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Home My WebLink About198-231Originated: Delivered to:22-Sep-21Halliburton Alaska Oil and Gas Conservation Comm.Wireline & Perforating Attn.: Natural Resource TechnicianAttn: Fanny Haroun 333 West 7th Avenue, Suite 1006900 Arctic Blvd. Anchorage, Alaska 99501Anchorage, Alaska 99518Office: 907-275-2605FRS_ANC@halliburton.comThe technical data listed below is being submitted herewith. Please address any problems orconcerns to the attention of the sender aboveWELL NAME API # SERVICE ORDER # FIELD NAME JOB TYPE DATA TYPE LOGGING DATE PRINTS #DIGITAL #1 1B-09 50-029-20655-00 907383247 Kuparuk River Multi Finger Caliper Field & Processed 11-Sep-21 0 12 2M-19 50-103-20158-00 907335394 Kuparuk River Multi Finger Caliper Field & Processed 19-Aug-21 0 13 2M-19 50-103-20158-00 907335394 Kuparuk River Plug Setting Record Field- Final 20-Aug-21 0 14 2M-27 50-103-20175-00 907335397 Kuparuk River Plug Setting Record Field- Final 18-Aug-21 0 15 2M-33 50-103-2024-00 907316545 Kuparuk River Packer Setting Record Field- Final 8-Aug-21 0 16 2N-333 50-103-20525-00 907331967 Kuparuk River Radial Bond Record Field- Final 17-Aug-21 0 17 2N-333 50-103-20525-00 907383501 Kuparuk River String Shot Record Field- Final 13-Sep-21 0 18 2T-207 50-103-20287-00 907326322 Kuparuk River Packer Setting Record Field- Final 15-Aug-21 0 19 2V-04 50-029-21041-00 907398078 Kuparuk River Correlation Record Field- Final 20-Sep-21 0 110 2V-11 50-029-21311-00 907365411 Kuparuk River Leak Detect Log Field- Final 1-Sep-21 0 1PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF:Fanny Haroun, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518FRS_ANC@halliburton.comDate:Signed:Transmittal Date:09/23/2021Wd͗ϭϵϴϮϯϭϬͲ^Ğƚ͗ϯϱϳϬϲBy Abby Bell at 10:25 am, Sep 23, 2021 ! " # " $ %& ' ()! * '$ +, !- ."!! /, +, 01021*-1 3+ - " ' $ % $ 4 5 + 677 - 8 5+ '7 - 0 96 ' ) + - : 9 2" 8 $ ' " %& ' $ , ' (" 8 ; "$, % $ ; ;)!< = ,=; '!!3 %& ! 6 ") ' % % % !"# $%& % : '!"!()$*"+$,-. $/ ;8, ')0 *)' ' '8 8 %&#1 % > +9 01021*17021*7?020.:- ; #4 <8 2$3 % 87) %,@ ,@),!$;!% 5)!44))! )/ ) +20 )45 /)6 2 2 $ !0 ! ! $ ' )A $ % % % % % % % B&11:(1 7@//21 #B >" B"8 " #B /.("7/66//#.1/.(" /.("7/66//#.1/.(" /.("78$%2!-9"$-/!9/.(" /.("7 ("2 :"*/.(/.(" 2227 ;# ;# $ ' 'C +/1*-(2/#*00> 6!$ ' 6 ")!<"; 1#>1> :30101 " :1' By Meredith Guhl at 1:49 pm, Sep 14, 2021 Digitally signed by Dusty Freeborn DN: OU=AK WELLS, O=ConocoPhillips, CN=Dusty Freeborn, E=dusty.freeborn@conocophillips.com Reason: I am the author of this document Location: your signing location here Date: 2021.09.14 13:44:11-08'00' Foxit PDF Editor Version: 11.0.0 Dusty Freeborn VTL 01/24/2022 RBDMS HEW 9/15/2021 DSR-9/14/21 Last Tag Annotation Depth (ftKB)End Date Wellbore Last Mod By Last Tag: 4,415.0 6/8/1999 2T-207 WV5.3 Conversion Last Rev Reason Annotation End Date Wellbore Last Mod By Rev Reason: Set patch 8/16/2021 2T-207 fergusp Casing Strings Casing Description CONDUCTOR OD (in) 16 ID (in) 15.06 Top (ftKB) 37.0 Set Depth (ftKB) 112.0 Set Depth (TVD)… 112.0 Wt/Len (l… 62.58 Grade H-40 Top Thread WELDED Casing Description SURFACE OD (in) 9 5/8 ID (in) 8.70 Top (ftKB) 37.4 Set Depth (ftKB) 4,243.0 Set Depth (TVD)… 3,013.4 Wt/Len (l… 40.00 Grade L-80 Top Thread BTC-MOD Casing Description GRAVEL PACK LINER OD (in) 4 ID (in) 3.48 Top (ftKB) 4,080.8 Set Depth (ftKB) 4,414.0 Set Depth (TVD)… 3,125.2 Wt/Len (l…Grade Top Thread Liner Details Top (ftKB)Top (TVD) (ftKB)Top Incl (°)Item Des Com Nominal ID (in) 4,080.8 2,909.6 50.49 PACKER BAKER MODEL SC-1 GRAVEL PACK PACKER 4.875 4,085.8 2,912.8 50.46 EXTENSION UPPER EXTENSION 4.875 4,090.7 2,915.9 50.44 SLEEVE BAKER GRAVEL PACK SLIDING SLEEVE 4.875 4,092.82,917.3 50.43SBE BAKER SEAL BORE 4.875 4,093.62,917.8 50.42 EXTENSIONLOWER EXTENSION4.875 4,114.12,930.9 50.32 KOIV BAKER MODEL 'B' KOIV 3.437 4,190.7 2,979.9 50.17 SCREEN BAKERWELD GRAVEL PACK SCREEN 4.00" x 020 GAUGE 3.476 4,413.0 3,124.5 48.03 BULL PLUG BAKER BULL PLUG 0.000 Tubing Strings Tubing Description TUBING String Ma… 4 1/2 ID (in) 3.96 Top (ftKB) 28.4 Set Depth (ft… 4,047.8 Set Depth (TVD) (… 2,888.6 Wt (lb/ft) 12.60 Grade L-80 Top Connection IBTM Completion Details Top (ftKB) Top (TVD) (ftKB) Top Incl (°)Item Des Com Nominal ID (in) 28.4 28.4 0.21 HANGER FMC ESP TYPE H BVP HANGER 4.000 473.9 472.211.37 NIPPLE CAMCO DB NIPPLE 3.812 2,605.22,018.5 55.19 PACKER TWIN SUBMERSIBLE PUMP PACKER 3.920 3,927.7 2,812.2 50.79 NIPPLE CAMCO DB NIPPLE 3.562 3,968.7 2,838.2 50.53 XO Reducing 4 1/2 8rd EUE x 3 1/2 8rd EUE X-O SUB 3.500 3,974.2 2,841.7 50.50 GAUGE WELL LIFT DGU 2.992 3,991.0 2,852.4 50.41 XO Reducing 3 1/2" PUP JT w/ CROSSOVER SUB, 3 1/2" EUE BOX X 2 3/8" EUE PIN 2.375 3,991.9 2,853.0 50.40 DISCHARGE CENTRILIFT DISCHARGE HEAD 380 SERIES 3,992.8 2,853.6 50.40 PUMP CENTRILIFT 116 STAGE P116 PUMP, PUMP INTAKE & GAS SEPERATOR 4,013.3 2,866.7 50.31 SEAL CENTRILIFT TANDEM SEAL SECTION 4,027.22,875.5 50.36 MOTOR CENTRILIFT 562 SP1,168 HP,190/2415/048 ESP MOTOR 4,044.02,886.2 50.42GAUGEWELL LIFT MGU 4,045.92,887.4 50.42Centralizer MOTOR CENTRALIZER Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top (ftKB) Top (TVD) (ftKB) Top Incl (°)Des Com Run Date ID (in)SN 1,320.01,227.4 39.43 PACKER - PATCH - UPR Set upper packer assembly, P@P packer, XO, spacer pipe, anchor latch, (21.5' OAL) 8/16/2021 2.000 CPP45002 1,324.31,230.7 39.55 SPACER PIPE Spacer Pipe & Anchor Latch (15.7' OAL, included in the upper patch assembly) 8/16/2021 1.995 CPAL45011 1,333.01,237.4 39.79 LEAK - TUBING TUBING LEAK FOUND WITH ARCHER LEAKPOINT ACOUSTIC LDL 7/15/2021 3.960 1,340.01,242.7 39.98 PACKER - PATCH - LWR Set Lower 3.76" P2P packer 8/15/2021 2.000 CPP45010 Perforations & Slots Top (ftKB)Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB)Linked Zone Date Shot Dens (shots/ft )Type Com 4,081.0 4,413.02,909.83,124.5 2/18/1999 99.0 IPERF OPEN HOLE GRAVEL PACK Mandrel Inserts St ati on N o/Top (ftKB) Top (TVD) (ftKB) Top Incl (°)Make Model OD (in)Serv Valve Type Latch Type Port Size (in) TRO Run (psi)Run Date Com 1 2,485.8 1,950.5 55.57 CAMCO KBMG 1 ESPDMYINT0.000 0.08/2/2021 Ext. Packi ng (2:00) 2 2,731.22,089.8 55.62 CAMCO KBMG 1 ESP DMY BK-5 0.000 0.0 7/31/2012 2:00 3 3,876.02,779.7 51.16 CAMCO KBMG 1 ESP DMY BK-50.000 0.0 7/31/2012 12:30 Notes: General & Safety End Date Annotation 12/10/2010 NOTE: View Schematic w/ Alaska Schematic9.0 2T-207, 9/9/2021 1:46:15 PM Vertical schematic (actual) GRAVEL PACK LINER; 4,080.8- 4,414.0 IPERF; 4,081.0-4,413.0 SURFACE; 37.4-4,243.0 MOTOR; 4,027.2 PUMP; 3,992.8 ESP MANDREL; 3,876.0 ESP MANDREL; 2,731.2 PACKER; 2,605.2 ESP MANDREL; 2,485.8 PACKER - PATCH - LWR; 1,340.0 LEAK - TUBING; 1,333.0 SPACER PIPE; 1,324.3 PACKER - PATCH - UPR; 1,320.0 NIPPLE; 473.9 CONDUCTOR; 37.0-112.0 KUP PROD KB-Grd (ft) 35.70 Rig Release Date 12/14/1998 2T-207 ... TD Act Btm (ftKB) 4,495.0 Well Attributes Field Name TABASCO Wellbore API/UWI 501032027800 Wellbore Status PROD Max Angle & MD Incl (°) 57.26 MD (ftKB) 2,356.59 WELLNAME WELLBORE Annotation Last WO: End Date 7/31/2012 H2S (ppm)DateComment SSSV: NIPPLE ! " # ! $ % &'$! ( $ %(&'$! )*+) , -& ! ) & $! *+ $ (. #!/ $! & $! , $' (#!! *+ & $! (!/$! * +!! !%& ! % $ **. 0++ #0*'+&'! $# '0& ! -1" #0*'+,& ! *+" - - 23456789: 2;;7<=>?@A<784>5B C:\Users\aebell\Desktop\July 2021 Data Drop\CPA Data Drop 07162021\2021-07-15_15794_KRU_2T-207_LeakPointSurvey_Transmittal.docx DELIVERABLE DISCRIPTION Ticket # Field Well # API # Log Description Log Date 15794 KRU 2T-207 50-103-20278-00 LeakPointSurvey 15-Jul-21 DELIVERED TO Company & Address DIGITAL FILE # of Copies LOG PRINTS # of Prints CD’s # of Copies 1 AOGCC ****Revised Archer LeakPoint Final Job Report**** Attn: Natural Resources Technician 333 W. 7th Ave., Suite 100 Anchorage, Ak. 99501-3539 Delivered By: CPAI Sharefile FTP ______________________________ ______________________________________ Print Name 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 37' (6HWdZ^hD/dd> _____________________________________ re Abby Bell By Abby Bell at 4:36 pm, Jul 19, 2021 C:\Users\aebell\Desktop\July 2021 Data Drop\CPA Data Drop 07162021\2021-07-15_15794_KRU_2T-207_LeakPointSurvey_Transmittal.docx DELIVERABLE DISCRIPTION Ticket # Field Well # API # Log Description Log Date 15794 KRU 2T-207 50-103-20278-00 LeakPointSurvey 15-Jul-21 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 FTP ______________________________ ______________________________________ Print Name 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 ________________________________________________Abby Bell 37' (6HW By Abby Bell at 9:14 am, Jul 16, 2021 Originated: Delivered to:1-Jul-21Halliburton Alaska Oil and Gas Conservation Comm.Wireline & Perforating Attn.: Natural Resource TechnicianAttn: Fanny Haroun 333 West 7th Avenue, Suite 1006900 Arctic Blvd. Anchorage, Alaska 99501Anchorage, Alaska 99518Office: 907-275-2605FRS_ANC@halliburton.comThe technical data listed below is being submitted herewith. Please address any problems orconcerns to the attention of the sender aboveWELL NAME API # SERVICE ORDER # FIELD NAME JOB TYPE DATA TYPE LOGGING DATE PRINTS # DIGITAL #1 1A-24 50-029-22984-00 907203651 Kuparuk River Packer Setting Record Field- Final 11-Jun-21 0 12 1E-34 50-029-22805-00 n/a Kuparuk River Leak Detect Log Field- Final 27-Jun-21 0 13 1E-34 50-029-22805-00 n/a Kuparuk River Plug Setting Record Field- Final 27-Jun-21 0 14 1J-168 50-029-23260-00 907188201 Kuparuk River Packer Setting Record Field- Final 3-Jun-21 0 15 2M-33 50-103-20240-00 907209681 Kuparuk River Packer Setting Record Field- Final 17-Jun-21 0 16 2N-347 50-103-20337-00 906961909 Kuparuk River Plug Setting Record Field- Final 14-Jun-21 0 17 2T-207 50-103-20287-00 907201320 Kuparuk River Leak Detect Log Field- Final 9-Jun-21 0 18 2T-207 50-103-20287-00 907199652 Kuparuk River Multi Finger Caliper Field & Processed 9-Jun-21 0 19 2V-03 50-029-21040-00 907177252 Kuparuk River Plug Setting Record Field- Final 27-May-21 0 110 3F-08 50-029-21464-00 907196137 Kuparuk River Plug Setting Record Field- Final 10-Jun-21 0 1PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF:Fanny Haroun, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518FRS_ANC@halliburton.comDate:Signed:Transmittal Date:07/01/2021Wd͗ϭϵϴϮϯϭϬͲ^Ğƚ͗ϯϱϯϮϰBy Abby Bell at 3:53 pm, Jul 01, 2021 Originated: Delivered to:1-Jul-21Halliburton Alaska Oil and Gas Conservation Comm.Wireline & Perforating Attn.: Natural Resource TechnicianAttn: Fanny Haroun 333 West 7th Avenue, Suite 1006900 Arctic Blvd. Anchorage, Alaska 99501Anchorage, Alaska 99518Office: 907-275-2605FRS_ANC@halliburton.comThe technical data listed below is being submitted herewith. Please address any problems orconcerns to the attention of the sender aboveWELL NAME API # SERVICE ORDER # FIELD NAME JOB TYPE DATA TYPE LOGGING DATE PRINTS # DIGITAL #1 1A-24 50-029-22984-00 907203651 Kuparuk River Packer Setting Record Field- Final 11-Jun-21 0 12 1E-34 50-029-22805-00 n/a Kuparuk River Leak Detect Log Field- Final 27-Jun-21 0 13 1E-34 50-029-22805-00 n/a Kuparuk River Plug Setting Record Field- Final 27-Jun-21 0 14 1J-168 50-029-23260-00 907188201 Kuparuk River Packer Setting Record Field- Final 3-Jun-21 0 15 2M-33 50-103-20240-00 907209681 Kuparuk River Packer Setting Record Field- Final 17-Jun-21 0 16 2N-347 50-103-20337-00 906961909 Kuparuk River Plug Setting Record Field- Final 14-Jun-21 0 17 2T-207 50-103-20287-00 907201320 Kuparuk River Leak Detect Log Field- Final 9-Jun-21 0 18 2T-207 50-103-20287-00 907199652 Kuparuk River Multi Finger Caliper Field & Processed 9-Jun-21 0 19 2V-03 50-029-21040-00 907177252 Kuparuk River Plug Setting Record Field- Final 27-May-21 0 110 3F-08 50-029-21464-00 907196137 Kuparuk River Plug Setting Record Field- Final 10-Jun-21 0 1PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF:Fanny Haroun, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518FRS_ANC@halliburton.comDate:Signed:Transmittal Date:07/01/2021Wd͗ϭϵϴϮϯϭϬͲ^Ğƚ͗ϯϱϯϮϯBy Abby Bell at 3:53 pm, Jul 01, 2021 STATE OF ALASKA • AAA OIL AND GAS CONSERVATION COM SSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Abandon r Repair w ell P Rug Furforations r Ferforate r Other Alter Casing r Pull Tubing (;► Stimulate - Frac r Waiver r Time Extension r Change Approved Program r Operat. Shutdown r Stimulate - Other r Re -enter Suspended Well r 2. Operator Name: 4. Well Class Before Work: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development J Exploratory r _ . 198 -231 3. Address: 6. API Number: Stratigraphic r Service r �1 P. O. Box 100360, Anchorage, Alaska 99510 50- 103 - 20278 -00 v 7. Property Designation (Lease Number): 8. Well Name and Number: ADL 25569 2T -207 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field /Pool(s): none Kuparuk River Field / Tabasco Oil Pool 11. Present Well Condition Summary: Total Depth measured 4495 feet Plugs (measured) 3928', 4413' true vertical 3179 feet Junk (measured) None Effective Depth measured 3951 feet Packer (measured) 2605, 4081 true vertical 2827 feet (true vertucal) 2019, 2910 Casing Length Size MD TVD Burst Collapse CONDUCTOR 75 16 112 112 SURFACE 4206 9.625 4243 3013 LINER 333 4 4414 3125 RECE Perforation depth: Measured depth: 4081' -4413' x 1 4)-. ; `` , t; J ?� True Vertical Depth: 2910' -3125' 4 i l AOGCC Tubing (size, grade, MD, and ND) 4.5, L -80, 4048 MD, 2889 ND Packers & SSSV (type, MD, and ND) PACKER - TWIN SUBMERSIBLE PUMP PACKER @ 2605 MD and 2019 ND PACKER - BAKER MODEL SC -1 GRAVEL PACK PACKER @ 4081 MD and 2910 ND SSSV - CAMCO DS NIPPLE @ 474 MD and 472 ND 12. Stimulation or cement squeeze summary: Intervals treated (measured): not applicable Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil - Bbl Gas - Mcf Water - Bbl Casing Pressure Tubing Pressure Prior to well operation 247 37 529 -- 248 Subsequent to operation shut -in 14. Attachments 15. Well Class after work: Copies of Logs and Surveys run Exploratory r Development p' + Service r Stratigraphic r 16. Well Status after work: -.Oil p Gas r WDSPL r Daily Report of Well Operations XXX GSTOR r WINJ r WAG r GINJ r SUSP r SPLUG r 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: none Contact Brett Packer @ 265 -6845 Printed Name Brett Packer Title Sr. Wells Engineer /J Signature '� Phone: 265 -6845 Date 8,• 7 / tZ NaDMS AUG 21 20'x' " , q� 7/ Submit Original Only KUP • 2T -207 6. nOCOPI i ' a eus , Well Attributes Max Angle & MD TD Welibore API/UWI Field Name Web Status Inc' ( °) MD (ftKB) Act Btm (ftKB) ups ' 501032027800 TABASCO PROD 57.26 2,356.59 4,495.0 Comment H2S (ppm) Date Annotation End Date KB (ft) Rig Release Date "' SSSV: NIPPLE 65 6/23/2009 Last WO: 7/31/2012 35.70 12/14/1998 Well COnBP' 0 2T - -2 -Act eI 7'5333 AM A nnotation Depth ftKB End Date Annotation Last P ( ) Lt MdB By End Date Last Tag: 4,415.0 6/8/1999 Rev Reason: WORKOVER ninam 8/12/2012 - °�. Casing Strings HANGER, 28 Casing Description String 0... String ID ... Top (ftKB) Set De f... Set Depth (TVD) ... String Wt... String String Top Thrd 9 P 9 9 P ) Depth th P( P( 1 9 9 9 P *La - - -, .,._. CONDUCTOR 16 15.062 37.0 112.0 112.0 62.58 H - 40 WELDED ___1911 IF Casing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd SURFACE 95/8 8.697 37.4 4,243.0 3,013.4 40.00 L - 80 BTC - MOD Casing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt... String... String Top Thrd GRAVEL PACK 4 3.476 4,080.8 4,414.0 3,125.2 CONDUCTOR. LINER 37112 Liner Details Top Depth (TVD) Top Inc/ Nom'... NIPPLE, 471- !:: )'; Top (ftKB) (ftKB) r) Item Description Comment ID (in) 4,080.8 2,909.6 50.49 PACKER BA KER MODEL SC-1 GRAVEL PACK PACKER 4.875 4,085.8 2,912.8 50.46 EXTENSION UPP EXTENSION 4.875 4,090.7 2,915.9 50.44 SLEEVE BAKER GRAVEL PACK SLIDING SLEEVE 4.875 4,092.8 2,917.3 50.43 SBE BAKER SEAL BORE 4.875 4 1 4,093.6 2,917.8 50.42 EXTENSION LOWER EXTENSION 4.875 4,114.1 2,930.9 50.32 KOIV BAKER MODEL'B' KOIV 3.437 4,190.7 2,979.9 50.17 SCREEN BAKERWELD GRAVEL PACK SCREEN 4.00" x 020 GAUGE 3.476 7 ----- 7 I 4,413.0 3,124.5 47.92 BULL PLUG BAKER BULL PLUG 0.000 ES MANDREL t ' '= Tubing Strings 2,486 Tubing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd TUBING 41/2 3.958 28.4 4,047.8 2,888.7 12.60 L -80 IBTM •w _- - '--' t . Completion Details Top Depth ita (TVD) TO Inc/ Nom'... PACKER. 2.605- Top (ftKB) (ftKB) ( °) Item Description Comment ID (in) 28.4 28.4 1.78 HANGER FMC ESP TYPE H BVP HANGER 4.000 V , ` ,� 473.9 472.1 11.37 NIPPLE CAMCO DB NIPPLE 3.812 ' 1' 2,605.2 2,018.5 55.19 PACKER TWIN SUBMERSIBLE PUMP PACKER 3.920 3,927.7 2,8122 50.76 NIPPLE CAMCO DB N PLE w/ RHC -M PLUG INSTALLED 3.562 MANDREL " 3,968.7 2,838.0 50.16 XO Reducing 41 /2x31/28rd EUE X -0 SUB 3.500 2,731 '' 3,974.2 2,841.6 50.18 GAUGE WELL LIFT DGU 2.992 2 3,991.0 2,852.4 50.24 XO Reducing 3 1/2" PUP JT w/ CROSSOVER SUB, 3 1/2' EUE BOX X 23/8" EUE PIN 2.375 3,991.9 2,853.0 50.24 DISCHARGE CENTRILIFT DISCHARGE HEAD 380 SERIES ESP _ -- - - 3,992.8 2,853.5 50.24 PUMP CENTRILIFT 116 STAGE P116 PUMP, PUMP INTAKE & GAS MANDREL. SEPERATOR 3,876 _ 4,013.3 2,867.0 50.82 SEAL CENTRILIFT TANDEM SEAL SECTION 4,027.2 2,875.7 50.75 MOTOR CENTRILIFT 562SPt ,168HP,190/2415/048 ESP MOTOR IN 4,044.0 2,886.3 50.67 GAUGE WELL LIFT MGU NIPPLE. 3.928 Al 4,045.9 2,887.5 50.66 Centralizer MOTOR CENTRALIZER PLUG, 3,928 g / ////,f//// / /////// 1' iy ( Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) , Top Depth (TVD) Top Inel Top (ftKB) (ftKB) (') Description Comment Run Date ID (in) 3,928 2,812.2 50.76 PLUG RHC w/ BALL & ROD 7/31/2012 0.000 Perforations & Slots Shot GAUGE, 3,974 .iir:D> : Top (TVD) Btm (TVD) Dens Top (ftKB) Btm (ftKB) (ftKB) (ftKB) Zone Date (oh... Type Comment 4,081 4,413 2,909.8 3,124.5 2/18/1999 99.0 IPERF OPEN HOLE GRAVEL PACK } Notes: General & Safety DISCHARGE, End Date Annotation 3.992 Tom: 12/10/2010 NOTE: View Schematic w/ Alaska Schematic9.0 PUMP, 3,993 ID SEAL. 4,013 MOTOR. 4.027 GAUGE, 4,044 Centralizer, l 4,046 1 1 li II Mandrel Details El:.. Top Depth Top Port (TVD) Inc! OD Valve Latch Size TRO Run Stn Top (ftKB) (ftKB) (1 Make Model (in) Sery Type Type (!n) (psi) Run Date Com... '.. 1 2,485.8 1,950.3 55.13 CAMCO KBMG 1 ESP SOV BEK 0.000 0.0 7/31/2012 2 2,731.2 2,089.8 55.62 CAMCO KBMG 1 ESP DMY BK -5 0.000 0.0 7/31/2012 '.. 3 3,876.0 2,779.7 51.16 CAMCO KBMG 1 ESP DMY BK -5 0.000 0.0 7/31/2012 SURFACE, 37 -4,243 IPERF, 4,081 -4,413 GRAVEL PACK LINER, 4,081 -4,414 TD, 4,495 , 2T -207 Pre Rig Well Work Summary • DATE SUMMARY 5/22/12 PRE- RWO - -T -POT (FAILED), - PPOT (PASSED), PRIMARY CASING HANGER SEAL -PO (PASSED), PRIMARY CASING HANGER SEAL -PPPOT (PASSED), FUNCTION TESTED ALL LDS'S (GOOD) 6/2/12 TAG TOP OF PLUG @ 3948' RKB WITH 2.33" GAUGE, PULLED 2.31 XX PLUG @ 3948' RKB, TAG TOP OF GRAVEL PACKER @ 4090' RKB WITH 2" BAILER UNABLE TO WORK IN TO GRAVEL SCREEN. MEASURED BHP @ 4046' SLM [1351 -psi; 68 -deg F]. COMPLETE. • • ConocoPhillips Time Log & Summary Wellview Web Reporting Report Well Name: 2T - 207 Rig Name: NORDIC 3 Job Type: RECOMPLETION Rig Accept: 7/23/2012 9:00:00 AM Rig Release: 7/31/2012 3:00:00 PM Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 24 hr Summary MIRU Nordic Rig 3. Pull BPV. Kill Well. 08:00 09:00 1.00 MIRU MOVE MOB P Move Nordic Rig 3 from 2T -215 to 2T -207. Nordic Rig 3 Accepted a_t 09:00 on 07/23/2012. 09:00 11:00 2.00 MIRU MOVE RURD P Spot Cuttings Box, Hook up Hardline, Spot Auxiliary Equipment and Load pits w/ Filtered 9.1 ppg 3 % KCL Brine. Load lubricator. 11:00 11:30 0.50 MIRU WELCTL SFTY P PJSM and Pre Spud meeting with FMC, Nordic and CPAI. 11:30 13:30 2.00 MIRU WELCTL MPSP P Lubricate out CIW 4" Type "H" BPV. 13:30 18:00 4.50 MIRU WELCTL CIRC P PJSM, PT lines, Open Well, 280 psi on Tbg (diesel) 340 psi on Csg (gas) Notify DSO and security of bleeding gas. Bleed pas cap off IA. Circulate BU 220 bbls 9.1 ppg 3% KCL 5 bpm, ICP 380 psi, FCP 350 psi, shut down, 75 bbls return, line up down IA, Reverse circ. 3 bpm, ICP 220 psi. with 60 psi back pressure, FCP 3bpm at 120 psi, clean 9.1 ppg to surface, shut down. 18:00 19:00 1.00 MIRU WELCTL OWFF P Monitor well for flow. After 1 Hour the IA had 40 psi and 160 psi on the Tubing. Crew Change Out. 19:00 20:30 1.50 MIRU WELCTL KLWL P Reverse Circulate another 150 bbls of 9.1 PPG Brine down IA while taking returns up the TBG at 5 bpm. ICP 220 psi on IA and 80 psi on TBG FCP 250 on the IA and 100 psi on the TBG. Started seeing fluid returns at surface after 30 bbls pumped, heavy crude and gas. Had 50% Lossses after Circulating 200 bbls. 20:30 21:30 1.00 MIRU WELCTL OPNW P Monitor well for flow. After 1 Hour the IA had 50 psi and 60 psi on the Tubing. Shoot Fluid Level. Fluid at surface on IA side and Straight gas on TBG side. 21:30 23:30 2.00 MIRU WELCTL KLWL P Start Bullhead Kill. Circulated 65 bbls of 9.1 PPG Brine down TBG at 5 bpm, 380 psi. Shut down & Circulate 344 bbls of 9.1 PPG Brine down IA at 5 bpm, 440 psi. FCP on IA & TBG, 90 psi. Page 1 of 7 • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 23:30 00:00 0.50 MIRU WELCTL OWFF P Observe well for flow. X7/24/2012 Set BPV. ND Tree. NU BOPE and Start BOPE Test 250/3500. 00:00 02:00 2.00 0 0 MIRU WELCTL OWFF P Observe well for flow 02:00 03:00 1.00 0 0 MIRU WELCTL CIRC P Tubing Pressure Showing 0 psi and 50 psi on IA with Heavy Crude. Circulate Down TBG taking returns up the IA to flush crude cap off IA. Pump Rate 3 BPM at 170 psi on TBG and 100 on IA. Circulate until clean. Shut down after 105 bbls to check returns in kill tank. Pumped 105 bbls and 82 bbls return. Shut End TBG and IA pressure (30 psi on TBG and 40 psi IA) Still See Heavy Crude on IA. 03:00 04:00 1.00 0 0 MIRU WELCTL CIRC P Continue to Circulate down TBG at 3 bpm and taking returns up the IA. Tbg psi 120 and 50 psi on IA. Pumped 100 bbls Down TBG with. Crude and a Trace of gas in returns. Keep Circulating.at 3 bpm, 120 psi on TBG and 50 psi on the IA. 04:00 04:30 0.50 0 0 MIRU WELCTL OWFF P Done CBU. Observe well for flow. Crane on Location at 0415 hours to swap out spools. 04:30 05:30 1.00 0 0 MIRU WELLPF PULD P PJSM with Equipment Support and Nordic Crew. Swap Out ESP Spools. 05:30 08:30 3.00 0 0 MIRU WELCTL OWFF P Monitor well, Bled 22 bbls of crude and gas to kill tank. Discuss results with town. order out hot oil unit and a load of diesel. Suck out kill tank, load pits. SITP 10 psi / SIIAP 20 psi. Weight up pits from 9.1 PPG to 9.2 PPG heavy. 08:30 12:45 4.25 0 0 MIRU WELCTL CIRC P PJSM with LRS and Nordic Crew. Start Bullheading 220 bbls of Hot Diesel down IA at 1 bpm, ICP 25 psi / FCP 450 psi. 12:45 14:00 1.25 0 0 MIRU WELCTL OTHR P Completed Pumping Operation. Allow Hot Diesel to Soak. 14:00 15:15 1.25 0 0 MIRU WELCTL CIRC P SIDPP 30 psi / SIIAP 380, bleed down pressure from IA and start circulating 9.2 PPG heavy brine down TBG at 3 bpm with 50 psi on TBG and 170 psi on the IA. FCP on TBG 140 psi and 40 psi on IA with 9.2 PPG brine at surface. Pumped a total of 315 bbls with 320 bbls returned. 15:15 16:45 1.50 0 0 MIRU WELCTL OWFF P Shut down mud pumps and monitor well, still seeing small amount of flow to tanks. Shut in well and monitor pressure. Shut in psi on tbg 10 psi and 40 psi on IA. Offload fluid from kill tank. Page 2 of 7 • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 16:45 18:15 1.50 0 0 MIRU WHDBO MPSP P Well static or sight vac after 1 hour. PJSM with FMC and Nordic. Set BPV and RD Hoses from cellar. 18:15 23:00 4.75 0 0 MIRU WHDBO NUND P PJSM. RD Tree and Inspect Lift Threads. Install Blanking Plug and NU BOPE. 23:00 00:00 1.00 0 0 MIRU WHDBO BOPE P PJSM. Attempt to Shell Test, Ongoing 07/25/2012 Complete BOPE Test 250/3500 psi. Pull Hanger and Condition Well if needed. Prep and Pull 4 1/2" Y -Block Completion. 00:00 04:30 4.50 0 0 COMPZ WHDBO BOPE P Purge air from Surface Test Equipment and continue to attempt Shell Test. Leak appears to be in Blanking Plug. 04:30 05:30 1.00 0 0 COMPZ WHDBO MPSP P Pull and Inspect Blanking Plug. Find flat spot on Ball and slight abraision on 0-ring. Redress Blanking Plug and Reset. 05:30 15:00 9.50 0 0 COMPZ WHDBO PRTS P PJSM. Obtain Shell Test On Stack, 250/3500 psi, Start BOP Test . 250/3500 psi w/ 3 1/2" & 4 1/2" Test Joint. Perform Annular test and Draw down test. 15:00 15:30 0.50 0 0 COMPZ WHDBO MPSP P RD Test Joint and Test Hoses and Pull Blanking Plug and BPV 15:30 16:00 0.50 0 0 COMPZ RPCOM OWFF P Verift well is static and no flow to surface. 16:00 16:15 0.25 0 0 COMPZ RPCOM PULD P PJSM. PU Landing joint and install side isolation sleeve. 16:15 16:30 0.25 0 0 COMPZ RPCOM THGR P Screw into TBG hanger w/ landing joint and mark pipe at rotary table. BOLDS's. 16:30 16:45 0.25 0 0 COMPZ RPCOM THGR P Un -Land TBG hanger and pull hanger above flow- cross. 92k to un -seat hanger. 16:45 18:30 1.75 0 0 COMPZ RPCOM CIRC P PJSM. CBU to KT at 3 bpm until clean. Load Heat Trace Spooler to Rig floor. ICP 70 psi on TBG and 10 psi on IA. Pumped 287 bbls, with 202 bbls returned. 18:30 20:00 1.50 0 0 COMPZ RPCOM OWFF P Monitor Well, taking 10.8 bph, prep for decompletion 20:00 22:00 2.00 0 4,045 COMPZ RPCOM PULD P PJSM, Pull Hanger to Floor, up 90k# and Down 70k #, Test ESP Cable, Penetrators, and LD Landing Joint and Hanger 22:00 00:00 2.00 4,045 3,258 COMPZ RPCOM PULL P POOH with Y -Block ESP Completion from 4045', up 90k# to 3258'. Up wt 77k# and Down wt 68k# 07/26/2012 Complete Pulling of Y -Block ESP Completion, Fish Bands and Debris with Reverse Circ Junk Basket to top of SC -1 Packer at 4081' 00:00 07:30 7.50 3,258 227 COMPZ RPCOM PULL P Continue POOH from 3258' to 227' at 4 -1/2" to 3 -1/2" X -over. Up wt 45k #. 07:30 09:30 2.00 227 0 COMPZ RPCOM PULD P Pull 3 ioints of 3 -1/2" Tubing before Y- Block. Disassemble motor and TBG Leg on Y- Block. Page 3 of 7 • • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 09:30 11:00 1.50 0 0 COMPZ RPCOM PULD P PJSM. Offload ESP Equipment, heat trace spool, spooler and TBG. Clean and Clear Floor. 11:00 12:45 1.75 0 0 COMPZ RPCOM EQRP P PJSM. C/O Floor Equipment to run 3 1/2" Drill Pipe. Load Baker Tools to Rig Floor. 12:45 13:45 1.00 0 57 COMPZ RPCOM PULD P PU and MU BHA #1. RCJB, boot basket, jars and string magnet. 13:45 16:00 2.25 57 4,075 COMPZ RPCOM TRIP P TIH with BHA #1 on 3 1/2" Drill Pipe down to 4,075 -ft. 16:00 16:15 0.25 4,075 4,075 COMPZ RPCOM CIRC P Start pumping at 7 bpm, 1140 psi while working basket up and down. Shut down pump and PUH 50 -ft. Start Rotating back down at 30 rpm 1500 free torque to 4,075 -ft while pumping at 7 bpm, 1140 psi. Up Wt 82k / 72k Dn Wt and 75k rotating weight. 16:15 17:00 0.75 4,075 4,075 COMPZ RPCOM OWFF P Monitor well, Well on Vac, 13 bph. 17:00 21:00 4.00 4,075 0 COMPZ RPCOM TRIP P TOOH and Inspect Junk Backet. Up Wt 82k, Recovered —5 Bands for RCJB 21:00 23:30 2.50 0 4,077 COMPZ RPCOM TRIP P Run Rank in Hole with RCJB to 4027'. Wash Down at 8 bpm at 1570 psi to 4077' and Lightly tag 2k #. Pick up off bottom to 4056'. Rotate 30 rpm at 1500 fp of tq. Work Pipe dwn and stop rot at 4075. Circ over top of SC -1 for 2 minutes. 23:30 00:00 0.50 4,077 3,540 COMPZ RPCOM TRIP P PU to 4027'. Blow Down Top Drive and monitor Well, 13.2 bhh static loss. POOH, up wt 82k #. Midnight 3540'- Up wt 75k# 37/27/2012 Fish Bands and Debris with RCJB, Run 9 -5/8" Casing Scraper, Set Retreivable Bridge Plug at 4060' and PT Surf Casing to 2500 psi. Good Test. 00:00 04:00 4.00 3,540 0 COMPZ RPCOM TRIP P TOOH and Inspect Junk Backet. Up Wt 82k, Recovered —9 Bands for RCJB 04:00 05:45 1.75 0 4,077 COMPZ RPCOM TRIP P Run Back in Hole with RCJB to 4027'. Wash Down at 8 bpm at 1570 psi to 4077' and Lightly tag 2k #. Pick up off bottom to 4056'. Rotate 30 rpm at 1500 fp of tq. Work Pipe dwn three times total and stop rot at 4075. Circ over top of SC -1 for 5 minutes. 05:45 08:30 2.75 4,077 0 COMPZ RPCOM OWFF P PU to 4027'. Blow Down Top Drive and monitor Well, 13.2 bhh static loss. POOH, up wt 82k #. LD BHA #3. Recovered 3 Bands. 08:30 09:30 1.00 0 0 COMPZ RPCOM PULD P PJSM. MU BHA #4 9 5/8" CSG Scraper Assembly. 09:30 09:45 0.25 0 0 COMPZ RPCOM SFTY P PJSM. Discuss Hazard for lifting operation to swap out ESP spools with Nordic and ASRC heavy equipment operator and crane rigger. Page 4 of 7 • • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 09:45 12:00 2.25 0 0 COMPZ RPCOM OTHR P Perform ESP Spool swap out.0 /O Pipe Spinners. 12:00 14:00 2.00 0 4,107 COMPZ RPCOM TRIP P PJSM. MU & RIH with BHA #4, 30 -ft 3 1/2" Stringer w/ muleshoe, 9 5/8" Scraper with Oil Jars down to 4,107 -ft. Up Wt 82k / Dn Wt 72k. Rotated into SC -1 packer with stringer and start circulating. 14:00 15:00 1.00 4,107 4,107 COMPZ RPCOM CIRC P PJSM. NU to top drive and circulate at 10 bpm, 1350 psi, 335 bbls, continue uintil returns where clean. 15:00 15:30 0.50 4,107 4,107 COMPZ RPCOM OWFF P Monitor well for 30 minutes. Blow Down Top Drive. Well on a slight vac. 15:30 17:30 2.00 4,107 0 COMPZ RPCOM TRIP P TOOH and UD BHA#4 17:30 23:30 6.00 0 4,060 COMPZ RPCOM PULD P MU & RIH with BHA #5. RBP and Test Packer Assembly. Set RBP at 4060'. Pull up hole to 4035', up 82k #, down 72k# 23:30 00:00 0.50 4,060 4,060 COMPZ RPCOM PRTS P RISK, PT Casing Pressure lip Casing to 2500 psi and chart. 07/28/2012 Rig Down Baker RBP BHA. Perform Eline Casing Evaluation Logging from 4060 to Surface- CAST, Caliper, Gyro. 00:00 00:30 0.50 4,060 4,060 COMPZ RPCOM PRTS P PJSM, PT Casing. Pressure up Casing to 2500 psi and chart. Good Test. 00:30 01:30 1.00 4,060 4,060 COMPZ RPCOM PULL P Retreive RBP at 4060'. Monitor Well, 24 bph static losses. 01:30 04:30 3.00 4,060 0 COMPZ RPCOM TRIP P POOH with with RBP / Test Packer. 04:30 05:00 0.50 0 0 COMPZ RPCOM PULD P LD BHA and Kick Out. Load Dutch Riser for Eline. 05:00 12:00 7.00 0 0 COMPZ RPCOM ELOG P Rig Up Eline. PT Eline PCE 500 psi. OK. RIH w/ CAST -M Logging tools to C_I) 4 060-ft and Log to Surface. 12:00 17:00 5.00 0 0 COMPZ RPCOM ELOG P PJSM. Swap Tools and RIH w/ 40 Arm Caliper down to 4,060 -ft and Log to Surface. 17:00 23:00 6.00 0 0 COMPZ RPCOM ELOG P PJSM. Swap Tools and RIH w/ Gyro down to 4,060 -ft and Log to Surface. 23:00 00:00 1.00 0 0 COMPZ RPCOM ELOG P Rig Down HES Eline. 07/29/2012 Fish Bands and Debris with RCJB, Run 9 -5/8" Casing Scraper, Set Retreivable Bridge Plug at 4060' and PT Surface Casing to 2500 psi. Good Test. 00:00 01:00 1.00 0 0 COMPZ RPCOM ELOG P Finish Rigging Down HES. LD Dutch Riser. 01:00 02:00 1.00 0 0 COMPZ RPCOM PULD P Changeout Floor Equipment. Prep to RIH with Decompletion to Single down and Kick Out. 02:00 04:30 2.50 0 3,763 COMPZ RPCOM TRIP P RIH to 3763'. Up wt 73k# and Down wt 66k #. 04:30 09:00 4.50 3,763 0 COMPZ RPCOM TRIP P POOH Laying Down 4 1/2" Decompletion and Kick Same. Page 5 of 7 • • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 09:00 10:30 1.50 0 0 COMPZ RPCOM PULD P PJSM. Pull Wear Bushing. and Wash BOP Stack. C/O Handling Equipment and Inspect Same. RU Cable Thru Sheave. Check electrical integrity on ESP cable. 10:30 10:45 0.25 0 0 COMPZ RPCOM SFTY P PJSM. Discuss Hazard for Lifting and MU Lower ESP Section. 10:45 13:00 2.25 0 72 COMPZ RPCOM PULD P PU Lower ESP Assembly and Service Same. 13:00 14:30 1.50 72 72 COMPZ RPCOM RCST T Found some damage threads on the 4 1/2" x 3 1/2" Cross -over and damage o -ring centrilift equipment. Call for another XO and C/O o -ring. 14:30 18:00 3.50 72 1,439 COMPZ RPCOM RCST P Continue to RIH w/ remainder of completion and checking electrical integrity Of ESP cable every 1000 -ft. 18:00 00:00 6.00 1,439 1,439 COMPZ RPCOM RCST P Make UP Packer at 1439', Up 58k #, Down 55k #. Splice ESP Cable. 07/30/2012 Finish RIH with ESP FTP Completion, 00:00 01:00 1.00 1,439 1,439 COMPZ RPCOM RCST P Continue to Splice ESP Cable. 01:00 06:00 5.00 1,439 4,046 COMPZ RPCOM RCST P Continue to RIH w/ remainder of completion and checking electrical integrity of ESP cable every 1000 -ft. 06:00 08:00 2.00 4,046 4,046 COMPZ RPCOM THGR P PJSM. MU Tubing Hanger and Install Penetrators and Make Final Splice. 08:00 10:30 2.50 4,046 4,046 COMPZ RPCOM THGR P PJSM. land hanger, up wt 88k, do wt 72k. RILDS, test packoffs to 250/5000 psi for 15 minutes each. 10:30 12:00 1.50 4,046 4,046 COMPZ RPCOM RURD P PJSM. RU Hoses in cellar to IA for pumping operation. Crew Change Out. 12:00 14:30 2.50 0 0 COMPZ RPCOM CIRC P PJSM. PT Equipment 250/3500 psi. Open Well and Bullhead 160 bbls of corrosion inhibited 9.2 ppg NAC1 brine down IA at 3 BPM, 400 psi. 14:30 15:00 0.50 0 0 COMPZ RPCOM OTHR P Drop ball & rod to land in the RHC plug and allow to freefali. 15:00 15:15 0.25 0 0 COMPZ RPCOM SFTY P PJSM. Discuss the hazard for high pressure testing and setting baker packer. 15:15 16:15 1.00 0 0 COMPZ RPCOM PACK P Pressure upon TBG and start setting the Twin Seal Packer and continue to pressure up to 3,000 psi on TBG and hold for 30 minutes. 16:15 16:45 0.50 0 0 COMPZ RPCOM PRTS P Bleed TBG down to 2000 psi and, pressure up on IA to 2500 psi and chart for 30 minutes. f 16:45 21:00 4.25 0 0 COMPZ RPCOM OTHR P Hold 2,500 psi on IA and start bleeding down tubing to shear the l4 SOV. Start bleeding IA & tubing l�^ while following the decompression schedule. 21:00 21:30 0.50 0 0 COMPZ RPCOM OWFF P Observe well for flow. Monitor Static No Flow Test for 30 minutes. Pass. 21:30 22:30 1.00 0 0 COMPZ RPCOM PLUG P PJSM, Lay Down Landing Joint, Set BPV Page 6 of 7 • • Time Logs Date From To Dur S. Depth E. Depth Phase .Code Subcode T Comment 22:30 00:00 1.50 0 0 COMPZ RPCOM NUND P PJSM, Nipple Down BOPE 07/31/2012 ND BOPs, NU Tree, Pump Freeze Protect, Install BPV, Perform Final ESP electrical tests, RDMO Released Nordic Rig 3 at 15:00 hrs. 00:00 00:30 0.50 0 COMPZ WHDBO NUND P ND BOPE. 00:30 01:00 0.50 COMPZ WHDBO OTHR P Test ESP Cable. 01:00 03:00 2.00 COMPZ WHDBO NUND P PJSM, NU Tree. 03:00 03:30 0.50 COMPZ WHDBO PRTS P Pressure test hanger void at 250 / 5,000 psi and chart for 15 minutes. 03:30 04:00 0.50 COMPZ WHDBO MPSP P Pull BPV, Set TWC 04:00 07:30 3.50 COMPZ WHDBO PRTS P PJSM, Test tree at 250 / 5,000 psi and chart 250 / 5,000 - chart for 15 minutes. 07:30 08:00 0.50 COMPZ WHDBO MPSP P PJSM, Pull TWC 08:00 11:30 3.50 COMPZ RPCOM FRZP P Held PJSM with Little red services on pumping diesel. PT lines at 1,500 psi. Freeze protect w/ 40 bbls of neat diesel followed by 140 bbls of gelled diesel at 1.4 bpm at 500 psi. RD LRS. 11:30 12:30 1.00 COMPZ RPCOM DHEQ P Test ESP cable and down hole gauges - good test. while u- tubing diesel in well, cleaning pits and RD misc equipment. 12:30 14:00 1.50 COMPZ RPCOM MPSP P PJSM, Set BPV w/ lubricator. Dress tree and record SI pressures 180 psi TBG, 180 psi IA. Secure well. 14:00 15:00 1.00 COMPZ MOVE RURD P Remove auxiliary equipment from around rig in preparation for rig move. Release Nordic rig 3 at 15:00 hrs. Page 7 of 7 • • @ ocoPhillips Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 i 'L) , ..„,, ,— L7. , 7 :1 - f D - L1 , 4,MtoltiOAAR ;',/ o u , Lrc' March 9, 2012 ; i j 2112 Commissioner Dan Seamount .)! "1 ' '31J .)i L'A.,,d..1]_,JJL j Alaska Oil & Gas Commission 1 333 West 7 Avenue, Suite 100 Anchorage, AK 99501 ilq - I Commissioner Dan Seamount: a- ao 7 Enclosed please find a spreadsheet with a list of wells from the Kuparuk field (KRU). Each of these wells were found to have a void in the conductor. These voids were filled with cement and corrosion inhibitor, engineered to prevent water from entering the annular space. As per previous agreement with the AOGCC, this letter and spreadsheet serves as notification that the treatments took place and meets the requirements of form 10-404, Report of Sundry Operations. The cement was pumped in the fall of 2011. The corrosion inhibitor/sealant was pumped on various days in January and February 2012. The attached spreadsheet presents the well name, top of cement depth prior to filling, and volumes used on each conductor. Please call MJ Loveland or Martin Walters at 907-659-7043, if you have any questions. 1 .. Sinceri / 4, MI eland Z ConocoPhillips Well Integrity Projects Supervisor . • ConocoPhillips Alaska Inc" Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10 -404) Kuparuk Field Date 3 -09 -2012 2A,M,T,X PAD Corrosion Initial top of Vol. of cement Final top of Cement top off Corrosion inhibitor/ Well Name API # PTD # cement pumped cement , date inhibitor sealant date ft bbls ft gal 2A-19A 50103201970100 2010830 12" NA 39" NA 15.3 2/11/2012 2M -02 50103201790000 1920830 10'5" 1.62 19" 11/22/11 5.1 2/11/2012 _ 2M -29 , 50103201830000 , 1920970 SF NA 24" NA 3.4 2/11/2012 2T-18 50103202130000 1950170 4'2" 0.50 9" 11/22/11 2.55 2/12/2012 27-28 50103202250000 1950920 9" NA 16" NA 2T-207 50103202780000 1982310 273" 3.70 7" 11/21/11 , 2.98 2/12/2012 2T-215 50103202800000 1982420 18'6" • 2.40 10" 11/22/11 4.25 2/122012 2X-06 50029209880000 1831100 SF NA 21" NA 2.13 2/12/2012 f Page 1 of 1 (' I PHilliPS Alaska, Inc. A Subsidiary of PHILLIPS PETROLEUM COMPANY Transmittal #71 Detail Date: 11/2/01 To (External Party): Email: blank First Name: Howard Last Name: Oakland From (PAl Contact): Email: cworley@ppco.com First Name: Catherine Last Name: Worley Phone (907)793-1235 Number: Company: AOGCC Address: 333 W. 7th City: Anchorage State: AK Zip Code: 99510 Phone Number: (907) 265-1129 Company: Phillips Alaska Add A TO 1490 700 G ress: Street City: Anchorage State: AK Zip Code: 99510 Transmittal Info: Sent Via: hand delivery Justification: compliance - replacement Tracking #: 1 Data Detail: Description Phillips 2T -207 digital well log data by Sperry Sun logged J f)39f- 04FEB99 Type 3" floppy disk Quantity Attachments: Filename: None Received By: Signature: ;CiECE\VED Filesize: ~m NOV 0 2 2001 Date: Alaska Oil & Gas cons. Commissio Anchorage Approver: Signature: Date:~) ~CGA!~NE'[} DEC 3 @ 2003 ~~'N,~ http://www .akppco.comltransmittal/printasp?transno=71 11/2/01 Re: 2T-207 Subject: Re: 2T-207 Date: Mon, 12 Mar 2001 14:32:31 -1000 From: "Catherine Worley" <cworley@ppco.com> To: Rob_Kalish@sperry-sun.com CC: CFarley@sperry-sun.com, "Sandra D Lemke" <slemke@ppco.com>, howard_okland@admin.state.ak, us, "Deirdre L Schwartz" <dschwar@ppco.com> Hi Rob, We are looking for the di 'tal data on 2T-207 I do not have any digital data on this well. Looks ~ke that well will ~e released by the AAOGC and they are looking for the data. could you get that to us as quickley as possible. Thanks Cathy Forwarded by catherine worley/PPCO on 03/12/2001 02:25 PM Deirdre L schwartz 03/12/2001 01:33 PM To: Catheri ne worl ey/PPCO@Phi I I i ps cc: subject: Re: 2T-207 cathy, Melanie reported this missing in 1999. I found this. on 5/13/99 I have an e-mail from Marshall that he was behind but had the instructions for 2T-207 (and many others). I checked my logs directory and I don't have anything for 2T-207. Please contact Sperry (forward this?). Dede Forwarded by Deirdre L schwartz/PPCO on 03/12/2001 02:31 PM Deirdre L schwartz 09/16/99 03:18 PM To: MMunyak@sperry-sun.com cc: Douglas S Hastings/AAI/ARCO@ARCO, Melanie K Marquardt/AAI/ARCO@ARCO subject: Re: 2T-207 Marshall, we are unable to locate the data for this well. Can you please let me know the status? Dede ............... Forwarded by Deirdre L SchwartZ/AAI/ARCO on 09/16/99 03:17 PM catherine worley 09/16/99 02:27 PM To: Deirdre L schwartz/AAI/ARCO@ARCO CC: subject: Re: 2T-207 (Document link: Database 'Deirdre L schwartz', view ' ($Inbox)') Hi, We have not received the digital data for 2T-207. RSO shows we have only a directional survey. No reproducibles or anything else. cathy 1 of 1 3/12/01 2:55 PM 0 !:t I I--I-- I I~J G S E !:!~./I ~-- E S WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Lori Taylor 3001 Porcupine Dr. Anchorage, Alaska 99501 6~' May 20, 1999 RE: MWD Formation Evaluation Logs 2T-207, AK-MW-90030 The technical data listed below is being submitted herewith. Please address any problems or concems to the attention of.' Jim Galvin, Sperry-Sun Drilling Services, 5631 Silverado Way, #G, Anchorage, AK 99518 2T-207: 2" x 5" MD Resistivity & Gamma Ray Logs: 50-103-20287-00 2" x 5" TVD Resistivity & Gamma Ray Logs: 50-103-20287-00 2" x 5" MD Density Logs: 50-103-20287-00 2" x 5" TVD Density Logs: 50-103-20287-00 1 Blueline 1 Folded Sepia l Blueline 1 Folded Sepia 1 Blueline 1 Folded Sepia 1 Blueline 1 Folded Sepia i999 ~ns. Commi~i0n 5631 Silverado Way, Suite G · Anchorage, Alaska 99518 · (907) 273-3500 · Fax (907) 273-3535 A Halliburton Company .... 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 [] Gas [] Suspended [] Abandoned [] Service [] 2. Name of Operator 7. Permit Number ARCO Alaska, Inc. 98-231 3. Address 8. APl Number P. O. Box 100360, Anchorage, AK 99510-0360 50-103-20278 4. Location of well at surface '?. ............... ~~ 9. Unit or Lease Name 630' FSL, 556' FWL, Sec. 1, T11 N, R8E, UM ; i,1,~l~,~tll¢l~*. Kuparuk River Unit At Top Producing Interval i! ~~'-~ il',/i:'~'., ¢~~--=~ - : ~ 10. Well Number At Total Depth "'~l,~~ ~ :11. Field and Pool 345' FNL, 2154' FEL, SEC 11, T11 N, R8E, UM :': ...... ~ ~",' ..... ~.-c-'¢' . Kuparuk River Field 5. Elevation in feet (indicate KB, DF, etc.) 16. Lease Designation and Serial No. 31 feetI ADL 25569 ALK 2667 Tabasco Oil Pool (proposed) 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. Or Aband. 115. Water Depth, if offshore 16. No. of Completions December 6, 1998 February 4, 1999 February 11, 1999I N/A feet MSL 1 17. Total Depth (MD + TVD) 18. Plug Back Depth (MD + TVD) 19. Directional Survey 120. Depth where SSSV set 21. Thickness of Permafrost 4495' MD/3179' TVD 3951' MD/2827' TVD YES [] No []I N/A feetMD 1730' (approx) 22. Type Electric or Other Logs Run GR/Res/Density 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORDI AMOUNT PULLED 16" 62.5# H-40 41' 112' 24" :9 cu yds High Early 9.625" 40# L-80 41' 4243' 12.25" 560 sx AS III L, 725 sx Class G, 6O sx AS I 4" 32# L-80 4081' 4116' 8.5" gravel pack assembly 4" 11.6# L-80 4116' 4413' 8.5" gravel pack assembly 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) 4.5" x 3.5" 3849'/3948' 4081' GP Packer 4116'-4191' MD 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. gravel pack DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED N/A 27. PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) March 11, 1999 Flowing Date of Test Hours Tested Production for OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE IGAS-OIL RATIO 4/5/1999 10.0 Test Period > 255 25 5 1761 145 Flow Tubing Casing Pressure Calculated OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY - APl (corr) Press. 317 psi 0 24-Hour Rate · 596 86 2 0 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and pressence of oil, gas or water. Submit core chips. . · , * This 10-407 is submitted as directed per the 10-401 form approved (Permit #98-231) ORIGINAL Form 10-407 Rev. 7-1-80 CONTINU ED ON REVERSE SIDE Submit in duplicate 29. 30. GEOLOGIC MARKERS Top Tabasco Base Tabasco NAME MEAS. DEPTH 4374' TRUE VERT. DEPTH 3052' 4408' 3121' FO RMATION TESTS Include interval tested, pressure data, all fluids recovered and gravity. GOR, and time of each phase. Annulus left open - freeze protected with diesel. 31. LIST OF ATTACHMENTS Summary of Daily Operations and Directional Survey 32. I hereby certify that the following is true and correct to the best of my knowledge. Paul Mazzolini Title Drilling Team Leader Date INSTRUCTIONS Prepared by Sharon AIIsup-Drake General: This form is designed for submitting a complete and correct well completion report and Icg on all types of lands and leases in Alaska. Item 1' Classification of Service wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Sh ut-in, Oth er-explain. Item 28: If no cores taken, indicate "none". Form 10-407 Date: 2/25/99 ARCO ALASKA INC. WELL SUMMARY REPORT Page: 1 WELL:2T-207 WELL ID: AK9677 TYPE: -- AFC: AK9677 STATE:ALASKA AREA/CNTY: NORTH SLOPE WEST FIELD: KUPARUK RIVER UNIT SPUD:12/06/98 START COMP: RIG:NORDIC 3 BLOCK: FINAL: WI: 0% SECURITY:0 API NUMBER: 50-103-20278-00 12/05/98 (D1) TD: 117'(117) SUPV:DONALD LUTRICK 12/06/98 (D2) TD: 1253'(1136) SUPV:DONALD LUTRICK 12/07/98 (D3) TD: 2491'(1238) SUPV:DONALD LUTRICK 12/08/98 (D4) TD: 4070' (1579) SUPV:FRED HERBERT 12/09/98 (D5) TD: 4247'(177) SUPV:FRED HERBERT 12/10/98 (D6) TD: 4247'( 0) SUPV:FRED HERBERT 12/11/98 (D7) TD: 4247'( 0) SUPV:FRED HERBERT MW: 0.0 VISC: 0 PV/YP: 0/ 0 APIWL: 0.0 SPUD WELL Move rig to 2T-207. Rig up. MW: 9.4 VISC: 125 PV/YP: 46/45 APIWL: 6.4 DRLG @ 1627' Function test diverter. Drill from 117' to 1253' MW: 9.5 VISC: 187 PV/YP: 44/46 APIWL: 5.8 DRLG AT 3100' Drilling from 1253' to 1725'. CBU. POH, swabbing. Backream from 1620' to 703'. RIH, hit bridge at 1570'. Ream from 1570' to 1725'. Drilling from 1725' to 2491' MW: 9.5 VISC: 121 PV/YP: 36/47 APIWL: 5.2 CIRC BTTMS UP @ 4247' Drilling 12.25" hole from 2491' to 4070'. CBU. Mad pass w/LWD tool from 3538' to 3653' MW: 9.7 VISC: 125 PV/YP: 36/46 APIWL: 5.0 CIC & COND FOR CASING RUN Drill 12.25" hole from 4070' to 4247' Survey @ 1847' POOH. Tight from 558' to 260'. RIH to take MWD survey @ 1341' MW: 9.7 VISC: 118 PV/YP: 31/41 APIWL: 4.6 CIRC & COND MUD FOR CEMENT JOB Wash and ream thru doglegs from 700' to 800', and 1300' to 1400' Run 9.625" casing. MW: 9.7 VISC: 50 PV/YP: 27/13 APIWL: 4.4 NIPPLE DOWN DIVERTER Continue to run 9.625" casing. Hold safety meeting. Pump first and second stage cement. Date: 2/25/99 ARCO ALASKA INC. WELL SUMMARY REPORT Page: 2 12/12/98 (D8) TD: 4247' ( 0) SUPV:FRED HERBERT MW: 9.3 VISC: 43 PV/YP: 11/11 DRILLING ON STAGE COLLAR NU BOPs and test to 250/3000 psi. APIWL: 7.0 12/13/98 (D9) TD: 4247' ( 0) SUPV:FRED HERBERT MW: 8.6 VISC: 28 PV/YP: 0/ 0 WAIT ON PENETRATOR FOR TUBING HANGER APIWL: 0.0 Clean out cement from 2020' to 2038' Drilling cement, plug & stage collar from 2038' to 2060'. Tag stage collar @ 2060'. Clean out cement from 3788' to 4124' 12/14/98 (D10) TD: 4247'( 0) SUPV:FRED HERBERT MW: 0.0 VISC: 28 PV/YP: 0/ 0 RIG RELEASED @ 1300 HRS 12/14/98 APIWL: 0.0 Freeze protect well. P/U 4.5" tubing hanger and landing jt. Attempt to install penetrators, won't go. Work on tubing hanger (wrong threads). ND BOPE, NU tree and test to 250/5000 psi, OK. 01/26/99 (Dll) MW: 0.0 VISC: 28 PV/YP: 0/ 0 APIWL: 0.0 TD: 0' ( 0) MOVING RIG F/ 3M PAD TO 2T PAD - @ 0600 RIG AT CPF 2 SUPV:DEARL W. GLADDEN Work to find leak source in mud pits, found 2 cracks, repaired same. Begin turn key move to 2T pad. 01/27/99 (D12) MW: 0.0 VISC: 28 PV/YP: 0/ 0 TD: 0' ( 0) N/U BOP SUPV:DEARL W. GLADDEN Continue moving rig to 2T pad. APIWL: 0.0 01/28/99 (D13) MW: 0.0 VISC: 28 PV/YP: 0/ 0 TD: 0' ( 0) P/U 5" DP AND STAND BACK IN DERRICK SUPV:DEARL W. GLADDEN Rig up. NU BOPE. APIWL: 0.0 01/29/99 (D14) MW: 0.0 VISC: 0 PV/YP: 0/ 0 APIWL: 0.0 TD: 0' ( 0) P/U 3 1/2" DP AND STAND BACK IN DERRICK SUPV:DEARL W. GLADDEN Test BOPE to 250/3000 psi, OK. Top drive froze up. Stand pipe & mud manifold frozen, thaw out. Rack 3.5" DP in shed to thaw and strap. 01/30/99 (D15) MW: 0.0 VISC: 0 PV/YP: 0/ 0 APIWL: 0.0 TD: 0' ( 0) TIH P/U BHA % 1 SUPV:DEARL W. GLADDEN Continue to rack and tally 3.5" DP. Thaw and rabbit each joint. Top drive and goose neck still frozen up, wrap with plastic and apply steam to thaw out. Rack and thaw 3.5" HWDP in shed. Date: 2/25/99 ARCO ALASKA INC. WELL SUMMARY REPORT Page: 3 01/31/99 (D16) MW: 9.5 VISC: 45 PV/YP: 9/15 APIWL: 15.2 TD: 0' ( 0) TIH -STRAP DP SUPV:DEARL W. GLADDEN Tag small ice stringers. Displace diesel cap w/water. Displace hole w/ new LSND mud. 02/01/99 (D17) MW: 9.5 VlSC: 44 PV/YP: 9/18 APIWL: 15.0 TD: 4120' (4120) CORRECTED TAG DEPTH @ 4120.18' RKB NORDIC -WOW- NEED TO BUIL SUPV:DEARL W. GLADDEN Waiting on weather. Safety meeting. Thaw kelly hose. 02/02/99 (D18) MW: 9.7 VlSC: 45 PV/YP: 11/13 APIWL: 15.0 TD: 4141' ( 21) C/O & DRILL 20' NEW HOLE LOT EMW 14.9 PPG. CHANGE OVER FROM SUPV:DONALD L. WESTER Waiting on weather. Tag cement @ 4118' clean out float equipment, clean out cement to 4141' 02/03/99 (D19) MW: 9.7 VISC: 57 PV/YP: 15/24 APIWL: 3.2 TD: 4163'( 22) CONTINUE RIH TO 4243', CHANGE SHAKER SCREENS AND DRILL AHEAD SUPV:DONALD L. WESTER Continue to clean out cement from 9-5/8" casing. Drill 8.5" hole from 4243' to 4263'. Perform LOT, EMW 14.9 ppg. 02/04/99 (D20) MW: 9.7 VISC: 56 PV/¥P: 13/22 APIWL: 4.0 TD: 4496' (333) CHANGE PIPE RAM. SUPV:DONALD L. WESTER Drill 8.5" hole to 4430', started packing off. Tight hole on connection. Drill from 4430' to 4496' 02/05/99 (D21) MW: 9.7 VISC: 57 PV/YP: 15/24 APIWL: 4.4 TD: 4496' ( 0 PUMPED 9.8 PPG BRINE AROUND. W/ BRINE AT SURFACE A 3" HOSES SUPV:DONALD L. WESTER Install test plug RILDS. Change top & bottom pipe rams to 3.5". Test plug leak. Pull test plug change rubbers. Leak change out test plug. Change rubbers and test to 3000 psi. Weekly BOP test 250/3000 psi. Pump jell pill ahead of brine & KCl clean fluid down annulus. 02/06/99 (D22) MW: 9.8 VISC: 0 PV/YP: 0/ 0 APIWL: 0.0 TD: 4496'( 0 PUMPING FORMIC ACID 2 18 BBL BATCHS SUPV:DONALD L. WESTER Continue displacing drill in mud w/clear 15% KCl brine completion fluid. Had a 10 bbl brine spill. Pump sand. Pump caustic wash. Clean out sand. Reverse out sand. 02/07/99 (D23) MW: 9.8 VISC: 0 PV/YP: 0/ 0 APIWL: 0.0 TD: 4496'( 0 POOH W/ MULE SHOE, R/U TO RUN BAKER GRAVEL PACK SCREENS. SUPV:DONALD L. WESTER Pump formic acid job. Circulate and filter completion fluid. Reverse out keeps plugging off. Reverse out sand. Still having trouble packing off. Date: 2/25/99 ARCO ALASKA INC. WELL SUMMARY REPORT Page: 4 02/08/99 (D24) MW: 9.8 VISC: 0 PV/YP: 0/ 0 APIWL: 0.0 TD: 4496'( 0) COMPLETE GRAVEL PACKING BAKER SCREENS IN OPEN HOLE W/ 10,200 SUPV:DONALD L. WESTER Monitor well, pipe plugged. Well flowing from 100 bbl loss while reversing. POOH wet pipe, last three joints plugged with river rocks, formation sand & frac sand. RIH w/ Baker gravel pack screen assembly. Set packer @ 4080'. Start gravel packing screens. 02/09/99 (D25) MW: 9.8 VISC: 0 PV/YP: 0/ 0 APIWL: 0.0 TD: 4496'( 0) PICKING UP TRICO Y-BLOCK ASSY SUPV:DEARL W. GLADDEN Reverse out excess gravel. TOH. Change top pipe rams to 4.5", test rams to 3000 psi. RIH w/4.5" tbg. 02/10/99 (D26) MW: 9.8 VISC: 0 PV/YP: 0/ 0 TD: 4496' ( 0) RUN COMPLETION @ 2800' SUPV:DEARL W. GLADDEN Run completion string 4.5" tubing and ESP. APIWL: 0.0 02/11/99 (D27) MW: 9.8 VISC: 0 PV/YP: 0/ 0 APIWL: 0.0 TD: 4496'( 0) FREEZE PROTECTING WELL SUPV:DEARL W. GLADDEN Continue to RIH w/completion string and heat trace. 02/12/99 (D28) MW: 9.8 VISC: 0 PV/YP: 0/ 0 APIWL: 0.0 TD: 4496'( 0) N/U BOP SUPV:DEARL W. GLADDEN N/D BOPs, N/U tree and test to 250/5000 psi, OK. Freeze protect well. Release rig @ 2/12/99 @ 1800 hrs. Sperry-Sun Drilling Services Survey Report for 2T-207 Your Ref: API-501032027800 Job No. AKMM90030, Surveyed: 4 February, 1999 Prudhoe Bay Unit ., Measured Depth Incl. (ft) Azim. Sub-Sea Depth (ft) Vertical Local Coordinates Global Coordinates 'Depth Northings Eastings Northings Eastings (ft) (fi) (fi). (ft) (ft) Alaska State Plane Zone 4 Kuparuk 2T Dogleg Rate (°/lOOft) Vertical Section (ft) Comment 2T-207 D- 19 0.00 161.78 190.57 221.43 253.09 278,27 308,13 336,26 370.92 401,33 432.02 460.01 491.73 521.83 546.12 578.83 608.41 637.30 669.55 699.22 721.17 761.03 790.78 815.56 845.42 0,000 1,220 1,100 1,550 2.530 3,640 4,950 5,810 6,690 7,770 9,160 10,770 12,150 13,110 13,980 14,470 15,650 17,290 19,190 21,390 22,690 24,100 24.430 25,240 26,600 0.000 4.510 354.630 322.690 303.070 293.96O 291.150 286.290 282.87O 278.950 277.110 275.170 273.190 270.190 267.640 265.270 263.510 261.490 258.880 257.170 254.790 253.820 253.790 254.790 254.990 -110,95 50,82 79.60 110,45 142,09 167,24 197,01 225,02 259,47 289,64 320,00 347,56 378,65 408,02 431,64 463.34 491,91 519,61 550,24 578,07 598,41 634,99 662,12 684,60. 711,46' 0.00 161.77 190.55 221.40 253.O4 278.19 307.96 335.97 370.42 400.59 430.95 458.51 489.60 518.97 542.59 574.29 602.86 630.56 661.19 689.02 709.36 745.94 773.07 795.55 822.41 0.00 N 0.00 E 5970610.10 N 498945.02 E 1.72 N 0.14 E 5970611.82 N 498945.16 E 2.30 N 0.13 E 5970612.40 N 498945.15 E 2.92 N 0.15W 5970613.02 N 498944187 E 3.65 N 0.99W 5970613.75 N 498944.03 E 4.27 N 2.19W 5970614.37 N 498942.83 E 5.12 N 4.26W 5970615.22 N 498940.76 E 5.96 N 6.75W 5970616.06 N 498938.27 E 6.90 N 10.41W 5970617.00 N 498934.61 E 7.62 N 14.16W 5970617.72 N 498930.86 E 8.24 N 18.64W 5970618.35 N 498926.38 E 8.75 N 23.45W 5970618.86 N 498921.57 E 9.21N 29.74W 5970619.31N 498915.28 E 9.39 N 36.32W 5970619.50 N 498908.71E · 9.28 N 42.00W 5970619.39 N 498903.02 E 8.78 N 50.02W 5970618.89 N 498895.00 E 8.03 N 57.67W 5970618.14 N 498887.35 E 6.95 N 65.79W 5970617.06 N 498879.23 E 5.22 N 75.73W 5970615.33 N 498869.29 E 3.08 N 85.79W 5970613.19 N 498859.23 E 1.08 N 93.78W 5970611.19 N 498851.24 E 3.21 S 109.01W 5970606.91 N 498836.00 E 6.62 S 120.76W 5970603.50 N 498824.26 E 9.43 S 130.77W 5970600.69 N 498814.24 E 12.84 S 143.38W 5970597.29 N 498801.64 E 0,754 0.809 2.747 3.758 4.806 4.442 3.457 2.756 3.902 4.614 5.875 4.523 3.862 4.344 2.327 4.278 6.012 6.412 7.679 7.184 3.667 1.110 3.682 4.564 0.00 -0.71 -0.91 -0.86 -0.31 0.60 2.26 4.32 7.44 10.73 14.72 19.07 24.83 30.95 36.33 44.05 51.49 59.49 69.43 79.62 87.81 103.60 115.80 126.18 139.18 Continued... 30 March, 1999 - 10:31 - 2 - DrillQuest Sperry-Sun Drilling Services Survey Report for 2T-207 Your Ref: A PI-501032027800 Job No. AKMM90030, Surveyed: 4 February, 1999 Prudhoe Bay Unit' Measured Depth (ft) Incl. Azim. Sub-Sea Depth (ft) Vertical Depth (ft) 875.66 27.670 254.330 738.37 849.32 902.29 28.650 251.910 761.85 872.80' 936.93 29.340 250.560 792.15 903.10 968.24 29.330 249.980 819.44 930.39 994.54 29.000 250.690 842.41 953.36 . 1027.58 29.030 249.820 87!.30 982.25 1058.04 29.900 252.050 897.82 1008.77 1084.24 29.990 250.790 920.53 1031.48 · 1119.61 30.590 250.660 951.07 1062.02 1151.97 30.780 250.440 978.90 1089.85 1180.78 31.340 250.450 1003.58 1114.53 1213.72 33.240 250.810 1031.42 1142.37 1246.01 35.560 250.740 1058.06 1169.01 1274.76 37.890 250.130 1081.10 1192.05 1308.02 39.100 249.510 1107.13 1218.08 1338.94 39.960 249.530 1130.98 1241.93 1368.20 40.620 249.620 1153.30 1264.25 1404.78 40.940 249.300 1181.00 1291.95 1437.30 41.150 249.140 1205.53 1316.48 1466.04 42.340 249.180 1226.97 1337.92 1501.91 44.440 250.720 1253.04 1363.99 1537.98 45.870 250.580 1278.47 1389.42 1563.91 46.810 251.560 1296.37 1407.32 1591.94 48.530 250.620 1315.25 1426.20 1624.36 48.810 251.370 1336.66 1447.61 Local Coordinates Global Coordinates Northings Eastings Northings Eastings (ft) '(ft) (ft) (ft) 16.49 S 156.68W 5970593,64 N 498788,34 E 20.14 S 168.70W 5970589,99'N 498776,32 E 25,54 S 184,59W 5970584.59 N 498760,42 E 30,72 $ 199,03W 5970579,41 N 498745,98 E 35,03 S 211,10W 5970575,10 N 498733,91 E 40,45 S 226.19W 5970569,69 N 498718,83 E 45,34 S 240,35W 5970564.80 N 498704.67 E 49.50 S 252,74W 5970560,63 N 498692.27 E 55,39 S 269,58W 5970554,75 N 498675,43 E 60,89 S 285,15W 5970549,25 N 498659,86 E 65,87 S 299,16W 5970544,28 N 498645.85 E 71,70 S 315.76W 5970538.44 N 498629.25 E 77,71S 332,98W 5970532.44 N 498612,03 E 83.47 S 349,18W 5970526,68 N 498595.83 E 90,61S 368,61W 5970519,54 N 498576,40 E 97,50 S 387.05W 5970512,66 N 498557,96 E 104.10 S 404,78W 5970506,06 N 498540,23 E 112,48 S 427.15W 5970497,68 N 498517,85 E 120,06 S 447,12W 5970490,11 N 498497,89 E 126,86 S 465,00W 5970483,30 N 498480.00 E 135,31 S 488,15W 5970474,86 N 498456,85 E 143,78 S 512,28W 5970466,39 N 498432,72 E 149,86 S 530,02W 5970460,31N 498414.98 E 156,58 S 549,62W 5970453,60 N 498395,38 E 164,51 S 572,64W 5970445,67 N 498372,36 E Alaska State Plane ZOne 4 Kuparuk 2T Dogleg Vertical Rate Section (°/100ft) (ft) Comment 3,676 152,93 5.651 165,48 2,745 182,27 0,908 . 197.60 1.818 210.42 1.280 226.45 4.596 241.43 2.425 254.50 1.706 272.34 0.682 288.85 1.944 303.72 5.798 321.31 7.186 339.55 8.203 356.74 3.819 377.44 2,782 397,12 2,264 416,04 1.045 439,93 0,722 461.28 4.142 480.42 6.555 505.06 3.974 530.63 4.541 549.38 6.618 570.10 1194O 594.44 Con#nued... DrillQuest 30 March, 1999 - 10:31 - 3 - Prudhoe Bay unit Measured DePth Incl. (ft) Azim. 1654.65 49.290 250.290 1692.88 49.900 252,010 1725.59 50.020 251.740 1780.55 54.470 251,750 1846.92 55.570 251.730 1910.26 55.920 252.360 1977.77 54.490 248.290 2039,19 54.200 247.450 2104.95 53.550 247.850 2164.41 54.100 247.400 2227.63. 53.730 249.160 2292.47 55.750 247.510 2356.58 57.260 246.770 2417.32 56.320 247.530 2480.89 55.600 246,820 2548.73 55.160 2608.84 55.190 2675.55 55.760 2739.28 55.600 2799.55 55.660 247.660 247,63O 247.790 247,920 248.380 2865.19 55.410 248.340 2928.77 55.280 249.040 2991.70 54.780 248.920 3056.10 54.200 248.710 3120.19 53.850 248.620 Sub-Sea Depth 1356.51 1381.29 1402.33 1435.98 1474.03 1509.68 1548.21 1584.02 1622.78 1657.88 1695.12 1732.55 1767.93 1801.20 1836.78 1875.32 1909.65 1947.46 1983.39 2017.42 2054.56 2090.72 2126.78 2164.19 2201.84 Sperry-Sun Drilling Services Survey Report for 2T-207 Your Ref: API-501032027800 Job No. AKMM90030, Surveyed: 4 February,. 1999 Vertical Depth 1467.46 1492.24 1513.28 1546.93 1584.98 1620.63 1659.16 1694.97 1733,73 1768.83 1806.07 1843.50 1878.88 1912.15 1947.73 1986.27 2020.60 2058.41 2094.34 2128.37 2165.51 2201.67 2237,73 2275.14 2312.79 Local Coordinates Northings Eastings (ft) (ft) 172.02 S 181.42 S 189.22 S 2O2.82 S 219.86 S 236.00 S 254.64 S 273.44 S 293.64 S 311.91S 330.82 S 350.37 S 371.14 S 390.88 S 411.31S 432.91S 451,68 S 472,53 S 492.37 S 510.88 S 530.84 S 549.84 S 568.34 S 587.29 S 606.16 S 594.25W 621.80W 645.60W 686.85W 738.49W 788.30W 840.49W 886.72W 935,84W 980,22W 1027.68W 1076.88W 1126.14W 1172.97W 1221.52W 1273.00W 1318.64 W 1369.49 W 1418,24 W 1464.42W 1514.72W 1563.44W 1611.58W 1660.46W 1708.77W Alaska State Plane Zone4 Kuparuk 2T Global Coordinates Dogleg Northings Eastings Rate (ft) (ft) (°/100ft) 5970438.16 N 498350.75 E 5970428.76 N 498323.20 E 5970420.98 N 498299.40 E 5970407.37 N 498258.14 E 5970390.34 N 498206,49 E 5970374,21 N 498156.69 E 5970355.58 N 498104,50 E 5970336.78 N 498058.27 E 5970316.59 N 498009.14 E 5970298,33 N 497964.75 E 5970279.42 N 497917.29 E 5970259.88 N 497868,09 E 5970239.11 N 497818.83 E 5970219.39 N 497772,00 E 5970198.96 N 497723.44 E 5970177.37 N 497671.96 E 5970158.61 N 497626,32 E 5970137.77 N 497575.46 E 5970117.93 N 497526.71 E 5970099.43 N 497480.53 E 5970079.47 N 497430.23 E 5970060.48 N 497381.50 E 5970041.98 N 497333.36 E 5970023.05 N 497284.48 E 5970004,18 N 497236.16 E Vertical Section (ft) Comment 3.125 3.779 ' 0.731 8.097 1.658 0.991 5.384 1.2O7 1.104 1.109 2.325 3.745 2.544 1.868 1.463 1.208 O.O65 0.877 0.302 0.638 0.384 0.928 0.810 0.939 0.558 617.32 646.42 671.45 714.88 · 769.23 821.56 876.97 926.84 979.91 1027.86 1078.92 1131.84 1185.23 1235.98 1288.58 1344.34 1393.64 1448.55 1501.15 1550.87 1604.96 1657.24 1708.80 1761.21 1813.06 Continued... 30 March, 1999 - 10:31 .4 - DrillQuest Sperry-Sun Drilling Services Survey Report for 2T-207 Your Ref: API-501032027800 Job No. AKMM90030, Surveyed: 4 February, 1999 Prudhoe Bay Unit Measured Depth Incl. (ft) Azim. 3181.84 53.300 248.050 '3247.99 53.340 248.640 3311.63 52.160 248.970 3375.19 51.660 248.900 3439.46 51.520 249.420 .3501.22 51.280 248.870 3561.26 51.110 249.820 3627.16 51.300 251.000 3688.25 51.300 251.050 3751.35 51.120 251.880 ,. 3819.47 51.480 252.300 3881.28 51.130 251.760 3943.92 50.670 250.370 4009.99 50.300 250.010 4074.22 50.520 250.270 4133.04 50.230 249.640 4181.96 50.180 249.870 Sub-Sea Depth (ft) 2238.44 2277.96 2316.48 2355.69 2395.62 2434.15 2471.78. 2513.07 2551.26 2590.79 2633.38 2672.03 2711.53 2753.57 2794.50 2832.02 2863.33 Vertical Local COordinates Global Coordinates Depth Northings Eastings Northings Eastings (ft) ,(ft) .(ft) (ft) . (ft) 2349.39 2388.91 2427.43 2466.64 2506.57 2545.10 2582.73 2624.02 2662.21 2701.74 2744.33 2782.98 2822.48 2864.52 2905.45 2942.97 2974.28 2T-207 4283.48 50.090 248.930 2928.40 3039.35. 4374.40 48.270 249.770 2987.83 3098.78 4430.31 47.920 251.310 3025.t8 3136.13 4495.00 47.920 251.300 3068.53 3179.48 624.47 s 1754.87w 5969985.88 N 497190.06 E 644.04 S 1804.18W 5969966.31 N 497140.75 E 662.36 S 1851.41W 5969948.00 N 497093.52 E 680.34 S 1898~09W 5969930.03 N 497046.83 E 698.26 S 1945.16W 5969912.12 N 496999.77 E 715.44 S 1990.26W 5969894.94 N 496954.66 E 73.1.94 S 2034.04W 5969878.44 N 496910.88 E 749.16 S 2082.43W 5969861.23 N 496862.49 E 764.67 S 2127.51W 5969845.73 N 496817.40 E 780.30 S 2174.15W 5969830.11N 496770.77 E 796.65 S . 2224.73W 5969813.76 N 496720.18 E 811.53 S 2270.62W 5969798.89 N 496674.29 E 827.30 S 2316.60W 5969783.12 N 496628.30 E 844.58 S 2364.55W 5969765.86 N 496580.35 E 861.39 S 2411.11W 5969749.05 N 496533.79 E 876.92 S 2453.67W 5969733.53 N 496491.23 E 889.93 S 2488.93W 5969720.52 N 496455.96 E 917.34 S 2561.87W 5969693.12 N 496383.02 E 941.61S 2626.25W 5969668.86 N 496318.64 E 955.47 S 2665.48W 5969655.00 N 496279.41E 970.86 S 2710.96W 5969639.62 N 496233.92 E Alaska State Plane Zone4 Kuparuk 2T Dogleg Rate (°/lOOft) Vertical Section (ft) Comment 1.162 0.718 1.900 0.791 0.670 0.797 1.265 1.425 0.064 1.064 0.715 0.886 1.872 0.700 0.463 0.961 0.375 1862.64 1915.67 1966.31 2016.33 2066.68 2114.94 2161.72 2213.08 2260.75 2309.92 2363.05 2411.27 2459.87 2510.84 2560.34 26O5.64 2643.23 TIE-ON SURVEY 0.716 2.120 2.143 0.011 2721.14 2789.94 2831.54 2879.55 PROJECTED SURVEY Continued... 30 March, 1999 - 10:31 - 5 r DrillQuest , Sperry-Sun Drilling Services Survey Report for 2T-207 Your Ref: API-501032027800 Job No. AKMM90030, Surveyed: 4 February, 1999 Prudhoe Bay Unit Alaska State Plane Zone 4 Kuparuk 2T ~..AII data is in feet unless otherwise stated~ Directions and coordinates are relative to True North. ~lVertical depths are relative to Well. Northings and Eastings are relative to Well. Magnetic Declination at Surface is 26.993° (04-Feb-99) The Dogleg Severity is. in Degrees'per 100ft. Vertical Section is from Well and calculated along an Azimuth of 250.100° (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 4495.00ft., The Bottom Hole Displacement is 2879.56ft., in the Direction of 250.296° (True). Comments Measured· Station Coordinates Depth TVD Northings Eastings (ft) (ft) (ft) (ft) 0.00 0.00 0.00 N 0.00 E 4181.96 2974.28 889.93 S 2488.93 W 4495.00 3179.48 970.86 S 2710.96 W COmment Tie-on Survey TIE-ON SURVEY PROJECTED SURVEY 30 March, 1999- 10:31 -6- DrillQuest D F:t I I--I-- I I~1 G S E I:!~./I ~-- ~ S 04-Mar-99 AOGCC Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 2 KBE RIG SECOND HALF OF SURVEYS WITH ADJUSTED KBE Re: Distribution of Survey Data for Well 2%207 Dear Lori Taylor: Enclosed are two survey hard copies. Tie-on Survey: Window / Kickoff Survey: Projected Survey: 4,181.96' MD 'MD 4,495.00' MD (if applicable) Please call me at 273-3545 if you have any questions or concerns. Regards, William T. Allen Survey Manager Attachment(s) t' 4 R 0 9 999 5631 Silverado Way, Suite G · Anchorage, Alaska 99518 · (907) 273-3500 · Fax (907) 273-3535 A Halliburton Company MEMORANDUM TO: State of Alaska Alaska Oil and Gas Conse~tion Commission David Johnston, · DATE: December 12, 1998 Gheimlal~ THRU: Blair Wondzell, P. I. Supervisor FILE NO: abfkllfe.doc FROM: Chuck Scheve, ~ $ SUBJECT: Petroleum Inspector BOPE Test Doyon 19 KRU 2T-207 PTD # 98-23 Saturday December 12,1998: I traveled to Arco's KRU 2T Pad and witnessed the initial BOPE test Doyon Rig 19. As the attached AOGCC BOPE Test Report indicates there was 1 non-compliance item noted. The Top Drive unit has only one IBOP valve installed. A second valve is to be installed and tested prior to drilling a producing zone. This rig is currently drilling the surface holes and top setting the Tabasco formation. The somewhat extended test time was primarily due to problems with the test pump. The rig was clean and all equipment seemed to be in good working order. The location was well organized and all excess equipment was properly stored. Summary: I witnessed the BOPE test on Doyon Rig 19 drilling Arco's 2T-207 Well. Doyon 19, 12/12198, Test Time 6 hours, I failure Attachment: abfkllfe.xls X Unclassified STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION BOPE Test Report OPERATION: Drlg: X Workover: Drlg Contractor: Doyon Rig No. Operator: ARCO Well Name: 2T-207 Casing Size: g 5/8 Set @ 4,243 Test: Initial X Weekly Other DATE: 1~ PTD# 98-231 Rig Ph.# 263-3150 Rep.: Fred Herbert Rig Rep.' Tim Krupa Location: Sec. I T. 11N R. 8E Meridian 12/12/98 Umiat Test MISC. INSPECTIONS: Location Gen.' OK Housekeeping' OK (Gen) PTD On Location Yes Standing Order Posted Yes FLOOR SAFETY VALVES: Well Sign Yes Upper Kelly / IBOP Drl. Rig OK Lower Kelly / IBOP Hazard Sec. OK - Ball Type · Inside BOP Quan. Pressure P/F 250/3,000 P 250/3,000 P 250/3,ooo P BOP STACK: Annular Preventer Pipe Rams Lower Pipe Rams Blind Rams Choke Ln. Valves HCR Valves Kill Line Valves Check Valve Quan. Test Press. P/F I 250/3000 P 1 250/3,000 P I 250/3,000 P 1 250/3,000 P I 250/3,000 P 2 250/3,000 P I 250/3,000 P N/A N/A N/A CHOKE MANIFOLD: No. Valves 15 No. Flanges 3~ Manual Chokes Hydraulic Chokes Test Pressure P/F 250/5,000 P 250/5,000 Functioned Functioned P P P ACCUMULATOR SYSTEM: System Pressure 2750 I Pressure After Closure 1450 i MUD SYSTEM: Visual Alarm 200 psi Attained After Closure minutes 30 sec. Trip Tank OK OK System Pressure Attained 4 minutes 25 sec. Pit Level Indicators OK OK Blind Switch Covers: Master: Yes Remote: Yes Flow Indicator OK OK Nitgn. Btl's: 4 bottels at Meth Gas Detector OK OK · 2300 Psig. H2S Gas Detector OK OK ' Number of Failures: I ,Test Time: 6.0 Hours. Number of valves tested 23 Repair or Replacement of Failed Equipment will be made within days. Notify the Inspector and follow with Written or Faxed verification to :he AOGCC Commission Office at: Fax No. 276-7542 Inspector North Slope Pager No. 659-3607 or 3687 If your call is not returned by the inspector within 12 hours please contact the P. I. Supervisor at 279-1433 REMARKS: Only one IBOP installed on top drive.'Second valve to be installed before drilling prduction interval Distribution: orig-Well File c - Oper./Rig c - Database c - Trip Rpt File c - Inspector F1-021 L (Rev. 12/94) STATE WITNESS REQUIRED? YES X NO 24 HOUR NOTICE GIVEN YES X NO Waived By: Witnessed By: abfkllfe Chuck Scheve TONY KNOWLE$, GOVERNOR ALASKA OIL AND GAS CONSERVATION COMMISSION 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 Novcmbcr 13, 1998 Thomas W. McKav Drilling Tcam Lcader ARCO Alaska, Inc. P O Box 100360 Anchorage, AK 99510-0360 R¢~ Kuparuk River Unit 2T-207 ARCO Alaska. Inc. Permit No: 98-231 Sur Loc: 630'FSL, 556'FWL, Sec. 1, T11N, R8E. UM Btmholc Loc. 382'FNL, 2232'FEL, Sec. 11. T11N. R8E. UM Dcar Mr. McKav: Enclosed is the approved application for permit to drill the above referenced well. Thc permit to drill docs not exempt you from obtaining additional permits required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permitting determinations are made. Annular disposal has not been requcstcd as part of thc Permit to Drill application for Kuparuk River Unit Well No. 2T-207. Please note that any disposal of fluids generatcd from this drilling opcration which arc pumped down thc surface/production casing annulus of a ,,','ell approved for annular disposal on Drill Site 2T must comply with the requirements and limitations of 20 AAC 25.080. Approval of this permit to drill does not authorize disposal of drilling waste in a volume greater than 35.000 barrels through thc annular space ora single ,,','ell or to use that well for disposal purposes for a period longer than one ,,'car. Blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25 035. Sufficient notice (approximately 24 hours) must be giVen to allow a representative of the Commission to witness a test of BOPE installcd prior to drilling new hole. Notice may bc givcn by contacting thc Commissio_L~r>ctrolcum field inspector on the North Slope pager at 659-3607. David W. Johnst~-- .... ~ ~ Chairman ~ BY ORDER OF THE COMMISSION dltTEnclosurcs l)cpartment of Fish & Game, Habitat Section w/o encl. Depamnent of Enviromnental Conservation w/o cmcl. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION coM~-issION PERMIT TO DRILL 20 AAC 25.005 la. Type of Work Drill X Redrill / lb Type of Well Exploratory Stratigraphic Test Development Oil X Re-Entry Deepen/ Service Development Gas Single Zone X Multiple Zone 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool ARCO Alaska, Inc. RKB 41', Pad 70' feet Kuparuk River Field 3. Address 6. Property Designation Tabasco Oil Pool (proposed) P. O. Box 100360, Anchorage, AK 99510-0360 ADL 25569, ALK 2667~ 4. Location of well at surface 7. Unit or property Name 11. Type Bond (see 20 AAC 25.025) 630' FSL, 556' FWL, Sec. 1, T11N, R8E, UM Kuparuk River Unit Statewide At top of productive interval (@ TARGET ) 8. Well number Number 297' FNL, 2002' FEL, Sec. 11, T11 N, R8E, UM 2T-207 #U-630610 At total depth 9. Approximate spud date Amount 382' FNL, 2232' FEL, Sec. 11, T11 N, R8E, UM 11/16/98 $200,000 12. Distance to nearest I 13. Distance to nearest well 14. Number of acres in property 15. Proposed depth (ME) and TVD) propertylineI 2%31 4595' MD 297' @ Target feet 71.7' @ 388' feet 2560 3229' TVD feet 16. To be completed for deviated wells 17. Anticipated pressure (see 20 AAC 25.035(e)(2)) Kickoff depth 250' feet Maximum hole angle 52.66° Maximum surface 1965 psig At total depth (TVD) 2313 psig 18. Casing program Setting Depth size Specifications Top Bottom Quantity of cement Hole Casing Weight Grade Coupling Length MD TVD MD TVD (include stage data) 24" 16" 62.5# H-40 Weld 69' 41' 41' 110' 110' +_200 CF 12.25" 9.625" 40.0# L-80 BTC 4196' 41' 41' 4237' 3012' 571 Sx Arcticset I11 L & 688 Sx Class G & 60 sx AS I 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured feet Plugs (measured) true vertical feet Effective depth: measured feet Junk (measured) true vertical feet Casing Length Size Cemented Measure4Lde~¢~ ~ ~ %~'ue-Ve~tical depth Structural Conductor.--~, ~, ~, '~,* ~ Sudace ki~r?e!U%~id~ante 0 R I G I N A L "':0V"; Perforation depth: measured ~]9..~k8. 0il & ~as ~s. true vertical 20. Attachments Filing fee X Property plat ~, BOP Sketch X Diverter Sketch X Drilling program X Drilling fluid program X Time vs depth plot [~ Refraction analysis F~ Seabed report Fl 20AAC 25.050 requirements X 21. I hereby ce~i~t the foregoing is true and correct to the best of my knowledge ¢.~ / ~ Signed )~/'~¢ ¢.,~ y Title Drilling Team Leader Date Commission Use Only I APl number ~/~ [ Approval date f/~/¢.~ ~, ¢ ~) Isee cover letter for Permit N~r_ ¢'~ ~ 50- J{2~ ~, ~ Z'~ o~ -O t5 -- other requirements Conditions of approval Samples required r-~ Yes .~f No Mud Icg required r-~ Yes ~ No Hydrogen sulfidemeasures E~ Yes ~ No Directional surveyrequired ~' Yes E~ No Required working pressure for DOPE 2M E~ ("~M~E~ 5M r'~ 1OM FI 15M Other: ~i,'i~J~-~,i Signed By O~.vid W. J~hnston byorderof Approved by Commissioner the commission Date Form 10-401 Rev. 7-24-89 Submit in triplicate ARCO Alaska, Inc. Kuparuk Drillsite Development Post Office Box 100360 Anchorage, Alaska 99510 Telephone 907 265-6206 Michael Zanghi Supervisor November 4, 1998 Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 (907) 279-1433 Re: Application for Permit to Drill Tabasco 2T-207 Tabasco Producer, Kuparuk River Unit Dear Sirs: ARCO Alaska, Inc. hereby applies for a Permit to Drill an onshore production well to the prospective Tabasco interval from 2T Pad in the Kuparuk River Unit ("KRU"). The well is designed to penetrate and develop the production potential of the Tabasco sands in the vicinity of 2T pad. The well is designed as a producer using an open hole gravel pack completion technique for sand control purposes. The surface hole will be drilled and cased using Doyon Rig 19. After this rig moves off the well, Nordic Rig 3 will move onto location to drill out the production interval and run the completion. Completion plans call for running a 4-1/2" production tubing string with an ESP and Y-block assembly, 2-7/8" I-tube, and heat trace. Please find attached information as required by 20 AAC 25.005 (a) and (c) for your review. Pertinent information attached to this application includes the following: 1 ) Form 10-401 Application for Permit to Drill per 20 AAC 25.005 (a). 2) Fee of $100 payable to the State of Alaska per 20 AAC 25.005 (o) (1). 3) A directional plat showing the surface and bottomhole locations proposed for the well per 20 AAC 25.005 (c) (2). 4) Directional plots and proximity calculations in accordance with the requirements of 20 AAC 25.050. 5) Diagrams and descriptions of the BOP and diverter equipment to be used as required by 20 AAC 25.035 (a) (1) and (b). Note that due to the pressures expected in the Tabasco sands, ARCO proposes to test the 5000 psi BOP equipment to a maximum of 3000 psi, pending AC)GCC approval per this letter and APD. Please note that due to the large number of KRU wells which have penetrated the Tabasco sands in this area, ARCO has a clear understanding of the formation pressures to be encountered. As a result, no overpressured strata is expected in this area. There are also no shallow hazards expected at 2T-207, such as shallow gas. 6) A complete proposed casing and cementing program is attached as per 20 AAC 25.030. A wellbore schematic is also attached visually depicting the proposed well and completion design. ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany 7) The drilling fluid program, in addition to the requirements set forth in 20 AAC 25.033 are attached in this APD package. 8) A copy of the proposed drilling program is attached. 9) Also note that ARCO does not anticipate the presence of H2S in the formations to be encountered in this well. However, there will be H2S and combustible gas monitoring equipment functioning on the rig as is the standard operating procedure in the Kuparuk River Unit drilling operation. 10) Please note that because of the large volume of regional information available in this area, ARCO considers this well to be a development well, and as such, no mudlogging operations such as type log generation and sample catching are planned. Please note that the anticipated spud date for this well is November 23, 1998. If you have any questions or require further information, please contact Tom Brockway at (907) 263-4135 or Tom McKay at (907) 265-6890. Sincer_ely~ ..... ' Thomas A. Brockway Operations Drilling Engineer Attachments: CC: Tabasco 2T-207 Well File Tom McKay ATO-1060 Jack Walker ATO-1200 Steve Kranker ATO-1252 Lewis Ledlow ATO-1063 Drill, Case and Completion Plan for Tabasco 2T-207 (D) Producer General Procedure: 1. Excavate cellar, install cellar box, set and cement 16" conductor to +/- 110' RKB. Weld landing ring on conductor. 2. Move in / rig up Doyon Rig 19. Install diverter & function test same. 3. Spud and directionally drill 12-1/4" hole to 9-5/8" surface casing point (+/4237') according to directional plan. Run MWD / LWD logging tools in drill string as required for directional monitoring and formation data gathering. 4. Condition hole for casing, POOH. 5. Run and cement 9-5/8" 40.0# L-80 BTC casing to surface, displace cement with mud. Perform stage job and top job as required. NOTE: Stage (DV) tool to be installed +/- 200 ft TVD below the base of permafrost interval. 6. Nipple down diverter and install wellhead. Nipple up BOPE and test to 3000 psi. Record results. Pick up 8-1/2" bit and BHA. Trip in and drill out stage collar. Clean out to top of float collar. Shut in BOP's and pressure test casing to 3,000 psi for 30 minutes per AOGCC regulations. Record results. Freeze protect well. Install BPV. Nipple down B©P stack and nipple up production tree. Pull BPV. Install test plug. Pressure test production tree. Pull test plug. 10. Secure well. Release rig. 11. Move in / rig up Nordic Rig 3. Nipple up BOPE and test to 3000 psi. Test casing to 3000 psi. Record results. Drill out cement and 20' of new hole. Perform formation integrity test, taken to leak off if possible, maximum pressure allowed 16.0 ppg EMW. Drill 8-1/2" hole to well total depth (+/- 4595') according to directional plan, running LWD logging equipment as needed. Circulate and condition hole. POOH Run open hole wireline logs as needed. RIH with clean out BHA. Scrape casing. Displace well to completion brine. Pump caustic wash. Pump pickle job. Circulate brine. Pump acid pill across formation. Reverse out with brine. POOH Run in hole with 4" Gravel Pack screen assembly. Set gravel pack packer. Pressure test lines. Pump gravel pack sand and pack screens. Reverse out excess sand. Circulate well to non-freezing, clean completion brine. POOH Pick up Centrilift ESP motor, seal assembly, Y-block, and 2-7/8" tubing I-tube on 4-1/2" 12.6# L-80 BTCM production tubing. Run in well with ESP motor assembly with power cable and data gathering information wire attached to tubing. Attach Raychem heat trace cable to tubing at pre-determined depth to position bottom of heat trace below permafrost, and spaced out correctly to avoid surface splicing of heat trace cable. Position ESP at desired depth, set tubing hanger and run electrical penetrators through same. Make surface electrical connections as required. Pull landing joint. Install BPV. Nipple down BOP stack, and nipple up horizontal production tree. Pull BPV. Install test plug. Pressure test production tree. Pull test plug. Secure well. Freeze protect well. Make final conductivity check of ESP cable and instrumentation wire. Set BPV. Release rig and turn well over to production. . , 12. 13. 14. 15. 16. 17. 18. 19. 20. 21. 22. 23. 24. 25. 26. 27. 2T-207 (D) Page I TAB, 11/03/98, v.1 DRILLING FLUID PROGRAM, PRESSURE CALCULATIONS, & DRILLING AREA RISKS Well Tabasco 2T-207 (D) Drilling Fluid Properties: Density PV YP Viscosity Initial Gel 10 Minute Gel APl Filtrate pH % Solids Doyon Rig 19 Spud to 9-5/8" surface casing 8.5-9.6 16-26 25-50 150-250* 10-20 10-30 8-15 8-10 4-6% Nordic Rig 3 Drill out to TD 10.2 4-7 15-30 60-120 2-4 4-8 8-15 8.0-8.5 4-7% Drilling Fluid System: Doyon Rig 19 Triple Derrick Shale Shakers Centrifuge, Mud Cleaner Desander, Degasser Pit Level Indicator (Visual / Audio Alarm) Trip Tank Fluid Flow Sensor Fluid Agitators Flow Line Cleaner Nordic Rig 3 Tandem Geolograph/Swaco Shale Shakers Mud Cleaner, Degassers Pit Level Indicator (Visual / Audio Alarm) Trip Tank Fluid Flow Sensor Fluid Agitators *Spud mud should be adjusted to a FV between 200-250 sec/qt to drill gravel beds Notes: Drilling fluid practices will be in accordance with the appropriate regulations stated in 20 AAC 25.033. Maximum Anticipated Surface Pressure: Maximum anticipated surface pressure is calculated using an expected surface casing leak-off of 14.1 ppg EMW (0.73 psi/fi) and a gas gradient of 0.11 psi/ft. This shows that formation breakdown would occur at a surface pressure of 2221 psi. The leak off EMW was chosen based on an open hole FIT on 2T-202 taken to 14.1 ppg at 2829' -I-VD (0.73 psi/fi). Therefore, Arco Alaska, Inc. will test the BOP equipment to 3000 psi. MASP = (3168 fi)(0.73 - 0.11) - 1965 psi Based on offset well data, reservoir pressures in the Tabasco sands in the vicinity of 2T pad are expected to be 1500 psi (0.50 psi/fi). Assuming a 100 psi overbalance is required to safely drill and trip in this formation, then a required mud weight of '10,1 ppg can be predicted as the maximum mud weight needed to safely drill in this formation, assuming a TVD of 3042'. Well Proximity Risks: The nearest existing well to 2T-207 is 2T-31. As designed, the minimum distance between the two wells would be 71.7' at 388' MD. Drilling Area Risks: Risks in the 2T-207 drilling area are limited to lost circulation and potential borehole instability in the Tabasco formation. Lost circulation will be addressed with lost circulation material (LCM) and reduced circulating rates as needed. Based on previous DS 2T drilling results, 10.1 ppg mud should be adequate to control both the West Sak and Tabasco formation pressures without resulting in lost circulation. The 9-5/8" casing shoe will be tested to leak off or a maximum equivalent mud weight of 16.0 ppg upon drilling out of the surface casing. Annular Pumping Operations: Incidental fluids developed from drilling operations will be hauled to the nearest permitted disposal well or will be pumped down the surface/production casing annulus of an existing well on 2T Pad. (Note that cement rinseate will not be injected down the dedicated disposal well but will be recycled or held for an open annulus.) The open annulus will be left with a non-freezing fluid during any extended shut down (> 4 hr) ~n pumping operations. The 2T-207 4-1/2" x 9-5/8" tubing annulus will be filled with kill weight brine and diesel after setting the 4-1/2" production tubing string and prior to the drilling rig moving off of the well. Tabasco Producer 2T-207 (D Producer Completion 16" Conductor @ 80' .I Weatherford Gemoco 9-5/8" DV Stage Collar Stnd. Grade BTC Threads (+/- 2060' MD / 1691' TVD) 4-1/2" Nova Clamps AII Depths RKB Nordic 3~ 3-1/2" Nova Clamps ESP power cable splice above Y-block B. 1 jt, 3-1/2" 9.3# L-80 EUE8RD tubing A. Centrifllt Series 562 ESP assembly w/power cable, 5.62" OD Super-Bands to top of Y-block +/- 3' intervals 9-5/8" Surface Casing 40.0# L-80 BTCM (+/- 4237' MD / 3012' TVD) N. FMC Tabasco Producer horizontal wellhead/hanger system w/125 amp penetrators M. Heat Trace, Raychem, 3000' L. 4-1/2" 12.6# L-80 BTCM tubing to surface K. XO sub, L-80 4-1/2" BTCM box x 3-1/2" BTCM Special Clearance pin J. 3 jts, 3-1/2" 9.3# L-80 BTCM tubing 3.865" Special Clearance couplings I. Baker Dual 'Sentry' gauges, 3-1/2", w/I-wire, Clamp-on style (suction) and Sidemount kit (discharge) H. 3-1/2" x 10' Landing pup, 9.3#, L-80, BTCM 3.865" Special Clearance couplings G. 3-1/2" Trico Y-Block w/couplings, 3-1/2" EUE8RD pin on motor leg, 2-7/8" EUE8RD pin on I-tube leg, 3-1/2" BTCM Special Clearance box on uphole end F. 2-7/8" Trico 'X' landing nipple w/2.312" profile, EUE8RD box x Hydrill 511pin E. 3-11/16" x 2' L-80 'Swivel Sub', 2.875" iD Hydrill 511 D. 3 jts, 2-7/8" 6.5# L-80 Hydrill 511 flush jt tubing (d** 0.184" planned clearance as per Centrilift ~ rift) - (ESP OD) - (I tube OD) = 8.679" - 5.62" - 2.875~) C. 2-7/8" Wireline Entry Guide, Hydrill 511 Gravel Pack Assembly (run on ddllpipe) -- Baker SC-1 Gravel Pack packer, 9-5/8" -- 4 jts, Baker 4" blank tubing, Hunting Seal Lock threads -- Baker ceramic flapper valve -- Baker 4" Gravel Pack screen, Hunting Seal Lock 20 gauge (0.02") screen 12-20 US mesh gravel pack sand TAB, 10/28/98, vl t _ : .gL sUo!leJad0 ooseqel ;!un Je^!~! .)lnJednN 6~ B!~! u'~-~oo-- o!leuJeqos Jap'- ....... ',!O ,,g~ 13-5/8" 5 )0 psi BOP Stack--D~,on Rig 19 Kuparu. k River Unit Tabasco Operat,ons - Producer Wells 4' B IJ~ · ,Y O 1/4" o' lO" BoP STACK WELL.Hr. AD . i BOP STACK ELEVATION 13 5/8'. 5000 PS1 HYDRIL ANNULAR BOP, ETUD.DED TOPig:'LANGED BOTTOM · . . SING't_E: 13' 5/B", 5(300 PSI, 10' t4PL OPERATOR~, HYDEIL PIPE RAM - n.~cE ~Tou/sm~(3~ ~oP" . Sl~ 13 5/B'. ~00 PSI, 14' UPL ~P~TO~, BUND SH~ ~ 3 1/8' ~ ~ HCE V~ . 2' m~ UNE -. 3 i/8' ~ ~ ~ v~ SIN~ 13 5/8;, 5000 Psi, lO"U~ OP~ToR$'" ~RIL PiPE ~ ~ ~ HUB x 11" 50 .3 psi BOP Stack-- No; ..... ,ic Rig 3 Kuparuk River Unit Tabasco Operations - Producer Wells Accumulator Capacity Test 1. Check and fill accumulator reservoir to proper level with hydraulic fluid. 2. Assure that accumulator pressure is 3000 psi with 1500 psi downstream of the regulator. 3. Observe time, then close all units simultaneously and record the time and pressure remaining after all units are closed with the charging pump off. 4. Record on the IADC report. The acceptable lower limit is 45 seconds closing time and 1200 psi remaining pressure. BOP Stack Test 1. Fill BOP stack and manifold with water. 2. Check that all hold-down screws are fully retracted. Predetermine depth that test plug will seat and seat in wellhead. Run in lock-down screws in head. 3. Close annular preventer, chokes, and bypass valves on the manifold. All others open. 4. Test all components to 250 psi and hold for 3 minutes. Increase pressure to 3000 psi and hold for 3 minutes. Bleed back to zero psi. 5. Open annular preventer and manual kill and choke line valves. 6. Close top pipe rams and HCR valves on kill and choke lines 7. Test to 250 psi and 3000 psi as in step 4. Continue testing all valves, lines, and chokes with a 250 psi Iow and 3000 psi high. Test as in step 4. Do not pressure test any choke that is not a full closing positive seal choke. 8. Open top pipe rams and close bottom pipe rams. Test bottom rams to 250 psi and 3000 psi for 3 minutes. 9. Open pipe rams. Back off running joint and pull out of hole. Close blind rams and test to 250 Iow and 3000 psi high for 3 minutes. Bleed to zero psi. 10. Open blind rams and recover test plug. Make sure manifold and lines are full of arctic diesel and all valves are set in the drilling position. 11. Test standpipe valves to 3000 psi for 3 minutes. 12. Test kelly cocks and inside BOP to 3000 psi with BOP test pump. 13. Record test information on blowout preventer test form. Sign and send to drilling supervisor. 14. Perform BOPE test once per week and functionally operate BOPE daily. 1. 16" Starting Head 2. 11" 5000 psi Horizontal Tubing Head 3. 11" 5000 psi Double Flange Adapter/Spacer Spool 4. 11" 5000 psi Hydril Type V Single Pipe Rams, 3-1/8" 5000 psi Side Outlets w/ manual locks 5. 11" 5000 psi Drilling Spool with Choke and Kill Lines, 2 Choke valves - one 3" 5000 psi Hydraulic gate and one 3" 5000 psi Manual gate, 2 Kill valves - each are 3" 5000 psi gate 6. 11" 5000 psi Hydril Double Ram with Pipe Rams on Top and Blind Rams on Bottom, 3-1/8" Side Outlets w/Manual Locks 7. 11" 5000 psi Hydril Annular Preventer TAB, 09/30/98, v.1 19/16/981 MRT JM PE ...... ;SB# K98075ACS .... ,- 62.5' . 3o ~CINI~ MAP ~'= 2 MILES e 29 e 28 e 27 SEE SHEET 2 FOR NOTES AND e 26 LOCATION INFORMA~ON e 202 e 23 e 22 e 3 e 5 e 6 I I I e I0 e 12 e t3 3a e (NO SCALE) e 14 2 1 · 15 ~ 369 11 112 ' e 18 DRILL SITE e 2o 2-T · 2~ e 37 LEGEND o ~w co~o~c~o~ ~oc,~o~s ~ LOUNSBURY , [x~s~ co~auc~o~s ~~[ ~ ~ssoc~a~s, ~c. ~kk CO~ClO~S 207-2~0,215,2~8 · 220 Subsidiory of ~tlontic ~ichfield Compony LK622012 9/16/98 CEA-D2~-6220D12 OOl OF 2 1 119/16/981 MRT JM PEk =1 ' S~ ~ K98075ACS I I I .... T II 2. COORDINATES SHO~ ARE A.S.P. ZONE 4, N.A.O. 27. X S 3. ELEVATIONS SHO~ ARE B.P.M.S.L. 4. WELLS ARE LOCATED ~THIN PROTRAC~D SECTION 1, 5. DATE OF SURLY: 9/13/98, FIELD BK. L98-71 pg. 14-23. 6. DRILL SI~ 2-T GRID NOR~ IS ROTATED 179' 59' 40" ~/ I ~ST FROM A.S.P. ZONE 4 GRID NOR~. 7. SEE REFERENCE DRAWINGS: CEA-D2TX-866, FOR CONDUCTOR ~ = 2-17 LOCATIONS, CEA-D2~-6220D7 FOR CONDUCTOR 18-23, I ~ClNI~ MAP 2 26-32, 36-38 ~ TABASCO LOCA~ONS, AND CEA-D2TX-6220D9I ....... FOR CONDUCTOR 202. LOCA~D IN SEC~ON 1, T 11 N, R 8 E, U,M, : ~ ~ SEC. ~ SEC. ~LL LINE LINE O.G. PAD NO. Y X LATITUDE LONGITUDE O/S O/S ELEV. ELEV. ' ~ F.S.L. F.W.L. I 207 L 5,970,610.10 498,945.02 70'19'51.368- ~ 150~0'30.805- 630' 556' 75.2' 80.4' 208 5,970,622.69 . 4.98,944:87 7019'51.492- 150-00'30.810- I 642' 556' 75.2' 80.4' 209 5,970,635.10 ~ 498,944.90 70'19'51.614- 150-00'30.809- 655' ~ 556' 74.9' 80.4' I 210 ~,970,647.69 4.98,944.73 ~ 70'19'51.738" 1~p'00'30.814" 667' 556' 74.7' ~ 80.4' I I .0..' 220 5,970,772.57 498,944.90 , 70~9'52.966" ~ 150'00'30.810" 792' 556' 74.1' ~ 80.4' i~* 4~ ~2~*'*. LICENSED TO P~ACTICE LAND SURVEYING IN THE STATE OF I ..... " ........... '"~~ 'g~'~ ..... S. ALASKA AND THaT THIS PLAT R~P~ESENTS ~ SU. VEY .~ DONE BY ME OR UNDER MY DIRECT SUPERVISION AND. AREA: 2T MODULE: X~' UNIT: D2 ~ DElL SI~ 2-m ARCO Alaska, Inc. ~LL CONDUCTORS 207-210,215,218 ~ 220 Subsidiery of Atlontic Richfield Compony AS-BUILT LOCA~ON , SEC. SEC. WELL LINE LINE O.G. PAD NO. Y X LATITUDE LONGITUDE O/S O/S ELEV. ELEV. F.S.L. F.W.L. 207 5,970,610.10 498,945.02 70'19'51.368" 150'00'30.805" 630' 556' 75.2' 80.4-' 208 5,970,622.69 498,944:87 70'19'51.492" 150'00'30.810" 642' 556' 75.2' 80.4' 209 5,970,635.10 498,944.90 70'19'51.614" 150°00'30.809" 655' 556' 74.9' 80.4' 210 .5,970,647.69 498,94.4,73 70'19'51.738" 15,,0'00'30.814." 667' 556' 74.7' 80.4? 215 5,970,709.72 49.8,944_.99 70'19'52.348" 150'00'30. S07" 729' 556' 74.2' 80.4' 218 5,970,747.74. 4.98,94.4.97 70'19'52.722" 150'00'30.807" 768' 556' 74.1' 80.4' 220 5,970,772.57 498,944.90 70'19'52.966" 150'00'30.810" 792' 556' 74.1' 80.4' Cr:ated by ,}ones For: T Brockway1 Dote plotted : 31-Aug-98 ~ Plot Reference is 207 Version ~5. ~ Caord;natcs ore in feet reference slot 1~207. J lc'dC VerUcal Depths ~[at.RKB {]Nordic ImO,~ 25O 5OO 750 lOOO] 1250- t500- 1750 2000 2250 250O 2750 3000 5250 Estimo[ed RKB 111' A CO Alaska, Inc. Structure : Pod 2T Well : 207 Field : Kuparuk River Unit Loca'tion : North Slope, Alasko 250.10 AZIMUTH 2721' (TO TARGET) ***Plsne of Proposol*** <- West (feet) .oP ~0:250 TMO=250 2800 2600 2400 2200 2000 1800 1600 1400 1200 1000 800 600 400 200 0 4.00 BEGIN TURN TO TARGET TVD=375 TMD-375 DEP=5 ~ i ~ i i ~ ~ ~ i i ~ i i ~ ~ ~ i i ~ ~ i , ~ i ~ ~ ~ ~ ~ i l~?0 Az 9.82 Begin Turn~ 13.77 [ TARGET LOCATION: 17.74 I 297' FNL, 2002' FEL l SEC. 11, T11N, RSE 21.72 BLS: 4.00 deg per 100 ft 25.71 ------'-~~-- I 382' [-NL, 2232 FEL / "~P ..... 1 / SEC. 11, TllN, RSE J ...... 33~68 .... SOUTH 926 ~ 41.68 WEST 2558 / mx. ~oo_' ' ~ 45.67 , /~ -ueo~ '~v~e ~ [ SURFACE LOCATION: ~. % ~ % I 630' FSL, 556' FWL K-13 ~0=2105 TMD=2742 DEP=1493 o~ ~d r T/ WEST SAK SNDS ~D=2234 TMD=2955 DEP=1662 'coo AVERAGE ANGLE 66 DEG B/ WEST SAK SNDS TVD=2666 TMD=5667 DEP=2228 9 5/8" CSG PT TVO=3012 TMD=4.237 DEP=2681 TARGET - T/ TABASCO SND 'rVD=304g TMD=4287 DEP=P~Tgl B/ TABASCO SND 'TVD=3168 TMD=4495 DEP=2886 1'I) TYD=3229 TMD=4595 DEP=~965 0 250 500 750 1000 1250 1500 1750 2000 2250 2500 2750 3000 Vertical Section (feet) -> Azir-nu~h 250.10 with reference 0.00 N, 0.00 E from slot //207 200 400 600 8OO lOOO 1200 Creoted by jones For: m Brockway Dote plotted : 31-Au ~-98 Plot Reference is 207 Versla,, #5. Coordinotes ore in feet reference slot .~.07. ARCO A aska Structure : Pad 2T Well : 207 Field : Kuparuk River Unit Location : North Slope, Alaska West (feet) 380 560 540 320 300 280 260 240 220 20C 180 160 14 120 100 80 60 40 20 0 20 40 60 100 I I I I I I I I I I I I I I ] I t I I I I I I I 8O 6O 1600 40 1200 1500 1500 4O0 90( 1400 1000.. ........... "" 1 1500 200C 1 i i i'~a.o,, soo 9o~X ",,~ 5oo.-, "'-,.... ',,;1 3o 'e~(~ ' 200 '"'-,, 700 600 1200 ,1500 .. "-... 600 1100 1100 1800 140 1000 1100 1200 1100 800 4000 70~ 8OO 2100 700 9O( IOO0 "3 40 0 I 60 1600 80 100 t200.....- 120 140 1700 160 · 380 360 :340 320 500 280 260 240 220 200 180 160 140 120 1 O0 80 60 4-0 20 0 20 ,tO 60 <- West (fee~) 1 O0 60 0 V 100 120 140 160 Creoted by jones For: T Brockway Dote plot{ed : 31-Aug-g8 Plot Reference is 207 Version ~5. Ceordlnetes ere in f~[ reference slot ~207, Truc Vc,;col Ocp[hs O~ Est. RKa (Nordic ARCO A]laska Inc. Structure : Pad 2T Well : 207 Field : Kuparuk River Unit Location : North Slope, Alaska <- Wed (feet) 0 100 200 300 4-00 500 600 700 I v 800 2700 2600 2500 2400 2300 2200 21 O0 2000 1900 1800 1700 1600 1500 1400 1300 1200 11 O0 1000 900 800 700 600 500 400 I I I I J I I I I I I I I I I I ~ T I I I I I I I I I I I I I I I I I I I I I I I I I I I - 1900 170~ 1500 ~ 2100 ~" 200 300 4-00 ~o~ ......... o~ ...... ~ ~oo~?~.~ Is°° ~oo ........ :~oo_.q~ 2~ oo~._~,-~1_ .......... 250~ 23~ I600 ........ ~~ ~soo ~ ~ ~ 700 2500 31 O0 1700~ ...-""" ,,~ ~~'~700 1 go0~ v ....... ~oo ~oo~ ~~~ ~oo v ~ ~7~ ~ ~~~ ~ ~70~ ~00 390~ ~/- ~~ ~/' 41 O~00- ....... ~ .......... ~~-~ 3300 ~ ,2~ ~-----~~ 1200 1300 , , , r ~ -~T-' ~ i i' --~' ] ~-~ i ~---r i i i 1 i~ ~' ~ ] i ---T-~----[--~ i -~----~---~--~ i ~ i i--~.-- ~ ~ ~ 1 ~00 700 2600 2500 2400 2300 2200 2100 2000 1900 1800 1700 1600 1500 1400 1300 1200 1100 1000 900 800 700 600 500 4.00 <- Wesf (feel) 1000 ARCO Alaska, Inc. Pad 2T 207 slot #207 Kuparuk River Unit North Slope, Alaska SUMMARY CLEARANCE REPORT Baker Hughes INTEQ Your ref : 207 Version #5 Our ref : prop3049 License : Date printed : 31-Aug-98 Date created : 14-Jul-98 Last revised : 28-Aug-98 Field is centred on nT0 16 18.576,w150 5 56.536 Structure is centred on nT0 19 45.172,w150 0 47.054 Slot location is nT0 19 51.363,w150 0 30.801 Slot Grid coordinates are N 5970609.573, E 498945.186 Slot local coordinates are 629.50 N 556.00 E Projection ty~e: alaska - Zone 4, Spheroid: Clarke - 1866 Reference North is True North Object wellpath PMSS <893 - 12977'>,,23,Pad 2T PMSS <469-10632'>,,18,Pad 2T PGMS <0-7897'>,,3,Pad 2T PMSS <O-9298'>,,27,Pad 2T PMSS <O-4175'>,,201,Pad 2T PMSS <918 - 10193'>,,22,Pad 2T PMSS <741-15471'>,,36,Pad 2T PMSS <0 - 9210'>,,26,Pad 2T PMSS <O-12821'>,,21,Pad 2T PMSS <921-10235'>,,20,Pad 2T PMSS <918' - 10890'>,,28,Pad 2T PMSS <650 - 11080'>,,37,Pad 2T PGMS <0-8262'>,,14,Pad 2T PGMS <0-7625'>,,15,Pad 2T PMSS <1604-3625'>,,16,Pad 2T P~MS <0-8947'>,,16B,Pad 2T PMSS <5917-7957'>,,16A,Pad 2T PGMS <0-7650'>,,8,Pad 2T PGMS <0-8250'>,,10,Pad 2T PMSS <380 - 11400'>,,31,Pad 2T PMSS <0-9845'>,,19,Pad 2T PMSS <O-10570'>,,29,Pad 2T PGMS <0-8890'>,,2A, Pad 2T PMSS <1287-1725'>,,2,Pad 2T PMSS <4757-6800'>,,12A,Pad 2T P~MS <0-6725'>,,12B,Pad 2T PMSS <3115 - 3645'>,,12,Pad 2T P~MS <O-6789'>,,11,Pad 2T Closest approach with 3-D Minimum Distance method Last revised Distance M.D. Diverging from M.D. 25-Aug-98 191.9 775.0 775.0 1-Apr-98 305.9 4160.0 4160.0 26-Aug-98 248.0 725.0 725.0 23-Jan-98 134.8 600.0 600.0 26-Aug-98 304.5 1600.0 1600.0 23-Jan-98 187.8 950.0 950.0 23-Jan-98 591.3 1400.0 3140.0 23-Jan-98 151.9 550.0 550.0 23-Jan-98 712.4 200.0 2240.0 23-Jan-98 610.3 1100.0 1100.0 23-Jan-98 118.9 575.0 575.0 23-Jan-98 706.6 825.0 825.0 23-Jan-98 554.2 950.0 950.0 23-Jan-98 588.5 850.0 850.0 23-Jan-98 627.5 0.0 0.0 23-Jan-98 627.5 0.0 0.0 23-Jan-98 627.5 0.0 0.0 23-Jan-98 366.9 825.0 825.0 23-Jan-98 454.7 950.0 950.0 23-Jan-98 71.7 387.5 387.5 23-Jan-98 304.5 4595.0 4595.0 23-Jan-98 107.5 100.0 100.0 26-Aug-98 145.2 1050.0 1050.0 26-Aug-98 145.2 1050.0 1050.0 23-Jan-98 502.9 975.0 975.0 23-Jan-98 502.9 975.0 975.0 23-Jan-98 502.9 975.0 975.0 23-Jan-98 489.0 900.0 900.0 PG'MS <O-?868'>,,13,P~-~2T PG~S <0-8445'>,,1?,Pad 2T PGMS <O-8160~>,,4,Pad 2T PGMS <O-7670~>,,5,Pad 2T PGMS <O-8208'~,,6,Pad 2T PGMS <0-6975'>,,?,Pad 2T PG~S <O-6370w~,,9,Pad 2T MSS <4046-4427'>,,202,Pad 2T PMSS <12144-13360~>,,38A,Pad 2T PMSS <4627 - 10686~>,,30A,Pad 2T PMSS <O-4749~>,,30,Pad 2T PMSS <5497-13787~>,,32B,Pad 2T PMSS <O-5924w>,,32,Pad 2T PMSS <4850 - 5918~>,,32A,Pad 2T 23-Jan-98 23- Jan- 98 23-Jan-98 23-Jan-98 23-Jan-98 23-Jan-98 23-Jan-98 26-Aug-98 23-Jan- 98 16 -Jul- 98 16 -Jul- 98 24-Feb- 98 24-Feb-98 24-Feb-98 533.6 652.4 259.8 294.0 299.2 344.5 391.8 96.3 371.4 80.4 80.4 62.5 62.5 62.5 100.0 1050.0 750.0 825.0 ??5.0 850.0 1000.0 3580.0 600.0 600.0 0.0 0.0 0.0 975.0 100.0 1050.0 750.0 825.0 ??5.0 850.0 1000.0 3580.0 600.0 600.0 0.0 0.0 0.0 ARCO Alaska, Inc. Structure : Fad 2T Well : 207 Field : Kuparuk River Unit Location : North Slope, Alaska WELL PROFILE DATA ..... Pc~n( ..... MO Inc O[r TVO North East T~e an 0.00 0.00 0.00 0.00 0.00 0.00 End al' Turn ' 250.00 o.oa 270.00 250.00 0.00 o.oo KCP 375.00 5.00 270.00 374.84 0 O0 -5.45 End of Build/Turn 1574.§7 52,66 249,65 13',b,~J5 - I ,'6 30 --536.36 Target 2T-0 Rvsd 27-Ju 4287.2.] 52.66 249.65 .]04~.00 -926.21 -2558.24 End of Hcld 4494-.96 52.66 249,65 3168.00-98;~.65--2715.10 JT.D. & End of Hold 4594.96 52.66 249.65 5228.65--1011.50 --2787.64 32O 33O 34O 35O 310 V. SectGe§/100 O.O0 0.00 O.OO 0.00 5.13 4.00 564.34 4,00 2720.750.01 2885.91O.CO 2965.41O.OOJ TRUE ~NORTH ; ~ ," 10 Icreoted by jones For: T I/rockwayj Oote p[oU~ed : 28-Aug-98 Plot Reference is 207 Version ~5. 3OO I00 290 280 270 ~0 go 26O 100 25O 110 2¢0 120 230 220 210 2OO 190 Normal Plane Travelling Cylinder - Feet Al! depths shown are Measured depths on Reference Well WELL PERMIT CttECKLIST ADMINISTRATION __~l~t I)A'I E .-. ENGINEERING INI'I Cl..ASS ~ E~J I- b lb 1 f'e~nfil fee atlached .................... 2. lease ~umber appropliate ............... 3 Uniq~le well name and number ......... 4 Well Ioc:aled in a defined pool ............ 5 W(fll located i)~ope[ distance Iion~ (hilling unit bO~liM~uy 6 W~ll located ploper distance flora other wells . . . 7 Stdlicienl acreage available in drilling t,~il . . 8 If deviated, is wellbore plat i~mluded .... 9 Operator only affected pady ............... 10. Operator has appropriate bond in force ............. 11. Permit can be issued wilhout consewation order ........ 12. Permit can be issued without administrative approval ...... i 3. Can permit be approved before 15-day wait ........... 14 Co~Muclor string provided ................. 15 Surlace casing protects all known USDWs ......... 16 (:MI vol adequale to circulate on conductor & surf csg ..... 17 (:M I vol adequale to tie-in long siring to stuf csg ..... 18 CM 1 will cover all known productive horizons .......... 19. Casing designs adequate for C, T, B & permafrost ....... 20. Adequate tankage or reserve pit ................. 21. It a re.drill, has a 10-403 for abandonment been approved. 22. Adequate wellbore separation proposed ............. 23. If diverter required, does it meet regulations .......... 24. Drilling fluid program schemalic & equip list adequale .... 25. BOPEs. do Ihey meet regulation ................ L)AI E .... j.t. t o ON/C)I:..F SHORE lb ~ N N N N Y N Y N Y N Y N Y N Y N 26. BOPE press rating appropriate; test to _~j::~..~):~)_ ....... psig. 27. Choke manifold complies w/APl RP-53 (May 84) ........ 28. Work will occur without operation shutdown ........... 29. Is p~'esence of H2S gas probable ................. GEOLOGY 30. Pemfit can be issued w/o hydrogen sulfide meas~ 31. Data presented on potential over~ ...... 32. Seismic analysis of s~ones ..... '. ....... 33 Seat~v~-shore) ........... I)AII. 34 (~% re, ports .... ....... o,,y] ' ANNULAR DISPOSAL 35. WJlh proper cementing records, this plan (A) will contain waste in a suitable receiving zone; ....... Al:"l)l.t I)AI f': (B) will ~rot contaminate freshwaler; or cat,se drilling waste. lo st,face; (C) will ~lol impair mechanical integrity ol tl~e well used for disl)osal; (I)) will i~ol danmge prodtmil~fl formation ol i~pair lecove~y flora a ....... ~) will nol circumvent 20 AAC 25.252 or 20 AAC 25.412. M ,':lu,ldml l,,v ,Ill ( \liF,ffflu ,,\/'vrll(h;ul\rh,lrh¢, I,', Ih, I ENGINEERING: U I C/_A__!~ L!.l_a.._r COMMISSIQ..N.: Comments/Instructions' JDH -"""-~.--~- ............................ RNC ................... ~ ~ ~~'~.. ,~,--~-~ ,~"~"~', ~~ ~.."l,..~L""~,.,..,_. 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. Sperry-Sun Drilling Services LIS Scan Utility Fri Apr 06 09:34:34 2001 Reel Header Service name ............. LISTPE Date ..................... 01/04/06 Origin ................... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Previous Reel Name ....... UNKNOWN Comments ................. STS LIS Writing Library. Scientific Technical Services Tape Header Service name ............. LISTPE Date ..................... 01/04/06 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Previous Tape Name ....... UNKNOWN Comments ................. STS LIS Writing Library. Scientific Technical Services Physical EOF Comment Record TAPE HEADER TOBASCO MWD/MAD LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: # SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD MWD RUN 1 AK-MW-90030 J. MARTIN D. LUTRICK 2T-207 501032027800 ARCO ALASKA, INC SPERRY-SUN DRILLING SERVICES 06-APR-01 MWD RUN 2 AK-MW-90030 M. HALL D. WESTER 1 lin 008 63O 556 110.90 110.90 80.40 OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 1ST STRING 2ND STRING 24.000 16.000 117.0 3RD STRING 12.250 9.625 4243.0 PRODUCTION STRING 8.500 4495.0 REMARKS: 1. ALL DEPTHS ARE MEASURED DEPTHS (MD) UNLESS OTHERWISE NOTED. 2. MWD RUN ! IS DIRECTIONAL, DUAL GAMMA RAY (DGR) UTILIZING GEIGER-MUELLER TUBE DETECTORS, AND ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR4). THIS HOLE SECTION WAS DRILLED BY RIG DOYON 19, WITH KBE 117.50 FT AMSL. 3. RUN 2 IS DIRECTIONAL, DUAL GAMMA RAY (DGR) UTILIZING GEIGER- MUELLER TUBE DETECTORS, EWR4, AND STABILIZED LITHO-DENSITY (SLD). THIS HOLE SECTION WAS DRILLED WITH RIG NORDIC 3 WITH KBE 110.95 FT 'AMSL. 4. ALL RUN 1 DATA IS CORRECTED UPWARD 6.5 FT AND MERGED WITH RUN 2 DATA. DEPTH SHIFTING OF MWD DATA IS WAIVED AS PER THE E MSIL FROM D. SCHWARTZ OF ARCO ALASKA, INC. ON 12/30/98. MWD DATA IS PDC. 5. MWD RUNS 1 & 2 REPRESENT WELL 2T-207, WITH API%: 50-103-20278-00. THIS WELL REACHED A TOTAL DEPTH (TD) OF 4495'MD, 3180'TVD. SROP = SMOOTHED RATE OF PENETRATION WHILE DRILLING. SGRC = SMOOTHED GAMMA RAY COMBINED. SEXP = SMOOTHED PHASE SHIFT DERIVED RESISTIVITY (EXTRA SHALLOW SPACING). SESP = SMOOTHED PHASE SHIFT DERIVED RESISTIVITY (SHALLOW SPACING). SEMP = SMOOTHED PHASE SHIFT DERIVED RESISTIVITY (MEDIUM SPACING). SEDP = SMOOTHED PHASE SHIFT DERIVED RESISTIVITY (DEEP SPACING). SFXE = SMOOTHED FORMATION EXPOSURE. SBD2 = SMOOTHED BULK DENSITY- COMPENSATED (LOW COUNT BIN) . SCO2 = SMOOTHED STANDOFF CORRECTION (LOW COUNT BIN). SNP2 = SMOOTHED NEAR DETECTOR PHOTOELECTRIC ABSORPTION FACTOR {LOW COUNT BIN). ENVIRONMENTAL PARAMETERS USED IN DENSITY LOG PROCESSING: FLUID DENSITY: 1.0 G/CC MATRIX DENSITY: 2.65 G/CC $ File Header Service name ............. STSLIB.00! Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 01/04/06 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.000 Comment Record FILE HEADER FILE NUMBER: 1 EDITED MERGED MWD Depth shifted and clipped curves; all bit runs merged. DEPTH INCREMENT: .5000 FILE SUMMARY PBU TOOL CODE START DEPTH GR 53 5 FET 100 0 RPD 100 0 RPM 100 0 RPS 100 0 STOP DEPTH 4486 0 4466 5 4466 5 4466 5 4466 5 4466 5 4496 0 4475 5 4475 5 4475 5 RPX 100 ROP 101 DRHO 4238 RHOB 4238 PEF 4426 $ BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) BASELINE DEPTH $ MERGED DATA SOURCE PBU TOOL CODE MWD MWD $ # REMARKS: MERGED MAIN PASS. $ EQUIVALENT UNSHIFTED DEPTH BIT RUN NO MERGE TOP MERGE BASE 1 100.0 4241.0 2 4241.0 4495.0 Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .lin Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 PEF MWD BARN 4 1 68 4 2 DRHO MWD G/CM 4 1 68 8 3 RHOB MWD G/CH 4 1 68 12 4 RPD MWD OHMM 4 1 68 16 5 RPM MWD OHMH 4 1 68 20 6 RPS MWD OHMM 4 1 68 24 7 RPX MWD OHMM 4 1 68 28 8 FET MWD HOUR 4 1 68 32 9 GR MWD API 4 1 68 36 10 ROP MWD FT/H 4 1 68 40 11 Name Min Max Mean DEPT 53.5 4496 2274.75 PEF 2.2 16.77 3.97304 DRHO -0.01 0.42 0.106954 RHOB 1.95 2.57 2.20811 RPD 0.0673 2000 192.916 RPM 0.0698 2000 93.7371 RPS 0.1423 2000 50.8616 RPX 0.15 2000 29.2451 FET 0.0642 10.2991 0.652546 GR 9.6618 149.09 63.1444 ROP 3 2191.99 186.184 Nsam 8886 5OO 476 476 8673 8673 8673 8673 8673 878O 8790 First Reading 53.5 4226 4238 4238 100 100 100 100 100 53.5 101.5 Last Reading 4496 4475 5 4475 5 4475 5 4466 5 4466 5 4466 5 4466 5 4466 5 4486 4496 First Reading For Entire File .......... 53.5 Last Reading For Entire File ........... 4496 File Trailer Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 01/04/06 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.002 Physical EOF File Header Service name ............. STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 01/04/06 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.001 Comment Record FILE HEADER FILE NUMBER: 2 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: DEPTH INCREMENT: FILE SUMMARY VENDOR TOOL CODE GR FET RPD RPM RPS RPX ROP $ LOG HEADER DATA 1 .5000 START DEPTH 53 5 100 0 100 0 100 0 100 0 100 0 101 5 STOP DEPTH 4193 0 4202 0 4202 0 4202 0 4202 0 4202 0 4240 5 DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT) : TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT) : BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY EWR4 ELECTROMAG. RESiS. 4 $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT) : BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) : MUD PH: MUD CHLORIDES (PPH) : FLUID LOSS (C3) : RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF {IN): EWR FREQUENCY (HZ): REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .lin Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 09-DEC-98 ISC 5.07 ISC 5.07 MEMORY 4241.0 100.0 4241.0 .0 57.3 TOOL NUMBER Pl158CRG8 Pl158CRG8 12.250 12.3 SPUO 9.50 187.0 9.6 250 5.8 2.400 1.460 2.200 2.800 39.5 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD 1 FT/H 4 1 68 GR MWD 1 API 4 1 68 RPX MWD 1 OHMM 4 1 68 RPS MWD 1 OHMM 4 1 68 RPM MWD 1 OHMM 4 1 68 RPD MWD 1 OHMM 4 1 68 FET MWD 1 HOUR 4 1 68 8 12 16 20 24 28 Name Min Max Mean Nsam DEPT 53.5 4240.5 2147 8375 ROP 3.3921 2191.99 193.277 8279 GR 9.6618 142.775 61.2235 8280 RPX 0.4027 2000 28.6519 8205 RPS 0.1423 2000 38.8243 8205 RPM 0.0698 2000 77.4622 8205 RPD 0.0673 2000 179.328 8205 FET 0.0642 10.2991 0.606425 8205 First Reading 53.5 101.5 53.5 100 100 100 100 100 Last Reading 4240.5 4240.5 4193 4202 4202 4202 4202 4202 First Reading For Entire File .......... 53.5 Last Reading For Entire File ........... 4240.5 File Trailer Service name ............. STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 01/04/06 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.003 Physical EOF File Header Service name ............. STSLIB.003 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 01/04/06 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.002 Comment Record FILE HEADER FILE NUMBER: 3 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 2 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH PEF 4226.0 4475.5 FET 4233.0 4466.5 RPD 4233.0 4466.5 RPM 4233 0 RPS 4233 0 RPX 4233 0 GR 4236 5 DRHO 4238 0 RHOB 4238 0 ROP 4246 5 $ # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY EWR4 ELECTROMAG. RESIS. 4 SLD STABILIZED LITHO DEN $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT) : 4466 5 4466 5 4466 5 4486 0 4475 5 4475 5 4496 0 BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) : MUD PH: MUD CHLORIDES (PPM) : FLUID LOSS (C3) : RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 04-FEB-99 ISC 5.07 ISC 5.07 MEMORY 4495.0 4263.0 4495.0 47.9 50.1 TOOL NUMBER P1218HRLG6 P1218HRLG6 P12!SHRLG6 8.500 8.5 KCL DRILL-N 9.70 57.0 8.5 3.2 .160 .147 .110 .t10 20.0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .lin Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep DEPT FT 4 1 68 GR MWD 2 AP1 4 1 68 RPX MWD 2 OHMM 4 1 68 RPS HWD 2 OHHM 4 1 68 RPM MWD 2 OHHM 4 1 68 RPD HWD 2 OHHM 4 1 68 ROP MWD 2 FT/H 4 1 68 FET MWD 2 HOUR 4 1 68 RHOB MWD 2 G/CM 4 ! 68 DRHO MWD 2 G/CM 4 1 68 PEF MWD 2 BARN 4 1 68 Code Offset Channel 0 1 4 2 8 3 12 4 16 5 20 6 24 7 28 8 32 9 36 t0 40 11 Name Min Max Mean DEPT 4226 4496 4361 GR 47.76 149.09 94.9543 RPX 0.15 1635.91 39.6451 RPS 0.16 2000 261.9 RPM 0.2 2000 379.069 RPD 0.18 2000 431.139 ROP 3 1536 71.718 FET 0.45 3.48 1.46113 RHOB 1.95 2.57 2.20811 DRHO -0.01 0.42 0.106954 PEF 2.2 16.77 3.97304 Nsam 541 5OO 468 468 468 468 5OO 468 476 476 5OO First Reading 4226 4236.5 4233 4233 4233 4233 4246.5 4233 4238 4238 4226 Last Reading 4496 4486 4466.5 4466.5 4466.5 4466.5 4496 4466.5 4475.5 4475.5 4475.5 First Reading For Entire File .......... 4226 Last Reading For Entire File ........... 4496 File Trailer Service name ............. STSLIB.003 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 01/04/06 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.004 Physical EOF Tape Trailer Service name ............. LISTPE Date ..................... 01/04/06 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Next Tape Name ........... UNKNOWN Comments ................. STS LIS Technical Services Writing Library. Reel Trailer Service name ............. LISTPE Date ..................... 01/04/06 Origin ................... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Next Reel Name ........... UNKNOWN Comments ................. STS LIS Writing Library. Technical Services Scientific Scientific Physical EOF Physical EOF End Of LIS File