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184-223
• 223 Nov ConocoPhillips Alaska AUG 2 9 2016 P.O. BOX 100360 ANCHORAGE,ALASKA 99510-0360 AOGCC August 25, 2016 Commissioner Cathy Foerster Alaska Oil & Gas Commission 333 West 7th Avenue, Suite 100 �E� SEP 3 0 2016 Anchorage, AK 99501 Commissioner Cathy Foerster: Enclosed please find a spreadsheet with a list of wells from the Kuparuk field(KRU). Each of these wells was found to have a void in the conductor. These voids were filled with cement and corrosion inhibitor, engineered to prevent water from entering the annular space. As per previous agreement with the AOGCC, this letter and spreadsheet serves as notification that the treatments took place and meets the requirements of form 10-404, Report of Sundry Operations. The attached spread sheet presents the well name,top of cement depth prior to filling and volumes used on each conductor. Please call Roger Winter at 907-659-7006 or MJ Loveland at 907-659-7043, if you have any questions. Sinpprely, 'e�r' it Roger Winter ConocoPhillips Well Integrity Field Supervisor 1 • • ConocoPhillips Alaska Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Kuparuk Field Date 8/25/2016 1 D,2A,2L,2N&2W PAD Corrosion Initial top of Vol.of cement Final top of Cement top off Corrosion inhibitor/ Well Name API# PTD# cement pumped cement date inhibitor sealant date ft bbls ft gal 1D-09 50029228750000 1980650 14" NA 14" NA 7 8/24/2016 2A-19A 50103201970100 2010830 11" NA 11" NA 4.25 8/24/2016 2L-306 50103206300000 2101820 12" NA 12" NA 2.55 8/24/2016 2N-341 50103202630000 1981030 14" NA 14" NA 6.8 8/24/2016 2N-347 50103203370000 2000630 13" NA 13" NA 10.2 8/24/2016 2W-10 50029212390000 1842230 10" NA 10" NA 6 8/24/2016 � = • • c .r hL oNW a Nm H\ Y cc N ,0! e9u :WC: 0 1•Z 9 O _ N Qy QJ >oD J !— 0 co O • a II 0 _.u >a) 0 0 1--,oOO 'EsH W (D > 0Q ro in Q •o mcO1OcOcO o E ^ m Q 1— Q fa 1C 16 c6 fa ''' L C C (p t. 2 E E 2 2 E Y co t- 2 cn F M o r co v `— o -0 > V1 z Q r• N O ro aJ 0_ Z Q 0 O -O 4- u > V CC ~ . 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Q O N _1 d N N N E Z aJ co '� t N. j c c re a 6 y L 1 d` 7 m a, o �- a Q 111 2x30, WELL LOG TRANSMITTAL To: Alaska Oil and Gas Conservation Comm. January 4, 2012 Attn.: Howard Okland 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 SCANNED NOV 0 3 2016 RE: Plug Setting Record: 2W-10 Run Date: 1/3/2011 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 2W-10 Digital Data in LAS format, Digital Log Image file 1 CD Rom 50-029-21239-00 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline&Perforating Attn: Klinton Wood 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907-273-3527 Fax: 907-273-3535 klinton.wood@halliburton.com Date: 4\([ Signed: 1-1 t L a:Zeedo6 • • WELL LOG TRANSMITTAL To: Alaska Oil and Gas Conservation Comm. June 24, 2011 Attn.: Howard Okland 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: Plug Setting: 2W -10 Run Date: 6/20/2011 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 2W -10 Digital Data in LAS format, Digital Log Image file c �� 1 CD Rom t PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline & Perforating Attn: Klinton Wood 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907 - 273 -3527 Fax: 907 -273 -3535 klinton.wood@halliburton.com Date: 71. l Signed: /I 6/1, 1?1,t..? - 3 • • WELL LOG TRANSMITTAL To: Alaska Oil and Gas Conservation Comm. July 28, 2011 Attn.: Howard Okland 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: Leak Detect Log: 2W -10 na 'fi Run Date: 7/17/2011 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 2W -10 Digital Data in LAS format, Digital Log Image file 1 t-+ 3 L � 1 CD Rom 50- 029 - 21239 -00 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline & Perforating Attn: Klinton Wood 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907 - 273 -3527 Fax: 907 - 273 -3535 klinton.wood@halliburton.com DaterDate: / ot4hit Signed: i„,-. (f y z 2,3 • • WELL LOG TRANSMITTAL PRoAcTivE DINNOS>nc 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 attention of : ProActive Diagnostic Services, Inc. RECEIVED Attn: Robert A. Richey 130 West International Airport Road Suite C JUL 2 5 2011 Anchorage, AK 99518 Fax: (907) 245 - 8952 Alaska Oil & Gas Cons. Commission Anchorage 0 .,, .,-.) AUG . 0 201't 1) Caliper Report 17- Jul -11 2W -10 1 Report / CD 50- 029 - 21239 -00 1 �5 2) Signed: vi " Date: .) %k. I � Print Name: \\04 W 0.r& tS �C�.. . PROACTIVE DIAGNOSTIC SERVICES, INC., 130 W. INTERNATIONAL AIRPORT RD SUITE C, ANCHORAGE, AK 99518 PHONE: (907)245 -8951 Fax: (907)245 -8952 E -MAIL : PDSANCHORAGE(O.MEMORYLOG.COM WEBSITE : WWW.MEMORYLOG.COM D:\ Archives\ Distribution\ TransmittalSheets \ConocoPhillips Tran tnit.docx ley — 3 1 III • Multi- Finger Caliper � Log Results Summary 1 Company: ConocoPhillips Alaska, Inc. Well: 2W -10 Log Date: July 17, 2011 FiOd: Kuparuk I Log No.: 10258978 ZX70 State: Alaska Run No.: 2 API No.: 50- 029 - 21239 -00 Pipet Desc.: 3.5" 9.3 Ib. J -55 EUE 8RD Top Log Intvll.: Surface Pipet Use: Tubing Bot. Log Intvll.: 8,426 Ft. (MD) Inspection Type : Corrosive & Mechanical Damage Inspection COMMENTS : II The caliper data is correlated to the Tubing Tally. I This log was run to assess the condition of the tubing with respect to corrosive and mechanical. The caliper recordings indicate the 3.5" tubing logged appears to be in good to fair condition, with a maximum recorded wall penetration of 29% in joint 115 (3,724'). Additional wall penetrations ranging from I 20% to 29% wall thickness are recorded in 15 of the 270 joints logged. Recorded damage appears as a line of pits and scattered pitting. No significant areas of cross - sectional wall loss or I.D. restrictions are recorded throughout the tubing logged. 1 The caliper recordings indicate slight buckling from —4,800' to — 8,400'. This is the second time a caliper has been run in this well and the 3.5" tubing has been logged. A U comparison of the current and previous log (July 5, 2010) indicate no increase in corrosive damage during the time between Togs. A graph illustrating the difference in maximum recorded wall penetrations on a joint- by-joint basis between logs is included in this report. I This summary report is an interpretation of data provided by Halliburton Well Services. MAXIMUM RECORDED WALL PENETRATIONS: 1 Line of Pits ( 29 %) Jt. 115 @ 3,724 Ft. (MD) Isolated Pitting ( 29 %) Jt. 198 @ 6,340 Ft. (MD) Isolated Pitting ( 25 %) Jt. 80 @ 2,598 Ft. (MD) I Line of Pits ( 24 %) Jt. 129 @ 4,143 Ft. (MD) Isolated Pitting ( 24%) Jt. 82 @ 2,667 Ft. (MD) I MAXIMUM RECORDED CROSS - SECTIONAL METAL LOSS: No significant areas of cross - sectional wall loss (> 7 %) are recorded throughout the tubing logged. I MAXIMUM RECORDED ID RESTRICTIONS: No significant I.D. restrictions are recorded throughout the tubing logged. 1 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 1 I • • Mandrel Orientation I 2W-10 ConocoPhillips Alaska, Inc. Kuparuk July 17, 2011 Joint No. Tool Deviation Mandrel No 63.1 44 1 5:30 I 114.1 49 2 8:30 134.1 52 3 1:00 159.1 52 4 1:00 183.1 52 5 12:00 204.1 52 6 3:00 225.1 54 7 10:30 I 246.1 50 8 1:30 260.1 47 9 9:30 I I I I I I I I I I I I Field Engineer: M. Biery Analyst: C. Waldrop Witness: B. Boehme ProActive Diagnostic ,c. / P.O. Box 1369, Stafford, TX 7i 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 • Correlation of Recorded Damage to Borehole Profile I ® Pipe 1 3.5 in (21.1' - 8408.5') Well: 2W -10 Field: Kuparuk I Company: ConocoPhillipsAlaska,Inc Country: USA Survey Date: July 17, 2011 I I li Approx. Tool Deviation ■ Approx. Borehole Profile 1 25 i 1 25 811 I 50 1 1603 I GLM 1 JIIL 75 2429 I 100 - 3219 0 I GLM 2 - 125 4012 LL GLM 3 f . _ L t :E' Q I 150 4809 0 GLM 4 1 175 5608 GLM 5 I GLM 6 200 6398 I GLM 7 225 7 7194 GLM 8 I 250 _ 7998 GLM 9 _ f 262 8409 I 0 50 100 Damage Profile (% wall) / Tool Deviation (degrees) I Bottom of Survey = 262 I I • • 1 Maximum Recorded Penetration "' Comparison To Previous I Well: 2W -10 Survey Date: July 17, 2011 Field: Kuparuk Prey. Date: July 5, 2010 Company: ConocoPhillips Alaska, Inc. Tool: UW MFC 24 HAL I Country: USA Tubing: 3.5° 9.3 lb J -55 EUE 8RD Overlay Difference I Max. Rec. Pen. (mils) Diff. in Max. Pen. (mils) I 0 50 100 150 200 250 -100 -50 0 50 100 0.1 7 7 — I 17 17 27 _ 27 37 37 I I - 47 47 _ 57 j 57 63.1 63.1 1 73 73 83 --- 83 93 93 -- 1 103 A I 103 113 _� 113 E 122 E 122 I z 132 z 132 S 141 a 141 151 151 I 160 j 160 170 170 i 180 180 1 189 —ins 189 199 199 208 208 I 218 218 — 227 227 237 -- 1 237 I 246.1 246.1 256 — I 256 261.4 _.' 261.4 I -97 -48 0 48 97 • July 17, 2011 • July 5, 2010 Approx. Corrosion Rate (mpy) 1 I I • I PDS Report Overview Body Region Analysis I Well: 2W -10 Survey Date: July 17, 2011 Field: Kuparuk Tool Type: UW MFC 24 I IAL Company: ConocoPhillips Alaska, Inc. Tool Size: 1.69 I Country: USA No. of Fingers: 24 Tubing: 3.5 ins 9.3 ppf J -55 EUE 8RD Analyst: C. Waldrop Tubing: Nom.OD Weight Grade & Thread Nom.ID Nom.Upset Upper len. Lower len. 3.5 ins 9.3 ppf J -55 EUE 8RD 2.992 ins 3.5 ins 6.0 ins 6.0 ins 1 I Penetration(% wall) Damage Profile (% wall) 300 �___ Penetration body Metal loss body 0 50 100 __ ° 250 -__ 0 I 200 ■��� 150 ___ I 100 50 I J 47 0 �__ I GLM 1 0 to 20 to 40 to over 20% 40% 85% 85% Number of joints analysed (total = 270) 95 I 254 16 0 0 GLM 2 I Damage Configuration ( body) GLM 3 145 100 GLM 4 I 80 60 GLM 5 40 195 GLM 6 20 0 GLM 7 I Isolated General Line Other Hole{ Pitting Corrosion Corrosion Damage Pos. Hole GLM 8 2 ` I Number of joints damaged (total = 84) GLM 9 84 0 0 0 0 Bottom of Survey = 262 I I 1 I • • PDS REPORT JOINT TABULATION SHEET I Pipe: 3.5 in 9.3 ppf J -55 EUE 8RD Well: 2W -10 Body Wall: 0.254 in Field: Kuparuk Upset Wall: 0.254 in Company: ConocoPhillips Alaska, Inc I Nominal I.D.: 2.992 in Country: USA Survey Date: July 17, 2011 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 0.1 21 0 0.02 9 2.97 Pula 1 25 0 0.03 10 2 2.92 1.1 57 0 0.02 8 4 2.95 Pup 1.2 67 0 0.03 10 7 2.91 Pup 1.3 77 0 0.01 6 4 2.95 Pup I 2 81 0 0.02 8 2 2.93 3 113 t1 0.03 10 s 2.90 4 145 0 0.02 7 3 2.91 5 177 0 0.02 7 2 2.91 I 6 209 0 0.02 7 3 2.94 7 240 0 0.02 8 2 2.93 8 272 0 0.02 9 2 2.92 ■ 9 304 0 0.02 9 2 2.95 I 10 11 336 0 0.02 9 2 2.96 367 0 0.02 7 2.93 12 399 0 0.02 8 2 2.93 13 431 0 0.02 9 5 2.91 ■ 14 462 0 0.02 9 2 2.95 I 15 494 0 0.02 8 2 2.95 16 526 0 0.03 11 2 2.94 ■ 17 557 0 0.02 9 2 2.90 18 589 0 0.02 8 2 2.94 I 19 621 0 0.02 6 2 2.92 20 653 0 0.02 8 2 2.94 21 684 0 0.02 7 2 2.91 22 716 0 0.02 9 2.91 I 23 747 0 0.02 7 % 2.94 24 779 0 0.02 7 2 2.93 25 811 0 0.02 9 2 2.96 26 842 0 0.02 7 2 2.88 1 27 874 0 0.02 7 2 2.94 28 906 0 0.02 7 2 2.93 29 938 0 0.02 7 2 2.94 30 969 0 0.02 7 2 2.93 31 1001 0 0.02 7 2 2.94 I 32 1033 0 0.02 7 1 2.96 33 1064 0 0.02 7 2 2.97 34 1096 0 0.01 +, 2.93 35 1128 0 0.01 t 2.94 I 36 1159 0 0.02 7 2 2.95 37 1191 0 0.02 8 2 2.95 38 1223 0 0.02 7 2 2.93 39 1255 0 0.01 5 1 2.95 I 40 1286 0 0.02 6 1 2.93 41 1318 0 0.01 6 2 2.94 42 1349 0 0.02 6 2 2.93 43 1381 0 0.02 7 2 2.94 44 1412 0 0.02 8 2 2.94 1 45 1444 0 0.02 6 2 2.94 46 1476 0 0.02 6 1 2.93 Penetration Body I Metal Loss Body Page 1 I • PDS REPORT JOINT TABULATION SHEET I Pipe: 3.5 in 9.3 ppf J -55 EUE 8RD Well: 2W -10 Body Wall: 0.254 in Field: Kuparuk I Upset Wall: 0.254 in Company: ConocoPhillips Alaska, Inc Nominal I.D.: 2.992 in Country: USA Survey Date: July 17, 2011 I Joint it. Depth Pen. Pen. Pen. Metal Min. Damage Profile No. (Ft.) Upset Body % Loss I.D. Comments (% wall) (Ins.) (Ins.) % (Ins.) 0 50 100 I 47 1508 0 0.01 6 2 2.94 48 1540 0.02 7 2 2.91 III 49 1571 0.02 8 2 2.92 ■ 50 1603 0.02 8 2 2.91 II 51 1635 0.03 10 2 2.92 1III I 52 1667 ti 0.02 8 2 2.93 53 1695 0 0.02 7 2 2.95 54 172 7 0 0.02 7 2 2.95 55 1759 0 0.02 9 2 2.92 IN I 56 1791 57 182 3 0 0.02 u 2.95 U 0 0.02 7 2.94 M 58 1854 0 0.02 7 2 2.90 58.1 1886 0.01 4 1 2.96 Pup I 58.2 1894 0 0 0 2.82 Baker FVL Safety Valve 58.3 1908 0.02 9 6 2.95 Pup 59 1918 0 0.02 8 2 2.95 60 1949 0 0.02 8 2 2.95 61 1981 0 0.02 7 2 2.94 I 62 2012 0 0.02 9 2 2.92 63 2044 0 0.02 6 2 2.91 63.1 2076 , 0 0 0 0 2.94 GI M 1 (Latch @ 5:30) 64 2083 ,1 0.02 9 2 2.93 I 65 2114 0.02 8 2 2.94 M 66 2146 0 0.03 12 2 2.91 Shallow Pitting. 67 2178 0 0.01 6 2 2.95 68 2209 0.07 0.02 8 2 2.93 I 69 2240 0 0.02 7 2 2.94 70 2271 0 0.02 8 2 2.93 71 2303 0 0.02 7 2 2.93 0 72 2334 0 0.03 10 2 2.95 E 11.1 I 73 2366 0 0.06 22 2 2.92 Isolated Pitting 74 2398 0 0.02 9 2 2.93 75 2429 0 0.04 16 2 2.94 Shallow Pitting. R 76 2461 0 0.04 15 2 2.95 Shallow Pitting. 77 2493 0 0.04 15 2 2.94 Shallow Pitting. I 78 2524 '.04 0.04 17 2 2.91 Shallow Line of Pits. 79 2556 0 0.03 11 2 2.93 80 2588 0 0.06 25 2 2.94 Isolated Pitting. 81 2620 0 0.02 9 2 2.96 82 2651 0 0.06 24 2 2.92 Isolated Pitting. �' 83 2683 0 0.02 9 2 2.95 IN 84 2714 m 0.03 12 2 2.92 MI 85 2747 0 0.04 17 2 2.95 Shallow Pitting. I 86 2778 0 0.03 2.94 87 2810 0.04 0.05 2.93 Shallow Pitting 88 2842 0 0.02 2.92 89 2873 U 0.03 12 2 2.92 Shallow Line of Pits. I 90 2905 0.03 11 2 2.92 9 1 2937 0 0.03 13 2.96 Shallow Pitting. 92 2969 0 0.05 19 2 2.96 Shallow Pitting. I Penetrati Body Metal Loss on Body Page 2 I 1 • PDS REPORT JOINT TABULATION SHEET I Pipe: 3.5 in 9.3 ppf J -55 EUE 8RD Well: 2W -10 Body Wall: 0.254 in Field: Kuparuk I Upset Wall: 0.254 in Company: Conoco Alaska, Inc Nominal I.D.: 2.992 in Country: USA Survey Date: July 17, 2011 Phillips 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 93 3000 0 0.06 24 2 2.93 Line of Pits. 94 3032 0 0.03 11 2 2.93 95 3064 0 0.06 22 4 2.93 Line of Pits. 96 3095 0 0.05 19 2 2.94 Shallow Pitting. 97 3125 0 0.04 17 2 2.91 Shallow Pitting. I 98 3157 0 0.03 11 2 2.95 99 3188 0.03 0.06 22 3 2.98 Line of Pits. 100 3219 0 0.05 19 2 2.94 Shallow Pitting. 101 3251 0 0.02 8 2 2.95 I 102 3282 0 0.04 15 2 2.93 Shallow Pitting. 103 3314 0 0.03 12 2 2.94 Shallow Pitting. 104 3345 0 0.02 () i 2.91 105 3378 0 0.04 1 _ 2.95 Shallow Pitting. I 106 3409 0 0.02 8 2.92 107 3441 0 0.05 21 2.95 Isolated Pitting. 108 3472 0 0.03 11 2 2.92 109 3504 0 0.04 14 2 2.93 Shallow Pitting. I 110 3536 0 0.02 8 2 2.93 111 3567 0 0.04 17 3 2.91 Shallow Pitting. 112 3599 0 0.03 12 2 2.92 Shallow Pitting. 113 3628 0 0.05 18 2 2.95 Shallow Pitting. 113 3659 0 0.04 17 2 2.91 Shallow Pitting. I 114.1 3691 0 0 0 0 2.93 GLM 2 (Latch @ 8:30) 115 3698 0 0.07 30 3 2.97 Line of Pits. 116 3730 0 0.03 10 2 2.95 In 117 3760 0 0.04 17 2 2.94 Shallow Pitting. I 118 3790 0 0.02 8 2 2.94 119 3822 0 0.03 13 2 2.93 Shallow Pitting. 120 3854 0 0.02 8 2 2.94 121 3885 0 0.05 20 2 2.95 Shallow Pitting. I 122 3917 0 0.03 I 2.94 123 3949 0 0.03 2.94 Shallow Pitting 124 3981 0 0.02 2.92 125 4012 0 0.04 15 _ 2.92 Shallow Pitting. 126 4044 0 0.03 10 2.92 I 127 4076 0 0.04 17 2.91 Shallow Pitting. 128 4108 0.06 0.05 20 2.89 Isolated Pitting. 129 4140 0 0.06 24 2.95 Line of Pits. 130 4171 0 0.03 12 2.94 Shallow Pitting. I 131 4203 0 0.03 12 _ 2.94 132 4234 0.06 0.03 12 2 2.96 Shallow Pitting. 133 4266 0 0.03 11 2 2.95 E 1 134 4297 0 0.02 9 2 2.92 I 134.1 4329 0 0 0 0 2.92 GLM 3 (Latch Cr 1:00) 135 4336 0 0.04 5 2 2.94 Shallow Line of Pits. 136 4367 0 0.03 2 2.92 Shallow Pitting. 137 4398 0 0.02 2.92 138 4430 0 0.03 I 0 2.93 I 139 4462 0 0.05 19 2.94 Shallow Pitting. 140 4494 0 0.02 8 2.93 1 ,Penetration Bo I Metal Loss Body Page 3 1 I 1 • • PDS REPORT JOINT TABULATION SHEET I Pipe: 3.5 in 9.3 ppf J -55 EUE 8RD Well 2W -10 Body Wall: 0.254 in Field: Kuparuk I Upset Wall: 0.254 in Company: Conoco Alaska, Inc Nominal I.D.: 2.992 in Country: USA Survey Date: July 17, 2011 Phillips I Joint Jt. Depth Pen. Pen. Pen. Metal Min. Damage Profile No. (Ft.) 1pset Body % Loss I.D. Comments (% wall) (Ins.) (Ins.) % (Ins.) 0 50 100 I 141 452 4 0 0.02 7 3 2.89 142 4556 0 0.02 8 2 2.94 143 4587 0 0.02 8 2 2.92 N 144 4619 0 0.02 8 2 2.95 N 145 4651 0 0.03 12 2 2.94 • I 146 4682 0 0.04 18 2 2.95 Shallow Line of Pits. MN 147 4714 0 0.02 7 2 2.92 • 148 4746 0 0.03 11 3 2.95 • 149 4777 0 0.02 8 2 2.94 • I 150 4809 0 0.03 10 2.92 Slight Buckling. 151 4841 0 0.02 7 2.95 • • 152 4872 0 0.02 8 2.93 153 4904 0 0.02 8 2.91 L I 154 4936 0 0.02 7 s 2.90 !M'i 155 4968 0 0.02 7 2 2.94 156 4999 0 0.02 9 2 2.93 r 157 5031 0 0.02 7 2 2.95 v 158 5063 0 0.02 9 3 2.94 Slight Buckling. 159 5094 0 0.03 11 2 2.94 159.1 5126 0 0 0 0 2.92 GLM 4 (Latch @ 1:00) 160 5133 0.04 0.02 7 3 2.93 161 5164 0 0.02 7 2 2.95 I 162 5196 0 0.02 8 2 2.92 ■ 163 5228 0 0.02 9 2 2.91 a 164 5259 0 0.02 7 2 2.88 Slight Buckling. 165 5291 0 0.02 9 2 2.96 I 166 5323 0 0.03 11 3 2.93 167 5354 0 0.03 10 2 2.93 168 5386 0.03 0.03 12 2 2.95 169 5418 0 0.02 7 2 2.94 170 5449 0 0.02 9 2 2.93 I 171 5481 0 0.02 8 2 2.91 Slight Buckling. 172 5513 0 0.02 6 2 2.93 173 5544 0 0.02 8 3 2.94 I 174 5576 0 0.02 7 2 2.94 175 5608 0 0.03 10 2 2.94 176 5640 0 0.03 11 2 2.94 177 5671 0 0.03 12 2 2.94 Slight Buckling. b 178 5699 0 0.05 18 2 2.92 Shallow Line of Pits. a I 179 5731 0 0.03 10 2 2.91 180 5763 0 0.05 20 2 2.91 Line of Pits. 181 5793 0 0.03 11 2 2.95 182 582 5 0 0.02 6 2 2.94 I 183 5856 0 0.03 10 2 2.94 Slight Buckling. 183.1 5888 0 0 0 0 2.92 GLM 5 (Latch 12:00) 184 5894 0 0.02 9 3 2.94 185 592 6 0 0.02 8 2 2.95 1 186 5958 0 0.04 14 2 2.96 Shallow Pitting. 187 5989 0 0.04 14 2 2.97 Shallow Pitting 188 6021 0 0.02 9 2 2.94 'Penetration Body I Metal Loss Body Page 4 1 1 • • PDS REPORT JOINT TABULATION SHEET I Pipe: 3.5 in 9.3 ppf J -55 EUE 8RD Well: 2W -10 Body Wall: 0.254 in Field: Kuparuk I Upset Wall: 0.254 in Company: ConocoPhillips Alaska, Inc Nominal ID.: 2.992 in Country: USA Survey Date: July 17, 2011 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 189 6052 0 0.02 9 2.92 Slight Buckling. 190 6084 0 0.03 10 4 2.91 ■ 191 6115 0 0.03 12 3 2.92 Shallow Pitting. ■ 192 6148 0 0.04 16 2 2.91 Shallow Pitting. 193 6179 0 0.04 15 2 2.95 Shallow Line of Pits. I 194 6211 0 0.03 10 2 2.93 195 6242 0 0.03 11 2 2.94 Slight Buckling. 196 6274 0 0.03 13 2 2.93 Shallow Pitting. 197 6306 0 0.06 23 2 2.94 Isolated Pitting. I 198 6337 0 0.07 29 3 2.90 Isolated Pitting. 199 6368 0 0.02 8 2 2.92 • 200 6398 0 0.03 12 2 2.92 201 6429 0 0.03 12 2 2.94 I 202 6460 0 0.02 7 2 2.93 Slight Buckling 203 6492 0 0.03 10 2 2.91 204 6524 0 0.03 11 2 2.92 • 204.1 6555 0 0 0 0 2.92 GLM 6 (Latch @ 3:00) I 205 6561 0 0.02 8 2 2.94 206 6593 0 0.02 8 2 2.96 ■ • 207 6625 0 0.02 8 2 2.92 Slight Buckling. • 208 6656 0 0.04 15 2 2.93 Shallow Line of Pits. 209 6688 0 0.02 9 2 2.94 I 210 6720 0 0.03 12 2 2.91 211 6751 0 0.03 11 2 2.91 212 6783 0 0.03 11 2 2.89 Slight Buckling. 213 6815 0 0.04 16 2 2.91 Shallow Pitting. I 214 6847 0 0.04 16 3 2.92 Shallow Pitting. 215 6878 0.06 0.04 15 2 2.92 Shallow Pitting. 216 6910 0 0.05 18 2 2.94 Shallow Pitting. 217 6941 0 0.04 15 2 2.93 Shallow Pitting. I 218 6973 0 0.04 14 2 2.91 Shallow Pitting. 219 7005 0 0.02 9 2 2.94 Slight Buckling. 220 7036 (1 0.05 21 3 2.94 Isolated Pitting. 221 7068 0 0.04 14 2 2.91 Shallow Pitting. 222 7100 0 0.03 13 6 2.90 Shallow Pitting. I 223 7132 0 0.02 6 2 2.94 224 7162 0 0.02 9 2 2.94 Slight Buckling. • 225 7194 0 0.03 12 2 2.93 225.1 7227 0 0 0 0 2.91 GLM 7 (Latch @ 10:30) I 226 7233 0 0.03 12 3 2.91 Shallow Pitting. ■ 227 7265 0 0.02 9 2 2.92 228 7296 0 0.03 13 2 2.89 Shallow Pitting. 229 7328 0 0.02 9 2 2.94 Slight Buckling. I 230 7359 O 0.03 13 2 2.92 Shallow Pitting. ■ 231 7391 0 0.04 16 3 2.92 Shallow Line of Pits. is 7423 0 0.03 12 2 2.94 Shallow Pitting. 233 7454 0 0.03 10 3 2.92 I 234 7487 0 0.04 17 2 2.92 Shallow Pitting. 235 7518 0 0.04 14 2 2.94 Shallow Pitting. 236 7549 0 0.03 12 2 2.91 Shallow Pitting. 'Penetration Body I Metal Loss Body Page 5 1 1 • PDS REPORT JOINT TABULATION SHEET I Pipe: 3.5 in 9.3 ppf J -55 EUE 8RD Well: 2W -10 Body Wall: 0.254in Field: Kuparuk Upset Wall: 0.254 in Company: ConocoPhillips Alaska, Inc. I Nominal I.D.: 2.992 in Country: USA Survey Date: July 17, 2011 I Joint Jt. Depth Pen. Pen. Pen. Metal Min. Damage Profile No. (Ft.) Upset Body % Loss I.D. Comments (% wall) (Ins.) (Ins.) °/O (Ins.) 0 50 100 I 237 7581 0.04 0.04 15 2 2.94 Shallow Pitting. Slight Buckling. iii 238 7612 0 0.02 9 2 2.91 ■ 239 7644 0 0.03 10 2 2.94 ■ 240 7675 0 0.03 10 2 2.90 241 7707 0 0.02 8 2 2.91 I 242 7739 0 0.05 19 2 2.90 Shallow Pitting. ■1 243 7770 0 0.02 9 2 2.94 Slight Buckling. d 244 7802 0.04 0.04 15 3 2.89 Shallow Line of Pits. • 245 7834 0.03 0.04 14 3 2.92 Shallow Line of Pits. 1 246 7866 0 0.02 9 3 2.90 246.1 7897 0 0 0 0 2.92 GLM 8 (Latch @ 1:30) 247 7904 0 0.02 6 2 2.93 Slight Buckling. 248 7936 0 0.03 13 2 2.93 Shallow Pitting. ■ I 249 7967 t) 0.04 18 2 2.90 Shallow Line of Pits. ■ 250 7998 0 0.03 10 3 2.90 ■ 251 8031 0 0.03 10 2 2.90 • 252 8062 0 0.03 13 2 2.92 Shallow Pitting. 253 8094 0 0.02 7 2 2.92 Slight Buckling. I 254 8125 0 0.03 13 2 2.91 Shallow Pitting. ■ 255 8157 0 0.02 9 2 2.92 ■ 256 8188 0 0.04 14 3 2.92 Shallow Pitting. ■ 257 8220 0 0.05 18 6 2.92 Shallow Pitting. 1 I 258 8251 0 0.04 . 14 2 2.95 Shallow Pitting. ■ 259 8283 0 0.03 11 2 2.94 Slight Buckling ■ 260 8315 0 0.04 14 2 2.93 Shallow Line of Pits. 260.1 8346 0 0 0 0 2.91 GLM 9 (Latch @ 9:30) I 1 261 8353 0 0.04 15 2 2.93 Shallow Pitting. 261.1 8384 0 0.02 9 3 2.96 Pup 261.2 8388 0 0.03 11 2 2.96 Pu I 261.3 8400 0 0 0 0 3.97 Baker PBR I 261.4 8402 0 0 0 0 2.95 Baker FHL Retrievable Packer 262 8409 0 0.02 9 3 2.95 Slight Buckling. Penetration Body Metal Loss Body 1 1 1 1 1 Page 6 1 1 1 1 • • 1 PDS Report Cross Sections ( 14_,.. I Well: 2W -10 Kuparuk Survey Date: July 17, 2011 Field: Tool Type: UW MFC 24 HAL Company: ConocoPhillips Alaska, Inc. Tool Size: 1.69 Country: USA No. of Fingers: 24 1 Tubing: 3.5 ins 9.3 ppf ) -55 EUE 8RD Analyst: C. Waldrop 1 1 Cross Section for Joint 115 at depth 3724.370 ft Tool speed = 25 Nominal ID = 2.992 I Nominal OD = 3.5 Remaining wall area = 98% -'\ Tool deviation = 50° \ ■ / \ 1 1 1 ' 1 \ _ 1 \ . N / / Finger = 17 Penetration = 0.074 ins I g Line of Pits 0.07 ins = 29% Wail Penetration HIGH SIDE = UP 1 1 1 1 1 • 1 PDS Report Cross Sections TaS„, I Well: 2W -10 Kuparuk Survey Date: July 17, 2011 Field: Tool Type: UW MFC 24 HAL Company: ConocoPhillips Alaska, Inc. Tool Size: 1.69 Country: USA No. of Fingers: 24 1 Tubing: 3.5 ins 9.3 ppf J -55 EUE 8RD Analyst: C. Waldrop 1 1 Cross Section for Joint 198 at depth 6339.810 ft Tool speed = 50 Nominal ID = 2.992 I Nominal OD = 3.5 Remaining wall area = 99% Tool deviation = 52° i 2\. 1 1 / 1 1 1 1 Finger = 16 Penetration = 0.074 ins Isolated Pitting 0.07 ins = 29% Wall Penetration HIGH SIDE = UP 1 1 1 1 1 • I ConocoPhillips KUP oP W W Well Attributes & MD TD Wellbe API Field •gle Name Well Status Ind ( °) MD (MB) 2W -10 Act Bun (IKB) con000ndkpa 500292123900 KUPARUK RIVER UNIT INJ 55.30 7,200.00 9,147.0 '' Co H2S (ppm) Date Annotation End Date KB (4t) Rig Release Date Well cone9. - 2W - 10 6 - Arzott 9:31 58 AM SSSV: LOCKED OUT Last WO: 34.09 12/10/1984 smematic Actual Annotation Depth (ti(8) End Date Annotation Last Mod... End Dale Last Tag: SLM 9,005.0 10/19/2010 Rev Reason: SET WRP & LOWER PATCH PACKER ninam 6/21/2011 Casing Strings Casing Description String 0... String ID ... Top (tl(8) Set Depth (4... Set Depth (1VD) ... String Wt... String ... String Top ThW HANGER 24 CONDUCTOR 16 15.250 32.0 92.0 92.0 65.00 H - 40 WELDED n , Casing Descrtptlon Smug 0... String ID ... Top(RKB) Set Depth g... Set Depth (TVO)... String Wt... String... String Top 11m1 7 SURFACE 9 8.921 30.2 4,026.8 3,116.2 36.00 J BUTT Casing Description String 0... String ID ... Top (1806) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Tnrd PRODUCTION 7 6276 0.0 9,136.0 6,253.1 26.00 J-55 BTC Tubing Strings Tubing DesgiptIon String 0... String ID ... ITop (411(8) ISet th 4- Set Depth VD) I St dng YR... String ._ String Top,brtl TUBING 3 1/2 2.992 23J 8 ( 5,992.(7 _. 8 9.30 J-55 EUEBRD CONDUCTOR 32 Completion Details Top Depth SAFETY VLV. (WO) Top Ina 1.895 Top (m ( B) (°) Item Description Comment 0 @4 23.7 23.7 0.20 HANGER FMC GEN 111 TUBING HANGER 3.500 1 GAS LIFT. ,077 T t 1,896.0 1, 781.1 39.89 SAFETY VLV BAKER FVL SAFETY VALVE - LOCKED OUT 8/30/2006 2.810 2 ( 8,389.0 5,738.0 49.12 PBR BAKER PBR 2.937 GAS LIFT, L 8,402.0 5,746.4 48.46 PACKER BAKER FHL RETRIEVABLE PACKER 2.667 3,690 5 8,743.0 5,975.4 46.88 PACKER BAKER FB-1 PERMANENT PACKER 2.867 8,760.0 5,987.1 46.69 NIPPLE CAMCO D NO GO NIPPLE 2.750 8,768.0 5,992.5 46.59 WLEG BAKER WIREUNE ENTRY GUIDE 3.000 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) SURFACE. i - Top Depth 304,027 (TVD) Top Ind Top (MB) ( (°) Description Comment Run Date ID (In) I GAS LIFT, . 327 Gas - 8,434 5,767.5 48.33 WRP WEATHERFORD WRP 6/2012011 0.000 4,32] 8,572 5,859.6 47.70 PACKER 2.74" Weatherford Lower Patch Packer. Set 5 "deeper than 2/21/2011 procedure, need m adjust upper assy +5' longer_ LIFT, 0.124 (( 1 8,775 5,997.3 46.52 FISH PDS CENTRALIZER ARM 6 "x 3/4" 7/5/2010 0.000 G AS LIFT. 1 1 Perforations & Slots 5.886 snot Top (TVD) Bhp ( Dens 1 To (rtK8) Min S) IN/ (ge ) Zone Date (sin... Type Comment GASg 8,570 8,674 5,858.3 5,928.5 C -1, C-2, C -3, 1/26/1985 12.0 IPERF 5" Dressler Atlas HD; 120 deg ( ( C.4, 2W -10 phasing i GAS LIFT. .^.. 8,700 8,705 5,946.0 5,949.4 UNIT B, 2W -10 1/26/1985 12.0 IPERF 5" Dressler Mas HD; 120 deg 7.225 phasing 8,836 8,890 6,039.8 6,077.3 A -3, A -4, 2W -10 1/26/1985 4.0 IPERF 4" Dressler Atlas JJ; 120 deg phasing GAS LIFT. 7,897 - 8,837 8,842 6,040.5 6,043.9 A -4, 2W -10 1/26/1985 6.0 IPERF SOS 2 1/8" Enerjet; 120 deg phasing 8,851 8,879 6,050.1 6,069.6 A -3, 2W -10 1/26/1985 6.0 IPERF SOS 2 1/8" Enerjet; 120 deg phasing Gas 6,LIFT. 8,910 8,936 6,091.3 6,109.8 A- 2,2W -10 1/26/1985 4.0 IPERF 4" Dressler Atlas JJ; 120 deg phasing 34] Notes: General & Safety End Date Amoalon MR. s aa9 I 12/15/2010 NOTE: View Schematic w/ Alaska Schematic9.0 PACKER. 8402 _�- 6/21/2011 NOTE: MANDREL #11 - HISTORY OF FLOW CUT ak VAR 8,434 , i. INJECTION, I Li , 8,447 1 INJECTION, 8,514 PACKER. ,570-8,674 , 7 PERF, 8 IPERF, 8.700-8.705 I INJE BIO PACKER, 8,743 ;a(A' ?: NIPPLE, 8760 l ! 7LEG.8.768 Mandrel Details Top Depth Top Port i FISH, 8,775 (74(8) Ind 0D Valve iWe In) (P SO RIM S tn Top gm(B) i B) ( ") Make Model (in) Sent Type Type (4e) (PS6 Run Date Can... 1 2,077.0 1,914.3 45.82 MMH FMHO 1 GAS LIFT DMY BK -2 0.000 0.0 12/10/1984 2 3,690.0 2,901.9 51.18 MMH FMHO 1 GAS LIFT DMY BK -2 0.000 0.0 12/10/1984 IPERF, 3 4,327.0 3,299.6 52.90 MMH FMHO 1 GAS LIFT DMY BK -2 0.000 0.0 12/10/1984 8,837$,842 IPERF, 4 5,124.0 3,775.4 54.09 MMH FMHO 1 GAS LIFT DMY BK -2 0.000 0.0 12/10/1984 8'sa6 a's9o 5 5,886.0 4,227.3 5323 MMH FMHO 1 GAS LIFT DMY BK -2 0.000 0.0 72110/1984 IPERF. 8.851$679 6 6,554.0 4,628.0 53.52 MMH FMHO 1 GAS LIFT DMY BK -2 0.000 0.0 12110/1984 7 7,225.0 5,019.3 54.05 MMH FMHO 1 GAS LIFT DMY BK -2 0.000 0.0 12/10/1984 i 8 7,897.0 5,425.2 51.12 MMH FMHO 1 GAS LIFT DMY BK -2 0.000 0.0 12/10/1984 IPERF. 8,810 9 8,347.0 5,710.6 49.38 MMH FMHO 1 GAS LIFT DMY BK 0.000 0.0 5/5/1991 PRODUCTION, o - s,13s� 10 8,441.0 5,772.1 48.30 MERLA TPDX 1 1/2 (NJ DMY RM 0.000 0.0 2/26/1985 TD, 9,147 I ConocoPhillips • KUP 2W - 10 KB-Grn (ft) Rig Release Date I well con99. -2w-10 6/21rzo11 9:31 58 AM schematic - 1 /201 34.09 12/10/1984 HANGER, 24 Milli f i 11911 ..-___3ftwim CONDUCTOR. f 3291 } SAFETY VLV, 1,895 GAS LFT } 2.0 } GAS .60 ( 3,690 ( /_ 1 1 Q SURFACE. 1 30-4,027 1 GAS LIFT. 4.327 GAS LIFT, ri 5 ,124 IIII -k 11 I GAS LIFT. ] 5,886 _. GAS LIFT, 6,554 I GAS LIFT. 7.225 GAS LIFT, r ) 7,897 t GAS LIF7, 1 8,347 PEIR, 8,389 r PACKER, 8,402 1 \MOP. 8.434 t INJECTION. 8,441 I INJECTION, �. 8,514 L. III PACKER. 8.572 ' _- II IPERF, 8,5705674 PERF, 8.700-8,705 IPERF. I INJECTION, l� 8,725 1. PACKER, 8,743 . :. r NIPPLE. 8.760 1.1 1W OLEG.8,786 ir Mandrel Details I Top DD Top Port FISH, 8,775 A (89/8) Ind fin) Valve ath (9» (p T Run YY Stn Top(mc6) ( 6 ) ) P) Make Mond On) Sera TYpo Pe Tfine P ") (psi) Run Dare Cart_ 11 8,514.0 5,820.8 47.85 MERLA TPDX 1 1/2 INJ DMY RM 0.000 0.0 10/19/2010 12 8,725.0 5,963.1 47.09 MERLA TPDX 1 1/2 INJ DMY RM 0.000 0.0 5/5/1991 N ill IPERF 8.8375642 IPERF, 8,8368,89 PERF 11 8,8515,879 I IPERF, 8,910 -8.936 PRODUCTION. 09,136 TD, 9,147 Paaclofl Maunder, Thomas E (DOA) From: N8K Problem Well 8upv[n1O17fDnonocophiUipu.nom] Sent: Sunday, May 22.2D111:4QPyW To: Regg, James B (DOA); Maunder, Thomas E (DOA); Schwartz, Guy L (DOA) Cc: NSK Problem Well Supv; NSK Well Integrity Proj Subject: ConocoPhillips Apr 2011 Injector Report Attachments: CPAI Failed MITIA Monthly Data 04- 1.xls Jim/Tom/Guy, Attached for your records is the ConocoPhillips April 2011 monthly injector report. Wells added to the report: 2VV-10: Failed State witnessed MITIA 2X-05: Surface casing leak Wells removed from the report: None Please contact me at your convenience if you have questions or comments. Martin Martin Walters I Brent Rogers Problem Wells Supervisor ConocoPhillips Alaska Inc. Office 007-659-7224 Cell 907-943-1720 /1999 Pager 907-659-7000 #009 MAY 3 90i1i • • ConocoPhillips Well 2W -10 Injection Data • Tbg Psi • IA Psi • OA Psi I 4000 - 3500 •�'«• 3000 • .cs 2500 U, a a 2000 - • 1500- �.• ; 1 • ♦ • • • .w•• 1000 500 •Yr ASIR 0 M • 01/11 02/11 03/11 04/11 05/11 Date I PTD: 184 -223 Failed State Witnessed MITIA on 05/08/11 • • ConocoPhillips Well 2W -10 Injection Data \ • Water Injection ♦ Gas Injection I 4000 3500 M 3000 U, 2500 a a 2000 1500 � • y ♦• 1000 _ y A11 • 500 0 0 1000 2000 3000 4000 5000 6000 7000 Injection Rate, bwpd or mscfpd \.. J Date of Water Gas Tubing IA Pressure OA Pressure Injected Injected Pressure Injection (bwpd) (mscfpd) (psi) (psi) (psi) 30- Apr -11 5289 0 1538 600 500 29- Apr -11 5313 0 1541 600 500 28- Apr -11 5320 0 1533 650 575 27- Apr -11 5348 0 1534 650 575 26- Apr -11 4610 0 1356 500 625 25- Apr -11 2985 0 1023 1050 625 24- Apr -11 2990 0 1025 1025 850 23- Apr -11 2980 0 1018 1025 600 22- Apr -11 2991 0 1010 1025 600 21- Apr -11 2920 0 1037 1025 600 20- Apr -11 2003 0 808 1025 600 19- Apr -11 2027 0 814 975 580 18- Apr -11 2006 0 817 1000 600 17- Apr -11 1993 0 818 1000 550 16- Apr -11 1915 0 809 1000 550 15- Apr -11 2119 0 853 1000 550 14- Apr -11 2369 0 901 1000 600 13- Apr -11 1907 0 827 1000 600 12- Apr -11 3245 0 1138 1000 600 11- Apr -11 3893 0 1266 1000 600 10- Apr -11 3889 0 1268 1000 600 9- Apr -11 3876 0 1261 1025 700 8- Apr -11 3870 0 1262 1025 650 7- Apr -11 3882 0 1257 1025 650 6- Apr -11 3863 0 1248 1050 700 5- Apr -11 4577 0 1416 1050 700 4- Apr -11 5421 0 1599 1025 660 • • 3- Apr -11 5433 0 1592 1025 660 2- Apr -11 3859 0 1231 1025 660 1- Apr -11 2626 0 956 1025 670 31- Mar -11 2621 0 956 1025 670 30- Mar -11 2629 0 963 1025 670 29- Mar -11 2655 0 980 1000 625 28- Mar -11 2669 0 994 1000 625 27- Mar -11 2754 0 1041 1000 680 26- Mar -11 5628 0 1685 1000 680 25- Mar -11 5649 0 1691 1000 680 24- Mar -11 5710 0 1688 1000 680 23- Mar -11 5665 0 1669 1000 700 22- Mar -11 5654 0 1667 1000 700 21- Mar -11 5707 0 1681 1000 700 20- Mar -11 5687 0 1683 1000 700 19- Mar -11 5730 0 1688 1000 700 18- Mar -11 5736 0 1678 1000 700 17- Mar -11 5659 0 1663 1000 700 16- Mar -11 5667 0 1680 1000 700 15- Mar -11 5676 0 1681 1000 700 14- Mar -11 5658 0 1666 1000 700 13- Mar -11 5443 0 1668 1000 700 12- Mar -11 5658 0 1662 1000 750 11- Mar -11 5691 0 1670 1050 750 10- Mar -11 5685 0 1665 1050 750 9- Mar -11 5688 0 1664 1000 750 8- Mar -11 5705 0 1666 1000 750 7- Mar -11 5714 0 1667 1000 750 6- Mar -11 5746 0 1678 1000 750 5- Mar -11 5770 0 1679 1000 . 750 4- Mar -11 5770 0 1672 1000 750 3- Mar -11 5711 0 1668 1000 725 2- Mar -11 5806 0 1670 1000 725 1- Mar -11 5791 0 1663 1000 725 28- Feb -11 5827 0 1672 1000 650 27- Feb -11 5854 0 1675 1000 650 26- Feb -11 5739 0 1631 1000 650 25- Feb -11 5705 0 1622 1000 650 24- Feb -11 5694 0 1618 1000 650 23- Feb -11 5739 0 1610 1000 650 22- Feb -11 4087 0 1231 1000 650 21- Feb -11 2769 0 1351 1000 650 20- Feb -11 3332 0 1057 1000 650 19- Feb -11 4106 0 1220 1050 560 18- Feb -11 5429 0 1493 1050 560 17- Feb -11 5444 0 1485 1050 560 16- Feb -11 5507 0 1482 1050 560 15- Feb -11 5013 0 1368 1050 560 14- Feb -11 4496 0 1255 1050 560 13- Feb -11 4531 0 1228 1050 560 12- Feb -11 206 4004 1999 800 180 11- Feb -11 0 4004 3485 800 180 0 • 10- Feb -11 0 3900 3491 800 180 9- Feb -11 0 3965 3518 800 180 8- Feb -11 0 3962 3509 800 180 7- Feb -11 0 4017 3514 800 180 6- Feb -11 0 3988 3516 600 150 5- Feb -11 0 3950 3498 600 150 4- Feb -11 0 3891 3490 600 150 3- Feb -11 0 4015 3490 600 150 2- Feb -11 0 0 3141 600 150 1- Feb -11 0 0 3528 600 100 31- Jan -11 0 0 3510 600 100 30- Jan -11 0 5046 3484 600 100 • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE: Friday, May 13, 2011 TO: Jim Regg ,' t f P.I. Supervisor / G� SUBJECT: Mechanical Integrity Tests C CONOCOPHILLIPS ALASKA INC 2W -I0 FROM: Bob Noble KUPARUK RIV UNIT 2W -10 Petroleum Inspector Src: Inspector Reviewed By: P.I. Supr< NON - CONFIDENTIAL Comm Well Name: KUPARUK RIV UNIT 2W -10 API Well Number: 50- 029 - 21239 -00 -00 Inspector Name: Bob Noble Insp Num: mitRCN110511113514 Permit Number: 184 -223 -0 Inspection Date: 5/8/2011 Rel Insp Num: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well I 2W -I0 ' Type Inj. 1 W ' TVD I 5752 ' IA 7 725 1 2300 1920 1820 P.T.D 1842230 �TypeTest SPT Test psi ± 2300 - OA 580 650 630 630 Interval 4YRTST p/F F Tubin 1575 I 1575 1575 1575 — Notes: After bumping this well up 5 times for a total of 4.2 bbls pumped, I told Russ it was time to test it. r I � M° D MA: I E 1(1 Friday, May 13, 2011 Page 1 of 1 • Page 1 of 1 • Maunder, Thomas E (DOA) From: NSK Problem Well Supv [n1617 @conocophillips.com] Sent: Monday, May 09, 2011 8:06 PM To: Maunder, Thomas E (DOA); Regg, James B (DOA); Schwartz, Guy L (DOA) Cc: NSK Problem Well Supv Subject: 2W -10 (PTD 184 -223) Report of failed MITIA Attachments: 2W -10 schematic.pdf Tom, Jim, Guy Kuparuk injector 2W -10 (PTD 184 -223) failed an MITIA as witnessed by Bob Noble on 05/08/11. The initial TIO was 1575/725/580. The well has been SI and will be added to the monthly injector report. Diagnostics will be done and a 10 -403 for repair or an AA will be submitted for continued injection, which ever is appropriate. Attached is a 90 day TIO plot and schematic. Please let me know if you have any questions. Brent Rogers /Martin Walters 201 Problem Wells Supervisor l A `l ConocoPhillips Alaska, Inc. 1Ytt'� Desk Phone (907) 659 -7224 Pager (907) 659 -7000 pgr. 909 TRN_ANNL ANNULUS PRESSURE TRENDS TR11_R11NL MI T 3000. SC WELL NAM, WLKRU2W -10 3000 200. 3000. 3000. 2700 3000. MIL 2400 3000. 2100 ..- -.. . 1000 1 .._. 1500 _ Y—\ L . . .. -- 1200- _ --� - - -- yam �11t1 iA-- f,• - -ma ._ *At*** Anildr �7ik -Ya —A **** ***A AA • aA- 900 .. _ -. -__ .. . .... ..... .. ...._- _..- ..._._.- - ---- _ a. O. 600 •• O. O. 300 ... 0„ ? 0 ` PLOT START TIME MINOR TIME PLOT DURATION g P � 07- FEB -11 10:01 MAJOR TIME WEEK HRS■ PICK TINE ';' . ^. ;I ,f,,," 7D 1111151211113153 I SC TAG NAME DESCRIPTION P -VALUE LATEST NW WL2W -10 -CHOKE FLOW TUBING CHOKE 7777777 DRILL PREY WELL _ . pm SCRATCH 32 FLOW TUBING PRESSURE ? ? ? ? ?77 N W SCRATCH_32 FLOW TUBING TEMP ? ? ? ? ? ?? I NEXT WELL pp ? ? ?? ? ?? Wilt ? ? ? ? ? ?? ENTRY TYPE OPERATOR mg ? ? ? ? ? ?? MI OPERATOR pp SCRATCH_32 INNER ANNULUS PRES ? ? ? ? ? ?? Mr SYSTEM AU IOW SCRATCH_32 OUTER ANNULUS PRES ? ? ? ? ? ?? Mr BOTH 5/23/2011 • • WELL LOG TRANSMITTAL To: Alaska Oil and Gas Conservation Comm. February 25, 2011 Attn.: Christine Shartzer 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: Packer Setting Record: 2W -10 Run Date: 2/21/2011 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 2W -10 Digital Data in LAS format, Digital Log Image file 1 CD Rom 50- 029 - 21239 -00 AtIVOIED MAR 1 i i) 11 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 /t /° 3 3. 6 2-96/ Office: 907 - 273 -3527 Fax: 907 - 273 -3535 rafael b et halliburton com ri't : :'(%, r 1 A 9 r) Date: _; ,, _ Signed: a - w,, 1, ,__.:..rAl,.% _ ...yt, - -3 t.,W, CCM .. : T A ,, 4 !, vl • WELL LOG TRANSMITTAL To: Alaska Oil and Gas Conservation Comm. December 8, 2010 Attn.: Christine Shartzer 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: Injection Profile: 2W -10 Run Date: 11/26/2010 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 2W -10 Digital Data in LAS format, Digital Log Image file, Interpretation Report 1 CD Rom 50- 029- 21239 -00 Injection Profile Log 1 Color Log 50- 029 - 21239 -00 5 A FEB 2.0 .11 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline & Perforating Attn: Klinton Wood 6900 Arctic Blvd. Anchorage, Alaska 99518 /6603 Office: 907 - 273 -3527 Fax: 907 - 273 -3535 066-65' ta, ; Date: - � Signed: 5/ *aka Cad = ;has - i, _� AT:4;j CI AA %A SK AA SEAN PARNELL, GOVERNOR ALASKA OIL AND GAaS 333 W. 7th AVENUE, SUITE 100 M CONSERVATION CO H SSIO IQ ANCHORAGE, ALASKA 99501 -3539 PHONE (907) 279 -1433 FAX (907) 276 -7542 John Peirce Wells Engineer D� ConocoPhillips Alaska, Inc.%MNED P.O. Box 100360 Anchorage, AK 99510 Re: Ku aruk River Field, Ku P aruk River Oil Pool, 2W -10 P Sundry Number: 310 -395 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. 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 7 day of December, 2010. Encl. STATE OF ALASKA�1 V ALASOIL AND GAS CONSERVATION COMMISSIO • APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 1. Type of Request: Abandon Rug for Redrill Perforate New Pool Repair well Change Approved Program Suspend Plug Perforations Perforate Pull Tubing " Time Extension Operational Shutdow n J! Re -enter Susp. Well Stimulate After casin g Otheranstall Tubing Patch 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development j Exploratory" 184 -223 3. Address: 6. API Number: Stratigraphic `°" Service P. O. Box 100360, Anchorage, Alaska 99510 50 029 - 21239 - 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 ry 2W -10 9. Property Designation (Lease Number): 10. Field / Pool(s): ADL 25642 Kuparuk River Field / Kuparuk River Oil Pool 11. PRESENT WELL CONDITION SUMMARY Total depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 9147 6261 • 9050' 6190' 8775' Casing Length Size MD TVD Burst Collapse CONDUCTOR 92 16 92' 92' SURFACE 4026 9.625 4026' 3116' PRODUCTION 9136 7 9136' 6253' Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 8570'-8674',8700'-8705',8836'-8890',8910'-8936 5858'-5929',5946'-5949',6040 3.5 J -55 8770 Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft) PACKER - BAKER THL' PACKER MD= 8400 TVD= 5745 PACKER - BAKER FB -1 PACKER MD= 8745 TVD= 5977 BAKER 'FVL' MD= 1893 TVD= 1780 12. Attachments: Description Summary of Proposal rv 13. Well Class after proposed work: Detailed Operations Program BOP Sketch Exploratory > Development Service rv 14. Estimated Date for Commencing Operations: 15. Well Status after proposed work: 12/20/2010 Oil Gas WDSPL Suspended 16. Verbal Approval: Date: WINJ GINJ WAG Abandoned Commission Representative: GSTOR SPLUG 17. 1 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 Engineer Signature '— Phone: 265 -6471 Date 1 3 O 10 Commission nl Sundry Number: Conditions of approval: Notify Commission so that a representative may witness Plug Integrity BOP Test Mechanical Integrity Test Location Clearance Other: R M ED DEC 0 1 2010 Subsequent Form Required: / D L' Q y Alaska Uji & G as Cons. C® n1633 i n �. Qncmpg ' APPROVED BY � y 4 i Approved by: / i COMMISSIONER THE COMMISSION Date: I Form 10 -403 Re ise 1/ �L•3• /o Submit in Duplicate ORIGINAL 11� to KUP ConocoPh W Attri _ Max Angle 8r MD TD - - - - WellboreAPUUWI (Field Name Well Status Inel( °) MID(ftKB) Act Fit.(ftKB) AaaNc9 4rlr" 500292123900 I KUPARUK RIVER UNIT _JINJ 55.30 7,200.00 9,1360 p9 C ent m) Date IAn otation End Date KB-Grd (ft) Rig Release Date ... E a Ik ,Aiai p4 SAM I 1125 (pp -I-� SSSV. LOCKED OUT Last WO' 34 09 12!10 - Annotation Depth (ft KB) End Date Annotation Last Mod By End Date Last Tag: SLM I 9,020.0 I 71312010 Rev Reason: TAG _ Imosbor aaCasing Strings CONDUCTOR, String OD String ID Set Depth Set Depth (TVD) String Wt � g 92 '" Casi Descnption (in) (in) Top(ftKB) (ft KB) (HKB) (Ibs/ft) String Top Thrd CONDUCTOR 16 15.062 0.0 92.0 92.0 65.00 AO SAFETY V "'' SURFACE 95/8 8.765 C.0 4,026.0 3,115.7 J-55 36.00 1,893 PRODUCTION 7 6.151 0.0 9,136.0 6,253.1 26.00 J - 55 GASUFT, Tub S trings 2.075 S OD String ID Set Deth Set Depth (TVD) String Wt String In) (in) To,(ftKB (HKB) (ftKB) (lbs /ft) Grade String Top Third TUBING 3 12 2 9921 0 0 8,770.0 5,993 9 9.30 J - 8RD EUE GAS LIF Other In Hole (All Jewelry: Tubing Run & Retrievable, Fish, etc.) Top Depth SURFACE, ` KD) Top Inc/ acr 4 Top(ftKB (H B) (') Delption Comment - Run Date ID(in) 1'893 1'779 39.82 SAFETY VLV Baker'FVL' Locked Out 8/302006 12110119M 2.810 GAS LIFT' 2,075 1,912.9 45.76 GAS LIFT MMH/FMHO /l /DMYK -2/// Cent S I A 1 12!10!1984 2.937 4,32s B omm 3,688 2,900.6 51.19 GAS LIFT MMHIFMHO /l /DMYBK -2/// Comment: STA 2 12110/1984 2.937 GAS LIFT , 4,325 4,325 3,298A 52.90 GAS LIFT MMH/FMHO /l /DMYBK -21// Comment: STA 3 _ - 12/1O/1984 2.937 5,123 5,123 3,774.9 54.09 GAS LIFT MMH/FMHO /l /DMYBK- 21/1 STA4 1217011984 2.937 5,884 4,226.1 53.23 GAS LIFT MMWFMHOl1 /DMYBK -2l // Comment: STA 5 12/1011984 2.937 GAS LIFT, _ ,,. 6,552 4,626.8 53.51 GAS LIFT MMHlFMHOl1 /DMYBK 21/ /Comment: STA 6 12110/1984 2.937 5.884 7,223 5,018.2 54.04 GAS LIFT MMHlFMHO /1lDMY /BK -21/! Comment STA 7 12/10/1984 2.937 7,895 5,423.9 51.12 GAS LIFT MMH /FMHO /l /DMYBK -2/ /1 Comment: STA 8 - 12/10/1984 2.937 GAS . s,552 8,344 5,708.7 49.40 GAS LIFT MMH/FMHO /1 /DMYIBK!!l Comment STA 9 5/5/1991 2.937 ,ss2 _ 8,387 5,736.7 49.13 SBR Baker PBR 1211011984 2.992 GAS LIFT, _ 8,400 5,745.2 49.05 PACKER Baker'FHL' PACKER - 12/10/1984 3.000 7,223 - - - 8,439 5,770.8 48.31 INJECTION MERLA/ fPDX/1.5lDMY /RMl!/ CflmmeM: STA 10 2/26/1985 2.875 8,512 5,819.4 47.86 INJECTION MERLA/TPDX/1.51HFCV /RMJ.25II Comment HISTORY OF 6/25/2008 2.875 GASLIFT, FLOW CUT STA 11 7s95 8,724 5,962.4 47.10 INJECTION MERLA/TPDX/1.5 1DMYIRMI!! Comment: STA 12 5/5/1991 2.875 ' GAS LIFT, 8,745 5,976.8 46.86 PACKER BAKER FB-1 PACKER 12/10/1984 2.750 8,3" 8,762 5,988.4 46.66 NIPPLE CAMCO'D' Nipple NO GO 12/1011984 2750 8,767 5,991-81 46.61 SOS Baker 12/10/1984 2.992 SBR, 8,387 8,770 5,993.9 46.57 �FISH 12/10/1984 2.992 - . I 8,775 5,997.3 46.52 PDS CENTRA LIZER ARM 6 z 3/4" 7/5010 0.000 Perforations & Slots _ PACKER, 8.400 -- - - -- 4 Shot Top(TVD) 86n "D) Dons 7 op (ftKBI Blm HKB (HKB) (ftKB) Zone Date (sh•° Command - _ . 8,570 8,674 5,858.3 5,928.5 C - 1, 6 CJ, 126/1985 12.0 IPERF 5" Dressler Atlas HD; 120 deg INJECTION,_ C -4, 2W -10 phasing 8,439 _ 8,700 8,705 5,946.0 5,49 UNIT B, 2W -10 1/26!1985 12.0 IPERF 5" Dressler Atlas HD; 120 deg phasing INJECTION, _ 8,512 8,836 8,890,, 6,039.8 6,077.3A-3,A-4,2W-10 1/26/1985 4.0 IPERF 4" Dressler Atlas JJ; 120 deg phasing ; 1 8,837 8,842 6,0405 6 A-4 2 W -10 126/1985 6.0 IPERF SOS 2 1/8" Enedet; 120 deg phasing IPERF, 8,851 8,879 6,050.1 6,069.6 A-3, 2W -10 126/1985 6.0 IPERF SOS 2 1/8" Enedet; 120 deg phasing 8.570 - 8,674 - - -- - - - .- --- -._ -. 8,910 8,936 6,091.3 - 6 109.8 A - 2, 2W - 10 12617985 4.0 IPERF 4" Dressler Atlas JJ; 120 deg phasing IPERF, 8,700_8,705 INJECTION, 8,724 PACKER, 8,745 NIPPLE, 8,762 SOS, 8,767 TTL,8,770 - - FISH, 8,775 l IPERF, - 8,837 -8,842 a• IPERF, 8,836 -8,890 IPERF,_ _.. 8,851 -8,879 IPERF. 8,910 - 8,936 ' PRODUCTION, 9,136 TD, 9,136 - 2W -10 Retrievable Tubing Patch Installation 2W -10 is a Kuparuk A and C sand injector. The 11/26/10 Injection Profile log found C sand leaks at 8512' WLM (eroded injection mandrel) and at 8562' WLM (blast joint collar). A Caliper log run 7 -05 -10 indicated that there are no significant minimum ID restrictions in the tubing, and found overall condition of the tubing to be good. A single 60' OAL retrievable tubing patch is proposed to isolate both leaks to return 2W -10 to injection as an A sand only injector. Per this procedure, a 60' long retrievable tubing patch will be set in 2W -10 to isolate .% leaks at 8512' and 8562' WLM to halt C sand injection and enable A sand only injection. Procedure: Slickline: 1. Brush & flush 3.5" tubing between 8450 - 8600' RKB where a patch will be set. 2. RIH with dummy patch drift assembly to 8600' RKB to verify that the planned tubing patch run assemblies will drift OK to set depth. If successful drift is attained: Install -60' OAL Retrievable Tubing Patch as follows E -line 3. RIH with 2.74" run OD retrievable packer and set the packer in 3.5" tubing -5' below the lowest C sand leak at 8562' WLM. POOH. RD. Slickline 4. RIH with tubing patch run assembly #2 (-30' OAL) consisting from bottom to top of an anchor latch, -25' spacer pipe, and snap -latch receptacle. Latch run #2 into lower packer set in step #3 above. POOH. RD. 5. RIH with tubing patch run assembly #3 ( -30' OAL) consisting from bottom to top of a snap latch, -25' spacer pipe, and 2.74" run OD retrievable packer. Latch run #3 into snap -latch receptacle at top of assembly #2, and set the upper packer -5' above the upper C sand leak at 8512' WLM to complete the tubing patch at 8507 - 8567' WLM. POOH with running tools. RIH with test plug to set the plug in upper packer at 8507' WLM. PT upper packer and tubing to 2500 psi to verify integrity of top patch packer and tubing above patch. POOH with test plug. RD. Return 2W -10 to A sand only injection. T~4/1~~/TTA PROACTIVE DIACINOSTiC 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 Anchorage, AK 99518 ~ ~ r~ Fax: (907) 245-8952 ~-' 1) Caliper Report 05-Ju1-10 2 W-10 1 Report / EDE 50-029-21239-00 2) v ~~ t~s<s- ~~3 1 ~~~ -~ , ,~ .f ' ~ ~ 44x"3 t ~a ~- JJ ~ r~ ~ ~ ~, ! n, 'v~ y R~ ~ ti ~ .{ Signed : Date ; 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-MAIL: ~dsancl~orageCa~me:noralo~.~©r~s WEBSITE: v.~Tlernorrloa.ca~rra C.`~DocumznG and Sittings\Dianz Williams\Dzsktop\Transmit_Conoco.docx • Memory Multi-Finger Caliper Log Results Summary Company: ConocoPhillips Alaska, Inc. Well: 2W-10 Log Date: July 5, 2010 Field: Kuparuk Log No.: 7428 State: Alaska Run No.: 1 API No.: 50-029-21239-00 Pipet Desc.: 3.5" 9.31b. J-55 EUE 8RD Top Log Intvl1.: Surface Pipet Use: Tubing Bot. Log Intvl1.: 8,770 Ft. (MD) Inspection Type : Corrosive & Mechanical Damage Inspection COMMENTS This caliper data is tied into the tubing tail @ 8,770' (Driller's Depth). This log was run to assess the condition of the 3.5" tubing with respect to corrosive and mechanical damage. The caliper recordings indicate the 3.5" tubing appears to be in good to fair condition, with a maximum recorded wall penetration of 31% in joint 180 (5,775'). Wall penetrations ranging from 20% to 31% wall thickness are recorded in 27 of the 284 joints logged. The damage appears in the form of isolated pitting. No significant areas of cross-sectional wall loss or I.D. restrictions are recorded. The caliper recordings indicate slight buckling from _ 4,800' to -8,400'. A 3-D log plot of the caliper recordings across the area of suspected leak locations in the 3.5" tubing is included in this report. MAXIMUM RECORDED WALL PENETRATIONS: L ~ lsofated pitting (31%) Jt. 180 @ 5,775 Ft. (MD) Isolated pitting (30%) Jt. 196 @ 6,287 Ft. (MD) Isolated pitting (27%) Jt. 127 @ 4,117 Ft. (MD) ' Isolated pitting (26%) Jt. 198 @ 6,346 Ft. (MD) ' Isolated pitting (25%) Jt. 78 @ 2,570 Ft. (MD) MAXIMUM RECORDED CROSS-SECTIONAL METAL LOSS No significant areas of cross-sectional wall loss (> 8%) are recorded. MAXIMUM RECORDED ID RESTRICTIONS No significant I.D. restrictions are recorded. Field Engineer: Wm. McCrossan Analyst: C. Lucasan Witness: P. eessette ProActive Diagnostic Services, Inc. / P.O. Box 1369, Stafford, TX 77497 Phone: X281} or ,888} 555-9D85 Fax: (2ei;t 565-1369 E-maii: PDS~imemorylog.com Prudhoe Bay Field Office Phone: (9D7} 659-23D7 Fax: {907) 659-2314 ~ ~.~ i ~~r -ra~3 1 ~ ~~~ • • PDS Mu(tifinger Caliper 3D Log Plot ~~ ~. S Company : ConocoPhillips Alaska, Inc. Field : Kuparuk Well : 2W-10 Date : July 5, 2010 Description : Detail Caliper Recordings Across Area of Suspected Leak Locations in 3.5" Tubing. Comments Depth Max. Pen. (%) Max. I.D. (ins.) 3-D Log Image Map ~~._ - ~.-T.® 1ft:240ft 0 100 2.5 3.5 0° 0° 90° 180° 270° 0° Min. I.D. (ins.) 2.5 3.5 Nominal I.D. • 2.5 .............. 3.5 Joint 259 8310 .~ 8320 ~ -~ ' ~ --~ I 8330 ~: ~ ~ ._ Joint 260 ~ ~ ~- _ - _ ,..~.M 8340 ~ 5 - - ~. ~ ~" 8350 ~ GLM 9 ~I , ' i_ - - ~r-~--„a. ~ - . - ,fir ~., ' ~ - 8360 II i . ~ ~T - "'~= 8370 - Joint 261 - _a 8380 - Pap Jt. 8390 Pup Jt. _ 8400 _ _'- BakerSBR i , ,.--,._ ~__ ~ %° Baker FHL Packer 8410 I '~ ~ - ~ __ ~ ~ ;~~~~ o,, 8420 I Joiirtzsz I -- 8430 :~~ ~ - _ -T ~ tt I 8440 _ ~~- ~. _. __ Injection Mandrel _ r 10 8450 - ~„ • ~ 8460 Joint 263 $470 8480 8490 Joint 264 8500 8510 Injection Mandrel $520 77 8530 8540 Joint 2ss 8550 8560 8570 Joint 266 8580 8590 8600 Joint 267 $610 8620 8630 Joint 2ss $640 8650 ~~~~- r __ ~.. ~~ :: -__ • 8660 -~ Joint 269 8670 ~ ~ _ ~ "~ , -- ~ i -- -= _ 8680 i _ - __ %-- ~ ~ _ - _ ~ 8690 ~ ~; Pup Jt I ~{ - - 8700 - ~~, ~ 8710 ! ! j ___. Pup Jt. 8720 ~ ;;. `~ ~ ,:_.__..~- TM, _ . Pup Jt. ~ ~ _ _ Injection Mandrel 8730 -_. c ` ~ h ~; ~ ..,,r 12 __ ... ~ ~. '~ Pup Jt. 8740 I - ~0-.-A.-. x _ <. y„ - Pup Jt. .,. _ __ 8750 I Baker FB-1 Packer "" ~ ° _.. _ -- °--- -- - _- Pup Jt. ~ - Camco D-Nipple t.-- ~.F ~ Pup Jt. ! I ~ - _ "' ~ 3.5" Tubing Tail 8770 ~ ~ ~ ~ ~~ ~ "~ ~'"' 7" Production ! _ ~ _ s ~ ,: t '. Casing Nominal I.D. 2.5 3.5 Min. I.D. {ins.) 2.5 3.5 Comments Depth Max. Pen. (%) Max. I.D. (ins.) 3-D Log Image Map 1ft:240ft ~ ° ° ° ° ° ° 0 100 2.5 3.5 0 0 90 180 270 0 i • Correlation of Recorded Damage to Borehole Profile Pipe 1 3.5 in (45.6' - 8770.0') Well: 2W-10 Field: Kuparuk Company: ConocoPhillips Alaska, Inc. Country: USA Survey Date: July 5, 2010 ® Approx. Tool Deviation ^ Approx. Borehole Profile 1 49 831 1621 GLM 1 2445 3232 GLM 2 4023 GLM 3 4818 GLM 4 ~ 5615 i GLM 5 , c L GLM 6 6405 n. a~ GLM 7 7200 GLM 8 8003 GLM 9 INJ 10/11 INJ 12 2 71.2 87 70 0 50 100 Damage Profile (% wall) /Tool Deviation (degrees) Bottom of Survey = 271 .2 25 50 ~ I 75 100 " _ - P 125 150 ~ 175 Z ZOU 'o 250 ~_ I C~ ~~ PDS Report Overview ,4 ?~, Body Region Analysis Well: 2 W-10 Survey Date: July 5, 2010 Field: Kuparuk Tool Type: UW i~1FC 24 No. 214320 Company: ConocoPhillips Alaska, Inc. Tool Size: 1.69 Country: USA No. of Fingers: 24 Anal st: C. Lucasan Tubing: Nom.OD Weight Grade & Thread Nom.ID Nom. Upset Upper len. Lower len. 3.5 ins 9.3 f -55 8RD EUE 2.992 ins 3.5 ins 6.0 ins 6.0 ins Penetration and Metal Loss (% wall) ~ penetration body r~;~ metal loss body 250 200 150 100 50 0 0 to 1 to 10 to 20 to 40 to over 1% 10% 20% 40% 85% 85% Number of'oints anal sed total = 284 pene. 1 128 139 16 0 0 loss 218 66 0 0 0 0 Damage Configuration (body ) 150 i 100 50 0 isolated general line ring hole /puss pitting corrosion corrosion corrosion iblehole Number of ~oints dama ed total = 11 1 111 0 0 0 0 Damage Profile (% wall) penetration body ;;~„~; metal loss body 0 50 100 n GLM 1 GLM 2 GLM 3 GLM 4 GLM 5 GLM 6 GLM 7 GLM 8 INI 10/11 INJ 12 Bottom of Survey = 2 71.2 Analysis Overview page 2 • , PDS REPORT JOINT TABULATION SHEET Pipe: 3.5 in 9.3 ppf J-55 8RD EUE Well: 2W-10 Body Wall: 0.254 in Field: Kuparuk Upset Wall: 0.254 in Company: ConocoPhillips Alaska, Inc. Nominal I.D.: 2.992 in Country: USA Survey Date: July 5, 2010 Joint No. lt. Depth (Ft.) i'~~n. tllx~~t (Irn.l Pen. Body (Ins.) Pc~n. % Metal less `i~~ Min. LD• (Ins.) Comments Damage Profile (%wall) 0 50 100 .1 46 a 0.02 ~~ 5 2.90 1 49 U 0.01 5 t~ 2.90 1.1 81 to 0.02 ~) Z 2.92 PUP 1.2 91 l! 0.02 ~f ~ ~ 2.88 PUP 1.3 101 U 0.02 ~) i 1 2.92 PUP 2 105 t) 0.02 ~~ ! ~ 2.90 3 136 a 0.02 'i I 2.87 4 168 ~ 1 0.01 6 ~ i 2.89 5 200 a 0.01 5 (1 2.89 6 231 ~,~ 0.01 4 ' 2.91 7 263 0.02 8 ? 2.91 8 295 ' ~ 0.03 10 tl 2.88 9 326 ~.~ 0.03 13 (~ 2.90 Shallow ittin . 10 358 !~ 0.02 ~) I 2.90 11 389 t) 0.02 9 1 2.89 12 421 i? 0.02 ~) I 2.87 13 452 t ~ 0.01 t 2.87 14 484 t ~ 0.02 8 I 2.91 15 516 U 0.02 8 1 2.89 16 547 ! ~ 0.02 £3 i 2.90 17 579 ^. ~ 0.02 Y, a 2.89 18 610 U 0.03 I 1 I 2.90 19 642 t ~ 0.02 ~3 t 1 2.89 20 674 a 0.03 12 I 2.89 21 705 U 0,01 i U 2.89 22 737 ~~ 0.01 5 ~? 2.89 23 768 t~ 0.01 6 1 2.88 24 800 tt 0.03 lU t~ 2.90 25 831 t} 0.02 ~~ 2.93 26 863 t~ 0.02 ~i 2.87 27 894 1) 0.03 i 1 2.90 28 926 t) 0.01 5 t1 2.90 2 9 958 t 1 0.02 ~) _' 2.89 30 989 it 0.01 -~ i? 2.90 31 1021 a 0.02 ~~ ti 2.92 32 1053 U 0.01 i u 2.91 33 1084 (~ 0.01 ~ I 2.93 34 1116 I~ 0.01 ~ i 2.91 35 1148 t ~ 0.02 ~> ! ~ 2.90 36 1179 t~ 0.03 til I 2.91 37 1211 U 0.02 r3 a 2.91 38 1242 ~ ~ 0.03 1(1 Ci 2.89 39 1274 t? 0.02 9 I 2.89 40 1306 U 0.02 9 1 2.90 41 1337 Ci 0.02 9 I 2.87 42 1368 U 0.03 12 i1 2.91 43 1400 t ~ 0.01 i 2.90 44 1431 t 1 0.01 -1 2.91 45 1463 t ~ 0.01 t> ~ ~ 2.91 46 1495 t ~ 0.01 (> ! ~ 2.91 __ Penetration Body Metal Loss Body Page 'I • a PDS REPORT JOINT TABULATION SHEET Pipe: 3.5 in 9.3 ppf J-55 8RD EUE Well: 2W-10 Body Wall: 0.254 in Field: Kuparuk Upset Wall: 0.254 in Company: Conoco Phillips Alaska, Inc. Nominal I.D.: 2.992 in Country: USA Survey Date: July 5, 2010 Joint No. Jt. Depth (Ft.) Pe°n. ! l~,ti~~t 11ns.) Pen. Body (Ins.) Pen. °i~ Metal I c:>ss °-~~ Min. LD• (Ins.) Comments Damage Profile (%wall) 0 50 100 47 1526 U 0.02 9 It 2.90 48 1558 ! 1 0.02 9 u 2.87 49 1589 ! ? 0.01 6 1 2.90 50 1621 i ~ 0.01 i t ! 2.89 51 1653 ~ ! 0.02 ' ~ i ( 2.90 52 1684 ! ! 0.02 ~~ ? 2.89 53 1713 it 0.03 1O (t 2.93 54 1744 ll 0.02 9 ~J 2.92 55 1776 11 OA2 ~> i 2.90 56 1808 it 0.02 ~) { 2.90 57 1839 l! 0.02 I 2.91 58 1871 U 0.02 ~~ +~ 2.89 58.1 1903 a 0.01 Z I 2.94 PUP 58.2 1911 u 0 i) it 2.81 SSSV 58.3 1924 U 0.02 ~~ i, 2.94 PUP 59 1934 i? 0.04 14 2.88 Shallow ittin . 60 1966 a 0.02 9 I 2.93 61 1997 U 0.02 8 ! ~ 2.92 62 2029 l) 0.01 4 ~~ 2.90 63 2061 O 0.03 11 ? 2.88 63.1 2092 !? 0 i) !? N A GLM 1 Latch Q 5:00 64 2099 U 0.05 ZU i 2.91 Isolated ittin . 65 2131 +~ 0.02 8 ~~ 2.92 66 2163 +! 0.02 ~~ I 2.90 67 2194 ! ~ 0.03 1 ~ I 2.92 Shallow ittin . 68 2226 +~ 0.02 t3 2.91 69 2256 i) 0.03 1;; i 2.92 Shallow ittin . 70 2287 a 0.03 11 (( 2.91 71 2319 ~~ 0.03 11 !! 2.91 72 2350 i' 0.06 l1 I 2.92 Isolated ittin . 73 2382 i! 0.05 wit I 2.91 Isolated ittin . 74 2414 ! t 0.04 17 U 2.90 Shallow ittin . 75 2445 U 0.03 13 U 2.91 Shallow ittin . 76 2476 (t 0.04 16 1 2.92 Shallow ittin . 77 2508 r) 0.05 ZO I 2.91 Isolated ittin . 78 2539 ~ ~ 0.06 2 5 ! ! 2.89 Isolated ittin . 79 2571 i~ 0.04 14 i 2.91 Shallow ~ittin . 80 2603 O 0.02 9 2.92 81 2634 it 0.06 14 ~' 2.91 Isolated ittin . 82 2666 !! 0.04 16 2.90 Shallow ittin . 83 2697 it 0.05 li3 1 2.87 Shallow ittin Lt De osits. 84 2729 +~ 0.03 11 1 2.90 85 2760 (t 0.04 15 2.91 Shallow ittin . 86 2792 i~ 0.04 17 1 2.91 Shallow ittin . 87 2824 U 0.05 18 1 2.90 Shallow ittin . 88 2855 t' 0.04 17 0 2.90 Shallow ittin . 89 2887 U 0.04 17 1 2.90 Shallow ittin . 90 2919 t) 0.03 1:~ ! 2.90 Shallow ittin . 91 2951 !} 0.04 1I +~ 2.92 Shallow ittin . 92 2982 ! ~ 0.05 I £. 2.90 Shallow ittin . __ Penetration Body Metal Loss Body Page 2 • • PDS REPORT JOINT TABULATION SHEET Pipe: 3.5 in 9.3 ppf J-55 8RD EUE Well: 2W-10 Body Wall: 0.254 in Field: Kuparuk Upset Wall: 0.254 in Company: CunocoPhillips Alaska, Inc. Nominal I.D.: 2.992 in Country: USA Survey Date: July 5, 2010 Joint No. Jt. Depth (Ft.) I'~ ii. l il~c~! (I~~~.) Pen. Body (Ins.) Pen. °'~ Me!.il I os~ ",~~ Min. LD• (Ins.) Comments Damage Profile (% wall) 0 50 100 93 3013 ~) 0.03 13 U 2.91 Shallow ~ittin . 94 3045 U 0.04 1? t) 2.90 Shallow ittin . 95 3077 ~? 0.06 '_' I 2.91 Isolated ittin . 96 3109 ~ ~ 0.05 t ti ~ 2.91 Shallow ittin . 97 3138 .:) 0.03 1 ~ ~ ! 2.87 98 3170 c) 0.04 17 _' 2.92 Shallow ittin . 99 3201 0 0.06 ~:3 ~ 2.96 Isolated ittin . 100 3232 U 0.05 LU 1 2.93 Isolated ittin . 101 3264 O 0.04 16 I 2.89 Shallow ittin . 102 3295 t1 0.02 ') I 2.91 103 3327 ;?.(L> 0.04 tb I 2.92 Shallow ittin . 104 3358 !) 0.03 12 ( 2.88 Shallow ittin . 105 3390 U 0.05 I tt 2.92 Shallow ittin . 106 3421 a 0.02 (~ ~ ~ 2.90 107 3453 !? 0.06 2Z ~ 2.88 Isolated ittin . 108 3485 tl 0.05 21 1 2.90 Isolated ittin . 109 3516 i) 0.03 12 U 2.91 Shallow ittin . 110 3548 n 0.05 Zt) ! 2.91 Isolated ittin . 111 3579 U 0.06 22 I 2.90 Isolated ittin . 112 361 1 I) 0.03 I U t) 2.89 113 3639 !) 0.04 14 I 2.91 Shallow ittin . 114 3671 U 0.04 16 ? 2.91 Shallow ittin . 114.1 3702 !) 0 0 U N A GLM 2 Latch ®9:00 115 3709 !) 0.04 17 4 2.93 Shallow ittin . 116 3741 +) 0.03 I ~ 1 2.91 Shallow ittin . 117 3771 a 0.04 17 1 2.90 Shallow ittin . 118 3801 l? 0.05 19 I 2.89 Shallow ittin . 119 3833 l) 0.03 13 1 2.92 Shallow ittin . 120 3864 ~) 0.04 14 t) 2.93 Shallow ittin . 121 3896 U 0.05 20 I 2.92 Isolated ittin . 122 3928 !) 0.02 ~) a 2.92 123 3959 i.l 0.04 15 I 2.90 Shallow ittin . 124 3991 i) 0.02 t; 1 2.91 125 4023 ~) 0.03 I 1 l) 2.91 126 4055 i? 0.04 i(, U 2.90 Shallow ittin . 127 4086 ~) 0.07 _'i I 2.89 Isolated ittin . 128 4118 t) 0.04 17 0 2.88 Shallow ittin . 129 4150 ! ~ 0.05 21 1 2.90 Isolated ittin . 130 4182 0.02 7 i1 2.92 131 4213 0.04 15 t; 2.92 Shallow ittin . 132 4245 !? 0.03 I ~ ? 2.92 Shallow ittin . 133 4276 U 0.03 13 I 2.92 Shallow ittin . 134 4307 i? 0.01 4 I 2.91 a 134.1 4338 ~? 0 0 ~! NA GLM 3 Latch@2:00 135 4346 ~? 0.03 it) 1 2.90 136 4377 !? 0.03 1 i i 2.89 Shallow ittin . 137 4409 ' ~ 0.03 1 _> 2.91 Shallow ~ittin . 138 4440 ~? 0.04 1 ~ '! 2.91 Shallow ittin . 139 4472 ~? 0.02 2.90 140 4503 a 0.03 . ! 2.90 Penetration Body iVletal Loss Body Page 3 • PDS REPORT JOINT TABULATION SHEET Pipe: 3.5 in 9.3 ppf J-55 8RD EUE Well: 2W-10 Body Wall: 0.254 in Field: Kuparuk Upset Wall: 0.254 in Company: Conoco Phillips Alaska, Inc. Nominal I.D.: 2.992 in Country: USA Survey Date: July 5, 2010 Joint No. )t. Depth (Ft) !'cn. !Il~tif~t ~In5.1 Pen. Body (Ins.) Pen. "/o Metal Iosti ~~ Min. LD• (Ins.) Comments Damage Profile (%wall) 0 50 100 141 4533 ~' 0.03 I 1 i ~ 2.86 142 4565 i) 0.03 1:; I 2.91 Shallow ittin Lt. De osits. 143 4.597 t? 0.02 9 I 2.90 144 4628 ~ ~ 0.03 1 1 U 2.90 145 4660 i ~ 0.03 1 1 I 2.90 146 4691 ti 0.05 _'(I i 2.92 Shallow ittin . 147 472 3 ~) 0.02 £> I 2.90 148 4754 ~? 0.03 lid 2.93 149 4786 U 0.03 I 1 ~ ! 2.90 150 4818 U 0.02 9 2.86 Sli ht bucklin . 151 4849 r? 0.02 ~) I 2.91 152 4881 U 0.02 `~ I 2.89 153 4912 t1 0.02 '? ~1 2.89 154 4944 ~ ? 0.01 ~ ! 1 2.88 155 4976 ~? 0.03 I~ 1 2.92 156 5007 t) 0.02 `~ U 2.92 157 5039 a 0.02 fi U 2.92 158 5071 U 0.03 10 a 2.92 159 5102 ~? 0.01 4 1 2.92 159.1 5133 t~ 0 i) i? N A GLM 4 Latch ~ 1:30 160 5141 ~? 0.02 - t? 2.92 Sli ht bucklin . 161 5172 !) 0.02 ~~ I 2.93 162 5'204 ~? 0.01 4 u 2.91 163 5236 t? 0.03 12 c? 2.90 164 5267 ~? 0.03 13 !? 2.87 Shallow ittin . 165 5299 ~? 0.02 ~~ 2.92 166 5331 c? 0.03 12 i? 2.92 167 5362 a 0.02 £3 1 2.92 168 5394 ~? 0.02 t3 2.93 169 5425 t? 0.01 ~ I 2.92 170 5457 ~? 0.02 cJ 1 2.91 Sli ht bucklin . 171 5488 t) 0.03 11 2.89 172 5520 t I 0.03 1 1 (1 2.88 173 5552 U 0.02 ~3 I 2.92 174 5583 t~ 0.02 8 I 2.91 175 561 S ! ? 0.03 1 1 1 2.91 176 5646 t ~ 0.02 `) 1 2.88 177 5678 U 0.03 13 I 2.87 Shallow ittin . 178 5706 i? 0.06 24 1 2.90 Isolated ittin . 179 5738 ~ ~ 0.03 12 ?) 2.90 180 5769 ~,'~ 0.08 i I I 2.90 Isolated ittin . 181 5799 I'~ 0.02 9 2.93 Sli ht bucklin . 182 5831 0.03 12 ti 2.91 Shallow ittin . 183 5863 ~? 0.03 13 ~ ~ 2.90 Shallow ittin . 183.1 5894 ~? 0 0 t? N A GLM 5 Latch @ 12:00 184 5901 c } 0.03 12 I 2.91 185 5932 0.03 1 "; I 2.89 Shallow ittin . 186 5964 n 0.04 1 2.92 Shallow ittin . 187 5995 !? 0.03 13 ? 2.93 Shallow ittin . 188 6027 ~~ 0.03 12 t) 2.90 Sli ht bucklin . _ Penetration Body Metal Loss Body Page 4 • • PDS REPORT JOINT TABUL ATION SHEET Pipe: 3.5 in 9.3 ppf J-55 8RD EUE Well: 2W-10 Body Wall: 0.254 in Field: Kuparuk Upset Wall: 0.254 in Company: ConocoPhillips Alaska, Inc. Nominal LD.: 2.992 in Country: USA Survey Date: July 5, 2010 Joint No. Jt. Depth (Ft.) I'~=n. 1 !I „<~i !I~~~.I Pen. Body (Ins.) Pen. io Metal l ~»< °<, Min. LD• (Ins.) Comments Damage Profile (% wall) 0 50 100 189 6059 0.04 17 ! 2.91 Shallow ittin . 190 6090 ~~ 0.05 ~U i 2.90 Isolated ittin . 191 6122 ! ~ 0.04 14 1 2.91 Shallow ittin . 192 6154 +~ 0.06 ZZ ti 2.89 Isolated ittin . 193 6185 0.03 l i 2.93 Shallow ittin . 194 6217 t' 0.04 l i~ I 2.92 Shallow ittin . 195 6248 ~? 0.02 ~ ! 2.91 Sli ht bucklin . 196 6280 a 0.08 3U 2.88 Isolated ittin 197 6312 U 0.03 11 i 2.93 Sli ht bucklin . 198 6343 ti 0.07 ~~ 1 2.89 Isolated ittin . 199 6373 t i 0.04 17 1 2.92 Shallow ittin . 200 6405 0.02 ~) t> 2.89 201 6435 a 0.03 1 z _' 2.91 202 6466 !! 0.04 15 1 2.90 Shallow ittin . 203 6498 ;; 0.03 i 1 2.91 Sli ht bucklin . 204 6529 U 0.03 I1 I 2.90 204.1 6560 U 0 t) t) N A GLM 6 Latch @ 2:30 205 6568 ti 0.03 I1 s 2.93 206 6599 t? 0.03 lI I 2.93 207 6631 i ~ 0.02 ~) ! 2.89 208 6662 '! 0.05 lO 2.92 Shallow ittin . 209 6694 0.03 I U 1 2.91 Sli ht bucklin . 210 6725 0.03 I1 n 2.88 211 6757 C! 0.03 1 t) tt 2.91 212 6789 t? 0.02 y 2.90 213 6820 a 0.05 .'U 1 2.89 Shallow ittin . 214 6852 t) 0.02 ~) I 2.90 215 6884 ti 0.05 LO I 2.90 Isolated _ittin . 216 6915 =! 0.04 16 2.90 Shallow ittin . 217 6947 ~ ~ 0.01 5 I '2.90 Sli ht bucklin . 218 6978 ~} 0.04 14 U 2.87 Shallow ittin . 219 7010 ~'~ 0.03 13 I 2.89 Shallow ittin . 220 7042 r' 0.05 19 1 2. 0 Shallow ittin . 221 7073 0.02 ~) 1 2.90 222 7105 i ~ 0.03 12 l i 2.86 223 7137 0.04 )4 tt 2.91 Shallow ittin . 224 7168 0.03 1 ? I 2.92 Sli ht bucklin . 225 7200 ~) 0.03 I ~ 2.93 Shallow ittin . 225.1 7231 .) 0 U ~~~ N' A GLM 7 Latch @ 10:00 226 7238 t ~ 0.03 I I ~', 2.90 227 7270 ~? 0.06 ~'_t I 2.92 Isolated ittin . 228 7301 ti 0.03 13 I 2.90 Shallow ittin . 229 7333 O 0.04 15 ~ 2.93 Shallow ittin . 230 7365 t) 0.04 15 2.90 Shallow ittin . 231 7396 0 0.03 13 i i 2.91 Shallow ittin . 232 7428 U 0.05 1 t3 2.92 Shallow ittin 233 7459 +i 0.03 1_' 2.90 Sli ht bucklin . 234 7491 0.03 I:~) 2.88 Shallow ittin . 235 7523 !! 0.04 14 2.93 Shallow ittin ` 236 7554 ~:i 0.03 1? 2.92 Sli3htbucklin Penetration Body Metal Loss Body Page 5 • PDS REPORT JOINT TABUL ATION SHEET Pipe: 3.5 in 9.3 ppf J-55 8RD EUE Well: 2W-10 Body Wall: 0.254 in Field: Kuparuk Upset Wall: 0?54 in Company: ConocoPhillips ,Alaska, Inc. Nominal I.D.: 2.992 in Country: USA Survey Date: July 5, 2010 Joint Jt. Depth I'~ n. Pen. Pen. Mc•~,d Min. Damage Profile No. (Ft.) t!lisc~l Body °i, Kiss LD• Comments (%wall) ('n<..i (Ins.) °-~, (Ins.) 0 50 100 ~ ~dR ~ 7Qdn ~ i~ I n ne ~ l i'. ~ I ~ ~ q'~ I Cliaht ti~ u-Irlina rl 249 7972 ,) 0.03 1 ~1 ~, ~ 2.88 250 8003 0.02 `) ~ ~ 2.90 251 8035 t~ 0.03 1O i ~ 2.92 Sli ht bucklin . 252 8067 i> 0.04 17 2.91 Shallow ittin ~ 253 8098 t) 0.01 ~~ i 2.92 254 8130 tl 0.04 15 2.92 Shallow ittin . 255 8161 U 0.02 ~ ~ ~ 2.90 Sli ht bucklin . 256 8193 (~ 0.04 1-4 2.93 Shallow ittin . 0 . Penetration Body Metal Loss Body Page 6 • PDS REPORT JOINT TABULATION SHEET Pipe: 3.5 in 93 ppf J-55 8RD EUE Well: 2W-10 Body Wall: 0.254 in Field: Kuparuk Upset Wall: 0.254 in Company: ConocoPhillips Alaska, Inc. Nominal LD.: 2.992 in Country: USA Survey Date: July 5, 2010 Joint Jt. Depth Pr,n. Pen. Pen. Metal Min. Damage Profile No. (Ft) l J~ sel Body % (os~ LD• Comments (% wall) (In~.,= (Ins.) °i, (Ins.) 0 50 100 271.1 8764 ~ ~ 0.00 1 ~ ~~ 2.95 PUP 271.2 8770 +.~ 0 U is 0.00 f~TL _ Penetration Body Metal Loss Body Page 7 r~ U s, PDS Report Cross Sections ~.- Well: 2W-10 Survey Date: July 5, 2010 Field: Kuparuk Tool Type: UW MFC 24 No. 214320 Company: ConocoPhillips Alaska, Inc. Tool Size: 1.69 Country: USA No. of Fingers: 24 Tubin 3.5 ins 9.3 f J-55 8KD EUE Anal st: C. Lucasan Cross Section for Joint 180 at depth 5775.36 ft Tool speed = 43 Nominal ID = 2.992 Nominal OD = 3.500 Rernaining wall area = 99 Tool deviation = 58 " Finger 18 Penetration = 0.08 ins Isolated pitting. 0.08 ins = 31% Wall Penetration HIGH SIDE = UP Cross Sections page 1 PDS Report Cross Sections ,~ s ., Well: 2W-10 Survey Date: July 5, 2010 Field: Kuparuk Tool Type: UW MFC 24 No. 214320 Company: ConocoPhillips Alaska, Inc. Tool Size: 1.69 Country: USA No. of Fingers: 24 Tubin 3.5 ins 9.3 f J-55 8RD EUE Anal st: C. Lucasan Cross Section for Joint 196 at depth 6287.23 ft Tool speed = 43 Nominal ID = 2.992 Nominal OD = 3.500 Remaining wall area = 99 °% ~ Tool deviation = 52 " Finger 20 Penetration = 0.076 ins Isolated pitting. 0.08 ins = 30% Wall Penetration HIGH SIDE = UP Cross Sections page 2 ConocoPhillips G-;^ GSA LIiT, s8a. GAG lI1T, 6,57' G+~ LIfT GL^ LIIT e,3H ABP, 8,33: a ; ooe.=~ IEJ 6CTq 1, 8'.~ P.~L A EA, 8,?K ~IPP LE, 8,78: 3D^o, 8,T6] TTL,e`;0 N Attributes Ibon APl'U'vV'I Reld tl 500292123900 Y.UPP r m ent :KED OL17 Ba e. Tap D I 7f7 rm Last W0: Ltl 1,.trg Anno on 5 Rev Feason: UPDATE PACKER OD Mg ID... Top I; N: Bj set Cbptlt ii.. S et DApth (rl i5.U62 0.0 52.0 3LU ring l0._ TopittK Bl Se DepUr jt.. 9 et 6Apih iTr 8.765 0.0 4,026.0 3.115.7 OAS LIFT STA 8 2YV-10 8.387 5,736.7 49.13 8BR Baker PBR 12!70!1984 2.992 8,400 5,745.2 49.OS PACKER Baker'FHL' PACKER 12!1011984 3.000 $,435 5,770.8 48.31 INJECTION MERLAf<PD"XJi .SJDMYlFt Mffl Comment STA1U 2Y'8f1585 2.875 8,512 5,819.4 47.86 1IJJECTIOIJ MERLPJiPDXl7.5/HFCV/RM1.251J Comrrlent: HISTORY OF 6f25R008 2.875 F LOW CUT STP, Ii 8,724 5,962.4 47.10 INJECTION MERLA?PDW1.51DMY/RMlIJ CnmmenC STA 12 5'5!1997 2.875 8,745 5,9'+6.8 46.86 PACKER BAKER FB-1 PACKER 12110!1984 2.350 70 'ttK6' ehn ittP:Bi Trip i. T.i f,i ittb.el Ren iT.:n1 Ittl~Bl =ona late ^Anr iNt.. r e Comment 8.570 8,674 5,858.3 5,925.5 C-1, C,2, CJ, C4, 2W-10 7!26!1985 12.0 IPERF 5"Dressler .otlas HD; 120 deg phasing 8,700 8,705 5,946.0 5,949.4 UNIT B,2W-1D 1Y28f1985 12.0 IPERF 5"Dressler .6tlas HD; 720 deg phasing 8.836 B$30 6,038.8 6,077.3 A3, A4, 2W-10 12611965 4.0 IPERF 4" Dressler Ptlas JJ; 120 deg phasing 6,837 6,842 6,04U.5 6,043.9 A4,2W-10 1!28/1965 6.0 IPERF 5052179"Enenet; 7'20 dea ohasino P R40 • • Page 1 of 1 , Regg, James B(DOA) Qr~ ~ o~j _ Z23 From: NSK Problem Well Supv [n1617@conocophillips.com] Sent: Sunday, July 26, 2009 3:28 PM ~~~ 7+3~~~ I To; Regg, James B (DOA) ~ Cc: Schwartz, Guy L(DOA); NSK Well integrity Proj; NSK Problem Well Supv; CPF2 Prod Engrs; CPF2 DS Lead Techs NSK Subject: 2W-10 T/IA Pressure During SVS Test Attachments: 2W-10 TIO Plot.pdf Jim, As per the attached TIO plot, the 2W-10 was WAG'd to gas on 6/24/09 and began to experience increasing IA pressure on 7/6/09. The pressure continued to rise until finally stabilizing at + 230Q psi. Also illustrated in the attached piot is injection pressure that has not been below 3500 psi since the WAG date. The average T/IA/OA pressures indicated on the attached plot for the date of the AOGCC inspection are 3802/2300/50. CPAi will investigate the difference in pressures as recorded in our database compared to what was reported by Chuck Scheve during his inspection. I will report the resuits to you once finalized. Please contact me at your convenience if you have questions or comments. Martin Martin Walters / Brent Rogers Problem Welis Supervisor ConocoPhillips Alaska Inc. Office 907-659-7224 Cell 907-943-1720 / 1999 Pager 907-659-7000 #909 ~ r; ~,,.'';~l~~ ~1;~: ~~ _. ~l~Q~ :.*~s From: Regg, James B (DOA) [mailto:jim.regg@alaska.gov] Sent: Wednesday, July 22, 2009 5:22 PM To: NSK Problem Well Supv Cc: Schwar~, Guy L (DOA) Subject: KRU 2W-10 See attached safety valve test report; IA pressure seems high (2300psi; tubing 2500psi). Please review for possible communication - would appreciate a TIO plot. Thank you. Jim Regg AOGCC 333 W.7th Avenue, Suite 100 Anchorage, AK 99501 907-793-1236 7/30/2009 ~ ~~a~nC cvv-iv ~~vica. Date 8!1 i2009 ~ 120 Date 4%3~2009 Annular Communication Surveillance 4500 4000 3500 3000 2500 .Q 2000 1500 1000 500 0 Apr-09 sooo ~ooo 6000 n 5000 J m ~ 4Q00 LL ~ 3000 2000 1000 0 Apr-09 iso 140 120 100 LL 80 d ~ 60 40 20 0 ~ ~ May-09 Jun-09 Jul-09 May-09 Jun-09 Jul-09 Date 1; ,, '~ ,, ~~ ~ .~ ~ o ../ , sc~~umerer NO.4775 Schlumberger -DCS 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Well Job # ~~~ ~UL ~ ~~~~ Log Description Company: Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Kuparuk Date BL Color CD 07/10/08 2W-04 12061711 INJECTION PROFILE jot 06/24/08 1 1 1 L-20A 10215099 PRODUCTION PROFILE QU 'g 06/26/08 1 1 1 G-05 12080389 LDL (p 06/27/08 1 1 36-10 12061714 INJECTION PROFILE T - G / 06/27/08 1 1 2L-327 12061715 SBHP SURVEY 06/28/08 1 1 iJ-109 12080390 SBHP SURVEY / / 06/28/08 1 1 2N-323 12061716 SBHP SURVEY ~ 'fir.- ~ 06/28/08 1 1 2X-15 12080392 SBHP SURVEY G - 06/29/08 1 1 2N-303 12061717 SBHP SURVEY 06/29/08 1 1 2L-309 12061718 SBHP SURVEY 06/29/08 1 1 2X-14 12080391 SBHP SURVEY / 06/29/08 1 1 2X-11 12080393 SBHP SURVEY ~f S~ 06/29/08 1 1 1G-09 12080401 INJECTION PROFILE U --- ( ~(~j 07/05/08 1 1 2H-05 12080396 SBHP SURVEY c°'--- 06/30/08 1 1 2H-12 12080395 SBHP SURVEY _ b~ 06/30/08 1 1 2H-11 12080394 SBHP SURVEY - / 06/30/08 1 1 1D-07 12080398 SBHP SURVEY - .i 07/02/08 1 1 2N-341 12061720 SBHP SURVEY _- p 06/30/08 1 1 3C-15 11982441 USIT - (~(~ / (p 07!04/08 1 1 2W-10 11982445 INJECTION PROFILE ~ - (p 07/08/08 1 1 i L-19 12061724 PRODUCTION PROFILE ~ D -6 07/10/08 1 1 2W-02 11982446 INJECTION PROFILE - ,~ 07/09/08 1 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 State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg P.I. Supervisor ?æ,;'" !V?]' v v DATE: Monday, May 21. 2007 SCBJECT: Mechanical Integrity Tests CO'JOCOPHILLIPS ALASKA 1NC FROM: John Crisp Petroleum Inspector 2\\/-10 KUPARUK RlV UNIT 2W-IO \ töl.\' / q.'Y3 Src: Inspector Reviewed By: P.I. Suprv ~ Comm NON-CONFIDENTIAL Well Name: KUPARUK RIV UNIT 2W-IO API Well Number: 50-029-21239-00-00 Inspector Name: John Crisp Insp N urn: mitJCr070521102604 Permit Number: 184-223-0 Inspection Date: 5/19/2007 ReI Insp N urn: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. I --~---r -~~-- ---,-- Well i 2W-IO ¡Type Inj. j W I TVD I 5745 ¡ IA I 1490 I 2240 2260 I 2265 2270 I ~-T~--+----=": .. . I ! --- +-----------~ I I I -~-- P.T.D' 1842230 jTypeTest : SPT I Test psi 1500 OA 90 I 100 ¡ 100 100 i 100 ~._~~..-.._~---_. " I -- +-------- -- -+- --- -~._- -- f' Tubing I i I Interval 4YRTST P/F .,..Y" ~ 1300 i 1300 1300 I 1300 1300 i ì ------'- -'~-~--- -- ------ Notes: 11 bbl's pumped to achieve test pressure. IA was showing stabilization pressure decrease quickly, I requested Operator to wait 5 minutes & repressure IA to start test. Tota] of 12.5 bbl's pumped for test. IA pressure showing slight increase, tubing remained the same on test gauge. 1/ Possible thermal event or injection rate changes during MIT. I requested well trend chart for this wen during MIT for Supervisors review. Pass/fail determination wi]] be made by PI Supervisor. s~ JUN 0 6 2007 Monday, May 21, 2007 Page I of] c; \ \ 1,1 ZtJDj j,,';OOfk.- R~"''''' E"~--"" ,',I;C'," '~,:".:'''' ",.., '. .... ¡Jf \) I .... . ",,"=.~ \\ f....~,.. M "\ , ",.;:: L.., OCT J (;\ ZUOG Scblumbepger M~u::n (~CT '), 1 2nnô ~ÇAD~n~~,lL..'!'J V [ì c¡h J.. v..... /-~~~~~ Ü1~ g~ 13~;) [(m~" !(./fijt9~~~~it !\f¡~d1niliS:fY.~ Schlumberger -DCS 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth 10/13/06 u=r~ 11)"( - dÐ3 Company: Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Well Job# Log Description Date BL 1J-127 11404957 PROD PROFILE W/DEFT 09/14/06 1 2W-10 11404958 INJECTION PROFILE 09/15/06 1 2W-14 11404960 INJECTION PROFILE 09/17/06 1 2U-01 11404964 PROD PROFILE W/DEFT 09/20/06 1 2A-19A 11415618 PROD PROFILE W/DEFT 09/03/06 1 1 E-04 11421627 INJECTION PROFILE 09/13/06 1 2W-02 11296718 INJECTION PROFILE 09/14/06 1 3H-10B 11296723 PATCH/STATIC SURVEY 09/19/06 1 21 -39 11296724 PROD PROFILE W/DEFT 09/20/06 1 1 L-04 11415626 SBHP SURVEY 09/24/06 1 2V-04 11415628 INJECTION PROFILE 09/26/06 1 1A-17 11415622 PROD PROFILE W/DEFT 09/21/06 1 1 L-06 11415625 SBHP SURVEY 09/24/06 1 1 F-07 11415629 LDL 09/27/06 1 2F-06 11434750 FLOWING BHP SURVEY 10/03/06 1 2A-17 11434751 PROD PROFILE W/DEFT 10/04/06 1 2P-447 11404966 INJECTION PROFILE 10/06/06 1 2V-08A 11216327 USIT 09/21/06 Kuparuk l , Color CD ( Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: THRU: FROM' Randy Ruedrich Commissioner Jim Regg P.I. Supervisor John H. Spaulding Petroleum Inspector DATE: July 12, 2003 SUBJECT: Mechanical Integrity Tests CPAI 2W 9.10, 16 KRU Kuparuk River Field NON- CONFIDENTIAL Packer Depth Pretest Initial 15 Min. 30 Min. WellI 2W-09 TypetestI P ITestpsil 1422 I CasingI 1600I 2050I 2060I 2060I P/F I P I P.T.D.I 1842190 Type _ Notes: I I P.T.D.I ~842230 ITypetestl P ITestpsil 1436 I Casingl 1700 I 2200 I 2100 I 2080 I P/F I B Notes: ~.I.D.I ~842300 I*VpetestI ~ IIestpsil ~ae~ I casin~l ~a2s I 23s°1 2340 ~ 2340 I ~/F I ~ ~oto~: WellI ~Type Inj, P.T.D. ~ Type test Notes: WellI Type Inj. ~otos: Type INJ. Fluid Codes F = FRESH WATER INJ. G = GAS I NJ. S = SALT WATER INJ. N = NOT INJECTING Type Test M= Annulus Monitoring P= Standard Pressure Test R= Internal Radioactive Tracer Survey A= Temperature Anomaly Survey D= Differential Temperature Test Interval I= Initial Test 4= Four Year Cycle V= Required by Variance W= Test during Workover O= Other (describe in notes) Test's Details I traveled to Conoco/Phillips Alaska's KRU 2W pad to witness MIT's on the above wells. The pretest pressures were monitored and found stable, the standard annulus pressure test was performed and meets the AOGCC criteria for a successful MIT. M.I.T.'s performed' _3 Number of Failures: 0 Total Time during tests: 3 Attachments: cc: MIT report form 5/12/00 L.G. 2003-0712_M IT_KR U_2W- 16_js.xls 7/18/2003 / ARCO Alaska, Inc. Post Office B..._.100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 November 10, 1 993 WELL 2W-07 2W-10 Mr. David W. Johnston, Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 'Dear Mr. Johnston: Attached in duplicate are multiple Reports of Sundry Well Operations (Form 10-404) notices in the Kuparuk field. The wells are listed below. ACTION Perforate Perforate If you have any questions, please call me at 263-4241. P. S. White Senior Engineer Kuparuk Petroleum Engineering Gas Cons. co~issiO¢ Anchorage ARCO Alaska, Inc. is a Subsidiary of AtlanlicRichfieldCompany STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMI~-~ON REPORT OF SUNDRY WELL OPERATIONS .~ r '~,~r 1. Type of Request: Operation Shutdown Stimulate Plugging Perforate ~ Pull tubing Alter casing Repair well Other X '~ ~*~ ~ 2. Name of Operator 5. Type of Well: 6. Datum elevation (DF or KB) :~---/..~¢/,~ Development _ ARCO Alask¢,, In~;. Exploratory _ ~5' RKB feet .. 3. Address Stratigraphic _ 7. Unit or Property name P. O. Box 100360, Anchorage, AK 99510 Service X Kuparuk River Unit 4. Location of well at surface 8. Well number 523' FNL, 281' FEL, Sec. 33, T12N, RgE, UM 2W-10 At top of productive interval 9. Permit number/approval number 1404' FNL, 1288' FWL, Sec. 28, T12N, R9E, UM 84-223 At effective depth 10. APl number 1112' FNL, 1091' FWL, Sec. 28, T12N, R8E, UM 50-029-21239 At total depth 11. Field/Pool 1059' FNL, 1056' FWL, Sec. 28, T12N, R8E, UM Kuparuk River Oil Pool 12. Present well condition summary Total Depth' measured 91 4 7' feet Plugs (measured) true vertical 6259' feet None Effective depth: measured 9050' feet Junk (measured) true vertical 61 9 0' feet None Casing Length Size Cemented Measured depth True vertical depth Structural Conductor 9 2' 1 6" 285 Sx AS I 9 2' 9 2' Surface 4027' 9 5/8" 890 Sx AS III & 4027' 31 1 7' Intermediate 550 Sx Class G Production 91 36' 7" 350 Sx Class G & 91 36' 6253' Liner 250 bbl AS 1 Perforation depth: measured 8570'-8674', 8700'-8705' 12 SPF 120 degree phasing; 8835'-8676', 8889'-8909', 8915'-8936', 4 SPF 90 degree phasing true vertical 5858'-5928', 5946'-5950'. 6039'-6066', 6077'-6090', 6094'-6107' TVD Tubing (size, grade, and measured depth) 3.5" J-55 set at 8766' Packers and SSSV (type and measured depth)RECEIVED Baker FHL @ 8400', Baker FB-1 @ 8745'; Baker FVL SSSV @ 1893' 13. Stimulation or cement squeeze summary Reperforate A Sands @ 4 SPF @ 0° phasing l~J0V 1 7 Intervals treated (measured) 8837'-8842', 8851'-8879' MD RKB A,aska 0ii & Gas Cons. C0mmissio~ Treatment description including volumes used and final pressure Anchorage 14. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Md Water-Bbl Casing Pressure Tubing Pressure Prior to well operation (Water Injector) 241 4 1 450 2650 Subsequent to operation 1 9 6 8 1 5 0 0 2 5 7 0 15. Attachments 16. Status of well classification as: Copies of Logs and Surveys run ~ Water Injector X.~ Daily Report of Well Operations X Oil __ Gas Suspended Service 17. I hereby rtify that the/fgregoing is true and correct to the best of my knowledge. Si~ned "'< ~~/~-.~.(/~ ~/~ Title Senior Operations Engineer Date / ['"' /O -' ~,~ Form 10-404 Rev 09/12/90 SUBMIT IN DUPLICATE ARCO Alaska, Inc. Subsidiary of Atlantic Richfield Company WELL SERVICE REPORT IPBDT FIELD-DISTRICT-STATE IDAYS IDSE/ ~ITRACTOR OPERATION AT RE~RT TIME 0q, oo 9~t ~4 ~1 '¢$, ~v..' z.'/s" v~B, cci. 1~,5o I L,,45 5E1' CC b ~o0 ~.~ ~ B HOV 1 7 i~9Z, Alaska UJl & Gas Cons. Commission i--J CHECK.THIS BLOCK IF SUMMARY CONTINUED ON BACK 30(ii Porcupine Drive Anchorage, Alaska ggSal-31 g2 gOT-g7g-1 ~33 The following data is hereby acknowledged as being received: sent to sender: Yes No x~ Copy Alaska Oil Gas Conservation Commission 3001 Porcupine Drive · Anchorage, Alaska 99501-31 §2 907-279-1433 Receipt of the following material which was transmitted via is hereby acknowledged: Quanti~ Description Re cei¥.e.d bY: . .:. c.' Dated: Copy sent to sender:. Yes __----- _ -~ JUN 0 2 1992 ,.--!~_:.' .'-' Alaska 011 &'~a~ Cons. commi"io~ i~-~: '.'::.: i:~:i- Anchorage -~ ':...'.,: . · ~ ~:-~ 'i.. - . _ : , -, . : ARCO Alaska, Inc. ~ Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 September 5, 1991 Mr. David W. Johnston, Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Johnston' Attached in duplicate are multiple Reports of Sundry Well Operations notices in the Kuparuk field. The wells are listed below. WELL AOTION 2 W- 1 0 Other 2 W- 1 4 Other If you have any questions, please call me at 263-4241. P. S. White Senior Operations Engineer cc: KOE Manager ATO 1120 KOE1.4-9 w/o attachments ARCO Alaska, Inc. is a Subsidiary of Atlantic Richfield Company AR3B-6003-C REPORT OF SUNDRY WELL OPERATIONS 1. Type of Request: Operation Shutdown __ Stimulate __ Plugging -..- Perforate .. Pull tubing ----. Alter ¢a$1ng ~ Repair well ._._ Other X 2. Name of Operator 5. Type of Wall: 6. Datum elevation (DF or KB) Devalopme~ '-~ ARCO Alaska. Inc. Exploratory _ 95' RKB feet 3. Address Stratigraphic_ 7. Unit (x Property name P. O. Box 100360, Anchora~le, AK 99510 ser~ce ~ :~ Kuparuk River Unit 4. Location of well at surface 8. Well number 523' FNL, 281' FEL, Sec. 33, T12N, R9E, UM 2W-10 At top of produ~ve Interval 9. Permit number/approval number 1404' FNL, 1288' FWL, Sec. 28, T12N, R9E, UM 84-223 At effective depth 10. APl number 1112' FNL, 1091' FWL, Sec. 28, T12N, R8E, UM so-029-21239 At total depth 11. Field/Pool 1059' FNLr 1056' FWLr Sec. 28r T12N~ R8Er UM Kuparuk River Oil Pool 12. Present well condition summary Total Depth: measured 91 47' feet Plugs (measured) true vertical 6 259' feet Nor~ Effective depth: measured 9 0 5 0' feet Junk (measured) true vertical 61 90' feet Norle Casing bm'tgth Size Cemented Measured depth True vertical depth Structural Conductor 9 2' 1 6" 285 Sx AS I 9 2' 9 2' Surface 4027' 9 5/8" 890 Sx AS III & 4027' 31 17' Intermediate 550 Sx Class G Production 91 3 6' 7" 350 Sx Class G & 91 3 6' 6 2 5 3' Liner 250 bbl AS 1 Perforation depth: measured 8570'-8674', 8700'-8705' 12 SPF 120 degree phasing; 8835'-8676', 8889'-8909', 8915'-8936', 4 SPF 90 degree phasing true vertical Tubing (size, ~'ade, and measured depth) 3.5" J-55 set at 8766' .. Packers and SSSV (type and measured depth) Baker FHL (~ 8400'r Baker FB-1 (~ 8745'; Baker FVL SSSV @ 1893' ~P 13. Stimulation or cement squeeze summary ~---~ ~OJJ ~ P,,,,, ,, Non-selective C Sand profile modification with crosslinked FLOCON biopolymer. ~ ~17~ ',,~=? Intervals treated (measured) ~,~,~.~..~:/~. ~:,.,,~ _-~:~ 8570-8674' MD RKB Treatment description including volumes used and final pressure Pumped 4515 barrels of polymer at 2 BPM. Final treating pressure = 1700 psi. 14. Rem'esentative Daily Averaae Production or Iniection Data oiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation (Water Injector) 1855 475 1 41 8 Subsequent to operation 2 3 7 7 5 7 0 1 4 0 7 15. Attachments 16. Status of wall classification as: Copies of Logs and Surveys run ~ Water Injector X Dally Report of Well Operations X Oil Gas Suspended Service 17. I hereby certify that the foregoing is flue and correct to the best of my knowledge. Sicjned ~ ' Title Senior Operations Engineer Date :nrm I ri-4n4 i:l~v 0.(:1/1 Pl.(Ih RI IRMIT IN 1311Pl IC;ATI= ? WELL ARCO Alaska, Inc v~ Subsidiary of Atlantic Richfield Compan I FIELD - DISTRICT. STATE I ' ,4"d,,°,,%~ d/<. JOPERATION AT REPORT TIME CONTRACTOR / · ,,- " ~ARKS WELL SERVICE REPORT sEP 10 199! A/as,~ 0ii .& Gas Cons. Commission [-] CHECK THIS BLOCK IF SUMMARY CONTINUED ON BACK Weather Temp. Chill Factor I Visibility I Wind Vel. Report "F 'Fi miles ARCOAlaska, Inc ~ Subsidiary of Atlantic Richfield Company. WELL '--NTRACTOR ~cMARKS PBDT FIELD - DISTRICT- STATE OPERATION AT REPORT TIME WELL SERVICE REPORT DAYS I DATE ~ /~ -/~ -?o I-'] CHECK THIS BLOCK IF SUMMARY CONTINUED ON BACK Report 'F "Fi mile~ J Signed knot, ARCOAlaska, Inc ~ ~ubsidiary of Atlantic Richfield Company WELL .4TRACTOR ncMARKS J~/O iPBDT I FIELD - DISTRICT - STATE OPERATION AT REPORT TIME WELL SERVICE REPORT IDAYS !DATE //o~ ~ __ 900 gY'/. $ ~o z~Z,z I--~ CHECK THIS BLOCK IF SUMMARY CONTINUED ON BACK STATE OFALASKA ~? ~f~ ~ .! !~i-[ /~ ALA~57J~ OIL AND GAS ~SERVATION COMM'i~,.~,SION ~ ':'~ APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon _ Suspend _ Alter casing _ Repair well Change approved program_ Operation Shutdown _ Re-enter suspended well_ _ Plugging _ Time extension _ Stimulate _ Pull tubing _ Variance _ Perforate _ Other 2. Name of Operator ARCO Alaska, In¢, 3, Address P. O. Box 100360, Anchorage, AK 99510 5. Type of Well: Development Exploratory Stratigraphic 4. Location of well at surface 523' FNL, 281'FEL, Sec. 33, T12N, R9E, UM At top of productive interval 1404' FNL, 1288' FWL, Sec. 28, T12N, R9E, UM At effective depth 1112' FNL, 1091' FWL, Sec.28, T12N, R8E, UM At total depth 1059' FNL, 1056' FWL, Sec. 28, T12N, R8E, UM 12. Present well condition summary Total Depth: measured true vertical Effective depth: measured true vertical Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: Length 9147' 6259' 9050' 6190' Size feet feet feet feet Plugs (measured) Junk (measured) Cemented 92' 4027' I 6" 9 5/8" 9136' 7" measured 8570'-8674', 8700'-8705' 285 Sx AS I 890 Sx AS III & 550 Sx Class G 350 Sx Class G 250 Sx AS I 6. Datum elevation (DF or KB) RKB ~)5 7. Unit or Property name Kuparuk River Unit feet 8. Well number 2W-10 9, Permit number 84-223 10. APl number $o-029-21 239 11. Field/Pool Kuparuk River Field Kuparuk River Oil Pool ~:'~5;r~e~p6~,Tx~e Ceniml depth 92' 92' 4027' 31 1 7' 9136' 6253' 12 SPF 120 degree phasing; 8835'-8676', 8889'-8909', 8915'-8936' 4 SPF 90 degree phasing true vertical 5858'-5928', 5946'-5950', 6039'-6066', 6077'-6090', 6094'-6107' Tubing (size, grade, and measured depth) 3 1/2" J-55 set at 8766' Packers and SSSV (type and measured depth) Baker FHL @ 8400', Baker FB-1 @ 8745'; Baker FVL SSSV @ 1893' TVD 13. 14. 16. Attachments Description summary of proposal _ Inject polymer into C1 Sand (schedule attached). No BOP Estimated date for commencing operation 15. November 1. 19~)0 If proposal was verbally approved Name of approver Date approved Detailed operation program_ BOP sketch required - through water injection line Status of well classification as: Oil ~ Gas ~ Suspended _ Service WAG Injector FOR COMMISSION USE ONLY Date Conditions of approval: Plug integrity ~ BOP Test~ Location clearance Mechanical Integrity Test_ Subsequent form Original Signed ~Y David W. John~tor~ Approved by order of the Commission Notify Commission so representative may witness require Commissioner Form 10-403 Rev 09/12/90 Approved Copy. Returned : IApproval No. SUBMIT IN TRIPLICATE PFIZER INC. OIL FIELD PRODUCTS GROUP 7315 SHEEPHORN MOUNTAIN LITTLETON, COLORADO 80127 PFIZER OIL FIELD PRODUCTS GROUP TECHNICAL PROPOSAL FLOCON 4800 PROFILE MODIFICATION TREATMENT for ARCO ALASKA KUPARUK RIVER UNIT WELL NO. 2W-10 Due to the permeability heterogeneity that is common in oil producing formations, water injection is usually not uniform throughout a given interval. Zones of higher than average permeability can sometimes take a disproportional amount of injected water, resulting in thief zones. The objective of a profile modification treatment is to reduce the permeability to water in these thief zones and subsequently divert flow of injected water into unswept areas of the reservoir. FLOCON 4800 crosslinked gel treatments are specifically designed for each well using all available data to characterize the reservoir and define the thief zone. The gel system is tailored to yield the most effective gel in the thief zones and once emplaced, divert flow into lower permeability zones to produce a more uniform injection profile. The FLOCON 4800 gel system should provide improved vertical sweep efficiency, leading to incremental oil recovery. GELANT SYSTEM - FLOCON 4800/Cr+3 , / FLOCON 4800/Cr+3 is a two component gelant system specifically developed to improve i~ection well vertical conformance. The Pfizer FLOCON 4800/Cr-- system consists of a low molecular weight biopolymer, (FLOCON 4800P or 4800C), and a crosslinker, (X-LINK 1000 or 2000), that ionically bond to form a three dimensional structure. This type of bonding forms a gel that is psuedoplastic and shear thinning, allowing deep emplacement of the gel into the thief zone. The gels are not degraded by the high shear forces frequently encountered during injection. FLOCON 4800 is supplied as a 3-5% active solution, (4800P), or as a 12-13% active concentrate (4800C). The crosslinking agents, X-LINK 1000 or 2000, are supplied as 7-10% solutions of chromium chloride. Crosslinking produces fluids that can be varied from mobile liquids to nearly impenetrable gels. Gel characteristics can be controlled in virtually all types of injected brines. Viscosity during injection is a few times that of the injection water, based on the injection rate and the amount of shear developed as the gel moves through the perforations and into the formation. The FLOCON 4800 crosslinked gel system is mixed on the surface and injected into the well. After the gel slug has been injected, the tubing is flushed with brine and the well is shut in for two to three days to allow the gel to mature. When the well is brought back on injection, the rate should be increased slowly to avoid abrupt pressure surges on the gel. PFIZER FLOCON 4800 Profile Modification Treatment Design Company : ARCO ALASKA Field : I(UPARUK RIVER UNIT Well Name : WELL NO. 2W-10 Residual Oil Saturation Connate Water Saturation Porosity Makeup Water Specific Gravity Current Injection Pressure (psi) Current Water Injection Rate (BPD) Fraction of Flow Taken by Thief Zone Thief Zone Thickness (ft) Polymer Injection Rate Fraction 0.35 0.22 0.24 1.02 8OO 1000 1.00 8.00 1.00 TREATMENT RADIUS IN THIEF ZONE (ft) TOTAL GEL SLUG VOLUME (bbls) POLYMER INJECTION RATE AVERAGE (BPD) INJECTION TIME (days) 100 4617 1000 4.6 STAGE PERCENT POLYMER POLYMER VOLUM~ RADIUS of slug (PPM) (act lbs) (bbls) (ft) 10 3000 495 462 10 4000 660 462 80 5000 6596 3694 100 95 89 TOTAL 100 7750 4617 ARCO Alaska, Inc. Post Office Bo,,-'100360 Anchorage. Alaska 99510-0360 Telephone 907 276 1215 November 28, 1989 Mr. C. V. Chatterton, Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Chatterton: Subject: Kuparuk River Field Water Injection Surveys Spinner Documentation In compliance with Rule 4 of Conservation Order No. 198, Kuparuk River Field Waterflood Rules, w.e are hereby submitting the sepia and blueline reproductions of the spinner documentation for the injectivity surveys for Kuparuk water injection wells for the Third Quarter, 1989. If you have any questions concerning the information reported, please contact me at 263-4978. Sincerely, M. H. Kraly Operations Engineer MHK:LLP Attachment Oil & Bas Cons. 6ommissioll Anchoracje ARCO Alaska. inc. is a Subsidiary of AtlanticRichf]eldCom9any ADDENDUM WELL: 5/22/86 2W-10 B. J. Tital frac'd Kuparuk "A" sand perfs 8835'-8876', 8889'=8909' & 8915'-8936' in 8 stages per 5/13/86 procedure using diesel, Musol, gelled diesel, 100 mesh & 20/40 sand. Press'd annulus to 1350 psi w/diesel. Tst lns to 7500 psi; OK. Stage #1: Pmp'd 40 bbls 140° diesel w/5% Musol @ 6 BPM w/2000 psi. Stage #2: 75 bbls gelled diesel pad @ 20.5 BPM w/4740-3400 psi. Stage #3: 5 bbls gelled diesel pad @ 22 BPM w/3200 psi. Stage #4: 35 bbls gelled diesel w/.5 ppg 100 mesh @ 21 BPM w/3300 psi. Stage #5: 10 bbls gelled diesel pad @ 21BPM w/2950 psi. Stage #6: 18 bbls gelled diesel w/3 ppg 20/40 @ 20.5 BPM w/3000 psi. Stage #7: 30 bbls gelled diesel w/8 ppg 20/40 @ 20.5 BPM w/3050 psi. Stage #8: 77 bbls gelled diesel flush @ 20.5 BPM, 3000-3480 psi. Pmp'd 700# 100 mesh @ 11,863# 20/40 in formation leaving 537# 20/40 in casing. Load to recover 290 bbls of diesel. Job complete @ 2030 hrs, 5/22/86. Turn well over to Production. Drilling Supervisor Date STATE OF ALASKA ALASK~ OIL AND GAS CONSERVATION COMIV~SION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown [] Stimulate [] Plugging ~ Perforate [] Pull tubing [] Alter Casing [] Other ~ 2. Name of Operator ARCO Alaska, Inc. 3. Address P.O. Box 100360, Anchorage, Alaska 99510 4. Location of well at surface 523' FNL, 281' FEL, Sec. 33, T12N, RgE, UN 5. Datum elevation (DF or KB) RKB 95 Feet/ L 6. Unit or Property name Kuparuk River Unit 7. Well number 2W-10 Injector At top of productive interval 1404' FNL, 1288' FWL, Sec. 28, T12N At effective depth 1059' FNL, 1056' FWL, Sec. 28, T12N At total depth 1059' FNL, 1056' FWL, Sec. 28, T12N , R9E, UM , R9E, UM , R9E, UM 8. Approval number 8-457 9. APl number 50-- 029-21239-00 10. Pool Kuparuk River Oil Pool 11. Present well condition summary Total depth: measured true vertical 9050' 6190' feet Plugs (measured) feet Effective depth: measured 9025' feet Junk (measured) true vertical 6173' feet Casing Length Size Cemented Measured depth Structural Conductor 92' 16I' Yes 92' Surface 4027' 9-5/8" Yes 4027' Intermediate Production 9136' 7" Yes 9136' Liner Perforation depth: measured 88351-8936' MD true vertical 6038'-6109' TVD True Vertical depth 92' 3117' 6253' Tubing (size, grade and measured depth) 3 1/2" 9 3 lb/ft J-55, 8766' Packers and SSSV (typeb--~mL~a~¢~,d~eP~R, Baker FHL @ 8387', Baker FB-1 @ 8745'. 12. stimulation or cement squeeze sum~/~y Intervals treated (measured) N/A Treatment description including volumes used and final pressure N/A 13. Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure (Both Zones) 5000 800 Prior to well operation operati(Aon Sand 0nly) 3500 0 2400 Subsequent to Tubing Pressure 2000 3800 14. Attachments Daily Report of Well Operations Copies of Logs and Surveys Run [] 15. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed..,~/./__..,4..,¢.., ~ .~°'~ ~~2Title "fit/~ ~ Form 10-404 Rev. 12-1-8.5/' .... / Date ~ ~7'~ Submit ih Dul~licate Drillsite Morning Report ARCO Alaska, Inc. ,v' CPF Date 0'-- ~ / - ~,~ Time Status Production Well Status Gas Lift Status Shut-In iWell P.T. or TP Choke Temp Last H2S CSG Pressure PSI Gas i Inj. Rate # SI Zone PSI Bean OF WCO/o PPM 7" 10" Temp MeterTotal MSCFD Hrs Reason ,I Total 3~ ~ ~ Status Injection Well Status I Shut-In WeIIGI, PW inject. PressurePSl~empl Choke CSGPressurePSI Meter InjectionRate ' ' or SW Zone Allowable Actual °F Bean 7" 10" Total BBLS/Day [MMSCFD Hrs. Reason / ' ! 4 3 / o 5'~5" / 2'5-' ,135'.,l i 7~'o ~ Total ~q. V2V / ~, / ~ ~ SWI Total ,,~ ~,, z/~x-// PWl Total Drillsite Coil Temperature °F Coil Pressure PSI Bath Blanket Heater Prod I Test Prod I Test Temp. Gas PSI RunTime Out /~ /~-~, /Ps' / ?$ ~? /,,q /~" ~ ~ Headers Production Water Injection Gas Injection Gas Lift Drain 1-8: Pressu re .,-.9 o~ 9-16: Temperature g'/ 4",/' Comments Operater's Signature Chemicals Type 'Gal/Day ,¢,~!c o I J '/ Tank: Meoh/Diesel Level Temp. ,,. ,i Id /i¢. 3A 224,05,'27~87', STATE OF ALASKA ALAS;,~ OIL AND GAS CONSERVATION COMmiSSION ' ' APPLICATION FOR ,SUNDRY APPROyALS 1. Type of Request: Abandon Suspend;; Operation Shutdown ;] Re-enter suspended well [j Alter casing [] Time extension Change approved program L! Plugging ~ Stimulate -] Pull tubing; i Amend order ~ Perforate r' Other 2. Name of Operator 5. Datum elevation (DF or KB) 3. Address P.O. Box 100360~ Anchora§e~ Alaska 99510 4. Location of well at surface 523' FNL, 281' FEL, Sec. 33, T:[2N, RgE, UM 95 RKB feet 6. Unit or Property name Kuparuk River' Unit 7. Well number 2W- 10 /~d ~ ~<' ~ c,~ At top of productive interval 1404' FNL, 1288' FWL, Sec. 28, T12N, R9E, UM At effective depth 1059' FNL, 1056' FWL, Sec. 28, T12N, R9E, UM At total depth 1059' FNL, 1056' FWL, Sec. 28, T12N, R9E~ UM 11. Present well condition summary Total depth: feet feet measured 9050' true vertical 6190' Plugs (measured) 8. Permit number 84-223 9. APl number 50- 029-21239 10. Pool Kuparuk River Oil Pool Effective depth: measured 9025' feet Junk (measured) true vertical 6173' feet Casing Length Size Cemented Measured depth True Vertical depth Structural Conductor 92' 16" yes 92' 92' Surface 4027' 9-5/8" .yes 4027' 31:[7' Intermediate Production 9136' 7" .yes 9'136' 6253' Liner Perforation depth: measured 8835'-8936' MD true vertical 6038'-6109' TVD RECEIVED Tubing (size, grade and measured depth) JUN ! 0 3 1 / 2" 9.3 1 b/ft, J- 55, 8~{~a 0tl & ~as C0n~. Cornrnis~ion Packers and SSSV (type and measured depth) ~ Anchorage SSSV @ !893' PKR' Baker FHL _fa 8387' R~ FR-~ @ 8745' 12.Attachments Description summary of proposal ~ Detailed operations program ~ BOP sketch 13. Estimated date for commencing operation 6/88 14. If proposal was verbally approved Name of approver Subsequeut Work Reported on No./O- Date approved 15. I hereby certify that the foregoing is true and correct to the_best of my knowledge Signed ~ di~j~. /~ 2 ~ ,,~/~ Title ../~/~. Commission Use Only Conditions of approval Approved by ORIGINAL SIGNED BY I.OMIUlF C RMITH Notify commission so representative may witness ID Plug integrity [] BOP Test ~ Location clearance .~pp,'oved Copy Returned Commissioner Date Approval No. ~ ..~..~_. ~7 by order of the commission Form 10-403 Rev 12-1-85 Submit in triplicate Well 2W-10 Application for Sundry Approval I · Propose conversion from water injector to alternating gas injector. 2. No BOP equipment will be required. 3. The estimated static BHP is 3100 psi at 6200' SS. 4. No workover fluids will be required. jUN Alas~ 0ii & ~as Cons. commission ~chora~e FROM ,J'ok ee~leee Il FROM __ i °o ' CDete) -- i RECEIVED Cons. Commissior~ Anchorage op STATE OF ALASKA ALAS..,,., OIL AND GAS CONSERVATION COM ..... 3SION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown [] StimulateX~ Plugging U Perforate [] Pull tubing [] Alter Casing [] Other [] 2. Name of Operator ARCO Alaska, Inc 3. Address PO Box 100360, Anchorage, AK 99510 4. Location of well at surface ASt2tSo~ FNL, 28,1' FEL..Sec. of produc~we interval 33, T12N, R9E, UM 5. Datum elevation (DF or KB) RKB 95' 6. Unit or Property. name Kuparuk River Unit 2~._~1~11 number 8. Approval number 1404' FNL, 1288' At effective depth 1059' FNL, 1056' At total depth 1059' FNL, 1056' 11. Present well condition summary Total depth: measured 9050 true vertical 6190 FEL, Sec. 28, T12N, R9E, UM FWL, Sec. 28, T12N, R9E, UM FWL_. Sec. 28: T12N, R9E; UM Permit #84-223 9. APl number 50-- 029-2!239-00 10. Pool Kuparuk River Oil Pool feet feet Plugs (measured)None Effective depth' measured 9025 true vertical 6173 Casing Length Structural Conductor 92' Surface 4027' x x x~,texm~k,'~ e Production 9136' xxxL~R~xxxx Perforation depth: measured Size 16" 9.625" feet feet 8835' - 8936' MD Junk (measured) None Cemented Yes Yes Yes Measured depth 92' HD 4027' HD 9136' MD Feet 12. true vertical 6038' - 6109' TVD Tubing (size, grade and measured depth) 3.5", 9.3# J-55, 8766' Packers and SSSV (type and measured depth) Rakc, r FNI and FR-1 Packers - 8387' Stimulation or cement squeeze summary Intervals treated (measured) 8835 ' - 8936' and 8745' 13. Treatment description including volumes used and final pressure Gel 1 ed Diesel Hydraulic Fracture 240 bbls gelled diese'l, 700# 100 MS Sand~ 13~000# 20/40 MS Sand, Final Pressure = 3140 Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation Subsequent to operation 0 1100 625 2000 1540 1300 14. Attachments Daily Report of Well Operations [] Copies of Logs and Surveys Run [] 15. I hereby certify that the foregoing is true and correct to the best of my knowledge S~ ned ,~."~ 'g . . Form 10-404 Rev. ~-1-85 Title Sr. Operations Engineer Date Submit in Duplicate ~ue Vertical depth 92' TVD 3117' TVD 6253' TVB STATE OF ALASKA ALASKA Ui~L AND GAS CONSERVATION CO~r~iMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of ~C;erviee Well OIL Y[~ GAS [] SUSPENDED [] ABANDONED [] SERVICE [] 2. Name of Operator 7. Permit Number ARCO Alaska, Inc. 84-223 3. Address 8. APl Number P. 0. Box 100360, Anchorage, AK 99510 50- 029-21239 4. Location of well at surface 9. Unit or Lease Name 523' FNL, 281' FEL, Sec.33, T12N, R9E, UM Kuparuk River Unit At Top Producing Interval 10. Well Number 1404' FNL, 1288' FWL, Sec.28, T12N, R9E, UM 2W-10 At Total Depth 11. Field and Pool 1059' FNL, 1056' FWL, Sec.28, T12N, R9E, UM Kuparuk River Field 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. Kuparuk River 0il Pool 94' RKBI ADL 25642 ALK 2573 12. Date Spudded 13. DateT.D. Reached 14. Date Comp.,Susp. orAband. I 15. Water Depth, if offshore 116. No. of CompIetions 12/02/84 12/09/84 12/10/84'I N/A feetMSLI 1 17. Total Depth (MD+TVD) 18.PIugBackDepth(MD+I-VD) 19. DirectionaISurvey 20. Depth where SSSV set I 21. Thickness of Permafrost 9147 'MD ,6259 'TVD 9050 'MD ,6190 'TVD YES71~ NO [] 1895 feetMDI 1450' (approx) 22. Type Electric or Other Logs Run D I L/SFL/GR/SP/FDC/CNL/Cal, Gyro 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED i6" 62.5# I-I-~U 5urt 92' 24" 285 sx CS 1i 9-5/8" 36.0# J-55 Surf 4027' 12-1/4" 890 sx AS Ill & 550 sx Class C 7" 26.0# J-55 Surf 9136' 8-1/2" 350 sx Class G & 250 sx AS I 24. Perforations open to Production (MD+TVD of Top and Bottom and 25. TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 8936' - 8915' 3-1/2" 8768' 8402' & 8743' 8889' - 8909' w/4 spf, 120° phasing 8876' 8835 I 26. ACID, FRACTURE, CEMENT SOUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT& KIND OF MATERIAL USED 8700' - 8705' 8570' - 8572' 150 sx Class ,,G,, 8674' - 8570' w/12 spf, 120° phasing See attached Adden. lum, dated 6/9/86, for frac summary. 27. N/A PRODUCTION TEST Date First Production I Method of Operation (FIowing,.gas lift, etc.) 1 Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE IGAS-OILRATIO TEST PERIOD Flow Tubing Casing Pressure CALCULATED,~ OIL-BBL GAS-MCF WATER-BBL iOILGRAVITY-API (corr) Press. 24-HOUR RATE 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. NONE Form 10-407 Rev. 7-1-80 * NOTE: Tubing was run and the well perforated 1/28/85. CONTINUED ON REVERSE SIDE WC1/074 Submit in duplicate ' · ~- .... ' ~"30." ,/-- ~ -;:!: " :" GEOLOGIC MARKERS', : : ; :'" :'" :";' ;'!; :' ;:"-;":':-: ~-:." :: ;: ' '' ' -- '":':"~ORMAT. ION TESTS ' ' ' : ' ' '"' ',. " ' ":' ' t~; !. "' ,' -': ' : ";~ :~-~ - ? .-~ :, : - .: ' ..... ' ': ' '" ' ' ' .~ : :' ' ~ ' "' i: :. . .- .~ . ' - ~ '.; ' .: NAME Include interval tested, pressure data. all fluid~ recovered ~nd gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. Top Upper Sand 8567' 5855' N/A Base Upper Sand 8676' 5928' · Top Lower Sand 8818' 6025' Base Lower Sand 9003' 6156, ,. . 31. LIST OF ATTACHMENTS Addendum (dated 6/9/86) 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Associate Engi Signed ~1~(,,,4.,11U1~/~¢.4~/ Title neer Date INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1' Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24' If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23' Attached supplemental records for this well should show the details of any multiple stage cement- lng and the location of the cementing tool. Item 27' Method of Operation' Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28' If no cores taken, indicate "none". Form 10-407 STATE OF ALASKA ALAS,.. OIL AND GAS CONSERVATION COMN,~.oS. ION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon .,~ Suspend r~ Operation Shutdown ~!, Re-enter suspended well ~,' Alter casing [] Time extension ~ Change approved program~ Plugging [] Stimulate ~ Pull tubing ~ Amend order _~ Perforate ~ Other 2. Name of Operator 5. Datum elevation(DF or KB) ARCO Alaska, Inc. 95 RKB 3. Address 6. UnitorPropertyname Box 100360, Anchorage, Alaska 99510-360 Kuparuk River Unit 4. Location of wellatsurface 523' FNL, 281' FEL, Sec. 33, T12N, R9E Attop of productiveinterval 1404' FNL, 1288' FEL, Sec. 28, T12N, R9E Ateffective depth 1059' FNL, 1056' FEL, Sec. 28, T12N, R9E At total depth 1059' FNL~ 1056' FEL~ Sec. 28, 11. Present well condition summary Total depth: measured 9050 ' true vertical 6190' T12N, R9E feet Plugs (measured) feet Effective depth: measured 9025' feet Junk (measured) true vertical 6173' feet 7. Well number 2W-lO 8. Permit number 84-223 9. APl number 50-- 029-21239-00 10. Pool Kuparuk River Casing Length Size Cemented Measured depth Structural Conductor 92 ' 16" Yes 92 ' Surface 4027 ' 9. 625" Yes 4027' Intermediate Production 9136 ' 7" Yes 9136 ' Liner Perforation depth: measured 8835' - 8936' True Vertical depth 92' 3117' 6253' ,'._:.,' true vertical 6038' - 6109' MAY 2 0 .; Tubing (size, grade and measured depth) 3.5", 9.3# J-55, 8766' Packers and SSSV (type and measured depth) Baker FHL and FB-1 Packers -. 8387' and 8745' 12.Attachments Description summary of proposal ~, Detailed operations program ~ BOP sketch 13. Estimated date for commencing operation May 17, 1986 14. If proposal was verbally approved Name of approver Lonnie C. Smith Date approved May 14, 1986 15. I hereby certify that the foreg, oing is true and correct to the best of my knowledge '('7 .~ , ~' / " '/'/,"~(~ ;"" "' /" - '/~ ~.l, ~"~- . ,., ~_,.~ Title .t ,-~ ,,, .~..-~. .... -, _~.. Signed ..' . ~// .- z ¥' ~ ,,' .,, ~,/ ' Commission Use O~'6ly // I Date /,/' / / / Conditions of approval Notify commission so representative may witness [] Plug ntegrity Approved by I Approval No. [] BOP Test [] Location clearance / ........ ~d¢~missioner the commission Date~ Form 10-403 Rev 12-1-85 Submit in triplicate DESCRIPTION SUMMARY FRACTURE It is proposed that the A Sand in Kuparuk Well 2W-10 be hydraulically fractured and propped to improve injection. The treatment uses gelled diesel as the pad and carrying fluid and 20/40 mesh sand as the proppant. Lines and equipment will be pressure tested to 5000 psi prior to starting the job. Fluid: 350 BBLS Proppant: 14,000 LBS Anticipated Start Date: May 17, 1986 ARCO Alaska, Inc. Post Office B 00360 Anchorage, Aia~ka 99510-0360 Telephone 907 276 1215 January 16, 198~ 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 KupaFuk River Field' on the Well Action Date Performed 1L-1 Conver 1L-7 Conver lQ-2 Conver lQ-7 Conver 1Q-11 Conver 1Q-13 Conver 2B-5 Conver 2B-9 Conver 2C-1 Conver 2C-3 Conver 2C-6 Conver 2C-8 Conver 2D-2 Conver 2D-7 Conver 2D-11 Conver 2D-14 Conver 2F-1 Conver 2F-2 Conver 2F-13 Conver 2F-14 Conver 2G-3 Conver 2G-3 Conver 2G-5 Conver 2G-7 Conver 2G-10 Conver 2~-12 Conver 2G-16 Conver 2U-3 Conver 2U-4 Conver 2U-7 Conver 2U-16 Conver 2W-2 Conver 2W-4 Conver s on s on s on s on s on s on s on S Or3 s on s on s on s on $ on s on s on s on · s on s on · S on · $ on · s on · $ on S'on · $ on · S on · s on · S on s on · S on s on · $ on · s on · S on 11/18/85 11/18/85 11/17/85 11/17/85 11/17/85 11/17/85 11/23/85 11/23/85 11/19/85 11/19/85 11/19/85 11/19/85 11/20/85 11/20/85 11/20/85 11/20/85 11/21/85 11/21/85 11/2i/85 11/21/85 11/14/85 11114/85 11/14/85 11/14/85 11/14/85 11/14/85 11/14/85 11/16/85 RECEIVED 11/16/85 ~ ~,... 11 / 1 6/85 JAN. ) 11/16/85 11 / 1 5 / 8~k~ OU & Gas Cons, ~orr~ls~:ierl 11 / 22 / 85 A.".:ho?.n~ ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany ~Ar. C. V. Chatterton, Well Action Chairman Date Performed Page 2W-5 Conversion 2W-8 Conve rs i on 2W-1 0 Conver s i on 2W-1 4 Conve rs i on 2W-16 Conversion 2X-2 Conversion 2X-4 Conversion 2X-5 Conversion 2Z-9 Conversion 2Z-11 Conversion 2Z-14 Conversion 2Z-16 Conversion 11122/85 11115185 11/15/85 11/15/85 11/22/85 11118185 11118185 11118185 11117185 11/17/85 11117185 11117185 If you have any quest ions, please T. M. Drumm Kuparuk Operations Coordinator TMD/kmc Attachment (Duplicate) call me at 263-4212. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION SUNDRY NOTICES AND REPORTS ON WELLS DRILLING WELL[] COMPLETED WELL OTHER [] 2. Name of Operator ARCO ALASKA, INC. 3. Address P. O. BOX 100360, 4. Location of Well SURFACE LOCATION' T12N, RgE, UM 5. Elevation in feet (indicate KB, DF, etc.) 95' (RKB) ANCHORAGE, ALASKA 99510 523' FNL, 281' FEL, Sec. 33, 6. Lease Designation and Serial No. ADL 256q2, ALK 2573 7. Permit No. 85-223 8. APl Number s0- 029-21239 9. Unit or Lease Name KUPARUK RIVER UN IT 10. Well Number 2W-10 11, Field and Pool KUPARUK RIVER FI ELD KUPARUK RIVER OIL POOL 12. Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate [] Alter Casing [] Perforations [] Altering Casing Stimulate [] Abandon [] Stimulation [] Abandonment Repair Well [] Change Plans [] Repairs Made [] Other Pull Tubing [] Other [] Pulling Tubing [] (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). On November 15, 1985 Kuparuk well 2W-10 was converted from a producer to a water injector well as part of the full field waterflood conversion effort. Water is being injected into both "A" and "C" sands. the 14. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed J /~'~f~-'~ ~-,~/'~"~'~" Title KI_IpARI IK The space below for Commission use OPERAT IONS COORD ! NATOR Date 1 2 / 1 8 / 8 5 Conditions of Approval, if any: By Order of Approved by COMMISSIONER the Commission Date Form 10-403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate ARCO Alaska, Inc. Post Office Bt~,~ 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 September 20, 1985 Mr. L. C. Smith Alaska Oil and Gas Conservation Commission 3001 Porcupine Street Anchorage, AK 99501 Dear L. C. Smith: Per our conversation on September 4, 1985, ARCO Alaska, Inc. proposes to convert 110 production wells to water injection to implement fullfield waterflood of the Kuparuk River Unit. As discussed a single "blanket" sundry notice (form 10-403) has been completed for all well proposed to be converted to water injection. Individual subsequent sundry notices will be filed when the actual well conversions occur. As stated in form 10-403, well conversion to water injection will occur in two primary stages. The first stage will convert approximately four wells per drillsite to achieve a nine-spot pattern. First stage conversions are expected to be completed by approximately 10/15/85, prior to waterflood startup. The second stage of conversions will convert approximately four additional wells per dril!site to achieve a line drive pattern. Second stage conversions are expected to be completed mid-December to January 1986. I would like to express my thanks and appreciation to the Commission in working with ARCO Alaska, Inc. in this area. If you have any questions please call me at 263-4212. Sincerely, T. M. Drumm Kuparuk Operations Coordinator cc: J.F. Beall TMD:ps:013 ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany STATE OF ALASKA ALASKA 'L AND GAS CONSERVATION C¢ 1MISSION SUNDRY NOTICES AND REPORT ON WELLS 1. DRILLING WELL [] COMPLETED WELL ~3 OTHER [] 2. Name of Operator 7. Permit No. ARCO Alaska, Inc. see attached 3. Address 8. APl Number P.O. Box 100360, Anchorage, Alaska 99510 50- see attached 4. Location of Well · N/A 5. Elevation in feet (indicate KB, DF, etc.) N/A 12. 9. Unit or Lease Name Kuparuk River Unit 10. Well Number see attached I6. Lease Designation and Serial No. see attached Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT CFi (Submit in Triplicate) Perforate [] Alter Casing [] Perforations Stimulate [] Abandon [] Stimulation Repair Well [] Change Plans ~ Repairs Made Pull Tubing [] Other X~ Pulling Tubing (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 11. Field and Pool Kuparuk River Field Kuparuk River Oil Pool (Submit in Duplicate) [] Altering Casing [] [] Abandonment [] [] Other [] 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). Pursuant to form 10-403, it is proposed that the attached list of J^producing wells in the Kuparuk River Field be converted to water injection. The conversion will occur in two stages. The first conversion.- to a nine-spot pattern will occur approximately 10/15/85. The second conversion to a line drive pattern will occur approximately 12/15/85. Injection will be into the A and C sands. ECEIVED sEP 2 o AlasKa 0il & Gas Cons, Commission Anchorage 14. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ~' /~'~¢~ ~'~ Title Kuparuk Operations Coordinator Date The space below for Commission use 9/18/85 Conditions of Approval, if any: Approved by ..~ ~ '~ ' Rev. 7-1-80 Approved Copy J~,~turn~ / .... By Order of COMMISSIONER the Commission Date Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate -14 -16 2X- 1 - 2 - 3 - 4 - 5 - 6 - 7 - 8 2Z- 2 3 6 8 9 11 14 16 223 237 239 83- 84 103 109 118 107 110 113 114 83- 80 85 77 38 85-138 107 109 21239 21253 21255 029-20963 20982 20987 20995 20985 20988 029-20991 20992 029-20960 20964 20957 20924 21377 21379 21361 21363 25645 I! 25645 25653 25646 25653 25646 2576 2576 2579 2577 2579 2577 10 10 12 /15/85 /15/85 lO/15/85 12/15/85 lO/15/85 12/15/85 12/15/85 lO/15/85 12/15/85 lO/15/85 lO/15/85 lO/15/85 10/15/86 lO/15/85 12/15/85 12/15/85 12/15/85 12/15/85 MARK:0093 RECEIVED b~_P2U ,..~,,,,,. . AlasKa Oil & Gas Cons. Commms',or~ Anchorage ARCO Alaska, Inc. ~ Post Office Box ' '0 Anchorage, Alaska =-~510 Telephone 907 276 1215 · o November 14, 1984 Mrs. Elaine johnson State of Alaska Alaska Oil & Gas Conservation~ Commi s s i on 3001 Porcupine Drive. Anchorage, AK 99501 SUBJECT: Conductor As-Built Location Plats - 2W Pad Wells 1-8, 9-16- Dear Elaine: Enclosed are as-built location plats for the subject.wells. you have any questions, please call me at 263-4944.. Sincerely, Gruber Associate Engineer ,. JG/tw .GRU2/L93 Enclosures If AUGOll B5 - ~,' ~, G:~s Cons. commission Anchorage ARCO Alaska. Inc. Is · Subsidiary of AllanllcRIchfleldCompany PHASE ]Z AS-BUILT WELLS 9 Thru 16 2s 27 34- El' WELLS I (NSK 9. O5.223d!) AS-BUILT Thru 8 ~ELL g Y - $,gTg.g83.a$ LA?. 70°2],23.3383. X - $Z8.782.8! L01;. Z49eS0,$0.88&7. PlO £L£V. ~3.1 O.&. EL£V. 304 F£L $79 FNL $£C. 33 WELL Y - 5.g80.039.49 LAT. 70e21,23.8830. X . 518.805.0g LgNG. 1~g~SO,ES.2C33- ~*~ ELEV. ~3.~ 3.G. ELEY. ~g.g 28! tEL 523 ~NL SEC. ~3 WELL II' I , 5,9B0.095.05 L~T. 70°2!,2~.4258, X - 518.S27.61 LONG. I~g:50~49.~408,, PA0 £LEV. ~3.8 0.~. ELEV. 60.2 ~S8 ~EL ~88 rNL SEC. 33 ~ELL 12 ¥ - 5,980,150.70 LAT. 70°21,2~.9757,, X , 516,850.03 LONG. P~D ELEV. 53.~ 235 FEL 412 ~NL SEC. 33 ~ELL 13 Y - 5,980,31~.6§ LAT. ?0321,23.63~G,, X · 5~9,~83.71 LONG. PAD ELE¥. 52.7 0.~. ELE¥. 57.7 ~8 ~WL 5~8 WELL 1~ Y - S.g73,g§o.o$ LAT. 70o21,~3.~927 x . 519',!§1.31 L:NG. PA~ ELEV. 62.9 0.2. ELEV. 57.7 75 ?~L 503 ~NL SEC. WELL 15 Y - 5,~79,;04.~ L~. 7D°21,22.~67., X . 519.138.60 PAO ELEV. 52.0 0.~. EL£V. §~.0 52 ?WL WELL ¥ - 5,979.848.89- LAT. 70°2~,22.0005,, ~ = 5Z9,116.25 LONG. ~AO ELEV. 52.9 O.G. ELEV. 29 FWL 715 FNL SEC. LOCATED IN PROTRACTED SECT IONS 33 & :,'34 TOWNSHIP 12 N., RANGE 9 E.,.,.UMIAT MER. NO SCALE RECE'!VED NOTE' BASIS OF POSITION IS MONUMENTATION AUG0 i~ ?~o85 2W NORTH AND ?.W SOUTH PER LHD ~ ASSOCIATES. Ala Oil & Z7 T S ' Itk_ / TIINIj] r. P,,<:~,.~.~..~; L ' - ~_ · I /~ ';~~ / I1:,_~- DRILL , I; ill!l!~ CONDUCTOR ,__m__ ' Oct. 23, 1984 LICENSED. "')FRAC-ICE LAND gUAVFV'NG IN THE STATE OF A'.ASK~ ........ ~:;0 THA' ~,IS ~LA' ~'PRE2EN~ A SURVEY MA UNDER MY 2IRECT SUF£RV;S~ON 't;[ THAT ~,LL DETAILS ,:,RE C..,FF~E,,.:"' A3 Of OCTOBER 14, 1984. Alosko, Inc. ~jorth Slope ~'r,il SITE 2W AS-BUILT LOCATIONS $co~e &S SMOWN Ai~CO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 June 27, 1985 Mr. C. V.'Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT' Well Completion Reports Dear Mr. Chatterton' Enclosed are Well Completion Reports for the following wells- 3B-13 2W-10 If you have any questions, please call me at 263-4944. Sincerely, Gruber Associate Engineer JG/tw GRU10/L25 Enclosures Alaska Oil & Gas Cons. Commission Anchoraga ARCO Alaska, Inc. is a Subsidiary of AtlanlicRichfieldCompany , STATE OF ALASKA · ALASKA, ...... AND GAS CONSERVATION CC,__dlSSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well OIL [~X GAS [] SUSPENDED [] ABANDONED [] SERVICE [] 2. Name of Operator 7. Permit Number ARCO Alaska, Inc. 84-223 3. Address 8. APl Number P. 0. Box 100360, Anchorage, AK 99510 50- 029-21239 4. Location of well at surface 9. Unit or Lease Name 523' FNL, 281' FEL, Sec.33, T12N, R9E, UN Kuparuk River Unit At Top Producing Interval 10. Well Number 1404' FNL, 1288' FWL, Sec.28, T12N, R9E, UM 2W-10 At Total Depth 11. Field and Pool 1059' FNL, 1056' FWL, Sec.28, T12N, R9E, UM Kuparuk River Field 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. Kuparuk River 0i 1 Pool 94' RKB ADL 25642 ALK 2573 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. 15. Water Depth, if offshore 16. No. of Completions 1 2/02/84 1 2/09/84 1 2/10/84* N/A feet MSL. 1 17. Total Depth (MD+TVD) 18.Plug Back Depth (MD+TVD) 19. Directional Survey I 20. Depth where SSSV set 21. ThickneSs of Permafrost 9147'MD,G259'TVD 9050'MD,6190'TVD YES [] NO []I 1895 feet MD 1450' (Approx) 22. Type Electric or Other Logs Run D I L/SFL/GR/SP/FDC/CNL/Cal, Gyro 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 16" 62.5# H-40 Surf 92' 24" 285 sx CS I I 9-5/8" 36.0# J-55 Surf 4027' 12-1/4" 890 sx AS III & 550 sx Class G 7" 26.0# J-55 Surf 9136' 8-1/2" 350 sx Class G & 250 s> AS I 24. Perforations open to Production (MD+TVD of Top and Bottom and 25. TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 8936' - 8915' 3-1/2" 8768' 8402' & 8743' 8889' - 8909' w/4 spf, 120° phasing 8876' - 8835' 26. ACID, FRACTURE, CEMENTSOuEEzE,ETC. DEPTH INTERVAL (MD} AMOUNT& KIND OF MATERIAL USED 8700' - 8705' 8570' - 8572' 150 sx Class "G" 8674' - 8570' w/12 spf, 120° phasing 27. N/A PRODUCTION TEST Date First Production I Method of Operation (Flowing, gas lift, etc.} I Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE GAS-OIL RATIO TEST PERIOD Flow Tubing Casing Pressure CALCULATED.~ OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press. 24-HOUR RATE 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. NONE . ~'~-~, ~. ,-,'/i Form 10-407 Rev. 7-1-80 NOTE: Tubing was run and the well perforated 1/28/85, ~,/,T,~.R/WO_,~?fi?fS~,~, Subm,t in duplicate CONTINUED ON REVERSE SIDE NAME Include interval tested, pressure data, all fluids recover~ and gravity, MEAS. DEPTH TRUE VERT. DEPTH :GOR,.and time;of.each phase, v? '=~ . . , '. .. _ . . '.' . , .- - . . . . BaSe Upper Sand 8676' 5928~ Base Lower Sand 9003' 6156" - , ... ., .- . , .~ ., . . - . 31. LIST OF ATTACHMENTS 32. I hereby certify that the foregoing i¢ true and correct to thebest of my knowledge .. . Signed ~& ~_ _~-~_ Title AS SOO~ ate Eng~ neap Date INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. .. ... Item 1' Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. . Item 5' Indicate which elevation is used as reference (where not otherWise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval 'to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23' Attached supplemental records for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. Item 27: Method of Operation- Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". Form 10-407 ? ARCO Oil and Gas Company -_ Well History - Initial Report- Daily Inatructlonl: Prepare and submit the "lnlflll Report" on the first Wednesday after a well is spudded or work@vet operations are started. Daily wore prior to spuddJng should be summarized on the form giving inclusive dates only. District Alaska Field Kuparuk River Auth. or W.O. no. AFE 203637 Roll'N #4 ICounW, parish or borough North Slope Borough ADL 2564S or Unit Completion IState Alaska IWell no. 2W-10 API 50-029-21239 Operator ARCO Alaska, Inc. Spudded or W.O. begun Complete Date and depth as of 8:00 a.m. 1/22/85 1/23/85 1/24/85 1/25/85 1/26/85 thru 1/28/85 Tho above is correct Signature For form preparatl~'n-ahd-'~lst~'i'~u~l~n,~' -' soo Procedures Manu~, Section 10, Drilling, Pages 86 and 87. I ARCO W.L lDate 1/22/85 IH°ur 0630 hrs. IPri°r status if a w'°' Complete record for each day reported Waiting on weather. Moving to DS 2W-10. 56.24% 9050' PBTD, Staging sqz 10.2 NaC1/NaBr 10.2 ppg NaC1/NaBr Set RTTS @ 8344', att to sqz perfs w/100 sx C1 "G" cmt. cmt, WOC. Resqz w/75 sx C1 "G" cmt; no sqz. Clear perfs of 9050' PBTD, WOC, 10.2 NaC1/NaBr WOC. Sqz w/150 sx C1 "G" blend. Final sqz press = 2000 psi. POOH w/RTTS, WOC. RIH to 6000' w/bit, WOC. 7" @ 9136' 9050' PBTD, 9147' TD, Rn'g 3½" compl string 10.2 NaC1/NaBr RIH, tag cmt @ 8349', drl to 9016', tst sqz holes, circ well to brine. RU WL, RIH w/4" csg guns @ 4 SPF, 120° phasing. Perf 8936'-8915', 8889'-8909', 8876'-8835'. RIH w/5" csg guns @ 12 SPF, 120° phasing, perf 8700'-8705' & 8674'-8570'. Rn gauge ring/JB to 8850'. RIH w/Bkr FB-1 perm pkr & tailpipe, set pkr @ 8745' WLM, RD WL. RU & begin rn'g 3½", 9.3#, J-55 IPC, 8RD EUE CA. IDate 2/22/85 I 'title Drilling Superintendent 9050' PBTD, TIH w/7" Champ pkr 10.2 NaC1/NaBr Accept ri~ @ 0630 hrs, 1/22/85. ND tree, NU BOPE. TIH w/6.125" gage ring/JB to 9037'. Tst BOPE to 3000 psi. Perf f/8570'-8572' w/4", 4 SPF csg guns. TIH w/Champ pkr, PU 2-7/8" tbg. ARCO Oil and Gas company Daily w~i History-Final Report Instructions: Prepare and submit the "Final Report" on the first Wednesday after allowable has been assigned or well is Plugged, Abandoned, or Sold. "Final Reporl" should be submitted also when operations are suspended for an indefinite or appreciable length of time. On workovers when an official test [$ riot required upon completion, report completion and representative test data in blocks provided. The "Final Report" form may be used for reporting the entire operation it space is avadable. IAccounting cost center code State Alaska District JCounty or Parish Alaska I North Slope Borough Field ~Lease or Unit Kuparuk River I ADL 25645 Auth. or W.O. no. /Title AFE 203637 I Completion Well no. 2W- 10 Roll'N #4 Operator ARCO Alaska, Inc. Spudded or W.O. begun Complete AP1 50-029-21239 A.R.Co. W.I. [Total number of wells (active or inactive) on this Jcost center prior to plugging and J 56,2470 Jabandonment of this well I Date JHour J Prior status if a W.O. 1/22/85 J 0630 hrs. I Date and depth as of 8:00 a.m. 1/29/85 Complete record for each day reported 7" @ 9136' 9050' PBTD, 9147' TD, RR Crude/Diesel RIH w/265 jts, 3½" tbg. Set pkr & lnd tbg. ND BOPE. Displ well w/crude. Set BPV. RR @ 2400 hrs, 1/28/85. 2W-12. FHL Pkr @ 8402.19' - FB-1 Perm Pkr @ 8743.22' 'iD" Nipple @ 8759.55' - TT @ 8767.90' NU tree. Move to Old TO New TD Released rig Date 2400 hrs. Classifications (oil, gas, etc.) 0il I PB Depth 9147' JKind of rig I 1/28/85 Type completion (single, dual, etc.) Single Producing method Official reservoir name(s) Flowing Kuparuk Sands Potential test data 9050' PBTD Rotary Well no. Date Reservoir Producing Interval Oil or gas Test time Production Oil on t~sF .: ~ i 'GaS per~d.ay: Pump size, SPM X length Choke size T.P. C.P. I Water % GOR Gravity Allowable -._i ~ i ~:,; :~ ~Effect[v,e~ date ...... ted ...... The above is correct Signature I Date ITitle .,//~::~/~ _.....~,..~, 2/22/85 For form ;rep~ralio~%n;"~i-~ributi%~,-- see Procedures Manual, Section 10, Drilling, Pages 86 and 87. Drilling Superintendent Bill Sheffield, Governor ALASKA OIL ,4rD ~A$ ~',O#$E,~rAi~ION.(',Of~fMI$$10# / ~o., PO~CUPINE D~IVE We wt~l~ to bring to your ~ttentton that the yet received the following ~equired ttem~ on th~ ~ubJec~ ~ell Oh/ch our record~ 'Indicated ~ completed . /~-/~-~ Article 536(b) of Title 20, Chapter 25, Alaska Administrative Code, stipulates that this mntertal shall be filed within 30 dayB after completion of a drilled.well. Flease submit the above missing material. · Chairman lc~C.02~ ARCO Alaska, Inc. Post Offi :~ox 100360 Anchorage'Alaska 99510-0360 Telephone 907 276 1215 ARCC) AL,.-,.~kA; IHC, A'F'rN.- RI:-.CORDP. C.L. ERK ATC)-i t i 5B F:',O, P. OY i00760 t.':i ~'l.! (] ~-'! () l";: .A r]- lE .,.. i.'.-iI.:.~ ,t:,,,-,,.~_..-.~,l · · DA'f'E APRIL TRANS'HZTTAL NO' t 985 ....' t 4 8 liE:Rr..'hll'TH ARE TI-ir--" F'O! I FII.,.;:I:f./G ITEH£ F'I.-E:A'r'E A"- ........................... · .. C r... N 0 l,,J L E. I) 6 E I.:.:E:Tt..~r:.:N ONli..'. ,~I,';.;NED COI.'.'Y OF 'Fl-IlS 'FRANSM:rTTAL, ,..,(..E/INTEr. t:HITTE:NT LIFT F'F;:E.',.?,?URE SURVEY ,~O:U.,,'F'RC)D I..0(.'; & 'A' 3."AND F'I::U 5'OI!:'./F'T.,'I! .... ( T. NTTIAI_,., ,? 0 E / F' B U £OE,/F'.E:L.I ,?. OE/F'BU ,~ · ~ ,.~01:-/' C' 'SA ,.:- .. E/5'BHP STAT]:C BHP JTATIC BHF' STATIC BHF' £TATIC BI-IF' XTATIC BHF' ,?TATIC BHF' ,gTATIC BHF' :~'FATIC BHF' ~'f'A T.T. CBHP £TATIC BI. iF' 5'TAT]: F: '" . .::-,I. IF:' ,-qTATI C BI-iF' ,?TAT.'[ C B Hr.:' .'-:7 TAT i r' r_,~ ,,-, ,,... JLI ,"1 I "' ::TAT'lC .F.= H F' ,~T f:iT T r' r., LI m, · ~. ~...' .-~': i ! .?TA T~. C BHP ~TATIC FjH,r' 5'TATIC BI-IP ,~TAT:[ C r::l..IP ~ '!'AT ]:C ~I. IF' ,~TATIC ~ !-!F' 7'- '- ' "'"a V-" EDGED' ,::.C~:- Z F'T AC:,, -:F ~-.~E ::, C U.,.'::.:R I E R . "~--I !:f V R 0 N ND F'BU 'A' & DATA DATA DATA DATA DATA DATA DATA DATA DATA D A T A DATA DATA D A T A DATA D A T A DATA DATA DATA DAT'A DATA D,~,A D~T~.-i F' Fi'. E 5' £,' LJ F;,' E ) 'C' ,5'ANDS' 0. DRILLING W F'AS'Hr-:r:' L. ~°'..';'.' ~TnN EX,",(O N ,~ ,..I ~-./I I1~.~~, __ , · MOBIL F'HILLZF'5' OIL N,~.K CLERK d. F:ATI-iHELL 4/6-7/85 3/f t/85 ,. ~/'~6/05 ':/2/85,-' t124/85, 3/2/85 /2/85 3/2/85 3/t 7/~ 3/I o 3/24/85 1/25/85 ~= 85 i/5/85 t/24'/85 "f t/on RECEIVED APR 2 5 1 85 Alaska Oil ~ 6as 0ohs' ~ . . uO~lSSlO~ DATE' ,, ,~.~ /~iAI II K TWLr~' ARCO AlasKa, Inc ' ' · . Post Office Box 100360 Anchorage, Alaska 99510-0360 Tdepht)ne 907 276 1215 · , . . Rli:'T'UI':CN TO' AF<CO AI_A,?I<A; INC., · A 1' T N" R IZ C 0 R I) ,'.~' C I._ Ii: R I< A T {.].- i i i :> £ P~O~ BOX i0036() ANCHOI'::AF~.E, Al( 795i (') . · T F" ;",' ~ ';' =i T 'T"T' [.'. D I..FF.;i R E W I T Ii A R E: T I-.i E F' (3 I... L 0 W I H G R E C [.'. I F.' T .A t'..:D R 1:7. T U R N 0 iq E 3' I (: N E D [... 3 F Y ° ' ; .~ ~ I' % I) A']r'E. 4 .... ii-85 'F R A N.'; I,i I T T A L N O · I T E H ~i', . P L. E A 3 J-:. 01r 'F H I S 'F R A N 3 i"i I 'T T A I... (;.E;-'-,I';:H,'~R'F 'F'IN?,L_' I':'RIN'f'~' (ONI"!~ · .x. OF I:,;:;CH) PPI ...... -.. i:;: % :1: N :-':~ L F:' R l N'i" 3 ( O N E . . R l.I ~'~ ~':: i . , R U i--.~. .,,.'"' i R U i'.~ .,,-'"' i I"< U i',! '"' 'II' l R i..i N .:~-' .t RUN "'~: i .RUN .",,': i '": '"' '" 0 7'240 ...' · ,,,;; I' "" 799(')-9498 600(') .... 8t81 5:000" <::, '"'," 8 ,::,'"' / --, o,'~0 .... :iG'? , · 01'" I'Z A C l"l ';, ,o · ARCO Alaska, Inc. Post Office E,,.x 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 (' 0 N [!: .. %? .~j., .... I:.'.. 0 F:' Y 8 F' 'i' I' I:[ S CCi F' Y 0 I:" [: A C I.-I ) ARCO Alaska, In Post Office Lox 360 Anchorage, Alaska 99510 Telephone 907 277 5637 '-I;;/-" ?'I ('£ r') i'~ ')" 1' "-.? (;~ 'T ;',; ,? (:! %]; ,'? · I"'.."" '?~ ~"' ~" ....Il ,~.; ..., ..... .I....I t. J i .L ,.':. 0 i" T ;.-, ...j l.l~ I~;)! Ir:' ".:' I"~T """ .L i'"~ "i-',r -.'.', · ..: i 4. ~.;. [-: :", ;:4 ": f"l 1... ~"li I L.- '...~ E: f'.:~ ,;'"i ('_'- " .... i"iC 0 '.... ?t"'i~ IF"~ 1 .: '..., '.-:.: C;. :... L.. ...... '...:; ... i... L_ L_ '¢' I f.l!l'-l~ ....... .,..,.. ..... L-..- ~ -I llll,"'l.-!r"'--:' ..... ~I;~ I" ;[ E: ;::'~ j"'~ C' C',' C; (:'-, i":i ;"'"l .. -..: :.. "" "~" ]I ¢' ,..! ,.;. ,,'.'~-'? r-:'. -... .L ,.', (i;I "f'.,.'r ,.,":' C.,' f' ]I ;? il;) 'f' ]I I"~ '¥' 'r -.'"- ... ~ .,. ~.-. ARCO Alaska, Inc. Post Office [3c.~ 100360 Anchorage; Alaska 99510-0360 'Felephone 907 276 1215 Narch 14, 1985 Mr. C. V. Chatterton Commi s s i one r State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT' 2W-10 Dear Mr. Chatterton' Enclosed is a copy of the 2W-10 Well History to include with the Well Completon Report, dated 01/28/85. If you have any questions, please call me at 263-4944. Sincerely, J. Gruber Associate Engineer JG/tw GRU5/L27 Enclosure ARCO Alaska, Inc. is a Subsidiary of AtJantJcRichfieldCompany ARCO Alaska, Inc. Post Office B,'~ 360 Anchorsge,~ _~ ka 99510 Telephone 907 277 5637 Date:02/20/85 Transmittal No: 506'2~ RETURN TO: ARCO ALASKA, INC. ATTN: Records Clerk ATO-1115B P.O. Box 100360 chorage, AK 99510 itted herewith are the following items. Please acknowledge receipt turn one signed copy of this transmittal. OPEN HOLE FINALS (One blueline and-one sepia each). Schlumberger 2E-15 5" Dual Dipmeter 11/19/84 Run #3 2608-6942 5" Cyberdip 11/19/84 Run #3 2608-6942 5" Cyberlook 11/17/84 Run #3 2608-6890 2" FDC/CNL (Porosity) 11/17/84 Run #3 2608-6911 5" FDC/CNL (Porosity) 11/17.84 Run #3 2608-6911 2" FDC/CNL (Raw Data) 11/17/84 Run #3 2608-6911 5!' FDC/CNL (Raw Data) 11/17/84 Run #3 2608-6911 2" DIL/SFL 11/17/84 Run #3 2608-6936 5" DIL/SFL 11/17/84 Run #3 2608-6936 2" BHC Sonic 11/17/84 Run #3 2608-6938 5" BHC Sonic 11/.~7/84 Run #3 2608-6938 2W-10 2" DIL/SFL-GR 12/09/84 Run'#l 5" DIL/SFL-GR 12/09/84 Run #1 2" Density/Neutron-GR 12/09/84 Run '#1 (Raw Data) ~' 5" Density/Neutron-GR 12/09/84 Run #1 (Raw Data) 2" Density/Neutron-GR 12/09/84 Run #t (Porosity) Density/Neutron-GR 12/09/84 Run #1 (Porosity) Cyberlook 12/09/84 Run #1 511 11 Receipt Acknowledged: DISTRIBUTION -B. Currier Drillin~ BPAE Geology Chevron Mobil 4'02'7- ~ 12 4 4027-9124 8300-9093 8300-9093 8300-9093 8300-9093 W. Pasher G. Phillips 8300-9070 Phillips Oil Union D&M NSK Drill Clerk J. Rathmell Well Files ARCO Alaska. InC. i~, I subsidiary of AllantJcRJchli~.ldCompa.¥ ARCO Alaska, Inc. Post Office Box 1'00360 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: 2W-10 Dear Mr. Chatterton' Enclosed are the Well Completion Report and gyroscopic survey for the subject well. I have not received the portion of the 2W-10 Well History covering the completion details. When I do, ! will forward a copy to you. If you have any questions, please call me at 263-4944. Sincerely, . '~ L4 ~.,. L/~j I ,.~ I'~,..- . G~ube~ Associate Eng~neeP JG/tw GRU3/L86 Enclosures RECEIVED Alaska 0il & Gaa Cone. Commission Anchorage ARCO Alaska. Inc. is a Subsidiary of AtlanticRichfieldCompany STATE OF ALASKA ALASKA C._~ AND GAS CONSERVATION CO~. ,_ ,IlSSlON WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well OIL [] GAS [] SUSPENDED E~x ABANDONED [] SERVICE [] 2. Name of Operator 7. Permit Number ARCO Alaska, Inc. 84-223 3. Address 8. APl Number P. O. Box 100360, Anchorage, AK 99510 50- 029-21239 4. Location of well at surface 9. Unit or Lease Name 523' FNL, 281' FEL, 5ec.33, T12N, R9E, UN Kuparuk River Unit; At Top Producing Interval I L,,~...,-~, ~_~.., ~ 10. Well Number 1404' FNL, 1288' FWL, Sec.28, T12N, R9E, UN ¢ VE~!~i~_U I 2W-10 ! 11. Field and Pool At Total Depth 1059' FNL, 1056' FWL, 5ec.28, T12N, R9E, UMi~.~...~. ,. ~. ~' Kuparuk River Field 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Ser-~a'~-~TT'k[o~ ""~ Kuparuk Ri vet 0i l Pool 94' RKB ADL 25642 ALK 2573 12. Date Spudded 13. DateT.D. Reached 14. Date Comp.,Susp. orAband. 115. Water Depth, ifoffshore 116. Ne. of Completions 1 2/02/84 1 2/09/84 1 2/10/8#I N/A feet MSLI N/A 17. Total Depth (MD+TVD) 18. Plug Back Depth (MD+TVD) 19. Directional Survey 20. Depth where SSSV set I 21. Thickness of Permafrost 9147'MD,6259'TVD 9050'MD,6190'TVD YES [] NO [] N/A feet MDI 1450' (Approx) 22. Type Electric or Other Logs Run D I L/SFL/GR/SP/FDC/CNL/Cal, Gyro 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 16" 62.5# H-40 Surf 92' 24" 285 sx CS II 9-5/8" 36.0# J-55 Surf 4027" 12-1/4" 890 sx AS Ill & 550 sx Class G 7" 26.0# J-55 Surf 9136' '8-1/2" :~50 sx Class G & 250 s:< AS I 24. Perforations open to Production (MD+TVD of Top and Bottom and 25. TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) NONE N/A 26. ACID, FRACTURE, CEMENT SOUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT& KIND OF MATERIAL USED N/A 27. N/A PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE IGAS-OILRATIO TEST PERIOD II~ Flow Tubing Casing Pressure CALCULATED.~ OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press. 24-HOUR RATE 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. NONE RECEIVED Alaska 0it & Gas Cons. Commission Anchorage Form 10-407 GRU3/WC52 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE -. .';'~ . . - . _, . O. ' , ' . - " ' .... - NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTF GOR, and time of each phase. Top Upper Sand 8567' 5855' N/A Base Upper Sand 8676' 5928' Top Lower Sand 8818' 6025' Base Lower Sand 9003' 6156' 31. LIST OF ATTACHMENTS 32, I hereby certify that the foregoing is true and correct to the best of my knowledge INSTRUCTIONS General' This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1' Classification of Service Wells' Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than One interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. Item 27' Method of Operation' Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28' If no cores taken, indicate "none" Form 10-407 AtlanticRichfieldCompany Daily Well 'H Story-initial Report Instructions: Prepare and submit the "Initial Report" on the first Wednesday after a well is spudded or workover operations are started. Daily work prior to spudding should be summarized on the lorm giving inclusive dates only. District r county or Parish IState Alaska North Slope Borough Alaska Field ~Lease or Unit Well no. Kuparuk River I ADL 25645 2W-10 Auth. or W,O. no. /Title AFE 203637 J Drill, Complete & Perforate Parker 141 API 50-029-21239 Operator I A.R.Co's W.I. ARCO Alaska, Inc. I 56.24% Spudded or W.O. begUnSpUdded IDate 12/02/84 IHOur 1200 hrs [Prior status if a w.o. Date and depth as of 8:00 a.m. 12/03/84 12/04/84 12/05/84 12/06/84 Complete record for each day reported 16" @ 92' 1642', (1550'), Trip f/BHA Wt. 9.3, PV 17, YP 18, PH 9, WL 14.3, Sol 8 Accept rig @ 0700 hrs, 12/2/84. NU diverter sys. Spud well @ 1200 hrs, 12/02/84. Drl, DD & surv 12¼" hole to 1642'. 681', 5.9°, N35W, 680.76 TVD, 9.29 VS, 7.63N, 5.54W 1161', 18.9°, N41W, 1147.61TVD, 116.54 VS, 99.50N, 62.46W 1587', 30.9°, N44W, 1534.19 TVD, 294.74 VS, 228.90N, 184.10W 16" @ 92' 4050', (2408'), Short trip Wt. 9.9, PV 16, YP 20, PH 9.5, WL 11.9, Sol 9 Fin RIH, drl & surv to 4050', POOH to 1000', tight. RIH to 1700', rm tight spots to 1900'. 1815 , 36.8°, N46W, 1723.54 TVD, 421.13 VS, 318.70N, 273.90W 2223 , 49.6°, N48.5W, 2021.22 TVD, 696.08 VS, 540.82N, 480.43W 2628 , 53.4°, N38W, 2268.00 TVD, 1017.03 VS, 741.61N, 697.91W 2938 , 52.9°, N40W, 2453.91TVD, 1265.09 VS, 934.39N, 854.02W 3561 , 51.7°, N37W, 2834.89 TVD, 1757.77 VS, 1324.09N, 1155.78W 4000 , 50°, N36.5W, 3112.05 TVD, 2097.86 VS, 1596.87N, 1359.48W 9-5/8" @ 4027' 4050', (0'), Tst'g BOPE Wt. 9.7, PV 16, YP 17, PH 9.5, WL 14, Sol 9 RIHo rm 1939'-2500'. Circ & spot Lub 106 pill f/2500'-2000r. RIH, circ & sweep hole w/ 70 bbl hi-vis pill, spot Lub 106, POH, no overpull. LD BHA. RU & rn 101 jts, 9-5/8", 36#, J-55 butt csg to 4026' &lnd on fluted hgr. C&C mud. Cmt w/270 sx AS III w/1/2#/sx D-29. Pmp on Dowell cmt unit went dn, switch to rig pmp, circ cmt out of hole. M&P 890 sx AS III cmt w/1/2#/sx D-29, followed by 550 sx Cl "G" cmt w/2% S-1 & .2% D-46. Displ using rig pmp, bump plug. ND 20" Hydrl. NU BOPE. 9-5/8" @ 4027' 6274', (2224'), Drlg ahead Wt. 9.2, PV 9, YP 11, PH 10.5, WL 14.3, Sol 6 PU BHA, RIH, tst csg to 1500 psi. DO flt equip + 10' new formation. Conduct formation tst to 12.0 ppg EMW. Chg mud to XC polymer sys, drl to 4167', POH. PU & orient turbine, RIH, drl to 6274'. 4305', 53°, N39.5W, 3302 TVD, 2337 VS, 1785N, 1506W 5276', 54°, N41.5W, 3881TVD, 3116 VS, 2378N, 2012W 5899', 52.9°, N37.5W, 4254 TVD, 3615 VS, 2763N, 2330W R E C E i Vr Oi The above is correct Signature .~/J,,~ ~,~~, For form prepara~-io~-and distrlbut~n, - - see Procedures Manual, Section 1~, Drilling, Pages 88 and 87. JDate I Title Alaska 0ii & G~ C_n...s' Cemmissi0n Anch0raee Drilling Superintendent~ ARCO Oil and Gas Company Daily Well History--Interim Instructions: This form is used during drilling or workover operations. If testing, coring, or perforating, show formation name in describing work performed. Number all drill stem rests sequentially. Attach description of all cores. Work performed by Producing Section will be reported on "Interim" sheets until final completion. Report official or representative test on "Final" form. 1) Submit "Interim" sheets when filled out but not less frequently than every 30 days, or (2) on Wednesday of the week in which oil string is set. Submit weekly for workovers and following setting of oil string until completion. District Field Alaska I County or Parish IState North Slope Borough ILease ADL 25645 or Unit Kuparuk River Alaska Well no. 2W-10 Date and deptl3 as of 8:00 a.m. 12/07/84 12/08/84 thru 12/10/84 Complete record for each day while drilling or workover in progress 9-5/8" @ 4027' 7890', (1616'), Drlg ahead Wt. 9.2, PV 11, YP 9, PH 9.5, WL 10.0, Sol 6 Drl to 6285', att to surv, Gearhart tl not wrk'g, dropped surv, POH. Chg out pulser sub, RIH to csg shoe, break circ. RIH, rm & wsh 30' to btm. Drl to 7254', correction run 7254'-7286', drl to 7538', correction rn 7538'-7582', drl to 7890'. 6398', 53.2°, N36.5W, 4554 TVD, 4013 VS, 3081N, 2570W 6929', 53.9°, N38W, 4869 TVD, 4440 VS, 3421N, 2828W 7337', 54.2°, N35.5W, 5109 TVD, 4770 V$, 3686N, 3026W 7744', 51.3°, N37.5W, 5355 TVD, 5093 VS, 3946N, 3219W 9-5/8" @ 4027' 9147', (1257'), RU to rn 7" csg Wt. 10.1+, PV 13, YP 7, PH 8.5, WL 8.0, Sol 12 Drl to 9147', CBU, short trip to csg shoe. RIH, POH, RU Schl, rn DIL/SFL/GR/SP/FDC/CNL/CAL to 8256'; unable to go deeper. Cln tl & coat w/Lube 106. RIH to 8406'; unable to go deeper, POH, RD Schl. RIH, broke circ @ shoe, wsh & rm 45' to btm, C&C hole & sweep w/Lube 106. Spot Lube 106 pill on btm, POH, wrk stds f/8500'-8200', POH. RU Schl, rn DIL/SFL/GR/SP/FDC/CNL/CAL f/9132'-4027' WLM. RIH to shoe, break circ, RIH, rm & wsh 50' to btm. Drl to 9147', Circ & spot Lube 106 pill, POH 20 stds, POH, LD DP. Rn 20 stds in hole & LD same. LD HWDP & BHA. Chg top rams to 7" & tst to 3000 psi. RU to rn 7". 8246', 50.3°, N35W, 5673 TVD, 5482 VS, 4260N, 3449W 8394', 49.1°, N37.5W, 5768 TVD, 5595 VS, 4351N, 3515W 9031', 44°, N34.5W, 6206 TVD, 6056 VS, 4725N, 3787W RECEIVED Alaska Oil & Gas Cons. Commission AnChorage The above is correct Signature For form pre-~'~ation and-dis~iButi~n- -- see Procedures Manual SectiOn 10, Drilling, Pages 86 and 87 Date 12/20/841TM Drilling Superintendent ARCO Oil and Gas Company Daily Well History-Final Report Instructions: Prepare and submit the "Final Report" on the first Wednesday after allowable has been assigned or well is Plugged, Abandoned, or Sold. "Final Report" should be submitted also when operations are suspended for an indefinite or appreciable length of time. On workovers when an official test is not required upon completion, report completion and representative test data in blocks provided. The "Final Report" form may be used for reporting the entire operation if space is avadaole. District ICounty or Parish I Alaska Field ~hease or Unit Kuparuk River Auth. or W.O. no. ITitle AFR 203637 North Slope Borough Accounting cost center code State Alaska ADL 25645 Well no. 2W-10 Drill, Complete & Perforate Parker 141 API 50-029-21239 Operator ARCO Alaska, Inc. Spudded or W.O. begun IA.R.Co. W.I. 56.24% IDate 12/02/84 I otal number of wells (active or inactive) on this ost center prior to plugging and bandonment of this well our I Prior status if a W.O. I 1200 hrs Spudded Date and depth as of 8:00 a.m. 12/11/84 Complete record for each day reported 7" @ 9136' 9050' PBTD, RR 10.2 ppg Brine Rn 225 jts + 2 mkr jts, 7", 26#, J-55 BTC csg w/FS @ 9136', FC @ 9050' (top). RU circ head & circ, hole packed off initially & was unable to recip pipe. M&P 350 sx C1 "G" w/3% KC1, .8% D-60 & .2% D-46. Wsh cmt ins & pmp 336 bbls 10.2 ppg brine. Lost compl rtns last 60 bbls of displm't. Bump plug. PU stack & set slips. Cut 7t' csg & LD lnd'g lt. Make final cut on 7". NU tbg head & tst to 3000 psi. RR @ 2400 hrs, 12/10/84. Old TD New TD Released rig Date 2400 Hrs. Classifications (oil, gas, etc.) Oil 9147' (12/8/84) PSOepth 12/10/84 IKnd°frig Type completion (single, dual. etc.} Single Producing method Flowing ~ officia, reservoirKuparukname(S}sands Potential !est data e£CF! RotaryVED Well no. Date Reservoir Producing Interval Oil or gas Test time Production ~ChO~.,~ Oil on test Gas per day Pump size, SPM X length Choke size T.P. C.P. Water % GOR Gravity Allowable Effective date corrected The above is correct Signatu re I Date I Title /~,)~,"~ ~..~1~_...,~,', 12/20/84 For ,or-m p~eparatio'"'~ ;n~l~istrib~tion'-~ see Procedures Manual. Section 10, Drilling, Pages 86 and 87. Drilling Superintendent ARCO 011 and Gas Company Well History - Initial Report- Daily Inatructlone: Prepare and submit the "Initial Re,oH" on the first Wednesday after a well is spudded or workover operations are started. Dally work prior to spudding should be summarized on the form giving inclusive dates only. District ICounty. parish or borough IState Alaska North Slope Borough Itease ADL 25645 or Unit Imitie Drill, Complete & Perforate Field Kuparuk River Auth. or W.O. no. AFE 203637 Alaska Well no. 2W-lO Parker 141 API 50-029-21239 Operator [ARCO W.l. ARCO Alaska, Inc. Spudded or W.O. begun IDate IHour IPrior status Spudded 12/02/84 1200 hrs Date and depth as of 8:00 a.m. Complete record for each day reported 56.24% if a W.O. 12/03/84 12/04/84 12/05/84 12/06/84 16" @ 92' 1642', (1550'), Trip f/BHA Wt. 9.3, PV 17, YP 18, PH 9, WL 14.3, Sol 8 Accept ri$ @ 0700 hrs, 12/2/84. NU diverter sys. Spud well @ 1200 hrs, 12/02/84. Drl, DD & surv 12¼" hole to 1642'. 681', 5.9°, N35W, 680.76 TVD, 9.29 VS, 7.63N, 5.54W 1161', 18.9°, N41W, 1147.61TVD, 116.54 VS, 99.50N, 62.46W 1587', 30.9°, N44W, 1534.19 TVD, 294.74 VS, 228.90N, 184.10W 16" @ 92' 4050', (2408'), Short trip Wt. 9.9, PV 16, YP 20, PH 9.5, WL 11.9, Sol 9 Fin RIH, drl & surv to 4050', POOH to 1000', tight, RIH to 1700', rm tight spots to 1900'. 1815', 36.8°, N46W, 1723.54 TVD, 421.13 VS, 318.70N, 273.90W 2223', 49.6° 2628', 53.4° 2938', 52.9° 3561', 51.7° 4000', 50°, , N48.5W, 2021.22 TVD, 696.08 VS, 540.82N, 480.43W , N38W, 2268.00 TVD, 1017.03 VS, 741.61N, 697.91W · N4OW, 2453.91 TVD, 1265.09 VS, 934.39N, 854.02W , N37W, 2834.89 TVD, 1957.77 VS, 1324.09N, 1155.78W N36.5W, 3112.05 TVD, 2097.86 VS, 1596.87N, 1359.48W 9-5/8" @ 4026' 4050', (0'), Tst'g BOPE Wt. 9.7, PV 16, YP 17, PH 9.5, WL 14, Sol 9 RIH, rm 1939'-2500'. Circ & spot Lub 106 pill f/2500'-2000'. RIH, circ & sweep hole w/ 70 bbl hi-vis pill, spot Lub 106, POH, no overpull. LD BRA. RU & rn 101 its, 9-5/8", 36#, J-55 butt csg to 4026' & lnd on fluted hgr. C&C mud. Cmt w/270 sx AS III w/1/2#/sx D-29. Pmp on Dowell cmt unit went dn, switch to rig pmp, circ cmt out of hole. M&P 890 sx AS III cmt w/1/2#/sx D-29, followed by 550 sx C1 "G" cmt w/2% S-1 & .2% D-46. Displ using rig pmp, bump plug. ND 20" Hydrl. NU BOPE. 9-5/8" @ 4027' 6274', (2224'), Drlg ahead Wt. 9.2, PV 9, YP 11, PH 10.5, WL 14.3, Sol 6 PU BHA, RIH, tst csg to 1500 psi. DO flt equip + 10' new formation. Conduct formation tst to 12.0 ppg EMW. Chg mud to XC polymer sys, drl to 4167', POH. PU & orient turbine, RIH, drl to 6274'. 4305', 53°, N39.5W, 3302 TVD, 2337 VS, 1785N, 1506W 5276', 54°, N41.5W, 3881TVD, 3116 VS, 2378N, 2012W 5899', 52.9°, N37.5W, 4254 TVD, 3615 VS, 2763N, 2330W RECEIVED The above is correct For form preparation and dlstril~t, lon, see Procedures Manual, Section 10, Drilling, Pages 86 and 87. rDate JTitle A]c,c~,a Oi! & Gas Cons. Commission Drilling ~~tendent ARCO Oil and Gas Company v Daily Well History--Interim Instructions: This form is used during drilling or workover operations. If testing, coring, or perforating, show formation name in describing work performed. Number aH drill stem tests sequentially. AHach description of all cores. Work performed by Producing Section will be reported on "Interim" sheets until final complehon. Report official or represen(ative test on "Final" form. 1) Submit "Interim" sheets when filled out but not less frequently than every 30 days, or (2) on Wednesday of [he week in which oit string is set. Submit weekly for workovers and following setting of oil string until completion_ Dislrict ICountyorParish IState Alaska North Slope Borough Field ~Lease or Unit Kuparuk River I ADL 25645 Alaska Well no. 2W-10 Date and dep[t~ as of 8:00 a.m. 12/07/84 12/08/84 thru 12/10/84 The above is correct For form preparation and distribu~/'~n see Procedures Manual Section 1§, Drilling, Pages 86 and 87 Complete record for each day while drilling or workover in progress 9-5/8" @ 4027' 7890', (1616'), Drlg ahead Wt. 9.2, PV 11, YP 9, PH 9.5, WL 10.0, Sol 6 Drl to 6285', att to surv, Gearhart tl not wrk'g, dropped surv, POH. Chg out pulser sub, RIH to csg shoe, break circ. RIH, rm & wsh 30' to btm. Drl to 7254', correction run 7254'-7286', drl to 7538', correction rn 7538'-7582', drl to 7890'. 6398', 53.2°, N36.5W, 4554 TVD, 4013 VS, 3081N, 2570W 6929', 53.9°, N38W, 4869 TVD, 4440 VS, 3421N, 2828W 7337', 54.2°, N35.5W, 5109 TVD, 4770 VS, 3686N, 3026W 7744', 51.3°, N37.5W, 5355 TVD, 5093 VS, 3946N, 3219W 9-5/8" @ 4027' 9147', (1257'), RU to rn 7" csg Wt. 10.1+, PV 13, YP 7, PH 8.5, WL 8.0, Sol 12 Drl to 9147', CBU, short trip to csg shoe. RIH, POH, RU Schl, rn DIL/SFL/GR/SP/FDC/CNL/CAL to 8256'; unable to go deeper. Cln ti & coat w/Lube 106. RIH to 8406'; unable to go deeper, POH, RD Schl. RIH, broke circ @ shoe, wsh & rm 45' to btm, C&C hole & sweep w/Lube 106. Spot Lube 106 pill on btm, POH, wrk stds f/8500'-8200', POH. RU Schl, rn DIL/SFL/GR/SP/FDC/CNL/CAL f/9132'-4027' WLM. RIH to shoe, break circ, RIH, rm & wsh 50' to btm. Drl to 9147', Circ & spot Lube 106 pill, POH 20 stds, POH, LD DP. Rn 20 stds in hole & LD same. LD HWDP & BHA. Chg top rams to 7" & tst to 3000 psi. RU to rn 7". 8246', 50.3°, N35W, 5673 TVD, 5482 VS, 4260N, 3449W 8394', 49.1°, N37.5W, 5768 TVD, 5595.VS, 4351N, 3515W 9031', 44°, N34.5W, 6206 TVD, 6056 VS, 4725N, 3787W RECEIVED r_. S 0 J. lgSS Alaska Oil & Gas Cons. Commission Anch. cra~ JDate Title 12/20/84 Drilling Superintendent .. ARCO Oil and Gas ComPany Daily Well History-Final Report Instruclions: Prepare and submit the "Final Report" on the first Wednesday after ai!owable has been assigned or well is Plugged, Abandoned, or Sold. "Final Report" should be sub)mitred also when operations are suspended for an indefimfe or appreciable length of time. On workovers when an official test is not required upon completion, report completion and representative test data in blocks provided. The "Final Report" form may be used for reporting the entire operation if space ~s avadable. District I County or Parish I Alaska Field JLease or Unit I Kuparuk River Auth. or W.O. no. ITitle I AFE 203637 North Slope Borough Accounting cost center code State Alaska ADL 25645 JWell no. 2W-10 Drill Parker 141 A_PI 50-029-21239 Operator ARCO Alaska, Inc. Spudded or W.O. begun Spudded A.R.Co. W.I. 56.24Z Date 12/02/84 I otal number of wells (active or inactive) on this DSt center prior to plugging and ] bandonment of this well I our ] Prior status if a W.O. I 1200 hrs Date and depth as of 8.00 a.m Old TD Released rig 12/t1/84 2400 Hrs. Complete record for each day reported Classifications foil gas. etc.) Oil 7" @ 9136' 9050' PBTD, RR 10.2 ppg Brine Rn 225 its + 2 mkr its, 7", 26#, J-55 BTC csg w/FS @ 9136', FC @ 9050' (top). RU circ head & circ, hole packed off initially & was unable to recip pipe. M&P 350 sx C1 "G" w/3% KC1, .8% D-60 & .2% D-46. Wsh cmt Ins & pmp 336 bbls 10.2 ppg brine. Lost compl rtns last 60 bbls of displm't. Bump plug. PU stack & set slips. Cut 7" csg & LD lnd'g it. Make final cut on 7". NU tbg head & tst to 3000 psi. RR @ 2400 hrs, 12/10/84. Producing method Flowing JNew TD PB Depth 9147' (12/8/84) 9050' PBTD JDate Kind of rig 12/10/84 Rotary Type completion (single, dual. etc.) Single Official reservoir name(s) Kuparuk Sands RECEIVED Potential test data Well no. Date R ..... ir Producing Interval Oil or gas Test time oiiPr°ducti°non test k G~_a~e~da¢ 4'J~J'?' Alaska Oil ~, Gas Cons. size, SPM X length Choke size T.P. C.P. Water % GOR Gravity Allowable Efa~e~_~J~f-.l~S_. ~.'~ Pump corrected The above is correct ~ ~.~~ ]Date 12/20/84 Signature ITitle For form preparation and distrit:~fion, see Procedures Manual, Section 10, Drilling, Pages 86 and 87. Drilling Superintendent WELL: .,/26/84 ADDENDUM Arctic Pak w/41 bbls,~ollowed by 59 bbls Arctic Pak. RECEIVED AJaska 0il &.Gas Cons. Commission Anchorage Dr il 1-i~g (~up~ r l'~ t endent · Date $ UB-$ URFA CE DIRECTIONAL SURVEY n-~ UIDANCE I~-~ONTINUOUS r'~OOL Company Well Name RECEIVED ~Jaska Oi~ & ~as Cons. Commission" Anchorag~ ATLA~TZ C R~CHF~ E~D .qONPA,Y 2~-~0 {523' FNL,~ 2'8~' FEL~ S33~ T~2N~ RgE~ Field/Location KLIP/~BUK,_.NORTH SLOPE, ALASKA ....... Job Reference No. 69991 Logged By.' MURTALAND Date , 22-JAN-1985 Computed By; :STEVENS CCT .DIPECTIDNA[, SURYEY CU$"'O~EP L[ST!N~ FOR ARCO AI, ASKA, iNC. 2W-i 0 KUPARUK {,I. S[.,UPE, ALASKA SURVEY DATE: 3-JAN-B5 ENGINE]FiR: MURT[,A~ID ~ETHDDS F]F CO~qPUTA?i(DN TOnL LOCATION: TANGFNTIAL- averaged deviation and azimuth INTERPObATIC)N: T,I,NE~R VKRTICAI, SECTIOn): HORIZ. DIST. PROJECTED ONTO A TARGET AZIMIITH OF NORTH 39 DEG ~2 MIN WEST ARCO ALASKA, INC. 2W-10 KIIPARUK N. SLOP~, AI,ASKA CD~iPUTATION DATE: 21-JAN-B5 [)ATE OF SURVEY! I-JAN-85 KELLY B[ISHING ELEVATION: ENGINEER: MURTLAND IN']'F. RDOI.ATED VALUES FOR EVEN lm 00 F ~ E3' OP MEASIIRED DEPTH PAGE 1 TRU~C SUH-SEA COI/RSF MEASURED VERTICAl, VERTICAL DEVIATION AZIMUTH DEPTH DEPTH DEPTH 94,00 FT- 0.00 0.00 -94.o0 () 0 N 0 0 E 100.00 100.00 6.00 0 13 S 41 40 w 200.00 200,0n 106,00 0 15 S 21 33 w 300.00 300,00 20~.00 0 1~ s 42 59 w 400.00 400.00 306,00 0 1~ $ 45 7 W 500.00 4q9.99 405.99 0 46 N 55 40 W 600,00 599.86 505.~6 4 34 N 36 2~ W 700.00 609,3'~ 605,34 7 14 N 27 36 W ~00.00 798,07 704.07 10 42 N 20 46 W 900,00 805.95 R0~.95 13 19 N 23 37 W 1000.n0 992.5~ 89n.59 16 17 1100.00 10a8,00 994.00 18 10 1200,o0 1182.43 108~.43 20 15 1300.00 1275,36 118~,]6 ~3 14 1400 00 1366,2~ 1~7~,28 25 54 1500~00 1455,24 1361.74 28 26 1600,00 1541 64 1447.64 31 4P 1700.00 1625~45 1~3{,45 34 1~ 1800.00 1706,64 1612,64 37 6 1900,00 1784,86 1690,~6 ~0 3 VERTICAl, DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE SECT1ON SEVERITY NnRTfI/SOUTH EAST/WEST DIST, AZIMUTH F'~E'{' DEG/100 FEET FEET FEET DEG MIN ,2000.00 1859,49 1765,49 43 1~ 2100.00 1,930,35 ln36.35 46 35 2~00.00 ~996,87 190~,~7 49 52 230n,00 2059.07 1965,07 53 4 2400.00 2~18.35 2024,35 53 49 2500,00 2177.38 2083.38 53 45 2600.00 2236,7~ 21.42.78 53 26 2700.O0 2296.40 2202.40 53 22 2800.00 2356,10 226~.~0 53 17 .2900.00 ~416,06 2322.06 52 5~ '0.00 0.00 0.00 N 0.00 -0.10 0.15 0.18 S 0,07 -0.28 0.11 0.52 S 0.19 -0.44 0.09 0,94 S 0.44 -0.51 0.14 1.33 S 0,81 -0.27 3.21 1.4~ S 1,38 4,38 3.43 2.16 N 4,28 14.48 3,90 10,73 N 9 75 29.52 1.42 25,25 N ~5:77 4q.03 3.8~ 44,29 N 23.32 N 28 14 W 73.99 N 35 13 w 103.59 N 42 30 w 136.46 N 43 10, W 173.31 N 43 53 W 214.~1 N 44 30 W 260,29 N 44 46 w 310.39 N 44 55 W 364.66 N 44 9 W 422,R0 N 43 5~ W 484.~8 43 5l w 551,21 43 41 w 621.54 43 34 W 695,98 43 21 W 774.06 43 15 w 854,41 42 42 w 934,95 42 8 W 1015,29 4.1 ~2 W 1095.50 41 16 W 1~75.68 41 14 W 1255.66 51. 2382.51 52 39 30 2443.30 52 28 33 2504.33 52 1.4 66 2505.60 52 10 I l 2627.1.1 51 58 9 268~,~9 51 42 98 2750.98 51 29 46 2813,46 51 8 56 2~76,5~ 50 37 41, 2940,41 S0 7 3000.00 2476' 31.00.00 '2537 3200.00'2598 3300.00 i65,i 3400,0072 3500.00 78 3600.00 2844 3700.0O 2907 3~00.00 2970 3900,00 3034 ~' 40 52 W 1335,29 ~! 41 0 W 1414.,66 N 40 51, w 1493,84 ~ 40 33 W 1572.gl N 40 27 W 1651.68 N 40 33 W 1730.29 M 40 39 ,W 1808.67 M 40 45 w 1886,73 N a,O 40 W 196a.27 ~; a0 4(~ W 2041,22 0,00 N 0 0 E 0.20 S 21 16 ~ 0.55 S 20 9 W 1.03 S 25 22 W 1,56 S 31 31W 2,02 S 42 59 W 4,79 h 63 14 W 14 50 N 42 15 W 29~77 N 31 58, 50,05 N 27 46 . 2.79 3.19 2.84 3,41. 2.89 3.05 2,72 2,92 2,91 2,92 67,27 N 34,66 W 75,68 N 27 15 W 92.80 N 50,21W 105,51 N 28 24 W 118.14 N 71.15 W 137 91 N 31 3 W 145,04 N 96,45 W 174 18 N 33 37 W 175,33 N 124,96 W 215 30 N 35 28 W 207,99 N 156,86 W 260 51 N 37 1 W 243,81N 192.18 W 310 45 N 38 14 W 282.4! g 230,71W 364 67 N 39 14 W 323'99 N 271,67 W 422,8~ N 39 58 W 368,84 N 314.90 W 484,99 N 40 29 W 2.57 3.75 3.29 2.27 0.26 0.66 0,78 0.44 0.09 0.36 416,81N 360,99 W 551,40 N 40 53 W 467 73 N 409,81W 621 87 N 41 13 W 521 76 N 461,31W 696 45 N 41 28 W 578 59 M 515.14 W 774 69 N 41 40 W 637 18 N 570,41W 855 20 N 41 50 W b96 19 N 625,47 W 935 89 N 41 56 W 755 56 N 679,77 W 1016 34 N 41 58 W 815 43 N 733,25 W 1.096 62 k 41 57 W 875 65 N 786,27 W 1176 85 N 41 55,i' 935,77 N 839,08 W 1256,87 N 41 52 ,, 0.33 0.38 0.62 0.28 0.26 0,6~ ().44 0,46 0.48 0.41 995,86 N 891 38 W 1336 52 N 41. 49 W 1055,84 N 943 40 W 1415 91 N 41 46 W 1115.61N 995 1.175,53 N 1046 1235,52 N 1098 i295,31N 1149 1354,80 N 1200 1414 01 N 1251 1472~74 N 1301 1.530,96 N 1352 39 W 1495 86 W 1574 16 W 17 20 W 1809 11W 1888 77 W 1965 13 w ~042 12 N 41 44 W 10 N 41 41 W 97 N 41 37 W 58 N 41 34 W 96 N 41 32 04 N 41 ]0 W 60 N 41 28 W 57 N 41 27 W ARCO ALASKA, TNC, 2W-10 KIIPARIIK N. SLOP[:, ALASKA MEASURED DEPTH 4000.00 4100.00 4200.00 4300.00 4400.00 4500.O0 4600.O0 4700,00 4800,00 4900.n0 5000.00 51'00,o0 5200.00 5300.00 5400.00 5500.00 5600.00 570O.O0 5800.00 5900.00 ,.600o.00 6100.00 6200.00 6300,00 640o,o0 6500.00 6600.00 6700,00 6800 O0 6900~00 7000,00 7100.00 7200.00 7300.00 7400,00 7500.00 .00 7800.00 7900.00 COMPUTATION DATE: 21-JAN-85 IMTERP[JI.ATED VALUES FOR TRUE SUn-SEA COURSE VE'RTICAL VER'fTCAL DEVIATIDN AZI~[.ITH DF. PTH DEPTH DEG M.TN DEG MIN 3098,64 3004.64 49 53 ~ 40 54 w 3162.06 306~.06 51 51. ~ 41 8 W 3222.60 3128.60 ~3 Il N 41 1.6 W 3282.70 318n.70 52 59 N 41 16 W 3342.95 374P.95 52 5~ N 41 30 W 3403.24 3309.?4 52 50 N 41 4~ W 3463.63 3369.63 53 ~ N 41 53 W 3523.60 3429.60 53 14 N 42 1W 3583.37 3480.37 53 25 N 42 g W 3642.66 354~.&6 K3 44 N 42 17 W 3701,71 3607,71 53 49 ~ 42 15 W 3760.54 3666.54 ,~4 4 N 42 t2 W 38J9,i4 3725'.J4 54 10 N 42 2d W 3877,70 378],70 54 ~ N 42 la W 3936,27 384~.~7 ~4 3 N a2 6 W ]995.61 3oO1,61 53 15 N 40 32 w 4055,3~ 3961.38 53 ~1 N 40 1~ w 4115,1~ 4021,11 53 1~ t,~ 40 15 W 4174.9~ 408~.06 53 11 N 38 58 W 4234.90 4140.90 53 1~ N 38 4 w a294.94 4200.94 53 0 N 38 ~ W 4355,22 4~6~.22 52 54 N 37 55 w 4415,43 4321,43 52 5~ H 37 53 W 4475.57 4381.57 53 9 N 37 50 w 4535,39 4441,39 53 20 I'.l 37 48 W 4595.09 4501.09 53 2] N 38 8 W 4654,50 4560.50 53 38 N 38 14 W 47~3.68 4619.68 53 47 N 38 25 W 4772,60 467~.60 54 ~ N 38 2~ W '483~,22 4737,22 54 5 N 38 22 W 4889,6~ 4795,61 54 30 N 38 23 W 4947,48 4953.48 54 49 N 38 27 W 5004,~3 4910.73 55 1~ N 38 21 w 5062.49 4q68.49 54 15 N 3, 5 W 5178 6 5084.46 54 44 N 37 52 W 5238 4 5144.74 5~ 27 N 38 ~6 W 5]00 86 5206.~6 51 25 N 38 ]9 W 5363:35 5269..]5 51 14 N 38 2Q W 5426.06 533~.06 51 7 ~ 38 23 W EVEg ~.00 FEET UF MEASURE VERTICAl., DOGLEG RECTAN SECTION SEVERITY NORTH/ FEET DfiG/Ji00 FEE 2117.84 0.42 1588. 2195.11 2.51 1647. 2274.66 O.0q 1707' 2~54.54 0.56 ~767. 2434.30 0,04 1827. 2514.02 0,52 1886, 2593.66 0.18 1946. 2673.60 0,22 2005. 2753.68 0.6~ 2065. 2834.10 0.31 2124, 2914.70 0.52 2184, 2995.46 0.28 2244, 3076,39 0.45 2304, 3~57.34 0,18 2364, 3238.30 0.52 2424 331~,'74 0,52 24~4~ 3390.89 O,2~ 2545, 3470.09 0.25 2607, 3559.1,9 2.13 2668, 363q.23 0.21 2731. 371g.17 0.15 2794. 3798.94 0.26 2857, 3878.75 0,09 2920. 3958.62 0.25 2983. 4038.72 0,15 3046. 411~,02 0.28 3109. 4199,34 0,21 3173. 4279.04 0.51 3236, 4360,73 0.17 3299. 4441,73 0.58 3363, 4522.90 0.12 3426 4604.44 0,32 3490~ 4686,42 1.02 3554, 4768.04 0,28 3b19, 4849.34 0,12 3683, 4930.92 0.71 3747, 5010.66 1.13 3810, 5089,02 0.02 3871, 5167.08 0,18 3932, 5244.06 0.33 3993. PAGE 2 DATE OF SURVEY~ 3-JAN-85 KE[.bY BUSHING ELEVATION: 94,00 FT. ENGINEER: MURTLAND U DEPTH GUL~R COORDINATES SOUTH EAST/WEST T FEET HORIZ, DIST, FEET DEPARTURE AZIMUTH DEG 98 N 1402.21W 29 N 1452.96 W 16 N 1505,40 W 28 N 1558,06 W 14 N 1610.85 W 8~ N 1663.80 W 21N ~716.97 W 7! N 1770,47 W 1~ N 1824,23 W 84 N 1.878.33 W 2119,21 2196'51 2276.10 2356,02 2435,83 2515,61 2595,32 2675,34 2755,51 2836.03 N 41 25 W N 41 24 W N 41 24 W N 41 23 W N 41 24 W N 41 24 W N 41 25 ~ N 41 26 W N 41 27 N 41 28' 51N 1932. 40 ~ 1986. 35 N 2041, 29 N 2096, 34 N 2150, 78 ~ 2203. 85 N 2255, 04 N 2307, 49 N 2358 33 N 2408: 32 N 2457 19 N 2506 20 N 2555 28 N 2604 61N 2654 85 N 2703. 06 N 2753. 29 N 2803, 61N 2853, 17 N 2903, 77 N 66 N 3004 91N 3055 06 N 3106 13 N 3156 53 N 3206, 13 N 3255, 29 N 3304, 33 N 3353, 33 N 3401. 65 W 2916.72 99 W 2997,58 5l W 3078,60 07 w 31~,65 52 w 32 ,70 67 w 3321 19 61W 3401~34 46 W 3481,53 85 w 3561,60 44 W 3641,53 N 41 29 W N 41 31 W N 41 32 W N 41 33 W N 41 34 W N 41 34 W N 41 32 W N 41 30 W N 41 28 W N 41 24 W 7! w 3721,36 84 w 3801,02 87 W 3880,73 89 W 3960,48 00 W 4040,49 36 W 4120.60 1! W 4200 94 10 W 4281, i47 30 W 4362 20 53 w 4443 13 N 41 19 W N 41 15 W N 41 11 W N 41 7 W N 41 3 W N 41 0 W N 40 56 W N 40 53 W N 40 51: N 40 98 W 4524.24 66 W 4605,73 60 W 4687,65 08 W 4769,21 19 W 4850,46 30 W 4931,97 71W 5011.66 71W 5089,99 38 W 5168,02 81W 5245,86 N 40 45 W N 40 43 W N 40 40 ~ N 40 38 W N 40 35 W N 40 32 W N 40 30 W N 40 29 W N 40 27 w N 40 25 W ARCO ~LhSKA. INC. 2W-10 KUPARUK N, SLDPE. ALASKA COr~PUTATIDN DATE: 21-jAN-85 DATE OF SURVEY! 3-JAN-85 NEE, bY BUSHING EbEVATIONt ENGINEER: MURTLAND INTERPOLATED VAI,UE$ FOR EVEN 100 FE~T OF MEASURED DEPTH PAGE 3 94,00 FT TRUE SUP-SEA COURSE MEASURED VKRTICAL VERTICAL DEVIATInN AZIMUTH DEPTH DEPTH DEPTH DEG MTN I)EG MTN 8000,00 5488,86 5t94.86 51 7 8100.00 5551,64 5457,64 51 q 8200,00 5614,63 5520.b3 ~0 25 8300.00 5678,90 5584.90 49 40 8400 O0 5743.88 5649.88 49 3 8500:00 5810.03 5716,03 48 3 8600.00 5877.25 5783.25 47 38 8700 O0 5944 62 5850.62 47 22 8800'00 60~2:98 5~18 98 46 ~4 8900:00 8082.77 5988:77 45 15 9000.00 6153.90 6059.00 44 6 9100,00 6225.73 61.31.73 44 5 9%47.00 6259.48 6!55.48 44 5 VERTICAL DOGLKG RECTANGULAR COORDINATES HORIZ, DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST, AZIMUTH FEET LEG/lO0 FEET FE~T FEET DEG MIN N 38 10 W 5322.77 N 37 54 W 5400.59 N 37 53 W 5478.23 N 37 38 W 5554.82 N 37 2 W 5630,77 N 35 22 W 5705.67 N ]4 0 W 5779.42 N 34. 2 W 5853.00 N 34 4 W 5925,68 N 34 5 W 5997.00 0,52 0 33 1~66 0,56 1.14 1,85 0.46 0,71 1,4g 0,53 4054,43 N 3450,02 w 5323,63 N 40 23 4115,73 N 3497,99 W 5401,40 N 40 21W 4177.02 N 3545,69 W 5479,00 N 40 19 W 4237,55 N 3592.66 W 5555,54 N 40 17 4297,97 N 3638.77 W 563~,45 N 40 15 W 435B.34 N 3683.27 W 5706,28 N 40 12 44~.9.39 N 3725,13 W 5779,93 N 40 7 W 4480 63 N 3766,49 W 5853,4~ N 40 3 4541:02 N 3807.48 W 5926,02' N 39 58 4600.36 N 3847,59 W 5997,27 N 39 N 33 8 w 6066.94 N 33 6 W 6336.10 N 33 6 W 6.168,61 6,80 0.00 0.00 4658,78 N 3886,64 W 6067,15 N 39 50 W 4717,06 N 3924,65 W 6136,25 N 39 45 W 4744,46 N 3942,51W 6168,73 N 39 43 W ,,, ~L,i, L~ATE: 21'JAN'85 PA'GE 4 ARCD ;~b~$KA, INC. 2W-10 KUPAR[~K DATE OF SURVEY: 3-JAN-B5 KELbY BUSHING ELEVATIUN: ENGINEER: MtIRTbAND 94,00 FT- iNTERPOLATED VAI,UFS FOR EVEN 100[) FEET DF MEASURED DEPI' , TRUE S[JB-SEA COURSE: ~E~$UREL). VERTICAL VERTICAL DEVIATION AZIMUTH DEPTH DEPTH ,DEP'£~~ DEG MTN IDEG VERIICAL DOGLEG RECTANGULAR COORDINATES HORIZ, DEPARTURE SECTiON SEVERITY NORTH/SOUTH EAST/WEST DIST, AZIMUTH FEET DEG/IO0 FEET FEET FEET DEG n O0 0.()0 -94.00 0 0 1000:00 992.59 R9~.59 '16 17 2000,00 ~859.49 1765.49 43 18 3000.00 2476.5~ ~382.51 52 39 4000.00 30q8.64 3004.64 49 5~ 5000.00 3701.71 36U'7.'71 53 49 6000.00 4294.94 4~00.94 53 0 7000.00 4889.6~ 4795.61 54 30 8000.nO ~4~.86 5~94.86 51 7 9000.OU 6153.90 6n50.90 44 6 N 0 0 E 0.00 N ~8 ~4 W 73.99 N 43 51 W 55~,21 N 40 52 W 1335.29 N 40 54 W 2~7.~4 N 42 15 W 2914.70 N 38 2 W 37~g.~7 N 38 23 W 4522.90 N 38 ],0 w 532~.7'1 ~,~ 33 ~ W 6066.~4 0,00 2,79 2,57 0.33 0,42 0.52 0,15 0.12 0,52 6,80 0.00 N 0.00 E 0,00 N 0 0 E 67,27 N 34,66 W 75,68 N 27 15 W 416.81 N 360,99 W 551,40 N 40 53 W 995.86 N 891.38 W 1336,52 N 4~ 49 W 1588.98 N 1402,2~ W 21~9,21 N 41 ~5 W 2184,51N 1932,b5 W 291b,72 N 4! 29 W ~79~.32 N 2457.71 W 3721,36 N4~ 19 W 3426.77 N 2953,98 W 45~4,24 N 40 45 W a054,41N 3450,02 w 5323,63 N 40 23 4658.7~ N ~8R6,64 W 6067,15 N 39 50 9147.00 6259.4~ 6165.48 44 5 N 33 6 W 616~.&1 0.00 4744,46 N 3942,51 W 6168,73 N 39 43 W '-10 JPARUK . SLf~PF.., ALASKA 'TRUE ~SURFD VWRT.ICA[, ~EPTI! DF.,PTH 0.00 0.00 94.00 94.00 194.00 194.00 294.00 294,00 394,00 394.00 494.01 494,00 594.12 594,00 %94.A2 694.uO 795.86 794,00 !gR,00 894.0~ ~01 47 994.00 ,06: 2 094.00 32o. '7 1294.oo 430.93 13 4.oo 544,30 1.494.00 2.1,6 1594.oo ?B4.16 16q4.0n 7 4.oo 047,98 18.94.00 1.95.58 .~358 78 2528i07 .2695 97 '2~63.32 )028.81 3192.93 ~355.94 ~517.~9 ~67~,53 3836,84 ~992,80 {152.38 4318.74 4484 6 ',4817 88 4986:91 1994.00 2094'00 21~4,00 2294,00 2394,00 2494.00 2594.00 2694,00 2794~00 ~894,00 2994,00 3094~00 ]~94.~00 3294~00 ~94~00 ]404,00 3594.00 3694.00 3794,00 3894,00 CC)~PUTATION INTERPOLATED VALUFS FOR S~JD-SEA COURSE VERTICAL DEVIATInN AZI DEPTH DM(; MTN PEG ~IJTH -94.00 0 0 N 0 0.00 0 13 S 41 100.00 O 14 S 20 200.00 0 1~ $ 41 300.00 0 1~ S 43 40~.00 0 36 ~ 63 500,00 4 22 ~ 36 600.00 7 3 N 28 700.00 J0 3R ~ 20 ~00.00 13 15 N 23 0 E 45 W 37 W 56 w 42 w 21 W 45 w 22 w 47 W 30 w q00,00 16 1q N 28 lO()0.00 18 25 N 35 1100.00 20 34 N 42 1~00,00 23 47 ~ 43 130n.00 ~6 42 N 44 1400.00 30 6 ~ 44 150~.00 33 20 N 44 1600.00 36 39 ~I 44 1700.00 40 26 N 43 lPO0.O0 44 46 N 43 18 47 53 5 13 33 58 17 47 1~00.00 49 4~ N 43 2O00.00 52t 44 N 43 2100.00 53 38 N 42 2200.00 53 2] ~ 41 2300,00 53 6 N 41 2400.00 52 34 N 4,0 2500.00 52 16 N 40 2600.00 52 2 N 40 2700.00 51 40 N 40 2R00.00 51 13 N 40 DATE: 21'-JAN-85 2q00.00 50 27 N 40 3000.00 49 53 N 40 3100,00 52 4o N 41 3200,00 52 58 N 41 3300.00 52 53 N 41 3400.00 53 o ~: 41 3~00.00 53 31 N 42 3600,00 53 50 N 42 3700.00 54 8 ~ 4,2 3O00,O0 54 10 N 42 DATE OF SURVEY: 3-JAN-85 KELLY gUSHING ELEVATION: ENGINEER: MURTLAND EVE~ 100 FEET OF SUB-SEA DEPTH VERTICAL DOGLEG SECTION SEVERITY FEET DEG/100 0.00 0.00 -0.09 0,14 -0.27 0,15 -0.44 0.12 -0.51 0.09 -0,34 2.84 3.92 3.45 13.83 4.03 28.~0 1.49 48.60 3.82 74.41 2.77 105,57 3.35 140.71 3.04 181..48 2.51 228.49 2.32 281.77 4,29 343.73 2.20 413,28 3,30 492.60 2.99 584.44 3,30 RECTANGULAR COORDINATES HORIZ. NORTH/SOUTH EAST/WEST DIST. FEET FEET FEET 34 W 692.62 3.21 20 W 821,22 0,39 33 W 957.54 0,67 33 W 1092.27 0,45 17 W 1226.38 0,57 54 W 135R.18 0,34 53 W 148~.~5 0,71 28 W 1616.96 0'22 35 W 1744.32 0,65 4:t w 1~70,01 0.38 0,00 N 0,00 E 0.00 0.16 S 0,05 W 0,17 0.49 S 0,18 W 0,52 0,91S 0.42 w 1.00 1.30 S 0.79 W 1,52 1.52 S 1.32 W 2,02 1.79 N 4,00 W 4,39 10'15 N 9,44 W 13,86 24.54 N 15,49 W 29,02 43,87 N 23,14 W 49,60 12 W 20 w 30 .W 58 w 10 W t6 W 17 w 12 W 67.~4 N 34.86 W 76,10 94.42 N 51.36 W 107.49 121.27 N 74,03 W 142.08 151,03 ~ 102,04 W 182"27 185.19 N 134 52 W 228 89 223.36 N 171:99 W 201:90 267'53 ~ 215,84 W 343,74 317.14 N 265.02 W 413,30 374,41. N 320,26 W 492,70 440.85 N 3~4,09 W 584,70 5~9,32 N 612.97 N 712,84 N 813,01N 913.76 N ~013,17 N llll,3g N 1209,10 N 1305,96 N 1401.34 N 459,00 W 547,~0 W 640,79 W 731.10 W 819,75 W 906 37 W 991 73 W 1075 56 W 1158 28 W 1240 19 W 693.09 821"95 958,5! 1093,39 1227,57 1359,42 1489,53 1618,25 1745,6! 1871.32 1992.69 0.70 2112.34 0,39 2236.61 1.20 2369.48 0,43 2501,82 0,21 2634.04 0.41 2768.04 0,53 2904.14 0,48 3041.59 0.~P 3170,86 0.1~ 1494.25 N 1320,36 W 1584.82 N 1398~60 W 1678.54 N 1480,29 W 1778,52 N 1567,93 W 1877,70 N 1655,68 W 1976.28 N 1743 .98 W 2075.84 N 1833,89 W 2176,69 N 1925,54 W 2278,61N 2018.01W 2380.99 N 2111.23 W PAGE 5 94,00 FT DEPARTURE AZIMUTH DEG MIN N 0 0 E $ 18 22 W $2 0 6 W $ 24 49 W S 31 14 W S 40 53 W N 65 56 W N 42 56 W a 32 16" N 27 48~ N 27 15 W N 28 32 W N 31 24 W N 34 2 W N 35 59 W N 373 5 W N 38 53 W N 39 53 W N 40 32 W N 41 J - N 41 28 W N 41 46 W N 41 57 W N 41 57 W N 41 53 W N 41 48 W N 41 44 W N 41 39 W N 41 34" 4t 1994,03 N 41 27 W 2113,70 N 41 25 W 2238,03 N 41 24 W 2370,98 N 41 23 W 2503,41 N 41 24 W 2635,75 N 41 25 W 2769.88 N 41 27 W 2906,14 N 41 29 W 3043,75 N 41 3l W 3182,20 N 41 33 W {CO AI. aSKA, T. NC. ~4-10 !. S[uOPE, At. ASKA TRUE COMPUTATION DATE: 21-jAN-85 DATE OF SURVEY: 3-jAN-85 KELLY BUSHING ELEVATION: ENGINEER: ~URTbAND I~TFPPO[.ATED VALUFS FOR EVEN 100 FEET OF SUB-SEA DEPTH SUB-SEA COURSE PAGE 6 94,00 FT VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ, DEPARTURE ~SUREO VERTICAl. VERTICAL DEVIATION AZI~tJTH DEPTH DEPTH DEPTH DEG MTN DEG NTN SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST, FEET PEG/lO0 FEET FEET FEET AZIMUTH DEG MIN 497 32 3994.00 3qO0.O0 53 15 .664:68 40g4.00 4000.00 53 17 ~831,77 4194.00 4100.00 53 10 5998,~4 4204,00 4~00.00 53 0 5164,41 4394.00 4~00.00 52 59 a33~.75 4494.00 4aO0.O0 5] 12 -~498.18 4504.00 4500.00 53 23 ~666.74 4694.00 4600,00 53 43 836.47 4794,00 4700.00 54 5 007,56 4894.00 q800.00 5~ 31 ~? 40 33 W 3316.59 N 40 16 W 3450.77 ~! 38 2t W 3584.62 N 38 2 W 3717.93 N 37 5~ W 3850.34 g 37 47 w 3983.22 ~ 38 8 W 4~17.46 N 38 22 W 4253.13 N 38 lg w 4390.25 N 38 23 W 452~.05 0,6n 0,61 0.93 0,15 0.06 0~23 0,29 0.20 0,34 0.17 2483.15 N 2202,27 w 3319.04 N 41 34 W 2585.43 N 2289.15 W 3453,21 N 41 31 W 2688,38 ~ 2374,71W 3587,01 N 41 27 w ~7g3,34 g 2456.94 W 3720,12 N 41 20 W 2897,76 N 2538,42 W 3852,35 N 41 13 W 3002,72 N ~619 99 W 3985,06 N 41 6 W 31o8,70 N 2702:45 W 4119 14 N 41 0 W 3215,28 N 2786.45 W 4254 68 N 40 54 W 33~2"77 N 2871.b~ W 4391 69 N 40 50! 3431,60 N 2957,80 W 4530 39 N 40 45 .. 181.12 4904.00 4000,00 55 17 35~.06 5099.00 5nOO,O0 54 27. 526,~7 5194,00 5100,00 54 3 ,689,00. 5294,00 5PO0.O0 51 28 ~848,91 5394'00 5300,00 51 8 ~008.1..8 5494.00 5400.00 51 7 ~167.42' 5594.00 5500.00 50 53 1323.31 5694,00 5600,00 49 36 {475,99 5794.00 5700.00 48 19 ~6~.a8 5894.00 5900,00 47 43 ~ 38 23 w 4670.99 N 38 2 W 4811,95 g 37 59 W 4952,83 ~ 38 39 W. 5080.42 N 38 26 W 5205.19 N 38 q W 5320.13 ~ 37 54 w 5453.02 N 37 31 w 5572.57 f~ 35 54 W 5687,82 N 34 0 W 5797.75 0,76 0,36 4,6~ 0,36 0,21. 0.55 1.41 0,50 2,22 0.39 3542.73 N 3045.96 W 4672,13 N 40 41 3653.64 ~! 3133,17 W 4813.09 N 40 36 3764,83 N 3219 76 W 4953,87 N 40 32 3864,57 ~ 3299:34 W 5081 39 N 40 29 W 3962,17 g 3377:09 W 5206 10 N 40 4059,43 N 3453 95 W 5329 99 N 40 41. 57 12 ~ 3530.19 W 5453 80 4251;63 N 3603,50 W 5573 29 N 40 16 W 4343,80 N 3672 84 W 5688 44 N 40 17 4434,64 g 3735:43 W 5798 24 N 40 6 W ~772.d5 5994,00' 5900,00 46 37 8915.94 6094,00 6000.00 45 6 9055.83 6104,00 6100.00 44 5 7147.00 6259.48 6165.48 44 5 N 34 It W 5905.80 N 34 4 W 6008.~6 N 33 6 W 6105.55 N 33 6 W 6168'61 1,36 1,19 0,00 0.00 4524,49 N 3796.28 W 5906 4609.72 N 3853,93 W 6008 4691.32 N 3907,86 W 6105 4744,46 N 3942.51 W 6168 16 N 39 59 W 52 N 39 53 W 72 N 39 47 W 73 N 39 43 W ARCO AL, ASKA, INC 2W'lO KHPARUK N, SLOPF, ALASKA ~ADKRR TOP UPPER SAND BASF tIPPER SAND TOP L.nWFR S~ND PBTD TOTAL D~PTH CDMPUTATION DATE: 2~-jAN-85 INTRRDOI, ATEI) VALUR.S FOR CHOSEN HORIZONS MEASURED DEPTH BELOW KB FROM KB ORIGIN: TVD 523' SUB-SEA 8567.00 5R55.01 5761.01 8676.00 5928.39 5834.39 8818.00 6025.46 5931.46 9003.00 6156.06 6062.06 0050.00 618g.~2 6095.8~ 9~7o00 6~5g.48 6~65.48 DATE OF SURVEY: 3-JAN-B5 KELbY BUSHING EbEVATION: ENGINEER: MURTbAND PAGE 7 94.00 FT FNb, SURFACE LOCATION AT 28,' FEI,, SEC 33, TI2N RECTANGULAR COORDIN~T 4399.18 N 3711,50 4465 98 N 3756.60 455~76 N 3814.74 4660,53 N 3887.78 4687.92 N 3905.64 4744.46 N 3942.5! COMPUTATION DATE: 21-JA~-fl5 ARCO ~LASKA, tNC. 2W-10 KUPARUK N. SLOPE, ALASKA DATE OF SURVEY: 3-JAN-B5 KELleY BUSHING ELEVATION: ENGINEER: MURTbAND 94,00 ************ STRATYGRAPHIC SUMMAPY MARKER MV. ASURED DEPTH RELOW KB FROM ORTGTN: 523' TVD KB SUB-SEA FNb, SURFAC 281 ' FEb SE RF, CTA~GUL ~'ORTH/SO E LOCATION AT C 33 ~T12N, R9E, AR C60,,DINATES UTH EAST/WEST TOP UPPER SaND BASF: UPPER SAND TOP LOWER SAND BASE LOWER SAND P~TD TOTAL DEPTH 8567.00 5855.01 5761.01 R676,00 5928.]9 5834.39 P818.00 6025.46 5931.46 qO03,00 b~56.06 6062.06 9050,00 618q,82 R095.82 9147.00 6259.48' 6165.48 4399,18 4465.98 4551.76 4660.53 4687.92 4744.46 N 3711,50 N' 3756.60 N 3814,74 N 3887,78 N 3905,64 N 3.942.51 FINAL WF][,b Lr~CATIOM AT TO: TRUE SUB-SEA M~ASUPED VERTICAL VERTICAL DEPTH DEPTH DEPTH HORIZONTAl., DEPARTURE DISTANCE AZIMUTH FEET DEG MIN 9147.00 6259,48 6165.48 6168,73 N 39 43 W FT. SCHLUMBERGER ARCO ALASKA, INC. 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'.,..~.~...~..~:t:::...~...~: ....... ~ "'T-T"?'"TT"?T"T"; ....... ~'"T'T' T T"T'T"?'"~ ....... v"T"f"T']- ~'~"-~"~ ..... ~'"T'?"~-'f"T"~'"T"~ .... ~'"~'"f"f"~'"T": ...... ~ ....... ~'"f"f";'"~'":"~'"';'"f"f ...... :" ;"':"+"~ ....... ~'"~ ...... :' :'":"~:' f' :'"':":'": '"?"~'"?"?T-'~ ....... ?"~ ....... ~ ....... ?'?'"f"'~ "?'-?"t'"~'"~"-t-"?"t" ~"~'-~-"~ ....... ~'t'"t~'-'~"'t"t'"t ............ ?+'"~"-??-~-'-~ ........... t ....... ~'-'~-'t'": ............... ~ ................. ¥4 ....... ,...: ............. ~ ...... ~ ....... : ........... .-~-~.--~-¢-+--¥-L4--4---. ~ ~ ~ ~ ~ : : ~ :: ~ :.~ ~ : ~ ~ ~] : ~ ~ ~ ~ ~ ~ ~ ~'-4"4"-~---;--4--'~---~--4-~--.-4-..~--4-4.-~.-~..~..4-.4 ..... ~--4-~--4-~-4.-.~.-.~:: ~ ~ ~ , ~ ~ ~ ~ ..... ~:T~: : ~ ~': ' ' ~..-~--4..4 ....... ~...~.-.;: ' ; : ~ ' : ~ ~ : :L'4'"~ ......... ~ ........... ~...;..i.-.~...:. ~ ~ ~ : : ............. ~. ........ , : :i":'; ...... : NW .< --I rq ii z "'ri PROJECTION ON VERTICAL PLANE OF AZIHUTH 521 SCALEO IN VERTICAL OEPTH$ HORIZ SCALE = 1/2000 IN/FT WELL' 2W-10 -' SURFACE LOCATION: 523' FNL, 281' FEL, S.33, T12N,-RgE, UM HORIZONTAL PROJECTI ON SCALE : 1/20C~ IN/FT 400O 2000 -~001 -4000 -6000 -8000 SOUTH -10001 -14000 NEST 2OOO EAST -12000 -10000 -8000 -6000 -4000 -2000 0 Suggesta~a form ~o be inserted in each "AcTive" well folder to d~.eck for timely ccmpliance with our regulations. · O~erato~, W~i Name a[nd N~~? o ~ - . _ Reports and Materials to be received by: _Required Date Received Remarks · . · .~,>I Well History Yes -~-- [?i: :_~: , .. -.. _Samples Core Chips -- , · ,. . Core Description. -:~., .;"-' ,'~,"..~ 'k Registered Survey P~ . Drill Stem Test Reports /./. ? ~ ::,,..,,, ........ . .... /~ /~ ./ · Proddcti6n Test Reports Digitized Data ARCO Alaska, Inc. Post Office ~..: 360 Anchorage, Alaska 99510 Telephone 907 277 5637 Date: 1/15/85 Transmittal No 4977 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. OH LIS TAPES Schlumberger ~/69858 2E-12 12/10/84 Run 1 3391.5 - 7573.5 (Computed 1/11/85) ~/69880 2E-11 12/16/84 Run 1 4050 - 8398 (Computed 1/12/85) #69859 2W-10 12/09/84 Run 1 4018.5 - 9150.5 (Computed 1/12/85) Receipt Acknowledged: B. Currier Drilling DISTRIBUTION W. Pasher BPAE Geology G. Phillips Sohio Chevron Mobil Phillips Oil Union D & M NSK Ops. J. Rathmell Well Files ARCO Ale;ka. Inc. Is · subsidiary o! AllanllcRichlieldCompany ARCO Alaska, Inc. Post Office BOx 100360 Anchorage, Alaska 99510 Telephone 907 276 1215 January 14, 1985 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT: State Reports - December, 1984 Dear Mr. Chatterton' Enclosed are the December monthly reports for the following wells' DS 6-11 (Workover) - 2C-15 1Q-12 DS 11-12 2C-16 2W-9 DS 11-15 2D-13 2W-10 DS 15-16 (Workover) 2E-10 2W-11 DS 15-17 (Workover) 2E-11 2W-12 DS 17-13 2E-12 CPF-1A DS 17-14 2E-13 WSP-3 2X-9 2X-10 If you have any questions, please call me at 263-4944. Sincerely, Gruber Associate Engineer JG/tw GRU3/L68 Enclosures RF.¢EIVED JAN u~i a, (~as Cons. Commissi~ Anchorage ARCO Alaska, Inc. is a Subsidiary of AllanticRichfieldCompany STATE OF ALASKA ALASKA O~- AND GAS CONSERVATION COb.~,'/llSSlON MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS I1. Drilling well ~X Workover operation [] 2. Name of operator 7. Permit No. ARCO Alaska, Inc. 84-223 3. Address 8. APl Number P. 0. Box 100360, Anchorage, AK 99510 50- 029-21239 523' 4. Location of Well at surface FNL, 281 ' FEL, Sec.33, T12N, R9E, UM 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. 95' RKB ADL 25642 , 19 84 For the Month of December 9. Unit or Lease Name Kuparuk River Unit 10. Well No. 2W-10 11. Field and Pool Kuparuk River Field Kuparuk River Oil Pool 12. Depth at end of month, footage drilled, fishing jobs, directional drilling problems, spud date, remarks Spudded well ~ 1200 hfs, 12/02/84. Drld 12-1/4" hole to 4050'. csg. Drld 8-1/2" hole to 9147'TD as of 12/09/84. Ran OH logs. PBTD is at 9050'. Secured well & RR ~ 2400 hfs, 12/10/84. Ran, cmtd & tstd 9-5/8" Ran, cmtd & tstd 7" csg. 13. Casing or liner ru.n and quantities of cement, results of pressure tests 16", 62.5#/ft, H-40, weld conductor set @ 92'. Cmtd w/285 sx CS II. 9-5/8", 36.0#/ft, J-55, BTC csg w/FS ~ 4027'. Cmtd w/890 sx AS Ill & 550 sx Class "G" cmt. 7", 26.0#/ft, 3-55, BTC cs§ w/shoe ~ 9136'. Cmtd w/350 sx Class "G" cmt. 14. Coring resume and brief description None 15. Logs run and depth where run DIL/SFL/GR/SP/FDC/CNL/Cal f/9132' - 4027' 6. DST data, perforating data, shows of H2S, miscellaneous data N/A RECEIVED JAN 5 !985 Alaska Oil ~ Gas Cons. Commission 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. SIGNED ')~C' L ,~- TITLE Associate Engineer DATE 1-14-~.G NOTE--Report(~n this form is required for each calendar month, regardless of the status of operations, and must be filed in duplicate with the Alaska Oil and Gas Conservation Commission by the 15th of the succeeding month, unless otherwise directed. Form 10-404 JMM/MR40 Rev. 7-1-80 Submit in duplicate M EMORAN OUM State of Alaska ALASKA OIL A~D GAS CONSERVATION COt'~-'~ISSION TO: THRU: Lonnie C. Smith Commissioner DATE: December 21, 1984 F,LE NO: D.41.45 TELEPHONE NO: FROM' Doug Arflo s "' -. SUBJECT: Petroleum Inspector Witness BOP Test at ARCO Kup. 2W-10 Well. Sec. 33, Ti2N,R9E, iR-~, Permit No. 84-2~3 on Parker Rig ~ 141. Wednesday, December 5, 1984: After witnessing the BOP test at U.A.D. Rig #2, ! tra~-eled {o Parker Rig No. 141 to witness the BOP test there. The testing con~nenced at 4:30 am and was concluded at 6:45 am.... There were no failures and I filled out an AOGCC BOPE inspection Report which is attached. In summary, I witnessed the successful BOP test at ARCO's Kup. 2W-10 well. Attachment 02-O01A(P, ev. 10179) O&G #4 4/80 · STATE OF ALASKA ALASKA.%~L & GAS CONSERVATION COMMISSION B.O.P.E. Inspection Report Inspe_ctor D,... ~0~ Well A'U , Location: Sec ~ T ~klR'~8 M &,VXA, Drilling Contractor ~~6~ ,-, Date Well Representative Permit ~ ~ ~asing Set Rig ~ /$/ Representative' Location, General , Well Sign General Housekeeping Reserve pit .. Rig BOPE Stack ! Test Pressure Annular Preventer ~' / I l] ~ Pipe Rams Blind Rams ,~u;f Choke Line Valves H.C.R. Valve Kill Line Valves Check Valve ACCUMULATOR SYSTEM Full Charge Pressure. %~,~)6~69 psig Pressure After Closure '~ _(4~6~f5 psig 200 psig Above Precharge Attained:___j__min dkgs, Full Charge Pressure Attained: ~ rain ~ s~ Controls: Master O~ Remote ~.~ 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 [ U~'Test Pressure No. Valves q No. flanges Adjustable Chokes Hydrauically operated choke Test Results: Failures .A/~;~/~ Test Time ~ hrs. . / ~ Repair or Replacement of failed equipment to be made within days and Inspector/Commission office notified. _~ Ill Remarks: Distribution orig. - AO&GCC cc - Operator cc - Supervisor Inspector November 26, 1984 }Ir. Jeffrey B. Kewin Area Drilling Engineer ARCO Alaska, Inc. P. O. Box 100360 Anchorage, Alaska 99510-0360 Re: Kuparuk River Unit 2W-10 ARCO Alaska, inc. Permit No. 84-223 Sur. Loc. 523' FI~L, 28!' FEL, Sec. 33, T12i~, R9E, Btmhole Loc. 1054' FNL, 1102' F~-~L, Sec. 28, T12N, R9E, Dear Mr. Kewin: Enclosed is the approved application for permit to drill the above referenced ~el!. If coring is conducted, a one cubic inch chip from each~oo~ ~' ~ of recovered core is required. Samples of well cuttings and a mud log are not required. A continuous directional survey is required as per 20 AAC 25.050(b)(5). If available, a tape containing the digitized log information shall be submitted on all logs for copying except experimental logs, velocity surveys and dipmeter surveys. 1,iany rivers in Alaska and their drainage systems have been classified as important for the spawning or migration of anadromous fish. Operations in these areas are subject to AS 16.05.870 and the regulations promulgated thereunder (Title 5, 'Alaska Administrative Code). Prior to co~encing operations you may be contacted by the Habitat Coordinator's Office, Department of Fish and Game. Pollution of any waters of the State is prohibited by AS 46, Chapter 3, Article 7 and the regulations promulgated thereunder (Title 18, Alaska Administrative Code, Chapter 70) and by the Federal Water Pollution Control Act, as amended. Prior to ~ommencing operations you may be contacted by a representative of ~he Department of Environmental Conservation. To aid us in scheduling field t~-.~ork, please notify this office 24 hours prioz~ to commencing installation of the b!o%~out prevention Jeffrey B. Kewin Kuparuk River Unit 2W-i0 ~ovember 26, 1984 equipment so that a representative of the Conm~ission may be present to ~Jitness testing of the equipment before the surface casing shoe is drilled. ~,~ere a diverter system is required, please also notify this office 24 hours prior toco~e~c~'~- ln~' ~ equipment installation so that the Con~ission may witness testing before drilling below the shoe of the conductor pipe. in the event of suspension or abandonment, please give this office adequate advance notification so that v~e may have a witness present. Very._.._truly yours, ChaizTnan of Alaska Oil and Gas Consez~-ation Co~ission BY OPJOER OF THE CO~;R~IiSSiON lc Enclosure cc: Department of Fish &Game, Habitat Section w/o enct. Department o£ Environmental Conservation w/o encl. Doug L. Lowery Environmental Supervisor Pouch 1601 Fairbanks, Alaska 99707 w/o enc!. ARCO Alaska, Inc. Post Office b_x 100360 Anchorage, Alaska 99510 Telepl';one 907 276 1215 November 14, 1984 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT: Kuparuk 2W-lO Dear Mr. Chatterton: Enclosed are: An application for Permit to Drill Kuparuk 2W-lO, along with a $100 application fee Diagrams showing the proposed horizontal and vertical projections of the wellbore A proximity plat A diagram and description of the surface hole diverter system A diagram and description of the BOP equipment Since we estimate spudding this well on November 30, 1984, your earliest approval will be appreciated. If you have any questions, please call me at 263-4970. [~iiq-Cje r e 1 y, ~ Area Drilling Engineer JBK/JG/~w GRU2/L87 Attachments Alaska 0i! & Gas Cons. Commission Anchorage ARCO Alaska. Inc. is a Subsidiary of AtlanticRichfieldCompany STATE OF ALASKA ALASKA ~L AND GAS CONSERVATION C~'IMISSION PERMIT TO DRILL 20 AAC 25.005 la. Type of work. DRILL REDRILL DEEPEN lb. Type of well EXPLORATORY [] DEVELOPMENT OIL E~X DEVELOPMENT GAS [] SERVICE [] STRATIGRAPHIC SINGLE ZONE [] MULTIPLE ZONED ..,.,¢ 2. Name of operator ARCO Alaska, Inc. 3. Address P. O. Box 100360, Anchorage, Alaska 99510 4. Location of well at surface 523' FNL, 281' FEL, 5ec.33, T12N, RgE, UN (Approxo) At top of proposed producing interval 1444' FNL, 1421' FWL, Sec.28, T12N, RgE, UN At total depth 1054' FNL, 1102' FWL, Sec.28, T12N, R9E, UN 5. Elevation in feet (indicate KB, DF etc.) 6. Lease designation and serial no. RKB 95', PAD 65' ADL 25642 ALK 2573 12. Bond information (see 20 AAC 25.025) Federal Insurance Company Type Statewide Surety and/or number #8088-26-27 9. Unit Kuparuk River z~,~n,-,~.~' C0mrr~,~ssi0 10. Well number ..... ,V~ 2W-10 11. Field and pool Kuparuk River F~eld Kuparuk River 0~l Pool Amount $500,000 15. Distance to nearest drilling or completed 2W-9 well 60' (~ surface feet 13. Distance and direction from nearest town 14. Distance to nearest property or lease line 30 mi, NW of Deadhorse miles 1102~ @ TD feet 16. P-~-c~po-se~- clepth (MD & TVD) 17. Number of acres in lease 9118' MD, 6264' TVD fe~t 2560 19. If deviated (see 20 AAC 25.050) 120. Anticipated pressures KICK OFF POINT 500 feet. MAXIMUM HOLE ANGLE 52 oI (see 20 AAC 25.035 (c) (2) 18. Approximate spud date 11/30/84 2752 psig@ 80°F Surface 3160 psig@ 61b0 ft. TD (TVD) 21 Proposed Casing, Liner and Cementing Program SIZE r- CASING AND LINER SETTING DEPTH QUANTITY OF CEMENT __ Hole Casing Weight Grade Coupling Length MD TOP TVD MD BOTTOM TVD (include stage data) 24" 16"- 62.5# H-40 Weld 80' 29' I 29' 109! 109' + 200 cf I 29' 4052I~ 3130' 887 sx AS Ill & 12-1/4" 9-5/8" 36.0# J-55 BTC 4023' 29' HF-ERW ~ j 550 sx Class G 8-1/2" 7" 26.0# J-55 BTC 9090' 28' II 28' 9118~ 6264' 250 sx Class G blend ~ HF-ERW I I i I 22. Describe proposed program: ARCO Alaska, Inc., proposes to drill a Kuparuk R~ver Field development we]] to approximately 9118' HD (6264~ TVD). A 20", 2000 ps~ annular diverter will be ~nsta]led on the 16" conductor while drilling the surface hole. The 9-5/8" casing will be set through the ~est Sak sands at approximately 4052~ ND(~130~ TVD). A 13-5/8", 5000 psi, RSRRA BOPE stack will be installed on the 9-5/8" surface p~pe. It w~ll be tested upon ~nstallat~on and weekly thereafter. Test pressure w~]] be 3000 ps~g (1800 psi for annular). Expected maximum surface pressure ~s 2752 psi. Pressure calculations are based on latest reservoir pressure. Surface pressure ~s calculated w~th an unexpanded gas bubble at surface, ~nc]ud~ng temperature effects. Selected intervals will be logged. The well will be completed by the workover rig with 3-1/2", 9.2#, J-55, 8rd tbg. Non-freezing fluids will be left ~n uncemented annuli through the permafrost interval. Selected ~ntervals w~ll be perforated w~th~n the Kuparuk formation and reported on subsequent reports. A downhole safety valve w~ll be (see attached sheet) 23. I hereby certify_that the foregoing is true and correct to the best of my knowledge The space be/~'f~r/cC~i~n use- CONDITIONS OF APPROVAL Samples required I Mud log required ! Directional Survey required DATE JAPl number 50-- Ob~'t'/~-~ ~ E]YES [~NO i /[~YES []NO Approval date SEE COVER LETTER FOR OTHER REQUIREMENTS i ,COMMISSIONER DATE 1~,~,~,,~- 06 !0~4 by order of the Commission . Submit in triplicate i~l Y ES eNO Permit number APPROVED BY Form 10~101 Rev. 7-1-80 PERMIT TO DRILL 2W-10 installed and tested upon completion of the job. 2W-10 will be 60' away from 2W-9 at the surface. There are no other close wellbores or crossings anywhere downhole. Top of cement for the production string will be placed at 7476'MD, approximately IO00'MD above the top of the Kuparuk Sands. Reserve pit fluids will be disposed of down the 9-5/8" x 7" annulus. The 9-5/8" x 7" annulus will be left with a non-freezing fluid during any interruptions in the disposal process. After the workover rig has moved off location, this well will be fracture stimulated. ........ ~RCO ........ PAD '2W; ..... ~ELL'-NO . .... ~ ........ ..... , .... ~ ........... ~ ...... , ...... ~ .... 4 ....... ~__~_~_~ ..... W ..... ~__~__a ........... ~ .... ~ .......... ~ ........ _ .... · .~ .... ~ .... .......... ~-' ...... ~ ...... = ...., ....... ~ ...... ~ ........ , ....~ ............ ....... , ..... , ..... , ...... ~. _ = ............... ~ .... 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' SEC.'-~. T12N. R~ Surface Diverter System 1. 16"-2000 psi Tankco startingJhead. 2. Tankco quick connect assy. 3. 16" X 20" 2000 psi double studded adapter. 4. 20" 2000 psi drilling spool w/10" side outlets. 5. 10" ball valves, hydraulically actuated, w/10" lines to reserve pit. Valves to open automatically upon closure of annular preventer. 6. 20" 2000 psi annular preventer. 7. 20" bell nipple. Maintenance & Ooeration 1. Upon'initial installation close annular preventer and verify ~hat ball valves have opened properly. 2. Close annular preventer and blow air through diverter lines every 12 hours. Close annular preventer in the event that gas or fluid flow to surface is detected. If necessary, manually override and close ball valve to upwind diverter line. Do not shut in well under any circumstances. 16" Conductor ANNUL.AR 9 PIPE DIAGRAM ~1 !3-5/8" 5000 PSI RSRRA BOP STACK 1. 16" - 2000 psi Tankco starting head 2. 11" - 3000 psi casing head 3. 11" - 3000 psi x 13-5/8" - 5000 psi spacer spool 4. 13-5/8" - 5000 psi x 13-5/8" - 5000 psi drilling spool 5. 13-5/8" - 5000 psi pipe rams 6. 13-5/8" - 5000 psi drilling spool w/choke and kill lines 7. 13-5/8" - 5000 psi pipe rams 8. 13-5/8" - 5000 psi blind rams 9. 13-5/8" - 5000 psi annular BLIND · ~ ~"'~'~~ O R ILL I N~ ~D z ACCUMULATOR CAPACITY TEST '1. CHECK AND FiLL ACCUMULATOR RESERVOIR TO PROPER LEVEL WITH HYDRAULIC FLUID. 2. ASSURE THAT ACCUMULATOR PRESSURE IS 3000 PSI WITH 1500 PSI DOWNSTREAM OF THE REGULATOR. 3. OBSERVE TIME, THEN CLOSE ALL UNITS SIMULTANEOUSLY AND RECORD THE TIME AND PRESSURE REMAINING AFTER ALL UNITS ARE CLOSEI:) WITH CHARGING PUMP OFF. 4. RECORD ON NADC REPORT. THE ACCEPTABLE LOWER LIMIT IS 45 SECONDS CLOSING TIME AND 1200 PSI REMAINING PRESSURE. 13-5/8" BOP STACK TEST 1. FILL BOP STACK AND M~dtIFOLD WITH ARCTIC DIESEL. 2. CHECK THAT ALL HOLD DOWN SCREWS ARE FULLY RETRACT- ED. PREDETERMINE DEPTH THAT TEST PLUG WILL SEAT AND SEAT IN WELLHEAJ3. RUN IN LOCK DOWN SCREWS IN HEAD. 3. CLOSE ANNULAR PREVENTER AND l~&J~¥]~S U1)STl~J~/~lv~ OF C~-IOI<ES. DON~T TEST AGAINST CLOSED CHOKES 4. TEST ALL COMPONENTS TO 250 PSI AND HOLD 'FOR 10 MINUTES. 5. INCREASE PRESSURE TO 1800 PSI AND HOLE FOR !0 MINUTES. BLEED TO ZERO PSI. 6. OPEN ANNULAR PREVENTER AND CLOSE TOP SET OF PIPE RAMS. 7. INCREJkSE PRESSURE TO 3000 PSi AND HOLD FOR i0 8. ~~'PRESSU'I~ DOWNSTREAM OF CHOKE ISOLATION ~AL.VES, TO ZERO PSI TO TEST VALVES. TEST REMAINING UNTESTED MANIFOLD .VALVES, IF ANY, WITH 3000 PSI UPSTREAM OF VALVE AND ZERO PSI DOWNSTREAM. BLEED SYSTEM TO ZERO PSI. 9. OPEN TOP SET OF PIPE RAMS AND CLOSE BO1-FOM SET OF PIPE RAMS. 10. INCREASE PRESSURE TO 3000 PSi AND HOLD FOR 10 MINUTES BLEED TO ZERO PSi. 11. OPEN BOt-FOM SET OF PIPE RAMS. BACK OFF RUNNING jOINT AND PULL OUT OF HOLE. CLOSE BLIND RAMS AND TEST TO 3000 PSI FOR 10 MINUTES. BLEED TO ZERO PSI. 12. OPEN BLIND RgJqS AND RECOVER TEST PLUG. MAKE SURE MANIFOLD AND LINES ARE FULL OF ARCTIC DIESEL AND ALL VALVES ARE SET iN DRILLING POSITION. 13. TEST STANDPIPE VALVES TO 3000 PSi. 14. TEST KELLY COCKS AND INSIDE BOP TO 3000 PSi WiTH KOOMEY PUMP. RECORD TEST INFORMATION ON BLOWOUT PREVENTER TEST FORM SIGN AND SEND TO DRILLING SUPERVISOR. PERFORM COMPLE'FE BOPE TEST ONCE A WEEK AND FUNC- TIONALLY OPERATE BOPE DAILY. CHECK LIST FOR NEW WELL PERMITS Company ~ Lease & Well No. /~7~ Z~-I o ITRM APPROVE DATE (~ thru (3) Admin (10 and 12) (4) cas~ A'.r,'/ //-(f-,~"-/ (13 thru 21) ' YES NO REMARKS 1. Is the permit fee attached ...................................... .~- 2. Is well to be located in a defined pool ................... ,..~ .... 3. Is well located proper distance from property line ............... 4. Is well located proper distance from other wells ................ 5. Is sufficient undedicated acreage available in this pool ........ 6. Is well to be deviated and is wellb°re plat included ............ 7. Is operator the only affected party .............................. 8. Can permit be approved before ten-day wait ''' .. 9. Does operator have a bond in force .................................. 10. Is a conservation order needed ...................................... 11. Is administrative approval needed ................................... 12. Is the lease number appropriate ..................................... 13. Is conductor string provided ........................................ 14. Is enough cement used to circulate on conductor and surface ......... 15. Will cement tie in surface and intermediate or production strings ... 16. Will cement cover all known productive horizons ..................... 17. Will surface casing protect fresh water zones ....................... 18. Will all casing give adequate safety in collapse, tension and burst.. 19. Is this well to be kicked off from an existing~wellbore ............. 20. Is old wellbore abandonment procedure included on 107403 .~ .......... 21. Is adequate wellbore separation proposed .......... (5) BOPE ~22 thru 26) Add: W,r,,f il-ri, sC 22. Is a diverter system required ....................................... 23. Are necessary diagrams of diverter and BOP equipment attached ....... 24. Does BOPE have sufficient pressure rating - Test to ~.,~-~rZ> psig .. 25. Does the choke manifold comply w/API RP-53 (Feb.78) .................. 26. Is the presence of H2S gas probable ................................. 27. Additional requirements ............... : ............................. Additional Remarks:.h_)_~ ~L/~-/Z) ~/.J/,/..,~J~,~" ~/~Z~/~ Geo~gy: En~ineerin~: Hw~ ~ LCS ~A~X~EW ~ rev: 10/29/84 6. CKLT ~ITIA~ CEO. U~IT 0~/O~ POOL CLASS STATUS AREA NO. SHORE v~,~' ~ I-.,9 ~ ~ ~11~ o 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. ,~ .... SCHL U.M.B:.Z-:R G E q ........ ..~. LVP O1F~ . ' ~3F ...................... ' .~:~ FILE HEA.O.E F ~ .U E N ~ M :b: : ' ~ .£ T ,, ·3.:,)L SERVICE NAME D~'T E : ~X...$ NUI'~. ~.~.N~.TH ,l' "~.~." ~'. · "E2~ E TYP ...... '"' ..... .~ · ~. · :..t..... · ..~.R.~V~uJ;. E L:. . ....:.:.. · .... ?. '.. ~'...".:....... :.... '.... :...~" ...' .: II ..... ...,:ON ...;. A...~-...A..S~.~ .... ~N..C ...... 0'0 0 0 O 0 · .0.i.6....,. O:S..~ ....................... ~'?W!N".'.. 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