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Home My WebLink About184-202C:\Users\kmjunke\AppData\Local\Microsoft\Windows\INetCache\Content.Outlook\H2LGR515\2023-09-19_22122_KRU_2C-16_ProductionProfile_Transmittal.docx DELIVERABLE DISCRIPTION Ticket # Field Well # API # Log Description Log Date 22122 KRU 2C-16 50-029-21218-00 Production Profile 19-Sep-23 DELIVERED TO Company & Address DIGITAL FILE # of Copies LOG PRINTS # of Prints CD’s # of Copies 1 AOGCC Attn: Natural Resources Technician 333 W. 7th Ave., Suite 100 Anchorage, Ak. 99501-3539 Delivered By: CPAI Sharefile ______________________________ ______________________________________ Date received Signature PLEASE RETURN COPY VIA EMAIL TO: DIANE.WILLIAMS@READCASEDHOLE.COM READ CASED HOLE, INC., 4141 B STREET, SUITE 308, ANCHORAGE, AK 99503 PHONE: (907)245-8951 E-MAIL : READ-Anchorage@readcasedhole.com WEBSITE : WWW.READCASEDHOLE.COM 9/27/2023 PTD: 184-202 T38014 Kayla Junke Digitally signed by Kayla Junke Date: 2023.09.27 09:26:30 -08'00' Ima~roject Well History File' CoverOge XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. J (;~ _/-L'/- ¢-~ 0(¢ Well History File Identifier · RESCAN DIGITAL DATA OVERSIZED (Scannable) O Color items: D Diskettes, No. [] Maps: [] Grayscale items: c] ' Other, No/Type [] Other items scannable by large scanner [] Poor Quality Originals: OVERSIZED (Non-Scannable) [] Other: , NOTES: [] ' Logs of various kinds [] Other BY: (~'~BREN VINCENT SHERYL MARIA LOWELL DATE: ~'-//'"//~... IS~ Project Proofing BY: BEVERLY BREi~~SHERYL MARIA LOWELl_ Scanning Preparation .BY: BEVERLY BREN(~~HERYL MARIA LOWELL DATE:/Js IS/_~~ Production Scanning Stage I P^GE COUNT FROM SCANNED F ~ L E ' ~ ~ ~/~r PAGE COUNT MATCHES NUMBER IN SCANNING PREPARATION' ~ES Stage 2 IF NO IN STAGE 1, PAGE(S) DISCREPANCIES WERE FOUND' YES NO NO BY: BREN VINCENT SHERYL MARIA LOWELL DATE: t' /S! (SCANNING IS COM INT UNLESS SPECIAL ATTENTION IS REQUIRED ON AN INOIVlOUAL PAGE BASIS I RESCANNEDBY.' BEVERLY BREN VINCENT SHERYL MARIA LOWELL DATE: IS~ General Notes or Comments about this file: Quality Checked (done) 10/25/02Rev3NOTScanned.wpd ConocoPhillips aaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 January 1St, 2010 Mr. Guy Schwartz Alaska Oil & Gas Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 C a~-r1~ Dear Mr. Guy Schwartz: Enclosed please find a spreadsheet with a list of wells from the Kuparuk field (KRL)). Each of these wells was found to have a void in the conductor. These voids were filled with cement if needed and corrosion inhibitor, engineered to prevent water from entering the annular space. As per previous agreement with the AOGCC, this letter and spreadsheet serves as notification that the treatments took place and meets the requirements of form 10-404, Report of Sundry Operations. The cement was pumped November 10th, 20th and 24th, 2009. The corrosion inhibitor/sealant was pumped December 29th and 30th, 2009. The attached spreadsheet presents the well name, top of cement depth prior to filling, and volumes used on each conductor. Please call MJ Loveland or Perry Klein at 907-659-7043, if you have any questions. Sincerely, Perry K1 ConocoPhillips Well Integrity Projects Supervisor ConocoPhillips Alaska Inc. Surface Casing by Conductor Anlnulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10-404) Kuparuk Field Date 01/01/10 - Pad 2A. 2C. 2D ~ 3K Well Name API # PTD # Initial top of cement Vol. of cement um ed Final top of cement Cement top off date Corrosion inhibitor Corrosion inhibitor/ sealant date ft bbls ft al 2A-26 50103205750000 2080940 12" n/a 12" n/a 4.25 12/30/2009 2A-27 50103206040000 2091070 36" n/a 36" n/a 12.75 12/30/2009 2C-14 50029212260000 1842100 18' 2.5 50" 11 /20/2009 12.32 12/30/2009 2C-15 50029212190000 1842030 SF n/a 26" n/a 4.67 12/30/2009 2C-16 50029212180000 1842020 SF n/a 33" n/a 7.22 12/30/2009 2D-02 50029211770000 1841520 SF n/a 24" n/a 4.45 12/3012009 2D-03 50029211780000 1841530 SF n/a 24" n/a 4.67 12/30/2009 2D-04 50029211760000 1841510 SF n/a 24" n/a 4.45 12/30/2009 2D-05 50029211570000 1841260 SF Na 24" n/a 4.45 12/30/2009 2D-08 50029211580000 1841270 SF n/a 28" n/a 4.67 12/30/2009 2D-13 50029210700000 1840120 21' 3.0 27" 11/10/2009' 5.1 12/30/2009 2D-14 50029211830000 1841590 SF n/a 24" n/a 6.37 12/30/2009 2D-16 50029211850000 1841610 28' 4.0 26" 11/10/2009 5.1 12/30/2009 3K-27 50029227510000 1970460 7' 1.0 12" 11/24/2009 2.97 12/29/2009 06/08/07 Schlumberger NO. 4286 Schlumberger -DCS 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Company: Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 ~ ]. 2007 SCANNED JUN 1 4 2007 ~V V 115Á/ -c9& Field: Kuparuk Well Job # Log Description Date BL Color CD 2L-321 11629010 MULTI-FINGER CASING INSPECTION 05/12/07 1 2C-16 11629008 PPROFILDL 05/10107 1 2G-11 11638863 PRODUCTION PROFILE 05/05/07 1 1C-125 NIA MEM INJECTION PROFILE 05/05/07 1 2D-13 11638861 PRODUCTION PROFILE 05/03/07 1 2D-08 11638862 PRODUCTION PROFILE 05/04/07 1 2G-09 11638864 PRODUCTION PROFILE 05/06/07 1 2N-349A 11629004 RSTI WFL 05104/07 1 3H-19 11638867 PRODUCTION PROFILE 05/09/07 1 1Q-10 11628771 MEM PRODUCTION PROFILE 05/03/07 1 1 E-11 11629012 INJECTION PROFILE 05/14/07 1 2L-321 11665439 USIT 05/25/07 1 2V-08A 11629013 PMIT 05/15/07 1 1 J-160 11632704 PRODUCTION PROFILE 03/19/07 1 1H-07 11665436 SBHP SURVEY 05/20107 1 2F-11 11665434 PRODUCTION PROFILE 05/19/07 1 2X-07 11665433 INJECTION PROFILE 05/18/07 1 1B-01 11665432 PRODUCTION PROFILE 05/17/07 1 2X-01 11637338 INJECTION PROFILE 05/15/07 1 2Z-29 11665438 PRODUCTION PROFILE 05/22/07 1 1 H-22 11637339 INJECTION PROFILE 05/16107 1 1 Y -11 11632708 INJECTION PROFILE 05/23/07 1 1G-03 11637336 INJECTION PROFILE 05/14/07 1 1A-23 11665443 MEM PRODUCTION PROFILE 05/29/07 1 1 F-08 11665435 SBHP SURVEY 05/20107 1 1J-170 11632709 INJECTION PROFILE 05/24/07 1 1D-109 NIA INJECTION PROFILE 05/13/07 1 2M-24 11665440 SBHP SURVEY 05/28/07 1 I Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. . . . . WELL LOG TRANSMITTAL ProActive Diagnostic Services, Inc. To: AOGCC Howard Ok/and 333 West 7tJ1 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 tJ1e attention of : ProActive Diagnostic Services, Inc. Attn: Robert A. Richey 130 West Intemational Airport Road Suite C Anchorage, AK 99518 Fax: (907) 245-8951 1 BL / EDE Disk 1) 2) 3) 4) 5) 6) 7) 2C - 16 Caliper Report 6-Sept-06 8CANNf.:l5 2() RECE Print Name: Q-~~ CL :~-\-\~ rÎYt\.1 ,¡A,W £ìlA v - "'cI ..... 2 4 Signed: Da~~ au & Gãe t"""g ('i''''''R':1',§'!ì¡ir?1 --- __""".~.",,~~n...... -;,J<-; PRoAcTIVE DIAGNOSTIC SERVICES, INC., 130 W.INTERNATlONAL AIRPORT RD SUITE C, ANCHORAGE, AK 99518 PHONE: (907)245-8951 FAX: (907)245-88952 E-MAIL: PDSANCHORA;3E@I\.1EMORYLOG.COM WEBSITE : W'JVW.fv1EMORYLOG.cori] D;IOO ]DSANC-2006\Z _ W ord\Di.s1ributionlTransmittat SheetslTransmit_ Origínal.doc I~LI-dOd t:t J.<(J C, I I I I I I I I I I I I I I I I I I I I . . Memory Multi-Finger Caliper Log Results Summary Company: Log Date: Log No. : Run No.: Pipe1 Desc.: Pipe1 Use: Well: 2C-16 Field: Kuparuk State: Alaska API No.: N/A Top Log Intvl1.: Surface Bot. Log Intvl1.: 7,796 Ft. (MD) ConocoPhillips Alaska, Inc. September 6, 2006 7100 1 7" 26 lb. Casing Inspection Type: Corrosive & Mechanical Damage Inspection ." COMMENTS: "" This caliper data is tied into the Casing Hanger @ 0' Depth. This log was run to assess the condition of the 7" casing with respect to corrosive and mechanical damages. The 7" casing logged appears to be in good condition with respect to corrosive damage. No penetrations in excess of 20% are recorded in the casing interval logged. No significant areas of cross-sectional wall loss are recorded throughout the 7" casing interval logged. A slight bend is recorded in joints 158 (6,265') and 179 (7,092'). Deposits are recorded in some of the joints in the interval between 6,260' and 7,120', with a recorded minimum 1.0. of 5.96" in joint 176 (6,995'). Cross-sectional drawings of the most significant events recorded are included in this report. The distribution of maximum - recorded penetrations is illustrated in the Body Region Analysis Page of this report. A graph illustrating the correlation of recorded damage to borehole profile is included in this report. MAXIMUM RECORDED WALL PENETRATIONS: Isolated Pitting 165 @ 6,560' Ft. (MD) ( 20%) Jt. No other significant penetrations (> 20%) are recorded throughout the casing interval logged. MAXIMUM RECORDED CROSS-SECTIONAL METAL LOSS: No significant areas of cross-sectional wall loss (> 7%) are recorded throughout the casing interval logged. MAXIMUM RECORDED ID RESTRICTIONS: Deposits Deposits Deposits 176 @ 163 @ 166 @ 6,995 Ft. (MD) 6,474 Ft. (MD) 6,591 Ft. (MD) Minimum 1.0. = 5.96" Minimum 1.0. = 5.98" Minimum 1.0. = 5.99" Jt. Jt. Jt. No other significant 1.0. restrictions are recorded throughout the casing interval logged. RECEIVED OCT 2 4 2006 Field Engineer: Wm. McCrossan Analyst: M. Tahtouh /15'L./ - Qe> d P: /"-l/ 4 I I I I Well: Field: Company: Country: I Tubing: I 2C-16 Kuparuk ConocoPhillips Alaska, Inc. USA Nom.OD 7ins Weight 26 f Grade & Thread L·80 I Penetration and Metal loss (% wall) penetration body I 200 150 100 50 0 o to 1% I I metal loss body 1 to 10% 10 to 20 to 40 to over 20% 40% 85% 85% pene, loss o o I 40 Damage Configuration ( body) I I 30 20 I 10 I o isolated pitting general line ring hole I poss corrosion corrosion corrosion ible hole I o I I I I PDS Report Overview Body Region Analysis Survey Date: Tool Type: Too! Size: No, of Fingers: Anal sl: September 6, 2006 MFC 40 No. 40970 2.75 40 M. Tahtouh Nom.ID 6.276 ins Nom. Upset 7ins Upper len, 1.2 ins Lower len. 1.2 ins Damage Profile (% wall) penetration body o o metal loss body 50 100 150 50 100 Bottom of Survey = 196 Analysis Overview page 2 I I Correlation of Recorded Damage to Borehole Profile Pipe 1 7. in (0.3' - 7768.2') I I I Well: Field: Company: Country: Survey Date: 2C-16 Kuparuk ConocoPhillíps Alaska, Inc. USA September 6, 2006 Approx. Tool Deviation Approx. Borehole Profile 75 2921 0 Q¡ ~ ..Q <-' E lJ.- ::J .S z 100 3930 ..!:: E ..., Q. "() Q) ~ 0 125 4933 I I 25 I 50 I I I I I 150 I 175 I I 196 o 2 949 1936 5936 6926 I Bottom of Survey = 196 Damage Profile wall) / Tool Deviation (degrees) 50 7768 100 I I I I I I I I I I I I I I I I I I I I I PDS REPORT JOINT TABULATION SH Pipe: Body Wall: Upset Wall: NominaIID.: 7. in 26.0 ppf L-80 0.362 in 0.362 in 6.276 in Well: Field: Company: C:oun try: Survey Date: 2C-16 Kuparuk C:onocoPhillips Alaska, Inc. USA September 6,2006 Joint Jt. Depth 1\'11. Pen. Pen. :'vlelal Min. Damage Profile No. (Ft.) '1 Body LD. Comments (%wall) (Ins.) (Ins.) 0 50 100 .1 0 0 0.01 4 1 6.26 PUP 1 2 0 0.01 1 6.26 2 43 I 0.01 1 6.27 3 82 I 0.01 1 6.27 4 122 ( 0.01 ¡ 6.27 5 161 0.01 'j 6.28 6 201 ( 0.D1 í 6.27 7 240 I) 0.01 i 6.28 i 8 280 0 0.01 í2 I 6.28 9 319 0.01 í2 i 6.27 10 359 U 0.01 3 i 6.27 11 398 0 0.01 3 ¡ 6.26 12 438 0 0.01 i ¡ 6.27 13 477 0 0.02 6 I 6.27 14 516 0 0.01 3 2 6.27 15 555 0 0.D1 ¡ 6.26 16 595 0 0.D1 i 6.26 17 634 0 0.01 I 6.27 18 673 0 0.D1 I 6.27 19 713 0 0.01 'I 6.27 20 752 0 0.01 : 6.25 21 792 0 0.01 í2 ¡ 6.26 22 832 0.01 I 6.27 23 870 0.01 1 6.26 24 909 0.01 I 6.27 25 949 0.01 1 6.27 26 989 0.01 I 6.27 27 1028 0 0.01 ¡ 6.24 ¡ 28 1068 0 0.00 1 I 6.25 29 1108 0 0.01 í 6.27 30 1147 ) 0.01 I 6.26 31 1186 0.03 í2 6.26 " 32 1226 0 0.01 I 6.26 33 1265 0 0.01 4 I 6.26 34 1305 U 0.01 I í 6.27 35 1345 U 0.01 3 i 6.26 36 1384 0 0.01 1 6.25 37 1423 U 0.01 1 6.25 38 1462 0 0.01 I 6.29 39 1501 0 0.01 i 6.27 40 1542 0 0.01 I 6.27 41 1581 I 0.01 i 6.28 42 1620 0 0.00 I 6.28 43 1659 I 0.01 I 6.28 44 1699 I 0.02 Ii I 6.27 45 1739 I 0.01 2 'I 6.26 46 1778 ( 0.01 2 i 6.27 47 1818 0 0.01 3 i 6.26 48 1857 0 0.01 2 i 6.28 49 1897 0 0.01 2 ( 6.27 Body Metal Loss Body Page 1 I I I I I I I I I I I I I I I I I I I PDS REPORT JOINT TABULATION SHEET Pipe: Body Wall: Upset Wall: NominaIID.: 7. in 26.0 ppf L-80 0.362 in 0.362 in 6.276 in Well: Field: Company: Coun try: Survey Date: 2C-16 Kuparuk ConocoPhillips Alaska, Inc. USA September 6, 2006 Joint Jt. Depth Pc' Pen. \¡Ietal Min. Damage P rofile No. (Ft.) \;pset Body I.D. Comments (%wall) (Ins.) (Ins.) 0 50 100 50 1936 ( 0.ü1 I 6.27 51 1975 { 0.ü1 I 6.27 52 2015 ( 0.01 I 6.27 53 2054 ( 0.01 I 6.25 54 2094 {¡. 0.01 > 1 6.26 55 2133 (J 0.01 .f -1 6.27 56 2173 n 0.01 j ¡ 6.27 57 2210 n 0.01 ¡ 6.26 58 2249 0 0.01 I 6.25 59 2289 0 0.01 I 6.27 60 2328 0 0.01 I 6.24 61 2368 0 0.01 I 6.28 62 2407 n 0.01 ? ¡ 6.29 63 2447 I) 0.02 'i ) 6.27 64 2485 0 0.01 I 6.28 65 2525 ¡ 0.01 I 6.27 66 2565 0.01 I 6.27 67 2604 0.01 ! 6.27 68 2644 I 0.02 t 1 6.22 II 69 2683 ¡¡ 0.01 l 1 6.29 70 2723 I) 0.00 1 I 6.27 71 2763 I 0.01 I 6.27 72 2802 0.01 I 6.29 73 2841 0.01 I 6.27 74 2882 ¡ 0.01 I 6.25 75 2921 I 0.02 ¡ 6.28 ill ¡ 76 2961 I 0.02 I 6.27 Ii 77 3000 0 0.01 1 6.28 78 3040 0.01 I 6.29 79 3079 I 0.01 6.27 80 3119 { 0.01 ¡ 6.28 81 3160 ( 0.01 I 6.27 82 3198 { 0.01 1 6.25 83 3239 0.01 ¡ 6.27 84 3275 I 0.01 ) I 6.28 85 3317 I) 0.01 1 6.21 86 3358 0 0.01 I 6.28 87 3398 n 0.01 1 6.27 88 3439 U 0.01 , I 6.29 89 3481 U 0.01 í 6.26 90 3523 0 0.01 ¡ 6.28 91 3565 ( 0.01 j I 6.28 92 3602 I) 0.01 ) 6.26 Sli\Zht SliD Mash Unner Bodv. 93 3644 0 0.01 í 6.28 94 3681 0 0.01 ì 6.28 95 3722 ( 0.01 ¡ I 6.26 96 3764 0 0.01 1 6.25 97 3805 0 0.01 1 6.27 98 3846 0 0.01 1 6.27 99 3888 0 0.01 I 6.26 Body Metal Loss Body Page 2 I I I I I I I I I I I I I I I I I I I PDS REPORT JOINT TABULATION SH Pipe: Body Wall: Upset Wall: Nominal JD.: 7. in 26.0 ppf L-80 0.362 in 0.362 in 6.276 in Well: Field: Company: Country: Survey Date: 2C-16 Kuparuk ConocoPhìllips Alaska, Inc. USA September 6, 2006 Joint Jt. Depth Pen Pen. F'en. i Me'lal Min. Damage Profile No. (Ft.) .IP9;' Body I.D. Comments (%wall) (Ins.) (Ins.) 0 50 100 100 3930 0 0.01 :' :' 6.27 101 3970 0 0.01 :' 6.27 102 4012 0.01 I 6.26 103 4049 ( 0.01 1 6.26 104 4087 I 0.01 :' 6.25 105 4128 I 0.01 6.25 106 4170 0 om 6.27 107 4212 0 0.01 6.27 108 4253 ) 0.01 3 6.27 109 4291 0 0.01 6.23 110 4331 I 0.01 3 6.25 111 4373 I 0.01 I 6.27 112 4410 0.02 I 6.27 113 4452 0.04 10 I 6.27 Shallow pitting. !í1i1 114 4493 0 0.02 J 6.26 f" 115 4534 0 0.01 2 6.28 116 4575 0 0.01 I 6.27 117 4614 0 om I 6.29 I 118 4652 0 0.01 ¡ 6.28 119 4693 0 0.01 1 6.27 120 4734 0 0.04 12 I 6.25 Shallow pitting. Wi! 121 4775 0 0.01 3 6.28 122 4815 I 0.01 I 6.26 123 4852 0.01 I 6.26 124 4891 I 0.01 1 6.26 125 4933 0.01 I 6.25 126 4973 I om 1 6.27 127 5012 0 0.01 I 6.26 128 5054 0 0.03 F 6.19 Lt. Deposits. !í1i1 129 5095 0 0.01 1 6.27 130 5133 0 0.01 6.25 131 5174 11 0.01 I 6.26 132 5212 0 0.01 1 6.26 133 5252 11 0.01 I 1 6.25 134 5291 ( 0.01 I 6.27 135 5331 0 0.02 .5 ¡ 6.27 136 5373 I 0.02 6 I 6.26 137 5415 I 0.02 6 1 6.27 138 5452 0.02 I I 6.27 fIB 139 5493 0.01 J 6.27 140 5535 I om I 6.28 141 5577 0 0.04 10 I 6.26 Shallow pitting. !í1i1 142 5618 0 0.03 I 6.28 f" 143 5658 0.02 I 1 6.27 f" 144 5696 0.01 I 6.27 145 5734 0.01 ì 6.27 146 5776 I 0.03 ( ¡ 6.29 Shallow pitting. !í1i1 147 5814 0 0.ü3 ß 1 6.26 !í1i1 148 5856 0 0.03 ß I 6.27 f" I 149 5898 0 0.02 6 ¡ 6.27 Body Metal Loss Body Page 3 I PDS REPORT JOINT TABULATION SH I Pipe: 7. in 26.0 ppf L-80 Well: 2C-16 Body Wall: 0.362 in Field: Kuparuk I Upset Wall: 0.362 in Company: ConocoPhillips Alaska, Inc. Nominal LD.: 6.276 in Country: USA Survey Date: September 6, 2006 I Joint Jt. Depth PC'1 Pen. Pen. ·\·1e(al Min. Damage Profile No. (Ft.) 11'5('( Body LD. Comments (%wall) (Ins.) (Ins.) 0 50 100 I 150 5936 n 0.05 1. 2 6.25 Shallow pittiml. ~I 151 5976 I 0.06 1 2 6.25 Shallow pittiml. 152 6016 ( 0.05 I· I 6.27 Shallow oittim!. ~ 153 6055 ( 0.05 I 2 6.25 Shallow oittin2. 154 6093 0.03 7 ! 6.27 I 155 6134 0.03 9 1 6.26 Shallow oittin2. 156 6173 () 0.Q3 9 1 6.26 Shallow pittin2. 157 6212 0 0.04 II I 6.27 Shallow pittin2. 158 6252 n 0.03 9 6.17 Shallow pittin2. SIi2ht Bend. I 159 6291 n 0.04 11 6.20 Shallow oittin!!. Lt. Deoosits. 160 6331 0 0.04 10 6.23 Shallow oittin\!. 161 6371 0 0.02 (, 6.27 162 6410 (1 0.04 1 1 6.27 Shallow pitting. I 163 6449 0 0.03 2 5.98 Shallow oittìng. Denosits. 164 6488 0 0.04 2 6.18 Shallow pittin!!. Lt. Deoosits. 165 6527 0 0.07 D ) 6.15 Isolated pittin!!. Lt. Deoosits. 166 6567 0 0.03 I 5.99 Shallow oittin2. Deoosits. I 167 6607 0 0.04 10 I 6.12 Shallow Dittin2. U. DeDosits. 168 6646 0 0.02 (, 6.25 Lt. DeDosits. 169 6684 0 0.05 14 I 6.12 Shallow oittim;¡. Lt. Deoosits. 170 6724 0 0.05 n I 6.11 Shallow pittin!!. Lt. Denosits. 171 6764 0 0.02 7 I 6.16 Lt. Deposits. I 172 6805 0.07 19 1 6.20 Shallow nittiflll. U. Deoosits. 173 6847 I 0.04 10 I 6.06 Shallow pitting. Lt. Deposits. 174 6887 ! 0.04 11 2 6.25 Shallow Ditting. 175 6926 ( 0.04 10 1 6.24 Shallow Ditting. I 176 6966 ! 0.04 to 2 5.96 Shallow pitting. Deposits. 177 7005 0 0.02 I 6.23 178 7043 n 0.03 1 6.13 l.t. Deposits. 179 7085 Ii 0.03 2 6.16 Lt. Deposits. Sli\!ht Bend. I 180 7122 0 0.04 12 'I 6.27 Shallow pittim!. 181 7162 Ii 0.03 1 6.28 i 182 7201 0 0.06 16 I 6.25 Shallow Ditting. 183 7243 0 0.04 Iii I 6.18 Shallow pitting. 184 7284 0 0.02 6 I 6.26 I 185 7326 0 0.06 15 I 6.25 Shallow pittin!!. 186 7367 Ii 0.02 6 2 6.26 187 7409 0 0.02 7 1 6.26 188 7444 () 0.04 12 I 6.27 Shallow Ditting. I 189 7485 0 0.03 ß I 6.25 190 7527 () 0.04 1 I 6.26 Shallow pitting. Lt. Deposits. 191 7568 0 0.01 ¡ 6.26 192 7610 0 0.04 1 6.26 Shallow pittinQ. I 193 7652 ( 0.02 4 I 6.25 194 7690 0 0.05 I] I 6.26 Shallow pittimL 195 7728 0 0.04 H 2 6.26 Shallow Ditting. 196 7768 0 0.03 7 5 6.25 End of Log I Body Metal Loss Body I Page 4 I I ............ Well: Field: Company: Country: Tubin : .............. ......- PDS Report Cross Sections 2C-16 Kuparuk ConocoPhillips Alaska, Inc USA 7 ins 26 f L-80 September 6, 2006 MFC 40 No, 40970 ;us 40 M. Tahtouh SUlvey Date: Tool Type: Tool Size: No. of Fingers: Anal st: Cross Section for Joint 165 at depth 6560.307 ft Tool speed = 63 Nominal 10 = 6.276 Nominal 00 = 7.000 Remaining wall area = 99 % Tool deviation = 68 0 Finger 12 Penetration = 0,072 ins Isolated Pitting 0.07 ins = 20% Penetration HIGH SIDE = UP Cross Sections page 1 .. .. ------ ------- .. - - - - PDS Report Cross Sections Well: Field: Company: COUlltIY: Tubin : 2C-16 Kuparuk COllocoPhillips Alaska, Inc. USA 7 ins 26 f 1.·80 Survey Date: Tool Type: Tool Size: No. of Fingers: Anal st: September 6, 2006 MFC 40 ,"!o. 40970 2.75 40 M. Tahtouh Cross Section for Joint 1 76 at depth 6994.777 ft Tool speed 71 NominallD 6276 Nominal 00 = 7.000 Remaining wall area 99 % Tool deviation 650 Finger 15 Projection = -0.356 ins Deposits Minimum 1.0. = 5.96 ins HIGH SIDE = UP Cross Sections page 2 ------ Well: Field: Company: Country: Tubin : ------- - - -- - - PDS Report Cross Sections 2C-16 Kuparuk ConocoPhillips Alaska, Inc USA 7ins 26 f L·80 September 6, 2006 MFC 40 1'10. 40970 :1.75 40 M. Tahtouh Survey Date: Tool Type: Tool Size: ,"io. of Fingers: Anal st: Cross Section for Joint 163 at depth 6474.027 ft Tool speed = 67 NominallD = 6.276 Nominal OD = 7.000 Remaining wall area 99 01<, Tool deviation = 680 Finger 14 Projection = -0.31 ins Deposits Minimum I.D, 5.98 ins HIGH SIDE = UP Cross Sections page 3 nc orane 1. Operations Performed: Abandon D Repair Well D Plug Perforations D Stimulate D Other D Alter Casing D Pull Tubing 0' Perforate New Pool D Waiver D Time Extension D Change Approved Program D Operat. ShutdownD Perforate D Re-enter Suspended Well D 2. Operator Name: 4. Current Well Status: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development 0 Exploratory D ' 184-202 1 306-168 3. Address: Stratigraphic D Service D 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-029-21218-00 7. KB Elevation (ft): 9. Well Name and Number: RKB 33' 2C-16 8. Property Designation: 10. Field/Pool(s): ADL 25654: ALK 2580 Kuparuk River Field 1 Kuparuk Oil Pool 11. Present Well Condition Summary: Total Depth measured 8405' , feet true vertical 6162' , feet Plugs (measured) Effective Depth measured 8020' feet Junk (measured) 7837',8150',8267' true vertical 5871' feet Casing Length Size MD TVD Burst Collapse Structural CONDUCTOR 80' 16" 110' 110' SUR. CASING 3855' 9-5/8" 3855' 3062' PROD. CASING 8394' 7" 8394' 6154'~", r. 0; . .;¡\.""¡~ ;u"ë iti~ß: H.!' ~ $/ Perforation depth: Measured depth: 7881'-7928',7936'-7946',7952'-7970', 8078', 8092'-8112', 8139'-8162' true vertical depth: 5765-5801' , 5807'-5815', 5819'-5833', 5915', 5926'-5941', 5961'-5979' Tubing (size, grade, and measured depth) 3-1/2" , L-80, 7836' MD. Packers & SSSV (type & measured depth) Baker 'FHL' packer @ 7617' No SSSV 12. Stimulation or cement squeeze summary: Intervals treated (measured) not applicable RBDMS BFL OCT () 3 2006 Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casina Pressure Tubinn Pressure Prior to well operation 282 . 2528 3028 -- 161 Subsequent to operation 1009 7943 3632 -- 262 14. Attachments 15. Well Class after proposed work: Copies of Logs and Surveys run _ Exploratory D Development 0 Service D Daily Report of Well Operations _X 16. Well Status after proposed work: Oil0 . GasD WAGD GINJD WINJD WDSPL D 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C,O. Exempt: 306-168 Contact Howard Gober @ 263-4220 Printed Name Howard Gober Title Well Engineer c¡ I¿BICXt> Signature -az~ Phone Date -'T "/ PreDared b""haron AI/sun-Drake 263-4612 ...... f ~ RECEIVt::U · STATE OF ALASKA . SEP 2 9 2006 ALASKA Oil AND GAS CONSERVATION COMMISSION AŠ' ska Oil & Gas Cons, Commission REPORT OF SUNDRY WELL OPERATION A h Form 10-404 Revised 04/2004 OR\G\NAL t-tO b ~h ,.~.oç. Submit ~.t..Ori . 13t2"~~. ~;. ~'Þ'ì[W conOCOPhllllPS4tlaSka, Inc. . KRU 2C-16 ~ 2C-16 TUBING API: 500292121800 Well Tvce: PROD Anale /B) TS: 40 dea @ 7881 (0-7836, SSSV Type: Nioole Orin Comoletion: 12/23/1984 Anrlle @ TD: 41 den @ 8405 OD:3.500, Annular Fluid: Last W/O: 9/9/2006 Rev Reason: WORKOVER, GLV ID:2.992) C/O. PULL PLUG, BALL & ROD Reference LOri: 33' RKB Ref Loa Date: Last Undate: 9/24/2006 Last Taa: 8020 TD: 8405 ftKB LastTaaDate: 9/13/20~0 Casing String - ALL Description Size TOD Bottom TVD wt Grade Thread CONDUCTOR 16.000 0 110 110 62.50 H-40 WELDED SUR. CASING 9.625 0 3855 3062 36.00 J-55 BTC-MOD PROD. CASING 7.000 0 8394 6154 26.00 J-55 BTC-MOD Tubing StrinQ - TUBING Size I TOD I Bottom I TVD I wt I Grade I Thread 3.500 I 0 I 7836 I 5730 I 9.30 I L-80 I EUE 8RD Perforations Summary Interval TVD Zone Status Ft SPF Date TVDe Comment 7840 - 7842 5733 - 5735 2 4 2/20/1985 APERF Squeezed; 4" Dresser Atlas 7881 - 7928 5765 - 5801 4,C-3,C-1,UN 47 12 2/24/1985 APERF 5" Dresser Atlas B 7936 - 7946 5807 - 5815 UNITB 10 12 2/24/1985 APERF 5" Dresser Atlas 7952 - 7970 5819 - 5833 UNITB 18 12 2/24/1985 APERF 5" Dresser Atlas 8010 - 8012 5864 - 5865 UNITB 2 0 2/17/1985 8078 - 8078 5915 - 5915 A-5 0 1 2/24/1985 APERF 4" Dresser Atlas 8092 - 8096 5926 - 5929 A-4 4 6 3/30/1994 APERF 90 dea 'V PH 21/8" Eneriet 8096 - 8098 5929 - 5930 A-4 2 7 3/30/1994 APERF 90 den 'V PH 2 1/8" Eneriet 8098 - 8104 5930 - 5935 A-4 6 6 3/30/1994 APERF 90 deo 'V' PH, 2 1/8" Eneriet 8104 - 8106 5935 - 5936 A-4 2 7 3/30/1994 APERF 90 dea 'V' PH, 2 1/8" Eneriet 8106- 8109 5936 - 5939 A-4 3 6 3/30/1994 APERF 90 den 'V' PH 2 1/8" Eneriet 8109- 8110 5939 - 5940 A-4 1 7 3/30/1994 APERF 90 dea 'V PH, 2 1/8" Eneriet 8110 - 8112 5940 - 5941 A-4 2 6 3/30/1994 APERF 90 den 'V PH 2 1/8" Eneriet 8139 - 8162 5961 - 5979 A-3 23 4 2/24/1985 APERF 4" Dresser Atlas Stimulations & Treatments Interval I Date I TVDe Comment 8010 - 8012 I 2/17/1985 I Cement I ran 200 sx. did not PT, ran 100 more sx 7840 - 7842 I 2/20/1985 I Cement I ran 100 sx did not PT ran 100 more sx Gas Lift MandrelsNalves St MD TVD Man Man Type VMfr V Type VOD Latch Port TRO Date Run Vlv Mfr Cmnt 1 3570 2876 CAMCO MMG GLV 1.5 RK 0.188 1242 9/12/2006 2 5309 4046 CAMCO MMG GLV 1.5 RK 0.188 1247 9/12/2006 3 5837 4401 CAMCO MMG OV 1.5 RK 0.250 0 9/12/2006 4 6893 5073 CAMCO MMG DMY 1.5 RK 0.000 0 9/9/2006 5 7545 5514 CAMCO MMG DMY 1.5 RK 0.000 0 9/9/2006 Other [plugs, eauiD" ete.) - COMPLETION WORKOVER 9/9/2006) Depth TVD TVDe Description ID 33 33 HANGER TUBING HANGER 3.500 516 516 NIP CAMCO DS NIPPLE 2.875 7601 5554 PBR BAKER PBR 2.990 7617 5566 PACKER BAKER FHL PACKER 2.990 7670 5605 NIP CAMCO DS NIPPLE 2.812 7835 5729 Overshot POORBOY OVERSHOT 3.625 Fish - FISH Depth DescriDtion Comment 7837 Old Completion Cut off GLM, 3 blast joints, AVA Nipple, Baker PKR, Cameo D nipple- PUSHED FURTHER DOWNHOLE & OVERSHOT SET @ TOP 9/9/2006 8150 AVA Seal Retainina Band Lost Downhole 3/29/1994 8267 1"DMY DMYVALVE LOST 12/14/1990 OkJ Completion (7837-8260, I I OD:3.500) Perf - - (7936-7946) - - Perf (7952-7970) ~ ~ ~ = - - Perf I I (8010-8012) Perf - I------ (8139-8162) - I------ - I------ Conocóf)hillips Wel/liiew Web Reporting Time Log Summary 08/30/200621 :00 00:00 3.00 MIRU MOVE RURD 08/31/200600:00 05:00 5.00 MIRU MOVE MOB 05:00 13:00 8.00 MIRU MOVE RGRP 13:00 23:00 10.00 MIRU MOVE RGRP 23:00 00:00 1.00 MIRU RPCOfl, SFTY 09/01/200600:00 06:00 6.00 COMPZ RPCOfl, CIRC 06:00 10:30 4.50 COMPZ RPCOfl, CIRC P Jack down pipe shed & carrier, prep for move. Pull pipe shed away, move pits & carrier to 2C-16. Clean up around 2C-09. Move & spot BOPE behind well. Set mats around well. Line up carrier wlwell, layout Herculite for containment. P Back over well and Herculite. Jack and Level carrier. Spot and MU pit module. Install containment under pits. Sco e u derrick and latch down. P Rig shut down to install transferr case. P Transfer case in place; rigging linkage, etc. Continue with install. Note: 24-hr notice of upcoming BOP test given to Lou Grimaldi (AOGCC) at 13:00. Will give 2-hr notice prior to actual test. Transfer case installed and drive lines put back and tested. Put all guards back on and read to o. P Accepted Rig @ 2300 hrs 8/31/2006. Held Pre-spud/pre-job safety meeting with all involved in well kill rocedure. P RU lubricator, Pull BPV. Well has 2250 psi. RU LRS pump truck. Pump 50 bbls hot diesel (185 deg) followed by 310 bbls of hot seawater.(130 deg.) Pumped at 2 BPM holding back pressure with choke taking returns to ti er tank. P Conduct pre-job safety meeting with incoming crew on well kill ops. Circulate 9 bbls 9.0# brine @ 2.0 bpm from pits to tanks using rig pump to assure rig pump operational after previous days rig repairs. Initial pressures tbg=140, IA=120 psi. Swap to 2.5 ppb Flo-Vis sweep; pump 30 bbls at 2.0-2.5 bpm. Swap to 9.0# brine and up rate to 4.0 bpm, circulating 290 psi tbg, 110 psi IA. 150 brine away, losing fluid. Choke wide open. Begin dropping rate to lessen losses; little change. 330 bbls away, approx 50% losses circualting at 2.0 bpm, take rtns back to pill pit and watch for visc ill. Visc sweep to surface w/9.0# brine; losses at 75%. Shut down and monitor. Discuss w/ WO Engineer. Call out DHD to shoot fluid levels and begin mixing high-visc pill. Note: 50 bbls lost on initial seawater/diesel flush, 252 bbls 9.0# lost to well. Monitor well for flow. 13:00 14:30 1.50 COMPZ RPCO~ OWFF P Fluid Ivls shot: 660' tbg, 25' IA. Doesn't appear accurate; have DHD hands get different echometer and re-shoot.Shut in well and watch for build-up. Fluid levels 30' tbg, 47' IA. Verify tbg is on a vac, small amount of gas blowing from IA doesn't re ister on 300 si au e. 14:30 15:30 1.00 P 1/2 hour shut in; 10 psi on lA, 0 psi on tbg. Bleed off (bled quickly). Shut back in and monitor; 1/2 hour shut in, IA=50 psi, tbg =5 psi. Prep to circulate hi h-visc ill to bottom. 15:30 18:00 2.50 P Circulate 30 bbl 3# Flo-Vis pill to open pocket at 2.0 bpm, Tbg=70, IA=10. Close choke and bullhead at 1.25 bpm, Tbg=170 psi, IA=20, spotting pill across perfs. Shut down. 91 bbls including 30 bbl bullhead lost to formation while spotting pill. 393 bbls total lost to formation at shift chan e. 18:00 20:00 2.00 COMPZ RPCO~ OWFF P Monitor well, after 1 hr press on IA 0 and tb O. 20:00 23:00 3.00 COMPZ RPCO~ NUND P Set Cameron HP-BPV. ND tree. Inspect threads in hanger, good shape. Install test dart. Remove tree and adapter from behind rig and NORM test, send in for inspection and refurbish if ossible. 23:00 00:00 1.00 RPCO~ NUND P Start NU BOPE. Total fluid losses for last 24 hrs = 405 bbls. 09/02/200600:00 06:00 6.00 RPCO~ NUND P Continuing to NU BOPE. Filled hole @ 0100 w/14 bbls Fluid loss@ approx. 2 BPH. Filled hole again @ 0415 hrs w/25 bbls. Fluid loss @ approx. 8 BPH. Paged AOGCC at 06:00 regarding BOP test; informed of 7:30 start. Per discussion at 18:00, test waived if he was unable to show John Cris 06:00 07:30 1.50 RPCO~ NUND P Finish NU of BOP stack. Shoot fluid level = 30'; a ears inaccurate. 07:30 11:30 4.00 RPCO~ SFEQ P Begin testing BOP. Gravity feed hole fill into IA @ 09:00 = 19 bbls, 11 :00=21 bbls. 13:00=13 bbls. 11:30 13:00 1.50 COMPZ RPCO~ SFEQ P Complete BOP test @ 11 :30. Pick up Kelly (laying on rig floor post-rig move), supersuck mousehole. Fill hole; took 8 bbls. Hold pre-job safety meeting. Pull lu -off tool and BPV. BOLDS. 15:00 16:00 1.00 Unland hanger @ 114,000 Up; free movement at 105,000. Break out han er. 16:00 18:00 2.00 P Rig up cable sheave, squawk box. String cable over sheave and run to spooler.FiII hole: took 30 bbls. Watered back 9.0 brine to 8.8 18:00 00:00 6.00 P POH laying down the 3-1/2" tubing, pups, and jewelry, Spooling up the ESP cable. Still showing flluid losses but well acts like we are swabbing. Worked pipe up and down try to clean up.Continue to pull as slow as possible. Fluid losses for last 24 hrs = 218 bbls. 09/03/2006 00:00 06:00 6.00 COMPZ RPCO~ PULD P Continue to POH laying down ESP, tubing and jewelry. Shut down monitor well 30 min. 3.2 bbls to fill. Continue pulling slow as possible to prevent swabbin . 06:00 07:00 1.00 COMPZ RPCO~ OWFF P 110 jts out of the hole. Shut down during crew change to monitor fluid loss. 1/2 bbl hole fill 1 hour shut in. Discuss options w/ WO engineer; agree to weigh back up to 9.0# and circulate 8.8# out. Weigh up truck and pit system to 9.0 order out additional load of 9.0# from mud lant. 07:00 09:00 2.00 COMPZ RPCO~ CIRC P Monitor well while weighing up 9.0#. Well beginning to flow; see 1/2 bbl gain in 15 mins. Cut cable above clamp and RBIH. Close annular preventer (AOGCC notified). Fluid up to weight; circulate out 8.8# brine with 9.0#@3.0bpm,110psitbg,10psi csg. 131 bbls pumped, lost 74 bbls. Shut down and monitor. 09:00 10:00 1.00 COMPZ RPCO~ OWFF P 1/2 hour shut-in. Open bag and fill hole, 5 bbls to fill. Prep to continue pulling completion. String cable across sheave. 10:00 11:00 1.00 COMPZ RPCO~ PULD P Resume pulling ESP completion, pumping across top of hole. Pulling slowl to revent swabbin . 11:00 12:00 1.00 COMPZ RPCO~ CIRC P Fluids losses 54 bph. Stop pulling pipe and monitor, filling hole every 1/2 hour. First hole fill after shut down 4.5 bbl in 1/2 hr. 12:00 13:00 1.00 COMPZ RPCO~ OWFF P Shut down ops to repair/recalibrate H2S monitor. Filling hole every 30 mins, hole losses roughly 10 bph; loss rate s oratic. Resume pulling completion filling hole fill every 10 jts. Averaging 14 jts / hr. Hole losses averaging 7-8 bph. 190 jts out of hole @ shift change. 211 bbls fluid lost to the hole durin da shift. 18:00 00:00 6.00 P Continue POH with ESP completion monitoring pipe displacement and fluid losses. LD last of 5 GLM and D nipple. Fluid losses for last 24 hrs =286 bbls. (Lots of asphaltenes on clamps and collars and ESP um full as well. 09/04/2006 00:00 10:00 10.00 COMPZ RPCOFl. PULD P Disconnect and lay down 'Sentry" Gauges. Start breaking apart tandem pumps, separator, seal section, and motor. All bolts very hard to break loose, some had to be chisled out. Heavy asphaltenes on collars and clamps starting at jt 200. Motor full of asphaltenes. Recovered 139 LaSalle Clamps-2 SS bands-4 pressure sensor clamps. No clamps or bands lost in hole. 10:00 11:30 1.50 COMPZ P Clean rig floor after pulling ESP com letion. 11:30 14:30 3.00 COMPZ RPCOFl. SFEO P Set test plug. Retest annular preventer 250/2500 psi. Set wear ring. Centrilift reported all components of ESP completion were recovered. Fluid losses avera e - 9 bbls er hour. 14:30 17:00 2.50 COMPZ RPCOFl. TRIP P MU Baker BHA to dress-off top of 3-1/2" stub at 7819' rkb. BHA consists of 6" sizing shoe, 5.75" TSS WP Ext, 5.75" boot basket, x-over, 4.75" boot basket, 4.75" boot basket, 7" scraper, x-over, 4.75" bumper sub, 4.75" jars, 4.75" drill collars, 3.5" IF um out sub. 17:00 00:00 7.00 COMPZ RPCOFl. TRIP P RIH with Casing Scraper/Mill BHA on PH-6 workstring. 155 jts in the hole at midnight. (averaging 25-30jts / hr). Losses averaging 9-10 bph. Total losses for the da =229 bbls. 09/05/2006 00:00 05:00 5.00 COMPZ RPCOFl. TRIP P Running in the hole with casing scraper and mill to dress off top of 3-1/2" tubin stub. 05:00 08:00 3.00 COMPZ RPCOFl. SFEO P MU and test Kelly on rig floor. 08:00 09:30 1.50 COMPZ RPCOFl. TRIP P RIH with scraper/mill BHA and tag top of stub at 7827.58', rkb. 09:30 12:30 3.00 COMPZ RPCOFl. CIRC P PU string just off stub and circulate bottoms up. Losing approx 30% returns to formation. Getting small amounts of a haltene across shakers. 12:30 13:30 1.00 COMPZ RPCOFl. OTHR P Pump 35 bbl viscosified pill while milling over stub at 7827'. Continue to mill for 10' and ream out inside of stub. 14:30 16:00 1.50 16:00 18:00 2.00 18:00 18:30 0.50 18:30 00:00 5.50 09/06/200600:00 02:00 2.00 02:00 04:00 2.00 04:00 06:30 2.50 P 06:30 08:00 1.50 P 08:00 13:30 5.50 P 13:30 14:30 1.00 RPCOI\ SLKL P 14:30 17:00 2.50 RPCOI\ SLKL P 17:00 18:00 1.00 COMPZ RPCOI\ 18:00 19:00 1.00 COMPZ RPCOI\ PULD Shut down pumps and dry tag stub. Top of stub = 7830' rkb. (242 jts + bha = 7798.16') + 7.70' pup + 3.72' pup + 28' kelly = 7837.58' - 7.58' (from shoe to mill = 7830' rkb. P Monitor well. Set back Kelly. RU to POH. P POH stand back PH-6 work string. P Service rig. P Continue POH with Baker dressing mill assembly and casing scraper. POH slow to prevent swabbing. At BHA at 2400 hrs. P POH LD DC & BHA. Baker shoe showed marks from dressing outside of 3-1/2" stub. Inside mill had a good wear pattern from top of stub. Small amount of metal shavings recovered from ma nets on shaker. P Clean out boot baskets. No significant cuttings, mostly Asphaltines. Clear Baker tools off rig floor. Clear and clean u ri floor. PJSM with rig crews and HES slickline crew. RU slickline. Run 5.5" LIB. Got good impression of 3-1/2" tubing stub, on edge of LIB however. Run PDS memory caliper log in 7" casin from 7830' rkb to surface. RD HES slickline. Send in caliper log to PDS in Houston for full evaluation. Initial caliper results . indicated good casing, so decided to add an extra 4 joints below the packer and begin running completion while waiting on full anlysis from Houston. Prepare to run packer and tailpipe on work strin . PDS Analysis of casing showed minor corrosion and isolated pitting. No penetrations of more than 20% were found throu hout the 10 in interval. P MU Poorboy Overshot & RIH with 5 joints 3-1/2",9.3#, L-80, EUE 8Rd-Mod Tubing. PU & MU 3-1/2" Camco 2.812" DS-Nipple with 10' Tubing pups on each side, and with RHC plug seat in place. MU 1 joint of Tubing. PU & MU Baker FHL Retrievable Packer and PBR assembly. MU crossover to PH-6 work strin . RIH with packer and tail assembly on PH-6 work string. 105 stands in hole at midni ht. 09/07/200600:00 01:00 1.00 P RIH w/ Packer & tail assy on PH-6 work string. Tag top of tubing stub at 7830', slide Poor Boy overshot over stub and saw tattle-tail shear screws shear, set down to no-go at 5-1/2' over stub. PU to up weight plus l' to have acker and tail in settin osition. 01:00 03:30 2.50 COMPZ RPCOII. PACK P Drop dart with setting ball & let fall to DS Nipple. Pressure up to 2500 psi, set packer. Hold pressure for 5 minute test, no bleed off. Bleed off tubing. Pressure up on annulus to 2500 psi and hold for 5 minute test, no bleed off. PU and shear PBR at 42K# overpull. Pull seals out of PBR. LD 1 joint of work string. MU head pin and circulating hose. Top of PBR @ 7596' MD, Top of FHL Packer @ 7610' MD Nabors 3S R 03:30 04:00 0.50 RPCOII. CIRC P Circulate while cleaning rig floor & RU to LD work strin . 04:00 17:00 13.00 RPCOII. TRIP P PJSM. POH LD 3-1/2" PH-6 work string. Inspect seal assembly for any damage, seals look in good condition. Broke connections on Kelly and set back in rathole durin POH. 17:00 18:00 1.00 RPCOII. RURD P Clean rig floor. Pull wear bushing. RU to run 3-1/2" com letion strin . 18:00 21:30 3.50 RPCOII. RCST P MU seal assembly & run 3-1/2" completion string. With string run to 780', gas continues to break out in riser. 21:30 00:00 2.50 COMPZ RPCOII. OWFF T Monitor well. Gas boiling as before, possible slight flow. Circulate 9.0 ppg brine around at 780', no gain or loss while circulating, possible slight flow when pump off. Weight up brine in one pit to 9.6 ppg and circulate around, no gain or loss while circulating, gas still boiling as it breaks out in riser, near static with pump off. Start bringing weight in same pit to 9.8 ppg. (At 0100 hrs, with 9.8 ppg around at 780', gas still breaking out in riser, but no flow, showing slow loss in riser & re are to continue RIH. 09/08/2006 00:00 01:00 1.00 T Weight up one pit to 9.8 ppg and circulate around at 780'. Monitor well, gas still boiling as it breaks out in riser, but no flow and fluid level slowly fallin in riser. 01:00 09:30 8.50 P Resume running 3-1/2" completion after circulating 9.8# brine around top 780' of hole. Locate top of PBR with seals. PU wt of 65K, slack off wt of 42K. Bring pump on-line at 1 bpm and rih until tubing pressure up. RIH 12' to fully land seals in PBR. Pull to slack wt, then s ace out 2'. 10:30 11:30 1.00 COMPZ RPCOI\ HOSO P Pulled 2 joints for proper space out, well started to flow. 11:30 15:30 4.00 COMPZ RPCOI\ OWFF T Shut in Annular preventer and pumped 9.5# brine through choke. Pumped bottoms up and observed pressure. Pressure at 0 psi, so opened annular preventer and observed no flow. resumed space out for landing tubing hanger. Contacted AOGCC about closin of the annular reventer. 15:30 17:00 1.50 COMPZ RPCOI\ CIRC P Spot corrosion inhibited brine from GLM #3 (5832' rkb) to packer (7610' rkb) by pumping 55 bbls of 1% by volume CRW-132 corrosion inhibitor down tubing, followed by 67 bbls of 9.3# brine. 17:00 18:00 1.00 RPCOI\ HOSO P Land tubing hanger and tighten lock-down screws. 18:00 21:30 3.50 RPCOI\ DHEQ P RU lines to test tubing and annulus. Pressure up on tubing to 3000 psi, lost 80 psi in 30 minutes, good test. Bleed tubing down to 2000 psi. Pressure up on IA to test, bled back off and repaired leak in line. Pressure up on IA to 3075 psi, tubing squeezed up to 2700 psi, after 30 minutes IA 3000 psi and Tbg 2950 psi. Bled tubing down to 2000 psi and held 2920 psi on IA for 30 minutes, lost 20 psi on IA and 10 psi from tubing, good test. Bled down tubing and sheared valve in GLM #3 open, sheared at 1500 psi differential. Bled off remainin ressure. 21:30 22:00 0.50 RPCOI\ NUND P Set 'roNo-way check. 22:00 23:00 1.00 RPCOI\ RURD P Blowdown lines. Drain stack. LD mousehole. 23:00 00:00 1.00 RPCOI\ NUND P PJSM. ND BOPE. 09/09/2006 00:00 04:00 4.00 RPCOI\ ND BOP's 04:00 09:00 5.00 RPCOI\ NU 3-1/8" 5M tree. 09:00 12:00 3.00 RPCOI\ NU tree and test void to 250/5000 psi for 10 min. Tested tree to 5000 psi for 10 min. Pull TWC and set BPV. 12:00 12:00 0.00 COMPZ RPCOI\ Release rig at 1200 hrs. . . MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg?ef19{ß/O(.;, DATE: P. I. Supervisor September 03, 2006 \ \,/ 'ðP\ \<t\ FROM: John Crisp, SUBJECT: Petroleum Inspector Well Control Incident Rig I nspection Nabors 3S September 03, 2006: I traveled to CPA's Kuparuk River Field to perform Rig Inspection of Nabors 3S workover on KRU 2C-16. PTD 184-202 Sundry 306-168. ./ CPA Rig Foreman Chris Kennedy contacted me in the North Slope Office that secondary well control equipment was used on well 2C-16. Annular Preventer was closed to control gas influx. When I arrived on the Rig the annular preventer was open & Rig was circulating & conditioning workover fluids to continue POOH. BOP stack was inspected along with Accumulator system. No problems witnessed. The 3 H2S gas detectors were reading from 4 to 6 PPM when inspected. The Rig Foreman Chris Kennedy immediately checked area with calibrated hand held gas detector to determine if State required gas detectors were out of calibration. Determination was made to shut down Operations & / secure well to calibrate & test H2S gas detectors. Calibrated & tested OK. Summary: Rig Inspection performed & gas detectors found out of calibration. Attachments: Well control Email from Nabors 3S. ./ ') Well Control 38 2C-l6 jc.doc 2C-16 Closing Annular Pre venter/ Nabors 3S . . John, l '?<t - ~O~ Per our phone conversation, the annular preventer was closed this afternoon while spacing out with our 3-1/2" completion on weIl2C-16. The well was loaded with 9.0# brine and had been static while running in hole with the completion. We had previously set a packer and seal bore assembly with a workstring, and were in the process of stabbing into the PBR with our completion tubing. We pumped approx. 10 bbls of 9.0# brine down the tubing to locate the top of the PBR, then shut down the pump. As we pulled a few joints to space out, the well started to flow so we shut in the annular preventer. We pumped a bottoms up with 9.5# brine and the well is in static conditions again. Please call with any questions, Brad Gathman 659-7457 ~CANNE~.j) SEP 2 ? 2005 I of I 9/8/20063:53 PM Nabors 3S 1 2C-16 Shut In . . PTb"it- '84-atJ'- John, Per our phone call, the annular preventer was closed this morning while pulling the ESP completion from 2C-16. Well was loaded with 9.0# brine and had been losing on average 8 bph since the kill. Upon unlanding the hanger, losses increased to approx 15 bph at which time the brine system was watered back to 8.8# to mitigate the losses; pulling ops continued while circulating the 8.8# across the top of the hole. Losses lessened to zero at which time pulling ops were suspended to monitor the well and to weigh back up to the original 9.0# . Prior to getting the system weighted up, the well began to flow (approx 1/2 bbl gain in 15 mins) and the annular preventer closed until fluid was up to weight. We are currently circulating the 8.8# out and replacing with the 9.0#. Any questions, call 659-7457. Thanks, Chris Kennedy ~CANN¡;D SE? 2 "1 ,DUE: 1 of 1 9/5/20064:43 PM e e FRANK H. MURKOWSKI, GOVERNOR ALASKA OIL AND GAS CONSERVATION COMMISSION 333 W. 7'H AVENUE. SUITE 100 ANCHORAGE. ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Steve Mukavitz Well Engineer ConocoPhillips Alaska, Inc. PO Box 100360 Anchorage, AK 99510 R1ð- \ «L\; ~ 'J-v Re: Kuparuk River Field, Kuparuk Oil Pool, 2C-16 Sundry Number: 306-168 11 "\ -j Ç'¡ ?nm· ~CANNE.L ,ÞJr~ i iJ_~V J Dear Mr. Mukavitz: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. Sincerely, Of4~~ Cathy P. Foerster Commissioner (" J.. DATED thisZ! day of May, 2006 Enc!. e e Steve Mukavitz Well Engineer Kuparuk Drilling Conoc6Phillips P. O. Box 100360 Anchorage, AK 99510-0360 Phone: 907-263-4021 May 8, 2006 Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 333 West ih Avenue Suite 100 Anchorage, Alaska 99501 .s::r';/~~\fM';,;r ,1 \Ìiìi;1'\fl\f'"'k ...'¡;'_...... '..' ".'"~ Subject: Application for Sundry Approval for 2C-16 Dear Commissioner: ConocoPhillips Alaska, Inc. submits the attached Application for Sundry Approval for the Kuparuk weIl2C-16. If you have any questions regarding this matter, please contact me at 263-4021. Sincerely, 9J;c S. Mukavitz Well Engineer CPAI Kuparuk Drilling SM/skad e e kGl;)3 STATE OF ALASKA ALASKA Oil AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVAL 20 MC 25.280 1. Type of Request: Abandon D Suspend D Operational Shutdown D Perforate D Waiver D Other D Alter casing D Repair well D Plug Perforations D Stimulate D Time Ex1ension D Change approved program D Pull Tubing 0 Perforate New Pool D Re-enter Suspended Well D 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development 0 Exploratory D 184-202 . 3. Address: Stratigraphic D Service D 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-029-21218-00 . 7. KB Elevation (ft): 9. Well Name and Number: RKB 126' 2C-16 . 8. Property Designation: 10. Field/Pool(s): ADL 25654, ALK 2580 Kuparuk River Field 1 Kuparuk 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): 8405' 6162' 7624' 7819' Casing Length Size MD TVD Burst Collapse CONDUCTOR 80' 16" 110' 110' SUR. CASING 3855' 9-5/8" 3855' 3062' PROD. CASING 8394' 7" 8394' 6154' Perforation Depth MD (7881'-7928',7936'-7946', Perforation Depth TVD (ft): 5765'-5801' Tubing Size: Tubing Grade: Tubing MD (ft): 7952'-7970',8078',8092'-8112',8139'-8162' 5807'-5815',5819'-5833',5915',5926'-5941',5961'-5979' 3-1/2" J-55 7765' Packers and SSSV Type: Packers and SSSV MD (ft) no packer no SSSV 12. Attachments: Description Summary of Proposal 0 13. Well Class after proposed work: Detailed Operations Program D BOP Sketch D Exploratory D Development 0 Service D 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: June 28, 2006 Oil 0 Gas D Plugged D Abandoned D 16. Verbal Approval: Date: WAG D GINJ D WINJ D WDSPL D Commission Representative: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Howard Gober @ 263-4220 Printed Name !2 Steve Mukavitz /I . :-=Jc. Title: Well Engineer 1n...^ .vw lb... "/\ ) Sf'i?/Õb Signature Phone 26_-4021 Date L/ Commission Use Only Conditions of approval: Notify Commission so that a representative may witness sun~~tôr:_ll() ~ Plug Integrity D BOP Test ~ Mechanical Integrity Test D Location Clearance D Other: ~~'['!>\"-:..~lo.n-o.~~-\-(~R\ß'<./\\~'~b~ r ~OOO~SI ~'''\~\)M- \S{)\>~ Subsequent Form Required: '-\ro ~ RBDMS 8Ft. MAl[ 24 2006 ð/Lnh lh,- APPROVED BY Date: 5 - ¿3-fJ? Approved by: COMMISSIONER THE COMMISSION Form 10:03 Revled 7/2005 ~ r·IZ·CI(;. Submit in Duplicate ORIGINAL ~ #¡f~ e e Rig Workover - Description Summary of Proposal Well 2C-16 Kuparuk Producer Replace 3-1/2" Tubing and ESP with 3-1/2" Gas Lift Completion / · MIRU Nabors 3S. Kill well with weighted brine (to be determined based on pre-workover BHSIP). Nipple down tree and nipple up and test BOP (pressure test BOP to 3500 psi, based on maximum anticipated surface pressure of 2900 psi). · POOH with 3-1/2" J-55 tubing and ESP completion. If the ESP is not free, chemical cut the tubing in the first full joint above the ESP and fish ESP assembly. · RU slickline. RIH with gauge ring and junk basket to -7800' (top of old straddle assembly across "c" sand perfs at 7819' MD). RIH with 40 arm caliper log for 9-5/8" casing to -7750' MD and run log to surface. Download data at surface for preliminary indication of casing condition. · Run a new string of 3-1/2" 9.3# L-80 tubing, Baker FHL packer and a new gas lift completion. Set packer and shear PBR. · Space out and land tubing. Pressure test tubing and tubing/casing annulus to 3000 psi for 30 minutes. · Nipple up the tree and test. RDMO Nabors 3S. f 81M! 05-08-06 e e ConocoPhillips Alaska, Inc. KRU 2C-16 TUBING 20;;16 API: 500292121800 Well Tvpe: PROD AnQle tã1 TS: 40 deQ tã1 7881 {()'7765, SSSV Type: Nipple Orig 12/23/1984 Angle @ TO: 41 deg @ 8405 00:3.500, Completion: 10:2.992) Annular Fluid: Last W/O: Rev Reason: GLV DESIGN Reference Lo!!: Ref Lo!! Date: Last Update: 10/25/2003 Last TaQ: 7624 top of pump TO: 8405 ftKB Last Tag Date: 4/29/2000 Max Hole Angle: 52 deg @ 2700 Description Size Top Bottom TVD Wt Grade Thread CONDUCTOR 16.000 0 110 110 62.50 H-4ü SUR. CASING 9.625 0 3855 3062 36.00 Jo55 PROD. CASING 7.000 0 8394 6154 26.00 J-55 or......... \ ucnNU \< <))" Size Top I Bottom I TVD I Wt I Grade I Thread 3.500 0 I 7765 I 5676 I 9.30 I J-55 I EUE 8RD Interval TVD Zone Status Ft SPF Date Type Comment 7840 0 7842 5733 05735 2 4 2/20/1985 APERF Squeezed; 4" Dresser Atlas 7881 07928 576505801 ,Co3,C-1,U~ 47 12 2/24/1985 APERF 5" Dresser Atlas B 7936 0 7946 5807 05815 UNITB 10 12 2/24/1985 APERF 5" Dresser Atlas 7952 - 7970 5819 - 5833 UNITB 18 12 2/24/1985 APERF 5" Dresser Atlas 8010 -8012 5864 - 5865 UNITB 2 0 2/17/1985 8078 - 8078 5915 -5915 A-S 0 1 2/24/1985 APERF 4" Dresser Atlas 8092 0 8096 5926 0 5929 A-4 4 6 3/30/1994 APERF 90 deg 'V' PH, 21/8" Eneriet 8096 - 8098 5929 - 5930 A-4 2 7 3/30/1994 APERF 90 deg 'V' PH, 2 1/8" Eneriet 809808104 5930 0 5935 A-4 6 6 3/30/1994 APERF 90 deg 'V' PH, 2 1/8" Eneriet 8104 - 8106 5935 - 5936 A-4 2 7 3/30/1994 APERF 90 deg 'V' PH, 2 1/8" Eneriet 8106 - 8109 5936 - 5939 A-4 3 6 3/30/1994 APERF 90 deg 'V' PH, 2 1/8" Eneriet 8109-8110 5939 - 5940 A-4 1 7 3/30/1994 APERF 90 deg 'V' PH, 2 1/8" Eneriet 8110-8112 594005941 A-4 2 6 3/30/1994 APERF 90 deg 'V' PH, 2 1/8" Eneriet 8139 - 8162 5961 05979 A-3 23 4 2/24/1985 APERF 4" Dresser Atlas Interval Date Tvpe I Comment 8010 - 8012 2/17/1985 Cement I ran 200 SX, did not PT, ran 100 more sx 7840 - 7842 2/20/1985 Cement I ran 100 sx did not PT, ran 100 more sx ,.. SEP St MD TVD Man Man VMfr V Type VOD Latch Port TRO Date Vlv rrr2().7725, Mfr Type Run Cmnt OD:3.500} 1 100 100 CAMCO KBMM CAMCO DMY 1.0 BK 0.000 0 4/30/2000 2 3158 2614 CAMeO KBMM CAMCO GLV 1.0 BK 0.156 1275 0/24/200 3 5096 3901 CAMCO KBMM CAMCO GLV 1.0 BK 0.188 1313 0/24/200 4 5919 4454 CAMCO KBMM CAMCO OV 1.0 BK 0.250 0 0/24/200 SEAL 5 7575 5535 CAMCO KBMM CAMCO CV 1.0 BK 0.000 0 0/24/200 rrr25-7739, ""i,I"'.'''.'' . > 00:6.500) Depth TVD Type Description ID 7592 5548 NIP CAMCO D Nipple 2.750 7660 5597 PUMP Centrilift 513 tandem pum 0.000 7720 5642 SEP Centrilift Tandem Rotarv Gas Seperator 0.000 7725 5646 SEAL 0.000 7739 5656 MOTOR Centrilift 562 Tandem Motor 0.000 Fišh·<FISH = t= Depth Description Comment Perf - I-- 7819 Old Completion Cut off GLM, 3 blast joints, AVA Nipple, Baker PKR, Cameo D (7936-7946) - I- nipple Perf 8150 AVA Seal Retainin!! Band Lost Downhole (7952-7970) ¡¡¡¡¡ ~ 8267 1"DMY - I- Gêî1êral)N.õtes - I-- Date Note - I- 2/14/1999 3158' - suspect bad deflector in GLM, see WSR 2/14/99 - I-- 5919' - suspect bed deflector in GLM see WSR 2/14/99 - I- 2C-09 and 2C-I6 Workovers e e Tom, r '~~-d-Od As a follow up to our discussion this morning. 2C-09 and 2C-16 are currently producing on gas lift and we currently don't have a good number on shut in pressures. The reservoir engineer's early estimate of BHSIP based on offset wells was 3340 psi at 6200' tvd. For a absolute worst case of a full gas column to surface with a .65 gas gravity, maximum surface shut in pressure calculates at approximately 2900 psi. This is the number I stipulated in the Description Summary of Proposal for the two wells. The chances of ever seeing this pressure are obviously very small... the shut in period would have to be extremely long with a full gas column developing. This calculated pressure requires the use of a minimum 3000 psi stack with two rams and an annular. Since the available stack for Nabors 3S is currently a 13-5/8" 5000 psi stack, I stipulated a 3500 psi test pressure. We briefly shut in 2C-09 last week for 36 hours, and a bottom hole pressure of 2371 psi was measured at 5582' tvd with a SICP of 1250 psi (the annulus was likely mostly a column of gas lift gas). The extrapolated BHSIP at the "C" sand perfs was only 2500 psi. We don't feel this was a stabilized pressure. We will get a BHSIP with a longer shut in period just prior to starting the rig workover to better estimate our kill weight fluid. Call with questions. Regards, Steve Mukavitz ConocoPhillips Alaska, Inc. Drilling and Wells Group 907-263-4021 ,'.;;.f'."~NNF"j ~"9:1...<" "" ~,._ -J ~J )- <")' 1 of 1 5/23/2006 11 :35 AM - ) ) ,¡I',~,n J,' ~I' " ;78\" \ ,,~,: I''; 'I' :~' ',' '" I,~b :' /' ;!\' ,I ¡ ! 1 'i" '" ~ r 1" \ ,I ¡ I I. , ;' ~\; \, (:~ ,/,' j'"\ :' i ¡ j ,rj) :: ,I'¡-' ~ :j! I :,~ ,~ =. J,.", '\..~ Iki. ,-, /7'n-\ :¡;::J ì ¡I I'! :1' .,'", :1 ~ i i[ Þ ! it J ;¡ 'I <::;.) U FRANK H. MURKOWSKI, GOVERNOR AItASIiA OILAlWD GAS CONSERVATION COMMISSION 333 W. pH AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Brad Gathman Problem Wells Supervisor ConocoPhillips Alaska, In.c P.O. Box 100360 Anchorage, Alaska 99510 . ~Lf'-d-D~ \ Re: Kuparuk 2C-16 Sundry Number: 305-304 t:' I1)nn~ 'J.' ,IJ ~)~. "'L~ U\ ,1\ SCAWNEtJ¡ \\~O,~ C, d u Dear Mr. Gathman: 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. Please provide at least twenty-four (24) hours notice for a representative of the Commission to witness any required test. Contact the Commission's petroleum field inspector at (907) 659-3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. DATED thisMay of October, 2005 Enc!. 1. Type of Request: Abandon Alter casing 8. Property Designation: Kuparuk River Unit r~ ~ 0 -' t )// () ~ ) STATE OF ALASKA 0; )/Ö/i2/S" ALASKA OIL AND GAS CONSERVATION COMMISSION o o o Suspend 0 o o APPLICATION FOR SUNDRY APPROVAL 20 MC 25.280 Operational Shutdown 0 Plug Perforations 0 Perforate New Pool 0 Change approved program 2. Operator Name: ConocoPhillips Alaska, Inc. 3. Address: P. O. Box 100360, Anchorage, Alaska 99510 7. KB Elevation (ft): RKB 126' Repair well Pull Tubing 11. Total depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): 8405' 6162' Casing Length Size CONDUCTOR 110' 16" SUR. CASING 3729' 9-5/8" PROD. CASING 8268' 7" Perforation Depth MD (ft): 7881'-7928',7936'-7946',7952'-7970',8078', 8092'-8112', 8139'-8162' Packers and SSSV Type: no packer no SSSV 12. Attachments: Description Summary of Proposal [] Detailed Operations Program 0 BOP Sketch 0 14. Estimated Date for Signature Perforate 0 o Stimulate 4. Current Well Class: Development [] Stratigraphic 0 Exploratory 0 Service 0 R£C£/~ SEP 8 0 fOO5\~ Alaska Oil & G C \1 as ons. CfU!1m ·S~ Waiver [jnChOralf1er 0 Time Extension [] Re-enter Suspended Well 0 5. Permit to Drill Number: 184-202 6. API Number: 50-029-21218-00 9. Well Name and Number: 2C-16 10. Field/Pool(s): Kuparuk River Field I Kuparuk Oil Pool PRESENT WELL CONDITION SUMMARY Effective Depth TVD (ft): Plugs (measured): Junk (measured): MD 110' 3855' 8394' TVD Perforation Depth TVD (ft): 5765'-5801',5807'-5815',5819'-5833',5915', 5926'-5941', 5961 '-5979' Immediately Date: Tubing Size: 3-1/2 " Packers and SSSV MD (ft) no packer no SSSV 13. Well Class after proposed work: Exploratory 0 Development [] 15. Well Status after proposed work: Oil [] Gas 0 WAG 0 GINJ 0 Contact: Title: Phone 659-7224 Commission Use Only Conditions of approval: Notify Commission so that a representative may witness Commencing Operations: 16. Verbal Approval: Commission Representative: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Printed Name Brad Gathman y4=' Plug Integrity 0 BOP Test D Burst Collapse Tubing Grade: Tubing MD (ft): J-55 7765' Service 0 Plugged 0 WINJ 0 Abandoned D WDSPL 0 Brad Gathman, 659-7224 Problem Wells Supervisor Date ,,,.¿~,.c>~ s=mb?l~~ ~ Mechanical Integrity Test 0 Location Clearance 0 " 'S-:¡ ~''l <ê.. ¥- \'\ \t. ~ \'0 1\ - 0 ~ "--l ~ \- -\\~ 'êßc ~ -\ GL"'- . 'u ì~\0\1~r-\l Other: f"~'<.. ~ CJ.. ~ " ro~ù- \ \ "\'c~ ~ c:... -\ \ a ,. f'" --- COMMISSIONER APPROVED BY THE COMMISSION RBDMS 8FL 0 CT 1 3 2D05 D~:~mi'itz/!S- ) ) ConocoPhillips Alaska, Inc. SUNDRY NOTICE 10-403 Kuparuk We1l2C-16 (PTD 1842020) September 28, 2005 This application is for an extension of Sundry 303-275 for we1l2C-16 (PTD 1842020) and to document that the AOGCC and ConocoPhillips concur the well maybe produced with a variance from 20 AAC 25.200 (d) Production Equipment. Due to the configuration of the completion with an Electric Submersible Pump (ESP), the well does not have an isolation packer between the tubing and annulus. Approval for an exemption from 20 AAC 25.200 (d) was not documented at the time of the ESP completion. We1l2C-16 was originally completed in December 1984 as a gas lifted producer. The well was re-completed with an ESP in September 1998. The well produced via ESP until April 2000, at which time the pump failed. The AOGCC was notified of the pump failure on August 31, 2001. The well has the capability to flow without the ESP operating and has been kept on production with the ESP deactivated. There are no plans to run another ESP completion in the future. Should the well have another workover the expectation for the completion will be for standard gas lift with tubing and a packer. A casing inspection log will be run as part of a workover. Since the well does not have an isolating packer there is some annular flow (IA) of produced fluids. Wellbore fluids bypass the pump and enter the tubing through a GLM at 7575' measured depth. From that point produced fluids flow up the tubing and out the wellhead to production facilities. Gaslift is maintained on the well through gas lift valves at 3158', 5096', and 5919' to keep annular fluids to the lowest possible depth. The well is equipped with a wellhead Safety Valve System as per regulations. As per this request, ConocoPhillips intends to produce 2C-16 for an unspecified duration with an exemption to 20 AAC 25.200 (d) Production Equipment. ·~IIf;1\:::::::::::::::::: ::::::::::::. :.::: ..:.::::::..... ::::.:: :::::::: ::::::::::: dl(:.~~~¡¡¡:j ConocoPhdUps AI3Sk, a. .' Inc.. '1iØ~~ ~ 2C~16 ~ ~ ~ i TUBING (0-7765, OD:3,500, ID:2,992) SEP (7720-7725, 00:3,500) SEAL (7725-7739, 00:6,500) Perl (7936-7946) Perl (7952-7970) ~ i ~ I ]:m~? 'II:::::" ~¡¡¡1ii:,,'... ":::':',: ':':':¡" " ]',:::::::: ':I::::~" IIIIIIII !:.¡~, ]:::::::::::I:::::.. 111111·j,[:;;;;¡:. " ]1111111: 11~;::~< .........: ........... :;:;:;::::.::::::j" ]'!IIII!:,!'rll .........: :......~.. ':':':':", ,,":'1 I " ~ " I¡¡~ ?!J~ ::::I':'::':":::::::::::::::j ;:;:;:::::;:; :::::':"':::::~ ;:::;:;:::;:;.;.;:;:::; :::::~ ::I;:::::::::T~.:.:t! ~ L, ,';.Ï,.:.;-:" ~ .., :=:!: ~ -+-- -+-- -'I-- .., ;t;;;;;;; ;;;;;¡;; ~ T= --4- J ~ -+- ~ --4- -'I-- - ~ -+- -+ ~ . ) ) API: 500292121800 SSSV Type: Nipple Well Type: PROD Orig 12/23/1984 Completion: LastW/O: Ref Log Date: TD: 8405 ftKB Max Hole Angle: 52 deg @ 2700 Annular Fluid: Reference Log: Last Tag: 7624 top of pump Last Tag Date: 4/29/2000 Casing String·· ALL STRINGS Description Size CONDUCTOR 16.000 SUR. CASING 9.625 PROD. CASING 7.000 Tubing String. TUBING Size Top 3.500 0 KRU 2C-16 Angle (éÐ. TS: 40 deg (éÐ. 7881 Angle @ TD: 41 deg @ 8405 Rev Reason: GLV DESIGN Last Update: 10/25/2003 Top Bottom TVD Wt Grade Thread 0 110 110 62.50 H·40 0 3855 3062 36.00 J·55 0 8394 6154 26.00 J·55 Thread EUE 8RD Interval TVD Zone 7840 . 7842 5733 . 5735 7881 . 7928 5765 ·5801 4,C.3,C·1 ,U~ B 7936 . 7946 5807 . 5815 UNITB 7952 . 7970 5819·5833 UNITB 8010 - 8012 5864 . 5865 UNITB 8078 . 8078 5915.5915 A·5 8092 - 8096 5926 - 5929 A·4 8096 . 8098 5929 - 5930 A·4 8098 . 8104 5930 . 5935 A-4 8104·8106 5935 - 5936 A·4 8106 - 8109 5936 . 5939 A-4 8109 - 8110 5939 . 5940 A·4 8110 - 8112 5940 - 5941 A-4 status Ft SPF Date Type Comment 2 4 2/20/1985 APERF Squeezed; 4" Dresser Atlas 47 12 2/24/1985 APERF 5" Dresser Atlas 10 12 2/24/1985 18 12 2/24/1985 2 0 2/17/1985 0 1 2/24/1985 4 6 3/30/1994 2 7 3/30/1994 6 6 3/30/1994 2 7 3/30/1994 3 6 3/30/1994 7 3/30/1994 2 6 3/30/1994 23 4 2/24/1985 -t 8139 - 8162 5961 - 5979 StHnulåtions & Treatmerits Interval Date Type 8010 - 8012 2/17/1985 Cement 7840 - 7842 2/20/1985 Cement Gas Lift Mandre.lsN.dveS . St MD TVD Man Man Mfr Type 1 100 100 CAMeO KBMM 2 3158 2614 CAMeO KBMM 3 5096 3901 CAMeO KBMM 4 5919 4454 CAMeO KBMM 5 7575 5535 CAMeO KBMM OthEir:(:)IÔgs,':eqÚip;,.etc.)··JéwelrY Depth TVD Type 7592 5548 NIP CAMeO D Nipple 7660 5597 PUMP Centrilift 513 tandem pum 7720 5642 5EP Centrilift Tandem Rotary Gas Seperator 7725 5646 SEAL 7739 5656 MOTOR Centrilift 562 Tandem Motor Fish-:FISH Depth Description 7819 Old Completion A·3 APERF 5" Dresser Atlas APERF 5" Dresser Atlas APERF 4" Dresser Atlas APERF 90 deg 'V' PH, 2 1/8" Enerjet APERF 90 deg 'V' PH, 2 1/8" Enerjet APERF 90 deg 'V' PH, 2 1/8" Enerjet APERF 90 deg 'V' PH, 2 1/8" Enerjet APERF 90 deg 'V' PH, 2 1/8" Enerjet APERF 90 deg 'V' PH, 2 1/8" Enerjet APERF 90 deg 'V' PH, 2 1/8" Enerjet APERF 4" Dresser Atlas Comment ran 200 SX, did not PT, ran 100 more sx ran 100 SX, did not PT, ran 100 more sx V Mfr V Type VOD Latch Port TRO CAMeO DMY 1.0 BK 0.000 0 CAMeO GLV 1.0 BK 0.156 1275 CAMeO GLV 1.0 BK 0.188 1313 CAMeO OV 1.0 BK 0.250 0 CAMeO CV 1.0 BK 0.000 0 Description Date Run 4/30/2000 ·0/24/200:: 0/24/200:: 0/24/200:: 0/24/200:: Vlv Cmnt ID 2.750 0.000 0.000 0.000 0.000 Comment Cut off GLM, 3 blast joints, A VA Nipple, Baker PKR, Camco D nipple Lost Downhole 8150 AVA Seal Retaining Band 8267 1" DMY GeneralNotes Date Note 2/14/1999 3158' - suspect bad deflector in GLM, see WSR 2/14/99 5919' - suspect bed deflector in GLM, see WSR 2/14/99 ) ') ( ( ConocoPhillips Alaska, Inc. SUNDRY NOTICE 10-403 Kuparuk We1l2C-16 (PTD 1842020) September 11, 2003 This application for Sundry approval for well 2C-16 (PTD 1842020) is to document that the AOGCC and ConocoPhillips concur the well may be produced with a variance from 20 AAC 25.200 (d) Production Equipment. Due to the configuration of the completion with an Electric Submersible Pump (ESP), the well does not have an isolation packer between the tubing and annulus. Approval for an exemption from 20 AAC 25.200 (d) was not documented at the time of the ESP completion. ConocoPhillips met with the AOGCC on July 15,2003, at which time verbal permission was received to continue production from the well. The intent of this Sundry is to document AOGCC approval of the variance from the regulation. We1l2C-16 was originally completed in De~emþer 1984 as a_gas lifted producer. The well was re-completed with an ESP in September 1998. The well produced via ESP until April 2000, at which time the pump failed. The AOGCC was notified of the pump failure on August 3 t, 2001. The wen has the capability to flow without the ESP operating and has been kept on production with the ESP deactivated. There are no plans to run another ESP completion in the future. Should the well have another workover the expectation for the completion will be for standard gaslift with tubing and a packer. A casing inspection log will be run as part of a workover. Since the well does not have an isolating packer there is some annular flow (IA) of produced fluids. Wellbore fluids bypass the pump and enter the tubing via (4) gaslift mandrels from 3158'- 7575'measured depth. From that point producéd fluids flow up the tubing and out the wellhead to production facilities. Gaslift is maintained on the well to keep annular fluids to the lowest possible depth (top open GLV). The well is equipped with a wellhead Safety Valve System as per regulations. Recent well test data shows the following results: WELL TEST SUMMARY REPORT f, ~ ~TOTAL FORM TOTAL LIFT GA LIFT GAS \ DS WL LENGTH CHK FTP FTTOILWATEF %WC\FLUID GAS GOR GLR RATE PRES 2C 16 18:25 176 157 128 483 1804 \ 79 2287 641 1327 503 508 873 I 2C 16 17:53 176 152 128523 1735 77 2258 581 1111 485 514 864 \ 2C 16 6:22 176 155 127495 1673 77 2168 565 1141 497 514 874 2C 16 8:26 176 154 126495 1571 76 2066 545 1100 511 511 866 2C 16 20:00 176 161 128583 2261 d 2844 1591 2730 735 500 '- 951 .J As per this request, ConocoPhillips intends to produce 2C-16 for an unspecified duration with an exemption to 20 AAC 25.200 (d) Production Equipment. Summary by Month: Individual Well Production 2001 Jan Feb Mar Apr May Jun Jul Aug Sep Oct Nov Dee Meth Gas Lift Gas Lift Gas Lift Gas Lift Gas Lift Gas Lift Gas Lift Gas Lift Gas Lift Gas Lift Gas Lift Gas Lift Days 31 28 31 30 31 30 31 31 30 29 30 31 Oil 41,672 34,074 32,507 26,437 31,981 28,461 30,776 28,341 26,373 26,356 29,968 33,390 Wtr 114,078 91,958 94,872 83,167 87,575 91,191 96,818 96,913 96,115 105,636 102,408 93,814 Gas 95,531 64,871 42,255 21,231 19,316 19,566 20,203 21,973 24,602 44,924 56,831 50,559 ~S ~ 2001 Totals: Oil 370,336 Water 1,154,545 Gas 481,862 Cum Oil 8,797,822 Cum Wtr 11,955,377 Cum Gas 9,690,561 2002 Jan Feb Mar Apr May Jun Jul Aug Sep Oet Nov Dee Meth Gas Lift Gas Lift Gas Lift Gas Lift Gas Lift Gas Lift Gas Lift Gas Lift Gas Lift Gas Lift Gas Lift Gas Lift Days 31 28 31 30 31 30 31 31 30 31 28 31 "-J Oil 32,256 28,684 31,142 21,087 17,463 16,534 16,838 16,997 14,571 14,243 11,538 16,195 Wtr 88,477 77,790 79,026 76,672 76,478 75,772 75,328 70,261 66,051 64,171 53,088 59,169 Gas 49,758 41,162 41,472 26,717 22,162 19,586 19,799 19,714 22,233 21,081 15,646 21,021 i\..'E; 'A. 2002 Totals: Oil 237,548 Water 862,283 Gas 320,351 Cum Oil 9,035,370 Cum Wtr 12,817,660 Cum Gas 10,010,912 2003 Jan Feb Mar Apr May Jun Jul Aug Sep Oet Nov Dee Meth Gas Lift Gas Lift Gas Lift Gas Lift Gas Lift Gas Lift Gas Lift Gas Lift Gas Lift Gas Lift Gas Lift Gas Lift Days 31 28 31 30 31 30 31 31 30 31 30 31 Oil 14,311 10,577 13,408 13,160 13,822 13,384 18,050 15,264 14,757 15,156 15,138 16,078 Wtr 62,340 48,031 54,703 59,606 59,135 57,650 74,788 58,071 64,181 57,048 63,793 63,841 Gas 31,477 20,971 24,782 32,261 36,533 26,013 48,269 18,257 25,969 21,223 25,910 37,537 S5t:J :\ 2003 Totals: Oil 173,105 Water 723,187 Gas 349,202 Cum Oil 9,208,475 Cum Wtr 13,540,847 Cum Gas 10,360,114 2004 Jan Feb Mar Apr May Jun Jul Aug Sep Oet Nov Dee Meth Gas Lift Gas Lift Gas Lift Gas Lift Gas Lift Gas Lift Gas Lift Gas Lift Gas Lift Gas Lift Gas Lift Gas Lift ---- Days 31 29 31 29 31 30 31 31 30 31 30 31 Oil 17,833 16,764 14,585 13,342 15,259 16,000 13,952 12,607 11,888 14,062 10,516 9,276 Wtr 69,466 60,394 64,777 57,605 68,450 68,523 75,376 77,373 71,615 69,885 77,404 84,575 \0 Gas 60,016 38,939 22,669 15,806 17,146 15,861 23,283 30,096 32,496 35,571 27,415 28,784 ÝJ "S l 2004 Totals: Oil 166,084 Water 845,443 Gas 348,082 Cum Oil 9,374,559 Cum Wtr 14,386,290 Cum Gas 10,708,196 Thursday, October 06,2005 Page 5 Summary by Month: Individual Well Production 2005 Jan Feb Mar Apr May Jun Jul Aug Sep Oet Nov Dee Meth Gas Lift Gas Lift Gas Lift Gas Lift Gas Lift Gas Lift Gas Lift Gas Lift Days 31 28 28 30 31 30 29 31 Oil 6,754 5,692 5,310 4,487 8,167 7,377 7,255 10,813 Wtr 85,771 78,311 80,160 75,752 75,958 71,943 63,134 78,047 Gas 22,395 18,023 20,139 23,054 30,772 26,035 13,243 12,175 o..\le 2005 Totals: Oil 55,855 Water 609,076 Gas 165,836 Cum Oil 9,430,414 Cum Wtr 14,995,366 Cum Gas 10,874,032 '~ Thursday, October 06, 2005 Page 6 ConocoPhillips Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 October 27, 2003 Mr. Tom Maunder Alaska Oil & Gas Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 Dear Mr. Maunder: Enclosed please find 10-404 Report of Sundry Operations regarding wellwork associated with conditions in Sundry Notices #303-274 and #303-275. Gaslift entry point was lowered in wells 2C-09 and 2C-16 to minimize exposure of the casing to produced fluids. Please call Nina Woods, MJ Loveland or me at 907-659-7224 if you have any questions. Sincerely, / Jerry Dethlefs Problem Wen Supervisor ConocoPhillips Alaska Attachments ORIGINAL STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Abandon [] Suspend [~ Operation Shutdown ~] Perforate ~] Variance ~] Annular Disp. r--] Alter casing [-'] Repair Well [~ Plug Perforations {~] Stimulate [-"] Time Extension [-"] Other [] Change Approved Program [~ Pull Tubing [] Perforate New Pool E~] Re-enter Suspended Well [--~ 2. Operator Name: 4. Current Well Status: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development_)~ Exploratory E~] 184-202 / 3. Address: Stratigraphic [] Service r--] 6. APl Number: P. O. Box 10O360 50-029-21218-00 7. KB Elevation (ft): 9. Well Name and Number: RKB 126' 2C-16 8. Property Designation: 10. Field/Pool(s): Kuparuk River Unit Kuparuk Oil Pool 11. Present Well Condition Summary: Total Depth measured 8405' feet true vertical 6162' feet Plugs (measured) Effective Depth measured 8307' feet Junk (measured) true vertical 6087' feet Casing Length Size MD TVD Burst Collapse Structural CONDUCTOR 110' 16" 110' 110' SUR. CASING 3729' 9-5/8" 3855' 3062' PROD. CASING 8268' 7" 8394' 6154' Perforation depth: Measured depth: 7881 '-7928', 7936'-7946', 7952'-7970', 8078', 8092'-8112', 8139'-8162' true vertical depth: 5765'-5801', 5807'-5815', 5819'-5033', 5915I, 5026'-5041', 5961'-5970' OCT Tubing (size, grade, and measured depth) 3-1/2" J-55, 7765' MD. ,I~8S~ ................ Packers & SSSV (type & measured depth) no packer no packer no SSSV no SSSV 12. Stimulation or cement squeeze summary: Intervals treated (measured) N/A Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casin,q Pressure Tubin,q Pressure Prior to well operation 483 641 1804 873 157 Subsequent to operation Not yet tested 14. Attachments 15. Well Class after proposed work: Copies of Logs and Surveys run _ Exploratory [--[ Development F~ Service r--] Daily Report of Well Operations _X 16. Well Status after proposed work: oi FI Gasr-I WAGFI G NJi--I W NJ FI WDSPLFI 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: 303-275 Contact Jerry Dethlefs, 659-7043 Printed Name U.erry Dethlef.~----% ~ _ Title Problem Well Supervisor Signature ~'~'~ (-__._ (~ ~./)~'~'-7~ Phone 907-659-7043 Date / Form 10-404 Revised 2/2003 · U '~..~..?) ~¢JI.~ " SUBMIT IN DUPLICATE ConocoPhillips Alaska, Inc. REPORT OF SUNDRY WELL OPERATIONS 10-404 Kuparuk Well 2C-16 (PTI) 1842020) October 27, 2003 As per conditions set in Sundry #303-275, the following well work was performed on Kupamk well 2C-16. The operation was intended to lower the gaslift injection point into the tubing to the lowest point possible, minimizing the exposure of the casing to produced fluids. 10/23/03: PULLED 1" CV @ 7575' RKB, JOB IN PROGRESS. 10/24/04: PULLED/RAN DV @ 100', PULLED CV'S @ 3158', 5096', 5919', FOUND LIGHT EROSION, AND HEAVY SCALE, SET GLV'S @ 3158' & 5096', SET 1/4" OV @ 5919', SET MACCO HFCV @ 7575'. GConocoPhillips Alaska, Inc, (0-7765, 0D:3.500, ID:2.992) SEP (7720-7725, 0D:3.500) SEAL (7725-7739, 0D:6.500) (7936-7946) Pe# (7952-7970) 2C-16 APl: 500292121800 SSSV Type: Nipple Annular Fluid: Reference Log: Last Tag: 7624 top of pump Last Tag Date: 4129/2000 Casing String - ALL STRINGS Description CONDUCTOR SUR. CASING PROD. CASING Tubing String, TUBING Well Type:I PROD Odg 11212311984 Completion: Last WlO:I Ref Log Date: TO:IS405.KB IMax Hole Angle:IS2 deg @ 2700 perorations Summary Interval 7840-7842 7881-7928 7936-7946 7952-7970 8010-8012 8078-8078 8092-8096 8096-8098 8098-8104 8104-8106 8106-8109 8109-8110 8110-8112 8139.8162 Stiniulati°ns& Treatments TVD 5733-5735 5765-5801 5807-5815 5819-5833 5864-5865 5915-5915 5926-5929 5929-5930 5930-5935 5935-5936 5936-5939 5939-5940 5940-5941 5961-5979 Size Top 16.000 9.625 7.000 Bottom KRU 2C-16 TVD Angle ~ TS:I40 deg (~ 7881 ~ I~e::o~ :: 14:L~ e:E S~II ::05 Last Update:110125/2003 I Thread 110 110 3855 3062 8394 6154 Wt I Grade 62.50 H-40 I 36.00 J-55 I 26.00 J-55 I 3.500 I I 10 7765 5676 9.30 I J-55 I EUE8RD i : Zone Status Ft SPF Date Type Comment I2 I4 12/20/198SlAPERFIsqueezed; 4'' Dresser ,C-3,~C-I,U 47 12 212411985 APERF 5" Dresser Atlas I UNITB ! 110 112 12124119851APERF IS" Dresser Atlas /UNITB / I18 I12 12/24/19851APERFI5" Dresser Atlas / UNITB / I 2 I 0 12/17/19851 I / A-5/ 1011 12/24119851APERF I 4" Dresser Atlas / A-~/ 1416 13/30/19941APERF190deg'v'PH'21/8'' / / I I I I IEnerjet / A~ / 1217 13/30/19941APERF190deg'v'PH'21/8'' / / I I I I IEnerjet / A.~/ 1616 13/30119941APERF190deg'v'PH'2118'' / / I I I I IEnerjet / A~ / 1217 13/30/19941APERF190deg'V'PH'21/8.' / / I I I I IEnerjet / A~ / 1316 13/30/19941APERF190deg'v'PH'21/8.' / / I I I I IEnerJet / A.4/ I ll7 13130/19941APERF190deg'v''PH'21/8'' / / I I I I IEnerjet / A-4 / 1216 13/30/19941APERFI9°deg'v'PH'21/8.' / / I I I I IEnerjet / A-3 I 1231 4 12/24119851APERF I4" Dresser Atlas "${'I""M'D'"i' TV'D''I''' Man I Man I V Mfr"I V'TYpe'l v oD I Latch I Port I TRO I Date I Mfr Type Run 1 r 1°°1 1001CAMCOI KBMM I CAMCO I DMY I 1.0 I BK 10.000 I 0 14/3o/2oool 2 131581 26141CAMCOI KBMM I CAMCOI GLV I 1.0 I BK 10.156 11275~0/24/20031 3 15O961 39011CAMCOI KBMM I CAMCOI GLV I 1.0 I BK 10.18611313~0/24/20031 4 59191 44541CAMCOI KBMM 1CAMCO OV I 1'° I BK 10'2501 0 ~0124/2003~ 5 7575 5535 CAMCO KBMM I CAMCO CV I 1.0 BK 0.000 0 ~10124/2003~ :Other:.:(plugs';;equip.;'etC;)".'jeWelry: ..... ':.' '. ...... = ." ...::'.: .. i' :: · :.: .....' .... : ' Depth I TVDI Type I Description 7592 I 5548 I NIP I CAMCO D Nipple 7660 I 5597 I PUMP ICentrilift513tandempum 7720 I 5642 I SEP ICentrilift Tandem Rotary Gas Seperator 7725 156461 SEAL I 7739 I 5656 I MOTOR ICentriliff562Tandem Motor ·FiSh :,-i FiSH:.' ....... i....: ..: ..... ": · . ....' :...':.'. : .'.' ". "...'".':. · =. Depth I Description Comment Cut off GLM, 3 blast joints, AVA Nipple, Baker PKR, Camco D 7819 IOId Completion I nipple 8150 AVA Seal Retaining Band I Lost Downhole 8267 1" DMY I Gen'erali Nbtb's. ..... : ' : ':..' :.:..:. ' Date I Note 2/141199913158' - suspect bad deflector in GLM, see WSR 2/14/99 15919' suspect bed deflector in GLM~ see WSR 2114/99 Vlv Cmnt ID 2.750 0.000 0.000 0.000 0.000 ALA.SKA OIL AND GAS CONSERVATION COMMISSION FRANK H. MURKOWSKI, GOVERIVOR 333 W. 7~ AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Jerry Dethlefs Problem Wells Supervisor ConocoPhillips (Alaska), Inc. PO Box 100360 Anchorage, Alaska 99510 Re: KRU Kuparuk Pool. Wells Equipped with Electric Submersible Pumps (ESPs) KRU 2C 09 184-221 303-274 ESP failed flowing well KRU 2C 16 184-202 303-275 ESP failed flowing well KRU 3B 13 185-023 303-276 ESP failed gas lifted well KRU 3A 01 185-186 303-277 ESP failed gas lifted well KRU 3B 14 185-024 303-278 ESP failed gas lifted well KRU 3H 04 187-076 303-279 ESP operating KRU 3J 10 185-250 303-280 ESP failed gas lifted well KRU 3M 13 187-040 303-281 ESP failed gas lifted well KRU 3M 14 187-051 303-282 ESP operating Dear Mr. Dethlefs: You recently submitted Sundry Notices (Form 403) for the above nine (9) wells. Each sundry requested an exception to Commission regulation 20 AAC 25.200(d) where wells capable of unassisted flow are required to be equipped with tubing and a packer. It has been determined from examination of Commission records that the installation of ESPs in the wells was approved either by a Commission letter to ARCO Alaska (dated November 11, 1996) or individual sundry notices for some of the wells. No further exception is necessary. As shown in the table listing, two (2) of the pumped wells have operating pumps, five (5) of the wells have failed pumps and are being gas lifted and two (2) of the failed pump wells are flowing. After examination of the sundry applications and the Commission well files, we have determined the following actions with regard to those Kuparuk Pool wells equipped with ESPs: 1. Until the ESPs fail, 3H-04 and 3H-16 should be allowed to continue production with no restrictions. . The sundries for wells 3M-14, 3M-13, 3J-10, 3A-01 and 3B-13 are approved for a 2-year period. Production entry into the tubing should remain at the deepest mandrel as presently configured. o In order to remain in production, the tubing entry configuration of wells 2C-09 and 2C-16 should be changed to be similar to the other failed ESP wells with the fluid entry ~:'..~C~,¢~'~, O~T 1,5 200,t Jerry Dethlefs Problem Wells Supervisor October 2, 2003 Page 2 of 2 nominally at the deepest gas lift mandrel. With the fluid entry changed, the sundries are approved for 2 years. 4. You should submit form 404 to document the completion of the work on 2C-09 and 2C- 16. Please contact Tom Maunder at 793-1250 with any questions. Sincerely, Commissioner STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVAL 20 AAC 25.280 1. Type of Request: Abandon Alter casing Change approved program Suspend [] Operation Shutdown ["-] Perforate Repair well [] Plug Perforations r-] Stimulate Pull Tubing [~ Perforate New Pool [~ [~] Vadance ~-~ [] Time Extension r'~ Re-enter Suspended Well [~ Annular Disp. [] Other ['-'] 2. Operator Name: ConocoPhillips Alaska, Inc. 3. Address: P. O. Box 100360 4. Current Well Class: Development __ J-~ Exploratory Stratigraphic r~ Service 5. Permit to Drill Number: 184-202 6. APl Number: 50-029-21218-00 7. KB Elevation (ft): 9. Well Name and Number: RKB 126' 2C-16 8. Property Designation: 10. Field/Pool(s): Kuparuk River Unit Kuparuk Oil Pool 11. PRESENT WELL CONDITION SUMMARY Total depth MD (fi): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (fi): Plugs (measured): Junk (measured): 8405' 6162' 8307' 6087' 7819' (old packer) Casing Length Size MD TVD Burst Collapse CONDUCTOR 110' 16" 110' 110' S U R. CAS I N G 3729' 9-5/8" 3855' 3062' PROD. CASING 8268' 7" 8394' 6154' Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): i7881'-7928', 7936'-7946', 7952'-7970', 8078', 8092'- 5765'-5801', 5807'-5815', 5819'-5833', 5915', 5926'-5941', 8112', 8139'-8162' 5961 '-5979' 3-1/2" J-55 7765' Packers and SSSV Type: Packers and SSSV MD (ft) no packer no packer no SSSV no SSSV 2. Attachments: Description Summary of Proposal ['~ 13. Well Class after proposed work: Detailed Operations Program [~ BOP Sketch [] Exploratory BI Development ['~ Service [] 14. Estimated Date for Commencing Operations: Immediately 16. Verbal Approval: Date: 15. Well Status after proposed work: Oil [] Gas E~ Plugged D Abandoned [~] WAG I--I G NJ I'--I W NJ r-I WDSP, I--I 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Printed Name J~rry Dethlefs Signature ~r.,x/'~ ~ ~-. '/' Commission Use Only Contact: Jerry Dethlefs, 659-7043 Title: Problem Well Supervisor Phone 659-7043 Date ,~,,~,~'_.~ Conditions of approval: Notify Commission so that a representative may witness Sundry Number: Plug Integrity E~] BOP Test BI Mechanical Integrity Test BI Location Clearance ..~C E~VE E.~"~"; Subsequent Form Required: ~~ Alaska Oil & Gas Cons. Cgm~ssief~ 4~2 BY ORDER OF SUBMIT '~/~¢ p ovedb : H COMM,SS,ON FormlO- 003- ~ ~ ~ ~,"% j~.,_ . . _ IND PLIC ConocoPhillips Alaska, Inc. SUNDRY NOTICE 10-403 Kuparuk Well 2C-16 (PTD 1842020) September 11, 2003 This application for Sundry approval for well 2C-16 (PTD 1842020) is to document that the AOGCC and ConocoPhillips concur the well may be produced with a variance from 20 AAC 25.200 (d) Production Equipment. Due to the configuration of the completion with an Electric Submersible Pump (ESP), the well does not have an isolation packer between the tubing and annulus. Approval for an exemption from 20 AAC 25.200 (d) was not documented at the time of the ESP completion. ConocoPhillips met with the AOGCC on July 15, 2003, at which time verbal permission was received to continue production from the well. The intent of this Sundry is to document AOGCC approval of the variance from the regulation. Well 2C-16 was originally completed in December 1984 as a .gas lifted producer. The well was re-completed with an ESP in September 1998. The well produced via ESP unti~000, at which time the pump failed. The AOGCC was notified of the pump failure on August 31,2001. The well has the capability to flow without the ESP operating and has been kept on production with the ESP deactivated. There are no plans to run another ESP completion in the future. Should the well have another workover the expectation for the completion will be for standard gaslift with tubing and a packer. A casing inspection log will be run as part of a workover. Since the well does not have an isolating packer there is some annular flow (IA) of produced fluids. Wellbore fluids bypass the pump and enter t_he tubi__._..~ng via,(.4) gaslif, t mandrels from 3158'- 7575'measured depth. From that point produced fluids flow up the tubing and out the wellhead ~ilities. Gaslift is maintained on the well to keep annular fluids to the lowest possible depth (top open GLV). The well is equipped with a wellhead Safety Valve System as per regulations. Recent well test data shows the following results: WELL TEST SUMMARY REPORT i~~/o,~TOTAL FORM TOTAL LIFT DS WL LENGTH CHK FTPFTTOILWATE WC/FLUIDGAS GOR GLR RATE 2C 16 18:25 176 157 128483 1804 /79 2287 641 1327 503 508 2C 16 17:53 176 152 128523 1735 177 2258 581 1111 485 514 2C 16 6:22 176 155 127495 1673 177 2168 565 1141 497 514 2C 16 8:26 176 154 126495 1571 ]76 2066 545 1100 511 511 2C 16 20:00 176 161 128583 2261/~ 2844 1591 2730 735 500 864 I / 874 I/ I/ As per this request, ConocoPhillips intends to produce 2C-16 for an unspecified duration with an exemption to 20 AAC 25.200 (d) Production Equipment. A Subsidiary of PHILLIPS PETROLEUM COMPANY 2C-16 Gas Uft MandrelNalve 2 (3158-3159, OD:5.500) SUR. CASING (0-3855, OD:9.625, Wt:36.00) Gas Lift MandreINalve 3 (5096-5097, OD:5.500) Gas Lift MandrelNalve 4 (5919-5920, OD:5.500) Gas Lift MandrelNalve 5 (7575-7576, OD:5.500) NIP (7592-7593, OD:3.500) TUBING (0-7765, OD:3.500, ID:2.992) PROD. CASING (0-8394, OD:7.000, Wt:26.00) PUMP (7660-7720, OD:3.500) SEP (7720-7725, OD:3.500) SEAL (7725-7739, OD:8.500) MOTOR (7739-7788, OD:3.500) Cement (7840-7842) Perf (7840-7842) 1" DMY (8267-8268, OD:3.500) KRU 2C-16 APl: SSSV Type: Annular Fluid: 500292121800 Reference Log: Nipple Last Tag: 7624 top of pump Last Tag Date: 4~29~2000 Casing String - ALL STRINGS Description Size CONDUCTOR 16.000 SUR. CASING 9.625 PROD. CASING 7.000 Tubin9 Strin9 - TUBING Size Top 3.500 0 Well Type: I PROD Orig Completion: 112/23/1984 Last W/O:I Ref Log Date:I TD: 8405 ftKB Max Ho e Ang e: 52 deg (~ 2700 Perforations Summary Interval TVD 7840-7842 5733-5735 7881 -7928 5765-5801 7936-7946 5807-5815 7952-7970 5819-5833 8010-8012 5864-5865 8078-8078 5915-5915 8092-8096 5926-5929 8096-8098 5929-5930 8098-8104 5930-5935 8104- 8106 5935-5936 8106-8109 5936-5939 8109-8110 5939-5940 8110-8112 5940-5941 8139-8162 5961-5979 Stimulations & Treatments Top o Bottom 110 o 3855 o 8394 Angle ~ TS: Angle @ TD: Rev Reason: Last Update: Bottom 7765 40 deg @ 7881 41 deg @ 8405 Reset CVs by ImO 8/12/'2001 TVD I Wt I Grade I 110 I 62.50 I H-40 I 3062 36 00 J-55 6154 26.00 J-55 TVD Wt Grade Thread 5676 9.30 J-55 EUE 8RD IZone I Status I Ft ISPFI Date I Type I Comment / I 2 I 4 1 2/20/1985 I APERFI ,C-3,BC-1,U1 47 12 2/24/1985 APERF UNIT B / I 10 I 12 12/24/19851APERFI UNIT S / I 18 I 12 1 2/24/19851APERFI UNIT B / 1210 12/17/19851 I A-5 / I 0 I 1 12/24/19851APERFI A-4 / 14 I6 13/30/1994IAPERFI A-4 / 1217 I S/30/1994IAPERFI A-4 / I 6 I6 I3/30/1994IAPERFI A-4 / 1217 I3/30/1994IAPERFI A-4 / I 3 I6 I 3/30/1994 I APERF I a-4 I I1 I7 I3/30/1994IAPERFI A-4 / 1216 13130/19941APERF A-3 | I 23 I 4 [ 2/24/19851APERF Interval Date Type 8010-8012 2/17/1985 Cement 7840- 7842 2/20/1985 Cement Thread Squeezed; 4" Dresser Atlas 5" Dresser Atlas 5" Dresser Atlas 5" Dresser Atlas 4" Dresser Atlas 90 deg 'V' PH, 2 1/8" Enerjet 90 deg 'V' PH, 2 1/8" Enerjet 90 deg 'V' PH, 2 1/8" Enerjet 90 deg 'V' PH, 2 1/8" Enerjet 90 deg 'V' PH, 2 1/8" Enerjet 90 deg 'V' PH, 2 1/8" Enerjet 90 deg 'V' PH, 2 1/8" Enerjet 4" Dresser Atlas Comment ran 200 sx, did not PT, ran 100 more sx ran 100 sx, did not PT, ran 100 more sx St MD TVD Man I Man V Mfr VType V ¢ D I Latchl Port I TROI Date Vlv I I I Mfr I Type I ] I Run Cmnt 1I 1001 1001CAMCOI KBMM 1CAMCOI DMY I 1.{) BK 0.000 0 4/30/200C 2131581 26141CAMCOI KBMM I CAMCOI CV I 1.~) BE 0.313I 0 r8/12/2001 3 5096 3901 CAMCO KBMM CAMCO CV I 1.{) BK 0.313 0 18/12/2001 , ~ Q, ~ .... \ ' 4 a~l. 44a4 3A.MCO KBr.'M CAMCO C./ 1.1; .:JK 0.313 0 ~ 12 20;')1 5 7575 5535 CAMCO 'Other (plugs, equip., etc Depth I TVDI Type 7592 I 5548 I NIP 7660 155971 PUMP 7720 I 5642 I SEP 7725 5646I SEAL 7739 5656 MOTOR Fish - FISH KBr.'M CAMCO CV 1 0 .~K 0 313 9 5 21 2001 .. , - Jewelry DescriptiOn ID 2.750 CAMCO D Nipple Centrilift 513 tandem pum Centrilift Tandem Rotary Gas Seperator 0.000 0.000 0.000 Centriliff 562 Tandem Motor 0.000 Depth, Description 7819 Old Completion 8150 AVA Seal Retaining Band 8267 1" DMY Comment Cut off GLM, 3 blast joints, AVA Nipple, Baker PKR, Camco D nipple Lost Downho e Note 3158'- suspect bad deflector in GLM, see WSR 2/14/99 bed deflector in GLM see WSR 2/14/99 ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 October 8, 1998 Mr. David J. Johnston Commissioner State of Alaska Alaska Oil 8,: Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Subject: 2C-16 (Permit No. 84-202/398-196) Report of Sundry Well Operations Dear Mr. Commissioner: Enclosed is the report of Sundry Well Operations to cover any changes made to the completion during the recent workover operations on KRU 2C-16. If there are any questions, please call 265-6120. Sincerely, Graham C. Alvord Kupamk Drilling Team Leader GCA/skad RECEIVED OCT 68 1998 ~Oil& GasCons. Com~or~ Anchorage .,. STATE OF ALASKA"[' ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation Shutdown__ Pull tubing X Stimulate_ Plugging__ Perforate Alter casing __ Repair well __ Other 2. Name of Operator ARCO Alaska, Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510 4. Location of well at surface 1207' FNL, 426' FEL, Sec. 21, T11N, R9E, UM At top of productive interval 1703' FNL, 1543' FEL, Sec. 16, T11N, R9E, UM At effective depth At total depth 1383' FNL, 1662' FEL, Sec. 16, T11N, R9E, UM 12. Present well condition summary 5. Type of Well: Development X Exploratory __ Stratigraphic __ Service 6. Datum elevation (DF or KB) RKB 126' 7. Unit or Property name Kuparuk River Unit 8. Well number 2C-16 9. Permit number/approval number 84-202/398-196 10. APl number 50-029-21218 11. Field/Pool Kul:)aruk River feet Total Depth: measured 8405' true vertical 6161' feet feet Plugs (measured) Effective depth: measured 8307' true vertical 6087' feet feet Junk (measured) fish @ 7819' (refer to note below) Casing Length Size Structural Conductor 80' 16" Surface 3855' 9.625" intermediate Production 8394' 7" Liner Cemented Measured depth True vertical depth 300 sx CS II 110' 110' 850 sx AS III & 3855' 3062' 550 sx Class G 300 sx Class G & 8394' 6154' 250 sx AS I Perforation depth: measured 8139~-8162~~81~9~~811~~~81~4~~81~6~~8~96~~8~98~~8~78~~7952~~797~~~7936~~7946~~7881~~7928~~ 8092'-8112' true vertical 5961'-5979', 5939'-5940', 5935'-5937', 5929'-5931', 5915', 5819'-5833', 5807'-5815', 5765'-5801', 5925'-5940' Tubing (size, grade, and measured depth) 3.5", 9.3#, J-55 @ 7788' Packers and SSSV (type and measured depth) Baker 'DB' Perm. PKR @ 8020' 13. Stimulation or cement squeeze summary Intervals treated (measured) Treatment description including volumes used and final pressure Gas Cons. C0~llliSSiOn 14. Prior to well operation Subsequent to operation Representative Daily Avera.qe Production or Iniection Data ,'-,,,,v,a~l~ OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure 15. Attachments Copies of Logs and Surveys run _ Daily Report of Well Operations X 16. Status of well classification as: Water Injector__ Oil X Gas Suspended__ Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Form 10-4 Title Kuparuk Drilling Team Leader Date SUBMIT IN DUPLICATE NOTE: Old completion equipment left in hole, top of fish @ 7819'. Cut off (iet cut), GLM, 3 blast its., AVA nipple, Baker DB packer and Camco 'D' nipple. Date: 10/6/98 ARCO ALASKA INC. WELL SUMMARY REPORT Page: 1 REMEDIAL AND COMPLETION OPERATIONS WELL:2C-16 RIG:NORDIC # 2 WELL_ID: 999245 TYPE: AFC: 999245 STATE:ALASKA AREA/CNTY: NORTH SLOPE EAST FIELD: KUPARUK RIVER UNIT BLOCK: SPUD:08/25/98 START COMP:08/24/98 FINAL: WI: 0% SECURITY:0 API NUMBER: 50-029-21218-00 08/24/98 (Cl) TD: 0' PB: 8307' 08/25/98 (C2) TD: 0' PB: 8307' 08/26/98 (C3) TD: 0' PB: 8307' 08/27/98 (C4) TD: 0' PB: 8307' 08/28/98 (C5) TD: 0' PB: 8307' 08/29/98 (C6) TD: 0' PB: 8307' 08/30/98 (C7) TD: 0' PB: 8307' 08/31/98 (C8) TD: 0' PB: 8307' MW: 8.5 SUPV:DONALD L. WESTER Turn key well to well rig move from 2C-09 to 2C-16. Accepted rig @ 2200 hrs. 8/24/98. SW PUMPING ANOTHER LCM PILL, SUPV:RICK OVERSTREET Spotted LCM pill. Shut in. MW:ll.3 SW MW:ll.3 SUPV:RICK OVERSTREET Pump LCM pill. Pumped Thicksal. NU BOPE and test to 250/3500 psi. SW LOADING PIPE SHED (DP) MW:ll.3 SW SUPV:RICK OVERSTREET TOOH w/3.5" tubing, changing out couplings, drifting, strapping. POOH WITH BHA #1, 1ST. PA MW:10.9 SW SUPV:RICK OVERSTREET Continue to POH with 3.5" tubing. Set test plug and test to 250/3500 psi. Pull plug, set wear ring. RIH and sting into fish @ 7779' Pump LCM pill. CBU, W/SCRAPER @ 7808' MW:10.9 SUPV:RICK OVERSTREET POOH w/packer. Spear fish @ 7819'. Release spear. SW PU ESP. MW:10.9 SW SUPV:RICK OVERSTREET Set storm packer 8 31' and test. ND BOPE. Change out tubing spool. NU BOPE and test to 350/3000 psi. Set ESP spool and pull storm packer. MAKING UP TUBING HANGER I SUPV:RICK OVERSTREET RIH w/3.5" tubing and ESP. MW:10.9 SW Date: 10/6/98 ARCO ALASKA INC. WELL SUMMARY REPORT Page: 2 09/01/98 (C9) TD: 0' PB: 8307' MW: 0.0 DOILW SUPV:RICK OVERSTREET Continue RIH w/3.5" ESP completion. N/D BOPE and NU tree and test to 250/5000 psi. Freeze protect well. STATE OF ALASKA il ALASKA OIL AND GAS CONSERVATION COMMISSION RECEIVED JUL 2. ;~ 1998 APPLICATION FOR SUNDRY APPROVAI.~ska 0il & Gas Cons. Commission Anchorage u 1. Type of Request: Abandon _ Suspend _ Operation Shutdown __ Re-enter suspended well _ Alter casing _ Repair well _ Plugging __ Time extension _ Stimulate _ Change approved program_ Pull tubing ~ Variance_ Perforate_ Other X Install ESP 2. Name of Operator 5. Type of Well: 6. Datum elevation (DF or KB) Development _~X ARCO Alaska, Inc. Exploratory _ 126' RKB feet 3. Address Stratigraphic _ 7. Unit or Property name P. O. Box 100360, Anchorage, AK 99510 Service _ Kuparuk River Unit 4. Location of well at surface 8. Well number 1207' FNL, 426' FEL, Sec. 21, T11N, R9E, UM 2C-16 At top of productive interval 9. Permit number 1703' FNL, 1543' FEL, Sec. 16, T11 N, R9E, UM 84-202 At effective depth 10. APl number 1543' FNL, 1603' FEL, Sec. 16, T11 N, R9E, UM 50-029-21218 At total depth 11. Field/Pool 1383' FNL, 1662' FEL, Sec. 16, T11N, R9E, UM Kuparuk River 12. Present well condition summary Total Depth: measured 8405' feet Plugs (measured) None (approx) true vertical 6161 ' feet Effective depth: measured 8307' feet Junk (measured) (approx) true vertical 6087' feet Casing Length Size Cemented Measured depth True vertical depth Structural Conductor 80' 16" 300 sx CS II 110' 110' Surface 3855' 9.625" 850 sx AS III 3855' 3062' Intermediate & 550 sx Class G Production 8394' 7" 300sx Class G & 8394' 6154' Liner 250 sx AS I Perforation depth: measured 8139'-8162', 8109'-8110', 8104'-8106', 8096'-8098', 8078', 7952'-7970', 7936'-7946', 7881 '-7928', 8092'-8112' true vertical 5961 '-5979', 5939'-5940', 5935'-5937', 5929'-5931 ', 5915', 5819'-5833', 5807'-5815', 5765'-5801 ', 5925'-5940' Tubing (size, grade, and measured depth) ORi6!NAL Packers and SSSV (type and measured depth) . AVA 'RHA-XL' @ 7809', Baker 'DB' Perm. PKR @ 8020', AVA 'STV' SSSV @ 1904' 13. Attachments Description summary of proposal X Detailed operation program __ BOP sketch_× Contact Mark Chambers at 265-1319 with any questions_. 14. Estimated date for commencing operation 15. Status of well classification as: Au.qust 1998 Oil X Gas_ Suspended_ 16. If proposal was verbally approved Name of approver Date approved Service __ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. .../. Signed'~~ ~_~ g"¢K, (~,C,/~z, v'O~. ~:~ Title Kuparuk Drillin9 Team Leader Date FOR COMMISSION USE ONLY Conditions of approval: Notify Commission so repr,es~e~tative may witness IApproval Plug integrity_ BOP Test __~ Location clearance__ I N°Jl¢ --/ Mechanical Integrity Test_ Subsequent form requir~P'~Sigflea David W. Johnston'~ Approved by the order of the Commission Commissioner Date _ Form 10-403 Rev 06/15/88 SUBMIT I1 --RI LICATE KRU 2C-16 GENERAL WORKOVER PROCEDURE PRE-RIG WORK: 1. RIH w/wireline. Set isolation sleeve across AVA Nipple. 2. RU CTU and cleanout down to PBTD. 3. RIH w/wireline and pull isolation sleeve across AVA Nipple and pull DV from GLM #8 @ 7735' leaving an open pocket. 4. RU E-line unit. Chemical cut tubing 2' down into 10' pup joint above packer @ 7987'. In middle of first full joint above blast joints @ 7819'. 5. Set BPV in tubing. Install VR plug in annulus valve. GENERAL WORKOVER PROCEDURE: 1. MIRU Nordic Rig. Lay hard-line to tree. Pull BPV and VR plug. Load pits w/sea water. Displace tubing and annulus w/sea water. SI well and determine kill wt fluid required. 2. Load pits w/kill wt brine (expected kill wt = 10.7 ppg). Circulate well to brine. Ensure well is dead. Set BPV. 3. ND tree. NU and test BOPE. 4. Screw in landing joint. POOH w/3-1/2" tubing changing out couplings to modified thread. Stand back tubing and lay down all jewelry. 5. PU DP and RIH with spear. Latch into PBR barrel and pull retrievable packer free. POOH with packer, GLM and tubing down to cut above blast joints. 6. RIH w/overshot. Wash over tubing stub and fish blast ring joints. POOH and lay down fish. RIH w/overshot and fish remaining completion equipment down to bottom production packer. POOH and lay down fish. 7. RIH and mill permanent packer. POOH. RIH with spear and fish permanent packer. POOH w/fish. 8. PU bit and scraper. RIH cleaning out well to PBTD. Circulate hole clean. 9. Set storm packer and change out tubing head for ESP completion compatibility. Pull storm packer and verify well is dead. POOH laying down DP. 10. RIH w/Electric Submersible Pump completion on 3-1/2" tubing as per attached schematic. MU ESP cable penetrator system and conductor for downhole pressure gauge through tubing hanger. Test wellhead penetrators, tubing, and both cable conductivity's as needed. 11. ND BOPE. NU and test tree. Flush well with diesel. Lower Limit: 9.0 days Expected Case: 10.0 days Upper Limit: 12.0 days No problems pulling or re-running completion Difficulties encountered pulling completion, or running ESP completion MAC 5/29/98 2C-16 Proposed Completion M. 3-1/2" 5M FMC Eccentric tubing hanger with 'BIW' penetrators for ESP cable (125 amp) and downhole gauge conductor wire. 3-1/2" L-80 EUE 8rd tubing pup below hanger. Flat #1 power cable with tech wire in double armor wrap L. Rerun 3-1/2" J-55 EUE 8rd Mod IPC tbg to surface. Space-out 3-1/2" x 1" Camco 'KBMM' mandrels (box x box) w/DV's as follows: GLM# MD-RKB 2 TBD 3 TBD 4 TBD 5 100' NOTE: Install LaSalle cable protectors over the cplg of each of the first 6 joints above the bottom GLM, followed by every other joint to surface. (With the exception of each GLM as noted below.) Each GLM should be made up with a 10' pup below and a LaSalle cable protector placed on cplg below pup. LaSalle ESP Cable Protectors spaced out as per procedure Cable splice from motor lead to flat #1 power cable adjacent to 10' pup above pump LaSalle ,~ Protectolizers at each flange of ESP assembl, K. 3-1/2" X 1" Camco 'KBMM' mandrel (box x box) with STS-1 dump kill valve (pinned for 3500 psi tubing to casing differential). J. Pup jt, 3-1/2" x 10' L-80 EUE 8rd Mod tubing with LaSalle cable protector on cplg between 10' and 20' pups. I. Pup jt, 3-1/2" x 20' L-80 EUE 8rd Mod tubing. H. Internal sensing Baker 'Sentry' gauge with special cplg to replace conventional cplg on full joint of tubing below gauge. Conductor Wire for gauges will be run to surface with-in the 2nd Armor wrap of ESP cable. G. 1 jt of Rerun 3-1/2" J-55 EUE 8rd Mod IPC tbg w/annulus sensing Baker 'Sentry' gauge clamped to tbg OD. F. 3-1/2" Camco 'D' landing nipple with 2.75" No-Go profile. Standing Valve to be set as nipple is made-up. E. Pup jt, 3-1/2" x 4' L-80 EUE 8rd Mod tubing with LaSalle cable protector on cplg below pup. D. Centrilift '182GC8200' Series 513 Triple Pump with bolt-on intake and bolt on discharge head. 3-1/2" x 10' L-80 handling pup on top. C. Centrilift 'GRSXBCTH6' Tandem Rotary Gas Separator. B. Centrilift 'GST34B HL PFS' Tandem Seal Section. A. Centrilift '570 HP KMH 3560/98' Series 562 Motor with Motor Lead Extension Cable. Motor has a 6" centralizer threaded into base. Bottom of motor set at +/- 7796' MD RKB. 7" 26# J-55 @ 8394' C Sand Perfs A Sand Perfs PBTD @ 8307' 7881' - 7928' 12 SPF 7936' - 7946' 12 SPF 7952' - 7970' 12 SPF 8078'-8078' I SPF 8092'-8112' 6 SPF 8096'-8098' I SPF 8104'-8106' 1 SPF 8109'-8110' 1 SPF 8139'-8162' 4 SPF Perf depths are per E-Line log (-25' from tubing tally) WSI 2/12/98 ARCO Alaska, InC. l~',.' Post Office .. ~00360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 January 16, 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 ACTION 2C- 1 2 Stimulate 2C- 1 6 Stimulate If you have any questions, please call me at 263-4241. Sincerely, P. S. White Senior Operations Engineer CC: J. R. Brandstetter ATe 1120 L. L. Perini ATe 1130 S. M. Renke ATe 1126 KeEl .4-9 w/o attachments ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany AR35-6003-C ! STATE OF ALASKA ~ ~ OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Operation Shutdown m Pull tubing Alter casing Stimulate ~ Plugging Repair well Perforate Other 2. Name of Operator ARCO Alaska. Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510 5. Type of Well: Development Exploratory Stratigraphic Service . Location of well at surface 1207' FNL, 426' FEL, Sec. 21, T11N, R9E, UM At top of productive interval 1703' FNL, 1543' FEL, Sec. 16, T11N, R9E, UM At effective depth 1543' FNL, 1603' FEL, $ec.16, T11N, R9E, UM At total depth 1383' FNL~ 1662' FEL~ Sec. 16r T11N~ R9Er UM 12. Present well condition summary Total Depth: measured true vertical 8405' 6161' feet feetq Plugs (measured) None 6. Datum elevation (DF or KB) 62oo' s~ 7. Unit or Property name Kuparuk River Unit feet 8. Well number 2C-16 9. Permit number/approval number 84-202/90-§4i~ 10. APl number 5o-029-2121t~ 11. Field/Pool Kuparuk River Oil Pool Effective depth: measured 8 3 0 7' true vertical 6087' feet feet Junk (measured) None Casing Length Size Structural Conductor 8 0' 1 6" Surface 3 85 5' 9 5/8" Intermediate Production 839 4' 7" Liner Perforation depth: measured 8139'-8162', 8109'-8110', 8104'-8106', 7881 '-7928' true vertical 5961 '-5979', 5939'-5940', 5935'-5937', 5765'-5801' Tubing (size, grade, and measured depth) 3 1/2", 9.3 Ib/ft, J-55, 8016' Packers and SSSV (type and measured depth) Cemented Measured depth True vertical depth 300 Sx CS II 1 10' 1 10' 850 Sx AS III & 3855' 3062' 550 Sx Class G 300 Sx Class G 8 3 9 4' 61 5 4' 250 Sx AS I 8096'-8098', 8078', 5929'-5931', 5915', 7952'-7970' 7936'-7946', 5819'-5833', 5807'-5815', SSSV AVA STV ~ 1879'~ PKR Avg AVA @ 7794'~ PKR Baker DB ~ 7995' 13. Stimulation or cement squeeze summary Refractured A Sand Intervals treated (measured) 8078' - 8162' MD Treatment description including volumes used and final pressure 49,000 lbs. of 12/18 Carbolite, Final Treatincj Pressure 4421 psi 14. Reoresentative Dailv Average Production or In!ection Dat~ OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Alaska 0ii & Gas Cons. C0mm[ss%0t~ Anchorage Tubing Pressure Prior to well operation 496 '"' 221 50 1250 246 Subsequent to operation 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations 984 '-"' 476 17 1600 16. Status of well classification as: Water Injector__ Oil X Gas Suspended Service 174 Form 10-404 Rev 09/12/90 f (.,/SUBMIT IN DUPLICATE ARCOAlaska, Inle ~ Subsidiary of Atlantic Richfield Comp~l~ WELL CONTRACTOR ~k//,~_,~ ~ 'EMARKS FIELD- DISTRICT. STATE OPERATION AT REPORT TIME WELL SERVICE REPOR' IDAYS ID~j~E -//-~,o o~oo - oq$o - I~o - Iqo$ - iq/5 - ,~"//,,¢u . F',.,,¢. ~.,'/, /quT' I '-I ,s '--! /~o 11/5 17'/1 i 7o7~ . R (LE !VED ' ,JAN ~.'2 ~991 Alaska Oil & Gas Cons. Commission Anchorage [-] CHECK THIS BLOCK IF SUMMARY CONTINUED ON BACK knotsI ARCO Alaska, Inc. Post Office Box Anchorage, Alaska ~)9510-0360 Telephone 907 276 12'15 August 13, 1990 Mr. C. V. Chatterton, Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Chatterton: Attached in triplicate is an Application for Sundry Approval on the following Kuparuk well. Well Action Anticipated Start Date 2C-16 Stimulate August, 1990 If you have any questions, please call me at 263-4241. Sincerely, P. S. White Senior Operations Engineer cc: J.R. Brandstetter ATO 1120 w/o attachments L. Perini ATO 1130 KOE1.4-9 ARCO Alaska, ~nc. is ~ Subsidiary of ~"' STATE OF ALASKA COMM~ONISo AI_~b,,A OIL AND GAS CONSERVATION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon _ Suspend _ Alter casing _ Repair well Change approved program _ Operation Shutdown _ Re-enter suspended well _ _ Plugging _ Time extension _ Stimulate __X_ Pull tubing _ Variance _ Perforate _ Other 2. Name of Operator ARCO Alaska. Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510 5. Type of Well: Development Exploratory Stratigraphic Service 4. Location of well at surface 1207' FNL, 426' FEL, Sec. 21, T11N, R9E, UM At top of productive interval 1703' FNL, 1543' FEL, Sec. 16, T11N, R9E, UM At effective depth 1543' FNL, 1603' FEL, Sec.16, T11N, R9E, UM At total depth 1383' FNL, 1662' FEL~ Sec. 16~ T11N, R9E, UM 12. Present well condition summary Total Depth: measured Effective depth: 8405' true vertical 61 61 ' measured 83 0 7' true vertical 6 0 8 7' Length Size 80' 16" 3855' 9 5/8" 8394' 7" feet Plugs (measured) feet None Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: 8139'-8162', 7881 '-7928' feet Junk (measured) feet None Cemented 6. Datum elevation (DF or KB) 6200' S~ 7. Unit or Property name Kuparuk River Unit feet 8. Well number 2C-16 Producer 9. Permit number 84-202 10. APl number 5o-029-21 21 8 11. Field/Pool Kuparuk River Field Kuparuk River Oil Pool Measured depth ~l~cal depth 300 Sx CS II 1 10' 1 10' 850 Sx AS III & 3855' 3062' 550 Sx Class G 300 Sx Class G 8 3 9 4' 61 5 4' 250 Sx AS I measured 8109'-8110', 8104'-8106', 8096'-8098', 8078', true vertical 5939'-5940', 5935'-5937', 5961 '-5979', 5765'-5801' Tubing (size, grade, and measured depth 3 1/2", 9.3 Ib/ft, J-55, 8016' Packers and SSSV (type and measured depth) 7952'-7970' 7936'-7946', 5929'-5931', 5915', 5819'-5833', 5807'-5815', 13. Refracture A Sand with 50,000# of Iow density intermediate 14. Estimated date for commencing operation 15. August 20. 1990 16. If proposal was verbally approved Name of approver Date approved SSSV AVA STV @ 1879'~ PKR Avg AVA @ 7794'r PKR Baker DB @ 7995' Attachments Description summary of proposal _ Detailed operation program X BOP sketch _ strength, ceramic proppant. Status of well classification as: Oil X Gas _ Suspended _ Service Oil Producer 17. I h.~~ i~/~t thej, JZ~'~ _f°r~'g°ing is true and correct to the best of my knowledge. Si~lned--~'"-~. ~· I/~' ~""/v'-- Title Senior Operations Engineer FOR COMMISSION USE ONLY Conditions of approval: Notify Commission so representative may witness Plug integrity_ BOP Test_ Location clearance__ Mechanical Integrity Test_ Subsequent form require 10-''~-OT' IAppr_oval N.o.~ .¢/ Approved by the order Commission ORIGINAL SICNED BY LONNIE C. SMITH Commissioner Form 10-403 Rev 5/03/89 Approved Copy ... ~ztur~ed i ; '_Zl- I SUBMIT IN TRIPLICATE APPLICATION FOR SUNDRY APPROVALS- Addendum , . . No workover fluid is required for this operation. No BOP's are required for this operation. The estimated A Sand BHP at 6200' SS is 2450 psi. M. Lyden / L. Wade August 8, 1990 Page 4 Kuparuk Well 2C-16 A Sand Refracture AFE #K81573 PRE-FRAC 1. SLICKLINE MIRU slickline unit. Tag fill. NOTE: If fill is tagged above 8150' MD-RKB, a CTU cleanout is recommended before refracturing. 2. Pull AVA at 7980' MD-RKB and replace with AVA blanking sleeve. 3. Pull GLV's from mandrels at 5257', 5946', 6412', and OV from mandrel at 6854' MD-RKB. Replace with DV's. NOTE: Fill annulus with diesel before installing the DV at 6854' MD-RKB. 4. RDMO slickline unit. 5. Obtain a 24 hour A Sand only well test. FRACTURE TREATMENT 6. RU fracture equipment. Install 'Tree Saver'. Pressure up 7" annulus to 3500 psi. , Perform all fluid quality control procedures (On-site Operations Engineer). Obtain samples of: Clean proppant Pre-pad, pad, 2, 8, and 12 ppa stages and flush Record proppant weight before and after the frac. 8. Pump the 150 bbl pre-pad at 25bpm. 9. Pump refracture treatment per the attached schedule: WHTPE = 3800 psi Fracture Gradient = 0.70 psi/ft (5960' TVD) Tubing Friction = 300 psi/1000 ft (8015' MD) Recommended Max. WHTP = 6500 psi 10. NOTE: Rig down frac equipment. If treating pressure during the job exceeds 5500 psi, reduce rate. M. Lyden/L. Wade August 8, 1990 Page 5 POST FRAC 1 1. RU Slickline unit. 12. Tag fill. 13. RDMO slickline unit. 1 4. Follow attached flowback schedule. After well has completed flowback, obtain a 24 hour test. The well should be left on A Sand only production. ARCO Alaska, In(~'' Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 Date: August 11, 1987 Transmittal # 6020 RETURN TO: ARCO Alaska, Inc. Attn: Kuparuk Records Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted herewith are the following items. Please acknowledge receipt and return one signed copy of this transmittal. lA-5 Static Well Pressure Report 6-8-87 2T-13 PBU Well Pressure Report 7-11-87 2A-11 PBU Well. PressUre. Report 4-16,18-87 2U-13 Pressure Buildup Survey 4-25-87 2C-16 GLM Survey & Temp Gradient Survey 4-13-87 Anchorage Receipt Acknowledged: DISTRIBUTION: BP Chevron State of Alaska · . . MObil Date: D&M SAPC Unocal ARCO Alaska. Inc, is a Subsidiary ol AtlanlicRichlleldCompany ARCO Alaska J,, Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 RETURN TO: ARCO ALASKA, INC. ATTN: Kuparuk Records Clerk ATO 1119 P. O. Box 100360 Anchorage AK 99510-0360 DATE 09-15-86 TRANSMITTAL # 5761 Transmitted herewith are the following items. Please acknowledge receipt and return one signed copy of this transmittal. Final Prints: Schl: CET or CBL Logs: One * of each lA-7 12-03-85 Run #3 7585-8532 lA-14 .12-05-$5 Run #1 4550-4850 1H-4 12-26-85 Run #2 6893-7466 1H-8 12-08-86 Run #3 7875-8368 1H-8 12-09-86 Run #4 7850-8450 lQ-9 01-28-85 Run #1 4898-6534 lQ-13 06-02-85 Run #1 5300-7621 2C-16 02-19-85 Run #1 7200-8294 2E-9 01-14-85. Run #1 6780-8052 2E-15 01-12-85 Run #1 3350-6874 2E-16 01-12-85 Run #1 4840-7578 2H-10 12-05-85 Run #1 6500-7863 3A-7 11-04-85 Run #1 5726-7164 3A-11 12-15-85 Run #1 5796-7206 3A-12 12-16-85 Run #1 6426-7768 3A-13 12-29-85 Run #2 5644-7482 3A-14 12-29-85 Run #2 5462-7744 3C-13 10-30-85 Run #1 7075-9474 3F-5 11-13-85 Run #1 6947-8647 3F-6 11-13-85 Run #1 4600-7570 3F-9 12-19-85 Run #1 6188-7490 3J-5 12-22-85 Run #1 7000-8636 Receipt Acknowledged: S~te' 'o'o'o~ AK*~/s~ Vault*films '~ NSK Files*bl ARCO Alalka. inc. ~, a Subsidiary of AllanticRichfielcIComDlln¥ ARCO Alaska, Inc. ~'~ Post Office B~x 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 June 10, 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' 2C-16 2D-10 2D-13 2G-16 lQ-8 2U-6 If you have any questions, please call me at 263-4944. Sincerely, Gruber Associate Engineer JG/tw GRU9/L41 Enclosures RECEIVED Alaska 0il & Gas Cons. Commtssioa Anchorage ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany ,.. STATE OF ALASKA . ALASK{i .~,- AND GAS CONSERVATION ~., .~IISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well OIL l~(x GAS [] SUSPENDED [-] ABANDONED [] SERVICE [] 2. Name of Operator 7. Permit Number ARCO Alaska, Inc. 84-202 3. Address 8. APl Number P. 0. Box 100360, Anchorage, AK 99510 50- 029-21218 4. Location of well at surface 9. Unit or Lease Name 1207' FNL, 426' FEL, Sec.21, T11N, RgE, UM Kuparuk River Unit At Top Producing Interval 10. Well Number 1703' FNL, 1543' FEL, Sec.16, TllN, RgE, UM 2C-16 At Total Depth 11. Field and Pool 1383' FNL, 1662' FEL, Sec.16, TllN, RgE, UM Kuparuk River Field 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. Kuparuk River 0i 1 Pool 125.7' RKB ADL 25654 ALK 2580 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. 115. Water Depth, if offshore ] 16. No. of Completions 12/14/84 12/21/84 12/23/84-I N/A feet MSLI 1 17. Total Depth (MD+TVD) 18. Plug Back Depth (MD+'l'VD) 19. Directional Survey I 20. Depth where SSSV set I 21.Thickness of Permafrost 8405'MD,6161 'TVD 8307'MD,6087'TVD YES r'~x NO [] 1904 feet MD 1530' (Approx) 22. Type Electric or Other Logs Run D IL/SFL/GR/SP/Cal, CNL/FDC, GR/CET, Gyro, CBL/VDL/GR, Temp/CCL 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASINGSlZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED , 16" 62.5# H-40 Surf 110' 24" 300 sx CS II 9-5/8" 36.0# J-55 Surf 3855' 12-1/4" 850 sx AS III & 550 sx Class G , 7" 26.0# J-55 Surf 8394' 8-1/2" 300 sx Class C & 250 s;i AS I , 24. Perforations open to ProduCtion (MD+TVD of Top and Bottom and 25. TUBING RECORD i. nterval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) , 8139' - 8162' w/4 spf, 120° phasing 3-1/2" 8041' 7819' & 8020'. ~ 8104' - 8106' 26. ACID, FRACTURE, CEMENT SOUEEZE, ETC.' 8109' - 8110' w/1 spf, 120° phasing DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERiAL USED 8078', 8096'-8098' 8010' - 8012' 300 sx Class G 7840' - 7842' 100 ~x Clas~ (; (cont'd on following sheet) For frR~. infn.; _~_m ;~r, hed Adde_nd,im dated 5/2/_~5. .... 27. N/A PRODUCTION TEST Date First Production I Method of Operation (Flowing, gas lift, etc.} Date of Test Hours Tested ,PRODUCTION FOR OIL-BBL GAS~MCF WATER-BBL CHOKE SIZE [GAS-OILRATIO ,TEST PERIOD I~ I Ftow Tubing Casing Pressure ~CALCULATED OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press. 24-HOUR RATE I~ 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. None RECEIVED JUN ] 2 ]885 Alaska 0il 8, Gas Cons. Commission Anchorage Form 10-407 * NOTE: Tubing was run and well perforated on 2/24/85. GRUg/WC30 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE : .~ ;'.,!il GEOi'O~3'I(~M/~,RKERS. :.:':: -":'..." :::':~." ""."-",.:" ~":FORMATiON'TE~:i-S... ,' .." ' '.." · NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and t{me.of each phase. Top Upper Sand 7881' 5764' N/A Base Uppr Sand 7928' 5800' . Top Lower Sand 8064' 5903' ..'i" Base Lower Sand 8245' 6040' -: , ,.. , · , . , . 31. LIST OF ATTACHMENTS . . , Add~.nd~m ,. . 32. I hereby certify.that the foregoing is true and correct to the best of my knowledge .. Signed &~ ~ Title Associa~.e Engineer Date,,' INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and Icg on all types of lands and leases in Alaska.. ~ Item 1' Classification of Service Wells' Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 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 1'6, 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 (G L) 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 Well Completion or Re¢ompletion Report and Log 2C-16 ITEM #24 (cont'd): 7952' - 7970' 7936' - 7946' 7901' - 7928' 7881' - 7901' w/12 spf, 120° phasing RECEIVED JUN 1 ~ ~5 Alaska Oil & Gas Coos. ConlmJssion Anchorage ADDENDUM WELL: 12/31/84 2/09/85 4/01/85 2C-16 __ Arctic Pak w/41 bbls AS I, followed by 59 bbls Arctic Pak. Rn CBL/VDL/GR f/8288'-7174'. Rn gyro f/8240'-surf. Frac well in 7 stages w/290 bbls gelled diesel, 800# of 100 mesh & 11,200# 20/40 mesh. RU WL, tag sand @ 8142'. Rn Temp/CCL f/8140'-7750'. RD. Drilling tSuperintendent JUN Alaska Oil & Gas Cons. Commission Date Attachment Page 3' Drill Site 1Y Wel 1 No. Log Date 1Y-1 6/6/83 10/21/83 1Y-2 6/10/83 3/4/84 II~~6/18/83 1Y-4 7/2/83 1Y-5 6/29/83 1Y-6 6/27/83 1Y-8 6/22/83 1Y-9 6/20/83 flY, I'll' 5/10/83 1Y-12 5/25/83 1Y-13 5/27/83 1Y-14 5/13/83 5/18/83 1Y-15 5/29/83 1Y-16 5/30/83 10/23/83 Drill Site 2C Well No. Log Date 2C-4 2/19/85 2/28/85 2C-7 10/15/84 t2CEl~12/lltB$ Drill Site 2Z' Well No. Log Date 12Z~,_ 7/10/83 2Z-2 ': 6/24/83 7/19/83 2Z-3 ' 8/5/83 2Z-4 7/12/83 2Z-6 7/27/83 2Z-7 7/28/83 2Z-8 8/3/83 VLF-pg-O052 Alaska Oil & Gas Cons. Anchorage ARCO Alaska, inc( Post Office box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 I)A'I'F': 05-'07-85 I-RANSMIT'I"AL ND'Si 78 F~E'I'IJIqtN TO: Al:;:(](] ALASKA, INC, Al'TN: RECOF:;I)S CLERI< A 'T' O- 1 I t 5 B I::',0. BOX t0(')S60 ANCHORAGE, Al< 99510 ~~~ . TRANS'HITTE~) I"IEREWII'H ARE I'HE I:;OI...I..OWIN[; II'EHS, I::'L..EASIE ACI(NOWL. EI)GE RECEIF'T AND I:<ETURN ONE SIGNED COF'Y OF' THIS TRANSMITTAL, F:' I N A L F:' R ]: N CBL. ' $/SCI"II_UMBI""'i:?[, Ei:R 1 E-t U-'"," t (.)-30-84 RUN 4:'t 730G--789'."~ 2 [:- t :5 ~'"' 02- 0 S-- 85 I:;;l.J N '"' ''> ':"': .... · ,,. ,...:> .> 0 ~ -- 7 ''> 6 ':~ ">" 'l .... ,,. ~-. 380G-'6030 ~'..C'- t ,~,--'- 02'"'0/.'. -'8.'S RUN 2C"t D ~ 02'-08--85" i:;:UN:::t ':'" i?(.':-'t 6 "'""' 02-08-8.5 RUN :ll:t ',:'t 75-'8,".!80 ,.)- ,...&-t D I 0--2'?-84 RtJN :ll't ,1'790-6882 '2[;--t 6 ~ t 0-27-84 RIJN :::t '"i;6!:.~0.-7'?;]'~6 :~!L!.-t 5 ~/ 02-t 0--85 R~JN :II:t 6400--6985 "~l '.5 "~ ,....W.-9 "'" 0I-.0t-85 RLJN :::t 2 W -- t t ~ 0 t -- 0,..') -- ,.,° ~.:., R U N ¢,; t 2W-t ,:.,..w,,~ 0t -'G'2-85: RUN :::t 2640--797t L-'!W--t6'''~ (:').-') Ot-..SS RUN ::'.t 4Z';86--69'''~ . ,- - 8 ,-.. ::]X-t 4,,'~ t .i -.t ',;-8-I RUN :~:t 4S96-.7874 RECE I I""T ACK NOWi...EI)[;.E"D: .. .............. ii '!i! ::i: '-i' iii ['i :i: i!i i:i 'T .............. B I":' A l'i] :~ i) I:;: ]: I I.. I N [] .... B I... W, F:'A ,'.';' I' I E F;.: B. C LJ R R I !_:-"1::: 1_ ,, ,.! 0 i"1N,S' l' 0 N Iii: X X O N ' C I"1 [" V R 0 N M 0 B ;I I F:' I"11 I..I... I F:',S' 01 L D & Id -x'NS'I( CLI"::RI(-'BI .... !, RAI"HMli"'LI_ DA'I'f:: Alaska 0i~ , b "'.A "'" :, ' .S' 0 I"110 / -~{' IE U N I 0 N · X.l(, 'l"LJl_ I N/VAULT--F I LM ARCO Alaska, Inc. Post Office B~['~ .30360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 April 19, 1985 Mr. C. V. Chatterton Commi ssi oner State of Alaska Alaska Oil & Gas Conservation Commi ssion 3001 Porcupine Drive Anchorage, AK. 99501 SUBJECT: Revised Well Completion Reports Dear Mr. Chatterton' Enclosed are revised Well Completion Reports for the following wells: 2A-2 2D-5 2E-14 2A-3 2D-14 2E-16 2A-4 2E-10 2G-14 2A-5 2E-11 2H-3 2C-15 2E-12 2W-11 2C-16 2E-13 2X-15 These reports were revised to reflect the cement quantity used when each well was Arctic Packed. If you have any questions, please call me at 263-4944. Sincerely, Gruber Associate Engineer JG/tw GRU6/L06 Enclosures RECEIVED APR 2 21 B5 Alaska Oil & Gas Cons. Commisslo~t Anchorage ARCO Alaska, Inc. Is a Subsidiary of AtlantlcRIchfleldCompany STATE OF ALASKA ALASKA'{ LAND GAS CONSERVATION C~' .MISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well REVISI0N OIL [] GAS [] SUSPENDED [-~X ABANDONED [] SERVICE [] 2. Name of Operator 7. Permit Number ARCO Alaska, Inc. 84-202 3. Address 8. APl Number P. 0. Box 100360, Anchorage, AK 99510 50- 029-21218 4. Location of well at surface 9. Unit or Lease Name 1207' FNL, 426' FEL, Sec.21, TllN, RgE, UN (Approx.) Kuparuk River Unit At Top Producing Interval 10. Well Number TO be submitted when gyro is run. 2C-16 At Total Depth 11. Field and Pool To be submitted when gyro is run. Kuparuk River Field 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. Kuparuk River 0i 1 Pool 125.7' RKB ADL 25654 ALK 2580 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. I 15. Water Depth, if offshore 116. No. of Completions 12/14/84 12/21/84 12/23/84I N/A feet MSLI N/A 17. Total Depth (MD+TVD) 18.Plug Back Depth (MD+TVD) 19. Directional Survey I 20. Depth where SSSV set 21. Thickness of Permafrost 8405'MD 8307'MD YES [] NO []XI N/A feet MD 1530' (Approx) · 22. Type Electric or Other Logs Run D I L/SFL/GR/SP/Cal , CNL/FDC 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 110' 24" 300 sx CS II 9-5/8" 36.0# J-55 Surf 3855' 12-1/4" 850 sx AS III & 550 sx Class G 7" 26.0# J-55 Surf 8394' 8-1/2" 300 sx Class G & 244 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 SQUEEZE, 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 Flow Tubing CaSing Pressure CALCULATED.k 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 ., Form 10-407 JMM2/WC07 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE '.'i,.: '' i'.'!i:. (' i",: i';'i GEOi~O.Gi.~:;MARK'EFiS' '~;"~ '~':'. '~ "?i; '.. ':; ~!''' .;" '.~: :': ii.`.. 'F.', :: ~ 'y';F'oRM~,T~I'ON..i~i~;:~'i::~'? · NAME Include interval tested, pressure data, all fluids.roeovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. , . N/A None · . . · . .. , .... . ..... , 31. LIST OF ATTACHMENTS None ~ I 32. I hereby cer, tify.that the foregoing is true and correctto the best of my knowledge . . Signed (~)~ _ _~~L./ Title As$ociateiEI3~il3eeF 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 injectionj 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 i.s 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 Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 April 16, 1985 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT' 2C-16 Dear Mr. Chatterton' Enclosed are the Well Completion Report and gyroscopic survey for the subject well. If you have any questions, please call me at 263-4944. Sincerely, J. Gruber Associate Engineer JG/tw GRU5/LI08 Enclosures RECEIVED APR 1 8 1985 Alaska 0ii & Gas Cons. Commission Anchorage ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany STATE OF ALASKA ALASKi( ' ~ AND GAS CONSERVATION (J, ,vllSSION 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. 84-202 3. Address 8. APl Number P. 0. Box 100360, Anchorage, AK 99510 50- 029-21218 .--. 4. Location of weal at surface i"~'""' "" ..... ~ '"-" :'"' ':"? ~; 9. Unit or Lease Name 1207' FNL, 426' FEL, Sec.21, T11N, RgE, UM I 'v"/~i?,2D i Kuparuk River Unit At TOp Producing Interval I .Sur~.._____~ I 10. Well Number 1703' FNL, 1543' FEL, Sec.16, TllN, RgE, UN iB.H.---~--'~ 2C-16 At Total Depth~ 11. Field and Pool 1383' FNL, 1662' FEL, See.16, TllN, RgE, UM Kuparuk River Field 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. Kuparuk Ri vet Oi 1 Pool 125.7' RKB ADL 25654 ALK 2580 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. 115. Water Depth, if offshore 116. No. of Completions 1 2/14/84 1 2/21/84 1 2/23/84*I' N/A feet MS LI 1 17. Total Depth (MD+TVD) 18. Plug Back Depth (MD+TVD)19. DirectionalSurvey I 20. Depth where SSSV set I 21. Thicknes~ of Permafrost 8405'MD,6161 'TVD 8307'MD,6087'TVD YES []X NO [] 1904 feet MD 1530' (Approx) 22. Type Electric or Other Logs Run D IL/SFL/GR/SP/Cal, CNL/FDC, GR/CET, Gyro 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASINGSl. ZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 16" 62.5# H-40 Surf 110' 24" 300 sx CS II 9-5/8" 36.0# J-55 Surf 3855' 12-1/4" 850 sx AS III & 550 sx Class G 7" 26.0# J-55 Surf 8394' 8-1/2" 300 sx Class G 24. Perforations open to Production (MD+TVD 'of'Top and Bottom and 25. TUBING RECORD interval:, size. and number) SIZE DEPTH SET (MD) PACKER SET (MD) 8139' - 8162' w/4 spf, 120° phasing 3-1/2" 8041' 7819' & 8020' '~ 26. ACID, FRACTURE, CEMENT SQUEEZE, 8104' 8106' ETC. 8109, - 8110,---~ W/1 spf, 120° phasing DEPTH INTERVAL'(MD) AMOUNT&KI. ND OF MATERIAL USED 8078', 8096'-8098'~ 8010' - 8012' 300 sx Class G 7840' - 7842' 100 sx Class G (cont'd on following sheet) 27. N/A PRODUCTION TEST Date First Production l Method of Operation (Flowing, gas lift, etc.) I Date of Test Hours Tested PRODUCTION FOR OI L-BBL GAS-MCF WATER-BBL CHOKE SIZE GAS-OIL RATIO TEST PERIOD I1~ 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 Oil & Gas Cons. Commission Form 10-407 * NOTE: Tubing was run and wel 1 perforated on 2/24/85. TEMP/WC04 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE '- ':: ..... "' .FORMAT, ION TESTS--'-'~'-~' ,,:'. . GEOLOGIC MARK. ER§. '!:"{:. ~"~' ,.'" "':" ':':: ~' '[i, .. NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUEVERT: DEPTH · GOR, and time of each phase. . Top Upper Sand 7881" 5764' N/A Base Uppr Sand 7928' 5800' Top Lower Sand ,' -8064' 5903' ' ,:-.. -'~. i' ,. Base Lowe~; Sand 8245' 6040' · , ,. ~,, r . . ,. , .: . , .. . , .: ~ ~:. ,- . · , . .. 31. LIST OF ATTACHMENTS '32. I hereby certify that the foregoing is. true and correct to the best of my knowledge .. , -'., Signed ~0 ~ ,~~ Title Associate Engineer 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 ~orm 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 Well Completion or Recompletion Report and Log 2C-16 ITEM #24 (cont'd): 7952' - 797011~ 7936' 7946 w/12 spf, 120° phasing 7901 ' 7928 7881 ' 7901 Alaska OJJ & Gas Cons. (,o~,~m~ss~o~ Anchorage · ARCO OII and Gas Company Well History- Initial Report- Dally Instructions: Prepare and submit the "Initial Report" on the first Wednesday after a well Is spudded or workover operations are started. Daily wort; prtor to sPudding should be summarized on the form giving inclusive dates only. District Alaska Field Kuparuk River Auth. or W.O. no. AFE 503428 ICounty. parish or borougl~ North Slope Borough Lease or Unit 'rme ADL 25654 Completion IState Alaska IWell no. 2C-16 wws #1 API 50-029-21218 Operator ARCO Alaska, Inc. Spudded or W.O. begun Complete IDate IHour 2/16/85 Date end depth as of 8:00 a.m. 2/19/85 2/20/85 2/21/85 2/22/85 Complete record for each day reported 0300 hrs IARCO W.I. Prior status if a W.O. 56.24% 7" @ 8394' 8307' PBTD, Drlg cmt in 7" csg 10.0 NaC1/NaBr Accept rig @ 0030 hrs, 2/16/85. ND tree, NU &tst BOPE. RU WL, RIH w/4" csg gun, 4 SPF, 120° phasing. Perf 8070'-8012' POH. PU RTTS & set @ 7741'. Est IR. Pmp 200 sx cmt, POH w/RTTS. RIH, drl cmt f/7828'-~',. Tst csg to 2000 psi; would not hold. PU RTTS, RIH ~5' ~e-sqz. RIH w/RTTS & set @ 7739'. Pmp 100 sx cmt, POH. RIH, tag cmt @ 7946'. 7" @ 8394' 8307' PBTD, Sqz'g cmt 9.9 ppg NaC1/NaBr Drl cmt f/7975'-8035'. Tst 7" csg to 2000 psi. RIH to PBTD of 8298', circ, POOH. RU & rn CET f/8294'-7200'. Shoot 4" 4 SPF f/7840'-7842'. RIH w/Champ pkr, set same @ 7578'. Pmp 15 bbls wtr, 100 sx C1 "G" w/.6% D-60, 1% CaC19, .2% D-46 & 3% KC1, followed by 100 bbls wtr. Sqz cmt thr~ perfs @ 7840'-7842' w/final sqz press of 4500 psi. Pull pkr loose. Rev DP. 7" @ 8394' 8307' PBTD, DO cmt 9.9 ppg NaCl/NaBr Sqz 100 sx cmt, POH w/Champ pkr, WOC. TIH w/BHA, tag cmt @ 7595', DO cmt to 7850'. Tst perfs to 2000 psi; OK. 7" @ 8394' 8307' PBTD, Perf 9.9 ppg NaCl/NaBr Wsh to PBTD. Displ well to cln brine, POOH, LD DP. RU & perf w/ 4", 4 SPF, 120° phasing f/8142'-8162' & 8139'-8142', perf w/4", 1 SPF f/8104'-8106', 8109'-8110', 8078' & 8096'-8098'. Ccc'c The above is correct Signature For form preparation an~ -d~t~b~-tlbnT see Procedures Manual, Se~'tlon 10, Drilling, Pages 88 end 87. IDate 3/21/85 ITitle ' 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 De used for reporting the entire operation if space is available. District A.laska County or Parish Field Lease or Unit Kuparuk River Auth. or W.O. no. T tie AFE 503428 WWS #1 Accounting cost center code Slate North Slope Borough Alaska ADL 25654 Completion IWell no. 2C-16 API 50-029-21218 I otal number of wells (active or inactive) on this DSt center prior to plugging and bandonment of this well our I Prior status if a W,O. I 0030 hrs. Operator A.R.Co. W.I. ARCO Alaska, Inc. 56.24% Spudded or W.O. begun Date Complete 2/16/85 Date and depth Complete record for each day reported as of 8:00 a.m. Old TD Released rig 2/23/85 thr~ 2/25/85 7" @ 8394' 8307' PBTD, RR Crude/Diesel RIH w/5" csg gun, 12 SPF, 120° phasing & perf f/7970'-7952', 7942'-7936', 7881'-7928'. RIH w/WL pkr & set @ 7995'. RU & rn 249 jts, 3½", 9.3#, J-55 EUE 8RD I?C tbg. Lnd & tst tbg, set pkr. Set BPV, ND BOPE, NU tree. Pull BPV & tst tree. Displ well to crude. Set BPV & RR @ 0400 hfs, 2/24/85. DB Perm Pkr @ 8020.15' - "D" Nipple @ 8034.86' - TT @ 8041.12' SSSV @ 1903.78' New TD Date PB Depth Kind of rig 8307' PBTD 0400 hrs. 2/24/85 Rotary Classifications (oil, gas, etc.) Type completion (single, dual, etc.) Oil Single Producing method Flowing Official reservoir name(s) Kuparuk Sands Potential test data Well no. Date Reservoir Producing Interval Oil or gas Test time Production Oil on test Gas per day Pump size, SPM X length Choke size T.P. C.P. Water % GOR Gravity Allowable Effective date corrected The above is correct Signature Date Title j~~ 3/21/85 Drilling Superintendent For form preparation and distJ~bution, see Procedures Manual, Section 10, Drilling, Pages 86 and 87. ARCO, Alaska, Inc. .. Post Office B~ 00360 Anc.horage, Alaska 99510-0360 Telephone 907 276 1215 · , '-; m .... '..';,, . ,'"~ '~" ~' 2 ~'' "" i ~'~ "' '"' i .S' 2 C i '.;;[, O'f' ]: ,.".:7 ' '"'""' ...... :"" CT"T I ,:?. ..;. '..,, ~I ...,' ~ "~ r' ....' 0-1" '" ,.. .... '~ .<:. ~,".. · ..'...'2. F .... 6 ~ [) T' ]: ,? · oc..- 4 ,:'7 / ;"S~ '.'"HB/F< ~..., ~ ,..'~ ~... ..' ,':, .n......,.., i ':3 / n .l". ;[. ,:..:' :..'.:' "' ."'i 'T' '" : ...... i'.]' .. .,. ,.,. ..' .... ,..' 2_ :.... ~ .... '7 ¢ r'i... 'T' i ,? · m ~ ... ~ CL-' ,"l '1" T c' .,,'.. -.? ~ ~.. '.. ~ . ..... , .... L ~'~. .... v .... ,-:. 0-F I ,.,,,., ,-, · -r~-f. T ;!;, ~&'. ¥ -" ~;:.. ~..; · -~:: .... ,..'!?, ~...'.~ ,,' ,..~ :....T. · ':.. :: L.' J .i,,,,..' 2.::."' o -. [)l' ~' '~:, ~"~ ../'T'.. ,.':. :-,~! -.- r',"r T ? ..... ,'~ ~ ~ %., ! .~. ~.., ;7' '",: --.. i ,,";-- ..... r'! T I ,.~ · ""I~ ~."" ...... · i '7.'" ,n'¥' T '7 .. .... ,,,. ; .,. ~.. '" ).'.: .... 1 3 ' r', ~" ',' .'..' · .'.. .. , .L ~.., "'" :.'::': ..- '! -r,./ ."'l '~' 'r :, ...... :' ... I .L B' H F' ( I N I T I A I_ ) ¥'-. '~' <" '"t' r', '!' T', I ! %" ..... >, I .. .[.' .i. ,2. I ~ '...L .'.7 '...' ; .J.S..: · . ¥', l:', .r 1_ L ~' k', r'.: ! ~ r:, ,..'..~ '-',. :E r:.: ~ l'-I!- iL! .T T'r'~.'.' r-'v,..',";:.. ,'-... :.. ^ ;., ..., ..... ,.., j'q 1.':...":/',. '..' ~ '.: i'~O D I L .~.~ F:'H 'r.,. t...L - ;-. "'' ,~. ''" ri.. 'r.... I... ','.'... bi.71< . C I_ E: F;:I< J~ F;:,'~', 7' t-.I M I]; !.. [:.'.,,:. ARCO Alaska, In:.. is a Subsidiary ot All~nlicRichtieldOompan ! ARCO- Alaska, I(' Post Office Box 360 Anchorage, Alaska 99510 Telephone 907 277 5637 {C) T ii. C) '!" I ,';'.," C) "i' ]'l ,!':'.' i.') ,;!.: i'"'{ ..... i i . .., ARCO Atas~.a, Inc ~'~ a subs~(:J~ary of Atlanl:cR,ch':ei~CompanY ARCO Alaska, Inc. t Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 March 25, 1985 Mr. C. V. Chatterton Commi ssi oner State of Alaska Alaska Oil & Gas Conservation Commi ssi on 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT' 2C-16 Dear Mr. Chatterton- Enclosed is a copy of the 2C-16 Well History to include with the Well Completion Report, dated 02/19/85. If you have any questions, please call me at 263-4944. Sincerely, Gruber Associate Engineer JG/tw GRU5/L53 Enclosure xc: 2C-16 Well File RECEIVED UAE 2 7 1985 'Alaska, Oil & Gas Cons. ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany ARCO Alaska, Inc. Post Office Bo~ 360 Anchorage,"'/~' ~(a 99510 Telephone 907 277 5637 RETUP~N TO: Date: 03/06/85 Transmittal No: 5077 **Page 2 of 2*** ARCO ALASKA, INC. ATTN: Records Clerk ATO-1115B P.O. Box 100360 /~'chorage, AK 99510 · .~ansmitted herewith are the following items. Please acknowledge receipt i'/and return one signed copy of this transmittal. FINAL PRINTS OPEN HOLE (One Sepia Blueline of each) Schlumberger 2C-15-LCONTINUED from previous page. ~2" Density/Neutron-GR 12/30/84 Run #1 5" Density/Neutron-GR 12/30/84 Run #1 5" Cyberlook 12/30/84 Run #1 6545-7129 (Porosity) 6545-7129 (Porosity) 6545-7114 :2*' ............ "' DIL/SFL-GR 5'~ 2'~ 5~ 2'~ 5't 5~ 12/22/84 Run #1 DIL/SFL-GR 12/22/84 Run #1 Density/Neutron-GR 12/22/84 Run #1 Density/Neutron-GR 12/22/84 Run #1 Density/Neutron-GR 12/22/84 Run #1 Density/Neutron-GR 12/22/84 Run #1 Cyberlook 12/22/84 Run #1 3853-8392 3853-8392 3853-8392 (Raw' Data) 3853-8392 (Raw Data) 7650-8392 (Porosity) 7650-8392 (Porosity) 7850-8320 ~E-10 - 5" Cyberlook 12/28/84 Run #1 2" DIL/SFL-GR 12/28/84 -Run'#1 5" DIL/SFL-GR 12/28/84 'Run #1 2" Density/Neutron 12/28/84 Run #1 5" Density/Neutron 12/28/84 Run #1 2" Density/Neutron 12/28/84 Run #1 5" Density/Neutron 12/28/84 Run #1 6090-6605 3306-6652 3306-6652 6100-6623 (Raw Data) 6100-6623 (Raw Data) 6090-6623 (Porosity) 6090-6623 (Porosity) Receipt Acknowledged: B. Currier BPAE Chevron D &M DISTRIBUTION Drilling W. Pasher Geolog~L.Johnston Exxon Sohio Mobil Phillips Oil Union NSK Drill Clerk J. Rathmell K. Tulin/Vault ARCO Alaska. Inc. il, a subsidiary ol AllanticRIchlielclCompany ARCO Alaska, Inc. Post Office I~t 360 Anchorage ..../[ ka 99510 Telephone 907 277 5637 RET~RN TO: ., Date: 03/06/85 Transmittal No: **Page 1 of 2** 5077 ARCO ALASKA, INC. ATTN: Records Clerk ATO-1115B P./O. Box 100360 chorage, AK ~9510 ' ' /~kansmitted herewith are the following items. Wand return one signed copy of this transmittal. FINAL PRINTS OPEN HOLE (On%sepia of each) Blueline Schlumberger lQ-12 2" 5I, 2II 11 2II 11 DIL/SFL-GR DIL/SFL-GR Density/Neutron (Porosity) Density/Neutron (Porosity) Density/Neutron (Raw Data) Density/Neutron (Raw Data) Cyb~rlook 2W-12 11 5" 2'1 5" 2" 5!1 5II DIL/SFL-OR DIL/SFL-GR Density/Neutron-GR Density/Neutron-GR Density/Neutron-GR Density/Neutron-Gr Cyberlook .. 12/25/84 Run #1 12/25/84 Run #1 12/25/84 Run #1 12/25/84 Run #1 12/25/84 Run #1 12/25/'84 Run #1 12/25/84 Run PI · .. 12/29/84 Ru~ ffl 12/29/84 'Run #1 12/29/84 Run #1 12729/84 Run #1 12/29/84 Run #1 12/29/84 Run #1 12/29/84 Run #'1 Please acknowledge receipt 3570-6992 3570-6992 5570-6966 5570-6966 5570-6966 5570-6966 6450-6950 '2717-8038 2717-8038 2717-8012 2717-8012 2717-8012 2717-8012 7450-7950 (Raw Data) (Raw Data) (porosity) (Porosity) 2C-15 2" DIL/SFL 5" DIL/SFL 2" Density/Neutron-GR 5" Density/Neutron-GR Receipt Acknowledged: B. Currier 12/30/84 Run #1 12/30/~'', Run #1 12/30/$4 Run #1 12/30/84 Run #1 **CONTINUED** DISTRIBUTION Drilling W. 3154-7154 3154-7154 6545-7129,/~w D af~,) . Da t : .~~.~ Pasher State of BPAE Geolog~L.Johnston Exxon Sohio Chevron D &M Mobil NSK Drill Clerk Phillips Oil J. Rathmell Union K. Tulin/Vault ARCO Alaska, Inc. Is a subsidiary of AllanlicRichlieldCompany '" STATE OF ALASKA ALASKt . AND GAS CONSERVATION ~ AISSION WELL COMRLETION OR RECOMI LETION RE;I ORT AND LOO 1. Status of Well Classification of Service Well OIL [] GAS [] SUSPENDED [~ ABANDONED [] SERVICE [] 2. Name of Operator 7. Permit Number ARCO Alaska, Inc. 8/+-202 3. Address 8. APl Number P. 0. Box 100360, Anchorage, AK 99510 50- 029-21218 4. Location of well at surface 9. Unit or Lease Name 1207' FNL, 426' FEL, Sec.21, T11N, R9E, UN (Approx.) Kuparuk River Unit At Top Producing Interval 10. Well Number To be submitted when gyro is run. 2C-16 At Total Depth 11. Field and Pool To be submitted when gyro is run. Kuparuk River Field 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. Kuparuk River 0i 1 Pool 125.7' RKB ADL 25654 ALK 2580 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. I 15. Water Depth, if offshore 116. No. of Completions 12/1/+/84 1 2/21/8/+ 12/23/8/+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 21. Thickness of Permafrost 8405'MD 8307'MD YES [] NO r~x N/A feet MD 1530' (Approx) 22. Type Electric or Other Logs Run D IL/SFL/GR/SP/Cal , CNL/FDC 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 110' 24" 300 sx CS II 9-5/8" 36.0# J-55 Surf 3855' 12-1/4" 850 sx AS III & 550 sx Class G , 7" 26.0# J-55 Surf 8394' 8-1/2" 300 sx C]ass G 24. Perforations open to Production (MD+TVD of Top and Bottom and 25. TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) pACKER SET (MD) 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 I Method of Operation (Flowing, gas lift, etc.) I Date of Test Hours Tested PRODUCTION FOR OI L-BBL GAS-MCF WATER-BBL CHOKE SIZE I GAS-OI L RATIO TEST PERIOD I~ Flow Tubing Casing Pressure CALCULATED.1~ OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (cor'r) . 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 E.B 2 1 985 Alaska 0ii & Gas Cons. c0mmissi0r[ ..... Anchorage Form 10-407 GRU/+/WC36 . .' Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE ,- NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. · . ,,, N/A None 31. LIST OF ATTACHMENTS None 32. I h'ereby certify that the foregoing is true and correct to the best of my knowledge Signed ~ ~ ~'J~ Title Associate Engineer 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- Dally Inst."uctionl: Prepare and submit the "Initial RIp~I" on the flint Wednesday after a well is spudded or workover op~retions are started. Daily work prior to spudding should be summarized on the form giving inclusive dates only. District Alaska Field Kuparuk River ICoun~. parish or borough North Slope Borough /Lea.~orUnr ADL 25654 Title Drill, Complete & Perforate State , Alaska IWell no. 2C-16 Auth. or W.O. no. AFE 503428 Parker 191 Operator API 50-029-21218 IARCO W.I. Prior status if a W.O. ARCO Alaska, Inc. Spudded or W,O. begun Spudded IDate I Hour 12/14/84 0200 hrs. 56.24% Date and depth as of 8:0O a.m. 12/12/84 thru 12/13/84 12/14/84 2/15/84 thru 12/17/84 Complete record for each day reported MIRU. 16" @ 110' 522' (522') DD Wt. 9.5, PV 15, YP 28, PH 10.5, WL 18, Sol 4 Accept ri$ @ 1800 hrs, 12/13/84. NU diverter sys. 0200 hfs 12/14/84. Drl surf hole to 522'. Spud well @ 16" @ 110' 3875' (3353') Rng 9-5/8" Csg Wt. 9.9, PV 18, YP 9, PH 9.5, WL 12, Sol 10 DD, drl & surv 12½" hole to 3875', CBU, 15 std short trip. RU & att to rn 9-5/8"csg; hit bridge @ 2200'. Circ & att to wk thru bridge; could not get below 2200'. TOH, LD 9-5/8" csg. MU BHA, TIH, hit bridge @ 2131'. Wsh & rm f/2131'-2502', fin TIH; no fill, C&C, pmp pill, TOH & LD BHA. RU to rn csg. 500'MD 0° 0 500'TVD 0 0 0 1029'MI) 16° N12.5W 1023'TVD 73'VS N71 15W 1360'MD 26.9° N9.SW 1331'TVD 195'VS N192 37W 1705'MI) 35.4° N10.SW 1624'TVD 377'VS N370 69W 2195'MD 43.4° N6.SW 2003'TVD 687'VS N677 llSW 2537'MD 51.1° NS.SW 2234'TVD 938'VS N927 141W 2846'MI) 52.1° N3.SW 2426'TVD 1179'VS Nl168 160W 3267'MI) 51.7° N2.SW 2686'TVD 1508'VS N1499 177W 3790'MD 49° N3W 3020'TVD 1908'VS N1902 197W The above is correct Signature For form preparation an~ distribution, see Procedures Manual, Section 10, Drilling, Pages 86 and 87. Date I Title 1/24/85 MAR Z 7 1985 'N~stm 0il & Gas Cons. Commissior~ Anchorage 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 tests sequentially. Attach description of all cores. Work performed by Producing Section will be reported on "interim" sheets until final completion. Report official or representative test on "Final" form. 1) Submit "Interim" sheets when filled out but not less frequently than every 30 days, or (2) on Wednesday of the week in which oil string is set. Submit weekly for workovera and following setting of oil string until completion. District ICounty or Parish I State Alaska North Slope Borough Field ILease or Unit Kuparuk River I ADL 25654 Complete record for each day while drilling or workover in progress Date and depth as of 8:00 a.m. 12/18/84 12/19/84 12/20/84 12/21/84 Alaska IWell no. 2C-16 9-5/8" @ 3855' 3875' (0') DO cmt Wt. 9.7, PV 16, YP 7, PH 9.5, WL 1.3.5, Sol 9 RU & rn 96 jts, 9-5/8", 36#, J-55 Butt csg w/FC @ 3772', FS @ 3855'. M&P 850 sx AS III w/1/2#/sx cellophane flake, followed by 550 sx @ 15.8 ppg of Cl "G" w/2% S-1 & 0.2% D-46. Displ w/281§,~bl mud using rig pmps, bump plug. CIP @ 1100 hrs, 12/~'~4. Good rtns thruout cmt job. ND d~ve~e~7 P-~rm top job w/150 sx AS I @ 15.8 ppg. NU & tst BOPE. PU BHA, TIH, tag cmt @ 3770', circ & tst csg to 1500 psi 15 min, ok. DO hard cmt. 9-5/8" @ 3855' 5514' (1639') Drlg ahead Wt. 9.4, PV 13, YP 8, PH 10, WL 9, Sol 7 Fin DO cmt + 10' new hole. Conduct formation tst to 12.5 EMW. TIH, DD & surv to 5514'." 4347', 48°, N5W, 3387 TVD, 2322 VS, 2317N, 226W 4622', 47-1/2°, N9W, 3571TVD, 2525 VS, 2519N, 251W 5065', 47°, N15W, 3872 TVD, 2850 VS, 2838N, 318W 9-5/8" @ 3855' 7700' (2186') Drlg Wt. 9.8, PV 20, YP 15, PH 10, WL 6.5, Sol 10 Drl & surv 8½" hole to 7700'. 5628', 47°, N14-1/2W, 4257 TVD, 3261VS, 3236N, 424W 6246', 51-1/2°, N15W, 4660 TVD, 3727 VS, 3689N, 543W 6745', 49°, N15W, 4979 TVD, 4110 VS, 4060N, 642W 7311', 47°, N15-1/2W, 5358 TVD, 4528 VS, 4465N, 753W 9-5/8" @ 3855' 8340' (640'), Drlg Wt. 9.9, PV 21, YP 12, PH 10, WL 6.8, Sol 12 . Drl to 7875' CBU POOH LD DD PU RWP/new bit, GIH to 9-5/8" shoe, break circ, FIH, wsh to btm, drl to 7909'. Make connection, mud gas cut f/9.8 ppg to 8.3 ppg. Circ gas cut mud, well taking fluid @ 2-4 BPM. Cont to circ, mx & spot 35 bbl LCM pill; fluid loss stabilized w/9.9 in & out. Drl to 8340'. RECEIVED MAR 2 7 1985 Naska 0il & Gas Cons. Commission Anchorage The above is correct Sign atu re~_,,~f For form preparation and distribution see Procedures Manual SeEtion 10, Drilling, Pages 86 and 87 IDate 1/24/85 [Title 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 available. District ICounty or Parish Alaska I North Slope Borough Field Lease or Unit Kuparuk River ADL 25654 Auth. or W.O. no. ~ Title AFE 503428 I Drill, Complete & Perforate Parker 191 Operator ARCO Alaska, Inc. Spudded or W.O. begun Spudded IAccounting cost center code State Alaska IWell no. 2C-].6 Date and depth as of 8:00 a.m. 12/26/84 Old TD 12/31/84 2/o9/85 Released rig 2100 hrs. API 50-029-21218 IA.R.Co. W,I. rl'otal nurnber of wells (active or inactive) on thisI Icost center prior to plugging and 56.24% labandonment of this well 12/],4/84 / 0200 hrs. Complete record for each day reported 7" @ 8394' 8307' (65'), RR Wt. 9.9, PV 14, YP 10, PH 9.5, WL 6.4, Sol 12 Drl f/8340'-8405, CBU, 20 std short trip, C&C & logs, POOH. RU Schl, rn DIL/SFL/GR/SP/FDC/CNL/CAL; unable to get below 6208' WLM, POOH, RD Schl. PU 8½" BHA, RIH, CBU, POOH. RU Schl, log DIL/SFL/GR/SP/CAL f/8400'-3855', log CNL/FDC f/8400'-7650', POOH, RD Schl. RIH, rm 6050'-6256', FIN, wsh & rm 8395'-8405', C&C f/7", POOH. Chg top rams to 7" & tst to 3000 psi. RU & begin rn'g 210 its, 7"; well flowing 1" stream. MU circ head, CBU @ 4570'; well stable. Fin rn'g 7" w/FC @ 8307', FS @ 8394'. M&P 300 sx C1 "G" w/2% D-46, 3% KC1 & .8% D-60. Displ cmt w/10.0 ppg NaC1/NaBr. Bump plug; good rtns. ND BOPE, set slips on 7". RU & blow out ].20' brine f/7". Make rough cut. LD ldg jr, ND bull nipple. Instl pack-off, NU tbg head & companion flange. RR @ 2100 hfs, 12/23/84. 8345', 41°, N15W, 6124' TVD, 5216 VS, 5129N, 951W Pak. MAR 2 7 1985 Classifications (oil, gas, etc.) Oll 'Naska 011 & Gas Cons. Commission Anchorage Rn CBL/VDL/GR f/8288'-7174'. Rn gyro f/8288'-surf. New TD PB Depth 8340' (]..2/2]./84) 8307' Date 12/23/84 K nd of rig Rotary Type completion (single, dual, etc.) S±ngle Official reservoir name(s) Kuparuk Sands Producing method Flowing Potential test data Well no. Date Reservoir Producing Interval Oil or gas Test time Production Oil on test Gas per day Pump size, SPM X length Choke size T.P. C.P. Water % GOR Gravity Allowable Effective date corrected The above is correct Signature IDate ITttle Z,,z.,,f ~..~__~__-___~ 1/24/85 Fo; form preparatioJand distribution, see Procedures Manual, Section 10, Drilling, Pages 86 and 87. Drilling Superintendent $ UB-$ URFA CE DIRECTIONAL SURVEY ~'~ UIDANCE [~]ONTINUOUS, Company ATLANTIC~ RICHF, IEL,,D .CO, MPANY Well Name 2C-16 1207' FNL~ 4,26' FEL~ S21~ TllN~ R9E~ UM Field/Location KUPARUK,_ NORTH ,,S,,LOPE' ALASKA _ _ Job Reference No. Date 70131 25-FEB- 1985 Lo(j~3ed By: Computed By: BARBA STEVENS CCT DIRECTIOMAL ~URYEY CUSTOMER LISTING ~RCO AI, ASKA, INC, ?C-16 KUPARUK NORTH SLOPE, ALASKA SI]RVMY DATF: 8-FEB-B5 MNCINEER: D. BARBA METHODS OF COMPUTATION TOOL DOCATIOW: mANGFNTIAD- aYeraqed deviatloD and azlmuth INTE]RPObATIOW: I, INEAR VFRTICAI, SCCTTON: HORTZ. DIST, PROJECTED ONTO A TARGET AZIMUTH OF NORTH g DE~ 49 SIN WEST CnMPUTATiON DA~: 25-FgB-85 ARCO ALASKA, 2C- 1 6 K!II>IRI!K NORTit SLOPE, ALASKA TRbE SU~-SE~ ~KPT~-! D~PTH ~EPTH DKG M~N D~G 100.~0 ~00.00 300.0~ aO0,oO ~0o,o0 600.00 700,00 RO0,O0 qO0,O0 o O0 ln6'oo 200,U0 300 O0 400 On 50O OO 5O9 97 609 ?d 709 07 897.54 DATE OF SURVEY: 8-FEB-B5 KELhY BUSHING KD~VATION{ ENGINEER: D, BARBA 125,10 iNTFRPO[.ATED VAt. UFS FnR EVEN 100 FEET OF MEASURED DEPTH VERTICal. DOCLKG RECTANGULAR COORDINATES HORIZ', DEPARTURE SECTInN SEVERITY NORTH/SOUTH EAST/WE~T DIST, AZIMUTH FFET DEG/100 FEET FEET FEE~ DEG MIN -125.10 0 0 N u o K 0.O0 o.00 0,00 -25.10 0 5 N 30 26 w 0.05 0,25 0:05 ~! 0,04 74 g0 0 1~ ~ ~l 44 ~ 0,~6 0,20 0 3! N 0,28 174.O0 0 1~ ~ 43 30 ? O.58 O,0g 0,69 N 0 50 ~'74.00 0 14 N 49 3R ~ 0.77 0,05 0,94 N 0:86 37~,90 0 31 N 27 37 K 1.16 0,44 1,38 N " ' 3,35 N 1,55 47~87 2 '18 ~ ~9 41 ~ 3.03 3,54 574.64 5 11 N 6 23 W 0.68 2.70 9,99 N 0,92 673.o7 8 13 N 7 25 W 21,06 3.11 21,30 N 0,43 77~.44 11 56 N ~0 0 W 38.43 3.3~ 38,47 N 3,0~ ~ 12 34 w 61.o7 3.58 N 12 4 W 91,12 3,96 N 11 2n ~ 126.30 2,67 ~ ~O 5~ w 166.47 2.99 N 10 40 W 211.79 3,36 N 11 24 W ?b2,J. 6 2.44 N ~2 35 W ]16.22 N ~1 50 w 37~.Ol 1,47 N 9 2? w 555.ql ~ 8 45 w ~21,41 ~I H 19 W 689.36 N 7 3~ W 760,1! ~ 7 7 W 833.50 N 6 27 W 900.46 N 5 50 W 087.62 ~ 5 37 w 1066.35 ~} 5 1~ w 1~45.12 M 5 15 w ~923.74 lO0O.00 994 71 ~60,~1 !5 15 !100.o0 1u90:35 g65.~5 18 40 120o.00 11~3,91 105~,~3 ~2 O 1300.o0 127b.qO i150,]9 75 Iq 1400 nO ~364,6~ 1~$0,51 ~8 3~ 1500:00 1450.97 1325.~7 ~1 5~ 600.00 ~535.06 1400.O6 33 35 700.00 1617.40 1497.~0 ~5 2~ 1~00 OO 1698.10 1573.00 36 49 1~00:O0 ~777.44 165~.34 ~8 2! 2000.00 18~5.01 1720.01 39 57 2100.o0 !9~0.56 1~05.46 41 40 2~00 o0 7003.B0 1~7~.79 ~3 57 2100~o0 2074.5~ lo40.42 ~ 14 ~400.00 ~142.3~ 2017.76 Ag 24 2500 OU ~2~7,27 2087.17 5{'3 4~ 2600"00 2269,43 2144.33 51 50 2700:00 2330.81 ~?0K.7! 52 1~ 2900.~0 ~453,6~ 232~,51 51 5~ 3000.n0 2515,3n 2390,29 51 44 3100 Oo 2577,4~ 2457,38 3200:00 2639.75 2~14.65 ~1 20 3~00 O0 ~702.1& 2S77.n6 3400:00 2765.4~ 2640.34 50 22 3~00 00 ~899 3600:00 ~894:16 2769.06 49 33 3700.00 2959 3800.00 ~0~5~0~ 2899.92 3g00.O0 3001,26 2066.16 48 ~ 5 6 w 1102.12 ~ 4 57 w 1380.23 N 5 t w 145~.~0 N 5 10 w 1536.06 N 5 20 w 1613.~5 ~ 5 26 W 1680.~2 N 5 25 w 176~.~7 ~ 5 49 w ~84~.47 N 5 57 w lO16.73 ~ 6 37 w 199~.49 1,96 1.47 1,9~ 1,96 2,40 2,46 0 31 0:39 0,43 0,50 0,29 0,38 0,24 0,85 0,43 0.49 0,45 0,33 0,30 0,65 'I 72 w 0 O0 N 0 0 E 07 N 37 10 E 42 N 42 14 E 90 N 4O 27 E 27 N 49 40 E 85 N 41 33 E 69 N 24 47 E 03 N 5 31 N 1 9 59 N 4 29 W 62 04 N 7 9 W 14 01 w 91 61 56 N 124,53 N 21 163 95 N 28 208 40 g 37 257 90 N 46 310 85 N 58 366 30 ~ 70 4~4 17 N 81 483 99 N 9 3 06 W 126 B0 W 166 25 W 211 66 W 262 19 W 316 24 w 372 98 w 432 27 W 492 13 N 8 50 W j0 N 9 35 W 47 N q 57 W 79 N 10 7 W 17 N 10 15 W 25 N I0 ]6 W 97 N ~0 51 W 02 N 10 56 W 90 N 10 54 W 678 11N 1~4 748 21N 134 821 06 N 143 806,58 N 152 974,47 N 160 1053,02 N 168 1131,67 N 176 1210,21N 183 26 W 689 03 w 760 50 w 833 w 987 62 W 1066 06 w 1145 29 W 1224 40 N 10 23 W 12 N 10 9 W 50 N 9 54 W 46 N 9 ]9 W 65 N 9 22 W 28 N 8 O1 N 836 1288 52 N 190 42 W 1302 51 N 8 24 W 1366 61 N 197 27 W 13B0 77 N 8 12 W 1444 !522 1599 1675 1751 1827 1902 1976 55 N 204 09 W 1458 90 N 8 2 W 38 N 210 95 W 1536 93 N 7 53 W 49 N 218 09 W 1614 28 N 7 45 W 93 N 2~5 34 W 1691 02 N 7 39 N 87 N 232 52 W ~767 24 N 7 33 W 31N 239 93 W 1843'00 N 7 28 W 36 N 247 67 W 1918,41 N 7 25 W 83 N 255,77 W 1993,31 N 7 22 W 546 19 N 103 89 W 555 98 N 10 ~6 W 610 87 N 114 25 W 621 47 N 1015 W PAGE 2 CONPU~ATION PA~:~: 25-F~B-B5 2C-16 DATE O~ SURVEYt 0-FEB-R5 125.10 iNTERPOLATED VALUES FOR EVEN 100 FEE~ OF MEASURED DEPTH TRb~ St.I~-SEA CDUR~ VERTICAL DOGLEG RFCTANGULAR COORDINATES HURLS, DEPARTURE ~EA61It{~D V~RTI~AL VERTICAL DEVIATION AZIMUTH SECTION SEVERITY NORTH/SOUTH E~$T/WEST DI$T, AZIMUTH DEPTU DFPTH DEPTH DEG MTN DF(; MTN F~ET DE~/IO0 FEET FEET FEET OEG ~IN 400n.oO 3158,15 3033,n5 47 4~ 4100.00 32~5,18 3100,08 47 59 4900.00 3202.16 3167.06 47 56 430n. O0 3359,18 3~34,08 47 5~ 4400 O0 ~426o28 3~01.18 47 39 45O0:00 3493.6l 3308.51 47 30 4600.00 3561,52 3436,42 47 7 4700.00 30~9.7~ 3504.61 46 53 . 00 46 53 480~ O0 36~8.10 357~. 4900.00 3766,0q 3640.99 a7 14 5000.00 3834.2~ 3709.12 46 55 5100.00 3902.67 3777.57 40 41 5~09.O0 3971,34 3~46.~4 46 47 5300 O0 4038.70 3913.60 48 2~ 540n~0 4105.37 3080.27 47 54 5K00.OO ~172.68 4047.58 47 26 5600.00 424t),51 4!15.41 a7 ~ 5700.00 ~30B.'11 4183,61 ~6 4~ 5~00.00 437~.84 4251,74 a7 5~ 5900.00 4~41.46 4316,36 51 2~ 60oo,no 4503,28 4378.18 ql 44 6!00 O0 4-565.26 4440,16 ~1 3R 6200~00 4627,5o 4~07.4o %1 32 6300.00 4689.84 4~o4.74 gl i6 6400.00 a7~2.74 4627.64 50 50 6500 0U d816 2! 4691.11 q0 19 66()O"00 4880:7? 4755°62 49 40 67~)0[O(; 49a5.75 4a20.65 a9 '7 6R0O.~() 50li 40 4~6.30 AB 44 6900.00 5077:07 495~.97 ~9 27 7000.00 5141,~1 5016.71 49 26 7100.n0 ~207.35 5082.25 a0 43 90 0.n0 5273.85 51.48.75 47 58 .300,00 5341.47 5~1~,32 46 57 7400.00 5410 44 5785.34 45 43 7500.no 5480~6% 5355.55 45 7600,00 ~551.9~ 5426.R2 43 44 7700.00 5695.07 549Q.~7 41 5~ 7800.00 5700.U~ 5575.73 39 44 7~0~.00 5776.1~ 5653.O9 19 4~ ~ 7 50 W 2065.76 ~ '1 43 W 2t39.q2 W 7 31 W 2914.12 N 7 20 W 2288.28 N 7 5 W 2362.35 ~ 9 31 N 2a36,~3 N ~1 45 W 2509,61 ~ il 52 w 2582.7! N 15 7 W 2655.54 ~ ~7 2 W 272~.36 ~ 17 2 w 2n00.98 N 17 6 w 2873,30 ~ !7 27 W 2945,39 ~ 18 45 W ~092.18 E !8 50 W 3J65.~3 ~ 18 5~ W 3237.80 ~' !8 50 W 3310,01 N 19 36 w 3382.25 N ?0 23 w 3457.31 ~' 19 57 W 3534.62 ~ 19 5~ W 3611.07 N ~9 4~ W 3688.93 N ~9 47 W 3765.94 ~ !~ 24 W 3842.54 N 19 15 w 3olfl,75 ~ 1~ 57 W 399a.t7 ~ !9 O w 406o.17 ~ !9 l! W 4~43,59 H ~9 8 W 4218.0~ ~1 ~9 20 W 4293,~1 N !9 39 W 4367,66 N ~0 31 w 4441,13 ~ 20 35 W 4513.56 N ?0 44 W 4584.62 N 91 R W ~654.50 N 91 7 w 4723.~8 ~3 ~1 1~ W 4790,11 N 21 53 w 4854.01 ~ ~0 56 w 4916.06 0,33 205~, 0,31 212 0.27 2197 0,21 2271 0,67 ~344 3,35 24t8 0.27 2490 0 53 2561 3~33 2632 0,41 2703 0,'35 0,20 2842 1,59 2912 0,62 29R2 0 3~ 3053 0,2~ 3123 0,65 3192 0,38 3261 3.39 3330 2,36 3402 0,28 0,50 3550 0,09 3623 0.7~ 3697 0 75 3770 1i!6 3043 0 25 3915 0.44 3987 0,40 4058 1,53 4129 ,9~ ,63 0,8~ 1,48 1.12 0,51 · 1,31 2,86 3,05 1,21 55 N 265.27 W 2067 64 N 7 22 w 07 ~ 275 36 w 2141 85 N 7 23 w 67 N 285 21W 2216 27 , 294 81 W 2290 83 ~ 304 11 w 2364 06 N 31425 W 2438 08 N 328 36 W 2511 69 ~ 343 30 W ?584 74 N 359 82 W 2657 04 N 380,66 W 2729 10 N 7 23 W 32 N 7 23 W 47 N 7 23 W 39 N 7 24 W 64 N 7 30 W 59 N 7 37 ~. I N 7 46 ~1 N ~ 0 W 2773 03 N 402 12 W 2802 03 N 8 15 W 72 N 423 53 W 2874 09 N 8 28 W 16 N 445 43 N 467 04 N 491 05 N 515 58 N 539 78 N 563 01 W ?945 88 W 3018 74 W 3092 60 W 3165 35 W 3237 O0 W 3310 96 N 8 41 W 91 N n 54 W 39 N 9 8 W 32 N 9 22 W 82 N q35 W 01 N q 47 W 95 ~ 586 93 W 3382 27 N 9 59 W 57 N 613,24 W 3~57,39 N 10 12 W 3476 34 N 640 38 W 3534 83 N 10 26 W 10 N 667 15 W 3612 24 N 10 38 W 69 ~ 693 27 N 720 49 N 746 41 N 771 64 N 796 47 N 71N 846 94 ~ 871 82 W 3689 20 W 3766 37 W 3843 99 W 3920 89 W 3995 6t W 4071 41W 4146 18 W 4220 51 N 10 50 W 77 N 11 1 W 5N 1! 11 W 7 N 11 21 W 90 N I1 30 W 24 N 11 38 u,~, O3 N 11 46 83 N 11 54 W 4201 93 N 896 23 W 42q6 44 N 12 2 W 4273 11 ~ 921 47 W 4371 34 N 12 10 W 4343 4412 4479 4546 4611 4675 4736 47q5 24 N 947 14 W 4445 31 N 12 i8 ~ 26 ~ 973 03 W 4518 28 N 12 26 W 96 N 998 58 W 4589 90 N 12 33 W 49 N 1023 94 w 4660 37 N 12 41 W 91 ~ 1049.22 W 4729 76 N 12 49 W 47 N ~073,93 W 4797 22 N 12 56 W 18 N ]097,88 W 4861 76 N 13 3 W 12 ~ 1121,14 W 4924,44 N 13 9 W A~C~ KI!PARUK NORTH TRtI~ SUR-$E~ COURSE MEA$11HF'D V~RTI~AI, VERTICAL DgV]A~I~N A%IMUTH CO~aPUTA~ION DAT~: 25-FEn-R5 PA~E DATE KE£,bY BUSHING Eh~VATIONI ENGIN~ER~ D, RARBA INTFR~OI, A~ED VAlUeS FOR EVEN 10o ~EET OF MEASURED DFPTH VERTICAl. nOGDEG RECTANGULAR CDORDINATE5 HORIZ, DEPARTURE ~ECTIQN SEVERITY NORTH/SOUTH EAST/WEST DIST, AZIMUTH DEPT~ DEPTH DEPTH PEG MIN 8000 nO 58~4,02 572~,52 40 21 8100~OU 5930,81 5805,71 40 37 ~OO.nO 6006,24 5P81.,14 41 14 8300,00 6~al,71 5~56,61 40 57 840~,no 6157,27 6o32,!2 40 57 8405,00 6161,00 6035,90 40 57 DFG ~,iTN FEET PEG/lO0 FEET N ?0 43 W q97q.37 ~ ?0 24 W 5043,00 ~ ~0 31 W 5107.52 N ?0 2~ W 517~.03 ~' ~0 20 ~! 5236.48 ~ ?0 20 W 52~9.71 125,10 0,19 1,16 0.4~ o;oo 0,00 0.00 FEET DE~ ~IN 4855.42 N t143 97 W 4988 37 N 13 15 W 4916,06 N 1166 73 W 5052 61 N i] 21W 4977,56 N 1189 70 W 5117 77 N 13 ~6 W 5039.07 ~! 1212 57 W 5182 91 N 13 31W 5100.54 N 1235 35 W 5248 O1 N 13 36 W 5103,61 ~ 1236 40 ~ 5251 26 N 13 37 W AP. CO AL, A6KA, THC. 2C-lb NORTH ST,UPE, ALASKA COt~PUTATInp~ D~TEI 25-FEB-R5 DATE OW SURV~¥) R-FEB-85 KELLY BUSHING Eb~VATION: ENGTNEE~ D, BARBA IN'rFRP(]LATED VALUF$ FOR EvEN iO00 F~E"~ OF M.F. ASURED DEPT TRIJ~ SUB-S~A C~URSF MEASIIRFD VFRTICA[, V~RTICAL DEVIATION ~ZIMUTH ~EPTH D~PTH DEPTH DKG MTN DEG MT~ n.o0 o.00 -]25.~0 0 0 lnOO.OO 994.71 R6q,61 15 15 2000.00 18~5.01 172q,91 39 57 3000,00 2515,30 2190,29 51 44 4000,00 315~,15 3n33,05 47 48 5000.00 ~8~4,2~ 370~,~2 46 55 6000.00 4503,28 437~,~8 51 44 7000,00 5141,8i 5016,71 49 26 8nOO.nO 5~5~,67 5720,52 40 2! 8405,00 6~6~,0n 6035,g0 40 57 PAG£ 125,10 FT VgRTTCA[, DO~LEG RECTANGI.ILAR COORDINATES HORXZ, DEPARTUR~ 5~CTION SEVERITY NORTH/SOUTH EAST/WEST OlSX, AZIMUTH FEET D~/IO0 FEET FEET FEET OEG MIN 0,00 N 61 56 N 546 12R8 2050 2773 ~476 4201 4855 5103 7 19 N 103 52 N 55 ~ 265 03 N 402 34 N 640 93 N 896 42 N 1143 61N 1236 0 O0 E 72 W 62 ~9 w 555 42 W 1102 27 W 2067 12 W 2802 38 W 3534 23 W 4296 97 W 49B8 49 W 5251 0 O0 N 0 0 g 04 N 7 9 W 98 N 10 46 W 64 N ? 22 W O3 N a 15 W 8] N 10 26 W 44 N 17 2 ~7 N 13 15 26 N 13 37 w N 0 0 E 0,00 V 12 34 W bl,q7 ~ 9 22 W 555,ql ~ 5 ~ W 1302,12 N 7 50 W 2065,76 ~ 17 2 w 2800.9~ ~ 19 57 w 3934,62 ~ 19 20 W 429~.?1 ~ 20 43 W ~q7q.37 ~ 20 20 W 5739.71 0.00 3,58 1,96 0,29 0,33 0,35 0,28 0,92 O.lq 0'00 ARC~ Ab~KA~ T~, 2~=!b NO~TH S[,OPE~ A~aSKA TRUE SUB-SEA COUR$~ DEPTH DFPTH DEPTH DEG MIN DEG MTN Cnh!PUTATiDN DA'rF: 25-FEB-85 PA~ 5 DATE OF SURVEY] q-FEB-R5 KELLY RUSHING EbEVATION{ ~NGINEER: D, BARBA iNTERPOLATED VALUES FOR EVEN !00 FEBT OE SLIB-gEA DEPTH V~R~TCAL DOCbEG RECTANGUbAR COORDINATES HORIZ, DEPARTURE 5ECTION SEVERITY NORTH/SOUTH E~$T/WEST DIS'f, AZIMUTH FEET DE~/100 FEET FE~T FEET DEG ~IN o.nO 0.0o -125.!0 0 o N 0 o E 25,10 25,10 -lO0.O0 0 4 S 5 52 E 12~.10 125.10 ~,00 0 ~ N 37 24 ~ ~25,10 2~5,1~ 100,00 0 18 ~ 38 47 E 325.10 3~5.10 200.00 0 l~ N 46 52 ~ 42~,10 425.10 300,00 0 15 N 49 5 F 52~.11 525,10 400,00 0 41. N 21 ~ E 625,1_6 6~5,10 500,00 3 10 N 4 2] W 725.48 7~5.10 600,00 5 45 ~ 6 39 W ~26,33 8~5,10 700,00 9 g N 7 42 W 0.00 0.00 0,00 N 0,00 0.00 0.00 0,00 g 0,00 0,08 0,44 0,10 N 0,06 n.35 0.07 0,4~ N 0.37 0.63 0,04 0,75 N 0,65K 6.~3 0,09 1,00 N 0,94 14 1,6~ N 1,33 1.,37 1, 4.23 3,3~ 4,55 N 1.49 12,12 2,13 12,41 N 0.64 25,03 3,97 25,23 ~ 0,95 o29.73 9~5.10 ~00.00 12 58 1031.59 1.025.10 qOm. O0 ~6 lfl 1136.90 !1~5,10 1000.o0 ~0 11 1244.66 1225.10 1100.00 23 2R 1~5~.32 13~b 10 1700,00 97 In 1460.66 14~5':10 1300,00 30 57 158,.n8 !5~5~1n 1400.00 33 21 1700.47 lb~5,10 1~00,00 35 36 1833.fll ~7~5.10 1600.00 ~'7 17 10~1,!8 18~5,!0 1700.00 39 1~ N 10 4R W 44.52 N 12 34 w 70,59 ~! 11 36 w 103,50 N 11 ~ W 143,59 N 10 42 W 190,04 N 10 5~ W 246,32 N 12 36 W 309.68 W 11 46 W 37R.43 N 10 51W 452,~9 ~' 9 35 W 5.~.~7 209~.68 19~5.10 l~On. O0 al 4~ 2~29,~7 2075,1o lOOn,O0 44 37 2374.15 ~l?b,lO 2000,00 4'7 47 252R.'39 9295,10 210o,o0 51 1R 269~.6~ 23~b,lo 220n,00 52 10 2~5).6'? 74~5.1o 230n.00 ~2 2 ]015.68 25~5.10 2400.00 ~ 4~ 3176.47 76~5.10 2~00.00 gl 27 333&.~8 7775.10 2600.00 50 50 3493.~7 9825.10 2700.00 ~9 55 N ~ 48 W 616,53 N 8 q W 700,96 N 7 !6 W 814,~8 N 6 !1 W 93!,44 ~' 5 34 W 1050,01 ~ 5 14 W 1187.~3 ~ 5 4 w 1314.38 ~ 5 ~ w 143g,B5 ~) 5 16 W 1564,~1 N b 26 W 1684.61 N 5 39 W lg01,92 N 5 57 W 1016.~2 N 7 25 W 2020.99 N 'l 43 W 2130.03 N '1 25 w 2250.59 N 7 5 w 236i,06 N 11 17 w 2470.39 N 11 49 W 2577.79 N !~ 27 w 2684.34 ~ ~7 ~ w 279~.30 3647.~9 2925.10 2RO0.O0 49 18 3000.12 3025.10 2qOO.OO 48 53 3050.77 3125,10 3no0.oO 47 57 4090.~8 32~5,10 3100,00 47 59 4~49,17 33~5,10 3~00,00 47 54 4399,76 3t95,10 3300.00 47 30 4546.46 3525.10 3400.00 47 1~ 4693,75 3b~5,1n 3500,00 46 5~ 4930.60 3775.10 3600.00 4'7 g 4086.64 38~5,10 3700.00 46 57 3,83 3 21 3~45 3,61 3,02 3,9R 2,04 1,44 I 41 1~6~ 1.38 2.47 2.43 2,1S 0,29 0 22 0~20 0.27 0,32 0,54 0 60 0.30 1,63 0.30 0,26 0.64 1.SO 0,37 1,82 0.21 44 47 69 9~ 102 18 141 50 1~8 O0 242 43 3O4 46 371,70 444,15 521,79 125,10 FT 4,12 W 44,66 N 5 17 W 9 61 W 70,64 ii 7 49 W ' 16 55 W 103,51 N 9 1! W 24 43 W 143,59 N 9 47 W 33 37 W 190,94 N lO 3 W 43 62 W 246,32 N 10 12 W ~b 76 W 309,71 N 10 33 W 71 36 w 378,49 N 10 52 W R5.B6 W 452,37 N 10 $6 W 99,81W 531,25 N 10 ~9 W 606,05 N 113 51 W 616,59 N 10 36 698 51-N 127 18 W 709,99 N 10 19 W 801 97 N 141 09 W 8~4 29 N 9 918 47 N 154 96 W 9)1 45 N 9 ~045 70 N 167 90 W 1059 09 N 9 7 W 1.173 84 N 179 96 W ~107 55 N 1300 78 N 191 51 W 1314 80 N 8 22 W 1426 21N 202,4~ w 1440 51 N 8 4 1550 50 N 213,53 w 1565 14 N 7 50 1.670,73 N 224,~5 W 1695 79 N 1787,86 N 235 98 W 1803,37 N 7 31 W !902,45 N 247 68 W 1918 50 N 7 25 W 2123, .86 N 2014 39 N 260 99 N 275 ~233 289 2343 55 N 303 2451 65 N 320 2556 87 N 3a2 ~660 59 ~ 367 2763 69 N 399 37 W 2031 35 W ~141 96 W 2252 95 W 2363 46 W 2472 20 W 2579 75 W ~6~5 26 W 2792 15 N 7 21 W 76 N 7 23 W 60 N 7 23 W 18 N 7 23 W 51 N 7 26 W 68 N 7 37 W 89 N 7 52 W 38 N 8 13 W 0 O0 N 0 0 E 0,00 N 90 0 E 0,11 N 32 51E 0,56 N 41 40 E 0,99 N 40 57 E 1,38 N 43 13 E 2,10 N 39 29 g 4,79 N 1~ 6 g'~. 12,43 N 2 57 25,25 N 2 9 ~ PAGE 6 cnHPUTATInN [)~TEJ 25-F'EB-R5 A~cn AbAS~A, NORTH DATE OF SURVEYI 8-FEB-85 KELLY RUSHING EbEVATIONI ENGTNEER; D, SARMA 125,10 FT INTKRPOI,ATED VAI, UF<S FnR EVEN !00 FEET OF SUM-SEA DEPTH TDUF. ,KLIR-SEA COURSE VERC~ICAb DrJ~bfG RMC~ANGUDAR COORDINATES tlORIZ, DEPARTURE P~f~Bl!~r!:. VRRTICAI. VERTICAL DEVIATION AZI~UTh S~iCTION SEVERITY NORTH/SOUTH EAST/WESt' DIST. AZIMUTH DEPTH D~P~H DEPTH DEG MTN L)FG ~4TN FEET PEG/lO0 FEET FEET FEET PEG SIN 5132.69 3925.10 3800.00 46 38 5270.55 4095.10 30OO.O0 48 11 5420 40 d125.10 4000.00 47 48 5577']4 4225 i0 4100.00 47 12 572]'93 4325:10 4~00.00 46 45 5873:o8 .4425.1o 4~U0.00 50 37 6~35,~2 45~5 10 4400.00 51 40 6196.~5 4625:10 4500.00 51 31 6356.12 47~5.1o 4600.00 50 57 6513.~9 a~25.1o 4700.00 50 3 666~ 40 a925.10 4800.00 49 20 6820~79 5025.10 ~Ot) oo 48 46 6074.76 51~5.10 5000:00 49 38 7!26.fl8 52~5.10 5100 00 ~8 30 7420 Qb 54~5,10 5300.00 45 35 7K67 67 KS~5.10 5400.00 44 23 7700 04 5~5.10 5500.00 al 53 7831 36 5795 10 5600.0U 39 0 7961.9~ 5895110 5700.00 40 1~ 8092 47 ~925,1n 'n4 6025 872~, 8]57.48 61~5.1~ 8405.00 F161.O0 5800 O0 40 3] 5gOO:nO al 2 ~000.00 40 57 b035,00 aO 57 N 17 S W 2896,89 ~ ~8 20 W 300~,43 w ~8 46 W 311~,72 ~ ~.8 5! W 3221,38 ~' ~8 51W 3~27.23 N ~0 2] w 3437.41 ~ 19 56 W 35ol.83 N ~9 4~ W 3685.95 ~ 19 3~ w 3809.95 N ~9 17 W 3929.~8 P !9 3 W 4045.57 ~ ~9 10 W 4159.03 N !9 1] W 427].89 N ~9 40 W 4387.54 w ~0 3] W 4496.~2 ~ 90 43 W 4590.~3 N 91 7 W 4697.82 ~! 71 i9 W 4790.~4 M 91 46 w 4873 42 N ~0 4~ W 4954:75 w ?0 25 w 5038.19 N ~0 28 W 5123.72 N ~0 20 W 5209.08 ~' 20 20 W 523g,71 O.lq 1,50 O,bO 0.34 0,~ 0.31 0,19 0.66 1,47 1.11 0.16 O.B4 1,38 1.1] 0.42 1,29 2.86 1,88 0.60 1.16 2.34 0.00 0,00 2865.44 N 4]0 52 W 2897 bO N 8 ]2 W 2967,94 N 46] 06 W ]003 84 N 8 52 W 3073,68 N 498 76 W 3113 89 N 9 13 W 3i76.85 N 5]3 98 W 3221 41 N q 32 W ]278.28 N 568 3383 60 N 606 35O2 32 N 649 3620 85 N 692 3738 36 N 735 3853,48 N 775 63 W ~327 18 W 3437 80 W 3562 79 W 3686 03 W ~809 5O w 3930 23 N 9 5O W 47 N 10 9 W 09 N 10 30 W 53 N 10 49 w.-- 94 N 11 7 74 N 11 22 W 3964.88 N 813 77 W. 4047.53 N 11 ]5 W 4073 49 N 851 54 W 4161 54 N 11 48 W 4183 42q2 4395 4493 4587 4675 4754 4831 44 N 889 11N 928 84 N 966 97 N 1003 70 N 1039 40 N 1073 59 N 1105 96 N 1135 76 W 4277 02 N 12 0 W 28 W 4391 87 w 4500 88 W 4604 88 w 47O4 94 W 4797 29 W a881 lo w 496~ 35 N 12 12 W 91 N 12 24 W 7~ N 12 35 07 N 12 46 W 25 N 3'7 N i 50 N 13 13 W 4911,47 N '165,03 W '5047,75 N 13 20 W 4993.00 N 1!95,47 W 5134,~ N ~] 27 W 5074.40 N 1225,66 W 5220,33 N 13 34 W 5103.61 N 1236.49 w 5251,26 N 13 37 W Ar*CO_. ~bA,.SKA, TNC, 2r-16 KIIp~R~IK NORTH SLOPE, ALASKA MA~K~R TOP UPPFR SAND ~A~ LOWER ~AND PBTD TOTAL D~PTH CnMPUTATInN DAT~: 25-FEB-~5 INTF. RPO[,ATED VALUES FOR CHUSEN HORIZONS 7978,0n 8064,0n 8245,00 8307,00 8405,00 PAGE 7 DATE OF' SURVE¥I B-FEB-R5 KELLY RUSHTNG ELEVATIONI 125,10 FT ENGTN£ER~ D, ~ARBA SURFACE ~OCATZON AT ORIGIN= 1.207' FNL, 42b' FEI,, SEC 21 II1N, Rgg~ U~ TVD R~CTANGUbAR COORDINATES F~O~ KB SUB-SEA NORTH/SOUTH EAST/WEST 5763,55 5799,69 5003,42 0040.17 6086,99 6161,00 5638 45 5674 50 5778 32 5915 07 5961 80 6035 90 47B~,Rl N 1~16,79 481],89 N 1127,50 4894.~8 N 115~.57 5005,27 m 1200.04 504],38 N 1~14,16 5]0~,6! N 1236,49 ARCO A[,A$~'A, 2C-16 KIIP~RI1K NOR'tH SLOPE, ALASKA mARKer PBTP TOTal, D~PTH C~hPI]mATION DAT~: 25-FER-R5 ************ 6Tt<ATIGRAPHIC MEASIJR~D DEPTIt 78gl,0n 7928,00 ~064,00 ~245,0n 8307,00 84o5,00 DATE OF SURVE~I R-FEB-85 KELbY BUSHTN~ EbEVAT~DN{ ENGINEER{ D, BARBA 125.10 FT SURFAC~ LOCATION AT ORTGTN: ]207' FNL, 420' FEI,, SEC 2i, TllN RgE, UN TVD R~CTANGULAR COORDINATES FRO~ KB SUB-SEA NORTH/SOUTH EAST/WEST 5763.55 5638.45 4783."1 a 1116,79 5790.69 5674.59 4811.89 N 1127.50 03.42 ~778,32 4894.18 N 1158.57 W 6040.!7 5915.07 5005,27 N 1200,04 W 6086.09 5961.80 5043.38 N 1~14.16 6161.00 6035.90 510].61 N 1236.49 FINAI, WEI,D hOCATION AT TR!.IF SUB-SEA MFASURED V~RTICAL VERTTCAL DEPTH DEPTH DEPTH R4ns.0n b161.oo 6015,90 HORIZONTAL D~PARTUR~ DISTANCE AZTMtJTH FE~T DEG MTN 525t.26 N 13 37 W SCHLUMBERGER ARCO ALASKA. !NC. 2C- 16 KUPARUK NORTH SLOPE, ALASKA FEBRUARY 8, 198S TVN PLOT FROM OCT OATA dOB REFERENCE 70131 WELL: 2C-16 SURFACE LOCATION: 1207' FNL, 426' FEL, S21, TllN, R9E, ~{ VERTICAL PROJECTION SE -2000 -!000 0 0 I000 ~'000 9000 4000 SO00 ..~....,L...~....~ ...... ~,....~-..~...~. ...... ,j....,,...~,...~...,...~,-.~....~...,~ ....... .~...~..-.~-.~ ....... ~...~...~...~ ...... ~...~...~..~ ....... ~..~...~...~ ........... ~ ~ · ~ ~ ~ ~ ~ ~ ~ .~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ : ~ ~ .... ;4.4.4 ....... ~...~.4...~...~...z...~..~".~.......~...~...~4....~4.4=.~.&.....~...~...~...~... ...~,..~...~...z.......~...~...~...~..,...~..~...~...~.......~...~...~...~......~...~.,.~..!...~...i...i...!... ~ ~ i...~...~...~..i.~..i i i ~ ~, ~ .... ~...~..4...~...:...~...~...~...;..:...~....~...~...! ....... ~...L$...~.....~.~.~.~......~.4...~...~ ...... ~...~...~...~ ...... ~...~...~ ............ ~...~...~ .~...,...~..~...~...~ ........ ~,...~...L;...~..~..~...~...~...h.~...;...:,....~..L~..~..~..~ ....... ~-.~_.Li. ~ ~. ~ ~ ~ ~ : ~ ~ ~ ~', ~ T T'~ T ~ ~ ~ '~' ~ P : ~ : ~ ~ ~" : : ":"'~-'~'"T'"?'"~'"?":'"'F'T'".'"? ....... r"T"'r"~ ...... ~'"t"?'"?"' 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'''t'''fl''f''?'' l't'"t'"t'"f ........ ~...t...t...t..., '"?"'?~'"tl'' ['l'~'''?}l''t'" ''t'"tlllt'''tl'' "''~''ltll'?l''t ....... ?lll~lll?lll:l'll '..?..l~..1.~.:.t..: -BO00 -SO00 -4000 -9000 -2000 -1000 0 1000~RST ' Suggest~ form to I~ inser~cd lo each '-acbive*- ~,: .~,, for kt~ly c~ll~ce ~ o~ z~Ulakto~. , .. , · R~utrc~ Date * . c~~uo. ~~ · ~ ~_~/. ~ . .. . ~re ~ips ~/d~~ ~ Core ~scrip~on Registered S~ey ~" incltna~on S~ey Drt 11 ...... · .... ~e.s__~ ~ ~, r ARCO Alaska, Inc. ~ Post Office 80~ ~00380 .Anchorage, A~aska 99510 T,e~ephone 907 276 1215 February 20, 1985 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT' 2C-16 Dear Mr. Chatterton- Enclosed is the Well Completion Report for 2C-16. I haven't received the Well History. When I do, I will forward a copy to you. Also, the bottomhole location, geologic markers, TVDs, and tubing details will be submitted when the gyroscopic survey is run and the well completed. If you have any questions, please call me at 263-4944. Sincerely, Gruber Associate Engineer JG/tw GRU4/L159 Enclosure ARCO Alaska, [nc. is a Subsidiary of AtlanticRichfieldCompany ARCO Alaska, Inc. Post Offic(' ,x'360 Anchorage, '~,~ska 99510 Telephone 907 277 5637 Date: 1/30/85 Transmittal No: 5012 RETURN TO: ARCO ALASKA, INC. ATTN: Records Clerk ATO-1115B P.O. Box 100360 ~e~orage, AK 99510 ' /~l~ansmitted herewith are the following items. Please acknowledge receipt ~'and return one signed copy of this transmittal. OH LIS TAPES Schlumberger #69926 1Q-12/~2/25/84 #69927 ~ 12/22/84 #69995 2U-14~/ 1/17/85 #70000 2W-15/ 1/22/85 #70001 lQ-10 ~/ 1/13/85 · Run 1 3550 - 7019 Run 1 3808 - 8429 Run 1 3121 - 7181.5 Run 1 3711.5-8246.5 Run 1 3586 - 7448 (Computed 1/23/85.) /cat Receipt AcknOwledged: B. Currier BPAE Chevron D&M DISTRIBUTION Drilling Geology Mobil NSK Ops. W. Pasher G. Phillips Phillips Oil J. Rathmell State of AK Sohio Union Well Files ARCO Alaska. Inc. ii a subsidiary ol AtlanticRich'tieldCompany ARCO Alaska, Inc.i Post Office Box 100360 Anchorage, Alaska 99510 Telephone 907 276 1215 January 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' 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) 2£-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 RECEIVED Al'astra u. ~ 6as Cons. ~mmi~ Anchorage ARCO Alaska, Inc. is a Subsidiary of AllanllcRIchfieldCompany STATE OF ALASKA ~ ALASKA C~._ AND GAS CONSERVATION CO ,MISSION MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS · Drilling well J~ X Workover operation [] 2. Name of operator 7. Permit No. ARCO Alaska, Inc. 84-202 3. Address 8. APl Number P. 0. Box 100360, Anchorage, AK 99510 50- 029-21218 1207' FNL, 426' FEL, Sec.21, T11N, 4. Location of Well at surface R9E, UN 5. Elevation in feet (indicate KB, DF, etc.) 125.7' RKB 6. Lease Designation and Serial No. ADL 25654 9. Unit or Lease Name Kuparuk River Unit, 10. Well No. 2C-16 11. Field and Pool Kuparuk River Field Kuparuk River 0il Pool For the Month of December , 19 84 12. Depth at end of month, footage drilled, fishing jobs, directional drilling problems, spud date, remarks Spudded well ~ 0200 hfs, 12/14/84. Drld 12-1/4" hole to 3875'. Ran 8-1/2" hole to 8405'TD as of 12/21/84. Ran OH logs. Ran 7" csg, Displace 7" to brine w/crude in 9-5/8" x 7" annulus. Secured well 12/23/84. 9-5/8" csg. Drld PBTD is at 8307'. & RR ~ 2100 hrs, 13. Casing or liner ru.n and quantities of cement, results of pressure tests 16" 62 5#/ft, H-40, weld conductor set ~ 110' CIP w/300 sx CS' II 9-5/8", 36.0#/ft, J-55, BTC csg w/FS (~ 3855'. CIP w/850 sx AS II I, 550 sx Class G & 150 sx AS I (Top Job). 7" 26 O#/ft, J-55, BTC csg w/FS ~ 8394' CIP w/300 sx Class "G" cmt 14. Coring resume and brief description None 15. Logs run and depth where run DIL/SFL/GR/SP/Cal f/8400' CNL/FDC f/8400' - 7650' - 3855' 16. DST data, perforating data, shows of H2S, miscellaneous data N/A 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. NOTE--Repor(Jon 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/MR35 Rev. 7-1-80 Submit in duplicate ARCO Alaska, I~ Post Offi(},...,ox 100360 Anchorage, Alaska 99510 Telephone 907 276 1215 November 14, 1984 Mrs. Elaine Johnson State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT- Conductor As-Built Location Plats - 2C Pad Wells 9-16 Dear Elaine. Enclosed is an as-built location plat for the subject wells. you have any questions, please call me at 263-4944. Sincerely, Gruber Associate Engineer JG/tw GRU2/L92 Enclosure If i. ARCO Alaska, Inc. is a Subsidiary of AllanticRichfieldCompany 21',.. ~'22 WELL 9 Y = 5,958,350.583 LAT. 70°17'50.$495" X = 519, 109.2T6 LONG. 149°50' 42. 924" PAl) ELEV. 88. $ O.G. ELEV. 84.0 FNL 1115. FEL 78. SEC. 21 WEll I0 Y : 5,958,272.562 LAT. 70017'49.7786" I x = 519,124.643 LONG. 149°50'.42. 480" PAD ELEV. 88.1 0.(~. ELEV. 84. I FNL 117:~ FEL 65 SEC. 21 W WELL 11 y = 5,958,214.485 LAT. 70°17'49.2069" X = 519,140.045 LONG. 149°50'¢2. 035" PAD ELEV. 88.0 O.G. ELEV. 84.1 FNL 1231. FEL 48 SEC. 21 WELL 12 Y= 5,958,156.557 LAT. 70°17'48.6:~66" X: 519,155.470 LONG. 149°50'41. 590" / ~~../' PAD £LE¥. 88.10.G. £LFV. 84.0 FNL 1289. FEL :~2. SEC.21 ®9 WELL 13 Y : 5,958,064.075 LAT. 70017',47.7557'' X 518, 807.527 LONG. 149°50 51. 740" ~6® ®~0 PAD ELEV. 87.9 O.G. ELEV. 8¢.0 \ ~5® \ \\\et~ FNL 1381. FEL 381. SEC. 21 \ ,4' \ \\\®' \ WELL 14 Y :5,958,'22.046 LAT. 70°17'¢8.3063'' X : 518,792.127 LONG. 149°50'52.185" PAD ELEV. 88.:~ O.G. ELEV. 84.0 ~ FNL 13.23 FEL 396 SEC. 21 WELL 15 Y - 5,958,180J30 LAT. 70(:' 17'48.8780" X = 518,776.652 LONG. 149°50'52.631" PAD ELEV. 88.4 O.G. ELEV. 84..0 FNL 1265. FEL 411. ~Ef,. 21 WELL 16 Y : 5 958,238.038 LAT. 70°17',49.4480,',' X ' 518, 761.261 LONG. 149°50 53. 076 PAD ELEV. 88.1 0.6. ELEV 84.0 F'NL 1207 FEL 426. SEC. 21 _'~ LOCATED IN PROTRACTED SECTION 21 TOWNSHIP II N RANGE 9 E., UMIAT MER, h, F3V i NOTE: BASIS OF POSITION IS MONUMENTATION A!as~ Oil & Gas C,or~s,, Commls, si~L 2CMIDDLE I~ 2C SOUTH PER LHD 8 ASSOC. ,~, LICENSED TO PRACTICE LAND SURVEYING IN THE STATE OF 14 ALASKA AND THAT THIS PLAT REPRESENTS A SURVEY MADE · .. UNDER MY DIRECT SUPERVISION AND THAT ALL DETAILS' ,/UREY ,d'/ ARE CORRECT AS OF NOVEMBER 5, 1984. ARCO Aloske, Inc. L~ Kul)oruk Project North Slope Drillin(] DRILL SI'~E 2 CONDUCTOR AS- BUILT LOCATIONS , ,, Dote: NOV. 5, 1984 Scale' I.": 400' 26 mm,mm I I Drown By' MC Owg. NO. NsKg.052i~d$ ~ovember 5, 1984 Mr. J. B. Kewin Area Drilling Engineer ARCO Alaska, Inc. P. O. Box 10~360 Anchorage, Alaska 99510-0360 Re: Kuparuk River Unit 2C-16 ARCO Alaska, Inc. Permit No. 84-202 Sur. !Joe. 1207'FNL, 426'FEL, Sec. 21, T].IN, RgE, UM. Btmhole Loc. 1017'FNL, !372'FEL, Sec. 16, TllN, R9E, UM. Dear Mr. Kewin., Enclosed is the approved application for permit to drill the above referenced well. If coring is conducted, a one cubic inch chip from each foot of recovered core ts 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. Many 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 con~nencing oper.ations 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 commencing operations you may be contacted by a representative of the Department of Environmental Conservation. To aid us in scheduling field work, please not~.fy this office 24 hours prior to commencing installation of the blowout prevention ~{r. Jeffrey B. Mew~m ¥.uparuk River Unit 2C-16 -2- November 5, ]984 equipment so that a representative of the Commission may be present to witness testing of the equipment before the ~urface casing shoe is drilled. ~ere a diverter system is required, please also notify this office 24 hours prior to commencing equipment installation so that the Comm~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 we may have a witness present. Very truly yours, (z ,/ / /' I --, , ? ' .____-- BY ORDER OF ~{E COMMISSION be Enclosure c.c: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservatiop~ w/o enc!. ARCO Alaska, Inc. ~' Post Office B(~.. ~00360 Anchorage, Alaska 99510 Telephone 907 276 1215 October 25, 1984 Mr. C. V. Chatterton Commi s s i oner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT: Kuparuk 2C-16 Dear Mr. Chatterton: Enclosed are: o An application for Permit to Drill Kuparuk 2C-16, along with a $100 application fee o Diagrams showing the proposed horizontal and vertical projections of the wellbore o Proximity plats o A diagram and description of the surface hole diverter system ° A diagram and description of the BOP equipment We estimate spudding this well on November 25, 1984. If you have any questions, please call me at 263-4970. Sincerely, A~~eaB .~~__~~g Engi n]er JBK/JG/tw GRU2/L38 Attachments RECEIVED NOV o Alaska 0i~ & Gas Q.~'~s. Can~,[rlissi°n ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany :" STATE OF ALASKA " ALASKA ~f~lL AND GAS CONSERVATION COt,v, MlSSlON PERMIT TO DRILL 20 AAC 25.005 la. Type of work. DRILL [~}( lb. Type of well EXPLORATORY [] SERVICE [] ST'~.'~ TIGRAPHIC¢~\ REDRILL [] DEVELOPMENT OIL J~X SINGLE ZONEJ~ '~' DEEPEN [] DEVELOPMENT GAS [] MULTIPLE ZONE [] ~ 2. Name of operator ARCO Alaska, Inc. ~'~.. 3. Address P. 0. Box 1002'60, Anchorage, Alaska 99510 4. Location of well at surface 9. Unit or lease name 1207' FNL, /+26' FEL, Sec.21, T11N, Pge, UM (Approx.) Kuparuk River Unit At top of proposed producing interval 10. Well number 1/+7/+' FNL, 129/+' FEL, Sec.16, T11N, Pge, UH 2C-16 At total depth 11. Field and pool 1017' FNL, 12'72' FEL, Sec.16, T11N, Pge, UH Kuparuk River Field 5. Elevation in feet (indicate KB, DF etc.) 6. Lease designation and serial no. Kuparuk River 0i l Pool RKB 125.7', PAD 88.7' ADL 2565/+ ALK 2580 12. Bond information (see 20 AAC 25.025) Federal Insurance Company Type Statewide Surety and/or number #8088-26-27 Amount $500,000 13. Distance and direction from nearest town 14. Distance to nearest property or lease line 15. Distance to nearest drilling or completed 2'0 mi. NW of Deadhorse miles 1017 feet 2C-2 well 95' @ 2000'HD feet - 16. Proposed depth (MD & TVD) 17. Number of acres in lease 18. Approximate spud date 860:?,' MD, 6172' TVD feet 2560 11/25/8/+ -- 20. Anticipated pressures 19. If deviated (see 20 AAC 25.050) 2709 psig@__80°F Surface KICK OFF POINT 500 feet. MAXIMUM HOLE ANGLE /+9 o (see 20 AAC 25.035 (c) (2) 2'110 psig@ 6041 ft. TD (TVD) 21 Proposed Casing, Liner and Cementing Program SIZE CASING AND LINER SETTING DEPTH QUANTITY OF CEMENT Hole Casing Weight Grade Coupling Length MD TOP TVD MD BOTTOM TVD . (include stage data) 2/+" 16" 62.5# H-40 Weld 80' 2'6' I 2'6' 116' I 116' 4- 200 cf 12-1/4" 9-5/8" 2'6.0# J-55 BTC 3772' 2,5' 2,5' 2'807' I 2'02'6' 850 sx Arcticset III & HF-ERW ~ I 550 sx Class 8-1/2" 7" 26.0# J-55 BTC 8569' 2'/+' II :~/+' 8602" 16172' 2,00 sx Class G HF-ERW I 22. Describe proposed program: ARCO Alaska, Inc., proposes to drill a Kuparuk River Field development well to approximately 8602,'MD (6172' TVD). Selected intervals will be logged. A 20", 2000 psi annular diverter will be installed on the 16" conductor while drilling the surface hole. The 12,-5/8", 5000 psi, RSRRA BOPE stack will be installed on the 9-5/8" surface pipe. It will be tested upon installation and weekly.,:.~hereafter. Test pressure will be 3000 psig (1800 psi for annular). Expected maximum surface pressure is 2709 psi. Pressure calculations are based on virgin reservoir pressure. Surface pressure is calculated with an unexpanded gas bubble at surface, including temperature effects. Casing will be tested to 2000 psi prior to releasing the drilling rig. Non-freezing fluids will be left in uncemented annuli through the permafrost interval. 2C-16 will be 95' away from 2C-2 at 2000'MD. There are no closer wellbores anywhere downhole. Reserve pit fluids will be disposed of by pumping them down the 7" x 9-5/8" annulus of this well. The 7" x 9-5/8" annulus will be left with a non-freezing fluid during any (see attached sheet) · 23. I hereby certi~y~that the foregoing is true and correct to the best of my knowledge SIGNED ' ' TITLE Area Drilling Engineer DATE ~. The space b7 Tor~tJomyon use co.o, .o,s Samples required Mud log required Directional Survey required J APl number []YES /J~.o []YES ,,,~]NO J~YES F-INOJ 50_0%.,(~_'-L./'7..,i o Permit number Approval date ¢¢~'~q'' ., /-~~0~84, j SEECOVER LETTER FOR OTHER REQUIREMENTS APPROVED BY ......... COMMISSIONER DATE ]~O~7~m~T' ~; _~/ _ GRU2/PD12 Form 10-401 Submit in triplicate Rev. 7-1-80 Permit to Drill 2C-16 interruptions in the disposal process. The well will be completed by the workover rig using 3-1/2", 9.2#/ft, J-55, 8rd, BTC tubing. Selected intervals will be perforated within the Kuparuk formation and reported on subsequent reports. A subsurface safety valve will be installed and tested upon conclusion of the job. After the workover rig has moved off location, this well will be fracture stimulated. --i.- 'KUPAR~UK-F[ELD.l ·NORTH'S OPE~iALAS ~ ...... t ................ t .............. , .............. , .............. 'J.- ~ ............ + ....... ~ ....... t ....~ ....~ -- .; .-t .... ~ . . [ . . . ~ . ; , J : t ~ I ~,, ~, J .t..-~ .... :.,:. :-:~ . ;.;:~;:;~ ;[.; '-.. ~ ............ ~., t ..... -'~ ................. ~ .... ~ ........... ~ .... t ...... ~ . ~~~:~o~~~~.o '..' ...... : .... ..: '-:...?::: :.- .: ' -BAS~~H~STT-VD-~-~;2~D~-5~EP-299 , .... ~ : ...... :... ~.. i" ' " ff . EOC~ 1945 "D~21'39 DEP-66~" I'r'l f .... ' ..... iAV1ERA'GE! 'AN ,~ ,i, ............... t ..... · · ?nnn' ;000 ..... ~'nJFcT ~ nN ' i' ~AD:2C,:WELL NO.~'16 SE ' CUPARUK FIELD, .NORTH SLOPE, .ALASKA.-', [ASTM~N:WH PSTO6K' INO;''-.. ~ i '5 120Z'. FNL,. 42,6'-FEL .:..:, :~ SEC. 21: 'Tlt#.- 'RgE ~ ..... 4-". '(TO' TARGETi . ~" . NORTH ARCCI AL ' !NC~ ICUPARUK F! ELD. NORTH SLOPE. 4~88 287'3 REC NOV ! ...... : ...... :Alast~a Oil & Gat Cons. Commission i II,2Z 92O 393 300 I I?02 °~!n~iSSion : Surface Diverter System 1. 16"-2000 psi Tankco starting head. 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. ,,h 1 Maintenance & Operation 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. 3. 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 ANNULAll PIP~. R~ DIAGRAM ¢1 13-5/8" 5000 PSI RSRRA BOP STACK 1. 16" - 2000 psi Tankco starting head 2. ll" - 3000 psi casing heaa 3. ll" - 3000 psi x 13-5/8" - 5000 psi spacer spool 4. 13-5/B" - 5000 psi x 13-5/B" - 5000 psi drilling spool 5. 13-5/8" - 5000 psi pipe r~ms 6. 13-5/8" - 5000 psi drilling spool w/choke aha kill lines 7. 13-5/8" - 5000 psi pipe rams 8. 13-5/B" - 5000 psi :lind rams g. 13-5/8" -.5OOO psi annular BLIND ' ~.~ DRILLING SPOOl. 6 S 2 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 DOWNSTREAJ4 OF THE REGULATOR. 3. OBSERVE TIME, THEN CLOSE ALL UNITS SIMULTANEOUSLY AND RECORD THE TIME AND PRESSURE REMAINING AFTER ALL UNITS ARE CLOSED WITH CHARGING PUMP OFF. 4. RECORD ON NADC REPORT. THE ACCEPTABLE LOWER LIMIT IS 45 SECONDS CLOSING TIM£ AND 1200 PSI REMAINING PRESSURE. 13-5/8" BOP STACK TEST 1. FILL BOP STACK AND MANIFOLD WITH ARCTIC DIESEL. 2. CHECK THAT ALL HOLD DOWN SCREWS ARE FULLY RETRACT- ED. PREDETERMINE DEPTH THAT TEST PLUG WILL SEAT AND SEAT IN WELLHEAD. RUN IN LOCK DOWN SCREWS IN HEAD. 3. CLOSE ANNULAR PREVENTER AND '~.,aJ..,'V]~S UPS~ OF CHO~S. DON.~'T TEST AGAINST CLOSED CI-D~S 4. TEST ALL COMPONENTS TO 250 PSI AND HOLD'FOR 10 MINUTES. 5. INCREASE PRESSURE TO 1800 PSI AND HOLE FOR 10 MINUTES. BLEED TO ZERO PSI. . 6. OPEN ANNULAR PREVENTER AND CLOSE TOP SET OF PIPE RAMS. 7. INCREASE PRESSURE TO 3000 PSI AND HOLD FOR lO B. ~J~'PRESSURE DOWN~'I~REAM OF CI-IOI~ ISOLATION ~AL.V~S, 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 BOTTOM SET OF PI PE RAMS. 10. INCREASE PRESSURE TO 3000 PSI AND HOLD FOR 10 MINUTES BLEED TO ZERO PSI. 11. OPEN BOtg'OM 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 P,~24S 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. 15. RECORD TEST INFORMATION ON BLOWOUT PREVENTER TEST FORM SIGN AND SEND TO DRILLING SUPERVISOR. PERFORM COMPLETE BOPE TEST ONCE A WEEK AND FUNC- TIONALLY OPERATE BOPE DAILY. CHECK LIST FOR NEW WELL PSRMITS ITEM APPROVE DATE (2) Loc (,2 thru 8) (8) (3) Admin .~./;'~-,.~,'- /:''' ./"'"~./~'/ 9. (9 thru 12) 10. (10 and 12) 12. (13 thru 21) (5) BOeE //'Z// / (22 thru 26) 1. Is Company Lease & Well No. YES NO 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 wellbore plat included ..... 7. Is operator the only affected party .................... 8. Can permit be approved before ten-day wait 13. 14. 15. 16. 17. 18. 19. 20. 21. 22. 23. 24. 25. 26. 27. REMARKS Does operator have a bond in force .................................. Is a conservation order needed ...................................... Is administrative approval needed ................................... Is the lease number appropriate ..................................... Is conductor string provided ........................................ Is enough cement used to circulate on conductor and surface ......... Will cement tie in surface and intermediate or production strings ... Will cement cover all kno~ produC'tive horizons ................... Will surface casing protect fresh water zones ........... i i~ .... Will all casing give adequate safety in collapse, tension and urst. Is this well to be kicked off from an existing wellbore ............. Is old wellbore abandonment procedure included on 10-403 ............ Is adequate wellbore separation proposed ............................ ~ " Is a diverter system required ....................................... ~f Are necessary diagrams of diverter and BOP equipment attached ....... ~--~ Does BOPE have sufficient pressure rating - Test to ~,Z~'f~ psig .. ~ Does the choke manifold comply w/API RP-53 (Feb.78)..' ................ Is the presence of H2S gas probable ................................. Additional requirements ............................................. ~ Additional Remarks: 0 ~ o Geology: Engineering: LCS BEW / WVA~ JK~~ HJH ~-~ rev: 10/29/84 6. CKLT POOL INITIAL CLASS STATUS GEO. AREA UNIT NO. ON/OFF SHORE 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. RECEIVED ~: E B 0 5 1985 Alaska Oil & Gas Cons. [.~VP f~i.-'q.l','O? VF.P[FiCI~.Ti.(:k, .i,T.S"C..J_f4(; PAGE S .t:; P, V T (..' k M A :-", ~ DAME} :.PSIr) I/24 ~ { J ,'r.! T f r'; IJ A 'f' I P l'.,, g F'/i 15 F, ~! A ;,'~r'' .' f' [: f '.1.' D A T !::, .* ,,,4 A X 1 ~,' !J ~'~ f, F' Y {.; q' H ~' l I.,L. T'~' P E ,. .0() ! o24 ;'J {-~ : 2C- 16 TO':4 f,; '- ~ 1 t.:' ,qECT: 2 ! ("; iii Iv I r..:. s'.r t,T: C !"P ~': 000 000 018 065 000 000 0!4 065 000 000 0~4 065 000 000 O02 O65 000 000 004 065 OOO 000 002 065 000 000 0~2 065 000 000 006 065 000 UO0 003 065 D~,;NSSTV V ! Sc'F~5 T'!'V = ~,6?.5" ~ 47.00' '- F'IT SIZE = 8,5" TO 8405' = ,l~.c~ ~ eMF = 3,950 9 55,0 DF = l.C,.rl RMC = 2,640 ~ 61,0 DF = i'.P C3 ~ hT ~hT = 1,638 ~ t35, DF ~ SC.'~;I, liF:P,E~C;K~~ [.~,.qG$ !:~CL~.,'.DE[_~ ~'~ITH THIS ~.~AGf~ETIC TAPE: * DdAb I.~[)!~CT)[~i-~ SPh~ICALLY FDCUSED LOG (DiL) * * !J ~ 'L'/* F' L~ r," ,. ~. '1' t.,, F C r~ F. h :'J", ?YPb: $17. K ~'gP~ COi.~E 2 .i 66 0 [- 4 73 60 c. 4 65 .lin I~. .! 66 If" {_P/)FFt , !,r~.(; '.FYPF' CLASS S F 1, U r'~ j. l, r~ H ~, t,, ~) 0 22 (: 0 i 0 0 4 ILD r~ I I., f]~;~z ~i O0 12(' 4b 0 0 S P P }. f, ~ V 0 ~) 01 C 0 ] 0 0 4 GR r';] f. 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