 1985 Mr. C. V. Chatterton, Chairman Alaska Oil and Gas Conservation 3001 Porcupine Drive Anchorage, AK 99501 Dear Mr. Chatterton: Commi ssion Attached are our notices of intention Field well 1E-7 and re-perforate wells 1E-20. to fracture Kuparuk 1E-7, 1E-8, 1E-11 and If you have any questions, please call me at 263-4253. Mike L. Laue Kuparuk Operations Coordinator MLL/kmc Attachment (In Triplicate) RECEIVED JA IV £ 5 1985 Alaska 0~1 &AGas Cons. CommiSsion nChorage ARCO Alaska, Inc is a subsidiary of AflantlcRichf,eldCompany STATE OF ALASKA OC ALASKA OIL AND GAS CONSERVATION C MISSION SUNDRY NOTICES AND REPORTS ON WELLS 1 DRILLING WELL [] COMPLETED WELL OTHER [] 2 Name of Operator 7 Permit No ARCO ALASKA, INC. 80-81 3 Address 8 APl Number P. O. BOX 100360, ANCHORAGE, ALASKA 99510 50-029-20496 4 Location of Well SURFACE LOCATION' 1013' FSL, 629' FEL, T11N, RIOE, UM SEC. 16, 5 Elevation m feet (md~cate KB, DF, etc ) 105' (RKB) 12 6 Lease Designation and Serial No ADL 25651, ALK 469 9 Umt or Lease Name KUPARUK RIVER 10 Well Number 1E-8 11 F~eld and Pool KUPARUK RIVER KUPARUK RIVER POOL Check Appropriate Box To Indmate Nature of Not~ce, Report, or Other Data UNIT FIELD OIL NOTICE OF INTENTION TO SUBSEQUENT REPORT OF' (Submit m Triplicate) (Submit m Duplicate) Perforate X]] Alter Casing [] Perforations [] Altering Casing [] Stimulate [] Abandon [] Stimulation [] Abandonment [] Repmr Well [] Change Plans [] Repairs Made [] Other [] Pull Tubing [] Other [] Pulhng Tubing [] (Note Reportmult~plecomplet~onson Form 10-407w~thasubm~tted Form 10-407 for eachcomplet~on) 13 Describe Proposed or Completed Operations (Clearly state all pertinent detads and g~ve pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25 105-170) It is proposed that the "A" sand in Kuparuk well 1E-8 be re-perforated to enhance subsequent stimluation. Procedures call the well to be perforated with a wi reline conveyed gun under a lubricator. for Proposed Intervals (MD)' 7274'-7294' (4 SPF) 7304'-7356' ANTICIPATED START DATE' January 26, 1985 ECEIVED JAN 2 5 1g 5 ~s Cons. Commission anchorage 14 I hereby certify that the foregoing is true and correct to the best of my knowledge S,gned T,tle OPERATIONS COORDINATOR The space below for Commission use 1/25/85 Date Conditions of Approval, if any Approved by. ORIGINAL SliI[gX, 6Y LOH~(IE C. SMITII Approved Copy Returned By Order of COMMISSIONER the Commission Form 10-403 Rev 7-1-80 Submit "Intentions" m Triplicate and "Subsequent Reports" ,n Duplicate ARCO Alaska, Inc. Post Office,/' 360 Anchorage[ -ska 99510 Telephone 907 :'77 5637 Date: 1/07/85 Transmittal No: 494 2 RETURN TO: ARCO ALASKA, INC. ATTN: Records Cler~ ATO-1115B Box 100360 orage, AK 99510 ed herewith are the following items. Please acknowledge receipt n one signed copy of this transmittal. - CAMCO BHP REPORT-S/.fBU ?.ORQUE TURN PBU & TEMP SURVEYS t 1F-7-~ 12/02, 03/84 1F-4 12/12, 13/84 Gauge #64009 1G-4 ' 12/10,11/84 lB-3 11/26/84 1G-2~ 12/08/84 1E-8 12/12,13/84 lA-6 -' 10/21,22/84 1C-9,- '10/!2,14/84 Oo lB-11 10/10,12/84 ...... 1E-3 10/15/84 2B-4 10/19/84 2B-3 10/19/84 1E-2-" 10/15/84 /cat Receipt Acknowledged: B. Currier DISTRIBUTION W. Pasher State of AK BPAE Geology' G. Phillips Sohio Chevron Mobil Phill'ips Oil Union D&M NSK Ops. J. Rathmell Well Files ARCO Alaska In," is a substd,ary o! AtlamttcRIchheldCcmpant, ! ARCO Alaska, Inc. ~ Post Office Box 100360 Anchorage, Alaska 99510 Telephone 907 276 1215 December 31, 1984 Mr. C. V. Chatterton Commi ssi oner State of Alaska Alaska Oil & Gas Conservation Commi ssi on 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT: 1E-8 Dear Mr. Chatterton: Enclosed is a Subsequent Sundry Report for the subject well. If you have any questions, please call me at 263-4944. Sincerely, . Gruber Associate Engineer JG/tw GRU3/L23 Enclosures RECEIVED JAN 0 2 1.985 Oil & Gas Cons. Commi~ion Anchorage ARCO Alaska, Inc is a Subsidiary of AtlanhcRichheldCompany STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION C v~MISSION SUNDRY NOTICES AND REPORTS ON WELLS 1 DRILLING WELL [] COMPLETED WELL OTHER [] 2 Na~:ke~Rf ~per~ltor 7 Permit No ~r~.u ~asKa, Inc. 80-81 8 APl Number 3 ASd,.re~. Box 100360, Anchorage, AK 99510 50- 029-20496 4 Lo..catlgn of Well burTace:]013' FSL, 629' FEL, Sec.16, T11N, R10E, UM 5 Elevation ~n feet (indicate KB, DF, etc ) 12 105' RKB Lease Designation and Serial No ADL 25651 9. Unit or Lease Name Kuparuk River Unit 10 Well Number 1E-8 11 Field and Pool Kuparuk River Field Kuparuk River 0il Pool Check Appropriate Box To Indmate Nature of Notme, Report, or Other Data NOTICE OF INTENTION TO. SUBSEQUENT REPORT OF. (Submit m Tnplmate) (Submit m Duplicate) Perforate [] Alter Casing [] Perforations [] Altering Casing Stimulate [] Abandon [] Stimulation [] Abandonment Repair Well [] Change Plans [] Repairs Made .~[] Other Pull Tubing [] Other [] Pulhng Tubing ~ (Note Report multiple completions on Form 10-407 w~th a submitted Form 10-407 for each completion ) 13 Describe Proposed or Completed Operations (Clearly state all pertinent details and g~ve pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25 105-170) Accepted rig ~ 0300 hrs, 10/26/84. Killed well. Set BPV. ND tree. NU BOPE & tstd to 3000 psi - ok. Pulled tubing. Spotted 25 bbl Bridge Sal pill. Retrieved pkr. RIH & set retrievable bridge plug @ 6900'. Tstd csg and bridge plug to 2500 psi; no communication to 7" x 10-3/4" annulus. RIH and set R-3 pkr @ 6980'; tstd csg down backside to 3500 psi - ok. RIH and set FB-1 pkr @ 7140'WLM. Ran 3-1/2" completion assy w/tail ~ 7176', FHL pkr @ 6847' & SSSV ~ 1835'. Tstd tbg to 2500 psi - ok. Set BPV. ND BOPE. NU tree and tstd to 5000 psi - ok. Disp well w/30 bbls diesel and crude. Set BPV. Secured well & released rig ~ 2400 hfs, 11/01/84. RECEIVED 0 2 Alaska Oil & Gas Cons. Commission Anchorage 14 I hereby certify that the foregoing ~s true and correct to the best of my knowledge The space b~Jlow for Commission use Conditions of Approval, if any By Order of Approved by. GRUI/SN02 COMMISSIONER the Commission Date Form 10~,03 Rev 7-1-80 Subm,t "Intentions" in Tr,phcate and "Subsequent Reports" in Duphcate ARCO Alaska, Inc. ~ Post Office~rt ,60 Anchorage,~. .aska 99510 Telephone 907 277 5637 Date: 12/13/84 Transmittal No: 4912 RETURN TO: ARCO ALASKA, INC. ATTN: Records Clerk ATO-1115B P.J~ Box 100360 ichorage, AK 99510 and return one si§ned copy of this transmittal. Please acknowledge receipt PBU SURVEYS - CAMCO 1E-8 11/24/84 1E-16 11/13/84 1G-2 11/19/84 2D-10 11/06/84 /cat Receipt Acknowledged: Anchorage DISTRIBUTION B. Currier Drilling W. Pasher State of AK BPAE Geology G. Phillips Sohio Chevron Mobil Phillips Oil Union D & M Q__%P~4ip~ J. Rathmell Well Files ARCO Alaska Inc. IS a subslchary Ol AtlantlcRlchf~eldComDen~/ ARCO Alaska, In~ Post Office Box 1479 Anchorage, Alaska 99510 Telephone 907 277 5637 December 18, 1984 Mr. C. V. Chatterton State of Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Dear Mr. Chatterton: Attached in duplicate are subsequent notices on the following wells at the Kuparuk River Field: Well Action ~ Date Performed 1E-5 Fracture 11/15/84 1E-8 Stressfrac 12/3/84 1G-2 Stressfrac 11/22/84 1G-4 Acidize 12/4/84 1L-3 Fracture 10/28/84 2A-4 Stressfrac 12/8/84 2C-3. Perforate 10/27/84 2D-4 Perforate 12/5/84 2V-1 Conversion 11/8/84 2V-2 Conversion 11/8/84 2V-3 Conversion 11/8/84 2V-4 Conversion 12/8/84 If you have any questions, please call me at 263-4253. Mike L. Laue Kuparuk Operations Coordinator MLL/kmc Attachment (Duplicate) RF..C ED DEC 2 /~lasl(a Oil & Gas Cons. commission Anchorage ARCO Alaska, Inc is a subsidiary of AtlanticR,chheldCompany STATE OF ALASKA ~,, ALASKA OIL AND GAS CONSERVATION C ~MISSION SUNDRY NOTICES AND REPORTS ON WELLS 1 DRILLING WELL [] COMPLETED WELL [] OTHER [] 2 Name of Operator ARCO ALASKA, INC. 3 Address P. O. BOX 100360, ANCHORAGE, ALASKA 99510 4 Location of Well SURFACE LOCATION' 1013' FSL, 629' T11N, R10E, UN 5 Elevation m feet (md~cate KB, DF, etc ) 105 ' (RKB) 12 FEL, SEC. 16, 7 Permit No 80-81 8 APl Number 50- 029-20496 9 Umt or Lease Name KUPARUK RIVER UNIT 10 Well Number 1E-8 11 F~eld and Pool KUPARUK RIVER FIELD 6 Lease Des,gnat,onandSerml No KUPARUK RIVER OIL ADL 25651, ALK 469 POOL Check Appropriate Box To Indicate Nature of Not~ce, Report, or Other Data NOTICE OF INTENTION TO SUBSEQUENT REPORT OF (Submit m Triplicate) (Submit m Duplicate) Perforate [] Alter Casing [] Perforations [] Altering Casing [] Stimulate [] Abandon [] Stimulation )1~ Abandonment [] Repair Well [] Change Plans [] Repairs Made [] Other [] Pull Tubing [] Other [] Pulhng Tubing [] (Note Report multiple completions on Form 10-407 w~th a submitted Form 10-407 for each compleuon ) 13 Describe Proposed or Completed Operations (Clearly state all pertinent detads and g~ve pertinent dates, ~nclud~ng estimated date of starting any proposed work, for Abandonment see 20 AAC 25 105-170) On December 3, 1984, the "A" sands of Kuparuk well 1E-8 were stressfac'd to improve production. The treatment consisted 12 runs with the stressfrac tool. Prior to pumping, equipment was tested to 3000 psi. RECEIVED DEC 2 11. 4 Alaska Oil & Gas Cons. Commission Anchorage 14 I hereby certify that the foregoing ~s true and correct to the best of my knowledge S,gned T,tle OPERAT IONS The space below for Commission use COORDINATOR 12/18/84 Date Conditions of Approval, if any By Order of Approved by COMMISSIONER the Commission Date Form 10-403 Rev 7-1-80 Submit "Intentions" in Tr~phcate and "Subsequent Reports" ~n Duplicate ARCO post Olti~ ~' ~) ho;age, Ataska 99510 A_n.c_ ..,~, 90'/2'/'/563'/ leteph'-"'- November 13, 19B4 ~. ChattertOn' ChairmanssiOn Mr. C. Oil and Gas conservation Commi Alaska Drive 3001 porcupine 99501 AnchOrage ' AK Dear Mr- chattert°n: are our notices of intention to fracture Attached Field wells: following KUparu:E_5, 1E-B, 1E-11, 1E-lB, 1E-20 .questiOnS, please call me at 263-4253' Kuparuk operatmOnS Coordinator MLL / kmC Attachment {In Triplicate) the RECEIVED NOV 1 4 19114 Alaska 0il & Oas Cons. Commission Anchorage ARCO A%aska Inc is a substdte~¥ ot AttanticRichlleldc°mpan¥ '" STATE OF ALASKA ALAS OIL AND GAS CONSERVATION't.,o,~MISSION SUNDRY NOTICES AND REPORTS ON WELLS 1 DRILLING WELL [] COMPLETED WELL I~X OTHER [] 2 Name of Operator ARCO ALASKA, INC. 3 Address P. O. BOX 100360, ANCHORAGE, ALASKA 99510 4 Location of Well SURFACE LOCATION: 1013' FSL, 629' FEL, SEC. 16, TllN, R10E, UM 5 Elevation m feet (md~cate KB, DF, etc ) 105 ' (RKB) Lease Designation and Serml No ADL 25651: ALK 469 7 Permit No 80-81 8 APl Number 5o- 029-20496 9 Unit or Lease Name KUPARUK RIVER UNIT 10 Well Number 1E-8 11 F~eld and Pool KUPARUK RIVER FIELD KUPARUK RIVER OIL POOL 12 Check Appropriate Box To Indicate Nature of Not~ce, Report, or Other Data NOTICE OF INTENTION TO SUBSEQUENT REPORT OF (Submit m Tr~phcate) (Submit m Duplicate) Perforate [] Alter Casing [] Perforations [] Altering Casing Stimulate [~ Abandon [] Stimulation [] Abandonment Repair Well [] Change Plans [] Repmrs Made [] Other Pull Tubing [] Other [] Pulhng Tubing [] (Note Reportmult~plecomplet~onson Form 10-407w~thasubm~tted Form 10-407 for eachcomplet~on) 13 Describe Proposed or Completed Operations (Clearly state all pertinent detads and g~ve pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25 105-170) It is proposed that the "A" sand in Kuparuk well 1E-8 be hydraulically fractured and propped to improve production. The treatment uses gelled water as the pad and carrying fluid and 12/20 sand as the proppant. Lines and equipment will be pressure tested to 5000 psi prior to starting job. Pre-post frac logs are included in the treatment program. Fluid: Gelled Water 363 BBLS Gelled Diesel 45 BBLS Proppant: 12/20 Sand 14,910 LBS ANTICIPATED START DATE: November 15, 1984 RECEIVED NOV 1 1.9l Alaska Oil & Gas Cons C~ m~ssmr, Anchorage 14 I he~ fore~lojng ,s true and correct to the best of my knowledge KUPARUK 11 / 13 / 84 S,gned --f - F' '~)' I... ~..~-- T,tle OPERATIONS COORDINATOR Date The space I~elow for Commlss~o~n use Conditions of Approval, if any Approved by Approved Cop;, Returned Subsequc::t VFozk ~.e2ortecl .... l. J By Order of -- - ~ COMMISSIONER the Commission Date J/ ~/' ~ '~[""'~' / Form 10-403 Rev 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" ~n Duplicate ARCO Alaska, I{~ Post OffR.,. =30x 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 October 9, 1984 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK. 99501 SUBJECT: 1E-8 Dear Mr. Chatterton: Enclosed is a Sundry Notice for the subject well. We propose to convert 1E-8 to a selective single completion. Since we expect to start this work on October 15, 1984, your earliest approval will be appreciated. If you have any questions, please call me at 263-4970. Sincerely, J. B. Kewin Area Drilling Engineer JBK/JG/tw GRU1/L78 Enclosures oc ' AlaSk~ Oil & Gas Cons. Commission Anchorage ARCO Alaska, Inc ~s a Subsidiary of AtlantlcR~chfleldCompany ( Ir STATE OF ALASKA ALASKA 0IL AND GAS CONSERVATION'L, OmMISSlON SUNDRY NOTICES AND REPORTS ON WELLS DRILLING WELL [] COMPLETED WE LLx~ OTHER [] 2 Name of Operator ARCO Alaska, Inc. 3 Address P. 0. Box 100360, Anchoraqe~ AK 99510 4 Location of Well Surface: 1013' FSL, 629' FEL, Sec.16, T11N, R10E, UN 5 Elevation ~n feet (indicate KB, DF, etc ) RKB 105' Lease Designation and Serial No AI")~ 25651 7 Permit No 80-81 8. APl Number 50- 9. Unit or Lease Name _~,_lpar.-k River Un,.'t 10 Well Number 1E-8 11 Field and Pool Kuparuk River Field Kuparuk River Oil Pool 12 (Submit in Triplicate) Perforate [] Alter Casing [] Perforations Stimulate ~ Abandon [] Stimulation Repair Well [] Change Plans [] Repmrs Made Pull Tubing ~ Other ~ Pulhng Tubing (Note Report multiple completions on Form 10-407 w~th a submitted Form 10-407 for each completion ) Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO SUBSEQUENT REPORT OF' (Submit in Duplicate) [] Altenng Casing [] Abandonment [] Other 13 Describe Proposed or Completed Operations (Clearly state all perunent details and g~ve pertinent dates, includ~ng estimated date of starting any proposed work, for Abandonment see 20 AAC 25 105-170) ARCO Alaska, Inc., proposes to convert well 1E-8 to a selective single completion. The procedure will be as fol 1 owe: 1. Well will be killed with brine. Weight to be determined after running pressure bomb. 2. Current completion assembly will be pulled. 3. A retrievable packer will be run to test for zone isolation between the A and C sand, and to test casing integrity. 4. The well will be completed as a selective single and 5000# wellhead equipment will be installed. 5. After the rig is released, an acid and/or frac job will be done. A 13-5/8", 500~psi, SRRA BOP stack will be used on well work. BOP equipment will be tested weekly and operationally tested each trip. A non-freezing fluid will be left in all uncemented annuli within the permafrost interval. A 5000 psi WP wireline lubricator will be used and tested on all wireline work. The subsurface safety valve will be installed and tested upon conclusion of the job. Estimated Start: October 15, 1984 Subsequent Work Reported RECEIVED /0 OCT 1984 Ala.c:kn Oil ....... ~ u[40 tJUII~ bUlilllllb~lUll 141 hereby cer~ :~ the foregoing is true and correct to the best of my knowledge Anchorage , ~ T,tle Area Drilling Engineer Date [ The space below for Commission use Conditions of Approval, ~f any Approved C0J3¥ 6RIGIttAI $1il[I /,,~////p/_~'Retqrned . BT IOH~IE C. SMIT9 ~ By Order of Approved by. COMMISSIONER the Commission Date Form 10-403 Rev 7-1-80 GRU1/SN68 Submit "intentions" In Triplicate and "Subsequent Reports" in Duphcate KUPARUK [NGINEERIIIG TRAHSHITTAL # ~ D. Fay Allison DATE', ~, ,,:;~, ~',, ,_ !,~, / WELL NAME' // Transmitted herewith are the following- see below PLEASE NOTE' BL - BLUELINE, S - SEPIA, F - FILM, T - TAPE,..P/~C_~'' PHOTOCOPY Well Descript ion Date / z_:- 2 :? _ , ~' -..'-- Run R~PT ACKNOWLEDGED' ~PLEASE RETURN RECEIPT TO: DATE' ARCO ALASKA, INC. ATTII: D. FAY ALLISON - ATO/lll5-D P. O. BOX 100360 ANCHORAGE, AK. 99510 KUPAP&JK ~S I NEERI NG TRA~Lg,~ I'rTAL D. W. Bose/Shelby J. Matthews Transmitted herewith are the fol PLEASE NOTE: BL- BLUELINE, S- SEPIA, F- FI ! gA, T- TAPE~ __. \L ~PT PCJ<NO,'/I FIX3ED: PLEASE P, ERJP¢4 RECEIPT TO: ARCO ALASKA, INKg. ATTN: SHELBY J. ~v~TTI-IB',Fo - ATOI 111 5-B P. O. BOX 100360 ANKI~E, AK. 99510 . · f K~ STATE Of ALASKA ~'' ALAS ~.E AND GAS CONSERVATION _, .... .IISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1 Status of Well Class,f,catlon of Sermce Well OIL [~ GAS [] SUSPENDED [] ABANDONED [] SERVICE [] 2 Name of 'Operator 7 Permit Number ARCO Alaska, Inc. 80-81 3 Address 8 APl Number P.0.BOX .360, Anchorage, AK 99510 50- 02<)-20/+06 4 Locat~on of well at surface 101.3'FSL, 62~'FEL, Sec 16, T11N, RIOE, UM 9 Umt or Lease Name Kupa~uk 25651 AtTopProducmglnterval 1.3.35'FNL~ 11/+2'FEL~ Sec 16~ TllN~ RIOE, UM lOWellNumber 1E-8 ,_ At Total Depth ~/+2'FNL~ 1052'FEL~ Sec 16~ T11N~ R10E, UM ~ F,eld and Pool Kupa~uk R~vec F~eId I ' 5 ElevaBon ~n feet (red,cate KB, DF, etc ) 6 Lease Designation and Serml No 105' RKB ADL 25651 Kuparuk River 0i1 Pool 12' Date Spudded 13 DateT"D Reached 14 DateComp,Susp orAband ,15 Water Depth, ,f offshore 116 No of Complet,ons 10/15/80 10/2/+/80 10/28/80J I-- feet MSL 1 17 Total Depth (MD+TVD) 18 Plug Back Depth (MD+TVD)I 19 D~rectmnal Survey 20 Depth where SSSV set I 21 Thickness of Permafrost . 7590' 6558' 7/+85' 6486I YES ~X NO [] 1693' feetMD} 1650' (approx.) 22 Type Electmc or Other Logs Run ' ' ' DIL/BHCS/GR, FDC/CNL/NGT, GR/CBL ..... . 23 CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD '" CASING SIZE WT PER FT GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 1~" ~;5# H-40 Slll"f 80~ 2~' 20~ ~x P~.rm~¢rn_~. 10 3//+" 45.5~ K-55 Surf 2896' 13 3//+ 1350 sx Fondll & 25~ -~X AS 7" 2~://, K-55 S~rf 75~8' 8 3,/t~" 530 .qx Cla.~$ C & 230 sx AS TT 2nd Stage 2'~, 'Perfo~a~u3n~ o~en'to ProdCction (MD+TVD of Top and Bottom and" 25 TUBING RECORD ' ~nterval, s~ze and number) SIZE DEPTH SET (MD) PACKER SET (MD) 7010'-7104' 3 1 12" t~927' · 727/+' -729/+ ' 7.304' -7.356' w/4 SPF 26 ACID, FRACTURE, CEMENT SQUEEZE, ETC DEPTH INTERVAL (MD) AMOUNT& KIND OF MATERIAL USED 7~0/~'-735~' '~. ~5 hhl 17~ H('l 7P7/~ ' -729/*' 3 "/(ll(ll_"/ltlhl -/1~ hhl 19~ I-IPl . v .v . ,v , .,-- ,,. ,,,...,. , ,,.. ,.., ,, ~...,. r27 PRODUCTION TEST Date F~rst Production Method of Operatmn {Flowmg, gas I~ft, etc ) 12/15/81 Flowing "'bate of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE I GAS-OILRATI© 11/1/81 12.5 TESTPERIOD I~ 1/+58 573 -- 9r,/rJ,.{ 39_3 Flow Tub,ng Cas,ng Pressure CALCULATED OIL-BBL GAS-MCF wATER-BBL OiL-EF~AVIT~;-API (corr) Press 175 24-HOUR RATE * ~9.~c~ 1t73 . --. ~a_ 1 28 COP E DATA Brmf descmpt~on of I~thology, porosity, fractures, apparent d~ps and presence of o~1, gas or water Submit core ch~ps RECEIVED N/A MAR 1 5 1982 .%~s~ Oil & Gas Cons. Commission L Form 10-407 Submit ~n duphcate Rev 7-1-80 CONTINUED ON REVERSE SIDE 29 30 GEOLOGIC MARKERS FORMATION TESTS NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS DEPTH TRUEVERT DEPTH GOR, and tlme of each phase Top Kuparuk River Form. 7012' " 6144' Base Kuparuk River Form. 7414' 6438' 31 LIST OF ATTACHMENTS 32 I hereby certify that the foregoing ~s true and correct to the best of my knowledge Signed ~ ~ ~~,~ T,tle Area 0ps. En.cjr. Date INSTRUCTIONS General This form ~s 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 ~nject~on, water inject~on, steam ~nject~on, a~r ~nject~on, salt water disposal, water supply for injection, observation, injection for in-sltu combustion. Item 5 Indicate which elevation IS used as reference (where not otherwise shown) for depth measurements given ~n other spaces on th~s form and in any attachments Item 16 and 24 If th~swell ~scompleted for separate production from more than one ~nterval (multiple completion), so state in ~tem 16, and in item 24 show the producing ~ntervals for only the ~nterval reported in ~tem 27. Submit a separate form for each additional ~nterval 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 th~s well should show the details of any multiple stage cement- lng and the location of the cementing tool. Form 10-407 TO: T~~ransmltted herewith are FROM- D. W. Bose/Lorle L. Johnson WELL NAb:E: the following- PLEASE NOTE- BL - BLUELiNE, S - SEPIA, F - FILM, T - TAPE RECEIPT ACKNOWLEDG~[~-~ /~:~P~"~~~'/:: DATE ASE RETURN RECEIPT TO: ARCO ALASKA, INC. ATTN: LORIE L. JOHNSON - AFA/311 P. O. BOX 360 ANCHO~GE, AK 99510 iIORTii ~LO?E E~IGI~:EEP, Ii;G TRAilSMITTAL = ~7/ J. J. Pa'.,'elek/Ann Simonsen ilm,.IE ' DATE. /¢ --~ - ¢/ WELL "'" · Transmit'ced ~ere,.,:itn ar:e the following' PLEASE I:OTE' BL - BLUEL!HE, S - SEPIA, F - FILM, T - TAPE F. ECE ] PT PLE;.EE ~.ET.'?:, I.~.~,,TT TO' DATE:: .'.,,~ ~ ]:~, ~] ~ · Alaska 0~1 & Ga; Cons· Cornl~is,~iO~ ARCO ALAS}gA, I~C. Anchorag~ ~ , ,,~,,~ r-,I ATT;~ A;;:; SI,.,u,~=,, - AFA/311 P.O. DOX 360 ~. ,, ~., 9c510 2 Name of Operator ARCO Alaska, 3 Address P.O. Box 360, ( '~ STATE OF ALASKA C_~' ALASK .~iL AND GAS CONSERVATION .,IMISSION SUNDRY NOTICES AND REPORTS ON WELLS RECEIVED DRILLING WELL [] COMPLETED WELL ~ NOV ' 7 Perm,t No Inc. ^l::ka 0il & Gas Cons. Cam. miss!on 80-81 Anchorage, AK 99~10 4 Location of Well Surface T,ocatlon: 5 Elevation m feet (ind,cate KB,~DF, etc ) KB 105.5 1013' FSL, 629' FEL Section 16, TllN, R10E U.M. 6 Lease Designation and Serial No ADL 25651 OTHER [] 8 APl Number 50- 029-20496 9 Un,t or Lease Name Kuparuk 25651 10 Well Number 1~.-8 11 F~eld and Pool Kuparuk River Field Kuparuk River Oil Pool 12 (Submit in Tr,phcate) Perforate I--] Alter Casing [] Perforations Stimulate ~ Abandon [] Snmulat~on Repair Well [] Change Plans [] Repairs Made Pull Tubing [] Other [] Pulling Tubing (Note Reportmult~plecomplet~onson Form 10-407w~thasubmltted Form 10-407 for each completion) Check Appropriate Box To Indicate Nature of Not~ce, Report, or Other Data NOTICE OF INTENTION TO SUBSEQUENT REPORT OF (Submit m Duplicate) [] Altering Casing Abandonment [] Other 13 Describe Proposed or Completed Operations (Clearly state all pertinent detads and g~ve pertinent dates, including estimated date of startmgany proposed work, for Abandonment see 20 AAC 25 105-170) Began cleanout operations on 10/29/81. RU CTU & pumping equipment & tested to 4000 psi. RIH circulating diesel. Tagged hard fill at 7327' MD, 158' above PBTD. Began circulating Nitrogen and diesel w/foaming agent. Broke down bridge of fill and reciprocated through interval from 7327-7485'MD. Circulated clean diesel to expel foam and then squeezed Mudban, a mud dispersant, into the perf'd interval 7304-7356'MD, 7274-7294'MD and 70%0-7104'MD. Circulated clean diesel to expel Mudban emulsion. Flow to tanks for 10 hours to cleanup. No rate improvement seen. SI well awaiting acid. Total diesel circulated = 283 barrels, total N2 -diesel foam circulated = 103 bbls,I total 2% Mudban solution squeezed = 23 bbls. Began acid job on 10/31/81. RIH circulating diesel. Squeezed 65 bbls 12% HC1 with additives into lower perf'd intervals 7304-7356'MD and 7274-7294'MD at maximum surface tub%~g pressure of 1300 psi. Squeezed 72 bbls 12% ECl with additives into perf interval 7010-7104'MD at same tubing pressure. Circulated 50 bbls of N2-diesel foam followed by 75 bbls of clean diesel. RIH w/production logging equipment and conducted well test. Flowed well at rate of 2985 BOPD. GOR=393, FTP=175 psi FBHP=1641 psi. Ran production lO~s.' SI well for PBU. FSIBEP =3129 psi. Secured well 11/2/81. Note: HP Tool set at 6973'MD (6009'ss) 14 I hereby certify that the forego,ng ~s true and correct to the best of my knowledge S,gned '~. ~J~,~~~"' T,tl~rea Operations Engineer The space bel~v for Commission u~r Date Conditions of Approval, ~f any By Order of Approved by COMMISSIONER the Comm,sslon Date Form 10-403 Rev 7-1-80 Submit "Intentions" in Tr~phcate and "Subsequent Reports" ,n Duphcate STATE OF ALASKA (, ALASK .IL AND GAS CONSERVATION vIMISSION SUNDRY ]OTDC S A JD iRE;PORTS ON WEL S DRILLING WELL [] COMPLETED WELL I~ OTHER [] 2 Name of Operator 7 PermIt No ARCO Alaska, Inc. 80-81 3 Address 8 APl Number P. O. Box 360, Anchorage, AK 99510 5o- 029-20496 4 Locanon of Well Surface Location: 5 ElevatIon ,n feet (~nd,cate KB. DF. etc ) NB = ]05.5 12. 1013' FSL, 629' FEL Sec. 16, TllN, R1OE I 6 . Lease Des~gnatmn and Serial No. ADL 25651 9. Un,t or Lease Name Kuparuk 25651 10. Well Number F.-8 11. Field and Pool Kuparuk River Field Kuparuk River Oil Pool Check Appropr,ate Box To Indicate Nature of Notme, Report, or Other Data NOTICE OF INTENTION TO. SUBSEQUENT REPORT OF.' (Subm,t ,n Tr,pl,cate) (Submit ~n Dupl,cate) Perforate [] Alter Casing [] Perforations [] Altering Casing [] Stimulate ~] Abandon [] Stimulation [] Abandonment [] Repa,r Well [] Change Plans [] Repairs Made [] Other [] Pull Tubing [] Other I~ Pulling Tubing [] (Note Reportmult,plecomplet,onson Form 10-407w~thasubm,tted Form 10-407 for eachcomplet~on) 13 Descrtbe Proposed or Completed Operations (Clearly state all pertInent detads and give pert,nent dates, ~ncludlng estimated date of starting any proposed work, for Abandonment see 20 AAC 25 105-170) ARCO Alaska, Inc. proposes to cleanout drilling fluids in cased hole which cover the Lower Kuparuk sands. The work will be done using a coiled tubing unit with BOP assembly tested to 4000 psi. The well will be acidized after cleanout if an acceptable flow rate is not achieved. All circulated and flowed fluids will be diverted to tankage on location. The well will be tested after cleanout and/or acidization. Expected start date is Octobe~ 19, 1981. Conditions of Approvdl ~f any 14 I hereby certify that the foregoing is true and correct to the best of my knowledge Signed The space~owfor Commission - / / Approved by RECEIVED OCT 2 0 1981. Alaska Oil & Gas Cons. Commission Anchorage BY L~P, HJE C. SAIIT~J ,~,~?,.,,~.~ Copy COMMISSIONER the Commission Date Form 10-403 Rev 7-1 .S0 Submit "Intentions" in Triphcate and "Subsequent Reports" ,n Duplicate NORTH SLOP'~ EiIGI" '-: ~' ~ ,,E:,,I:;G TO' ~//~1 ~ ~c~-~ FROM' J. J. Pa,.:elek/$nn Simonsen DATE' f/ (,)-/2- ~ / WELL ',*".F.,,~,.,_ · . Transmltzed herewith are the following' .~, PLEASE '~--' " - [,~ BL - BLUEL!~E, S SEPIA, - TaP r.. F- FILM, T ~ ~' DATE: · P, F.. ',,., F__ PL~_~,S:_ RETUR:; '-^'-,?T TO' ARCO ALAS!tN, I~,'C. ATTH: A~;:I SI?.O;iSE~! - AFA/311 P.O. BO:,: 36O ~r, 9951 0 RE. CEIYEJ) OCT t lg t 0}{ & Gas Cons. ~chorage ilO~,Ttt SLO['E E~IGI~iEEP, I~ ~' FROM' J.J. Pa'.;elex/Ann Simonsen BATE' ~- Z~- ~/ WELL ';A:.iE' . · Transml ~.~d herewitn are th~ follc:;~ng' PL-A.~E HOTE' BL BLUELI:IE S SEPIA F FILM T TAPE ~ /,,9~.. ~..~/.. __,~/.~,,~ RE£EIVED RECEIPT ,-,C,,,,O,,LEBC, F-i~:'' ...... ,c'V-,,, Commission r- ,r) E- ~1 ,r), I ~r'- - PLEAS:_ ,,~,~,.,~ f.,LCF_i,-T TO: ARCO ALAS:~A, II~C. ATT!~' At~l SIMO:ISE!I - ARA/311 Anchorage P.O. COX 36O ~:' .... ~c510 STATE OF ALASKA (~' ALASKA ,L AND GAS CONSERVATION C ,v, MISSION SUNDRY NOTICES AND REPORTS ON WELLS I DRILLING WELL [] COMPLETED WELL EX OTHER [] 2 Name of Operator 7 Perm~tNo ARCO Alaska, Inc. 80-81 3 Address 8 APl Number P.O.Box 360, Anchorage, AK 99510 50- 029-2-496 4 Location of Well Surface Location: 1013' FSL, 629' FEL Sec. 16, TllN, R10E 5 Elevation m feet (md~cate KB, DF, etc ) KB=105 ' Lease Designation and Serial No ADL 25651 12 9 Unmt or Lease Name Kuparuk 25651 10 Well Number E-8 11 F~eld and Pool Kuparuk River Field Kuparuk River Oil Pool Check Appropriate Box To Indicate Nature of Not~ce, Report, or Other Data NOTICE OF INTENTION TO SUBSEQUENT REPORT OF (Submit ~n Triplicate) (Submit ~n Duplicate) Perforate [] Alter Casing [] Perforations X[] Altering Casing [] Stimulate [] Abandon [] Stimulation [] Abandonment [] Repair Well [] Change Plans [] Repa,rs Made [] Other [] Pull Tubing [] Other [] Pulling Tubing [] (Note Report multiple completions on Form 10-407 w~th ,a submitted Form 10-407 for each completion ) 13 Describe Proposed or Completed Operations (Clearly state all pertinent detads and g~ve pert,nent dates, ~nclud~ng est,mated date of start,ng any proposed work, for Abandonment see 20 AAC 25 105-170) Began operations on 8/21/81. Tagged fill over area to be perf'd. RU CTU & test to 4000 psi. RIH & pump 76 bbl diesel. Change over to Gel WTR, RIH to 7455', pump 76 bbl Gel. Changed over to diesel & POH while circ. RU Perf unit & test lub to 2500 psi. Tagged fill @ 7178'. RU CTU & test to 4000 psi. RIH pumping diesel, tag BTM @ 7493', good returns. Work CT f/PBTD - TBG tail. POH while circ. RU perf unit & test to 3000 psi. Perf'd intervals 7324'-7356', 7304-7324', 7274'-7294', 7072'-7104', 7040'-7072' & 7010'-7040'. RIH with production logging tools. Flowed well @ rate of 711 BOPD. GOR=443, FTP=100 psi, FBHP=1681 psi. Ran production logs. SI well f/PBU. SIBHP = 3159. Secured well 8/29/81. NOTE: HP Tool set at 6000'ss F,E£E VED 14 I hereby certlfy that the foregoing ~s true and correct to the best of my knowledge ~~ ~~ Area Operations S,gned · ~_~ , Title The space I~,ow for Comm,ss,on ~ Cond)t~ons of Approval, ~f any Engineer Date By Order of Approved by COMMISSIONER the Commission Date Form 10-403 Rev 7-1-80 Submit "Intentions" ~n Triplicate and "Subsequent Reports" ,n Duplicate A(L~ STATE OF ALASKA C~ ALASK ~L AND GAS CONSERVATION MMISSION SUNDRY NOTIC _S AND RZPORTS ON 1 DRILLING WELL [] COMPLETED WELL~ OTHER [] 2 Name of Operator 7 PermIt No ARCO Alaska Inc, 80-81 3 Address 8 APl Number Box 360 Anchorage, Alaska 99510 50-029-20496 4 Location of Well Surface Location: 1013' FSL, 629' FEL Sec 16, TllN, R10E 5 ElevatIon m feet (~ndmate I<B, DF, etc) KB olova~4n = 105 12. Lease Des,gnat,on and Serial No ADf, 2565] 9 Umt or Lease Name Kuparuk 25651 10 Well Number :E-8 11 F,eld and Pool Kuparuk River Field Kuparuk River Oil Pool Check Appropriate 8ox To Indmate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO. SUBSEQUENT REPORT OF (Submit m Tr~phcate) (SubmIt ,n Duplicate) Perforate EX Alter Casing [] Perforations [] Altering Casing [] Stimulate [] Abandon [] Stimulation [] Abandonment [] Repmr Well [] Change Plans [] Repmrs Made [] Other [] Pull Tubing [] Other [] Pulling Tubmg [] (Note Reportmutt~plecomplet~onson Form 10-407w~thasubm~tted Form 10-407 for eachcomplet~on) 13 Describe Proposed or Comple[ed Operations (Clearly state all pertinent detmls and g~ve pertinent dates, ~ncludmg estimated date of starting any proposed work, for Abandonment see 20 AAC 25 105-170) ARCO Alaska Inc. proposes to perforate and flow test selected intervals of 7010-7104, 7274-7294, and 7304-7356 of the Upper and lower Kuparuk Sands. All wire line work will be done through a 3000 psi lubricator which will be pressure tested after being in- stalled on the wellhead. Expected Start Date 7-16-81. RECEIVED JUL ! 4 1981 ~ch0rage 14 I hereby.~ert,fy tha/~/fhe/foregolng is true and correct tO the best of my knowledge ~,,,_,//.,'.O~,._~ff/'/(/, / K uparuk S tartup Director The space below for ~o~m~ss~on us_ Date Condtt~ons of Approval, ~f any 7/10/81 Approved by. ORIG'HAL SIC~ItEO BY LON2,11E IL S~I'Ttt ,Approved "opy Returned By Order of COMMISSIONER the Commission Date Fo,m 10-403 Rev 7-1 -SO Submit "Intentions" in Triplicate and "Subsequent Reports" ~n Dupl,cate NORTH SLOPE DISTRICT ENGINEERING TRANSMITTAL Transmitted herewith are the following for the subject well' DATE 1 GEOL FROM' 3err,y J. Pawelek/Leo Lash WELL NAME: ~L/~I~IA~ ~'- SCALE XEROX SEPIA LINE FILM BHC Sonic/Gamma Ray Log Cement Bond Log/VDL Compensated Formation Density Log Compensated Neutron-Formation Density Compensated Neutron Log Core Analysis - Interval Core No. Core Description (SWC) - Interval Core Description (Conv.) - Core No. Directional Survey - Gyro Single Shot Multi-shot .~ Drill Stem Test - Test No. '-~ Dual Induction Laterolog Formation Density Log 'Formation Density Log/Gamma Ray Spectralog TVD-DIL Differential Temperature Log Spinner Survey Fluid Density y_O_~_~!_~.~DCasing Collar Log Perforating Record Neutron Lifetime Log Carbon-Oxygen Log ! ! RECEIPT ACKNOWLEDGED FOR- DATE' 'u/~PLEASE RETURN RECEIPT TO- RECEIVED DEC- ]980 Nmlmal& G~Oons. Oommluion Anchorage ARCo Oil and Gas Company Attn: Mr. Leo Lash P.O. Box 360 - Rm. #311-FAB Anchorage, AK 99510 NORTH SLOPE DISTRICT ENGINEERING TRANSMITTAL# FROM' Jerry J. Pawelek/Leo Lash Transmitted herewith are the following for the DATE BHC Sonic/Gamma Ray Log Cement Bond Log/VDL Compensated Formation Density Log Compensated Neutron-Formation Density Compensated Neutron Log Core Analysis - Interval Core No. Core Description (SWC) - Interval Core Description (Conv.) - Core No. Directional Survey - Gyro Single Shot Multi-shot Drill Stem Test - Test No. Dual Induction Laterolog Formation Density Log Formation Density Log/Gamma Ray Spectral og TVD-DIL Differential Temperature Log Spinner Survey Fluid Density Casing Collar Log Perforating Record Neutron Lifetime Log Carbon-Oxygen Log subject well · BL SCALE XEROX SEPIA LINE FILM RECEIPT ACKNOWLEDGED FOR- DATE' PC/~LEASE RETURN RECEIPT TO' RECEIVED DEC- ~ !980 Alaska Oil & Gas Con.. Comm~ion rage ARCo Oil ah~Gas Company Attn' Mr. Leo Lash P.O. Box 360 - Rm. #311-FAB Anchorage, AK 99510 NORTH SLOPE DISTRICT ENGINEERING TRANSMITTAL# Transmitted herewith are the following for the DATE BHC Sonic/Gamma Ray Log Cement Bond Log/VDL Compensated Formation Density Log Compensated Neutron-Formation Density Compensated Neutron Log Core Analysis - Interval Core No. Core Description (SWC) - Interval Core Description (Conv.) - Core No. Directional Survey - Gyro Single Shot Multi-shot Drill Stem Test - Test No. Dual Induction Laterolog Formation Density Log Formation Density Log/Gamma Ray Spectralog TVD-DIL Differential Temperature Log Spinner Survey Fluid Density Casing Collar Log Perforating Record Neutron Lifetime Log Carbon-Oxygen Log FROM: Jerry J. Pawelek/Leo Lash WELL NAME' subject well: BL SCALE XEROX SEPIA LINE FILM RECEIPT ACKNOWLEDGED FOR: RECEIVED EASE RETURN DATE- DFC,- 1980 ~las~.~Oil & g,~s Cons. Commission RECEIPT TO: ARCo ~i~oa~d Gas Company Attn: Mr. Leo Lash P.O. Box 360 - Rm. #311-FAB Anchorage, AK 99510 NORTH SLOPE DISTRICT ENGINEERING TRANSMITTAL# DATE' FROM' Jerry WELL NAME' J. Pawelek/Leo Lash Transmitted herewith are the following for the DATE BHC Sonic/Gamma Ray Log Cement Bond Log/VDL Compensated Formation Density Log Compensated Neutron-Formation Density Compensated Neutron Log Core Analysis - Interval Core No. Core Description (SWC) - Interval Core Description (Conv.) - Core No. Directional Survey - Gyro Single Shot Multi-shot Drill Stem Test - Test No. Dual Induction Laterolog Formation Density Log Formation Density Log/Gamma Ray Spectralog TVD-DIL Differential Temperature Log Spinner Survey Fluid Density /O.~l~)Casing Collar Log Perforating Record Neutron Lifetime Log Carbon-Oxygen Log subject well · SCALE XEROX BL SEPIA LINE ? / FILM RECEIPT ACKNOWLEDGED FOR' DATE' &~PLEASE RETURN RECEIPT TO' DEC- 3 lggO Alaska "'"~,, & e~_~ .... nnn"._. _ P, nrnmi?inn Ancholage ARCo Oil and Gas Company Attn: Mr. Leo Lash P.O. Box 360 - Rm. #311-FAB Anchorage, AK 99510 - / Form No 10-404 REV 3-1-70 SUBMIT IN DUPLICATE STATE OF ALASKA OIL AND GAS CONSERVATION COMMITTEE MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS 5. AP! NUMERICAL CODE 50-029-20496 6. LEASE DESIGNATION AND SERIAL NO ADL 25651 WELL WELL OTHER 2 NAMj~I OPERATOR,., . 8~ UNI'~,FARM ORLEA~F,-I~,$.ME antic Klchfield Company ~uparuK z~ob~. 3. ADD~ES6OF~P~(AT~go. · Anchorage, AK 99510 ,. WEL~N_~ 4. LOC T ~F L l~J F~, 629'FEL, Sec 16, T11N, RIOE, UM 10 FIELD AND POOLOR WILi~CA~,~ Prudhoe Bay F~e~o/ OBJECTIVE) Sec 16, T11N, RIOE, UM ,2 PER~_N~i 13. REPORT TOTAL DEPTH AT END OF MONTH, CHANGES IN HOLE SIZE, CASING AND CEMENTING JOBS INCLUDING DEPTH SET AND VOLUMES USED, PERFORATIONS, TESTS AND RESULTS FISHING JOBS JUNK IN HOLE AND SIDE-TRACKED HOLE AND ANY OTHER SIGNIFICANT CHANGES IN HOLE CONDITIONS. Spud @ 0600 hrs 10/14/80. Drld 13-3/4" hole to 2920'. RU & run 70 jts US Steel 10-3/4" 45.5# BTC csg to 2896'. Cmt 10-3/4" csg w/1350 sx Fondu cmt followed w/250 sx Arctic- set cmt. Tstd pkoff to 2000 psi. Tstd BOP's to 3000 psi. Tstd 10-3/4" csg to 1500 psi. Drld FS, cmt to 2730'. Form tst to 12.5 ppg EMW. Drld 8-3/4" hole to 8422'. RU & run DIL/BHCS/GR & FDC/CNL/ NGT. RU & run 188 its 7" 26# K-55 BTC csg w/FS @ 7568' & FC @ 7489'. Circ csg & cmt w/530 sx. CIP 0700 hrs 10/26/80. Instl 7" pkoff & tst. Tag cmt @ 7259'. Pump 300 bbls HoO dwn 7" x 10-3/4" ann followed by 41 bbls AS II cmt & 114 bbls Arctic Pack. APIP @ ~545 hrs 10/26/80. Tag,,cmt @ 7273'. Drlg cmt to 7485' Tst csg to 1500 psi. Finish rng CBL. RU & run 3-1/2 tbg & compl assy. Land tbg w~tail @ 6927', pkr @ 6888' & SSSV @ 1693'. Tst SSSV. Displ well to diesel. Drop ball & set pkr. ND BOPE. NU xmas tree & tst. Begin long term tbg tst. Rig released @ 2400 hrs 10/28/80. I FCEIV D ~laska Oil &Anchorage~as Cons. Commission 14. 1 heteb --y~~t ~l~7~s t~nd~cort~c t SiONEDi..,--.,,,~g,e~,--~-~/r---i~/~l~ j~lii~ll~/~F~ District Drlg Engineer DATE 11/25/80 NOTE-Report on th,s form is required for each calendar month, regardless of the status of operations, and must be filed in duplicate with the oil and gas conservation comm,ttee by the 15th of the succeeding month,unless otherwise directed. December 1, 1980 Mr. P. A. Van Dusen District Drilling Engineer Arco Oil and Gas Comapny P.O. Box 360 Anchorage, Alaska 99510 Re: P.B.U. DS 2-1T P.B.U. DS 11-14 P.B.U. DS 17-4 Kuparuk D-6 · Kuparuk D-7 Kupar~, We have checked our files and do not fina Completion Reports (form 10-407} on the subject wells. ?Te understand the report on P.B.U. DS 2-17 was waiting for a final directional survey to be received. Available information indicates the other wells have been drilled and were completed as unpurforated oil wells during October, 1980. Please check your transmittals to confirm that the forms have been sent. If they have not, send the appropriate 10-407 forms at this time. Please let us know if it is necessary to delay the final reports until receipt of directional surveys on any of the welIs. Sincerely, , / John A. Levorsen Petroleum Geologist JAL ~ mm ARCO Oil and Gas( ,~pany North Slope u~stnct Post Office Box 360 Anchorage, Alaska 99510 Telephone 907 277 5637 November 26, 1980 Mr. Hoyle Hamil ton State of Alaska Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 COMAA CO:'x~kA ENG 1 ~NG ~-4 F,~ ~G -1 C'EOL i- 3 GEOL I ST <T T,SC ST/~T T~C CONF? FILF:- Subject: DS 17-4 Permit #80-85 DS 5-2 Permit #74-36 DS 2-4 Permit #70-17 DS 17-5 Permit #80-96 DS 15-10 Permit #80-88 DS 15-21 Permit #80-91 DS 14-9 Permit #80-89 Kuparuk E-7 Permit #80-80 D-6 Permit #79-96 D-7 Permit #79-112 D-5 Permit #79-95 E-4 Permit #80-57 E-8 Permit #80-81 D-3 Permit #79-84 Dear Sir: Enclosed please find: 1. A completion report, drilling history and a gyroscopic multishot survey for wells; DS 17-4, E-7, D-6, D-7 & E-8. 2. A Sundry Notice of subsequent report for wells; DS 5-2, DS 2-4, D-3, D-5 & E-4. (An updated Completion Report will be filed, for D-3, D-5 & E-4 as soon as produc- tion test data becomes available.) 3. A monthly report of drilling for wells; DS 17-5, DS 15-10, DS 15-21, DS 14-9, E-8 & D-7. Very truly yours~ , p. ^. YanDusen Distr~ct Dr~ll~n§ [n~ineer P^¥:sp Inclosures I ECEIVED Alaska Oil & Sas Coos Anchorag~ Commission ARCO Oil and Gas Company ~s a D~v~s~on of AtlanticR~chfleldCompany Form P--7 SUBMIT IN D E* STATE OF ALASKA (See other in- structions on reverse side) Gl L AND GAS CONSERVATION COMMITTEE WELL COMPLETION OR RECOMPLETION REPORT AND LOG* la TYPE OF WELL OWIELLL[~] GAS !-"1 WELLi I DRYO Other b TYPE OF COMPLETION NEW WORK DEEP- r-1 PLUG DIFF WELL ~-~ OVER 0 E" U BACK 0 RESER 0 Other 2 NAME OF OPERATOR Atlantic Richfield Company 3 ADDRESS OF OPERATOR P.O. Box 360, Anchorage, AK 99510 4 LOCATION OF WELL (Report location clearly and in accordance with any State requirements)* At surface 1013' FSL, 629' FEL, Sec 16, TllN, RIOE, UM At top prod interval reported below 1335' FNL, 1142' FEL, Sec 16, TllN, R10E, UH At total depth 942' FNL, 1052' FEL, Sec 16, TllN, R10E, UM 13 DATE SPUDDED ~14 DATETD REACHED 10/15/80I 10/24/80 18 TOTAL DEPTH MD&TVD 119 PLUG BACK 7590'MD ~558'TVDI 7~I~ MD T Kuparuk 7011' /LOW bang ~L)~;*5' MD T. Up Sand 7011' MD 6143' TVD B Low Sand 7355' MD B. Up S~nd 7104' MD 6214' TVD B Kuparuk 7414' MD 24 TYPE ELECTRIC AND OTHER LOGS RUN DIL/BHCS/GR, FDC/CNL/NGT, GR/CBL CASING RECORD (Report all strings set in well) 25 CASING SIZE 16" 5 APl NUMERICAL CODE 50-029-20496 6 LEASE DESIGNATION AND SERIAL NO ADL 25651 7 IF INDIAN, ALLOTTEE OR TRIBE NAME S UNIT, FARM OR LEASE NAME Kuparuk 25651 9 WELL NO E-8 10 FIELD AND POOL, OR WILDCAT Prudhoe Bay Field/Kuparuk 11 SEC,T,R,M,(BOTTOMHOLE River 0il OBJECTIVE) Pool Sec 16, TllN, RIOE, UN 12 PERMIT NO 80-81 115 DATE COMP' SUSP' OR ABAND 116ELEVATIONS{DF'RKB'RT'GR'ETC)* [17ELEVCASINGHEAD10/28/80 105' RKB MD&TVDI20 IF MULTIPLECOMPL [ CABLE TOOLS HOW rvtANY.~ ' 21 ROTARY TOOLS INTERVALS DRILLED BY 6486' TVDI single I all 23 WAS DIRECTIONAL 6333' TVD SURVEY MADE 6397' TVD 6438' TVD yes 10-3/4" 7II DEPTH SET (MD) 80' 2896' 7568' WE,G.T, LB/.T I GRADE 65# IH-40 LINER RECORD TOP (MD) BOTTOM (MD) SACKS CEMENT* SIZE n/a 28 PERFORATIONS OPEN TO PRODUCTION n/a 24" 1200 sx Pemafrost to surface 13-3/4"1 1350 sx Fondu + 250 sx A~ctic Set 8-3/4"1530 sx Class G + 200 sx ~S II- 2nd stage I / 27 TUBING RECORD SCREEN (MD) DEPTH SET (MD) PACKER SET ,MD) 3~~IzE 6927' 6888' 29 ACID, SHOT, FRACTURE, CEMENT SQUEEZE, ETC DEPTH INTERVAL (MD) n/a AMOUNT AN~ ,K,,~N;Q O~ M~,'r~::~IAL USED (Interval, size and number) PRODUCTION DATE FIRST PRODUCTION n/a IPRODUCTION METHOD (Flowing, gas lift, pumping--size and type of pump) , , ' .... ¢?.0. Commission ~~us (.~o~u~.. o, shut-In) DATE OF TEST HOURS TESTED CHOKE SIZE FLOW TUBING CASING PRESSURE CALCULATED PRESS 24-HOUR RATE 31 DISPOSITION OF GAS (Sold, used for fuel vented, etc ) I PROD'N FOR iOIL-BBL TEST PERIOD OIL--BBL GAS--MCF I GAS--MCF i WATER-BB L I GAS--Gl L RATIO lOlL GRAVITY-APl {CORR ) I ITEST WITNESSED BY 32 LIST OF ATTACHMENTS Dri. llin.q, h,ist~.y and Gryoscopic survey 33 I hereby certlf;~t)f~e fTgoig~d aty)l~d inforjlnatlon Is complete and correct as cletermmed from all available records ~¢.¢,¢..~.,~_.~~, ~ ~ ~~. D, strlct SIGNE TITLE ' ' Dril 1 lng Engineer *(See instructions and Spaces for Additional Data on Reverse Side) INSTRUCTIONS General Th~s form ~s designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item: 16: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given ~n other spaces on th~s form and in any attachments. Items 20, and 22: If this well is completed for separate production from more than one ~nterval zone (multiple com- pletion), so state ~n ~tem 20, and in item 22 show the producing ~nterval, or intervals, top(s), bottom(s) and name(s) (if any) for only the interval reported in item 30. Submit a separate report (page) on th~s form, adequately ~dent~fled, for each additional interval to be separately produced, showing the additional data pertinent to such ~nterval. Item 26: "Sacks Cement"' Attached supplemental records for this well should show the detmls of any multiple stage cementing and the location of the cementing tool. Item 28: Submit a separate completion report on this form for each interval to be separately produced. (See ~nstruct~on for items 20 and 22 above) RY OF FORMATION TESTS INCLUDING INTERVAL TESTED, PRESSURE DATA AND RECOVERIES OF OIL, GAS, WATER AND MUD 35 GEOLOGIC MARKERS NAME ,., MEAS. DEPTH TRUEVERT DEPT NONE T Kuparuk 70ll' 6143' T Up Sand 7011 ' 6143' B Up Sand 7104' 6214' T Low Sand 7265' 6333' B Low Sand 7355' 6397' B Ku pa ru k 7414' 6438' ,__ CORE DATA, ATTACH BRIEF DESCRIPTIONS OF LITHOLOGY, POROSITY, FRACTURES, APPARENT DIPS AND DETECTED SHOWS OF OIL, GAS OR WATER. NONE DRILLING HISTORY KUPARUK E-8 Spu.dded well @ 0600 hrs on 11/15/80. Drl & jet 13-3/4" hole to 1376'. Lost pump press, repair mule shoe sub. Drl 13-3/4" hole to 2920'. Circ & clean hole. Cmt 10-3/4" csg w/1350 sx Fondu cmt followed w/250 sx Arctic Set cmt. Good returns thru cmt job. Circ 107 sx. Set & tst pkoff to 2000 psi. Tst 10-3/4" csg to 1500 psi. Drl plugs, FC & cmt to 2890. Tst csg to 1500 psi. Drl FS cmt & 10' new hole to 2730'. Form tst to 12.5 ppg EMW. Chng t~ oil base mud. Drl 8-3/4" hole to 7550' & circ & cond F/logs. TOH. Pulled tight @ 7177' - TBIH to bottom. Circ btms up. TOH. RU Schlumberger & RIH to 6370' - would not go. RD Schlumberger. TIH. Worked thru tight spot 6336' - 6436' & RIH to btm. Circ & cond mud for logs. RU & run DIL/BHCS/GR & FDC/ CNL/NGT. Take sidewall cores. RD Schlumberger. Drl 8-3/4" f/7550' - 7590'. RU & run 188 its 7" 26# K-55 BT&C csg w/FS @ 7568'. Circ csg & cmt w/530 sx. Displ w/lO.O ppg NaC1/NaBr. Did not bump plug. Pump 300 bbls H?O down 7" x 10-3/4" annulus followed by 41 bbls AS-II cmt & ll4-bbls Arctic Pack. Drl cmt to 7485' w/3½" DP. Tst csg to 1500 psi. Run GR/CBL. RU & run 3½" tbg and completion assy. Land tbg w/tail @ 6927', pkr @ 6888'. Change over to diesel. Drop ball, set pkr, ND BOPE NU tree and test. Begin long term tbg test. Rig released @ 2~00 hrs, 11/28/80. NORTH SLOPE DISTRICT ENGINEERING il co~ : 13' ' !~____~, ~OL FROM: Jerry/ O. Pawelek/Leo Lash NELL NAHE' i ~E~ ,,,, , BL S6ALE XEROX SEPIA L~NE F~LM TRANSMITTAL# ~J Transmitted herewith are the following for the subject well: DATE BHC Sonic/Gamma Ray Log Cement Bond Log/VDL Compensated Formation Density Log Compensated Neutron-Formation Density Compensated Neutron Log Core Analysis - Interval Core No. Core Description (SWC) - Interval Core Description (Conv.) - Core No. Directional Survey - Gyro Single Shot Multi-shot Drill Stem Test - Test No. -~ Dual Induction Laterolog Formation Density Log Formation Density Log/Gamma Ray Spectral og TVD-DIL Differential Temperature Log Spinner Survey Fluid Density Casing Collar Log Perforating Record Neutron Lifetime Log Carbon-Oxygen Log RECEIPT ACKNOWLEDGED FOR: DATE: PLEASE RETURN RECEIPT TO: RECEIVED NOV 2 8 1980 AlasJa Oil & Gas Cons. Commission Anchorage ARCo Oil and Gas Company Attn: Mr, Leo Lash P.O. Box 360 - Rm. #311-FAB Anchorage, AK 99510 SCIENTIFIC DRILLING CONTROLS 700 West 41st Street GYROSCOPIC DIRECTIONAL SURVEY FOR ******************** * ARCO OIL & GAS * ******************** JOB NUMBER: 3811 DRILL NAME- Kuparuk E-8 0 LOCATION: PRUDHOE BAY · SURVEY DATE: l~-ll-80 SURVEY ENGINEER: ANDY LOCHHEAD GYRO REFERANCE READING: NOO-OOF METHOD OF CALCULATION: RADIUS OF CURVATURE · **DEPTH MEASURED IN FEET*** COMMENTS: THANKS ********************************** * THIS SURVEY IS CORRECT TO THE * * BEST OF MY KNOWLEDGE AND IS * * SUPPORTED BY ACTUAL FIELD DATA * * COMPANY REPRESENTATIVE * COMPLETION REPORT ARCO OIL & GAS GYROSCOPIC SURVEY RADIUS OF CURVATURE METHOD OF COMPUTATION COMPUTED FOR SDC BY FM LINDSEY 8 ASSOC 12 NOV 80 KUPARUK E-8 ~-- KB ELEV 105~--FT~) JOB NO 3811 RECORD OF SURVEY ALL CALCULATIONS PERFORMED BY I 6 M ELECTRONIC COMPUTER TRUE MEAS, DRIFT VERTICAL DEPTH ANGLE DEPTH D M SUB DRIFT SEA DIREC DEG, 0 0 0 100 0 45 99,99 200 0 40 199.98 300 0 45 299,98 400 0 19 399,97 500 0 10 499,97 600 0 45 599,97 700 0 55 699.96 800 0 49 799,95 900 0 45 899,94 1000 2 4 999.90 0,00 -105,00 N O,OOE -5,00 S56.53E 94,98 S23.53E 194,98 S13,55E 294,97 S 3,55E 394.97 S13.43W 494.97 S68.40E 594.96 S28.58E 694,95 S31,58E 794,94 S 1,58E 894.90 N38,57W 1100 5 10 1099,69 994,69 N33,55W 1200 7 15 1199.10 1094,10 N30,O2W 1300 12 0 1297,66 1192,66 N18,12W 1400 13 45 1395,14 1290,14 N22,00W 1500 16 45 1491,61 1386,61 N25,35W 1600 20 30 1586.36 1481.36 N21,45W 1700 24 45 1678,64 1573.64 N22,70W 1800 28 15 1768,12 1663,12 N18,87W 1900 31 0 1855.04 1750,04 N16,17W 2000 32 45 1939,96 1834,96 N21,68W 2100 32 15 2024,30 1919,30 N20,52W 2200 32 0 2108.99 2003,99 N20.63W 2300 32 30 2193.56 2088.56 N18.80W 2400 33 0 2277,66 2172,66 N18.77W TOTAL COORDINATES 0.00 S 0,00 W 0.25 N 0.47 E 0-68 S 1.25 E 1.85 S 1,65 E 2.78 S 1.79 E 3.21 S 1.75 E 3.87 S 2,09 E 4.81 S 3,16 E 6,14 S 3,92 E 7,44 S 4.31 E 8.09 S 2,55 E 2.98 S 1.16 W 6.21 N 6.86 W 21.44 N 13,66 W 42,37 N 21.30 W 66,45 N 31,86 W 95.75 N 44.54 W 131,39 N 59,00 W 173.09 N 7z+,82 W 220.22 N 89.70 W 270,15 N 106.82 W 320.28 N 126,16 W 370.06 N 144.85 W 420,30 N 162,85 W 471.51 N 180.27 W CLOSURES DISTANCE ANGLE .~ D M S 0,00 S 0 0 0 W 0,53 N 61 44 6 E 1.43 S 61 30 27 E 2,48 S 41 39 14 E . 3,31 S 32 43 31 E 3,66 S 28 34 13 E ~.4.40 S 28 23 19 E 5.76 S 33 16 23 E 7.28 S 32 36 17 E 8,60 S :30 5 58 E 8,48 S 17 31 15 E 3.20 S 21 20 50 W 9,25 N ~+7 51 ].0 W 25,42 N 32 30 36 W 47,42 N 26 41 52 W 73,70 N 25 37 11 W 105,60 N 24 56 56 W 144,03 N 24 10 54 w 188,57 N 23 22 43 w 237,79 N 22 9 47 W Z90.51 N 21 34 30 W 344.23 N 21 30 3 w 397.40 N 21 22 37 w 450,74 N 21 10 49 W 504,80 N 20 55 25 W DOG LEG SEVENITY DEG/IOOFT 0,000 0,750 0,080 0,080 0,420 0,160 0.580 0.170 0.090 0,080 1.34~ 3,090 2,081 4,778 1.764 3.013 3.780 4,256 3.604 2,842 2,380 0,599 0.252 0,727 0,500 SECTIO~N DIbTANCE O,OO 0,19 -0.83 -2.05 -2.99 -3,41 -4,10 -5.18 -6.59 -7,93 -8,35 7,C 23.01 44,74 69,9~ 100.66 137.85 181,23 229.B8 Z81,59 J33.77 385.54 437.66 490.68 ARCO KUPARUK E-8 GYROSCOPIC SURVEY JOB NO 3811 RECORD OF SURVEY ALL CALCULATIONS PERFORMED BY I B M ELECTRONIC COMPUTER 12 NOV 80 MEAS. DRIFT DEPTH ANGLE D "4 2500 32 45 2600 33 0 2700 33 30 2800 33 15 2900 32 45 3000 33 0 3100 33 0 3200 32 45 3300 32 45 3400 33 15 3500 35 15 3600 34 45 3700 33 30 3800 33 15 3900 33 15 4000 33 15 4100 33 45 4200 33 10 4300 32 15 4400 32 15 4500 31 15 4600 31 15 4700 31 30 4800 31 30 4900 32 0 5000 31 30 5100 31 0 5200 30 3O 5300 30 10 TRUE VERTICAL SUB DEPTH SEA 2361,65 2256,65 2445.63 2340,63 2529,26 2424.26 2612.77 2507.77 2696.64 2591,64 2780,62 2675.62 2864.49 2759.49 2948,47 2843.47 3032.58 2927.58 3116,45 3011.45 3199.10 3094.10 3281.02 3176.02 3363.80 3258.80 3447.30 3342,30 3530.93 3425,93 3614.56 3509.56 3697.95 3592.95 3781.38 3676.38 3865.52 3760.52 3950.09 3845.09 4035.12 3930.12 4120,61 4015.61 4205,99 4100.99 4291,26 4186.26 4376.29 4271.29 4461,33 4356.33 4546.82 4441.82 4632,76 4527.76 4719.07 4614.07 DRIFT DIREC DEG, TOTAL COORDINATES N20.GTW 522,61N 198.59 N19.78W 573.54 N 217.35 N19,28W 625,21 N 235,68 N18,97W 677.19 N 253,71 N17,38W 728,93 N 270,69 N16.85W 780,81 N 286.67 N16,92W 832,93 N 302,49 N15.28W 885,08 N 317,54 N14.48W 937,36 N 331,43 N15.33W 989,99 N 345,44 N12,48W 1044.61N 358.96 N13.92W 1100,45 N 372,06 N12.93W 1155,02 N 385,08 Nll.38W 1208.80 N 396.67 Nll.33W 1262.55 N 407,46 Nll,60W 1316,29 N 418.36 NIO.3?W 1370,47 N 428,88 NlO,53W 1424,69 N 438,88 NlO.78W 1477,80 N 448.87 Nll,32W 1530,17 N 459.10 NlO.38W 1581.85 N 469.00 N 9,58W 1632,94 N 477,99 N 9,72W 1684.27 N 486,72 N. 8.97W 1735,82 N 495,20 N 7,30W 1787,91 N 502,65 N 7,47W 1840,10 N 509.41 N 7.18W 1891.55 N 516.03 N 7.72W 1942.25 N 522.66 N 6.03W 1992,39 N 528,70 W W W W W W W W W W W W W W W W W W W W W W W W W W W W W CLOSURES DISTANCE ANGLE D M 559.07 N 20 48 24 W 613.34 N 20 45 19 w 668.i6 N 20 39 17 W 723,16 N 20 32 18 W 777,57 N 20 22 z2 W 831,77 N 20 9 37 W 886,15 N 19 57 33 W 940.32 N 19 44 11 W 994.23 N 19 2~ 21 W 1048.53 N 19 14 8 W li04,57 N 18 57 52 W 1161.65 N 18 40 49 W 1217.52 N 18 26 18 W 1272.22 N 18 10 2 W 1326.67 N 17 53 11 W 1381,17 N 17 37 55 W 1436.01N 17 22 38 W 1490,76 N 17 7 18 W 1544.46 N 16 53 45 W 1597,56 N 16 42 3 W '1649.91 N 16 30 52 W 1701.46 N 16 18 57 W 1753.18 N 16 7 6 W 1805.08 N 15 55 21 W 1857,23 N 15 42 10 W 1909,31 N 15 28 27 W 1960,68 N 15 15 34 W 2011,34 N 15 3 41W 2061,34 N 14 51 42 W DOG LEG SEVERITY DEG/IOOFT 0.610 0,364 0.b23 0.267 0.683 0.295 0.038 0.541 0,433 0,562 2,Z14 0,685 1,28~ 0.529 0,027 0,148 0,628 0,582 0,923 0,288 1,032 0,415 0.253 0.392 0,686 0,502 0.506 0.519 0.940 SECTION DISTANCL b96.61 650.20 704.06 757.55 811.04 864,75 918.40 97Z.03 1081.92 1138,97 1194,76 1249.57 1~04.27 1358,95 1414.'~ 1469.o~ 1523.04 1576,29 1628.81 1680,63 1732.65 1784.87 1837,4~ 1890.10 1941.98 199J.ll 2043.61 ARCO KUPARlJK E-8 GYROSCOPIC SURVEY JOB NO 3811 12 NOV 80 RECORD OF SURVEY ALL CALCULATIONS PERFORMED BY I B M ELECTRONIC COMPUTER MEAS, [)RIFT DEPTH ANGLE D M 5400 29 30 55OO 30 0 5600 3O 45 5?00 32 0 5800 32 45 5900 32 6000 32 !5 6100 31 0 6200 31 '15 6300 31 15 6400 32 0 6500 34 0 6600 36 0 6700 38 30 6800 41 0 6900 39 45 700O 39 15 7100 41 0 7200 42 15 7300 45 0 7400 46 30 7450 46 45 THE FOLLOW 7590 46 4 BOTTOM HOL TRUE VERTICAL SUB DEPTH SEA DRIFT DIREC DEG. TOTAL COORDINATES CLOSURES DISTANCE ANGLE D M 4805,81 4700,81 N 5,22W 4892.63 4787,63 N 3.48W 4978,90 4873,90 N 3,50W 5064.28 4959,28 N 3,90W 5148.74 5043,74 N 3,92W 5233,08 5128,08 N 2,25W 5317.65 5212.65 N 2,00W 5402.80 5297.80 N 1.60W 5488.40 5383.40 N 0,35W 5573,89 5468.89 N 0;65~ 5659.04 5554.04 N 1,30E 5742,90 5637,90 N 3,30E 5824,81 5719.81 N 4.78E 5904.41 5799,41 N 6,875 5981,29 5876.29 N 8,38E 6057,47 5952,47 Nll,17E 6134.63 6029,63 N 3.93E 6211.09 6106,09 Nll.43E 6285,84 6180,P4 Nll.60E 6358,22 6253,22 N12.95E 6428.00 6323.00 N14.65E 6462.34 6357.34 N12.98E 2041-90 N 533,58 W 2091,37 N 537,34 W 2141,85 N 540,42 W 2193,80 N 543,78 W 2247.22 N 547,43 W 2300,87 N 550,32 W 2354,20 N 552,30 W 2406.60 N 553.95 W 2458,29 N 554,83 W 2510,16 N 554,69 W 2562,59 N 553,80 W 2617.01 N 551.62 W 2674,22 N 547,57 W 2734,42 N · 541,43 W 2797.80 N 532,95 W 2861.63 N 2924,64 N 2988,46 N 3053,55 hi 3120.96 N 3190.51N 3225.80 M ING INFORMATION IS EXTRAPOLATED TO TD 5 6558.26 6453.26 N12.98E 3325.17 N E CLOSURE 3352,65 FEET AT N 7 20 28 W 2110,46 N 14 38 2159,30 N 14 24 2208.97~N 14 9 2260,19 N 13 55 2312,94 N 13 41 2365,77 N 13 27 2418,11N 13 12 2469,54 N 12 57 2520,12 N 12 43 2570.72 N 12 27 2621.75 N 12 ll 2674,51 N 11 54 2729,70 N 11 34 2787,51 N 11 12 2848~rlO-JN 10 47 521,95 W 2908,84 N 10 20 513.60 ~'/ 2969,40 N 9 57 504,99~ 3030,83 N 9 35 491,73/W 3092,89 N 9 8 477,07 W 3157,21N 8 41 459,9~ W 3223,50 N 8 12 451.~'0 W 3257.22 N 7 57 428,40 W 33.52,65 N 7 20 DOG LEG SEVER I TY DEG/IOOFT 41W 0,698 34 W 0,663 40 W 0,750 17 W 1,255 27 W 0.750 5 W 0.690 11 W 0,133 45 W 1.254 6 W 0,419 39 W 0,519 40 W 0,772 9 W 2,095 19 W 2,064 0 W 2,628 6 W 2,583 13 W 1.692 37 W 2,941 28 W 3.672 53 W 1.252 27 W 2.832 14 W 1,746 51W 1.841 SECTION DISTANCE 2093, 2142.89 2193,34 2Z45.30 2298.75 2362,33 2405.47 2457,66 2560,46 2612,35 2666e04 2722,26 ~781,19 2842,96 2904,86 2966,~ 3028.4~ 3091.35 3156,33 3223.14 3257.03 28 W 0.000 3352,65 ARCO KUPARUK E-8 GYROSCOPIC SURVEY JOB NO 3811 INTERPOLATED TRUE VERTICAL DEPTHS, COORDINATES AND CLOSURES FOR GIVEN DEPTHS TRUE CODE MEASURED VERTICAL NAME DEPTH DEPTH TOTAL COORDINATES CLOSURE DISTANCE ANGLE D M S NOV 80 SUB SEA T KUPARUK '7011 6143.14 B UP SA~;9 7104 6214.11 T LOW SAND 7265 '6333.26 B LOW SAND 7355 6396.83 B KUPARUK 7414 6437.63 PLUG BACK 74,~5 6486.32 TD 7590 655~,,26 2931,60 N 2991,04 N 3097.13 N 3159,19 N 3200,38 N 3250,74 N 3325,17 N 513,18 W 504,49 W 483.01W 468.56 W 457.57 W 446,00 W 428.40 W 2976,18 N 9 55 45 W 6038.14 3033.29 N 9 34 26 W 6109,11 3134,57 N 8 51 50 W 6228,26 3193.75 N 8 26 11W 6291.83 3232.93 N 8 8 12 W 6332.63 3281.19 N 7 48 44 W 6381.32 3352~.65 N 7 20 28 W 6453.26 ARCO KUPARUK E-B I¢,EASURED DEPTH AND OTHER DATA GYROSCOPIC SURVEY FOR EVERY EVEN 100 JOB NO 3811 FEET OF SUB SEA DEPTH, 12 NOV MEASUR ED DFPTH TRUE VERTICAL DEPTH SUB MD-TVD VERTICAL SEA DIFFERENCE CORRECTION TOTAL COORDINATES 205 5O5 405 505 6O5 705 ~05 9O5 1005 1105 1206 1307 1410 1514 1620 1729 1842 1959 2077 2195 2313 2432 2551 2671 2791 2glO 3029 3148 3267 3386 :~507 3629 3749 205. 305. · 405. 505. 605. 705. 805. 905. oo5. 1105. 1205. 1305. 1405. 1505, 1605. 1705, 1805. 1905. 20O5. 2105. 2205. 2305. 2405. 2505. 2605. 2705. 2805. 2905. 3005. 3105. 3205. 3305. 3405. 3505, 3605, 100 0 200 0 300 0 4OO 0 500 0 600 0 700 0 800 0 9C0 0 1000 0 1100 0 1200 2 1300 5 1400 8 1500 14 1600 24 1700 37 1800 53 1900 72 2OOO 9O 2100 108 2200 127 2300 146 2400 165 2500 186 2600 204 2700 224 2800 243 2900 262 3000 281 3100 302 3200 324 3300 344 3400 364 3500 383 0 0 0 0 0 0 0 0 0 0 0 2 3 6 10 13 16 19 18 18 19 19 19 21 18 20 19 19 19 21 22 20 20 19 0.73 S 1.91 S 2.81 S 3.23 S 3,89 S 4,88 S 6,20 S 7.51 S 7,94 S 2,60 S 6.87 N 22,83 N 44.59 N 70.17 N 102 .,41 N 142.91 N 192.40 N 249.44 N 308.94 N 367,76 N 426,94 N 488,04 N 548,62 N 610.24 N 672,53 N 734.08 N 795.99 N 858. O5 N 920,14 N 982.68 N 1048,56 N 1116,56 N 1181,45 N 1245,92 N 1309,92 N 1.27 E 1,66 E 1,79 E 1,75 E 2,15 E 3,20 E 3,96 E 4.31 E 2.43 E 1,41 W 7.24 W 14,12 W 22.21W 33,58 W 47,11 W 63,51 W 80,94 W 98,90 W 121.41 W 143,45 W 165,01 W 185,75 W 207,92 W 229,99 W 251,56 W 272.26 W 291,02 W 309,58 W 326,71 W 343,09 W 359.80 W 375,74 W 390.58 w 403,88 W 416,67 W ARCO KUPARUK E-8 , V, EASURED DEPTH AND OTHER t'IEASURFD I) ,,'"' P TH TRUE VERTICAL D£PT~t GYROSCOPIC DATA FOR EVERY SUB MD-TVD SFA DIFFERENCE SURVEY EVEN lO0 JOB NO 3811 FEET OF SUB SEA VERT I CAL CORRECTION TOTAL DEPTH, COORDINATES 12 NOV .80 4228 4347 4465 45B2 4699 4B16 5051 5168 5284 539q 5514 5630 5748 5867 5985 6102 6219 6z, 5z, 6~75 6731 6831 6962 7092 7226 7367 7512 3705, 3600 403 3805. 3700 423 3905, · 3800 442 4005. 3900 460 4105, 4000 477 4205, 4]00 493 4305. 4200 511 4405. 4300 529 4505. 4400 546 4605, 4500 563 4705, 4600 579 4805, 4700 594 4905, 4800 609 5005. 4900 625 5105, 5000 643 5205. 5100 662 5305. 5200 680 5405, 5300 697 5505. 5400 714 5605. 5500 731 5705, 5600 749 5805, 5700 770 5905. 5800 795 6005, 5900 826 6105, 6000 857 6205, 6100 886 6305, 6200 921 6405, 6300 961 6505, 6400 1007 20 20 19 17 16 18 18 17 17 16 15 15 16 18 19 18 17 17 17 18 21 25 31 31 29 35 4O 46 1374,84 N 1439.72 N 1502.31N 1563.79 N 1623.65 N 1683,76 N 1744,11N 1805.66 N 1866,45 N 1926,01N 1984,28 N 2041,42 N 2098,38 N 2157,25 N 2219,33 N 2283,14 N 2346,20 N 2407,63 N 2468,14 N 2528,91N 2591,63 N 2659.69 N 2734.89 N 2817.83 N 2900.49 N 2983.40 N 3070.82 N 3167.58 N 3269,98 N 429,65 W 441.53 W 453.29 W 465.44 W 476,07 W 486,04 W 496,36 W 504.83 W 512.65 W 520.26 W 527,51 W 533,43 W 537.71 W 541.23 W 545.12 W 549,10 W 551.91 W 553.97 W 554.83 W 554.63 W 553,02 W 549.09 W 541,38 W 529,97 W 516.12 W 506.72 W 488.33 W 466,59 W 441,91 W ARCO KUPARUK E-8 GYROSCOPIC SURVEY JOB NO 3811 INTERPOLATED VALUES FOR EVEN 1000 TRUE MEASURED VERTICAL SUB DEPTH DEPTH SEA 1CO0 999, 894, 2000 1939, 1834, 3000 2780. 2675. 4000 3614, 3509, 5000 4461. 4356, 6000 5317, 5212. 7000 6134. 6029, FEET OF MEASURED DEPTH, TOTAL COORDINATES 8.07 S 270.28 N 780.98 N 1316.37 N 1840.14 N 2354.20 N 2924.71N 2.55 E 106.45 W 286.11 W 417.92 W 509.06 W 552.19 W 514.21 W 12 NOV 80 HORIZONTAL VIEW ARCO OIL & GAS KUPARUK E- 8 RADIUS OF CURVATURE GYROSCOPIC SCALE I" -- I000' NOV. 1:5~ 1980 TVD' = 6558' TMD = 7590~ o r~ 629' 16 15 21 22. ALL DEPTHS SHOWN ARE TVD ........ T II N~R I0 E~ U.M. 400. 800' 1200 SURFACE LOCATION IS 1013' NSL ~ 629' WEL~ SEC. 16 T II N~ R IOE~ U.M. VERTICAL SECTION ARCO OIL & GAS KUPARUK E -8 RADIUS OF CURVATURE GYROSCOPIC SCALE I"= I000~ NOV. 15~1980 2800~ - 3600 ~ ..... \ .... 4000~ 4400,~0~'~ . , 52005600~'~ _ . . _ _ . ,' '-' 8°°°~X,X~. · ' 84ooTVD : 6558' TMD = 7590' ALL DEPTHS SHOWN ARE TVD SCIENTIFIC DR ,ING CONTROLS 700 West Street GYROSCOPIC DIRECTIONAL SURVEY FOR ******************** * ARCO OIL & GAS * YOB NUMBER: 3811 )RILL NAME: Kuparuk E-8 ~OCATION: PRUDHOE BA~ ~URVEY ENGINEER: ANDY LOCHHEAD ~YRO REFERANCE READING: NOO-OOF ~THOD OF CALCULATION: R~DIUS OF CURVATURE '**DEPTH MEASURED IN FEET*** ~OMMENTS: THANKS · * THIS SURVEY IS CORRECT TO THE * * BEST OF MY KNOWLEDGE AND IS * * SUPPORTED BY ACTUAL FIELD DATA * . ******~** ****** . * COMPANY REPRESENTATIVE * *********************************** COHPLETION REPORT ARCO OIL & GAS GYROSCOPIC SURVEY RADIUS OF CURVATURE METHOD OF COMPUTATION COMPUTED FOR SDC BY FM LINDSEY & ASSOC 12 NOV 80 KUPARUK E-8 KB ELEV 105. FT. JOB NO 3811 RECORD OF SURVEY ALL CALCULATIONS PERFORMED BY I B M ELECTRONIC COMPUTER TRUE MEAS, DRIFT VERTICAL DEPTH ANGLE DEPTH D M SUB DRIFT SEA DIREC DEG. 0 0 0 100 0 45 99,99 200 0 40 199,98 300 0 45 299,98 4do o 19 399.97 500 0 10 499.97 600 0 45 599.97 700 0 55 699.96 800 0 49 799.95 900 0 45 899.94 1000 2 4 999.90 0,00 -105.00 N O,OOE -5.00 S56.53E 94.98 S23.53E 194,98 S13.55E 294.97 S 3,55E 394,97 S13.43W 494,97 S68.40E 594,96 S28,58E 694,95 S31.58E 794e94 S 1.58E 894.90 N38.57W 1100 5 10 1099.69 994.69 N33.55W 1200 7 15 1199.10 1094.10 N30.O2W 1300 12 0 1297.66 1192.66 N18.12W 1400 13 45 1395,14 1290.14 N22.00W 1500 16 45 1491.61 1386,61 N25,35W 1600 20 30 1586.36 1481.36 N21,45W 1700 24 45 1678,64 1573.64 N22,70W 1800 28 15 1768.12 1663.12 N18,87W 1900 31 0 1855.04 1750,04 N16,17W 2000 32 45 1939,96 1834,96 N21,68W 2100 32 15 2024.30 1919.30 N20e52W .2200 32 0 2108,99 2003,99 N20.63W 2300 32 30 2193,56 2088,56 N18,80W 2400 33 0 2277,66 2172.66 N18.77W TOTAL COORDINATES 0.00 S 0.00 W 0.25 N 0.47 E 0.68 S 1.25 E 1.85 S 1.65 E 2,78 S 1,79 E 3.21 S' 1,75 E 3.87 S 2.09 E 4.81 S 3.16 E 6.14 S 3.92 E 7,44 S 4,31 E 8.09 S 2.55 E 2.98 S 1.16 W 6.21 N 6.86 W 21,44 N 13,66 W 42,37 N 21,30 W 66,45 N 31.86 W 95.75 N 44.54 W 131.39 N 59.00 W 173,09 N 74.82 W 220,22 N 89.70 W 270,15 N 106,82 W 320.28 N 126.16 W 370~06 N 144.85 W 420~30 N 162,85 W 471,51 N 180.27 W CLOSURES DISTANCE ANGLE D M S 0,00 S 0 0 0 W 0.53 N 61 44 6 E 1,43 S 61 30 27 E 2.48 S 41 39 14 E 3,31 S 32 43 31 E 3,66 S 28 34 13 E 4.40 S 28 23 19 E 5.76 S 33 16 23 E .. 7,28 S 32 36 17 E 8.60 S 30 5 58 E 8.48 S 17 31 15 E 3.20 S 21 20 50 W 9,25 N 47 51 10 W 25,42 N 32 30 36 W 47.42 N 26 41 52 W 73.70 N 25 37 11 W 105,60 N 24 56 56 W 144,03 N 24 10 54 W 188,57 N 23 22 43 W 237,79 N 22 9 4.7 W 290,51 N 21 34 30 W 344.23 N 21 30 3 W 397,40 N 21 22 37 W 450.74 N 21 10 49 W 504.80 N 20 55 25 W DOG LEG SEVERITY DEG/iOOFT 0.000 0.750 0,080 0.080 0.420 0.160 0.580 0.170 0,090 0,080 1,343 3.090 2,081 4.778 1.764 3,013 3,780 4,256 3.604 2.842 2.380 0.599 0.252 0,727 0,500 SECTIO,, DISTANCE 0.00 0.19 -0.83 -2.05 -2.99 -3.41 -4.10 -5.18 -6.59 -7.93 -8.35 7.0~ 23.01 44.74 69.98 100,66 137.85 181.23 229.88 281.59 333.77 385.54 437.66 490,68 ARCO KUPARUK E-8 GYROSCOPIC SURVEY JOB NO 3811 RECORD OF SURVEY ALL CALCULATIONS PERFORMED BY I B M ELECTRONIC COMPUTER 12 NOV 80 TRUE MEAS. DRIFT VERTICAL SUB DRIFT DEPTH ANGLE DEPTH SEA DIREC D M i DEG · TOTAL COORDINATES 2500 32 45 2361.65 2255.65 N20.67W 2600 33 0 2445.63 2340.63 N19.78W 2700 33 30 2529.26 2424.26 N19.28W 2800 33 15 2612.77 2507.77 N18.97W 2900 32 45 2696.64 2591.64 N17.38W 3000 33 0 2780.62 2675.62 N16.85W 3100 33 0 2864.49 2759.49 N16.92W 3200 32 45 2948.47 2843.47 N15.28W 33q0 32 45 3032.58 2927.58 N14.48W 3400 33 15 3116.45 3011.45 N15.33W 522.61 N 573.54 N 625.21N 677.19 N 728.93 N 780.81 N 832.93 N 885,08 N 937.36 N 989,99 N 3500 35 15 3199,10 3094,10 N12,48W 1044.61N 3600 34 45 3281.02 3176.02 N13.92W 1100.45 N 3700 33 30 3363.80 3258.80 N12.93W 1155.02 N 3800 33 15 3447.30 3342,30 Nll,38W 1208,80 N 3900 33 15 3530.93 3425.93 Nll.33W 1262.55 N 4000 33 15 3614.56 3509.56 Nll.60W 1316.29 N 4100 33 45 3697.95 3592.95 NlO.37W 1370.47 N 4200 33 10 3781.38 3676.38 NlO.53W 1424.69 N 4300 32 15 3865.52 3760.52 NlO-78W 1477-80 N 4400 32 15 3950.09 3845.09 Nll-32W 1530.17 N 4500 31 15 4035.12 3930.12 NlO.38W 1581.85 N 4600 31 15 4120,61 4015,61 N 9,58W 1632,94 N 4700 31 30 4205,99 4100,99 N 9,72W 1684,27 N 4800 31 30 4291,26 4186,26 N 8.97W 1735,82 N 4900 32 0 4376.29 4271.29 N 7.30W 1787.91N 5000 31 30 4461.33 4356.33 N 7.47W 1840.10 N 5100 31 0 4546.82 4441.82 N 7.18W 1891.55 N .5200 30 30 4632.76 4527.76 N 7.72W 1942.25 N 5300 30 10 4719.07 4614.07 N 6.03W 1992,39 N 198.59 W 217.35 W 235.68 W 253.71W 270.69 W 286.67 W 302.49 W 317.54 W 331.43 W 345.44 W 358.96 W 372.06 W 385.08 W 396.67 W 407,46 W 418.36 W 428.88 W 438.88 W 448.87 W 459.10 W 469.00 W 477.99 W 486.72 W 495,20 W 502.65 W 509,41 W 516.03 W 522.66 W 528.70 W C L 0 S U R E S DISTANCE ANGLE D M $ 559.07 N 20 48 24 W 613.34 N 20 45 19 W 668.16 N 20 39 17 W 7~3.16 N 20 32 18 W ?~7.57 N 20 22 22 W 831.77 N 20 9 37 W 886.15 N 19 57 33 W 940.32 N 19 44 11 W 994.23 N 19 28 21 W 1048.53 N 19 14 8 W 1104.57 N 18 57 52 W 11(~1.65 N 18 40 49 W 1217.52 N 18 26 18 W 1272.22 N 18 10 2 W 1326.67 N 17 53 11 W 1381.17 N 17 37 55 W 1436.01 N 17 22 38 W 1490.76 N 17 7 18 W 1544.46 N 16 53 45 W 1597.56 N 16 42 3 W 1649.91 N 16 30 52 W 1701.46 N 16 18 57 W 1753.18 N 16 7 6 W 1805.08 N 15 55 21 W 1857.23 N 15 42 10 W 19.09.31 N 15 28 27 W 1960.68 N 15 15 34 W 2011.34 N 15 3 41 W 2061.34 N 14 51 42 W DOG LEG SEVERITY DEG/IOOFT 0.610 0.364 0.523 0.267 0.683 0.295 0.038 0.541 0,433 0.562 2.214 0.685 1.286 0.529 0.027 0.148 0.628 0.582 0.923 0.288 1.032 0.415 0.253 0.392 0.686 0,502 0.506 0.519 0,540 SECTION DISTANCE 543. 596.61 650.20 704.06 757.55 811.04 864.75 918.40 972.03 1026.01 1081.92 1138.97 1194.76 1249.57 1304.27 1358.95 1414.0~.~ 1469.0~ 1523.04 1576.29 1628.81 1680.63 1732.65 1784.87 1837.48 1890.10 1941.98 1993.11 2043.61 ARCO KUPARUK E-8 GYROSCOPIC SURVEY JOB NO 3811 RECORD OF SURVEY ALL CALCULATIONS PERFORMED BY I B M ELECTRONIC COMPUTER 12 NOV 80 TRUE MEAS, DRIFT VERTICAL DEPTH ANGLE DEPTH D ~ SUB DRIFT SEA DIREC DEG. TOTAL COORDINATES 5400 29 30 4805,81 4700,81 N 5.22W 2041.90 N 5500 30 0 4892,63 4787.63 N 3.48W 2091,37 N 5600 30 45 4978.90 4873.90 N 3,50W 2141.85 N 5700 32 0 5064,28 4959.28 N 3,90W 2193.80 N 5800 32 45 5148.74 5043,74 N 3,92W 2247.22 N 59~0 32 15 5233.08 5128,08 N 2.25W 2300,87 N 6000 32 15 5317.65 5212.65 N 2,00W 2354,20 N 6100 31 0 5402,80 5297,80 N 1.60W 2406,60 N 6200 31 15 5488.40 5383,40 N 0,35W 2458,29 N 6300 31 15 5573,89 5468.89 N 0.65E 2510.16 N 6400 32 0 5659.04 5554,04 N 1,305 2562,59 N 6500 34 0 5742,90 5637.90 N 3,30E 2617.01 N 6600 36 0 5824,81 5719.81 N 4,78E 2674.22 N 6700 38 30 5904,41 5799,41 N 6,87E 2734,42 N 6800 41 0 5981,29 5876.29 N 8,38E 2797,80 N 6900 39 45 6057,47 5952,47 Nll,17E 2861,63 N 7000 39 15 6134,63 6029,63 N 3.93E 2924.64 N 7100 41 0 6211,09 6106.09 Nll.43E 2988.46 N 7200 42 15 6285,84 6180,84 Nll.60E 3053.55 N 7300 45 0 6358,22 6253.22 N12.95E 3120,96 N 7400 46 30 6428,00 6323.00 N14.65E 3190,51N 7450 46 45 6462,34 6357.34 N12.98E 3225.80 N 533,58 W 537,34 W 540,42 W 543,78 W 547,43 W 550,32 W 552,30 W 553.95 W 554,83 W 554,69 W 553,80 W 551,6Z W 547,57 W 541,43 W 532.95 W 521,95 W 513,60 W 504,99 W 491,73 W 477-07 W 459,98 W 451,30 W THE FOLLOWING INFORMATION IS EXTRAPOLATED TO TD 7590 46 45 6558,26 6453.26 N12.98E 3325,17 N 428,40 W C L 0 S U R E S DISTANCE ANGLE D M S DOG LEG SEVERITY DEG/IOOFT 2110,46 N 14 38 41W 2159,30 N 14 24 34 w 2208.97 N 14 9 40 W 2260,19 N 13 55 17 W 2312,94 N 13 41 27 W 2365,77 N 13 27 5 W 2418,11N 13 12 11W 2469.54 N 12 57 45 W 2520.12 N 12 43 6 W 2570,72 N 12 27 39 W 2621,75 N 12 11 40 W 2674,51N 11 54 9 W 2729.70 N 11 34 19 W 2787,51N 11 12 0 W 2848,10 N 10 47 6 W 2908,84 N 10 20 13 W 2969.40 N 9 57 37 W 3030,83 N 9 35 28 W 3092,89 N 9 8 53 W 3157,21 N 8 41 27 W 3223,50 N 8 12 14 W 3257,22 N 7 57 51 W 0,698 0,663 0,750 1,255 0,75O 0.690 0.133 1,254 0.419 0.519 0,772 2,095 2.064 2.628 2,583 1.692 2,941 3,672 1.252 2,832 1,746 1.841 3j"52.65 N 7 20 28 W 0.000 SECTION DISTANCE 2093.A 2142.8w 2193,34 2245.30 2298.75 2352,33 2405.47 2457.66 2509.03 2660.46 2612.35 2666,04 2722.26 2781.19 2642,96 2904.86 2966,2~"~. 3028,4. 3091.35 3156.33 3223.14 3Z57,03 3352,65 BOTTOM HOLE CLOSURE 3352.65 FEET AT N 7 201~28, W ARCO KUPARUK E-8 GYROSCOPIC SURVEY JOB NO 3811 I~TERPOLATED TRUE VERTICAL DEPTHS, COORDINATES AND CLOSURES FOR GIVEN DEPTHS TRUE CODE MEASURED VERTICAL NAME DEPTH DEPTH TOTAL COORDINATES CLOSURE DISTANCE ANGLE D M S NOV 80 SUB SEA T KUPARUK 7011 6143,14 B UP SAND 7104 i 6214.11 T LOW SAND 7265 6333.26 B LOW SAND 7355 6396.83 B KUPARUK 7414 6437,63 PLUG BACK 7485 6486.32 TD 7590 6558.26 2931.60 N 2991.04 N 3097e13 N 3159.19 N 3200.38 N 3250.74 N 3325,17 N 513.18 W 504.49 w 483.01W 468.56 W 457.57 W 446.00 W 428.40 W 2976.18 N 9 55 45 W 6038.14 3033.29 N 9 34 26 W 6109.11 3134.57 N 8 51 50 W 6228.26 3193.75 N 8 26 11 W 6291.83 3232.93 N 8, 8 12 W 6332.63 3281.19 N 7 48 44 W 6381 3352.,,65 N 7 20 28 W 6453.26 ARCO KUPARUK E-8 MEASURED DEPTH AND 'OTHER DATA GYROSCOPIC SURVEY FOR EVERY EVEN 100 JOB NO 3811 FEET OF SUB SEA DEPTH, 12 NOV 8O TRUE MEASURED VERT I CAL DEPTH DEPTH SUB HD-TVD VERTICAL SEA DIFFERENCE CORRECTION TOTAL COORDINATES 205 205. 305 305. 405 405. 505 505. 605 605. 705 705. 805 805, 905 905, 1005 1005. 1105 1105, 1206 1205. 1307 1305. 1410 1405. 1514 1505. 1620 1605. 1729 1705. 1842 1805. 1959 1905. 2077 2005. 2195 2105. 2313 2205. 2432 2305. 2551 2405. 2671 2505. 2791 2605. 2910 2705. 3029 2805. 3148 2905. 3267 3005. 3386 3105. 3507 3205. 3629 3305, 3749 3405, 3869 3505, 3988 3605. 100 0 200 0 3OO 0 40O 0 500 0 60O 0 700 0 80O 0 900 0 1000 0 1100 0 1200 2 1300 5 1400 8 1500 14 1600 24 1700 37 1800 53 1900 72 2000 90 2100 108 2200 127 2300 146 2400 165 2500 186 2600 204 2700 224 2800 243 2900 262 3000 281 3100 302 3200 324 3300 344 3400 364 3500 383 0.73 S 1,91 S 2.81 S 3.23 S 3.89 S 4.88 S 6,20 S 7.51 S 7.94 S 2.60 S 6.87 N 22.83 N 44.59 N 70.17 N 102.41 N 142.91 N 192,40 N 249.44 N 308.94 N 367.76 N 426.94 N 488.04 N 548,62 N 610,24 N 672,53 N 734.08 N 795 · 99 N 858.05 N 920 :*14 N 982,68 N 1048.56 N 1116.56 N 1181.45 N 1245.92 N 1309.92 N 1.27 E 1.66 E 1,79 E 1.75 E 2.15 E 3.20 E 3.96 E 4.31 E 2.43 E 1,41 W 7.24 W 14.12 W 22.21 W 33.58 W 47.11W 63.51 W 80.94 W 98.90 W 121.41 W 143.45 W 165,01 W 185.75 W 207.92 W 229.99 W 251.56 W 272.26 W 291.02 W 309.58 W 326,71 W 343.09 W 359.80 W 375,74 W 390.58 W 403.88 W 416.67 W ARCO K GYROSCOPIC SURVEY JOB NO 3811 MEASURED DEPTH AND OTHER DATA FOR EVERY EVEN 100 FEET OF SUB SEA DEPTH. · TRUE MEASURED VERTICAL SUB MD-TVD VERTICAL DEPTH DEPTH SEA DIFFERENCE CORRECTION TOTAL COORDINATES 12 NOV 80 4108 3705. 3600 403 20 4228 3805. 3700 423 20 4347 39J05, · 3800 442 19 4465 4005, 3900 460 18 4582 4105. 4000 477 17 4699 4205, 4100 493 16 4816 4305, 4200 511 18 4934 4405, 4300 529 18 5051 4505. 4400 546 17 5168 4605. 4500 563 17 5284 4705. 4600 579 16 5399 4805, 4700 594 15 5514 4905, 4800 609 15 5630 5005, 4900 625 16 5748 5105. 5000 643 18 5867 ~ 5205. 5100 662 19 5985 5305. 5200 680 18 6102 5405. 5300 697 17 6219 5505. 5400 714 17 6336 5605. 5500 731 17 6454 5705, 5600 749 18 6575 5805, 5700 770 21 6701 5905. 5800 795 25 6831 6005. 5900 826 31 6962 6105. 6000 857 31 7092 6205. 6100 886 29 7226 6305. 6200 921 35 7367 6405, 6300 961 40 7512 6505, 6400 1007 46 1374.84 N 1439.72 N 1502.31N 1563.79 N 1623.65 N 1683.76 N 1744.11N 1805,~6 N 18666~5 N 1926.01N 1984.28 N 2041.42 N 2098.38 N 2157.25 N 2219.33 N 2283.~4 N 2346.20 N 2407.63 N 2468.14 N 2528.91N 2591.63 N 2659,69 N 2734.89 N 2817.83 N 2900.49 N 2983.40 N 3070.82 N 3167.58 N 3269,98 N 429,65 W 441,53 W 453.29 W 465.44 W 476.07 W 486,04 W 496,36 W 504,83 W 512.65 W 520.26 W 527.51 W 533,43 W 537,71 W 541.23 W 545.12 W 549,10 W 551,91 W 553.97 W 554,83 W 554,63 W 553.02 W 549,09 W 541,38 W 529,97 W 516.12 W 506.72 W 488.33 W 466.59 W 441.91 W ARCO KUPARUK E-8 · GYROSCOPIC SURVEY JOB NO 3811 INTERPOLATED VALUES FOR EVEN 1000 FEET OF MEASURED DEPTH, TRUE MEASURED VERTICAL SUB DEPTH DEPTH SEA TOTAL COORDINATES 1000 999, 2000 1939. 3000 2780, 4000 3614, 5000 4461, 6000 5317, 7000 6134, 894. 8,07 S 2.55 E 1834. 270.28 N 106.45 W 2675. 780.98 N 286.11W 3509, 1316,37 N 417,92 W 4356. 1840.14 N 509,06 W 5212, 2354,20 N 552.19 W 6029, 2924.71N 514.21W 12 NOV 80 HORIZONTAL VIEW ARCO OIL & GAS KUPARUK E-8 RADIUS OF CURVATURE GYROSCOPIC SCALE ' I "- '~ -1000' NOV. I$, 1980 -TVD = 6558~ -- TMD = 7590' r" o ill ALL DEPTHS SHOWN ARE TVD ~' ........ 629' 16 15 21 22 - - T II N,R I0 E, U_.M. 400- --_ 800. 1200 - SURFACE _LOCATION IS_._ 1013,' NSL , 629' WEL, SEC. 16 T II N, R IOE, U.M. I . VERTICAL SECTION ARCO OIL 8~ GAS _ KUPARUK E - 8 RADIUS OF CURVATURE GYROSCOPIC SCALE I" = I000' --; NOV. ]3, 1980 ALL DEPTHS SHOWN ':-ARE-TVD -* ' .... ( SUB-SURFACE DIREC TiONA SURVEY Arco Oil & Gas COMPANY Pad E, Well No: 8 WELL NAME Kuparuk Field, North Slope, Alaska LOCATION JOB NUMBER A10800051 TYPE OF SURVEY Directional Single Shot DATE zo/~6/so SURVEY BY Don LeJeune OFFICE Alaska Eastman Wh ip? o f P. O. Box 4-1970/Anchorage, Alaska 99509/(907) 349-4617 TWX 910-881-5066/Cable: EASTCO November 5, 1980 Arco 0il & Gas P.0. Box 1479 Anchorage, Alaska 99510 Well Number: Pad E, Well No: 8 Location: Kuparuk Field, North Slope, Alaska Type of Survey: Directional Single Shot Date: . October 16, 1980 Method of Computation: Radius of Curvature Surveyor: Don LeJeune Job Number: AlO80D0051 ATTN: ~ Bob Hines Dear Mr. Hines, I am enclosing the original and one copy of the Directional Single Shot Survey run on the above men- tioned well. We wish to take this opportunity to thank you for calling on our services and trust that we may continue to serve you in the future. Sincerely, Jim Turnage District Operations Manager Alaska District cc: file eno. JT/cfw D,rect~onal Dnllers/Sub-Surface Surveyors/Instrument & Tool Rentals/Sales/Worldwide ARCO OIL AND GAS ............... F'AD E, WEI. L NO: 8 bINS/DSS JOB NO: A1080D0051 KUF'ARUK F1ELD, NORTH SI. OF'E., AI. ASKA "MM.S, 0-2?20 f~D, SURVEYOR; A HICKMAN, DATE RUN; 16-0CT-80 ....... ~0 DEG A/U NO: 368A, 454A, CA~ERA NO; 17~, 1213 HHS JOB NO: A1080S0055 '~oo ,1 DRILLER: D LEJEUNE ..... I.~.,, ~102-7 ~0 ~D, · VERTICAL SECTION CALCULAT D IN F'L. ANE~ OF FROFOoA~ DIRECTION; N 13 DEG. RECORD OF SURVEY RADIUS OF CURVATURE METHOD ~RCO 0II. A~ GAS . · "AD E, WELL NO: 8 MMS/DSS - x. UF'ARUK FIELD, NORTH SLOPE, ALASKA · ......... TRUE ~r COHF'UTA.T I ON · dOB NO: - AlO80DO051 ............... TIME [mATE - - - 14:35:08 24-0CT-80 NO. I 41£ASURED DRIFT DRIFT COURSE VERTICAL VERTICAL SUBSEA R E C T A N O U L A R C L 0 S U R E DOGLEG DEPTH ANGLE DIRECTION LENGTH DLPTH SECTION TVO C 0 0 R D I N A T E S DISTANCE D£RECTION SEVERIT FEET D Fi D FEET FEET FEEl' FEET FEET FEET D f4 [;G/100F O, 0 0 0 O, 0.00 0.00 -105.00 0,00 0.00 0.00 0 0 0.00 172, 0 ~0 S 17 E 172, 172.00 - -0,75 67,00 0,72 S 0.22 E 0,75 S 17 0 E 0.29 265. 0 ~0 S 15 E 93. 264.~9 -1.56 159,99 1,50 S 0.44 E 1.56 S 16 29 E 0.02 ~57. 0 0 0 92. 356.99 -1.9~ 251.99 1,89 S 0.55 E 1,96 S 16 11 E 0.54 449, 0 ]5 S $ E 92. 448,99 -2,16- 343,99 2,09 S 0,56 E 2,16 S 14 58 E 0.27 542. 0 0 0 9~. 541.~9 -2,~6 4~6,99 2.29 S 0,57 E 2,36 S 13 57 E s z7 6~4, 0 30 S 56 E 92, 6~3,99 -2.65 528,99 2,51S 0,90 E 2,67 S 19 44 E 0,54 726, 0 ~0 S 18 W 92, 725.99 -3.40 620,99 3,22 S 1.14 E 3,42 S 19 34 E 0.65 819. 0 ]5 N 71W 93. 818.99 -3.52 713.99 3.46 S O.6b E 3.52 S 10 42 E 0.61 911, 0 0 0 92, 910,99 ~- -3,41 ~ 805,99 3,40 S 0,47 E 3,43 S 7 48 E 0,27 1003. I 30 N 39 W 1096, 4 15 N 34 W 1188, 6 ~0 N 31 W 1280. 10 30 N 19 W J373, 12 15 N 15 W 1465, 15 30 N 22 W 1557. 17 45 N 2~ W 1650. 21 0 N 21W 1742. 24 $0 N 21 W ..... ~::~'~ -2 2:3 897,98 92, ~1002,98.~_ ' /1 ~ ' '1.957'!.5'90.85 92, ~ 1187.44 10,08 10'82,44 92, 1278.41 2~.37 1173,41~-~'~./ 20.85 N 9~,.:~1~69.58~;~ 41,66~~ 1264,58 ?~. 38'39 N 92. 1458.88 6~.61 1353.88 59.29 N ~2~ . 1547.0~ ~- 8~.59 1442.0~~ 8~.61 N 93, 16~4.75 120.07 1529,75 112,21 N 92, 1719,58 155, ~1 1614.58 145.42 N 2,46 S 0,29 W ).l,2?~.~N_.t~ .. 3,07 W 8,55 N ~ 7,70 W 13.43 W '; 18,79 W 25,79 W 35.86 W 47.41W 60.16 W 2,48 S 6 46 W 3.32 N 67 15 W 11,50 N 41 59 W 24,80 N 32 47 W 42,74 N 26 5 W 64,66 N 23 30 W 90,98 N 23 13 W 121,82 N 22 54 W 157,37 N 22 29 W 1834. 28 0 N 18 W .... 92. 1802,08 ....... 195,74 -1697,08 ..... 183,77 N .... 73,74 W ...... 198,01 N 21 52 W 1.63 2,97 2.46 4,73 2.06 3.97 2.47 3.57 3.80 1927. 30 15 N 15 W 2019. 32 15 N 19 W 2]11. 31 45 N 19 W 2204. 31 15 N 20 W 2296. 31 45 N 17 W 93, 1883,32 240,92 1778,32 227,16 N 92, 1961,97--~ 288,53 1856,97 ~ 272,79 N 92. 2039,99 337,03 1934,99 318,89 N 93, 2119.28 385.33 2014,28 364.69 N 92. 2197,72- 433.19 ~2092,72 410,27 N 86,60 W 100,55 W 116,42 W 132,64 W 147,89 W 243,11 N 20 52 W 290,73 N 20 14 W 339,47 N 20 3 W 388,06 N 19 59 W 436,11 N 19 49 W 2,88 3,13 0.54 0,78 1,79 2388. 32 0 N 18 W 2481. 32 0 N 18 W 2573. 32 0 N 19 W '266~, 32 1~ N 18 W 2758. 32 30 N 18 W 92, 2275,85 481,63 2170,85 456,60 N 162,50 W 484,66 N 19 35 W 9.~. 2354,72 ---'530.74 .... 2249.72'-- 503.4;~ N~- 177,73-W -- 533,92---N 19 27 W 92. 2432.74 5;79.28 2327.74 549 7( N 193.20 W 582.67 N 19 22 W ~'i~''' ~ 92, ~10,6~ 627,99 2405,65 596 10 N 208,72 W 631,58 N 19 18 W 93 2589,20 677,61 2484,20 643.46 N" o-~ 11 W 681,37 N 19 12 W 0,64 0,00 0,58 0,64 0.27 ~RCO OIL AN~- GAS · . "AD E, WFLL NO.' 8 NHS/DSS ,,IJF'ARIJK FIEI. I), NORT~I SLOF'E, ALASKA TRUE ,J,;~, COMPUTATI,ON - F',:,~, E ND. 2 JOB NO: AlO80DO051 TIME [lATE ' 14; 55:08 24-0CT-80 IF. ASURED BRIFT DRIFT COURSE VERTICAL VERTICAL SUBSEA R E C T A N G U L A R C L 0 S U R E DOGLEG · DEF'TH ANGLE DIRECTION LENGTH [E. FTH SECI'ION TV[; C 0 0 R D I N A T E S DISTANCE DIRECTION SEVE~RIT FEF..3' . D. _H D FEET FEET , FEET ....... FEET FEET FEET D M [~G/100F 2850. 32 15 N 17 W 92. 2666.90 726.74 2561.~0 690.44 N 238.92 W 730.61 N 19 5 W 0.64 -. ~.850 MD IS TIE-IN F'OINT FOR E/W DSS FROH PREVIOUS E/W HMS 3]02. 31 45 N 15 W 331~. 31 30 N 16 W 3633. 34 0 N 12 W 3942. 32 45 N 11 W 252. 2880.61 860.10 2775.61 818.80 N 275.7~ W 865.98 N 18 57 W 217. 3065.38 973.80 2V60o38 -~928.45 N 306.14 W 9/7.61 N 18 15 W 314. 3329,45 114~.60 ~224.45 1093.22 N 347.22 W 1147,04 N 17 ~7 W 309. 3587.48 1513.51 3482.48 1259o79 N' -$81.11~W 1316,17 N 16 50 W 0.47 0.44 4255. S1 45 N 10 W 4567. SO 50 N 10 W 4815. 31 0 N 9 W 5125. JO 0 N 8 W 54~6. 29 0 N 6 W 5651. 30 15 N 5 W 5962. J] 15 N 4 W 6272. 30 15 N 1 W 6495. 32 15 N 1 E 6744. 38 0 N 5 E 515. J852.19 1480.J4 J747.19 1424.01 N 411.54 W 1482.28 N 16 7 W 512. 4119.27 1641.36 ~ 4014.27 1582o83 N 4S9.55 W 1642.73 N 15 51 W 246. 43J0.69 ~.,1766.88 4225.69 1706.88 N 460.51 W 1767.86 N 15 6 W 512. 4~''~99.51 1924.76 4494.51 1865.J9 N 484.40 W 1925.~2 N 14 54 W Jll. ,4870.19 -,2077.07,~f 4765,,19j;~ 2015.~0 N ' 50~.72 W 2077.50 N 14 2 W "~ 215, 5057.08 2182.3~ 4~52.08" 212~.08 N 513.~1 W 2182.45 N 1S 37 W 310 ~0 76 24~5.~1 5485.76 24~7.~3 N 5~ 30 W 2495 58 N 12 20 W 2~ ~:1 · ~J. ~781 ,10 2607.94 5676.40 255J.61 N 555.50 W 2608.70 N 11 48 W 2~9. 59'84.97 2745.26 5879.97 2~6.55 N 525.18 W 2/47.21 N 11 I W 0.56 0.40 0.29 0.51 0.63 0.36 0.59 1.01 2.53 6972. 38 ].5 N 10 E 7490. 46' 0 N 13 E 228. 6164.33 2876.70 6059.33 2835.99 N 506.20 W 2880.81 N 10 7 W 518. 6548.23-~3191.47 ~6443.23~'' 3175.85 N ~ 435.51 W 3205.57 N 7 49 W 1.22 FINAL CLOSURE - DIRECTION~ DISTANCE; N 7 [lEGS 48 MINS 30~SECS W 3205.57 FEET · ' ( i i ~ ~ ~ , il i j ! i , L i i i . , i , ~ ~ . ,~ ~ , , , , ~ ;-T-r--,' '--"'! ! _: ,J L '.' , : ' - ' '-.---.L-~I-,-----L-----,-~ ~ ~ -'-.-4--'- ~ ' ' ~ ' ~ ~ , , I ! :-I---* ~ I · t I ' , t i ,- i , , i ,'"'~ ~ , , ~ i , , , I . ~ , I t . . 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Operator, Well N~ and Number f Reports and Materials to be received by: Completion Re~ort Well History Samples Mud Log Core Chips Core Description Registered Survey Plat Inclination Survey Directional Survey Drill Stem Test Reports Production Test Reports Logs Run Digitized Log Data Required Yes Yes ,4/O /U~C- Yes Date Received Remarks NORTH SLOPE DISTRICT ENGINEERING TRANSMITTAL FROM' Jerry/ J. Pawelek/Leo Lash WELL NAME' ~U~.l~4. ~/~" Transmitted herewith are the following for the subject well' DATE ~ XEROX BHC Sonic/Gamma Ray Log Cement Bond Log/VDL Compensated Formation Density Log Compensated Neutron-Formation Density Compensated Neutron Log Core Analysis - Interval Core No. Core Description (SWC) - Interval Core Description (Conv.) - Core No. Directional Survey - Gyro Single Shot Multi-shot Drill Stem Test - Test No. Dual Induction Laterolog Formation Density Log Formation Density Log/Gamma Ray Spectralog TVD-DIL Differential Temperature Log Spinner Survey Fluid Density Casing Collar Log Perforating Record Neutron Lifetime Log Carbon-Oxygen Log j_._"J COMM COMM ! IRES NG ! SEOL -- t 3 GEOL -- __ i 3TAT TFC .__[ STAT TEC CONFER: FILF: BL SEPIA LINE FILM RECEIPT ACKNOWLEDGED FOR- PLDATE- EASE RETURN RECEIPT TO- RECEIVED ['EC- l i980 Alaska Oil & Gas Cons. Commission Anchorage ARCo Oil and Gas Company Attn: Mr. Leo Lash P.O. Box 360 - Rm. #311-FAB Anchorage, AK 99510 TRANSMITTAL ft A FROM: Jerry J. Pawelek/Leo Lash ~--- STATT~ Transm~¢¢ed herew~¢h are Che follow~ng for Che sub,ccC well- BL DATE SCALE XEROX SEPIA LINE FILM ID!;Z~ BHC Sonic/Gamma Ray Log ~;/5/~' t/~/ Cement Bond Log/VDL Io~ Compensated Formation Density Log ~'-~ .... Ioj;t_~ Compensated Neutron-Formation Density ~°' ..... Compensated Neutron Log _ Core Analysis - Interval Core No. Core Description (SWC) - Interval Core Description (Conv.)- Core No. Directional Survey - Gyro Single Shot Multi-shot Drill Stem Test - Test No. 1~/~5] Dual Induction Laterolog Formation Density Log Formation Density Log/Gamma Ray Spectral og TVD-DIL Differential Temperature Log Spinner Survey Fluid Density Casing Collar Log Perforating Record , _ , Neutron Lifetime Log Carbon-Qxygen Log ~ . RECEIPT ACKNOWLEDGED FOR' DATE- PLEASE RETURN RECEIPT TO' ARCo Oil and Gas Company Attn: Mr. Leo Lash P.O. Box 360 - Rm. #311-FAB Anchorage, AK 99510 ALASKA OIL AND GAS CONSERVATION COMMISSION · 1ton ~ Hoyle H Hami Chairman/Commissio Thru5 Lonnie C. Smith~ Commissioner ~ ~ Ben LeNorman ~ Petroleum Inspector October 20, 1980 BOPE test on Arcots Kuparuk E-8, Sec. 16, T11N, R10E, UM. Kuparuk River_Undefined. ThuFsda¥ October 16 - I departed my home at 2~00 pm for a 2=30 pm 'Showup and-$545 pm departure via Wien flight %5 for Deadhorse arriving via Fairbanks at 6~20 pm. Weather5 .20'F, high over- cast, wind 15 mph from the west. Friday October 17 - BOPE tests on Arco ms Kuparuk D-7 were completed at '754-5 am, the subject of a separate report· BOPE tests on Arco's Kuparuk E-8 began at 10515 pm . . . Saturday October 18- . . and were completed at 12=15 am. BO~"InsP'~:[°n 'Re~rt is attached. I departed Deadhorse via Wien flight %72 at 10=20 am arriving in Anchorage via Fairbanks at 12~55 pm and at my home at 1=25 pm. In summa~, I witnessed successful BOPE test on Arco's Kupar~ BL ~mm O&G #4 4/s0 STATE OF ALASKA ALASKA OIL & GAS CONSERVATION COMMISSION B.O.P.E. Inspection Report Inspector ~ ~/~~f/-~~ Operator /~ ~.~D Well /~&/~ ;~ (2/~ Location: Sec.. /~ Drilling Contractor Well Representative Permit # ~69-~; /~.~%ing Set @ ~F~& Rig # ~4 Representativ~ ~F,'~J ft. Location, General Well Sign General Housekeeping Reserve pit Rig BOPE Stack Annular Preventer Pipe Rams Blind Rams Choke Line Valves H.C.R. Valve Kill Line Valves Check Valve Test Pres sure ACCUMULATOR SYSTEM Full Charge Pressure ~~ psig Pressure After Closure /~' psig 200 psig Above Precharge Attained: Full Charge Pressure Attained: ~ N2 ~ }J'6). ~J~O, ~ F~, ~.~psig Controls: Master ~ Remote mln ~ min ~97~-Blinds switch cover Kelly and Floor Safety Valves Upper Kelly Test Pressure Lower Kelly Test Pressure Ball Type_ ~ Test Pressure Inside BOP_ ~/~ Test Pressure Choke Manifold No. Valves No. flanges ~ ~ Ad] ustable Chokes / Hydrauically operated choke Test Pressure Test Results: Failures Test Time ~ hrs., Repair or Replacement of failed equipment to be made within days and · Inspector/Commission office notified. Distribution orig. - AO&GCC cc - Operator cc - Supervisor Inspector September 24, 1980 Mr. Hoyle Hamilton State of Alaska Division of Oil & Gas 3001 Porcupine Drive Anchorage, Alaska 99501 Subject- As-Built Survey Plats De ar Sir' ,': In an effort to insure that your files are complete, we ha~d copies of our well location as-built survey plats for all wells permitted thus far tn 1980, excluding those included in our original drilling permit applications. Very truly yours, P. A. VanDusen District Drilling Engineer PAV/JBK/jh Attachments WELL /8 V e, 2.9' < -- > ~31' -~ < 03 ~ 3 2_... r- 633' E < ,~, 034' i < E 2.e < -m ^ 'RTIFY THAT I AM I HEREBY CE S=A= A,AS ^ THIS PLAT REPRESENTS AN AS- BUILT SURVEY MADE BY ME, AND ' THAT ALL DIMENSIONS AND OTHER ^S OF: DATE "~/ll/,~ WELL #7 WELL WELL #5 WELL #4 WELL #3 WELL ~2 WELL #l 15 Y 5,960,600.230 X = 549,889°825 LAT ? 70°18Xllo283'' LONG = 149°35~45.185'' Y = 5,960,480.368 X = 549,889.486 LAT = 70.°18' 10. 104" LONG = 149°35:45o219'' Y = 5,9609360.207 X = 549,889.255 LAT = 70°18~08o923'' LONG = 149°35545.249'' Y = 5,960,240.410 X = 549,889.039 LAT = 70°18~07o744'' LONG = 149°35'45°278'' Y = 5,960,120o155 X = 549,889o818 LAT = 70°18J06o561'' LONG = 149°35Z45o279'' Y = 5,960,000°596 X = 549,8890506 LAT = 70°18z05.386I' LONG = 149°35~45.311" X = 5,959,880°504 Y = 549,889.996 LAT = 70°18X04o204I' LONG = 149,35'45.320" X = 5,959,760.244 Y = 549,889.514 LAT = 70°1'8J03o022'' LONG = 149o35'45°358'' IJlLll ii i I I I _ ___ j ~,'~:~- . .... II AtlanticRichfieldCompany O IDATE: IDRAWING No: NORTH AMERICAN PRODUCING DIVISION I O/lq[~O/ ALASKA DISTRICT -- :KUPARUK ~~/"t''' / - ~~,~ ...... - ......... ,;;:- ¢~ _ iiiii [ .... i iiiii ARCO Oil and Gas ~t '~pany Alaska Distrl~, Post Office Box 360 Anchorage, Alaska 99510 Telephone 907 277 5637 August 20, 1980 Mr. Hoyle Hamil ton Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Subject' Kuparuk Well E-8 Dear Sir' The maximum anticipated bottom hole and surface pressures for the subject well were not included with the application for a Permit to Drill. Based on data gathered from other wells drill- ed into the Kuparuk, the maximum bottom hole pressure to be en- countered is 3150 psi. If a gas bubble at bottom hole pressure and temperature were to rise without expanding but cooling to 80°F, it would exert 2780 psi on the BOP equipment. A 5000 psi 13-5/8" RSRRA BOP stack will be installed and tested to 3000 psi. A new surface hole diverter system with 10" diverter lines will be used. The ball valves on the diverter lines will open auto- matically when the annular preventer is closed, as per A.P.I. Recommended Practices. P. A. VanDusen District Drilling Engineer PAV'ruo ARCO OII and Gas Company Is a D~vts~oq o'~ Al~a~,h,.R~chfleloCor~p:~q¥ August 20, 1980 #r. P. A. VinDusen Diltrio~ Drilling Sngineer ARCO Oil and Gas Company P. O. Box 3S0 Anchorage~ Alaska 99510 Res Xuparuk 2S6S1 Atlantic R~ch£ield company Permit No. 80-8~ Sur. Loo. s XOX3'NSL, 6290WBL~ Sec 16t TI1H, RIOB, Bo tomhole Loc., X320'SFL, 1320'WEL~ Sec Bnclosed is ~he approved application for permit to drill the above referenced veil. Well samples~ core chips and a mud log are not required. A directional survey is required, i£ available, a tape contain- ing ~he digitized log ~n£oz~nation shall be submitted on all logs for espying except exper~uental logs, velocity surveys and dipmeter svrveys. PArty rivers in Alaska and their drainage systems have been chssi£ted as important £o~ ~he spawning or migration o~ anedromous lish. Operations in these areas are sublact to AS 16.50.870 and the regulations promulgated ~hereunder (Title 5, Alaska Administrative Code). Prior to conuencAng o~erations you may be contacted by the Habitat Coordinator's of£ice, Department of Fish and Game. Pollution of any raters of ~he State is prohibited by AS 46, Chapter 3, Ar~iole 7 and the regulations promulgated thereunder (Title X8, Alaska Adninistrative Code, Chapter 70) and by the Federal Water Pollution Control Act, as amended. Prior to M.r.P.A. VanDusen Euparuk 2565:1 -2- August 20, 1980 coumencing operations ~ou ma~ be contacted b~. a representative of the Department of Envirom~ntal Conservation. Pursuant to AS 38.40, Local ~ire Under State Leases, the Alaska Department of Labor is being notified of the issuance of this pe~lt to drill. To aid us in scheduling field work, we would appreciate your notifying this office within 48 hours after the well is spudded. We would also like to be notified so that a repre- sentative of the oonu~Lssion may be present to witness testing of blowout preventer equipmont before surface casing shoe is drilled. in the event of suspension or abandonment, please give this office adequate advance notification so that we may have a ~nees present. Very truly yours, Chai~aa~ of BY ORD.2 07 '"~ ~ .... ~'~'~ Alas~ Oil i ~as Conse~ation C~tssion Enclosure cc: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o/encl. Department of Labor~ Supervisor, Labor Law Compliance Division w/o encl. ARCO Oil and Gas Company Post O!hce ~,nrh ~', I( ~,1~,1, ( - . July 15, 1980 Mr. Hoyle Hamilton State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Subject: Kuparuk Wells E-7 & E-8 Dear Sir' Enclosed please find the Applications for Permits to Drill the above-mentioned wells, along with the required as-built surveys, directional maps, BOP diagrams, and filing fees. Very truly yours, P. A. Van Dusen District Drilling Engineer PVD/jh Enclosures ARCO C)d and r, ~, ( r, 'ii' ' t, ", ' , Form 10-401 REV. 1-1-71 STATE OF ALASKA OIL AND (~AS CONSERVATION COMMITTEE PERMIT TO DRILL OR DEEPEN la. TYPE OF WORK DRILL F~ b TYPE OF WELL OIL GAS WELL [J~ OTHER WELL ~] 2 NAME OF OPERATOR Atlantic Richfield Company SUBMIT IN TR~* ATE (Other instructions on reverse sade) ,, 3 ADDRESS OF OPERATOR DEEPEN SINGLE P. O. Box 360, Anchorage, Alaska 99502 4. I~DCATION OF WELL l~¥§¥emSk, 629' WEE, Sec. 16.., III___N, RIOE, DM At proposed prod zone @ 6005' ss' 1320' SNL, 1320' WEL, Sec. 16, TllN, RIO~E, UM API 950-029-20496 6 LEASE DESIGNATION AND SERIAL NO ADL 25651 7 IF INDIAN, ALLOTTEE OR TRIBE NAME 8 UNIT FARM OR LEASE NAME Kuparuk 25651 9 WELL NO. [-8 10 FIELD AND POOL, OR WILDCAT Prudhoe Bay-Kuparuk River Oil 11 SEC., T, R., M, (BOTTOM Pool HOLE OBJECTIVE) Sec.l~6, T11__N, RIO___E, UM 13 DISTANCE IN MILES AND DIRECTION FROM NEAREST TOWN OR POST OFFICE* 12 30.0 Miles NW of Deadhorse ~4. BONDINFOR~TION 0il and Gas Bond nE Statewides~etyand/o, No 8011 - 38 - 40 (Federal Insurance Co.)Amount $100,000 15. DISTANCE FROM PROPOSED * 17 NO,ACRES ASSIGNED' LOCATION TO NEAREST TO THIS WELL PROPERTY OR LEASE LINE, FT. 4267 320 (Also to nearest {lng, umt, ff any) 18 DISTANCE FROM PROPOSED LOCATION TO NEAREST WELL DRILLING, COMPLETED, OR APPLIED FOR, FT 120 21 ELEVATIONS (Show whether DF, RT, CR, etc ) 71.5' GL, 105.5' RKB 16 No OF ACRES IN LEASE 2560 19 PROPOSED DEPTH 6544' TVD 20 ROTARY OR CABLE TOOLS Rotary 22 APPROX DATE WORK WILL START 9/5/80 23 PROPOSED CASING AND CEMENTING PRDGRAM SIZE OF HOLE SIZE OF CASING WEIGHT PER FOOT GRADE 'SETTING DEPTH Quantity of cement 24" 16 65 H + flU 'MU Cmt %o Surf-approx. 200 13-3/4" 10-3/4" 45.5 K-55BTC + 28-93 MO Cmt to Surf-approx. 3000 ft3 9-7/8" 7" 26 K-55BTC +' 7517 MD Cmt with approx 1900 ft3 primary. - 233 ft3 secondary - Arctic Pack from + 2300'MD to surface Atlantic Richfield Company proposes to drill a Prudhoe Bay Kuparuk River Oil Pool development well to approximately + 7517'MD, +6544'TVD. Selected intervals will be logged and tested. A 20" x 2000 psi annula--r diverter-will be installed on the 16" conductor while drilling the surface hole. A 13-5/8" 5000 psi RSRRA BOPE stack will be installed on the surface pipe. It will be tested upon installation and weekly thereafter. Test pressure will be 3000 psig. The well will be completed with 3½" 9.2# J-55 buttress tubing. Non-freezing fluids will be left on uncemented annuli thru the permafrost interval. Selected intervals will be per- forated within the Kuparuk formation and reported on subsequent report. A downhole safety valve will be installed and tested upon conclusion of job. IN ABOVE SPACE DESCRIBE PROPOSED PROGRAM If proposal Is to deepen lgve data on present productive zone and proposed new productave zone. If proposal m to drdl or deepen d~recl~onally, g~ve pertinent data on subsurface locations and measured and true vertical depths. Gwe blowout preventer program. TiTLF_~--~I.~ ~ d~"d.//~,~/~ ~yi~'~ ~ SIGNED, ~ ~' DATE .... (TIus space for State office use) SAMPLES AND CORE CHIPS REQUIRED [] YEs ~.NO DIRECTIONA~ SURVEY REQUIRED ~ [] NO CONDITIONS OF APPROVAL, IF ANY MUD LOG [] ,,'ES OTHER REQUIREMENTS A.P I NUMERICAL CODE s-o- -co'/ PERMIT NO. f~' ~ I APPROVAL DATE APPOVED BY-/~ ~~//[/" ///~''~e~'~e~'~ TITLE ~ -- ~',, ~.~.6~. ~ .... '~.*[.,l ..... *See Instruction On Reverse Side August 20, 1980 DATE 08/2o/8o I I WELL //8 Y 5,960,600.230 X = 549,889.825 LAT .= 70°18~11.'283'' I LONG = 149°35t45.185" ~ WELL #7 Y = 5,960,480.368 i X = 549,889.486 ~,Z'~' < LAT = ~0918t10.104'' '~n' i WELL #6 Y 5,9609360.207 - ~ ~,51' i = O .- ' . ---i X = 549,889.255 - E'zi .I ,~ . LAT = .70°18~08.923'' i~' < LONG = 149o35'45.249''' E6,1~ - WELL #5 Y = 5,960,240.410 ~~ · X = 549,889.039 i~ > LAT = 70°18~07.744'' r- ._ ~'~ LONG = 149°35~45.278'' E~i < -'- -,~ WELL #4 Y = 5,960,120.155 ~n ._. e~4' ~ =_ X = 549,889.818 ,9 I-' > ~ LAT = 70°18~06.561'' E4.~. . i LONG = 149°35~45o279'' . m ~,~' WELL #3 Y = 5,960,000.596 ' ; E ~all~ X = 549,8.89.50.6 _ ~~ > LAT = 70°18~05.386" i !~--~ L_ ;'$~*' LONG = 149°35'45o 311" i EZ~I~- WELL #2 X = 5,959,880.504 'm Y = 549,889.996 ~ ~-~' LAT = 70°18~04.204'' El '4 -- LONG = 149,35'45o320" ~ WELL #1 X = 5,959,760.244 -m Y = 549,889.514 ~- LAT = 70°f8~030022'' ^ LONG = 149°35~45°358'' f 6~AL~ I"= ~OO' 16 , HEREBY CERTIFY THAT ' AM PROPERLY REGISTERED AND LICENSED TO PRACTICE LAND SURVEYING IN THE STATE OF ALASKA AND THAT JUL :i. ? THIS PLAT REPRESENTS AN AS- BUILT SURVEY MADE BY ME, AND Al~,~a Oi! & G-s THAT ALL D IMENS IONS AND OTHER Anch,~r,~j~; DETAILS ARE CORRECT AS OF: · WELL5 ,LO--AIl. Hq AtlanticRichfieldCompany 4) iDATE' DRAWING No: NORTH AMERICAN PRODUCING DIVISION 2/17/t~O ALASKA DISTRICT " -KUPARUK II i v O2~' < · ~ 653' ~I ES~ < RILEY THAT ! AM t J ' 7516 MD.- , )-3316. 15 -TVD .20 i Ill "'~:::t-:~,'-" ::- I t A f'tf't --1277 -'i 1540- t RNNULRR PREVENTOR BLIND RRMS PI PE RRI'IS le LL! SPOOL e PIPE RRI'IS . lo . e e . 13-5/8" BOP STACK DIAGRAM Accumulator Capacity Test . Check and fill accumulator reservoir to proper level with hydraulic fluid. Assure that accumulator pressure is 3000 psi with 1500 psi downstream of the regulator. Observe time,then close all units simultaneously and record the time and pressure remaining after all units are closed with charging pump off. Record on IADC report. (The acceptable lower limit is 45 seconds closing time and 1100 psi remaining pressure.) - !3-5/8" BOP STACK TEST Fill BOP stack and manifold with non-freezing fluid. Check that all hold down screws are fully retracted. Predetermine depth plug will seat & mark running joint. Run test plug on drill pipe and seat in wellhead. Run in lock down screws i n head. Close annular preventer and chokes and bypass valves on manifold. Test all components to 250 psi and hold for 10 minutes. Increase pressure to 3000 psi and hold for 10 minutes. Bleed pressure to 0 psi. Close top set of pipe rams and open annular preventer. Increase pressure to 5000 psi and hold for 10 minutes. Bleed pressure to 0 psi. Close bottom set of pipe rams and valves directly upstream of chokes, then open top set of pipe rams and chokes. Increase pressure to 5000 psi and hold for 10 minutes. Test remaining untested manifold valves (if any) with 5000 psi upstream of valve and zero pressur:: downstream. 10. Back off running joint and pull out of hole. Close blind rams and test to 5000 psi for 10 mir. 11. Bleed pressure off all equipment open bottom preventer. Make sure manifold & lines are full of non-freezing fluid and all valves are set in drilling position. 12. Test standpipe valves to 5000 psi. 13. Test Kelly cocks and inside BOP to 5000 psi with Koomey pump. 14. Check operation of De Gasser. 15. Record test information on Blowout preventer test form. Sign and send to Drilling Supervisor. 16. Perform complete BOPE test once a week and functional operate BOPE daily. · -18- -SURFACE DIVERTER ,SYSTEM e I'- e 1. 20" Bradenhead 2. 20" 2000 psi Drilling Spool 3. 20" 2000 psi Annular Preventer 4. 6" Ball Valves 5. Rig Drilling Riser 6. 6" Lines to Sump -15- CHECK LIST FOR NEW WELL PERMITS Item ~ Date (1) Fe__~e //~ ?~/ ? (2) Loc. ~/~ 1. Is ~e ~it fee at~ch~ .......................................... 2. Is ~11 to ~ l~at~ ~ a def~ ~ol ............................. 3. Is a regist~ ~ey plat at~ch~ ................ ................ 4. Is ~11 l~at~ pro~r dis~ce ~ pro~rty l~e .................. / 5. Is ~11 l~a~ pro~r die,ce fr~ o~r ~lls .................... 6. Is s~ficient ~d~icat~ acrea~ a~ilable 7. Is ~11 ~ ~ devia~ .............................................. / 8. Is o~ra~r ~ only affect~ ~ty ................................. 9. ~ ~mit ~ appr~ ~fore t~ay mit .......................... No Lease & Well No../~,,,.~,~,-'~'/.,. Remarks ! 10. Does operator have a bond in force .................................. ~z-. %'11 conservati ord eded ' ;' ~_._~ · Is a on er ne ...... ~. .................... . ...... - ..... 12. Is administrative approval needed ................................... ~ 13. Is conductor string provided ........................................ ~ (4) Casg. ~ 14. Is enough cement used to circulate on conductor and surface ........ 8~/Qa 15. Will cement tie in surface and intermediate or production strings .. · ~ ~6. Will cement cover all known productive horizons .................... (5)BOPE ~ 17. Will surface casing protect fresh water zones ....................... 18. Will all casing give adequate safety in collapse, tension and burst. 19. Does BOPE have sufficient pressure rating- Test to ~ .~(~ psig . ~ Approval Recked: _ Additional Requirements: Geology: Engineering: rev: 03/05/80 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. {! 000o00 ii 000000 1111 O0 O0 ill! O0 O0 11 oo o000 11 O0 0000 il O0 O0 O0 il O0 O0 O0 11 0000 O0 11 0000 O0 11 O0 O0 11 O0 O0 111111 000000 111111 000o00 '7777777777 7777777777 77 77 77 77 77 77 77 77 77 77 77 77 000000 000000 O0 O0 O0 O0 O0 0000 O0 0000 O0 O0 O0 O0 O0 O0 0000 O0 0000 O0 O0 O0 O0 O0 000000 000000 7777777777 7777777777 77 77 77 77 77 77 77 77 77 77 77 77 666066 11 11 060066 11 11 bb 1111 1111 il 66 1111 1111 11 66 11 11 66 11 11 66666666 11 11 66666666 11 11 66 66 11 11 06 60 11 11 66 66 11 1 66 66 11 11 666666 111111 111111 11 66o666 111111 111111 11 11 11 1l 11 11 11 11 11 11 11 11 1111 11il 666666 666606 66 66 66 66 06666600 66666660 66 06 66 66 66 66 66 66 666666 666660 U O DDDD O O D D U U D D U U D D U U D D U U D D UUUUU DDDD H H OOO LE£EL H H O O E H H O O E HHHHH u O LEEE H H O O L H H O O E H H UO0 ELEEE ,STAR1* USE~ PCAD [10707,61116] jOB MONIT{{R $w8 KLIOE40 SEP-80. ,START* ,START* USE~ PCAb 110707,61116] dOB MUNITi~R SW8 KLIOE40 SEP-80. ,START* SHIP SbU. 818 SHIP SEU. 818 DAT~ 29-OC'r-80 23:18:10 29-0CT-80 23:18:10 SSSSSSSS ~H HH SSSSSSSS HH HH SS ~H HH SS HH HH SS H~ ~H SSSSSS BHH~HHHHHH SSSSSS HHHHHHHHHh SS HH HH SS HH HH SS HH HH SS HH HH SSSSSSSS HH HH SSSSSSSS HH HH III iii I I i I i ! I 1 I I II1 iii Ill III I I I I I i I I I i III III PPPPPPPP PPPPPPPP PP PP pP pp PP PP PP PP PPPPPPPP PPPPPPPP PP PP PP PP PP PP TTTTTTTTTT OOOOf]O TTTTTTTTTT OUUUUO T? OO OO TT OO OO TT oo oo TT OO OO TT O0 TT OO oO TT O0 O0 TT OO O0 TT O0 O0 1T O0 OO TT 000000 TT O00OOO *START* USER PCAE [10707,61116] dOB SHIP S~Q. 818 DAT~ 29-OCT-80 MONITOR SwS KLIOE40 SEP-80 *START* JibE: DSKH:SHIPpBiNTED:*TO<255>[lO~O7~61116129.OCT.80 2:18:25 CREATED: 29-OCT-80 22:47 35 OU~,UE SWITCHES: /FILE:FURT /COPIES:I /$PACING:I /LIMiT:124 /fORMS:NORMAL 23:18:10 SHIP SHIPPING INSTRUCTIONS ISSUED 29oUCT-80 22:47 PCCC THANKS,.,,... BY ¢~,¥ PCCC VV VV VV VV VV VV VV YV YV VV VV VV VV VV VV Vv VV ELELEEEEEL RBRRRRRR VV EE RR RR ~V EE R~ RR VV ~,'E RR RR VV LEEEEEEE RRRRRRRR VV EEEE~EEE ~ERRRRR~ VV EE RR RR VV EE RE RR EEEgEEEEEE RR RR IIIIII iiiiii II II II I1 II II II II II II IIIIII IIIIII X¥ ¥¥ YY XY ¥¥ 000000 000000 11 000000 000000 11 O0 O0 O0 O0 1111 00 00 00 00 1111 00 0000 00 0000 11 00 0000 O0 0000 11 00 O0 O0 O0 O0 00 00 O0 00 00 O0 O0 11 0000 O0 0000 O0 1! 0000 00 0000 O0 1! 00 O0 OO O0 1! 00 O0 00 O0 11 000000 000000 111111 000000 000000 111111 *START* USER PCAL [10707,61116] dOB SHIP MONITUR $W$ KLIOE40 SEP'80. FILE: DS~HlVERIF¥,001<05!~[lO?07.611161 CREATED: PRI D: 29 o OOEOE SwitCHES: /F LE: On /¢OP S:I /SPACING:! /LiMIT:12% /FORMS:NORMAb 818 DATE 29-UCI-80 29-OCT-80 2~:16:17 23:18:10 SCHLUMBERGER COMPUTING C~NTE~ 10707,61116 FE~L HEADER I,ENGT~: 112 BYqES ~kEL NAME: P.C.A.L. SERVICE NAME: EDIT REEL CONTINUATION NUMBER: 0! PREV1UU$ REEL NAME: CUMMENI'S: LIS ~ORMAT CUSTUMER ~APE DATE: 80110129 TAPE HEADER LENGTH: 112 BYTES TAPE NAME: 611lb DATE: 80/10/29 SERVICE NAME: EDIT TAPE CUNTINUArlUN NUMBER: 01 PR~,VIUUS TAPE NAME: COMMENTS: TAPE COMMENTS CASING DR1LLER IO.75~2896/BIT SIZE 8.75/ELUiD TYPE £NVkRMUL/ DENS IO.7/VISC 49.0/~LUID LOSS 4.2 ML/MAX REC TMP 160 NO SP AND NU S~LU iN D1L.... TAKEN ~ROM RUN#] DIE LUGGED 2]0CT80 FiLE HEADER LENGTH: 62 B~TE5 FILE NAME: EDiT .001 MAXIMUM PHYSICAL RECURD LENGTH: PREVIOUS FILE NAME: 1024 BYTES WELL SITE 1NPURMATION RECORD LENGTH: CUMPAN ~ WELL: FIELD: ~ANGE: TUWN: SECT iON CtJiJNTY: 180 BYTES ATLANTIC RICHFIELD CO. KUPARUK E-8 KUPARUK IOE llN 16 N. SLOPE DATUM ,SPECI~ICATIi)N BLOCK,S: ENTRY lC TOOL SVUI~D# UNITS APl AP1 AP1 APl FII,E~ 6[Z~. EXP PROC SAM DEP~ lED DIE ILM OiL GR DID GR CNL CALl CNL DRHO CN ~ NPHI CND ~HUB CNL N~AT CNL NCNL CNL ~CNL CNL GA BHC DT BHC THOR [IRAN POTA SGR GRST FT 0 0 0 0 0 4 0 0 1 ~8 0 0 OHMM 7 12 46 0 0 4 0 0 I b8 0 0 OHMM 7 12 44 0 0 4 0 0 1 68 0 0 GAPI 7 31 32 0 0 4 0 0 1 68 0 0 GAPI 42 31 32 0 0 4 0 0 I 68 0 0 IN 42 28 1 0 0 i 0 0 1 68 0 0 G/C3 42 44 0 0 0 4 0 0 1 b8 0 0 PU 42 68 3 0 0 q 0 0 1 68 0 0 G/C3 42 35 1 0 0 4 0 0 I 68 0 0 C/C 42 42 I 0 0 4 0 0 1 68 0 0 CPS 42 34 92 0 0 4 0 0 1 68 0 0 CPS 42 34 93 0 0 4 0 0 1 68 0 0 GAPI 60 31 32 0 0 4 0 0 1 68 0 0 US/f 60 52 32 0 0 4 0 0 1 08 0 0 PPN 0 0 0 0 0 4 0 0 1 b8 0 0 PPM 0 0 0 0 0 4 0 0 1 68 0 0 NONE 0 0 0 0 0 4 0 0 1 68 0 0 GAPI 0 0 0 0 0 4 0 0 1 68 0 0 GAFf 0 0 0 0 0 4 0 0 1 68 0 0 DEPTH 7555,000 75O0.O0O 7400,000 7t00,000 7200.000 7100.000 7000.000 6900.000 b800,O00 MNEMONIC CAbI NRAT DT ILD CALl NRAT DT SGR 1LD CALl NPAT DT SGR iI,D CALl NRAT DT 8GR ILD CALl NRAT DT SGR CALl NRAT OT SGR lbo CALl NRAT DT SGR ILO CALl NRAT DT SGR iLD CALl NRAT DT SGR VAL 2 8 3 102 96 UE .027 .750 .221 .375 .125 . 8. 3. 102. 96. . 8. 3. 93. 81. . 8. 2. 94. 88. . g. 2. 86. 77. 10. 8. 2. 82. 57. 0 9. 3. 106. 111, I -999. -999. 102. -999. 1 -999. -999. 106. -999. 37t 648 391 188 875 805 734 160 375 813 508 805 908 375 688 867 172 75O 563 875 125 914 541 188 031 049 414 365 750 875 4lb 300 300 750 300 664 300 300 000 300 MNEMONIC IbM DRHO NCNb THOR GRST IbM DRMO NCNb ~HOR GRST IbM DRHO NCNb THOR GRST IbM DRHO NCNb IHC}R GRST DRHO NCNb GRST IbM DRHO NCNb THOR GRST DRHO NCNb THOR GRST ILM DRHO NCNb GRST DRHO NCNb THOR GRST VAL 2 0 1930 12 82 UE .348 .003 .OOO .914 .125 . O. 1856. 12. 83. . O. 2096. 9. 69. . O. 2104. 9. 64. . 0. 2642. 9. 64. 10. 0. 2548. 5. 40. . O. 1840. 10. 84. . -999. -999. -999. -999. . -999. -999. -999. -999. 527 0O2 000 O7O 875 787 O19 000 781 O00 551 OO6 000 O86 438 281 012 000 703 625 5OO O2O 000 953 875 066 053 O00 516 188 467 300 30O 3OO 300 781 300 300 300 300 MNLMONIC GR NPHI FCNL ORAN GR NPHI ~CNb ORAN GR NPHI fCNb URAN GR NPHI FCNL ORAN GR NPHI fCNb URAN GR NPHI FCNL ORAN GR NPHI FCNb ORAN GR NPHI fCNb ORAN GR NPHI ~CNL IJRAN VALUE 94.5O0 38.721 537.000 1.749 91.313 41.260 495.500 1.b24 85.875 37.012 596.500 1.762 87.813 32.129 693.000 2.625 74.438 29.297 883.500 1.821 52.938 26.514 878.500 1.99b 97.438 39.697 500.500 3.455 107.438 -999.300 -999.300 -999.300 129.000 -999.300 -999.300 -999.300 MNEMONIC G~ RHOB GR POTA GR RHOB GR PUTA GR GR POTA GR RHOD GR POTA GR RHOB GR POmA GR RHOB GR PUTA GR RHOB GR POTA GR RHUB GR POTA GR RHOB GR POTA VAbO~ 9b.125 2.441 94.500 0.022 96.875 2.420 91.31~ 0.023 Ul.813 2.411 85.875 0.021 2.445 81.813 0.022 77.875 2.436 74.438 0.019 57.031 2.383 52.93U 0.013 111.815 2.465 97.438 0.028 -999.300 -999.300 107.438 -999.300 -999.300 -999.300 129.000 -999.300 6700,000 6600.000 6500.000 6400.000 6300.000 6200.000 6100.000 6OOO.000 5900.000 M NLNON lC 1LD CALl NRAT DT SGR ILL CALl NRAT DT SGR CAL! NRAT DT ILD CALI NRAT DT SGR ILD CALl NRAT DT SGR CALl NRAT 6GR ILl) CALl NRAT DT SGR ILL CALl NRAT DT SGR iLD CALl NRAT DT SGR VA -99 -99 11 -99 -99 -99 11 -99 LUE 2.512 9,300 9.300 1.563 9.300 2.824 9.300 9.300 6,375 9.300 2.951 -999.300 -999.300 102.375 -999.300 2 -999 -999 115 -999 2 -999 -999 12b -999 3 -999 -999 106 -999 t -999 -999 130 -999 1 -999 -999 118 -999 1 -999 -999 118 -999 .848 .300 .300 .000 .300 .084 .300 .300 .750 .300 .125 .300 .300 .000 .300 .396 .300 .300 .000 .300 .45b .300 .300 .000 .300 .541 .300 .300 .750 .300 MNEMONIC IbM DBHO NCNb THOR GRST ILM DRHO NCNb rHUR GRST IbM DRHO NCNb THOR GRST ILM DRHO NCNb THOR GRST DRHO NCNb THOR GRST ILM DRHO NCNb THOR GRST ibm DRHO NCNb THOR GRST IbM DRHO NCNL THOR GRST ILM DRHO NCNb THOR GRST VALUE 2,613 -999,300 -999.]O0 -999,300 -999.300 2,916 -999,300 -999.]00 -999,300 -999,300 3.098 -999.300 -999.300 -999.300 -999.300 2.824 -999.300 -999.300 -999.300 -999.300 2,035 -999,300 -999.]00 -999,300 -999.]00 3.303 -999.300 -999.300 2999.300 999.300 1.670 -999,300 -999,300 -999,300 -999,300 1,487 -999.300 -999.300 -999,300 -999,300 1,571 -999,300 -999,300 -999,300 -999.300 MNLMONIC GR NPH1 FCNL UHAN GR NPHI FCNL URAN GR NPH1 FCNL URAN GR NPHI PCNb ORAN GR NPHI fCNL U~AN GR NPHI ~CNL URAN GR NPHI URAN G~ NPHi ORAN GR NPHi fCNL URAN VALUE 195.375 -999,300 -999.300 -999.300 130.150 -999.300 -999.300 -999,300 88,188 -999,300 -999,300 -999,300 108,938 -999,300 -999,300 -999,300 99.250 -999.300 -999.300 -999.300 101,125 -999.300 -999,300 -999.300 134.125 -999.300 -999.300 -999.300 111.500 -999.300 -999,300 -999.300 127.625 -999.300 -999.300 -999.300 MNEMONIC GR RHUB GR POTA RHOB GR POTA GR RHUB GR POTA GR RHOB GR POTA GR RHUB GR POTA GR GR POTA GR RHUB GR POTA GR RHOB GR POTA GR RHUB GR POTA VAbUL -999.300 -999.300 195.375 -999.300 -999.300 -999.300 130.750 -999.300 -999.300 -999.300 88.188 -999.300 -999.300 -999.300 108.938 -999.300 -999.300 -999.300 99.250 -999.300 -999.300 -999.300 101.125 -999.300 -999.300 -999.300 13q.125 -999.300 -999.300 -999.300 111.500 -999.300 -999.300 -999,300 127.b25 -999.300 DEPTH 5800,000 5700,000 5600.000 5500.000 5400.000 5300,000 5200,000 5100.000 5000.000 ILD CALI NRAT DT CALl NRAT DT lED CALl NRAT DT SGR CALl NRAT DT SGR CALl NRAT DT SGR II, D CALl NRAT DT SGR ILD CALl NPAT OT SGR lED CALl NRAT DT SGR ILD CALl NRAT DT SGR VAL 1 -999 -999 102 -999 1 -999 -999 117 -999 UE .843 .300 .300 .188 .300 .839 .300 .300 .000 .300 1.731 -999.300 -999.300 119.000 -999.300 . -999. -999. 102, -999. . -999, -999· 102. -999. . -999. -999. 102. -999. , -999. -999, 107. -999. . -999. -999. 89. -999. . -999· -999· 105. -999· 330 3OO 3OO 563 3O0 332 300 000 300 248 3OO 300 563 3OO 316 3OO 300 750 3O0 424 300 300 750 300 689 3OO 3OO 75O 30O MNEMONIC IbM DRHO NCNb THOR GRST IbM DRHO NCNb THOR GR$t IbM DRHO NCNb THOR GRST IbM DRBO NCNb THOR GRST DRHU NCNb THOR GRST IbM DRHO NCNb THOR GRST ILM DRHO NCNb tHOR GRST IbM DRHO NCNb THOR GRST ILM DRHO NCNb THOR GRST VALU · -999. -999. -999. -999. · -999· -999. -999, -999. . -999. -999. -999. -999, 0 -999. -999. -999, -999, · -999. -999. -999. -999. -999. -999. -999. -999. , -999. -999. -999. -999. 0 -999, -999. -999. -999, . -999. -999, -999, -999. 755 3OO 3OO 3O0 3OO 857 300 3O0 300 300 799 300 ]00 300 300 268 300 300 300 300 260 300 300 300 300 010 300 300 300 300 303 300 300 300 300 477 300 300 300 300 625 300 300 300 300 MNLMON1C GR NPH1 ~CNL ORAN GR NPHI fCNb URAN GR NPHI FCNL ORAN GR NPHI FCNb ORAN GR NPHI fCNb URAN GR NPHI fCNL ORAN GR NPH1 FCNL ORAN GR NPH1 FCNL ORAN GR NPHI FCNb URAN VALUE 110.875 -999.300 -999.3o0 -999.300 137·750 -999·300 -999.300 -999.300 133,125 -999.300 -999.300 -999.300 61.906 -999.300 -999·300 -999,300 81.875 -999.300 -999.300 -999.300 79.563 -999,300 -999.300 -999.300 88.563 -999.300 -999.300 -999.300 75.188 -999.300 -999.300 -999.300 73.438 -999·300 -999.300 -999,300 MNEMONIC GR RMUB POTA GR RHUD GR POmA GR RHOB GR POTA GR RHUB GR POTA GR RHOB GR PUTA GR RHOB GR POTA GR RHOB GR POTA GR RHUB GR POTA GR RHt]~ GR POTA VALUE -999.300 -999.300 110.875 -999.300 -999.300 -999.300 137.750 -999.300 -999.300 -999.300 133.125 -999.300 -999.300 -999.300 bl.906 -999.300 -999.300 -999.300 81.875 -999·300 -999.300 -999.300 79.563 -999.300 -999.300 -999.300 88.563 -999,300 -999.300 -999.300 15.188 -999.300 -999.300 -999.300 73.438 -999.300 DE, P'I'H 4900.000 4800.000 4700.000 4600.000 4500.000 4400.000 4300.000 4200,000 4100.000 MNEMONIC ILD CALl N~AT DT CALl NRAT DT SGR CALl NRAT DT SGR ILD CALl NRAT DT iLL CALl NPAT OT SGR ILD CALl NBAT DT SGR ILL CALl NRAT DT SGR ILD CALl NRAT DT SGR ILD CALL NRAT DT 6(;R VALU -999. -999. 104. -999. 0 -999. -999. 108. -999. . -999. -999. 108. -999. . -999. -999. 115. -999. 0 -999. -999. 109. -999. . -999. -999. 115. -999. . -999. -999. 104. -999. . -999. -999. 114. -999. . -999. -999. 120. -999. 469 300 300 563 300 191 300 300 750 300 367 300 ]00 375 300 258 300 300 750 300 309 300 300 000 300 070 300 300 188 300 146 300 300 375 300 543 300 300 563 300 582 300 300 000 300 MNEMONIC IbM DRHO NCNb THOR GRST IbM DRHO NCNb THOR GRST IbM DRHU NCNb GRST ibm DRHO NCNb THOR GRST DRHO NCNb IHOR GRST DRHO NCNL THOR GRST ILM DRHO NCNb THOR GRST IbM DRHO NCNb THOR GRST ILM DRHO NCNb THOR GRMT VAGUE 3.439 -999.300 -999.300 -999.300 -999.300 4.113 -999.300 -999.300 -999.300 -999.300 ].166 -999.300 -999.]00 -999.300 -999.300 ],076 -999°]00 -999.]00 -999,300 -999,300 3.342 -999.300 -999.300 -999.]00 -999.300 3.996 -999.300 -999.300 -999.300 -999.]00 3.213 -999.300 -999.300 -999.300 -999.300 3.396 -999.300 -999.300 -999.300 -999.]00 5.203 -999.]00 -999.300 -999.300 -999.300 MNEMONIC GR NPHI ~CNh bRAN GR NPHI ~'CNL ORAN GR NPMI fCNL ORAN GR NPHI fCNL URAN NPHI ~CNL URAN GR NPHI fCNb URAN GR NPHI fCNb URAN GR NPHi FCNL URAN GR NPHI fCNb URAN VALUE 76.188 -999.300 -999.300 -999.300 72.938 -999.300 -999.300 -999.300 67.188 -999.300 -999.300 -999.300 94.025 -999.300 -999.300 -999.300 76.250 -999.300 -999.300 -999.300 76.500 -999.300 -999.300 -999.300 84.688 -999.300 -999.300 -999.300 65.250 -999.300 -999.300 -999.300 71.000 -999.300 -999.300 -999.300 MNtNON lC GR RHU~ GR POTA GR GR POrA GR GR PUTA GR GR POTA GR PUTA GR RHOB GR POTA GR RHOB GR POTA GR RHOB GR POTA GR RHOB GR POTA VALUk -999.300 -999.300 76.188 -999.~00 -999.300 -999.300 72.938 -999.300 -999.300 -999.300 67.188 -999.300 -999.300 -999.300 94.625 -999.300 -999.300 -999.300 76.250 -999.300 -999.300 -999.300 76.500 -999.300 -999.300 -999.300 84.68~ -999.300 -999.300 -999.300 65.250 -999.300 -999.300 -999.300 71.000 -999.300 DLPTH 4000.000 9900.000 3800.000 3700.000 3600.000 3500.000 3~00.000 ~300,000 {200.000 MNEM{}N lC ILD CALl NRAT DT SGR CALl NRAT DT 6GR ILD CALl NPAT DT ILO CALl NRAT DT SG~ CALl NRAT DT SGR ILD CAi, 1 NRAT DT SGR II, D CALl NRAT DT ILD CALl NRAT DT SGR 1LD CALl NRAT DT SGR VAL 6 3 119 64 10 9 3 135 54 11 9 3 111 73 10 10 ] 118 68 12 8 3 117 65 10 9 3 129 74 13 9 3 139 41 14 -999 -999 144 -999 7 -999 -999 127 -999 UE .180 ,914 .18b .188 .938 .680 .086 .498 .750 .938 .094 .500 .160 .750 .750 .469 .016 .42b .750 .375 .672 .883 .281 .000 .875 .211 .289 .418 .125 .125 .344 .289 .865 .750 .313 .O47 .250 .250 .500 .250 .969 .250 .250 .188 .250 MN EMON lC IbM DRHU NCNb THCJR GRST IbM DRHO NCNb THOR GRST DRHU NCNb THOR GRST DRHO NCNb THOR GRST IbM DRHU NCNb THOR GRST ibm DRHO NCNb THOR GRST IbM D~HO NCNb THOR GRST IbM DRHU NCNb THOR GRST DRHO NCNb IHOR GRST VAL 6 0 1982 6 53 11 -0 2076 4 45 11 -0 2154 8 63 10 0 2102 7 55 11 0 2012 7 53 9 -0 1990 8 61 13 -0 1931 4 32 -999 -999 -999 -999 7 -999 -999 -999 -999 UE .293 .008 .OO0 .988 .281 .656 .002 .000 .824 .906 .047 .002 .000 .523 .156 .000 .020 .000 .563 .938 .445 .033 .000 .891 .938 .578 .001 .000 .281 .969 .516 .O17 .O00 .191 .938 .563 .250 .250 .250 .250 MNEMONIC VALUE GR 56.469 NPHI 37.207 ~CNL 568.500 ORAN 2.123 GR 52.375 NPHI 42.578 ECNL 539.000 ORAN 1.111 GR b3.719 NPHI 35.889 FCNL 637.500 ORAN 1.320 GR 69.875 NPHI 39.941 ECNL 564.500 ORAN 1.558 GR 62.688 NPHI 38.965 ~CNL 516.500 ORAN 1.410 GR 69.500 NPHI 40.869 fCNL 543.500 ORAN 1.520 GR 38.594 NPH1 48.877 PCNb 434.500 ORAN 1.047 GR 28.250 NPHi -99925.000 ~CNL -999.250 URAN -999.250 .367 GR 75.125 .250 NPHI -99925.000 .250 FCNL -999.250 .250 ORAN -999.250 .250 MNEMONIC GR RHUB GR POTA GR RHUD GR PUTA GR RHOB GR POfA GR GR PO'IA GR RHUB GR PUTA GR RHOB GR POiA GR RHO8 GR POTA GR RHOB GR POTA GR RHOU GR POTA VALUE 64.938 2,229 bb.4b9 0.021 54.938 2.172 52.315 0,018 73.150 2.326 b3.719 0.019 68.375 2.363 69.875 0.017 65.815 2.398 62.688 0.018 /~.125 2,240 69.500 0.020 41.313 2.010 38.594 0.011 -999.250 -999.250 28.250 -999.250 -999.2b0 -999.250 75.125 -999.250 DEPTH ~lO0.O00 3000.000 2900.000 2820.000 MNEMONIC ibD CALl N~AT UT 8GR II~D CALl N~AT OT SG~ ILD CALl NRAT OT 1bD CALl NRAT DT SG~ VAL 9 -999 -999 133 -q99 -999 -999 134 -999 10 -999 -999 138 -999 -999 -999 -999 -999 -999 Uk ,211 .250 .250 .500 .250 .035 .250 .250 .375 .250 .523 .250 .250 .50O .250 .250 .250 .250 .250 .250 MNEM!JNIC VALUE ibm d.8o5 ORHU -999,250 NCNb -999.250 THOR -999.250 GRST -999.250 IbM 5.625 DRHO -999.250 NCNb -999.250 %HOR -999.250 GRST -999.250 IbM 11.914 DRHO -999.250 NCNb 999.250 THOR :999.250 GRST -999.250 IbM -999.250 DHHO 999.250 NCNb :999.250 THOR -999.250 GRST -999.250 MNEMONIC VALUE GR 74.375 NPHi -99925,000 fCNL -999.250 ORAN -999.250 GR 06.750 NPHi -99925.000 FCNh -999.250 ORAN -999.250 GR 41.469 NPHI -99925.000 FCNL -999.250 ORAN -999.250 GR -999.250 NPH1 -99925.000 fCNh -999.250 ORAN -999.250 MNEMONIC GR RHU~ GR POTA GR HHOB GR POTA GR GR POTA GR RHOB GR POTA VALUE -999.250 -999.250 74.375 -999.250 -999.250 -999.250 bb.750 -999.250 -999.250 -999.250 41.469 -999.250 -999.250 -999.250 -999.250 -999.250 SUMMARY OF DATA RECtJP, D,S NUMBER 01; RECORDS: 729 LENGTH UF RECORD,S: 994 BYTES I, ENGTH Uf LAST RECORD: 538 BY'tLS f ll,f. TRAILEP LENGTh: 62 FILE NAME: EDIT .001 MAXIMUM PHYSICAL RECORD LENGTH: NEXT ~'ILE NAME: kflF TAPE T~AILEH LENGTH: 132 BYTES TAPE NAME: Ulllb SERVICE NAME: EDIT TAPE CUNTINUATIUN NUMBER: 01 NEXT TAPE NAME: C[]MMENTS: 1024 B~TE$ DATE: 80/10/29