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HomeMy WebLinkAbout179-084MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Friday, July 22, 2022 SUBJECT:Mechanical Integrity Tests TO: FROM:Guy Cook P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL ConocoPhillips Alaska, Inc. 1D-03 KUPARUK RIV UNIT 1D-03 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 07/22/2022 1D-03 50-029-20408-00-00 179-084-0 W SPT 6084 1790840 1521 1420 1420 1415 1415 60 60 60 60 4YRTST P Guy Cook 7/10/2022 Testing completed with a Little Red Services pump truck and calibrated gauges. 30 MinPretestInitial15 Min Well Name Type Test Notes: Interval P/F Well Permit Number: Type Inj TVD PTD Test psi API Well Number Inspector Name:KUPARUK RIV UNIT 1D-03 Inspection Date: Tubing OA Packer Depth 430 2200 2130 2100IA 45 Min 60 Min Rel Insp Num: Insp Num:mitGDC220709073655 BBL Pumped:1.5 BBL Returned:1.4 Friday, July 22, 2022 Page 1 of 1 9 9 9 9 9 99 9 9 James B. Regg Digitally signed by James B. Regg Date: 2022.07.22 16:16:44 -08'00' WELL NAME API #SERVICE ORDER # FIELD NAMESERVICE DESCRIPTIONDELIVERABLE DESCRIPTION DATA TYPEDATE LOGGEDCOLOR PRINTS CDsCD5-1950103207600000 CRU WLSetting RecordFINAL FIELD3-Aug-21CD5-1950103207600000 CRU WLSetting RecordFINAL FIELD11-Aug-21CD5-9650103208110000 CRU WLPERFFINAL FIELD21-Jul-21CD2-31050103208260000 CRU WLDCSTFINAL FIELD16-Sep-21CD2-31050103208260000 CRU WLUSITFINAL FIELD24-Aug-21CD2-31050103208260000 CRU WLUSITFINAL FIELD25-Aug-21CD5-3150103208280000 CRU WLPERFFINAL FIELD27-May-21CD1-01A50103202990100 CRU WLRSTFINAL FIELD12-Sep-21MT7-0650103208310000 GMTU WLCORROSIONFINAL FIELD3-Oct-21MT6-0850103207720000 GMTU WLPSRFINAL FIELD14-Sep-21MT6-0850103207720000 GMTU WLPSRFINAL FIELD22-Oct-21MT7-0650103208310000 GMTU WLMECH CUTTERFINAL FIELD2-Sep-21MT7-0650103208310000 GMTU WLUSITFINAL FIELD12-Dec-21MT7-0650103208310000 GMTU WLUSITFINAL FIELD16-Dec-21MT7--0150103208320000 GMTU WLSCMTFINAL FIELD15-Nov-21MT7-0650103208310000 GMTU WLUSITFINAL FIELD19-Feb-21Lookout 150103203590000 GMTU WLRSTFINAL FIELD29-Mar-21Lookout 150103203590000 GMTU WLRSTFINAL FIELD2-Apr-21Delivery Receipt______ďďLJĞůů_____X_______________________________________Print Name Signature DatePlease return via courier or sign/scan and email a copy to Schlumberger.A Delivery Receipt signature confirms that a package (box, envelope, etc.) has been received. The package will be handled/delivered per standard company reception procedures. The package's contents have not been verified but should be assumed to contain the above noted SLB Auditor-Originated:PTS - PRINT CENTER600 E 57th Pl - Ste AAnchorage, AK 99518Delivered to:AOGCCATTN: Natural Resources Technician333 W. 7th Ave., Suite 100Anchorage, AK 99501-3539Transmittal Date:20-Dec-21Transmittal #:________________Signature12/21/2021Wd͗ϭϳϵϬϴϰϬͲ^Ğƚ͗ϯϲϭϲϭJRBy Abby Bell at 1:43 pm, Dec 21, 2021 1D-0350029204080000 KRU WLIPROFFINAL FIELD29-Aug-211F-0750029208300000 KRU WLGLSFINAL FIELD13-Oct-212W-0950029212350000 KRU WLSCMTFINAL FIELD18-Nov-212W-0950029212350000 KRU WLSCMTFINAL FIELD22-Sep-212U-1350029212610000 KRU WLPPROFFINAL FIELD16-Oct-213N-0650029215380000 KRU WLPPROFFINAL FIELD31-Oct-211Y-1750029223680000 KRU WLPPROFFINAL FIELD25-Jul-211Q-20A50029225890100 KRU WLSBHPSFINAL FIELD29-Jul-213S-24A50103204560100 KRU WLUSITFINAL FIELD25-Nov-212N-318A50103203430100 KRU WLSCMTFINAL FIELD12-Nov-211D-0350029204080000 KRU WLIPROFFINAL FIELD27-Mar-211D-0550029204170000 KRU WLSCMTFINAL FIELD8-Oct-211D-0250029204290000 KRU WLIPROFFINAL FIELD2-Apr-211A-0550029206270000 KRU WLLDLFINAL FIELD1-May-211B-1050029206560000 KRU WLWHIPSTOCKFINAL FIELD25-Sep-211F-0350029208530000 KRU WLPERFFINAL FIELD19-Oct-211Y-0650029209580000 KRU WLPPROFFINAL FIELD1-Nov-212D-0850029211580000 KRU WLGLSFINAL FIELD18-Jul-212D-0450029211760000 KRU WLBISNFINAL FIELD20-Nov-212D-0450029211760000 KRU WLSCMTFINAL FIELD10-Oct-212X-1550029211990000 KRU WLPPROFFINAL FIELD17-Oct-211Q-0950029212090000 KRU WLIPROFFINAL FIELD17-Nov-212E-1450029212140000 KRU WLSHBPFINAL FIELD30-Oct-212W-0950029212350000 KRU WLBISNFINAL FIELD19-Nov-211Q-0250029212480000 KRU WLIPROFFINAL FIELD29-Apr-212W-1450029212530000 KRU WLIPROFFINAL FIELD1-May-211Q-1550029213080000 KRU WLIPROFFINAL FIELD28-Apr-211R-0850029213330000 KRU WLIPROFFINAL FIELD3-May-211R-1350029213850000 KRU WLIPROFFINAL FIELD27-Jun-213F-0250029214470000 KRU WLWHIPSTOCKFINAL FIELD14-Nov-213F-1450029215000000 KRU WLLDLFINAL FIELD30-May-213M-0550029217060000 KRU WLCHEM CUTFINAL FIELD28-Oct-213M-0550029217060000 KRU WLSTRINGSHOTFINAL FIELD27-Oct-21 WELL NAME API #SERVICE ORDER # FIELD NAMESERVICE DESCRIPTIONDELIVERABLE DESCRIPTION DATA TYPEDATE LOGGEDCOLOR PRINTS CDsCD5-1950103207600000 CRU WLSetting RecordFINAL FIELD3-Aug-21CD5-1950103207600000 CRU WLSetting RecordFINAL FIELD11-Aug-21CD5-9650103208110000 CRU WLPERFFINAL FIELD21-Jul-21CD2-31050103208260000 CRU WLDCSTFINAL FIELD16-Sep-21CD2-31050103208260000 CRU WLUSITFINAL FIELD24-Aug-21CD2-31050103208260000 CRU WLUSITFINAL FIELD25-Aug-21CD5-3150103208280000 CRU WLPERFFINAL FIELD27-May-21CD1-01A50103202990100 CRU WLRSTFINAL FIELD12-Sep-21MT7-0650103208310000 GMTU WLCORROSIONFINAL FIELD3-Oct-21MT6-0850103207720000 GMTU WLPSRFINAL FIELD14-Sep-21MT6-0850103207720000 GMTU WLPSRFINAL FIELD22-Oct-21MT7-0650103208310000 GMTU WLMECH CUTTERFINAL FIELD2-Sep-21MT7-0650103208310000 GMTU WLUSITFINAL FIELD12-Dec-21MT7-0650103208310000 GMTU WLUSITFINAL FIELD16-Dec-21MT7--0150103208320000 GMTU WLSCMTFINAL FIELD15-Nov-21MT7-0650103208310000 GMTU WLUSITFINAL FIELD19-Feb-21Lookout 150103203590000 GMTU WLRSTFINAL FIELD29-Mar-21Lookout 150103203590000 GMTU WLRSTFINAL FIELD2-Apr-21Delivery Receipt______ďďLJĞůů_____X_______________________________________Print Name Signature DatePlease return via courier or sign/scan and email a copy to Schlumberger.A Delivery Receipt signature confirms that a package (box, envelope, etc.) has been received. The package will be handled/delivered per standard company reception procedures. The package's contents have not been verified but should be assumed to contain the above noted SLB Auditor-Originated:PTS - PRINT CENTER600 E 57th Pl - Ste AAnchorage, AK 99518Delivered to:AOGCCATTN: Natural Resources Technician333 W. 7th Ave., Suite 100Anchorage, AK 99501-3539Transmittal Date:20-Dec-21Transmittal #:________________Signature12/21/2021Wd͗ϭϳϵϬϴϰϬͲ^Ğƚ͗ϯϲϭϯϳJRBy Abby Bell at 1:43 pm, Dec 21, 2021 1D-0350029204080000 KRU WLIPROFFINAL FIELD29-Aug-211F-0750029208300000 KRU WLGLSFINAL FIELD13-Oct-212W-0950029212350000 KRU WLSCMTFINAL FIELD18-Nov-212W-0950029212350000 KRU WLSCMTFINAL FIELD22-Sep-212U-1350029212610000 KRU WLPPROFFINAL FIELD16-Oct-213N-0650029215380000 KRU WLPPROFFINAL FIELD31-Oct-211Y-1750029223680000 KRU WLPPROFFINAL FIELD25-Jul-211Q-20A50029225890100 KRU WLSBHPSFINAL FIELD29-Jul-213S-24A50103204560100 KRU WLUSITFINAL FIELD25-Nov-212N-318A50103203430100 KRU WLSCMTFINAL FIELD12-Nov-211D-0350029204080000 KRU WLIPROFFINAL FIELD27-Mar-211D-0550029204170000 KRU WLSCMTFINAL FIELD8-Oct-211D-0250029204290000 KRU WLIPROFFINAL FIELD2-Apr-211A-0550029206270000 KRU WLLDLFINAL FIELD1-May-211B-1050029206560000 KRU WLWHIPSTOCKFINAL FIELD25-Sep-211F-0350029208530000 KRU WLPERFFINAL FIELD19-Oct-211Y-0650029209580000 KRU WLPPROFFINAL FIELD1-Nov-212D-0850029211580000 KRU WLGLSFINAL FIELD18-Jul-212D-0450029211760000 KRU WLBISNFINAL FIELD20-Nov-212D-0450029211760000 KRU WLSCMTFINAL FIELD10-Oct-212X-1550029211990000 KRU WLPPROFFINAL FIELD17-Oct-211Q-0950029212090000 KRU WLIPROFFINAL FIELD17-Nov-212E-1450029212140000 KRU WLSHBPFINAL FIELD30-Oct-212W-0950029212350000 KRU WLBISNFINAL FIELD19-Nov-211Q-0250029212480000 KRU WLIPROFFINAL FIELD29-Apr-212W-1450029212530000 KRU WLIPROFFINAL FIELD1-May-211Q-1550029213080000 KRU WLIPROFFINAL FIELD28-Apr-211R-0850029213330000 KRU WLIPROFFINAL FIELD3-May-211R-1350029213850000 KRU WLIPROFFINAL FIELD27-Jun-213F-0250029214470000 KRU WLWHIPSTOCKFINAL FIELD14-Nov-213F-1450029215000000 KRU WLLDLFINAL FIELD30-May-213M-0550029217060000 KRU WLCHEM CUTFINAL FIELD28-Oct-213M-0550029217060000 KRU WLSTRINGSHOTFINAL FIELD27-Oct-21                                             !   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By Meredith Guhl at 2:22 pm, Jul 28, 2021 Stefan Weingarth Digitally signed by Stefan Weingarth Date: 2021.07.28 13:20:12 -08'00' VTL 8/4/21 SFD 7/28/2021 RBDMS HEW 7/29/2021 DSR-7/29/21                             !   " # $ %&       %    %   '   (    !       ' ) & *+ ,,    -  .. !                 %       !  "# $!&       %     & " %  ' (            ' ) &&*+ /   % ) &&*+ ,,    +..            &"0* &!*+ / ) &"*1*  2 &"*0*   ) &%*+     ) &!*+  3           -     - #    +   3'   %        / /     "           &+ +     &            0 +     0                       )            /  !  !             /          3%45678  9::45;<=>?5487<@A Last Tag Annotation Depth (ftKB) End Date Wellbore Last Mod By Last Tag: RKB 7,842.0 2/23/2021 1D-03 raineg Last Rev Reason Annotation End Date Wellbore Last Mod By Rev Reason: Set SPG with Integral Latch Top Sub 6/16/2021 1D-03 jleonar3 Casing Strings Casing Description CONDUCTOR OD (in) 16 ID (in) 15.06 Top (ftKB) 32.0 Set Depth (ftKB) 80.0 Set Depth (TVD) … 80.0 Wt/Len (l… 65.00 Grade H-40 Top Thread Casing Description SURFACE OD (in) 10 3/4 ID (in) 9.95 Top (ftKB) 31.2 Set Depth (ftKB) 2,904.2 Set Depth (TVD) … 2,708.1 Wt/Len (l… 45.50 Grade K-55 Top Thread Buttress Casing Description PRODUCTION OD (in) 7 ID (in) 6.28 Top (ftKB) 29.9 Set Depth (ftKB) 8,057.1 Set Depth (TVD) … 6,825.5 Wt/Len (l… 26.00 Grade K-55 Top Thread BTC Tubing Strings Tubing Description TUBING WO String Ma… 3 1/2 ID (in) 2.99 Top (ftKB) 27.0 Set Depth (ft… 7,255.4 Set Depth (TVD) (… 6,164.5 Wt (lb/ft) 9.30 Grade L-80 Top Connection EUE8rdMOD Completion Details Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des Com Nominal ID (in) 27.0 27.0 0.05 HANGER Tubing Hanger 3.030 497.9 497.9 0.15 NIPPLE 3 1/2" x 2.875" Camco DS Nipple 2.875 7,136.2 6,061.4 28.99 LOCATOR Seal Assembly Locator 7.32' space-out off NO-GO. 2.990 7,143.5 6,067.8 29.12 PBR Polish Bore Receptacle 3.000 7,163.3 6,085.0 29.45 PACKER Baker 3 1/2" x 7" FHL Retrievable Packer 2.910 7,206.1 6,122.2 30.19 NIPPLE 3 1/2" x 2.812" Camco DS Nipple 2.812 7,247.0 6,157.4 31.03 OVERSHOT Baker Poorboy Tubing Stub Overshot (swallow 6.03-ft) 3.630 Tubing Description TUBING Original String Ma… 3 1/2 ID (in) 2.99 Top (ftKB) 7,250.0 Set Depth (ft… 7,345.5 Set Depth (TVD) (… 6,240.8 Wt (lb/ft) 9.20 Grade K-55 Top Connection BTC Completion Details Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des Com Nominal ID (in) 7,271.6 6,178.3 31.53 SBR BAKER 3L-1 SEAL BORE RECEPTACLE 2.813 7,300.9 6,203.3 32.14 PACKER BAKER 'FHL PACKER 2.890 7,339.6 6,235.8 32.91 NIPPLE CAMCO 'D' NIPPLE 2.750 7,344.6 6,240.1 33.01 WLEG WIRELINE ENTRY GUIDE 2.992 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft )Type Com 7,422.0 7,519.0 6,304.4 6,383.4 UNIT D, C-4, 1D -03 8/4/1980 4.0 IPERF 2 1/8" Enerjet; 0 Deg. Phase 7,445.0 7,460.0 6,323.3 6,335.6 UNIT D, C-4, 1D -03 12/17/2002 4.0 RPERF 2 1/8" FJ,BH Chrgs, 0 Deg Phase 7,525.0 7,531.0 6,388.3 6,393.1 C-3, 1D-03 8/2/1980 4.0 IPERF 2 1/8" Enerjet; 0 Deg. Phase 7,539.0 7,545.0 6,399.6 6,404.4 C-2, 1D-03 8/2/1980 4.0 IPERF 2 1/8" Enerjet; 0 Deg. Phase 7,556.0 7,567.0 6,413.3 6,422.2 C-2, 1D-03 8/2/1980 4.0 IPERF 2 1/8" Enerjet; 0 Deg. Phase 7,778.0 7,798.0 6,593.7 6,610.2 A-5, 1D-03 8/7/1980 4.0 IPERF 2 1/8" Enerjet; 0 Deg. Phase 7,808.0 7,832.0 6,618.5 6,638.3 A-4, 1D-03 8/7/1980 4.0 IPERF 2 1/8" Enerjet; 0 Deg. Phase Stimulation Intervals Interva l Numbe r Type Subtype Start Date Top (ftKB) Btm (ftKB) Proppant Designed (lb) Proppant Total (lb) Vol Clean Total (bbl) Vol Slurry Total (bbl) 1 FRAC 12/21/2002 7,422.0 7,476.0 0.0 0.00 0.00 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 7,050.9 5,986.2 27.71 Camco KBMG 1 GAS LIFT GAUG E Integra l 6/16/2021 Notes: General & Safety End Date Annotation 9/12/2016 NOTE: Pumped 24,523-BBL 5k-10k-ppm MARCIT gel treatment to the Upper Unit D, C4 sands 7422-7460’MD 6/19/2010 NOTE: VIEW SCHEMATIC w/Alaska Schematic9.0 1D-03, 7/21/2021 10:34:25 AM Vertical schematic (actual) PRODUCTION; 29.9-8,057.1 IPERF; 7,808.0-7,832.0 IPERF; 7,778.0-7,798.0 IPERF; 7,556.0-7,567.0 IPERF; 7,539.0-7,545.0 IPERF; 7,525.0-7,531.0 IPERF; 7,422.0-7,519.0 RPERF; 7,445.0-7,460.0 FRAC; 7,422.0 PACKER; 7,301.0 PACKER; 7,163.3 GAS LIFT; 7,050.9 SURFACE; 31.2-2,904.2 NIPPLE; 497.9 CONDUCTOR; 32.0-80.0 KUP INJ KB-Grd (ft) 38.99 Rig Release Date 12/30/1979 1D-03 ... TD Act Btm (ftKB) 8,070.0 Well Attributes Field Name KUPARUK RIVER UNIT Wellbore API/UWI 500292040800 Wellbore Status INJ Max Angle & MD Incl (°) 42.87 MD (ftKB) 3,050.00 WELLNAME WELLBORE1D-03 Annotation Last WO: End Date 6/13/2010 H2S (ppm) DateComment SSSV: NIPPLE Well Name KUPARUK RIV UNIT 1D-03 API Well Number 50-029-20408-00-00 Inspector Name: Austin McLeod 0 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min DATE: Tuesday, July 17, 2018 TO: Jim Regg P.I. Supervisor 7 �8 jl SUBJECT: Mechanical Integrity Tests 1380 1380 CONOCOPHILLIPS ALASKA, INC. 1379 I D-03 FROM: Austin McLeod Type Test SPT Test psi KUPARUK RIV UNIT 1D-03 Petroleum Inspector 100 2285 2175 2150 Src: Inspector BBL Pumped: Reviewed By: 1.8 OA P.I. Supry 20' NON-CONFIDENTIAL Comm Well Name KUPARUK RIV UNIT 1D-03 API Well Number 50-029-20408-00-00 Inspector Name: Austin McLeod Permit Number: 179-084-0 Inspection Date: 7/13/2018 - Insp Num: mitSAM180713184537 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well ID -03 ' Type Inj W TVD 6084 Tu ,pg 1380 1380 1378 1379 PTD 1790840 Type Test SPT Test psi 1521 IA_ 100 2285 2175 2150 BBL Pumped: 2 BBL Returned: 1.8 OA l9 20' 20 " 20 Interval 4YRTST P/F L p Notes: MIT -IA -SCANNED AUG 0 7 M6 Tuesday, July 17, 2018 Page 1 of 1 �v •• • N S 0 O It t0 3 m ~ ? O v E ro e 5 U > U col Q O L y 2 L1 9 w a, _c -0 O b , N Z `.. 0 -0 E r OZm ,•, _ a . r N r N v0 O v v F- (`4Y u a a c C •o v >" lu-j-li m o v a E a CI J w m t0 COLO t0 c "0 N O J a . L N U N a �_ 0 U U N Q1 w N �'' _O O W 0 d, 0 0 0 0 oO N 0 C U C z Z ' ,- 0U -0 cz 0 Z 4, > E 17 u ce v O C 0 0 0 0 0 0ms N 16 0 U a J J J J J J C c o o O W W W W W W in i I— LL LL LL LL LL LL ,. 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H z 0CO2 L3Q � i a` F. 3-z AMIE OF ALASKA A <A OIL AND GAS CONSERVATION COMM ION REPORT OF SUNDRY WELL OPERATIONS 1.Operations Abandon E Plug Perforations r Fracture Stimulate E Pull Tubing E Operations Shutdown r-- Performed: Suspend IT Perforate r Other Stimulate r--••••.. Alter Casing IT Change Approved Program Plug for Redrill T Perforate New Pool T Repair Well I ••••••.. Re-enter Susp Well I- Other: MarcitGet Jb& 2.Operator Name: 4.Well Class Before Work: 5.Permit to Drill Number: ConocoPhillips Alaska, Inc. Development T Exploratory IT 179-084 3.Address: 6.API Number: P. O. Box 100360,Anchorage,Alaska 99510 Stratigraphic I""', Service 50-029-20408-00 7.Property Designation(Lease Number): 8.Well Name and Number: ADL 25650 KRU 1 D-03 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): NONE Kuparuk River Field/Kuparuk River Oil Pool 11.Present Well Condition Summary: Total Depth measured 8070 feet Plugs(measured) 7471 true vertical 6836 feet Junk(measured) None Effective Depth measured 7990 feet Packer(measured) 7163, 7301 true vertical 6769 feet (true vertical) 6085,6203 Casing Length Size MD TVD Burst Collapse CONDUCTOR 48 16 80 80 SURFACE 2873 10 3/4 2904 2708 PRODUCTION 8027 7 8057 6825 RECEIVED --OCT 0 6 2016 AOGCC Perforation depth: Measured depth: 7422, 7445,7525, 7539, 7556, 7778,7808 True Vertical Depth: 7519,7460, 7531, 7545,7567, 7798,7832 SCANNED FEB 2 3 2017 Tubing(size,grade,MD,and ND) 3.5, K-55, 7345 MD,6241 TVD Packers&SSSV(type,MD,and ND) PACKER-Baker FHL Retrievable Packer @ 7163 MD and 6085 TVD PACKER-Baker FHL Packer @ 7301 MD and 6203 ND SSSV: NONE 12.Stimulation or cement squeeze summary: Intervals treated(measured): NONE 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 Shut-in - - 0 0 Subsequent to operation Shut-in - - 0 0 14.Attachments(required per 20 MC 25.070,25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations F, Exploratory Development I ` Service FStratigraphic i...(''''''�� Copies of Logs and Surveys Run IT 16.Well Status after work: Oil IT Gas I •••••.. WDSPL IT Printed and Electronic Fracture Stimulation Data r GSTOR IT WINJ F WAG T GINJ T SUSP T SPLUG I '••••. 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: 316-374 Contact Mike @ 265-1032 Email Michael.C.Hazen@conocophillips.com Printed Name Mike Haz Title Staff Wells Engineer Signature ---)i Phone:265-1032 Date 106116 Form 10-404 Revised 5/2015 VTC— o�e2 /u- RBDMS �V OCT 0 2016 Submit Original Only • 1 D-03 DTTMSTAR JOBTYP SUMMARYOPS 9/5/16 Conformance NALCO Champion and AES rigged up NALCO hydration unit and pump, NALCO Polymer Treatment Support Unit, four 400-bbl upright tanks, two choke skids, bleed tiger tank, and hardline to 1D-03 target well and 1D-114 injection trunk line for supply and slipstream injection contribution. Electricians verified generator wiring and ground complete. Began staging product and additives. 9/6/16 Conformance Performed complete function test of NALCO system rigged up on location. Pumped Polymer Treatment 125-bbl produced water to tiger tank during process. Pumped Stage#1, Step Rate Injection Test: Step#1 — 1050-BPD, 175-BBL; Step#2 —2000-BPD, 333-BBL, Step#3—3750-BPD, 631-BBL; Step#4—5000-BPD, 854- BBL. 1993-BBL pumped. Initial WHP: 1235-psi, Final WHP: 1113-psi. Began Stage#2, 3000-ppm MARCIT. Injection line 2000-BWPD. 76-BBL away. 9/7/16 Conformance Continue Stage#2 pumping 3000-ppm MARCIT gel. 2699-BBL pumped; 7301-BBL Polymer Treatment remaining. Initial WHP: 1,235 psi Current WHP: 1,352 psi Injection Rate: 4,500 BWIPD Total Injected: 4,692 BBLS. 9/8/16 Conformance Continue Stage#2 pumping 3000-ppm MARCIT gel. 2699-BBL pumped; 7301-BBL Polymer Treatment remaining in 3000-ppm stage. Initial WHP: 1,235 psi Current WHP: 1,433 psi Injection Rate: 4,500 BPD 9/9/16 Conformance Continue Stage#2 pumping 3000-ppm MARCIT gel. 9054-BBL pumped; 946-BBL Polymer Treatment remaining in 3000-ppm stage. Initial WHP: 1,235 psi Current WHP: 1,504 psi Injection Rate: 4,500 BPD 9/10/16 Conformance Continue Stage#3 pumping 5000-ppm MARCIT gel. 3626-BBL pumped; 3874-BBL Polymer Treatment remaining in 5000-ppm stage. Initial WHP: 1,235 psi Current WHP: 1,661 psi Injection Rate: 4,500 BPD Total Injected: 15,618 BBLS. 9/11/16 Conformance Completed Stage#3 5000-ppm and at 13:10-hrs began the 7000-ppm MARCIT Polymer Treatment Stage#4. Stage#4, 527-BBL pumped; 4473-BBL remaining 7000-ppm stage. Initial WHP: 1,235 psi Current WHP: 1,878 psi Injection Rate: 4,500 BPD Total Injected: 20,019 BBLS. 9/12/16 Conformance Completed Stage#4 7000-ppm and at 16:00-hrs began the 10000-ppm MARCIT Polymer Treatment Stage#5. Stage#5, Approximately 400-BBL pumped. Defered the 30000-ppm stage due to having acheived MAWP and went to flush. Job Complete. Well SI and freeze protected. 111.' • a .... KUP INJ • 1 D-03 a Conoa)philhips a I Well Attributes Max Angle&MD TD Alaska Ine (Wellbore API/UWI Field Name Wellbore Status ncl(") MD(ftKB) Act Btm(ftKB) [�oa'tiP711Ntpc ` 500292040800 KUPARUK RIVER UNIT INJ 42.87 3,050.00 8,070.0 --- rM. Comment H2S(ppm) Date Annotation End Data KB-Grd(ft) Rig Release Date 1D-03,10/5/2016 2.13.53 PM SSSV:NIPPLE _ Last WO: 6/13/2010 38.99 12/30/1979 Vertical schematic(6ctuall Annotation Depth(ftKB) End Date Annotation Last Mod By End Date .._....._......_._...._..__....__...__ nazi Tae:sLN Lop cnc03)7,437.0 8/17/2016 Rev Reason:SEE NOTES pproven 10/5/2016 HANGER;27.0 1111;1 ICasing Strings r. Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread I CONDUCTOR 16 15.060 32.0 80.0 80.0 65.00 H-40 11 J,r Casing Description OD(in) ID(in) Top OMB) Sat Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread SURFACE 10 3/4 9.950 31.2 2,904.2 2,708.1 45.50 K-55 Buttress ii,',j Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread , PRODUCTION Tubing Strings 7 6.276 29.9 8,057.1 6,825.5 26.00 K-55 BTC Tubing Description Stung Ma...ID(in) Top(ftKB) Set Depth(ft..Set Depth(TVD)(...Wt(Ib/ft) Grade Top Connection CONDUCTOR;32.0-80.0 TUBING WO 31/2 2.992 27.0 7,255.4 6,164.5 9.30 L-80 EUE8rdMOD Completion Details Nominal ID NIPPLE;497.9 isii. Top(ftKB) Top(TVD)(ftKB) Top Incl(3 Item Des Com (in) sur 27.0 27.0 0.05 HANGER Tubing Hanger 3.030 497.9 497.9 0.15 NIPPLE 3 1/2"x 2.875"Camco DS Nipple 2.875 7,136.2 6,061.4 28.99 LOCATOR Seal Assembly Locator 7.32'space-out off NO-GO. 2.990 • 7,143.5 6,067.8 29.12 PBR Polish Bore Receptacle 3.000 - 7,163.3 6,085.0 29.45 PACKER Baker 3 1/2"x 7"FHL Retrievable Packer 2.910 7,206.1 6,122.2 30.19 NIPPLE 3 1/2"x 2.812"Camco DS Nipple 2.812 A 'A 7,247.0 6,157.4 31.03 OVERSHOT Baker Poorboy Tubing Stub Overshot(swallow 6.03-ft) 3.630 Tubing Description String Ma...ID(in) Top(ftKB) Set Depth(ft..'Set Depth(TVD)(...Wt(Iblrt) Grade Top Connection TUBING Original 3 1/2 2.992 7,250.0 7,345.5 6,240.8 9.20 K-55 BTC 1 Completion Details Nominal ID SURFACE',312-2,9042-asTop(ftKB) Top(TVD)(ftKB) Top Incl(3 Item Des Com (in) i iii 7,271.6 6,178.3 31.53 SBR BAKER 3L-1 SEAL BORE RECEPTACLE 2.813 7,300.9 6,203.3 32.14 PACKER BAKER'FHL PACKER 2.890 7,339.6 6,235.8 32.91 NIPPLE CAMCO'D'NIPPLE 2.750 7,344.6 6,240.1 33.01 WLEG WIRELINE ENTRY GUIDE 2.992 GAS LIFT;7,050.9 Other In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.) Top(TVD) Top Incl 11 Top(ftKB) (ftKB) 1") Des Com Run Date ID(in) 7,471.0 6,344.5 35.49 SAND PLUG Pumped Fullbore Sand Plug;29 bbl 6ppa 20-40 river 6/17/2016 0.000 sand slurry LOCATOR;7,1362 I DUMP BAILED 3'CaCO3 ON SAND PLUG TOP OF PER;7,143.5 1 i CaCO3 @ 7471'RKB(8/17/2016) PACKER;7,183.3 . `•' Perforations&Slots ilii Shot IF Dens Top(TVD) Blm(TVD) (shots/f NIPPLE;7,206.2 Top(ftKB) Btm(ftKB) (ftKB) (ftKB) Zone Date t) Type Com 7,422.0 7,519.0 6,304.4 6,383.4 UNIT D,C-4, 8/4/1980 4.0 IPERF 2 1/8"Enerjet;0 Deg. 1 D-03 Phase 4 7,445.0 7,460.0 6,323.3 6,335.6 UNIT D,C-4, 12/17/2002 4.0 RPERF 2 1/8"FJ,BH Chrgs,0 OVERSHOT;7,247.0 11 _ _ 1D-03 Deg Phase 7,525.0 7,531.0 6,388.3 6,393.1 C-3,1D-03 6/2/1980 4.0 IPERF 2 1/8"Enerjet;0 Deg. I Phase 508;7,271.6 :2 7,539.0 7,545.0 6,399.6 6,404.4 C-2,1D-03 8/2/1980 4.0 (PERF 21/8"Enerjet;0 Deg. Phase 7,556.0 7,567.0 6,413.3 6,422.2 C-2,1D-03 8/2/1980 4.0 (PERF 2 1/8"Enerjet;0 Deg. PACKER;7,301.0 •'"• Phase 7,778.0 7,798.0 6,593.7 6,610.2 A-5,1D-03 8/7/1980 4.0 IPERF 21/8"Enerjet;0 Deg. NIPPLE;7,339.6 ;,) Phase 7,808.0 7,832.0 6,618.5 6,638.3 A-4,1D-03 8/7/1980 40 IPERF 21/8"Enerjet;0 Deg. r. WLEG;7,344.6 Phase Stimulations&Treatments Min Top Max 8lm (Depeth) (DeKBth) Top(TVB)D) 050 ftK(VD) Stg B.1 Type Date Com 7,422.0 7,476.0 6,304.4 6,348.6 1 FRAC 12/21/200 C-SAND FRAC _T 2 FRAC;7,422.0 '1 Mandrel Inserts RPERF;7,445.0-7,460.0 S[ Ili } r atii IPERF;7,422.0-7,519.0 1 1 o Top(ND) Valve Latch Port Size TRO Run SAND PLUG;7,471.0 . I N Top(ftKB) (ftKB) Make Model OD(in) Sere Type Type (in) (psi) Run Date Com 41 '1 ) 1 7,050.9 5,986.2 Camco KBMG 1 GAS LIFT DMY BK 0.000 0.0 7/15/2010 1 r Notes:General&Safety End Date Annotation IPERF;7,525.0-7,531.0 6/19/2010 NOTE:VIEW SCHEMATIC w/Alaska Schematic9.0 9/12/2016 NOTE:Pumped 24,523-BBL 5k-10k-ppm MARCIT gel treatment to the Upper Unit D,C4 sands 7422-7460'MD IPERF;7,539.0-7,545.0-1 r 1 r IPERF;7,556.0-7,567.0-1 r IPERF;7,778.0-7,798.0 IPERF;7,808.0-7,632.0 PRODUCTION;29.9.8,057.1 • OF T� 49aI//77 sv THE STATE Alaska Oil and Gas fLAS KA. ti p Conservati®n Commission . _= 333 West Seventh Avenue GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 Main: 907.279.1433 ALAS *P' Fax: 907.276.7542 www.aogcc.alaska.gov John Peirce Sr. Wells Engineer soma) FEB 0 6 20174 ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510 Re: Kuparuk River Field, Kuparuk River Oil Pool, KRU 1D-03 Permit to Drill Number: 179-084 Sundry Number: 316-374 Dear Mr. Peirce: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, CA4- 7/V7 Daniel T. Seamount, Jr. Commissioner DATED this'Oday of July, 2016. RBDMSI� VL 1 201617 • STATE OF ALASKA• • RECEIVED ALASKA OIL AND GAS CONSERVATION COMMISSION JUL 21 2016 APPLICATION FOR SUNDRY APPROVALS AOGCC 20 AAC 25.280 1.Type of Request: Abandon r Plug Perforations E Fracture Stimulate Repair Well 1- Operations Shutdown fl Suspend n Perforate Other Stimulate r Pull Tubing I- Change Approved Program E Plug for Redrill EPerforate New Pool E Re-enter Susp Well E Alter Casing E Other: MAR(IT RFI JOR F. 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: ConocoPhillips Alaska,Inc. Exploratory 1 Development E 179-084 ' 3.Address: 6.API Number: P.O.Box 100360,Anchorage,Alaska 99510 Stratigraphic Service F . 50-029-20408-00 • 7.If perforating: 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? NONE Will planned perforations require a spacing exception? Yes r- No r'` KRU 1 D-03 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL 25650 • Kuparuk River Field/Kuparuk River Oil Pool ` 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD: Effective Depth TVD: MPSP(psi): Plugs(MD): Junk(MD): 8,070' • 6,836' • 7990 + 6769 ' 3000 NONE NONE Casing Length Size MD TVD Burst Collapse Structural Conductor 48' 16 80' 80' Surface 2,873' 10 3/4 2,904' 2,708' Production 8,027' 7" 8,057' 6,825' Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 7422-7832 ` 6304-6638 3.500" K-55 7,345' Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft): PACKER-BAKER 3 1/2"X 7"FHL RETRIEVABLE PACKER • MD=7163 TVD=6085 PACKER-BAKER'FHL PACKER . MD=7301 TVD=6203 12.Attachments: Proposal Summary 0 Wellbore schematic 0 13.Well Class after proposed work: Detailed Operations Program 0 BOP Sketch 0 Exploratory l Stratigraphic E Development la Service 14.Estimated Date for 8/19/2016 15.Well Status after proposed work: Commencing Operations: OIL r WINJ WDSPL r Suspended E 16.Verbal Approval: Date: GAS I- WAG E GSTOR E SPLUG E Commission Representative: GINJ E Op Shutdown I- Abandoned 17.I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Contact John Peirce @ 265-6471 Email John.W.Peirce@conocophillips.com Printed Name John Peirce Title Sr.Wells Engineer 7/2 i/I 6 Signature _. -' • Phone 265-6471 Date COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: \Le — 37 `f Plug Integrity ❑ BOP Test El Mechanical Integrity Test 0 Location Clearance 0 Other: Post Initial Injection MIT Req'd? Yes ❑ No I RBDMS LL- M-2 7 2016 Spacing Exception Required? Yes . No Subsequent Form Required: / v — 4-(/4- APPROVED BY Approved by' 1 / COMMISSIONER THE COMMISSION Date: 7/ZL /b L-- Sub Form and Form 10-4n3 Reij.d1/2017-7,26,4i-kpG Ip,>Ai`alid for 12 months from the date of;i3 ro /` Attachments in Duplicate • • KRU 1D-03 Injector MARCIT Gel Treatment 1D-03 injector has strong communication with 1E-33. A 3/29/16 IPROF verified 100% of injection enters the upper half of the C4 perf interval above 7470' RKB. 1 D-03 was a producer prior to July 2010 and the C4 sand had been fracture treated. Fractures from the Frac may have connected to a north-south fault to directly connect 1 D-03 to 1 E-33, resulting in high conductivity from 1 D-03 to 1 E-33. 1D-03 has been a prolific injector averaging 5600 BWPD at 1500 psi WHIP. This is 1000 psi below max WHIP available at 1D Pad. Water transit is—100 ft/day through a VSC (Void Space Conduit)or an open fracture network thought to exist from 1 D-03 to 1 E-33. It is proposed that MARCIT Gel be pumped in 1D-03 to improve injection conformance. The VSC is at the heel of 1 D-03, so the toe of 1D-03 is to be isolated below 7490' RKB with a sand plug. MARCIT will be pumped to achieve a 100% shutoff of all C4 perfs above 7490' RKB in communication with the VSC thief or fracture network. The sand plug will be removed after the MARCIT job to restore matrix injection at much higher WHIP's to the perforation intervals located below 7490' RKB. Procedure: Slickline: 1. RIH &tag PBTD for sand plug volume verification needed to sand back to 7490' RKB. Last tag= 7725'RKB on 3/29/16. RIH &set a Plug in the 2.75" D Nipple at 7339' RKB. Set Catcher Sub at 7339' RKB. Pull DV from GLM at 7050' RKB. Circulate Diesel down tubing with returns from IA to tanks until well is liquid packed for MIT's. Reset DV in GLM at 7050' RKB. Perform MIT-T& MIT-IA both to 2500 psi.Last 1D-03 MIT/A passed to 2010 psi on 8/26/14. Pull Catcher Sub off Plug at 7339' RKB. Pull Plug at 7339' RKB. RD. Coil Tubing: 2. RIH & tag PBTD. PU & pump gelled sand slurry while POOH with nozzle to spot sand plug in 7" casing to 7490' RKB (target) to isolate all perfs below 7490' RKB for MARCIT Gel job(step 5 below). POOH with CT. RD CTU. Slickline: 3. RIH &tag TOS. If TOS is in the 7470-7510' RKB window, POOH & RD SL. If TOS is out of the window,then bail sand in or out as needed until TOS is adjusted into the acceptable window. If excessive SL bailing will be needed to adjust TOS, the contingency plan is to RD SL to RU CTU to make an adjustment of TOS to within the acceptable window. Pumping: 4. Pump a Step Rate Injection Test (SRIT) down tubing to verify 'baseline' injectivity at several injection rates between 1.3- 3.5 bpm. Record stable rates vs. injection pressure. 5. MIRU polymer mixing unit and equipment as per approved job site rig-up plans. Pump—25,000 bbls of MARCIT Gel as follows: 10-03 Polymer Gel Rate Schedule _Tank Usable Volume 300 bbl Target Rate ....... 45C0 bpd •.Tank Fill Rate... ..._ 4bPrn _. .... _. ..... .. Seth ing Time 240.min Target Concentration PU 24 Rate Treatment Rate Total Treatment lar et Pol 3 Tank Design Volume(bbl) Dougon Rah 9 ymer PU24 Polymer Concentration Deys gagyhr Tank Drain Tank FIII Total Tank Drain DlDerence (ppm) (bpd) (bpd) Rah(bpm) (B/day) (ppm) (min) (min) Flu(min) (hr) (min) 3000 10000 2500 2000 3.13 4720 540)) 2.2 3.6 173 75 315 518 3.4 5000 7500 2500 �.d ;,�',\,�`, 2000 3.13 7867 •...'octitt . 1.7 6.0 173 75 315 518 3.4 7000 5000 2450 �.. n" 1050 2.43 8566 (Wo, 1.4 6.5 176 75 315 529 3.6 10000 2300 MW 2000 '.v-..� 0 139 6993 10W0 12 53 216 75 315 648 5,6 30000 200 lOW IOW"-; 0 0.69 10490 30000 0.2 7.9 432 75 315 1296 16,4 Total 25000 8.7 0 Ccnstreints ....._... .. _...._ _ .._. ____. 8 hags/hr ...._......... ......... __.... 4 h settling time .... 4bpm tank fill(17ft/s) 3 h difference b/t 3 tank drain and 1 tank fill-I-settle time _.. 30700 ppm max out PU24 ....... Coil Tubing: 6. RIH &jet out Gel and sand plug from the wellbore to as deep as possible. POOH with CT. RD CTU. Return 1 D-03 to injection. JWP 7/21/2016 KUP I 1D-03 ConocoPhillips Well Attribut Max Angle TD Alaska.Inc, Wellbore API/UWI Field Name Wellbore Status ncl(°) MD(ftKB) Act Btm(ftKB) gaps 500292040800 KUPARUK RIVER UNIT INJ 1 42.87 3,050.00 8,070.0 ••• Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date 10-03,7/19/20163:44:24 PM SSSV:NIPPLE Last WO: 6/13/2010 38.99 12/30/1979 Variiml srlrsma0c{aplua(1 Annotation Depth ftKB End Date Annotation P (ftKB) Last Mod By End Date Last Tag:SLM 7,703.0 7/18/2014 Rev Reason:TAG pproven 3/22/2016 HANGER;27.0 i"Iltali Casing Stings Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread CONDUCTOR 16 15.060 32.0 80.0 80.0 65.00 H-40 F Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)... Wt/Len(I...Grade Top Thread III SURFACE 103/4 9.950 31.2 2,904.2 2,708.1 45.50 K-55 Buttress It Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)... Wt/Len(I...Grade Top Thread PRODUCTION 7 6.276 29.9 8,057.1 6,825.5 26.00 K-55 BTC Tubing Strings Tubing Description String Me...ID(in) Top(ftKB) Set Depth(ft.Set Depth(ND)(...Wt(Ib/ft) Grade Top Connection CONDUCTOR;32.0-80,0 TUBING WO 3 1/2 2.992 27.0 7,255.4 6,164.5 9.30 L-80 EUE8rdMOD ��Completion Details ( Nominal ID NIPPLE;197.9 Top(ftKB) Top(TVD)(ftKB) Top Incl C) Item Des Corn (in) 27.0 27.0 0.05 HANGER Tubing Hanger 3.030 • • 497.9 497.9 0.15 NIPPLE 3 1/2"x 2.875"Camco DS Nipple 2.875 • • • 7,1362 6,061.4 28.99 LOCATOR Seal Assembly Locator 7.32'space-out off NO-GO. 2.990 I 7,143.5 6,067.8 29.12 PBR Polish Bore Receptacle 3.000 r • 7,163.3 6,085.0 29.45 PACKER Baker 3 1/2"x 7"FHL Retrievable Packer 2.910 7206.1 6,122.2 30.19 NIPPLE 3 1/2"x 2.812"Camco DS Nipple 2.812 I 7,247.0 6,157.4 31.03 OVERSHOT Baker Poorboy Tubing Stub Overshot(swallow 6.03-ft) 3.630 4i , Tubing Description String Ma...ID(in) Top(ftKB) Set Depth(ft..Set Depth(TVD)(...Wt(16/ft) Grade Top Connection TUBING Original 3 1/2 2.992 7,250.0 7,345.5 6,240.8 9.20 K-55 BTC • • i • Completion Details Nominal ID Top(ftKB) Top(ND)(ftKB) Top Incl(1 Item Des Com (in) 7,271,6 6,178.3 31.53 SBR BAKER 3L-1 SEAL BORE RECEPTACLE 2.813 SURFACE;31.2-2,801.2 l 7,300.9 6,203.3 32.14 PACKER BAKER'FHL PACKER 2.890 7,339.6 6,235.8 32.91 NIPPLE 'CAMCO'D'NIPPLE 2.750 • 7,344.6 6,240.1 33.01 WLEG WIRELINE ENTRY GUIDE 2.992 Perforations&Slots GAS LIFT;7,050.9 Shot Dens Top(TVD) Btm(ND) (hots/ I Top(MB) Btm(ftl(B) (ftKB) (ftKB) Zone Date ft) Type Com 7,422.0 7,519.0 6,304.4 6,383.4 UNIT D,C-4, 8/4/1980 4.0 (PERF 21/8"Enerjet;0 Deg. 10-03 Phase LOCATOR;7,136.2111 7,445.0' 7,460.0 6,323.3 6,335.6 UNIT D,C-4, 12/17/2002 4.0 RPERF 2 1/8"FJ,BH Chrgs,0 PBR;7.1436 1D-03 Deg Phase .. .. 7,525.0 7,531.0 6,388.3 6,393.1 C-3,10-03 8/2/1980 4.0 (PERF 21/8"Enerjet;0 Deg. PACKER;7,163.3 Phase 7,539.0 7,545.0 6,399.6 6,404.4 C-2,10-03 8/2/1980 4.0 IPERF 2 1/8"Enerjet;0 Deg. Phase NIPPLE;7,206.2 7,556.0 7,567.0 6,413.3 6,422.2 C-2,10-03 8/2/1980 4.0 (PERF 21/8"Enerjet;0 Deg. Phase , LE E 7,778.0 7,798.0 6,593.7 6,610.2 A-5,10-03 8/7/1980 ' 4.0 IPERF 21/8"Enerjet;0 Deg. Phase 7,808.0 7,832.0 6,618.5 6,638.3 A-4,1D-03 8/7/1980 4.0 IPERF 2 1/8"Enerjet;0 Deg. OVERSHOT;7,247.0 I. 1' Phase Stimulations&Treatments SBR;7271 6 r 0 Min Top Max Btm Depth Depth Top(ND) Sim(ND) (ftKB) (ftKB) (ftKB) (ftKB) Type Date Com PACKER:7,301.0 7,422.0 7,476.0 6,304.4 6,348.6 FRAC 12/21/200 C-SAND FRAC . .._ 2 M. Mandrel Inserts NIPPLE;7,339.6 11rr7-t ' 5t of Top(TVD) Valve Latch Port Size TRO Run WLEG;7,344.6 II _„N Top Top(ftKB) (ftKB) Make Model 00(in) Sery Type Type (in) (psi) Run Date Com 1 7,050.9 5,986.2 Camco KBMG 1 GAS LIFT DMY BK 0.000 0.0 7/15/2010 Notes:General&Safety End Date Annotation 6/19/2010 NOTE:VIEW SCHEMATIC w/Alaska Schematic9 0 FRAC;7,422.0 1 RPERF;7,445.0-7,460.0 (PERF;7,422.0-7,519.0 IPERF;7,525.5-7,531,5-. IPERF;7,539.0-7,545.0 IPERF;7,556.0.7,567.0 IPERF;7,778.0-7,798.0 (PERF;7,808.0-7,832.0 PRODUCTION;29.941,057,1 ` l c\ - aiS41 ' I ' • • 2--1 k a-t s MAY g10 2U1`,) WELL LOG TRANSMITTAL#903214107 ;A `yyC; To: Alaska Oil and Gas Conservation Comm. May 5, 2016 Attn.: Makana Bender 333 West 7th Avenue, Suite 100 DATA LOGGED Anchorage, Alaska 99501 544/2 K BENDER RE: Injection Profile : 1D-03 Run Date: 3/29/2016 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Chris Gullett, Halliburton Wireline &Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 FRS_ANC@halliburton.com 1D-03 Digital Data in LAS format, Digital Log Image file, Interpretation Report 1 CD Rom 50-029-20408-00 Injection Profile LogCANNED1 Color Log 50-029-20408-00 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline &Perforating Attn: Chris Gullett 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907-273-3527 Fax: 907-273-3535 FRS_ANC@halliburton.com Date: Signed: / ' ,ia� ayicv � / ...e144 Imag~l~roject Well History File' Cover e XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. _~ ? OL- ~ ~ ~ Well History File Identifier RESCAN DIGITAL DATA OVERSIZED (Scannable) E] Color items: [] Diskettes, No. [] Maps: [] Grayscale items: D Other, No/Type [] Other items scannable by large scanner [] Poor Quality Originals: OVERSIZED (Non-Scann able) [] Other: NOTES: [] Logs of various kinds [] Other Scanning Preparation ~L_ x 30 = (c~ O + J ~)'"" = TOTAL PAGES BY: ~BREN Production Scanning Stage 1 BY; Stage 2 VINCENT SHERYL MARIA LOWELL. BY: {SCANNING IS COMPLETE AT THIS POINT UNLESS~IS REQUIRED ON AN INDiVIOUAL PAGE BASIS DUE TO QUALITY, GRAYSCALE OR COLOR IMAGES) PAGE cou.T FROM SOA..ED F,'E: PAGE COUNT MATCHES NUMBER IN SCANNING PREPARATION: ~ NO IF NO IN STAGE '~, PAGE(S) DISCREPANCIES WERE FOUND: YES NO BE VER,Y BRE. V,NCENT. S,ERYL MAR,A L OWEL~ D ATE:/-~-~ ,S, ~-.'-~ IIIIIIIII III IIII RESCANNEDBY: BEVERLY E~REN VINCENT SHERYL MARIA LOWELL DATE: IS~ General Notes or Comments about this file: Quality Checked (done) 10125/02Rev3NOTScanned.wpd MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE: Tuesday, September 16, 2014 TO: Jim Regg P.I. Supervisor � f Gl 3I 14 SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 1 D-03 FRm1: Jeff Jones KUPARUK RIV UNIT 1D-03 Petroleum Inspector Sre: Inspector Reviewed By: P.I. Supry NON -CONFIDENTIAL Comm Well Name KUPARUK RIV UNIT 1D-03 API Well Number 50-029-20408-00-00 Inspector Name: Jeff Jones Permit Number: 179-084-0 Inspection Date: 8/26/2014 Insp Num: mitJJ140915190958 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min -- - -- _ _ — - -- i - - 1D-03 W 1 6084 T— 1090 - 1089 1089 - 1091 _ Well Type InJ TVD Tubing TDt— 1790840 Type Test sPT Test p psi 1521 IA a6o zolo -1- 1980 - 1980 Interval 4YRTST PAF --------45 DA 51-52� 52 Notes' 1.3 BBLS diesel pumped. I well inspected, no exceptions noted. SCANNED OCT 3 02014 Tuesday, September 16, 2014 Page I of 1 • MEMORANDUM To: Jim Regg P.I. Supervisor / O FROM: Bob Noble Petroleum Inspector State of Alaska • Alaska Oil and Gas Conservation Commission DATE: Tuesday, August 31, 2010 SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 1D-03 KUPARUK RIV UNIT 1D-03 Src: Inspector NON -CONFIDENTIAL Reviewed By: P.I. Supry Comm Well Name: KUPARUK RIV UNIT 1D-03 API Well Number: 50-029-20408-00-00 Inspector Name: Bob Noble Insp Num: mitRCN100831123407 Permit Number: 179-084-0 Inspection Date: 812812010 Rel Insp Num: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well 1D 30 " T p j, w TVD 6084 IA 360 2303 2246 P.T.D 1790840 ' TypeTest iSPT Test ps�z303 OA 5 5 f2247 6 Interval INITAL P/F P ' Tubing 1310 1303 4 1320 Notes: Post rig workover. �p5; �N o I ` 2�11Ct Tuesday, August 31, 2010 Page 1 of 1 Page 1 of ~, • Regg, James B (DOA) ~ ~ ~~_~~~ From: CPF1 Prod Engr [n1269@conocophillips.com] Sent: Friday, August 13, 2010 9:16 AM To: Regg, James B (DOA) Cc: Maunder, Thomas E (DOA) Subject: FW: LPP/SSV Returned to Service on 1 D-03 (179-084) on 8/11 Jim, I meant to add your name to the original distribution but forgot David Lagerlef/Dan Bearden CPF1 Production Engineers n1269@conocophillips.com 659-7493 ~: ~:_ °~(}~(~ pager 659-7000 765 ~:,. ~ {"~~~~~,~-` ~ airy "` ~± From: CPFl Prod Engr Sent: Friday, August 13, 2010 9:13 AM To: (tom.maunder@alaska.gov) Cc: CPF1 DS Lead Techs; CPF1 Ops Supv; NSK Problem Well Supv; Kovar, Mark; NSK Prod Engr & Optimization Supv; Seitz, Brian; CPF1&2 Ops Supt; NSK Prod Engr Specialist Subject: LPP/SSV Returned to Service on 1D-03 (179-084) on 8/11 Tom /Jim, The low pressure pilot (LPP) on Kuparuk injector 1D-03 (179-084) was returned to service on 08/11/2010 after the wellhead injection pressure stabilized above the setting of the low pressure pilot. Current wellhead pressure is 1172 psig; injection rate is 4050 bwpd. This pilot had been defeated on 07/23/2010 in accordance with "Administrative Approval No. CO 432D." Please let me know if you have any questions. David Lagerlef/Dan Bearden CPF1 Production Engineers n 1269 @con oco p h i l l i ps. co m 659-7493 pager 659-7000 765 Fro • Maunder, Thomas E (DOA) [mailto:tom.maunder@alaska.gov] Sent: Fri July 23, 2010 4:04 PM To: NSK Prod Specialist Cc: CPFl Prod Engr Subject: RE: 1D-03 (179-08 st for waiver Dan and Darrell, I have spoken with Commissioners Seamount and operate 1 D-03 as described in your message. Plan to injection rates and pressures. They have given oral approval for you to ;1;me on Monday with an update of the 8/13/2010 Page 1 of 6 i i Maunder, Thomas E (DOA) From: Maunder, Thomas E (DOA) Sent: Tuesday, August 10, 2010 10:13 AM To: 'NSK Prod Engr & Optimization Supv' Subject: RE: 1 D-03 (179-084) request for waiver *. , ': ~ ' ~'± ~ ~ ~~~~-~ ~' ~ ~' ~~ [l 1~ Denise, Thanks much for the information; lots of voidage to replace down there. The injection rate is you all's call, I was just curious of the trends through these past weeks. Tom Maunder, PE AOGCC From: NSK Prod Engr & Optimization Supv [mailto:n2046@conocophillips.com] Sent: Monday, August 09, 2010 4:43 PM To: Maunder, Thomas E (DOA); CPF1 Prod Engr Subject: RE: 1D-03 (179-084) request for waiver Tom, I have attached our daily average injection rateslpressures. I recently spoke with the reservoir engineer and he is not opposed to raising the injection rate while the reservoir "fills up" so the well fall within our typical flowing conditions. We'll be increasing the injection rate very soon. Denise From: Maunder, Thomas E (DOA) [mailto:tom.maunder@alaska.gov] Sent: Monday, August 09, 2010 4:16 PM To: NSK Prod Engr & Optimization Supv; CPF1 Prod Engr; NSK Prod Engr Specialist Subject: RE: iD-03 (179-084) request for waiver Thanks Denise. Do you have a listing of the rates and pressures since the well was put back in service? I'd appreciate if you or if you could have someone provide that listing. Regards, Tom Maunder, PE AOGCC From: NSK Prod Engr & Optimization Supv [mailto:n2046@conocophillips.com] Sent: Monday, August 09, 2010 1:34 PM to: CPF1 Prod Engr; Maunder, Thomas E (DOA); NSK Prod Engr Specialist Subject: iD-03 (179-084) request for waiver Hi Tom, In the absence of the CPF1 Production Engineers, I have been keeping an eye on 1 D-03. The well is currently taking 6000 BWPD at 580psi. Please let me know if you have any questions. Denise Denise Titus /Gary Targac Production Engineering & Optimization Supervisors ConocoPhillips Alaska Inc 8/13/2010 • • DAY AVG data DATE-TIME FI-1 D1153~ PI-1 D5239-0 1 D03 H2O.1 D03 H2O/G FLOW PRESSURE 7/22/2010 23:59 0 0 7/23/2010 23:59 1914.69 353.525 7/24/2010 23:59 4624.91 174.881 7/25/2010 23:59 5084.8 244.861 7/26/2010 23:59 5333.59 344.332 7/27/2010 23:59 5771.29 414.491 7/28/2010 23:59 5433.74 400.044 7/29/2010 23:59 5635.08 438.763 7/30/2010 23:59 5712.76 461.611 7/31 /2010 23:59 5723.7 473.776 8/1/2010 23:59 5750.62 485.496 8/2/2010 23:59 5630.68 482.353 8/3/2010 23:59 5544.37 474.505 8/4/2010 23:59 4300.67 367.488 8/5/2010 23:59 4513.04 349.846 8/6/2010 23:59 6039.1 542.513 8/7/2010 23:59 5992.32 552.689 3 AS INJ 7000 6000 5000 4000 D a m 3000 2000 1000 0 7/21 1D-03 Water Injection 600 500 400 as 300 '~ a 200 100 0 8/10 7/23 7/25 7/27 7129 7/31 8/2 8/4 8/6 8/8 ~ 1 D-03 WI Rate (BWPD) -f-1 D-03 Inj Press j Page 1 of 4 Maunder, Thomas E (DOA) From: CPF1 Prod Engr [n1269@conocophillips.com] Sent: Thursday, August 05, 2010 10:40 AM To: CPF1 Prod Engr; Maunder, Thomas E (DOA); NSK Prod Engr Specialist Cc: NSK Prod Engr & Optimization Supv Subject: RE: 1 D-03 (179-084) request for waiver Good Morning Tom, 1 D-03 is currently injecting 6,031 BWIPD at 430 prig. Due to waterflood re-stabilization across CPF1 as a result of our seawater tightline project, injection rates were decreased yesterday afternoon. This caused a drop in wellhead injection pressure. This morning, we were able to return increased injection rate on 1 D-03. Regards, David Lloyd Lagerlef/Daniel Bearden CPF1 Production Engineers n1269@conocophillips.com 659-7493 pager 659-7000 765 From: CPF1 Prod Engr Sent: Wednesday, August 04, 2010 8:14 AM To: 'Maunder, Thomas E (DOA)'; NSK Prod Engr Specialist Subject: RE: 1D-03 (179-084) request for waiver Hi Tom, 1D-03 is currently injecting 5,832 BWIPD at 518 psig. We had waterflood pump issues yesterday concerning our Seawater Tightline project. Regards, David Lloyd Lagerlef/Daniel Bearden CPF1 Production Engineers n1269@conocophillips.com 659-7493 pager 659-7000 765 __ ___ From: CPFi Prod Engr [mailto:n1269@conocophillips.com] Sent: Monday, August 02, 2010 9:02 AM To: CPFi Prod Engr; Maunder, Thomas E (DOA); NSK Prod Engr Specialist Subject: RE: iD-03 (179-084} request for waiver Good morning Tom, 1 D-03 is currently injecting 5,851 BWIPD at 508 psig. Regards, 8/5/2010 Page 1 of 4 Maunder, Thomas E (DOA) • From: CPF1 Prod Engr (n1269@conocophillips.com] Sent: Wednesday, August 04, 2010 8:14 AM To: Maunder, Thomas E (DOA); NSK Prod Engr Specialist Subject: RE: 1 D-03 (179-084) request for waiver Hi Tom, 1 D-03 is currently injecting 5,832 BWIPD at 518 psig. We had waterflood pump issues yesterday concerning our Seawater Tightline project. Regards, David Lloyd Lagerlef/Daniel Bearden CPF1 Production Engineers n1269@conocophillips.com 659-7493 pager 659-7000 765 From: CPFi Prod Engr [mailto:n1269@conocophillips.com] Sent: Monday, August 02, 2010 9:02 AM To: CPF1 Prod Engr; Maunder, Thomas E (DOA); NSK Prod Engr Specialist Subject: RE: iD-03 (179-084) request for waiver Good morning Tom, 1 D-03 is currently injecting 5,851 BWiPD at 508 psig. Regards, David Lloyd Lagerlef/Daniel Bearden CPF 1 Production Engineers n 1269@conocophillips.com 659-7493 pager 659-7000 765 From: CPF1 Prod Engr Sent: Saturday, July 31, 2010 7:05 PM To: CPFi Prod Engr; 'Maunder, Thomas E (DOA)'; NSK Prod Engr Specialist Subject: RE: 1D-03 (179-084) request for waiver Good evening Tom, 1 D-03 is currently injecting 5;709 BWIPD at 474 psig. Regards, David Lloyd Lagerlef/Daniel Bearden CPF1 Production Engineers n1269@conocophillips.com 8/5/2010 Page 1 of~ n U • Maunder, Thomas E (DOA) From: CPF1 Prod Engr [n1269@conocophillips.com] Sent: Thursday, July 29, 2010 7:30 AM To: CPF1 Prod Engr; Maunder, Thomas E (DOA); NSK Prod Engr Specialist Subject: RE: 1 D-03 (179-084) request for waiver Good morning Tom, 1 D-03 is currently injecting 5,661 BWIPD at 437 psig. CPF1 has recovered from our plant upset and returned to normal operations. David Lloyd Lagerlef/Daniel Bearden CPF1 Production Engineers n 1269@conocophillips.com 659-7493 pager 659-7000 765 From: CPF1 Prod Engr Sent: Wednesday, July 28, 2010 11:46 AM To: 'Maunder, Thomas E (DOA)'; NSK Prod Engr Specialist Cc: NSK Prod Engr & Optimization Supv Subject: RE: iD-03 (179-084) request for waiver Thank you Tom. 1 D-03 is currently injecting 4,487 BWIPD at 297 psig. This is due to a CPF1 plant upset that we are currently undergoing. I will provide an update in the morning, or when our process systems return to normal. Regards, David Lloyd Lagerlef/Daniel Bearden CPF1 Production Engineers n 1269@conocophillips.com 659-7493 pager 659-7000 765 From: Maunder, Thomas E (DOA) [mailto:tom.maunder@alaska.gov] Sent: Wednesday, July 28, 2010 8:31 AM To: CPF1 Prod Engr; NSK Prod Engr Specialist Subject: RE: iD-03 (179-084) request for waiver Dan and Darrell, Here is that Administrative Approval. How goes the well operation? Tom Maunder, PE AOGCC 7/29/2010 Page 1 of 3 r~ LJ Maunder, Thomas E (DOA) From: CPF1 Prod Engr [n1269@conocophillips.comj Sent: Wednesday, Juiy 28, 2010 11:46 AM To: Maunder, Thomas E (DOA); NSK Prod Engr Specialist Cc: NSK Prod Engr & Optimization Supv Subject: RE: 1 D-03 (179-084) request for waiver Thank you Tom. 1 D-03 is currently injecting 4,487 BWIPD at 297 psig. This is due to a CPF1 plant upset that we are currently undergoing. I will provide an update in the morning, or when our process systems return to normal. Regards, David Lloyd Lagerlef/Daniel Bearden CPF1 Production Engineers n1269@conocophillips.com 659-7493 pager 659-7000 765 From: Maunder, Thomas E (DOA) [mailto:tom.maunder@alaska.gov] Sent: Wednesday, July 28, 2010 8:31 AM To: CPFi Prod Engr; NSK Prod Engr Specialist Subject: RE: iD-03 (179-084) request for waiver Dan and Darrell, Here is that Administrative Approval. How goes the well operation? Tom Maunder, PE AOGCC From: CPF1 Prod Engr [mailto:n1269@conocophillips.com] Sent: Tuesday, July 27, 2010 6:24 AM To: CPF1 Prod Engr; Maunder, Thomas E (DOA); NSK Prod Engr Specialist Subject: RE: iD-03 (179-084) request for waiver Good morning Tom, 1 D-03 is currently injecting 5,800 BWIPD at 414 psig. David Lloyd Lagerlef/Daniel Bearden CPF1 Production Engineers n 1269@conocophillips.com 659-7493 pager 659-7000 765 From: CPF1 Prod Engr Sent: Monday, July 26, 2010 9:42 AM 7/28/2010 Page 1 of 2 s Maunder, Thomas E (DOA) From: Maunder, Thomas E (DOA) Sent: Tuesday, July 27, 2010 7:29 AM To: 'CPF1 Prod Engr'; NSK Prod Engr Specialist Subject: RE: 1 D-03 (179-084) request for waiver Thanks Dan. The AA should be finalized later today. Tom From: CPF1 Prod Engr [mailto:n1269@conocophillips.com] Sent: Tuesday, July 27, 2010 6:24 AM To: CPFi Prod Engr; Maunder, Thomas E (DOA); NSK Prod Engr Specialist Subject: RE: 1D-03 (179-084) request for waiver Good morning Tom, 1 D-03 is currently injecting 5,800 BWIPD at 414 psig. David Lloyd LagerleflDaniel Bearden CPF1 Production Engineers n 1269@conocophillips.com 659-7493 pager 659-7000 765 From: CPFl Prod Engr Sent: Monday, July 26, 2010 9:42 AM To: 'Maunder, Thomas E (DOA)'; NSK Prod Engr Specialist Subject: RE: iD-03 (179-084) request for waiver Good morning Tom, 1 D-03 is currently injecting 5,200 BWIPD at 331 .psig. When we began injection on Friday the well was on a vacuum. We are slowly pressuring up the reservoir in the area, and are almost halfway to the injection pressure where we can re-engage our LPP. We continue to request administrative approval under CO 432D to continue water injection operations with the safety valve system defeated. Regards, David Lloyd Lagerlef/Daniel Bearden CPF1 Production Engineers n 1269@conocophillips.com 659-7493 pager 659-7000 765 __ _ _ From: Maunder, Thomas E (DOA) [mailto:tom.maunder@alaska.gov] 7/27/2010 Page 2 of 2 Sent: Monday, July 26, 2010 9:33 AM To: NSK Prod Engr Specialist Cc: CPFl Prod Engr Subject: RE: 1D-03 (179-084) request for waiver Dan and Darrell, Do you have any updated information regarding rates and pressures for 1 D-03? Thanks in advance. Tom Maunder, PE AOGCC From: Maunder, Thomas E (DOA) Sent: Friday, July 23, 2010 4:04 PM To: 'NSK Prod Engr Specialist' Cc: CPFi Prod Engr Subject: RE: 1D-03 (179-084) request for waiver Dan and Darrell, I have spoken with Commissioners Seamount and Norman. They have given oral approval for you to operate 1 D- 03 as described in your message. Plan to contact me on Monday with an update of the injection rates and pressures. Tom Maunder, PE AOGCC From: NSK Prod Engr Specialist [mailto:n1139@conocophillips.com] Sent: Friday, July 23, 2010 3:42 PM To: Maunder, Thomas E (DOA) Cc: CPF1 Prod Engr Subject: iD-03 request for waiver Tom - ConocoPhillips requests administrative approval under CO 432D to operate a Kuparuk water injection well with a defeated safety valve system. This request is similar to CO 4066 administrative approval granted to the West Sak Pool. The LPP for injection well 1 D-03 has been defeated due to low injection pressure as the well was converted to an injector and brought online today. We expect injection pressure to increase sufficiently by this weekend, pending completion of the seawater tight line project at CPF1 to expand injection capacity. This will allow us to re- engage the SVS system and the well to operate under normal conditions. This event is an anomaly within Kuparuk and we don't anticipate further requests of this nature. The well is currently injecting 3400 bwpd at pressures below the minimum LPP set point. Your response either by email or phone to our request is greatly appreciated. Regards, Dan Bearden / Darrell Humphrey ConocoPhillips Alaska, Inc. Office (907) 659-7493 NSK-69 7/27/2010 ConocoPhillips ~~ P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 ~o~~ August 3, 2010 ~~ ~~ ~~ ~~D Commissioner Dan Seamount ~°~ Alaska Oil & Gas Commission ~ ~ 201~D 333 West 7~' Avenue, Suite 100 ~ ~ '~ Anchorage, AK 99501 "` f `f ```' c~ ~+~~ ~i~~K~ .~s. ~~s Ce+t~. fission gc~~~~r;~ge Commissioner Dan Seamount: Enclosed please find a spreadsheet with a list of wells from the Kuparuk field (KRU). Each of these wells was found to have a void in the conductor. These voids were filled with 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 corrosion inhibitor/sealant was pumped August 1St & 2"d 2010. The attached spreadsheet presents the well name, top of cement depth prior to filling, and volumes used on each conductor. Please call Perry Klein or MJ Loveland at 907-659-7043, if you have any questions. ConocoPhillips Well Integrity Projects Supervisor ConocoPhillips Alaska Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off '~~l~ s Report of Sundry Operations (10-404) Kuparuk Field Date 8/03/10 ell Name PI # TD # Initial top of cement Vol. of cement um ed Final top of cement Cement top off date ~r>> ~v~ ~a. Corrosion inhibitor rnv Corrosion inhibitor/ sealant date ft bbls ft al 1A-26 50029221150000 1901660 SF n/a 12" n/a 2.6 8/1/2010 1A-27 50029221240000 1901800 SF n/a 27" n/a 4.3 8/1/2010 V 1 D-03 50029204080000 1790840 17" Na 17" Na 1 8!2/2010 1D-06 50029204180000 1790960 16" n/a 16" n/a 1.7 8/2/2010 1D-07 50029204300000 1791120 17" n/a 17" n!a 4.3 8/2/2010 1L-05 50029211550000 1841230 17" n/a 17" n/a 3.4 8/1/2010 1L-21 50029220439000 1910060 17" n/a 17" n/a 4.3 8/1/2010 1L-24 50029221700000 1910660 32" n/a 32" n/a 7.5 8/1/2010 • • D O a s O SEAN PARNELL, GOVERNOR ,c7usc~5~A OIL ~1BD ~ua-7 333 W. 71h AVENUE, SUITE 100 CO1Q51~'R'QA.'1`I014 COrIMI551OK ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 ADMINISTRATIVE APPROVAL NO. CO 432D.008 Mr. Daniel Bearden CPF 1 Production Engineer ~~~ ~. ~ ~~ { `1 a~ ~~~ ConocoPhillips Alaska ~ ~ u t~ ~, P.O. Box 100360 Anchorage, AK 99510-0360 RE: Conservation Order 432D KRU 1 D=Q3 (1790840) Defeating Low Pressure Pilot on Water Injection Well with Low Tubing Pressure Dear Mr. Bearden: By electronic message letter dated July 23, 2010, ConocoPhillips Alaska, Inc. ("CPAI") requested approval to disable Automatic Shut-In Equipment on water injection well KRU 1 D-03. CO 432D Rule 5 prescribes what surface wellhead equipment must be employed on all wells in the Kuparuk River Unit. Rule 5 (b) requires that "...safety valve systems ("SVS") shall not be deactivated except during repairs ... or if the pad is manned ... and if the SVS cannot be returned to service within 24 hours, the well must be shut in ..." This well has recently been converted to water injection (service). Since production began in December 1981, the well has produced some 6.8 million barrels of oil, 15.4 million cubic feet of gas and 5.7 million barrels of water. Due to the- large voidage in the reservoir, the surface pressure while injecting is low, below the threshold of the pressure sensor that activates the surface safety valve ("SSV"). To prevent the safety valve system from repeatedly functioning and shutting in the well, CPAI requests approval to defeat (prevent from functioning) the pressure sensor ("low-pressure pilot") until the operating injection surface pressure reaches about 700 psi. A localized reduction in BHP resulting from production is not unusual, although this is likely the first time this situation has been experienced in the Kuparuk Oil Pool. After watex injection has been in operation for a while, the local BHP should increase giving sufficient surface pressure to allow the low-pressure pilot to operate properly. A check valve remains functional at all times to prevent flow from the well if the flowline were to be damaged. The well was recently worked over and passed a mechanical integrity test ("MIT") at the conclusion of the work. Granting CPA's request will not increase the risk • CO 432D.008 July 28, 2010 Page 2 of 2 • to any fresh water since all aquifers have been exempted by EPA per 40 CFR 147.102 (b) (3). Now therefore, as provided by Rule 12 of CO No. 432D, CPAI's request to operated KRU 1D-03 with the SVS defeated in APPROVED subject to the following: 1. 2. 3. 4. 5. The defeated pilot and safety valve must be tagged and recorded on the "Facility Defeated Safety Device Log" which must be available for AOGCC inspection. A copy of this document should be available for AOGCC inspection at CPF-1. CPAI will monitor and record the daily injection volume and surface injection pressure. The SVS must be returned to service when the surface injection pressure reaches 700 psi. CPAI will notify the Commission when the SVS is returned to service and provide the volume and pressure information required in (1). Notification and information may be sent electronically. DONE at Anchorage, Alaska and dated July 28, 2010. Alaska ,, Cathy . Foerster Commissioner TION AND As provided in AS 31.05.080(a), within ZO days after written notice of the entry of this order or decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for reconsideration of the matter detennined by it. If the notice was mailed, then the period of time shall be 23 days. An application for reconsideration must set out the respect in which the order or decision is believed to be erroneous. The Commission shall grantor refuse the application for reconsideration in whole or in part within 10 days after it is filed. Failure to act on it within !0-days is a denial of reconsideration. If the Commission denies reconsideration, upon denial, this order or decision and the denial of reconsideration are FINAL and may be appealed to superior court. The appeal MUST be filed within 33 days after the date on which the Commission mails, OR 30 days if the Commission otherwise distributes, the order or decision denying reconsideration, UNLESS the denial is by inaction, in which case the appeal M19UST be filed within 40 days after the date on which the application for reconsideration leas filed. If the Commission grants an application for reconsideration, this order or decision does not become final. Rather, the order or decision on reconsideration will be the FINAL order or decision of the Commission, and it may be appealed to superior court. That appeal A1L'ST be tiled within 33 days after the date on which the Commission mails, OR 30 days if the Commission otherwise distributes, the order or decision on reconsideration. As provided in AS 31.05.080(6), "[t]he questions reviewed on appeal are limited to the questions presented to the Commission by the application for reconsideration." In computing a period of time above, the date of the event or default after which the designated period begins to run is not included in the period; the last day of the period is included, unless it falls on a weekend or state holiday, in which event the period runs until 5:00 p.m. on the next day that does not fall on a weekend or state holiday. Maunder, Thomas E (DOA) From: Maunder, Thomas E (DOA) Sent: Friday, July 23, 2010 4:04 PM To: 'NSK Prod Engr Specialist' Cc: CPF1 Prod Engr Subject: RE: 1 D-03 (179-084) request for waiver Dan and Darrell, I have spoken with Commissioners Seamount and Norman. They have given oral approval for you to operate 1 D- 03 as described in your message. Plan to contact me on Monday with an update of the injection rates and pressures. Tom Maunder, PE AOGCC From: NSK Prod Engr Specialist [mailto:n1139@conocophillips.com] Sent: Friday, July 23, 2010 3:42 PM To: Maunder, Thomas E (DOA) Cc: CPFl Prod Engr Subject: 1D-03 request for waiver Tom - ConocoPhillips requests administrative approval under CO 432D to operate a Kuparuk water injection well with a defeated safety valve system. This request is similar to CO 4066 administrative approval granted to the West Sak Pool. The LPP for injection well 1 D-03 has been defeated due to low injection pressure as the well was converted to an injector and brought online today. We expect injection pressure to increase sufficiently by this weekend, pending completion of the seawater tight line project at CPF1 to expand injection capacity. This will allow us to re- engage the SVS system and the well to operate under normal conditions. This event is an anomaly within Kuparuk and we don't anticipate further requests of this nature. The well is currently injecting 3400 bwpd at pressures below the minimum LPP set point. Your response either by email or phone to our request is greatly appreciated. Regards, Dan Bearden / Darrell Humphrey ConocoPhillips Alaska, Inc. Office (907) 659-7493 NSK-69 7/26/2010 Page 2 of 2 Cc: CPF1 Prod Engr Subject: 1D-03 request for waiver Tom - ConocoPhilli s re uests administrative a royal under CO 432D to operate a Kuparuk water injection we-I with a defeated safety valve system. This request is similar to 4 administrative approval granted to the West Sak Pool. The LPP for injection well 1 D-03 has been defeated due to low injection pressure as the well was converted to an injector and brought online today. We expect injection pressure to increase sufficiently by this weekend, pending completion of the seawater tight line project at CPF1 to expand injection capacity. This will allow us to re- engage the SVS system and the well to operate under normal conditions. This event is an anomaly within Kuparuk and we don't anticipate further requests of this nature. The well is currently injecting 3400 bwpd at pressures below the minimum LPP set point. Your response either by email or phone to our request is greatly appreciated. Regards, Dan Bearden / Darrell Humphrey ConocoPhillips Alaska, Inc. Office (907) 659-7493 NSK-69 7/26/2010 Page 1 of 1 • Schwartz, Guy L (DOA) From: Packer, Brett B [J.Brett.Packer@conocophillips.com] Sent: Friday, June 11, 2010 3:51 PM To: Schwartz, Guy L (DOA) Subject: 1 D-03 (PTD#179-084) CANCEL request for BOP test extension Guy, Just disregard anything I've said in the last several hours. Apparently the guys on the slope were mis-diagnosing the problem and they have since moved the RBP to a different depth and the BOP test is now passing with perfect straight lines on the chart recorder for all the VBR's/pipe rams, Blinds and Annular. Apparently they think the RBP element was placed across a collar and not sealing completely rather than the IC packoffs leaking. Sorry for all the confusion, I'm ready for a beer, have a good weekend. ,~ Brett Backer ~Dril&ng ~'WeQs ~WmfQver~Engineer 4Nork# (907) 265-6845 CelZ'# (907) 230-8377 ~;,. 8/12/2010 • Page 1 of 1 Schwartz, Guy L (DOA) From: Packer, Brett B [J.Brett.Packer@conocophillips.com] Sent: Friday, June 11, 2010 11:14 AM To: Schwartz, Guy L (DOA) r: Subject: FW: 1 D-03 Weekly BOP Test extension ~/J l 7 ~ - ~ Guy, Our Nordic 3 rig is on standby waiting on a response from the AOGCC reps on the slope. We've run into complications with the BOP test because we have a know IC packoff leak. Plans are to change out the tubing head and packoffs anyway, but it just so happens because of our fishing operation for the past couple days, we weren't able to do the wellhead work before our 7 day BOP test. We are looking fora 3 day extension to run the completion and complete the tubing head and packoffs change out. Your quick response would be greatly appreciated. Thanks!!! Brett seack~r ~Dn~ng s'C'Wetis 'Workor~er~Engineer 'Wol~,# (907) 265-6845 ~ r~ ~ CeQ# (907) 230-&377 ~ '~ ! +,i ! ~~ ' ~:;, From: Nordic 3 Company Man Sent: Friday, ]une il, 2010 i1:D2 AM To: Packer, Brett B Subject: iD-03 Weekly BOP Test extension GUyS, We are 1 D-03 and We have been in the process of attempting to do our weekly BOP test since 01:30 on 6- 11-10. We have isolated and tested our surface equipment -passing test. We have set a Baker G-6 RBP @ 6' from surface in attempt to test our Rams and Annular against, The Blind ram low test of 250 -passed, but on the high test of 3,000 we are getting a minor leak of 80 psi in 8 minutes. The pre-rig integrity test shows that we have an inner casing pack off leak. But we have run into some minor set backs with this being an out dated McEvoy Gen I design. 1) There is no test plug available for this 11" Gen I McEvoy design. 2) The Elements on the original TBG hanger pulled from the well are damaged beyond repair with no replacement elements available. The program calls to change out the McEvoy GI 11" 3M x 11" 3M TBG spool and ICP to a McEvoy Gen IV 7 1/16" 5M x 11" 3M Spool. This would be done after we RIH w/ 3 1/2" Completion string and seta 7" Storm packer below surface. We currently have CA-2 plug set in a profile nipple @ 7,339' with Sea water as KWF -tested @ 500 psi after being set. We have had no fluid losses after the plug set in place. We had a passing Initial BOP test on 6-3-10. For these reasons we are asking fora 3 day extension on the weekly BOP test starting on 6-11-10 thru 6-14-10. Thanks, Randy Dolcater /Lee Hinket Office Phone - 659-7446 Cell Phone - 943-1096 6/11/2010 WELL LOG TRANSMITTAL To: Alaska Oil and Gas Conservation Comm. Attn.: Christine Mahnken 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: Radial Cutting Torch Record: 1D-03 Run Date: 6/7/2010 June 10, ZO10 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of Rafael Barreto, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 1 D-03 Digital Data in LAS format, Digital Log Image file 1 CD Rom 50-029-20408-00 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline & Perforating Attn: Rafael Barreto 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907-273-3527 Fax: 907-273-3535 rafael.barre i ,cad ~ ~h ~ ,~ . Date: ~ ~~ ~~ ~ °~ ~L! ~ Signed: ,, • WELL LOG TRANSMITTAL To: Alaska Oil and Gas Conservation Comm. Attn.: Christine Mahnken 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: Radial Cutting Torch Record: 1D-03 Run Date: 6/5/2010 June 10, 2010 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Rafael Barreto, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 1D-03 Digital Data in LAS format, Digital Log Image file 1 CD Rom 50-029-20408-00 j~V ~, ~,r 't1iC+ ~{~~ Fri PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline & Perforating Attn: Rafael Barreto 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907-273-3527 Fax: 907-273-3535 rafael.b ' 4 ~ Date: _' ~~ ~ ~ ~ ?'l' '~ • /~'`~~~y <9~S ~~~ Signed: STATE OF ALASKA ALASKA AND GAS CONSERVATION COMMISS~ REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Abandon ~"` Repair w ell Plug Fbrforations ~" Stimulate ~` Other '°" Alter Casing Pull Tubing i~ Perforate New Pool Waiver Time Extension Change Approved Program Operat. Shutdown (-" Perforate "` Re-enter Suspended Well ~°"` 2. Operator Name: 4. Current Well Status: .Permit to Drill Number: ConocoPhillips Alaska, Inc. Development ~ Exploratory ~""" 179-084 3. Address: Stratigraphic ~' Service .API Number: P. O. Box 100360, Anchora e, Alaska 99510 50-029-20408-00 7. Property Designation: 8. Well Name and Number: ~ ADL 25650 1 D-03 9. Field/Pool(s): Kuparuk River Field /Kuparuk River Oil Pool 10. Present Well Condition Summary: Total Depth measured 8070 feet Plugs (measured) 7339 true vertical 6836 feet Junk (measured) None Effective Depth measured 7990 feet .Packer (measured) 7163, 7301 true vertical 6769 feet (true vertucal) 6085, 6203 Casing Length Size MD TVD Burst Collapse CONDUCTOR 80 16 80 80 SURFACE 2904 10.75 2904 2708 PRODUCTION 8057 7 8057 6825 o.~ s ~~~~ ~~i ~ ~ W ~.1 ~.. .}. ~ L l f° ~ v Perforation depth: Measured depth: 7422'-7519', 7525'-7531', 7539'-7545', 7556'-7567', 7778'-7798', 7808'-7832' True Vertical Depth: 6305'-6384', 6389'-6394', 6400'-6405', 6414'-6422', 6594'-6610', 6619'-6638' Tubing (size, grade, MD, and TVD) 3.5, L-80, 7255 MD, 6164 TVD Packers & SSSV (type, MD, and TVD) PACKER -BAKER 3 1/2" X 7" FHL RETRIEVABLE PACKER @ 7163 MD and 6085 TVD PACKER -BAKER 'FHL PACKER @ 7301 MD and 6203 TVD >~~~~~~~ NIPPLE - 3 1/2" x 2.875" Camco DS Nipple @ 498 MD and 498 TVD 11. Stimulation or cement squeeze summary: , ~ ~ 20~Q j ! E' ., _ < Intervals treated (measured): 110t applicable Treatment descriptions including volumes used and final pressure: ~' ~f ~~;~ ,~ ~;;,~ ~~~~~ ~DIi1l111SSj0 t5 12. Representative Daily Average Production or Injection Data " Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 476 3732 3524 -- 203 Subsequent to operation si 13. Attachments 14. Well Class after proposed work: Copies of Logs and Surveys run Exploratory """ Development Service 15. Well Status after work: Oil Gas WDSPL Daily Report of Well Operations XXX GSTOR ~` WAG GASINJ "` WINJ SPLUG 16. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: 310-158 contact Brett Packer ~ 265-6845 Printed Name Brett Packer Title Wells Engineer Signature ~~ Phone: 265-6845 Date~~~~~~ Form 10-404 Revised 7/2009 ~8~5 .~~ 0 ~ .~ ~, 7 ~~~~Submit Original Only ~' ~/~~v ~~ KU P Corto'cQPh~{t~~}s ~ ~ + WeII Attributes ~ ~ _,; 1 - Wellbore API/UWI Field Name ' f ~. 500292040800 .KUPARUK RIVER UNIT Comment ~.H2S (ppm) Date - - ` SSSV: NIPPLE 50 8!7/2009 W&I COnfi 1003, 6/t9/10 .. ~ SUemeB Actu ~ - e al i A otation De th ftKB End Date Annotation P ( ) Last Tag: SLM ~' 7 480.0 ~I 1/22/2009 Rev Reason' HANGER. 27 --- LaSI~-Strip s " -- Casing Descri ption ( 'String O._ String lD._ TOp (ftKB) CONDUCTOR 16 15.060 32.0 ( Casing Description _ String 0... String ID ... Top (ftKB) iSURFACE 10 3/4 9.794 31.2 .3 Casing Description 'String O.-. String ID ... _ Top (ftKB) 'PRODUCTION 7 6.151 26.9 ' Tubing Strings - "~ Tubing Descr ption _ '.String O... String lD ... TOp (ftKB) CONDUCTOR,_ _ TDBING ( 31/2 2.992 27.6 32-80 Com letion De tails Top Depth ~ (ND) Top lncl NIPPLE, d98 - Top (ftK81 (ftKB) (°) Item n i~~i~oii SURFACE, 31-2,904 GAS LIFT, ],051 ~ 1 D-03 Max Angle & MD TD Status Incl (°) MD (ftKB) Act Btm (ftKB) 1Di 42 87 I 3 050 00 8 070.0 i End Date KB-Grd (ft) Rig Release Date 38.99 12/30/1979 Last Mod ... Entl Date R Imosbor ~ 6/19/2010 Set Depth (ND) .. Str rig WI... i Strmg .. String Top Thrd 80.0 65.00 h140 . Set Depth (ND) .. Str rig WI.-. Sh rig String Top Thrtl 2,708.1 45.50 K-55 Buttress Set Depth (ND) ... String Wt... String _ String Top Thrtl 6,825.5 26.00 K-55 BTC Set Depth (ND) ... String Wt... String ._ String Top Thrd 6.164.3 9.30 L-80 EUE Srd - M 4y/.`J 4`J /.`J U.IS NIYYLt ~JI/L"XL.tS/5-l:amCO VJ NIpple L.8/J 7,136.2 6,061.0 28.76 LOCATOR iSeal Assembly Locator 7.32'spaceout off NO-GQ 2.990 - 7,143.6 6.067.4 28.91 . PBR 'Polish Bore Receptacle I 3 000 - 7,163.3 6,084.9 29-31 - _ ---___ PACKER ~iBaker 3 1/2" x 7" FHL Retrievable Packer __ 2.910 7,206.2 6,122.2 30.19 - - - __ NIPPLE 3 1/2" x 2.812" Camco DS Nipple wIRHC Plug _- - 2.812 7,247.0 6,157.1 31 03 OVERSHOT (Baker Poorboy Tubing Stub Overshot (swallow 6.03-ft) 3.630 Tubing Des cription String 0 ... !Str rig ID ... Top (kK6) Set Depth (f... Set Depth (ND) .. String Wt... Str g ... String Top Thrd TUBING O r gnal 'i 3 1/2 _ _ -2 992. _ 1. .7,250.0 I J,345.5 - I - 6,240.6 _ 920. _ I K 55 1.-. _BTC Comple '~ ( tion Details TOP Depth/ -....- - -__. -__ - __. (ND) ' Top Incl Nomi... Top (ftKB) (ftKB) (°) Item Description Comment ID (in) 31.53 8 SBR BAKER 3L-1 SEAL BORE RECEPTACLE 2.813 - 7,301.0 ,4 6,20 32.20 PACKER - ___ _ _ BAKER'FHL PACKER 2.890 Incl ). Descriptior PBR, 7,td4 PACKER, 7,163 NIPPLE, ],20fi OVERSHOT, _ - 7,za7 SBR, 7,272 PACKER, 7,301 - PLUG, 7,339 ---. NIPPLE, 7,340 WLEG. 7,345 'op (ftKB) ~ ToP (TVD) Btm (ftKB)!. (ftKB) Btm (TVD) i (ftKB) Zone Date lsb-~~ Type Commend 7,422 7,5191 6,304.9 6,384.1 UNIT D, C-0, 8/4/1980 4.0 IPERF 2 1!8"Enerjet; 0 Deg. Phase 1 D-03 7,445 I 7,460;, 6,323.5 6,335.7 _ -_. UNIT D, C-0, - 12/17/2002 - - 4.0 - RPERF _- -- ---. 21/8" FJ,BH Chrgs, 0 Deg Phase 1 D-03 7,525 7,531 ~~ 6,388.9 6,393.6 C-3, 1D-03 8/2/1980 4.0 IPERF 2 1B"Enerjet; 0 Deg. Phase 7,539 7 545; 6400.0 6404.8 C-2, 1D-03 8/2/1980 4.0 IPERF 2 1/8" Enerjet; 0 Deg. Phase 7,556 7,567. 6,413.5 6,422.3 C-2, 1D-03 &2/1980 4.0 IPERF 2 1/8"Enerjet; 0 Deg. Phase 7,778 7,798 6,593.7 6,610.2, I A-S, 1D-03 8/7/1980 4.0 IPERF 2 118" Enerjet; 0 Deg- Phase i 7,808 7,8321 6 618.5 6,638-3' A-4, 1D 03 _ 8/711980 4 OIPERF 2 1/8" Enerjet; 0 Deg. Phase >timula , tions & Treatme nts ' -.-- - -__ _-__ -~ u -. -- _. _.. __-_ - _ __ Min Top Max Btm Top Depth ~ Bottom Depth ' I li Depth Depth (ND) (TVDI (ftKB) (HKB) (ftKB) (ftKB/ Type Date Comment 7,4220 1 74760 6,304.9 6,348.7 FRAC 12/21/2002C-SAND FRAC Jotes~ General 8 Safet y ~...~-. w/Alaska FRAC, 7,422 RPERF,. 7,465-7,660 IPERF,_ ,~ ],622-7,519 ' IPERF, __ 7 525-7,531 IPERF, 7.539-7.545 IPERF, 7.556-7.567 IPERF, _ _ 7.178-7 796 IPERF, 7,808-7,832 PRODUCTION. 27-8,05] \ TD. 8.070 ~ - Mandrel Details __ ~TOp Depth Top Port (TVO) Incl OD Valve Latch Size TRO Run :n Top (ftKB) (ftKB/ (°) Make Model {in) Serv Type Type (in) (psi) Run Date Co 1 7,050.9 5,986-1 27.71 Camco KBMG 1 GAS LIFT SOV DCK-2 .0.000 0.0 6/13/2010 ~1 D-03 Pre Rig Workover Events DATE SUMMARY 4/2/10 PRE RWO T-POT (PASSED ), T-PPPOT (PASSED ), FT-LDS ALL NORMAL. 5/28/10 ATTEMPT TO PULL 13' ER PATCH @ 5647' RKB. IN PROGRESS. 5/29/10 ATTEMPT TO PULL 13' ER PACKER @ 5647' RKB. PARTED WIRE. RECOVERED ALL WIRE & TOOLSTRING. IN PROGRESS. 5/30/10 PULLED ER PULLING TOOL, UNABLE TO RELATCH W/ STANDARD SPEAR. SET 3.5" RELEASABLE SPEAR @ 5614' SLM. ATTEMPT TO PULL PATCH. APPEARS TO HAVE MOVED PATCH UP 1'. IN PROGRESS. ((SPEAR IS PULLED W/ 3" GR )) 5/31/10 ATTEMPT TO PULL WEATHERFORD ER PKR/PATCH ASS'Y @ 5647' RKB W/ .160 WIRE. NO MOVEMENT NOTICED. RELEASABLE SPEAR STILL IN HOLE. IN PROGRESS. 5/31/10 PULL RELEASABLE SPEAR FROM PACKER @ 5612' SLM. ATTEMPT TO DRIFT PATCH TO 1.69", UNABLE TO PASS @ 5633' SLM. TIGHT W/ 10' x 1.5" STEM @ 5633' SLM. APPEARS TO BE LENGTH ISSUE. PERFORMED SBHP @ 5628' SLM (2395 PSI) & GRADIENT @ 5505' SLM (2389 PSI) CREW C/O. IN PROGRESS 6/1/10 PULLED DV @ 6797' RKB W/ K KICKOVER TOOL. TAGGED LIGHTLY & MEASURED BHP @ 7457' SLM (2491 PSI) & GRADIENT @ 7334' SLM (2483 PSI) DRIFTED THROUGH PATCH ASS'Y W/ 12' OF 1.5" WB & 1.69" SWAGE, HAD TO HIT 2 MEDIUM JAR LICKS DN TO PASS THROUGH & 3 MEDIUM JAR LICKS TO GET BACK THROUGH. READY FOR CTU 6/1/10 ATT MPT TO RUN BAKER 1 Fig IRP, UNABLE TO DRIFT THROUGH WEATHERFORD ER PATCH @ 5669 CTMD, WELL IS FREEZE PROTECTED. 6/1/10 PULL OV @ 4455' RKB. PULL GLV @ 2416' RKB. SET DV's @ 2416' AND 4455' RKB. COMPLETE. 6/5/10 CUT 3.5" TUBING AT 5621' USING RCT-2500-200 CUTTER.. TUBING WAS PLACED IN 10,000 LBS TENSION PRIOR TO CUT. WELL WAS TAKING FLUID AT AN AVERAGE OF 50 BBL PER HOUR. WAITED 1 HOUR AFTER LAST TIME FLUID ADDED TO WELLBORE BEFORE FIRING CUTTER. 6/7/10 TAGGED @ 7334' SLM WITH 2.796" GAUGERING.SET 2.75" CA-2 PLUG @ 7340' RKB.TESTED TBG 500#.GOOD.SET AVA CATCHER SUB ON PLUG.READY FOR ELINE. 6/7/10 PERFORMED 3.5" TUBING CUT AT 7250' WITH RCT-2500-200. TUBING WAS PULLED IN 15,000 LBS TENSION FOR CUT AND USED EMA SYSTEM TO ANCHOR CUTTER. PIPE PULLED HEAVY FOR FIRST FEW JOINTS THEN RETURNED TO STRING WEIGHT. 6/9/10 FISHED JUNK CATCHER ASSY FROM LOST 24' BHA WASH PIPE @ 1156' SLM.RIG FISHED BHA.RAN 2.75" O.D. 40 ARM CALIPER GAMMA RAY/CCL FROM 7249' SLM TO SURFACE. ***Rig Job -Nordic 3*** • Conoc©Phitlips Time Log & Summary Welfview Web RepoKirtg Report Well Name: 1 D-03 Rig Name: NORDIC 3 Job Type: RECOMPLETION Rig Accept: 6/3/2010 3:00:00 PM Rig Release: 6/14/2010 11:00:00 AM `''Time Lo s Date From To Dur S. De th E. De th Phase Code Subcode T Comment 6/03/2010 2a hr Summary Accept Rig. MIRU. Spot support equipment. Berm up equipment. 14:00 19:30 5.50 MIRU MOVE MOB P Move rig mats from 1D-14 and set up on 1 D-03. Accepted Nordic 3 rig @ 1500 hrs. 6-3-2010. Spot Wellhead equipment on mats. Build ramp up to double mats. 19:30 20:30 1.00 MIRU MOVE MOB P Move Rig up onto mats. Center over Wellhead. Level u Ri . 20:30 22:00 1.50 MIRU MOVE RURD P Berm up Rig. Spot and berm up support equipment. Rig up hard lines. 22:00 00:00 2.00 MIRU MOVE RURD P Load Pits with Sea Water. Pick up Lubricator. Pull BPV. Lay down Lubricator. Open Well. Wellhead pressures as follows: Tbg = 2,150 si, IA = 2,100 si, OA = 1,100 si. 6/04/2010 Pressure test lines. Bleed Gas. Kill Well. ND Tree. NU BOPE. Perform intial BOPE test. Pull BPV. 00:00 01:15 1.25 COMPZ WELCTL KLWL P Complete nipple up lines to Tree. PJSM. Test lines at 300/3,000 psi. Notify Security and Pad-Operator that we will be venting Gas to the Kill Tank. 01:15 04:30 3.25 COMPZ WELCTL KLWL P Line up Tubing through Choke. Bleed Gas pressure down 975 psi. Line up on Sea Water down Tubing. Bring Pump on line at 3.0 bpm/1,300 psi. Continue to gradually increase pump rate and while regulating IA pressure through the Choke. 270 bbls pumped. Returns =intermittent gas cut produced fluids. 5.0 bpm. TP = 100 psi. Choke pressure - 150 psi. Close in Choke and bullhead 60 bbls at 5.0 bpm/160 psi. Shut down Pump and leave Well shut in to gauge Kill Tank and off-load Vac Truck with Sea Water. Total Sea Water Pumped = 350 bbls. Total measured return volume to Kill Tank = 63 bbls. Resume pumping at 5.0 bpm/220 psi. No returns after pumping the second hole volume. Total volume pumped the second time 260 bbls. 04:30 07:00 2.50 COMPZ WELCTL RURD P Monitor Well. Well on vacuum- Install BPV. Page 1 of 11 l • Time Lo s .Date From To Dur S. De th E. De th Phase .Code Subcode T Comment 07:00 11:30 4.50 COMPZ WELCTL RURD P ND tree. Troub-e getting flange to come loose between the tree and tubing head, and removing studs. Install test dart in'HP' BPV. 11:30 16:30 5.00 COMPZ WELCTL RURD P NU 11", 5K,BOP w/3 1/2" rams in to and variables in bottom. 16:30 20:30 4.00 COMPZ WELCTL PRTS P Function and PT BOPE to 250/3000 psi, PT annular to 250/3000 psi. Good test. Rig down test equipment. Blow down lines. The State's right to witness the test was waived b B. Noble. 20:30 23:00 2.50 COMPZ RPEOPI THGR P Pick up T-Bar and screw into BPV. Observe gas. Lay down T-Bar. Pump through BPV and load Tubing with 60 bbls of Sea Water. Tubing pressure 0 psi. Screw back into BPV. Pull and la down same. 23:00 00:00 1.00 COMPZ WELCTL CIRC P Make up Landing Joint and screw into Top Drive. Circulate Well with Sea Water to clear gas from the 7" x 3 1/2" Annulus. 6!05/2010 Kill Well. BOLDS. Pull Tubing Hanger off seat. Work Tubing. Unable to shear SBE. RU HES E-line Unit. RIH and cut 3 1/2" Tubing at 5,621-ft. POOH and lay down the 3 1/2" Completion to the cut off stub. Continue to load 3 1/2" Drill Pi a in Pi a Shed. 00:00 01:30 1.50 COMPZ WELCTL CIRC P Continue to circulate Well at 5.0 bpm/100 psi. Total pumped 60 bbls. Close in Tubing. Bring pump on down the 7" x 3 1/2" Annulus at 5.0 bpm130 psi. Bullhead 200 bbls of Sea Water. 01:30 06:00 4.50 COMPZ RPEOPI PULL P Monitor Well on slight vacuum. BOLDS. Pull Tubing Hanaer off seat (hanger was landed in compression) at 40K with no rob! .Work Tubing up to a max of 150K (80% of tubing 114K and 35K Block weight) in an attempt to shear SBR at 7,271-ft. Continue to work Tubing. Call out Halliburton E-Line Unit to cut tubing. Continue to work Tubing up to 150 K. Load and tally Drill Pipe in Pipe Shed. Pump 40 - 50 bbls/hr to keep Well loaded. while waiting for E-Line Unit. 06:00 09:00 3.00 COMPZ RPCOM ELNE P PJSM w/HES crew. RU HES E-line equipment. Attempted to set hanger back down and RILDS but hanger would not go. Stacked out 4" before seating. PU 10K over string wt and set sli s. Page 2 of 11 Q~~:~ ~S ,~u ~~ • Time Lo s .:Date From To Dur S. De th E. De th Phase Code Subcode T .Comment 09:00 11:30 2.50 COMPZ RPCOM ELNE P RIH w/HES 2.5" RCT cutter w/electromagnetic anchor and CCL. On depth with collars above tubiing patch. Cat 3 1/2" tcbinfl ~+6 1' middle of the first full joint above the patch located between 5,606' & 5,636'. POOH w/E-line, set tools aside and lowered u er sheave. 11:30 12:00 0.50 COMPZ RPCOM PULL P PU on tubing and confirm good cut. Up wt 70K w/slight drag. Pulled hanger to floor. Break out and LD same. 12:00 12:30 0.50 COMPZ RPCOM ELNE P RD HES E-line equipment. 12:30 21:30 9.00 COMPZ RPCOM PULL P RU SLB spooling unit for SSSV control line. POOH laving down 3 1/2 " 9.2# BTC ,removing all jewelry, and spooling up control line to the SSSV. Rig down Spooling Unit. Continue to POOH and lay down 3 1/2" Tubing to the cut joint. 3 1/2" Completion recovered to the cut joint as follows: 177 Joints of 3 1/2" 9.2 Ib/ft K-55 BTC Tubing, SSSV (including 34 control line clamps), 3 ea GLM assemblies, and a 14.87-ft cut off stub. The Halliburton RCT cut was good. Top of cut off stump left is at 5,621-ft elmd. 21:30 22:30 1.00 COMPZ RPEQPI PULD P Clear and clean floor. Klck out remaining 3 1!2" Completion Tubing from Pi a Shed. 22:30 00:00 1.50 COMPZ RPEQPI PULD P Load Pipe Shed with remaing 3 1/2" Drill Pi e. Tall same. 6/06/2010 MU 5 3/4" Overshot BHA. RIH to top of 3 1/2" Cut-Off Stump at 5,619-ft dpmd. Latch Fish. Attempted to work and jar SBR free. Release Overshot and POOH. MU External Cutter BHA. RIH. Make outside cut on the 3 1/2" Tubin at 5,667-ft d md. Start TOH. 00:00 02:00 2.00 COMPZ RPCOM PULD P Finish loading remaining 3 1/2" Drill Plpe in Pipe Shed and tally same. Load 4 3/4" Drill Collars in Pipe Shed and tall same. Brin BHA to Floor. 02:00 08:30 6.50 0 COMPZ RPEQPI PULD P PJSM. Make up BHA #1 as follows: 5 3/4" Overshot (3 3/4" catch), Overshot Extention, Top Sub, Lubricated Bumper Sub, Oil Jar, Pump-Out-Sub, 9 ea 4 3/4" Drill Collars, Accelerator Jar. Single in BHA with 3 1/2" Drill Pipe from Pipe Shed. Page 3 of 11 Time Lo s Date From To Dur S. De th E. De th Phase Code Subcode T Comment 08:30 09:30 1.00 5,619 COMPZ RPCOM FISH P Tagged top of fish @ 5619' pipe measurements. Up wt.= 120K Dwn wt = 85K .Swallowed 3' with overshot. Attempted to jar SBR free, jarring @ 100K over string wt & block wt. and pulling up to max of 114K of tubing. Jarred for 1 hr. solid with no movement. 09:30 14:30 5.00 5,619 0 COMPZ RPCOM TRIP P Release overshot & POOH standing back 3 1/2" drillpipe. Break out BHA #1. 14:30 16:00 1.50 0 0 COMPZ RPCOM NUND P Load pipeshed w/Baker tools for outside cut. MU BHA #2 consisting of 6" external cutter, 2jts 5 3/4" wash i e. 16:00 21:00 5.00 0 5,619 COMPZ RPCOM TRIP P RIH on 3 1/2" drill ,ipe,,,. Had to work and rotate from surface down to 400-ft. due to 7" Casin roblems buckling?). Continue from 400-ft down to -800-ft with no problems. Encountered tight problems in the Casing once again from 800-ft down to _1,150-ft. Mixed and bullhead a 20 bbl Safe Lub Pill down the 7" x 3 1!2"Annulus. Continue RIH with no further roblems. 21:00 22:00 1.00 5,619 5,667 COMPZ RPEQPI FISH P Up Weight = 125K. Down Weight = 80K. RTW = 95K. Torque 3 - 4K. Tag top of 3 1/2" Tubing Stump at 5,619-ft dpmd. Swallow the section of Tubing with the Patch Assembly at 5,647-ft. Locate the Tubing Collar at 5,665-ft dpmd. RPMs = 42. ~,_ m ke an outside cut at 5,667-ft in 12 minutes. Blow down To Drive. 22:00 00:00 2.00 5,667 3,550 COMPZ RPEQPI TRIP P Trip out with 3 1/2" Drill Pipe, BHA, and Fish. Standing Drill Pipe back in Derrick. 3,550-ft. U Wei ht = 80K. 6/07/2010 Recover outside cut 3 1/2" Tubing Fish with Tubing Patch inside. TIH with Overshot and 3 1/2" Completion Tbg to 5,667-ft. Latch into old 3 1/2" Completion Tbg. Space out. RU S-line and set CA-2 Plug in D-Nlpple at 7,340-ft. RU E-Line and cut Tb at 7,250-ft. 00:00 02:00 2.00 3,550 64 COMPZ RPEQPI TRIP P Continue to Trip out with Drill Pipe. At 1,500-ft from surface, bullhead a 20 bbl Safe Lub Pill down the 7" x 3 1/2"Annulus. From 1,226-ft- 1,130-ft had overpull throught this area, 15 - 30K. Remainder of TOH had normal string weight. BHA at surface. ..Page 4 of 11 • • Time Lo s Date From To Dur S. De th E. De th Phase Cade Subcode T ,.comment 02:00 03:00 1.00 64 0 COMPZ RPEQPI PULD P L down BHA and Fish. Recovered the 3 1/2" Tubing Stump that was cut with HES RCT Cutter, 1 full Joint of 3 1/2" Tubing with the Weatherford Patch inside, and the 2-ft stub from the next 3 1/2" Tubing Joint below where the outside cut was made. Found one 1/2" hole in the Joint that the Tubing Patch isolated. All 5 Cutter knives on the External Cutter were broken off. Clear and clean floor. 03:00 08:30 5.50 0 0 COMPZ RPEQPI PUTS P Load Pipe shed with 240 Joints of 3 1/2" Completion Tubing. Drift and tally same. Bring next BHA to floor. Read floor. 08:30 14:00 5.50 0 0 COMPZ RPEQPI PULD P MU BHA #3 (5 3/4" x 3 1/2"overshot) and RIH on 3 1/2" EUE tubin . 14:00 14:30 0.50 5,667 5,667 COMPZ RPEQPI OTHR P Up wt = 85K Dwn wt = 65K. Latch onto fish @ 5667', space out for slick line w/10K overpull, set slips. Install salty valve, pump in sub, and xover for slickline. 14:30 15:00 0.50 COMPZ RPEQPI SLKL P PJSM w/HES crew. Rig up slickline for runnin in and settin lu . 15:00 19:30 4.50 COMPZ RPEQPI SLKL P RIH w/2.796" Gauge Ring. RIH w/ CA-2 Plug and set in the D-Nipple at 7,340-ft rkb. Fill hole with Sea Water. Pressure test Plug at 500 psi x 15 minutes and record on chart. Good test. Set Catcher Sub. RDMO S-Line Unit. 19:30 23:30 4.00 COMPZ RPEQPI ELOG P PJSM. MIRU HSE E-Line Unit. Rig up to cut tubing. RIH with RTC Cutter/CCL. Tie into Packer Setting Record (3.5" Weatherford ER Packer) Log dated 03/05/2009. Position Cutter at 7,250-ft elmd. Set Anchor. Cut tubing. Jar anchor free. POOH and stand b . 23:30 00:00 0.50 7,250 7,250 COMPZ RPEQPI OTHR P Fill problems. Working Tubing throu h fill. 6/08/2010 Work stuck Tubing free through Fill and continue to POOH with 3 1/2" Tbg, standing back new completion in Derrick. LD remaining 3 1/2" old Completion Tbg. RTC Cut was perfect. RIH with Washover Shoe/Extensions on 3 1/2" Drill Pipe. Clean out fill and swallow 3 1/2" Stump at 7,250' down to 7,259'. POOH and LD 3 1/2" Drill Pi e. 00:00 01:00 1.00 7,250 7,185 COMPZ RPEQPI OTHR P Worked stuck Tubing through Fill. Release HSE E-Line Unit. 01:00 02:30 1.50 7,185 7,185 COMPZ RPEOPI CIRC P Circulate bottoms up at 4.0 bpm/340 psi from the empty GLM pocket at -6,735-ft. Total Volume circulated = 250 bbls. Blow down To Drive. Page 5 of 11 • Time Lo s Date From To Dur S. De th E. De th Phase Code Subcode T Comment 02:30 11:00 8.50 7,185 0 COMPZ RPEQPI TRIP P Trip out with 3 1/2" Completion Tubing standing back in Derrick. Lay down Overshot BHA. Continue pulling out and single down old 3 1/2" Completion Tubing and Jewelry. Remaing old Completion recovered: External Cut Joint (stump), 47 Joints, 4 GLM Assemblies, and the RTC Cut 16.0-ft Stub. RTC was perfect. The bottom. -50-ft of the string was shinny were we worked it through the fill to get free. Clear and clean floor. Kick out 3 1/2" old com letion i e from Pi a Shed. 11:00 11:30 0.50 0 0 COMPZ RPEQPI SFTY P Held PJSM with Baker fishing hand and ri crew 11:30 12:30 1.00 0 328 COMPZ RPEQPI PULD P PU clean out BHA and 7" CSG Scra er to 328' 12:30 16:00 3.50 328 7,248 COMPZ RPEQPI TRIP P RIH w/ C/O BHA from 328' to 7,248' To of Fish 16:00 19:00 3.00 7,248 7,259 COMPZ RPEQPI WASH P Pump 30 bbl hi visc sweep @ 8 bpm @ 1,710 psi, Wash over TBG stub to 7,259'. Reverse circulate two bottoms up at 6.0 bpm/1,810-ft. Blow down To Drive. 19:00 00:00 5.00 7,259 1,325 COMPZ RPEQPI PULD P POOH and single down 3 1/2" Drill Pipe in Pipe Shed from 7,259-ft. to 1,325-ft. 6/09/2010 Finish laying down 3 1/2" Drill Pipe. Left part of BHA in the Hole. Fishing operations in progress with Slick Line. 00:00 04:00 4.00 1,325 0 COMPZ RPEQPI PULD P Finish laying down 3 1/2" Drill Pipe. Lay down 4 3/4" Drill Collars. Begin to lay down BHA. However, discovered that the TSS connection between the Drive Sub and the Screen Sub Bushing came apart. (Top of Fish left in hole at 7,235-ft, top of 3 1/2" Tubing Stump is at 7,250-ft). Discuss options with BFT Supervisor. Order out Fishing Spear. Clear Kick out recovered BHA. Clear and clean floor. Service Ri . 04:00 06:30 2.50 0 0 COMPZ RPEQPI OTHR P Wait on S-Line. Wait on Fishing Tools. 06:30 07:00 0.50 0 0 COMPZ RPEQPI SFTY P Held PJSM with PDS, HES Slickline crew and Rig crew on rigging up and o erations. 07:00 08:00 1.00 0 0 COMPZ RPEQPI SLKL P RU slick line and MU PDS 40 arm Cali er with CCL and Gamma Ra . 08:00 10:00 2.00 0 0 COMPZ RPEQPI SLKL T MU pack off to 7" Otis Shooting nipple, RIH with slick line to 700' and set down. POOH and lay down PDS Tools. MU and RIH w/ 3.5" OD Fishing magnet to 700' and POOH - No fish. Had centralizer to assy and RIH to 700' and POOH - No fish. Page6of11 l Time Lo s Date From To Dur S. De th E. De th Phase Code Subcode T Comment 10:00 14:30 4.50 0 0 COMPZ RPEQPI TRIP T PU and MU drive sub, RIH to 700' - Attempt to screw in -POOH - No fish. Inspect tool face and Run back in hole and attempt to screw in - pushing down hole, chase to 950', seen weight change -chase down hole to 1,150', while rotating with top drive @ 10 rpm's with 500 - 1,000 ft/Ibs of torque. Seen torque increase to 2,000 ft/Ibs with 5k slack off -POOH from 1,159' - No fish - Shoulderflared and first 1" of threads scarred u . 14:30 18:00 3.50 0 0 COMPZ RPEQPI SLKL T RU slick line and RIH w/ 3.75" OD LIB to 1,153' -spank spang jars and POOH -showed threads on side and top of screen cage along with screen. PU and MU 1.18" OD single prong wireline spear, 1.375" OD X-O, 2.81" x 3.2" OD centralizer, 1.75" OD Quick connect = 32" in length, RIH on Oil jar, Spang Jar and 10' of 1.875" OD sinker bar to 1,150' - PU wt of 200#. RIH and set down @ 1,159' and work spang jars for 20 minutes, PU 100# OSW and let fishing jars bleed. Straight pull to 650# OSW. POOH - No fish -Barbs were sheared. MU 3.75" Tapered centralizer and RIH to 1,100' and get PU wt of 225#. RIH and set down @ 1,155' and work down to 1,158', beat down for 20 minutes -made no hole, PU with no over ull. 18:00 00:00 6.00 0 COMPZ RPEQPI SLKL T RIH w/LIB found top of Screen Cage at 197-ft. POOH LIB inconclusive. RIH with 4-prong grab. POOH no recovery. RIH #2 w!4-prong Grab and push Screen Cage from 197' down to 1,114' Work Spang Jars. POOH. No recovery (two prongs bent outward). RIH with 2-Prong Grab. Push Screen Cage from 1,114' down to 1,155'. Work Spang Jars. POOH (one prong bent at a 90 deg angle. RIH w/3.750" LIB to 1,155'. POOH and study marks. RIH w/2.80" LIB to 1,155'. POOH and study marks. (modify a 4-Prong-Grab with barbs on the outside). RIH w/2.60" Magnet to 1,155'. POOH. No recovery. RIH w/3.625" Magnet to 1,155'. POOH. NO recove 6/10/2010 Recovered Screen Sub Fish with Slick Line tools. Recover remainder of Washover Fish on Tubing. RU Slick Line/PDS. Record Cali er/GR/CCL Lo . Page 7 of 11 l Time Lo s ;: Date From To Dur S. De th E._De th Phase Code Subcode T Comment 00:00 05:00 5.00 0 0 COMPZ RPEQPI SLKL T Continue fishing operations with Slick Llne. RIH with a modified 4-Prong inside/outside Grab to 1,155'. Work Spang Jars. Had a bite. POOH. No recovery. RE-run same to 1,155'. Work Spang Jars. Had a bite. POOH. No recovery. RIH w/Center Grab to 1,155'. POOH. No recovery. RIH with modified 4-prong inside/outside Grab to 1,155'. Work Spang Jars. POOH. Recovered Screen Sub fish, with much= o . Ri S-Line out of the wa . 05:00 17:00 12.00 0 0 COMPZ RPEQPI FISH T Prep to continue fishing with Tubing to retrieve the remaining Washover BHA. Make up Baker Spear BHA with 4.431" grapple. RIH to 1,223', engage fish and POOH -seen 4 to 8k overpull f/ 1,140' to 1,120', Lay down spear and PU 3 - 4 3/4" dc's and rack back while waiting for tools to arrive. PU and MU taper tap and RIH on 3 1/2" TBG to to 1,134' - attempt to engage fish and push down w/ 5k slack off to 1,220' while rotating. POOH - No fish. Lay down Taper Tap while waiting on spear to arrive. PU and MU spear w/ 4.610" Grapple and RIH to 2,159', 50k Up and Dn wt. POOH to 1,160' to 700' seen extra drag, continue to POOH recovered fish. Break down tools and fish. Offload fishin tools. 17:00 23:30 6.50 0 COMPZ RPEQPI SLKL P PJSM.Rig up S-Line and PDS to record Caliper/GR/CCL Logs. Calibrate tool string. RIH. Log well at +/- 50-ft/min from 7,249-ft to surface. Down load and verify data. Ri down S-line Unit. 23:30 00:00 0.50 COMPZ RPEQPI BOPE P Clear and clean Floor. Prep for BOPE test. 6/11 /2010 Perform Weekly BOPE Test. Run 3 1/2" Completion as designed. Page S of 11 • Time Lo s =Date From To Dur S. De th E. De th Phase Code Subcode T Comment 00:00 17:00 17.00 0 35 COMPZ RPEQPI BOPE P Wrong Test Plug sent to location. (Proper test plug not available). Set Baker Model G Loc-Set Bridge Plus 6 -ft below surface. RU test equipment, Testing BOPE @ 250 / 3;000 psi. Attempt to isolate and pin point leak off. Change out Top drive Upper and Lower valves. Test blind rams, had small bleed off of 80 psi in 8 minutes. Check Inner csg Pack off - no leakage, Continue to attempt to Isolate leak -Test LPR's with 3 1/2 Test jt -good test, Test UPR's - Good Test, Test Annular -Good Test, Retest Blind Rams -Good test. Release RBP at 35' and POOH. 17:00 23:00 6.00 0 7,255 COMPZ RPCOM PULD P P_U and RIH w/ 3 1/2" Recomoletion , as follows: Baker Poor-Boy Overshot Assembly, 1 Jt 3 1/2" 9.3 Ib/ft L-80 EUE 8rd Tbg, 2.812" DS Nipple w/ RCM Plug, 1 Jt 3 1/2" 9.3 Ib/ft L-80 EUE 8rd Tbg, Baker 3 1/2" x 7" FHL Packer Assembly, Polish Bore Receptacle Assembly, Seal Assembly 2 Jt 3 1/2" 9.3 Ib/ft L-80 EUE 8rd Tbg, 3 1/2" x 1" GL Assembly, 209 Jts 3 1/2" 9.3 Ib/ft L-80 EUE 8rd Tbg, 2 875" DS Nipple, 14 Jts 3 1/2" 9.3 Ib/ft L-80 EUE 8rd Tbg. Up Weight = 95K. Down Weight = 75K. Pick up Landing Joint and locate the top of the 3 1/2" Tubing Stump at 7,250-ft. Saw the pins shear in the Poor-Boy Overshot. Continue to swallow the Stump to NO-GO. Pick up to neutral weight lus 1-ft. Mark Pi e. 23:00 00:00 1.00 7,255 7,255 COMPZ RPCOM CIRC T Problems loading Vac Truck with Corrosion Inhibited Sea Water. WO Vac Truck to arrive on location. (Vac Truck was called to be on location at 21:00 hrs . 6/12/2010 Circulate Well with corrosion Inhibited Sea Water. Set Packer. Shear Seal Assembly. Hang Completion off with Storm Packer. ND BOP Stack. Snub 7" Casing using 3-ft bolts and allow Casing to grow. Spear Casin .Set Emer enc Sli s. RILDS. Release S ear. Set-u Wachs Cutter to cut off 7" Casin . 00:00 01:30 1.50 7,255 7,255 COMPZ RPCOM CIRC T Continue to wait on Vac Truck to load and arrive on location. 01:30 03:15 1.75 7,255 7,250 COMPZ RPCOM CIRC P Displace Wellbore with corrosion Inhibited Sea Water. at 3.0 bpm/270 si. Total um ed 255 bbls. Page 9 of 11 ~~ '~5 J Time Lo s Date From To Dur S. De th E. De th Phase Code Subcode T Comment 03:15 05:30 2.25 7,255 7,063 COMPZ RPCOM PACK P Re-check tag and pull up to Packer setting depth. Drop Packer setting Ball/Rod and wait for same to go on seat. Pressure up on Tubing and set Packer with 1,800 psi. Bump pressure up to 2,100 psi and test Tubing for 15 minutes. Good. Record the initial tubing test on chart. Packer set with center element at 7,163-ft. Shear Seal Assembly. Pull 3 stands of 3 1/2" Tubing and stand in Derrick. Run a stand of 4 3/4" Drill Collars back in well. Pick up Baker Storm Packer. RIH with Packer and set just below surface. Hang Completion String off for wellhead work. 05:30 06:30 1.00 7,068 0 COMPZ RPCOM NUND P Drain stack 06:30 08:30 2.00 0 0 COMPZ RPCOM SFTY P Conduct man down drill in the cellar with Kuparuk Emergency Services and Ri crew. 08:30 10:30 2.00 0 0 COMPZ RPCOM NUND P ND BOPE and TBG Spool 10:30 18:00 7.50 0 0 COMPZ RPCOM NUND P PU and MU new TBG Spool with 3' studs and BOLDS, Back off studs allowin 7" CSG to row. 18:00 00:00 6.00 0 COMPZ RPCOM NUND P Continue to snub 7" Casing with 3 foot studs as it "grows". Total "growth gained = 11 1/2 inches at midni ht. 6/13/2010 Spear Casing. Set Emergency Slips. Release Spear. Cut Casing. Install 5K Tubing Head. NU BOPE. Pull Storm Packer. Land 3 1/2" Com letion and test. ND BOPE. 00:00 03:30 3.50 0 0 COMPZ RPCOM NUND P Completed snubing the 7" Casing out with 3-ft bolts, as it grows (17 1/2"). Rig down equipment and clear Cellar. Make u Casin Sear 03:30 04:30 1.00 0 COMPZ RPCOM NUND P Spear 7" Casing. _Pick up on Casing 12 more inches to begin over pull. Total Casing growth = 29.5". Continue to pick up on Casing. Set Emergency Slips. Land Casing in 65K tension. Note due to a Collar right under the Slips this was the best we could do. RILDS. Release S ear and la down same. 04:30 06:00 1.50 COMPZ RPCOM OTHR P Set up Wachs Cutter and cut off Casin . 06:00 09:30 3.50 COMPZ RPCOM NUND P Install Inner CSG pack off and NU 7 1/16" 5M x 11" 3M TBG Spool. Test PO and void @ 3,000 psig for 15 minutes. 09:30 13:00 3.50 COMPZ RPCOM NUND P NU BOPE a ui ment. 13:00 16:00 3.00 COMPZ RPCOM BOPE P Install 7 1/16" Test plug, Shell test BOP @ 250/3,000 psi. with 3 1/2 Test jt. -Good Test. Pull Test plug and RD test a ui . Page 10 of 11 ' ~~ Time Lo s .Date From To Dur S. De th E. De th Phase Code Subcode T Comment 16:00 16:30 0.50 7,035 7,000 COMPZ RPCOM MPSP P RIH and rel ase Baker sto 35' and POOH and la down the same. 16:30 19:30 3.00 7,000 7,155 COMPZ RPCOM TRIP P Continue to RIH w/ 3 1/2 TBG completion from 7,000' to 7,147-ft. Up Weight = 90K. Down Weight = 80K. No-Go out on the 3 1/2" Tubing Stump at 7,150-ft. Space out. Make up Tubing Hanger. Land same. RILDS. 19:30 22:30 3.00 COMPZ RPCOM PRTS P Rig up test equipment. Pressure up on the Tubing to 3,000 psi x 15 minutes (IA = 0 psi, OA = 20 psi). Good test. Bleed TP down to 2,250 psi. Pressure up on the 7" x 3 1/2" Annulus to 4,000 psi x 30 minutes (TP = 2,800 psi, OA = 20 psi) Good test. Bleed Annulus pressure to 0 psi. Bleed Tubing pressure to 0 psi. Bring pressure up on the Tubing and shear the SOV at 1,450 psi. All test were recorded on Chart. Pump through the SOV to confirm communications. Rig down test e ui ment. 22:30 00:00 1.50 COMPZ RPCOM NUND P Set Check Valve. Nlpple down BOP Stack. 6/14/2010 Complete ND BOPE. NU Tree and test at 5K: Pull Check Valve. Freeze Protest Well. Install BPV. Secure Cellar. Release Nordic Ri 3 11:OO~hrs. RDMO. 00:00 01:30 1.50 COMPZ RPCOM NUND P Complete nipple down BOP Stack and set back on Stum . 01:30 04:30 3.00 COMPZ RPCOM NUND P Nlpple up Mc Evoy Tubing Head Adaptor. Test Hnger void at 5,000 psi x 15 minutes. Good test. Nipple up 3 1/8" x 5K Tree. Test Tree at 5,000 psi x 10 minutes. Record test on Chart. 04:30 07:30 3.00 COMPZ RPCOM FRZP P PJSM. Spot Lil' Red Hot Oil Unit. Freeze protect Well with 93 bbls Diesel at 2 bpm @ 625 psi ICP and 825 FCP. U-Tube Diesel. 07:30 11:00 3.50 COMPZ RPCOM MPSP P Attempt to dry rod, well returning fluid, RU lubricator and lub in BPV. RD Lubricator. Secure well, 10 psi TBG, 50 psi IA, and 0 psi OA. Release Nordic Rig 3 @ 11:00 hrs on 6-14-10 Page 11 of 11 ,~ ~~ ~~, PROACTIVE DIAtINOSi1C SEmncES~ roc. A~~ L To: AOGCC Christine Mahnken 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 (907) 659-5102 ~, ~ r ~~ 5 ~ ' , ' ~ a i x ;R ~~~ ?, ~~, ~ ~~~.;. RE : Cased Hole/Open Hole/Mechanical Logs and /or Tubing Inspection(Caliper/ MTT) The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the following ProActive Diagnostic Services, Inc. Attn: Robert A. Richey 130 West International Airport Road Suite C ~ ~ ~.4 ~ ~,, ~ ~;, Anchorage, AK 99518 ``~" ~~ ~' ~ "J '' ~~ ~ l _ ~ ~ Fax: (907j 245-8952 1) Caliper Report 09,Jun-10 1D-03 1 Report j EDE 50-029-20408-00 2) s l~~o~~. `~ . ~ .~ ~ g ~~~-~ ~Ull ~ ~ )~1r? Signed : L~--%~ Date Print Name: O e'#C . PROACTIVE DIAGNOSTIC SERVICES, INC., 130 W. INTERNATIONAL AIRPORT RD SUITE C, ANCHORAGE, AK 99518 PHONE: (907)245-8951 FAX: (907)245-88952 E-dlAll.: ~dsaneltoracteCa7~aaem®rylog.com WEBSITE : •rvwrw.merraOrylOq.~om CiDocuments and Settings\Diane Williams\Desktop\Transmit_Conoco.docx • Memory Multi-Finder Caliper Log Results ~ummar Company: ConocoPhillips Alaska, Inc. Well: 1 D-03 Log Date: June 9, 2010 Field: Kuparuk ', tog No.: 't0835 State: Alaska Run No.: 2 API No.: 50-029-20408-00 Pipet Desc.: 7" 26 Ib. K-55 Top Log Intvl1.: 41 Ft. (MD) Pipet" Use: Production Casing Bot. Log Intv11.: 7,23J Ft. (Mf3j ' Inspection Type : Corrosive $ Mechanical Damage Inspection ' CC7MIVIEiVTS This caliper data is correlated to the Scitlumberger Leak Detection Log dated February 5, 2009. ' This I"og was run to assess ttie condition ofttie production casing with respec~tto corrosive: and rneclian'ical damage. The caliper recordings indicate the 7" production casing logged appears to be in good to poor condition, with a maximum recorded wall penetration of 55% in joint 162 (6,784'). Recorded damage appears as scan-eyed- prating: Altftot)gti the majority"of-the prodiic~on casing logged appears Fo lie in good" ' condition, wall penetrations ranging from 20% to 55% wall thickness are recorded in 7 of the 177 joints logged. No significant areas of cross-sectional wall loss or I.D. restrictions are recorded throughout the produoti"on casir-g logged. ' The caliper recordings indicate buckling from 41' (top of interval logged) to _2,035'. This is the second. time a"PDS caliper has been-run- in"this well and-the first-time the 7" production-casing-has _ been logged. MAXIMUM RECORDED WALL PENETRATIONS: lsolal;ed prtt"ing (55°l0)" Jt. 't67 @" 6,784 Ff~ (MD) Isolated pitting (38°~) Jt. 133 @ 5,620 Ft. (MD) Isolated pitting (26%) Jt. 143 @ 6,017 Ft. (MD) Isolated pitting (25%) Jt. 62 @ 2,624 Ft. (MD} Isolated pitting (22%) Jt. 130 @ 5,489 Ft. (MD) NtAXFMUM REEORDEfr CRE}3:Y-SECTtOi+tAt METAL LOSS: No significant areas of cross-sectional wall loss (> 12%) are recorded throughout the production casing logged. MAXIMUM RECORDEE} iE} RESTRI~TiONS: No significant I.D. restrictions are recorded throughout the production casing fogged. Field Engineer: G. Etherton & E. Gustin Analyst: C. Waldrop Witness: L. Hinkle & R. Dolcater ProActive Diagnostic Services, Inc. / P.O. Box 1369; Stafford, TX 77497 Phone: (281) or {88$) 565-9085 Fax: (281) 565-1369 E-mail: PDS`a!memorylog.com Prudhoe Bay Field Office Phone: {907) 659-2307 Fax: {907) 659-2314 i • Correlation of Recorded Damage to Borehole Profile Pipe 1 7. in (40.9' - 7217.9') Well: 1 D-03 Field: Kuparuk Company: ConomPhillips Alaska, lnr.. Country: USA Survey Date: June 9, 2010 A pprox. Tool De viation A pprox. 1 3oretx~l e Profil e 1 41 25 1030 50 2070 75 3157 ~ v ~ .~ Z ~ ' o ~ ~ 100 J 4246 125 i 5274 9 15f1 6268 173 7218 0 5 0 1 00 Da mage Pr ofile (% wall) / Tool D eviatio n (degr ees) Bottom of Survey = 173 PDS Report Overview ry.. ~,. Body Region Analysis Well: 1 D-03 Survey Date: June 9, 2010 Field: Kuparuk Tool Type: UW MFC 40 Ext. No. 218451 Company: ConocoPhillips Alaska, Inc. Tool Size: 2.75 Country: USA No. of Fingers: 40 Anal st: C. Waldro Tubing: Nom.OD Weight Grade & Thread Nom.ID Nom. Upset Upper len. Lower len. 7 ins 26 f K-55 6.276 ins 7 ins 6.0 ins 6.0 ins Penetration and M penetration body etal Loss (% wall) metal loss body 200 150 100 50 0 0 to 1 to 10 to 20 to 40 to over 1°/ 10% 20% 40% 85% 85% Number of ~oints anal s ed total = 177 pene loss . 0 161 11 61 115 1 4 1 0 0 0 0 Damage Configuration (body ) 20 10 0 isolated general line ring hole /pons pitting corrosion corrosion corrosion ible hole Number of ~oints dama ed total = 19 19 0 0 0 0 Damage Profile (% wall) r penetration body ;• metal loss body 0 50 1 51 Bottom of Survey = 173 • 100 97 147 Analysis Overview page 2 • PDS REPORT JOINT TABL Pipe: 7. in 26.0 ppf K-55 Well: Body Wall: 0.362 in Field: Upset Wall: 0.362 in Company: Nominal I.D.: 6.276 in Country: Survey Date: • iLATION SHEET 1D-03 Kuparuk ConocoPhilGps Alaska, Inc. USA June 9, 2010 Joint No. Jt Depth (Ft.) I'e~n. t-1{~sf~~ ±In~.~ Pen. Body (Ins.) Pen. °/> :Metal loss °~~ Min. LD• (Ins.) Comments Damage Profile (%wall) 0 50 100- 1 44 O 0.01 3 I 6.24 Bucklin . 2 74 U 0.01 1 6.24 3 117 t) 0.01 ~ 1 6.23 4 159 t~ 0.01 I 6.22 5 197 i) 0.03 a 6.21 6 238 t) 0.01 ~, I 6.23 Bucklin . 7 280 0.01 1 6.23 8 321 a 0.01 4 6.26 9 359 a 0.02 7 ~ 6.24 10 401. U _ 0.0.1. _ 3 _1 _- 6.23 11 443 n 0.02 7 ~ 6.23 Bucklin . 12 486 t~ 0.03 7 ~ 6.24 13 528 !~ 0.03 7 -1 6.24 14 570 +) 0.01 3 I 6.24 15 611 U 0.02 6 ; 6.24 16 653 t} 0.01 3 1 6.24 Bucklin . 17 695 a 0.01 4 ? 6.24 ~ 18 738 U 0.01 S I 6.24 19 779 0 0.01 3 1 6.23 20 821 U 0.01 4 6.23 21 862 t) 0.03 -4 6.23 Bucklin . 22 903 t) 0.01 -1 6.24 23 945 a 0.02 6 3 6.23 24 986 t~ 0.01 ; I 6.23 25 1030 t) 0.01 ~ 1 6.24 26 1072 i) 0.02 ~ 6.23 Bucklin . 27 1115 ~) 0.02 7 3 6.32 28 1153 U O.D1 4 ? 6.24 29 1191 U 0.03 7 4 6.24 30 1233 U 0.03 7 -1 6.23 31 1275 t) 0.01 3 ~' 6.26 32 1318 O 0.02 G ~ b.21 Bucklin . 33 1357 U 0.02 b ~ 6.23 34 1399 a 0.02 6 6.26 35 1442 U 0.01 4 ? 6.24 36 1484 a 0.02 6 ~ 6.27 37 1528 (~ 0.02 6 6.24 Bucklin . 38 1569 t) 0.01 4 Z 6.22 39 1610 .) 0.01 4 ? 6.23 40 1652 i1 0.01 4 6.24 41 1692 t> 0.01 4 ~ 6.25 42 1733 U 0.01 3 i 6.24 Bucklin . 43 1774 O 0.01 I 6.28 44 1817 i ~ 0.02 c> 6.2 9 45 1860 t) 0.03 7 -+ 6.29 46 1901- E) 0.02 b 6.30 47 1944 t) 0.03 7 ~ 6.27 48 1985 (~ 0.01 4 ~ 6.27 Bucklin . 49 2028 t7 0.02 6 6.28 50 2070 t> 0.01 ~ 1 6.27 _ Penetration Body Metal Loss Body Page 1 • PDS REPORT JOINT TABI, Pipe: 7. in 26.0 ppf K-55 Well: Body Wall: 0.362 in field: Upset Wall: 0.362 in Company: Nominal I.D.: 6.276 in Country: Survey Date: • iLATION SHEET 1D-03 Kuparuk ConocoPhillips Alaska, Inc. USA June 9, 2010 Joint No. )t. Depth (Fk) Pen. l ll,tir~t f,in~.; Pen. Body (Ins.) Pen. %, Mortal I ~xs ~~ Min. LD• (Ins.) Comments Damage Profile (%wall) 0 50 100 51 2113 t) 0.03 7 -i 6.22 52 2153 )) 0. 3 7 4 6.22 53 2196 a 0.03 7 -1 6. -1 53.1 2236 )! 0.03 7 -i 6.24 PUP 53.2 2257 O 0 t) t) N A 7" Halco Cementer 53.3 2260 l! 0.03 - 4 6.23 PUP 54 2282 i) 0.03 ? 6.21 54.1 2317 i J 0 t) t ~ N A 7" Baker Model " " Sta e Collar 54.2 2319 u 0 Cl t> N A 7" L nos Ex. Casin Packer 55 2327 t) 0.03 t3 i 6.21 56 2370 t) 0.03 7 -i 6.21 57 2410 t) 0.03 i 7 6.22 58 2449 U 0.03 i -k 6.24 59 2490 t) 0.02 7 6.23 60 2532 t+ 0.03 - -: 6.23 61 2574 )? 0.03 1 6.19 62 2615 t) 0.09 5 6.21 Isolated ittin . 63 2657 l) 0.03 =t 6.22 64 2699 r? 0.03 7 4 6.21 - 65 2741 U 0.02 b ~ 6.21 66 2781 ~? 0.02 7 I 6.21 67 2823 t! 0.02 ~ 6.23 68 2864 i 1 0.02 7 6.19 69 2904 !,i 0.01 ~ I 6.21 70 2945 U 0.02 6.21 71 2988 U 0.03 7 -t 6.19 72 3030 U 0.01 3 I 6.21 73 3072 t) 0.01 > i 6.29 74 3114 ~~~ 0.01 ; I 6.29 75 3157 n 0.01 .t Z 6.27 76 3198 t) 0.01 > 1 6.24 77 3240 i) 0.01 9 I 6.24 78 3282 U 0.01 1 6.29 79 3324 t) 0.01 I 6.25 80 3366 t> 0.01 ~ I 6.27 81 3409 t t 0.01 ~ I 6.24 82 3450 t 1 0.01 3 i 6.25 83 3490 U 0.01 ~ i 6.20 ' 84 3532 t? 0.02 (> 6.25 ~' 85 3573 !? 0.01 4 6.22 86 3614 U 0.02 U i 6.21 87 3658 U 0.02 6 6.21 88 3699 t) 0.01 4 ~ 6.25 89 3741 C) 0.01 4 _' 6.22 90 3780 t) 0.02 6 ~ 6.20 91 3820 U 0.03 - -~ 6.21 92 3864 t) 0.01 6.23 93 3905 U 0.02 6 6.24 94 3946 U 0.02 ~ 6.23 95 3988 t) 0.01 3 I 6.23 ` _ Penetration Body Metal Loss Body Page 2 • PDS REPORT JOINT TABS Pipe: 7. in 26.0 ppf K-55 Well: Body Wall: 0.362 in Field: Upset Wall: 0.362 in Company: Nominal I.D.: 6.276 in Country: Survey Date: • )CATION SHEET 1D-03 Kuparuk ConocoPhillips Alaska, Inc USA tune 9, 2010 Joint No. Jt. Depth (Ft.) Pen. Ul~sc~l (Ins.) Pen. Body (Ins.) Pen. % Metal loss ",~~ Min. LD• (Ins.) Comments Damage Profile (%wall) 0 50 100 96 4031 ~) 0.03 8 1 6.21 96.1 4073 n 0.03 7 4 6.25 Marker Dint 9.6.2 4094 n 0.01 4 6.25 Marker Dint 97 4117 t~ 0.07 ~'i) t 6.19 Shallow ittin . 98 4159 i~ 0.02 6.26 ~' 99 4203 t) 0.02 !> 6.21 100 4246 i t 0.03 7 -1 6.19 101 4289 a 0.03 f3 1 6 20 102 4325 t) 0.02 b 6.19 .__103 .. ...4366 _ _t1 0.03_ i _ ..._.6.20 _ _ 104 4407 n 0.03 -t 6.19 105 4450 i) 0.01 4 ? 6.22 106 4493 (> 0.03 7 -J 6.20 107 4535 i) 0.03 7 -i 6.20 108 4577 i'~ 0.02 6 6.24 109 4616 a 0.01 4 6.23 110 4657 U 0.03 7 ~ 6.27 111 4694 i> 0.03 7 -t 6.20 112 4735 ~) 0.01 3 6.23 113 4777 i) 0.03 7 -i 6.19 114 4818 i) 0.03 tt I 6.17 115 4862 t! 0.02 7 ~ 6.20 116 4903 !) 0.02 6 3 6.24 117 4946 O 0.03 7 ~ 6.20 118 4986 U 0.01 ~ J 6.17 119 5028 c) 0.01 4 6.22 120 5071 t ~ 0.01 4 6.20 121 5112 !~ Q03 7 1 6.21 1 2 5154 i ~ 0.01 ) I 6.21 123 5193 a 0.01 3 1 6.25 124 5236 i) 0.01 1 6.25 ~ 125 5274 U 0.01 I 6.24 126 5314 ~> 0.04 1U 5 6.23 Shallow ittin . 127 5351 t ~ 0.01 ~ 1 6.25 128 5390 c ~ 0.01 4 6.24 129 5431 i ~ 0.01 ~1 ~~ 6.25 130 5472 t) 0.08 L2 6.23 Isolated ittin 131 5514 a 0.07 1U !t 6.25 Iso ated ittin . 132 5556 i? 0.05 1 . 6.26 Shallow ittin . 133 5596 !~ 0.14 >8 ! 6.25 Isolated ittin . 134 5637 U 0.04 1 Z 6.25 Shallow ittin . 135 5678 t) 0.02 b r 6.24 136 5719 O 0.05 14 1 6.26 Shallow ittin . 137 5759 i) 0.04 11 1 6.23 Shallow ittin . 138 5801 !) 0.03 7 1 6.24 139 5843 0:01 3 6.21 140 5883 0.05 13 6.25 Shallow ittin . 141 5920 ;) 0.03 t5 6.22 142 5957 c i 0.01 s f 6.23 143 5996 !' 0.10 1E~ I.' 6.30 Isolated ittin . _ Penetration Body Metal Loss Body Page 3 PDS REPORT JOINT TABI. Pipe: 7. in 26.0 ppf K-55 Well: Body Wall: 0.362 in Field: Upset Wall: 0.362 in Company: Nominal I.D.: 6.276 in Country: Survey Date: • iLATION SHEET 1D-03 Kuparuk ConocoPhillips Alaska, Inc USA June 9, 2010 Joint No. Jt. Depth (Ft) Pen. Up>~~t {Ins.) Pen. Body (Ins.) Pen. `% ~~letaf I oss °i~, Min. LD• (Ins.) Comments Damage Profile (% wall) 0 50 100 144 6033 C) 0.01 4 1 6.24 145 6068 U 0.07 19 ? 6.26 Shallow ittin 146 6102 [? 0.05 13 1 6.21 Shallow ittin . 147 6140 l) 0.03 7 6.17 148 6182 O 0.01 ~ I 6.21 149 6225 t? 0.06 15 6.19 Shallow ittin . 150 6268 ~? 0.05 1.~ 6.20 Shallow ittin . 151 6310 i) 0.03 7 1 6.20 152 G352 ~? 0.02 7 6.19 --1.53. ._..6394 _ _ ~ D.0 _7 __ ]_ -. ._6.1.8 154 6437 ~? 0.03 7 4 6.20 155 6478 i) 0.03 7 -1 6.18 156 6520 i? 0.03 7 1 6.18 ~ 157 6562 i) 0.02 7 3 x.19 158 6602 t1 0.03 7 4 6.19 ~ 159 6644 i) 0.01 3 1 6.17 ~ 160 6685 t) 0.02 6 6.17 161 6727 ~? 0.02 6 ~ 6.17 162 6769 a 0.20 55 ~' 6.17 Isolated ittin . 163 6812 !? 0.01 i I 6.19 164 6853 i? 0.03 7 1 6.17 165 6893 i) 0.03 7 ~ 6.16 166 6933 L) 0.04 I U 5 6.18 Shallow itlin . 167 6976 U 0.01 ~ I 6.21 168 7015 U 0.04 10 5 6.27 Shallow ittin . 169 7054 i) 0.01 3 I 6.22 170 7094 i) 0.03 7 ~ 6.24 171 7136 (? 0.01 3 I 6.21 172 7176 l) 0.01 ~i 1 6.22 ° 173 7218 a 0.01 a _' 6.21 __ Penetration Body Metal Loss Body Page 4 ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ^~ ~ ~ ~ ~ r ~ ~ - PDS Report Cross Sections Well: 1D-03 Survey Date: June 9, 2010 Field: Kuparuk Tool Type: UW MFC 40 Ext. No. 218451 Company: Conoco Phillips Alaska, Inc. Tool Size: 2.75 Country: USA No. of Fingers: 40 Tubgn 7 ins 26 f K-55 Anal st: C. Waldro Cross Section for Joint 162 at depth 6783.75 ft Tool speed = 43 Nominal ID = 6.276 Nominal OD = 7.000 Remaining wall area = 98 Tool deviation = 28 ° Finger 38 Penetration = 0.226 ins Isolated pitting 0.20 ins = 55% Wall Penetration HIGH SIDE = UP r~ LJ Cross Sections page 1 PDS Report Cross Sections Weli: 1 D-03 Survey Date: June 9, 2010 Field: Kuparuk Tool Type: UW MFC 40 ext. No. 218451 Company: ConocoPhillips Alaska, Inc. Tool Size: 2.75 Country: USA No. of Fingers: 40 Tubin 7 ins 26 f K-55 Anal st: C. Waldro Cross Section for Joint 133 at depth .619.78 ft Tool speed = 43 Nominal iD = 6.276 Nominal OD = 7.000 Remaining wall area = 96 Tool deviation = 41 ° • Finger 33 Penetration = 0.119 ins Isolated pitting 0.14 ins = 38% Wall Penetration HIGH SIDE = UP Cross Sections page 2 ................................................... .......................... ........... .. '# " ~ ' ~tlanticRichfieldCompany ~~ ~~~~ ~~~ Drilling -Completion - Workaver Log - - ---- ------- nit r+- lease ~ / I/ Welt number Oate :eld {~~/ /G/f~,r~ _. !. ~. ~ ! / T ~ ~ ~ -- District/ --,. _.-..~ ~ ,._ ._.. ~.5._~/_ V -.~(_-/,/--_.~_ fT /rte ~ ~Il ounty or parish Provi ~ ~ ~ ~ Q~~±/ ~~ nce or slate ~S Tlme distribution • hours Morn. Day Eve .___ -Y _ ontractar /~ q ~+ /~ ~ ' /yf n~~ ~+~'LSLi ~ ... /Y ; +~--- ~ -~•--- ~i+ / x Rig up and tear down •~ ~ Drilling normal -_- --- _'' r' O Directional drilling ---- - ws-a .~' ~ ,t~o ~ ~ ~ ~ ~•~`+~J" ~' TT'h' ~r ~ ~Q ~" + ~ - Reaming - .. ,. + ._ _ _._ _ _ _ - e~ .rr •• ~~~1~! aG L T i+ ~ f ------ • ~ !~ ~ a.i ~• ~ Trips to change bit - ---~- "'~ T. ~~ w ~' .. 2ti ~ ..~~ __/~ ~~+.~~-. --- S~ • - f .~~ / . Oriliing with partial returns - E • •' + ~ / _~~l~ 1 T t~iL~o.2 j ~• T'L • q Combating lost circulation __ .. /yam. .,r•++ y ~•• ~j+~.yo ~/_~~ !,~3_~__~~i7{~ ~S~ ...__ _.___ ~j •~f • ,].7Q'./! ,~+ • J_'~~ Conditioningmud and circulating + ~ Fishing r Deviation survey _ +~~/ /~ 4 - Lubricate rig ~ Q~ p !! ~ ~~r• _-L~~~~ ~• ~.iTG° L~ f~",___ - ~G • ~8 ~ ~ f~ • a Gut otf drilling line ------ ~ +~_~_ ~ ?"•os~.a~E- s.41Ga~-_~~L~A'~--~'-•_ -_._a~~-~ _0--~3_~-~`7' Repaif rig - _ ~ Kt r ~ • ~ ~~ ~~ s - ~ Test casing i~ A• •~ ~ ~ • . ' ~ ~ 1. ~ • ~ ~' Side waU .._._ ~~• M N ~ it • Conventional _ e. r. .~-.'-~~~_ /~ ss arc s's _ ~ •_Aa • .Z z.B~~~l=~ ~ Diamond __. ,_ '- Wire line _ __ . '~ ~~~' .~y ~~ 's~ ,~/_~ f~ ' / .- .~~~5_t7_.! ' -~ ~Sr ~~r'_---------- • ----.+~! ~~ ~•~.~! +~~ Drill stem test open hole x ,. • r ~t f- ~ '~'l~l T4 • r//~ r/• • /. Q ' ~ ~t Wire line logging open hole 1 -- '1 •' ~ • Plugging-back __ ' l,C~,. _!L ,. 7 /I ~ ~/ ~J.t ~ _ _ _-- ------ ~S~ • ~~ I ~~0 Running casing and Cementing Waiting ort : . ~~~ ` ~~/ AN /f+~/ ~D/~Y~~.F~ !S~L~~ ~t Qd ~ ~ ~ ~~ cement -~ . ~ __~ - ---- _ .-- .. -. _- Lo99ing cased hole ~ ~'- ~ _ __ Perforating ----- ~ -. . 7„ ~~~`N~ /~vKX,N~ ~7 _m_, ... -_ -- -_ -- _:1C __ _ _ ___n/~ G ~E~ ~//~E . Wirei3netormati test cased hole ~ ' /~ ,~-~ / /a ,.~ P /.~ ~_ Jsl/~~~.__•!4r0~~+Q ~I~-YI±Y_~y~4`J~ _I'r.!.S!-~-- -/-~~- --f /.T i ~ . Dri1I stem test cas©d hole ~ ,~C. - P,~l~• ~ ~A!t~~ ~ o~t'~v ~gK'~'K P~us ~o4'Ga,~ STR6'~ Testing ~ f _ #-_- -__... _._ _ _. ____. ~ ~ _. _. _--- . Swabbing _ f " USE'•D ~t~R~i? ~~L,tkt ,t/ L°r • R~~E• ~ ~ ~E~l~C• ~~` ~ • ~ _ .._- r.___ . . ._. ONE" /,~/ ~ENTE~ D~ f/' ~,fT /~lr .~~.~ r _._ ~ . . - ~_ .E`U TN -- Acidizing __ J,,., ~5.~ 4 ~ ~ _ ®~ ~..~- ~ ~~~~r Fracturing w~ DER .1r•_oN sf.vo?. Tic of /z . - .. -- -- - iwl~` E'vER~r ~:~~+! Jr f`/ - Tubing trips -- - ----_ - SNak". of SrrR~_~.Z~~~ ~---5'~~d~'-- /~tlE•D si,~-~v~~ 1~: Other -- r~tt t3acker ---- - - --- --- __ ~ - _- 'f`dtals ! • • Page 1 of 1 Schwartz, Guy L (DOA) From: Packer, Brett B (J.Brett.Packer@conocophillips.com] Sent: Friday, June 11, 2010 3:51 PM To: Schwartz, Guy L (DOA) Subject: tE~A3 (PT~'i79=t)84) CANCEt_ request far BOP test extan~n Guy, Just disregard anything I've said in the last several hours. Apparen#ly the guys on the slope were mis-diagnosing the problem and they have since moved the RBP to a different depth and the BOP test is now passing with perfect straight lines on the chart recorder for all the VBR's/pipe rams, Blinds and Annular. Apparently they think the RBP element was placed across a collar and not sealing completely rather than the IC packoffs leaking. Sorry for all the confusion, I'm ready for a beer, have a good weekend. ,~ Brett ~Pac~r ~Dri~xng ~'Welis 'Workor~er Engineer 'Work# (907) 265-6845 CeIC# (907) 230-8377 z ~ 4 ~'~' S"~..~ ~. .~ ,.,~.~n.~u ~'~t.-- b/11/2010 Page 1 of 2 Schwartz, Guy L (DOA) From: Packer, Brett B [J.Brett.Packer@conocophillips.com] Sent: Friday, June 11, 2010 3:35 PM To: Schwartz, Guy L (DOA) Subject: 1 D-03 (PTD#179-084} Request for BOP Test Extension Guy, To clarify the situation, we have approximately 2 days left of the workover which includes running the completion and changing the #ubing head and packoffs. The following is the exact procedure as planned with the BLUE section added due to the discovery of the corkscrewed 7" casing. Had we not had the two days of trouble time fishing our BHA, we would have been done with the workover before our 7 day BOP test was due, but since we hit the 7 days and we still had a couple days remaining, we decided to attempt the BOP test rather than originally ask for an extension. Below the procedure is the current situation. The remainder of the workover includes: 1. RIH w/ the following 3 'h", 9.3#, L-80 gas lift completion: a. 3 ''/a" po-boy overshot w/ 3 5/e" ID and shear pins 2' up inside overshot. b. 1 joint 3 'h", 4.3# L-80 EUE 8rd Mod tubing. c. 2.813" `DS' Nipple w/ 6' pups and RHC plug installed. d. 1 joint 3 'h", 9.3# L-80 EUE 8rd Mod tubing. e. Baker 3 'h" x 7" FHL packer (Min. ID = 3", pinned to 60M# shear) f. 20' PBR seal assembly (pinned to 40M# shear) g. 2 joints 3 ''/2", 9.3# L-80 EUE 8rd Mod tubing. h. 3 '/z" x 1" KBMG gas lift mandrel w/ ZO' handling pups and SOV installed (1500 psi csg-~tbg differential). i. 3 ''/2", 9.3# L-80 EUE 8rd Mod tubing. j. 2.875" DS Nipple @ 500' MD. k. 3 ''/z", 9.3# L-80 EUE 8rd Mod tubing to surface. 2. Locate tubing stub, pull up, and circulate the well full {approx. 255 bbls) of corrosion inhibited 8.6 ppg seawater. (1% by volume Baker Petrolite CRW-132) 3. Engage tubing stub, look for shear screw indicators as the overshot slips over the stub. Leave overshot 1' from fully located. 4. Drop the ball 8~ rod and set the packer w/ 2500 psi. 5. Shear the PBR, calculate space out approximately 7' from fully located ensuring at least one full joint of tubing immediately below the tubing hanger. 6. PU two stands and rack back in derrick. MU storm packer to set at +/-100' MD. ND BOP and tubing head [allowing 7" casing to grow. Remove IC packoffs, spear 7" casing and pull to 50K Ibs tension and land in emergency slips. RU Wachs cutter and cut excess 7" casing.] Install new IC packoffs and install new McEvoy Gen 4, 7-1116" 5K flange top x 11" 3K flange btm tubing head. Verify the tubing head orientation w/ operations prior to final make up. 7. NU BOP w/ 11" x 7-1/16" DSA to new tubing head. Pressure test below blinds to 250/3000 psi. (Note: 24-hour notification to AOGCC require prior to testing BOPE.) 8. Pull storm packer. 9. RBIH w/ the two stands of tubing stood back in the derrick with proper space out. MU new McEvoy Gen IV tubing hanger and land. RILDS. 10. RU chart recorder to IA. With the annulus open, PT tubing to 3000 psi for 15 min. Monitor annulus for returns. Bleed off tbg pressure to 2250 psi. While holding the tbg pressure at 2250 psi, PT the IA to 3000 psi for 30 min. Bleed IA to 0 psi, then bleed tubing to 0 psi. Ramp up the IA pressure to shear the SOV. 6/11/2010 11. Pull the landing joint. Install two-way check. ND BOP Stack. Page 2 of 2 12. NU tubing head adapter and tree. Ensure proper orientation of the tree. If needed, contact the Drillsite Operator or Drillsite Lead to verify alignment prior to NU. Pressure test tree to 250/5000 psi. Test packoff to 5000 psi. Pull two-way check. 13. Freeze protect the well down to 2,500' TVD by pumping 93 bbls diesel down the IA taking returns up the tubing. Put the tubing and IA in connection and allow sufficient time for the fluids to U-tube. 14. Set 3" `HP' BPV in tubing hanger profile. 15. RDMO. Turn well over to operations via handover form. Well Status • We have a CA-2 plug set in the profile nipple @ 7,339' MD and pressure tested to 500 psi. • We have a RBP set approximately 6' below the wellhead. • We have 8.6 ppg seawater in the hole which is KWF (reservoir pressure = 8.23 ppg) • We have seen no fluid loss during the workover • The well passed a CMIT and MITOA pre-rig. . The weA is secure! . The well has an old McEvoy Gen 1 tubing head, and there is no test plug to fit this old style wellhead for the BOP test. . The elements on the original tubing hanger we pulled from the well are damaged beyond repair and there are no replacement elements for this old style hanger because the workover plans included changing the tubing head and hanger. • We did not anticipate needing a test plug for this tubing head because the well should have been finished in less than 7 days or we should have done our tubing head swap prior to needing a BOP test. • We have the tubing already stood back in the derrick ready to be run. We laid down the drillpipe during our last scraper run. We could do the tubing head swap right now with the RBP in the hole, but since this well has subsided ~30" and we know that the 7" casing is in compression, for safety reasons, we'd prefer to do the tubing head change out with the completion hanging in the 7" casing for added down weight rather than rely totally on the top drive and a landing joint to hold back the 7" compressive forces. The well passed the initial BOP test on 6/3/10 when we had the hanger and blanking plug in the well. Currently, we are testing the BOP's against the RBP in the 7" casing because we don't have a test plug to fit the tubing head and we can't use the old hanger. It passes the low test of 250 psi, but has a very minor leakoff of 80 psi over 8 minutes at 3000 psi through the IC packoffs (which are to be replaced anyway). We are requesting a two day extension on the required 80P test so that we may finish up this well and get it secured. In reality, we have noway of testing the BOP's or securing this well until we make the wellhead modifications, and once those modifications are done, we should be finished up with the well within approximately 12 hours. Thanks! Bic ~~ ~DrfQ'ng ~C 4Netiss 'Worl~gver~Engineer `Work# (907) 265-6845 Ce[t"# (907) 230-8377 6/1 i/2010 Page 1 of 1 Schwartz, Guy L (DOA) f=rom: Packer, Brett B [J.Brett.Packer@conocophillips.com] Sent: Friday, June 11, 2010 11:14 AM ~ y To: Schwartz, Guy L (DOA) OC6~f Subject: FW: 1 D-03 Weekly BOP Test extension ~ `~~ Guy, Our Nordic 3 rig is on standby waiting on a response from the AOGCC reps on the slope. We've run into complications with the BOP test because we have a know IC packoff leak. Plans are to change out the tubing head and packoffs anyway, but it just so happens because of our fishing operation for the past couple days, we weren't able to do the wellhead work before our 7 day BOP test. We are looking fora 3 day extension to run the completion and complete the tubing head and packoffs change out. Your quick response would be greatly appreciated. Thanks!!! ,~ Brett ~Pacf~r ~Dri~ng ~`G `WeQs 4Norkover~Engineer ~Work# (907) 265-6845 ~'e[f# (907) 230-837 From: Nordic 3 Company Man Sent: Friday, June 11, 2010 11:02 AM To: Packer, Brett B Subject: 1D-03 Weekly BOP Test extension GUyS, We are 1D-03 and We have been in the process of attempting to do our weekly BOP test since 01:30 on 6- 11-10. We have isolated and tested our surface equipment -passing test. We have set a Baker G-6 RBP @ 6' from surface in attempt to test our Rams and Annular against, The Blind ram low test of 250 -passed, but on the high test of 3,000 we are getting a minor leak of 80 psi in 8 minutes. The pre-rig integrity test shows that we have an inner casing pack off leak. But we have run into some minor set backs with this being an out dated McEvoy Gen I design. 1) There is no test plug available for this 11" Gen I McEvoy design. 2) The Elements on the original TBG hanger pulled from the well are damaged beyond repair with no replacement elements available. The program calls to change out the McEvoy GI 11" 3M x 11" 3M TBG spool and ICP to a McEvoy Gen IV 7 1/i6" 5M x 11" 3M Spool. This would be done after we RIH w/ 3 1/2" Completion string and seta 7" Storm packer below surface. We currently have CA-2 plug set in a profile nipple @ 7,339' with Sea water as KWF -tested @ 500 psi after being set. We have had no fluid fosses after the plug set in place. We had a passing Initial BOP test on 6-3-10. For these reasons we are asking fora 3 day extension on the weekly BOP tes# starting on 6-11-10 thru 6-14-10. Thanks, Randy Dolcater /Lee Hinkel Office Phone - 659-7446 Cell Phone - 943-1096 6/11/2010 u ~~Q~~ OCR Q~Q~~Q /,E,..~..~o~~. Brett Packer Wells Engineer ~,~~~~~~ JUv ~ 3 2010 ConocoPhillips Alaska, Inc. m a (~- P.O. Box 100360 p ~ .- I Anchorage, AK 99510 ;~-- Re: Kuparuk River Field, Kuparuk River Oil Pool, 1 D-03 Sundry Number: 310-158 Dear Mr. Packer: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good -cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. Sincerely, Daniel T. Seamount, Jr. d Chair DATED this 3 day of June, 2010. Encl. rc~c+~F~~il~i~-s Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 May 20, 2010 Commissioner Dan Seamount State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Dear Commissioner Seamount: ConocoPhillips Alaska, Inc. hereby applies for an Application for Sundry Approval to workover the Kuparuk Well 1 D-03 (PTD 179-084). 1 D-03 was originally completed in December of 1979. The well is a single A & C sand gas lifted producer. Since the completion of the 1 D-EORX project in 3Q 2008 which brought MI (miscible injectant) to 1 Dyad _it is._desired to convert this well to an MWAG injector to provide iniection support to an area that has seen minimal waterflood and MI support due to the arrangement of producers. In February 2009, an isolated leak was found in the tubing at 5,655' MD. The tubing was patched and brought back online. In November 2009, we discovered the IC packoffs failed to test and it appears there is minor gas communication through the packoffs. The well passes a CMIT and an MITOA. The most recent SBHP is on 1/22/09 measuring 2724 psi at 6,364' ND which equates to 8.23 ppg. Anew SBHP will be obtained during the pre-rig work and is not anticipated to be any ' higher. The purpose of this workover is to set it up for MWAG injection. This sundry application is to document the change of service for this well. MWAG injection requires a tubing head rating of 5K psi which it currently does not have. During this workover, the objectives are to pull & replace the tubing due to the known tubing leak, as well as replace the IC packoffs and upgrade the tubing head. If you have any questions or require any further information, please contact me at 265-6845. Sind, J. Brett Packer Wells Engineer CPAI Drilling and Wells STATE OF ALASKA ti~I~ ALASK~L AND GAS CONSERVATION COMMISS~ ~ ~ APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 RECEIVED MAY202010 1. Type of Request: Abandon I"" Rug for Redrill ~` F~rforate New Pool Repair well ~~GYA~y~~~I~ggjO Suspend '" Rug Perforations ~ F~rforate ~" Rall Tubing ~~~nsion ]~'" Operational Shutdown ~" Re-enter Susp. Well ~ Stimulate ARer casin g Other: CoN~/, ~ rNS 2. Operator Name: 4. Current Well Class: .Permit to Drill Number: ConocoPhillips Alaska, Inc. Development ~ Exploratory ~"'' 179-084 3. Address: Stratgraphic ~" Service ~"" 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-029-20408-00 ' 7. If perforating, closest approach in pool(s) opened by this operation to nearest property line 8. Well Name and Number: where ownership or landownership changes: Spacing Exception Required? Y2S No W' 1D-03 9. Property Designation: ~ 10. Field/Pool(s): ADL 25650 • Kuparuk River Field /Kuparuk River Oil Pool 11. PRESENT WELL CONDITION SUMMARY Total depth MD (ft): Total Depth ND (ft): Effective Depth MD (ff): Effective Depth ND (ft): Plugs (measured): Junk (measured): 8070 6836 - 7990' 6769' Casing Length Size MD ND Burst Collapse CONDUCTOR gp 16 80' 80' SURFACE 2904 10.75 2904' 2708' PRODUCTION 8057 7 8057' 6825' Perforation Depth MD (7422'-7519', 7525'-7531' Perforation Depth ND (ft): 6305'-6384', 6389'- Tubing Size: Tubing Grade: Tubing MD (ft): 7539'-7545', 7556'-7567', 7778'-7798',7808'-7832' 6394', 6400'-6405', 6414'-6422', 6594'-6610', 6619'-6638' 3.5 J-55 7346 Packers and SSSV Type: Packers and SSSV MD (ft) and ND (ft) PACKER - BAKER'FHL' PACKER MD= 7303 ND= 6205 Locked Out - CAMCO TRDP - MD= 1968 ND= 1920 12. Attachments: Description Sumrery of Proposal ~, .Well Class after proposed work: Detailed Operations Program "` BOP Sketch ~ Exploratory r Development Service 14. Estimated Date for Commencing Operations: ~'~, Well Status after proposed work: 6/3/2010 Oil Gas ~"" WDSPL ~ Suspended 16. Verbal Approval: Date: WIND ~ GINJ ~ WAG ~: Abandoned Commission Representative: GSTOR SPLUG "' 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Brett Packer @ 265-6845 Printed Name Brett Packer Title: Wells Engineer Signature ~ ,•'S~ ~~.~ Phone: 265-6845 ` Date ~/ ~~,~ ~ i i n Sundry Number:~`~-~' ~~ Conditions of approval: Notify Commission so that a representative may witne s Plug Integrity BOP Test J"/Mechanical Integrity Test Location Clearance ~'" /~ ,p Other: ''~ 3 DO O P s~ 1J ~ i ~ 5-~-~ a~- ~ ZSOO P3 e: ~ ~'' l ~S ~ ~`ht~~~ ~ .N1 I I b ~ -~ ~ ~- .~.. ~~ e~c.~i ors Subsequent Form Required: /D ` ~ ~~ APPROVED BY ~ J `-' ~~ Approved b . COMMISSIONER THE COMMISSION Date: Form 10-403 R~~~~~1~li~l OJUH d~ ~ 0 R I G I N A L ~ Submit in Duplicate ~~~,, ,- - • • 1D-03 Capital Rig Workover (PTD #: 179-084) Current Status: 1D-03 was originally completed in December of 1979 as a Kuparuk A & C single completion. It has been on production since then and is currently producing about 275 bopd at a 91% watercut. '' Scope of Work: Convert to injector, pull & replace the tubing w/ po-boy overshot and stack packer, upgrade the . wellhead and replace the IC packoffs. General Well info: MASP: 2,088 psi Reservoir pressure/TVD: 2,724 psi / 6364' TVD (8.23 ppg) Wellhead type/pressure rating: McEvoy Gen 1, 11" 3K~si top x btm BOP configuration: Annular /Pipe Rams /Blind Rams /Mud Cross /Pipe Rams CMIT and MITOA results: CMIT-passed on 11/12/09, MITOA-passed on 11/1/09. Well Type: Producer Earliest Estimated Start Date: June 3, 2010 Production Engineer: Dan Bearden /David Lagerlef Workover Engineer: Brett Packer (265-6845 / j.brett.packer@conocophillips.com) Pre-Rid Work Request: 1. Pull the tubing patch located at 5,647' - 5,660' MD. 2. Obtain SBHP mid-perf at 7,627' MD (6,471' TVD) ~ 3. Set a plug in the 2.75" D nipple at 7,340' MD. Set a catcher sub on top of plug. C M 1 T ~^'~ Q.~a..~s 4. Pull GLV and OV from 2,416' MD and 4,455' MD respectively and replace w/ DV's. Pull DV from 7,186' MD. Leave pocket open. 5. Cut the tubing in the middle of the first full joint above the SBR at 7,249' MD. Proposed Procedure 1. MIRU Nordic 3. Pull BPV. Circulate 8.6 ppg seawater. Verify well is dead. Set BPV. ND tree. Install blanking plug. NU 11" SK BOP. Pressure test BOP including annular to 250/3000 psi. ._ 2. Pull blanking plug and BPV. POOH laying down tubing. 3. RU E-line and RIH with an oriented caliper w/ GR, log from top of tbg stub back to surface. 4. PU & RIH w/ po-boy overshot and stack packer assembly. 5. With 2500' RIH, install storm packer & PT. 6. ND BOP stack, ND tubing head, change IC packoffs, install new McEvoy Gen 4, 11" 3K x 11" SK tubing . spool NU BOP stack, test wellhead breaks and shell test BOP stack to 3000 psi. 7. Retrieve storm packer and continue RIH w/ 3 'h" completion. 8. Locate tubing stub, circulate in corrosion inhibited fluid. Drop ball & rod and set packer. Shear PBR, space out tubing and land hanger. PT tubing and IA to 3000 psi. Shear SOV. 9. Set 2-way check. ND BOP. NU tree and pressure test. 10. Pu112-way check. Freeze protect well. Set BPV. RDMO Nordic 3. Post-Rig Work request: 1. Pull ball & rod. Pull SOV and install DV. Pull RHC plug body. Pull catcher sub & plug from D nipple. s'-~` ~a P~. 2. Complete facilities tie-in to the MI header. 3. Return well to injection. --~- v~/ ~ TN`~5 E ~ /~ ~ T-~~ ~Fh -~~"-5~~~~z~ GAS LIFT, 2,416 SURFACE, 2.906 GAS LIFT, 4.455 GAS LIFT, 5.470 PATCH ASSV, s.sa7 GAS LIFT, 5.588 GAS LIFE, s.a11 GAS LIFT, 6.797 GAS LIFT. 7,186 SDR. 7.272 PACKER. 7,303 NIPPLE. 7.3a0 805, ]345 --- TTL. 7.346- -- FRAC.7422 RPERF, 7 445-7 660 IPERF, 7,422-7.519 IPERF, 7,539-7,565 IPERF,_ _ __ 7 ]78-7,798 IPERF, 7,808-],632 PRODUCTION, 8,057 TD. B,0]0 KUP (bore APVUWI Field Name Well Sta[u 500292040800 KUPARUK RIVER UNIT PROD ment ~H25 (ppm) Date Annotation/End SV: TRDP 100 ( 8!27/2008 ( Last WO: potation (Depth (ftKB) ''~,Entl Date ( Annotation a TaD~ SLM 7.480.0 ~~ 1!22/2009 Rev Reason: GLV C/O Tubing Description (in; TUBING 3 Other In-Hole (All Jev Top Depth (TVD) Top Inc! Tnn lftKRl ((iK6) ("1 1 D-03 tK8) Act Btm (ftKB) S 050.00 I 8,070 0 ird (ft) ~. Rig Release Dat 38.99 i 12130/1979 Mod By End Date 6.1511 0.0~ 8,05701 6,82541 26.OOK 55 I l --. _. _ _.-_ -_.. _--. _-. _-_ _-_-_.-__ _ itring ID Set Depth Set Depth (ND) String Wt String (in) Top (ttK6) (ftKB) (ftKB) (Ibs/ft) Grade St ng Top Thr 2.992 Tubing 0.0 7,346.0 6,241 0'I 920jJ 55 Run & Retrievable,-Fish, etc.) -___ - -BTC - - cription Comment Run Date ID TY VLV Camco TRDP - Upper hytlraulic control line not locketl 12/30/1979 2.9 open. 1968' RKB TRDP 1A-SSA flapper locketl out. 322/1999 LIFT CAMCO/KBUG/1/GLV/BK1.188/1263 Comment: STA 1 1/22/2009 2.8 LIFT CAMCO/KBUG/1/OVIBTML188//Comment: STA2 11/13/2009 2.8 LIFT CAMCO/KBUG/1/DMYBK///Comment: STA3 1/22/2009 2.8 :H ASSY WEATHERFORD ER LOWER PATCH PACKET MID 3/21/2009 1.7 , ELEMENT @5660 set 3/5/2009. UPPER ', WEATHERFORD 3.6" ER PACKER ASSY (OAL=13') set 1 3/21/2009 LIFT GAMCG/KBDG/1/DMY/BK///Comment: STA4 12/162002 2.E 'FHL' 7 346 6.241 Min Top '~ Max Btm Depth Depth (ftKB) (ftKB) J 12/30/1979 12.992 Shot Den Zone Date _ (sh~s Type Comment D, C-0, 18/4/1980 4.0 IPERF 2 1B" Enerjet; 0 Deg- Phase S 6,335.7 UNIT D, C-0, 12!17/2002 4.0 RPERF 21/8" FJ,BH Chrgs, U Ueg Phase 1 D-03 6,393.6 C-3, 7 D-03 812!1980 4.0 IPERF 2 1/8" Enerjet; 0 Deg. Phase 6,404.8 C-2, 1D-03 82/1980 4.0 IPERF 2 1/8" Enerjet; 0 Deg. Phase 6.422.3 C-2, 1D-03 82/1980 4.0 IPERF 2 118" Enerjet; 0 Deg. Phase 6,610.21 A-S, 1D-03 8/7/1980 4.0 IPERF 2 118" Enerjet; 0 Deg. Phase 6 638-3 tS A-4, 1 D-03 - 8/7/1980 4.0 IPERF 21/8" Enerjet; 0 Deg. Phase _- eonom Depth (TVD) (ftKB) Type Date Comment 6.348.7 FRAC 12/21/2002~C-SAND FRAC Annotation _ ED WELL: IAx OA COMMUNICATION • • Page 1 of 1 Schwartz, Guy L (DOA) From: Schwartz, Guy L (DOA) Sent: Tuesday, June 01, 2010 2:51 PM To: 'Kappel, Erica J' Subject: 1 D-03 workover and Inj conversion. (PTD 179-084) As we discussed, I need the cement data for the 7" casing and your CBL interpretation. Also the AOR needs to be complete before any injection can commence. The workover can proceed without the AOR completed but it would be best to do this ASAP. Guy Schwartz Senior Petroleum Engineer AOGCC 793-1226 (office) 444-3433 (cell) From: Kappel, Erica J [mailto:Erica.].Kappel@conocophillips.com] Sent: Tuesday, June 01, 2010 1:18 PM Tp: Schwartz, Guy L (DOA) Subject: My a-mail I will get you the requested documents ASAP. Erica Kappel Drillsite Fetroleum Engineer - CPF1 ConocoFhillips Alaska, Inc. Work: (907)265-6492 Mobile: (918)521-4675 6/1/2010 1 i ,~a -3500 KRU 1 D-03 Area of F KPRKC = I<uparul~ C Sand ~C~ot~ =true vertical dept (feet) along well SFD 6/2/2010 _~-(v ~ 7 ~ -o~~ ~ Acous is cY Cement Bo DRESSER V D L FILE No. COMPANY AR,CO OI L ~ GAS • aal WELL NO. WELL_ Q - 3 AP/~ 6 -x.29-~55~0~ " FIELD KUPARUK CT n (3t ~'" COUNTY NORTH SLOPE STATE ALASKA ~ ~ LOCATION: ` ' Other Servi~ 3 SNL ~ 601 WEL Q u. CHES f 23 1 HOIST ~G TWP 1N RGE l0E SEC Permanent Datum M.S•L. Elev. 0 ElevSions: KB 10 Log Measured from K• B. 1 O,~Ft. Above Permanent Datum DF 1 03 Drilling Measured from K• B ~ GL .~-... Date 12-21-79 Run No. 'ONE Service Order No. - - - • Depth-Driller $070 Bottom Logged Interval 2 Top Logged Interval $ 0 Type Fluid• in Hole ! NVERMUL ' Salinity Ppm CI. - - - pH and Fluid Loss - - cc cc Density Lb/Gal. 10. ~#/GAL . Level FULL Max. Rec. Temp. Deg. F N . R . ~. Opr. Rig Time 6 HRS.;'• ~ ter. 1 ~ ~ , Recorded BY BLOUNI'/ESARY - ~ ~ Witnessed By M N K Run Bore Hole Record Casing Record No. Bit From To Size Wgt. From To 10 /4" 1# SURFACE 2 04 7" 26# SURFACE 070 ~..~.. N ~. z o 0 ~ ~ W ~ uu _i J ... ~ • m u ~_ ~ ~ N W ° Q a ~ a W, z Q ~ 7 W ~f O ~ Z~ z Z ~ J c 7 u~ ~ ~ ¢ °C ~ n .. w . O . ,a. ~ 4 +~ 2 w O , O ~ O ' ~ t V Q ~ ~ .~ a Q ~n ~: U� K KEN _44 710M®R MAP ,tea ins- o ~:~ AtlanticRichfieldCarnparty ~~ Daily Weli History-interim Inswetions: This Corm is used dudry drilling or workover operations. ii testing, coping, r L`ertora;•nq, show formation name in desCrfbin~ worts perlormed, i Number ail drill stem teals sequentially. Atlech description of all cores. Work performed by Producing aecllgn wrN be reporletl on "tnlerim' sheets unlit final coin piolron. Report official of repreaertatlve less on "Final" fmm. tl Submit "Interim" sheets when Tilled om but not less IrequeNly than every 5g days, or (2) on `.'ledneaday of the weo-k in whroh orl string is set. Submit wookly for workovers and fotlowrng aetl,nq pf mt suing until Complellon. +- - r... ~..,.tr~- '~ Distric/ County or Parish Slate - - North Alaska North 51o a Borou h Alaska Fiold Leaie or UnR 1ye11 no. u Ku aruk ADL 25650 D-3 Dato a d d Dm as otbM-e.m. Complete record for each day while drilling or woraover in progress 6:0 a. 12/16/79 10-3/4 @ 2904 8070 Strap out of hole for Logs Rig up Schlimber, Run GR/FDC/CNL wire line T.D. 8064. Mud 10.4 Vis 60m O,V, 29 TO 21 GCLS 3/9 w.Li.2 cake 2 salt 230M solids I8 oil 71. Daily cost 49.847 acc 970.665 12/17/79 10-3/4 @2904 ndition hole for d tri M d bi i 8070 co per p an a e t w Ran GRL/FDC/CNL/TOOL. side wall cores. Run side wall core gun tool failed. Trip out w%same. Mud 10.4 Vis 52 PV 21 YP 11 GCLS 3/8 vrt 1.2 cake 2 salts 230M solids 1$% oil 71% Daily costs 62,281 acc 1,032, 946 12/18/79 10-3/4 @2904 Day 18 Side wall core samples. Rig down Schlumberger, change raves. Pick up 8070 32 D.P. Hailiburton and Baker equipment stand in Derrick. Change Rams trip in hole w/5" cir. and condition hole stand 50 stands in Derreck trip outlaying down 5" D.P. Mud 10.5 via 40, P.V. 21 YP 10 GELS 3/8 W.L.1.1 Cake 2 Solids 18 Salt 236 M Oil 72 12/19/79 10-3/4 @2904 Day 19 Finish lay down D.P. and BHA change Rams to 7" Rig up and run 293 8070 3oints of 7" 26# K-55 w/shoe @8057 Cemented w/1600 sks self stress Slurry wt 14.4 to 14.6 Displaced w/Rig pumps 296 BBLS Bumped plug cement in place @0145 floats held ok. Open stage collar and CIR up back side 3 cir. Lay down landing 3oint install and test 7" pack off to 3000 psi. Ok, Change Rams to 3~ Daily cost 154,366 acc 1,262,360 12120/79 Finish changing Rams. Rig up and do Arctic Pack. Close O.V. Reverse Day 20 out test casing to 1500 psi. Ok. Trip out. Lay down tools. Pick 8070 up B.H.A.- Trip in to stage collar @2325. Drill out same. Trip out Pick up casing SRRaper. Trip in picking up 32 D.P. Mud 10.6 Vis 45 P.V. 15 UP 8 GELS 3/7 W.L. 1.4 cake 2 salt 230M solids 18% oil 71% 12/21/79 7" @8057 Day 21 Pick up 3~ D.P. Tog landing collar @7623. Drill cement to 7990 7990 PBTD Cir. Strap out. Rig up. Dresser atlas. Run Gyro survey Mis run 8070 TD Run CBL/VDL/GRJCCL from 7980 to surface Daily cost 32,722 acc. 1,451,306 12/22/79 7" @8057 Day 22 Logging 8 7DTD Spectra Log 7982-7350 & 4600-3300 Rerun Gyro from surface to 7950 . 8 The shove fa correbt ~~ i; j¢'~ e ,. t~L ' ~~~. 5..~~ AA38-4S9-2•A x_---- - Dale Tttle `. ,, ~ /~ ~G District Drilling Supervisor Number all daily wall history tams conaewpvaly Page no. as mey are prepared for each well. 5_- - • STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION , ~~ ~~; REPORT OF SUNDRY WELL OPERA I~llnAt,n,~,.~ ' 1. operations Performed: Abandon ^ Repair Well ^ Plug Perforations ^ Stimulate ^ Other ^J Install Patch , Alter Casing ^ Pull Tubing ^ Perforate New Pool ^ Waiver ^ Time Extension ^ Ghange Approved Program ^ Operat. Shutdown ^ Perforate ^ Re-enter Suspended Well ^ 2. Operator Name: 4. Well Class Before Work: 5. Permit to Drill Number: ConocoPhlllips Alaska, Inc. Development 0 ' Exploratory ^ 179-084 / 3. Address: Stratigraphic ^ Service ^ 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-029-20408-00 7. KB Elevation (ft): 9. Well Name and Number: RKB 105' 1 D-03 . 8. Property Designation: 10. Field/Pool(s): ADL 25650 Kuparuk River Field /Kuparuk Oil Pool 11. Present Well Condition Summary: Total Depth measured 8070' feet true vertical 6836' feet Plugs (measured) Effective Depth measured _ feet Junk (measured) true vertical feet Casing Length Size iND ND Burst Collapse Structural CONDUCTOR 80' 16" 80' 80' 1640' 630' SURFACE 2799' 10-3/4" 2904' 2708' 3580' 2090' PRODUCTION 7952' 7" 8057' 6825' 4980' 4330' Perforation depth: Measured depth: 7422' - 7832' true vertical depth: 6305' - 6638' Tubing (size, grade, and measured depth) 3-1/2" , J-55, 7346' MD. Weatherford ER Patch from 5650' - 5660' (1.75" ID) Packers & SSSV (type & measured depth) Baker FHL 7303' Camco TRDP (locked out} 1968' 12. Stimulation or cement squeeze summary: ~`lS~ ~,( `~ ~~~ Intervals treated (measured) not apprcable ~~~ Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casin Pressure Tubin Pressure Prior to well operation Subsequent to operation -- 14. Attachments 15. Well Class after work: Copies of Logs and Surveys run - Exploratory ^ DevelopmeM ^`~ Service ^ Daily Report of Well Operations X 16. Well Status after work: CQ • Ga~] WAG^ GINJ ^ WINJ ^ WDSPL ^ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or wA if C.O. Exempt: N/A contact Martin Walters @ 659-7224 Printed NameMartin Walters Title Problem Wells Supervisor ~ Signature ~Z~ I ~ / ~ Phone: 265-6471 ~ l Ce Date `~ ' C•G ~'~ Me arN ~ Martin Walters !5l-7224 a . 4 ~., . • "_" ... Form 10-404 Revised 04/2006 • ~ ~-~. Submit Original Only • 1 D-03 DESCRIPTION OF WORK COMPLETED SUMMARY Date Event Summary 1/22/2009 1/23/2009 1/24/2009 2/4/2009 2/5/200: TAGGED FILL @ 7480' SLM (OBTAINED SAMPLE ). OBTAINED SBHPS @ 7495' RKB SURVEY) AND 7371' RKB (GRADIENT) W/ DUAL PANEX GAUGES. SET 3 1/2 SLIP STOP CATCHER SUB @ 5909' SLM. PULLED GLV'S @ 2416', 4455', AND OV @ 5470' RKB. SET GLV @ 2416' RKB AND DGLV @ 5470' RKB (( STA # 2 @4455' HAS EMPTY POCKET /CATCHER SUB STILL IN HOLE )). IN PROGRESS. SET OV W/ BOTTOM LATCH @ 4455' RKB. PULLED CATCHER SUB @ 5909' SLM. SET 2.75 CAT STANDING VALVE @ 7340' RKB. UNABLE TO P.T. TBG. DUE TO ANN COM. (( CAT STILL IN HOLE - IN PROGRESS IDENTIFIED LEAK IN TBG. W/ HOLEFINDER APPROX. 5642' RKB. (( LEFT CAT STANDING VALVE -27 1/4" OAL - IN D-NIPPLE @ 7340' RKB FOR E-LINE LEAK DETECT MADE BASELINE TEMPERATURE PASS FROM SURFACE TO 7250' FOR LEAK DETECTION LOG. WAITED FOR WELLS SERVICES TO INSTALL INTEGRAL FLANGE TO lA TO TAKE RETURNS. ASRC UNABLE TO MAKE IT TO LOCATION. JOB WILL START AGAIN TOMORROW. PERFORMED LEAK DETECT LOG. LOGGED FROM CAT STANDING VALVE AT 7320' TO 200' WHILE PUMPING AT 0.5 BPM LEAK RATE. LEAK FOUND AT 5655'. VERIFIED LEAK WITH UP/DOWN OVERLAY AND STOP COUNT. ((JOB COMPLETE.)) 2/7/2009 LOGGED PDS CALIPER FROM 7324' SLM TO SURFACE, TWICE. GOOD DATA RECOVERY ON 2ND EFFORT. COMPLETE. 2/23/2009 PULLED CAT STANDING VLV @ 7345' RKB. BRUSH & FLUSH TBG FROM 5600' SLM TO 5700' SLM. DRIFTED TBG WITH 15' X 2.78" DMY PATCH. NO OBSTRUCTION'S. READY FOR E-LINE. 3/5/2009 WEATHERFORD ER LOWER PATCH PACKER AT 5660' MID ELEMENT. READY FOR SL TO SET UPPER PATCH ASSY. 3/21/200' 3/22/2009 DRIFT 2.79" CENT TO LOWER 3 1/2" ER PKR @ 5660' RKB.CMIT GOOD.SET UPPER ! WEATHERFORD 3 1/2" ER PKR SPACER PIPE ASSY (OAL=13',MIN ID 1. ~ cil v~ RKB ON WEATHERFORD SLICKPUMP.IN PR GRE TESTED UPPER PACKER ASSEMBLY 30 MIN MIT-T PASSED.RIH W / 31/2" GS AND ER TESTTOOL TO TOP OF UPPER ER PKR @ 5625' SLM TAP DOWN. T/I/0=725/575/1020 BUMP UP TBG WITH 266E T/I/0=2500/590/1000 HALIBURTON LEAKING BLEED BACK AND FIX.BUMP UP TBG 166E T/I/0=2500/585/1000 AFTER 15 MIN T/I/0=2375/580/1000 AFTER 30 MIN T/I/0=2350/575/1000 MITT PASS.BLEED TBG BACK.SHEAR TEST TOOL AND PUH. GIVEN TO DSO TO BO . JL UB COMPLETE. TIFL -passed; Initial T/I/O/OOA= 200/1240/1500/0; Shut in WH and LG; Shot initial FL @ I 455. V; Stacked out TBG with liftgas; T/I/O/OOA= 1000/1000/1350/0; Bled IA; Shot second FL ~ same location. Bled down OA: Final T/I/O/OOA= 1000/350/420/0 Summary Troubleshoot TxIA communication. Set Weatherford patch assembly and conducted passin TIFL. ~r ~ , ~, Schlumberger -DCS 2525 Gambell Street, Suite 400 ; ,, Anchorage, AK 99503-2838 _ _ ATTN: Beth Well Job # Log Description NO. 5063 Company: Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Kuparuk Date BL Color CD 02/09/09 i L-13 11978475 PRODUCTION PROFILE f- L $- 08/16/08 1 1 2A-26 AZJZ-00010 USIT ~- ~ 01/16/09 1 1 iD-141A ANHY-00041 FLOWING BHP -Q 01/21/09 1 1 3K-15 B04C-00004 INJECTION PROFILE ~' ~ 01/21/09 1 1 1E-105 AZED-00019 INJECTION PROFILE 01/23/09 1 1 1E-119 AYS4-00023 INJECTION PROFILE U 01/23/09 1 1 3J-01 AYS4-00024 INJECTION PROFILE , -r _ 01/24/09 1 1 2V-06 AZED-00022 INJECTION PROFILE /$?- - 01/26/09 1 1 2K-22 AZED-00024 LDL f~,~ J 01/28/09 1 1 2L-301 AZED-00025 SBHP SURVEY 01/29/09 1 1 1 R-03A ANHY-00045 INJECTION PROFILE T •~- ~- 02/09/09 1 1 2B-11 AZED-00028 INJECTION PROFILE 02/01/09 1 1 2F-16 AZED-00029 INJECTION PROFILE 02/02/09 1 1 3J-05 AZED-00030 INJECTION PROFILE 02/03/09 1 1 3G-07A AYS4-00033 PRODUCTION PROFILE j ~ 02/04/09 1 1 1 D-03 ANHY-00042 LDL ~~- 02/05/09 1 1 g Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. 9•y •, • • Ut/~LL L 1°l4~/1/~11~1/1~~L ProActive Diagnostic Services, Inc. To: AOGCC Christine Mahnken 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 (907] 859-5102 RE : Cased Hole/Open Hole/Mechanical Logs and/or Tubing Inspection(Caliper/ MTT) The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the following ProActive Diagnostic Services, Inc. Attn: Robert A. Richey 130 West International Airport Road ; , , Suite C ~~~~~±~~a~~~' ~~~ ~ ~~ ~~ Anchorage, AK 99518 Fax (907j 245.8952 1 ] Caliper Report 08-Feb-09 1 Y-09 1 Report / EQE 50.029-20935-00 2] Carper Report 07-Feb~09 1[}03 v i ~ -'~ 3 -052 *~ ~ ~ sar i 1'x-41- D'~5C/ ~ ~'~ ~°! a I u Signed Print Name: 1 Report / Eft 5Q-029-2040500 ~. ~ -. - ~, ~,:. ~, Date ~ ~ ~ ' -rti;J,J~ ;,,,, ,,, ., ; , PROACTIVE DIAGNOSTIC SERVICES, INC., 130 W. INTERNATIONAL AIRPORT RD SUITE C, ANCHORAGE, AK 99518 PHONE: (907)245-8951 Fax: (80T)245~58952 E-MAIL : ~~~ar~~h9r~~C~?~~~~~tl~a:q.~arr~ WEBSiTE : ~rsv~~r<~es~a~~Iag.L~~ .17 C:1Docoments and Settings\Oamer\Desktop\Transnut Cm~oco.docx it • • Memory Multi-Finger Caliper ,~ Log Results Summary Company: ConocoPhillipsAlaska,lnc. Well: 1D-03 Log Date: February 7, 2009 Field: Kuparuk Log No.: 7298 State: Alaska Run No.: 1 API No.. 50-029-20408-00 Pipet Desc.: 3.5° 9.2 Ib. J-55 BTC Top Log Intvl: Surface Pipet Use: Tubing Bot. Log Intvl: 7,338 Ft. (MD) Inspection Type : Corrosive & Mechanical Damage Inspection COMMENTS This caliper data is tied into the tap of the Baker `EL-1 ` SBR at 7,272' (Driller's Depdt). This log was run to assess the condition of the 3.5" tubing with respect to internal corrosive and mechanical damage. The caliper recordings indicate the 3.5" tubing is in good condition, with no significant wall penetrations, areas of cross-sectional wall loss or I.D. restrictions recorded throughout the interval togged. The caliper recordings indicate slight buckling, severity gradually increasing with depth, from 1,000' to packer at 7,304'. MAXIMUM RECORDED WALL PENETRATIONS No significant wall penetrations (> 10°10} are recorded throughout the tubing logged. MAXIMUM RECORDED CROSS-SECTIONAL METAL LOSS : No significant areas of cross-sectional wall loss (> 6%} are recorded throughout the tubing logged. MAXIMUM RECORDED ID RESTRICTIONS No significant I.D. restrictions are recorded throughout the tubing logged. Field Engineer: Wm. McCrossan Analyst: M. Lawrence Witness: C. Fitzpatrick ProActive Diagnostic Services, Inc. / P.O. Box 1369, Strafford, TX 77497 Phone: (281) or {888) 565-9085 Fax: {281) 565-1369 E-mail: PDS@memoryiog,com Prudhoe Bay Field Office Phone: (907) 659-2307 Fax: (907) 659-2314 ~~~-o~`l ~~-s-~a • • Correlation of Recorded Damage to Borehole Profile Pipe 1 3.5 in (14.1' - 7311.6') Well: 1 D-03 Field: Kuparuk Company: ConocoPhillips Alaska, Inc. Country: USA Survey Date: February 7, 2009 ^ A pprox. T ool De viation ^ A pprox. Borehol e Profil e 17 767 1547 GLM 1 2343 3136 ~ i+ 3919 s a a~ !] GLM 2 4715 GLM 3 5512 GLM 4 6312 GLM 5 GLM 6 7123 GLM 7 229 7312 0 5 0 1 00 Da mage Pr ofile (% wall) / Tool D eviatio n (degr ees) Bottom of Survey = 229 1 25 50 100 `v I_ Z 125 c ~O 150 175 200 • • PDS Report Overview ~~,. ~. Body Region Analysis Well: 1 D-03 Survey Date: February 7, 2009 Field: Kuparuk Tool Type: UW MFC 24 No. 218183 Company: ConocoPhillips Alaska, Inc. Tool Size: 1.69 Country: USA No. of Fingers: 24 Anal st: M. Lawrence Tubing: Nom.OD Weight Grade & Thread Nom.ID Nom. Upset Upper len. Lower len. 3.5 ins 9.2 f -55 BTC 2.992 ins 3.5 ins 6.0 ins 6.0 ins Penetration and Metal Loss (9'° wall) ttttti penetration body ~ metal loss body 250 200 150 100 50 0 0 to 1 to 10 to 20 to 40 to over 1% 10% 20% 40% 85% 8$% Number of 'oints anal sed total = 247 pene. 110 137 0 0 0 0 loss 29 218 0 0 0 0 Damage Configuration (body ) 10 0 isolated general line ring hole / poss pitting corrosion corrosion comosion iMe hole Number of 'oints dama ed total = 0 0 0 0 0 0 Damage Profile (% wall) ~ penetration body ~,~~;; metal loss body 0 50 100 n GLM 1 GLM 2 GLM 3 GLM 4 GLM 5 GLM 6 GLM 7 Bottom of Survey = 229 Analysis Overview page 2 PDS REPORT JOINT TABI, Pipe: 3.5 in 9.2 ppf J-55 BTC Well: Body Wall: 0.254 in Field: Upset Wall: 0.254 in Company: Nominal I.D.: 2.992 in Country: Survey Date: • ~ LATI O N SHEET 1D-03 Kuparuk ConocoPhillips Alaska, Inc. USA February 7, 2009 Joint No. )t. Depth {Ft.) Nc n. Up~r~t (lns.~ Pen. Body (Ins.) I'e~n. % alc~(.il I iris ,~~ Min. LD• (Ins.) Comments Damage Profile (%wall) 0 50 100 .1 14 O 0.01 5 ~ 2.9 PUP 1 17 ~ 0. 1 2 2.96 48 U 0. 1 ~ ~ 2. 5 3 80 l) 0 01 ' .94 4 111 U 1 ' 2.96 5 14 U 0.01 ~ ~t 2. 7 6 174 U 0.01 4 2.95 7 205 a .00 1 ' .94 8 236 U 0.01 ~ 6 9 67 (~ 0.01 ' .95 10 298 O 001 3 2. 5 11 329 U 0.01 Z 2.95 1 361 l~ 0.00 1 .9 Sli ht uckli 13 392 l~ 0. 0 1 2. 14 424 U 0.01 ' _' 2.94 15 453 l) 0.01 Z .' 2.96 16 5 u 0.01 ~~ 2. 3 17 516 U 0.01 ~ ' 6 18 548 O 0. 1 Z .95 19 5 u 0.00 1 I 2. 7 20 611 t~ 000 I 2.97 21 643 c? 0.00 1 2.95 22 74 U 0.01 ' .95 23 706 tl 0.00 1 2.96 Sli ht Buckli 73 l) .0 1 8 25 767 t ~ 0.00 1 .' 2.93 26 798 ~ ~ 0.00 1 2 2.94 27 828 !? 0.01 2 2 2.95 8 859 ~ ? 0.00 1 ' ~ .97 29 890 {? 0.00 I ' 2.96 921 U 0. 1 4 .95 31 952 (~ 0.01 4 2.96 32 98 U .00 1 .96 33 i 015 (1 0,00 1 ' 2.95 4 1046 l~ 0.00 1 s 2.93 Sli ht Buckli 35 1076 a 0.01 2 .' 2.96 6 11 7 l) 0.0 1 8 37 1139 U .01 2 ' 2.94 38 1170 U 0.0 1 .97 39 1202 !) 0.00 I I 2.96 12 4 n 0.00 1 ~ 2.97 41 1 65 (~ 0.00 1 _' 2.97 1 96 (~ 0.00 I 2.94 43 132 7 U 0.00 I ,' 2.95 44 1358 ~~ 1 ~~ .96 45 1389 U 0.00 1 _' 2.96 46 1421 ! ~ 0.00 1 ~ 2.9 i ht c in . 47 1452 (~ 0.01 2 Z 2.96 48 1484 ~ 0.01 2 2 6 49 1515 0.01 ~ 2.96 _ Penetration Body Metal Loss Body Page 1 PDS REPORT JOINT TABI. Pipe: 3.5 in 9.2 ppf J-55 BTC Well: Body Wall: 0.254 in Field: Upset Wall: 0.254 in Company: Nominal I.D.: 2.992 in Country: Survey Date: • ELATION SHEET 1D-03 Kuparuk ConocoPhillips Alaska, Inc. USA February 7, 2009 Joint No. Jt. Depth (FtJ I'c~n. l_11~sc~t (In.) Pen. Body (Ins.) Pen. °~b 1~lctal I ~~ss ~~ Min. LD• (Ins.) Comments Damage Profile (%wall) 0 50 100 0 1547 ~ ~ 0.00 1 2.9 1 1 78 U ~ I 2.94 5 1609 ~t 0.01 Z I .97 53 1641 u 0 01 ? ~ 2.97 54 167 ~~ 0.01 2 ' 2.95 5 1703 U 0.00 1 ~ 2 6 1734 U 0.00 1 ~ 2.94 7 1765 U 0.00 1 ~ 2.9 58 1 9 U 0.00 1 .' .9 Sli ht B c i 59 18 6 I I 0.01 2 95 60 858 U .00 1 a 2 96 61 189 t ~ 0.01 ? 2.94 192 c~ 0. 1 > I 2.9 62.1 1953 l1 0.0 _' .95 P 62.2 957 (1 0 ~~ .81 SSSV 6 .3 19 8 U 0. 0 1 2.96 PUP 63 972 U 0.00 1 ' 4 2003 O 0. 1 ~ ' 9 65 2034 U 0 0 1 1 .9 66 20 6 U 0 00 1 ~ 2.9 67 2 97 tl .01 2 9 68 212 a 0.00 1 .95 9 2 60 ~ I 0.00 1 .94 70 2189 ~ ~ 0.00 1 2.95 71 U 0.01 I~ t c 72 2250 i I 0. 1 1 2.96 7 2281 II 0.00 1 i .96 74 2313 i ~ 0.00 2 ~' 2.97 75 23 3 c~ 0. 0 1 Z 2.96 76 2375 ~~ 0.01 ~' 2.95 761 6 t) 0.00 1 I .96 PUP 76.2 2411 U 0 U u N A GLM 1 Latch ®9:30 76. 418 O .01 2 ~~ 2.97 P P 77 2423 U 0.01 1 _' 2.98 7 245 0 .00 1 .96 79 2486 l) 0.01 2 t 2.96 2517 tl 0.01 2 2 .96 81 2548 I ~ 0.01 2 1 2.95 82 258 t 1 0 01 Z _' 2.96 83 2611 a 0.00 1 _' 2.96 64 a 0.00 1 ' .95 85 2674 (~ 0.01 5 ~ 2.93 7 5 ~ I 0. 1 2 94 87 2737 l~ 0.00 1 2.94 Sli ht BucMi 2768 ~) 0.01 2 2.93 89 2798 II 0.00 1 I 2.94 90 2828 c1 0.01 ' .9 91 2859 ~ ~ 0.00 1 ? 2.95 91 ~ ? 0.01 .93 93 2922 i'~ 0.01 2.95 _ Penetration Body Metal Loss Body Page 2 • • PDS REPORT JOINT TABULATION SHEET Pipe: 3.5 in 9.2 ppf J-55 BTC Well: 1 D-03 Body Wall: 0.254 in Field: Kuparuk Upset Wall: 0.254 in Company: ConocoPhillips Alaska, Inc. Nominal I.D.: 2.992 in Country: USA Survey Date: February 7, 2009 Joint No. Jt. Depth (Ft.) Pcn. Upset 11ns.) Pen. Body (Ins.) Pen. % ~1c~t,il I os~ ~~ Min. LD• (Ins.) Comments Damage Profile (%wall) 0 50 100 94 952 U 0 00 I 2.9 9 ' 984 U .00 2 ' .94 6 3015 U 0.00 1 ~ 2.94 97 3044 t) 0.00 I I 2.93 9 3076 U 0.01 _' _' .9 Sli ht Bu kin . 99 3107 U 0.0 I ' .94 1D0 3136 ~) 0.01 ? ~ 2.94 101 3167 U 0.00 1 1 .94 102 31 9 Q 0.01 Z 2. 5 103 3231 U 0.01 ' .9 104 3 6 U 0.01 2 _' 2.96 105 329 i) 0.01 4 Z 2 94 106 3324 U 0.01 2 ? 2.96 107 3356 i) 0.01 2 ? 2.95 10 3387 U .0 .9 109 3418 l) 0.00 1 2.95 S i t ucklin . 110 3449 U 0.01 2.94 1 1 3481 U 0. 1 .94 112 3512 t~ 0. 1 .94 113 3544 U 0. 1 2 ~ 2.93 114 3575 a 0.01 2 2.93 115 3606 !) 0.01 ~~ ~, 2.98 11 637 U 0.00 1 2.95 117 3669 tl 0.01 2 2.96 700 (1 0.00 1 .93 119 3732 i) 0.00 1 2.93 120 3761 U 0.03 10 _' 2. 121 3793 U 0.00 1 ~~ 2.97 Sli t Bucklin . 12 824 U 0.01 ' ~ 2.9 123 3856 i) 0.00 1 ~ 2.95 1 4 38 7 O 0.01 2 2 .94 125 3919 ~) 0.00 1 _' 2.94 126 3950 i) 0.01 2 _' .96 127 3981 U 0.01 ? 2.94 128 4012 i) 0.00 1 ' 9 129 4044 U 0.01 2 ? 2.93 130 74 O 0.01 2 _' 2.97 131 4106 U 0.00 1 _' .94 1 2 4137 i) 0. 0 1 ' .94 133 4169 0 0.01 4 .93 Sli ht Bucklin . 134 4199 i) 0.00 1 ~ .95 135 4230 U O.OD I _' 2.95 36 426 i) .00 1 .97 137 4293 t1 0.01 2 ~ 2.95 138 4323 U 0.00 1 ,' 2.95 139 4354 t) 0.00 1 ~' 2.96 140 4386 U 0.00 1 ! 2.9 141 4417 i ~ 0.00 1 2.94 141.1 4448 0.00 1 .97 PUP 141.2 4455 0 ! ~ ! ~ N A GLM 2 Latch Q 9:3D Penetration Body Metal Loss Body Page 3 s ~ PDS REPORT JOINT TABULATION SHEEP Pipe: 3.5 in 9.2 ppf )-55 BTC Well: 1 D-03 Body Wall: 0.254 in Field: Kuparuk Upset Wall: 0.254 in Company: ConocoPhillips Alaska, Inc. Nominal I.D.: 2.992 in Country: USA Survey Date: February 7, 2009 Joint No. Jt. Depth (Ft.) Pcn. Ulri~•i Una.) Pen. Body (Ins.) Pc•n. % Mc~l•rl I oss `,4~ Min. LD• (Ins.) Comments Damage Profile (%wall) 0 50 100 141.3 4461 a 0. 0 1 1 2.9 PUP 142 4464 l) 0.0 1 ' 2.9 143 44 6 U 0 1 .9 144 45 7 U 0.01 Z ~ 2. 3 45 45 9 ~) 0. 0 1 .94 146 4591 U 0.00 1 ? .94 147 46 2 ~) 0.00 1 ' 2.96 148 4653 a 0.00 1 ~ 2.94 Sli ht Buckli 149 4684 ~) 0.00 1 _' .95 150 4715 ~) 0.01 ~ ~' 2.97 151 4747 t) 0.01 2 _' 4 152 4777 U 0.01 2 2. 3 1 3 4809 a 0.01 2 _' 2.94 154 4839 t1 0.00 1 _' .95 Sli t Buckli 155 4871 O 0.00 1 ~ .97 156 4901 t) 0.01 2 _' 2.95 157 4933 ~) 0.01 ' .' .96 158 4 6 O 0. 1 ' 159 4996 l) 0.00 Z ? .93 160 5027 t) 0.01 ? 1 .93 li ht uc i 161 059 t) 0.01 4 I 2.9 162 5089 U 0.01 .' ' 2.93 163 1 0 t) 0.00 Z 2.94 164 5151 U 0.01 _' ~ 2.94 65 183 ~) 0 00 I .95 166 5214 ~) 0.01 _' 2.94 167 52 ~ ~ 0. 1 ~ .95 Sli ht Bucklin . 168 5276 i) 0.01 ,_' -1 2.96 169 5307 t) 0,01 .9 170 5339 t) 0.01 2 ~' 2.94 171 5371 c t 0.00 1 1 2.93 172 5402 a 0.01 Z -1 2.96 Sli ht Bucktin . 17 5434 a 0.00 I 2.96 173.1 5465 t) 0.01 2.96 PUP 173. 5471 t) 0 O ~) N A GLM 3 atch ~ 3: 0 173.3 5478 ti 0.02 ~) 2.98 PUP 174 5481 t) 0.01 ~ ~' 2.93 175 5512 i) 0.01 ~ ? 2.93 Sli ht Buckli 76 5543 U 0.00 1 2 3 177 5575 t ~ 0.01 _' _' 2.93 178 606 c) 0.01 ~ I 2.93 179 5637 t) 0.00 1 I 2.93 180 5669 t~ 0.01 _' _' 2.9 181 5701 t ~ 0.02 ' ~ 2.94 Sli ht Bucktin . 8 73 ~ ~ 0. I 2.94 183 5765 ~ ~ 0.01 _' i 2.93 184 5795 U 0.00 I .95 185 5827 (~ 0.00 I ~' 2.94 Sli ht Bucklin . 1 6 58 8 ~) 0.00 I _' 2.93 187 5890 t) 0.00 1 2.94 _ Penetration Body Metal loss Body Page 4 • • PDS REPORT JOINT TABULATION SHEET Pipe: 3.5 in 9.2 ppf )-55 BTC Well: 1 D-03 Body Wall: 0.254 in Field: Kuparuk Upset Wall: 0.254 in Company: ConocoPhillips Alaska, Inc. Nominal I.D.: 2.992 in Country: USA Survey Date: February 7, 2009 Joint No. Jt. Depth (Ft.) I'~~n. t llxr~f (Ins.) Pen. Body (Ins.) Pen. % 'Nc~t,il I oss °~~ Min. LD• (Ins.) Comments Damage Profile (%wall) 0 50 100 8 5921 U .00 1 .93 189 95 U 0. 0 1 ? 2.95 189.1 985 t? 0. 1 ~ Z 2.97 P P 189. 5989 t) 0 (t ~ ? N A GLM 4 atch ®11:30 189.3 599 tl 0.03 10 2.96 PUP 190 6000 U 0.00 1 ~ 5 191 6031 I1 0 00 1 I 2 93 192 6063 U 0.00 1 ~' 2.94 193 609 t ~ 0.01 2 _' 9 Sli ckl' 94 612 t) 0.00 1 ~ .94 195 6157 t? 0.00 1 ~' 2.93 196 6189 U 0.00 1 ? 2. 4 197 1 U 0.01 2 ~ .9 li h c lin . 19 625 a 0.01 4 2.9 1 9 628 (t .00 1 I .92 200 6312 c? 0.00 1 .94 201 6345 i ~ 0 1 2 ~ 2.9 6376 U 0. 1 k 6 02.1 640 tt 0. 2 8 2.9 PUP 202 641 ~? 0 u i? N A GLM 5 at •00 202.3 419 U 0.03 l i l -1 2. 6 P P 203 6423 (? 0.00 I .94 204 6454 t? 0 0 1 I .93 205 6487 (~ 0.01 2 2.93 Sli ht Bucklin . 6 6 t 1 .01 ' ' 207 6548 O 0.00 1 2.96 208 657 O 0.00 1 ~~ .94 209 6611 U 0.00 1 ? 2.96 10 664 cl 0.00 I 2. 4 li uc in . 211 6670 t 1 O.UO 1 _' 2.93 12 6 O1 U .00 Z 9 213 6733 a 0.00 I 2.92 1 676 (t 0.01 3 .96 214.1 6794 a 0.01 Z I 2.96 PUP 214.2 6799 U 0 0 U N A LM 6 atch ~ 6:30 214.3 6806 a 0.03 10 i 2.92 PUP 215 6810 11 0 Ol 2 .92 216 6840 i ? 0.01 ~ ~ i 2.93 217 87 i? 001 2 .94 G htBucklin . 218 6903 r ? 0.01 2 2.93 219 6 5 (~ 0.01 ' 294 220 6965 (? 0.01 5 ' 2.95 2 1 69 7 (t 0.01 4 ! .9 Sli ht B cklin 222 7028 (I 0.01 4 I 2.91 223 706 i 1 0.00 1 I .91 224 7092 (~ 0.01 2 Z 2.95 li t Bucklin . 2 5 71 3 (~ 0. 1 4 ' 2.94 226 7154 (~ 0.03 lU ~ 2.97 226.1 7187 ? .01 -1 2.94 P P 226.2 7191 0 !:~ N A GLM 7 Latch ~ 12:30 Penetration Body Metal Loss Body Page 5 i ~ PDS REPORT JOINT TABULATION SHEET Pipe: 3.5 in 9.2 ppf )-55 BTC Well: 1 D-03 Body Wall: 0.254 in Field: Kuparuk Upset Wall: 0.254 in Company: ConocoPhillips Alaska, Inc. Nominal I.D.: 2.992 in Country: USA Survey Date: February 7, 2009 Joint No. Jt. Depth (Ft.) I'c~n. UI„f~t Ilnti.l Pen. Body (Ins.) Nen. % ~tet,~l I ins ~~ Min. LD• (Ins.) Comments Damage Profile (%wall) 0 50 100 2 6.3 7199 t) 0.02 ~) ~ 2.91 PUP uc in . 27 7203 ~~ 0.01 2 I 2.92 8 7234 ~~ 0.0 2 1 2.93 228.1 7266 ~~ 0.01 2 2.9 P P 228. 7272 U 0 t~ .80 Baker'FL-1' SBR 228. 7304 0 0 u 2.89 Baker'FHL' Packer 2 9 731 U 0.01 2 .92 Penetration Body Metal Loss Body Page 6 FW: 1D-03 (PTD 1790840) Report of high IA pressure Regg, James B (DOA) From: NSK Problem Well Supv [n1617@conocophillips.com] Sent: Wednesday, January 21, 2009 8:49 AM To: Regg, James B (DOA); Maunder, Thomas E (DOA) Subject: FW: 1 D-03 (PTD 1790840) Report of high IA pressure Attachments: 1 D-03 schematic.pdf; 1 D-03 90 day TIO plot.png Page 1 of 1 '\C~~ ~IZ~~UI From: NSK Problem Well Supv Sent: Wednesday, January 21, 2009 8:07 AM ~~ ~~ a a r ~:; 4 ' ~~ ~ a~.,•.. To: 'tom.maunder@alaska.gov'; 'Regg, James B (DOA) ' '? x ~'~ ~~~ ~. Subject: 1D-03 (PTD 1790840) Report of high IA pressure Tom, Jim Kuparuk gas lifted producer 1 D-03 (PTD 1790840) was reported by the DSO to have a high IA pressure while the well is shut in. The current TIO is 2250/2100/540/0 and the well remains SI. A leaking GLV is s_us- pecte~c~L will troubleshoot the leak and repair if possible. ~~ ` Attached is a schematic and 90 day TIO plot. «1 D-03 schematic.pdf» «1 D-03 90 day TIO plot.png» `~ Please let me know if you have any questions. Brent Rogers/Martin Walters Problem Wells Supervisor ConocoPhillips Alaska, Inc. Desk Phone (907) 659-7224 Pager (907) 659-7000 pgr. 909 c~~P= 4z.Z~~ ~ ~- c~[-- ` nlC1~~'c~ w~~ C~ ~4 1 /28/2009 KRU 1 D-03 PTD 179-084 1 /21 /2009 T1U0 Piot -1 D-03 2000 1500 a 1000 500 0 .............................................................................................................................:..................... c1w lac --~ ~~v .................... . i i ~~ i k _ .................. ........ .......... ...... 1..... ........ _....1 ~~ ~~ 01-Nov-08 01-Dec-08 Date 01-Jan-09 200 150 a E as 100 Y O t V 50 0 • ~. _ "- KUP _ _ ~ 1D 03 ~~. _ Can©COPh11~tp5 ( well Attributes __ ____ _ Max Ankle & MD _ITD _ _ rrsllbore APIIUW I Field Name Well Slalus Protlllnj Type Incl (°) MD (ftK6) Act Btm (ftK6) `~ i""`"`"~ 500292040800 KUPARUK RIVER UNIT PROD 42.87 3,050.00 8,070.0 Comment H2S (ppm) Date Annotation Entl Dste KB-0rd (N) Rig Release Dab w ' -"- ' -- SSSV: TRDP 100 7/1Y2008 Last WO: 38.99 12/30/1979 ___,_____ ou c«,ro: - 1D-o~,l izi?oo4 za9al am Scnemalk ~ Acwel Annotation Depth (ftK6) End Dah Annotation End Data Last Tag: CTMD 7,550.0 2/25/2007 Rev Reason: TAG T 1/2/2009 Casin Stnn s String OD String ID Sat Depth Sat Depth (ND) String Wt String coNDUC'ro ~ I Casing Deacnphon (inl lint Top (ftK8) (ftK6) (ftKBt (Ibs/tt) Grade String TOp Thrd 6o r. CONDUCTOR 16 15.060 0.0 80.0 80.0 65.00 Hd0 SURFACE 103/4 9.794 0.0 2,904.0 2,707.9 45.50 K-55 sAFErrvLV, ~ PRODUCTION 7 6.151 0.0 8,057.0 6,825.4 26.00 K-55 1,966 - ~ ' ', ', Tubing Strings 51 ng uD Sl g ID ~ sat D p n 5~1 L =plh (TVD] Slr ng wt 9t ing ~ Tubing D pt on (~) ( 1 Top (ftK6) IfIK9) (nKB) (lhs (1) G ndo SI ng Top Thrd cAS 1 ~ j 1 ~ ~ i2 n U ,45 U ~,~-11-1 9?D J ~ BT(, 2 4 6__ - I J I '' Other In HOIe ~A II Jewe~_Tubing Run 8 Retrievable, Flsh, etc:) _ _ _ - - - Top Depth T SURFACE, (ND) Top Incl 2.904 _ Top (flKB) (ftK0) (°) Description Comment Run Data ID (in) - 1,968.0 1,919.9 24.57 SAFETY VLV Camco TRDP - Upper hydraulic control line not locked 12/30/1979 2.813 cns uFT, a,45s F L ~ 3/221999 2,416.0 2,319.0 32.25 GAS LIFT CAMCO/KBUG/1/GLV/BW.15 I { ~ 4,455.0 3,875.5 41.59 GAS LIFT CAMCO/KBUG/1/GLV/BW.25 cns uFr, sp]o ~_ ~ _; _L 5,470.0 _____ 4,646.5 _____ 38.48 _. __ GAS LIFT _-_..- j open. 1968' RKB TRDP 1A-SSA flapper locked out. CAMCO/KBUG/1/OV/BW.313 ___-__.. _.._.. ___._..... GAS LIFT, 6,411 _-.. ~ . GAS LIFT, 8,797 GAS LIFT, c ~ =y Sa R, ],2]2 p 4 j1 PACKER, ],303 t NIPPLE ] 340 , , '} sos, ].3as ~, _ 9 ( TTL, 7,346 I L- _~ FRAC, 7,422 RPERF, ],445],460 '" IPERF, j, 7,422-7,519 I IPERF, ],525-],531 IPERF, 7,539-7,545 IPERF, 7.556-].567 IPERF, ] ]]8 ] ]98 ____ Perforations - _- - _._ hit Top (ND) Btm (TVD) Dens Top (RKB) Btm (ftKe) (RKB) (ftK6) Zona Data (sh,,, Tvw I Comment Stimula tions & Treatme _ nts - - - _--- eenom - Min Top Ma: Bim Top Depth Depth Depth Depfh (ND) (ND) (ftK8) (ftK6) (flKB( (flKB) Type Deta Comment 7,422.0 7,476.0 6.304.9 _ 6,348.7 FRAC 12/21/2002 C_SAND FRAC Notes: General R Safety End Date Annotaticn 5/15/2003 NOTE: WAIVERED WELL: IAx OA COMMUNICATION •1 IPERF. ],808-7,832 PRODUCTION, 8,057 rD, e.mo 02/16/07 Schlumbel'gel' NO. 4142 Schlumberger -DCS 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Company: Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 SCANNED FEB 2 1 2007 l-:=t Cj - 0 75 ~/ Field: Kuparuk Well Date Color CD BL Job# Log Description 10-111· 11638816 INJECTION PROFILE 01124107 1 1H-19 . 11663824 INJECTION PROFILE 01125107 1 2T -30 . 11663825 PRODUCTION PROFILE 01/26/07 1 2K-02 . 11663829 PRODUCTION PROFILE 01/30107 1 3J-02 11632653 INJECTION PROFILE 01130107 1 3J-08 11632657 INJECTION PROFILE . 02103107 1 2M-OS· 11632658 SBHP SURVEY 02104/07 1 1A-19· 11632660 PRODUCTION PROFILE 02105107 1 3J -04 . 11628963 INJECTION PROFILE 02108107 1 1C-09· 11638818 INJECTION PROFILE 02109107 1 2M-26 11638819 INJECTION PROFILE 02110107 1 1 D-03 11628967 PRODUCTION PROFILE 02111/07 1 1 C-20 NIA RSTIWFL 02112107 1 Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. ¡/f . . 12/06/06 Scblumbepgep NO. 4061 Schlumberger -DCS 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth .¡,£" Ii. ,,~M~H'1 ~~\:,6'~.~d ·~l;;j&,c.-' r I" Company: Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 r-:::¡g- 015¿/ Field: Kuparuk . Well Job# Log Description Date BL Color CD 1G-16 11486083 INJECTION PROFILE 11/26/06 1 1C-133 11486084 INJECTION PROFILE 11/27/06 1 1R-20 11486085 LDL 11/28/06 1 1 D-05 11486086 INJECTION PROFILE 11/29/06 1 1 D-03 N/A SBHP 11/25/06 1 1 D-09 N/A SBHP 11/25/06 1 2T-18 11477636 INJECTION PROFILE 12/01/06 1 1R-03A 11483497 INJECTION PROFILE 11/30/06 1 2X-03 11483499 INJECTION PROFILE 12/02/06 1 1E-04 11477639 INJECTION PROFILE 12/04/06 1 . Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. ConoCOphillips Mike Mooney Wells Team Leader Drilling & Wells P. O. Box 100360 Anchorage, AK 99510-0360 Phone: 907-263-4574 January 22,2003 Commissioner Cammy Oechsli Taylor State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Subject: Report of Sundry Well Operations for 1D-03 (179-084) Dear Commissioner: ConocoPhillips Alaska, Inc. submits the attached Report of Sundry Well Operations for the recent stimulation operations on the Kuparuk well 1D-03. If you have any questions regarding this matter, please contact me at 263-4574. Sincerely, M. Mooney Wells Team Leader CPAI Drilling MM/skad Alaska 01., & e~s, '~ ........ SCANNED FEE~~ STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown_ Stimulate _XX Plugging _ Pull tubing _ Alter casing _ Repair well _ 2. Name of Operator ConocoPhillips Alaska, Inc. 3. Address P. O. Box 100360 Anchorage, AK 99510-0360 5. Type of Well: Development _ X Exploratory __ Stratigraphic _ Service__ 4. Location of well at surface 3' FNL, 601' FEL, Sec. 23, T11N, R10E, UM At top of productive interval 742' FSL, 1328' FWL, Sec. 14, T11N, R10E, UM At effective depth At total depth 4312' FNL, 4252' FEL, Sec. 14, T11N, R10E, UM (asp's 560486, 5959664) (asp's 556827, 5960602) 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Length CONDUCTOR 80' SUR. CASING 2799' PROD. CASING 7952' Perforate _XX Other_ 6. Datum elevation (DF or KB feet) RKB 105 feet 7. Unit or Property name Kuparuk Unit 8. Well number 1 D-03 9. Permit number / approval number 179-084 / 10. APl number 50-029-20408 ~.~ 11. Field / Pool Kuparuk Oil Pool 8070 feet Plugs (measured) sand plug @ 7476' 6836 feet 7722 feet Junk (measured) 6548 feet Size Cemented Measured Depth True vertical Depth 16" 216 sxAS I 115' 115' 10-3/4" 3200 sx AS 2904' 2708' 7" 1600 sx Dowell Self Stress 8057' 6825' Perforation depth: measured 7422' - 7519', 7525' - 7531' 7539' - 7545', 7556' - 7567', 7778' - 7798', 7808' - 7832' Tubing (size, grade, and measured depth) Packers & SSSV (type & measured depth) 3-1/2", 9.2#, J-55 Tbg @ 7346' MD. BAKER 'FHL' @ 7303' MD. CAMCO TRDP-1. LOCKED OUT 3/22/99. @ 1968' MD. 13. Stimulation or cement squeeze summary Intervals treated (measured) 7422' - 7476' MD Treatment description including volumes used and final pressure 245,415# of proppant behind pipe 14. Prior to well operation Subsequent to operation Representative Daily Averaqe Production orlniection Data OiI-Bbl Gas-Mcf WatePBbl 1250 2287 1564 1158 978 1584 Cas ng Pressure Tubing Pressure 264 255 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations Oil__ X Gas_ Suspended__ Service _Water Injector 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed M~chael Mooned/ Form 10-404 Rev 06/15/88 · Title: Wells Team Leader Questions? Call Mike Mooney 263-4574 Prepared b~/ Slfa/fon Al/sup-Drake 263-4612 SUBMIT IN DUPLICATE Date Comment 1D-03 Event History 12/16/02 12/17/02 DRIFTED TBG W/5' X 2.125"STEM. TAGGED FILL @ 7833' RKB. EST 1' RATHOLE. DUMMIED GAS LIFT STRING. PT TBG TO 2500#. GOOD TEST. [PT TBG-CSG, TAG, GEV] PERFORATED 7445-7460 ET MD WITH 2 1/8" ENERJET BH CHARGES. RAN JEWELRY LOG AND TAGGED mD AT 7821 FT MD. T TAIL AT 7335 FT MD. LEFT WELL SHUT IN- INFORMED PAD OPERATOR. [PERF] 12/18/02 12/19/02 12/20/02 12/21/02 12/23/02 PUMPED 8200 LBS OF 20/40 RIVER SAND IN 40# HEC GEL TO COVER LOWER PERFORATIONS. FREEZE PROTECTED WELL WITH 23 BBLS OF DIESEL. [OTHER STIM] PUMPED 2200# OF 20/40 SAND IN 40# HEC. DISPLACED SAND TO TUBING TAIL, THEN SHUT DOWN TO LET SAND SE'I-FLE TO BO'I-rOM. INITIAL TAG TOO DEEP. PUMPED ADDITIONAL SAND.TAGGED FILL @ 7467' RKB. FILL IN CENTER OF FRAC WINDOW. [TAG] LOADED IA W/137 BBLS SW W/53 BBL DIESEL CAP. INSTALLED PETRADAT @ 7186' RKB. PT TBG & CSG. TASGGED FILL @ 7476' RKB (ELM CORR)o INSTALLED FRAC SLEEVE @ 1968' RKB. [PT TBG-CSG, TAG] PUMPED FRACTURE TREATMENT WITH 40# DELAYED X-LINK AT 20 BPM. PLACED A TOTAL OF 245,415 LBS OF PROPPANT (241,693# 16/20, 3,722# 12/18) BEHIND PIPE WITH 10 PPA OF 12/18 PROPPANT ON PERFS. RECOVERED ALL TREESAVER RUBBER. [FRAC-REFRAC] POST FRAC FCO - CLEAN OUT TO C SAND PERFS WITH SLICK SEAWATER - WELL BEGAN TAKING FLUID - SWITCH TO SLICK DIESEL FOR REMAINDER OF FCO - CLEANOUT TO 7835' CTM - WASH SLOWLY PAST ALL MANDRELS - LEFT WELL FLOWING - F-I-F=109 DEG [FCO] SCANNED FEB 1 0 2003 Page I of I 1/13/2003 / / Drill Site lA Well No. ATTACHMENT I I KUPARUK RIVER UNIT Production Logs Log Date 7/6/83 10/29/83 2/8/82x~ 517/82/ 1/25/82~x3-- 3123183 / 1/19/83") 3/21/83/ 318182 4/1/82 6/5/82 5/11/82~ Drill Site Well No. Log Date 18 '"'18-1 12/26/81 ~18-2 6/25/81 '~18-3 11/16-18/81'-.7 "' 3/12/82/ ~18-6 11/18/81k,. "~ 9/10/82/ ~" ~18-7 - 11/23/81 ~IB-8 12/28/81',~ '~ 8~4/82/~' ~IB-g ~ 6/24/82,..-~q~, Drill Site Well No. lC _x"~lC-1 '"'1C-2 "1C-3 '-~1C-4 '~X,~lC-5. / ""1C-6 '"~1C-7 "~ 1C-8 Log Date · 5/9/81 5/8/81 7/13/81 1~1818r,> 3/9/81/ 2/26/81 11/30/81 5/19/81 5/21/81 Drill Site 1D Well No. Log Date "x~lO-1 1/80"~ ~,. ~ 5/23/83/ '"'1D-3 8/5/80 ]D-4 ~7/30/80~ ~ 8/13/80/ '~' ~1D-5 6/11/81 - ~1D-6 6/9/81 . ~1D-7 6/8/81 %JlD-8 (WS-8) 5/10/78 ARCO Alaska, Inc. ~ Post Office Bt 60 Anchorage, A,_~a 99510 Telephone 907 277 5637 July 21, 1982 C. V. Chatterton State of Alaska Oil and Gas Conservation Comm. 3001 Porcupine Drive Anchorage, Alaska 99504 DearMr. Chatterton: Enclosed are subsequent reports for KuparukWells lA-5, lA-6, 1D-2, 1D-3, 1D-4, and lD-5 covering acid stimulations. Sincerely, E. A. Simonsen EAS/er cc: L. K. Blacker -AFA 330 w/o Attac~t L. B. Kelly -AST 306 w/Attachment L. M. Sellers - ANO 332 w/Attachment H. C. Vickers -AFA 326 w/o Attachment ARCO Alaska Inc is a ~ub.~d,ary of AllanhcR~chheldCot~panx A( STATE OF ALASKA ~L, ALASK ~JIL AND GAS CONSERVATION ,vlMISSION SUNDRY NOTICES AND REPORTS ON WELLS 1 DRILLING WELL [] COMPLETED WELL I~ OTHER [] 2 Name of Operator 7 Permit No ARCO Alaska, ]:nc. 79-84 3 Address 8 APl Number P.0.Box 360, Anchorage, AK 99510 50- 029-20408 4 Location of Well SL' 3' FNL, 601' FEL, Sec. 23, TllN, RiOE, UM 5 Elevation in feet (indicate KB, DF, etc ) KB=105' 6 Lease Designation and Serial No ADL 25650 9 Umt or Lease Name Kuparuk River Unit 10 Well Number 1D-3 11 F~eld and Pool Kuparuk River Field Kuparuk River 0il Poo 12 (Submit in Triplicate) Perforate [] Alter Casing [] Perforations Stimulate [] Abandon [] Stimulation Repair Well [] Change Plans [] Repairs Made Pull Tubing [] Other [] Pulhng Tubing (Note Report multiple completions on Form 10-407 w,th a submitted Form 10-407 for each completion ) Check Appropriate Box To Indicate Nature of Notme, Report, or Other Data NOTICE OF INTENTION TO SUBSEQUENT REPORT OF (Submit in Duplicate) [] Altenng Casing Abandonment [] Other 13 Describe Proposed or Completed Operations (Clearly state all pertinent detads and g~ve pertinent dates, ~nclud~ng estimated date of starting any proposed work, for Abandonment see 20 AAC 25 105-170) Begin acid procedure May 16, 1982. RU CTU and pumping equipment. Tested to 4000 psi. RIH to 7990' circulating diesel. Squeezed 12% HC1 acid with additives into perforations 7422-7519', 7525-7531', 7539-7545', 7556-7567', 7778-7798', 7808-7832' MD. Maximum TP:600 psi. Total acid pumped : 118 bbls. Circulate nitrogen and diesel alternate- ly to clean up POOH with CT pumping diesel. Flowed well for two hours to clean up. Turned well into test line. Well tested at 4336 BOPD with 337 psi wellhead pressure. A-30 RECEIVED JUL o L982 Alaska Oil & Gas Cons. Commission Anchorage 14 I hereby certify that the foregoing ~s true and correct to the best of my knowledge S~gned~._ . ,, T~tle The space ow for Commission se Conditions of Approval, ~f ang Operations Engineer Date Approved by, By Order of COMMISSIONER the Commission Date Form 10-403 Rev 7-1-80 Submit "Intentions" in Tnpl,cate and "Subsequent Reports" ~n Duplicate KUPARUK ENGINEERING TO: Transmitted herewith are the following: PLEASE NOTE: BL - BLUELINE, S - SEPIA, F - FILM, T - TAPE RECEIPT ACKNOWLEDGED: PLEASE RETURN RECEIPT TO: AIa$~a Oil & aas cons. Commission DATE: Anchorage ARCO ALASKA, INC. ATTN: LORIE L. JOHNSON - AFA/311 P. O. BOX 360 ANCHORAGE, AK 99510 ARCO Alaska, Inc. Post Ofhce Anchorage, Alaska 99510 Telephone 907 277 5637 ApriI 21, 1982 Mr. C. V. Chatterton State of Aiaska OiI and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99504 Dear Mr. Chatterton: Attached please find Sundry Notices of Intention for Kupaurk Wells 1D-2, 1D-4, 1D-5, 1E-3, 1E-5, 1D-3, 1C-1, lA-7, 1A-9, lA-10, and lA-11. The work on these wells is scheduled for the latter part of April, 1982. Also attached is the subsequent notice for Well 1B-gGI which was perforated in late December, 1981. We apologize for the untimeliness of this report. A recent review of our records revealed this submission had been overlooked earlier. Sincerely, bi Attachments STATE OF ALASKA Ct ALASKA OIL AND GAS CONSERVATION rv~MISSION SUNDRY NOTICES AND REPORTS ON WELLS 1 DRILLING WELL [] COMPLETED WELL OTHER [] 2 Name of Operator 7 Perm~tNo ARCO Alaska, Inc. 79-84 3 Address 8 APl Number P .0. Box 360, Anchorage, AK 99510 50- 02_9-20408 4 Location of Well 9 Umt or Lease Name Kuparuk ;>5650 S.L. 3'FNL, 601'FEL, Sec 23, T11N, RIOE, UM B.H.L. 937'FSL, 1064'FEL, Sec 13, TllN, RIOE, UM 10 Well Number 1D-3 5 Elevation m feet (,nd~cate KB, DF, etc ) I 6 Lease Designation and Serial No __ 101' RKB I ADL 25650 12 Check Appropriate Box To Indicate Nature of Not~ce, Report, or Other Data 11 Field and Pool Kuparuk River Kuparuk River NOTICE OF INTENTION TO SUBSEQUENT REPORT OF (Submit m Tr~phcate) (Submit m Duplicate) Perforate [] Alter Casing [] Perforations [] Altering Casing Stimulate X[] Abandon [] Stimulation [] Abandonment Repmr Well [] Change Plans [] Repmrs Made [] Other Pull Tubing [] Other [] Pulhng Tubing [] (Note Report multiple completions on Form 10-407 w~th a submitted Form 10-407 for each completion ) Field Oil Pool 13 Describe Proposed or Completed Operations (Clearly state all pertinent detads and g~ve pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25 105-170) ARCO Alaska, Inc. proposes to stimulate this well using a 12% HC1 plus additives treatment. Acid will be spotted across and squeezed into the perforated interval using a coiled tubing unit. All circulated and flowed fluids will be diverted to on site tankage. After clean up, the well will be turned into the CPF test separator for rate determination. This work is scheduled for the later part April, 1982, and will take one day to complete. of 14 I hereby certify that the foregoing ~s true and correct to the best of my knowledge ~ (~.~ Area Operat,ons Engineer S~gned . _ T~tle The space ~w for Commission f Conditions of Approval, ~f any ~.pproved ~oDY Date Returned By Order of Approved by I~¥ [0ti~1~ ~, ~l~ COMMISSIONER the Commission Date Form 10-403 Rev 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" In Duplicate - ' ( STATE OF ALASKA ! ALASKA .~ AND GAS CONSERVATION C ,, ,IISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG I Status of Well Classification of Service Well OIL [~ GAS [] SUSPENDED [] ABANDONED [] SERVICE [] :2 Name of Operator 7 Permit Number ARCO Alaska, Inc. 79-84 3 Address 8 APl Number P.0.Box 360, Anchorage, AK 99510 50- 029-20408 4 Locat,on of weIl at surface 3'FNL, 601' i-EL, Sec 23, TllN, R10E, UM 9 Un,t or Lease Name Kuparuk 25650 AtTopProduclnglnterval 742'FSL, 1328'FWL, Sec 14, T11N, R10E, UM 10WellNumber - 1D-3 At Total Depth 963'FSL, 1029'FWL, Sec 14, TllN, R10E, UM 11 Fleld and Pool Kuparuk River Field 5 Elevation ,n feet (~ndmate KB, DF, etc } I 6 Lease Designation and Serial No 105' RKB[ ADL 25650 Kuparuk River Oil 'Pool 12 Date Spudded 13 Date T D Reached 14 Date Comp, Susp or Aband 15 Water Depth, ~f offshore [ 16 No of Completions 11/30/79 12/15/79 12/30/79 -- feetMSLI 1 17 Total Depth (MD+TVD) 18 Plug Back Depth(MD+TVD) 19 D~rect~onal Survey 20 Depth where SSSV set I 21 Thickness of Permafrost 8070' 6836' 7990' 6769' YES (~( NO [] 1968' feetMDI 1650' (approx) 22 Type Electmc or Other Logs Run DTL/BHCS/GR, FDC/CNL/GR, CBL/VDL/GR/CCL, Spectralo.q, C.O, NLL 23 CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT PER FT GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 16" 65t~ welded H-40 Surf 80' 24" 216 sx Aretfe.~et T'r 10 3/4 45.5t~ R~Jtt K-55 Surf 2904' 13 3/4 3200 sx Aretieset 2mt 7" 26t~ Butt K-55 Surf 8057' 9 7/8 1600 sx Dowel] gel ? Stres.~ Cement _ 24 Perforations open to Production (MD+TVD of Top and Bottom and 25 TUBING RECORD interval, s~ze and number) SIZE DEPTH SET (MD) PACKER SET (MD) 3 !/2" 7347 ' ' 7309' 7422' -7519 ' 7525' -7531 ' 26 ACID, FRACTURE, CEMENT SQUEEZE, ETC ~ 7539 ' -7545' DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED ,, 7556 ' -7567 ' N/A 7778 '-7798 ' 7808'-7832' w/4 SPF 27 PRODUCTION TEST Date F~rst Production Method of Operation (Flowing, gas lift, etc ) , 12/16/81 Flowing Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAs-McF WATER-BBL CHOKE SIZE IGAS-OILRATIO 8/8/80 17 TEST PERIOD [~ 1925 809 -- RR/6z~I 4?0 Flow Tubing Casing Pressure CALCULATED OI L-BBL GAS-MCF WATER-BBL OIL ~RAVITY-API (corr) Press 190 24-HOUR RATE II~ 2719 1142 -- 23-3 ~ 28 CORE DATA Brlefdescr~pt~onofl~thology, poros~ty, fractures, apparent d~ps and presence of o~l, gasorwater Submit corech~ps N/ARECEIVEi) MAR 1 5 1982 A-27 ~jts'~ 0il & Gas Cons, C0mmi~i0~ Form 10-407 Submit ~n duplmate Rev 7-1-80 CONTINUED ON REVERSE SIDE 29 30. GEOLOGIC MARKERS FORMATION TESTS NAME Include interval tested, pressure data, all flu,ds recovered and grawty, , MEAS DEPTH TRUE VERT. DEPTH -GOR,and t,me of each phase Top Kuparuk River Form. 7423 ' ~' 6305 ' Base Kuparuk River Form. 7879' 6677' 31 LIST OF ATTACHMENTS 32 I hereby certify that the foregoing ~s true and correct to the best of my knowledge S,gned ~,_ (~t. ~"~~ T,tle Area 013.~,. F'n0~'. Date MAR 1 0 '~8~ INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1: Classification of Service Wells: Gas injection, water injection, steam injection, air ~njection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- lng and the location of the cementing tool. Item 27' Method of Operation' Flowing, Gas L~ft, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". Form 10-407 I ~ \,/ELL ~I Y = 5,959,904. ]9 ,,. x  ~ GOl' ~ LAT 70 18:O3.672" < LONG ~ ]49°30'36.426" > I ~ WELL :2 Y ~ 5,959,784.20 I , x - s0, 8s.20 ~ i LAT = 70 ]8'02.~92" ' ~: LONG I~9°30'36 ~2~" I ~, WELL 3 Y - 5 959 664 22 / ] ~ X = ~60,486.26 I~ L~. ~ LAT- 70 18'01.312" P~* '~ ' '~ ~2~ 2~ -- LONG = '49°30'36.42''' < (TIID~RIOe,U~)' WELL "4 , ~ I '~ Y = 5 959 544.23 I ~. X = ~60 487 32 ' > P~ 'F LAT = 70 18~00.~31'' .- ~ LONG = 149°30'36.4~8"~ 1 I <P~ ~ WELL 5 Y = 5 959,424 25 , X = ~60,488.38 > , ~ LAT 70 17' 58.951" v I ... WELL -6 Y = 5,959,304.26 I ~ X = ~60 489 44 > I ~ ~ ~ D]~ ~, > < LAT = 70 17:57. 71" i < ~ LONG = 149°30'36.413" I ~ ........ WELL ~7 Y = 5,959,184.28 D& X = ~60,490.51 ~W~T ~AK~ LAT = 70 17'~6.591" LONG = 149°30'36.409" ~ ~ WELL ~8 Y = 5,959,064.29 ! A X = ~60,491.56 ~ LAT = 70~7'55.411'' ~CALB: 1"=20o' LONG = 149°30'36.407~ ~"'~~"~'".~v~c~-i~ ~1 HEREBY CERTI FY THAT I AM ~.' ~ "%~f~ PROPERLY REGISTERED AHD LICEMSED ~:'49~~ .*;~ TO PRACTICE LAND SURVEYING IN '~,J~". ~ ~. C~~ ..:_~ ~ THIS PLAT REPRESENTS AN AS- ~a'g.'-.~o.. "~ BUILT SURVEY MADE BY ME, AND ~, ~'. No. 4277-S .. ~ ~ ~ ~... ....~ ~ TttAT ALL DIMEHSIONS A~D OTItER J ~" ....... ' ~%~ DETAILS ARE CORRECT,AS OF 'A~~ DATE q/7/7~ ~ illlll i i i -- ii ill ii i WELL5 LOCATION5 5- UILT ~1 i i ~ i ii i iii ]11 i ii i i i ii ii AtlanticRichfieldCompany ~ DATE; DRAWING NORTH AMERICAN PRODUCING DIVISION ALASKA DISTRICT-, KUPARUK SOH I O , LS RICTED SOHIO ALASKA PETROLEUM COMPANY ARCO ~ ,, - -- C~¥~oo -- 3111 "C" STREET ANCHORAGE, ALASKA TELEPHONE (907) 265-0000 MAIL: POUCH 6-612 ANCHORAGE, ALASKA 99502 TO ~ ...... -- Date: 10/7/81 # 1105 SFO/UNIT/STATE [_~.~.~,,~ ~,~ l~ll~l~ ...... - ~1 i. ii i i ii i  . ._ :,,. i i i -- _ _. II J ,D-3 ~D-3 H-12 GC 3B REFERENCE TheSOHIO FINAL DATA CASED HOLE following material is being ~ubmitted herewith. Please acknowledge receipt by signing a copy of this letter and returnmg it to this office:-- Spinner/FIT (Otis) 7/21/81 #1 5" Spinner (Otis) 7/24/81 #3 5" Spinner (Otis) 7/21/81 #1 5" CCL/Perf. Depth Control (Sch). 9/18/81 #1 5" EPL (Sch) 9/7/81 #1 2"/5" - -. SEIVED OCT ? 2 l~! 19 DATE Alaska 0il & Gas Cons. Coma/ssi011 Anchorage D~V ~e ~~nt Geology We l~~ords ARCO Oil and Gas~ mpany North SlopeX Anct Post Ofhce Box 360 Anchorage, Alaska 99510 Telephone 907 277 5637 November 26, 1980 Mr. Hoyle Hamilton State of Alaska Alaska Oil and Gas Conservati on Commi ss i on 3001 Porcupine Drive Anchorage, Alaska 99501 Subject: DS 17-4 Permit #80-85 DS 5-2 Permit #74-36 DS 2-4 Permit #70-17 DS 17-5 Permit #80-96 DS 15-10 Permit #80-88 DS 15-21 Permit #80-91 DS 14-9 Permit #80-89 7 ~NG 2_ ENG 4 -~ ~o~1 STA T T~c STAT T~C - 1 1 Kuparuk E-7 Permit #80-80 D-6 Permit #79-96 D-7 Permit #79-112 D-5 Permit #79-95 E-4 Permit #80-57 E-8 Permit #80-81 D-3 Permit #79-84 Dear Sir' Enclosed please find' 1. A completion report, drilling history and a gyroscopic multishot survey for wells; DS 17-4, E-7, D-6, D-7 & E-8. 2. A Sundry Notice of subsequent report for wells; DS 5-2, DS 2-4, D-3, D-5 & E-4. (An updated Completion Report will be filed, for D-3, D-5 & E-4 as soon as produc- tion test data becomes available.) 3. A monthly report of drilling for wells; DS 17-5, DS 15-10, DS 15-21, DS 14-9,.E-8 & D-7. Very truly yours7 , P. ^. VanDusen D~str~ct Drill~n~ [n~ineer ?AV' sp Inclosures Alaska 0, I A,tcl~,or~3 Oumraiss;on ARCO 0~1 and Gas Company ~s a D~v~s~on of AtlanhcR~chfleldCompany Form 10-403 REV. 1-10-73 Submit "1 ntentlons" in Triplicate & "Subse~luent Reports" in Duplicate STATE OF ALASKA OIL AND GAS CONSERVATION COMMITTEE SUNDRY NOTICES AND REPORTS ON WELLS (Do not use this form for proposals to ~lrlll or to ~leel~en Use "APPLICATION FOR PERMIT--" for such proposals.) 2. NAME OF OPERATOR Atlantic Richfield Company 5. APl NUMERICAL CODE 50-029-20408 6. LEASE DESIGNATION AND SERIAL NO. ADL 25650 7. IF INDIAN, ALLOTTEE OR TRIBE NAME 8. UNIT, FARM OR LEASE NAME Kuparuk 25650 3. ADDRESS OF OPERATOR 9. WELL NO. P.O. Box 360, Anchorage, Alaska 99510 Kuparuk D-3 4. LOCATION OF WELL At surface 3' FNL, 601' FEL, Sec 23, Tl lN, RIOE, UM 13- ELEVATIONS (Show whether DF, RT, GR, etc.) 105' RKB 10. FIELD AND POOL, OR WILDCAT Prudhoe Bay Field/ Kuparuk River Oil ~. SEC.. T.. R.. M.. (BOTTOM HOLE OBJECT,YE) P001 Sec 14, TllN, RIOE, UM 12. PERMIT NO. 79-84 Check Appropriate Box To Indicate Nature of Notice, Repo~rL_o~Other Data NOTICE OF INTENTION TO: SUBSEG~UEN.TREPORT OF; SHUT-OFF PULL OR ALTER CASING WATER SHUT:Ola~' *~ [~ TEST WATER FRACTURE TREAT MULTIPLE COMPLETE FRACTURE TREATMENT ~ ALTERING CASING SHOOT OR ACIDIZE ABANDON* SHOOTING OR ACIDIZING I I ABANDONMENT* REPAIR WELL CHANGE PLANS (Other) Perforate (Other) (NOTEs Report results of multiple completion on Well C Completion or Recompletion Report and Log form.) 15. DESCRIBE PROPOSED OR COMPLETED OPERATIONS (Clearly state III pertinent der&lis, and give pertinent dates, including estimated clate of starting any proposed work. (See attached perforating history) 16. I hereby certify' that the $oj~gol~gHs true and correct District Drilling Engineer DATE November 25, 1980 (This space for State office use), APPROVED BY CONDITIONS OF APPROVAL, IF ANY.. TITLE · DATE See Instructions On Reverse Side DRILLING HISTORY KUPARUK D-3 API #50-029-20408 Permit #79-84 Began perf operations on 7/30/80. Bled tbg press to 0 psi, instld lubri- cation and tst same w/2000 psi. Ran 2-1/8" dummy gun to bridge @ 7802'. Spud on bridge to 7854'. Chng out wireline unit, run 2-1/4" Baker & clean out to 7900'. Chng out wireline unit. Run 2-1/8" perf gun & perf 7556' - 7567', 7939' - 7545', 7525' - 7531', 7505' - 7519'. RIH w/pkr & flow water. Set pkr @ 7493', insure flow rate to record. Set press bomb @ 7360' Monitor press & flow well to tank, avg. 50 bpd FTD 2277 psi. FBHP 3199 ~si /8" ' ·Run 2-1 perf gun & perf 7422 - 7505'. Run press bomb & flow well to separation, avg 2800 bpd. Flow to final stable rate of 2175 bpd. SI for press build-up. Run 2-1/8" perf gun & perf 7778' - 7798' & 7808' - 7832'. Flow well to tank for clean up. Flow test thru separator. Flow tst to stable rate of 1747 bpd. Run Gradiomanometer. Pull tst tools. Shut-in safety ball valve & tst same. RD lubricator. Install & tst tree cap w/5000 psi. Released well to operations group @ 1900 hrs 8/10/80. Anc~ora,ge NORTH SLOPE DISTRICT ENGINEERING TRANSMITTAL # FROM' Jerry J. Pawelek/Leo Lash WELL NAME' ~//uP~tuV_ - ~ ~ Transmitted herewith are the following for the subject well: DATE SCALE XEROX BL SEPIA LINE FILM BHC Sonic/Gamma Ray Log Cement Bond Log/VDL Compensated Formation Density Log Compensated Neutron-Formation Density Compensated Neutron Log Core Analysis - Interval Core No. Core Description (SWC) - Interval Core Description (Conv.) - Core No. Directional Survey - Gyro Single Shot Multi-shot Drill Stem Test - Test No. Dual Induction Laterolog Formation Density Log Formation Density Log/Gamma Ray Spectral og TVD-DIL Differential Temperature Log Spinner Survey Fluid Density Casing Collar Log Perforating Record Neutron Lifetime Log Carbon-Oxygen Log RECEIPT ACKNOWLEDGED FOR: DATE: EASE RETURN RECEIPT TO' ARCo Oil and Gas Company Attn: Mr. Leo Lash P.O. Box 360 - Rm. #311-FAB Anchorage, AK 99510 ARCO-Oil and Ga(""~mpany Post Olifct- P,~,, ,,:~., Anchorage, ~ ' Tc:]ephon,:- LD7 ;'"', September 24, 1980 Mr. Hoyle Hamilton State of Alaska Division of Oil & Gas 3001 Porcupine Drive Anchorage, Alaska 99501 Subject' As-Built Survey Plats Dear S ir- ' 1-.I.\1 co,'^M___! JT-I F_N ?:T - I 4 ENO L/-J 1 GEOL [ STAT TEC ! STAT TEC i , C~NFFR: ~.' ,.' -..' - C ', · In an effort to insure that your files are complete, we havd~attached copies of our well location as-built survey plats for all wells permitted thus far in 1980, excluding those Included in our original drilling permit applications. Very truly yours, P. A. VanDusen D~strlct Drilling Engineer PAV/JBK/jh Attachments Thru~ ALASKA OIL AND GAS CONSERVATION COMMISSION Hoyle H. Hamilto.~~ Chairman/Commissi4~er Lonnie C. Smi~ Commissioner~//~v James K. Trimblee~ Petroleum Engine August 22,1980 Flow Test, Kuparuk Dev- elopment, Well D3. August 6~ .19.8.0~ I left Anchorage at 7500 am, arriving at the Kuparuk at 11=30 am. I met with Kenny Keys, Arco foreman and Eric Skaalure, Arco test engineer. From 12t00 to 8~45 pm Schlumberger worked to get the perforating gun to TD. The oil base mud in the bottom of the hole was very viscous and retarded sinking of the gun. At 8=45 pm perforated 7808~-7832t, 24t - Schlumberger 2 1/8' Enerjet with no response. At 11=30 pm perforated 7778~-7798t, 20t Schlumberger Enerjet, with slight response. The bottom hole pressure before flow started was 3338 psig. AUgust 7, 1980= 02=00 am Started a spinner survey, finishing at 02~30. There was little contribution from the lower zone. The upper zone had previously been perforated from 7422'-7505t. 02~57 am Start clean up flow (see schematic of Kuparuk test, ~3). Average tubing pressure Choke Well head temp Heater temp Fluid flow rate 400 psig 32/64m 52~F 108OF 1850 BPD 08~45 am Started flow test (approximate average valves) Average tubing pressure Well head temperature Choke Heater temperaure Gas temperature Gas gravity API gravity Fluid flow rate BPD GOR BS & W Final flowing bottom hole pressure. 465 psiq 70~F 32/64~ 122~F 107CF 0.77 24.7 1780 370 TR 2330 psig. Flow Test, XUl~.~,uk Devel- opment, Nell AUgust 26~ 1980 Gas measurement-or e, 6.065u bore ~ 2.000" orl£Ace plate, flange taps. Oil ~meaaurenent-! 1/2u turbine meter and tank gaging using 4-400 bbl tanks 12'~ x 20', 1.679 bbl/inch. Bottom hole pressure gas taken continously with a Hewlett-Packard pressure gauge ~n~eoorded at intervals betveen 30 sec. and 10 min. dependln~.~on seleotion. August 8, 1980 02821 aB Finished £1ow test and shut well in initial shut in pressure was 2330 psig. fox' pressure buildup. 07,$0 an Pressure buildup had reached 3282 psig. See plot of first S hours of pressure buildup. X departed for Anchorage. Xn sumnary, I witnessed the £1ov test of Azco's K~aruk Develop- nent~ well ~-3 fron AnA~Aal flow until shut-An for pressure buildup. Flow ~est~ EUl~mjuk Devel- opment, Well -3- August 26~ 2980 Testing Procedure ARCO Kuparuk Perforations, well had been perforated with Schlumberger 2 1/8' BnerJets, 4 spf. Intervals perforated, Upper Sand Stringer Sands Lower Sands 7422-7S05 7556-7567 753g-7545 7525-753! 7778-7798 7808-7832 ~roeedure, Flow to tanks 3 to $ hours to clean up veil. 2, Flow through separators for approximately 24 hours at constant rate. 3. Shut-in two times flow perAod. 4. Analyse draedown and pressure buildup. Data to be taken and =alculated, Well head ~emperature and pressure GOR and WOR Separator ~emperature and pressure FLew rates (gas with or~fiee ue~er, oil with tank gagAng and turbine meter) APl Gravity ~as ;rav~ty H S aon~ent Samples ~aken, Bo~tom hole Separator oil and gas Water \ ARCO Oil and G;~ 'ompany Alaska D~s~, Post Ofhce Box 360 Anchorage, Alaska 99510 Telephone 907 277 5637 July 15, 1980 Mr. Hoyl e Hamil ton State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 J RES ENG i ~ENG J 2 ENG 14 -- I~-I 1 G~OL I 2 OEOL J 3 GFOL J STAT TSC '~l STAT TEC CONFER: , FILF: __ Subject: Kuparuk D-3 Dear Sir: Enclosed please find a Sundry Notice detailing plans for the above-mentioned well. Very truly yours, P. A. Van Dusen District Drilling Engineer PVD/jh Enclosure ARCO Od and Gas Company is a D~v~slon of AtlanhcRIchfmldCompany F'o~tn 10-403 REV. 1-10-73 Submit "1 ntentions" In Triplicate & "Subsequent Reports" in Duplicate STATE OF ALASKA OIL AND GAS CONSERVATION COMMITTEE SUNDRY NOTICES AND REPORTS ON WELLS (Do not use this form for proposals to drill or to deaden Use "APPLICATION FOR PERMIT--" for such proposals.) O,L I~1 GAS I--'! WELL ~1..~ WELL I.--.J OTHER 2. NAME OF OPERATOR ARCO Oil and Gas Company 5. APl NUMERICAL CODE 50-029-20408 6. LEASE DESIGNATION AND SERIAL NO. ADL-25650 7. IF INDIAN, ALLOTTEE OR TRIBE NAME 8. UNIT, FARM OR LEASE NAME Kuparuk 25650 3. ADDRESS OF OPERATOR 9. WELL NO. P. 0. Box 360, Anchorage, Alaska 99510 D-3 4. LOCATION OF WELL At surface 3' FNL, 601' WEL, Sec 23, TllN, RIOE, UM 13. ELEVATIONS (Show whether DF, RT, GR, etc.) 105' RKB 14. Check Appropriate Box To Indicate Nature of Notice, Re 10. FIELD AND POOL, OR WILDCAT Prudhoe Bay-Kuparuk River Oil Pool 11. SEC., T., R., M., (BOTTOM HOLE OBJECTIVE) Sec 14, TllN, RIOE, UM 12. PERMIT NO. 79-84 )orr, or Other Data NOTICE OF INTENTION TO: TEST WATER SHUT-OFF [~ PULL OR ALTER CASING FRACTURE TREAT MULTIPLE COMPLETE SHOOT OR ACIDIZE ABANDON* REPAIR WELL CHANGE PLANS (Ot.er) Perforate and Test SUBSEQUENT REPORT OF= WATER SHUT-OFF ~ REPAI RING WELL FRACTURE TREATMENT ALTERING CASING SHOOTING OR ACIDIZING ABANDONMENT* (Other) (NOTEs Report results of multiple completion on Well COmDletlon or Recompietion Report and Log form.) 15. DESCRIBE PROPOSED OR COMPLETED OPERATIONS (Clearly state all pertinent details, and give pertinent dates, inclu(llng estimated date of starting any proposed work. Atlantic Richfield Company proposed to perforate and flow test selected intervals within the Upper and Lower Kuparuk Sands. A 3000 psi wireline BOP/lubricator will be utilized with all wireline work. All perforated intervals and test volumes will be reported on a subsequent report. Expected Start Date ..J.uls 21, 1980. - ¢:&.~equent Work Beportccl , ,'orm No./15 "Y ~ ~- Dated (This space for State o~f7 use) COMM!SgTO'."*rt · TITLE DATE CONDITIONS OF A~P~OVAL, IF AN~:"' ~ra~or ~11 no~ ~e ~(~ion ~or. to. test~g ~ order ~t a C~ssion ~et~rr,~e ~~ti~ ~y ~ ~~t to ~ess ~ ~s~. ,n..ru ,on On ,.v... Drilling Histo D-3 (24-14-11-1~ API NO. 50-029-20408, ADL 25650, Permit No, 79-84 Spudded well @ 1300 hrs 11/30/79. Drld 13-3/4" hole to 2955'. Ran 10-3/4" 45.5# K-55 csg w/shoe @ 2904'. Cmtd csg w/3200 sx Arcticset cmt. Instl & tstd pkoff to 2000 psi. NU BOP & tstd. Drld cmt, shoe, + 10' new hole. Tstd new form to 12.5p~p,g, EMW. Drld 9-7/8" hole to 8070' Ran DIL/BHCS/GR, FDC/CNL/GR logs. Ran, 26#, K-55 csg w/shoe @ 8057'. ~mtd csg w/1600 sx Dowell self stress cmt. Instld & tstd pkoff to 3000 psi. SLM in hole to DV tool @ 2325'. Tag stage collar. RU to Arcticpack. Circ ann. Pump 130 bbls Arcticpack followed by 100 sx Arcticset I cmt. Set DV sleeve & tstd to 1500 psi. Ran gyro. Ran CBL/VDL/GR/CCL logs & spectralog. Ran C/O log & NLL log. Ran 3-1/2" 9.3# K-55 tbg w/shear sub @ 7347' & pkr @ 7309' Tstd pkoff to 3000 psi. NU tree & tstd to 3000 psi. Displ tbg. Set pkr] Ran lng trm tbg tst. Leak in tbg. Ran temp sur & noise log. Fnd lead in gas lift mandrel. Pulled dummy valve & attempted to set new one. Failed. Ret- rieved valve & chng over to oil base mud. ND tree. NU BOPE. Pulled 3-1/2" tbg. Replaced 2 mandrels. Reran 3-1/2"' tbg. Press tbg to 3175 psi. OK Chng oil base mud to diesel. ND BOPE. NU Xmas tree. Press tst pkoff well- head tree to 3000 psi. OK. Conduct lng trm tbg tst. Released rig @ 0600 hrs, 12/30/79. ,( hOt, TI l-O' Transmitted herewith are the fol DATE ~HC Sonic/Gamma Ray Log Cement Bond Log/VDL Compensated Formation Density Log Compensated Neutron-Formation Density Compensated Neutron Log Core Analysis - Interval Core No. Core Description (SWC) - Interval Core Description (Conv.) - Core No. Directional Survey - Gyro Single Shot Multi-shot Drill Stem Test - Test No. Dual Induction Laterolog Formation Density Log Formation Density Log/Gamma Ray Location Plat TVD-DIL Differential Temperature Log Spinner Survey Fluid Density Casing Collar Log Perforating Record Nuclear Flo-log . (,,_) ICT ENGIIIEERING FROM' Jerry J. Pawel~-ete~._ Woodring__~ WELL NAME- ~LYP~d/~ ~)-~.~ subject well- SCALE XEROX SEPIA BL LINE RECEIPT ACKNOWLEDGED FOR' P~ELEA DATE' SE RETURN RECEIPT TO' ARCo Oil and Gas Company Attn' Hr. Pete Woodring P.O. Box 360- Rm. ~449 Anchorage, AK 99510 1/10/80 TO' DATE' Transmitted herewith are the f( DATE 4 EN~ --q-, -~ r~__o~-- FROM: 3 ¢ 0LL STA, T TEC ,, STAT T£C foF :ILF: -- ,, WELL NAME: the subject well- SCALE XEROX SEPIA BL LINE _ BHC Sonic/Gamma Ray Log Cement Bond Log/VDL Compensated Formation Density Log Compensated Neutron-Formation Density Compensated Neutron Log Core Analysis - Interval Core No. Core Description (SWC) - Interval Core Description (Conv.) - Core No. Directional Survey - Gyro Single Shot Multi-shot Drill Stem Test - Test No. Dual Induction Laterolog Formation Density Log Formation Density Log/Gamma Ray Location Plat TVD-DIL Differential Temperature Log Spinner Survey Flui~t Density /o-~-.?~Casi~n'§ Collar Log . !PerfOrating Record Nu:cl ear Flo-log RECEIPT ACKNgWLEDGED FOR: DATE' L/EASE RETURN RECEIPT TO- ~1/10/80 ARCo Oil and Gas Company Attn: Mr. Pete Woodring P.O. Box 360 - Rm. =~449 Anchorage. AK 99510 TO' NORTH SLOPE DISTRICT ENGINEERING TRANSMITTAL FROM' Transmitted herewith are the following for the subject well- /COM COM, .,-~ffCOM, EN( Jerr.y ,.1. Pawelel~ 'L J_ 3-GEl WELL NAME ,,~/-.}J?,~/~/<" Z) ,~. J STAT ' ~'... I STAT CONFE~ L FILF:- DATE SCALE XEROX SEPIA BL LINE B~,C Sonic/Gamma Ray Log Cement Bond Log/VDL Compensated Formation Density Log Compensated Neutron-Formation Density Compensated Neutron Log Core Analysis - Interval Core No. Core Description (SWC) - Interval Core Description (Conv.) - Core No. Directional Survey- Gyro Single Shot Multi-shot Drill Stem Test - Test No. Dual Induction Laterolog Formation Density Log Formation Density Log/Gamma Ray Location Plat ~VD-_DIL Differential Temperature Log Spinner Survey Eluid' Density C~sing Collar Log- PerfOrating Record Nuclear Fl-o-Tog ~ j / / J -/ _ RECEIPT ACKNOWLEDGED FOR' DATE: PLEASE RETURN RECEIPT TO: ARCo Oil and Gas Company Attn: Mr. Pete Woodring P.O. Box 360- Rm. :449 Anchorage, AK 99510 ARCO Oil and Ga~ ompany North Alasl~ D~stnct Post Ofhce Box 360 Anchorage Alaska 99510 Telephone 907 277 5637 February 20, 1980 Mr. Hoyl e Hamilton State of Alaska Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 ~r/coMM /~' i.-COM~ ~ RcS EN~'-' ENG 1 G~OL __ I STAT TEC  3 GEOL~ STAT CONFER: FILF: Subject- Kuparuk 25650 D-3, Permit No. 79-84 Dear Sir: Enclosed please find a revised completion report for Kuparuk 25650 D-3 reporting a corrected top producing interval location of 1328' FWL, and a corrected bottomhole location of 1029'FWL. Very truly yours, P. A. VanDusen District Drilling Engineer PAV'cs Enclosure ARCO O~1 and Gas Company as a D~ws~on of AtlanhcR~chheldCompany )p Form P--7 SUBMIT IN DU ..... , E* STATE OF ALASKA (see other m- structlons on reverse side) OIL AND GAS CONSERVATION COMMITTEE WELL COMPLETION OR RECOMPLETION REPORT AND LOG* la TYPE OF WELL OIL GAS WELLF~ WELLI I b TYPE OF COMPLETION NEW I[/--I WORKI----I DEEP-[--~ PLUG WELLI~ I OVER I I EN I I BACKI I 2 NAME OF OPERATOR Atlantic Richfield Company 3 ADDRESS OF OPERATOR P.O. Box 360 Anchorage, AK 99510 DRY ~] Other 7 DIFF 8 RESER n'-] Other 4 LOCATION OF WELL (Report location clearly and in accordance with any State requirements)* At surface 3'FNL & 601'WEL, Sec 23, TllN, RIOE, UM At top prod ~nterval reported below 742' FSL & 1328'FWL, Sec 14, TllN, RIOE, UM At total depth 963'FSL & 1029'FWL, Sec 14, TllN, RIOE, UM 13 DATE SPUDDED 11/30/79 14 DATETD REACHED 12/15/79 15 DATE COMP, SUSP, OR ABAND 12/30/79 5 APl NUMERICAL CODE 50-029-20408 LEASE DESIGNATION AND SERIAL NO ADL 25650 IF INDIAN, ALLOTTEE OR TRIBE NAME UNIT, FARM OR LEASE NAME Kuparuk 25650 9 WELL NO D-3 (24-14-11-10) 10 FIELD AND POOL, OR WILDCAT Prudhoe Bay-Kuparuk River 11SEC,T,R,M,IBOTTOMHO'~il Pool OBJECTIVE) Sec 14, TllN, RIOE, UN 12 PERMIT NO 79-84 116 ELEVATIONS {DF' RKB' RT'GR' ETC)* [17 ELEV CASINGHEAD1 05' RKB 18 TOTAL DEPTH' MD & TVD 119 PLUG BACK MD & TVDI20 IF MULTIPLE COMPL [ I I DEPTH I HOW MANY" ' 21 ROtaRY TOOLS INTERVALS DRILLED BY CABLE TOOLS 8070'MD 6836'TVD 17990'MD 6769'TVD I Sinqle All 22 PRODUCING INTERVAL(S), Of THIS COMPLETION -- TOP, BOTTOM, NAME (MD & TVD)* 23 WAS DIRECTIONAL Upper Sand 7419'MD 6301'TVD Top Lower Sand 7762'MD 6580'TVD Base Kuparuk I SURVEYMADE Upper Sand 7600'MD 6448'TVD Base Lower Sand 7828'MD 6634'TVD 7882'MD 6679']TVD Yes 24 TYPE ELECTRIC AND OTHER LOGS RUN DIL/BHCS/GR, FDC/CNL/GR, 25 1 6" 10-3/4" 7" CBL/VDL/GR/CCL, Spectralog, C/0, NLL CASING RECORD (Report all strings set In well) CASING SIZE WEIGHT, LB/FT I GRADE I 65# Weldedl H-40 I 45.5# ButtI K-55 I ,26# Butt I K-55 I 26 LINER RECORD SIZE TOP (MD) BOTTOM (MD) SACKS CEMENT* 28 PERFORATIONS OPEN TO PRODUCTION 30 DEPTH SET (MD) HOLE SIZE AMOUNT PULLED 71' 24" 2904' DATE FIRST PRODUCTION 8057' (Interval, size and number) 13-3/4" ~16 s CEMENTING RECORD I x Arcticset II I sx Dowell Self Stres~ 9-7/8" f~ sx Arcticset Cmt/ / 1 2~ TUBING RECORD SCREEN (MD) SIZE DEPTH SET (MD) -1/2" 7347' 29 ACID, SHOT, FRACTURE, CEMENT SQUEEZE, ETC DEPTH INTERVAL (MD) N/A PRODUCTION IPRODUCTION METHOD (flowing, gas hft, pumping--size and type of pump) Cmt PACKER SET (MD) 7309' IAMOUNT AND KIND OF MATERIAL USED WE LL. STA'l~US,jPrgdu~l~g or shut-In) N/A DATE OF TEST FLOW TUBING ]HOURS TESTED ICHOKE SIZE I PROD'N FOR I TEST PERIO2 iCAS,N PRESSURE OIL-BBL OIL-BBL GAS--MCF I RATIO PR ESS 31 DISPOSITION OF GAS (Sold, used for fuel, vented, etc ) GAS--MCF I WATER-BBL ~OIL GRAVITY-APl (CORR) I ~' Iii Iii, I ~ TEST WITNESSED BY 32 LIST OF ATTACHMENTS Y t~ihe~,~ a~.~n;~che~av~lnf~matl°n Is c°~'n plete and c°rrect as determined fr°m ali available rec°rds 33 I hereby certlf going SIGNED . - ~.~TITLS District Drilling Engineer DATE 2/2~/R0 *(See instructions and Spaces for Additional Data on Reverse Side) INSTRUCTIONS General Th~s form ~s designed for submitting a complete and correct well completion report and log on all types of lands and leases ~n Alaska Item. 16: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on th~s form and ~n any attachments Items 20, and 22. If th~s well ~scompleted for separate production from more than one interval zone (multiple com- pletion), so state in item 20, and in ~tem 22 show the producing interval, or ~ntervals, top(s), bottom(s) and name(s) (if any) for only the interval reported in item 30 Submit a separate report (page) on this form, adequately ident~hed, for each additional ~nterval to be separately produced, showing the additional data pertinent to such ~nterval. Item 26: "Sacks Cement" Attached supplemental records for th~s well should show the detmls of any multiple stage cementing and the location of the cementing tool. Item 28: Submit a separate completion report on this form for each interval to be separately produced. (See instruction for items 20 and 22 above). 34 SUMMARY OF FORMATION TESTS INCLUDING INTERVAL TESTED, PRESSURE DATA AND RECOVERIES OF OIL, GAS, WATER AND MUD 35 GEOLOGIC MARKERS NAME None MEAS. DEPTH TRUE VERT. DEPT Top Upper Sand 7419' 6301' Base Upper Sand 7600' 6448' Top Lower Sand 7762' 6580' Base Lower Sand 7825' 6634' Base Kuparuk 7882' 6679' 36 CORE DATA, ATTACH BRIEF DESCRIPTIONS OF LITHOLOGY, POROSITY, FRACTURES, APPARENT DIPS AND DETECTED SHOWS OF OIL, GAS OR WATER None Eastman/ Whipstock A PETROLANE COMRANY REPORT of SUB-SURFACE DIRECTIONAL SURVEY ARCO OIL & GAS COMPANY Kuparuk D-3 WELL NAME KUPARUK FIELD, NORTH SLOPE, ALASKA LOCATION JOB NUMBER Al179D0116 SURVEY BY Don LeJeune TYPE OF SURVEY DATE Directional Single shot OFFICE Alaska 0-302 FILE 162 I,'1 I LII(.U 0!' ~.~Ll!','~'i. 't t. 0 I ~ A N 13 tl t. A t'~ R U [ ti A ¥ [' t LF.]' L I £i2 '.:,]tJl. l {:Il i , I i~,J t ,' J1e, f IU16,¥1 lo01 · L'.6 i / 70. 3 18')4. · I,.' =' 0,3,' 5.44 W '~' 05 W ,,.. , o ¥ W l ¥ 8 ,-2 2] ,',9 22o ' 15 30 45 N ,-::.: W 9J , N dS W ¥4. N uS W 93, N E.~5 W i 9 '.',/. 44 ./u ./2.98 "LO/, SE, 219L. Ii, '.~ ',J/S. 50 ~ :e., N 8 [ 54 N 82 21 W '-~V ,{ 0 "; 0 N 88 W 94. N f":';' W 93, N ~'0 W 94. 452,44 bB. 79' N 499.,.,-~9 e 0,09 d t:,4:,-~, ",7 i ,-:,0 · 55 N ~00.74 60. b':', N ,.,'1.90 6:;, ","' 4,',:3. 12 b6b./4 ,',.? 1 · 81 c.80 · '.'., · '? ? . 7:5 · i~t,'. IF [ i. OUI';':,t.L~I I' [ I t. t'll YJ' t', I J ~; i I','L t i 1.~.iN I.i~'t.tJ3"i t'i Di'~'I'It ',.:',1: t,'i' ] Or4 l~ I-- L 1:.. '~~ i-t. [ t- I.E t i tlli [.,',TI ,l' 4 't ~' '",'' , ~ *[ J I ii: ? .i'l'l ~ (.I t, F D i. N A 'i L- ',-. ~i ,i,,~l 1 I-)"~ 1[ ~i t [ (ILi.,'I.L i ],~l · ,l "1 ,' , i i , I ."',LJ!"VL ~ t 354:5., ;; 2,,.- ~: :,...,,) , ~,,'L:L:,· """ Ill 111 [ I I I I i~l Iit l I I I t ~ ti i I t I I 'l I~i * ! I 1 i :J i I ! I ~ ....... 1 ~'1~ JllJ];~il~(l lall t I I i I I I ~ i I ~ ' t 1 i I , 1 I i i I I .... [ ~ I : :: , .... ' ~. ~ _ ~ :::_ ::': .,r~& ' I ! i ( I ~ 1i ~ i ~ , I I ~I I I I t -~ I I I T I I 1 i 1' I I I 1 I ! ! I '-~ 'l- I I t t I I i [ ~ I ~ t ~' ~ ~ . ,i ~ ~' ! ~ ! ~ ~ ~ ~ ~, i, i .! 'i I I I ! ! [ ~ ! ~'i I ! I I~ ' I ~' t ~ i ~ ~ .... ~ ~.: ~ ~i=-,q,~ ~ ~,~ ;~,:~ ~.: ~:~ J ' I .... & [rl~ m ~_ I I ~ I : I ' I i I ! il ! [ i : i I .~ :il I ..... I I : ~ ' ~ i ]~ ~1 I ......... I I [ ~ ~ : : ~ i . l I , ~.~ . i , , ~] , , ~ L,,, ..... ~ ' t ~ - [ L. ~ i II qL . ~ ~' '1 I ~ I. .... , , ~b , ~ ~ . ~.. ~ ..... ' I ~ .I [ r .....~ ,, t ~ %, I N I ~ll ... I L .... ~ ~ i .... I '~ ~ ~ I _.. ~ I i } .% ' I I ' ' I i t i .I i!~1 ~[1' Iii f ~;, 1~ fi i~' ~ I ~ 'id d A Fouch~ President Mr. Minos Hebert Arco Oil & Gas P. O. Box 360 Anchorage, AK 99510 January 2, 1979 Re: Our Boss Gyroscopic Survey Job No. Boss-16512 Well: D-3 Kuparuk Field North Slope, Alaska Date of Survey: December 21, 1979 Dear Mr. Hebert: Please find enclosed the "Original" and one (1) copy of our Boss Gyroscopic Multishot Directional Survey on the above well. Also included is a horizontal and vertical projection. Thank you for giving us this opportunlty to be of service. Yours very truly, Ken Broussard Distrmct Manager KB/kc ~closures t:E.' A S L'r'F ] ~)EPI' ~- (, 106 20C 500 7ru 9b (; llCO 12GO 1ZOO laC0 1500 16(C 17C0 1FC'O 1900 260O 2166 22C0 2AOC · I,,, 2500 2ECU , ' 2700 2~:~0 O PACE [ATE CF SURVEY PECEf'PEq 21, VERTICAL SECTION PIRECTIOh N-Oa-3G-CO-V '[RTE SUb, VLFTTCAL SE~ E F;T~ 1 VD SPERRY-SUN RECORD OF SUPVEY CC UKSE COUP SE DOG-LEO INCLI%~TION CIFECTION SEV LEG MTN DEG ~'~IN DEG/IO0 0.00 -106.00 ORIGIN AT SURFACE 100.00 -6.00 0 12 k 15 30 E .20 ?00.00 54.U0 O ? N 27 ~8 E .07 ZOO.OD 154.00 0 11 S a q8 E .32 c99.92 8:3.9a 1 7 N 58 12 W 1.29 1155.2] 10T3.21 £ 16 N 75 42 W 3.88 1257,~1 1151.~I 12 P N 83 1E W A.09 13qq.44 126C.qq 16 ~3 ~ 86 0 W 4.63 14fi9.0m 13g3.09 20 51 N 85 12 W q.lq 1582.15 1476.15 22 5 N 87 ~ b 1.42 1¢74,51 1568.~3 22 55 N 85 6 W 1.13 1766.50 1~,66.~0 23 20 k 2~ G k .60 1~58.00 1752.00 2~ 15 N ~3 q2 W .92 80ssmJ_6512 TOTAL RECTANGULAR COORDINATES VEF~-IC~L NORTH/SOUTH EAST / WE S l SE C TI ON O.O0 N 0.00 E 0.00 : · 17 N .05 E .02 ,45 N .16 E_. .40 N .24 F -.07 · 31N .27 E -.ltl · 42 N .~2 E -.2~ · 3q N .75 E -.ES · *6 N 1,13 E -.8~ ..... .41N 1.57 F -1.31 · 30 N 2.0q F -1.83 .98 N 1.50 E -1.0~ 3.06 N 2.9fl W 3.85 6.41 N 13,52 5.41 N 30.$3 g 3~.23 ll.6q N 55.73 W 56.12 1~.13 N 87.82 W 86.89 16.58 N 12a.$3 W 121.75 19.19 N 162.50 k 156.23 22.92 N 201.60 W 195.97 27.25 N 241.70 W 234.87 lgAm. O0 18q3.00 2~ .3 N S~ 0 W .~8 20Z9.70 1933.70 25 7 N 8A 18 W .~2 2125.S0 2023.90 26 1. ._k 8A 18 W _ ,90 2218.7q 2112.74 26, ~7 ~ 86 6 ~ 2.73 2305.55 21~9.55 30 53 N 88 18 W 2.52 23g0.02 36 W 2,72,17 36 W 2552.05 ....... 2A~6_~0~_ ._1~,.~ 2E29.~6 2523.46 ~2 W ..... ._,,_~L1.L_ ............ 8__8.9. A.O 25 $ 88 3.1~ 1,87 51.68 N 2A2.9] W ~7~.83 35.98 N 32q.$2 W 315.~0 40,26 N _ 367.76 W 356.92 q4.07 N ~13.q6 W 400.86 46,46 N ,63,03 W qq7,$q 46,63 N 573.51 W 550.70 63%, 5~ W 606.37 696.90 W 66~.8~ 2.27 4~..9A N 3050 3[SC '2OC ~2~0 ,v 3~OC 37OO 3800 3~00 4000 4100 4200 43(10 4400 q 5 C. (i 4600 4700 4900 5006 5100 - 5200 5300 · 5400 5500 O,a-S TPUE VE ;. T !CA~,L [ E I:' Th ~770.0F 2~15.72 2968 · 20 ~t06.76 ," f F2 "1~ 2,.2~ 3?34 · 02 5309.a'7 53,44.64 34,r-q. F? 3~10.1,~ 405~.25 4210.08 4~F1.5~ 4437.68 a591,R2 PACE C4T[ CF SURVEY DECEMBER 21, -V E.-R T I C AL S-E'C-T'! C N---D"I FfKC';F-~ Of{' N-6 [~-3D -C SUP SEA TVLi .......... S P-~-R Y -'SUN "- RECORD O~ SURVEY CCUPSF COURSE DOG-LEG IkCLI~,4TIOfN DIRECTICE SEV POSS-16512 TOTAL RFET4kOULAR COCPBINATES VERTI£AL NORTb/$OUTP [AST/~EST SECTIO~ 267 270 ,-74 27~ 282 3.08 42 41 S ~ 36 W 1.15 9.78 42 52 S 89 12 W .89 6 · 9_4 _~ 81 ..8 .......... ]~ _&¢__~.q. ~ ..... 6 · 26 b.O0 3~ 47 k 82 C W 6.91 3.55 ~9 22 N 76 48 V 6.68 40.52 N 263.48 W 818.25 44,29 N 929.19 ~ 280.76 ~0.14 N 960.~7 W 912.02 2c0 305 2.20 39 23 N 75 36 W 6.06 0.76 3o a2 N 69 2~ W 5.38 6.gF ....... Aj__20 .... N.._7~Q_Sq._W 1.90 2.2~ 40 4Z N 7~ 24 ~, a.96 8.02 ~0 47 k 78 b4 W .33 _ . . 58.2~ N ' ~iTi~ .... ~' ~4~.~i 68.3~ N io2i.3o W 975.28 ....... ~0...~_.~ iosz._~o w io~o.2i__ 107.75 N 1145.59 W 1]0~.37 i2o.6o k i2os.58 ~, ii~s.6~ 52O 327 335 342 550 ~.6~ ql 17 r,i 7& 24 w .73 3.24 fit 6 N 7~ 18 W .19 9.09 41 22 R 79 1S W .7t 4.13 41 23 N 78 3e ~ 1~5.54 N 133P.79 W 129~.97 171,6~ N 1flE7,9~ W 1428,71 184.36 N 1532.80 W 1493.72 3579.03 al 37 N 79 1t W 3653.63 41 53 N 79 30 W .30 $72~.31 3P03.11 41 ql N 78 3F W .45 3['78,05 41 15 ~ 77 48 ~ .68 157.12 ~ 1597.82 W 1558.85 209.37 N 1663,28 W 1624,27 221.66 N 1728.63.~_ 16~'9..59 2~4.A3 N 179Z.76 W 175~.87 2~7.97 ~ 185~.58 W 1820.~ ?6i.Si'N -'i's25.os ~ ....i~XsTif .... 275.14 N 1997.~8 W 1950.02 289,21 N 2051.~? 30;.72 k 2115.35 W 2079,~7 318.57 N 217~.92 W 2144.0E a531.G8 40' '7 4~08.46 39 ~485.82_ 3~ 5 N 76 12 W .50 456~.92 Z~ 13 N 75 24 W 1.00 348.89 N 230A.00 W 2271.55 S~O.,ii..N .... 2Z65.5i.~ ....... 379,43 N 2426.06 W 2gS&,Zl ~'L 4 S', L' R "' F' P L7CC 600C 61CO $ 4 C! 0 6700 6700 8900 7]0C 7200 7100 7400 750(/ 7600 7700 7800 7950 8070 CAS gATT OF SURVEY 2ECEP'RER 21~ 1979 VERTICAL SECTION DIRECTION N-6A-30-OO-N TRUE ~,FF TICAL L ~ FTP ~951.lb 5073.Z; 51[&.C1 5125.91 SUB SEA TVC SFERRY- PECORD OF S COUPSE COURSE INCLINATION DIRECTI CEO YIN CFG MI SLN URVEY DOG-LEG ON SEV N bEG/lO0 q722.~5 36 38 4803.58 3F 42 4885.15 5~ 59 4967.32 3~ 30 5133,~5 32 58 5217.91 31 q3 h 7~ 54 ~ .72 N 75 0 N .94 N 75 1~$ W .7fl N 73 18 W 1,24 P 75 24 W .57 N 73 42 W .98 N 72 24 ~ 1.43 540-9 · 4 g .... 5 lQ 3..A 8 ........ ~.4q6.22 53~0,2° tt~.4.10 547~. 10 5761.92 50 3& ............ ~7~__ _0_ W .... 1.30 29 3 N 69 36 W 1.73 27 L6 ~, 68 1~ W 1.22 5566.73 27 15 N 67 1P k .83 5655.°2 26 31 h 65 36 ~ 1.06 TOTAL RECTANGULAR COORDINATES NORTh/SOUTH EAST/WEST VERTICAL SECTIO~ 411.20 k 2543.21 426.52 N 2600.20 4q1.55 N 2656.11 ~56.76 N 2710.97 472.87 N 276q.84 2516.c~ 257~.5S 2653-05 2629.73 2745.76 488.48 N 2817.70 W 504.06 N 2868.87 W 557.06 N 2964.86 W 554,19 N 3009,3g W 5093.71 W 3C49.40 t ~116.7E (202.~E 62P6.12 63e7.q~ ~448.67 6529.7~ 6~11.73 [735.95 6836.09 57.~5.5q ......... 26_._ 9 .......... N_ 6.4 56 W 583~.97 27 1 N 62 3E W 5923.50 28 23 h 58 24 W 60]0.76 30 4 R 56 3C 6096.38 32 7 N 5~ 24 6180.12 6261,9fl 36 6342.67 36 ]8 N 54 12 W 6423.73 35 23 N 54 18 W ~505.73 54 26 h 53 6 W 6588.3_8 .......... 5~ ...... 5-- ....... ~.~--~-.-~ .... 6629.95 33 26 N 53 12 W 6730-09 ~3 26 N 53 12 W 1,28 628,$5 N 317~,00 W 2,34 651,2~ N 321~,39 W 3]38.86 3183,~4 3229.4~ 2.05 ~73~. 99_.N ........ ~3~_2- 8_! ..,~W 1.95 772,93 N 5388.b9 W · 22 807.54 N 3436,40 W 3277.3~ 3327.61 3380,50 342~.08 3~95,25 · ~2 8ql.75 N 3483,~2 W 1,17 875,62 N 3530,04 W 1.41 9~6,31 N 3597.12 W O,O0 965.92 N 3650.06 W ._ 3~50,01 3605,33 36_t9.55 3686,32 375C.09 1 &RCC elL f:D,O D-.~ KdPARUK F IELD NORTh SLF't E bOSS SUkWEL CAS PAGE DATF. OF SURVEY DECEMHER 21~ 19'7 VERTICAL SECTION DIRECTION N-68-30-00-~I ** THE RECCRC OF SLRVEY CALCULATIONS ARE BASED CN THE MINIMUM RADIUS OF CuRVA'TURE' METHO~'.'~ ...... FOFIZC~TAL DISPL~CFKEKT = ~3.~7.5,_7~O_~_~FFT AT NORTH START CF SLRVEY NAS !06.00 FEET ABOVE 75 DEG, 11 MIN, WEST SFA LEVEL (TRUE) ~,qCO OIL ALAS</ r-' E/~ SURED DEPTW 0 5 106 406 70A 1006 1106 1E2b ~7~4 $ ND [',AS ANCHORAGE ~ ALASKA ~ [~M ~0 l~--A T i-'b ~ DAT'E OANUARY ~ i980 INILRPOLATLD VALUES FOR EVEN CO~PA~Y 97-9 dOB NUMBER BOSS-J6512 ~[LLY BUS~ING ELEV, = lC6.0~ FT, TRUE VLRTICAL D-EPTH O.OO ~'o o 106.00 206,00 30~,00 ~06.00 506.00 606,00 706.00 80&,O0 906,00 1006,00 llOG,O0 120G,00 ]30G,O0 lqO6,O0 1506,00 1606,00 1706,00 SUB-SEA TOTAL VERTICAL RECTANGULAR COORDINATES -io6.oo o.oo o. ........ f'dO-, o o o.oo 0.00 ,i9 N ,05 lOC,OD .46 N .17 200.00 ,'38 ,U ,2~+- 300,00 ,32 N .27 ~00,00 .42 N -500.00 .3,,5 N'- .78' 600.00 ,A-.9 N 1.1~+ 700,00 ,38 N 1.60 800,00 ,32 N 2,12 9DO,OD 1,05 N 1.37 1000,00 3,26 N 3,~2 1100,00 6.6z~ N 1fl,52 1200,00 9,62 N 32,79 1300.00 11, ~0 N 59.28 lqO0,O0 1 ~+, 67 N 9~,'2~ 150.0, O0 17,06 N 133,99 1600.00 20,33 N 1Z5,76 MD-TVD VERTICAL O0 0.00 oo .................... o .-o-b~ ..... o.oo ,00 ;00 ,DO .00 ,00 ,00 · 00 ,00 ,00 .00 · 00 ,00 .OU ,OO · 01 .00 · 01 .00 · 02 .01 ,18 · 87 .69 2,59 1,72 6,10 3.51 12.09 5,99 19,7~ 7,65 28,16 8.42 aRCO C'IL K UP ~, R UK ALASk 4 AND GAS SPERRY-SUN WELL' SURVEYING ANCHORAGE~ ALASKA COMPUTATION DATE dANUARY 3, 1'980 COMPANY DATE OF SURVEY DECEMBER 21, 197'9 dOB NUMBLR 90SS-]6512 KELLY BUSHING ELEV, = lO6,00 FT, ~EASURED DEPTW 1952 2862 2373 2295 2z+60 25]9 276'9 2':;01 3036 .';169 3~62 3695 3f28 3961 FEET. OF _.SUBrSEA DEPJ_H ....................... %RUE VERTICAL DEPTH SUB-SEA TOTAL __ y.L.Rj__I~C_._A L._ ....R_E C T A N GU_L_A. R CO0 DEPTH NORTH/SOUTH E R D IN &!ES ......... M.D.._-. T.v.P AST/WEST D I F. Fb R ENCE CORR'EC TI ON 1806.00 1 1906,00 1 2006.00 1 2106~.0_0 ..... 2 2206.00 2 23'06,00 2 2406.00 25.06,00 2 2EO6,O0 2 2706,00 2 2806,00 2 2q06,00 2 3006,00 2 -- 3106.00 3 3206.00 3 3306.00 3 3406.00 3 3506,00 3 3606 , Or) 700.00 24.71 N 800,00 29,61 N 900,00 34.~+1 N OOO,O0 3q.ll N 10.0, O0 43.58 N 200,00 46,47 N 218,57 N 37,03 8,87 263.25 W 46.67 9,64 309.10 W 56.78 10.11 356,15 .W 406.62 W 7~.52 12,12 453,30 W 94,53 15,01 _2.2 8b W 135,67 22,44 95 W 166.19 21,52 4,3 W 195,44 32.25 40 W 2~0,'66 35, 22 ~.6 W 263,~9 32,83 71 W 29,3,01 29,52 75 W 524,86 31,85 87 W 356,99 32,13 06 W 389,38 32.39 1G W ~22,~3 33,05 77 W 455,24 32,8] 24 W q88,~9 33,26 ~00,00 46,46 N 597, boo,go 4b.39 N 6lG, 600,00 q3.07 N 763. 700,00 40,65 N 854, 800,00 4'6,29 N 941. 900,00 68.12 N 1020. O00,OO 9G,61 N llOl, 100,00 115,95 N 1185. 200,00 132,3q N 1271, 300,00 IA9,31 N 1357. ~00,00 166,g8 N 1~42, 3500,00 ]83.64 N 1529, ARCO ,OIL KUPARUK ALASKA AND GAS ANCHORAGE', ALASKA C~-MP~U~T A-'~'ION DATE dANUARY 3'~ 198U PAGE 7 DA,TE OF SURVEY DECEMBER dOB NUMBLR BOS$-16512 ~"EASURED -OEPTH 4 22R A362 4495 4629 4762 ~894 5027 5158 5545 .~7! 5795 5918 6039 6160 6,278 6511 INTERPOLATED V~LUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-SEA TOTAL VLRTICAL VLRTICAL RECTANGULAR COORDINAT DEPTH ...... O E~FT H' '--'~'O'R-¥HT'~ 00'Y ~ ........ E~AST 2WE ES M,D-TVD VERTI S T ..... Di FiFE RE N~C E ........ c'O R'~R CAL T'i~O~ 522,05 3 566,20 3 58.9,83 ~ 623,20 S 656,1~ ~ 688,62 3 721,03 3 152,57 3 785,02 3 812,27 2 8~9.89 2 865,52 2 889,59 2 ~)12,12 2 9 3.3,65 2 954.13 2 3,56 3,63 3.37 2,9:3 2,49 2,41 1,54 0,45 9,25 7,62 5,63 4.07 2,53 ................... 1.5.3 O,A8 5706.00 JGO0.O0 200.58 N 1616,13 W 5806,00 37-00;.0-0 ..... ""-~-1g,96 N :1704;0-4.- ¢ 3:')06,00 3800,00 233,89 N 1791,0zi W 4(106,00 3900.00 252,04 N 1877,39 W 4106,00 ~O00,O0 269,79 N 1'963,16 W 4206,00 4100,00 288,45 N 2048,04 W ~306,00 4200,00 ~07,78 N 2132,64 W 4406,00 4300,00 327,23 N 2215,85 W 4506,00 ~.~OO,O0 347.19 N 2297,21 W 4606.00 ~500.00 366.86 N 2376,,70 W 4706,00 4600,00 386,60 N 2453,49 W 4806,00 4700,00 406,77 N 2526,81 W q. 906,00 480.0,00 4.25,85 N 2597,72 W 5006;00 ........... 4 90 O'.'fji~ 4-'~'"3~ 9 ~ N 2666~, l~6~'W 5106.00 5000,00 463,21 N 2732.48 W 5206.00 5100,00 482,39 N 2796,88 W 5406.00 5300,00 519,64 N 2916.07 W 989,95 17,03 5506,00 5~gO,OU 538,96 N 2969,96 W 1805,19 15,2A L: -~ KUP (';AS ANCHORAGE, /NLASKA COMPUTATION DATE JANUARY 3, 1980 CO, PA Y ............................................. PAGE- DATE OF SURVFY DECEMBER 21, 19'7¢ dOB NUMBER BOSS-16512 KELLY BUSHING ELEV, = 106,00 FT, 8 ! INTERPOLA.TEU.__V_A._LU.ES__E_O_K_EV_E.N._._/O0 FEET OE..SUB.-SEA OEP'IH ~*,FA SURED DFPTW TRtJE VERTICAL DEPTH SUB-SEA TOT,AL VER~FICAL REL;TA NGULAR COORDINATES DEPTH NORTH/SOUTH EAST/WESI MD- %V_D ......... ~.ER_T_~. CA. L D'I-F, Fb. RLNCE CORRECTION'- 6624 5606,00 c, 737 5706,00 t ~qa .5806,00 5960 5q06,00 7e73 6006.00 7187 6106.00 730q F-206.00 742q 6306.00 7547 6~06.00 7670 650&,00 7795 6606,00 7~14 6706,00 5033 6806,00 $C70 68.56,09 5500,00 558,48 N 3020,17 W 5600,00 578.30 N 3068.07 W 5700,00 5~8,8~ N 3113,70 W 5800,00 620,12 N 3158,19 W 590.0,00 644,64 N 3203,58 W 6000,00 67~,1~ N 5250,33 W 6100,00 708,20 N 3299,87 W 6200,00 7~6,98 N 3353,05 W 6300.00 789,22 N ~1].02 W 6~00,00 831,92 N 3~70,24 W 6500',00 87~,26 N 3526.90 W 6600.00 914,3~ N 3581,20 N 6700,00 qSq,02 N 365~.15 W 6750,09 965,92 N 5650,06 W 1018,79 15.60 1031,~3 12,6~ 10q3,25 11,82 106~,75 11,50 1067.29 12.5~ 1081.57 1~.28 10~8.27 16.71 1118.01 19,73 11~1,08 23~, 07 116~.90 23.82 1187.05 22,15 1208.03 20,98 1227.94 19,91 123de91 5,97 THF C~LCULAT ION PROCEDURES THE NEARES1 20 FOOT MD USE A LINEAR INTERPOLATIO (FROM RADIUS OF CURVATURE) N BETWEEN' POINTS ARCC DIL KUP ~,RUK i, LA$<L 6AS S P E R R Y - S d'~-- ~i'~(L"~- ~'Ok V E~;'~-~ ~ ~' M P A ~ Y ANCHORASE~ ALASKA ............................. COMPUTA(IoF~ OATE dANU.ARY 3~ 1980 PAGE' DATE OF SURVEY DECEMBER 21, lg79 dOB NUMBER FOSS-16512 KELLY ~JUSHING ELFV. = lOB,00 FT, DF FTH 7q19 7~ (.lO 7762 7E27 7¢5[` 79?0 F('7P INTERPOLATED VALUES FOR SPECIAL SURVEY POINTS TRUE SUB-SEA TOIAL VERTICAL VERlIC~L RECTANGULAR COORDI D E P T ~t ....... OEP '~ tZl- ..... ~I~'~R"~'~t:I'~S-o 0"¥ 1-'~- ....... ~'~,~'S ¥ 6580.3") 6G3q,82 6679.~+7 67,3b . 95 R769.33 _ _ 74. b, 31 N 3350 807,5q N 3~36 8474.39 862.72 N ,.5512 6528.82 885,12 N 35q. 2 6629.95 t326,51 [4 3697 NATES /w E'g~T , 7'9 W UPPLR · z~O W BASE ,86 W · 70 W · 92 W ,12 W ,76 W .OG W SAND UFPER SAND LOt/ER SAND BASE LOWER SAND BASE KUPARUK SURVEY DEPTH PLUG BACK TD TOTAL DEPTH HORIZONTAL VIEW ARCO OIL ~ GAS KUPARUK D 3 RADIUS OF CURVATURE GYROSCOPIC SURVEY SCALE I"=1000' ~IAN. 2 ~ 19 80 , TVD = 6735 TMD = 7950' 6400 CLOSuR_ 4000 ~ ~ . 5600 5200 2800 2400 2000 1600 ALL DEPTHS SHOWN ARE TVD VERTICAL SECTION ARCO OIL E~ GAS KUPARUK D 5 RADIUS OF CURVATURE GYROSCOPIC SURVEY SCALE I"=1000' dAN. P_~ 1980 ( NORTH SLOPE DISTRICT ENGINEERING TRAN SM I TTAL :;z2~/~2- TO: FROM: Jerry J. Pawelek~~ WELL NAME: ~.//.//o~ ~~ TransmitTed herewith are the following for the subject well- DATE SCALE XEROX . r'm~ BHC Soni c/Gamma Ray Log Cement Bond Log/VDL Compensated Formation Density Log Compensated Neutron-Formation Density Compensated Neutron Log Core Analysis - Interval Core No. Core Description (SWC) - Interval Core Description (Conv.) - Core No. Directional Survey- Gyro Single Shot Multi-shot ;,~ Drill Stem Test - Test No. Dual Induction Laterolog Formation Density Log Formation Density Log/Gamma Ray location P1 at TVD-DIL /~-.~-~Differentfal Temperature Log Spinner Survey Fluid Density Casing Collar Log Perforating Record Nuclear Flo-log I STAT TE~-~ CONFER: . ,_ SEPIA BL LINE - _ / / / RECEIPT ACKHOWLEDGED FOR' . ~~ ~ ~ C ~E RETURN RECEIPT TO: ARCo Oil and Gas Company Attn' Mr. Pete Woodring P.O. Box 360- Rm. ~469 Anchorage, AK 99510 1/10/80 February 14, 1980 I~G~. Ceu~ ~u please e~m~A~mn sin~m~ty ~ uar~e~a nodr~es DATE' /'-~- ~'0 i COMM ,] I c-o~- I RES I ~Ng I :2 ENG--- TRANSMITTAL ~'~;7~ , ,, J~ } L · ENG ~ GE~ ~ELL NAME' ~~~U ~ ~-~~'--' NORTH SLOPE DISTRICT ENGINEERII~G Transm~z-:ed herewith are the following for the subject well- DATE SCALE XEROX SEPIA BL LINE /~./$-~/ ~--:C Sonic/Gamma Ray Log Cement Bond Log/VDL ~.t~.7~/ Compensated Formation Density Log xm.z~,~/ Compensated Neutron-Formation Density Compensated Neutron Log Csre Analysis - Interval Core No. Core Description (SWC) - Interval Core Description (Conv.) - Core No. Directional Survey - Gyro Single Shot Multi-shot Drill Stem Test - Test No. /~./~-,~ Dual Induction Laterolog Formation Density Log Formation Density Log/Gamma Ray Location Plat TVD-DIL Differential Temperature Log Spinner Survey Fluid Density Casing Collar Log Perforating Record Nuclear Flo-log /.,~../,ff.~ ¢~ r- -'rz:~ -~-~. , RECEIPT ACKNOWLEDGED FOR' p[E/ASE R DATE' _ ETURN RECEIPT TO' ARCo Oil and Gas Company Attn' Hr. Pete Woodring P.O. Box 360 - Rm. ~4~9 Anchorage, AK 99510 BY' NORTH SLOPE DISTRICT ENGINEERING TRANSMITTAL -~ 7,.0- DATE' FROM' Jerry J. Pawelek~te Wood WELL NAME' ~UP~ ~ ~/<' ~Z)-~ Transmitted herewith are the following for the subject well- DATE SCALE XEROX . BHC Sonic/Gamma Ray Log Cement Bond Log/VDL ~,, Compensated Formation Density Log ....... Compensated Neutron-Formation Density Compensated Neutron Log Core Analysis - Interval Core No. Core Description (SWC) - Interval Core Description (Conv.) - Core No. Directional Survey- Gyro Single Shot Multi-shot Drill Stem Test- Test No. Dual Induction Laterolog Formation Density Log Formation Density Log/Gamma Ray Location Plat TVD-DIL Differential Temperature Log Spinner Survey Fluid Density Casing Collar Log Perforating Record Nuclear Flo-log SEPIA __/__ BL LINE / / /_ C'. C' I~' 2 ENG 3 1 GEOL 2 GEOL STAT TE~ i CONFER: FILF.' -- RECEIPT ACKNOWLEDGED FOR' DATE' PL~~EA~E RETURN RECEIPT TO' 1/10/80 ARCo Oil and Gas Company Attn' Mr. Pete Woodring P.O. Box 360- Rm. #449 Anchorage, AK 99510 BY- RECEIVED 1980 Anct~u[a[le DATE' NORTH SLOPE DISTRICT Transmitted herewith are the following for the ENGINEERING TRANSMITTAL FROM' Jerry J. WELL NAME- J~.i ~ Panel ek/Pete .~_.d~'~~ I /1 ~t _] subject well- I~_LSTa, T TECC3 DATE SCALE XEROX SEPIA BL LINE E. hC Sonic/Gamma Ray Log Cement Bond Log/VDL Compensated Formation Density Log Compensated Neutron-Formation Density Compensated Neutron Log Core Analysis - Interval Core No. Core Description (SWC) - Interval Core Description (Conv.) - Core No. Directional Survey- Gyro Single Shot Mul ti-sh(~t Drill Stem Test - Test No. Dual Induction Laterolog Formation Density Log Formation Density Log/Gamma Ray Location Plat TVD-DIL Differential Temperature Log Spinner Survey Fluid Density Casing Collar Log Perforating Record Nuclear Flo-log RECEIPT ACKNOWLEDGED FOR' DATE' P~~LEASE RETURN RECEIPT TO' ARCo Oil and Gas Attn: Mr. Pete P.O. Box 360 - Anchorage, AK Company " Woodring .4~,, '~,.~ Rm. ~449 99510 1/lO/8O ARCO ~Olland G~,.. Company n~'0 277 January 15, 1980 Mr. Hoyle H. Hamilton State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 N-KE~ t FILF:- Subject:_.J~=~_-14, Permit No. 79-82 Permit No 79-84 Dear Si r' Enclosed please find a Completion Report along with the Drilling History and Gyroscopic Survey for the above-mentioned wells. P. A. VanDusen District Drilling Engineer PAV 'mb Attachments ARCOO¢ ,ndG,TM r ~rnpan) aDiv,slonof ~tlnnhcRl,-~leldCn,,r ~y Form r~ SUBMIT IN DU~. .FE* STATE OF ALASKA (Sec'other In- structions on reverse side) OIL AND GAS CONSERVATION COMMITTEE WELL COMPLETION OR RECOMPLETION REPORT AND LOG* la TYPE OF WELL .,-- ,--, ,O.,I~L, Lr~-) GAS WELLI--I DRYI--I O,.er 2 NAME OF OPERATOR Atlantic Richfield Company 3 ADDRESS OF OPERATOR P.O. Box 360, Anchorage, Alaska 99510 4 LOCATION OF WELL (Report location clearly and tn accordance with any State requirements)* §t,s~,~[e & 601 'WEL Sec 23, TllN, RIOE, UM At top prod mnterval reported below 742'FSL & 2531'FWL Sec 14, TllN, R10E, UM At total depth 963'FSL & 2231'FWL Sec 14, TllN, R10E, UH 5 APl NUMERICAL CODE 50-029-20408 6 LEASE DESIGNATION AND SERIAL NO ADL 25650 7 IF INDIAN, ALLOTTEE OR TRIBE NAME 8 UNIT, FARM OR LEASE NAME Kuparuk 25650 9 WELL NO D-3 (24-14-11-10) 10 FIELD AND POOL, OR WILDCAT Prudhoe Bay-Kup. River Oil 11 SEC ,T, R, M, (BOTTOM HOLE P001 OBJECTIVE) Sec 14, TllN, RIOE, UM 12 PERMIT NO 79-84 13 DATE SPUDDED [14 DATE T D REACHED 115 DATE COMP' SUSP' OR ABAND11/30/79 1 2/15/79 12/30/79 116 ELEVATIONS (DF' RKB' RT' GR' ETC)* [17 ELEV cASINGHEAD 105'RKB 18 TOTAL DEPTH MD&TVD 119 PLUG BACK MD&TVDI20 IF MULTIPLECOMPL I I CABLE TOOLS ' H MANY.* ' 21 ROTARY TOOLS INTERVALS DRILLED BY 8070'MD 6836'TVD I7~0~ID 6769'TVD I °~'ngle J All I 22 PRODUCING INTERVAL(S), OF THIS COMPLETION --TOP BOTTOM NAME (MD & TVD)" J23 WAS DIRECTIONAL )p Upper Sand 7419'MD 6301'TVD Top Lo~/er Sand 7762'MD 6580'TVD Base,KuparukJ SURVEYMADE ~se Upper Sand 7600'MD 6448'TVD Base Lower Sand 7828'MD 6634'TVD 7882 MD 6679'TrVD Yes 24 TYPE ELECTRIC AND OTHER LOGS RUN DIL/BHCS/GR, FDC/CNL/GR, CBL/VDL/GR/CCL, Spectralog, C/O, NLL 25 CASING SIZE J WEIGHT, LB/FT J GRADE J DEPTH SET (MD) ] 6II , 65# Welded I H-40 I 71 10-3/4" R,,tt_l K-.~.~ i ~q0~, 26 LINER RECORD CASING RECORD (Report all strings set in well) HOLE SIZE I CEMENTING RECORD I AMOUNT PULLED I I 24" 216 sx Arctic~P_t TT '§-~'/8"I ~)~)~ 'Db~v611'~61T"Strlss Cmt SIZE TOP (MD) BOTTOM (MD) SACKS CEMENT* 27 TUBING RECORD SIZE DEPTH SET (MD) 3-1/2" 7347' 28 PERFORATIONS OPEN TO PRODUCTION (Interval, size and number) N/A SCREEN (MD) PACKER SET (MD) 7309' 29 ACID, SHOT, FRACTURE, CEMENT SQUEEZE. ETC DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED 3O DATE FIRST PRODUCTION J WELL STATUS (Producing or N/A J shut-in) PRODUCTION JPRODUCTION METHOD (Flowing, gas hft, pumping--size and type of pump) 32 LIST OF ATTACHMENTS ~U~g~ ' Dr~ll~nq H~story and Gyroscopic Survey 33 I hereby certify that th foregoing nd atta ed Information IS complete and correct as determined from all available records SIGNED ,~~. ~~~ TITLE District Drilling Engineer DATE FLOWTUBING CASING PRESSURE CALCULATED OIL-BBL GAS--MCF WATER--BBL (~IL/IGF~ITY-API (CORR) PRESS 24-HOUR RATE ~ 31 DISPOSITION OF GAS (Sold. used for fuel. vented, etc ) ~) ITEST WI~NE~ BY ~(See ~nstructions and Spaces for Additional Data on Reverse Side) INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item: 16: 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. Items 20, and 22: If this well is completed for separate production from more than one interval zone (multiple com- pletion), so state in item 20, and in item 22 show the producing interval, or intervals, top(s), bottom(s) and name(s) (if any) for only the interval reported in item 30. Submit a separate report (page) on this form, adequately identified, for each additional interval to be separately produced, showing the additional data pertinent to such interval. Item 26: "Sacks Cement": Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 28: Submit a separate completion report on this form for each interval to be separately produced. (See instruction for items 20 and 22 above). 34. SUMMARY OF FORMATION TESTS INCLUDING INTERVAL TESTED, PRESSURE DATA AND RECOVERIES OF OIL, GAS, WATER AND MUD ' 35. GEOLOGIC MARKERS NAME · MEAS. DEPTH TRUE VERT. DEPT NONE ~ToP Upper Sand 74'19' 630'1' "' Base Upper Sand 7600' 6448' Top Lower Sand 7762' : 6580' Base Lower Sand 7825' 6634' Base Kuparuk 7882' , 6679' ~ 36. CORE DATA, ATTACH BRIEF DESCRIPTIONS OF LITHOLOGY, POROSITY, FRACTURES, APPARENT DIPS AND DETECTED SHOWS OF OIL, GAS OR WATER. NONE Alaska 0tl and Gas Conservation Commission Hoyle H. Hamtlton Ch&t rean of the Contn~l Lonnte C Smtth C~)n~t s s t ~ne r Bobby Foster ~, Petroleum Inspector December 12, 1979 tqttness BOPE Test on ARCO's Kuparuk 0-3 Sec. 23, TllN-RlOE, UM Perm1 t #79-84 Wtednesday December 5, 1979 , i,,~, , ~ ~ · - ~ ~ ~ ~ ' ~ ~ · I traveled to Prudhoe Bay thts~ da, tq at the request of Mr. Ken ~lones, ARCO drtlltng foreman to wttn~s~ ,~he~BO~E test on Kuparuk ~0-3. Thursday ~~er.....6, 1979 The BOPE at l:O0 a.~ and were concluded at 7:30 a.m. The ~sults of are attache~'~tO.tH~ ~port. In su~ry, I ~tnessed the BOa',test on A~CO's Kuparuk O-3. ~d% Ai~ Oil and Cas Conservation Cc~,nj_ssion ~' l'ield Insl~ction of Blc.:Duh Prcvcnt[on'F~ui?:~nt Well Sign ...... ' Gener 31 i!ousckccping Reserve pit Rig __ ACCU~ ~i~tTOR SYSTt.2q gOPE Stack ,- Annular Pre ~Cr,~ Pilx~ R~-'~S __ _~_____ Blind Rams / Choke Line Valves ,/ H.C.R. Valve / Kill Lj_ne Valves ..,~, Check Valve /'us t Pressnrc _~.?~._~ __ _ Test Results: Failures Ful 1 Charge Pressure.~ <) __ psig Pressure Afker Closur. e/~.~-(~. ___psig 200 psig ~vc Predmrg~ ArEa.'~'~,',c~: -- mi~:, ~11 ~%argc Pressure At~ain~:~___ mi~ ~, ConSols: Master ~~._ COLk~ i' ~ ----~ - KcllI and Fi~cr S,~e/y Valves _ _ Lo'.,nr Kelly. / lest Pres: dg,p~e~O__ Ball ~,Lo / Tesh Pr,.':~'.ure -- ~ Inside ~P / 'Pose Pf~_ ~'~2r. ~ No. Valves /~ __ No. flan~e~ ~ ~ Ad] ~r3t~)le Chokes~ -- - _.- / Repazr or Replac~nent of failed cquipme~,, to be Di ~z ,%t- iI ~U t: orig. - AO~'~C cc - F~eld O}~ralior/iut~viso~ __ cc - Drilling Dcpt. Sup2rintende,::~,~. November 7, 1979 Xuparuk 25650 No. D-3 ARCO Oil and Gas Company Permit Ho. 79-84 BUr. Loc.~ 3*FNL, 601'WEL, Sec 23, TllN, RIOE, Bottcsahole Loc.= 1320tNSL, 1320tEWL, Sec 14, T11N, R10E, UN. Nr. P. A. Va~usen District Drilling Engineer A~CO Oil and Gas Company P. O. ~x Dear ~. VanDusen~ Encl0sed is the approved application for permit to drill the above referenced well. Well samples, core chips and a mud log arc,not required. A directional survey is required, if available, a tape contain- ing the .digitized log information on all logs shall be submitted for copying e~ept experimental logs, velocity surveys and dip~eter surveys. · Many rivers in Alaska and their drainage systems have been Ol&es.ifled as i~portant for the spawning or migration of anadromous fish. Operations in these areas are subject to AS i6.50.870 a~d the regvlations promulgated thereunder (Title 5, Alaska Administrative Code}. Prior to commencing operations you may be oontauted by t.he Habitat Coordinator's office, Department of Fish and Game. Pollution of any waters of the State is prohibited by AS 46, Chapter 3, Article 7 and the regulations promulgated thereunder (Title 18, Alaska Administrative Code, Chapter 70) and by the Federal Water Pollution Control Act, as amended. Prior to Nr. P. &. VanDusen Kuparuk 25650 No. -2- November 7, 1979 cosmencing operations you may be contacted by a representative of the Department of Environmental Conservation. Pursuant to AS 38.40, Local Rite Under State Leases, the Alaska Department of Labor is being notified of the issuance of this per. it to dril 1. To aid us in scheduling field work we would appreciate your noti£ying this office within 48 hours after the well is spudded. We would also like to be notified so that a repre- sentative of the com~ission may be present to witness testing of blowout preventer equip~ent before surface casing shoe is drilled. In, the event of suspension or abandonment, please give this office adequate advance notification so that we may have a Enclosure, oc~ Department of Fish & Game, HaBitat Section w/o encl. Depar~t of Environmental Conservation w/o/anti. Depar~nt of Labor~ Supervisor, Labor Law Compliance Division w/o encl. ARCO Oil and Gas[ -npany North Alask~ ,strict Post Ofhce Box 360 Anchorage, Alaska 99510 Telephone 907 277 5637 November,l, 1979 Mr. Hoyle H. Hamilton State of Alaska Department of Natural Resources Division of Oil and Gas 3001 Porcupine Drive Anchorage, AK 99501 Subject: D-3 Dear Mr. Hamilton: Enclosed herewith is the Permit to Drill, the $100.00 filing fee, and the required survey plat for the above-mentioned well. Very truly yours, P. A. VanDusen District Drilling Engineer PAV:jh Enclosures ARCO OH and Gas Company ss a D~ws~on of AtlanhcRschfseldCompany Form 10-401 REV 1-1-71 la. TYPE OF WORK STATE OF ALASKA OIL AND GAS CONSERVATION COMMITTEE ( SUBMIT IN TRI~ ATE (Other instructions on PERMIT TO DRILL OR DEEPEN DRILL [] b TYPE OF WELL WELL WELL OTHER 2 NAME OF OPERATOR ARCO Oil and Gas Company 3 ADDRESS OF OPERATOR P. O. Box 360, Anchorage, AK 4 LOCATION OF WELL At surface DEEPEN [-1 reverse rode) SINGLE MULTIPLE RECEIVED 99510 NOV-§ lgTg API #50-029-20408 6 LEASE DESIGNATION AND SERIAL NO. ADL 25650 7. IF INDIAN, ALLOTTEE OR TRIBE NAME 8 UNIT FARM OR LEASE NAME Kuparuk 25650 9 WELL NO. D-3 10 FIELD AND POOL, OR WILDCAT Prudhoe Bay Kuparuk River Oil 3'FNL, 601'WEL, Sec 23, TllN, RIOE, UM AlaskaOil & C:~, ,.' An~nurage At proposed prod zone @ 6250'ss 1320'NSL, 1320'EWL, Sec 14, TllN, RIOE, UM 13 DISTANCE IN MILES AND DIRECTION FROM NEAREST TOWN OR POST OFFICE* 30 miles Northwest of Deadhorse 14. BONDIN~OmV~TION Oil & Gas Bond nE Statewi desurety and/or No. #8011 - 38-40 ( Federa 1 Insurance Co. ) 11 SEC, T , R., M , (BOTTOM HOLE OBJECTIVE) Sec 14, TllN, RIOE Amount $1 00,000 Pool 15. DISTANCE FROM PROPOSED * LOCATION TO NEAREST PROPERTY OR LEASE LINE, FT. (Also to neaxest dng, umt, ff any) 4679' DISTANCE FROM PROPOSED LOCATION TO NEAREST WELL DRILLING, COMPLETED, OR APPLIED FOR, FT No OF ACRES IN LEASE 2560 PROPOSED DEPTH , +6750'TVD 17. NO.ACRES ASSIGNED TO THIS WELL 20 ROTARY OR CABLE TOOLS 320 240' Rotary 21 ELEVATIONS (Show whether DF, RT, CR, etc.) 22 APPROX DATE WORK WILL START 105' RKB, 71' Ground Level November 20, 1979 23 PROPOSED CASING AND CEMENTING PROGRAM . . SIZE OF HOLE SIZE OF CASING WEIGHT PER FOOT GRADE SETTING DEPTH Quantity of cement 24" 16" 65 H-40 80'+_MD Cmt t6 surf - approx 200 ft3~ 13-3/4" 10-3/4" 45.5 , K-55BTC 2931'_+MD Cmt to surf approx.2450 ftj 9-7/8" 7" 26 K-55BT( 8062'-+MD Cmt w/approx 2250 ft~ kRCO Oil and Gas Company proposes to drill a Prudhoe Bay Kuparuk River Oil Pool development well to ~pproximately +8062'MD, +6750'TVD. Selected intervals will be logged and tested. A 20" x 2000 psi ~nnular preventer and surface diverter system will be installed on the 16" conductor while drilling ;he surface hole. A 13-5/8" 5000 psig RSRRA BOPE stack will be installed on the surface pipe. It rill be tested upon installation and weekly thereafter. Test pressure will be 3000 psig. The well rill be completed with 3-1/2" 9.2# J-55 Buttress tubing. Non-freezing fluids will be left in 4ncemented annuli thru the permafrost interval. Selected intervals will be perforated within the (uparuk formation and reported on subsequent report. A downhole safety valve will be installed ~nd tested upon conclusion of job. IN ABOVE SPACE DESCRIBE PROPOSED PROGRAM If proposal ~s to deepen g~ve data on present producUve zone and proposed new productive zone. If proposal ~s to drdl or deepen dixect~onally, gave pertinent data on subsurface locations and measured and true vertical depths. G~ve blowout preventer progxam. 24. I hereby certl.~y that the Fo~g~ SIGNED. ~~'~~ DATE 11/1/79 CIlus space for State office use) CONDITIONS OF APPROVAL, IF ANY SAMPLES AND CORE CHIPS REQUIRED MUD LOG OTHER REQUIREMENTS [] VEs E[NO [] YES ~ NO DIRECTIONAL SURVEY REQUIRED A.P I NUMERICAL CODE ,.._r~',ES []NO ~ - o'~-q - %0 District Drilling Engr. TITLE APPOVED BY ~ BY ORDER OF THE APPROVALDATE November 7, 1979 Ccmuissioner 11/7/79 TITLE DATE *Seelnstruction On ReverseSide ~ WELL9 W[~.L ,'il Y - 5,959,904.19 l X ~- ~60484.14 v ~ toOl' /~ LAT- 7018JO3.~72'' ~ LONG - 14~°30'36.426~ > ~ ~4ELL /2 Y - 5,959,784.20 X = ~60,485.20 Dt~[ It LAT = 7018'02.492" j ~ ~ , ~ LONG- 149°30'36.424'', I D~' ~ ~ELL , ~ Y ~ 5,959,664.22 ~I ~ ' X = ~60,4~6 26 I ~' LAT ~ 70 lB'01. 12" D~~ ~ -- LONG - 149°30'36.421" 23 24 ~ (~ I~ I,RIOE,UM.) NELL I ~ Y ~ 5,959,544.23 I ~ X = ~60,487.32 i~~ LAT ~ 70~18'00.131'' LONG 149°30' 36.4~8~ I I ~ ~. ,¢ELL 5xY == 5,~59,424.2560,488.38 ~ , ~ LAT 7017' 58.951" ~ ~ LONG ~ WELL .~ Y = ~ V -->/~ a~ LAT 70~17'57.771'' I O~~ " ~> < LONG 14g°30'36.413" ~ <I ~{ A m ~ o~ WELL '7 Y = 5,959,18k.28 ~ X = ~60, > D~ ~ LAT = 70~17'~.59~'' ' R E C E I V E D LONG ' ~9°]0' 36, ~09' ~ NClV-~ l~ NELL t~8 Y x - ~60,~.56 LAT - 70~7'55.~11'' ~CAk~: I"~0o' ~ Oil 8 g.s , ,~s. UUh,,illggl6,~ LON8 --,~ ~ HEREBY CERTIFY THAT I AM ~ O, '"~:~' "~ v~ PROPERLY REGISTERED AND LICENSED '-'-' ~"~t-~; '~;'~) TO PRACTICE LAND SURVEYING IN (,/~~,~ ~/~Z~/~ THE STATE OF ALAS~ ArID THAT ........ '/~'~,"--' ......... ~ THIS PLAT REPRESENTS AN AS- / ~ ~ g~E~ ~ BUILT SURVEY HADE BY HE, AND -' ~ TI{AT ALL DIMENSIONS AND OTHER ' "" · -'~ ,, ~ DETAILS ARE CORRECT,AS OF ~' "~ cL,,~'-.'L-~ DATE q/7/Tq AtlanticRichfiildCompany ~ DAT~ DRAWING No: NORTH AMERICAN PRODUCING DIVISION D,ST.,CT KUm. UK II FC~2~ CR-13 2ASING STRING CASING SIZE HCLC SIZE FIELD CObq~IFY C/SING AND TUBIJG L[SIGN DESIGN BY ~ %5 /&, INTERVAL Bottom Top 0 LE:GTH. DESCR.iPTiOif ',f£ IGH 2 TENSION ~n~'r ~ W/ BP -top o£ STREIfG~H Wt. Grade %-r. raad W/O ~5" "' section TENSION lbs lbs !OO0 lbs COLLAPSE COLLAPSE PRESS. ~ DESIST. bottom tenszon DSZ CDF BUP£T !i,TgRJ. AL BDF PPSCE P.RESSO?xE 12lg~ PER YiCLD ~2_. ,. psi ps~ /d. yo 9' / 0 ,- ¢ . Formulae- Collapse resistance in tcnsion= X (Collapse press~re raters) Ca!culat~ons: Burst Pressure = ~2SP + I)ep%h ( Hyd. Gr. II --.~) BE (Bouyancy Factor) = ~.co - (o.oz53 x ~':~a wt. z) To~al Cost f. Is the permit fee attached ........................... 2. Is ~11 to be located in ~ defined pool 3. Is a registered survey plat attached ................ proper distance frcm property line .................. 4. Is t~ll located 5. IS well located proper distance frcm other wells .................... 6. Is sufficient underdicated acreage available in this pool 7. Is well to be deviated .............................................. 8. Is operator the only affected party .......................... 9. Can per, lit be approved before ten-day ~i~ 10. DOes operator ha~e a bond in force .................................. Is a conservation order needed ...................................... 12. !3. Is administrative approval needed ................................... Is conductor string provided ........................................ ~ Yes No Lease & Well ~No. Item A~prove Date / 14. 15. Is enough cement used to cLrculate on conductor a~ surface ......... Will cement tie in surface and intermediate or production strings ... (4) ~sg. ~ 11'~-7~ 16. Will c~ent cover all known productive horizons ..................... 17. tqill surface casing protect fresh ~ter zones ....................... ~ 18. Will all casing give adequate safety in collapse, tension and burst.. ~.~ 19. Does BOPE have ~fficient pressure rating - Test to ~6) psig .. ~ Approval Reccmmended: (5) Additional Requirements: Engineering: rev: 06/21/7 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. il - 11 11 11 11 11 11 11 11 11 111111 111111 000000 7777777777 000000 7777777777 O0 O0 77 O0 O0 77 O0 0000 77 O0 0000 77 O0 O0 O0 77 O0 O0 O0 77 0000 O0 77 0000 O0 77 O0 O0 77 O0 O0 77 000000 77 000000 77 oobooo 000000 O0 O0 O0 O0 O0 0000 O0 0000 O0 O0 O0 O0 O0 O0 0000 O0 0000 O0 O0 O0 O0 O0 000000 000000 7777777777 7777777777 77 77 77 77 77 77 77 77 77 77 77 77 666666 666666 66 66 66 66 66666666 66666666 66 66 66 66 66 66 66 66 666666 666666 000000 11 000000 11 O0 O0 1111 O0 00 1111 O0 0000 11 O0 0000 11 O0 O0 O0 11 O0 O0 O0 11 0000 O0 11 0000 O0 11 O0 O0 11 O0 O0 11 000000 111111 000000 I 11 4~ 44 4 44 44 44 44 44 4444444444 4444444444 44 44 44 44 44 44 77777 77 77 7 77 77 77 77 77 77 77 77 M M O AAA MM MM d A A M M M J A A M M ,J A A M M j J AAAAA M M j d A A M M did A A PPPP RRRR U U P P R R U U P P R R U U PPPP RRRR U U P ~ R U U P R R U U P ~ R UUUUU *SfART* USER PCAL [10707,60147] JOB MONITOR SWS KL10E34 JUL'79. *START* *START* USER PCAL [10707,60147] dOB MONITOR S~$ KL10E34 JUL'79. *START* SHIP SEQ. SHIP SEQ. DDDD H H OOO D D H H O 0 D D H H 0 0 D D HHHHH O 0 D D H H O O D D H H 0 O DDDD H H 000 7153 DATE 04-MAR-80 7153 DATE 04-NAR-80 EEEEE E EEEE L LEEEL 15:05:52 15:05:52 ¥¥ ¥¥ EEEEEEEEEE RRRRRRRR VV ~¥ EEEEEEEEEE RRRRRRRR VV VV EE ~R RR V¥ VV EE RR RR VV VV EE RR RR VV VV EE R~ RR VV V¥ EEEEEEEE RBRRRRRD YV YV EEEEEEEE R~RRRRRR V¥ ¥¥ EE R8 RR YV ¥¥ EE R~ RR VV VV EE R8 RR VV VV EE RR RR VV EEEEEEEEEE RR RR VV EEEEEEEEEE RR RR llIIII IIIIII II II II II II II I1 II II Ii IIIIII IIIIII ffFfFFFFFF FF ~F FF FF PFfFffFP f f P'P~FFFf FF fF Ff FF FF Ff YY YY Y¥ YY YY ¥¥ YY ¥Y YY ¥¥ YY YY 000000 000000 222222 000000 000000 222222 00 O0 00 O0 22 22 00 O0 O0 00 22 22 00 O000 00 0000 22 00 0000 O0 0000 22 O0 O0 O0 00 00 00 22 O0 O0 O0 O0 O0 O0 22 0000 O0 0000 O0 22 0000 O0 0000 O0 22 00 O0 O0 O0 22 00 00 O0 00 22 ~00000 000000 2222222222 00000 000000 2222222222 *START* USER PCAL [10707,60147] dOB SHIP MONITOR SWS KL10E34 dUb-79. *START* FILE: DSKH:VERIF~.002<057>[I0707 60147] CREATED: PRIN~ED: 04-MAR-80 15:0g:08 QUEUE SWITCHES: /FILE:FORT /COPIES:I /SPACING:I /LIMIT:70 /FORMS:NORMAL 7153 DATE 04-MAR-80 04-MAR-80 15:03:17 15:05:52 SCHLUMBERGER COMPUTING CENTER 10707,60147 REEL HEADER LENGTH: 132 BYTES REEL NAME: P.C.A.L. SERVICE NAME: EDIT REEL CONTINUATION NUMBER: O! PREVIOUS REEL NAME: COMMENTS: LIS FORMAT CUSTOMk~ TAPE DATE: 80/ ]/ 4 TAPE HEADER LENGTH: 112 BYTES TAPE NAME: 60147 DATE: 80/ 3/ 4 SER¥1CE NAME: EDIT TAPE CONTINUATION NUMBER: Ol PREVIOUS ~APE NAME: COMMENTS: TAPE COMMENTS CSG 10.75 IN. @ 2906' / BIT 9.875 IN @ 8070 / FLUID OiL BASE / VISC 46 / PH 0.0 / BHT 150 DF FILE HEADER LENGTH: 62 BYTES FILE NAME: EDiT .001 ~AXIMUM PHYSICAL RECORD LENGTH: PREVIOUS fILE NAME: 1024 BYTES WELL $IIE INFORMATION RECCRD LENGTH: COMPANY: WELL: fIELD: RANGE: TOWN: 5ECTION: COUNTY: STATE: 168 BYTES ARCO ,O1b & GAS CO. D-3 KUPARUK IOE lin 23 N. SLOPE ALASKA DATA ~[]RMAT 6PECIFiCATION LENGTH: 570 BYTES ENTRY BLOCK$~ TYPE 0 SIZE 1 REP COOE 66 ENTRY 0 DATUM 6PEClFiCATION BLOCKS: ENTRY lC TOOL 1 DEPT 2 1LD DIL 4 DIE 5 GR BHC 6 DT BHC 7 GR CNL 8 CALl CNL 9 DRHO FDC 10 NPHI CNL ll RHO8 CNL 12 NRAI CNL 1] NCNL CNL 14 FCNL CNL SVURD# UNITS AP1 API AP1 API FILE# SIZE EXP PROC SAM REP DEPT SHIFT FT 0 0 0 0 0 4 0 0 I 68 0 0 OHMM 7 1~ 46 0 ~ 4 0 0 1 68 0 0 OHMM ? 1 44 0 4 0 0 I b8 0 0 GAP1 7 ]1 32 0 0 4 0 0 1 68 0 0 GAPI 60 )1 32 0 0 4 0 0 1 68 0 0 U$/f 60 52 3~ 0 0 4 0 0 1 68 0 0 GAPi 42 31 3 0 0 4 0 0 1 68 0 0 IN 42 28 1 0 0 4 0 0 1 68 0 0 G/C3 42 44 0 0 0 4 0 0 1 68 0 0 PU 42 68 ) 0 0 4 0 0 1 68 0 0 G/C~ 42 ,5 1 0 0 4 0 0 1 68 0 0 c,c ~ ~ , o o ~ o o ~ ~ o o c~ ~ ~ ~ o o ~ o o ~ ,~ o ° CPS 42 34 93 0 0 4 0 0 1 68 0 0 DEPTH 8075.000 8000.000 7900.000 7800.000 77O0.000 7600.000 7500.000 7400.000 7300.000 7200.000 7100.000 MNEMONIC ILD DT NPHI FCNL 1LD DT NPHI FCNL 1LD DT NPH1 fCNL iLD DT NPHI FCNL 1LD DT NPHI fCNL iLD DT NPH1 FCNL 1LD DT NPHI FCNL 1LD DT NPHI ~CNL ILD DT NPHi FCNL ILD DT NPHI FCNL ILD DT NPHI FCNL VALUE 1.890 97.188 47.021 -541.500 2.221 102.000 41.455 503.250 2.350 104.188 44.434 463.750 3.787 96.750 36.914 649.000 4.742 93.750 3i.738 717.000 3.359 83.750 33.691 732.000 16.875 85.750 29.932 816.500 1.736 105.375 37.891 508.750 1.831 117.000 44.189 431.000 2.898 95.000 38.525 465.750 1.736 117.000 44.629 429.000 MNEMONIC ILM GR RHOB ibm GR RHOB RHUB ILM GR RHOB ibm GR RHOB GR RHOB ibm RHOB ILM GR RHOB ILM GR RHOB 1bM GR RHOB ILM GR RHOB VALUE 2.154 -117.563 1.639 2.322 112.125 2.424 2.480 109.688 2.]69 3.936 98.188 2.418 4.953 89.0~3 2.{ 1 3.242 86.500 2.494 18.391 49.250 2.277 .859 13 .250 2.424 1.890 129.500 2.418 ].055 229.000 2.438 1.752 257.750 2.]30 MNkMONIC G~ CALl NRA1 GR CALl NRAT GR CALl NRAT GR CALl NRAT GR CALl NRAT GR CALI NRAT GR CALl NRAT GI~ CALl G~ CALl NRAT GR CALl NRAT GR CALl NRAT VALUE 78.500 9.875 3.482 89.938 9.781 3.492 92.375 9.867 3.664 83.063 10.242 3.277 77.563 10.703 3.037- 74.813 10.203 3.096 40.094 9.375 2.807 106.500 10.617 3.363 110.000 10.516 3.703 177.875 10.313 3.373 191.375 10.375 3.719 MNEMONIC GR DRHO NCNb GR DRHO NCNb GR DRHU NCNb GR DRHO NCNb GR DRHO NCNb GR DRHU NCNL GR DRHO NCNb G~ DRHU NCNb GR DRHO NCNb GR DRHO NCNb GR DRHO NCNb VALU~ 78.500 -0.138 -2002.000 89.938 -0.005 1933.000 92.575 -0.011 1942.000 83.063 -0.004 2114.000 17.563 -0.004 2260.000 74.813 -0.010 2422.000 40.094 -0.005 2514.000 106.500 -0.001 1792.000 110.000 -0.017 1655.000 177.875 0.017 1834.000 191.375 0.001 1776.000 DEPTH ?000.000 6900,000 6800,000 6700,000 6600,000 6500,000 6400.000 6300.000 6200,000 6100.000 6000,000 MN EMONIC ILD DT NPHI )CNL 1LD DT NPHI FCNL ILD DT FCN 1LD DT NPH1 FCNL iLD DT NPH! ~CNL iLD DT NPHI ~CNL iLD DT NPHI [CNL ILD DT NPHI FCNL ILD DT NPHI ~CNL ILD DT NPHI BCNL ILD DT NPHI FCNL VALUE 2,355 115.563 40.576 521.000 1,672 109,000 48.193 509,250 1.600 130.OO0 50.732 438.500 2,041 111.375 42,090 528.000 2.986 113.188 42.822 447.500 2.545 104.000 35.254 597.000 1.812 106,375 34.912 583,500 3.297 94,188 37.451 636,500 2.209 109,000 39.307 611,500 1.517 116.000 46.631 439.250 1.951 109.188 -999.250 -999,250 MNEMONIC GR RHOB RHOB ILM GR RHOB GR RHOB IbM GR RHOB ILM GR RHOB IbM GR RHOB IbM GR RHOB IbM GR RHOB IbM GR RHOB IbM GR RHOB VALUE 2.402 177.500 2.426 1.543 181.500 2.324 1.764 116,625 2.225 2.029 155.250 2.371 3.023 2. 2.816 196.00~ 2.31 1.921 191.500 2.357 3.162 121.250 2,244 2.180 148.125 2.434 1,567 50O 15~:~44 1.954 103.813 -999.250 MNEMONIC CALl NRAT GR CALl NRAT GR CALl NRAT GR CALl NRAI GR CALl NRAT GR CALl NRAI GR CALl NRA2 GR CALl NRAI GR CALl NRAT GR CALl NRAT GR CALl NRAT VALUE 138.b25 10.328 3.488 .234 3.904 98.b25 10.242 4.047 130.500 10.367 3.574 138.250 15 155.750 10.41~ 3.19 153.625 10.383 3.178 103.063 10.492 3.328 121.438 10.523 3.434 131.750 10.484 3.838 92.063 10.391 -999.250 MNEMUNIC GU DRHU NCNb GR DRHU NCNb GR DRHO NCNb GR DRHO NCNb GR DRHO NCNb GR DRHU NCNb GR DRHO NCNb GR DRHO NCNb GR DRHO NCNb GR DRHO NCNb GR DRHO NCNb VALUE 138.625 -0.014 1918.000 152.000 -0.013 2386.000 98.625 -0.014 1913.000 130.500 0.009 2188.000 138.250 ~0.010 18 0.000 155.750 -0.015 2130.000 153.625 0.000 1879.000 103.063 -0.001 222b.000 121.438 -0.015 2146.000 131.750 -0.00~ 1838.000 92.003 -999.250 -999.250 DEPTH 5900,000 5800.000 5700.000 5600,000 5500,000 5400.000 5300o000 5200,000 5i00,000 5000,000 4900,000 MNEMONiC ILO DT NPHI ~CNL ILD DT NPHI ~CNL ILD DT NPHI ~CNL ILD DT NPH1 FCNL ILD DT NPHI FCNL iLD DT NPHI fCNL ILO DT NPHi ~CNL ILD DT NPH1 ~CNL ILO DT NPHI ~CNL ILD DT NPHi FCNL DT NPH1 ~CNL VALUE 2.182 105.563 -999.250 -999.250 2.584 104.563 -999.250 -999.250 2.572 101.375 -999.250 -999.250 2.734 101.375 -999 2.867 105.188 -999.250 -999.250 2.533 110.188 -999.250 -999.250 3.965 99.375 -999.250 -999.250 4.15b 106.375 -999.250 -999.250 2.957 105.000 -999.250 -999.250 4.012 112.000 -999.250 -99g.250 2.531 110.563 -999.250 '999.250 MNEMONIC ILM GR RHOB ILM GR RHOB ILM GR RHOB ILM GR RBOB 1bM GR RHOB ILM GR RHOB GR RHOB ILM GR RHOB ILM GR ~HUB ibm GR RHUB ILM GR RHOB VALUE 2.201 105.9~8 -999.2 0 2.557 103.000 -999.250 2.555 93.625 -999.250 2.701 95.438 -999.250 2.850 108.063 -999.250 2.533 1~3.500 -9 9.250 4.078 82.313 -999.250 4.223 103.063 -999.250 2.936 95.875 -999.250 4.008 110.313 -999.250 2.375 86.750 -999.250 MNEMONIC GR CALl NRAT GR CALl NRA2 GR CALl NRAT G~ CALl NRAT GR CALl NRAT GR CALl NRAI GR CALk NRAT GR CALl NRAT GR CALI NRAT GR CALl NRA']. GR CALl NRAT VALUE 81.375 10.523 -999.250 91.000 10.602 -999.250 80.813 ~0.469 9.250 84.688 10.422 -999.250 86.250 10.469 -999.250 85.188 10,516 -999.250 70.750 10.656 -999.250 78.813 10.539 -999.250 78.375 10.664 -999.250 77.563 10.805 '999.250 70.938 10.641 -999.250 MNEMONIC GR DRHU NCNb GR DRHO NCNL GR DRHO NCNb GR DRHO NCNb GR DRHU NCNb GR DRHO NCNb GR DRHU NCNb GR DRHO NCNb GR DRHO NCNb GR DRHO NCNb GR DRHU NCNb VALUE 81.375 -999.250 -999.250 91.000 -999.250 -999.250 80.813 -999.250 -999.250 84.b88 -999.250 -999.250 8b.250 -999.250 -999.250 85.188 -999.250 -999.250 70.750 -999.250 -999.250 18.813 -999.250 -999.250 78.375 -999.250 -999.250 77.563 -999.250 -999.250 70.938 -999.250 -999.250 DkP1H 4800.000 4700.000 4600.000 4500.000 4400.000 4300.000 4200.000 4100.000 4OO0.000 3900.000 3800.000 MNEMONIC DT NPHI fCNb ILD DT NPHI ~CNb ILD DT NPHI FCNL ILD DT NPHi FCNL ILD DT NPHi fCNb ILD DT NPHi ~CNL ILD DT NPHI fCNL 1LD DT NPHI fCNL lED DT NPHi fCNL lED DT NPHI ~CNL ILD DT NPHI ~CNL VALUE 2.578 115.000 -999.250 -999.250 6.844 112.188 -999.250 -999.250 3.654 115.188 42.188 484.250 8.922 118.750 40.283 603.000 14.898 125.750 42.969 500.750 6.746 124.375 47.705 483.000 27.047 130.000 44.971 478.500 11.797 114.000 43.701 479.250 6.730 112.563 41.357 537.500 22.844 133.500 44.092 515.000 9.414 129.375 42.090 582.000 MNEMONIC ILM GR RHOB ILM GR RHOB ILM GR RHOB IbM GR RHOB IbM GR RHOB ILM GR ~HOB ILM GR RHOB ILM GR RHUB IbM GR RHOB IbM GR RHOB ILM RHOB VALUE 2.486 107.938 -999.250 6.813 98.313 -999.250 3.494 102.813 2.281 8.852 74.188 2.174 14.188 72.000 2.123 6.227 79.375 2.205 29.609 6~,688 .t27 10.156 87.313 2.314 6.625 81.438 2.326 23.703 50.656 2.090 9.813 61.500 2.061 MNEMONIC GR CALl NRAT GR CALl NRAT GR CALI NRAT GR CALl bRAT GR CALl NRAT GR CALl NRAT GR CALl NRAT GR CALl NRAT GR CALl NRAT GR CALl NRAT GR CALl NRAT VALUE 80.750 10.664 -999.250 82.125 10.547 -999.250 86.875 10.641 3.604 61.094 9.727 3.422 53.625 9.523 3.557 71.438 10.297 3.881 56.938 9.797 3.589 77.250 10.258 3.656 69.875 11.305 3.578 47.~88 9.945 3.552 58.469 9.564 3.520 MNEMONIC GR DRHU NCNb GR DRHO NCNb GR DRHO NCNb GR DRHO NCNb GR DRHU NCNb GR DRHO NCNb GR DRHO NCNb GR DRHO NCNb GR DRHU NCNb GR DRHO NCNb GR DRHO NCNb VALUE 80.750 -999.250 -999.250 82.125 -999.250 -999.250 86.875 -0.006 1937.000 61.094 -0.004 2092.000 53.625 0.001 1912.000 71.438 -0.012 1979.000 56.938 -0.007 1810.000 77.250 0.057 1815.000 69.875 0.003 2048.000 47.688 -0.014 1889.000 58.459 -0.004 2043.000 DEPTH 3700.000 ]600.000 3500,000 3400.000 3JO0.O00 3200.000 3100.000 3000.000 2900,000 2800.000 2770,000 MNEMONIC VALUE ILD 10.297 DT 136.750 NPHI 43.701 FCNL 447.500 ILD 10.070 DT 121.5b] NPHI 40.674 FCNL 521.500 ILD 10.~66 DT 139. 50 NPHi 44.189 FCNL 422.500 1LD 11.539 DT 129.750 NPHI 46.~84 FCNL 441. 50 ILD 6.145 DT 139.125 NPHi -99925.000 fCNL -999.250 1LD 10.367 DT 150.375 NPHI -99925.000 PCNL -999.250 ILD 10.258 DT 141.500 NPHI -99925.000 ~CNL -999.250 iLD 10.961 DT 137.500 NPHI -9.992~.~00 FCNL 99 . 50 1LD 5.164 DT 96.000 NPHI -99925.000 ~CNL -999.250 1LD 12.023 DT 56.]75 NPH1 -99925.000 ~CNL -999.250 ILD -999.250 DT -999.250 NPHI -99925.000 ~CNL -999.250 MNEMONIC IbM GR RHOB RHOB ILM GR RHOB GR RHOB ILM GR RHOB GR RHOB 1LM GR RHOB IbM GR RHOB ILM GR RHOB 1LM GR RHOB ILM GR RHOB VALUE 11.086 46.875 2.000 9.805 69.250 2.188 10,742 60.469 2.078 11.438 80.750 2.219 6.434 -999.250 -999.250 11.094 -999.250 -999.250 I0.742 -999.250 -999.250 11.523 -999.250 -999.250 2000.000 -999.250 -999.250 2000.000 -999.250 -999.250 -999.250 -999.250 -999.250 MNLMONIC GR CALl NRAT GR CALl NRAT GR CALl NRAT GR CALl NRAT GR CALl NRAT CALl NRAT GR CALl NRAT GR CALl NRAT CALl NRAT GR CALl NRAT GB CALl VALUE 43.56] 10.500 3.676 56.250 9.492 3.424 56.781 10.953 ].725 59.906 9.7O] 3.764 62.625 -999.250 -999.250 4].594 -999.250 -999.250 47.781 -999.250 -999.250 46.531 -999.250 -999.250 39.750 -999.250 -999.250 38.]44 -999.250 -999.250 -999.250 -999.250 -999.250 MNEMONIC GR DRHU NCNb GR DRHO NCNb GR DRHU NCNb GR DRHO NCNL GR DRHO NCNb GR DRHU NCNb GR DRHO NCNb GR DRHO NCNb GR DRHO NCNL DRHO NCNL GR DRHU NCNb VALUE .017 1819.000 5b.250 -0.004 18b0.000 56.781 -0.022 1680.000 59.906 -0.003 1699.000 b2.625 -999.250 -999.250 43.594 -999.250 -999.250 47.781 -999.250 -999.250 46.531 -999.250 -999.250 39.750 -999.250 -999.250 38.344 -999.250 -999.250 -999.250 -999.250 -999.250 SUMMARY OF DATA RECORDS NUMBER OF RECORDS: 590 LENG1H OF RECORDSI 1014 BYTES LENGTH OF LAST RECORD: 510 B¥IES FILE TRAILER LENGTH: 62 BYTES FILE NAME: EDIT .001 MAXIMUM PHYSICAL RECORD LENGTH: NEXT ~ILE NAME: 1024 BXTE$ EOF TAPE TRAILER LENGTH: 112 B~TES TAPE NAME: 60147 SERVICE NAME: EDIT TAPE CONTINUATION NUMBER: 01 NEXT TAPE NAME: COMMEN~S: DATE: 80/ ]/ 4