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186-043
5035', 5060', 7639', 7764', 7896', 7999', 8027' 3731', 3749', 5603', 5700', 5804', 5886', 5908' By Anne Prysunka at 3:31 pm, Nov 15, 2022 C:\Users\kmjunke\AppData\Local\Microsoft\Windows\INetCache\Content.Outlook\99RGP1KB\2022-10-04_20246_KRU_2T-17_LeakDetectionLog_Transmittal.docx DELIVERABLE DISCRIPTION Ticket # Field Well # API # Log Description Log Date 20246 KRU 2T-17 50-103-20060-00 Leak Detection Log 04-Oct-22 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 , S UITE 308, ANCHORAGE, AK 99503 P HONE: (907)245-8951 E-MAIL : READ-Anchorage@readcasedhole.com W EBSITE : WWW.READCASEDHOLE.COM PTD:186-043 T37161 Kayla Junke Digitally signed by Kayla Junke Date: 2022.10.17 15:50:06 -08'00' C:\Users\kmjunke\AppData\Local\Microsoft\Windows\INetCache\Content.Outlook\99RGP1KB\2022-10-04_20247_KRU_2T-17_CaliperSurvey_LogData_Transmittal.docx DELIVERABLE DISCRIPTION Ticket # Field Well # API # Log Description Log Date 20247 KRU 2T-17 50-029-20060-00 Caliper Survey w/ Log Data 04-Oct-22 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 PTD:186-043 T37150 Kayla Junke Digitally signed by Kayla Junke Date: 2022.10.14 11:32:04 -08'00' ! " # " $ %& ' ()! * '$ +, !- ., +, /0 /10*- 0 2 + - " ' $ 34551 ! (4/51 30*04303. % $ 34551 (4/51 + 644 -/#*237 ,#3028#11 **1.92305(9 1(.(921./59 : ;+ '4 - *4(<.9=$ 14(0<9;$ **(59=$ *3.(9=$ *.59=$ 1*009;$ 13059;$ 1339;$ *...9=$ 30*9=$ 30/*9=$ 133(9;$ 1.09;$ 1.039;$ / >6 ' !2 < > 1" : $ ' " %& ' $ , ' (" : ? "$, ? ?)!8 @,@? '! !2 %& ! 6 % !"# 6! 6 % % *.1(#*.33430.1#30/43(#35* 131/#13**41.(<#1.(341.30#(001 A% #BA% C, A% A% #C9BC9CD$ , % B,A A% # ?!)) C A% A% # ?!)) C A% % $ ")!8"? *)' ' ': $%& *1 <0 5/1 <10 /10 5 +> /0 /10*04/10*4E/1/3<- #B ? #= " #B 0 /(< .3< <(0 /1( ;#!!% $ ' ) F $ = ; A% # ?!)) C A% A% # ?!)) C A% A% #C#B% =!%! A% $@ )! (4510 * 99 345<39=$ (4/509;$ !$@ 30 ( 99 (9=$ (9;$ @ % <4(<3 .12399 <4(*9=$ /4*.39;$ $@ )! 4.1( * 99 4..09=$ 4*1<9;$ : ' ( ) * +, $%&A: 2A: 8 : -. ' < B &00<(04 4 :..10 10#0<#/00(0#00#00 3"! ! /01 +"2 & ( 33 %,A ,A),!$? !% ;)! ==))! 0 40+451$ 06((4 0&+74$ / ! :4) 5" B " : 1 $ ! 28 " #! Steven G. Drake Digitally signed by Steven G. Drake Date: 2020.07.09 10:11:24 -08'00' By Samantha Carlisle at 10:17 am, Jul 09, 2020 SFD 7/13/2020 RBDMS HEW 7/9/2020 VTL 7/27/20 DSR-7/9/2020 ! "#$ !!$%!& $ ' "!'$ % ! () ( # "###$ ###$%!'$ *+,--./0-112+* 3/4+,-15,6 "*#'&$* +,--./0-112+**+,-788,6839:,6"*!#;$* *+,--./0-112+*5-,+-./0-112 ' * # < & % %'8,63-.1/+7==36> Last Tag Annotation Depth (ftKB) End Date Wellbore Last Mod By Last Tag: SLM 8,198.0 6/18/2019 2T-17 bworthi Last Rev Reason Annotation End Date Wellbore Last Mod By Rev Reason: Recoverd SL tool fish, set 2 PIIP Patches across C sand leaks 5/10/2020 2T-17 rogerba Casing Strings Casing Description CONDUCTOR OD (in) 16 ID (in) 15.06 Top (ftKB) 36.0 Set Depth (ftKB) 116.0 Set Depth (TVD) … 116.0 Wt/Len (l… 62.50 Grade H-40 Top Thread WELDED Casing Description SURFACE OD (in) 9 5/8 ID (in) 8.92 Top (ftKB) 33.2 Set Depth (ftKB) 3,671.4 Set Depth (TVD) … 2,797.6 Wt/Len (l… 36.00 Grade J-55 Top Thread BTC Casing Description PRODUCTION Tie Back OD (in) 7 ID (in) 6.28 Top (ftKB) 33.4 Set Depth (ftKB) 1,989.7 Set Depth (TVD) … 1,753.0 Wt/Len (l… 26.00 Grade L-80 Top Thread TCII Casing Description PRODUCTION Post WO OD (in) 7 ID (in) 6.28 Top (ftKB) 1,988.4 Set Depth (ftKB) 8,438.3 Set Depth (TVD) … 6,239.6 Wt/Len (l… 26.00 Grade J-55 Top Thread Buttress Tubing Strings Tubing Description TUBING WO String Ma… 2 7/8 ID (in) 2.44 Top (ftKB) 31.0 Set Depth (ft… 7,607.5 Set Depth (TVD) (… 5,579.6 Wt (lb/ft) 6.50 Grade L-80 Top Connection EUE-M Completion Details Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des Com Nominal ID (in) 31.0 31.0 0.03 HANGER CAMERON TUBING HANGER 2.992 485.7 485.4 5.71 NIPPLE CAMCO DS NIPPLE 2.312 7,584.0 5,561.8 40.65 SEAL ASSY LOCATOR SEAL ASSEMBLY w/ 19.35 STROKE w/ 7' Space Out 2.400 Tubing Description STACKER PACKER String Ma… 2 7/8 ID (in) 2.44 Top (ftKB) 7,598.9 Set Depth (ft… 7,759.0 Set Depth (TVD) (… 5,696.3 Wt (lb/ft) 6.50 Grade L-80 Top Connection EUE 8rd Completion Details Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des Com Nominal ID (in) 7,598.9 5,573.1 40.54 PBR 80-40 PBR 3.250 7,638.5 5,603.3 40.13 PACKER BAKER FHL PACKER 2.940 7,695.9 5,647.4 39.52 NIPPLE HES X NIPPLE 2.312 7,743.2 5,684.0 39.06 SEAL ASSY SEAL ASSEMBLY 2.500 Tubing Description TUBING Original String Ma… 2 7/8 ID (in) 2.44 Top (ftKB) 7,746.8 Set Depth (ft… 8,046.3 Set Depth (TVD) (… 5,924.0 Wt (lb/ft) 6.50 Grade J-55 Top Connection EUE8rdABMOD Completion Details Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des Com Nominal ID (in) 7,746.8 5,686.8 39.02 PBR HPT PBR 2000# SHEAR - WORKOVER COMPLETION STABBED INTO PBR 2.500 7,763.9 5,700.1 38.85 PACKER HPT 'BH' HYDRAULIC SET RETRIEVABLE PACKER 3.000 7,939.7 5,838.8 37.14 BLAST JT 2.441 8,025.6 5,907.4 36.80 SEAL ASSY LOCATOR SEAL ASSEMBLY w/CL LOCATOR 3.250 8,026.6 5,908.2 36.80 PACKER HPT 1-B PERMANENT PACKER 2.500 8,037.9 5,917.3 36.78 NIPPLE CAMCO 'D' NIPPLE 2.250 8,045.4 5,923.3 36.77 SOS CAMCO RE-ENTRY GUIDE SHEAROUT SUB 2.568 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Des Com Run Date ID (in) SN 7,896.0 5,804.0 37.38 PIIP UPPER C SAND PATCH PIIP PATCH SET @ 7896' RKB TO 7914' RKB (MID ELEMENT TO MID ELEMENT). UPPER PATCH ASSEMBLY 18.77' LONG, LOWER PACKER 3.55' LONG 5/9/2020 1.375 7,906.0 5,811.9 37.30 TUBING LEAK TUBING LEAK AT 7906' CONFIRMED W/ LDL AT 7906', LLR= 1 BPM AT 800 PSI. UNABLE TO SEE LEAK AT 8007', PREVIOUSLY IDENTIFED 10/17/11. MAY BE MASKED BY LARGE LEAK AT 7906' 8/11/2018 2.440 7,999.0 5,886.1 36.85 PIIP LOWER C SAND PATCH PIIP PATCH SET @ 7999' RKB TO 8017' RKB (MID ELEMENT TO MID ELEMENT). UPPER PATCH ASSEMBLY 18.77' LONG, LOWER PACKER 3.55' LONG 5/9/2020 1.375 8,007.0 5,892.5 36.84 TUBING LEAK LEAK CONFIRMED DURING PPROF 10/17/2011. BOTH C-SAND PRODUCTION MANDRELS LEAKING AT 7906' & 8007' W/ DMY VALVES SET 10/17/2011 2.440 8,070.0 5,943.0 36.72 FISH BOTTOM OF WEATHERFORD WRP, 1 ANCHOR, 3 ANCHOR SPRINGS 6/1/2010 0.000 8,089.0 5,958.2 36.69 FISH Lower Half of GLV Lost in Rathole from 5/13/88 8/15/1990 0.000 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft )Type Com 7,956.0 7,988.0 5,851.8 5,877.3 C-4, UNIT B, 2T -17 9/7/1986 12.0 IPERF 120° Phase 5" HyperJet II 8,095.0 8,102.0 5,963.0 5,968.6 A-4, 2T-17 9/7/1986 4.0 IPERF 90° Phase; 4" HyperJet II 8,116.0 8,147.0 5,979.9 6,004.8 A-3, 2T-17 9/7/1986 4.0 IPERF 90° Phase; 4" HyperJet II Cement Squeezes Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Des Start Date Com 33.2 1,989.7 33.2 1,753.0 CEMENT 5/18/2010 Mandrel Inserts St ati on N o/Top (ftKB) Top (TVD) (ftKB) Make Model OD (in) Serv Valve Type Latch Type Port Size (in) TRO Run (psi) Run Date Com 1 3,366.8 2,614.6 CAMCO KBMG- M 1 GAS LIFT GLV BK-5 0.019 1,246.0 12/15/2019 2T-17, 7/8/2020 1:48:31 PM Vertical schematic (actual) PRODUCTION Post WO; 1,989.7-8,438.3 IPERF; 8,116.0-8,147.0 IPERF; 8,095.0-8,102.0 FISH; 8,089.0 FISH; 8,070.0 SOS; 8,045.4 NIPPLE; 8,037.9 PACKER; 8,026.6 SEAL ASSY; 8,025.7 PIIP LOWER C SAND PATCH; 7,999.0 TUBING LEAK; 8,007.0 PRODUCTION; 8,003.7 IPERF; 7,956.0-7,988.0 TUBING LEAK; 7,906.0 PRODUCTION; 7,901.6 PIIP UPPER C SAND PATCH; 7,896.0 PRODUCTION; 7,832.3 TUBING; 7,770.3 PACKER; 7,763.9 PBR; 7,746.8 SEAL ASSY; 7,743.2 NIPPLE; 7,695.9 PACKER; 7,638.5 PBR; 7,598.9 SEAL ASSY; 7,584.0 GAS LIFT; 7,528.9 GAS LIFT; 7,023.1 GAS LIFT; 6,132.8 GAS LIFT; 5,022.8 SURFACE; 33.2-3,671.4 GAS LIFT; 3,366.8 PRODUCTION Tie Back; 33.4- 1,989.7 CEMENT; 33.2 ftKB NIPPLE; 485.7 CONDUCTOR; 36.0-116.0 HANGER; 31.0 KUP PROD KB-Grd (ft) 42.00 Rig Release Date 3/10/1986 2T-17 ... TD Act Btm (ftKB) 8,445.0 Well Attributes Field Name KUPARUK RIVER UNIT Wellbore API/UWI 501032006000 Wellbore Status PROD Max Angle & MD Incl (°) 53.50 MD (ftKB) 3,800.00 WELLNAME WELLBORE2T-17 Annotation Last WO: End Date 5/18/2010 H2S (ppm) 25 Date 12/19/2017 Comment SSSV: NIPPLE Mandrel Inserts St ati on N o/Top (ftKB) Top (TVD) (ftKB) Make Model OD (in) Serv Valve Type Latch Type Port Size (in) TRO Run (psi) Run Date Com 2 5,022.8 3,721.9 CAMCO KBMG- M 1 GAS LIFT OV BK 0.250 0.0 12/14/2019 3 6,132.8 4,517.2 CAMCO KBMG- M 1 GAS LIFT DMY BK-5 0.000 0.0 5/18/2010 4 7,023.1 5,150.1 CAMCO KBMG- M 1 GAS LIFT DMY BK-5 0.000 0.0 5/18/2010 5 7,528.9 5,520.1 CAMCO KBMG- M 1 GAS LIFT DMY BK-5 0.000 0.0 9/24/2018 6 7,832.3 5,753.6 CAMCO KBMG 1 PROD DMY BK 0.000 0.0 4/28/1995 7 7,901.6 5,808.4 CAMCO KBMG 1 PROD DMY BK 0.000 0.0 8/11/2018 Exten ded Packi ng DMY Valve 8 8,003.7 5,889.9 CAMCO KBMG 1 PROD DMY BK 0.000 0.0 4/26/1995 Notes: General & Safety End Date Annotation 5/19/2010 NOTE: View Schematic w/ Alaska Schematic9.0 5/18/2010 NOTE: *** SURFACE ANNULUS CEMENTED FROM 1989.7' TO SURFACE 2T-17, 7/8/2020 1:48:32 PM Vertical schematic (actual) PRODUCTION Post WO; 1,989.7-8,438.3 IPERF; 8,116.0-8,147.0 IPERF; 8,095.0-8,102.0 FISH; 8,089.0 FISH; 8,070.0 SOS; 8,045.4 NIPPLE; 8,037.9 PACKER; 8,026.6 SEAL ASSY; 8,025.7 PIIP LOWER C SAND PATCH; 7,999.0 TUBING LEAK; 8,007.0 PRODUCTION; 8,003.7 IPERF; 7,956.0-7,988.0 TUBING LEAK; 7,906.0 PRODUCTION; 7,901.6 PIIP UPPER C SAND PATCH; 7,896.0 PRODUCTION; 7,832.3 TUBING; 7,770.3 PACKER; 7,763.9 PBR; 7,746.8 SEAL ASSY; 7,743.2 NIPPLE; 7,695.9 PACKER; 7,638.5 PBR; 7,598.9 SEAL ASSY; 7,584.0 GAS LIFT; 7,528.9 GAS LIFT; 7,023.1 GAS LIFT; 6,132.8 GAS LIFT; 5,022.8 SURFACE; 33.2-3,671.4 GAS LIFT; 3,366.8 PRODUCTION Tie Back; 33.4- 1,989.7 CEMENT; 33.2 ftKB NIPPLE; 485.7 CONDUCTOR; 36.0-116.0 HANGER; 31.0 KUP PROD 2T-17 ... WELLNAME WELLBORE2T-17 Image Project Well History File Cover Page XHVZE This page identifies those items that were not scanned during the initial production scanning. They are available in the original file, may be scanned during the rescan activity or are viewable by direct inspection of the file. j ~- ¢~_ Well History File Identifier Organization (do.e) RESCAN Color items: Grayscale items: [] Poor Quality Originals: Other: DIGITAL DATA [] Diskettes. No. [] Other. No/Type TOTAL PAGES: 6 ~),, NOTES: ORGA.,ZEDSV: ~;~Y')BRE. V,.OENT S.ERV' MAR~ LOWELL Project Proofing OVERSIZED (Scannable) D Maps: Other items scannable by large scanner OVERSIZED (Non-Scannable) Logs of vadous kinds [] Other By: Date: PROOFED BY: BEVERLY BREN VINCENT SHERYL MARIA LOWELL DATE: Is~ PAGES: ~ ~ the time of scanning) SCANNED BY: BEVERLY BREN VINCE~~ARIA LOWELL RESCANNEDBY-' BEVERLY BREN VINCENT SHERYL MARIA LOWELL General Notes or Comments about this file: / O/ /7'/O''~-- DATE: /SI Quality Checked (done) RevlNOTScenned.wpd STATE OF ALASKA ALASKA AND GAS CONSERVATION COMMIS~I REPORT OF SUNDRY WELL OPERATIONS 1. Operations Pertormed: Abandon ~`"` Repair w ell ~ Plug Perforations ~ Stimulate Other ARer Casing ~ Pull Tubing ~' Perforate New Pbol "` Waiver ~ Time Extension Change Approved Program ""', Operat. Shutdow n ~ Perforate Re-enter Suspended Well ~° 2. Operator Name: 4. Current Well Status: Permit to Drill Number: ConocoPhillips Alaska, Inc. Development ~ Exploratory ~ 186-043 3. Address: - ~. API Number: P. O. Box 100360, Anchora e, Alaska 99510 Stratigraphic r Service ~` 50-103-20060-00 7. Property Designation 8. Well Name and Nurrlber: ~ ADL 25569 2T-17 9. Field/Pool(s): ~ Kuparuk River Field /Kuparuk River Oil Pool 10. Present Well Condition Summary: Total Depth measured 8445 feet Plugs (measured) 7817 true vertical 6245 feet Junk (measured) 8089 Effective Depth measured 8248 feet Packer (measured) 7638, 7764, 8027 true vertical 6084 feet (true vertucal) 5603, 5700, 5908 Casing Length Size MD TVD Burst Collapse CONDUCTOR 80 16 116 116 SURFACE 3671 9.625 3671 2797 PRODUCTION 8438 7 8438 6239 R~~~IVED .,Perforation depth: Measured depth: 7956'-7988', 8095'-8102', 8116'-8147 ~ ~.~ ~ ~ ~. ~ a 1 Q True Vertical Depth: 5852'-5877', 5963'-5969', 5980'-6005' Alawak~ Qill ~ Gas Gttti~, Gr~mmission Ah+~h~rl~~~ Tubing (size, grade, MD, and TVD) 2.875, L-80, 7608 MD, 5923 TVD Packers 8 SSSV (type, MD, and TVD) PACKER -BAKER FHL PACKER @ 7638 MD and 5603 TVD PACKER - HPT'BH' HYDRAULIC SET RETRIEVABLE PACKER @ 7764 MD and 5700 TVD PACKER - HPT 1-B PERMANENT PACKER @ 8027 MD and 5908 TVD NIPPLE - 2.312" CAMCO "DS" Nipple @ 486 MD and 485 TVD 11. Stimulation or cement squeeze summary: Intervals treated (measured): not applicable 4 , ,- .~1 ~~~~+ ~ l j ~ '~" ~`~ " " ~ ! ~ ` '"'`' ` "' Treatment descriptions including volumes used and final pressure: ~'~'` 12. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation si Subsequent to operation si 13. Attachments Well Class after proposed work: Copies of Logs and Surveys run Exploratory Development )~ Service Well Status after work: Oil Gas WDSPL Daily Report of Well Operations XXX GSTOR WAG ~"" GASINJ ~ WINJ SPLUG 16. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or NIA if C.O. Exempt: 310-103 Contact J. Brett Packer (a)_ 265-6845 Printed Name J. B tt Packer Title Wells Engineer Phone: 265-6845 Date ~ /~~ ` -- ~ ~? Si t ~ ~ ~ ~ ,~ ure . gna L~,.M. /'2 ~ / Form 10-404 Revised 7/2009 R$~S 1~N ~ ~, ~ 7 ~9~° Submit Original Only Cc~nnc~cc~Phillips nl.~SfiiS, it q,;. _ _.WZI1C fig_2T; 176/26/, _ ___. Scirerliatc-Ac HANGER, 31 - CONDUCTOR,- 36116 NIPPLE. 486- PROOUCrION re Bari, - 33-1,990 GAS LIFT, 3,36] SURFACE,_ 33-3,6]1 GAS LIFT, 5.023 GAS LIFE, _ 6.133 GAS LIFT, ],023 GAS LIFT. 7 529 SEAL ASSV, 7.584 PBR. 7,599 PACKER. ].636 NIPPLE.I,s96 '':.,~ SEAL ASSV, -_ PBR, ],]4] - } y -- PACKER 7,]64 --- TUBING, ],I10~ ~~-~ ~~ CATCHER, 7,800 PLUG. 7,817 - --- PRODUCTION, ~--'' 7,832 '; PROOUCnoN, w 7,902 IPERF_ __ ~~ ],956-7,588 PRODUCTION, 8,004 SEAL ASSY,_ . -~ 8,626 __ PACKER. 8,027 -- NIPPLE. 8,038-- ~,__ SOS. B.WS '~ FISH. 8.089 -- -~ IPERF, 8,095-8,102 IPERF, _ _. -_ 8,116-8,14] I PRODUCTION Ly Pos[WO,-\\~-J,, 1,9908,438 TD. 8,445 KU P ~ 2T-17 Well Attributes Max Angle 8 MD TD WellboreAPIlUW1 Field Name Well Status lncl (°) MD (HKB) _- Act Btm (ftKB) 501032006000 I i KUPARUK RIVER UNIT PROD 5350 3,800.00 8445.0 Comment IH25 (ppm) iDate Annotation Entl Date KB-Grtl (H) Rig Release Date SSSV.- NIPPLE ~ 30 j 1/11/2009 ..(Last WO: I 5/18/2010 4200 3/10/1986 Annotation (Depth (ftKB) End Date End Date Annotation Last Mod... Last Tag: SLM 327.0 i 7/7/2009 / Rev Reason: GLV C!O Imosbor 5/26;201.0_ Casinnn~Strin s Casing Description String 0... String ID ... Top (ftKB) Set Depth (L.. Set Depth (ND) ... String W[... String ... (String Top Thrd CONDUCTOR 16 15 062 36.0 116.0 116.0 62.50 H-40 Casing Description String 0... String ID ._ Top (HKB) Set Depth (f... Set Depih (ND) ... String W[... String ... String Top Thrd SURFACE 95/8 8.765 33.2 3,671.4 27975 36.00 J_-55 BTC Casing Description String 0... String ID ... Top (HKB) Set Depih (f... Set Depth (ND) ... String Wt... Str g ... String Top Thrd PRODUCTION 7 ~ 6.276 33.4 1,989.7 1753.0 26.00 L-80 TCII Tle Back Casing Des Iptlon Str g 0... String ID ... Top (HKB) Set Depth (f... Sat Depth (ND) ... String Wt... Str g .. Sfing Top Thrd PRODUCTION 7 6.151 1,988.4 8,438.3 6,239.6 26.00 J 55 Buttress Post WO . _. Tubing Strings -~. _._.- __ Tubing Des ptlon __ String 0... String ID ... _ Top (ftKB) Set D pth (i... Set Depth (ND) _. String Wl... Str ng ._ Siring Top Thrd TUBING WO 2 7/8 2.441 31.0 7,607 5 5,580.1 6.50 I L-80 EUE-M Completion De tails Top Depth (NDJ Top Inc! Nomi... Top (HKB) (ftKB) (°) Item Description Comment __ _ _ I ID (in) 31.0 31.0 '1 -0.06 HANGER CAMERON Tubing Hanger i 2.992 485.7 485.4 5.93 NIPPLE 2.312" CAMCO "DS" Nipple _ 2.312 7,584.0 5,561.8 40.70 SEAL ASSY Seal Assembly Locator w719.35'stroke w(T Space Out 2.400 ~ Tubing Description '. String O ._ String ID _.. String Wf...Str ng ... Top (ftKB) SeI Depih (f...Set Depth (ND1 . - . (String Top Thrd STACKER PACKER 3.668 2.441 I I 7,598.9 7,759.0 5,696.3 6 SO J L 80 EUE 8rd Completion De tails _ ~'. Top Dep[h (ND) Top Inc! Nomi... Top (ftKB) (ftKB) (°) Item Description Comment ID GN 7,598.9 5,573.1 40.54 PBR 80A0 PBR 3.250 7,638.5 5,6035 4008PACKER Baker FHL Packer 2.940 7,695.9 5,6474 1 39.52 NIPPLE ~ 2.312" HES "X" Nipple EUE 8rd w/RHC Plug "G-Fishing Neck" 2312 7,743.2 5,684.1 ', 39.06 SEAL ASSY SEAL ASSEMBLY 2.500 Tubing Description St g 0... Str ng ID ... Top (HKB) Set Depth (f... Set Depth (ND) . Str ng Wt... String String Top Thrtl I ~ EUESrdABMOD I 8046.3 I. 5,924.1 __ ~ 6.50 J55 , 2441 1 7,7468 TUBING Original 27/8 .._ _ Completion Details - -- Top Depth (ND) Top Inc! Nomi... T`p (ftKB) (HKB) (°) Item Description Commenl ID (in) 7,746.8 5.686.9 39.02 PBR HPT PBR 2000# SHEAR - WORKOVER COMPLETION STABBED INTO 2.500 PBR 7,763.9 5,700.1 38.SS ,PACKER HPT'BH' HYDRAULIC SET RETRIEVABLE PABKE 3.000 7,939.7 5,838.8 37.14 BLAST JT ~ - 2.441 8,025.6 5,907.7 ~ 37.00 SEAL ASSY LOCATOR SEAL ASSEMBLY w/CL LOCATOR 3.250 8,026.71 5,9084 1 36.99 PACKER HPT 1-B PERMANENT PACKER 2.500 8,037.9 ' 5,9174 1 36.94 NIPPLE ICAMCO'D'NIPPLE ---- 2.250 8,045.41 5,923.4 36.91 SOS _. CAMCO RE-ENTRY GUIDE SHEAROUT SUB -_ __- 2.568 I Other I ! i n Hole (W irelin _.____-.-.. e retrievable plugs, valves, pumps, fish, etc.) _ ___ -~ , _ Top Depih' ____ _ ' (TVD) lop Inc! T o p (HKBJ (HKB) (°) Description Comment _ Run Date ID (in) _ _ 7,800 5,728.3 38.50 CATCHER CATCHER SET ON TOP OF WRP (OAL=T) 4/29/2010 0.000 7,817 5,741.5 37J3 PLUG WEATHERFORD WRP PRE-TUBING CUT 4/29/2010 0-000 8,089 5.958.2 36 72 FISH Lower Half of GLV Lost in Rathole from 5/13/88 8/15/1990 Perfora tions & Slots Shot Top (TVD) etm (ND) I Dens Top (ftKB) Bim (ftKB) (ftKB) (HKB) Zone Date (sh Type Commeld 7,956 7 988 5 851.8 5,877.3 C~4, UNIT B, 9/7/1986 12.0 IPERF 120 deg Phase 5" Hype rJet II 2T-17 R DQS R 7f17 S Qfi'i H S QfiR fi All 7T-17 9!7l19R6 1 4.01 1PERF 90 ilea. Phase' 4" HvnerJe[ II 7/7/2009 NOTE TAG 32T (ND) Inc! i OD V I e 1 Latch I Size TRO Run Stn Top (ftKB) (HKB) (') , Make Model (in) Sarv Typ '. ~ Type (in) (psi) RunD te_ Com... 1 3,366.8] 2,6146 53.20 CAMCO KBMG-M 1' GAS LIFT GLV BK-5 1 0.188 1 2460 5/25/2010 2 5,022.8' 3,721.0 41.52 CAMCO KBMG-M 1 GAS LIFT OV BK-5 0.250 0 0 5/25/2010 I __ 3 _.. 6,132.8 4,517 4 I 45.92. CAMCO KBMG-M 1 _.. GAS LIFT DMY BK-5 0.000 0.0 __ 5118/2010 . .._. 4 __. 7,023.1 5,150.2 I 44.03 'CAMCO KBMG-M 1 _ GAS LIFT DMY ___. BK-5 .. 0.000 _ 0.0 5/18/2010 5 7,528.9 5,520.5 41.28 CAMCO KBMG-M 1 GAS LIFT DMY 8K-S 0.000, 0.0 5/25/2010 6 7 832.3 5,753.5 37.65 CAMCO KBMG 1 PROD DMY BK 0.0001 , 0.0 4/28/1995 7 7,901.6 5,808 4 37.32 CAMCO KBMG 1 PROD DMY BK 1 0.000 0.0 4/28/1995 8 8003J, 5,890.2 37.09 CAMCO KBMG - 11 PROD DMY I BK 10.000 0.0 4/26!1995 i • Time Log & Summary ConocoPhitlips iNe/Iview Web ReAOning r1 e ~ O Well Name:. 2T-17 Rig Name: NORDIC 3 Job Type: RECOMPLETION Rig Accept: 4/27/2010 2:00:00 PM Rig Release: 5/19/2010 3:00:00 PM Time Lo s Date From To Dur S. De th E. De th Pha e Code Subcode T Comment 4/27!2010 24 hr Summary Move rig to 2T-17, Accept rig @ 14:00 hrs on 4-27-10. Rig on Hi Line power at 1800 HRS. Load pits. Rig up and bleed IA and tbg pressures to kill tank. Continue pump 9.6 PPG brine to load the hole down the annulus 3 BPM. Bullhead 20 BBLS of brine down tb 2 BPM 10:00 10:30 0.50 COMPZ MOVE DMOB P Move Nordic Rig 3 to 2T-17 10:30 13:30 3.00 COMPZ MOVE OTHR P Change out Shaffer 11" 5M double ate BOP for H dril 11" 5M 13:30 14:30 1.00 COMPZ MOVE MOB P Load New 2 9/16" 5M CIW Tree in cellar and pull over and set down. Acce t ri 14:00 hrs on 4-27-10 14:30 16:00 1.50 COMPZ MOVE PSIT P Berm up and spot auxiliary equipment. Load pits w/ 9.6 ppg Brine. 16:00 17:30 1.50 COMPZ WELCTL MPSP P Load lubricator in pipe shed, Lubricate out BPV, Lay down and offload lubricator. 17:30 18:30 1.00 COMPZ WELCTL RURD P Rig up lines to kill well. Pressure test same to 3500 PSI. 18:30 19:00 0.50 COMPZ WELCTL SFTY P Held PJSM with crew & mud engineer. Discuss safety & hazard recognitioj issues. Discuss rocedure to kill well. 19:00 20:00 1.00 COMPZ WELCTL KLWL P Load rig with 290 BBLS more of 9.6 Brine. Contact Security, and DSO for as ventin o s. 20:00 23:00 3.00 COMPZ WELCTL KLWL P IA initial pressure = 510 PS. Bleed pressure through choke to kill tank to 20 PSI. Tubing pressure initial = 1550 PSI. Bleed pressure to kill tank to level off at 360 PSI. Pump down IA at 3 BPM with pressure to 3150 PSI observing after 195 BBLS punped, fluid returns to surface. Returns included diesel and brine mixed. Continue pumping to achieve full circulation through OV at 5141'. FCP on annulus = 1550 PSI. Pump down tubing at 3 BPM bullheading 20 BBLS. 23:00 00:00 1.00 COMPZ WELCTL KLWL P Blow down kill lines to kill tank. RU to circulate through Poorboy degasser to the pits. Load last of 9.6 Brine on location - 270 BBLS. Page 1 of 25 l ~ Time Lo s Date From To Dur S. De th E. De th Phase Code Subcode T Comment 4/28/2010 24 hr Summary Continue circulating down tubing observing no returns at 3 BPM. Pump 40 BBLS. Pump down IA at 3 BPM observing returns, and losses up to 96 BBLS / HR while pumping. Shut down pumps after 160 BBLS down annulus and 82 BBLS down tbg. 62 BBLS of 9.6 ppg brine into the formation. Open up well, tbg on a vaccuum, annulus dead. Instal CIW HP BPV. ND Tree, inspect lift threads. Install test dart. Pressure ion CL to open SSSV, and hold pressure installiong a needle valve on the OD of the hanger. Bull head 290 BBLS down the IA at 3 BPM - 2800 PSI. NU BOP stack. Test BOP's. Observed trouble with hydraulic lines on upper rams. Replaced same. Witness of test waived by AOGCC rep John Crisp. RD test equipment. Chnage out To drive saver sub. Fluid losses while fillip IA = 40 BPH. Total Fluid loss for the = 00:00 02:00 2.00 COMPZ WELCTL KLWL P Continue circulating down tubing observing no returns at 3 BPM. Pump 40 BBLS. Pump down IA at 3 BPM observing returns, and losses up to 96 BBLS / HR while pumping. Shut down pumps after 160 BBLS pumped. Pump down tbg 82 BBLS @ 3 BPM -little or no returns. Shut down um s. 02:00 02:30 0.50 COMPZ WELCTL OWFF P Monitor well. O en tubin u veri in well on a vaccuum. Annulus dead. 02:30 03:00 0.50 COMPZ WELCTL OTHR P Install Cameron HB Plug as per CIW re . 03:00 08:00 5.00 COMPZ RPEOPI NUND P Nipple down tree. Attempt to load annulus after one hour. Well took 3 BBLS. 08:00 09:30 1.50 COMPZ RPEQPI KLWL P Bullhead 290 bbls down IA at 2-3 BPM - 2800 PSI. 09:30 14:00 4.50 COMPZ RPEOPI NUND P Ni le u BOP stack & Install 2 7/8" rams in upper set of double gates. Continuous fill IA with losses at 40 BBLS / HR. 14:00 22:30 8.50 COMPZ RPEOPI BOPE P Test BOP's. Test choke manifold and all valves. Test upper, lower rams and annular to 2 7/8" and 3 1/2" test jnts. Test all rig floor safety valves. Perform Accumulator test with first 200 PSI in 17 ses, with fu113000 PSI in 80 secs. 4 nitrogen bottles with avg PSI of 2300. Observed failure in hydraulic line to upper rams. Replaced same. Witness of test waived b AOGCC re John Cris . 22:30 23:00 0.50 COMPZ RPEOPI RURD P Rig down all test equipment. Clean & clear ri floor area and cellar. 23:00 00:00 1.00 COMPZ RPEQPI SVRG P Held PJSM with crew. Discuss safety & hazard recognition issues. Discuss procedure to change out saver sub. Change out saver sub. Total fluiid losses for the day = 657 BBLS. Avg fluid losses = 40 BBLS / HR. Page 2 of 25' r~ • Time Lo s Date From To Dur S. De th E. De th Phase Gode Subcode T Comment /29/2010 24 hr Summary Change out Grabber dies on TD. MU DP pups with crossover to make up in hanger. Observed approximately 2 inches growth with top drive set down weight of 15K. Pull up to 85K, observing free movement, indicating seals coming out of PBR. Stop, set slips with 85K tension. RU HES Slickliners with Lubricator. WLIH with 2.250' LIB to 7850'. MU and WLIH to set WRP @ 7817' WLM. MU and WLIH with catcher sub to set at 7810' WLM. Attempt to WLIH with SSSV locking sleeve. No go past the drill pipe pups. Lay down same, re-attempt run with no success, as assembly wouldn't go past hanger. RD HES slickline. RU to pull completion string. Release 5K pressure on control line. Note: past slickline runs indicated SSSV stuck open. Decisiion to POOH without settin lockin sleeve. 00:00 00:30 0.50 COMPZ RPEQPI SVRG P Change out Grabber dies on Top Drive. 00:30 01:30 1.00 COMPZ RPEQPI OTHR P Pull HP BPV. Observed a liitle gas under the valve but bled off in a few minutes. Fluid fallin in stack. 01:30 02:00 0.50 COMPZ RPEQPI PUTB P Make up Drill pipe pup joints 20', 6' 10' with crossover to hanger. Screw into To drive. Set down 15K. 02:00 02:30 0.50 COMPZ RPEQPI PUTB P BOLDS ,observed approximately 2 inches growth in string. Pull slowly to up wei ht of 35K TD WT 3', then continue to up weight of 87K observing movement in string suspecting seals puilling from PBR. Sto with 85K, set in sli s. 02:30 03:00 0.50 COMPZ RPEQPI CIRC P Circulated down tbg string 65 BBLS, and filled annulus. Observed minimal gas breaking out on surface. Pump rate 3 BBLS /Min. 740 PSI. 03:00 03:30 0.50 COMPZ RPEQPI SFTY P PJSM with HES Slick line crew and ri crew. 03:30 07:00 3.50 COMPZ RPEQPI RURD P Pull tools to floor, with HES slicline crew spotted on location. Make up crossover & pump in sub. Continue rig up slickline crew with lubricator. Continuously fill hole across the top with losses observed at 20 BBLS / H R. 07:00 07:30 0.50 COMPZ RPEQPI SLKL T RIH w/ 2.25" OD drift and was unable to ast 3' below rota floor. 07:30 08:30 1.00 COMPZ RPEQPI OTHR T Break out TIW valve and pump in sub. look down 3 1/2 DP pup jts. 20' pup jt had a 2.25" ID. Gather equipment to Change out to 3 1/2 8rd landin 't. 08:30 09:00 0.50 COMPZ RPEQPI CIRC T Pump TBG volume @ 4 bpm @ 1,200 si. 09:00 10:30 1.50 COMPZ RPEQPI PULD T Pull hanger to rig floor and change out 3 1/2 DP pup jts with 3 1/2 8rd landingtjt. RIH and attempt to stab seals -not successful. Pull hanger back to rig floor and lay down landing ~t. RU to RIH w/ 2.25" LIB. 10:30 12:30 2.00 COMPZ RPEQPI SLKL T Make up 2.25" OD LIB and RIH and set down @ 7,743'. POOH and LIB _ showed top of PBR. Hang back slick line and prepare to PU 3 1/2 8rd Landin ~t. Page 3 of 25 Time Lo s Date Fram To Dur S. De th E. De th Phase Code Subcode T Comment 12:30 13:00 0.50 COMPZ RPEQPI PULD T MU 3 1/2 8rd landing jt and tag top of PBR. Rotate 3/4 of turn and fell in - RIH and Tag up, PU to string wt of 75k w/ 20' of landin 't in. 13:00 13:30 0.50 COMPZ RPEQPI OTHR T MU Slick line lubricator to TIW valve and um in sub. 13:30 14:30 1.00 COMPZ RPEQPI SLKL P RIH w/ 2.25" LIB w/ 2.28" OD x 60" Centralizer sub to 7,834' -POOH for WRP. 14:30 20:30 6.00 COMPZ RPEQPI MPSP P MU and RIH w/ Weatherford 2.25" OD WRP and RIH to 7,817' SLM. Wait for timing firehead to go off. Indication with slickline are that the plug is set. Indications form fluid losses verified. O losses after plug set. POOH and PU catcher sub and RIH.to set at 7810' WLM. 20:30 23:00 2.50 COMPZ RPEQPI SLKL P MU and attem t to run SSSV to k~i~a sleeve._Could not get past drill pipe pups. Pull hanger to floor and attempt to get tools through the hanger, with no success. RD HES slickline crew. Decision to POOH. Note: Past records indicated that the SSSV was stuck in the open osition. 23:00 23:30 0.50 COMPZ RPEQPI PUTB P 5K pressure bled form the control line Breakout & lay down hanger & u . RU control lines ool. 23:30 23:45 0.25 COMPZ RPEQPI SFTY P Held PJSM with crew & Schlumberger rep. Discuss safety & hazrd recognition issues. Discuss procedure to POOH laying down 2 7/8" tb with CL. 23:45 00:00 0.25 COMPZ RPEQPI PUTB P POOH laying down 2 7/8" tbg & control Iine.Total fluid losses for the day = 482 BBLS. Total for well = 1139 BBLS 4/30/2010 Continue POOH laying down 2 7/8" tbg and CL, Recovered 31 SS Bands. Laid down a total of 245 jnts, SSSV, 7 - GLM's and Seal assembly. MU & Run BHA #1, bit & scraper assembly to tag at 283'. POOH. Lay down Bit. RIH with cling scrape ron DP only to tag PBR @ 7736' DPM. Reverse circulate Hi Visc sweep until clean 4 BPM - 720 PSI. 00:00 11:00 11.00 COMPZ RPEQPI PUTB P Continue lay down 2 7/8" tbg and CL. recovered all 31 SS Bands originally run. Laid down a total of 245 joints of tbg, and 7 GLMs with the seal assembl . 11:00 14:30 3.50 0 0 COMPZ RPEQPI PULD P Clean and prep floorfor upcoming scraper run. Load and make up scra er runnin BHA. 14:30 15:30 1.00 0 283 COMPZ RPEQPI TRIP P RIH with 7" casing scraper, bit sub, bumper jars, and DC's. Stacked out at 283'. 15:30 16:30 1.00 283 0 COMPZ RPEOPI TRIP P POOH with scraper BHA. Lay down Bit & rack back DC's. Page 4 of 25 r~ • Time Lo s Date From To Dur S. De th E. De th Phase Code Subcade T Comment .16:30 17:00 0.50 0 0 COMPZ RPCOM PULD P Rack back DC's. MU and rack back remaining DC's while waiting for e-line. 17:00 22:00 5.00 0 7,736 COMPZ RPCOM TRIP P MU BHA #2, Scraper assembly with drill pipe only. RIH with no issues through 283', continuing to in hole to tga PBR lightly at 7736' DPM. UP WT = 145K, SO WT = 76K. 22:00 00:00 2.00 7,725 7,725 COMPZ RPCOM CIRC P Reverse circulate Hi Visc sweep at 4 BPM - 720 PSI. 5/01 /2010 Continue reverse circulate sweep. POOH with BHA #2. Lay down Scraper. Held PJSM. RU HES wireline crew. MU and run 40 arm caliper log. Log from 7730 to surface. MU & run CBL Fast Cast Log. Logs indicated top of cement to be at 2050'. Make up and run Gyro assembly. Observed trouble with communications to tools. Trouble shoot assembl .Fluid loss - 0 BBLS. Total losses for the well - 2161 BBLS. 00:00 00:15 0.25 7,725 7,725 COMPZ RPEQPI CIRC P Flnish Circulating. Blow down Top Drive & lines. 00:15 04:45 4.50 7,725 0 COMPZ RPEOPI TRIP P POOH with BHA #2. Breakout & lay down scra er assembl . 04:45 05:15 0.50 0 0 COMPZ RPEQPI SFTY P Held PJSM with crew &HES wireline crew. Discuss safety & hazard recognition issues. Discuss procedure to RU and run logging tools. 05:15 05:45 0.50 0 0 COMPZ RPEQPI PRTS P PT WRP to 1500#. All good. 05:45 07:30 1.75 0 0 COMPZ RPEQPI ELOG P Rig up HES a-line unit utilizing the shootin ni le. 07:30 13:00 5.50 0 0 COMPZ RPEQPI ELOG P Begin RIH with 40-arm caliper. Log from 7730' to surface at 40 fpm. At 4400' tool quit working. Had to close arms and RBIH for several feet to create an overlap for splicing ur oses. 13:00 18:00 5.00 0 0 COMPZ RPEQPI ELOG P Swap to run CBL (FAST-CAST). Log from 7730' to surface. WLOH Lay down Tools. 18:00 20:00 2.00 0 0 COMPZ RPEQPI ELOG P MU Gyro Assembly &WLIH. Observed trouble with new tool, communications, POOH 20:00 00:00 4.00 0 0 COMPZ RPEQPI ELOG T Troubleshoot issues with communication on Gyro tool assembly. Swap out CCL, and com uters. 5/02/2010 Continue trouble shoot GYRO assembly problems. Change out entire tools string. WLIH to log from 7350'. WLOH breakout & lay down tools. MU &WLIH with 240 grain string shot to locate & fire on collar at 1981'. WLOH, RD HES wireline crew. MU BOT IBP ,and RIH to locate & set IBP at 2598' DPM. Pressure test same to 3000 PSI. DUmp 23 sacks of mason sand. Puill up wait and retag at 2530'. (57') POOH. MU 4 3/4" DC;s RIH could not get past 389'. POOH. MU 3 1/2" DP, RIH to 2388. MU Storm valve, a\nd set at 101'. PT same to 1500 PSI. Held PJSM. ND BOP's and work on tubing head bolts for removal and installation of long thread bolts. Fluid losses toda = 0 BBLS. 00:00 02:30 2.50 0 0 COMPZ RPEQPI ELOG T Continue trouble shoot GYRO tool assembly. Change out entire tools string. Test same, and initialize. Good test. 02:30 06:30 4.00 0 0 COMPZ RPEQPI ELOG P WLIH with GYRO assembly logging from .Page 5 of 25 Time Lo s Date From To Dur S. De th E. De th Phase Code Subcode T Comment 06:30 08:00 1.50 0 0 COMPZ RPEQPI ELOG P WLIH with 5' of 240 grain stringshot. Fire across collar at 1989'. 08:00 08:30 0.50 0 0 COMPZ RPEQPI PULD P Rig down a-line and begin making up BOT's IBP. 08:30 09:30 1.00 0 2,598 COMPZ RPEQPI TRIP P TIH with BHA #3 (IBP). 09:30 11:00 1.50 2,598 2,598 COMPZ RPEQPI MPSP P TIH to 2598' (bottom of plug). Drop ball and circulate until on seat. Slowly step pressure up in 200 psi increments. Setting tool sheared @ 2150 psi and set IBP at 2598'. Pick up off of IBP and PT plug to 3000#. All ood. 11:00 12:15 1.25 2,598 0 COMPZ RPEQPI TRIP P TOOH with setting tool. 12:15 13:30 1.25 0 2,514 COMPZ RPEQPI TRIP P TIH with BHA #4. Pull Setting tool and replace with mule shoe for sand lacement. 13:30 14:30 1.00 2,514 2,514 COMPZ RPEQPI CIRC P Circ out 9.6 ppg brine with clean SW at 4 BPM. 14:30 17:00 2.50 2,514 2,514 COMPZ RPEQPI OTHR P Begin dumping 23 sacks of mason sand on top of IBP. Complete dumping sand on IBP. Wait 1 hour for sand to fall/settle before trying to to TOS. 17:00 17:15 0.25 2,514 2,530 COMPZ RPEQPI OTHR P Tag TOS @ 2530' DPM. Estimate 57' of sand on to of IBP. 17:15 18:00 0.75 2,530 0 COMPZ RPEQPI TRIP P TOOH for swap over to DC's and storm acker. 18:00 20:00 2.00 0 389 COMPZ RPEQPI TRIP P Pick up 8 DC's, and continue RIH with 4 3/4" DC to tag up at 292'. DPM. Attempt to work through tight s of to 389'. Could not o further. 20:00 20:30 0.50 389 0 COMPZ RPEQPI TRIP P POOH racking back DC"s. from 389'. 20:30 22:30 2.00 0 0 COMPZ RPEQPI TRIP P Trip in hole with Bullnose & DP to make up and set BOT storm valve at 101', with Bullnose at 2388' for a total of 28K han in on casin .Test casin to 1500 PSI - ood test. 22:30 23:00 0.50 0 0 COMPZ RPEQPI SFTY P Held PJSM with crew & Cameron Wellhead reps. Discuss sagety & hazard recognition issues. Discuss procedure to ND BOP's and install long thread bolts on wellhead for casin ex ansion. 23:00 00:00 1.00 0 0 COMPZ RPEQPI NUND P Nipple down flow riser. Continue work on tbg head bolts for installation of Ion thread bolts. 5/03/2010 Continue work on tbg head bolts installing long threads for casing expansion. Continue loosen long thread bolts to allow 7" caing to grow a total of 26". Set back BOP's. Make a cut on the 7" casing with the WACHS cutter. MU Spear, RIH to engage casing and pull stretch only to 90K up weight or 1 foot of movement. . Observed emergency slips loacated at a casing collar, not allowing for a full 150K pull. NU BOP stack, & lines. Chna a out lower set of rams to 7" solid bod . 00:00 03:00 3.00 0 0 COMPZ RPEQPI NUND P Continue work on tbg head bolts installing long threads for casing ex ansion. Page 6 of 25 • Time Lo s Date From To Dur S. De th E. De th Phase Code Subcode T Gomment 03:00 06:00 3.00 0 0 COMPZ RPEQPI NUND P Casing has grown to ~6" so far. 06:00 07:00 1.00 0 0 COMPZ RPEQPI NUND P Notified AOGCC of upcoming body test and test of the 7" rams. Waived by John Crisp. Continue to release tubing head bolts with hammer wrench. Sweeney wrench has quit workin .....current) troubleshootin . 07:00 11:00 4.00 0 0 COMPZ RPEQPI NUND P Replacement Sweeney Wrench on location to continue to release long bolts. 11:00 12:30 1.50 0 0 COMPZ RPEQPI NUND P Have to pick up and move off the BOP's in order to get the longer 4' bolts in. Also had to cut -4" off of the 4' bolts to get them in past the to flan e. 12:30 15:45 3.25 0 0 COMPZ RPEQPI NUND P Continue to release tendon on longer bolts. TybirSg fina~fF`y'~}op~ed growing after a total of 26". 15:45 18:30 2.75 0 0 COMPZ RPEQPI NUND P Remove packoff and preparing to cut off the 8 long bolts as the threads are all galled. RU WACHS pneumatic cutter and cut casing stump above sli s. 18:30 20:00 1.50 0 0 COMPZ RPEQPI OTHR P Make up casing spear. RIH to engage and pull to 175K. Observed casing collar in the bowl with the emergency slips, not allowing proper seating of e-slips. Slack off to allow only 90K pull on casing with 1 ft of movement. 20:00 23:00 3.00 0 0 COMPZ RPEQPI NUND P Nicole ~RBOP stack & lines. with s avers ool mud cross. 23:00 00:00 1.00 0 0 COMPZ RPEQPI NUND P Change out lower rams installing 7" solid bod rams. O fluid loss toda . 5/04/2010 Continue change out rams. Fill OA with seawater to obtain a 1500 PSI test on BOP body. Test 7" Rams to 1500 PSI. Make up casing cutter. Cut casing at 1,965' DPM. Establish circulations. Displace Arctic Pack from 9 5/8" x 7" Annulus. ND BOP Stack. Pull 7" Casin Sli s. NU BOP Stack. 00:00 01:00 1.00 0 0 COMPZ RPEQPI NUND P Continue change out lower rams to 7" solid bod . 01:00 05:00 4.00 0 0 COMPZ RPEQPI BOPE P Pick up 7" test joint, RIH to obtain a 1500 PSI shell test on BOP's. Perform 1500 PSI test on 7" rams against wellbore. Fill OA with seawater for test. 05:00 07:30 2.50 0 0 COMPZ RPEQPI TRIP P Pull storm packer and rack back all DP. 07:30 10:30 3.00 0 2,030 COMPZ RPEQPI TRIP P MU and TIH BHA #5 (5.5" 10:30 13:30 3.00 2,030 1,965 COMPZ RPEQPI CPBO P Locate 1st collar at 2030' DPM and 2nd at 1985' DPM. PU 20' and begin cutting @ 1965'. Once cut, saw gas in returns. Had to take gas to kill tank. Circ. 2+ bottoms up. Confirmed cut com lete. 13:30 15:15 1.75 1,965 0 COMPZ RPEQPI TRIP P TOOH and while watching for any additional as in returns. `Page 7 of 25 Time Lo s Date From To Dur S. De th E. De th Phase Code Subcode T Comment 15:15 15:45 0.50 0 0 COMPZ RPEQPI TRIP P Stab into 7" with spear. PU to confirm en a ed. 15:45 17:15 1.50 0 0 COMPZ RPEQPI NUND P Rig flange to mud cross to take returns from OA. 17:15 20:00 2.75 0 0 COMPZ RPEQPI CIRC P Begin circulating 90' diesel down 7" and taking returns from 9-5/8" to open top tank. Pumping 4 bpm/330 psi. Allow diesel to soak. Continue Arctic Pack displacement. Pump 200 bbls of 170 deg F. Sea Water at 4.0 bpm/225 psi. until clean returns. Blow down lines. 20:00 22:00 2.00 0 0 COMPZ RPEQPI NUND P Drain Stack. Nipple down BOP Stack. Pick-up on 7" Casing. Up weight = 84K, Remove Casing Slips recovered com lete . 22:00 00:00 2.00 0 0 COMPZ RPEQPI NUND P Nipple up BOP Stack 5/05/2010 Lay down 7" Casing. Perform weekly BOPE test. Run 9 5/8" Casing Scraper to 1,962-ft. Rig up E-Line Unit. 00:00 02:00 2.00 0 0 COMPZ RPEQPI BOPE P Rig up test equipment. Body test BOP Stack at 250 psi. Flange leak. Re-tighten same. Resume test at 250/1,500 psi. Good test. Btow down line and rig down test e ui ment. 02:00 07:00 5.00 1,965 0 COMPZ RPEQPI PULD P Pull Casing Spear to floor. Release and lay down same. Continue to single down 7" Casing to Pipe Shed. Have -12-ft section of 9 5/8" section where the 7" collars/centralizers "bobble" through at 85K - 95K. 7" Casing is severally "cork-screwed". Stop to clear Pipe Shed. Continue to lay down remainder of the 7" Casing. Recovered a total of 46 full joints, 1 cut joint (19.90') and 14 centralizers. 07:00 10:00 3.00 0 0 COMPZ RPEQPI MPSP P Conduct PJSM. Cleared pipe shed and rig floor. Install 11"test plug in re aration for BOP test. 10:00 16:30 6.50 0 0 COMPZ RPEQPI BOPE P Conduct weeklx BOP test. _ Test witness was waived by John Crisp on 5/4/10. 16:30 19:00 2.50 0 1,962 COMPZ RPEQPI TRIP P MU and RIH with BHA #6., BHA consists of 9-5/8" casing scraper. bit sub, crossover and 20 stds of DP. Trip in to 1,962-ft. Up Weight = 55K. Down wei ht = 55K. 19:00 21:00 2.00 1,962 1,962 COMPZ RPEQPI CIRC P Circulate at 5.0 bpm/330 psi. and recovered several small slugs of the remaining Arctic Pack. Blow down lines. 21:00 23:00 2.00 1,962 0 COMPZ RPEQPI TRIP P Trip out from 1,962-ft standing 3 1/2" Drill Pipe in Derrick. Lay down 9 5/8" Casing Scraper BHA. Clean and clean floor. Page 8 of `25 C~ Time Lo s Date From To Dur S. De th E. De th Phase Code Subcode T Comment 23:00 00:00 1.00 0 COMPZ RPEQPI ELOG P PJSM. Spot E-Line Unit and rig up to to Well. 5/06/2010 Record Caliper and Gyro Logs. Trip in with Drift and enter 7" Casing Stump. Swap Well over to 9.6 Brine. Make up and trip in with Baker Back Off Tool. Back Off 7" Casing Collar at 1,985-ft and a total of 4 rounds. Tri out and la down BHA. 00:00 06:00 6.00 0 0 COMPZ RPEQPI ELOG P Complete. E-Line Rig up. RIH with PDS 40-Arm Caliper/Memory GR Log. Record Caliper survey from 1,965-ft to surface. Lay down Caliper logging tool. Make up and RIH with Gyro tool. Record Gyro survey from 1,965-ft to surface. 06:00 09:00 3.00 0 2,296 COMPZ RPEQPI TRIP P Make up and TIH with BHA #7 to drift the 7" stub. Slight bobble in wt. when enterin the cut. 09:00 12:00 3.00 2,296 2,296 COMPZ RPEQPI OTHR P Standby for fluid to arrive. Conducted Spill Drill while waiting (36 second response time to cuttings box . 12:00 13:00 1.00 2,296 2,296 COMPZ RPEQPI CIRC P Begin circulating 9.6 ppg brine to load the well with heavier fluid. 13:00 14:30 1.50 2,296 0 COMPZ RPEQPI TRIP P TOOH with BHA #7. Lay down 6 jts of 4-3/4" drill collars. 14:30 18:00 3.50 0 1,965 COMPZ RPEOPI TRIP P Make up BHA #8 (A&B) and RBIH to back-off 7" stub. Bottom of the back-off tool has 2 pins at 440 psi each (880# shear) and the top has 5 pins aY440 psi (2200# shear). Filling up hole every 5th stand with fresh water. Enter the 7" Casing Stump at 1965-ft. 18:00 19:00 1.00 1,985 2,277 COMPZ RPEQPI FISH P Continue to ease down inside the 7" Stump with Bull Nose and Drill Collars. Position the Lower Anchor below the 7" Collar at 1,985-ft md. Upper Anchor and Power Section above the same collar. Bring pump on line. Set Lower Anchor at _ 800 psi. Set Upper Anchor at 2,200 psi. Make initial connection break with 1,600 psi. Perform 8 total cycles. Final cycle pressure was 900 psi. Connection loosened a total of 4 rounds. Ralaaca Rark-nff Tnnl 19:00 00:00 5.00 2,277 0 COMPZ RPEOPI TRIP P Trip out standing back 3 1!2" Drill Pipe.. Break out and lay down Baker -_ _.. Back-Off Tool BHA. Clear floor. Kick ____-- out tools and load tools for next BHA in Pipe Shed. Attempt to install Wear Bushing. Problems with Wear Bushing and Running Tool. Call-out new Wear Bushing and Running Tool. Page'9 of 25 ~~ J "Time Lo s Date From To Dur S. De th E. De th Phase Code Subcode T Comment 5/07/2010 2a hr summary Make up tandem 8 3/8"and 8 1/2" String Mills. RIH and work tight spots at 143' - 158', 369' - 379'. Continue down to 1,579-ft with no further problems. RIH with tandem 8 1/2" and 8 1/2" String Mills. Work tight spots at 143' - 171', 380' - 385', 389' - 411'. Continue down to 1,960-ft with no problems. Make up 7" Casing Drift Run. Drift 9 5/8" Casin down to 1,960-ft with no roblems. Circulate Well. 00:00 01:00 1.00 0 0 COMPZ RPEQPI PULD P Make up BHA #9 as follows: 8 3/8" Lower String MIII, Upper 8 1/2" Watermelon Mill, Bumper Sub, Oil Jar, XO, 3 ea 6 1/4" Drill Collars, XO. 01:00 02:30 1.50 0 30 COMPZ RPEQPI TRIP P Make up and install back-up Wear Bushing. Set at 29.5-ft. Lay down Runnin Tool. 02:30 03:00 0.50 0 143 COMPZ RPEQPI TRIP P Trip in with BHA #9 and 3 1/2" Drill Pi e. Set down at 143-ft 03:00 07:30 4.50 143 379 COMPZ RPEQPI MILL P Work tight spot at 143.0-ft - 158-ft md. Continue down to next tight s of at 369-ft - 379-ft md. 07:30 09:00 1.50 379 1,579 COMPZ RPEQPI TRIP P Decide to pass through tight spot and continue to TIH to see how some of the other areas of concern might be. TIH down to 1579' DPM without seein an ti ht s ots. 09:00 10:00 1.00 1,579 0 COMPZ RPEQPI TRIP P TOOH to space replace the 8-3/8" mill with an 8-1/2" mill. Backream throu h ti ht s ots on wa OOH. 10:00 16:00 6.00 0 1,960 COMPZ RPEQPI MILL P Make up BHA #10 with tandem 8-1 /2" string mills. RBIH and begin milling area from 143' - 171'. Make several passes both down and backreaming up through. Milling at 63 RPMs and 100 SPM @ 60#. Stop rotating and try to slide through. Able to pass but takes 5-6K#. Continue RIH and work tight spots at 380' - 385' and 389' - 411'. Continue down to 1,960-ft with no further roblems. 16:00 18:30 2.50 1,960 1,960 COMPZ RPEQPI CIRC P Mix and pump a 25 bbl HI-Vis Sweep. Circulate Sweep back to surface at 8.0 b m/380 si. 18:30 19:30 1.00 1,960 0 COMPZ RPEQPI TRIP P Trip out with 3 1/2" Drill Pipe standing back in Derrick. Lay down Tandem 8 1/2" Strin Mills BHA. 19:30 21:00 1.50 0 0 COMPZ RPEQPI RURD P Clear Floor. Bring equipment for 7" Casing drift run to floor. Rig up casin a ui ment 21:00 23:00 2.00 0 1,960 COMPZ RPEQPI TRIP P PJSM. Make up 7" Casing Drift Run as follows: 8 3/8" Cut-Lip Guide Shoe, Triple Connect Screw In Sub, 7" x 10-ft Pup Jt, ES-Cementer, 7" x 10-ft Pup Jt, XO, XO, Head Pin, String Magnet. Trip in with 3 1/2" Drill Plpe from Derrick. Passed through all expected tight spots with no problems down to 1,960-ft. Up wei ht = 50 k. Down wei ht = 50 K. 23:00 00:00 1.00 1,960 1,960 COMPZ RPEQPI CIRC P Circulate bottoms up at 5.0 bpm/125 si. Page 10 of 25 Time Lo s Date From To Dur S. De th E. De th Phase Code Subcode T Comment 5/08/2010 2a hr summary Lay down 7" Casing Drift. RIH with 7" ITCO Spear and complete back-off. Rig up and run 7" Tie-Back Casing as designed. Screw into Casing Collar at 1,989-ft. Pull test Casing connection. Pressure test Casing. Rig up Cementers. Pump Cement as designed. Launch Closing per Plug and displace with Sea Water. Bump Plug and shift ES-Cementer closed. Check flow back, static. Rig down Cementers. Nipple down BOP Stack and lift. Set 7" Casin Sli s. 00:00 01:00 1.00 1,960 0 COMPZ RPEQPI TRIP P Blow down Top Drive. Trip out with 3 1/2" Drill Pipe and stand back in Derrick. Rig up to lay down 7" Casin Drift. 01:00 02:00 1.00 0 0 COMPZ RPEQPI TRIP P Lay down 7" Casing Drift BHA. Clean String Magnet (full). Rig down Casing handling equipment. (Wash inside of BOP Stack to clean metal mill fillin s with "Swizzle Stick" . 02:00 03:00 1.00 0 1,965 COMPZ RPEQPI TRIP P Make up Spear BHA as follows: Bull Nose, 7" ITCO Spear, Spear Extension, Stop Sub, XO Sub, String Magnet. Run in with 3 1/2" Drill Pipe to 1,965-ft. 03:00 05:00 2.00 1,965 0 COMPZ RPEQPI TRIP P Plant Spear. Complete back-out. Trip out with 3 1/2" Drill Pipe and stand back in Derrick. Lay down BHA Recovered 7" Casing Stump with pin end. (Have 7" Casing Collar looking up). Clean String Magnet full . 05:00 07:30 2.50 0 0 COMPZ RPEQPI OTHR P Lay down 6 1/4" DC's and kick out fishin tools. 07:30 08:00 0.50 0 0 COMPZ RPEQPI OTHR P Pull wear ring. 08:00 15:00 7.00 0 1,989 COMPZ RPEQPI PULD P RU csg equipment and RIH w/ Baker 8 3/8" 7" BTC Triple Connect LusFing,LL10' x 7"BTC pup jt, ES Cementer, 10' x 7" pup jt and jt #1 (7" BTC xTCII X-O jt) and 47 jts 7" TCII to 1,989' and tag up, pull jts 48 and 47, add 15' pup jt and jt 47, XO pup jt, and 10' BTC pup jt. Placing mid body of jt 47 across slip area. MU to To drive. 15:00 16:00 1.00 1,989 1,989 COMPZ RPEOPI CIRC P Displace 9.6 ppg brine w/ Sea water @ 4 bpm @ 200 psi. 190 psi ICP and 160 psi FCP. Start rigging up Cementers. 16:00 17:00 1.00 1,989 1,989 COMPZ RPEQPI OTHR P Gather Parameters: 60 psi @ .5 bpm, ROT wt 75k @ 8 rpms w/ 2k free torque. Screw into CSG collar @ 1,989' and torque up to 7,000 ft/Ibs. and work torque into connection @ 5k up and dn, 10k up and dn, 15k up and dn, 20k up and dn, 25k up and dn. Pull 50k OSW of 77k up wt prior to screwing in. PT connection 1,000 si . 17:00 19:00 2.00 COMPZ RPEQPI CMNT P Finish rigging up Cementers. Stage Vac Trucks. Page 11 of 25 -~ Time Lo s .Date From.. To Dur S. De th E. De th Phase Code Subcode T Comment 19:00 21:45 2.75 COMPZ RPEOPI CMNT P PJSM and Ops meeting. Flood lines and prime up. Pressure test lines at 800/4,200 psi. Good. Pressure test Casing at 2,00 psi x 3 minutes. Increase pressure test to 2,500 psi x 3 minutes. Good. Bleed pressure to "0". Walk pressure up and open ES Cementer at 3,400 psi. Pump 10 bbls of Fresh Water to confirm circulations. Good. Shut down DS Pump. Bring Rig Pump on line and pump a 20 bbl colored pill (red). Shut down Rig Pump. Bring DS Pump on line. Pump 10 bbls Fresh Water spacer. Mix and pump ARCTICSET I Cement. Start Cmt, 2.5 bp_m/150 psi/14.0 ppg. 15 bbls gone, 2.5 bpm/170 psi/15.7 ppg. Increase rate. 50 bbls gone, 4.4 bpm/416 psi/15.75 ppg. 75 bbls gone, 5.0 bpm/510 psi/15.65 ppg. 100 bbls gone, 4.1 bpm/395 psi/15.71 ppg. 125 bbs gone, 4.1 bpm/375 psi/15.76 ppg. 153 bbls gone, 4.1 bpm/395 psi/15.7 ppg. End Cement. Down on Pump. Launch Closing/Wiper Plug. Plug away at 20:58 hrs. Bring DS Pump back on line with a 10 bbl Fresh Water displacement spacer. Switch to Sea Water and continue displacement. 25 bbls gone, 4.2 bpm/520 psi. 50 bbls gone, 4.0 bpm/750 psi. 60 bbls gone, 4.0 bpm/805 psi. 65 bbls gone, slow down rate, 2.0 bpm/680 psi. 70 bbls gone, 2.1 bpm/695 psi. Calculated displacement Volume = 75.7 bbls. Bumped Plug with a total displacement of 78.9 bbls. Shifted ES Cementer closed with 1,900 psi. Plug down at 21:24 hrs. Increase pressure to 2,400 psi. and hold for 5 minutes. Bleed off pressure slowly. Volume bleed back 0.75 bbls. Check "Floats" Static. Knock line loose from Cement Head and verify "no flow" End Job. Rig down Cementers. ~" Total Cementpum~ed_= 1bbls• 9 7/8" x 7"Annular Volume = 58.7 bbls. 7" Displacement Volume to the ES Cementer calculated = 75.7 bbls. Displacement volume pumped to bump plug and close ES Page 12 of 25 C~ Time Lo s Date From To Dur S. De th E. De th Phase Code Subcode T Comment Cementer = 78.9 bbls. Plug down at 21:24 hrs. Check "Floats", good. Est Cement returned to surface = 80 bbls. 21:45 00:00 2.25 COMPZ RPEQPI NUND P Rinse out BOP Stack and Wellhead. Blow down lines and rig down same. PJSM. Nlpple down BOP Stack and lift. Install 7" Casing Slips. Leave Casin with 50K tension ulled. 5/09/2010 Cut off 7" Casing Install Pack-Off and test same. Nipple up BOP Stack. Install 2 7/8" x 5" Variable Bore Pi a Rams. Test BOPs. Make u 6 1/8" Bit BHA. RIH to ES Cementer at 1,972-ft. 00:00 02:00 2.00 COMPZ RPEQPI NUND P Rig up WACHS Cutter and cut off 7" Casin La down Cut Off Joint. 02:00 03:00 1.00 COMPZ RPEQPI NUND P Lower BOP Stack and remove lower S ool. 03:00 10:00 7.00 COMPZ RPEQPI NUND P prep well head for acceptance of pack off, Install Pack off and TBG spool. Test pack off to 3,000 psi for 30 minutes. 10:00 15:00 5.00 COMPZ RPEQPI NUND P NU BOP and_ change LPR's from 7" to 2 7/8 x 5" and UPR's to 3 1/2 15:00 16:00 1.00 COMPZ RPEQPI BOPE P Set 7" Test plug and fill stack. Rig u test a ui ment. Fill Stack. 16:00 18:00 2.00 COMPZ RPEQPI BOPE P Test BOP 3 1/2" Plpe Ram with the 3 1/2" Test Joint. Test VB Pipe Rams with the 3 1!2" and the 2 7/8" Test Joints. Test Kill Llne and Choke. Tested performed at 250/3,500 psi. The State's right to witness the test was waived by C. Scheve. 18:00 19:30 1.50 COMPZ RPEQPI BOPE P Rig down test equipment. Pull Test Plu .Set Wear Bushin . 19:30 21:00 1.50 0 967 COMPZ RPEOPI TRIP P Make up 6 1/8" Bit BHA as follows: . 6 1/8" Bit, Boot Basket, Boot Basket, Bit Sub, 12 ea 4 3/4" Drill Collars. Trip in with 10 stands of 3 1/2" Drill Plpe from the Derrick. Stop at 967-ft. to Cut & Sli . 21:00 23:00 2.00 967 976 COMPZ RPEQPI SLPC P PJSM. Slip and Cut 84-ft of Drilling Line (routine scheduled maintenance). Inspect brake bands and links e. 23:00 00:00 1.00 967 1,972 COMPZ RPEQPI DRLG P C ntinue RIH and tag stringer at 1,920-ft. Up Weight = 65K. Down weight = 58K. Establish parameters. Pump Rate = 4.9 bpm/244 psi, RPMs = 60, Torque = 2K. Drill through minor stringer and continue down to the ES Cementer at 1,972-ft md. 5/10/2010 Drill out ES Cementer at 1,972-ft. Continue down to TOS. Dry drill. Test Casing. POOH. LD BHA. PU Globe Basket BHA. RIH to to of IBP. Rev Circ until returns are clean. Page 13 of 25 ~~ ~~ Time Lo s Date From To Dur S. De th E. De th Phase Code Subcode T Comment 00:00 05:00 5.00 1,972 2,500 COMPZ RPEQPI DRLG P Drill out ES Cementer at 1 972-ft and to 1,974-ft (load and tally 2 7/8" Completion Tubing). Continue to wash and rotate down to 2,500-ft: Found no strin ers below. 05:00 05:30 0.50 2,500 2,500 COMPZ RPEQPI CIRC P Mix and pump a 20 bbl Hi-Vis sweep. Chase back to surface at 8.0 b m/800 si. 05:30 07:00 1.50 2,500 2,500 COMPZ RPEQPI PRTS P RU and Test 7" CSG to 3,000 psi for 15 minutes. RD Test E ui ment. 07:00 08:30 1.50 2,500 2,510 COMPZ RPEQPI DRLG P MU Top Drive and tag up @ 2,510' - Dry drill and attempt to break up, chase down to 2,550'. 08:30 09:00 0.50 2,510 2,468 COMPZ RPEQPI OWFF P Blow down top drive and monitor well. 09:00 10:30 1.50 2,468 0 COMPZ RPEQPI TRIP P POOH from 2,468' 10:30 11:00 0.50 0 0 COMPZ RPEQPI OTHR P Clean out Junk baskets and recovered 2 allons of metal debris. 11:00 11:30 0.50 0 22 COMPZ RPEQPI PULD P PU and MU Reverse Jet basket BHA #14 to 22' 11:30 13:00 1.50 22 2,532 COMPZ RPEQPI TRIP P RIH w/ BHA #14 on 3 1/2 DP f! 22' to 2,532' and to u . 13:00 14:00 1.00 2,532 2,468 COMPZ RPEQPI FISH P EST. Parameters: 7.5 bpm @ 1,030 psi. 15 RPM's and wash down f/ 2,532' to 2,552' PU to 2,468' and Blow down To drive. 14:00 15:00 1.00 2,468 22 COMPZ RPEQPI TRIP P POOH f/ 2,468' to 22.0 15:00 15:30 0.50 22 0 COMPZ RPEQPI OTHR P Lay down BHA #14 and Clean off magnet. Recovered 2 large pc's of aluminum and full ma net. 15:30 17:00 1.50 0 967 COMPZ RPEQPI PULD P PU and MU BHA with Globe basket to 967-ft. Change of orders. POOH and la down Globe Basket..0 17:00 19:00 2.00 21 2,017 COMPZ RPEQPI TRIP P RIH f/ 21' w/ BHA #15 as follows: 6 1/8" Bit, Casing Scraper, Bit Sub, Bumper Sub, 12 ea 4 3/4" Drill Collars. Trip in with 3 1/2" Drill Pipe from Derrick to 2,017-ft. 19:00 20:30 1.50 2,017 0 COMPZ RPEQPI TRIP P Trip out with 3 1/2" Drill Pipe standing back in Derrick. Single down Drill Collars in Plpe Shed. Lay down Bit and Casin Scra er. 20:30 22:00 1.50 0 2,586 COMPZ RPEQPI TRIP P Make-up BHA#16 as Follows: 6" Globe Basket Assembly. Trip in with 3 1/2" Drill Pipe from Derrick. Tag To Of Sand at 2,532-ft. 22:00 00:00 2.00 2,586 2,586 COMPZ RPEQPI CIRC P Rig up to Reverse Circulate. Wash through sand while Reverse Circulating at 8.0 bpm/760 psi. Reverse down to 2,586-ft. Reverse until clean. Recovered some metal cuttings, some small bits of rubber, and lots of sand. Total volume um ed 200 bbls. 5/11 /2010 Swap Well over to 9.6 Ib/gal Brine. POOH. RIH and retrieve IBP at 2,586-ft. Run Completion Packer Assembl on 3 1/2" Drill PI e. Unable to enter HPT/PBR. POOH. ..Page 14 of 25 ' i Time La s .Date From To Dur S. De th E. De th Phase Code Subcode T Comment 00:00 01:30 1.50 2,586 2,582 COMPZ RPEQPI CIRC P Pull up to 2,582-ft. Swap well bore over to 9.6 Ib/gal Brine at 6.0 b m/670 si. .01:30 03:00 1.50 2,582 0 COMPZ RPEQPI TRIP P Trip out with 3 1/2" Drill Pipe standing back in Derrick. Lay down and empty Globe Basket. Recovered three small pieces of alumium from the ES Cementer "drill-out". 03:00 05:30 2.50 0 2,589 COMPZ RPEQPI TRIP P Make up Inflatable Bridge Plug Retrieving Tool. Trip in with 3 1/2" Drill Plpe from Derrick to 2,588.5-ft. Attempted many time to latch IBP. No-Joy. Blow down Top Drive and re to POOH. 05:30 07:00 1.50 2,589 0 COMPZ RPEQPI TRIP T POOH to inspect Retrieving Tool. 07:00 09:00 2.00 0 0 COMPZ RPEQPI OTHR T Wait for Short catch Overshot w/ 1.375" Grapple to arrive. Kick out Baker fishing tools and Strap 2 7/8 Com letion a ui ment. 09:00 09:30 0.50 0 0 COMPZ RPEQPI SFTY P held PJSM with Baker fishing hands and rig crew on MU of fishing e ui ment. 09:30 10:30 1.00 0 2,514 COMPZ RPEQPI TRIP T MU overshot and RIH on 3 1/2 DP to 2,514' 10:30 11:00 0.50 2,514 2,586 COMPZ RPEQPI FISH T Gather Parameters: 4 bpm @ 200 psi, 64k up wt, 60k do wt. Latch uo to IBP and~ull 5k osw and allow to equalize. Monitor well -static. BDTD. 11:00 12:00 1.00 2,586 0 COMPZ RPEQPI TRIP P POOH f/ 2,586' w/IBP. 12:00 12:30 0.50 0 0 COMPZ RPEQPI PULD P Lay down fishing tools and IBP. 12:30 13:30 1.00 0 0 COMPZ RPEQPI OTHR P Change over f/ 3 1/2 DP equipment t/ 2 7/8 TBG a ui ment. 13:30 14:00 0.50 0 0 COMPZ RPEQPI SFTY P Held PJSM w/ Baker Packer hands and Rig crew on PU and RIH w/ FHL com letion aaker. 14:00 14:30 0.50 0 0 COMPZ RPEQPI OTHR P Pull wear ring. 14:30 15:00 0.50 0 167 COMPZ RPCOM PULD P PU and MU Brown seal assy, pup jt, 1 jt, pup jt, HES "x" Nipple w/ RHC plug in place, pup jt, 1 jt, pup jt, Baker FHL packer, pup jt, Baker 80-32 PBR, u ~t, X-O to 167'. 15:00 15:30 0.50 167 167 COMPZ RPCOM OTHR P Chan a over f/ 2 7/8 TBG a ui ment t/ 3 1/2 DP a ui ment. 15:30 19:15 3.75 167 7,737 COMPZ RPCOM TRIP P RIH w/ 2 7/8 Stacker packer assy f/ 167' to 7,737-ft md. Bring charge pump on with 60 psi. Attempt to enter HPT Packer with HPT PBR. Page 15 of 25 Time Lo s Date From To Dur S. De th E. De th Phase Code Subcode T Comment 19:15 21:00 1.75 7,737 7,737 COMPZ RPCOM PACK T Attempt to enter Packer with Seal Assembly. Bull Nose stacks out of top of Packer. No pressure change. Continue may times to enter using slight rotation, different set down weights, charge pump on/charge pump off. Also tried jetting with Rig Pump at 2.0 bpm. No-Joy. Discuss plan forward with Anchorage En ineer. Pre to POOH. 21:00 00:00 3.00 7,737 1,425 COMPZ RPEQPI PACK T Trip out with 3 1/2" Tubing Standing back in Derrick to 1,425-ft 5/12/2010 Modify Bull Nose on Seal Assembly. Run back in hole with Comp-etion Packer Assembly on 3 1/2" Drill Pi e. Once a ain unable to enter HPT/PBR. TOOH. 00:00 01:30 1.50 1,425 0 COMPZ RPCOM TRIP T Finish tripping out with 3 1/2" Drill Plpe. Lay down Completion Packer Assembly. Inspect Bull Nose on bottom of Seal Assembly. Observed many ding from setting down on the HPT/PBR. 01:30 03:00 1.50 0 0 COMPZ RPEQPI OTHR T Modify Bull Nose on the end of the Seal Assembly into a Half Mule Shoe. 03:00 04:00 1.00 0 168 COMPZ RPEQPI PULD T Make up lower Completion Packer Assembly as follows: Brown Seal Assembly w/mod Mule Shoe, 2 7/8" Pup Joint, 1 Joint 2 7/8" Tubing, 2 7/8" Pup Joint, 2.313" Nipple, 2 7/8" Pup[ Joint, 1 Joint 2 7/8" Tubing, 2 7/8" Pup Joint, Baker FHL Packer, 2 7/8" Pup Joint, 2 7/8" Pup Joint, PBR, 2 7/8" Pup Joint and Locator Sub, XO. 04:00 04:30 0.50 168 168 COMPZ RPEQPI SFTY T PJSM on RIH w/ Packer assy 04:30 09:30 5.00 168 7,743 COMPZ RPEQPI TRIP T Trip in with 3 1/2" Drill Plpe from the Derrick. 09:30 10:30 1.00 7,743 7,717 COMPZ RPEQPI OTHR T Attem t to stab seal_assy into PBR @ 7,743' while circulating rotating with no luck. 10:30 12:00 1.50 7,717 7,717 COMPZ RPEQPI CIRC T Circulate bottoms up at 2 bpm @ 230 si. 12;00 16:00 4.00 7,717 168 COMPZ RPEQPI TRIP T POOH w/ Packer assy to make clean out run on the PBR. 168 168 COMPZ RPEQPI OTHR T Change over from 3 1!2 DP e ui ment to 2 7/8 TBG a ui ment. 16:00 17:30 1.50 168 0 COMPZ RPEQPI PULD T Lay down Packer assy and inspect mule shoe. Mule Shoe had many dings and gouges from attempting to et inside the HPT/PBR. Page 16 of 25 ~J P r~ Time Lo s -Date From To Dur S. De th E. De th Phase Gode Subcode T Comment 17:30 00:00 6.50 0 2,546 COMPZ RPEQPI TRIP T Order out Packer Mill from BFT. While WO MIII, Rig up handling, equipment, load 4 3/4" Drill Collars, install Wear Bushing (6 3/8" ID). Make up Packer Mill BHA as follows: 6" x 3 1/2" Packer Mill, Boot Basket, Boot Basket, Bit Sub, String Magnet, Bumper Sub, Oil Jar, 9 ea 4 3/4" Drill Collars, Pump-Out-Sub. Trip in with 3 1/2" Drill Pipe from Derrick. 5/13/2010 RIH with Packer Mill. Dress top of HPT/PBR. POOH. Run Lower Completion Packer Assembly. Sting into HPT/PBR ands ace out. Set Baker FH 47B-2 Packer. Sin le down 3 1/2" Drill PI e. 00:00 02:00 2.00 2,546 7,736 COMPZ RPEQPI TRIP T Continue Trip in with Packer Mill BHA and 3 1/2" Drill Pipe from the Derrick. Establish parameters as follows: Up weight= 135K. Down weight = 85K. RPMs = 60. ROTW = 111 K. Torque = 5K. Pump Rate = 3.0 bpm/300 psi. Tag top of HPT/PBR at 7,736-ft md. 02:00 03:00 1.00 7,736 7,737 COMPZ RPEQPI MILL T WOB = 5 - 7K. Milled and dressed off top of HPT/PBR from 7,736' - 7, 737'. 03:00 04:45 1.75 7,737 7,736 COMPZ RPEQPI CIRC T Pump a 25 bbf Hi-Vis Sweep and chase back to surface at 7.0 b m/1250 si. Blow down To Drive. 04:45 09:00 4.25 7,736 0 COMPZ RPEQPI TRIP T Trip out with 3 1/2" Drill Pipe standing back in Derrick. Lay down Packer MIII BHA. Clean out junk baskets and clean off string magnet. 6" Packer mill face showed good pattern and the nose carbide was un-touched. 09:00 09:30 0.50 0 270 COMPZ RPEQPI TRIP T RIH w/ DC's 09:30 10:00 0.50 270 0 COMPZ RPEQPI PULD T PJSM, POOH laying down DC's 10:00 10:30 0.50 0 0 COMPZ RPEQPI OTHR T Pull wear ring 10:30 11:30 1.00 0 0 COMPZ RPEQPI OTHR T Swap handling equipment 11:30 12:00 0.50 0 0 COMPZ RPEQPI SFTY T Held PJSM w/ w/ Baker production hands and Ri crew 12:00 12:30 0.50 0 167 COMPZ RPEQPI PULD T PU and MU Stacker acker com letion 12:30 16:00 3.50 167 7,713 COMPZ RPEQPI TRIP T RIH w/ Stacker Packer assy on 3 1/2 DP to 7,713' 16:00 16:30 0.50 7,713 7,713 COMPZ RPEQPI SFTY T PJSM on spotting the CI 9.6 ppg brine and stabbin seal ass in PBR. 16:30 17:00 0.50 7,713 7,736 COMPZ RPEQPI CIRC T RIH to 7,736' and Spot 5 bbl CI 9.6 brine on bottom. Page 17 of 25 r~ Time Lo s Date From To Dur S. De th E. De th Phase Gode Subcode T Comment 17:00 17:30 0.50 7,736 7,751 COMPZ RPEQPI PACK T Locate top of PBR @ 7,739' and rotate to walk off to 7,740' set down 5k. Attempt to Work seal assy into PBR while circulating - no pressure increase was seen along with nowt loss. Set 10k to 15k down and was able to work in the PBR to 7,754'. Attempt to circulate ,had pressure increase. Bleed off pressure and s ace out 3'. 17:30 20:00 2.50 7,751 7,751 COMPZ RPEQPI PACK P Drop and wait for packer Setting Ball/Rod to go on seat. Pressure up on Drill Pipe to 2,500 psi x 15 minutes and set Baker FH 47B-2, 2 7/8" x 7" Packer. Bleed pressure on Drill Pipe down to 1,500 psi. Pressure up on the 7" x 3 1/2" Annulus and test Casing at 3,000 psi x 15 minutes. Good. Record on Chart. Bleed pressure to "0" on both sides. Re-pressure up on the Drill Pipe to 2,000 psi. Pull 145K (20K over string weight) and shear the PBR Seal Assembly. Top of FH/PBR at 7,590.6-ft md. 20:00 00:00 4.00 7,751 3,200 COMPZ RPEQPI PULD P Single down with 3 1/2" Drill Pipe in PI a Shed from 7,751-ft md. 5/14/2010 Finish POOH laying down 3 1/2" Drill Plpe. Run 2 7/8" Gas Lift Completion. Locate and space out completion. Pump inhibited 9.6 Ib/gal Brine. Land Completion. Pressure test Tubing. Good. Attempt to ressure test 7" Casin Observe a sli ht ressure loss. Be in leak evaluation. 00:00 01:30 1.50 3,200 3,200 COMPZ RPEQPI SVRG P Stop at 3,200-ft. to slip and cut Drillin Line 84-ft . 01:30 04:30 3.00 3,200 0 COMPZ RPEQPI PULD P Continue to single down 3 1/2" Drill Pi a to Pi a shed from 3,200-ft. 04:30 05:30 1.00 0 0 COMPZ RPEQPI PULD P Change handling equipment to pull remaining2 7/8" Tbg and Seal Assembl . 05:30 06:00 0.50 0 0 COMPZ RPCOM SFTY P Held PJSM w/ Baker Production and Rig crew on Pu and RIH w/ 2 7/8 Gas lift Com letion. 06:00 12:00 6.00 0 7,590 COMPZ RPCOM PULD P Inspect seal assy and RIH w/ 2 7/8 Gas lift completion as per run order to 7,590'. 72k u wt, 60k do wt. 12:00 13:30 1.50 7,590 7,614 COMPZ RPCOM HOSO P Locate PBR @ 7,591' and No-go @ 7,614' Space out 7'. POOH and PU 26.03' in Space out Pup jts, jt# 231, CIW hanger, and landing jt. RIH to 7, 590'. 13:30 14:30 1.00 7,590 7,590 COMPZ RPCOM CIRC P Pump 250 bbls of CI 9.6 ppg brine and follow w/ 10 bbls of clean 9.6 ppg brine circulating @ 4 bpm @ 800 si . 14:30 15:00 0.50 7,590 7,607 COMPZ RPCOM THGR P Land hanger and RILDS w! mule shoe 7,607. Page 18 of 25 • l ~ Time Lo s Date From To Dur S. De th E. De th Phase Code Subcode T Comment 15:00 18:00 3.00 7,607 7,607 COMPZ RPCOM PRTS P RU and PT TBG 3 000 si for 15 minutes, bleed back to 2,250 psig. Pressure up on IA to 3,150 psig -fell to 2,960 psig - 190 psig over 21 minutes. Bleed off pressures and re-connect by passing multiple valves. PT TBG to 2,250 psig for 5 minutes and Pressure up on the IA to 3,170 si 18:00 00:00 6.00 7,607 COMPZ RPCOM PRTS T Continue to evaluate pressure fall off in the 7" Casing. Test #1 Start: Tbg=2,800 psi. IA= 3050 psi. IA Loss, 15 min = 100 psi, 30 min (cum loss) = 170 psi, 45 min (cum loss) _ 210 psi, 60 min (cum loss) = 260 psi, 120 min (cum loss) = 345 psi. Test #2 Bleed Tubing pressure down to 19,50 psi. IA = 2600 psi. IA loss, 15 min = 20 psi, 30 min (cum loss) _ 40 psi, 45 min (cum loss) = 50 psi, 60 min (cum loss) = 60 psi, 120 min cum loss = 120 si. 5/15/2010 Continue pressure testing to evaluate pressure fall on the 7" Casing. Rig up S-line Unit. Pull SO Valve and install Dumm Valve. Continue testin to evaluate ressure fall off. Perform week) BOPE test. 00:00 00:30 0.50 COMPZ RPCOM PRTS T S-line Unit arrive on Location. Bleed IA pressure to "0". Bleed Tubing Pressure to "0". 00:30 01:00 0.50 COMPZ RPCOM PRTS T PJSM w/ HES and Rig crew 01:00 09:30 8.50 COMPZ RPCOM SLKL T Spot and Rig up S-Line Unit. RIH and pull Packer Setting Ball/Rod. Pull SOV from GLM @ 7,536' and RIH and set dummy valve. Standby whiole testin 7" cs . 09:30 10:00 0.50 COMPZ RPCOM SFTY T PJSM w/ rig crew on PT csg. ..Page 19 of 25 • 'Time Lo s Date From Tp Dur S. De th E. De th Phase Code Subcode T Comment 10:00 11:30 1.50 COMPZ RPCOM PRTS T RU test equipment and Test 2 7/8" x 7" annulus @ 2,500 psig w/ 2 7/8 TBG open for 50 minutes 1st - 5 minutes lost 75 psig, 2nd - 5 minutes lost 50 psig, 3rd - 5 minutes lost 5 psig, 4th - 5 minutes lost 5 psig, 5th - 5 minutes lost 5 psig, 6th - 5 minutes lost 5 psig, 7th - 5 minutes lost 5 psig, 8th - 5 minutes lost 5 psig, 9th - 5 minutes lost 20 psig For a total loss of 175 psig in 45 minutes. Test 2 7/8" x 7" annulus @ 3,000 psig w/ 2 7/8 TBG open for 50 minutes 1st - 5 minutes lost 25 psig, 2nd - 5 minutes lost 25 psig, ~P \ 3rd - 5 minutes lost 10 psig, ~ V 4th - 5 minutes lost 10 psig, 5th - 5 minutes lost 10 psig, 6th - 5 minutes lost 5 psig, 7th - 5 minutes -ost 5 psig, For a total loss of 90 si in 35 minutes. Bleed off pressure and send results to Town en ineer for review. 11:30 12:00 0.50 COMPZ RPCOM OTHR T RD Slick line unit 12:00 12:30 0.50 COMPZ RPCOM PULD T Pull landing jt. 12:30 13:00 0.50 COMPZ RPCOM MPSP T Set BPV and test plug 13:00 00:00 11.00 COMPZ RPCOM BOPE T RU test equipment, Fill stack. Conduct BOPE test @ 250 / 3,500 psig with 2 7/8 and 3 1/2 Test jts. Notice was given to AOGCC @ 11:30 AM and Return call was received @ 11:32 AM. Right to witness test by AOGCC was waived by Bob Noble. Valve #9 in Choke Manifold failed. Nipple down Choke Manifold to get to Valve. Replace valve. 5/16/2010 POOH w/ 2 7/8" Gas Lift Completion. ,PU Baker Test Packer. RIH and set at 3,005-ft. Begin Leak Hunt, testin and workin u hole. 00:00 03:00 3.00 COMPZ RPEQPI BOPE T Complete installing number 9 valve in choke manifors. Test at 250/3,500 si. Good test Page 20 of 25 ~°e~ `Time Lo s Date From To Dur S. De th E. De th Phase Code Subcode T Comment 03:00 04:00 1.00 7,607 4,161 COMPZ RPEQPI TRIP T Pull BPV. Make up Landing Joint. BOLDS. Pull Tubing Hanger to Floor. Lay down same. Up weight = 72K. Trip out with 2 7/8 Gas Lift Completion, standing back 2 7/8" Tubin in Derrick. 04:00 06:30 2.50 4,161 4,161 COMPZ RPEQPI TRIP T POOH to 4,161' w/ 2 7/8", 6.5 Ib/ft, L-80, 8rd EUE. Found pin hole in Door hinge on the 11" Double gate. 50k u wt, 50k do wt. 06:30 -08:00 1.50 4,161 0 COMPZ RPEQPI HOSO T PU TBG hanger and MU on landing jt. Drain stack and Wait for wellhead service hand to arrive. Land hanger and set BPV and test plug. Well secured. Notified AOGCC and will re-test and Chart blind rams when re air is com lete. 08:00 15:30 7.50 COMPZ RIGMNT RGRP T Remove door hinge w/ pin hole in body from 11" 5M Hydril double gate BOP and replace same. Build pressure in accumulator and Function test Blind rams -good test. Fill stack and PT blind rams @ 250 / 3,500 psig. Pull test plug and BPV. PU landing jt and BOLDS. Un-land han er and ull to floor. 15:30 19:00 3.50 4,161 0 COMPZ RPEQPI TRIP T Continue to POOH w/ 2 7/8 completion string. Lay down Seal Assembl . 19:00 19:30 0.50 0 COMPZ RPEQPI TRIP T Change out handling equipment. Install Wear Bushin . 19:30 22:30 3.00 COMPZ RPEQPI TRIP T PJSM. Make up Baker EA Retrievamatic Test Packer. Top of Packer to Center Element = 4.20'. OAL= 8.74'. Single in with 3 1/2" Drill Plpe from Pipe Shed. Up Wei ht = 63K. Down Wei ht = 55K. 22:30 23:30 1.00 COMPZ RPEQPI PRTS T Set Packer at 3,004-ft md. Begin Leak Hunt testing. Pressure test down the Drill Pipe at 3,040 psi. Annulus at 0 psi. After 5 minutes Drill Pipe = 3,038 psi. Bleed Drill Pipe zero. Pressure up on 7" x 3 1/2" Annulus to 3,100 psi. Drill Pipe = 0 psi Annulus lost'150 psi in 10 minutes. Bleed Annulus and prep to release and move Packer u -hole. 23:30 00:00 0.50 COMPZ RPEQPI TRIP T Release Packer. Pull up hole. 5/17/2010 Casing Test in progress. Work suspended due to Phase 3 weather conditions. Resume Operations. Continue with Leak Hunt testin . Page 21 of 25 i r~ Time L s ..Date From To Dur S. De th E. De th Phase Code Subcode T Comment 00:00 04:00 4.00 COMPZ RPEQPI PRTS T Set Packer at 3,005-ft. Test #1: Pressure up on Drill Pipe to 3,040 psi and chart for 10 min. Lost -15 psi. Release pressure. Pressure up on Annulus to 3,100 psi. Lost -140 psi in 10 mins. Release and move Packer up to 2,135-ft. Test #2: Test Annulus at 3,075 psi. Lost -170 psi in 12 mins. Release and move Packer up to 2,035-ft. Test #3: Test Annulus at 3,100 psi. Lost -140 psi in 15 mins. Release and move Packer up hole to 2,015-ft (Note: TOC at -2,050-ft). Test #4: Test Annulus at 3,100 psi. Lost -200 psi in 10 mins. Release and move Packer up hole to 1,956-ft (Note: Packer now set in the 7" Tie-Back Liner with Cement behind pipe and above the ES-Cementer, 1972-ft and and the Tripple Connection Sub, 1,989-ft md). Test #5: Test Annulus at 3,100 psi. Lost -130 psi in 12 mins. Release and move Packer up hole to 1,813-ft. Test #6: Test Annulus to 3,070 psi. Lost 130 psi in 15 mins. All test recorded on chart. Test Drill Pipe at 3,000 psi for 15+ mins. Lost ~30 psi. This just nullified all other Annulus tests as this test tested down the DP into the 7" Csg to the WRP Plug in the Tailpipe and back to below the Packer. 04:00 10:30 6.50 COMPZ RPEQPI PRTS T Release Packer and test the entire Wellbore at 3,000 psi x 60 minutes. Lost 100 psi. Open OA w! fluid level visual and PT 7" to 3,100 psi for 1 hr. Lost 100 psig in this interval. PT to 2,500 psi for 30 minutes with 25 psi loss. PT to 2,500 psi for 30 minutes with 25 psi loss with no returns on OA. PT to 2,750 psi for 30 minutes with 50 psi loss with no returns on OA. PT to 3 000 psi for 30 minutes with 60 psi loss with no returns on A. 10:30 18:00 7.50 COMPZ RPEQPI OTHR T Field went to phase 3 on pads and access roads. Page 22 of 25 Time Lo s °'Date From To Dur S. D th E. De th Phase Code Subcode T Comment 18:00 22:00 4.00 COMPZ RPEQPI TRIP T Now in Phase 2 weather conditions. Resume operations. POOH with 3 1/2" Drill Pipe and Baker Retrievmatic Test Packer. Lay down Packer. Pull Wear Bushing. Prep to perform a differential test on the Tubing Hanger/Pack-Offs. Discuss Lock-Down Pin (s) rating that hold down the Tubing Hanger with 3,000 psi applied from below. RIH with 3 1/2" Drill Pipe from Derrick (31 stands) for weight. Make-up Tubing Han er. Land Han er and RILDS. 22:00 23:30 1.50 COMPZ RPEQPI PRTS T Perform Tubing Hanger/Pack-off differential test. Test Hanger void to 3,000 psi. Good. Bleed void pressure to 500 psi, block in and monitor. Pressure up on Drill Pipe/Wellbore to 2,000 psi. The void pressure increased to 1,500 psi. Record DP/WB pressure on chart for 10 minutes. Lost -10 psi. Void pressure remained at 1,500 psi. Bleed DP/WB pressure to "0". Void pressure returned to 500 psi. Bring DP/WB pressure up to 3,000 psi. Void pressure went up to 1,500 psi once again. Record DP/WB pressure on chart for 30 minutes. Lost 110 psi. Void pressure remained steady at 1,500 psi. Bleed DPMlB pressure to "0" psi. Void pressure returned to 500 psi. End test. 23:30 00:00 0.50 COMPZ RPEQPI TRIP T Test Hanger void to 3,000 psi x 5 minutes. Good. Bleed off pressure. BOLDS. 5/18/2010 Continue with Leak Hunt with a Baker Full Bore Test PKR. Testing Showed 7" CSG Integrity to be good. Layed down 3.5" Drill pipe and test packer. Run 2 7/8" Gas Lift Completion. Located, space out and Landed Com letion. 00:00 01:30 1.50 COMPZ RPEQPI TRIP T Pull Tubing Hanger to Floor. Trip out with 3 1/2" Drill Pipe standing back in Derrick. 01:30 03:00 1.50 0 68 COMPZ RPEQPI PRTS T Pick up Backer C-1 Fullbore Packer. RIH to 68-ft. Set Packer and pressure up on Drill PipeNVellbore to 3,000 psi. Record on Chart. Lost -50 si in 15 minutes. 03:00 03:30 0.50 68 2,036 COMPZ RPEQPI TRIP T Release Packer and move downhole to 2,036-ft. Set Packer. 55k up wt, 55k do wt. Page 23 of 25 l I l~ Time Lo s Date :.From To Dur S. De th E. De th Phase Code Subcode T Comment 03:30 13:00 9.50 2,036 1,973 COMPZ RPEQPI PRTS T Pressure up on DP/WB to 3,000 psi. Lost ~25 psi in 15 minutes. Bleed off pressure. Pressure upon the Annulus to 3,000 psig for for 15 minutes -lost 300 psi. Release packer and move up to 1,942'. Set and Test below PKR @ 3,000 psi for 15 minutes -lost 50 psi. Test IA above PKR @ 3,000 psi for 30 minutes. -lost 20 psi. RIH to 1,984'. Set and test below PKR @ 3,000 psi for 30 minutes - 100 psi. Test IA above PKR @ 3,000 psi for 30 minutes -lost 100 psi. RIH to 1,994'. Set and Test @ 3,000 psi for 30 minutes -lost 50 psi. POOH to 1,973'. Set and Test below PKR @ 3,000 psi for 30 minutes -lost 100 psi. Release PKR -test wellbore @ 3,050 psi - 30 minutes Lost 25 psi in the 1st 15 minutes and 5 psi in the 2nd 15 minutes. Test showed that 7" CSG integrity to be good. RD test e ui ment. 13:00 13:30 0.50 1,973 3,004 COMPZ RPEOPI TRIP T RIH w/ remaining DP to 3,004' 13:30 16:00 2.50 3,004 0 COMPZ RPEQPI PULD T POOH laying down 3 1/2 IF Drill pipe and Baker Full bore Test PKR. 16:00 17:00 1.00 0 0 COMPZ RPEQPI OTHR T Swap handling equipment,clean and clear ri floor. 17:00 22:00 5.00 0 COMPZ RPCOM TRIP T PU seal assy and change out seals. Crew change. MU and RIH w/ 2 7/8, 6.5 Ib/ft L-80 EUE 8rd Gas lift completion down to 7591'. 58k do wt / 70k u wt. 22:00 22:30 0.50 COMPZ RPCOM HOSO T Locate PBR 7,590' and No-go @ 7,575' Space 7' MU Tubing Hanger & Landing Jt. Bleed psi and Drained stack. 22:30 23:00 0.50 COMPZ RPCOM THGR T Landed hanger & Completion @ 7607'. RILDS. 23:00 00:00 1.00 COMPZ RPCOM PRDT T RU & PT TBG @ 3100 psi for 15 mins, lost a total of 50 psi. Recorded on Chart 5/19/2010 PT Tubing, Pt IA. Shear Out SOV. Set BPV. ND BOPE / NU New 2-9/16 5M Tree. Freeze Protect. RDMO. 00:00 00:30 0.50 COMPZ RPCOM PRTS T Bleed psi back to 1750 psi. Pressure Up IA to 3050 psi & Record pressure on Chart. INITIAL=3050 PSI 15 MINUTE=3025 PSI 30 MINUTE=3000 PSI 00:30 00:45 0.25 COMPZ RPCOM PRTS P Pressure Up IA and Shear SOV @ 1650 psi, after bleeding IA & Tubing to Zero. 00:45 01:00 0.25 COMPZ WELCTL SEOP P Lay Down pumping iron and Pull landin 'oint and set BPV. Page 24 of 25 - Time Lo s Date From To Dur S. De th E. De th Phase Code Subcode T Comment 01:00 03:00 2.00 COMPZ WELCTI NUND P Nipple Down BOPE. 03:00 06:00 3.00 COMPZ WELCTI NUND P NU 2-9/16", 5M psi tree. Call DSO & He Waived to Witness NU Tree. PT Tree to 5000# For 45 mins 06:00 06:30 0.50 COMPZ WELCTL MPSP P Pull BPV 06:30 07:00 0.50 COMPZ WELCTI SFTY P PJSM w/ LRS and Rig crew on freeze rotectin the well. 07:00 09:00 2.00 COMPZ WELCTL FRZP P RU hoses and PT same @ 2,500 psi. Pump 115 bbts diesel down IA @ 1.25 bpmn @ 300 PSI ICP and FCP of 650 si. 09:00 10:00 1.00 COMPZ WELCTL OTHR P Allow well to u-tube. 10:00 10:30 0.50 COMPZ WELCTL MPSP P 0 psi TBG/ 0 psi IA/ Opsi OA Set BPV 10:30 13:30 3.00 COMPZ MOVE MOB P Install tree cap and prep rig for rig move. 13:30 15:00 1.50 COMPZ MOVE MOB P Pull rig off 2T-17, clean cellar and prep well for hand over. Release Nordic rig 3 @ 15:00 hrs on 5-19-10 Page 25 of 25 '' • VY~L.L L~i.7 TR~4/VS~IfTTAL lo• PrtoAciive D'u-gNOSTic SeRVicES, INC. To: AOGCC Christine Mahnken 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 (907) 659-5102 RE : Cased Hole/Open Hole/Mechanical Logs and /or Tubing Inspection(Caliper/ MTTj The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the following ProActive Diagnostic Services, Inc. Attn: Robert A. Richey 130 West International Airport Road Suite C Anchorage, AK 99518 Fax: (907j 245-8952 1) Caliper Report 05-Ma~10 2T-17 1 Report/ EDE 50-103-20060-00 I ~~ -au3 ~9~3 ~~~~0~ I~AY~i2010 Signed : ~ Date .a .C Print Name: PROACTIVE DIAGNOSTIC SERVICES, INC., 130 W. INTERNATIONAL AIRPORT RD SUITE C, ANCHORAGE, AK 99518 PHONE: (907)245-8951 FAX: (907245-88952 E-neAll.: pdsanchoeage~memorvlog.com WEesITE : www.rnemorvlog.com C:\Documerts and Settings\Diane Williams\Desktop\Tmnsmit_Conoco.docx SELL LQG TRANSM/TTAL ,,. PeoAcrivE DiayNOSric SertvicES, Inc. n u To: AOGCC Christine Mahnken 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 (907J 659-5102 RE : Cased Hole/Open Hole/Mechanical Logs and /or Tubing Inspection(Caliper / MTT) The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the following ProActive Diagnostic Services, Inc. Attn: Robert A. Richey 130 West International Airport Road Suite C Anchorage, AK 99518 +,.` ~. _ ~ •, .. `~ ~'~'`:4 Fax: (907) 245-8952 1 ] Caliper Report 30Apr-10 2T-17 1 Report / EDE 50103-2006000 2) Signed Print Name: ~~ ~ , ~~~ 3 I~~~LI Date : aAnv , ~: ~nan &$ ~ ~.~ PROACTIVE DIAGNOSTIC SERVICES, INC., 130 W. INTERNATIONAL AIRPORT RD SUITE C, ANCHORAtiE, AK 99518 PHONE: (907)245-8851 Fax: (907)245$8952 E-MaIL : pdsanchoraae~memorvlog.com WEBSITE : www.memorylog.com C:\DocumanCC and Settittgs\Diane Willisms\Desktop\Transmit_Conoco.docx • WELL LOG TRANSMITTAL To: Alaska Oil and Gas Conservation Comm. Attn.: Christine Mahnken 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: Radial Cement Bond Log: 2T-17 Run Date: 5/1/2010 May 7, 2010 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Rafael Barreto, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 2T-17 Data in LAS format, Digital Log Image files 1 CD Rom 50-103-20060-00 Cement Bond Log 1 Color Log 50-103-20060-00 ;~., s _~ E ti »,. +4 PLEASE ACKNOWLEDGE RECEIl'T BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline & Perforating Attn: Rafael Barreto ~ ~ (o ' C7 ~ l 3 rafael.barret o Date: MAY ~ 7 2010 Signed: ~ ® l WELL LOG TRANSMITTAL To: Alaska Oil and Gas Conservation Comm. Attn.: Christine Mahnken 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: String Shot Perforating Record: 2T-17 Run Date: 5/2/2010 i May 7, 2010 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Rafael Barreto, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 2T-17 Digital Data in LAS format, Digital Log Image file 1 CD Rom 50-103-20060-00 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline & Perforating Attn: Rafael Barreto 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907-273-3527 Fax: 907-273-3535 rafael.barret .off t :-' ~ ~. ~' ' ~" . ~ ' Date: ~~AY ~ ~ 2010 1 ~~'~l3 1 AI Co~~So r, Signed: J ~~ t%. tom rr i • • Memory Mufti-Finger Caliper Llag Results Summary Company: ConocoPhillips Alaska, Inc. Well: 2T-17 Log Date: May 5, 2010 Field: Kuparuk Log No.: 7406 State: Alaska Run No.: 2 API No.: 50-103-20060-00 Pipet Desc.: 9.625" 36 Ib. J-55 Top Log Intvl1.: Surface Pipet Use: Surface Casing Bot. Log Intvl1.: 1,959 Ft. (MD) Inspection Type : Buckling & Restriction Inspection COMMENTS this caliper data is correlated to the Halliburton Radial Cement Bond Log (Run 1) dated May 1, 2010. This log was run to assess the condition of the 9.625" surtace casing. The caliper recordings indicate severe buckling in the surtace casing in joint 3 at -132', joint 9 from -345' to 367', joint 21 at -849', joint 25 from --978' to 993', and joint 27 at 1,082', restricting the I.D. to 8.45" and 8.55" in joint 9 (361') and joint 27 (1,081') respectively. Buckling is recorded from -150' to -500', with moderate buckling recorded from -500' to 538', 620' to 737', and -856' to 896', and slight buckling recorded from 780' to -856', 935' to 972', and 1,090' to -1,290'. Log plots of the centered and off-center caliper recordings across buckling recorded in the surtace casing logged and a graph illustrating minimum recorded diameters on a joint-by joint basis are included in this report. The caliper recordings indicate the 9.625" surface casing logged is in good condition with respect to corrosive and mechanical damage, with the exception of a possible part in the casing in joint 9 (365'), where the caliper also recorded 96% cross-sectional wall loss. No other significant wall penetrations or areas of cross-sectional wall Toss are recorded throughout the surtace casing logged. fll 0 This is the second time a PDS caliper has been run in this well and the first time the 9.625" surtace casing has been logged. MAXIMUM RECORDED WALL PENETRATIONS: Possible Parted Casing (100%) Jt. 9 @ 365 Ft. (MD) No other significant wall penetrations (> 19%) are recorded throughout the surface casing logged. MAXIMUM RECORDED CROSS-SECTIONAL METAL LOSS: Possible Parted Casing (96%) Jt. 9 ~ 365 Ft. (MD) No other significant areas of cross-sectional wall loss (> 14%) are recorded throughout the surtace casing logged. MAXIMUM RECORDED ID RESTRICTIONS: Severe Buckling Minimum I.D. = 8.45" Jt. 9 @ 361 Ft. (MD) Severe Buckling Minimum I.D. = 8.55" Jt. 27 @ 1,081 Ft. (MD) Severe Buckling Minimum I.D. = 8.59" Jt. 25 @ 980 Ft. (MD) No other significant I.D. restrictions are recorded throughout the surtace casing logged. Field Engineer: Wm. McCrossan Analyst: C. Waldrop Witness: Heim & 3endon ProActive Diagnostic Services, Inc. f P.O. Box 1369, Stafford, TX 77497 Phone: {281) or (8$8) 565-9085 Fax: (281} 565-1369 E-mail: PDS(amemoryiog.com Prudhoe Bay Field ©ffice Phone: (907) 659-2307 Fax: (907) 659-2314 ~ (o - v~r3 ~ ~ (or'o~ • PDS Multifinger Caliper 3D Log Plot ~,_. _ ~~_ Company : ConocoPhillips Alaska, Inc. Field : Kuparuk Well : 2T-17 Date : May 5, 2010 Description : Detail of Centered Caliper Recordings Across Buckling Recorded in 9.625" Casing. Comments Depth Max. I.D. (ins.) 3-D Log Image Map (Centered) 1 ft:900ft 7.7 9.7 0° 0° 90° 180° 270° 0° Min. I.D. (ins.) 7.7 9.7 Nominal I.D. / O.D. i .................................................................... 7.7 9.7 0 ~..~- Pup Jt. _ ~.. , ' ;~- - Joint 1 50 i Joint 2 _ 100 ~ ` Joint 3 ~_ ~ d, Severe Buckling Min. LD. = 8.82" _~__~_ °. ~+__ ' 150 Joint 4 ~-- Buckling 0 Joints 2 0 Buckling . ~ . Joint 6 2 ~ _:_ _ - , ~ ; ; Buckling 50 ' " Joint? Buckling ' ~ "r ---~- - _~ 300 Joint 8 Buckling ~ ~ ~ ; P. _. _ - ._ . Jo1M9 350 ~' a Severe Buckling .~_>r, ~ ~-- ,----;~' ^--- Min. LD. = 8A5" __.. _._ i i '` Joint 10 ~ - Buckling 400 Joint 11 Buckling 4 50 Joint 12 Buckling i° :- F _ Joint 13 500 Moderate Buckling 550 ~ Joint l4 • . E1 Joint 15 at 600 Joint 16 Moderate Buckling - - 650 Joint 17 Moderate Buckling - - 700 .~ , Joint 18 Moderate Buckling 750 Joint 19 y ~ _~, Buckling Slight 800 Joint 21 - k~ _ Severe Buckling ;¢~ Min. LD. = 8.77" r ,. 850 dz Joint 22 i i Moderate Buckling ~i ---~- - I 900 ~ . I - - Joint 23 Joint 2a i - 950 _ Slight Buckling - "' :~ , ~ Joint 25 N. ~ Severe Buckling Mi LD = 8 59" I n. . . 1000 `' _ _ ~ ~° t i Joint 26 _,__ - -; ~ i ;, Joint 27 1050 .__ . ., _ Severe Buckling - ~ Min. LD. = 8.55" i - ~ _~ _ i _.., ; I _ i 1100 = Joint 28 SIigM Buckling - Joirrt 2s 50 ~, G f __ , ~`, Slight Buckling 11 °~ s Joint 30 Slight Buckling 20 1 0 Joint 31 ~ ~ s Slight Buckling ~ _- 1250 ~- Joint 32 1_ t SIigM Buckling _~ " ; .. ` '~ -. 1300 • Joint 34 1350 Joint 35 1400 Joint 36 5 Joint 37 14 0 Joint 38 1500 Joint 39 1550 Joint 40 Joint 41 1600 Joint 42 1650 Joint 43 1700 JoirB 44 1750 Joint 45 Joint 46 1800 Joint 4T 1850 ~„., ~~~: ~a .: ~'~ ;:` Joint 4s 1900 Joint 49 - ~, 1950 ~~~: Nominal I.D.1 O.D. :.....................................................................: 7.7 9.7 Min. I.D. (ins.) 7.7 9.7 Comments Depth Max. I.D. (ins.) 3-D Log Image Map (Centered) 1ft:900ft 7.7 9.7 0° 0° 90° 180° 270° 0° • PDS Multifinger Caliper 3D Log Plot ~~ Company : ConocoPhillips Alaska, Inc. Field : Kuparuk Well : 2T-17 Date : May 5, 2010 Description : Detai- of Off-Center Caliper Recordings Across Bucking Recorded in 9.625" Casing. Comments Depth Max. I.D. (ins.) 3-D Log Image Map (Off-Center) 1ft:900ft ~ 7.7 9.7 17° 0° 90° 180° 270° 0° Min. I.D. (ins.) 7.7 9.7 Nominal I.D. / O.D. 7.7 9.7 0 Pup Jt. ~ ~ ' --- - _~ Joint 15 600 Joint 16 Moderate Buckling 6 0 5 Joint 17 Moderate Buckling 700 Joint 18 Moderate Buckling }- -- 750 Joint 19 ~f Joint 20 SIigM Buckling 800 Joint 21 Severe Buckling r Min. LD. = 8.77" 850 Joint 22 Moderate Buckling - 900 Joint 23 Joint 24 950 Slight Buckling Joint 25 Severe Buckling 59" Mi I D = 8 n. . . . 1 000 Joint 26 ,_ _:_~ _ 0 1 50 '' Joint 27 c Severe Buckling Min. LD. = 8.55" Joint zs 1100 Slight Buckling ~., Joint 29 Slight Buckling 1150 ~,._. Joint 30 SIigM Buckling 1200 ~-:. Joint 31 , ~ - SIigM Buckling 1250 Joint 32 SIigM Buckling .__--- 1300 ~~: ._. .~__._ -~ ~.~ ._ iF~.-.r.~r. ir~:s.ro ~' ..: ~ ~ - _ °-~! it.-;=---a..~ .. r ~ ;." ~. t • . • ~~ Minimum Diameter Profile Well: 2T-1 7 Survey Date: May 5, 2010 Field: Kuparuk Tool: UW MFC 40 Ext. No. 218451 Company: ConocoPhillips Alaska, Inc. Tool Size: 2.75 inches Country: USA Tubing I.D.: 8.765 inches i ~ PDS Report Overview ~~,.._ ~_,: Body Region Analysis Well: 2T-17 Survey Date: May 5, 2010 Field: Kuparuk Tool Type: UW MFC 40 Ext. No. 218451 Company: ConocoPhillips Alaska, Inc. Tool Size: 2.75 Country: USA No. of Fingers: 40 Analyst: C. Waldrop Tubing: Nom.OD Weight Grade & Thread Nom.ID Nom. Upset Upper len. Lower len. 9.625 ins 36 f -55 8.765 ins 9.625 ins 6.0 ins 6.0 ins Penetration and Metal Loss (% wall) ~ penetration body metal loss body 50 40 30 20 10 0 0 to 1 to 10 to 1% 10%. 20% 20 to 40 to over 40% 85% 85% Nurnber of ~oints anal sed total = 50 pene loss . 0 0 49 0 7 42 0 0 1 0 0 1 Damage Configuration (body ) 10 0 isolated general line ring hole /pons pitting corrosion corrosion corrosion ible hole Number of ~oints dama ed total = 1 0 0 0 0 1 Damage Profile (% wall) ~ penetration body rnetal loss body 0 50 0 10 Bottom of Survey = 49 100 20 30 40 Analysis Overview page 2 • PDS REPORT JOINT TABULATION SHEET Pipe: 9.625 in 36.0 ppf J-55 Well: 2T-17 Body Wall: 0.430 in Field: Kuparuk Upset Wall: 0.430 in Company: ConocoPhillips Alaska, Inc. Nominal I.D.: 8.765 in Country: USA Survey Date: May 5, 2010 Joint No. Jt. Depth (Ft) I'c~n. lli~set (Ins.) Pen. Body (Ins.) Pen. ~/o ~1c~t,~l loss ",~<, Min. LD• (Ins.) Comments Damage Profile (%wall) 0 50 100 .1 25 t~.t1~`> 0.08 19 1 ' 8.86 PUP 1 30 O.08 0.08 19 l 8.78 2 69 U.07 0.08 19 11 8.86 3 109 Q08 0.08 18 i _' 8.82 Severe Bucklin . 4 148 0.08 0.08 18 I! 8.87 Bucklin . 5 187 U.08 0.07 17 13 8.86 Bucklin . 6 227 0.O'~ 0.08 18 1-t 8.88 Bucklin . 7 266 ~ I. I U 0.07 1 7 ! -1 8.82 Bucklin . 8 303 u. i l l 0.07 I _ i ~ 8.87 Bucklin . 9 342 ll. l I 0.67 I U(1 gib 8.45 Severe Bucklin Possible Parted Casin . 10 380 U.~)9 0.08 i 8 12 8.86 Bucklin . 11 419 0.11 0.08 18 14 8.83 Bucklin . 12 460 0.10 0.08 18 1 Z 8.81 Bucklin . 13 499 U. l 1 0.08 1 t1 . -~ 8.82 Moderate Bucklin . 14 538 [l.t)8 0.07 1' I ~ 8.82 15 577 U.U7 0.07 17 I Z 8.79 16 620 U.1 1 0.08 18 1 ~ 8.85 Moderate Bucklin . 17 659 t~.1 t) 0.08 1 t3 ! ~ 8.83 Moderate Bucklin . 18 698 (~. I l) 0.08 19 i i 8.83 Moderate Bucklin . 19 737 llU% 0.08 18 i _' 8.81 20 779 U.U8 0.08 18 I -t 8.75 Sli hl Bucklin . 21 818 U.Uti 0.07 I i I -l 8.77 Severe Bucklin . 22 857 U.1 1 0.08 1 ~~ 1 8.79 Moderate Bucklin . 23 896 U.U9 0.08 19 I -1 8.81 24 935 (? 0.06 14 ~ 8.70 Sli ht Bucklin . 25 972 0.1t) 0.07 17 I > 8.59 Severe Bucklin . 26 1011 U.11 0.08 18 I > 8.76 27 1050 O.U9 0.08 19 13 8.55 Severe Bucklin . 28 1089 (~.~~~) 0.07 17 I ~ 8.78 Sli ht Bucklin . 29 1131 ~~.U~l 0.08 1 ti I ~ 8.74 Sli ht Bucklin . 30 1170 t1.U5 0.07 I ~ I ; 8.74 Sli ht Bucklin . 31 121 1 t).r)I, 0.08 1'>> I ; 8.67 Sli ht Bucklin . 32 1251 (?.l)f5 0.07 17 I-1 8.67 Sli ht Bucklin . 33 1290 0 0.08 18 1 u 8.68 34 1330 U.UB 0.07 1 i' 1 ~ 8.64 35 1371 0.08 0.08 18 I ~~ 8.67 _ 36 1412 0.08 0.08 18 i -t 8.68 37 1451 0.06 0.08 Ica II 8.72 38 1490 0 0.08 18 ~~ 8.65 39 1527 u. 12 0.08 I tf ) ; 8.70 40 1566 O.U(i 0.08 18 ; l 8.79 41 1604 0.05 0.08 19 I1 8.79 42 1644 U.U6 0.08 18 1 ' 8.79 43 1683 ~? 0.07 16 8 8.74 44 1719 iI.OS 0.08 18 11 8.79 45 1759 U.U6 0.08 18 I I 8.79 46 1798 0 0.07 16 ~> 8.75 _ 47 1837 0.08 0.07 17 13 8.78 48 1878 ~1_~u, 0.07 17 f; 8.73 49 1922 i ~.i ~ 0.07 1 h t3 8.76 Penetration Body Metal Loss Body Page 1 i ~ ~ r ~ ~ ~ ~ ~ ~ i ~ ~ ~ ~ ~ ~ ~ ~ PDS Report Cross Sections ~~,~ , ~ _.-~. - „ Well: 2T-17 Survey Date: May 5, 2010 Field: Kuparuk Tool Type: UW MFC 40 Ext. No. 218451 Company: Conoco Phillips Alaska, Inc. Tool Size: 2.75 Country: USA No. of Fingers: 40 Tubin 9.625 ins 36 f J-55 Anal st: C. Waldro Cross Section for Joint 9 at depth 364.7 ft Tool speed = 43 Nominal ID = 8.765 Nominal OD = 9.625 Remaining wall area = 4 Tool deviation = 1 ° Finger 3 Radius = 4.98 ins Possible Parted Casing 0.67 ins = 100% Wall Penetration / 96%Cross-Sectional Wall Loss HIGH SIDE = UP r~ L_J u Cross Sections page 1 PDS Report Cross Sections Well: 2T-17 Survey Date: May 5, 2010 Field: Kuparuk Tool Type: UW MFC 40 Ext. No. 218451 Company: Conoco Phillips Alaska, Inc. Tool Size: 2.75 Country: USA No. of Fingers: 40 Tubin 9.625 ins 36 f J-55 Anal st: C. Waldro Cross Section for Joint 9 at depth 361.08 ft Tool speed = 43 Nominal ID = 8.765 Nominal OD = 9.625 Remaining wall area = 86 Tool deviation = 1 ° Finger 9 Projection = -0.263 ins Severe Buckling Minimum I.D. = 8.45 ins HIGH 51DE = UP • r~ Cross Sections page 2 PDS Report Cross Sections Well: 2T-17 Survey Date: May 5, 2010 Field: Kuparuk Tool Type: UW MFC 40 Ext. No. 218451 Company: Conoco Phillips Alaska, Inc. Tool Size: 2.75 Country: USA No. of Fingers: 40 Tubin 9.625 ins 36 f J-55 Anal st: C. Waldro Cross Section for Joint 27 at depth 1081.46 ft Tool speed = 43 Nominal ID = 8.765 Nominal OD = 9.625 Remaining wall area = 83 Tool deviation = 27 ° Einger 13 Projection =-0.189 ins Severe Buckling Minimum I.D. = 8.55 ins HIGH SIDE = UP • Cross Sections page 3 ~~ ~ KUP ~ 2T-17 ConocoPhilli ps 1 ell Attributes An le 8 MD TD NHti;~1. IIi. /1 WellhoreAPl/UW1 501032006000 FleldNama KUPARUK RIVER UNIT Well Status Inch`) MDIM(Bt PRODUCING 53.50 3.800.00 ActBlmntl(B) 8,445.0 -- Comment NIS (ppml SSSV: TRDP 30 Date 1!112009 Annofatlon Last WO: End Date NB-Ord IRl 42 00 Rlg Release Date 3/10!1986 WHI Confi '. - T-17 & 20093'.58'.0 4 PM . c emetic - ctu Mnofatlon Dapm )Itl(B) End Date Annotatlon Last Mod By End Dale Lest Tag: SLM 327.0 7/72009 Rev Reason: TAG, ADD NOTE triplwj 7/82009 Casin Strin s . . ) CasingDutriptlon String OD Ilnl String ID Ilnl Top RKB) Set Depth (DKBI Set Ospth (f VD) 1~1 String Wt Imstrtl Strng Orede String lop Thrd ~._ __ _.._ I CONDUCTOR 1 6 15.062 36.0 116.0 176.0 62.50 40 coNCUCroR 11s SURFACE 95/ 8 8.765 0.0 3,671.0 2.797.3 36.00 -55 RODUCTION 7 6.151 0.0 8.438.0 6.239.4 26.00 -55 SAFETY vLV. 1 eta o Tubin Strin s Tubing Descnptlon String OD 11^I String 10 fnl Top ptl(B) Ser Depth 161 Set Depth 1T11D) CBI String Wt IloslRl String Oracle Strirg TOpTmd GAS LIFT. 3 0]6 TUBING 2 7/ 8 2.441 0.0 8,046.0 5,923.9 6.50 -55 B-MOD EUE RD . Other I n Hole A ll Jewe l :Tubin Run & Retrievable Fish etc. SURFACE lop Depth 1~) Top lnc! 3 67i Top Qtl(B) I~BI (°) Deserptlon Comment Run Date D pnl 1,810 1,636.7 49.38 S AFELY VLV emco TRDP-tA-SSA /7/1986 2.312 GASUFT. s,14t 3,076 2,440.1 53.03 G AS LIFT MCO/KBMG/1/GLVBW.188/1278/Canment STA1 2/11/1994 2.347 5.141 3.808.8 42.97 G AS LIFT MCO/KBMGr1/OVBW.25//Comment: STA2 2/11/1994 2.347 6,230 4,585.2 44.99 G AS LIFT MCO MG/1/DMYBW//Comment: STA3 !7/1986 2.347 GASLIFT, e,23o 6,670 5,040.8 44.56 G AS LIFT MCO/ICBMG/1/DMYBW//Canment: STA4 /3/1990 2.347 7,219 5,292.3 44.15 G AS LIFT MCO/KBMG/1/DMYBW//Canment: STAS !7/1986 2.347 7.537 5.526.5 41.79 G AS LIFT MCO/KBMG/1/DMYBW//Canment STA6 !7/t 986 2.347 GAS LIFT. s,97o 7.700 5.650.5 39.48 G AS LIFT MMWFMHOl1.5/DMV/R W//Canment STA7 /5/1990 2.347 7.743 5.683.9 39.06 P BR HPT(&oan) 17/1986 2.500 7,760 5,697.1 38.89 P ACKER HPT'HB' Retr. hyd set !1/1986 3.000 GnsuFr, ],2ts 7,828 5,750.2 37.68 P RODUCTION MCO/7(BMG/1/DMYBW//Comment CLOSED, STAB 28/1995 2.347 7,8 8 5.805.6 37.34 P RODUCTION MCO/KBMG/1/DMYBW//Canment: CLOSED. STA9 28/1995 2.347 8,000 5,886.9 36.85 P RODUCTION MCOIKBMG]1/OMYBW//Canntent: CLOSED, STA 10 26/1995 2.347 GAS LIFT, 7.53] 8,023 5,905.5 37.01 P ACKER PT'1-B' A/t 986 2.500 8,034 5,914.3 36.96 N IPPLE mco'D' Nipple NO GO 17/1986 2.250 8,041 5,919.9 36.93 S OS emco Shear Out 8 Re-Entry Guide n/1986 2.441 GAs71' 0 8,043 5,921.5 36.92 T TL ELMD TTL ~ 8043.5' dudng PERF RECORD on 09/06/86 !1/1966 2.441 8.089 5,958.2 36.72 FI SH Lower Half of GLV lost in Rathde from 5/13/88 /15/1990 Perforations 8 5bts PBR, 7,743 Top lltl(B) Blm ntl(8) Top INDI I~BI B[m (NDI 161 Zone Dsb Shot ens sh^• Type Comment 7.956 7,988 5,851.8 5.877.3 G 2 4, UNIT B, T 17 17/1986 12.0 PERF 20 deg Phase 5" HyperJet II PACI(ER. -i ]6D - 8.095 8,102 5,963.0 5.968.6 4, 2T-17 !7/1986 4.0 PERF 0 deg. Phase; 4" HyperJet II 8,116 8,147 5,979.9 6,004.8 3, 2T-17 !7/1986 4.0 PERF 0 deg. Phase; 4" HyperJet It PRODUCTION. ? 928 Notes: General & Safe End Data Annohtlon 522/1995 NOTE: WAIVER ED WELL: IAx OA ANNULAR COMMUNICATION 7!72009 NOTE: TAG 32T SLM (1.5" SLINKY TOOL STRING), PRIOR TAG 8079, 426/1995 PRODUCTION. 7 898 (PERF. 7,956-] 968 PRODUCTION, 8 ODD PACKER,9023 NIPPLE, 8,034 505.8,041 TTL, 8.043 FISH, 5,D89 IPERF. 8.0958 102 IPERF 8.1168,147 '. PRODUCTION. 8438 TD, sg4s r a ~ er ge 15 of 32 0424/10 s ,. C: SING /TUBING 1 LINER DET~ DRILL SITE •z ~ - ~ ARCO Alaska, Inc. ®; DATE 3-3-~r G Subsidiary of AHanticRichtielclComparty Page 1 of ! pages #ITEMS COMPLETE DISCRIPTION OF EQUIPMENT RUN LENGTH DEPTH ~I s ~ ~ ~ r~ ~ ~, ~~ ~ e l/ /l c4 f ~ "" 6 g. j -~ ~- ! ~ .arc . ~ ~. ~ ! l0aif /lar S. 8 ~~ ~ ~ " cv S 7 7 fo S mot/ ~ l cep •~r 3 33.42 3 ~ y ~ .,t ,~' ~ ~ v~ ~ i e. BOTTOM OFTUBING TAIL Remarks -3 narvic~r • • Memory Multi-Finger Caliper LOg Results Summary Company: ConocoPhillips Alaska, Inc. Well: 2T-17 Log Date: April 30, 2010 Field: Kuparuk Log No.: 7403 State: Alaska Run No.: 1 API No.: 50-103-20060-00 Pipet Desc.: 7" 26 Ib. J-55 Top Log Intvl1.: Surface Pipet Use: Production Casing Bot. Log lntvl1.: 7,732 Ft. (MD) ', Inspection Type : Buckling & Restriction inspection COMMENTS This caliper data is tied info the Schlumberger Density Log (Run No. 7) dated 03/08/1986. Tied into GR signature @ -3,700'. ' This log was run to assess the condition of the 7" production casing. The caliper recordings indicate bends in the production casing in Jts 8-10 from 350' to 450', Jt. 28 at 1,280 and Jt. 31 at 1,310', with the only significant ID restriction recorded through the bends in Jt. 31 ~ 1,299' (6.19"). Buckling is recorded from ' surface to 650', Moderate Buckling is recorded from -650' to 1,350' and Slight Buckling is recorded from 1,350' to 2,075, some areas of deposits are also recorded throughout the interval logged. Log plots of the centered and off-center caliper recordings across these areas of bends and buckling are included in this report. The caliper recordings indicate the 7" production casing logged is in good to fair condition with respect to corrosive and mechanical damage, with a maximum wall penetration of 21% recorded at an isolated pit in joint 125 (5,157'). Other recorded damage appears as apparent wear and shallow corrosion. No significant areas of cross-sectional wall loss are recorded throughout the production casing logged. MAXIMUM RECORDED WALL PENETRATIONS: Isolated pitting (21%) Jt. 125 @ 5,157 Ft. (MD) MAXIMUM RECORDED CROSS-SECTIONAL METAL LOSS: No significant areas of cross-sectional wall loss (> 13%) are recorded throughout the production casing logged. MAXIMUM RECORDED ID RESTRICTIONS: Bend Min ID = 6.19 Jt. 31 @ 1,299 Ft. (MD} Buckled Pipe Min ID = 6.19 Jt. 29 @ 1,214 Ft. (MD) Buckled Pipe Min ID = 6.19 Jt. 34 ~ 1,464 Ft. (MD) Deposits Min ID = 6.11 Jt. 163 ~ 6,686 Ft. (MD) Deposits Min ID = 6.19 Jt. 138 @ 5,683 Ft. (MD) Field Engineer: Wm. McCrossan Analyst: J. Thompson Witness: Heim/Sendon ProActive Diagnostic Services, Inc. j P.O, Box 1369, Stafford, Th 77497 Phone: (281) ar ($88) 565-9085 Fax: (281) 565-1369 E-mail: PDSrwmemorylog.com Prudhoe Bay Field Office Phone: (907) 659-2307 Fax: (907) 659-2314 ~`~10.~6~~3 ~ ~~~ • • PDS Multifinger Caliper 3D Log Plot <-~.__~ Company : ConocoPhillips Alaska, Inc. Field : Kuparuk Well : 2T-17 Date : April 30, 2010 Description : Detail of Centered Caliper Recordings Across Bends and Buckling in 7" Casing Comments Depth Max. Pen. (°/a) Max. I.D. (ins.) 3-D Log Image Map ~~ _r. 1ft:950k 0 100 6 7 ~0° 0° 90° 180° 270° 0° Min. I.D. (ins.) 6 7 Nominal LD. (ins.) i ............................................... . 6 7 0 ~ ~ I Joint 1 50 j ',. _.. . Buckled Pipe ~~ 1 } :: ~. Buckled Pipe 100 - r. Joint 3 I i I ~ -- Buckled Pipe 150 ~~ I - Joint 4 ~ °, Shallow App. Wear i Buckled Pipe 200 t %- " Joint 5 : Buckled Pipe 250 Joint 6 j _ Buckled Pipe Joint 7 300 j - Shallow Appar. I - Wear ~ Buckled Pipe ~ , Joint 8 350 ' - Bends ~`~ Buckled Pipe Joint 9 _- Bends 400 - Buckled Pipe Joint l0 'i i__IL a Buckled Pipe 450 + Joint 11 ~ _ L -- Buckled Pipe ~ ~ _ _ ~ _7 . ~ '~ ,. 500 . Joint 12 ~ Buckled Pipe Joint 13 550 Shallow Appar. Wear F Buckled Pipe Shallow Appar. 1400 Wear SIigM Buckling Joint 34 SIigM Buckling 1450 Joint 35 SIigM Buckling 1500 Joint 36 Shallow Appar. Wear SIigM Buckling 1550 Joint 37 SIigM Buckling 1600 Joint 38 SIigM Buckling Joint 39 1650 SIigM Buckling Joint 40 Shallow Appar. wear 1700 Slight Buckling Joint 41 SIigM Buckling 1750 Joint 42 Line Shallow Corrosion SIigM Buckling 1800 Joint 43 SIigM Buckling Joirrt 44 1850 Slight Buckling Joint 45 SIigM Buckling 1900 Joint 46 Shallow Corrosion SIigM Buckling 1950 Joint 47 Slight Buckling JoiM48 2000 Line Shallow Corrosion SIigM Buckling Joint 4s 2050 SIigM Buckling Joint so 2100 -yT ~_•-~! -- ~._ _~y r_ 6 -=. e-q ~-_._ r PDS Multifinger Caliper 3D Log Plot ~~ __ Company : ConocoPhillips Alaska, Inc. Field : Kuparuk Well : 2T-17 Date : April 30, 2010 Description : Detail of Off-Center Caliper Recordings Across Bends and Buckling in 7" Casing Comments Depth Max. I.D. (ins.) 1ft:9$Oft fib 7 Min. I.D. (ins.) 6 7 Nominal I.D. (ins.) ...................................................................t 6 7 3-D L 0° 0° 90° 180° 270° 0°I Joint 1 50 Buckled Pipe Joint 2 Buckled Pipe 100 Joint 3 Buckled Pipe 150 Joint 4 Buckled Pipe 200 Joint 5 Buckled Pipe 250 Joint 6 Buckled Pipe 300 Joint 7 Buckled Pipe Joint 8 350 Bends Buckled Pipe -7 __1 Joint 9 B d en s 400 Buckled Pipe Joint 10 Bends Buckled Pi e p 450 Joint 11 Buckled Pipe 500 Joint 12 Buckled Pipe 550 Joint 13 Buckled Pipe "°' '!'., ~' . r *w~ ~, ~., ~ ~. ~~ Joint l4 6UU ~ -'~"'" ~ Buckled Pipe _' - M - -_ 3 . . Joint 15 650 .d_.~~ - ~ i l ~ ae : - y~. ~ ~''" Moderate :. -» _ ,. Buckling __- . .. ; ,,,E Joint 16 i ~ ,* ~ ~ .~.,,, Moderate 700 a ""'""` ,~ :. . Buckling . ~ Joint 17 --- -' ' ' -- -~ ----+- --_ -- -: oderate - r I - fi 1 ~: . <: ,;: Bucklin s 750 ~ , Joint 18 - ~ ~ _- i _ i Moderate • : ~ ~ ~ _- , Buckling i '' ~ _ _~ ; .~ - ~ 800 - _ ~; ~ ,. Joint 19 - Moderate ~ ~ __~- ~-~.. ~°` Buckling Joint 20 $50 m :: Moderate • ~ Buckling , ~ - Joint 21 - Moderate 900 - - Buckling .... _ - - Joint 22 i _ - ~ p, Moderate 950 Y ` ' Buckling _ ^`~~ 'II Joint 23 : _ .,; A ,.... -~. , . Moderate klin B ~' uc g 1000 Joint 24 ~-~ -- . "~"~" Buckling - 1050 '. ~ ~ ~"- r Joint 25 ~~ «: _. Moderate , Buckling __- , Joint 26 1100 Moderate - t Buckling '' ": Joint 27 1150 .:... Moderate ~ ~~ Buckling r - Joint 28 ~ ' Moderate 1200 - ~ : -- ~ e' I ° Buckling ° Joint 29 ., Moderate -~ - Buckling _ ~~~ 1250 Joint 30 t -' `~ - ' Moderate _ ~ __ _ _ ~ ~' _ Buckling - 0 -- - 130 • Joint 31 - r. Bend _, - • ;;a - Joint 3z 1350 ~ ~. '"" ,. ~~` ~ '' Slight Buckling -l ~ ~~ ~' ~~ ., .. °_. t 1 1 1 1 1 1 • • Joint 33 1400 Slight Buckling Joint 34 Slight Buckling 45 1 0 Joint 35 Slight Buckling 1500 Joint 36 Slight Buckling 1550 Joint 37 Slight Buckling 1600 Joint 38 Slight Buckling Joint 39 1650 Slight Buckling Joint 40 Sli ht Bucklin 1700 g g Joint 41 Slight Buckling 75 1 0 Joint 42 Slight Buckling 1800 Joint 43 Slight Buckling Joint a4 1850 Slight Buckling Joint 45 Slight Buckling 1900 Joint 46 Slight Buckling 1950 Joint 47 -- Slight Buckling 2000 Joint 48 Slight Buckling • Joint 49 2050 Slight Buckling - Joint 50 Slight Buckling ~ Buckling Stops 2100 2,075' ~'! +~; _~~ ~, s -~ ~, I Correlation of Recorded Daman Pipe 1 7. in (31.5' - 7727.7') Well: Field: Company: Country: Survey Date: • ;e to Borehole Profile 2T-17 Kuparuk ConocoPhillips Alaska, Inc. USA April 30, 2010 :'"~ A pprox. Tool D eviation ^ A pprox. Boreho le Profil e 1 2.5 I \~ 32 1051 5l) 2077 75 3093 ~ ~ E ~ ~ 100 4084 a ' v o 125 5132 150 ~ 6138 175 j~ l 7132 190 7728 0 5 0 1 00 Dam age Pr ofile (% wall) / Tool D eviatio n (degr ees) Bottom of Survey = 190 n PDS Report Overview ~--~ 5,,. Body Region Analysis Well: 2T-17 Survey Date: April 30, 2010 Field: Kuparuk Tool Type: UW MFC 40 No.218451 Company: ConocoPhillips Alaska Inc Tool Size: 2.75 Country: USA No. of Fingers: 40 Anal st: .Thom son Tubing: Nom.OD Weight Grade & Thread Nom.ID Nom. Upset Upper len. Lower len. 7 ins 26 f -55 6.276 ins 7 ins 6.0 ins 6.0 ins Penetration and Metal Loss (% wall) ~ penetration body ----metal loss body 150 100 50 0 0 to 1 to 10 to 20 to 1'% IO°/ 20% 40% 40 to over 85% 85% Number of'oints anal sed total = 187 pene loss . 30 106 50 1 117 69 1 0 0 0 0 0 Damage Configuration (body ) 40 30 20 10 0 isr listed general line ring hule~poss pitting corrosion corrosion corrosion ible hole Number of ~oints dama ed total = 64 8 20 36 0 0 Damage Profile (% wall) ~ penetration body metal loss body 0 50 1 51 Bottom of Survey = 190 U 100 101 151 Analysis Overview page 2 PDS REPORT JOINT TABI. Pipe: 7. in 26.0 ppf J-55 Well: Body Wall: 0.362 in Field: Upset Wall: 0.362 in Corrrparry: Nominal I.D.: 6.276 in Country: Survey Date: • iLATION SHEET 2T-17 Kuparuk ConocoPhillips Alaska Inc USA April 30, 2010 Joint No. Jt. Depth (Ft.) I'en. t llxc°t (Ins.j Pen. Body (Ins.) Pen. % ~~1c~t~d I oss %~ Min. LD• (Ins.) Comments Damage Profile (% wall) 0 50 100 1 32 U.1i~ 0.07 19 8 6.20 Sli Mash. Buckled Pi e. 2 75 t1 0.07 18 ~ 6.22 Shallow A arent Wear.Buckled Pi e. 3 118 (~ 0.07 20 6.20 Buckled Pi e. 4 162 !? 0.07 18 6.20 Shallow A anent Wear. Buckled Pi e. - 5 205 U 0.07 19 6.20 Buckled Pi e. 6 249 1).14 0.07 ,?0 6.23 Buckled Pi e. 7 293 I) 0.06 I' !, 6.20 Buckled Pi e. - 8 336 a 0.07 ! ~) I ; 6.20 Bends. Buckled Pi e. 9 380 l~.Ub 0.07 I t3 I ~' 6.21 Bends. Buckled Pi 10 419 (~.(?(, 0.06 17 f3 6.22 Bends. Buckled Pi e. 11 459 t) 0.07 18 7 6.20 Buckled Pi e. 12 502 0.10 0.07 18 6.23 Buckled Pi e. 13 545 0 0.06 15 4 6.24 Shallow A anent Wear. Buckled Pi 14 589 t) 0.06 1 7 ~ 6.22 Buckled Pi e. 15 632 U 0.06 . ' - 6.22 Shallow A anent Wear. Moderate Bucklin . 16 676 (1 0.07 <t1 'i 6.21 Moderate Bucklin . 17 718 U 0.07 10 s 6.21 Shallow A anent Wear. 18 759 U 0.07 .'U 5 6.22 Moderate Bucklin . 19 798 i~ 0.06 17 6 6.21 Moderate Bucklin . 20 838 t) 0.06 I h 4 6.20 Shallow A anent Wear. 21 881 tl_U; 0.07 :.'(i -1 6.20 Moderate Bucklin . 22 924 l~ 0.06 16 -t 6.21 Shallow A arena Wear. 23 968 U 0.06 1 5 1 6.21 Moderate Bucklin . 24 1011 U 0.07 I ~) ~, 6.22 Moderate Bucklin . 25 1051 U 0.06 1 ;' ~ 6.21 Moderate Bucklin . 26 1090 1~.1 ~~ 0.05 1.1 S 6.20 Shallow A anent Wear. 27 1134 11 0.06 17 3 6.20 Moderate Bucklin . 28 1174 !~ 0.07 ~t) 8 6.21 Moderate Bucklin . 29 1214 ~~ 0.04 1 _' 6.19 Shallow A anent Wear. 30 1253 1) 0.06 15 4 6.22 Moderate Bucklin . 31 1297 C) 0.07 19 7 6.19 Bend. 32 1335 U 0.06 1 7 (~ 6.21 Sli ht Bucklin . 33 1378 (~ 0.05 14 ~1 6.21 Sli ht Bucklin . 34 1421 11 0.06 1 5 2 6.19 Shallow A anent Wear. 35 1465 U 0.05 14 G 6.22 Sli ht Bucklin . 36 1508 U 0.05 14 ~ 6.23 Sli ht Bucklin . 37 1551 U 0.04 10 _' 6.23 Sli ht Bucklin . 38 1591 11 0.05 1 _S ~ 6.21 Shallow A anent Wear. 39 1635 !? 0.05 13 6.23 Sli ht Bucklin . 40 1674 ! ~ 0.03 9 6.24 51i ht Bucklin . 41 1715 11. 1 t1 0.04 1 U 6.23 Sli ht Bucklin . 42 1755 lh 0.04 1 U 6.25 Line shallow corrosion. Sli ht Bucklin . 43 1794 t~ 0.04 lt1 6.24 Line shallow corrosion. Sli ht Bucklin . 44 1837 c1.(It~I 0.04 lt) 6.22 Line shallow corrosion. Sli ht Bucklin 45 1876 U 0.04 I (i s 6.23 Line shallow corrosion. Lt. De osits. 46 1916 U 0.05 14 r, 6.24 Shallow corrosion. Sli ht Bucklin . 47 1954 ! ~ 0.04 1 Z > 6.24 Shallow corrosion. Sli ht Bucklin . 48 1994 t) 0.05 1 3 h 6.23 Line shallow corrosion. 49 2037 t) 0.04 1(? 6.21 Line shallow corrosion. 50 2077 (r. I I 0.03 f3 I 6.20 Bucklin Ends @ 2 075'. ` Penetration Body Metal Loss Body Page 1 i PDS REPORT JOINTTABI. Pipe: 7. in 26.0 ppf J-55 Well: Body Wall: 0.362 in Field: Upset Wall: 0.362 in Company: Nominal LD.: 6.276 in Country: Survey Date: • ELATION SHEET 2T-17 Kuparuk ConocoPhillips Alaska Inc USA April 30, 2010 Joint No. Jt. Depth (Ft) I'en. i_Jpse+ (Ins.) Pen. Body (Ins.) Pen. °i~, Vlel,+l Ie~s~ `i~, Min. LD• (Ins.) Comments Damage Profile (%wall) 0 50 100 51 2121 +). I ~' 0.04 I _' 3 6.23 Line shallow corrosion. 52 2160 U 0.04 I ~' 6.22 Line shallow corrosion. 53 2199 t) 0.05 13 ~' 6.22 Shallow ittin . 54 2239 +) 0.04 !' ~ 6.24 Line shallow corrosion. 55 2283 U 0.03 " 6.23 Line shallow corrosion. 56 2322 +) 0.04 1 ~' 6.25 Line shallow corrosion. 57 2364 U 0.03 ~~ 6.23 Line shallow corrosion. 58 2407 i) 0.04 ! 6.20 Line shallow corrosion. Lt. De osits. 59 2450 +' 0.03 I 6.20 60 2490 !) 0.03 8 ~ 6.23 61 2534 ~) 0.03 S3 ~' 6.24 62 2573 !) 0.03 & 1 6.23 63 2613 t).I i 0.03 7 I 6.24 ~ 64 2657 U 0.02 6 1 6.24 65 2700 +) 0.03 ~ 1 6.24 66 2737 u.uts 0.03 8 6.25 - 67 2776 l).I1 0.02 t~ 6.24 ~ 68 2816 t) 0.03 ~ I 6.24 69 2856 i i 0.03 c3 ~ 6.24 70 2895 t i 0.02 (~ I 6.24 71 2935 a 0.02 6 ! 6.24 72 2974 a 0.02 (~ i 6.24 73 3014 O 0.03 ti ? 6.25 74 3054 t) 0.03 ti ! 6.24 75 "093 +t 0,02 b I 6.24 ~' 76 3133 t) 0.02 6 6.22 ~ 77 3173 +i 0.02 6 I 6.26 78 3212 t) 0.03 t3 I 6.24 79 3251 U 0.01 3 +) 6.23 80 3295 U 0.02 G _' 6.25 81 3335 0.(1b 0.02 6 I 6.25 82 3374 U 0.02 6 I 6.24 83 3414 U 0.03 t3 Z 6.26 84 3453 (> 0.02 6 I 6.23 85 3493 U 0.03 7 I 6.25 86 3533 +) 0.02 (~ 6.25 87 3572 O 0.02 ~ 6.25 88 3612 U. i ~~ 0.02 4 I 6.26 89 3651 +~.II 0.02 (~ I 6.24 90 3691 ~~ ~ 0.02 6 I 6.22 91 3731 +? 0.03 ,3 6.23 92 3770 a 0.02 t> 6.26 93 3810 ! ? 0.02 6 I 6.24 94 3849 ~? 0.00 1 I 6.20 95 3889 t ). i ~ 0.01 3 1 6.21 96 3929 t) 0.01 2 U 6.23 97 3968 +) 0.00 1 O 6.22 98 4008 +) I ~' 0.03 7 1 6.21 99 4042 +) 0 t? ~.~ 6.21 100 4084 +).I!~ 0.01 4 ~) 6.20 _ Penetration Body Metal Loss Body Page 2 • PDS REPORT JOINT TABI. Pipe: 7. in 26.0 ppf J-55 Well: Body Wall: 0.362 in Field: Upset Wall: 0.362 in Company: Nominal I.D.: 6.276 in Country: Survey Date: • ILATION SHEET 2T-17 Kuparuk ConocoPhillips Alaska Inc USA April 30, 2010 Joint No. Jt. Depth (Ft.) I'~~n. lllscl (Ins.) Pen. Body (Ins.) Pc~n. %, Mcl~~l loss °~~> Min. LD• (Ins.) Comments Damage Profile (%wall) 0 50 100 101 4127 O 0.00 1 O 6.20 102 4170 ~) 0 U U 6.21 103 4212 lJ 0 (1 l) 6.21 104 4256 1) 0.00 I O 6.20 105 4299 {) 0 U (1 6.21 106 4343 0 0 U 1 6.21 107 4387 i~ 0.01 1 n 6.24 108 4430 t ~ 0.02 ~> . 6.22 109 4471 (a 0 U !) 6.20 110 4514 U 0.00 1 ~) 6.20 111 4558 U.t)~3 0.02 5 O 6.22 112 4597 t1 0 U u 6.20 113 4641 a 0.01 ~ 1 6.20 114 4685 i) 0.01 ~) 6.22 115 4725 t) 0.01 I 6.23 116 4764 t? 0.00 1 u 6.21 117 4808 0 0.01 2 O 6.23 118 4847 t) 0.00 1 t) 6.21 119 4887 U 0.01 2 ~ ~ 6.22 120 4926 U.1 1 0.00 1 i ~ 6.21 121 4966 U 0.00 1 c? 6.20 122 5010 O 0 U n 6.20 123 5053 1) 0.02 6 1 6.21 124 5092 t) 0.02 6 I 6.20 ~_ 125 5132 O.U5 0.08 Z1 6.22 Isolated ittin 126 5171 U 0.04 1 U 1 6.20 Shallow ittin . 127 521 1 0.1 Z 0.02 b I 6.20 ~ 128 5250 U 0.05 ? ~ i 6.19 Shallow ittin Lt De osits. - 129 5290 i1 0.01 ~' i 6.19 130 5330 O 0.01 ~ U 6.21 131 5369 i) 0 tl 0 6.20 132 5409 O 0.01 2 O 6.21 133 5448 l).11 0.00 1 U 6.20 134 5492 ~) 0 U U 6.20 135 5535 O 0.01 2 i) 6.21 136 5575 i) 0.02 U 1 6.21 137 5615 i) 0.02 4 O 6.22 138 5654 i) 0.07 1~) I 6.19 Shallow ittin . 139 5694 U.I 1 0.02 !~ U 6.20 Lt. De osits. '~ 140 5737 t) 0.04 I1 i) 6.20 Shallow ittin . 141 5781 0 0.03 £3 I 6.22 142 5821 U 0.03 i I 6.22 143 5860 O 0.03 8 I 6.20 Lt. De osits. 144 5900 U 0.02 7 U 6.20 145 5939 O 0.03 9 1 6.22 Shallow ittin . 146 5979 U 0.02 7 1 6.21 147 6019 (~ 0.01 2 i) 6.22 148 6058 0.01 ? U 6.20 149 6098 t) 0.02 ~ i~ 6.20 150 6138 u. 1 i~ 0.02 -> I 6.22 _ Penetration Body Metal Loss Body Page 3 • PDS REPORT JOINT TABI. Pipe: 7. in 26.0 ppf J-55 Well: Body Wall: 0.362 in Field: Upset Wall: 0.362 in Company: Nominal I.D.: 6.276 in Country: Survey Date: • ILATION SHEET 2T-17 Kuparuk ConocoPhillips Alaska Inc USA April 30, 2010 Joint No. Jt. Depth (Ft.) P~~i~. Ul~~c-~t (Ins.) Pen. Body (Ins.) Pen. % ~~1c~t.~l logs °~~ Min. LD• (Ins.) Comments Damage Profile (%wall) 0 50 100 151 6177 t+.il 0.01 Z i) 6.22 152 6216 U 0 U U 6.20 153 6256 U 0.02 t~ I 6.21 154 6296 O 0.02 6 1 6.21 155 6335 (LUt> 0.01 2 !~ 6.20 156 6375 +) 0.01 2 t+ 6.21 157 6415 t) 0.01 _' i% 6.21 158 6454 +~.t i 0.00 1 +) 6.21 159 6494 ~) 0.02 6 U 6.21 160 6533 (> 0.00 i u 6.20 161 6573 O 0 t) i~ 6.21 162 6617 U 0.00 1 t) 6.20 163 6656 l) 0.00 1 i~ 6.19 164 6696 n 0.00 1 ~) 6.20 165 6735 U 0.01 ~ ~ 6.20 166 6775 +~ 0.02 b i ~ 6.21 167 6815 O 0.01 i± 6.21 168 6854 a 0.02 6 O 6.21 169 6894 t1 0.01 ~ +~ 6.21 170 6934 U 0.01 _~ it 6.20 171 6973 +) 0.01 ~ (~ 6.21 172 7012 O 0 U i 6.21 173 7052 n 0.04 1(1 6.20 Shallow ittin . 174 7091 l7 0.02 t~ i 6.21 175 7132 a 0.03 ~ r 6.21 176 7171 t) 0.01 ? !) 6.21 177 7215 i) 0.01 ~ +~ 6.20 178 7254 +) 0.00 1 i) 6.20 179 7294 (? 0.01 2 U 6.20 180 7333 !?. l rs 0.01 ~~ (~ 6.23 181 7372 t) 0.01 2 (? 6.21 182 7412 O 0.01 2 O 6.21 183 7451 U.l I 0.02 6 I 6.21 184 7490 O 0 0 U 6.23 185 7530 +) 0.01 3 ~ 6.21 186 7570 +~ 0.03 ti i 6.21 187 7609 (~ 0.01 ~~ 6.20 188 7648 (? 0 u ~) 6.25 189 7688 i+ 0 tl +~ 6.24 190 7728 t) 0 O t) 6.20 _ Penetration Body Metal Loss Body Page 4 ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ i ~ PDS Report Cross Sections t--~ -- - -- ~_„ Well: ZT-17 Survey Date: April 30, 2010 Field: Kuparuk Tool Type: UW MFC 40 No.218451 Company: Conoco Phillips Alaska Inc Tool Size: 2.75 Country: USA No. of Fingers: 40 Tubin 7 ins 26 f J-55 Anal st: J. Thom son Cross Section for Joint 125 at depth 5157.34 ft Tool speed = 43 Nominal ID = 6.276 Nominal OD = 7.000 Remaining wall area = 99 Tool deviation = 50 ° Finger 33 Penetration = 0.076 ins Isolated Pitting 0.07 ins = 21 % Wall Penetration HIGH SIDE = UP • Cross Sections page 1 ~ ~ ~ ~ r ~ ~ ~ ~^^ ~ ~s ~ ~ ~ ~ ~ ~ ~ ~ PDS Report Cross Sections ~, ~ „ Well: 2T-17 Survey Date: April 30, 2010 Field: Kuparuk Tool Type: UW MFC 40 No.218451 Company: Conoco Phillips Alaska Inc Tool Size: 2.75 Country: USA No. of Fingers: 40 Tubin 7 ins 26 f J-55 Anal st _ J. Thompson Cross Section for Joint 31 at depth 1299.23 ft Tool speed = 43 Nominal ID = 6.276 Nominal OD = 7.000 Remaining wall area = 98 Tool deviation = 33 ° Finger 2 Projection = A.078 ins Bend Min ID = 6.19 ins HIGH SIDE = UP • Cross Sections page 2 PDS Report Cross Sections ~~,.d_ ~.~~ ., Well: 2T-17 Survey Date: April 30, 2010 Field: Kuparuk Tool Type; UW MFC 40 No.218451 Company: ConocoPhillips Alaska Inc Tool Size: 2.75 Country: U5A No. of Fingers: 40 Tubin 7 ins 26 f J-55 Anal st: J. Thom son Cross Section for Joint 29 at depth 1214.08 ft Tool speed = 43 Nominal ID = 6.276 Upset OD = 7.000 Remaining wall area = 100 In upset region Tool deviation = 31 ° Finger 21 Projection = •0.062 ins Buckled Pipe Mind ID = 6.19 ins HIGH SIDE = UP Cross Sections page 3 ~`'~~ KUP ~ 2T-17 Conocort filli ps II Attributes An le 8 IND TD AI;{.,:,,, it t Wellbore APIIUWI 501032006000 Fieltl Name WeH Shlus nsl (°( MD IRKB) KU PARUK RIVER UNIT PRODUCING 53.50 3.800.00 Act Bbn (RKB) 8.445.0 Comnrenl NYS Ippm) SSSV~ TRDP 30 Date 1/112009 Mnotaeon Last WO: End Data KB-0rd (th 42.00 Rig Release Date 3/10/1986 well Con I - T-17 R /22/?009'_ s9 a s r-M moo - dual Mnotatlon Depth tBK6) End Date Annefatlon Laat Mad By End Date Last Tag: SLM 327.0 7!72009 Rev Reason: TAG. ADD NOTE tri Iwj 7/82009 Casin Strin s Casing DesaipDOn String 00 lm) Strirg ID Pn1 TaD ItBr61 Set Depth IMBI Sal Depth (rVD) MKBI String Wt (lbs/Iq Strlnp Wade String TOp Thrd CONDUCTOR 1 6 15.062 36.0 116.0 116.0 62.50 40 coNwcroR. 11s SURFACE 95! 6 8.765 0.0 3.671.0 2,797.3 36.00 -55 PRODUCTION 7 6.151 0.0 8,438.0 6,239.4 26.00 -55 SAFETY vw. 1 810 o: Tubin Strin s , Tubing Dessdptlon String OD 8n1 Strlrg ID 8n) Top QD(B( Set Depth (RKB( Set Depth (TVD( lM(6) String Wt QbsIR) String Orada String Top Thrd cASUFr, 3 076 TUBING 2 7/ 8 2.441 0.0 8,046.0 5,923.9 6.50 -55 MOD EUE RD Other I n Hole A ll Jewe l :Tubin Run 8 ReMevabl Flsh etc. SURFACE 3,6]1 Top mKg) Top Depth (TVD( (fIKB( Top Inc! (°( Description Comment Run Date (ln( 1,810 1,636.7 49.38 S AFETY VLV emco TRDP-tA-SSA /7/1986 2.312 cASUFT. 5,141 3,076 2,440.1 53.03 G AS LIFT MCO/ICBMG/1/GLVBK/.188/1278/Comment: STA1 2/11/1994 2.347 5,141 3,808.8 42.97 G AS LIFT AMCOMBMG/1/OVBK/.25//Canmenk STA2 2/11/1994 2.347 6,230 4,585.2 44.99 G AS LIFT MCOMBMG/1/DMYBK///Comment: STA3 /7/1986 2.347 GASLIFT s 230 6,870 5,040.8 44.56 G AS LIFT MCO/KBMCat/DMYBK///Comment STA4 /3/1990 2.347 7,219 5,292.3 44.15 G PS LIFT MCO/KBMCJI/DMVBK///Canment: STAS !//1986 2.347 7,537 5,526.5 41.19 G AS LIFT MCO/KBMC~l1/DMYBK///Canment: STA6 /7/1986 2.347 cnsrLl Fr, ,,ao 7,700 5;650.5 39.48 G AS LIFT MH/FMHO/1.5/DMY/RK///Comment: STA7 /5/1990 2.347 7,743 5.683.9 39.06 P BR HPT(Bravn) !111966 2.500 7,760 5,697.1 38.89 P ACKER HPT'HB' Retr. hyd set !7/1986 3.000 cos uFT, 7.21s 7,828 5,750.2 37.68 P RODUCTION AMCO/KBMG/1/DMYBK/// Comment: CLOSED, STA 9 28/1995 2.347 7,898 5,805.6 37.34 P RODUCTION MCO/ICBMG/1/DMYBK///Comment: CLOSED, STA9 2811995 2.347 8,000 5,686.9 36.85 P RODUCTION MCO/KBMG/1/DMYBK///CcmmenF. CLOSED, STA 10 26/1995 2.347 cnsuFT 7,53] 8,023 5,905.5 37.01 P ACKER HPT'1-B' !711986 2.500 8,034 5,914.3 36.96 N IPPLE amco'l7 Nipple NO GO x//1986 2.250 8,041 5,919.9 36.93 S OS emco Shear Out d Re-Entry Guide 71/1986 2.441 cos LIFT ].700 8,043 5,921.5 36.92 T TL ELMD TTL @ 8043.5' during PERF RECORD on 09/06/86 71/1986 2.441 8,089 5,958.2 36.72 FI SH Laver Helf of GLV Lost in Rathde from 5/13/88 /15/1990 Perforations 8 Slots PBR, 7,743 Top (RI(BI etrn (RKB) ToP (TVD) (M(B( Btrn (TVDI IBKB( Iona Date Shot ens sh-• Type Comment 7,956 7,988 5,851.8 5,877.3 G 2 4, UNIT B, T-17 77/1986 12.0 PERF 20 deg Phase 5" HyperJet II PACKER.-i 760 8.095 8,102 5.963.0 5.968.6 4, 2T-17 77/1986 4.0 PERF 0 deg. Phase; 4" HyperJet II 8,116 8,147 5,979.9 6,004.8 3, 2T-17 !7/1986 4.0 PERF 0 deg. Phase; 4" HyperJet II PRODUCTION, 8 Notes: General 8 Safe ], 2P End Date Mnotetlen 522/1995 NOTE: WAIVERED WELL: IAx OA ANNULAR COMMUNICATION 7772009 NOTE: TAG 327' SLM (1.5" SLINKY TOOL STRING), PRIOR TAG 8079, 426/1995 PRODUCTION, ] ase IPERF, 7 956] 9R8 PRODUCTION, R V00 PACKER,8023 NIPPLE. 8.034 SOS. 8,041 TTL, 8,093 FISH. 6089 (PERF, 6 0958 102 (PERF 6.1168 147 PRODUCTION, 4,436 TD. e,445 re a ~ er ge 15 of 32 04724/10 • • ~~~aJ~ 0~ al~p~~{Q /~,.a~ao~~w J. Brett Packer Wells Engineer ~ l•~ ConocoPhillips Alaska, Inc. c~~~~~h~~t>~~;~, ~~,~ ~, {~ ~~1~`> ~y(~j`~ P.O. Box 100360 Anchorage, AK 99510 Re: Kuparuk River Field, Kuparuk River Oil Pool, 2T-17 Sundry Number: 310-103 Dear Mr. Packer: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. ~~ Sincerely, Daniel T. Seamount, Jr. Chair DATED this day of April, 2010. Encl. • • Page 1 of 1 Schwartz, Guy L (DOA) From: Packer, Brett B [J.Brett.Packer@conocophillips.com] Sent: Thursday, April 08, 2010 9:07 AM To: Schwartz, Guy L (DOA) Subject: RE: 2T-17 RWO (PTD 186-043) Guy, In response to your questions: 1. The OA is arctic packed. 2. If we can pull the tubing through the 7", we will know that it drifts to a minimum of 5.5" because of the OD of the GLM's. We will then run a scraper and caliper of the 7" casing. The multi-string cutter also has an OD of 5.5", so no matter what, if the tubing comes out, we should be able to get the cutter down. 3. The top flange is rated for 5,000 psi and the tubing packoffs were tested good to 5000 psi, and COP internal policy is to BOP test at least 1000 psi above MASP, so that is why I went with a 3500 psi BOP test (MASP = 2258 psi). ,7. Brett Wacker ~DriQsng e.'/'WelCs `Wort yver Engineer 'Work# (907) 265-6845 Cell# (907) 230-$377 From: Schwartz, Guy L (DOA) [mailto:guy.schwartz@alaska.gov] Sent: Thursday, April 08, 2010 8:45 AM To: Packer, Brett B Subject: 2T-17 RWO (PTD 186-043) Brett, Couple of questions. 1) Is the OA antic packed?? I am assuming so. 2) Do you have a contingency plan if you can't drift the 7" casing after you pull tubing??? 3) You also state in step 1 to test the BOP to 3500 psi. Don't you want that as 3000 psi since it is a Gen IV. Guy Schwartz Senior Petroleum Engineer AOGCC 793-1226 (office) 444-3433 (cell) 4/8/2010 Cc~~~~~ ~ i has Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 April 6, 2010 Commissioner Dan Seamount State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7'h Avenue Suite 100 Anchorage, Alaska 99501 Dear Commissioner Seamount: RECEIV€~ APR Q ~ 201 ~ ~~ isSion ConocoPhillips Alaska, Inc. hereby applies for an Application for Sundry Approval to workover the - Kuparuk Well 2T-17 (PTD 186-043). 2T-17 was originally completed in September of 1986. The well is a selective single gas lifted producer located in an area with surface subsidence due to permafrost thawing. This well has had a history of IA x OA communication and has been waivered for quite some time. The communication is most likely due to a minor thread leak as the surface casing repeatedly passes an MITOA and a drawdown test. The tubing, although corkscrewed, regularly passes a TIFL and appears to have mechanical integrity. The actual condition of the production casing is unknown, as we have not been able to dummy off the gas lift mandrels and get an MITIA due to the corkscrewed tubing. In September 2009, the lift gas to this well was SI in response to gas bubbling around the VSM's and wellhouses on 2T pad. Although further testing has indicated that this well is not the suspected source of the gas, the lift gas lift was to remain shut in; and consequently, the well was shut in because it struggled to produce without artificial lift. This well remains shut in while ConocoPhillips plans to take proactive measures to mitigate future potential subsidence related problems. The purpose of this workover is to replace the corkscrewed tubing, cut & pull a portion of the 7" casing, rerun new 7" casing, and circulate cement into the 9-5/8" x 7" annulus. The 7" casing work is not required to fix an existing problem, but it will be done while the rig is on the well as a proactive measure. New 2-7/8" L-80 tubing along with a stack packer will be run into the well to repair the corkscrewed tubing. If you have any questions or require any further information, please contact meat 265-6845. Sincerely, - ~.~ ~~~ J. Brett Packer Wells Engineer CPAI Drilling and Wells $,~'~ STATE OF ALASKA ~~ ALASK~L AND GAS CONSERVATION COMMISSIO APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 E~~~~'I~ APR p ~ ZQ1Q 1. Type of Request: Abandon ~ Rug for Redrill ~ ~ Perforate New Pool '" .Repair well ~ ~,gjp Suspend ~"- Rug F~rforations ~ Perforate ~'- $.) n q~nsion Full Tubing ~ Operational Shutdow n ~ Re-enter Susp. Well ~' Stimulate ~' ~ After casing Other: 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development ~, Exploratory r 186-043 3. Address: Stratigraphic Service 6. API Number: P. O. Box 100360, Anchora e, Alaska 99510 50-103-20060-00 7. If perforating, closest approach in pool(s) opened by this operation to nearest property line 8. Well Name and Number: where ownership or landownership changes: Spacing Exception Required? Yes No ~I 2T-17 9. Property Designation: 10. Field/Pool(s): ADL 25569 Kuparuk River Field /Kuparuk River Oil Pool 11. PRESENT WELL CONDITION SUMMARY Total depth MD (ft): Total Depth ND (ft): Effective Depth MD (ff): Effective Depth ND (ft): Plugs (measured): Junk (measured): 8445 ~ 6245 • 8248' 6084' 8089' Casing Length Size MD ND Burst Collapse CONDUCTOR 80 16 116' 116' SURFACE 3671 9.625 3671' 2797' PRODUCTION 8438 7 8438' 6239' Perforation Depth MD (ft): Perforation Depth ND (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 7956'-7988', 8095'-8102', 8116'-8147' 5852'-5877', 5963'-5969', 5980'-6005' 2.875 J-55 8046 Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft) PACKER - HPT 'HB' RETR. HYD SET MD= 7760 ND= 5697 PACKER - HPT '1-B' MD= 8023 ND= 5905 TRDP - CAMCO TRDP-1A-SSA MD= 1810 ND= 1636 12. Attachments: Description Summary of Proposal 13. Well Class after proposed work: Detailed Operations Program ~ BOP Sketch ~' E~loratory ~ Development Service 14. Estimated Date for Commencing Operations: 15. Well Status after proposed work: 4/25/2010 Oil ~ Gas WDSPL Suspended 16. Verbal Approval: Date: WIND ~ GINJ ~ WAG Abandoned Commission Representative: GSTOR ~ ..~ SPLUG ri 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: J. Brett Packer @ 265-6845 Printed Name J. t Packer Title: Wells Engineer ~~~~ ~ ~/ f ~O /,~( D t Signature ~ e a Phone: 265-6845 I Sundry Number. ~~ ~- lO~j // Conditions of approval: Notify Commission so that a representative may witness Plug Integrity [~' BOP Test Mechanical Integrity Test r Location Clearance [' ~ 3~ psi /~d P !mss (- Other. ®® ~- ,,~ Z •SOO PS e. /4n h.+...[a.r (c. S'7~ ~ r^.e"~ J Subsequent Form Required: / ~,YDS/ APPROVED BY ~ /~ Approved bv: ~ COMMISSIONER THE COMMISSION Date: Form 10-40 is~~2 Q 9 R ~ ~ ~ { V A ~ ~{• ~ • /6 r Submit in Duplic ~ (/~ • • 2T-17 Expense Rig Workover (PTD #: 186-043) Current Status: The well is currently shut in awaiting a Workover to replace the corkscrewed tubing and proactively repair the 7" production casing. This well is located in an area with surface subsidence due to permafrost thawing. This well has subsided a total of 49" as of February 2009. Indications of corkscrewed tubing have been seen as early as 1995, and has limited our ability to get any tools downhole. We have been unable to drift the tubing to set any downhole plugs. The well .passes a TIFL and MIT-OA indicating competent tubing and surface casing. We are unable to dummy off gas lift valves to get an MIT-IA, but the IA fluid level does not change during a drawdown test. Scope of Work: Replace the corkscrewed tubing, proactively cut & pull a portion of the 7" casing, re-run new 7" casing, circulate cement into the 9 5/" x 7" annulus, and install a stack packer with new 2 %a" L-80 tubing. General Well info: MASP: 2,258 psi Reservoir pressure/TVD: 2856 psi / 5984' TVD --~ `x.17 ('P~} Wellhead type/pressure rating: Cameron Gen IV " 3K btm x7-1/16" 5K top flange BOP configuration: Annular /Pipe Rams /Blind Rams /Mud Cross /Pipe Rams CMIT and MITOA results: MITOA-passed, no CMIT. Well Type: Producer / D fl i s /4r..~': c ~..c.Fe.Q w~ cG....s...~ S!-r,, e . Estimated Start Date: April 25, 2010 Production Engineer: Mike Balog /Evan Reilly Workover Engineer: Brett Packer (265-6845 / j.brett.packer@conocophillips.com) Pre-Ria Work Request: 1. Set BPV. Proposed Procedure 1. MIRU Nordic 3. Pull BPV. Reverse circulate 9.6 ppg brine through the OV at 5141' RKB to surface. Close the tubing and bullhead 9.6 ppg brine to the formation. Verify well is dead. Set BPV. ND tree. NU 11" 5K BOP. Pressure test BOP including annular to 250/3500 psi. . 2. Pull blanking plug and BPV. Reverse circulate hole clean. Attempt to pull tubing. A. If tubing does not pull free from PBR, set tubing intension, RU E-line and cut tubing above PBR. POOH with tubing 3. Run 7" scraper assembly to top of tubing stub. 4. RU E-Line. Run caliper log, gyro survey, and cement bond log in 7" casing from tubing stub to surface. Based on cement top, determine depth of 7" collar to back off following casing cut. RIH and fire string shot across that collar. RD E-Line. 5. Set retrievable bridge plug below top of cement. Pressure test to 2500 psi and drawdown test to 0 psi. Dump sand on top of RBP. 6. POOH to drill collars, install storm packer and hang off in 7" casing below surface (to reduce casing compression at the wellhead). 7. ND BOP and tubing head. Spear 7" csg and pull in tension and reland in slips. Tack weld slips to casing. 2 be~.rr;err - t) S~ro~cM P~~~-t-e. 2) R d P >. ~ • ~-Proposed Procedure Continued~~ 8. NU 11" 5M BOP on casing head. Pressure test break to 3000 psi. 9. Retrieve storm packer. 10. Cut 7" casing with mechanical cutter above TOC. Circ 9-5/8" x 7" annulus clean w/ hot seawater. 11. Spear and POOH laying down 7" casing. 12. Run 9-5/8" casing scraper to top of 7" stub. Circ clean. 13. RU E-Line. Run caliper log and gyro survey in 9-5/8" casing. RD E-Line. 14. Run back off tool and back off casing stub. 15. Run tandem string mills to gauge the 9 %" csg for the ES cementer. 16. Spear and recover backed off 7" casing stub. 17. RU E-line and run caliper log. RD E-line. 18. RIH with new 7" casing and Halliburton ES cementer. Screw into top of 7" casing. Pressure test casing. 19. Open ES cementer and pump cement into 9-5/8" x 7" annulus. Close cementer. 20. WOC. ND BOP, pull 7" and land in slips. Cut 7" casing and install packoff. NU new tubing head. 21. NU 11" 5M BOP and test break to 3000 psi. 22. Drill out cement. Pressure test casing to 2500 psi. . 23. RIH with wash shoe and circulate out sand on top of RBP. POOH. RIH w/ retrieving tool on work string. Release RBP and POOH. 24. RIH with poorboy overshot, packer, and PBR on 3-1/2" drill pipe. Go over tubing stub. Circ in corrosion inhibited fluid. Set packer. POOH laying down drill pipe. 25. RIH with new 2 %a" tubing and seal assembly. Load tubing and IA with corrosion inhibited fluid. Stab into PBR, space out and land. Pressure test tubing and IA to 2500 psi. Shear SOV. 26. Set 2-way check. ND BOP. NU tree and pressure test. 27. Pull 2-way check. Freeze protect well. Set BPV. RDMO Nordic 3. ' Post-Rig Work request: 1. Pull ball and rod. Pull SOV and run new gas lift design. Pull RHC body. 2. Return well to production. ~r ~onocoPhiilips CONDUCTOR, 116 SAFETY VLV, _ 1.810 GAS LIFT. 3,0]6 SURFACE, 3,6]1 GAS LIFE, s.1a~ GAS LIFT, 6.230 GAS LIFT, 6,8]0 GAS LIFT, 7.219 GAS LIFT. 7.537 GAS LIFT. 7,700 PBR. ].]43 PACKER, 7.]60 PRODUCTION. _._ __ ].828 PRODUCTION, __ _. _. _ ],898 IPERF, 7,956-7.988 PRODUCTION, -__ 8.880 PACKER, 8.823 NIPPLE,8034 SOS, 8 041 TTL, 8,043 - FISH. 6.09H IPERF. 8,095-8,102 IPERF. 6.1168.14] ~ KUP Ibore APIIUWI Field .501032006000 KUP/ ment SV: TRDP 2.97 GAS LIFT CAMCOIKBMG/1/OV/BK/25// Comment_ STA 2 12/11/1994 i I 2.347 1.99 GAS LIFT CAMCO/KBMGl1/DMY/BW//Comment: STA3 9A/1986 1 2.347 4.56 GAS LIFT CAMCO/KBMG11lDMYlBW//Comment: STA4 8/3/1990 2.347 1.15 GAS LIFT CAMCO/KBMGl1/UMYlBK///Comment: STAS 9/7/1986 : 2.347 1.19 GAS LIFT CAMCO/KBMG/1/OMYlBW//Comment: STA6 9!7/1986 ~ 2.347 3.48 GAS LIFT MMH/FMHO/1.5/DMY/RW/I Comment: STA 7 8/5/1990 2.347 3.061 PBR HPT (Brown) 9/7!1986 2.500 3.89i PACKER HPT'HB' Retr. hyd set 9/7/1986 3.000 7.681 ~PR000CTION CAMCO/KBMGl1/UMYIBK!//Comment CLOSED, STAB 4/28/1995 2.347 7.34 PRODUCTION CAMCOIKBMGl1/DMY/BKI!l Comment: CLOSED, STAS 4728/1995 2.347 1.85 PRODUCTION CAMCO/KBMG/1 /DMYIBKf!/ Comment: CLOSED, STA 10 4126/1995 2.347 7.01 PACKER HPT'i-8' 9/7!1986 2.500 1.96 NIPPLE Camco'D' Nipple NO GO 9!7/1986 2250 9 SIt', 8 765 0 0 3.671 0 ~ 797.3 36.00 J-55 7'I 6-151 0 0' ~ 438.(1 6.239.4 25 00 J-55 ring OD '~, Str g ID 'i ~ i Set Depth Set Depth (TVD) String Wt String (i^) (^I 'i 1 Top (ftK8( ~, (kK81 (ftK8) (Ibs/ft( Grade Sir ng Top Tl 2718 2441 00~ 8,0430 5923.9 6.50 J-55 AB-MOD EUI Jewelry: Tubin g Run & Retrievable , Fish, etc.} ~ 8RD Intl ') Description Comment _ _ Run Date ID 3.38 SAFETY VLV Camco TRDP-tASSA ~9l7/1986 2. 3.03 GAS LIFT CAMCOIKBMG/1IGLV/BK/.1 8 8 /1 27 81 Comment: STA i 12111/1994 2. 2T-17 Max Angle & MD ~TD ~=~ Well Status Inc!(") MD(fiK6) ACt Btrn (kK8) RIVER UNIT PRODUCING 5"3.50 3,800.00 8 445 0 Date 5(ppm) Annotation End Date KB-Grd (ft) Rig Release Date ( 30 1/11/2009 Last WO: 42.00 3/10!1986 i Date '~ Annotation Last Mod By ~, End Data 'A/2009 Rev Reason 1 AG, AUU NO I E triplwj 7/8/2009 ~C String ID Set Depih Set Depth (iVDI String Wt String i (in) Top (kK8( (ftK8) (kK8) (Ibs/ft) Gratle String Top Thrd 15.062. 36.0 116.0 116.0 6250 H-40 ' 8,041 5 919.9,1 36.93 SOS Camco Shear Out 8 Re-Entry Guide 9/7/1986 2.441 8,043 5 921.5 36.92'.Tl L ELMD TTL @ 8043.5'tluring PERF RECORD on 09/06/86 9A/1986 2.441 8.089 5958 2 35.72+ISH Lower Half of GLV Lost In Rathole from 5!13/88 8/15/1990 'erforations 8 Slots ---- -- snot Top (TVD) Btm (TVD) Dens op (kK6) 81m (ftK8( (ftK8) (ftK8) Zone Date (sh... Type Comment 7,956 7,988 5,851.8 5,877.3 C-0, UNIT B, 9/7/1986 12.0 (PERF 120 tleg Phase 5'HyperJet II I 2T-17 8,095 8,1021 5,963.0 5,968.6 A-0, 27-17 9/7/1986 4.0 IPERF 190 deg. Phase; 4" HyperJet II 8,116 8,147' 5,979.91 6,004.8 A-3, 2T-17 totes: C,enerall& Safety., End Date /22/1995 NOTE~WAIVEREU WELL: IAxOA ANNUI 17/2009 NOTE: TAG 32T SLM (15"SLINKY TOOL ,TION TAG 8079, 4/26/1995 PRODUCTION,_ 8638 TD.8445 • • Page 1 of 2 Regg, James B (DOA) From: Bradley, Stephen D [ Steve .Bradley @conocophillips.com] Sent:. Tuesday, March 02, 2010 2:46 PM � y� To: Regg, James B (DOA) Subject: 2T -17 Annular Pressures Hi Jim, Perry asked me to provide some additional info regarding 2T -17 from an operations perspective. Described below are some of the details. We are continuing to gather information on this well and will keep you in the loop. Please give me a call if you want to discuss or I can come by your office later this week. As a result of the known, historic anncomm problems (IAxOA) and the new suspect subsidence issues (unable to drift tubing) the decision was made to shut in Well 2T -17 on 12/11/09. We have this well on our workover schedule for May 2010. The slickline crew that reported the wellhead pressures on 2/19 was actually working on the well in preparation for the upcoming workover. The lift gas line to the well was blinded off on 9/11/2009. During the period -of 1/25 - 2/19, the operator(s) incorrectly entered the IA daily pressures in the morning report system by failing to click the manual entry selection. This caused the pressure measured by the pressure transmitter on the lift gas line (which was essentially 0 psi since it was blinded) to be recorded in the system as the IA pressure rather than the manual entry. On a normal gas lifted producer, the lift gas line pressure will normally be equal to the IA pressure, but since this well had the lift gas line blinded off, the pressure that was being recorded in the TIO data base was the lift gas line pressure rather than the annulus pressure. We corrected this problem on 2/19 in the database and also pointed out the problem to the operator(s). We installed an OA pressure transmitter on this well on Nov 3rd, 2009 . The pressure transmitter was incorrectly programmed in SCADA to indicate an IA pressure measurement. Also, the data was not programmed to automatically record in the TIO database. Since the well had a pressure transmitter installed on the OA, the operator(s) relied on the pressure transmitter to record the OA pressures and since the OA transmitter was not programmed correctly, the pressure transmitter data was not recorded in the TIO system. We have corrected this problem as well. The Well Integrity group is continuing to do some diagnostic work on this well to better understand the current state of the well and to be able to better define the scope of the upcoming workover: A shut in TIFL was performed 2/23/09. PRE TIO= 2200/2200/595. The IA fluid level was found at the OV, 5141'. After bleeding the IA, the final TI0= 2200/1050/205. There was no inflow. The IA fluid level remained at 5141'. Slow TxIA communication was observed with the IA climbing from 1050 on the 23rd to 1118psi on the 24th, and 1380 psi on the 26th. The tubing was loaded with diesel on 2/26, initial TIO= 1720/1380/210, final TIO = 660/1390/320. The tubing pressure has been stable post load, the IA pressure is dropping as the gas cap bleeds slowly to the OA as is expected due to the historic IA x OA communication. The calculated pressure differential at the OV considering surface pressures and a column of diesel in the tubing was approximately 600 psi greater in the tubing than IA. Despite this pressure difference, the fluid level in the IA remained at the OV indicating a slow TxIA leak with a column of gas in the tubing and integrity when it is diesel filled. In the interim, bleed the IA and OA to — 200 psi and continue to closely monitor the well. We do not plan to put this well back in service until after the workover. In addition, we are taking this opportunity to do refresher training for our operators on well operating guidelines, pressure recording, and reporting. Thanks, Steve Steve Bradley Kuparuk Operations Manager 659 -7219 3/3/2010 • • Page 1 of 4 Regg, James B (DOA) From: Regg, James B (DOA) �� 3/1 1 10 Sent: Monday, March 01, 2010 12:37 PM I\ I To: NSK Well Integrity Proj Subject: RE: 2T -17 (PTD 186 -043) Report of SCP Attachments: 2T -17 Revised Waiver Prod 05- 12- 03.xis The monitoring approach required per CO 494, Rule 2 is fundementally flawed without verification of the accuracy of pressure measurement devices. Daily pressure monitoring doesn't mean a thing if the field personnel are only looking at a pressure gauge and writing down a (wrong) number. What is CPAI's PM practice for wellhead pressure measurement devices used at 2T -17? Please provide a copy. There needs to be a more complete explanation supported with pressure history. Some questions: - how long was OA instrumentation operating with "a problem "? - since instrumentation is now "working correctly ", what are the current pressure readings? Are these representative of actual past pressures; if so, based on what? - re: "morning report data, manually recorded data 1//26/10 - 2/20/10 was inaccurate" - inaccurate compared to what? what does this mean? - what is meant by operators "are now aware of this well's specific details "? - did OA pressure exceed the 1400psi limit in the internal CPAI waiver (approved 5/13/2003)? And, what about the apparent TxIA communication? Since there was no mention of there being an instrumentation problem with the IA, the equalized tubing and IA pressures should invalidate the waiver. Results of most recent TIFL? Jim Regg AOGCC 333 W.7th Avenue, Suite 100 Anchorage, AK 99501 907 - 793 -1236 From: NSK Well Integrity Proj [ mailto :N1878 @conocophillips.com] Sent: Thursday, February 25, 2010 10:32 AM To: Regg, James B (DOA) Cc: NSK Problem Well Supv Subject: RE: 2T -17 (PTD 186 -043) Report of SCP Jim, There has been no recent report of SCP for 2T -17 other then the report on Feb 20th. Well 2T -17 is internally waivered by CPAI for IAxOA communication. Waiver documentation is included in the quarterly SCP reports to AOGCC. The annulus for 2T -17 has a DNE of 1400 psi. There are no typographical errors in regards to the TIO pressures observed and reported less the errors in the 90 day TIO plot, which are discussed below. The T /I /O = 2225/2225/1813, when the SCP was observed. I've requested that operations provide details surrounding the event. Please see these below. Jim, Perry, Per your request 3/1/2010 is Page 2_of-4 "Upon discovery of the annulus pressures on 2T -17 on 2/19 by the slick line crew, and further investigation at the wellhead, we found a problem with the instrumentation used to record the OA pressure. This has been repaired and is now working correctly. In addition to the instrumentation problem, we identified that the morning report data, manually recorded between 1/26/10 - 2/20/10 was inaccurate. We have addressed this issue with the operators, and they are now aware of this well's specific details and we have been accurately recording the data since the problem was initially discovered." If more details are needed please let us know. Please let me know if you have further questions. Sincerely, Perry Klein Well Integrity Project Supervisor ConocoPhillips Alaska, Inc. Desk Phone (907) 659 -7043 Cell Phone (907) 943 -1244 Voice Pager 659 -7000 x937 From: Regg, James B (DOA) [mailto:jim.regg @alaska.gov] Sent: Tuesday, February 23, 2010 11:42 AM To: NSK Problem Well Supv Cc: NSK Well Integrity Proj; Maunder, Thomas E (DOA); Schwartz, Guy L (DOA) Subject: RE: 2T -17 (PTD 186 -043) Report of SCP OA pressure of 1813psi would be 51.5% of MIYP (9 -5/8" J55, 36ppf; MIYP = 3520psi). Is is a typo (reading IA pressure)? I don't see either the IA or OA pressures you are reporting on the attached 0 plot. You indicate immediate response was to bleed OA pressure to 500psi - that d' not occur until pressures had increased to nearly 1500psi. I cannot accurately interpret the time scale o our TIO plot, but it appears this was about 3 weeks after exceeding the 1000psi notification threshold requir by CO 494. [I interpret the TIO plot as showing OA pressure exceeding 1000psi the first week of January essure bled 3rd week of January] checked our records and do not find notification of the 0 ressure exceeding 1000psi in KRU 2T -17. Only SCP notice I have found was for wells KRU 2T -04, 2T- , 2T -10, 2T -11, 2T -15, and 2T -16 on April 20, 2009 (addressing subsidence issues on 2T). This one needs some additional review an larification. Thank you. Jim Regg AOGCC 333 W.7th Avenue, Suite 100 c))� \ Anchorage, AK 99501 907 - 793 -1236 3/1/2010 Notice of Ku P aruk Waivered Well WELL: 2T -1 7 WELL TYPE: Producer Gaslift DATE: 05 -13 -03 ....................... ................................ ............................... ..... ............................... p - 2540 WATER CUT = 82 % Production Data: OIL= 450 bo d GOR - ............... Pressures: Tubin IA OA Producing: 335 psi 1256 psi 1250 psi Shut -In: 1000 psi 1300 psi 1280 psi REASON FOR NOTICE: Production casing by surface casing communication (IA x OA) TUBING x IA COMMUNICATION? YES NO XX • TIFL passed 05/12/03 showing no T x IA communication. IA x OA COMMUNICATION? YES XX NO • IA x OA communication has been evident since 1995 when it was first waivered; • Production casing packoffs passed positive and negative pressure tests in 1997; • Annulus trends and recorded bleeds indicate a constant but slow leak from the IA to OA; • IA x OA communication exists and may be downhole or through the casing packoffs. IMPORTANT CONSIDERATIONS /COMMENTS: • Well requires gas lift to produce; • Production casing packoffs may be leaking based on 10/04/97 test; • Surface casing has integrity based on passing MITOA @ 1800 psi on 05/12/03; • The surface casing has a cement shoe and Arctic Pack pumped 04/18/86; • IA x OA communication may be downhole or through production casing packoffs. PLAN OF ACTION: XX Grant waiver to continue operations ......... .I ............................. • Allow operation with gaslift as needed; • Allow OA to equalize with IA pressure up to 1400 psi; • Monitor well head pressures daily and log as per surveillance requirements into Setcim; • Perform the following waiver compliance testing: • 2 -year TIFL / MITOA @ 1800 psi alternating with a 2 -year OA fluid level; • A failing MITOA will void the waiver and require SI the well and securing; • T x IA communication (failed TIFL) will void the waiver and require SI the well and securing. Problem Well Supervisor CPF Production Engineer Problem Well Supervisor Date: Date: ENDORSEMENT: CPF Supervisor Date: Wells Team Leader Date: Distribution: Send Original to: Problem Well Supervisor, NSK -69 DS Operator CPF PE Wells File and schematic Central Files ATO Central Files Kuparuk Page lof/ Regg, James B (DOA) From' RagQ James _ . , (0 Sent: Tuesday, February 23.2O1O11:42AM To: 'NGK Problem Well Supv' Cc: NSKVVeU Integrity P j; Maunder, Thomas E (DOA); 8ohvvortz. Guy L (DOA) Sub RE: 2T'17(PTO1 Report ofSCP OA proaouna cf1813paiwould be 51.5% ofKX|YP (9-5/8" J55, 36ppt K8|YP = 3520pai). Is this typo (reading |A pressure)? I don't see either the IA or OA pressures you are reporting on the attached TIO plot. You indicate immediate response was to bleed OA pressure to 500psi - that did not occur until pressures had increased to nearly 1500psi. | cannot accurately interpret the time, scale on your TIO plot, but. it appears this was about 3 weeks after exceeding the 1 000psi notification threshold required by CO 494. [Unbarpnet the T|(J plot ao showing OA pressure exceeding 1000psi the first week of January; pressure bled 3rd week of January] | checked our records and donot find notification of the O/\ pressure exceeding 1OO8pmiinP{RU2T-17. Only 8CP notice | have found was for wells KRU2T'O4.2T-O9.2T'1O.2T-11.2T-15. and 2T-1Gon April 2O.2OD0 (addressing s bsidenoeissues on2T) ' This one needs some additional review and clarification. Thank you. Jim Regg AOGCC 333 W.7th Avenue, Suite 100 Anchorage, AK 99501 From: NSK Problem Well- Supv [mailto:n1617@conocophillips.com] 3A Sent: Saturday, February 20, 2010 6:49 PM To: Maunder, Thomas E (DOA); Regg, James B (DOA); Schwartz, Guy L (C I q5(,) 3�26p - Cc: NSK Well Integrity Proj; NSK Problem Well Supv Subject: 2T-17 (PTD 186-043) Report of SCP Tom. Jinn, Guy Nuporuhgas lifted producer 2T-17 (PTD 186-043) was reported to have 8CP on the IA and the OA. The TlO that was observed is 2225/2225/1813. The well has been G related issues on 2T pod. Immediate action taken was to bleed the OA dow -- to i� The weather on the North Slope had deteriorated and further diagnostics have been de|ovad unti| the weather improves. Further actions will include performing a SI TIFIL to verify suspected TxIA communication, possibly pumping kill weight fluid down the T and [A, and at worst case scenario, pumping cement down the tubing. The appropriate paperwork will be submitted pending which actions will betaken. Attached iaa9O day T|[> plot and aschematic. P|aaaa let me know if you have any questions. Brent Rogers/Martin VVo|baro Problem Wells Supervisor Con000PhiUipa Alaska, Inc. Oaoh Phone (007) 859-7224 � 2/73/2010 KRU 2T-17 PTD 1 860430 2/2 0/2010 TIO Pressures Atti!(�1ULlJ Pf2ESUF� END 3000. 300 zoD. 3DOD. ' 300(1: 270n 3000. 2AUn 3000. 2100 t i, ■rri r■i ■■ —■■ 900 ', ��t ■� / __ ■■ ■3 ■■:'poi ■■ tl ' hL� �:T T1M1 MINOR TIME: -1 i` 21 -hJ(iV Q9 ].3:21 MA.IOR `I'IMEWEEf: +02ifi0:Ut1:OO p� <,19- FI ?Fi -lO 13::1 Plcx rINF. 17- FEH -10 03:32:10 � i I I -� A �� 'fAG NAME UE >C$IPTiON Y YhLUb: 1hT�' >"f� P WLZT- 17- CfiOKE FLOW TUBING CHOKE j� PREV WELL r SCRATCH 40 FLOW TUBING PRESSURE ?7 ? ? ? ?? i 2T 17 idEXT WELL � Al P2 I'5OO2 17 GL CA:It7G PRF:�i':;tiRt•: 7'�'1�??': 1-- a ? ? ? ? ?? ENTRY 'i"YPF. OPERATOR r �???T?? � OPERATOR VEitIPIED . 'I.,1 "ICII 41i GU('FI' AN}JiJi.U; ['RPg 7 ?? ^ ? ?7 � OOTII KUP 2T-1 7 ConocoPhillip5 �T tttr[ - v Ma IUD r Y l B R (� Wellbom API7UWI Field Name Well Status Incl ( °) MD (kKB) Act Btm (ftKB) 501032006000 KUPARUK RIVER UNIT PRODUCING 53.50 3,800.00 8,445.0 Comment H2S (ppm) Data Annotation End Date KS -Grd (ft) Rig Release Date SSSV: TRDP 30 1/11/2009 Last WO: 42.00 3/10/1986 eN Cane -t ` dlamail :ion Depth (ftKB) End Date Annotation Last Mod By End Date Last Tag: SLM 327.0 717/2009 Rev Reason: TAG, ADD NOTE triplwj 7/8/2009 String OD String ID Sat Depth Set Depth (TVD) String Wt String Casing Description (in) (in) Top (ftKB (ftK8) (ftK8) (IbsMt) Grade String Top Thrd CONDUCTOR 16 15.062 36.0 116.0 116.0 62.50 H-40 CONDUCTOR, SURFACE 95/8 8.765 0.0 3,671.0 2,797.3 36.00 J -55 - PRODUCTION 7 6.151 0 -0 8,438.0 6,239.4 26.00 J -55 SAFETY VLV. 'al'�tl _- 1,810 String OD String ID Set Depth Set Depth I D) String Wt String Tubing Description (in) (in) Top (ftKB) (ftKB) (INKS) (lbsflt) Grade String Top Thrd TUBING 27/8 2.441 0.0 8,046.0 5,923.9 6.50 J -55 AB -MOD EUE GAS LIFT, 8RD 3,076 T Ub111 Y.trr8r Rai[ I @h etc. Top Depth SURFACE, - (TVD) Top Incl 3,671 - Top (ftKB) (ftKB) ( °) Description Comment Run Date ID (in) _ 1,810 1,636.7 49.38 SAFETY VLV Camoo TRDP -IA -SSA 9/7/1986 2.312 GAS LIFT, 3,076 2,440.1 53.03 GAS LIFT CAMCO /KBMG /1 /GLV /BK/.188 /1278 /Com 5,141 ment: STA 1 12/11/1994 2.347 5,141 3,808.8 42.97 GAS LIFT CAMCO /KBMG /1 /OV /BK/.25/ /Comment: STA2 12/1111994 2.347 6,230 4,585.2 44.99 GAS LIFT CAMCO /KBMG /1 /DMY /BK/ // Comment: STA 3 9/7/1986 2.347 GAS L 1 FT, FT, 6,870 5,040.8 44.56 GAS LIFT CAMCO /KBMG/l /DMY /BW / /Comment: STA4 813/1990 2.347 7,219 5,292.3 44.15 GAS LIFT CAMCO /KBMG/l /DMY /BK/ // Comment: STA 5 9/7/1986 2.347 7,537 5,526.5 41.19 GAS LIFT CAMCO /KBMG /l /DMY /BK/ // Comment: STA 6 9(7/1986 2.347 GAS LIFT, 6,870 7,700 5,650.5 39.48 GAS LIFT MMH /FMHO /1.5 /DMY /RK/ // Comment: STA 7 8/5/1990 2.347 7,743 5,683.9 39.06 PBR HPT (Brown) 9/7/1986 2.500 7,760 5,697.1 38.89 PACKER HPT'HB' Retr. hyd set 9/7/1986 3.000 GAS LIFT, - 7,828 5,750.2 37.68 PRODUCTION CAMCO/ KBMG /l /DMY /BKI // Comment: CLOSED, STA 8 4/28/1995 7,219 2.347 _ 7,898 5,805.6 37.34 PRODUCTION CAMCO /KBMG /l /DMY /BK/ // Comment: CLOSED, STA 9 4/28/1995 2.347 8,000 5,886.9 36.85 PRODUCTION CAMCO /KBMG /l /DMY /BK/ // Comment: CLOSED, STA 10 4/26/1995 2.347 GAS ,53 LIFT, 7 6,023 5,905.5 37.01 PACKER HPT'1 -8' 9/7/1986 2.500 5 8,034 5,914.3 36.96 NIPPLE CamCO'D' Nipple NO GO 9/7/1986 2.250 ti 8,041 5,919.9 36.93 SOS Camoo Shear Out 8 Re -Entry Guide 9/7/1986 2.441 GAS LIFT, - 8,043 5,921.5 36.92 TTL ELMO TTL @ 8043.5' during PERF RECORD on 09/06/86 9/7/1986 2.441 7,700 8,089 5,958.2 36.72 FISH Lower Half of GLV Lost in Rathole from 5/13/88 8/1511990 Sf '#$TGMSI91$ 8 St Ots PBR, 7,743 Shot Top(TVD) Stm (TVD) Dens Top(ftKB) Btm IRKS) (ftKB) (ftKB) Zone Data (sh° Type Comment 7,956 7 5,851.8 5,877.3 C-4, UNIT B, 9/7/1986 12.0 IPERF 120 deg Phase 5" HyperJet It 2T -17 PACKER, 7,760 _ 8,095 8,102 5,963.0 5,968.6 A -4, 2T -17 9/7/1986 4.0 IPERF 90 deg. Phase; 4" HyperJet II 8,116 8,147 5,979.9 6,004.8 A -3, 2T -17 9/7/1986 4.0 IPERF 90 deg. Phase; 4" HyperJet II PRODUCTION, Nt ( t� 7,828 (i f�1 End Date Annotation 5/22/1995 NOTE: WAIVERED WELL: IA x OA ANNULAR COMMUNICATION 7/7/2009 NOTE: TAG 32T SLM (1.5" SLINKY TOOL STRING), PRIOR TAG 8079,4126/1995 PRODUCTION, - 7,898 IPERF, 7,956 -7,988 PRODUCTION, 8,000 PACKER, 8,023 NIPPLE, 8,034 SOS, 8,041 TTL, 8,043 FISH, 8,089 IPERF, 8,095 -8,102 IPERF, 8,116-8,147 PRODUCTION, 8,438 TD, 8,445 Alaska Oil and Gas Conservation Commisssion - Conservation Order No. 494 Pagel of STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION 333 West Seventh Avenue, Suite 100 Anchorage Alaska 99501 Re: Proposed Rules Regulating Sustained ) Kuparuk River Field: All Pools Casing Pressures in Development Wells ) in All Pools Within the Kuparuk River ) September 4, 2003 Field Conservation Order No. 494 IT APPEARING THAT: 1. On its own motion, the Alaska Oil and Gas Conservation Commission ("Commission" or "AOGCC") proposed to adopt rules regulating sustained annulus pressures in Kuparuk River Field development wells. 2. Notice of opportunity for a public hearing on the proposal was published in the Anchorage Daily News on June 30, 2003. 3, No request for a hearing was received. 4. No written comments on the proposal were received. FINDINGS: 1. In considering proposed rules regulating sustained casing pressures in Kuparuk River Field development wells, the Commission reviewed: annulus pressure surveillance requirements, annular pressure control guidelines, problem wells testing and evaluation guidelines, and well operating guidelines submitted by the operator, ConocoPhillips Alaska, Inc.; the operator's annular communications issues well list for the Kuparuk River Field; Applied Drilling Engineering by Bourgoyne, et al.; the Halliburton Cementing Tables; an annular pressure simulator developed by Commission staff as contained in an IVIS Excel spreadsheet; information on well pressures provided by the operator; and the hearing record in connection with Conservation Order No. 492. 2, Annulus pressure is common in development wells. Pressures may be purposely imposed, thermally induced or the result of leaks in tubing, casing, packer or other well components. 3. Excessive annular pressure can develop in wells as a result of thermal effects. Well startup can involve significant annular pressure increases due to fluid expansion as a well heats above ambient temperature. Changing produced fluid characteristics and production mechanisms can also create thermal conditions that affect annular pressures, 4. For service (injection) wells, AOGCC regulations require, unless superseded by a Commission order, an operator to notify the Commission by the next working day if an injection rate, operating pressure observation, or pressure test indicates pressure communication or leakage in any casing, tubing, or packer. The operator must implement corrective action or increased surveillance, as the Commission requires (20 AAC 25.252(e) and 20 AAC 25.402(f)). 5. Unless specifically authorized by the Commission, AOGCC regulations require all producing wells capable of unassisted flow to be completed with suitable tubing and packer that effectively isolates the tubing-casing annulus from fluids being produced. Wellhead equipment must include appropriate gauges and valves on the tubing, http://doa.alaska.gov/ogc/orders/co/co400 2/23/2010 Alaska Oil and Gas Conservation Commisssion - Conservation Order No. 494 Page 2 of 3 casing-tubing annulus and casing-casing annuli to show surface pressures and control flow for the range of conditions expected (20 AAC 25.200(c) and (d)). 6. No current AOGCC regulation or Commission order for the Kuparuk River Field establishes annular pressure management requirements for producing wells, similar to those for injection wells. However, Conservation Order No. 492 establishes such requirements for producing wells in the Prudhoe Bay Field. 7. Several practicable techniques are available to manage annular pressures including manual pressure bleeding and engineered solutions such as pressure controls and pressure relief systems. 8. Values of "burst pressure rating" and "minimum internal yield pressure" of well tubulars are numerically equal. 9. Pertinent characteristics of well construction in the Kuparuk River Field are similar to those in the Prudhoe Bay Field. 10. Pressure in an active Kuparuk River Field well not exceeding 45% of the burst pressure rating, or minimum internal yield pressure, of well tubulars is within the range of pressure that will not result in failure of well integrity, uncontrolled release of fluid or pressure, or threat to human safety. 11. The operator relies on a well pressure limit waiver process to continue operating Kuparuk River Field wells that exhibit inner annulus pressure exceeding 2000 psig with two pressure bleeds per week, or outer annulus pressure exceeding 1000 prig with two pressure bleeds per week, CONCLUSIONS: 1. There is a need for regulatory oversight of the management of Kuparuk River Field wells that exceed specific pressure thresholds, by administering rules regulating annular pressures. This methodology is consistent with similarly intended efforts by other regulatory agencies. 2. The objectives of rules regulating sustained annular pressures in Kuparuk River Field development wells are to conserve Alaska petroleum resources and protect human safety and the environment, through proper management of annular pressures. Proper annular pressure management aims to prevent failure of well integrity, uncontrolled release of fluid or pressure, or threat to human safety. 3. Kuparuk River Field annular pressure rules should recognize the variety of well completions and development well characteristics in the Kuparuk River Field. 4. Well heating-induced annular pressure increases must be taken into account before initiating well start-up, to ensure that annular pressures at well operating temperature will not result in failure of well integrity, uncontrolled release of fluid or pressure, or threat to human safety. 5. The annular pressure rules adopted in this order are practicable and appropriate to the objectives stated in Conclusion 2. NOW, THEREFORE, IT IS ORDERED: that each of the Conservation Orders Nos. 406,430,4326, 435, and 456 is amended to add the following rules: 1. The operator shall conduct and document a pressure test of tubulars and completion equipment in each development well at the time of installation or replacement that is sufficient to demonstrate that planned well operations will not result in failure of well integrity, uncontrolled release of fluid or pressure, or threat to human safety. 2. The operator shall monitor each development well daily to check for sustained pressure, except if prevented by extreme weather conditions, emergency situations, or similar unavoidable circumstances. Monitoring results shall be made available for AOGCC inspection. http://doa.alaska.gov/ogc/orders/co/co400 2/23/2010 Alaska Oil and Gas Conservation Commisssion - Conservation Order No. 494 Page 3 of 3 3, The operator shall notify the AOGCC within three working days after the operator identifies a well as having (a) sustained inner annulus pressure that exceeds 2000 psig or (b) sustained outer annulus pressure that exceeds 1000 psig. 4. The AOGCC may require the operator to submit in an Application for Sundry Approvals (Form 10-403) a proposal for corrective action or increased surveillance for any development well having sustained pressure that exceeds a limit set out in paragraph 3 of this rule. The AOGCC may approve the operator's proposal or may require other corrective action or surveillance. The AOGCC may require that corrective action be verified by mechanical integrity testing or other AOGCC approved diagnostic tests. The operator shall give AOGCC sufficient notice of the testing schedule to allow AOGCC to witness the tests. 5. If the operator identifies sustained pressure in the inner annulus of a development well that exceeds 45% of the burst pressure rating of the well's production casing for inner annulus pressure, or sustained pressure in the outer annulus that exceeds 45% of the burst pressure rating of the well's surface casing for outer annulus pressure, the operator shall notify the AOGCC within three workino days and take corrective action. Unless well conditions require the operator to take emergency corrective action before AOGCC approval can be obtained, the operator shall submit in an Application for Sundry Approvals (Form 10-403) a proposal for corrective action. The AOGCC may approve the operator's proposal or may require other corrective action. The AOGCC may also require that corrective action be verified by mechanical integrity testing or other AOGCC approved diagnostic tests. The operator shall give AOGCC sufficient notice of the testing schedule to allow AOGCC to witness the tests. 6. Except as otherwise approved by the AOGCC under paragraph 4 or 5 of these rules, before a shut-in well is placed in service, any annulus pressure must be relieved to a sufficient degree (a) that the inner annulus pressure at operating temperature will be below 2000 psig and (b) that the outer annulus pressure at operating temperature will be below 1000 psig. However, a well that is subject to paragraph 3, but not paragraph 5, of these rules may reach an annulus pressure at operating temperature that is described in the operator's notification to the AOGCC under paragraph 3, unless the AOGCC prescribes a different limit. 7. For purposes of these rules, "inner annulus" means the space in a well between tubing and production casing; outer annulus" means the space in a well between production casing and surface casing; sustained pressure" means pressure that (a) is measurable at the casing head of an annulus, (b) is not caused solely by temperature fluctuations, and (c) is not pressure that has been applied intentionally. DONE at Anchorage, Alaska and dated September 4, 2003. Sarah Palin, Chair Alaska Oil and Gas Conservation Commission Randy Ruedrich, Commissioner Alaska Oil and Gas Conservation Commission Conservation Order Index Home Web aster http://doa.alaska.gov/ogc/orders/co/co400 2/23/2010 MICROFILMED 9/11/00 DO NOT PLACE ANY NEW MATERIAL .UNDER THIS PAGE DEPT. OF NATURAL RESOURCES DIVISION OF OIL AND GAS April 12, 1991 D. W. Johnston, AOGCC Commissioner Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501-3192 Subject: Release of ARCO Kuparuk River Unit 2T Well Data WALTER d. HICKEL, GOVERNOR P.O. BOX 107034 ANCHORAGE, ALASKA 99510-7034 PHONE: (907) 762-2553 . ..:-.~:.~ _...'-' ;, ',,~ f.', ' ~ ,, i'. :~ *x y? ~---- .... --~--..:¢- o L ..... ~ ~ .~-'c .. ' - 1 · ..i..~: ~ .~_! Dear Commissioner Johnston: On August 5, 1988 1 granted extended confidentiality for the Kuparuk River Unit 2T wells. The Kuparuk River Unit 2T-2, 3, 4, 5, 6, 7, 8, 9, 10, 11, 12, 12A, 13, 14, 15, 16, and 17 wells were granted extended confidentiality until 90 days after the unleased land in T1 iN R7E Umiat Meridian could be offered for lease. The unleased land in this township was offered for lease in Sale 70A whtch was held on January 29, 1990. Therefore, the wells no longer qualify for extended confidentiality and the well data should be released on April 30, 1991. By copy of this letter I am notifying ARCO Alaska Inc. of the upcoming release of the above listed wells. Sincerely, ~:~.mes E. Eason ~)irector cc' J. L. Dees, ARCO Alaska Inc. RECEIVED APR 1 6 1991 Alaska Oil ,& Gas Cons. 6ommlss[On Anchorage /STATE OF ALASKA f~ ~''~ ALA,SKA OIL AND GAS CONSERVATION COMMI,.~SION REPORT OF SUNDRY WELL OPERATIONS 1. Type of Operation: Operation Shutdown__ Stimulate X Plugging Perforate _ Pull tubing Alter casing Repair well Other m 6. Datum elevation (DF or KB) 2. Name of Operator ARCO Alaska. Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510 5. Type of Well: Development X Exploratory _ Stratigraphic _ Service Location of well at surface 23' FNL, 556' FWL, Sec. 12, T11N, R8E, UM At top of productive interval 1574' FSL, 1294' FEL, Sec. 12, T11N, R8E, UM At effective depth 1476' FSL, 1150' FEL, Sec.12, T11N, R8E, UM At total depth 1410' FSL, 1053' FEL, Sec. 12, T11N, R8E, UM 12. Present well condition summary Total Depth: measured true vertical RKB 117 7. Unit or Property name Kuparuk River Unit 8. Well number PT-17 feet 9. Permit number/approval number 86-43 / 90-631 10. APl number 5o-103-20061 11. Field/Pool Kuparuk River Field/ Kuparuk River Oil Pool 8445' feet Plugs (measured) 6243' feet Cement: 8248'-8445' Effective depth: measured 8248' feet Junk (measured) true vertical 6 0 8 4' feet None Casing Length Size Cemented Measured depth Structural Conductor 8 1' 1 6" 225 Sx CS II 1 1 6' Surface 3636' 9 5/8" 1250 Sx AS III & 3671' Intermediate 360 Sx Class G Production 8 4 0 3' 7" 375 Sx Class G 8 4 3 8' Liner 175 Sx AS I Perforation depth: measured 7956'-7988' 12 SPF 120 degree phasing 8095'-8102', 8116'-8147' 4 SPF 90 degree phasing, true vertical 5850'-5875', 5961'-5967', 5978'-6003' TVD Tubing (size, grade, and measured depth 2 7/8" J-55 set at 8046' Packers and SSSV (type and measured depth) HPT "HB" @ 7760', HPT 1-B @ 8023', Camco TRDP-1A-SSA @ 1811' True vertical depth 116' 2796' 6237' 13. Stimulation or cement squeeze summary Intervals treated (measured) 8095'-81 02', 8116'-8147' Treatment description including volumes used and final pressure 710 bbls gelled water, 47 bbls diesel, 49,300 lbs 12/18 Carbolite~ final pressure 6900 psi. 14. Representative Daily Ayer~,ge Production or In!ection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 820 1335 45 1100 254 Subsequent to operation 1390 2000 75 1200 270 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. Sic~ned ~~, '~.~ ~ Title Senior Operations Engineer Form 10-404 Rev 09/12/90 SUBMIT IN DUPLICATE ARCO Alaska, In¢~~ 8ul~idlary of Atlantic RlchflMd C~pan) d' w~,~ PT- I~ "~ ~NT~CTOR REMARKS ~.-ELL SERVICE REPORT OPERATION AT REPORT TIME I DAY~ I DATE I ~I7/~ 23o.oseFrt- I f - ~? ['"] CHECK THIS BLOCK IF SUMMARY CONTINUED ON BACK ~,o.,,- ~ i~.~ o~ ic-~.~-.i-..,-, ..i-,v.. knot~ islgn~ STATE OF ALASKA ALASKA OIL AND GAS ~ERVATION ~Mg:~SION - APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon _ Suspend _ Operation Shutdo~r~_ Re-enter suspended well Alter casing _ Repair well _ Plugging _ Change approved program _ 2. Name of Operator ARCO Alaska. Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510 Pull tubing _ 5. Type of Well:' Development .~. Exploratory _ Stratigraphic _ Service _ Time extension _ Stimulate X Variance _ Perforate _ Other 6. Datum elevation (DF or KB) RKB 117 7. Unit or Property name Kuparuk River Unit feet 4. Location of well at surface 23' FNL, 556' FWL, Sec. 12, T11N, R8E, UM At top of productive interval 1574' FSL, 1294' FEL, Sec. 12, T11N, R8E, UM At effective depth 1476' FSL, 1150' FEL, Sec. 12, T11N, R8E, UM At total depth 1410' FSL~ 1053' FEL~ Sec. 12~ T11N~ R8E~ UM 12. Present well condition summary Total Depth: measured 8445' feet Plugs (measured) true vertical 6243' feet Cement: 8248'-8445' Effective depth: measured 8248' feet Junk (measured) true vertical 6 0 8 4' feet Non~ Casing Length Size Cemented Measured depth Structural Conductor 8 1 ' 1 6" 225 Sx CS II 1 1 6' Surface 3636' 9 5/8" 1250 Sx AS III & 3671' Intermediate 360 SX Class G Production 8 4 0 3' 7" 375 Sx Class G 8 4 3 8' Liner 175 Sx AS I Perforation depth: measured 8. Well number 2T-17 9. Permit number 86-43 10. APl number so-103-20060 11. Field/Pool Kuparuk River Field Kuparuk River Oil Pool True vertical depth 116' 2796' 6237' 7956'-7988' 12 SPF 120 degree phasing 8095'-8102', 8116'-8147' 4 SPF 90 degree phasing, true vertical 5850'-5875', 5961'-5967', 5978'-6003' TVD Tubing (size, grade, and measured depth 2 7/8" J-55 set at 8046' Packers and SSSV (type and measured depth) HPT "HB" @ 7760', HPT 1-B ~ 8023'~ Camco TRDP-1A-SSA ~ 1811' RECEIVED AUG 1 o 1990 & Gas Cons. Cqmmissi0 chorage 13. Attachments Description summary of proposal X Detailed operation program _ Refracture stimulate A Sands with gelled water and Iow density ceramic proppant. 14. Estimated date for commencing operation 15. Status of well classification as: August. 1990 OU ~[ Gas __ 16. If proposal was ve~rbally approved ? Name of approver~~¢I-~-' ~~ % ~' [ Date approved S e r v i c e BOP sketch Suspended _ 17. I he,~~t,~he foregoing is true and correct to the best of my knowledge. Signed , ~ 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 Approved by the order of the Commission Form 10-403 Rev 5/03/89 ORIGINAL SIGNED BY IApproval No. I 10- .6 ¢~ GO~3~ 9_~°'~ed ed SUBMIT IN TRIPLICATE Application for Sundry- Well 2T-17 A Sand Refracture Treatment No BOP's are used during the fracture. The fracture treatment will be pumped through a manifold on surface. A Sand Pressure (6200' SS) = 3291 psi 10/26/86 SBHP No workover fluid will be used during this process. PRE-FRAC SLICKLINE 8/2/90 Kuparuk Well 2T-17 A Sand Fracture Procedure Cost Tracking AFE #K81093 . , MIRU Slickline unit. Tag bottom. Pull C Sand CV's at 8003', 7902', and 7832' RKB and replace with DV's. Pull GLV's @ 6870', 5141', and 3076' RKB and OV @ 7700' and replace with DV's. Set standing valve in Camco °D' nipple at 8034' RKB. Pressure test the tubing to ensure C Sand is dummied off. Pull DY from 1-1/2" mandrel @ 7700' and leave mandrel open. Displace annulus by pumping 218 bbls of 9.8 ppg brine followed by 45 bbls of diesel down the tubing. This volume should leave a pad of 15 bbls (500') of diesel in the annulus, and the tubing full of diesel. Run DV @ 7700'. Pressure test the tubing. Pull standing valve. RDMO. NOTE: Make sure at all times while the brine ia in the annulus that the surface casing pressure is no more' than 1900 psi higher than the surface tubing pressure to maintain tubing' integrity. NOTE: Fill last tagged at 8197' RKB, 50' below bottom perf. 2. Obtain 24 hour A Sand well test. 3. Shut in well at least twenty four hours before frac is planned to allow tubing pressure to build up. FRAC TREATMENT . RU fracture equipment. Install "Tree Saver". If tubing pressure is at least 1600 psi, pressure up 7" annulus to 3500 psi. If tubing pressure is less than 1600 psi, pressure up annulus to 1900 psi greater than tubing pressure and increase as possible after pumping begins, up to 3500 psi. Maintain this pressure of 3500 psi on the annulus throughout the remainder of the job. . Carry out all fluid quality control procedures(Onsite Operations Engineer). Obtain a sample of the proppant and of the gelled water and gelled diesel with breaker. Check the proppant for fines. Record proppant weight prior to pumping. After frac, verify and record weight of remaining proppant. Obtain samples from pad and slurry stages while pumping. 6. Pump the 100 bbl pre-pad at 20 BPM. Shut down and determine the ISIP. 7. Pump fracture treatment per the attached schedule. Expected wellhead treating pressure: WHTPE = 4560 psig Fracture Gradient = 0.70 psi/ft (5935' TVD) Tubing Friction = 375 psi/1000 ft (8014' MD) Recommended Max WHP = 6500 psi * If excessive treating pressures are experienced, reduce rate to 15 BPM, adjusting additive rates as appropriate. NOTE: Bleed annulus pressure down as necessary after frac, to keep no more than 1900 psi greater than SIWHP. 8/2/90~ Kuparuk Well 2T-17 A Sand Fracture Procedure Cost Tracking AFE #K81093 8. Rig down ifa:= equipment. Follow attached flowback procedure. After well has completed flowback, obtain a 24 hr well test. The well should be left on A Sand only production for about three weeks. Obtain 24 hr tests at one-week intervals. Contact Operations Engineering for a new gas lift design following evaluation of increased productivity. DEPARTMENT OF NATURAL RESOURCES DIVISION OF OIL AND GAS August 5, 1988 Jon Wood, Area Landman ARCO Alaska, Inc. P.O. Box 100360 Anchorage, AK 99§10-0360 Dear Mr. Wood: STEVE COWPER, G~~! PO, BOX 7034 ~ ~.~_.,~ _~--~,/ -- /i In your July 8 letter and in our August 3 meeting, you requested extended confidentiality for the data from the Kuparuk River Unit "drtllsite 2T" wells. You indicated that reports and information from these wells contain significant information relating to the valuation of unleased land in Township ll North, Range 7 East, U.M. This unleased land is currently scheduled to be offered for lease in Sale 70A in September 1989. Following your written request, the August 3 meeting and further review of the well data by my staff, I agree to extend the confidentiality of the data from the ARCO Kuparuk River Unit 2T-2, 3, 4, 5, 6, 7, 8, 9, lO, ll, 12, 12A, 13, 14, 15, 16 and 17 wells. The data from these wells will be released after the aforementioned land is offered for lease. In your letter and supporting data, you requested confidentiality for data from a "2T-16A" well. The Alaska Oil and Gas Conservation Commission (AOGCC) has advised the division that they have no record of a "2T-16A" well. The 2T-16 well was side-tracked but no new number was assigned to the well. Therefore, all of the data from the well are filed under 2T-16 at AOGCC. The first 2T well scheduled to be released is the 2T-12 Well (August 6, 1988) and the last 2T well release date is the 2T-8 Well (January 15, 1989). The division is making a special exception to our policy of considering extended confidentiality no sooner than 90 days prior to a release date because it is prudent to, in this case, grant the extension of confidentiality for the 2T wells as a group. By copy of this letter I am requesting that AOGCC keep confidential the data from all of the Kuparuk River Unit 2T wells until further notice. Sincerely, amesE Eason i recto~ cc: C.V. Chatterton, Commissioner, AOGCC Judith M. Brady, Commissioner, DNR I ECEIV AUG - 5 " .... ARCO Alaska, Inc. Date: July 8, 1988 Transmittal #: 7218 RETURN TO: ARCO Alaska, Inc. Attn: Brenda K. Miernyk Kuparuk Records Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted herewith are the following items. Please acknowledge receipt and return one signed copy of this transmittal. 1 Y-0 4 ' Kuparuk Well Pressure Report 7 - 0 1 - 8 8 'C' Sand 2 T- 1.7 Kuparuk Fluid Level Report 6 - 2 9 - 8 8 Casing 3 Q- 0 9 Kuparuk Fluid Level Report 6 - 2 9 - 8 8 Casing Receipt Acknowledged: Alaska 0il & Gas Cons. Commission Anchorage .......... ~ ................ Date: ............ DISTRIBUTION; D&M State of Alaska .ir Chevron Unocal SAPC Mobil ARCO Alaska, Inc. Post Office i~ox 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 Date: March 18, 1987 Transmittal #: 5936 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. 2A-12 CETo 3-8-86 6410-7007 3F-16 CET 1-13-86 7740-8443 2A-lO CBL 3-20-86 6500-7042 3N-4 CET 3-25-86 6690-7736 3N-3 CET 3-25-86 6587-8016 3Q-7 CBL 2-15-87 6698-8908 3Q-6 CBL 2-14-87 7494-9545 3Q-2 CBL ~2-15-87 7843-9752 ___3Q-5 CBL 2-15-87 7809-9941 3N-5 CET 3-25-86 5590-7456 2T-17 CET 9-5-86 6947-8236 2T-13 CET 9-1-86 6900-7752 2T-10 CET 9-4-86 4700-8118 · Receipt Acknowledged: DISTRIBUTION: NSK Drilling Mobil SAPC Unocal Vault (film) ARCO Alaska, Inc. Is a Subsidiary of AtlanticRichlieldCompany STATE OF ALASKA ' ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well OIL [Xl GAS [] SUSPENDED [] ABANDONED [] SERVICE [] 2. Name of Operator 7. Permit Number ARCO Alaska, Inc. 86-43 3. Address 8. APl Number P. 0. Box 100360, Anchorage, AK 99510 50- 103-20060 4. Location of well at surface ~I !~i ~'~ ~ ;~'%11::':! !!~ i:'~ ill .....!! ii~ ';"~ i~ ~ 9. Unit or Lease Name 2~' FNL, 556' FWL, Sec.12, T11N, R8E, UM~:~.~ ~ ~ ~ /- ~ Kuparuk River Unit At Top Producing Interval ~ ~ '~ ~ ; ~ ~' ~ ~ ~ y.- ~ 10. Well Number 1574' FSL, 1294' FEL, Sec.12, T11N, R8E, UM ~ ~ · ~ ~ ~.. 2T-17 At Total Depth i ~'~,. ~ 1410' FSL, 1053' FEE, Sec. 12, T11N, R8E, UM ~ ~"~...~ ~.j yj~: ~ [~..~_ ] Kuparuk River Field ~ Elevation in feet (indicate KB, DF, etc.) ] 6. Lease Designation and Serial No. - ..... Kuparuk Ri ver 0i 1 Pool 117'RKB~ ADL 25569 ALK 2667 12. Date Spudded 13. Date T.D. Reached 14. Date COmp., Susp. or Aband. 15. Water Depth, if offshore 116. No. of Completions 02/28/86 03/09/86 1 2/08/86* N/A feet MSLI 1 17. Total Depth (MD+TVD) 18. PIug Back Depth (M~D) 19. DirectionaISurvey I 20. Depth where SSSV set 21. Thickness of Permafrost 8445'MD, 6243'TVD 8248'MD 6084'TVD YES ~ NO ~~ 1814' feet MD 1500' (Approx) 22. Type Electric or Other Logs Run D I L/GR/SP/SFL, FDC/CNL,RFT,CET,GCT 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 116' 24" 225 sx CS II 9-5/8" 36.0~ J-55 Surf 3671' 12-1/4" 1250 sx ASlll & 360 sx ;lass G 7" 26.0~ J-55 Surf 8438' 8-1/2" 375 sx Class G & 175 sx ASI 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) 7956'-7988'MD w/4 spf, 90~ phasing 2-7/8" 8046' 7764', 8027' 8095 ' -8102 'MD 8116'-8147'MD w/12 spf, 90~ phasing 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. 5850'-5875 'TVD DEPTH I'NTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 5961 '-5967'TVD See Attached Addendum, dated 12/15/86 5978'-6003'TVD For Fracture Data 27. N/A PRODUCTION TEST Date First Production ~ Method of Operation (Flowing, gas lift, etc.) Dateof Test Hours Tested PRODUCTION FOR OIL-BBL GAs-McF WATER-BBL CHOKE SIZE ~GAS-OILRATIO TEST PERIOD ~ I Flow Tubing Casing Pressure CALCULATED OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press. 24-HOUR RATE ~ .,, 28. CORE DATA ..... ~"rief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. None Note: Drilled RR 03/10/86. Well perforated & tubing run 09/07/86. ~.. ~., -::~ Form 10-407 Rev. 7-1-80 WC1:1 77:DANI CONTINUED ON REVERSE SIDE Submit in duplicat~)~ GE~3~LOGiCMA ~;'-; £" '"'~ !"; ~' '"' "~':~ ~:;'~ '? :;'~'" ;' ' ..... :' '-" FORMA:~'ION TESTS i::-" ~' "" '- !-" '""-': :~'-,": ~':i '~' .-' .'~;~-' ~'~- :.~-.,z,.: ~',~.~;;..~,:..,... , · ;.. - .. ,.,....~... . ~; ..... ' ' ' ~ : - · - ' %z . .t · '~ ?. -, ..* ~' ', -. ' ~,, - . ' ' . o. . . NAM E Inclu de interval testedj pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase· ., Top Kupa ruk C 7954 ' 5848' DEPTH HYDRO FORNAT I ON Base Kuparuk C 7990' . 5877' (F--+) Press Press - Top Kupa ruk A 8075 ' 5945 ' 8213.0 3473.8 Base Kuparuk A' '. !8248' 6084' 8211.8 3476;'7 ,8~1.,45,7 3431.1 3207.1 '"' ? ' '~ ':~' 8144.0 3428.8 ~-"-",' '. :- ',':'. 8140.0 3435.3 3136.8 ' 8131 0 3431.9 "'3'120.5' · . 8124.9 3432.8 3111.4 ' :'" ' :~ ',~, 8120.0 ' 3433.7 3111'.1 ,: , · ', 8100.0 3423.0 3118.1 ,. 8096.0 3424.2 3112.0 7986.0 3364.0 3299.3 7981,0 3365.7 3300.3 7973.0 3360.5 3295.2 · . 7971:.0 3361.8 3296.4 7965.2 3360.5 3292.1 7960.0 3359.5 3293.4- 7956.9 3359.9 31. LIST OF ATTACHMENTS Addendum~, (dated 12/15/86) 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed I~~ .~~ TitleAssOc~a'ce En§'neer' Date // INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1: ClasSification of Service Wells: Gas. injection, water i'njection, steam injection, air injection, salt water disposal, water supply for injection, obserVation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21: Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- lng and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". Form 10-407 ADDENDUM WELL: 12108/8/ 2T-17 Frac "A" sand perfs 8095'-8102' & 8116'-8147' in eight stages per 11/4/86 procedure using Musol, diesel, gelled diesel, i00 and 20/40 mesh sand. Press'd ann to 2330 psi w/diesel. Tst lns to 8000 psi; OK. Stage #1: Pmp 50 bbls diesel w/5% Musol @ 2800 psi, 2 BPM Stage #2: 46 bbls diesel, 2 BPM, 2800 psi Stage #3: 44 bbls gelled diesel pad @ 5 BPM, 2760 psi avg Stage #4: 19 bbls gelled diesel w/ 1 ppg 100 mesh sand @ 20 BPM, 4790 psi Stage #5: 15 bbls gelled diesel pad @ 20 BPM, 4360 psi Stage#6: 12 bbls gelled diesel w/3 ppg 20/40 mesh sand @ 20 BPM, 4180 psi Stage #7: 24 bbls gelled diesel @ 8 ppg 8 ppg 20/40 mesh sand @ 4450 psi, 20 BPM Stage #8: 46.5 bbls gelled diesel @ 4390 psi, 20 BPM Pmp'd 750# 100 mesh sand & 5978# 20/40 mesh sand in formation leaving 672# 20/40 mesh sand in csg. Underflushed by 2 bbls as per procedure. ~ Load to recover 248 bbls of diesel. Job complete.@ 8:49 hfs, 12/8/86. Drilling Supervisor $ UB-$ URFA CE DIRECTIONAL [~UIDANCE SURVEY r~ONTINUOUS [-~ OOL ComPany Well Name Field/Location ARCO ALASKA~ INCORPORATED 2T-17 (23' FNL~ 556' ,,,FWL~ SEC 12~TllN~R8~,UM) KUPARUK~ NORTH SLOPE, 4LASKA Job Reference,, No. 71704 Lo(jc3ed By; MCBRIDE Date 5-SEP-86 Computed By: KRUWELL SCHLUMBERGER GCT DIRECTIONAL SURVEY CUSTOMER LISTING FOR ARCO ALASKA, INC- ZT-17 KUPARUK 'NORTH SLOPE,ALASKA SURVEY DATE: 05-SEP-86 ENGINEER: M. MCBRIDE METHODS OF COMPUTATION TOOL LOCATION: TANGENTIAL- AVERAGED DEVIATION AND AZIMUTH INTERPOLATION: LINEAR VERTICAL SECTION: HORIZ. DIST. PROJECTED ONTO A TARGET AZIMUTH OF SOUTH 40 DEG 51 MIN EAST COMPUTATION DATE: 16-SEP-86, PAGE ARCO. ALASKA~ INC. 27-17 KUPARUK NORTH SLOPEtALASKA DATE OF SURVEY: 05-SEP-86 KELLY BUSHING ELEVATION: 117.00 FT ENGINEER: M. MCBRIDE INTERPOLATED VALUES' FOR EWEN 100 FEET OF MEASURED DEPTH TRUE SUB-SEA COURSE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH DEPTH DEPTH DEPTH DEG MIN DEG MIN 0o00 0.00 -117.00 0 0 N 0 0 E 100.00 100.00 -17.00 0 6 N 47 5 E 200.00 200.00 83.00 0 20 S 79 48 E 300.00 300.00 183.00 0'41 S 87 59 E 400.00 399.96 282.96 2 12 S 68 I E 500.00 699.67 382.67 6 18 S 59 38 E 600.00 598.75 481.75 8 53 S 55 11 E ,'~ 700.00 697.05 580.05 12 21 S 51 800.00 793.75 676.75 16 40 S 47 7 E 900.00 888.76 771.76 19 56 $ 42 55 E 1000.00 981.79 864.79 22 38 1100.00 1073.26 956.26 25 25 1200.00 1162.19 1045.19 28 42 1300.00 1248.60 1131.60 31 51 1400.00 1331.57 1214.57 36 0 1500.00 1410.71 1293.71 39 7 1600.00 1486.68 1369.68 41 46 1700o00 1560.22 1443.22 43 57 1800.00 1629.73 1512.73 48 13 1900.00 1694.74 1577.74 49 44 VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH FEET DEG/iO0 FEET FEET FEET DEG MIN 2000.00 1759.13 1642.13 50 7 2100.00 1823,06 1706.06 50 13 2200.00 1887.26 1770.26 49 55 2300.00 1951.54 1834.54 50 1 2400.00 2015.86 1898.86 49 58 2500.00 2079.85 1962.85 50 24 2600.00 2143.46 2026.46 50 37 2700.00 2206.52 2089.52 51 6 2800.00 2269.36 2152.36 50 57 2900.00 2331.95 2214.95 51 44 0.00 0.00 0.00 N 0.00 E 0.00 0.18 0.09 N 0.11 E 0.18 0.41 0.14 N 0.44 E 0.82 0.65 0.01 N 1.27 E 2.61 2.90 0.49 S 3.43 E 9.38 3.85 3.86 S 9.88 E 22.36 2.72 11.22 S 21.21 E 40.20 3.78 22.24 S 35.74 E 65.28 2.91 38.78 S 54.95 E 96.35 4.25 60.82 S 76.97 E 3000.00 2393.29 2276.29 52 30 3100.00 2453.69 2336.69 53 2 3200.00 2513.87 2396.87 53 1 3300.00 2573.78 2456.78 53 18 3400.00 2633.62 2516.62 53 9 3500.00 2693.59 2576.59 53 5 3600.00 2753.66 2636.66 53 2 3700.00 2813.92 2696.92 52 59 3800.00 2873.70 2756.70 53 30 3900.00 2933.22 2816.22 52 53 S 42 3 E 133.00 S 43 32 E 173.35 S 46 10 E 218.91 S 46 35 E 268.97 S 45 45 E 324.48 S 45 51 E 385.36 S 44 55 E 450.16 S 43 42 E 517.79 $ 43 8 E 589.57 S 43 27 E 665.48 S 43 19 E 741.91 S 43 8 E 818.74 S 43 12 E 895.35 S 43 12 E 971.89 S 43 9 E 1048.40 S 42 58 E 1125.19 S 43 4 E 1202.29 S 43 16 E 1279.84 S 43 32 E 1357.55 S 43 54 E 1435.44 S 44 17 E 1514.29 S 44 22 E 1593.84 S 44 29 E 1673.54 S 44 49 E 1753.44 S 44 54 E 1833.36 S 44 58 E 1913.17 S 45 3 E 1992.91 S 45 32 E 2072.48 S 45 35 E 2152.37 S 44 48 E 2232.46 0.00 N 0 0 0.15 N 49 51 E 0.46 N 72 8 E 1.27 N 89 24 E 3.47 $ 81 56 E lO.61 S 68 38 F 23.99 S 62 7 42.10 S 58 6 E 67.26 S 54 47 E 98.10 S 51 41 E 2.16 3.92 2.85 3.77 4.04 2.73 1.77 3.85 4.48 0.36 88.13 S 101.42 E 134.36 S 49 0 E 117.74 S 128.86 E 174.55 S 47 34 E 150.08 S 161.12 E 220.19 S 47 1 E 184.66 S 197.65 E 270.50 S 46 56 E 223.26 S 237.89 E 326.25 S 46 49 E 265.89 S 281.67 E 387.35 S 46 39 E 311.48 $ 328.02 E 452.34 S 46 28 E 359.92 S 375.39 E 520.06 S 46 12 E 412.32 S 424.54 E 591.81 S 45 50 E 467.53 S 476.73 E 667.73 S 45 33 E 0.59 0.30 0.17 0.18 0.41 0.29 0.43 0.27 0.33 1.17 523.08 S 529.35 E 744.20 S 45 20 E 579.12 S 58Z.01 E 821o05 S 45 8 E 635.09 S 634.42 E 897.671 S 44 58 E 690.91 S 686.87 E 974.24 S 44 49 E 746.72 S 739.30 E 1050.79 S 44 42 E 802.88 S 791.75 E I127.60 S 44 36 E 859.30 S 844.38 E 1204.73 S 44 29 915.91 S 897.48 E 1282.32 S 44 25 E 972.44 S 950.91 E 1360.10 S 44 21 E 1028.82 S 1004.80 E 1438.08 S 44 19 E 0.70 0.64 0.38 0.26 0.15 0.37 0.12 0.89 0.23 3.03 1085.48 S 1059.81 E 1517.06 S 44 18 E 1142.48 S 1115.52 E 1596.76 S 44 18 E 1199.51 S 1171.41 E 1676.62 S 44 19 E 1256.47 S 1227.69 E 1756.69 S 44 20 E 1313.24 S 1284.23 E 1836.80 S 44 21 E 1369.88 S 1340.76 E 1916.82 S 44 23 E 1426.40 S 1397.30 E 1996.76 S 44 24 E 1482.60 S 1453.96 E 2076.56 S 44 26 E 1538.68 S 1511.24 E 2156.71 S 45 29 E 1595.04 S 1568.52 E 2237.05 S 44 31 E ARCO ALASKAt INC. 27-17 KUPARUK NORTH SLOPEsALASKA COMPUTATION DATE: 16-SEP-86 PAGE DATE OF SURVEY: 05-SEP-B6 KELLY BUSHING ELEVATION: ENGINEER: M. MCBRIDE INTERPOLATED VALUES FOR EVEN 100 FEET OF MEASURED DEPTH 117.00 FT 4000.00 2995.71 2878.71 49 26 4100.00 3063.02 2946.02 46 26 4200.00 3132.23 3015.23 46 6 4300.00 3201.79 3084-79 45 38 4400.00 3271.87 3154.87 4521 4500.00 3342.37 3225.37 44 57 4600.00 3413.41 3296.41 44 28 4700.00 3485.07 3368.07 43 59 4800.00 3557.27 3440.27 43 31 4900.00 3630.14 3513.14 42 54 5 41 45 E 2310.42 S 38 5 E 2384.32 S 37 11 E 2456.36 S 37 32 E 2528.07 S 37 57 E 2599.30 S 38 28 E 2670.L4 S 39 3 E 2740.48 S 39 33 E 2810.20 S ~0 0 E 2879.38 S 40 27 E 2947.85 4.59 2.60 0.21 0.60 0.46 0.48 0.63 1651.79 S 1622.06 E 2315.06 S 44 28 E~ 1708.37 S 1669.63 E 2388.76 $ 44 20 E 1765.81 S 1713.33 E 2460.41 S 44 8 E 1822.95 S 1756.89 E 2531.76 S 43 56 E 1879.34 S 1800.58 E 2602.69 S:43 46 E 1935.06 5 1844.45 E 2673.28 S 43 37 F 1989.96 S 1888.49 E 2743.41 S 43 30 L 0.50 2043.91 S 1932.70 E 2812.98 S 43 23 E 0.61 2097.10 S 1976.95 E 2882.04 S 43 lB E 0.67 21¢9.35 S 2021.21 E 2950.42 S 43 14 E 5000.00 3703.69 3586.69 42 27 $ 40 41 E 3015.61 5100.00 3777.64 3660.64 &2 28 S 40 0 E 3082.92 5200.00 3850.51 3733.51 43 42 ~:' S 37 25 E 3151.32 5300.00 3922.90 3805.90 43 21 S 37 11 E 3220.17 5400..00 3995.86 3878.86 42 56 S 37 20 E 3288.42 5500'00 4069.34 3952.34 42 27 S 37 26 E 3356.13 5600.00 4143.21 4026.21 43 5 S 37 17 E 3423.43 5700.00 4215.32 4098.32 43 48 S 36 44 E 3492.53 5800.00 4287.11 4170.11 45 29 S 36 59 E 3561.98 5900.00 4355.37 4238.37 47 14 S 36 25 E 3634.85 6000-00 4423.67 4306.67 46 37 6100.00 4492.69 4375.69 46 .3 6200.00 4562.41 4445.41 45 28 6300.00 4632.90 4515.90 44 48 6400.00 4704.07 4587.07 44 32 6500.00 4775.34 4658.34 44 33 6600.00 4846.62 4729.62 44 31 6700.00 4917.91 4800.91 44 30 6800.00 4989.13 4872.13 44 38 6900.00 5060.31 4943.31 44 30 S 36 45 E 3707.69 S 37 9 E 3779.88 S 37 27 E 3851.43 S 37 43 E 3922.24 S 38 25 E 3992.41 S 39 15 E 4062.51 S 40 19 E 4132.64 S 41 Z E 4202.77 S 41 24 E 4272.96 S 42 22 E 4343.19 7000.00 5131.75 5014.75 44 18 7100.00 5203.52 5086.52 43 50 7200.00 5275.91 5158.91 43 34 7300.00 5348.43 5231.43 43 19 7400.00 5421.81 5304.81 42 18 7500.00 5496.37 5379.37 41 15 7600.00 5571.88 5454.88 40 32 7700.00 5648.55 5531.55 39 29 7800.00 5726.27 5609.27 38 30 7900.00 5805.12 5688.12 37 20 S 44 25 E 4413.08 S 45 48 E 4482.52 S 47 47 E 4551.14 S 49 23 E 4619.35 S 50 55 E 4686.40 S 52 53 E 4751.80 S 54 55 E 4815.64 S 55 49 E 4877.79 S 57 2 E 4938.38 S 56 29 E 4997.46 0.41 2.19 0.60 0.56 0.46 0.59 3.28 0.54 4.43 0.55 0.62 0.66 0.65 1.06 0.79 0.61 1.11 0.43 0.42 1.32 1.22 1.35 1.43 1.42 1.40 1.70 1.71 1.17 0.97 1.19 2200.79 S 2065.30 E 3018.10 S 43 10 E 2251.85 S 2109.17 E 3085.36 S 43 7 E 2305.50 S 2151.70 E 3153.59 S 43 I E 2360.44 S 2193.43 E 3222.23 S 42 53 E 2414.86 S 2234.83 E 3290.29 S 42 46 E 2468.75 S 2276.04 E 3357.84 S 42 40 E 2522.21 S 2317.09 E 3424.97 S 42 34 E 2577.65 S 2358.64 E 3493.91 S 42 27 E 2633.26 S 2400.48 E 3563.20 S 42 21 E 2691.89 S 2444.10 E 3635.92 S 42 14 E 2750.57 S 2487.60 E 3708.61 S 42 T E 2808.39 S 2531.10 E 3780.68 S 42 I E 2865.35 S 2574.62 E 3852.13 S 41 56 E 2921.62 S 2617.80 E 3922.85 S 41 51 E 2976.93 S 2661.11 E 3992.95 S 41 47 E 3031.56 S 2705.11 E 4063.00 S 41 44 E 3085.48 S 2749.97 E 4133.10 S 41 42 E 3138.59 S 2795.76 E 4203.22 S 41 41 E 3191.39 S 2842.02 E 4273.41 S 41 41 E 3243.78 S 2888.81 E 4343.65 S 41 41 E 3294.58 S 2936.91 E 4413.58 S 41 42 E 3343.72 S 2986.25 E 4483.09 S 41 46 E 3390.98 S 3036.51 E 4551.82 S 41 50 E 3436.43 S 3088.22 E 4620.19 S 41 56 E 3479.99 S 3140.35 E 4687.45 $ 42 3 E 3521.17 S 3192.73 E 4753.12 S 42 11 E 3559.67 S 3245.79 E 4817.31 S 42 21 E 3596.17 S 3298.61 E 4879.88 $ 42 31 E 3630.90 S 3351.07 E 4940.97 S 42 42 E 3664.44 S 3402.62 E 5000.59 S 42 52 E TRUE SUB-SEA COURSE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH DEPTH DEPTH DEPTH DEG MIN DEG MIN VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH FE~T DEG/ZO0 FEET FEET FEET DEG MIN COMPUTATION DATE: 26-SEP-86 PAGE ARCO ALASKAt INC. DATE OF SURVEY: 05-SEP-86 ZT-17 KUPARUK NORTH SLOPE~ALASKA KELLY BUSHING ELEVATION: ENGINEER: M. MCBRIDE 227.00. FT INTERPOLATED VALUES FOR EVEN 200 FEET OF MEASURED DEPTH TRUE SUB-SEA COURSE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH DEPTH DEPTH DEPTH DEG MIN DEG MIN VERTICAL DOGLEG RECTANGULAR COORDINATES HORZZ. DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/WEST DZSTo AZIMUTH FEET DEG/100 FEET FEET FEET DEG flIN 8000.00 5884.89 5767.89 36 51 8200.00 5965.01 5848.01 36 40 8200.00 6045.37 5928.37 36 14 8300.00 6126.00 6009.00 36 26 8400°00 6206°62 6089.62 36 16 8445.00 6242.90 6125.90 36 16 S 55 20 E 5055.76 S 55 34 E 5113.64 S 55 51 E 5171.17 S 55 46 E 5228.3Z S 55 46 E 5285.49 S 55 46 E 5311.21 0.54 0.17 3.73 0.00 0.00 0.00 3698.44 S 3452.42 E 5059.42 S 43 1 E 3732.34 S 3501.72 E 5117.85 S 43 10 E 3765.80 S 3550.97 E 5175.97 S 43 19 E 3799.06 S 3599.89 E 5233.74 S 43 27 E 3832.34 S 364~.80 E 5291.56 S 43 35 E 3847.31 S 3670.81 E 5317.58 S 43 39 F ~ COMPUTATION DATE: Z6-SEP-86 PAGE ARCO ALASKA, I~NC. 27-17 KUPARUK NORTH SLOPE~ALASKA DATE OF SURVEY: 05-SEP-86 KELLY BUSHING ELEVATION: 117o00 FT ENGINEER: M. MCBRIOE INTERPOLATED VALUES FOR EVEN 1000 FEET OF MEASURED OEPT TRUE SUB-SEA COURSE MEASURED VERTICAL VERTICAL DE¥IATION AZIMUTH DEPTH DEPTH DEPTH DEG MIN DEG MIN 0-00 0.00 -117.00 0 0 1000.00 981.79 864.79 22 38 ZO00.O0 1759.13 1642.13 50 7 3000.00 2393.29 2276°29 52 30 4000.00 2995.71 2878.71 ,9 26 5000.00 3703.69 3586.69 42 27 6000°00 4423.67 430&o67 ,6 37 7000.00 5131.75 501,.75 ** 18 8000.00 5884.89 5767.89 36 51 8,45..00 62*2.90 6125.90 36 16 VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH FEET DEG/IO0 FEET FEET FEET DEG MIN N 0 0 E 0.00 S 42 3 E 133.00 S *3 19 E 741.91 S ,4 17 E 1514.29 S ,1 45 E 2310.42 S 40 ,1 E 3015'61 S 36 45 E 3707.69 S 44 25 E 4413.08 S 55 20 E 5055.76 S 55 46 E 5311.21 0.00 2.16 0.59 0.70 4.59 0.41 0.62 1.22 0.54 0.00 0.00 N 0.00 E 0.00 N 0 0 E 88.13 S 101.42 E 134.36 S~49 0 E 523.08 S 529.35 E 744.20 S 45 20 E 1085.48 S 1059.81 E 1517.06 S 44 18 E 1651.79 S 1622.06 E 2315.06 S 44 28 E 2200.79 S 2065.30 E 3018.10 S 43 10 ~ Ii 2750.57 S 2487.60 E 3708.61 S 42 7 L 3294.58 S 2936.91 E 4,13.58 S 41 42 E 3698.44 S 3452.42 E 5059.42 S 43 1 E 3847.31 S 3670.81 E 5317.58 S 43 39 E ARCO ALASKAt INC. 27-17 KUPARUK NORTH SLOPEgALASKA COMPUTATION DATE: 16-SEP-86 PAGE . DATE OF SURVEY: 05-SEP-86' KELLY BUSHING ELEVATION: 117.00. FT ENGINEER: M. MCBRIDE INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE SECT[ON SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH FEET DEG/IO0 FEET FEET FEET DEG TRUE SUB-SEA COURSE MEASURED. VERTICAL VERTICAL DEVIATION AZIMUTH DEPTH DEPTH DEPTH DEG MIN DEG 0.00 0.00 -117.00 0 0 N 0 0 E 17.00 17.00 -100.00 0 10 N 32 Z E 117.00 117.00 0.00 0 7 N 58 33 E 217.00 217.00 100.00 0.24 S 78 16 E 317.01 317.00 200.00 0 50 S 87 42 E 417.05 417.00 300.00 Z 46 S 66 1, E 517.44 517.00 400.00 6 56 S'58 42 E 618.48 617.00 500.00 9 25 S 54 33 E 720.46 117.00 600.00 13 17 S 50 36 E 824.33 817.00 700.00 17 19 S 46 10 E 930.18 917.00 800.00 20 58 1038.27 1017.00 900.00 23 29 1148.84 1117.00 1000.00 Z7 11 1263.07 1217.00 1100.00 30 34 1382.01 1317.00 1200.00 35 17 1508.15 1417.00 1300.00 39 21 1640.86 1517.00 1400.00 42 24 1781.21 1617.00 1500.00 &7 24 1934.46 1717.00 1600.00 49 52 2090.52 1817.00 1700.00 50 15 0.00 0.00 0.00 N 0.00 E 0.00 0.89 0.00 N 0.00 E 0.00 0.25 0.11 N 0.14 E 0.27 0.21 0.12 N 0.55 E 0.97 1.06 0.01 N 1.50 E 3.28 3.71 0.78 S, 4.11 E 11.31 3.43 4.90 S 11.62 E 25.15 3.48 12.87 S 23.57 E 44.69 4.93 25.11 S 39.28 E 72.40 2.88 43.71 S 60.15 E 2246.22 1917.00 1800.00 49 59 2401.77 2017.00 1900.00 49 58 2558.37 2117.00 2000.00 50 30 2716.70 2217.00 2100.00 51 8 2875.91 2317.00 2200.00 51 28 3039.07 2417.00 2300.00 52 45 3205.21 2517.00 2400.00 53 2 3372.29 2617.00 2500.00 53 12 3538.98 2717.00 2600.00 53 5 3705.11 2817.00 2700.00 53 0 S 42 I E 106.96 S 42 40 E 147.96 S 44 53 E 195.03 S 46 36 E 249.96 S 45 52 E 313.96 S 45 49 E 390.53 S 44 29 E 4~7.49 S 43 5 E 575.76 S 43 27 E 691.76 S 43 9 E 811.46 1872.87 2917.00 2800.00 53 ZO 4032.37 3017.00 2900.00 48 13 4178.03 3117.00 3000.00 46 8 4321.73 3217.00 3100.00 45 35 4464.10 3317.00 3200.00 45 6 4605.03 3417.00 3300.00 44 26 4744.33 3517.00 3400.00 43 48 4882.04 3617.00 3500.00 43 0 5018.03 3717.00 3600.00 42 22 5153.68 3817.00 3700.00 43 17 S 43 13 E 930.71 S 43 9 E 1049.75 S 43 i E 1170.17 S 43 18 E 1292.83 S 43 46 E 1416.58 S 44 ZO E 1545.28 S 44 30 E 1677.70 S 44 53 E 1811.24 S 45 0 E 1944.26 S 45 33 E 2076.54 S 45 18 E 2210.78 S 40 40 E 2334.79 S 37 9 E 2440.56 S 37 38 E 2543.56 S 38 17 E 2644.77 $ 39 5 E 2744.00 S 39 44 E 2840.93 S 40 23 E 2935.62 S 40 43 E 3027.77 S 38 14 E 3119.39 0.00 N. 0 0 E' 0.00 N 56 18 E 0.18 N SO 31 E 0.56 N 77 43 E 1.SO N 89 43 i 4.18 S 79 15 F 12.61 S 67 7 26.86 S 61 21 E 46.62 S 57 24 E 74.35 S 53 59 E 3.14 2.53 3.58 3.16 4.49 2.78 1.62 4.40 0.52 0.26 68.68 S 84.11 E 108.58 S 50 45 E 99.18 S 111.51 E 149.23 S 48 21 E 133.32 S 143.99 E 196.24 S 47 12 E 171.55 S 183.76 E 251.39 S 46 58 E 215.89 S 230.33 E 315.70 S 46 51 E 269.50 S 285.39 E 392.53 S 46 38 E 330.93 S 347.30 E 479.72 S 46 22 E 402.21 S 415.12 E 578.01 S 45 54 E 486.63 S 494.84 E 694.03 S 45 28 E 573.80 S 577.03 E 813.76 S 45 9 E 0.15 0.42 0.21 0.21 1.13 0.63 0.39 0.35 0.28 0.88 660.87 S 658.66 E 933.05 S 44 54 E s E s E 835.81 S 822.44 E 1172.60 S 44 32 E s oa .so s 1.32 1579.7Z S 1553.07 E 2215.30 S 44 30 E 4.49 1670.10 $ 1638.16 E 2339.40 S 44 26 E 0.22 1753.19 S 1703.76 E 2444.69 S 44 10 E 0.40 1835.24 S 1766.36 E 2547.18 S 43 54 E 0.63 1915.16 S 1828.68 E 2648.00 S 43 40 E 0.60 1992.70 S 1890.71 E 2746.93 S 43 29 E 0.56 2067.58 S 1952.31 E 2843.66 S 43 21 E 0.63. 2140.04 S 2013.27 E 2938.20 S 43 15 E 0.41 2210.01 S 2073.23 E 3030.25 S 43 10 E 2.88 2280.16 S 2132.19 E 3121.75 S 43 4 E COMPUTATION DATE: 16-SEP-86 PAGE ARCO ALASKAt INC. 2T-17 KUPARUK NORTH SLOPEtALASKA INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH DATE OF SURVEY: 05-SEP-86 KELLY BUSHING ELEVATION: ENGINEER: M. MCBRIDE TRUE SUB-SEA COURSE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH DEPTH OEPTH DEPTH OEG 5291.88 3917.00 3800.00 43~24 5428.83 4017.00 3900.00 42 48 5564.47 4117o00 4000.00 42 25 5702.33 4217e00 4100.00 43 47 5843.38 4317.00 4200.00 46 56 5990.29 4417.00 4300.00 46 40 6134.97 4517.00 4400.00 45 53 6277.60 4617.00 4500.00 44 59 6418.12 4717.00 4600.00 44 31 6558e47 4817e00 4700.00 44 32 6698.73 4917o00 4800.00 44 30 6839.16 5017.00 4900.00 44 39 6979.37 5117.00 5000.00 44 21 7118,66 5217.00 5100.00 43 43 7256.69 5317.00 5200°00 43 30 7393.50 5417.00 5300.00 42 22 7527.38 5517,00 5400.00 41 6 7659.02 5617.00 5500.00 39 50 7788.15 5717.00 5600.00 38 36 7914.92 5817.00 5700.00 37 15 8040.12 5917.00 5800.00 36 46 8164.78 6017.00 5900.00 36 19 8288.84 6117.00 6000.00 36 16 8412.87 6217.00 6100.00 36 16 8445.00 6242.90 6125.90 36 16 117,00, FT S 37 11 E 3214,61 S 37 23 E 3308.00 S 37 32 E 3399,47 S 36 45 E 3494.14 S 36 41 E 3593,34 S 36 43 E 3700.64 S 37 19 E 3804.97 S 37 34 E 3906.49 S 38 35 E 4005.09 S 39 49 E 4103.53 0.59 0.42 0.80 0.53 2.42 0.62 0.54 1.18 0.66 0.88 2355.99 S 2190.06 E 3216.68 S 42 54 E' 2430.45 S 2246.74 E 3309.82 S 42 45 E 2503.17 S 2302.47 E 3401.07 S 42 36 E 2578.94 S 2359.60 E 3495,51 S 42 27 E 2658.42 S 2419.34 E 3594.49 S 42 18 E 2744.91 S 2483.37 E 3701.58 S 42 8 F 2828.41 S 2546.31 E 3805.73 S 41 59 L 2909.12 S 2608.17 E 3907.12 $~41 52 E 2986.86 S 2669.02 E 4005.62 S 41 47 E; 3063.20 S 2731.23 E 4104.00 S 41 43 E S 41 2 E 4201.87 S 41 39 E 4300.47 S 44 3 E 4398.69' $ 46 :9 E 4495.38 S 48 47 E 4589.86 S 50 49 E 4682.09 S 53 31 E 4769,39 S 55 24 E 4852.48 S 57 0 E 4931.30 S 56 12 E 5006.16 0.45 0.51 1.33 1,43 1,06 1.30 1,51 1,01 0.99 1.38 3137.92 S 2795.18 E 4202.33 S 41 41 E 3211,99 S 2860o16 E 4300.93 S 41 41 E 3284.28 S 2926.83 E 4399.18 S 41 42 E 3352.68 S 2995.54 E 4495.97 S 41 46 E 3416.93 S 3065.69 E 4590.63 S 41 53 E 3477.24 S 3136.95 i 4683.12 S 42 3 E 3531.95 S 3207.16 E 4770.80 S 42 14 E 3581.38 S 3277.03 E 4854.40 S ~2 gl E 3626.91 S 3344.88 E 4933.83 S 42 41 E 3669.43 S 3410.14 E 5009.37 S 42 54 E S 55 28 E 5079.03 S 55 54 E 5151.01 S 55 46 E 5221.94 S 55 46 E 5292.84 S 55 46 E 5311.21 0.78 0.79 0.00 0.00 0.00 3712.09 S 3472.23 E 5082.91 S' 43 5 E 3754.11 S 3533.67 E 5155.59 S 43 16 E 3795.35 S 3594.43 E 5227.29 S 43 26 E 3836.62 S 3655.10 E 5299.00 S 43 36 E 3847.31 S 3670.81 E 5317.58 S 43 39 E VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH FEET OEG/IO0 FEET FEET FEET DEG ARCO ALASKAt INC. ZT-1T KUPARUK NORTH SLOPEtALASKA MARKER TOP KUPARUK C BASE KUPARUK C, TOP KUPARUK A BASE KUPARUK A PBTD TD COMPUTATZON DATE: 16--SEP-86 PAGE DATE OF SURVEY: 05-SEP-86 KELLY BUSHING ELEVATION: 117,00, FT ENGINEER: M. MCBRIDE INTERPOLATED 'VALUES FOR CHOSEN HORZZONS MEASURED DEPTH BELOW 7954.00 7990,00 8075.00 8248°00 8Z48.00 84¢5.00 SURFACE LOCATION AT ORIGIN= 23 FNLt 556 FWL, SEC 12t TZ1Nt RBE UM TVD RECTANGULAR COORDINATES FROM KB SUB-SEA NORTH/SOUTH EAST/WEST 5848o13 5731.13 3682.70 $ 3429.69 E 5876.88 5759.88 3695.04 S 3447.49 E 5944.97 5827,97 3723,89 S 3489,¢0 E 608~.08 5967°08 3781°76 S 3574.45 E 608~.08 5967.08 3781o76 S 3574.45 E 6242°90 6125.90 3847.31 S 3670o81 E 'COMPUTATION DATE: 16-SEP-86 PAGE ARCO ALASKAt INC. DATE OF SURVEY: 05-SEP-86 2T-17 KUPARUK NORTH SLOPEsALASKA KELLY BUSHING ELEVATION: ENGINEER: M. MCBRIDE 117o00, FT ~~~ STRATIGRAPHIC SUMMARY MARKER MEASURED DEPTH BELOW KB SURFACE LOCATION AT ORIGIN: 23 FNL, 556 FRE,TANG TVD FROM KB SUB-SEA NORTH/SOUTH EAST/WEST TOP KUPARUK C BASE KUPARUK C TOP KUPARUK A BASE KUPARUK A PBTO TD 7954.00 7990.00 -8075.00 8248°00 8248.00 5848.13 5731o13 3682.70 S 3429.69 E 5876.88 5759°88 3695.04 S 3447°49 E 5944.97 5827.97 3723.89 S 3489.40 E 6084.08 5967,08 3781°76 S 3574.45 E 6084.08 5967.08 3781o76 S 3574.45 E 6242.90 6125.90 3847.31 S 3670.81 E FINAL WELL LOCATION AT TO: TRUE SUB-SEA MEASURED VERTICAL VERTICAL. 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' 6000 EAST WELL' 2T-17 (23' FNL, 556' FWL, SEC. 12,TllN,R8E,UM) VERTICAL PROJECTION - ]OOO 0 0 ]OOO 2000 :3000 4000 SOOO 6000 7000 1Bg. r- : .> , PROJECTIO, i 0~1 ~,'ER[,~'2~L PLA 'E t-39. - 91S, SCc._7-_O I;i VE:~7IEA'. OEFrHi t-;3Rf-' ;I.~ '. '. Form to be inserted in each "Active" well folder to check for timely compliance with our regulations. · .o. Required Date Received Remarks Completion Report Well History .................. . .. _ . - ~ ~ ~ ....... ~ . · ~ Core Chips ....... , Core Description _ .. . . ...... - Rgg~scered Survey , Inclination Survey ~'r/ ~" "- -- ~ K ~ ......... ~ , , , ,.~ , ,, ~ ...... Directional Survey ............ ~ - ~ .- ~ - ~ Drill Stem Test Reports, . ~ .......... Production Test Reports ............. .... Log Run .... -- STATE OF ALASKA .... AL~- _ iL AND GAS CONSERVATION COk .ON REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown [] Stimulate [] Plugging [] Perforate Alter Casing [] Other I~ Complete Pull tubing 2. Name of Operator ARCO Alaska. Irl~, 3. Address P.O. Box 100360 Anchorage, AK 99510 4. Location of well at surface 23' FNL, 556' FWL,. Sec. 12, T11N, R8E, UM At top of productive interval 1574' FSL, 1294' FEL, Sec. 12, TllN, R8E, UM At effective depth 1475'FSL, 1150' FEL, Sec. 12, T11N, R8E, UM At total depth 1410' FSL, 1053' FEL, Sec. 12, TllN, R8E, UM 5. Datum elevation (DF or KB)" RKB 1 I 7 ' Feet 6. Unit or Property name Kuparuk River Unit 7. Well number 2T-17 8. Approval number 45 9. APl number 50-- 1 03 -20060 10. Pool Kuparuk River 0il Pool 11. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Length Conductor 80' surface 3638' feet 8445'MD feet 6243'TVD 8248 'MD 6084 ' TVD Size 1 6" 9-5/8" Producti on 8405 ' 7" feet feet Plugs (measured) Junk (measured) None None Cemented Measured depth 225 sx CS I I 116'MD 1250 sx AS II I & 360 sx Class G 3671 'MD 375 sx Clas§ G & 175 sx AS I 8438 'MD ~ue Verticaldepth 116'TVD 2797'TVD 6238'TVD Perforation depth: measured 7956' - 7988'MD 8095' - 8102'MD true vertical 5850 ' ' 5875 'TVD 5961 ' - 5967'TVD Tubing (size, grade and measured depth) 2-7/8", J-55, tbg w/tail @ 8046' Packers and SSSV (type and measured depth) HB pkr ~ 7764' 8116' - 8147'MD 5978' - 6003'TVD , 1-B pkr 8 8027', & TRDP-1A-SSA SSSV ~ 1814' Alaska 0il & Gas Cons. 12. Stimulation or cement squeeze summary I n~le/rOals treated (measured) 13. Treatment description including volumes used and final pressure N/A Representative Daily Average Production or Injecti~' ~ata OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation Subsequent to operation 14. Attachments (Comp. Well History w/Addendum, dated 8-06-86) Daily Report of Well Operations [] Copies of Logs and Surveys Run ~ C-yz:o 15. I hereby certify that the foregoing is true and correct to the best of my knowledge Form 10-404 Rev. 12-1-85 Title Associate ~ngin~r Date Submit in Duplicate f DAM ~ SWO/1 Ol ARCO Oil and Gas Company Daily Well .istory-Final Report Instructions: Prepare and submit the "Final Report" on the first Wednesday after allowab!e has been assigned or '~,ell is Plugged. Abandoned, or Sold. "Final Report" shourd 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. fAccounting cost center code State Alaska Well no. 2T-17 District County or Parish Alaska North Slope Borough Field Lease or Unit Kuparuk River ADL 25567 Auth. or W.O. no. T t e AFt AK0847 Completion Nordic 1 AP1 50-103-20060 AR,Co. W.I. 56.24% Operator ARCO Alaska, Inc. Spudded or W.O. begun Complete Date and depth Complete record for each day reported as of 8:00 a.m. Date 9/03/86 I otal number of wells (active or inactive) on this ost center prior to plugging and bandonment of this well our Prior status if a W,O. 1445 hrs. 9/04/86 9/05/86 9/06/86 thru 9/08/86 7" @ 8438' 7798' WLM PBTD, RIH 10.8 ppg Brine Accept rig @ 1445 hrs, 9/3/86. OK. PU BHA & RIH. ND lower tree, NU & tst BOPE; 7" @ 8438' 8248', Prep to rn gyro 10.8 ppg Brine Drl cmt f/7836'-8248'. Rev circ, tst csg to 3500 psi, POOH. RU Schl, rn CET f/6950'-8239', POOH. PU GCT gyro. 7" @ 8438' 8248', RR 6.9 ppg Brine Rn gyro f/8203'-8236', RD WL. RIH w/bit & scrpr, circ & filter brine, POH. RU Schl, RIH, perf w/4" gun, 4 SPF f/8116'-8147' & 8095'-8102'. Perf w/5" gun, 12 SPF f/7956'-7988'. Rn 6-1/8" gage ring/JB. Bleed off fluid gain. RD WL. RIH, circ & wt up brine, POOH, chg pipe rams. RU WL, RIH, set lB pkr @ 8023'. Rn completions. SSSV @ 1814', HB pkr @ 7764', 1-B pkr @ 8027', & TT @ 8046'. Tst ann & tbg. Set pkr, shear SBR. Displ well to diesel. RR @ 2400 hrs, 9/7/86. Old TD New TD PB Depth Released rig Date Kind of r g 2400 hrs. 9/7/86 Classifications (oil, gas, etc.) I Type completion (single, dual, etc.) Oil I Single Producing method Official reservoir name(s) Flowing Kuparuk Sands Potential test data Well no. Date Reservoir Producing Interval Oil or gas Tesl 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 Date¢/'~ ~"/¢ ~' ITitle For form preparation and distribution, see Procedures Manual, Section 10, Drilling, Pages 86 and 87. ADDENDUM WELL: 4/21/86 8/o5/86 2T-17 Arctic Pak well w/175 sx AS I, followed by 60.5 bbls Arctic Pak. RU Otis S/L, RIH w/2.75" blind box, tag cmt @ 7798' WLM (7826' RKB), FC @ 8356' RKB. POH, RD Otis. Approx 530' of cmt in 7" above FC. Drilling Supervisor ARCO Alaska, Inc. Post Office ~ ~00360 Anchorage. Aiaska 99510-0360 Te!ept~one 907 27'6 121.5' TO: ARCO .ALASKA, INC. AT?N: Kuparuk Records Clerk ATO 1119 P. O. Box 100360 .~nchorage AK 99510-0360 DATE 08-08-86 TRANSMITTAL # 57&1 Transmitted herewith are the following items. Please acknowledge receipt and return one signed copy of this transmittal. Open Hole ~' ~znai Prints: Schl' One * of each 2T- 1 ~5'' DIL/SFL-GR 03-08-86 Run //1 3671-8365 ~2" .DIL/SFL-GR 03-08-86 Run I/1 3671-836,5 ~ 5" Den/Neu-GR (poro) 03.-08-86 Run ~/1 3671-8340 /I ~ 5" ~en/Neu-GR (raw) 03-08-86 Run t/1 3671-8340 ~ ~2" Den/Neu-GR (raw) 03-08-86 Run #1 3671-8340 ' ~ Cyberlook . 03-08-86 Run ~J! 7850-834~ ~"~Productive Interval 03-08-86 Run #1 7850-8340 ~Oo 03-08-86 Run #1 7957-8212 /3I--9 5" DiL/SFL-GR 2" D!L/SFL-GR 5" Den/Neu 2" Den/Neu 5" Den/Neu 2" Den/Neu Cyberlo0k 03-13-86 RUn~#l 1500-9122 03-13-86 ~.n #1 1500-9122 (poro) 03-13-86 ~n ~/1 8440-9096 ~poro) 03-13-86 Run #1 8440-9096 (raw) 03-13-86 Run #1 8440-9096 (raw) 03-13-86 Run #1 84&0-9096 03-13-86 Run #1 84A0-9065 3N-7'--5" DiL/SFL-_GR 03-06-86 Run #1 ~~/ ~-~2" DiL/SFL-GR 03-06-86 Run 5" Den / Neu-GR <poro ) 03-06-86 Run 2~- Den/Neu-GR .<poro) 03-06-86 Run //1 ~'~"5'~ Den/Neu-GR (raw) 03-06-86 Run #] 2" Den/Neu-GR (raw) ~Cyber!ook 1800-7777 1800-7777 6790-7752 6790-7752 6790-7752 03-06-86 Run #1 6790-7752 03-06-86 Run #1 7190-7752 3I-~" DIL/SFL-SR Den/Neu Den/Neu Den/Neu ~Cyberlook Recei 03-02-86 Run //1 1500-9204 03-02-86 Run #1 1500-9204 (poro) 03-02-86 Run #1 8750-9178 (poro) 03-02-86 Run ~/1 8750-9178 (raw) 03-02-86 Run. ~/1 8750-9178 (raw) 03- Run //1 8750-9178 8750-91 Rathmell*bl NSK Files*bl D & M*bl Vault*films ARCO Alaska, Inc. ,,* a ,'~u~$~diary o! &tlanticRichfiel~CompanY STATE OF ALASKA ~ ALASK. OIL AND GAS CONSERVATION COMN .SION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request.: Abandon [] Suspend ~ Operation Shutdown ,~ Re-enter suspended well ~ Alter casing ~ Time extension D Change approved program i% Plugging [] Stimulate ~ Pull tubing ~ Amend order ? Perforate ~ Other 2. Name of Operator ARCO Alaska, Inc. 5. Datum elevation (DF or KB) 117' RKB feet 6. Unit or Property name K,,n~r,,b Ri~/Pr liner 3. Address P. 0o Box 100360 AnchoraqD, AK 99S10 4. Location of well at surface 7. 23'FNL, 556'FWL, Sec.12, T11N, R8E, UM 2 T11N, R8E, UM (approx.) T11N, R8E, UM (approx.) TllN, R8E, UN (approx.) Well number T-17 8. Permit number 86-43 9. APl number 50-- 103-20060 At top of productive interval 1408'FSL, 1396'FEL, Sec.12, At effective depth 1391'FSL, 1145'FEL, Sec.12, At total depth 1360'FSL, 1097'FEL, Sec.12, 10. Pool Kuparuk River 0il Pool 11. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Conductor 8445 feet Plugs (measured) No ne 6227 feet Surface Production feet Junk (measured) 8356 feet No ne 6159 Length Size Cemented Measured depth True Vertical depth 80' 16" Conductor report 116'MD 116'TVD not available. 3638' 9-5/8" 1250 sx AS III & 3671 'MD 2817'TVD 360 sx Class G 8405' 7" 375 sx Class G 8438 'MD 6222'TVD Perforation depth: measured None true vertical N o n e Tubing (size, grade and measured depth) Packers and SSSV (type and measured depth) None None BOP sketch 12.Attachments Description'summary of proposal [] · Detailed operations progra~ Well Hi story 13. Estimated date for commencing operation June, 1986 · 14. If proposal was verbally approved Name of approver Date apl~r0ved 15. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed ~~.,, .~./A~ Title Associate Engineer Date ~/ Commission Use Only (DAM) SA/025 Conditions of approval Notify commission so representative may witness I Approval No. [] Plug integrity ~ BOP Te, s,t. ~ Location clearancel ¥~p~roveo ~.c~ ~- · ~i ~ 'Commissioner the commission Date --~' Approved by ~'~ [~¢:?~ ~' ':' '~'~z~ by order of Form 10-403 Rev 12-1-85 Submit in triplicate ARC° Oil and Gas Company Well History- Initial Report- Daily Instructions: Prepare and submit the "Initial Report" on the first Wednesday after a well is spudded or workover operations are started, Daily work prior to spudding should be summarized on the form giving inclusive dates only· District Field Alaska Kuparuk River ICounty, parish or borough North Slope Borough ILease or Unit ADL 25567 JTitle Drill State Alaska IWell no. 2T-17 Auth. or W.O. no, AFE AK0847 Rowan 34 AP1 50-103-20060 Operator ARCO Alaska, Inc. 2119186 2/20/86 2/21/86 2/22/86 thru 2/24/86 2/25/86 2/26/86 2/27/86 2/28/86 3/01/86 thru 3/03/86 Date and depth as of 8:00 a.m. Complete record for each day reported 0530 hrs. IARCO W.I. Prior status if a W,O. 56.24% 16" @ 116' Modifying rig. 16" @ 116' Modifying rig. 16" @ 116' Modifying rig. 16" @ 116' Modifying rig. 16" @ 116' Modifying rig. 16" @ 116' Modifying rig. 16" @ 116' Modifying rig. 16" @ 116' Modifying rig. 16" @ 116' 3700', (3593'), TOH f/9-5/8" csg Wt. 9.8, PV 19, YP 11, PH 8.5, WL 20, Sol 10 Accept ri~ @ 2130 hfs, 2/28/86. NU diverter sys. Spud well @ 0530 hfs, 3/1/86. Drl & surv 8½" hole to 3700', 25 std short trip, C&C, TOH. 396', Assumed vertical 6.8°,S60.4E, 556.72 TVD, , 22.2°,S40.9E, 996.45 TVD, , 37.9°,S44.5E, 1395.44 TVD, , 47.0°,S42.8E, 1630.55 TVD, , 50.1°,S41.9E, 2007.87 TVD, 9.00 VS, 4.72S, 8.30E 123.80 VS, 83.25S, 93.01E 351.60 VS, 244.75S, 254.52E 564.96 VS, 397.86S, 403.65E 992.05 VS, 713.60S, 961.46E , 53.1°,S44.4E, 2537.08 TVD, 1647.97 VS, 1200.60S,1131.08E , 53.1=,S44.5E, 2807.27 TVD, 2007.12 VS, 1457.49S,1383.08E 557', 1013' 1474' 1792' 2362' 3205' 3655' The above is correct Signature For form preparation and distribut~m, see Procedures Manual, Section 10, Drilling, Pages 86 and 87. Date . I Title li,h , 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 workovers and following setting of oil string until completion. District Field Alaska County or Parish IState North Slope Borough ILease ADL 25567 or Unit Kuparuk River Alaska JWell no. 2T-17 Date and depth as of 8:00 a.m. 3/04/86 3/05/86 3/06/86 3/07/86 3/08/86 thru 3/10/86 Complete record for each day while drilling or workover in progress 9-5/8" @ 3671' 3700', (0'), NU BOPE Wt. 9.8, PV 18, YP 6, PH 8.5, WL 20, Sol 10 RU & rn 91 its, 9-5/8", J-55, 36#, HF/ERW BTC csg w/FC @ 3586', FS @ 3671'. Cmt ,w./1250 sx AS III w/10#/sx Kolite, followed by 360 sx C1 "G" w/2% S-1 & .2% D-46. Displ using rig pmp, bump plug. CIP @ 1830 hrs, 3/3/86. ND diverter. NU BOPE. 9-5/8" @ 3671' 4703', (I003'), Drlg Wt. 8.8, PV 3, YP 7, PH 11, WL 22, Sol 2 NU & tst BOPE. TIH w/BHA, tag cmt @ 3570', tst csg to 2000 psi. Drl flt equip, cmt & 10' new hole. Conduct formation tst to 8.9 ppg EMW. Drl & surv 8½" hole to 4703'. 4133', 46.3°, S36.1E, 3116.44 TVD, 2371.66 VS,1735.52S,1618.87E 9-5/8" @ 3671' 6855', (2152'), Drlg Wt. 9.5+, PV 10, YP 7, PH 9.5, WL 8.5, Sol 6 Drl & surv 8½" hole to 6855'. 4697', 44.0°, S38.3E, 3514 TVD, 2770 VS, 2054S, 1860E 5255', 43.5°, S35.5E, 3917 TVD, 3155 VS, 2362S, 2092E 5876', 47.8°, S36.1E, 4351TVD, 3598 VS, 2722S, 2352E 6501', 44.7°, S38.1E, 4783 TVD, 4048 VS, 3082S, 2624E 9-5/8" @ 3671' 7880', (1025'), POH 30 stds Wt. 10.8+, PV 17, YP 9, PH 9.0, WL 9, Sol 12 ~ Drl & surv 8½" hole to 7880', break circ w/no rtns, TOH 7 stds,.~ giving mud back to DP. Pmp wt pill, POH dry 30 stds. 7056', 44.2°, S46.6E, 5179 TVD, 4437 VS, 3370S, 2886E 7552', 41.3°, S55.3E, 5544 TVD, 4768 VS, 3582S, 3147E 7807', 38.7°, S58.0E, 5739 TVD, 4926 VS, 3672S, 3284E 7" @ 8438' 8445' TD, 8356' PBTD, ND BOPE 10.8 ppg NaC1/NaBr POOH to shoe, C&C. Stage back in hole, hit bridge @ 5527'. Wrk thru, TIH to 7795', rm to 7880', drl to 8385' TD, short trip, TOH f/logs. RU & rn DIL/GR/SP/SFL f/8375'-3671', FDC/CNL f/8375'-7740', 6750'-6550', 5020'-4820' & 4450'-3671', RFT f/7957'-8213' (22 sets), RD loggers. TIH, drl 8½" hole f/8385'-8445', circ, TOH, LD DP. RU & rn 207 + mkr jts, 7", 26#, J-55 BTC csg w/FS @ 8438', FC @ 8356'. Cmt w/125 sx 50/50 Poz & 250 sx C1 "G" w/3% KC1, .9% D-127, .3% D-13 & .2% D-46. Displ w/10.8 ppg NaC1/NaBr, did not pump plug. CIP @ 0030 hrs, 3/10/86. ND BOPE. The above is correct Signature For form preparation and ~istribution see Procedures Manual Section 10, Drilling, Pages 86 and 87 JDate ]Title Drilling~Su~p~ [0 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 comptetion, 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 Field Alaska ICounty or Parish Lease or Unit Title North Slope Borough Accounting State cost center code Alaska Kuparuk River Auth. or W.O, no. AFE AK0847 ADL 25567 Drill IWell no. 2T-17 Rowan 34 Operator ARCO Alaska, Inc. Spudded or W.O. begun Spudded Date and depth as of 8:00 a.m. 3/11/86 Old TD AP1 50-103-20060 A.R.Co. W.I. rrotal number of wells (active or inactive) on this i Icost center prior to plugging and 56.24% labandonment of this well Date IHour I Prior status If a W,O. 3/1/86 ! 0530 hrs. I Complete record for each day reported 7" @ 8438' 8445' TD, 8356' PBTD, RR 10.8 ppg NaC1/NaBr Set pack-off. NU & tst tree. RR @ 0800 hrs, 3/10/86. New TD Released rig Date 0800 hrs. Classifications (oil, gas, etc.) Oil Producing method Flowing PB Depth 8445 ' TD K nd of rig 3/10/86 Type completion (single, dual, etc,) Single Official reservoir name(s) Kuparuk Sands 8356' PBTD Rotary 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 ITitle For form prepara~.',on and distribution, see Procedures Mat;ual, Section 10, Drilling, Pages 86 and 87. Drilling Superintendent ARCO AlasKa. Ir, Post Office Box 100360 Anchorage. AlasKa 99510-0360 Telephone 907 276 1215 DATE 04-01-86 TRANSMI."~IAL # 5613 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. return one signed copy of this transmittal. Please acknowledge receip~ and OH LIS Tapes plus Listings: Schl: One of each 3N-9 03-23-86 3N-8 03-14-86 3N-8A 03-19-86 3N-7 03-06-86 31-12 03-22-86 3I-9 03-13-86 3I-8 03-02-86 2T-17 03-08-86 Run #1 0091.0-44241~~9_~-~-~P~/~ - ~/--Z/q~_~ R~ #1 0115 0-6670 O&933-5-O/~e~-- //~- ~ ~ R~ ~2A 3624.0-6859.~~~--~--~e~--~~~ R~ ~1 1986 5-7568.~~y3F-3-~~--~ [- a~ ~1 1500.0-9122-~~q,3~-3-Npa~- /~-- ~/~ Receipt Acknowiedqed: State Of AK. f-' STATE OF ALASKA ~(~,...~l/' ALASKA ~..- AND GAS CONSERVATION CC _MISSION MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS !1. Drilling well ~( Workover operation [] 2. Name of operator 7. Permit No. ARCO Alaska, Inc. 86-43 99510 3. Address P. 0. Box 100360, Anchorage, AK 4. Location of Well at surface 23' FNL, 556' FWL, Sec.12, T11N, R8E, UM 5. Elevation in feet (indicate KB, DF, etc.) 117' RKB 6. Lease Designation and Serial No. ADL 25569 ALK 2667 8. APl Number 50- 103-20060 9. Unit or Lease Name Kuparuk River Unit 10. Well No. 2T-17 11. Field and Pool Kuparuk River Field Kuparuk River Oil Pool For the Month of. March , 19 86 12. Depth at end of month, footage drilled, fishing jobs, directional drilling problems, spud date, remarks Spudded well ~ 0530 hrs, 3/1/86. Drld 12-1/4" hole to 3700'. Ran, cmtd, & tstd 9-5/8" csg. Drld 8-1/2" hole to 8385'. Ran logs. Cont'd drlg 8-1/2" hole to 8445'TD (3/9/86). Ran, cmtd, & tstd 7" csg. PBTD = 8356'. Secured well & RR ~ 0800 hrs, 3/10/86. 13. Casing or liner rgn and quantities of cement, results of pressure tests 16", 62.5#/ft, H-40, weld conductor set ~ 116'. Conductor report not available. 9-5/8", 36.0#/ft, J-55, BTC csg w/shoe ~ 3671'. Cmtd w/1250 sx AS Ill & 360 sx Class G. 7" 26.0#/ft, J-55, BTC csg w/shoe ~ 8438' Cmtd w/375 sx Class G 14. Coringresumeand briefdescription None 15. Logs run and depth where run DIL/GR/SP/SFL f/8375' - 3671 ' FDC/CNL f/8375' - 7740', 6750' - 6550', 5020' - 4820', 4450' - 3671' RFT f/7957' - 8213' (22 sets) 6. DST data, perforating data, shows of H2S, miscellaneous data None 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. NOTE -Report i~ 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 DAM2/MR07 Submit in duplicate February 13, 1986 Mr. J. B. Kewin Regional Drilling Engineer ARCO Alaska, Inc. P. O. Box 100360 Anchorage, Alaska 99510-0360 Telecopy: (907) 276-7542 Re: Kuparuk River Unit 2T- 17 ARCO Alaska, Inc. Permit No. 86-43 Sur. Loc. 23'F~, 556'F%~L, Sec. 12, TllN, R8E, Btmhole Loc. lll9'FSL, !146'FEL, Sec. 12, TllN, RSE, UM. Dear Mr. Kewin: EnClosed is the approved application for permit to drill the above referenced well. The permit to drill does not indemnify you from the probable need to obtain additional permits required by law from other governmental agencies prior to commencing operations at the well site. To aid us in scheduling field work, please notify this office 24 hours prior to commencing installation of the blowout prevention equipment so that a representative of the Commission may be present to witness testing of the equipment before the surface~ casing shoe is drilled. Where a diverter system is required, please also notify this office 24 hours prior to commencing eqdipment installation so that the Commission may witness testing before drilling below the shoe of the conductor pipe. Ve~/~ tru~y6~_s-, / ., C. V. Chat~t~n.. Chairman of Alaska Oil and Gas Conservation Commission BY ORDER OF I~HE COMMISSION dlf Enclosure CC: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. Mr. Doug L. Lowery ARCO Alaska, Ir '- Post Offic --f J0360 Anchorage .... =~(a 99510-0360 Telephone 907 276 1215 February 3, 1986 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT: Kuparuk 2T-17 Dear Mr. Chatterton: Enclosed are: o An application for Permit to Drill 2T-17, along with a $100 application fee o Diagrams showing the proposed horizontal and vertical projections of the wellbore o A proximity plot o A diagram and description of the surface hole diverter system o A diagram and description of the BOP equipment We estimate spudding this well on February 14, 1986. If you have any questions, please call me at 263-4970. Sincerely, ~/Regional Drilling Engineer JBK/LWK/tw PD/L229 Enclosures ARCO Alaska, Inc, is a Subsidiary of AtlanticRichfieldCompany RECEIVED Alaska Oi~ & Gas Gons. Gomm~ssiorl Anchorage la. Type of work. ":~- STATE OF ALASKA .... ALASKA O,- AND GAS CONSERVATION COIv, MISSIO~ DRILL DRILL I~]x lb Type of well EXPLORATORY [] SERVICE [] sTF~'i'~APHI~ · ~,, ,, DEVELOPMENT OIL L~A SINGLE ZONE DEVELOPMENT GAS [] MULTIPLE ZONE 2. Name of operator ARCO Alaska~ Inc, 3. Address P, 0, Box 100360~ Anchorage~ Alaska 99510 REDRILL [] DEEPEN [] 4. Location of well at surface 23~ FNL~ 556~ F~L~ Sec,12~ T11N~ R8E~ UN At top of proposed producing interval 1408~ FSL~ 1396~ FEL~ Sec,12~ T11N~ RSE~ UN At total depth 1119' FSL, 1146' FEL, Sec.12, T11N, R8E, UM 5. Elevation in feet (indicate KB, DF etc.) 6. Lease designation and serial no. RKB 117~ PAD 82~ ADL 25569 ALI( 2667 .~ , 12. Bond information (see 20 AAC 25.025) I-edera! Insurance Company Type Statewide Surety and/or number #8088-26-27 13. Distance and direction from nearest town I 14. Distance to nearest property or lease line 30 mi, NW of Deadhorse miles I 1119 feet 16. Proposed depth (MD & TVD) 17. Number of acres in lease 8503 ' ND~ 6165' TVD feet 2560 19. If deviated (see 20 AAC 25.050) 120. Anticipated pressures KICK OFF POINT 400 feet. MAXIMUM HOLE ANGLE 48 Ol(see20AAC25.035 (c) (2) 9. Unit or lease name Kuparuk River Unit ~10. Well number 2T-17 11. Field and pool Kuparuk River Field Kuparuk River 0il Pool Amount $500,000 15. Distance to nearest drilling or completed 2A-13wel12450' ~ 8503'MD/6165'TVDeet 18. Approximate spud date 02/14/86 2977 psig@_ 80°F Surface __ psig@ 6031 ft. TD (TVD) 3418 21 Proposed Casing, Liner and Cementing Program CASING AND LINER SETTING DEPTH QUANTITY OF CEMENT Length MD TOP TVD (include stage data) SIZE ...... Hole Casing Weight :z~" 1 b" 62,5# 2-1/4" 9-5/8" 36.0# 8-1/2" 7" 26.0# 22. Describe proposed program: Grade H-40 -55/HF-E[ ,-55/HF-EF Coupling Weld '.W BTC :W BTC 80' 3464' 8469' 35' I 35' 35' I 35' I 34' 34 I M D BOTTOM TV D 115i 115' 34991 2821' 8503 '1 6165 ' + 200 cf 1070 sx AS III & 360 sx Class G blend 300 sx Class G ARCO Alaska, Inc., proposes to drill a Kuparuk River Field development well to approximately 8503'MD(6165'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 13-5/8", 5000 psi, RSRRA BOP stack will be installed on the 9-5/8" surface casing. The stack and related equipment will be tested to 3000 psig upon installation and weekly thereafter. Expected maximum surface pressure is 2977 psi. Surface pressure is calculated with an unexpanded gas bubble at surface, including temperature effects. Casing will be tested to 3500 psi prior to releasing the drilling rig. Non-freezing fluids will be left in uncemented annuli through the permafrost interval. 2T-17 will be 2450' away from 2A-13 at TD (8503'MD/6165'TVD). 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 interruptions in the disposal process. (continued on attached sheet) · 23. I hereby certify that the foregoing is true and correct to the best of my knowledge SIGNED ~ TITLE Regional Drilling Engineer DATE T h e spa c/~o~'-¢r ~ o/m i ss i'-o n u'se'~- co.o,T,O.S o. Samples required Mud log required E~]YES J~O I-lYES Permit number Approval date I _ o2/L3/.86 Form 10401 (L~ PD/PD22~ / Rev. 7-1-80 Directional Survey required I APl number SEE COVER LETTER FOR OTHER REQUIREMENTS ',COMMISSIONER DATE February 13, 1986 by order of the Commission Submit in triplicate PERMIT TO DRILL 2T-17 (cont'd) Upon completion of the disposal process, the 9-5/8" x 7" annulus will be sealed with a minimum of 175 sx cement followed by Arctic Pack. The well will be completed by the workover rig using 3-1/2" or 2-7/8" 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. ?AD 2T._WELL NO, 17 PI~OPOSED ': - KUPARUK FIELD. NORTH SLOPE. ALASKA ....................................................EASTMAN. WH ! PSTOCK. 3KOP'- TVD=400 TMD=400 DEP=O . BUILD . _ 1 1 $ ..... PER .,lDO .Fl'. 21 BASE PERMAFROST TOP UGNU SNDS '~$ EOC TVD--1821 TOP 3000 ...... TXD=2821 TVD=I 561 -TMD=1648 DEP=393 TVD=IT'll TMD=1845 DEP=521 THD=2002 DEP=634 _. . . _ W SAK SNDS TVD=2281 TMD=2691 DEP=1146 K-i2 TVD=2621 TMD=3200 DEP=1525 9 5/8" CSG PT THD=3499 DEP=1747 4000 AVERAGE ANGLE 48 DEG 4 MI N <-5 TVD=4391 THD=5849 DEP=3495 5001 T/ ZONE C TVD=5821 TMD=7989 DEP=5088 T/ ZONE A TVD=5908 TMD=8'll9 DEP=5184 6 TARGET CNTR--. TVD=5926--,THD=8146 DEP=5205 , B/ KUP SNDS TVD=6031TMD=8303 DEP=5321 t TD (LOG. PT) TVD=6165 TMD=8503 DEP=5470 7000 'l ' ; ' , 0 i000 2000 3000 .......................... : ........................ VERTiCAL~SECTiON 4000 I I 5OOO 6OO0 ................... HOR I ZONT AL ~PROJECT I oN L ~LE 1 IN,. = 1000 FEET ARCO ALASKA, INC. -' ................. ,/Iix PAD 2T. WELL NO, 17 PROPOSED ..... ~' ./II ~__'~ - - . ..................... KU..P_^RUK _FIELD :_.._NOR_ _T_.H_ SL_O.P_E_.,. _A.I,A~._KAii'; ~'_~,~_._.~;.-~ ...................... . ............ . __. EASTMAN WHIPSTOCK .~,~i-. -.. ............. ........................................................... . ................ . .......................................... ............. , .................. _ _ ......... : . .' "_.~'.-'i'_ .;._.~ ._.-. ..................... ;...._;-_.;~ .WEST_EAST ~ - - _ ..... :1000 ..... 0.' ........ 1 000 . 2000 3000 4000 5000 ........... 1000 ._ ' ........ - ' ' ...... . .............................. ........ - RtE'CEIVED .......... l .... 2000 ' . ........................................................................... . . 'i u. p, I--~ ---I _ .... -r .......................... A!aska Oil & Gas Cons. Commissior¥ ..... Anchflmoe ......... 3000__ ..... -- . ...... ' .......... ' ........... .;.."..' ................. L.....'2_. -- 4000 ....... TAReET CENTER .... ....... . TVD-$926 ................... : ................................ THD=8146 ...... ~ ..... ~ ......... DEP-S205 ............................................ ......................................................................... SOUTH '- 393'/'--':- .............. ' ................................................. -' EAST 3404 ............ ~ - - ......... = - . : ....................... ............ 5000 ................... _J ...... !_ ..... Z..]'.. .... "..- ...... L.i ..~ .... L-TARu'~ET' LOOATION,~- !~'iLi'._:,L_ TD LOCATION, · 1320' FSL, 1320' FEI_ .... 111g' FSL, 1146' FEL .... - .... - ' ; ' ..... .-- SEC, 12, .TI1N, RSE ..... SEC, !2, TI1N, R8E '..- ....... ' .... -: ..... i .S:40 DEC 51. MI N E"-. .... .... ~ .": :. "._:. . , ... 5205_" (TO-TARGET) ._._ KUPARUK R! VER UNIT 20" DIVERTER SCHEMATIC DE S CR I P T I ON ,J 5 2 1. I G' COf, OUCTOR. 2. TANI,(O STARTER HEAD. 3. TAh,~O SAVER SUB. 4. TAf~O LO~ER QUICK-C~CT ASSY. 5. TANI<O UPPER QUICK-C~CT ASSY. 6. 20' 20CE) PSI DRILLING SPOOL W/I O' . OUTLETS. 'fo I0' HCR BALL VALVES W/lO" DIVERTER LINES,, VALVES OPEN AUTOMATICALLY UPON CLOSURE OF Ah, N.E. AR PREVENTER° 8° 20" 2000 PSI Ah, I%ULAR PREVENTER. Anchorage MAINTENANCE & OPERAT. ION I, UP~)N INITIAL INSTALLATION. CLOSE PREVENTER AND VERIFY THAT VALVES · HAVE OPENED PROPERLY. 2. CLOSE AI',INZJLAR PREVENTER AND BLOW AIR THROU~ DIVERTER LINES EVERY 12 HOURS. CLOSE Ah~ULAR PREVENTER IN THE EVENT 'THAT AN Ih,FLUX OF ~ELLB~ FLUIDS OR GAS IS DETECTED. IF NECESSARY,. N~Ah~JALLY OVERRICE[ AND CLOSE APPROPRIATE VALVE TO ACHIEVE DO~'e~'I~IND DIVERSION, DO NOT SHUT IN ~ELL < < I ' ,] 5 > > 1~-5/8 ~<]{x] PS] RSR~A BOP STACK 1. I G' - 2000 PSI TA~CO STARTING FF_AD 2. I1' - ~)00 PSI CASING FEAO 3. Ii' - ~X]O PSI X 15-5/8' - 5~ PSI SPACER SPOOL 4. 15-5/8' - 5000 PSI PIPE RA~ 5. 15-5/8' - 5000 PSI DRILLING SF~20_ W/C~CKE AhD KILL LIhES G. 15-5/8' - 5000 PSI DOL~ RAM W/PIPE RA~ CN TOP, 7. 15-5/8' - 5000 PSI AI~ AC~LATOR CAPACITY TEST I. Q-E~ AN3 FILL AOO, M.JLATOR RESERVOIR TO'~ LEVEL WITH HYDRALLIC FLUID. 2. AS~ THAT A~TCR PRE~ IS ~ PSI WITH 1500 PSI D(~TREAM OF THE REGL~TOR. 3. CE~VE TII~, TFEN CL__C~_ ALI. UNITS SIh~LLTAh~CUSLY AhO RECORD ~ TIt~E AflO PR~ RE'24AINING AFTER ALL UNITS ARE CLOSED WITH Q-L~ING PL~ OFF. 4. RECC~ ON NADC F~_PCRTo T~ ACCEPTABLE LO~ LIMIT IS 45 SEC~ CLOSING TIDE~ AhO 1200 PSI RE~INING PRESSURE. 4 3 2 A. laska Oil & Gas Cons, Commissior, Anchorage 13-5/8" 80P STAC)( TEST I. FILL BOP STACX AflD CHC]<E MANIFOLD WITH ARCTIC DIESEL. 2. Q-ECX THAT ALL LOCX D~ S~ IN ~E]_[J-F_AD A~ F-~Y RETRAOTI~. SF_AT T-r_ST PLUG IN WITH RUNNING JT Arid RUN IN LO(~ SC~. LIh~ VALVES ADJACE3VT TO E~ STAC~ ALL OTHER VALVES AJ',D ~ SHO,.LD BE C~gN. 4. PRESSURE UP TO 250 PSI Ah~ HOLD FOR I0 MIN. IN- CR~ PRESS~ TO 3000 PSI AhO HOLD FOR I0 MIN. BLEED PRESSL~ TO 0 PSI. 5. OPEN A~ PREVENTF~ A~ ~4NNLJAL KILL AhD OHOKE LI~E VALVES. CLOSE TOP PIPE RAMS AhD HCR VALVES ON KILL ~ CHOKE LINES. TEST TO 250 PSI A~ 3000 PSI AS IN STEP 4. 7. CCINTI~ TESTING ALL VALVES° LIN~So A~ CHOKES WITH A ~ PSI LC~ AhO 3000 PSI HIGH. TEST AS IN STEP 4. DO NOT F~,~ TEST ANY O-~ THAT iS F~ F~J_L O..OS~N~ P0~TIVE SE~L O-K~KE. 0hL. Y I'CIN TEST Q-K~$ 1-HAl' DO hOT FILLY CLOSE. 8. CPEN TO: PIPE RA~ ~ CLOSE BOI'FO~4 PIPE RAI~. TEST BCrrTC~ PIPE RANIS TO ~ PSI AflD ~X)0 FX3I. 9. OPE~ BO'~OM PIPE RANIS, BACX OL/T RUNNING JT ]O. OLOE~ BLIhO RAMS AIxO TEST TO 250 PSI PSI. I~. ~ BLIhO RAMS AI~ RETRIEVE TEST PLLK3. I~ SURE MANIFO_D AflO LINES ~ FULL. OF NOfl~-FF~E'ZING. FLUID. ~ ALL VALVES IN DRILLING POSITIO'~. 12. TEST STAN2PIPE VALVES, K~IY, KELLY OOCXS, DRILL' PIPE SAFETY VALVE, AflD INSIDE BOP TO ~ PSI AN2 3000 PSI. 13. RECORD TEST IN:'~TION ON BLOWOL. FT I:~ TEST F~, SIGNo A. hO SE. AD TO DRILLING SUPERVISOR. ECE VE ' ' 510084001 REV. ARCO-Alaska, Inc. Pos~ Office ~× 100360 Ancbor~ge~ ~,~ask~ 99510-0360 Te~e~ho~':~e 907 276 1215 January 31, 1986 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT- Conductor As-Built Location Plat - 2T Pad (Wells 2- 17) Dear Mr. Chatterton' 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 GRU13/L44 Enclosure If ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany ? I f 9 8 , , LOCATED IN PROTRACTED LOCATED IN PROTRACTED · SEC. I, Tii N,R8E, U.M. SEC. I , TI I N,R8E, U.M. 2 - Y = 5,970,382.43 LAT. 70°19'49.1287" 10 - Y = 5,970,132.65 LAT. 70°19'46.6719" X = 498,944.93 LONG. 150°O0'30.807" X = 498,945.27 LONG.150000'30.796" 4.02' FSL, 556' FWL OG = 77' PAD = 81.5 152'FSL, 556' FWL OG ' 76.0 PAD = 81.7 3 - Y = 5,970,357.42 LAT. 70"19'48.8828" 11 = Y = 5,970,107.71 LAT. 70019'46.4267'' X = 498,944.91 LONG. 150"00"30.808" X = 498,945.10 LONG. 150000. 30.801" 377' FSL, 556' FWL OG = 77' PAD -- 81.5 127' FSL, 556' FWL OG = 75.9 PAD = 81.7 4 - Y = 5,970,332.46 LAT. 70°19'4.8.6372'' 12 - Y = 5,970,082.58 LAT. 70°19'46.1794" - X : 498,944.84 LONG. 150°00' 30.809" o X : 498,944.98 LONG. 150o00' 30.804" 352" FSL 556' FWL OG = 77' PAD : 816 '~ 102' FSL, 556' FWL OG ' ' CO 5- Y = 5,970,307.52 LAT. 70°19'48.3919" '~ 13 - Y = 5,970,057.59 LAT. 70°19'45.9336 X = 498,944.91 LONG. 150000' 30.808" ~oF:: X 77': FSL,498' 945. 08556, FWL oGLONG"' 75150°00'5 PA030'801"= 81.6 327' FSL, 556' FWL OG = 77' PAD : 81.6 LO c.~ ' 6- Y : 5,970,282.50 LAT. 70°19'48.1459'' ~ ~ 14- Y = 5,970,032.60 LAT. 70019'45.6879" X 498 944.95 LONG 150°00 30.806" ~ ~ c-; c~ ' = r_~ X : 498,944.91 LONG.150°O0'30.806" = ' ' ~ ('~ 302' FSL, 556' FWL OG = 77' PAD = 81.7 '="'= LF~ c.~ ~.i 52' FSL, 556' FWL OG = 75.3 PAD : 81.7 7 - Y : 5,970,257.54 LAT. 70°19'47.9003'' [--[-.J 0 ~ c-~ 15 - Y : 5,970,007.69 LAT. 70019'45.4428" ' ~ ,,~ X 498,944.93 LONG. 150°00' 30.806" X = 498,944.95 LONG. 150°O0 30.806" U ~ 27' FSL, 556' FWL OG = 75.2 PAD = 81 6 . ~ . 277' FSL 556' FWL OG : 77' PAD : 81.6 ~ · 8 - Y : 5,970,232.63 LAT. 70°19'47.6553" .~ 16 - Y = 5,969,982.85 LAT. 70°19'45.1985'' X : 498,944.96 LONG.150°O0'30.806'' ~ ~ ~ X = 498,944.88 LONG.150°O0'30.807'' 252' FSL, 556' FWL OG = 76.9 PAD = 81.6 ~ 2' FSL, 556' FWL OG : 75.1 PAD -- 81.7 9 - Y= 5,970.207.62 LAT. 70°19'47.4093" '[~m LOCATED IN PROTRACTED X = 498,945.01 LONG. 150°00'30.804'' ~ SEC.12, TI I N, ESE, U.M. 227' ESL, 556' FWL OG = 76.3 PAD : 81.6 17 - Y : 5,969,957.72 LAT. 70°19'44.9514" .J =_ .498,9~,4.94 . .LON~,jS~°0{)' 3.~.805" ~ ~'~.~i~F~,.L~ ~5'61". ;Ft~4L' OG ~ '~5~-!0 ~AI)~= 81.6 ,. NOTES I, ALL COORDINATES ARE A.S.P.~ZONE4. 2. SECTION LINE DISTANCES ARE TRUE. ~ ~iL.:: '- ....... :5. HORIZ~ POSITIONS BASED ON TEMP. MON's 2T-EAST, 2. T-WEST I~ 2T-MIDDLE PER LHDi~ ASSOC. 4. VERT. POSITIONS BASED ON TBM's 2T-6 & NI9+75, EI1+52 PER F.R.B. I~ ASSOC. 5. O.G. ELEVATIONS INTERPOLATED FROM S/C DRAWING CED- RIXX-3140 rev. Z~o I CERTIFICATE OF SURVEYOR: i PIEREBY CERTIFY THAT I AM PROPERLY REGISTERED AND LICENSED TO PRACTICE LAND . · ~ ~' ~ SURVEYED FOR. ~ ~ ~ · DR&WE WM U~I~ ~1/~ ~/ ~l~V~)~ f'G ~ ~,~= ~K F.R.~.~5~ AS- BUILT LOCATIONS ~5 Arctic Bou/evard, Suite 20 ~, Anchorage, Alaska 99503 S~LE N.T. 8. JOB CHECK LIST FOR NEW WELL PERMITS Company Lease & Well No. /<~ ~ ITEM APPROVE DATE (2) 8) (aL / / (3) mdminf/~-~''/ ~-'/Z'~ 9. ~,9 thru '1~ 10. '(~ 0 'a~d ~ 2. (13 thru 21) -(22 t~u 26) 1. Is the permit fee attached ......................................... 2. Is well to be located in a defined po~l ............................ 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 ................ ! ' !i® i !i 8. Can permit be approved before ten-day wait ~ ........... 13. 14. 15. 16, 17. 18, 19. 20. 21. 22. : 23. 24. 25. 26. (6) Add: ~7.~. ,,~-/£-~& 27. YES NO Does operator have a bond in force .................................. ~ Is a conservation order needed ...................................... Is administrative approval needed ................................... I th 1 b ppr pri ' ~ s e ease num er a o ate ..... o ....... ... · ................... L~ Is conductor string provided ........................................ /Iff Is enough cement used to circulate on conductor and surface ......... /7~( Will cement tie in surface and intermediate or production strings ... ~ ., Will cement cover all known productive horizons ..................... z~ Will surface casing protect fresh water zones ....................... ~ Will all casing give adequate safety in collapse, tension and burst.. ~ Is this well to be kicked off from an existing wellbore ............. Z~ Is old wellbore abandonment procedure included on 10-403 ............ Is adequate wellbore separation proposed ........................... ~ -- · ,, Is a diverter system required ....................................... ~ Are necessary diagrams of diverter and BOP equipment attached ....... _~ Does BOPE have sufficient pressure rating - Test to ~j~ psig .. ~ Does the choke manifold comply w/API RP-53 (Feb.78) .................. Is the presence of H2S gas probable ................................. Additional requirements ............................................. REMARKS Geology: Engin, eerin~: HWK LCS ~ BEW-- ~ JAL~/%--~· rev: 03/13/85 6,011 ...... INITIAL GEO. " UNIT ON/OFF POOL CLASS STATUS AREA NO. SHORE 0 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. LiS T.&P~ V ER'IsZC~TZ'ON LISTING · q/tLloO · RECEIVED APR 1 5 1986 Anchorage LVP 010.~0~ Vf~IFiC'~TiSN LISTING PAG~ I .... ~- REEL HZ~DER SERVICE NAME :EOIT 9~TE :85103118 ORIGIN : 'REEL NAME :149'410 CgNTINUATION m :01 PREVIOUS C O ~ M ~ N T S ;:~;',.- TAPE riE~DER SERVICE NAME :EDIT D~TE :85/03/18 ORIGIN :FSIA TAP5 NAME CONTINUATZgN ~ :01 PREVIOUS T~P~ C3MMENTS :LIBRARY TAPE ;ILE NAME : ~,DiT SERVICE N~ME : VERSIDN ~ : DATE : M~XIMUM LENGTH : ~!LE TYPE : PREVIOUS FIL~ : .001 1024 !'.~NEM CSNTENTS i N C. ,',1 N 5 !,,1 C 0 N T E N T S UNIT TYPE C~&TE SIZE COOE UNiT OOC 000 01~ 065 000 000 006 055 000 000 014 065 000 OOO 002 065 000 OOO 004 055 SO0 000 002 065 000 000 912 055 000 OOO 006 065 TYP~ C~TE SIZ= COOE OOC O0~', ~. 001 065 LYP OlO.H02 VErIFiCATiON LISTING JO:~ NUMBER AT aCC: 713~2 RUN ~ON~'_-, DATE LO,SGEO: ~ MAR 8.6, LDP'. T MALST=A.D~ CASING : 9.6Z5" & 3671' - ~IT SIZE : 8.5" TO 8381' TYPE FLUID = LSND gENSITY = i0.8 LS/G RM = 3.63,9 ,~ 6,5 OF ViSCgSITY : 37.0 S RMF : 4.010 @ 56 OF PH : 8.0 RMC = 2.850 ~ 66 DF ~LUZD LOSS = 5.0 C3 RM AT 5HT = t.755 ~ 1~ OF MATRIX SANOSTGNm · ,--, ........ ,- ,~.S D T-. ,,a~ ,'~OT ~c.,~ ~,~PT . ~.~ T~u - uV..~LAYS F~cLD PRINTS '~ ........... .,~ .,..i~ .~ .~ .~ .~:~ .~ LVP 010.~02 V~i~ICATiO~ kiSTING ~G~ 3 SCHLUMBERGER LOGS INCLUJED WITH THIS MAGNETIC 'TAPE: DUAL INDUCTION SP.~BRICALLY FDCUSED LOG (GIL) OATA AVAILABLE: 8.365' 'TS 367i' :::~:: DATA FORMAT RECORD ~:=:: ENTRY BLOCKS TYPE SIZE REDR CODE ENTRY 2 i 66 0 4 1 66 ! 6 4 73 60 9 4 55 .lin 16 1 66 i 0 1 66 0 DATUM SPECIFICATION ~LOCKS MNEM SERVICE SERViC'~ L:NIT AoI APl ADZ APi FILE SIZE BPi REPR ID ORDER ~ LCG TYmE CLASS SEPT FT O0 000 CO S~LU OIL ~jHMM O0 220 O! iLS DIL OHMM O0 120 46 ILM OIL 3HMM O0 120 44 SP OIL MV O0 OiO Ol SR DIL GA~I O0 310 O! 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RiF!~ri2N· ~ ~ ,~ iSTING ,°4,3=~- ~=~ RH05 MPHI DEPT SP NPH i DEPT SP NPHI DEPT SP NPHI SP NPHI SEPT SP NPH~ DEPT SP NPHI 3EPT SP NPHI DEPT SP NPHI DE?T SP DEOT SP -999,2500 ORHO -999,2500 NCNL 7500,0000 SFLU -128.3125 GR -999,2500 DRH2 -999.2500 NCNL 7400.0000 S~LU -153.1875 GR -999.2500 DRHO -999.2500 NCNL 7300,0000 SFLU -137,0625 GR -9'99,2500 ORmO -999,2500 NCNL 7200.3000 SFLU -125,1602 GR -999.2500 DRHO -999.2500 NCNL 7100.0000 SFLU -146.3125 GR -999.2500 DRH8 -999.2300 NCNL 7000,0000 SFLU -125,72.27 GR -999.2300 DR~S -999.2500 NCNL 6900.0000 SFLU -154, i=75~ GR -999.2500 DRH$ -999.2300 NCNL 5800.0030 SFLU -1,53.9375 GR -999.2500 DR~O -999.2500 NCNL 5700.0000 SFLU -154.0625 SR 2.4065 ORH'3 36.8154 NCNL -161.~125 2.3535 .... 35.0,~. -999.2500 NR4T -999.2500 FCNL 4.0398 iLO 159.5525 GR -999.2500 NRAT -999.2500 FCNL 4.5492 iLD 128,1875 GR -999.2500 ~4RAT -999,2500 FCNL 4.2598 ILD 1!2.2'773 GR -999.2500 NRAT -9'}9.2500 FCNL 3,5979 iLD 97.6323 GR -999,2500 NR2T -999,2500 FCNL 4,0203 iLO 121.7148 GR -999,2500 NRAT -999.2500 FCNL 3.3342 ILD 13!,3125 SR -999.2300 NRAT -999,2500 =CNL 3.57~+5 iLD 107.714,8 GR -999.25,00 NRAT -999. 2500 ~'CNL 4.4617 IL3 86.6523 GR -999.2500 NRAT -999.2500 FCNL 3.276& iL,'2 100.71~8 OR C.0459 NR~T 2265.5000 FCNL 4.t4!4 '03 464a 0.0244 Nq~T 2335.3330 FCNL -999.2300 -999.2.500 3.5g03 150.562~ -999.2500 -999.2500 3.5975 128.1875 -9~9.2500 -999.2500 4.0242 112.2773 .-999.2500 -999.2500 3.5334 97.6523 -999.2500 -999.2500 3,4612 121.7145 -999.2500 -999,2500 3.1467 131.3123 -999.2500 -999.2300 3.8030 107.71~+$ -999. 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ORH~ -999.2500 NCNL 116.7148 GR 0.0259 NRAT 1877.6875 Fr ~ ,~NL :3.4221 ILO 150.6875 GR -999.2500 NRAT -999.2500 FCNL 1.2685 ILO 134.3125 GR -999,2500 NRAT -99'9.2500 FCNL Z.3401 IL3 16.2.5625 GR -9:99.2500 NRAT -999.2500 FCNL 2.0510 ILO 120.4023 GR -999.2500 NRAT -999.2500 FCNL 1.6700 ILO 1i2.4023 GR -999.2500 NRAT -999.2500 FCNL 1.6729 ILD 96.7773 GR -999.2500 NR&T -999.i500 FCNL 3.6077 ILO 72.9023 GR -999.2500 NR&T -9'~9.2500 FCNL 2.4749 ILO 100.5898 GR -99'9.2500 NRAT -999.2500 FCNL 4.1257 ILO 147.5625 GR -9~9.2500 NR~T -999.2500 ~CNL 2.8894 ILO 97.2773 GR -999.2500 NRdT -91~9.2500 -~CNL 116.7 t ~ ~ 3.6 07 7 545.B!25 3.2483 -999.2500 -999.2500 -999.2500 1.2315 -999.2500 -999.2500 -999.2500 2.2581 -999.2500 -999.2500 -999.2500 1.9893 -999.2500 -999.2500 -'999.2500 1.7833 -999.2500 -999.2500 -999.2500 2.2209 -999.2500 -9'99.2500 -999.2500 3.3010 -999.2500 -'999.2500 -9:99.2500 2.4531 -999.2520 -999.2500 -999.2500 &.1453 -'~99.2500 -999.2500 -999.2500 2.8245 -999.2500 -999.2500 -999.2500 CALl RNRA ILM C4LI IL M rALI RNRA ILM CALl RNRA ILM CALl RNRA ILM CALi ILM C ALI RNR ~ ILM C4LI RNR~ ILM CALI RNR& ILM C4L I RNR ~ ~LM C~LZ 10.3066 · 3.2834 -999.2500 -999.2500 1.3731 -999.2500 -999.2500 ~ 3088 -99:9.2500 -999.2500 2.0120 -999.2500 -999.2500 1.7852 -999.2500 -999.2500 2.0120 -999.2500 -999.2500 3.2639 -999.2500 -999.2500 2.4651 -999.2500 -999.2500 4.1179 -999.2500 -999.2500 2.8088 -999.2500 -999.2500 LVP OlO.H02 VERiFIC~TiCN L!3T!NG PAGE. 7 3EPT S~ NPHI 3~PT NPHI O~PT SP NPH! 'DE PT S P NPHI D~PT SP RHO$ NPHi 35PT S? RHOB NPHI DEPT SP NFHI DE,~T SP SP ~..,. NPHI 3EPT SP DEPT SP 5¢00.0000 SFLU -146.6n75 GR -999.2500 DRHC -999.2500 NCNL 5300.0000 SFLO -t42.8125 GR -999.2500 DRHO -99'9.2500 NCNL 5ZOO.O000 SFLU -149.5975 GR -999.2500 DRHO -99:9.2500 NCNL 5100.0000 ,SFLU -1~8.5875 GR -:99'9.2500 DRHi] -999.2500 NCNL 5000.0000 SFLU -151.5625 GR 2.3127 DRHg 47.3145 NCNL ~900.0000 SFLU -155.812,5 GR 2.2539 DRHO ~5.'7520 NCNL 4800.0000 SFLU -157.0625 SR -999.2500 gRHO -995.2500 NC~L 4700.0000 SFLU -155.5525 GR -999.2500 3R~;3 -999.2500 NCNL 4500.0000 SFLU -137.1~75 G~ -999.2500 gRHg -999.2503 NCNL 4500.0300 SFLU -157.~375 GR -999.2500 DRY8 -999.2500 NCNL ~00.0000 SFLd -156.4375 GR 2.2659 DRHO 44.~730 NCNL 3.0120 ILO 115.5273 G2 -9'99.2500 NRAT -999.2500 FCNL 2.58~2 iLD 86.2773 GR -999.2500 NRAT -999.2500 FCNL 2,4241 ILO 107,5.273 GR -999,2500 NRAT -999,2500 FCNL 2.8577 ILD 113.5,273 GR -999.2500 NRAT -999.2500 FCNL 2.5686 I L D 96..2148 G R 0.0181 NR&T 1920.6875 FCNL 2.8167 ILD 10!.3398 GR 0.0029 NRAT 1910.6875 FCNL 2.6428 ILD 109.9023 GR -999.2500 NRAT -999.2500 FCNL 2.~417 I'~ 104.0273 GR -999.2500 NRAT -999.2~00 FCNL 3.1135 97.9023 GR -999.2500 NRAT -999.2500 FCNL 2.908~ iLS 100.9023 Gq -999.2500 NR&T -999.2500 :CNL 3.6582 176.4375 GR 0.0332 NRAT 1~58.6875 FCNL 3.0323 -999.2500 -999.2500 -999.2500 2.3850 -999.2500 -999.2500 -999.2500 3.0255 -999.2500 -999.2500 -999.2500 3.0334 -9'99.2300 '-999.2300 -999,2500 2.7971 96.21~8 3.7971 520.8125 3.0530 131.3398 3.7o3a 512.8125 2.8957 -999.2500 -999.2500 -999.2500 3.5555 -999.2300 -999.2500 -999.2500 3.3850 -9~9.2300 -999.2300 -999.2500 2.7695 -999.2503 -999.2300 -999.2500 4.0867 176.&375 3.5545 536.3125 ILM C&Lt !LM CALi RNRA ILM C4ti RNRA ILM C4LI RNRA ILM C&LI RNRA ILM C~Li RNRA ILM CALI RNR 4 iLM CALl RNRA ILM C~LI RNRA ~LM C4Li RNRA ILM CALl RNR 4 3.0705 -999.2500 -999.2500 2.~885 -999.2500 -999.2500 3.0178 ,-999.2500 -999.2500 2.9612 -999.2500 -999.2300 2.6877 9.3926 3.6877 2.9495 9.2598 3.7268 2.7795 -999.2500 -999.2500 3.4202 -999.2500 -999.2500 3.2522 -99'9,2500 -999.2500 2.6877 -999.2500 -9'99.2500 3.7~2~ 9.2576 3.4651 .VP 010 HO2 VERIFICAT~ ~ - ~uN L~STIN8 P4G~ 8 3E~T 4300.0000 SFLU 3P -153.4375 GR ~HOE 2.1311 ORHO ~PHl 45.3565 NCNL ]EPT 4Z00.0000 SFLU ~P -!57.1875 GR RHO~ 2.2365 DRHO ~PMI ~2.2852 NCNL ]EPT 4100.0000 SFLU $P -155.0625 GR ~HOB 2.1975 DRHO 'JPHI 46.1~26 NCNL 3:E~T 4000.0000 SFLU ~ -157.3125 GR qHOB 2. 1877 ORHO ~ P H I 44 · 6777 N C N L ]Em'T 3900.0000 SFLU SP -15'7.6125 GR RHOB 2.2229 DRHS ~PHI 42.3528 NCNL DE~T 3800.0000 SP -159.5875 GR ~H05 2.2346 DRHS qPHI 44.1406 NCNL D[OT 3700.0000 SFLU SP -160.8125 GR ~05 2.1838 ORH3 "JP~I,, 3q...~=996 NCNL 3EmT 3542.5000 SFLU SP -148.4375 GR RHOS -999.2500 DRHO NP~I -999.2500 NCNL · ~LE TRAILER ;;:~;= ;ILE NAME :EDIT .001 S=RViCE NAM-Z : VERSZSN ~ : 9ATE : ~!AXiMUM LEN$TH : !02~ FiLi TYaE : q~XT FILE NA~,~ : 4.2000 ILD 85.464~ GR -0.0005 NRAT 2007,5875 ~CNL 3.9651 ILD 107.9023 GR 0.026'9 NRAT 1996.6875 FCNL 5.7390 iLD 55.0273 GR 0.0293 NRAT 2067.5000 FCNL 3.6135 iLD 94.5898 GR -0.0039 NRAT 1912.6875 FCNh 4. 1843 36.5895 GR 0 . 0278 N R A T 1917. 6875 FC NL ~.1687 ILO ~7.4023 GR 0.0215 NRAT 1949.6875 FCNL 4.6335 76.1523 0.0063 N~AT 1876.6875 2000.6875 iLO 53.9305 -999.2500 -999.2500 FCNL 4.5437 85.4648 3.6877 5~6.81Z5 4.1726 107.9023 3.5491 603.3125 5.63'35 85.0273 3.7795 571.3125 4.2234 94.5898 3.7795 554.3125 5.3250 86.5898 q 6409 547.8125 5.3640 87.-4023 3.6721 528.3125 6.6375 76.1523 3.5256 525.3125 8.4238 -999.2500 -999.2500 -999.2500 C ALI RNRA ILM CALI RNRA ILM CALi RNR~ ILM C4LI RNRA iLM CALI RNRa ~ALY ILH CALl RNR4 iLM CALl 4.3454 9.2129 3.6721 3.9788 9.6973 3.3088 5.5789 9.'9473 3.5174 3.9475 il.3770 3.4514 4.9'773 10.8770 3.5002 4.7351 9.97~95 3.6897 5.7429 12.3066 3.5725 2000.6875 -999.2500 -999.2500 .Vo, 010.MO2 VSRI~IC&TIO~~ _~ ISTtNG '?tG~= ~9 ~$; TAPE TRAILER ~ERVICE NAME :EDIT )ATE 2RZGZN :~St~ TAPE N~ME $~NTZNUATZON ~ :0t NE'XT TAPE N~ME $OMMENTS :LIBRARY SE~,VlCE N~ME :EDIT D~TE :85/03/I~ ~JRIG!N : R E,.= L NAME : 149~+10 CONTZNUATZSN ~ :01 NEXT REEL NAME COMMENTS ':LIBRAR:Y TAPE
