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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 #:________________Signature12/21/2021Wd͗ϭϵϬϭϲϳϬ Ͳ^Ğƚ͗ϯϲϮϭϳJRBy Abby Bell at 1:43 pm, Dec 21, 2021 3M-1750029217290000 KRU WLWFLFINAL FIELD24-Apr-213M-1950029217370000 KRU WLLDLFINAL FIELD25-Apr-213H-0150103200840000 KRU WLCHCFINAL FIELD26-Aug-213H-1250103200880000 KRU WLCCLFINAL FIELD23-Sep-213H-1250103200880000 KRU WLCHCFINAL FIELD29-Aug-213H-1250103200880000 KRU WLCUTTERFINAL FIELD23-Sep-213H-1250103200880000 KRU WLCUTTERFINAL FIELD24-Sep-211L-1250029220330000 KRU WLSBHPSFINAL FIELD6-Nov-213G-2450103201450000 KRU WLTBG CORRFINAL FIELD29-Oct-211A-2550029221160000 KRU WL WHIPSTOCKFINAL FIELD12-Oct-211A-2350029221310000 KRU WLRBPFINAL FIELD12-Jun-211R-2050029222070000 KRU WLPPROFFINAL FIELD2-Jun-212M-1150103201590000 KRU WLPPROFFINAL FIELD27-Aug-212M-0750103201780000 KRU WLBACKOFFFINAL FIELD5-Aug-211Y-1950029223910000 KRU WLPPROFFINAL FIELD31-May-212T-3050103202190000 KRU WLLDLFINAL FIELD2-May-211Q-20A50029225890100 KRU WLSET RECFINAL FIELD2-Aug-212M-3350103202400000 KRU WLLDLFINAL FIELD18-Oct-211F-03A50029208530100 KRU WLPERFFINAL FIELD19-Oct-211Q-08A50029212250100 KRU WLIPROFFINAL FIELD30-Apr-211E-3350029227970000 KRU WLPPROFFINAL FIELD26-Mar-211D-13550029228160000 KRU WLLDLFINAL FIELD16-Jul-213F-13A50029214990100 KRU WLGLSFINAL FIELD17-Jul-212N-318 50103203430000 KRU WLSCMTFINAL FIELD12-Nov-211C-12750029230240000 KRU WLIPROFFINAL FIELD17-Nov-213S-24A50103204560100 KRU WLCUTTERFINAL FIELD25-Oct-213S-0350103204580000 KRU WLIBPFINAL FIELD26-Oct-211B-2050029231640000 KRU WLPPROFFINAL FIELD22-Apr-211E-11950029231980000 KRU WLLDLFINAL FIELD26-Jun-212W-1750029233700000 KRU WLPPROFFINAL FIELD28-Aug-211H-11850029235780000 KRU WLIPROFFINAL FIELD4-Nov-211H-11450029235840000 KRU WLIPROFFINAL FIELD23-Jun-211H-11350029235880000 KRU WLWFLFINAL FIELD22-May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y Samantha Carlisle at 3:29 pm, Nov 22, 2021 Digitally signed by Jeff Connelly DN: C=US, OU=CTD, O=ConocoPhillips, CN=Jeff Connelly, E=jeff.s.connelly@conocophillips.com Reason: I am the author of this document Location: your signing location here Date: 2021.11.22 12:54:05-09'00' Foxit PDF Editor Version: 11.0.0 Jeff Connelly DSR-11/22/21 RBDMS HEW 11/24/2021 SFD 11/29/2021VTL 01/24/2022 1A-25 CTD Final Schematic 3-1/2" Camco DS nipple @ 488' MD (2.875" min ID)3-1/2" 9.3# L-80 EUE 8rd Tubing to surface3-1/2" Camco gas lift mandrels @ 2982', 4572', 5760', 6597', 7186'Baker PBR @ 7249' MDBaker FHL Packer @ 7272' MDDS Nipple @ 7325' MD (2.812" ID)Baker Locator Sub @ 7343' MDMule Shoe @ 7344'MD_________________Baker PBR @ 7347' MDBaker HB Packer @ 7361' MD_________________3-1/2 Otis XN nipple @ 7459' MD (2.75" min ID, No-Go)9-5/8" 36# J-55 shoe @ 4641' MD7" 26# J-55 shoe @ 8093' MD16" 65# H-40 shoe @ 80' MDA-sand perfs 7776' - 7842' MDC-sand perfs 7576' - 7643' MDModified by JSC 11/1/20211A-25L1TD: 11,033' MDSwell packer (Element @ 7697')TOC: 7759' RKBSlotted liner from TD to 9921' MDLTP (7419')TOL (7429')KOP @ 7594' MD Casing Strings Casing Description Liner OD (in) ID (in) Top (ftKB) 7,429.4 Set Depth (ftKB) 11,033.0 Set Depth (TVD) … 5,987.5 Wt/Len (l…Grade Top Thread Liner Details Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des Com Nominal ID (in) 7,429.4 5,965.8 35.59 Deployment Sleeve w/6' Sealbore Receptical (PBR) Deployment Sleeve w/6' Sealbore Receptical (PBR) 0.000 7,683.5 6,144.5 76.88 Packer - Swell XO 511 Pin X STL Box 9,920.4 6,067.5 99.21 NSAK 350-238, OH QCLL-L80, Dissolvable Bullnose Down 1A-25L1, 11/19/2021 7:59:45 AM Vertical schematic (actual) Liner; 7,429.4-11,033.0 PRODUCTION; 1,278.1-8,093.3 IPERF; 7,797.0-7,842.0 IPERF; 7,776.0-7,783.0 LINER TOP; 7,429.0 Cement Plug; 7,759.0 ftKB APERF; 7,622.0-7,643.0 APERF; 7,596.0-7,618.0 WHIPSTOCK; 7,596.0 APERF; 7,584.0-7,596.0 APERF; 7,576.0-7,584.0 NIPPLE; 7,458.6 PACKOFF; 7,419.0 PACKER; 7,360.9 NIPPLE; 7,325.1 PACKER; 7,272.3 GAS LIFT; 7,185.6 GAS LIFT; 6,596.9 GAS LIFT; 5,760.5 SURFACE; 35.0-4,641.1 GAS LIFT; 4,571.6 GAS LIFT; 2,982.1 PRODUCTION TIE-BACK; 35.0- 1,278.1 NIPPLE; 488.0 CONDUCTOR; 36.0-80.0 Hanger; 31.0 KUP PROD KB-Grd (ft) 35.01 Rig Release Date 1/1/1991 1A-25L1 ... TD Act Btm (ftKB) Well Attributes Field Name KUPARUK RIVER UNIT Wellbore API/UWI 500292211660 Wellbore Status PROD Max Angle & MD Incl (°) 103.79 MD (ftKB) 9,860.47 WELLNAME WELLBORE1A-25 Annotation End DateH2S (ppm) 75 Date 8/10/2016 Comment Last Tag Annotation Depth (ftKB) End Date Wellbore Last Mod By Last Tag: RKB (Top Of Cement) 7,759.0 8/28/2021 1A-25 zembaej Last Rev Reason Annotation End Date Wellbore Last Mod By Rev Reason: Set LTP 11/3/2021 1A-25 fergusp Casing Strings Casing Description CONDUCTOR OD (in) 16 ID (in) 15.06 Top (ftKB) 36.0 Set Depth (ftKB) 80.0 Set Depth (TVD) … 80.0 Wt/Len (l… 65.00 Grade H-40 Top Thread WELDED Casing Description SURFACE OD (in) 9 5/8 ID (in) 8.92 Top (ftKB) 35.0 Set Depth (ftKB) 4,641.1 Set Depth (TVD) … 3,838.9 Wt/Len (l… 36.00 Grade J-55 Top Thread BTC Casing Description PRODUCTION OD (in) 7 ID (in) 6.28 Top (ftKB) 35.0 Set Depth (ftKB) 8,093.3 Set Depth (TVD) … 6,459.3 Wt/Len (l… 26.00 Grade J-55 Top Thread ABMOD BTC Casing Description PRODUCTION TIE- BACK OD (in) 7 ID (in) 6.28 Top (ftKB) 35.0 Set Depth (ftKB) 1,278.1 Set Depth (TVD) … 1,269.0 Wt/Len (l… 26.00 Grade TC-ll Top Thread TC-ll Tubing Strings Tubing Description Tubing – Production String Ma… 3 1/2 ID (in) 2.99 Top (ftKB) 31.0 Set Depth (ft… 7,352.1 Set Depth (TVD) (… 5,902.4 Wt (lb/ft) 9.30 Grade L-80 Top Connection 8rd EUE Completion Details Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des Nominal ID (in) OD Nominal (in)Make Model Com 31.0 31.0 0.04 Hanger 3.000 7.167 McENVOY GEN IV TUBING HANGER 488.0 488.0 0.08 NIPPLE 2.875 4.520 CAMCO DS' CAMCO 'DS' NIPPLE 2,982.1 2,601.2 43.65 GAS LIFT 2.920 5.968 CAMCO MMG CAMCO MMG GLM w/DV 4,571.6 3,786.1 40.76 GAS LIFT 2.920 5.968 CAMCO MMG CAMCO MMG GLM w/DV 5,760.5 4,680.8 42.23 GAS LIFT 2.920 5.968 CAMCO MMG CAMCO MMG GLM w/DV 6,596.9 5,300.1 41.71 GAS LIFT 2.920 5.968 CAMCO MMG CAMCO MMG GLM 7,185.6 5,764.6 34.30 GAS LIFT 2.920 5.968 CAMCO MMG CAMCO MMG GLM w/ DV 7,241.8 5,811.1 34.19 SEAL ASSY 2.990 3.980 BAKER 80-40 BAKER 80-40 SEAL ASSEMBLY 7,248.8 5,816.9 34.16 PBR 2.990 5.010 BAKER 80-40 BAKER PBR 7,272.3 5,836.3 34.08 PACKER 2.910 5.960 BAKER 47B2 - FHL BAKER FHL PACKER 7,325.1 5,880.1 34.24 NIPPLE 2.812 4.500 'DS' NIPPLE 7,342.8 5,894.7 34.42 LOCATOR 2.990 4.530 BAKER GBH-22 BAKER GBH-22 LOCATOR SUB 7,344.0 5,895.7 34.43 MULE SHOE 2.990 3.780 BAKER 80-40 8 ' MULE SHOE, Spacer Tube w/1 FT Space out Tubing Description TUBING 4"x3.5" Post 2013 WO String Ma… 3 1/2 ID (in) 2.99 Top (ftKB) 7,347.2 Set Depth (ft… 7,471.0 Set Depth (TVD) (… 5,999.4 Wt (lb/ft) 9.30 Grade J-55 Top Connection EUE8rdMOD Completion Details Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des Nominal ID (in) OD Nominal (in)Make Model Com 7,347.2 5,898.3 34.47 PBR 3.000 5.125 BAKER PBR, 10' STROKE 7,360.9 5,909.6 34.60 PACKER 2.870 6.063 BAKER 'HB' RETRIEVABLE PACKER 7,458.6 5,989.4 36.18 NIPPLE 2.800 4.520 OTIS XN NIPPLE. Milled out to 2.80" on 7/26/21 7,470.3 5,998.8 36.42 SOS 2.992 3.500 BAKER SHEAR OUT SUB Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Des Com Run Date ID (in) SN 7,419.0 5,957.3 35.38 PACKOFF NSAK Compression PTSA Liner Top packer w/ 1.781" R Nipple. 2.73" OD X 1.78" ID X 9.50' OAL) 11/3/2021 1.780 7,429.0 5,965.4 35.59 LINER TOP CTD 2.375" Liner top, deployment sleeve w/ 6' seal bore. 10/28/2021 1.992 7,596.0 6,098.2 39.15 WHIPSTOCK 2.625" Northern Solutions High Expansion Wedge (8.78' OAL) 10/12/2021 0.000 Mandrel Inserts St ati on N o/Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Make Model OD (in) Serv Valve Type Latch Type Port Size (in) TRO Run (psi) Run Date Com 1 2,982.1 2,601.2 43.65 CAMCO MMG 1 1/2 GAS LIFT GLV RK 0.188 1,229.0 8/1/2021 2 4,571.6 3,786.1 40.76 CAMCO MMG 1 1/2 GAS LIFT OV RK 0.250 0.0 8/1/2021 3 5,760.5 4,680.8 42.23 CAMCO MMG 1 1/2 GAS LIFT DMY RK 0.000 0.0 6/17/2015 4 6,596.9 5,300.1 41.71 CAMCO MMG 1 1/2 GAS LIFT DMY RK 0.000 0.0 6/17/2015 5 7,185.6 5,764.6 34.30 CAMCO MMG 1 1/2 GAS LIFT DMY RK 0.000 0.0 11/19/2014 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft )Type Com 7,576.0 7,584.0 6,082.6 6,088.9 C-4, C-3, C-2, UNIT B, 1A-25 1/5/1992 8.0 APERF 180 deg Phase; HLS 2.5" 7,584.0 7,596.0 6,088.9 6,098.2 C-4, C-3, C-2, UNIT B, 1A-25 1/5/1992 8.0 APERF 180 deg Phase; HLS 2.5" 1A-25, 11/19/2021 8:01:31 AM Vertical schematic (actual) Liner; 7,429.4-11,033.0 LINER TOP; 7,429.0 PRODUCTION; 1,278.1-8,093.3 IPERF; 7,797.0-7,842.0 IPERF; 7,776.0-7,783.0 Cement Plug; 7,759.0 ftKB APERF; 7,622.0-7,643.0 APERF; 7,596.0-7,618.0 WHIPSTOCK; 7,596.0 APERF; 7,584.0-7,596.0 APERF; 7,576.0-7,584.0 NIPPLE; 7,458.6 PACKOFF; 7,419.0 PACKER; 7,360.9 NIPPLE; 7,325.1 PACKER; 7,272.3 GAS LIFT; 7,185.6 GAS LIFT; 6,596.9 GAS LIFT; 5,760.5 SURFACE; 35.0-4,641.1 GAS LIFT; 4,571.6 GAS LIFT; 2,982.1 PRODUCTION TIE-BACK; 35.0- 1,278.1 NIPPLE; 488.0 CONDUCTOR; 36.0-80.0 Hanger; 31.0 KUP PROD KB-Grd (ft) 35.01 Rig Release Date 1/1/1991 1A-25 ... TD Act Btm (ftKB) 8,120.0 Well Attributes Field Name KUPARUK RIVER UNIT Wellbore API/UWI 500292211600 Wellbore Status PROD Max Angle & MD Incl (°) 47.19 MD (ftKB) 2,500.00 WELLNAME WELLBORE1A-25 Annotation Last WO: End Date 11/22/2014 H2S (ppm) 75 Date 8/10/2016 Comment SSSV: NIPPLE Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft )Type Com 7,596.0 7,618.0 6,098.2 6,115.2 C-4, C-3, C-2, UNIT B, 1A-25 1/5/1992 8.0 APERF 180 deg Phase; HLS 2.5" 7,622.0 7,643.0 6,118.3 6,134.4 UNIT B, 1A-25 1/5/1992 4.0 APERF 180 deg Phase; HLS 2.5" 7,776.0 7,783.0 6,234.4 6,239.6 A-5, 1A-25 6/11/1991 4.0 IPERF 180 deg Phase; HLS 2.5" TT 7,797.0 7,842.0 6,249.9 6,282.7 A-4, 1A-25 6/11/1991 4.0 IPERF 180 deg Phase; HLS 2.5" TT Cement Squeezes Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Des Com Pump Start Date 7,759.0 7,798.0 6,221.8 6,250.6 Cement Plug 8/24/2021 Notes: General & Safety End Date Annotation 8/4/2010 NOTE: View Schematic w/ Alaska Schematic9.0 1A-25, 11/19/2021 8:01:33 AM Vertical schematic (actual) Liner; 7,429.4-11,033.0 LINER TOP; 7,429.0 PRODUCTION; 1,278.1-8,093.3 IPERF; 7,797.0-7,842.0 IPERF; 7,776.0-7,783.0 Cement Plug; 7,759.0 ftKB APERF; 7,622.0-7,643.0 APERF; 7,596.0-7,618.0 WHIPSTOCK; 7,596.0 APERF; 7,584.0-7,596.0 APERF; 7,576.0-7,584.0 NIPPLE; 7,458.6 PACKOFF; 7,419.0 PACKER; 7,360.9 NIPPLE; 7,325.1 PACKER; 7,272.3 GAS LIFT; 7,185.6 GAS LIFT; 6,596.9 GAS LIFT; 5,760.5 SURFACE; 35.0-4,641.1 GAS LIFT; 4,571.6 GAS LIFT; 2,982.1 PRODUCTION TIE-BACK; 35.0- 1,278.1 NIPPLE; 488.0 CONDUCTOR; 36.0-80.0 Hanger; 31.0 KUP PROD 1A-25 ... WELLNAME WELLBORE1A-25 ! "# $%&' &( &( )( " &'! * ) * ! + & &'" %( ! ,# &'! - &(+# .%'! - +#$% ',+#)&'! - % - +# .%'! - + % # % , &. + *+ *+ *+ *+ *+ & # )&'! &. &) + % )& % )) % .. % & + + + ! &$ )&'! " + + $ ' % & , !,& .& / 0 1 . %' % %'! 1 %' && &.( , # .%'! -# %)'! , # %)%'! , )& # %)%'! . % !!# $ .! &)'! .%'! / " .( %( %)(! * $ %' %'! * ! $ %' ! %' ! 1 * ) $ % % )' %)%' 2. $ * 2.& " %) ! 2 '* 2 % ) $' %$$ 3456789: ;<<=>?8@5A>=748B6 Page 1/11 1A-25 Report Printed: 11/17/2021 Operations Summary (with Timelog Depths) Job: DRILLING SIDETRACK Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 10/17/2021 00:00 10/17/2021 04:00 4.00 MIRU, MOVE RURD P *** Rig Released @ Midnight from 1B- 10 ***. Continue to work RD checklist, call for fuel for halfway house, load out KDTH trucks. 0.0 0.0 10/17/2021 04:00 10/17/2021 05:00 1.00 MIRU, MOVE MOB P Trucks on location, PJSM w/crews, discuss communication, spotters, and walkarounds. Spot sows, weighted sows, off load dozer. 0.0 0.0 10/17/2021 05:00 10/17/2021 05:30 0.50 MIRU, MOVE MOB P Jack service & sow up. 0.0 0.0 10/17/2021 05:30 10/17/2021 06:00 0.50 MIRU, MOVE MOB P Pull service away from Sub, spot on pad in queue to head out. 0.0 0.0 10/17/2021 06:00 10/17/2021 06:30 0.50 MIRU, MOVE MOB P Drop sow from service, jeep up, sow up, attach weighted sow. 0.0 0.0 10/17/2021 06:30 10/17/2021 06:42 0.20 MIRU, MOVE MOB P Crew C/O, walka round, jack sub & sow up. 0.0 0.0 10/17/2021 06:42 10/17/2021 07:06 0.40 MIRU, MOVE MOB P Pull sub away from 1B-10, spot on pad in que to head out. 0.0 0.0 10/17/2021 07:06 10/17/2021 07:42 0.60 MIRU, MOVE MOB P Jeep up sub. Final walk arounds of convoy, load up crews, notify security / field. 0.0 0.0 10/17/2021 07:42 10/17/2021 08:30 0.80 MIRU, MOVE MOB P Move service followed by sub from 1B- 10 ~.6 miles to 1A-25 pad. 0.0 0.0 10/17/2021 08:30 10/17/2021 09:00 0.50 MIRU, MOVE MOB P On pad, drop weighted sows, sows and jeeps, re-sow sub. 0.0 0.0 10/17/2021 09:00 10/17/2021 09:42 0.70 MIRU, MOVE MOB P Swap out adapter, set herculite cellar pit liner square up Sub. 0.0 0.0 10/17/2021 09:42 10/17/2021 10:00 0.30 MIRU, MOVE MOB P Back Sub over 1A-25. 0.0 0.0 10/17/2021 10:00 10/17/2021 10:30 0.50 MIRU, MOVE MOB P Set matts under sub 0.0 0.0 10/17/2021 10:30 10/17/2021 10:42 0.20 MIRU, MOVE MOB P Take sub off jacks, de sow. 0.0 0.0 10/17/2021 10:42 10/17/2021 11:12 0.50 MIRU, MOVE MOB P Sow up, pull service to end of pad, back sevice to sub and spot while setting inside mats. 0.0 0.0 10/17/2021 11:12 10/17/2021 11:24 0.20 MIRU, MOVE MOB P Set outside mats under service mod 0.0 0.0 10/17/2021 11:24 10/17/2021 11:36 0.20 MIRU, MOVE MOB P Take service side off jacks, de sow. 0.0 0.0 10/17/2021 11:36 10/17/2021 14:00 2.40 MIRU, WHDBOP RURD P RU CDR3-AC to the well. Set BOP stack ***Rig accept 14:00 *** 0.0 0.0 10/17/2021 14:00 10/17/2021 19:30 5.50 MIRU, WHDBOP RURD P Continue to folow rig up checklist. Remove old choke and kill lines, replace with new hoses, MU transducers, install new gauge on IA 0.0 0.0 10/17/2021 19:30 10/18/2021 00:00 4.50 MIRU, WHDBOP RURD P Connect interconnect, remove inner reel iron, remove counter, lowered levelwind centered up and secured stack, dressed down hole end of coil for grapple install 0.0 0.0 10/18/2021 00:00 10/18/2021 01:00 1.00 MIRU, WHDBOP RURD P Finish removing inner reel iron and bulkhead, replace all 2" 1502 hardline gaskets 0.0 0.0 10/18/2021 01:00 10/18/2021 03:00 2.00 MIRU, WHDBOP RURD P Install grapple, PJSM for unstabbing coil. 0.0 0.0 10/18/2021 03:00 10/18/2021 04:00 1.00 MIRU, WHDBOP RURD P Unstab coil 0.0 0.0 10/18/2021 04:00 10/18/2021 06:00 2.00 MIRU, WHDBOP RURD P Set old storage reel on Sow, pick and hang new string in saddles 0.0 0.0 Rig: NABORS CDR3-AC RIG RELEASE DATE 10/31/2021 Page 2/11 1A-25 Report Printed: 11/17/2021 Operations Summary (with Timelog Depths) Job: DRILLING SIDETRACK Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 10/18/2021 06:00 10/18/2021 07:30 1.50 MIRU, WHDBOP RURD P Shim reel and install saddle clamps / bolster. 0.0 0.0 10/18/2021 07:30 10/18/2021 12:00 4.50 MIRU, WHDBOP RURD P Prep coil for internal grapple. Change out stripper brass and restring stabbing cable. Install reel house duck ponds. Stage hoses for reverse circulation. Install BOP risers and collect RKB's. Change out all riser 7" otis O-rings. Prepare for pull test on Internal grapple. 0.0 0.0 10/18/2021 12:00 10/18/2021 16:00 4.00 MIRU, WHDBOP RURD P PJSM, pull test grapple and re torque internal grapple. Remove shipping chains and stab coil through injector and stripper. Rig down stabbing equipment. Make up 2" 1502 HP hoses to managed pressure manifold for recirculation. Spot check torques in all connection in the cellar ( BOPs and choke and kill line) 0.0 0.0 10/18/2021 16:00 10/18/2021 18:00 2.00 MIRU, WHDBOP RURD P Add 10 gal of MetOH to stack, stab injector. Load coil backwards with meth spear and seawater taking returns via the managed pressure manifold to the shaker. Crew change 0.0 0.0 10/18/2021 18:00 10/18/2021 20:00 2.00 MIRU, WHDBOP RURD P Ramp pump rate through oil three times, hear wire move. Shut down bleed down. Find wire at managed pressure manifold. Break down hoses. Rig up inner reel iron and high pressure bulk head. 0.0 0.0 10/19/2021 00:00 10/19/2021 03:30 3.50 MIRU, WHDBOP RURD P Cut to find e-line, install/pull test CTC 35k, sim-ops prep for BOP test, service all valves after pumping N2, secure cellar, scaffolding in way of SSV, jack up and safe out scaffolding 0.0 0.0 10/19/2021 03:30 10/19/2021 04:45 1.25 MIRU, WHDBOP RURD P MU BHI upper quick, re-test e-line (good test), PT 4k (good test) 0.0 0.0 10/19/2021 04:45 10/19/2021 05:15 0.50 MIRU, WHDBOP RURD P Stab INJH, line up and bring mud pump #2 online, jet stack @ 2.0 bpm/3,860 psi, (45 bbls) 0.0 0.0 10/19/2021 05:15 10/19/2021 06:45 1.50 MIRU, WHDBOP RURD P Blow down, Unstab INJH, MU & bore- scope BOPE. 0.0 0.0 10/19/2021 06:45 10/19/2021 09:30 2.75 MIRU, WHDBOP RURD P Finish greasing valves R1 & R3, LD QTS and installed Bleeder on C4, 0.0 0.0 10/19/2021 09:30 10/19/2021 12:00 2.50 MIRU, WHDBOP BHAH P Test PDL's TT line, Install floats in upper quick connect. Make up BHA 1 Window milling BHA with 1° motor, 2.80 DSM, 2.79 swtring reamer., Load into ODS PDL 0.0 0.0 10/19/2021 12:00 10/19/2021 19:30 7.50 MIRU, WHDBOP BOPE P Perform shell test 4,000 psi/250 psi (good test), perform initial BOP test, witness waived by AOGCC (Lou Laubenstein), 4,000 psi high / 2,500 psi Annular. 0.0 0.0 10/19/2021 19:30 10/19/2021 21:00 1.50 MIRU, WHDBOP BOPE P Well Control choke C not holding any back pressure. Pull apart choke. Seat and needle look good. Recalibrate choke. Still not holding back pressure. Out of ten hour test window. Continue trouble shooting choke 0.0 0.0 10/19/2021 21:00 10/19/2021 22:30 1.50 MIRU, WHDBOP BHAH P PU/MU/Pressure deploy, Milling assembly BHA #1 with 1.0° fixed bend motor, 2.80" window mill and 2.79 sting reamer 0.0 0.0 10/19/2021 22:30 10/20/2021 00:00 1.50 MIRU, WHDBOP BHAH T Unable to get test on choke C. Stand by for parts 0.0 0.0 Rig: NABORS CDR3-AC RIG RELEASE DATE 10/31/2021 Page 3/11 1A-25 Report Printed: 11/17/2021 Operations Summary (with Timelog Depths) Job: DRILLING SIDETRACK Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 10/20/2021 00:00 10/20/2021 02:00 2.00 MIRU, WHDBOP BOPE T Trouble shoot repair choke C. Seat found abraided upon removal. Replace seat and test. Good 0.0 0.0 10/20/2021 02:00 10/20/2021 04:36 2.60 PROD1, WHPST WPST P PJSM, Run pre deploy valve check list. Make up mill, string reamer, and pup. Place in well. Make up coiltrak to motor. Surface test tool - Good. Strip on well make up lubricator. PT QTS to 4000 PSI. Open BOP. Tag up. Restart MWD computers 0.0 0.0 10/20/2021 04:36 10/20/2021 06:48 2.20 PROD1, WHPST WPST P Trip in well, EDC open pumping 1 BPM, switch to milling fluid 0.0 7,490.0 10/20/2021 06:48 10/20/2021 07:06 0.30 PROD1, WHPST DLOG P Log K1 for depth control minus 4.0' 7,490.0 7,519.0 10/20/2021 07:06 10/20/2021 08:06 1.00 PROD1, WHPST WPST P Continue displacing well to milling fluid, shut down pumps when muds at surface, obtain static BHP *** 11.7 ppg **** 7,519.0 7,638.0 10/20/2021 08:06 10/20/2021 09:36 1.50 PROD1, WHPST DLOG T RIH, tag pinch point, no wedge found, pull back up hole, log K1 again to confirm depth control minus 1', discuss with engineering team, desicion to RBIH to 7,700', no tag 7,638.0 7,700.0 10/20/2021 09:36 10/20/2021 10:48 1.20 PROD1, WHPST WPST T Open EDC, POOH 7,700.0 1,831.5 10/20/2021 10:48 10/20/2021 12:06 1.30 PROD1, WHPST WPST T Lost hydraulic pressure to the INJH, back up and running, continue OOH 1,831.5 1,831.5 10/20/2021 12:06 10/20/2021 13:24 1.30 PROD1, WHPST WPST T PJSM, PUD milling assembly BHA #1 0.0 0.0 10/20/2021 13:24 10/20/2021 14:24 1.00 PROD1, WHPST WPST T Perform Rig maint/service Standby for NS wedge 0.0 0.0 10/20/2021 14:24 10/20/2021 14:39 0.25 PROD1, WHPST WPST T NS Wedge on location load into rig and bring to the rig floor, find high side and place mark for picking up tools 0.0 0.0 10/20/2021 14:39 10/20/2021 16:27 1.80 PROD1, WHPST WPST T PD NS 3.5"x7" High Expansion Wedge (19.83') BHA #2 0.0 0.0 10/20/2021 16:27 10/20/2021 16:33 0.10 PROD1, WHPST WPST T Tag up, reset counters to zero 0.0 73.1 10/20/2021 16:33 10/20/2021 18:45 2.20 PROD1, WHPST WPST T RIH w/BHA #2 73.1 7,505.0 10/20/2021 18:45 10/20/2021 18:51 0.10 PROD1, WHPST WPST T 7490', Start gamma tie in to 7505 Log K1 for depth control -8' correction, PUW=29K 7,505.0 7,575.0 10/20/2021 18:51 10/20/2021 19:09 0.30 PROD1, WHPST WPST T Continue into set depth @ 7607.78 bit depth, Orintation @ 0° HS. Close EDC. Bring pumps on .5. Hesatate @ 1500 psi, 2000psi, 2500psi, 3000psi. Go to 4000 psi. Setting tool shifted @ 3800psi. Sety down 5K, PUW=29K 7,575.0 7,607.7 10/20/2021 19:09 10/20/2021 20:39 1.50 PROD1, WHPST WPST T Pick up off whipstock, PUW=29K. PUH 30 feet. Open EDC. POOH 7,607.0 7,607.0 10/20/2021 20:39 10/20/2021 23:00 2.35 PROD1, WHPST WPST T Tag up, space out. PJSM PUD BHA #2 whipstock setting tools. No iregularities with tool. PJSM PD BHA #3 to mill window. Surface test good. Strip on well 7,607.0 77.1 10/20/2021 23:00 10/21/2021 00:00 1.00 PROD1, WHPST WPST T Tag up. Trip in well, EDC open, min rate on milling fluid 77.1 7,500.0 10/21/2021 00:00 10/21/2021 00:00 0.00 PROD1, WHPST WPST T Tripping in, Midnight depth 7500' 7,500.0 7,500.0 10/21/2021 00:00 10/21/2021 00:24 0.40 PROD1, WHPST WPST T Continue tripping in, Min rate, EDC open 7,500.0 7,490.0 10/21/2021 00:24 10/21/2021 00:42 0.30 PROD1, WHPST WPST T Log Gamma tie into K1 marker for -8.5' correction. Close EDC, PUW=30K 7,490.0 7,516.0 Rig: NABORS CDR3-AC RIG RELEASE DATE 10/31/2021 Page 4/11 1A-25 Report Printed: 11/17/2021 Operations Summary (with Timelog Depths) Job: DRILLING SIDETRACK Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 10/21/2021 00:42 10/21/2021 00:54 0.20 PROD1, WHPST WPST T Continue in, dry tag pinch point @ 7596', PUW=30K. PUH to 9585 7,516.0 7,585.0 10/21/2021 00:54 10/21/2021 01:06 0.20 PROD1, WHPST WPST P Bring pump online 1.7 BPM @ 3480 PSI, WHP=458. Trip in to mill 7,585.0 7,596.5 10/21/2021 01:06 10/21/2021 05:06 4.00 PROD1, WHPST WPST P 7596.5. See motor work and DHWOB. Mill window per procedure / Northern Solutions rep OBM, 1.7 bpm @ 3,468 psi, start time milling 7,596.5 7,601.0 10/21/2021 05:06 10/21/2021 06:06 1.00 PROD1, WHPST WPST P Drilling rat hole 1.7 bpm/3,757 psi 7,601.0 7,616.0 10/21/2021 06:06 10/21/2021 07:06 1.00 PROD1, WHPST WPST P Ream window, ADTF, 30° ROHS, 30° ROHS, and 180°, PUH to above window, pump 10x10 sweep 7,616.0 7,573.0 10/21/2021 07:06 10/21/2021 07:24 0.30 PROD1, WHPST WPST P Dry drift window exit 7,573' - 7,616' 7,573.0 7,616.0 10/21/2021 07:24 10/21/2021 08:24 1.00 PROD1, WHPST WPST P PUH slowly waiting on sweep to come around 7,616.0 7,578.0 10/21/2021 08:24 10/21/2021 09:00 0.60 PROD1, WHPST WPST P Obtain stattic above window 11.75 ppg 7,578.0 7,578.0 10/21/2021 09:00 10/21/2021 10:30 1.50 PROD1, WHPST WPST P POOH w/open EDC 7,578.0 77.2 10/21/2021 10:30 10/21/2021 12:00 1.50 PROD1, WHPST WPST P Tag up at surface, space out, PJSM, PUD milling assembly 77.2 0.0 10/21/2021 12:00 10/21/2021 13:15 1.25 PROD1, WHPST WPST P LD tools in catwalk and clear RF Gauge Mills - WIndow Mill 2.79 no-go, String Reamer 2.79 no-go 0.0 0.0 10/21/2021 13:15 10/21/2021 14:00 0.75 PROD1, WHPST SVRG P Work on hydraulics, service rig, clean counter, inspect INJH, 0.0 0.0 10/21/2021 14:00 10/21/2021 15:30 1.50 PROD1, DRILL PULD P PJSM, PD Build Assembly BHA #4 0.0 72.2 10/21/2021 15:30 10/21/2021 16:48 1.30 PROD1, DRILL TRIP P Tag up, reset counter depths, RIH holding 11.9 ppg MP 72.2 7,475.0 10/21/2021 16:48 10/21/2021 17:06 0.30 PROD1, DRILL DLOG P Log K1 for depth control -9.0' Close EDC 7,475.0 7,505.0 10/21/2021 17:06 10/21/2021 18:00 0.90 PROD1, DRILL TRIP P RIH, stack out in window, PUH roll pump to index bit. Try different speeds and TF's up to 10Left and right. Try rolling trough window at min rate HS. Stacking in same place. Clean pick ups with no negative WOB. Consult town. 7,505.0 7,600.0 10/21/2021 18:00 10/21/2021 18:18 0.30 PROD1, DRILL TRIP P Continue to work through window. Pass through clean at 20L no pumps 7,600.0 7,616.0 10/21/2021 18:18 10/21/2021 19:42 1.40 PROD1, DRILL DRLG P 7616', DSrill ahead in build section. 1.7 BPM @ 3500 PSI FS, BHP=3760 7,616.0 7,681.0 10/21/2021 19:42 10/21/2021 19:48 0.10 PROD1, DRILL DRLG P PUH, PUW=29K. Bring pump rate to 1.85 BPM @ 3800 PSI. RIW=13.5K. Near bit indicates close to 47° DLS 7,681.0 7,681.0 10/21/2021 19:48 10/21/2021 22:30 2.70 PROD1, DRILL DRLG P 7681', Drill ahead 7,681.0 7,770.0 10/21/2021 22:30 10/21/2021 22:48 0.30 PROD1, DRILL WPRT P Wiper trip to window, PUW=34K. W/sweeps, Turn around @ 7620. Clean trip up and down 7,770.0 7,770.0 10/21/2021 22:48 10/22/2021 00:00 1.20 PROD1, DRILL DRLG P 7770', Drill ahead, 1.8 BPM @ 3910 BHP=3863, WHP=420 PSI Midnight depth 7813' in build section 7,770.0 7,813.0 10/22/2021 00:00 10/22/2021 03:00 3.00 PROD1, DRILL DRLG P 7813', Drill ahead, 1.8 BPM @ 3910 BHP=3863, WHP=420 PSI 7,813.0 7,970.0 10/22/2021 03:00 10/22/2021 03:24 0.40 PROD1, DRILL WPRT P 7970', Call end of build, PUW=33KK, Slight bobble coming up throug window. Slow to 5 FPM @ 1.9 BPM Jet 7 inch. 7,970.0 7,480.0 Rig: NABORS CDR3-AC RIG RELEASE DATE 10/31/2021 Page 5/11 1A-25 Report Printed: 11/17/2021 Operations Summary (with Timelog Depths) Job: DRILLING SIDETRACK Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 10/22/2021 03:24 10/22/2021 03:30 0.10 PROD1, DRILL WPRT P 7480', Stop and open EDC, Comtinue up hole, RIH to log K1, Pumping 2.4 BPM 7,480.0 7,470.0 10/22/2021 03:30 10/22/2021 03:54 0.40 PROD1, DRILL WPRT P 7470, Log K1 for +2' correction. Trip in to tie in RA / Jet 7". 7515 log RA marker. Clean pass through window at HS TF. Log RA @ 7601, TOWS-7594, TOW=7597, BOW=7601 7,470.0 7,630.0 10/22/2021 03:54 10/22/2021 05:18 1.40 PROD1, DRILL TRIP P Trip out, Jet 7" 10 FPM 2.2 BPM, PUW=34K 7,630.0 62.0 10/22/2021 05:18 10/22/2021 06:18 1.00 PROD1, DRILL BHAH P On surface, PUD BHA #4, PD BHA #5 lateral drilling BHA 62.0 0.0 10/22/2021 06:18 10/22/2021 07:36 1.30 PROD1, DRILL BHAH P Pressure deploy latirel assemby bha#5 0.0 78.3 10/22/2021 07:36 10/22/2021 07:48 0.20 PROD1, DRILL TRIP P Tag up re set counters & rih 78.3 7,480.0 10/22/2021 07:48 10/22/2021 08:06 0.30 PROD1, DRILL DLOG P Log k1 -10.0' 27k puw riw 13.6 k 7,480.0 7,511.0 10/22/2021 08:06 10/22/2021 08:51 0.75 PROD1, DRILL TRIP P Continue in hole though window 0° HS clean with no pumps Send new mud down hole 7,511.0 7,971.0 10/22/2021 08:51 10/22/2021 10:39 1.80 PROD1, DRILL DDRL P OBD, FS 4650 psi, drill ahead @ 70 fph 7,971.0 8,040.0 10/22/2021 10:39 10/22/2021 10:57 0.30 PROD1, DRILL WPRT P Mud all the way around, PUH PUW 30k FS 4,256 psi, AP 3,870, IA 636, OA 6 RBIH to drill 8,040.0 8,040.0 10/22/2021 10:57 10/22/2021 12:09 1.20 PROD1, DRILL DDRL P BOBD, 1.89 bpm/4,256 psi, drilling ahead 80 fph 8,040.0 8,170.0 10/22/2021 12:09 10/22/2021 12:21 0.20 PROD1, DRILL DDRL P PUH PUW 30 k RBIH Drilling ahead 8,170.0 8,170.0 10/22/2021 12:21 10/22/2021 13:45 1.40 PROD1, DRILL DDRL P BOBD 1.85 bpm / 4783 Drilling ahead 88 fpm 8,170.0 8,320.0 10/22/2021 13:45 10/22/2021 14:21 0.60 PROD1, DRILL WPRT P Wiper trip from 8320' toTT PUW 33k Perform Jog to the end of build 8,320.0 7,594.0 10/22/2021 14:21 10/22/2021 14:51 0.50 PROD1, DRILL WPRT P Open ECD pump max max rate 2.5 BPM 4000 PSI 7,594.0 7,506.0 10/22/2021 14:51 10/22/2021 15:03 0.20 PROD1, DRILL WPRT P Logging K 1 marker @ 7581' 7,506.0 7,506.0 10/22/2021 15:03 10/22/2021 15:09 0.10 PROD1, DRILL WPRT P Pump bottoms up 7,506.0 7,520.0 10/22/2021 15:09 10/22/2021 15:30 0.35 PROD1, DRILL WPRT P Down on pump close ECD RBIH pumping .5 bpm @ 2100 psi 8080' -8120' starting to see some stacking 7,520.0 7,520.0 10/22/2021 15:30 10/22/2021 18:30 3.00 PROD1, DRILL DDRL P BOBD Free spin 4405 @ 2 bpm, 8,320.0 8,504.0 10/22/2021 18:30 10/22/2021 18:36 0.10 PROD1, DRILL WPRT P BHA wiper, PUW=38K 8,504.0 8,504.0 10/22/2021 18:36 10/22/2021 19:54 1.30 PROD1, DRILL DRLG P Drill, 1.81 BPM @ 4250 PSI FS, BHP=3880 8,504.0 8,525.0 10/22/2021 19:54 10/22/2021 20:06 0.20 PROD1, DRILL WPRT P Mini wiper, 100' stacking weight 8,525.0 8,525.0 10/22/2021 20:06 10/22/2021 21:06 1.00 PROD1, DRILL DRLG P Drill, 1.82 BPM @ 4250 PSI FS, BHP=3880 8,525.0 8,720.0 10/22/2021 21:06 10/22/2021 22:06 1.00 PROD1, DRILL WPRT P 800' wiper trip #1. PUW=35K RBIH clean through 8050 to 8150 full pump rate. 40 FPM 8,720.0 8,720.0 10/22/2021 22:06 10/22/2021 23:06 1.00 PROD1, DRILL DRLG P Drill ahead, 1.88 BPM @ 4400 PSI FS, BHP=3900 8,720.0 8,823.0 10/22/2021 23:06 10/22/2021 23:12 0.10 PROD1, DRILL WPRT P BHP wiper, PUW=34K 8,823.0 8,823.0 Rig: NABORS CDR3-AC RIG RELEASE DATE 10/31/2021 Page 6/11 1A-25 Report Printed: 11/17/2021 Operations Summary (with Timelog Depths) Job: DRILLING SIDETRACK Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 10/22/2021 23:12 10/23/2021 00:00 0.80 PROD1, DRILL DRLG P Drill Ahead, 1.88 BPM @ 4450 PSI FS, BHP=3900 Midnight depth 8924' 8,823.0 8,924.0 10/23/2021 00:00 10/23/2021 02:24 2.40 PROD1, DRILL WPRT P BHA wiper 90181' 8,924.0 9,181.0 10/23/2021 02:24 10/23/2021 02:36 0.20 PROD1, DRILL DDRL P BOBD @ 9181' 9,181.0 9,375.0 10/23/2021 02:36 10/23/2021 06:15 3.65 PROD1, DRILL WPRT At from 9375' to TT PUW 35 K 9,375.0 7,970.0 10/23/2021 06:15 10/23/2021 07:30 1.25 PROD1, DRILL WPRT P Perform jog in the build section 7,970.0 7,550.0 10/23/2021 07:30 10/23/2021 08:00 0.50 PROD1, DRILL WPRT P Perform jog in 7" @ 7550 open ECD pump 2.8 bpm PUH to TT 7,550.0 7,550.0 10/23/2021 08:00 10/23/2021 09:00 1.00 PROD1, DRILL WPRT P Perform tie in log @ K1 +4' correction close ECD 7,480.0 7,570.0 10/23/2021 09:00 10/23/2021 09:06 0.10 PROD1, DRILL WPRT P RBIH pumps off run thru window @7745' seen a bobble continue in hole 7,570.0 7,570.0 10/23/2021 09:06 10/23/2021 10:12 1.10 PROD1, DRILL DDRL P BOBD @ 9374' 9,374.0 10/23/2021 00:00 10/23/2021 01:42 1.70 PROD1, DRILL DRLG P Drill Ahead, 1.88 BPM @ 4450 PSI FS, BHP=3900 8,924.0 9,120.0 10/23/2021 01:42 10/23/2021 02:24 0.70 PROD1, DRILL WPRT P Wiper trip 800' #2, PUW= 39K, Clean trip up and down 9,120.0 9,120.0 10/23/2021 02:24 10/23/2021 02:48 0.40 PROD1, DRILL DRLG P Drill Ahead, 1.88 BPM @ 4565PSI FS, BHP=3950 9,120.0 9,153.0 10/23/2021 02:48 10/23/2021 02:54 0.10 PROD1, DRILL WPRT P BHA Wiper, PUW=45K 9,153.0 9,153.0 10/23/2021 02:54 10/23/2021 02:54 PROD1, DRILL DRLG P Drill, 1.88 BPM @ 4550 PSI FS, BHP=3960 9,153.0 9,375.0 10/23/2021 02:54 10/23/2021 06:12 3.30 PROD1, DRILL WPRT P Wiper trip to 7.00". Jog the build area. Jog the 7.00" 9,375.0 7,552.0 10/23/2021 06:12 10/23/2021 08:12 2.00 PROD1, DRILL WPRT P Open ECD bring pump back online 2.8 bpm 7,552.0 7,252.0 10/23/2021 08:12 10/23/2021 08:57 0.75 PROD1, DRILL WPRT P Jet the 7.00" 7,552.0 7,480.0 10/23/2021 08:57 10/23/2021 09:03 0.10 PROD1, DRILL DLOG P Gamma ray tie in. Plus 4 feet correction RBIH 7,480.0 7,480.0 10/23/2021 09:03 10/23/2021 09:09 0.10 PROD1, DRILL WPRT P Close ECD RBIH run thru window with pump down continue in hole 7,480.0 4,780.0 10/23/2021 09:09 10/23/2021 10:24 1.25 PROD1, DRILL DRLG P BOBD 9,377.0 9,499.0 10/23/2021 10:24 10/23/2021 12:24 2.00 PROD1, DRILL WPRT P BHA wiper 9,499.0 9,499.0 10/23/2021 12:24 10/23/2021 12:30 0.10 PROD1, DRILL DRLG P BOBD free spin 4400 psi @ 1.8 bpm Hold 95.0 9,499.0 9,574.0 10/23/2021 12:30 10/23/2021 14:30 2.00 PROD1, DRILL WPRT P At 9574' wiper trip to 9076' RBIH 9,574.0 9,574.0 10/23/2021 14:30 10/23/2021 16:30 2.00 PROD1, DRILL DRLG P BOBD free spin 4475 @ 1.8 bpm Bleed IA pressure from 800 to 500 9,574.0 9,628.0 10/23/2021 16:30 10/23/2021 16:48 0.30 PROD1, DRILL WPRT P BHA Wiper, PUW=35K 9,628.0 9,628.0 10/23/2021 16:48 10/23/2021 20:00 3.20 PROD1, DRILL DDRL P Drill, 1.81 BPM @ 4691 PSI FS, BHA=3943 9,628.0 9,745.0 10/23/2021 20:00 10/23/2021 20:18 0.30 PROD1, DRILL WPRT P Stacking. PUH to reset. Clean pick up @ 34K. Unable to RBIH. Pull 500' wiper. Clean trip up and down. 9,745.0 9,745.0 10/23/2021 20:18 10/23/2021 23:18 3.00 PROD1, DRILL DRLG P Drill, 1.81 BPM @ 4610 PSI FS, BHP=4010, 9,745.0 9,798.0 Rig: NABORS CDR3-AC RIG RELEASE DATE 10/31/2021 Page 7/11 1A-25 Report Printed: 11/17/2021 Operations Summary (with Timelog Depths) Job: DRILLING SIDETRACK Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 10/23/2021 23:18 10/23/2021 23:54 0.60 PROD1, DRILL DRLG P Start mnew mud down CT, String weight -4K, DHWOB=600LBS System 1 out @ 1812' 9,798.0 9,810.0 10/23/2021 23:54 10/24/2021 00:00 0.10 PROD1, DRILL WPRT P Wiper trip to TT chasing new mud. PUW=40K Midnight depth 9500 9,810.0 9,500.0 10/24/2021 00:00 10/24/2021 02:54 2.90 PROD1, DRILL WPRT P Continue wiper trip to TT. Over pull @ 7740'. Jog back in hole Work up through 7740. Clean up through windod. Jet 7". Open EDC jet recip 7" again. Log K1 for +3.5. Set down in window tripping in. Roll TF to 20L Clean. Saw 7740 . PUH and work through. Bobble @ 9742. Stop and continue through 9,500.0 9,810.0 10/24/2021 02:54 10/24/2021 06:24 3.50 PROD1, DRILL DRLG P 9810', Drill, 1.8 BPM @ 4350 PSI FS. BHP=3975. String weight -4.5, DHWOB=1.4 short wiper 9,810.0 9,810.0 10/24/2021 06:24 10/24/2021 06:30 0.10 PROD1, DRILL DRLG P 9932' back onn bottom drilling 9,810.0 9,932.0 10/24/2021 06:30 10/24/2021 07:30 1.00 PROD1, DRILL WPRT P Wiper trip 200' from 9996' 9,932.0 9,969.0 10/24/2021 07:30 10/24/2021 08:30 1.00 PROD1, DRILL WPRT P 9,969', wiper up hole to 9,500' 9,969.0 9,969.0 10/24/2021 08:30 10/24/2021 09:00 0.50 PROD1, DRILL DDRL P BOBD, 1.7 bpm/4,256 psi, BHP 3,936 psi, IA 370, OA 12 9,969.0 9,969.0 10/24/2021 09:00 10/24/2021 09:15 0.25 PROD1, DRILL WPRT P Wiper trip to bottom of build section BHP 4,000 psi IA 288 oa 12 9,969.0 8,050.0 10/24/2021 09:15 10/24/2021 11:15 2.00 PROD1, DRILL WPRT P At 8050 at bottom of build RBIH 8,050.0 8,050.0 10/24/2021 11:15 10/24/2021 12:15 1.00 PROD1, DRILL DDRL P BOBD @ 9969' free spin 4358 psi @1.8 bpm IA 401 OA 11 9,969.0 10,141.0 10/24/2021 12:15 10/24/2021 16:45 4.50 PROD1, DRILL WPRT P perform 299' wiper trrip PUW 35 K 10,141.0 9,950.0 10/24/2021 16:45 10/24/2021 17:09 0.40 PROD1, DRILL DDRL P BOBD @ 10141 10,141.0 10,153.0 10/24/2021 17:09 10/24/2021 19:15 2.10 PROD1, DRILL WPRT P PUH stacking, Struggle to get back on bottom. Pull 800' wiper, Initial PUW=33K 10,153.0 10,153.0 10/24/2021 19:15 10/24/2021 19:45 0.50 PROD1, DRILL DRLG P Drill, 1.81 BPM @ 4356 PSI FS, BHP=3954, String weight=-2K, DHWOB=.7K 10,153.0 10,169.0 10/24/2021 19:45 10/24/2021 22:21 2.60 PROD1, DRILL WPRT P Stacked out. PUH, PUW=40K. Unable to RBIH. Pump 10X10. Chase to TT. Jog below window 7640. Come up through window clean up to 7574. Open EDC recip 7" at max rate. 10,169.0 7,475.0 10/24/2021 22:21 10/24/2021 22:27 0.10 PROD1, DRILL DLOG P Log K1 for +7.5' correction 7,475.0 7,500.0 10/24/2021 22:27 10/24/2021 23:15 0.80 PROD1, DRILL WPRT P Continue wiper trip to bottom. Close EDC, Clean trip past window @ HS. 7740 Clear tripping in 7,500.0 8,200.0 10/24/2021 23:15 10/25/2021 00:00 0.75 PROD1, DRILL WPRT P Pump one showing VFD communication fault code tripping out pump. Trounle shoot pump. Tripped out multiple times. Power back up. Pump two seems stable. Are able to swap to back up pump one. RBIH to drill 8,200.0 8,300.0 10/25/2021 00:00 10/25/2021 01:18 1.30 PROD1, DRILL WPRT P Pump stabilized. Continue in to drill 8,300.0 10,172.0 10/25/2021 01:18 10/25/2021 01:42 0.40 PROD1, DRILL DRLG P Drill, 1.8 BPM @ 4512, BHP=4090, RIW=.6 off bottom, DHWOB=.92, CT Weight 2.1K 10,172.0 10,191.0 Rig: NABORS CDR3-AC RIG RELEASE DATE 10/31/2021 Page 8/11 1A-25 Report Printed: 11/17/2021 Operations Summary (with Timelog Depths) Job: DRILLING SIDETRACK Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 10/25/2021 01:42 10/25/2021 02:42 1.00 PROD1, DRILL WPRT P Stack out, PUH PUW=45K, Unable to turn aroun. Mix up Alpine beads in Hi viss, Pill pit #1, 1 LB/BBl, Pump 10 BBl pill. Continue to work to bottom 10,191.0 10,191.0 10/25/2021 02:42 10/25/2021 06:12 3.50 PROD1, DRILL DRLG P 2 BBls beads out, Bring rate up to 1.81 @ 4512 PSI FS, BHP=4135. 2 BBls beads out ROP ~100 FPH w/2K string weight. , Pump second 10 BBl pill @ 10,215 10,191.0 10,382.0 10/25/2021 06:12 10/25/2021 07:06 0.90 PROD1, DRILL WPRT P Styacking, Pull BHA Wiper, PUW=32k 10,305.0 10,305.0 10/25/2021 07:06 10/25/2021 08:48 1.70 PROD1, DRILL DRLG P PUH 30' PUW 40 KPicking up hole often to get it to slide in hole , Continue to drill 10,305.0 10,356.0 10/25/2021 08:48 10/25/2021 09:36 0.80 PROD1, DRILL WPRT Short wiper trip, PUW=40K, Struggle to get back on bottom 10,356.0 10,356.0 10/25/2021 09:36 10/25/2021 13:36 4.00 PROD1, DRILL DRLG P At 10411 pumped a 10 bbl pill of new mud and it seems to be working 10,356.0 10,477.0 10/25/2021 13:36 10/25/2021 16:54 3.30 PROD1, DRILL WPRT P Perfgorm a 800' wiper @ 1.8 bpm 4667 psi IA 498 OA 13 PUW 30 K 10,477.0 10,477.0 10/25/2021 16:54 10/25/2021 20:48 3.90 PROD1, DRILL DRLG P Drill, 1.52 BPM @ 3760 PSI FS, BHP=3965. Drilling on hard spot. Geo reports ankorite in sample pumped up from 10478 10,477.0 10,493.0 10/25/2021 20:48 10/25/2021 22:06 1.30 PROD1, DRILL WPRT P Lost pump, PUH, PUW=36K. Work pipe to get back to bottom. Pump beaded pill to get back on bottom 10,493.0 10,493.0 10/25/2021 22:06 10/26/2021 00:00 1.90 PROD1, DRILL DRLG P Drill, 1.63 BPM @ 3970 PSI FS, BHP=3976. Pumping beaded pills as needed for weight transfer. Midnight 10,559' 10,493.0 10,559.0 10/26/2021 00:00 10/26/2021 00:30 0.50 PROD1, DRILL DRLG P Drill, 1.63 BPM @ 3970 PSI FS, BHP=3976. Pumping beaded pills as needed for weight transfer. 10,559.0 10,575.0 10/26/2021 00:30 10/26/2021 00:36 0.10 PROD1, DRILL WPRT P Stacking out. PUW=42K. Pump Beaded pill, Work to bottom 10,575.0 10,575.0 10/26/2021 00:36 10/26/2021 02:36 2.00 PROD1, DRILL DRLG P Drill, 1.65 BPM @ 3950PSI FS, BHP=3975 10,575.0 10,595.0 10/26/2021 02:36 10/26/2021 02:42 0.10 PROD1, DRILL WPRT P Stacking, P/U and reset 10,595.0 10,595.0 10/26/2021 02:42 10/26/2021 08:27 5.75 PROD1, DRILL DRLG P Drill, 1.64 BPM @ 3950 PSI FS, BHP=4001 10,595.0 10,670.0 10/26/2021 08:27 10/26/2021 08:42 0.25 PROD1, DRILL DDRL P Broke thru something ROP increased 10,670.0 10,690.0 10/26/2021 08:42 10/26/2021 11:42 3.00 PROD1, DRILL WPRT P Perform wiper to TT POW 40 K pump press 4500 pis @1.8 BPM IA 531 OA 10 WHP 425 jog EOB 10,690.0 7,581.0 10/26/2021 11:42 10/26/2021 12:27 0.75 PROD1, DRILL WPRT P Started packing off @ 7740' RBIH came thru window clean pump a sweep and pump sweep to surface 7,581.0 7,558.0 10/26/2021 12:27 10/26/2021 14:27 2.00 PROD1, DRILL WPRT P Open ECD and recip 7"@ 3 bpm tie into K1+ 11' lots of shale on shaker pump another sweep close ECD will not close 7,558.0 7,559.0 10/26/2021 14:27 10/26/2021 16:12 1.75 PROD1, DRILL TRIP T POOH the ECD will not close 7,559.0 0.0 10/26/2021 16:12 10/26/2021 16:42 0.50 PROD1, DRILL PULD T At 500' hold PJSM for BHA swap 0.0 0.0 10/26/2021 16:42 10/26/2021 18:42 2.00 PROD1, DRILL PULD T At surface lay down BHA #5 Lateral drilliing assembly #1 .5 AKO xtreme motor / HCC 3D bit SN# A265234 0.0 0.0 10/26/2021 18:42 10/26/2021 19:42 1.00 PROD1, DRILL CLEN P Flush Beads from surface lines and rams for function test 0.0 0.0 Rig: NABORS CDR3-AC RIG RELEASE DATE 10/31/2021 Page 9/11 1A-25 Report Printed: 11/17/2021 Operations Summary (with Timelog Depths) Job: DRILLING SIDETRACK Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 10/26/2021 19:42 10/26/2021 20:12 0.50 PROD1, DRILL BOPE P Function test BOPE's, 0.0 0.0 10/26/2021 20:12 10/26/2021 22:12 2.00 PROD1, DRILL PULD T Pick up and Pressure Deploy BHA# 6 Lateral drilling assembly # 2 , .5 AKO xtreme motor W/ BH Dynamus (TX25207) SN# 5290676 0.0 0.0 10/26/2021 22:12 10/27/2021 00:00 1.80 PROD1, DRILL TRIP T RIH W/EDC open to 500', Close EDC pump 1.85 bpm 4568 psi Diff 975 agitator test good , RIH T/ 7475 tie in for -10 correction, 0.0 7,500.0 10/27/2021 00:00 10/27/2021 01:30 1.50 PROD1, DRILL TRIP P RIH clean pass through window , sat down @ 7667 due to orientation of the bha , pu and RIH to 7770 sat down 100 psi motor work popped through, RIH T/10690' no issues 7,500.0 10,690.0 10/27/2021 01:30 10/27/2021 02:30 1.00 PROD1, DRILL DRLG P Drill F/ 10690' T/ 10759' FREE SPIN = 1.8 BPM 4420 PSI DIFF 920 CT WT 1.5K WHP 401 PSI 12 PPG EQ @ WINDOW // DRILLING = 1.8 IN 1.8 OUT MW 8.65/8.75 CT WT 0 WOB .5 K 72 FPH 10,690.0 10,759.0 10/27/2021 02:30 10/27/2021 02:36 0.10 PROD1, DRILL WPRT P P/U ran out of push BHA wiper PU wt 42k 10,759.0 10,759.0 10/27/2021 02:36 10/27/2021 04:36 2.00 PROD1, DRILL DRLG P Drill F/ 10759' T/ 10841.00' FREE SPIN = 1.8 BPM 4420 PSI DIFF 920 CT WT 1.5K WHP 401 PSI 12 PPG EQ @ WINDOW // DRILLING = 1.8 IN 1.8 OUT MW 8.65/8.75 CTWT= 0 DHWOB= .5 K ROP=72 FPH 10,759.0 10,841.0 10/27/2021 04:36 10/27/2021 04:42 0.10 PROD1, DRILL WPRT P 100' Wiper continue with short wipers as needed 10,841.0 10,841.0 10/27/2021 04:42 10/27/2021 09:27 4.75 PROD1, DRILL TRIP P Town called TD pump a 10 x 10 sweep / sweep is out of bit POOH TD 11030' pump sweeps at EOB and jog 10,841.0 11,030.0 10/27/2021 09:27 10/27/2021 12:12 2.75 PROD1, DRILL TRIP P Pulled thru build section and window clean continue OOH 11,030.0 7,594.0 10/27/2021 12:12 10/27/2021 14:27 2.25 PROD1, DRILL TRIP P Tagged up at surface RBIH for tie in and get bottom hole pressure for kill wait mud and confirm TD 7,594.0 78.0 10/27/2021 14:27 10/27/2021 19:27 5.00 PROD1, DRILL TRIP P Tie into k1 marker -9.5' bottom hole press 3654 WHP 863 MD 7500' 5880.8 TVD @ sensor confirm well at 11.79 ( 12.0 KWF), RIH window clean @ HS, Run through build clean no set downs continue to bottom to confirm TD @ 11033' 78.0 11,033.0 10/27/2021 19:27 10/27/2021 20:00 0.55 PROD1, DRILL CIRC P Pump 12 ppg Liner running pill 2 ppb beads 1.5% Low Torque and 1.5% 776 to bit 11,033.0 11,033.0 10/27/2021 20:00 10/27/2021 23:15 3.25 PROD1, DRILL TRIP P POOH laying liner running pill to window , 12 ppg KWF to surface 11,033.0 102.0 10/27/2021 23:15 10/27/2021 23:45 0.50 PROD1, DRILL OWFF P Flow check well confirm no flow at surface, PJSM laying down bha 102.0 102.0 10/27/2021 23:45 10/28/2021 00:00 0.25 PROD1, DRILL PULD P Pop injector off the well, check coil for flat spots, Lay down BHA# 6 Lateral drilling assembly # 2 102.0 0.0 10/28/2021 00:00 10/28/2021 01:00 1.00 PROD1, DRILL PULD P Lay down BHA# 6 Lateral Drilling Assembly 2 0.0 0.0 10/28/2021 01:00 10/28/2021 04:45 3.75 COMPZ1, CASING PUTB P PJSM, Pick up and run 36 jts 2-3/8 stl liner w/ solid bullnose and QCLL Receptical- L80 // Total footage 1112.25' 0.0 1,112.3 10/28/2021 04:45 10/28/2021 05:00 0.25 COMPZ1, CASING PUTB P Rig down liner running equipment prep to pick up BHI BHA 1,112.3 1,156.0 Rig: NABORS CDR3-AC RIG RELEASE DATE 10/31/2021 Page 10/11 1A-25 Report Printed: 11/17/2021 Operations Summary (with Timelog Depths) Job: DRILLING SIDETRACK Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 10/28/2021 05:00 10/28/2021 06:20 1.34 COMPZ1, CASING TRIP P RIH w / liner run #1 1,158.0 11,028.7 10/28/2021 06:20 10/28/2021 10:07 3.78 COMPZ1, CASING TRIP P Liner run #1 is on bottom @ 11028.7' CTMD MWD is shorted out PUH PUW 30 k set back down pump off liner POOH fil hole down BS 11,028.7 7,572.0 10/28/2021 10:07 10/28/2021 11:30 1.38 COMPZ1, CASING TRIP P At 7572' park coil perform a no flow good no flo continue OOH 7,572.0 25.0 10/28/2021 11:30 10/28/2021 13:30 2.00 COMPZ1, CASING PUTB P At surfacehold a PJSM for laying down BHA perform no flow ck WHP 0 / IA 73 / OA 11 GOOD NO FLOW after laying down tools the wire pull out of the E-line head re-head 25.0 0.0 10/28/2021 13:30 10/28/2021 16:00 2.50 COMPZ1, CASING PUTB P PJSM for picking up 71 joints of solid liner rig up floor for running liner 0.0 0.0 10/28/2021 16:00 10/28/2021 21:00 5.00 COMPZ1, CASING PUTB P , pick up disolvable bullnose and make up to solid liner , Pick up 71 jts 2-3/8" stl solid liner 0.0 2,238.0 10/28/2021 21:00 10/28/2021 22:00 1.00 COMPZ1, CASING PULD P PJSM, Pick up Baker Hughes Coil track BHA, Knuckle, and QCLL 2,238.0 2,238.0 10/28/2021 22:00 10/28/2021 23:00 1.00 COMPZ1, CASING PULD T BHA would not read ANN/Bore Press when powered up, Swab BHA 2,238.0 2,238.0 10/28/2021 23:00 10/29/2021 00:00 1.00 COMPZ1, CASING TRIP P RIH with liner run # 1 Knuckle jt, NSAK GS spear, NSAK Permanent QCLL, 71 jts 2-3/8" 4.7# L-80 Solid Linter = 2189.66, 2-3/8" Dissolvable Bull Nose 2,238.0 7,400.0 10/29/2021 00:00 10/29/2021 03:30 3.50 COMPZ1, CASING TRIP P RIH with liner run 2 , tie into EOP flag - 16.72' correction, pu wt = 30k pass through the window clean , set down at 9719' work pipe worked past spot , pu wt 40 k up wt , latch into 1st liner run @ 9911.81, pu wt 50k, set down pump off liner , pick up to 7709' subtract liner from bit depth TOL =7728.73 7,400.0 9,911.0 10/29/2021 03:30 10/29/2021 05:00 1.50 COMPZ1, CASING TRIP P Trip out of hole 9,911.0 0.0 10/29/2021 05:00 10/29/2021 06:00 1.00 COMPZ1, CASING PULD P At surface hold PJSM pop off well L?D MWD tools set up to pump slack management cut 184' and found wire hand cut coil and re-head total pipe cut 190' PULL TEST CTC to 35 k PT to 3500 ps displace seawater out of coil with 12 ppg kill weigth mud 0.0 0.0 10/29/2021 06:00 10/29/2021 11:45 5.75 COMPZ1, CASING PUTB P Open swab fill well took1 bbl to fill well pop off well pick up liner run #3 crew change hold another PJSM 0.0 0.0 10/29/2021 11:45 10/29/2021 14:00 2.25 COMPZ1, CASING TRIP P Liner is in the well stab injector on well RIH Nabors is having computer issues 344.6 7,000.0 10/29/2021 14:00 10/29/2021 16:00 2.00 COMPZ1, CASING TRIP P Tie into HRV shale -10.5' correction 7,000.0 7,000.0 10/29/2021 16:00 10/29/2021 17:30 1.50 COMPZ1, CASING CIRC P Set down at 7725.9' PUH 40k Top of liner at 7424.3' Circ out kill weight mud with seawater freeze protect with diesel from 2500' 7,000.0 7,000.0 10/29/2021 17:30 10/29/2021 18:45 1.25 DEMOB, WHDBOP TRIP P POOH to 2500' for freeze protect of well 7,000.0 2,500.0 10/29/2021 18:45 10/29/2021 20:00 1.25 DEMOB, WHDBOP CIRC P Rig up Little Red, Little Red stuck on the pad 15 min to get them spotted up , pressure test to 4500 psi , fill coil with 30 bbls diesel, 2,500.0 2,500.0 10/29/2021 20:00 10/29/2021 21:30 1.50 DEMOB, WHDBOP TRIP P POOH laying in diesel for freeze protect F/ 2500' T/ Surface taking returns to tiger tank 2,500.0 0.0 Rig: NABORS CDR3-AC RIG RELEASE DATE 10/31/2021 Page 11/11 1A-25 Report Printed: 11/17/2021 Operations Summary (with Timelog Depths) Job: DRILLING SIDETRACK Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 10/29/2021 21:30 10/29/2021 23:15 1.75 DEMOB, WHDBOP PULD P Pressure Un-Deploy BHA # 9 Swell packer bha , Diesel in stack take returns to tiger tank , lay down 0.0 0.0 10/29/2021 23:15 10/30/2021 00:00 0.75 DEMOB, WHDBOP CTOP P Make up nozzle and flush stack and surface lines with sea water, flush to tiger tank Blow down surface lines 0.0 0.0 10/30/2021 00:00 10/30/2021 04:00 4.00 DEMOB, WHDBOP RURD P RD, MT pits and off load TT, remove transducers, nipple down stack, break down dike around cellar (3"x12"), secure cellar for pulling off well, blow down steam, drain line blown down, secure reel, INJH, and PDL's for transport, Load out rig equipment on KDTH trucks *** Rig Released @ 0400 on 10/30/2021***. Continue to work RD checklist, call for fuel for halfway house, load out KDTH trucks *** Rig Released @ 0400 on 10/30/2021 ***. 0.0 Rig: NABORS CDR3-AC RIG RELEASE DATE 10/31/2021 Originated: Delivered to:22-Oct-21Halliburton Alaska Oil and Gas Conservation Comm.Wireline & Perforating Attn.: Natural Resource TechnicianAttn: Fanny Haroun 333 West 7th Avenue, Suite 1006900 Arctic Blvd. Anchorage, Alaska 99501Anchorage, Alaska 99518Office: 907-275-2605FRS_ANC@halliburton.comThe technical data listed below is being submitted herewith. Please address any problems orconcerns to the attention of the sender aboveWELL NAME API # SERVICE ORDER # FIELD NAME JOB TYPE DATA TYPE LOGGING DATE PRINTS #DIGITAL #1 1A-25 50-029-22116-00 907415285 Kuparuk River Multi Finger Caliper Field & Processed 28-Sep-21 0 12 1D-117 50-029-22844-00 n/a Kuparuk River Packer Setting Record Field- Final 21-Oct-21 0 13 2F-14 50-029-21035-00 907412448 Kuparuk River Plug Setting Record Field- Final 25-Sep-21 0 14 2V-09 50-029-21300-00 907375358 Kuparuk RiverLeak Detect Log Field- Final 4-Oct-21 0 15 2V-09 50-029-21300-00 907429731 Kuparuk River Multi Finger Caliper Field & Processed 5-Oct-21 0 16 2V-13 50-029-21293-00 907399709 Kuparuk River Leak Detect Log Field- Final 21-Sep-21 0 178910PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF:Fanny Haroun, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518FRS_ANC@halliburton.comDate:Signed:Transmittal Date:10/25/2021Wd͗ϭϵϬϭϲϳϬ Ͳ^Ğƚ͗ϯϱϴϲϰBy Abby Bell at 11:08 am, Oct 22, 2021 C:\Users\aebell\Desktop\October Data Drop 2021\CPA Data Drop 10122021\2021-10-09_15808_KRU_1A-25_StaticBottomHolePressureSurvey_Transmittal.docx DELIVERABLE DISCRIPTION Ticket #Field Well #API #Log Description Log Date 15808 KRU 1A-25 50-029-22116-00 Static Bottom Hole Pressure Survey 09-Oct-21 DELIVERED TO Company & Address DIGITAL FILE # of Copies LOG PRINTS # of Prints CD’s # of Copies 1 AOGCC Attn: Natural Resources Technician 333 W. 7th Ave., Suite 100 Anchorage, Ak. 99501-3539 Delivered By: CPAI Sharefile FTP ______________________________ ______________________________________ Print Name Signature PLEASE RETURN COPY VIA EMAIL TO: DIANE.WILLIAMS@READCASEDHOLE.COM READ CASED HOLE,INC., 4141 B STREET,SUITE 308, ANCHORAGE, AK 99503 PHONE: (907)245-8951 E-MAIL :READ-Anchorage@readcasedhole.com WEBSITE :WWW.READCASEDHOLE.COM ______________________________________ gnaturrrrrrrrrrrrrrrrrrrrrrreeeeeeeeeeeeeeeeeeeeeee Abby Bell 37' (6HW C:\Users\aebell\Desktop\October Data Drop 2021\CPA Data Drop 10122021\2021-10-09_15808_KRU_1A-25_CaliperSurvey_Transmittal.docx DELIVERABLE DISCRIPTION Ticket #Field Well #API #Log Description Log Date 15808 KRU 1A-25 50-029-22116-00 Caliper Survey 09-Oct-21 DELIVERED TO Company & Address DIGITAL FILE # of Copies LOG PRINTS # of Prints CD’s # of Copies 1 AOGCC Attn: Natural Resources Technician 333 W. 7th Ave., Suite 100 Anchorage, Ak. 99501-3539 Delivered By: CPAI Sharefile FTP ______________________________ ______________________________________ Print Name Signature PLEASE RETURN COPY VIA EMAIL TO: DIANE.WILLIAMS@READCASEDHOLE.COM READ CASED HOLE,INC., 4141 B STREET,SUITE 308, ANCHORAGE, AK 99503 PHONE: (907)245-8951 E-MAIL :READ-Anchorage@readcasedhole.com WEBSITE :WWW.READCASEDHOLE.COM __________________________________________ Signatururururururururururuuuururuuurururuurururuururuuruuue Abby Bell 37' (6HW 1. Type of Request: Abandon Plug Perforations Fracture Stimulate Repair Well Operations shutdown Suspend Perforate Other Stimulate Pull Tubing Change Approved Program Plug for Redrill Perforate New Pool Re-enter Susp Well Alter Casing Other: CO261B Whipstock 2.Operator Name:4.Current Well Class:5. Permit to Drill Number: Exploratory Development 3.Address:Stratigraphic Service 6.API Number: 7.If perforating:8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require a spacing exception?Yes No 9. Property Designation (Lease Number):10. Field/Pool(s): 11. Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi):Plugs (MD):Junk (MD): 8120 NA Casing Collapse Conductor 670 Surface 2020 Intermediate -- Production 4330 Production Ti-Back Packers and SSSV Type:Packers and SSSV MD (ft) and TVD (ft): 12. Attachments: Proposal Summary Wellbore schematic 13. Well Class after proposed work: Detailed Operations Program BOP Sketch Exploratory Stratigraphic Development Service 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations:OIL WINJ WDSPL Suspended 16.Verbal Approval:Date:GAS WAG GSTOR SPLUG Commission Representative: GINJ Op Shutdown Abandoned Contact Name: Contact Email: Contact Phone: Date: Conditions of approval: Notify Commission so that a representative may witness Sundry Number: Plug Integrity BOP Test Mechanical Integrity Test Location Clearance Other: Post Initial Injection MIT Req'd? Yes No Spacing Exception Required? Yes No Subsequent Form Required: APPROVED BY Approved by: COMMISSIONER THE COMMISSION Date: Comm. Comm. Sr Pet Eng Sr Pet Geo Sr Res Eng 907-263-4112 3296 NA -- -- Baker FHL Packer, Baker HB Retrievable Packer 7272' / 583'6, 7361' / 5910' Perforation Depth TVD (ft): Tubing Size: COMMISSION USE ONLY Authorized Name: Tubing Grade: Tubing MD (ft): 6082-6115, 6118-6134, 6234- 6240, 6240-6283 PRESENT WELL CONDITION SUMMARY STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL 25647 6478 190-167 PO Box 100360, Anchorage, AK 99510 50-029-22116-00-00 ConocoPhillips Alaska, Inc. Length Size KRU 1A-25 Kuparuk River Field / Kuparuk River Oil Pool 8093 6459 L-80 TVD Burst 7352 4980 MD -- 1640 3520 80 3839 80 4641 64597" 16" 9-5/8" Authorized Signature: Jul-21 44 ---- 4606 8093 Perforation Depth MD (ft): 8058 7" 3-1/2" 1269 7576-7618, 7662-7643, 7776- 7783, 7797-7842 jeff.s.connelly@conocophillips.com Jeff Connelly Authorized Title: 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. 12781243 Perforate Repair Wepair Well Exploratory Stratigraphic Development Service BOP TestMechanical Integrity Test Location Clearance No No Form 10-403 Revised 3/2020 Approved application is valid for 12 months from the date of approval. 06/21/202 James CTD Staff Drilling By Samantha Carlisle at 1:57 pm, Jun 22, 2021 321-304 Digitally signed by James Ohlinger DN: CN=James Ohlinger, O=ConocoPhillips, OU=CTD, E=James.J.Ohlinger@conocophillips.com, C=US Reason: I am the author of this document Location: your signing location here Date: 2021.06.22 10:19:05-08'00' Foxit PhantomPDF Version: 10.1.3 James Ohlinger 7622 X DSR-6/24/21 10-404 SFD 6/22/2021 VTL 7/12/21 SFD 6/22/2021 dts 7/12/2021 JLC 7/12/2021 Jeremy Price Digitally signed by Jeremy Price Date: 2021.07.12 11:09:07 -08'00' RBDMS HEW 7/12/2021 P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 June 22, 2021 Commissioner - State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Dear Commissioner: ConocoPhillips Alaska, Inc. hereby submits Sundry Application (10-403) to pump a cement plug to abandon A- Sand perforations and set a High Expansion Wedge in KRU 1A-25 (PTD #190-167) in order to drill one CTD lateral using the coiled tubing drilling rig, Nabors CDR3-AC. CTD operations are scheduled to begin in mid-October 2021, though pre-rig work is planned to begin July. The CTD objective will be to drill one lateral, KRU 1A-25L1, targeting the Kuparuk C-sand interval. Attached to this application are the following documents: 10-403 Sundry Application for KRU 1A-25 Operations Summary in support of the 10-403 sundry application Proposed CTD schematic If you have any questions or require additional information, please contact me at 907-263-4112. Sincerely, Jeff Connelly ConocoPhillips Alaska Coiled Tubing Drilling Engineer Digitally signed by Jeff Connelly DN: C=US, OU=CTD, O=ConocoPhillips, CN=Jeff Connelly, E=jeff.s.connelly@conocophillips.com Reason: I am the author of this document Location: your signing location here Date: 2021.06.22 06:54:17-08'00' Foxit PhantomPDF Version: 10.1.3 Jeff Connelly pump a cement plug to abandon A-p, y ypp()pp pg Sand perforations and set a High Expansion Wedge in KRU 1A-25 (PTD #190-167) in order to drill one CTDpgpg lateral using the coiled tubing drilling rig, Nabors CDR3-AC. CTD operations are scheduled to begin in mid-October 2021, though pre-rig work is planned to begin July. pg,gpg p The CTD objective will be to drill one lateral, KRU 1A-25L1, targeting the Kuparuk C-sand interval. I concur. The well has been offline since June 2019, and hadn't produced more than 100 BOPD for at least 5 years before that. DSR-6/24/21 Page 1 of 1 6/22/2021 KRU 1A-25 (PTD #190-167) CTD Summary for Sundry Steps in bold apply to sundry application (pumping cement plug & setting High Expansion Wedge) Summary of Operations: KRU well 1A-25 is equipped with 3-1/2” tubing and 7” production casing. The CTD sidetrack will utilize one lateral to target the C-sands to the north of 1A-25. A cement plug will be pumped from ~7813’ to ~7751’ RKB to abandon A-Sand perforations. A High Expansion Wedge (HEW) will then be set at ~7595’ MD to facilitate milling a window in 7” casing CDR3-AC will mill a window in the 7” casing at ~7595’ MD and the 1A-25 lateral will be drilled to TD at 11,950’ MD, targeting the C-sands to the north. It will be completed with 2-3/8” slotted liner, solid liner with a swell packer, and a seal-bore assembly from TD up to ~7460’ MD. Reservoir Pressure and Maximum Downhole Pressure (Requirements of 20 AAC 25.005 (c)(4)(a)) The formation pressure in KRU 1A-25 was measured at 3470 psi @ 5880’ TVD (11.34 ppg) on 5/27/2020. The maximum downhole pressure in the 1A-25 vicinity is 1A-05 at 3989 psi and 6226’ TVD (12.32 ppg – Measured 9/28/2011). Using the maximum formation pressure in the area at 3989 psi in 1A-05 (i.e. 12.32 ppg EMW), the maximum potential surface pressure in 1A-25, assuming a gas gradient of 0.1 psi/ft, would be 3296 psi. CTD Pre-Rig, CTD Drill and Complete, & Post Rig 1A-25 Operations: Pre-CTD Work (bold applicable to Sundry Application – other steps for reference) 1. Pre-CTD diagnostics 2. Slickline: Dummy whipstock drift, tag PBTD, c/o GLV’s 3.CTU: Mill nipple, pump cement (abandon A-Sand perforations) 4.Slickline: Tag TOC & obtain SBHP 5. E-Line: Run caliper 6.E-Line: Set High Expansion Wedge (HEW) Rig Work (for reference) 1.MIRU Nabors CDR3-AC rig using 2” coil tubing. NU 7-1/16” BOPE, test. 2. Drill 1A-25L1 Lateral (C-sand - North) a.Mill 2.80” window at ~7595’ MD. b. Drill 3” bi-center lateral to TD of 11,950’ MD. c.Run 2Ǫ” slotted liner, solid liner with swell-packer, & seal-bore assembly from TD up to ~7460’ MD (into tubing-tail) 3.Obtain SBHP, freeze protect, ND BOPE, and RDMO Nabors CDR3-AC. Post-Rig Work (for reference) 1. Set liner-top packer 2. Return to production VTL 7/12/21 The CTD sidetrackqppgp will utilize one lateral to target the C-sands to the north of 1A-25. Not this sundry. gp the maximum potential surface pressure inp(ppg), p 1A-25, assuming a gas gradient of 0.1 psi/ft, would be 3296 psi. Last Tag Annotation Depth (ftKB) End Date Wellbore Last Mod By Last Tag: RKB (Est. 29' of Fill) 7,813.0 5/8/2019 1A-25 zembaej Last Rev Reason Annotation End Date Wellbore Last Mod By Rev Reason: Pulled 2.81" CSA-2 Plug 4/27/2021 1A-25 rogerba Casing Strings Casing Description CONDUCTOR OD (in) 16 ID (in) 15.06 Top (ftKB) 36.0 Set Depth (ftKB) 80.0 Set Depth (TVD) … 80.0 Wt/Len (l… 65.00 Grade H-40 Top Thread WELDED Casing Description SURFACE OD (in) 9 5/8 ID (in) 8.92 Top (ftKB) 35.0 Set Depth (ftKB) 4,641.1 Set Depth (TVD) … 3,838.9 Wt/Len (l… 36.00 Grade J-55 Top Thread BTC Casing Description PRODUCTION OD (in) 7 ID (in) 6.28 Top (ftKB) 35.0 Set Depth (ftKB) 8,093.3 Set Depth (TVD) … 6,459.3 Wt/Len (l… 26.00 Grade J-55 Top Thread ABMOD BTC Casing Description PRODUCTION TIE- BACK OD (in) 7 ID (in) 6.28 Top (ftKB) 35.0 Set Depth (ftKB) 1,278.1 Set Depth (TVD) … 1,269.0 Wt/Len (l… 26.00 Grade TC-ll Top Thread TC-ll Tubing Strings Tubing Description TUBING WO - 2014 String Ma… 3 1/2 ID (in) 2.99 Top (ftKB) 31.0 Set Depth (ft… 7,352.1 Set Depth (TVD) (… 5,902.4 Wt (lb/ft) 9.30 Grade L-80 Top Connection 8rd EUE Completion Details Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des Com Nominal ID (in) 31.0 31.0 0.04 Hanger McENVOY GEN IV TUBING HANGER 3.000 488.0 488.0 0.08 NIPPLE CAMCO 'DS' NIPPLE 2.875 7,241.8 5,811.1 34.19 SEAL ASSY BAKER 80-40 SEAL ASSEMBLY 2.990 7,248.8 5,816.9 34.16 PBR BAKER PBR 2.990 7,272.3 5,836.3 34.08 PACKER BAKER FHL PACKER 2.910 7,325.1 5,880.1 34.24 NIPPLE 'DS' NIPPLE 2.812 7,342.8 5,894.7 34.42 LOCATOR BAKER GBH-22 LOCATOR SUB 2.990 7,344.0 5,895.7 34.43 MULE SHOE 8 ' MULE SHOE, Spacer Tube w/1 FT Space out 2.990 Tubing Description TUBING 4"x3.5" Post 2013 WO String Ma… 3 1/2 ID (in) 2.99 Top (ftKB) 7,347.2 Set Depth (ft… 7,471.0 Set Depth (TVD) (… 5,999.4 Wt (lb/ft) 9.30 Grade J-55 Top Connection EUE8rdMOD Completion Details Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des Com Nominal ID (in) 7,347.2 5,898.3 34.47 PBR BAKER PBR, 10' STROKE 3.000 7,360.9 5,909.6 34.60 PACKER BAKER 'HB' RETRIEVABLE PACKER 2.870 7,458.6 5,989.4 36.18 NIPPLE OTIS XN NIPPLE 2.750 7,470.3 5,998.8 36.42 SOS BAKER SHEAR OUT SUB 2.992 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft )Type Com 7,576.0 7,584.0 6,082.6 6,088.9 C-4, C-3, C-2, UNIT B, 1A-25 1/5/1992 8.0 APERF 180 deg Phase; HLS 2.5" 7,584.0 7,596.0 6,088.9 6,098.2 C-4, C-3, C-2, UNIT B, 1A-25 1/5/1992 8.0 APERF 180 deg Phase; HLS 2.5" 7,596.0 7,618.0 6,098.2 6,115.2 C-4, C-3, C-2, UNIT B, 1A-25 1/5/1992 8.0 APERF 180 deg Phase; HLS 2.5" 7,622.0 7,643.0 6,118.3 6,134.4 UNIT B, 1A-25 1/5/1992 4.0 APERF 180 deg Phase; HLS 2.5" 7,776.0 7,783.0 6,234.4 6,239.6 A-5, 1A-25 6/11/1991 4.0 IPERF 180 deg Phase; HLS 2.5" TT 7,797.0 7,842.0 6,249.9 6,282.7 A-4, 1A-25 6/11/1991 4.0 IPERF 180 deg Phase; HLS 2.5" TT Mandrel Inserts St ati on N o/Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Make Model OD (in) Serv Valve Type Latch Type Port Size (in) TRO Run (psi) Run Date Com 1 2,982.1 2,601.2 43.65 CAMCO MMG 1 1/2 GAS LIFT GLV RK 0.188 1,216.0 7/20/2017 2 4,571.6 3,786.1 40.76 CAMCO MMG 1 1/2 GAS LIFT OV RK 0.250 0.0 5/27/2020 3 5,760.5 4,680.8 42.23 CAMCO MMG 1 1/2 GAS LIFT DMY RK 0.000 0.0 6/17/2015 4 6,596.9 5,300.1 41.71 CAMCO MMG 1 1/2 GAS LIFT DMY RK 0.000 0.0 6/17/2015 5 7,185.6 5,764.6 34.30 CAMCO MMG 1 1/2 GAS LIFT DMY RK 0.000 0.0 11/19/2014 1A-25, 4/28/2021 4:07:35 PM Vertical schematic (actual) PRODUCTION; 1,278.1-8,093.3 IPERF; 7,797.0-7,842.0 IPERF; 7,776.0-7,783.0 APERF; 7,622.0-7,643.0 APERF; 7,596.0-7,618.0 APERF; 7,584.0-7,596.0 APERF; 7,576.0-7,584.0 SOS; 7,470.3 NIPPLE; 7,458.6 PACKER; 7,360.9 PBR; 7,347.2 MULE SHOE; 7,344.0 LOCATOR; 7,342.8 NIPPLE; 7,325.1 PACKER; 7,272.3 PBR; 7,248.8 SEAL ASSY; 7,241.8 GAS LIFT; 7,185.6 GAS LIFT; 6,596.9 GAS LIFT; 5,760.5 SURFACE; 35.0-4,641.1 GAS LIFT; 4,571.6 GAS LIFT; 2,982.1 PRODUCTION TIE-BACK; 35.0- 1,278.1 NIPPLE; 488.0 CONDUCTOR; 36.0-80.0 Hanger; 31.0 KUP PROD KB-Grd (ft) 35.01 Rig Release Date 1/1/1991 1A-25 ... TD Act Btm (ftKB) 8,120.0 Well Attributes Field Name KUPARUK RIVER UNIT Wellbore API/UWI 500292211600 Wellbore Status PROD Max Angle & MD Incl (°) 47.19 MD (ftKB) 2,500.00 WELLNAME WELLBORE1A-25 Annotation Last WO: End Date 11/22/2014 H2S (ppm) 75 Date 8/10/2016 Comment SSSV: NIPPLE 1A-25 Proposed CTD Schematic3-1/2" Camco DS nipple @ 488' MD (2.875" min ID)3-1/2" 9.3# L-80 EUE 8rd Tubing to surface3-1/2" Camco gas lift mandrels @ 2982', 4572', 5760', 6597', 7186'Baker PBR @ 7249' MDBaker FLH Packer @ 7272' MDCamco DS Nipple @ 7325' MD (2.812" ID)Baker Locator Sub @ 7342' MDMule Shoe @ 7344'MD_________________Baker PBR @ 7347' MDBaker HB Packer @ 7361' MDCMU Sliding Sleeve @ 7718' MD (2.812" ID)_________________3-1/2 Otis XN nipple @ 7458' MD (2.75" min ID, No-Go)3-1/2" tubing tail @ 7471' MD9-5/8" 36# J-55 shoe @ 4641' MD7" 26# J-55 shoe @ 8093' MD16" 65# H-40 shoe @ 80' MDA-sand perfs 7776' - 7842' MDKOP @ 7595' MDC-sand perfs 7576' - 7643' MDModified by JSC 6/21/20211A-25L1 wp02Plan TD: 11,950' MDWOB Limit: 10,600' MDLTP (~7464')Swell packer (depth TBD) Originated: Schlumberger PTS- PRINT CENTER 6411A Street Anchorage, AK 99518 (907)273-1700 main (907)273-4760fax Delivered to: AQGCC ATTN: Natural Resources Technician 11 Alaska Oil & Gas Conservation Commision 333 W. 7th Ave, Suite 100 Anchorage, AK 99501 19©167 30979 NAME API # ORDERSERVICE # FIELD NAME DESCRIPTIONWELL DELIVERABLE DESCRIPTION DATA DATELOGGED Prints CD's 1A-25 50-029.22116.00 EBNL-00028 KUPARUK RIVER WL PPROF FINAL FIELD 21 -Jun -19 1 3Q-11 50-029-21676-00 EBNL-00029 KUPARUK RIVER WL LDL FINAL FIELD 22 -Jun -19 1 3K-23 50-029-22771-00 EBNL-00030 KUPARUK RIVER WL LDL FINAL FIELD 23 -Jun -19 1 2V-02 50.029-21037.00 EBNL-00034 KUPARUK RIVER WL (PROF FINAL FIELD 27 -Jun -19 1 1Y-14 50-029-20910.00 EBNL-00035 KUPARUK RIVER WL IPROF FINAL FIELD 28 -Jun -19 1 1H-109 50.029-23595-00 EBNL-00036 KUPARUK RIVER WL IPROF FINAL FIELD 29 -Jun -19 1 11-1-113 50-029-23588-00 EBNL-00037 KUPARUK RIVER WL IPROF FINAL FIELD 30 -Jun -19 1 1H-117 50-029-23602-00 EBNL-00038 KUPARUK RIVER WL IPROF FINAL FIELD 1Jul-19 1 31-1-14B 50-103-20092-02 EOSH-00062 KUPARUK RIVER WL LDL FINAL FIELD 3 -Jul -19 1 2G -14A 50-029-21161.01 EOSH-00064 KUPARUK RIVER WL LDL FINAL FIELD 5Jul-19 1 1B -O6 50.029.20603-00 EOSH-00065 KUPARUK RIVER WL PPROF FINAL FIELD 6 -Jul -19 1 18-09 50.029-20655-00 EOSH-00066 KUPARUK RIVER WL IPROF FINAL FIELD 7 -Jul -19 1 3G-03 50-103-20245-00 EOSH-00067 KUPARUK RIVER WL PPROF FINAL FIELD 8 -Jul -19 1 1R -22A 50-029.22206.01 EOSH-00048 KUPARUK RIVER WL LDL FINAL FIELD 8 -Jul -19 1 jUL 12 2P19 14 Signature return via courier or sign/scan and email a copy / /�A Transmittal Receipt signature confirms that a package (box, and CPAI. point. envelope, etc.) has been received and the contents of the package have been verified to match the media noted above. 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O O O O O O O N 0 0 N 0 0 N p, N N N N N N N N N N N N N NJO < O) O O) T O O) rn O) OO O O) O)) M G) , R N N N N N N NNNNNONN -� Q1 O o o O O O O O 0 0 O 0 O 3 O 6 OO 6 O O O O O O 6 O O 4, CoCOM U) N U) U) in U) U) U) U) N U) U) U) U) a u a1 03 w U) C OJ • O = z m - v > U LU Y w CC C C 63 U a Q o 3 a` 'O Ed m 'i a 0 0 0 0 0 0 0 N r M 0) O M (0 a+ C Z �, z N O O N O O +_+ E 1n �7 -CE V) 2 N = 2 = 2 2 = = •c' a >. M N N £ Z WW ro C �. CL Q O H of Y 30 fig . ,-A L n C f0 N m CD N u 3 14 N ro 0CM aaac � I- O a Q a STATE OF ALASKA ALA OIL AND GAS CONSERVATION COMAION REPORT OF SUNDRY WELL OPERATIONS 1.Operations Performed: Abandon r Repair w ell l Rug Perforations r Perforate r Other r Alter Casing r Pull Tubing F'• Stimulate-Frac l Waiver IT Time Extension r Change Approved Program r•;Operat. Shutdown r Stimulate-Other r" Re-enter Suspended Well I 2.Operator Name: 4.Well Class Before Work: 5.Permit to Drill Number: ConocoPhillips Alaska, Inc. 190-167 p Development � Exploratory 3.Address: 6.API Number: P. O. Box 100360,Anchorage,Alaska 99510 Stratigraphic r= Service r 50-029-22116-00 • 7.Property Designation(Lease Number): 8.Well Name and Number: ADL 25647 . 1A-25 • 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 8120 feet Plugs(measured) 7459 true vertical 6478 feet Junk(measured) none Effective Depth measured 8009 feet Packer(measured) 7361 true vertical 6400 feet (true vertical) 5910 Casing Length Size MD TVD Burst Collapse CONDUCTOR 44 16" 80 80 SURFACE 4606 9.625" 4641 3839 PRODUCTION 8098 7" 8093scoNED NOV 1 442k13 RECEIVED OCT 0 9 2013 Perforation depth: Measured depth: 7576-7618, 7622-7643,7776-7783, 7797-7842 3CC True Vertical Depth: 6083-6115,6118-6134,6234-6240,6250-6282 *�' Tubing(size,grade,MD,and TVD) 4"x 3.5",J-55,7471 MD, 5999 TVD Packers&SSSV(type,MD,and ND) PACKER-BAKER HB RETRIEVABLE PACKER @ 7361 MD and 5910 ND SSSV-CAMCO TRDP-4A SSSV @ 1783 MD and 1738 TVD 12.Stimulation or cement squeeze summary: Intervals treated(measured): no stimulation or cement squeeze 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 Subsequent to operation shut-in 14.Attachments 15.Well Class after work: Copies of Logs and Surveys run_ Exploratory fl Development F7 • Service l Stratigraphic 16.Well Status after work: Oil . . Gas r• WDSPL Daily Report of Well Operations XXX GSTOR IT WIND IT WAG r°" GINJ r SUSP IT SPLUG IT 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: 313-202 Contact Jonathan Coberly a,265-1013 Email Jonathan.Coberly(u�conocophillips.com Printed Name Jonat an Coberl Title Senior Wells Engineer Signature 4.1 Phone:265-1013 Date /0 • 11-2.675 v-L}= ,,e/9:f-/, 3 RBDMS OCT 11 kiji Form 10-404 Revised 10/2012 Submit Original Only ' • • J.Coberly Sr.Wells Engineer RECEIVED Drilling&Wells P.0.Box 100360 110V OCT Q 9 2013 Anchorage,AK 99510-0360 ConocoPhiHips Phone: 907-265-1013 AOGCC October 8, 2013 AOGCC Commissioner 333 W. 7th Ave, Suite 100 Anchorage, Alaska 99501 Subject: Report of Sundry Well Operations for 1A-25 Dear Commissioner: Attached for your files is the report of Sundry Well Operations for the recent workover on 1A-25. Included with these reports are emails between AOGCC and ConocoPhillips detailing the reason we have suspended operations for the time being. If you have any questions, please feel free to call me at anytime. Sincerely, Jonathan Coberly Sr. Wells Engineer CPAI Drilling JC/skad • , # KUP PROD • 1A-25 ConocOP fillips `= Well Attributes Max Angle&MD ID Alaska Inc. T . Wellbore APIIUWI Field Name I Wellbore Status �ncl(°) 1 MD(ORB) Act Btm(ftKB) u45rnnw,,„0 i`' 500292211600 KUPARUK RIVER UNIT PROD 47.19 2,500.00 8,120.0 -.- Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) -Rig Release Date 1A-25,9/27/201311.22'.02 AM SSSV:Partial Lock Out Last WO: 9/19/2013 35.01 1/1/1991 Vertical schematic(actual) Annotation I Depth(ftKB) End Date Annotation Last Mod By End Date Last Tag'SLM 7,760.0 6/4/2012 Rev Reason:Workover-WELL SUSPENDED osborl 9/27/2013 HANGER;31 0 I• ,, Casg Casing ing Description Strin s OD(in) ID('n) Top(ftKB) Set Depth(ftKB) Set Depth(ND)...Wt/Len(I...Grade Top Thread 1, CONDUCTOR 16 15.062 36.0 80.0 80.0 65.00 H-40 WELDED f Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)...Wt/Len('...Grade Top Thread SURFACE 95/8 8.921 35.0 4,641.1 3,838.9 36.00 J-55 BTC Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)... Wt/Len(I...Grade Top Thread PRODUCTION 7 6.276 35.0 8,093.3 6,459.3 26.00 J-55 ABMOD BTC CONDUCTOR',35.0-00.o Tubing Strings.. 11 Tubing Description String Ma...ID(in) Top(ftKB) Set Depth(ft..Set Depth(ND)(...Wt(Ib/ft) Grade Top Connection TUBING 4"x3.5"Post I 3 121 2.9921 31.01 7,471.01 5,999 41 9.30 J-55 I EUE8rdMOD I I 2013 WO J Completion Details Nominal ID SAFETY VLV;1,783.4 Top(ftKB) _Top(ND)(ftKB) Top Inc'(°) Item Des C (in) " ° 31.0 31.0 0.04 HANGER MCEVOY GEN IV TUBING HANGER w/PUP 3.476 1,783.4 1,738.0 31.88 SAFETY VLV CAMCO 4"TRDP-4A SAFETY VLV-LOWER PORTION 3.312 LOCKED OUT 4/25/2000 3,687.9 3,125.0 41.97 XO Reducing CROSSOVER REDUCING 4"x 3.5" 3.500 GAS LIFT',2,582.1 7,305.0 5,863.4 34.04 OPEN POST 2013 WO PULLED TUBING,THEN DROPPED SAME 2013 WO TUBING BACK DOWNHOLE,WITH 15'OF PUPS AT ® THE BOTTOM OF THE TUBING NOT RESET 7,347.2 5,898.3 34.47 PBR BAKER PBR,10'STROKE 3.000 7,360.9 5,909.6 34.60 PACKER BAKER'HB'RETRIEVABLE PACKER 2.870 GAS LIFT,3,783.1 7,458.6 5,989.4 36.18 NIPPLE OTIS XN NIPPLE 2.750 7,470.3 5,998.8 36.42 SOS BAKER SHEAR OUT SUB 2.992 Other In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.) Top(ND) Top(not Top(ftKB) (ftKB) (°) Des Corn Run Date ID(in) 7,429.6 5,965.9 35.60 CATCHER 2.72"x124"CATCHER 6/9/2013 0.000 7,458 6 5,989.4 36.18 PLUG 2.81"XXN PLUG SET IN NIPPLE(OAL=53") 2/13/2013 0.000 SURFACE,35.0-4,641.1-A s. Perforations&Slots y Shot GAS LIFT;4,683.4 Dens II Top(ND) Btm(ND) (shotsR Top(ORB) Btm(ftKB) (ftKB) (ftKB) Zone Date t) Type Coral 7,576.0 7,584.0 6,082.6 6,088.9 C-4,C-3,C-2, 1/5/1992 8.0 APERF 180 deg Phase;HLS GAS LIFT;5,276.0 UNIT B,1A- 25 2.5" III ,584.0 7,596.0 6,088.9 6,098.2 C-4,C-3,C-2, 1/5/1992 8.0 APERF 180 deg Phase;HLS GAS LIFT;5.587.4 UNIT B,1A- 25 2.5" 11 I 7,596.0 7,618.0 6,098.2 6,115.2 C-4,C-3,C-2, 1/5/1992 8.0 APERF 180 deg Phase;HLS UNIT B,1A- 2.5" 25 GAS LIFT;7,290.6 w 7,622.0 7,643.0 6,118.3 6,134.4 UNIT B,1A- 1/5/1992 4.0 APERF 180 deg Phase;HLS 25 2.5" 7,776.0 7,783.0 6,234.4 6,239.6 A-5,1A-25 6/11/1991 4.0 IPERF 180 deg Phase;HLS OPEN POST 2013 WO;7,305.0 2.5"TT 7,797.0 7,842.0 6,249.9 6,282.7 A-4,1A-25 6/11/1991 4.0 IPERF 185"0 deg TT Phase;HLS 2. 1 Mandrel Details PBR',7,347.2 St eh C o PACKER;7.360.9 on Top(TVD) Valve Latch Port Size TRO Run o No Top(ftKB) (ftKB) Make Model OD(in) Sery Type Type (in) (psi) Run Date m 1 2,582.1 2,321.3 CAMCO KBMG 1 GAS LIFT DMY BK 0.000 0.0 6/8/2013 CATCHER;7,a296 j '. 2 3,783.1 3,195.7 MACCO SPM-1A 1 GAS LIFT DMY BTM 0.000 0.0 6/8/2013 PLUG,7,458.6 3 4,683.4 3,871.1 MACCO SPM-1A 1 GAS LIFT DMY Broke 0.000 0.0 5/15/1993 NIPPLE;7.458.61 /////? 4 5,278.0 4,320.7 MACCO SPM-1A 1 GAS LIFT DMY BK 0.000 0.0 6/8/2013 5 5,587.4 4,552.2 MACCO SPM-1A 1 GAS LIFT DMY BK 0.000 0.0 6/9/2013 6 7,290.6 5,851.5 CAMCO MMG-2 1 1/2 GAS LIFT OPEN 6/9/2013 SOS,7,470.3 Notes;General&Safety End Date Annotation 5/15/1993 NOTE:Valve latch @ GLM#3,4683'is broken right above the No GO APERF;7,5760-7,584.0- 7/15/2008 NOTE:POSSIBLE SCALE IN WELL PER LAST DRIFT 7/15/08 APERF,7,584.0-75960 8/4/2010 NOTE:View Schematic w/Alaska Schematic9.0 APERF;7,596 0-7,618.0-- 9/17/2013 NOTE:Tight spots in 7"casing @ 908',620'&376';SSSV not pulled past 366' - 9/18/2013 NOTE:Approximately 1200'control line left downhole on top of SSSV - 9/19/2013 NOTE:WORKOVER ATTEMPT FAILED,TBG DROPPED BACK DOWNHOLE;WELL SUSPENDED APERF;7,622.0-7,643.0 IPERF;7,776.0-7,783.0- IPERF;7,797.0-7,842.0 PRODUCTION;350-8,093.3 • • •1A-25 Pre-Rig Well Work Summary • • DATE SUMMARY 6/8/2013 PULLED OV @ 5588' RKB AND GLV's @ 5278', 3783', 2582' RKB. SET DV's @ 2582', 3783', 5278' RKB. IN PROGRESS. 6/9/2013 SET DV @ 5588' RKB; PULLED DV @ 7291' RKB; PULLED AVA CATCHER ON XXN PLUG @ 7459' RKB AND SET 2.72"x 124"JUNK CATCHER @ SAME. COMPLETE. (READY FOR BPV) 9/7/2013 PRE RWO): BLEED OA TO—0 PSI. • s • Conoc Phillips Time Log & Summary We/Mew Web Rebelling Report Dili 1",,t7;,,„ Well Name: 1A-25 Rig Name: NABORS 7ES Job Type: RECOMPLETION Rig Accept: 9/14/2013 6:00:00 PM Rig Release: 9/19/2013 11:59:00 PM TimeLogs P III - :111,■■ 11011 l �� Date From To aDur S.Death E.Depth Phase Code Subootfe. T'4d6 Goinment 111114 09/14/2013 24 hr summary Blow down pull out cuttings tank and herculite, Move and stage pit complex down pad. Pull herculite and mats,warm up moving system on sub and move off 1A-07 well, remove herculite and old well tree and spools, stage new tree&spools in 1A-25 cellar area, Spot mats for sub. Move sub over 1A-25 well, Lay herculite for pits and spot same,spot mud shack and cutting tank, Berm rig and tanks, Hook up high pressure lines, electrical,water,air and steam, Take on 580 bbls of 9.6 ppg brine, Rig accepted @ 18:00 hrs 9/14/2013, Rig up lubricator. 00:00 04:30 4.50 MIRU MOVE MOB P Secure cellar, Blow down all lines, Break apart interconnects,Take down berming from around cutting tank and remove cutting truck. Break hard line down to cutting tank. 04:30 06:30 2.00 MIRU MOVE MOB P Jack up and move and stage pit complex down pad. Pull up matting boards and herculite. 06:30 12:00 5.50 MIRU MOVE MOB P Warm up hydraulics on moving system, Pull off 1A-07 well with sub, pull up herculite, Remove old tree and spools from cellar,stage in new tree and spools and spot mats& herculite for cellar. 12:00 14:00 2.00 MIRU MOVE MOB P Move sub over 1A-25 well. 14:00 14:30 0.50 MIRU MOVE MOB P Lay out herculite for pit module. 14:30 16:00 1.50 MIRU MOVE MOB P Spot pit complex. (Pad very soft from the rain) 16:00 22:30 6.50 MIRU MOVE RURD P Spot mud shack, cuttings tank, hook up electrical,water, air and steam, Hook up high pressure lines at interconnects, Berm pits,sub and cuttings tank.Take on 580 bbls of 9.6 Brine(Rig accepted @ 18:00 hrs,9/14/2013. R/U hard lines to tiger tanks. 22:30 00:00 1.50 MIRU WHDBO KLWL P R/U Lubricator and to pull BPV. 39/15/2013 Attempt to pull BPV Master&swab valve leaking on tree, Grease valves numerous times,valves holding, failed to retrieve BPV, reinstall lubricator&pull BPV, R/U and kill well pumped 273 bbl's of 9.6 ppg brine, Circulate another surface to surface, Monitor well for 30 min(Static)Take pictures of tree and N/D tree, Held pre-spud meeting with both crews, N/U BOPE, R/U test equipment,Test BOP components 250 low/3500 high for 5 min each,Witness of test waived by AOGCC Rep. Bob Noble. 00:00 00:30 0.50 COMPZ WELCTI SEQP P Pull BPV using lubricator, Closed master valve and swab valve, observed bleeder still leaking before removing lubricator. Page 1 of 6 • Time Logs st1 i'h iik I���� i B ip �� Date's , From To 'Dui* ', ,S.!Debth' E.Deoth Phase Code u co e'r 1P,HINH 00:30 03:00 2.50 COMPZ WELCTL SEQP T Call out valve service truck to grease valves on tree, Greased the master 2 times and the Swab valves three times and ended up closing the Hydraulic valve also and it leaked, grease it twice. Leak stopped. Pulled lubricator off and found the BPV was not pulled. Called valve service truck back out to release grease from master. 03:00 04:00 1.00 COMPZ WELCTL SEQP P Run hydraulic rod down and engage BPV with 10/15 turns, Saw 300 psi on gauge, run hydraulic rod back up and shut in master&swab valves, No leaks. Pull lubricator and found BPV with bent plunger rod. 04:00 05:00 1.00 COMPZ WELCTL RURD P R/U to pump down tbg with 9.6 ppg brine and take returns to choke house and open top tank&tiger tank.(Test lines to 1500 psi) 05:00 07:00 2.00 COMPZ WELCTL CIRC P Bleed TBG down to zero to tiger tank and start Pumping 9.6 ppg brine, TBG psi= 100 psi, IA psi=0 psi, ICP=660 psi at 2 bpm, Stage pump rate up to 4.5 bpm with 900 psi, Holding 80/100 psi back pressure, FCP= 1100 psi. Shut down pump and close in well, Strap tank volume, Got back 272.9 bbls. Pumped total of 272 bbls of 9.6 ppg brine. 07:00 09:30 2.50 COMPZ WELCTL CIRC P Circulate down tbg and out IA @ 104 spm 1100 psi, monitor well(Static) Blow down lines and clean up cellar area. 09:30 11:30 2.00 COMPZ WELCTL NUND P Nipple down 4 1/16"Model"C"5K Production Tree. 11:30 12:00 0.50 COMPZ WELCTL SFTY P PJSM and Spud Meeting with both Crews. 12:00 13:30 1.50 COMPZ RPCOM NUND P Remover spacer spool. 13:30 19:30 6.00 COMPZ RPCOM NUND P N/U new spacer spool, remove tree from cellar, N/U BOP stack, install turnbuckles and riser. 19:30 20:00 0.50 COMPZ RPCOM OTHR P Pull BPV and install TWC valve. 20:00 21:00 1.00 COMPZ RPCOM BOPE P M/U 3.5" test joint, FOS and IBOP, Fill stack with water. 21:00 22:30 1.50 COMPZ RPCOM BOPE P With 3.5"test joint,test upper VBR, Lower VBR&Annular, Kill stand pipe, HCR&Manual kill,choke valves 1-9&16,Air IBOP, Lower kelly valve, HT-38 FOS&IBOP 250 psi low,3500 psi high for 5 min each, all good test, (Witness of test waived by AOGCC Rep. Bob Noble) 22:30 23:00 0.50 COMPZ RPCOM BOPE P UD 3.5"test joint and make up 4" test joint. Fill stack. Page 2 of! `j Ra "" L 11"togs III i 11,4l f� III O h Ilia x�; Date From To Dur 4 S. Depth E. eqt i R)iasb Gode` Subcot e T Comm 23:00 00:00 1.00 COMPZ RPCOM BOPE P Test with 4"test joint,test upper VBRs, choke valves 10, 11 and 15, 250 psi low,3500 psi high for 5 min each all test good. 39/16/2013 Finish testing BOPE, (All Good tests)M/U 3.5"dp pups and cross over into hanger, Pulled to 135K max twice, No Go, Call out Halliburton E-Line, Spot Halliburton truck and rig up e-line, M/U 5' 160 grain string shot assembly and RIH to 700'MD, Encountered CCL failure, POOH and change out CCL tool, RIH and locate @ 7320'MD,fire tool, POOH, L/D string shot assembly and found one missing bolt and nut from shot rod connection, M/U RCT assembly. Found the OD of RCT is 2.5"OD and 3.5"pups to hanger are 2-7/16"ID, called out 1-3/4 RCT from Deadhorse. 00:00 02:00 2.00 COMPZ RPCOM BOPE P Continue testing BOP's with 4"test jt.Test annular, Lower VBRs, HCR& manual choke, Choke valves 11-13, low 250 psi/3500 psi 5 min each. 02:00 02:30 0.50 COMPZ RPCOM BOPE P Koomey draw down test, Start=3025 psi,after closing= 1725 psi,200 psi build up= 19 sec,full recovery=95 sec,5 bottles @ 2025 psi, Electric pump recovery=42 sec,Air pumps= 230 sec, Closing times:Annular= 19 sec, Upper VBR&Sim. Lower VBR, Blinds=5 sec each, HCR choke& kill= 1 sec each. 02:30 03:30 1.00 COMPZ RPCOM BOPE P Test Blinds, Inner&outer test ports, 250 psi low/3500 psi high 5 min each. 03:30 04:00 0.50 COMPZ RPCOM BOPE P R/D test equipment and blow down choke and lines. Suck out stack. 04:00 04:30 0.50 COMPZ RPCOM OTHR P Pull TWC valve. Monitor well. 04:30 06:00 1.50 COMPZ RPCOM OTHR P M/U cross over and 3.5"dp pups for landing joint and to be able to space out,screw into hanger and BOLDS 06:00 06:30 0.50 COMPZ EVALWE PULL P Pull tubing to observe 8'stretch,with t5 K. R w successension ,to pulling 13 to 135K.epeat pull Call for ith no E-line. Backout pup to locate tbg hanger in BOP stack with 25K overpull on tbg string. 06:30 11:30 5.00 COMPZ EVALWE RURD P Spot HES E-Line Unit. Hold PJSM. Rig up equipment. 11:30 17:30 6.00 COMPZ EVALWE RURD P Make-up tool string and pick-up String Shot. Start to run in with String Shot. Lost signal to the CCL at 700-ft. Pull out to troubleshoot problem. 17:30 18:30 1.00 COMPZ EVALWE RURD T Electronics problem with the Collar Locator. Replace same. Check good. Page 3 of 6, Time Logs ,i a s 33ate . '-&frorh To bur '.f .S`1Debfh E. Depth VPhase Code Subcotle T Con meht °°Illlq 11 7 , 18:30 21:30 3.00 COMPZ EVALWE ELOG P Run in hole with a 5-ft 160 grain String Shot. Record a jewelry pass across the Packer, PBR Joint to be cut and the GLM. Make a(4-)7-ft correction. Repeat tie-in pass. Stop with the String Shot 2.5-ft above and 2.5-ft below the target cut depth of 7,320-ft. Fire String Shot. Good POOH. 21:30 22:30 1.00 COMPZ EVALWE ELOG P L/D string shot assembly. 22:30 00:00 1.50 COMPZ EVALWE ELOG P M/U RCT assembly and attempted to run in but OD of RCT is 2.5"OD and ID of 3.5"dp pups is 2-7/16"ID, call out 1-3/4"RCT from deadhorse. 39/17/2013 RU and cut tubing at 7320'. MU landing joint and engage hanger, pull 130K and tubing came free. RU GBR and pull and LD tubing. After 12 joints out of the hole the control line was parted and not recovered. Tight spots encountered at 980',620'and 376'. Progress was stopped at 366'when overpull reached maximum and the string could not be pulled out. A Lub pill was spotted around the SSSV to try to gain more, but no more recovery was attained. The decision was made to return the tubing in the hole and land it for later recovery. RIH with tubing. 00:00 02:30 2.50 COMPZ EVALWE ELOG T Wait on 1-3/4"RCT assembly from deadhorse,The one they brought out was 2.5"RCT OD to big. 02:30 03:30 1.00 COMPZ EVALWE ELOG P M/U 1-3/4"RCT assembly and make up pump in sub to pups, 03:30 05:00 1.50 COMPZ EVALWE ELOG P M/U RCT assembly and RIH, CCL to top of RCT= 10.8' Record a jewelry pass across the Packer, PBR Joint to be cut and the GLM. Make a(+) 7.5-ft correction. Repeat tie-in pass. Stop with the String depth of 7308' and set anchors going down and pull 200#over going up at odometer reading of 7307' Fired RCT @ 7,320-ft. 05:00 06:00 1.00 COMPZ EVALWE FLOG P POOH with e-line and R/D Halliburton. 06:00 06:30 0.50 COMPZ RPCOM TRIP P Install TIW to landing joint, Pull 130K to pull pipe free; PU= 100K and S0= 65K. 06:30 08:00 1.50 COMPZ RPCOM RURD P RD Halliburton,and RU GBR for casing lay down operations. 08:00 08:15 0.25 COMPZ RPCOM SFTY P PJSM for pulling and laying down tubing. 08:15 11:30 3.25 COMPZ RPCOM PULD P Pull and LD 4"J-55 11#DSS-HTC tubing 7320'to 6915'; PU=90K, S0= 60K. Observed control line would not come out of hole with the tubing. Utilize tugger and strap to pull control line 1 for 1.Observed control line parted on joint#12 out of hole. NOTE:We could se partial control line in BOP stack when drained, but could not recover anymore line. Page4of6 r mil 4 I r lip m� Time Logs off__ . m gqa 0ilo ''Date From T66,,Z4P.Dur S. Depth E.'beoth Phase Code .3 Subcbde T Corr' Pent 1. 9i8 11:30 17:30 6.00 COMPZ RPCOM PULD P Pull and LD 4"J-55 11#DSS-HTC tubing 6915 to 376'; PU=90K, SO= 53K. Recover 10 SS bands.Tight spots encountered at 980',620'and 376'SSSV depths. Control line after 12 joints pulled was not recovered.Total of 35 jnts pulled out of hole,and encountered tight spot with SSSV at 366'. Repeat attempts to pass throough tight spot with no success. Max pull-25K over upweight. 17:30 18:30 1.00 COMPZ RPCOM CIRC P Build and pump lubrication pill,spot around SSSV. 3 BPM with 190 psi. 18:30 19:30 1.00 COMPZ RPCOM PU LL P Attempt multiple times to pull through tight spot at 376'to 366' (SSSV Depth)without success. Once again, max pull 25K over upweight of 90K. Observed tubing hung up while running back in hole, worked the string to break free,and continue run in hole with 2 more joints to free-movement point. 19:30 00:00 4.50 COMPZ RPCOM PULD P Confer with engineer and decision made to continue RIH with the tubing and land it with the old hanger. RIH with the tubing and cleared control line that could be seen in the stack. Total tubing run back in hole-35 jnts.We left out 15'of pup jnts. Bottom of tubing tail at 7305'. 39/18/2013 Tubing in the hole with PU=97K, SO=63K. MU hanger,clear and recover 155'of control line in stack with 1 SS band. Pump 51 BBLs of corrosion inhibitor getting returns of inhibitor to pits and land tubing, RILDS. Lay down landing joint. Install BPV and PT to 1000 psi for 10 minutes. ND BOPE and rack back. NU original tree and test 250/5000 psi Good test. Final pressures:Tbg=0 psi, IA=25 psi, OA=0 psi. RD and prep for move. 00:00 02:00 2.00 COMPZ RPCOM FISH P Tubing in the hole with PU=97K, SO=63K. Made up tubing hanger. RIH attempted to land tubing hanger, observed control line across well head.When pulling tubing hanger back to floor,observed control line came out, Pulled and recovered 155' more of broken control line and 1 SS band. 02:00 03:00 1.00 COMPZ RPCOM CIRC P RU and reverse circulate corrosion inhibitor @ 209 GPM, 900 psi, pump 51 BBL and get inhibitor back to pits. 03:00 04:00 1.00 COMPZ RPCOM RURD P Trip in tubing hanger and RILDS. Blow down lines and RD landing joint. 04:00 05:00 1.00 COMPZ RPCOM RURD P Install BPV and PT from below with 1000 psi-Good test. 05:00 08:30 3.50 COMPZ RPCOM NUND P ND stack; pull riser and RD lines, rack back stack and secure. Remove adapter flange. Page 5 of • ��' (ime dogs . . , � � ��� ate. Date From 'o - fur F= S. Depth t.i"Death3Phase Code. Subcode T Caitrtient 08:30 11:30 3.00 COMPZ RPCOM NUND P NU Original tree; install adapter and test seals 250/5000 psi Good test. Install tree and toraue all connections. 11:30 12:30 1.00 COMPZ RPCOM PRTS P Pressure test tree 250/5000 psi Good test. RD testing equipment. 12:30 13:00 0.50 COMPZ RPCOM RURD P Remove TWC per Cameron rep. 13:00 14:00 1.00 COMPZ RPCOM RURD P RU equipment to pump freeze protect in well. 14:00 14:30 0.50 COMPZ RPCOM SFTY P PJSM with LRS for freeze protect operations. 14:30 16:30 2.00 COMPZ RPCOM FRZP P PT lines to 2500 psi Good test. Reverse circulate, pump 75 BBL of diesel, at 60 BBLs away diesel returns observed at the pits. 16:30 18:00 1.50 COMPZ RPCOM CIRC P Open tubing by IA to allow U-tube. 18:00 18:30 0.50 COMPZ RPCOM PRTS P Install BPV per Cameron rep. PT BPV to 500 psi 5 minutes-Good. 18:30 19:30 1.00 COMPZ RPCOM RURD P RD all circulating equipment. 19:30 00:00 4.50 COMPZ RPCOM RURD P Perform tree work; remove secondary valve and install blind flange. Install guages on IA and Tbg. Final pressures Tbg=0 psi, IA=25 psi, OA=0 psi. Remove 3-1/2"DP from shed, clean and clear cellar for rig move and perform housekeeping on rigfloor and mezzanine level. X9/19/2013 Prep for RDMO. Wait on third party work on 1A-26. Rig maintenance and PM for rig equipment. Rig release at 23:59 9/19/2013 00:00 12:00 12.00 DEMOB MOVE RURD P RD equipment and prep for move; perform rig maintenance,equipment PMs and house keeping. Service top drive and drawworks,grease gripper blocks adjust brakes, maintenance blocks,condition and return to service. CO secondary choke hose. 12:00 00:00 12.00 DEMOB MOVE RURD P Perform rig maintenance, PM on equipment and cut and slip drill line; cut off 9 wraps of drilling line,61'. CO brake coolant, remove high pressure interconnect, install door safety handles, Rig Release at 23:59 9/19/2013 Page 6 of 6 • • Allsup-Drake, Sharon K From: Coberly,Jonathan Sent: Tuesday, September 24, 2013 11:27 AM To: Senden, R.Tyler; Packer,J.Brett; Nelson, Erik Q;Toomey,Ian A; Myers, Monty M; Lee, Theresa M;Voss,Jake;Chan, Paul (Petrotechnical Resources of Alaska) Cc: Allsup-Drake, Sharon K Subject: FW: 1A-25 (PTD 190-167, Sundry# 313-202) FYI....lt appears that we can have multiple 10-404's with one sundry. The first 10-404 just tells them how we have left it. The second one will close out the RWO. However,a new sundry will still have to be applied for if we do not complete the second RWO during the 1 year timeframe. -Jonathan From: Ferguson, Victoria L (DOA) [mailto:victoria.ferguson@ alaska.gov] Sent: Tuesday, September 24, 2013 11:22 AM To: Coberly, Jonathan Subject: [EXTERNAL]RE: 1A-25 (PTD 190-167, Sundry# 313-202) yes From: Coberly, Jonathan [mailto:Jonathan.Coberly@conocophillips.com] Sent: Tuesday, September 24, 2013 11:20 AM To: Ferguson, Victoria L(DOA) Subject: RE: 1A-25 (PTD 190-167, Sundry# 313-202) Victoria, So the sundry is still good for one year even if we have submitted the 10-404 as long as we do not change the scope? Thank you for clarifying. Jonathan Coberly Senior Wells Engineer ConocoPhillips Alaska Inc. 700 G Street(ATO-1504) Anchorage,AK 99501 Phone:907-265-1013 Cell:907-538-8398 From: Ferguson, Victoria L(DOA) [mailto:victoria.fergusonOalaska.gov] Sent: Tuesday, September 24, 2013 9:15 AM To: Coberly, Jonathan Subject: [EXTERNAL]RE: 1A-25 (PTD 190-167, Sundry# 313-202) Jonathan, If you plan to return to 1A-25 within 60 days, hold off on filing a 10-404. If you don't plan to return to the well within 60 days then file a 10-404 on work done to date. The sundry is good for a year from the approval. If the sundry scope does not change,then send an email notification that you plan to return to the well under the approved sundry. If the scope changes,then a new sundry will need to be submitted. 1 Thanx, Victoria Victoria Ferguson Senior Petroleum Engineer State of Alaska Oil&Gas Conservation Commission 333 W.7th Ave,Ste 100 Anchorage,AK 99501 Work: (907)793-1247 victoria.ferqusonaalaska.gov From: Coberly, Jonathan [mailto:Jonathan.Coberly@ conocophillips.com] Sent: Monday, September 23, 2013 1:33 PM To: Ferguson, Victoria L(DOA) Cc: Allsup-Drake, Sharon K Subject: 1A-25 (Sundry# 313-202) Victoria, We elected to re-land the tubing hanger and RDMO after we were unable to retrieve the SSSV during the initial pulling of the completion equipment on the 1A-25 Subsidence RWO(Sundry#313-202). We intend to return to this well in the future to complete the remediation of the well. Do we need to submit any forms(10-403,...)in the mean time? Is there a certain amount of time that we have to complete operations on this well under the current sundry? Thank you, Jonathan Coberly Senior Wells Engineer ConocoPhillips Alaska Inc. 700 G Street(ATO-1504) Anchorage,AK 99501 Phone:907-265-1013 Cell:907-538-8398 2 P7-70 /ci C -/6 7- Ferguson, Victoria L (DOA) From: Ferguson,Victoria L(DOA) Sent Tuesday, September 24, 2013 9:15 AM To: 'Coberly,Jonathan' Subject: RE: 1A-25 (PTD 190-167, Sundry*313-202 Su � ct ( ry 313-202) Jonathan, If you plan to return to 1A-25 within 60 days, hold off on filing a 10-404. If you don't plan to return to the well within 60 days then file a 10-404 on work done to date. The sundry is good for a year from the approval. If the sundry scope does not change,then send an email notification that you plan to return to the well under the approved sundry. If the scope changes,then a new sundry will need to be submitted. Thanx, Victoria Victoria Ferguson Senior Petroleum Engineer FEB 2 5 2014 State of Alaska SCANNED Oil&Gas Conservation Commission 333 W. 7th Ave,Ste 100 Anchorage,AK 99501 Work: (907)793-1247 victoria.ferguson@a,alaska.gov From: Coberly, Jonathan [mailto:Jonathan.Coberly@conocophillips.com) Sent: Monday, September 23, 2013 1:33 PM To: Ferguson, Victoria L(DOA) Cc: Allsup-Drake, Sharon K Subject: 1A-25(Sundry# 313-202) Victoria, We elected to re-land the tubing hanger and RDMO after we were unable to retrieve the SSSV during the initial pulling of the completion equipment on the 1A-25 Subsidence RWO(Sundry#313-202). We intend to return to this well in the future to complete the remediation of the well. Do we need to submit any forms(10-403,...)in the mean time? Is there a certain amount of time that we have to complete op erations on this well under the current sundry? Thank you, Jonathan Coberly Senior Wells Engineer ConocoPhillips Alaska Inc. 700 G Street(ATO-1504) Anchorage,AK 99501 Phone:907-265-1013 Cell:907-538-8398 1 • OF Thy e w I %7 ,v THE STATE Alaska, • il and Gas °f A LAS� ! _ __ _ Conservation Commission GOVERNOR SEAN PARNELL 333 West Seventh Avenue LAS ACP Anchorage, Alaska 99501 -3572 Main: 907.279.1433 Fax: 907.276.7542 Jonathan Coberly SCANNED M 1 0 2613 Senior Wells Engineer ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510 0 Re: Kuparuk River Field, Kuparuk River Oil Pool, 1A -25 Sundry Number: 313 -202 Dear Mr. Coberly: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Cathy P oerster Chair DATED this ivy of May, 2013. Encl. STATE OF ALASKA p(44-' KA OIL AND GAS CONSERVATION COM /SSION .„ 10' 1 i D N FOR SUNDRY APPROVALS 5//0'3 APPLICATIO T5 O p • 20 AAC 25.280 APR 2 6 2013 1. Type of Request: Abandon r Aug for Redrill f Perforate New Pool I" Repair w ell r;.7. Change A pr.v-. f Suspend E Rug Perforations is Perforate r Pull Tubing r. '_ �� r Operational Shutdow n I""° Re -enter Susp. Well E Stimulate Alter casing r,; � g Other: 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development r • Exploratory (' 190 - 167 • 3. Address: Stratigraphic r Service ( 6. API Number. P. O. Box 100360, Anchorage, Alaska 99510 50 029 - 22116 - 00 • 7. If perforating, What 8. Well Name and Number: Regulation or Conservation Order govems well spacing in this pool? Will planned perforations require spacing exception? Yes I — No I� 1A -25 ' 9. Property Designation (Lease Number): 10. Field /Pool(s): ADL 25647 • Kuparuk River Field / Kuparuk River Oil Pool - 11. PRESENT WELL CONDITION SUMMARY Total depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 8120 6478 .7459' none Casing Length Size MD TVD Burst Collapse CONDUCTOR 44 16 80' 80' SURFACE 4606 9.625 4641' 3839' PRODUCTION 8098 7 8120' 6478' Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 7576 -7618, 7622 -7643, 7776 -7783, 7797 -7842 6083 -6115, 6118 -6134, 6234 -6240, 6250 -6282 4" x 3.5" J - 7470 Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft) PACKER - BAKER HB RETRIEVABLE PACKER ' MD= 7361 TVD= 5910 SSSV - CAMCO TRDP -4A . MD =1783 TVD =1738 12. Attachments: Description Sunmary of Proposal r 13. Well Class after proposed work: Detailed Operations Program r BOP Sketch I — Exploratory J Stratigraphic I Development r • Service 14. Estimated Date for Commencing Operations: 15. Well Status after proposed work: 7/4/2013 Oil r • Gas r WDSPL r Suspended E 16. Verbal Approval: Date: WINJ I GINJ C` WAG j Abandoned r Commission Representative: GSTOR I- SPLUG fl 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Jonathan Coberly @ 265 -1013 Email: Jonathan .Coberlyeconocophillios.com Printed Name Jonathan berl Title: Senior Wells Engineer Signature Phone: 265 -1013 Date *j..6r zOI5 Commission Use Only Sundry Number: 2I'-'Z02 Conditions of approval: Notify Commission so that a representative may witness Plug Integrity (v BOP Test I' Mechanical Integrity Test F Location Clearance r RBDMS MAY 1 0 201 3 Other. 8 U/ 7 / i--, 3 5 / 7 S L Spacing Exception Required? Yes ❑ No li Subsequent Form Required: / a D /L APPROVED BY / - Approved by: r p I n is vaEfc� �r nths from th I §Oval. Date: J - 2 d .- [ ✓ Form 10 -403 (Revis 10/2012) j i Submit Form and Atta ents in Duplicate �� \yo ti� ORIGINAL 45 - �(� ���° • • • RECEIVED APR 26 2013 AOGCC April 25, 2013 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 Producer 1A -25 (PTD: 190 -167). Well 1A -25 was originally completed in 1991 as a fractured Kuparuk A -sand only producer with a single packer completion above the Kuparuk A and C sands. In 1992 the Kuparuk C -sand was perforated and brought online. The well has produced as a Kuparuk A and C sand producer until the well was shut in due to TxIA communication discovered with a failed TIFL on 1/9/2013. On 1/10/2013 the well failed an MITOA and a surface casing leak was confirmed to be at 240' RKB on 1/11/2013. A CMIT TxIA/DDT passed on 1/31/2013 confirming the integrity to fluid of the production casing. However, the well's pressure history shows evidence of communication to gas from the IA to the OA. After the RWO the well is expected to be brought back online with gas lift at a rate of 114 BOPD. The objective of this workover is to pull the existing gas lift completion, cut and pull the 7" production casing above the top of cement, tie in and cement a new 7" TC -II threaded production casing from the back off, and run a new 3 '' /z" gas lift completion. If you have any questions or require any further information, please contact me at 265 -1013 or Y Y9 9 Y p Jonathan.Coberly@conocophillips.com. Sincerely, A 'MA" Jonathan Coberly Senior Wells Engineer CPAI Drilling and Wells • • 1A -25 Rig Workover, Subsidence Repair (PTD #: 190 -167) Current Status: The well is currently shut in. It has leaks in the tubing and surface casing. The production casing is thought to leak to gas. Scope of Work: Pull the existing gas lift completion, cut and pull the 7" production casing above the top of cement, tie in and cement a new 7" TC -II threaded production casing from the back off, and run a new 3 Y2" gas lift completion. General Well info: MASP: 1,861 psi (using 0.1 psi /ft gas gradient) Reservoir pressure /TVD: Combined Kuparuk A, B, C -Sands — 2,460 psi / 5,990' TVD (7.9 ppg EMW) measured 2/13/2013. Wellhead type /pressure rating: McEvoy Gen IV, 7'/ 5M Top x 11" 3M Bottom Nabors 7ES BOP Config: Annular / 7" Pipe Rams / Blind Rams / Mud Cross / Variable Pipe Ram MIT results: CMIT TxIA/DDT — Passed 1/31/2013 TIFL — Failed 1/9/2013 MITOA — Failed 1/11/2013 Well Type: Producer Estimated Start Date: July 4, 2013 Production Engineers: David Lagerlef / Dana Glessner Workover Engineer: Jonathan Coberly (265 -1013 / Jonathan .Coberly @conocophillips.com) Proposed Pre -Rig Work: Slickline: 1. RU slickline. Pull GLV's and OV. Replace w/ DV's. Pull DV from bottom GLM. Leave open. Other 1. Set BPV within 24 hours prior to rig arrival. Proposed Procedure: 1. MIRU . 2. Pull BPV. Circulate 9.6 ppg brine to kill well. 3. Install BPV. ND tree. 4. Install the blanking plug. NU BOPE. Test BOPE to 250/3,500 psi. 5. Pull the blanking plug. Pull the BPV. 6. BOLDS, un -land tubing hanger, and pull to the floor. 7. POOH laying down tubing. Spool up control line. 8. RIH on DP and casing scraper to the PBR. POOH standing back DP. LD casing scraper assembly. 9. RU E -Line. Log w/ CAST -M. Locate TOC. RIH and fire string shot. POOH. RDMO E -line. 10. Set 7" RBP below TOC. PT/DDT the RBP. Dump sand. POOH with DP. 11. Monitor OA for flow. ND BOPE. Remove tubing head. Spear the 7" casing and re -land it in the slips. Cut off excess casing. NU the BOPE to the casing head. PT the casing head. 12. Cut the 7" casing above TOC. POOH with DP. 13. Reverse circulate out the Arctic Pack from the OA with heated diesel. 14. Spear the 7" casing. POOH laying down the 7" casing. • • 15. Set the test plug in the casing head. PT the BOPE to 250/3,000 psi. (limited by 3, 000 psi casing head) 16. RIH with 9 %" casing scraper to the cut 7" casing. POOH with DP. 17. Gauge the 9 %" casing for the ES cementer with tandem string mills. POOH with DP. 18. Dummy drift the ES cementer. POOH with DP. 19. Backoff the top 7" casing joint. POOH with DP. 20. Engage spear on casing stub to retrieve fish. POOH with DP. 21. Run new 7" casing. PT the 7" casing. NU cement head. 22. RU SLB cementers. Close pipe rams and open the annulus valve. Pressure up the casing to open the ES cementer. Cement the 7" casing to surface. 23. PT the cement plug. Bleed production casing pressure to zero. ND cement head. WOC. 24. ND BOPE. Land 7" casing in the slips. Cut excess casing off. Install packoff. NU new tubing head and BOPE. Install BPV and blanking plug. Pressure test BOPE to 3,500 psi. Pull BPV. 25. Mill up cement, closing plug, and ES cementer. POOH with DP. 26. PT the casing. Record test on chart for 30 minutes. ✓ 27. Mill remaining debris from the top of the sand. POOH with DP. 28. RIH with wash string and circulate sand out from on top of the RBP. POOH with DP. 29. RIH with RBP retrieving assembly. Retrieve RBP. POOH laying down DP. 30. Run new 3 %" gas lift completion. 31. Sting into PBR. Space out for subsidence, mark the pipe, and POOH two joints. Space out with pups. 32. MU tubing hanger. Swap the well over to corrosion inhibited seawater. Land the hanger and RILDS. 33. PT tubing. While holding 2,000 psi on tubing, pressure test the IA to 2,500 psi for 30 minutes and record casing pressure test on chart recorder. ✓ 34. Bleed T and IA. Shear the SOV. Bleed tubing and IA pressures to zero. Monitor for flow. 35. Pull landing joint. Install TWC. Pressure test IA to test TWC from below. 36. ND BOP stack, NU tree. PT tree and tubing hanger packoffs to 250/5,000 psi. 37. Remove TWC. 38. Freeze protect w/ diesel to 2,000' TVD. Set BPV. 39. RDMO. Proposed Post -Rig Work: 1. Pull BPV. 2. RU Slickline. Pull catcher. Run new gas lift design. Pull `XXN' plug. 3. Reset well house(s) and flowlines of adjacent wells. 4. Handoffto operations. • ConocoPhillips Well: 1A-25 2013 RWO PROPOSED COMPLETION API: 500292211600 Conductor: PTD: 190 -167 16 ", 65 #, H -40 to 80' RKB Wellhead: McEvoy Gen IV X -mas Tree: 4- 1/16 ", 5K psi DS 4 Surface Casing: Lift Threads: 4" DSS -HTC 8rd EUE 9.625 ", 36.0 #, J -55 to 4,641' RKB BPV: 4" CIW'H' J Production Casing: 7 ", 26.0 #, J -55 TOC to 8,128' RKB 7 ", 26.0 #, L -80 KB to TOC J Perforations: MD Zone 7,576' - 7,618' Kuparuk -C 7,622' - 7,643' Kuparuk -B J 7,776' - 7,783' Kuparuk -A 7,797' - 7,842' Kuparuk -A A ■ J — 2.875" ID CAMCO 'DS' Nipple at -500' RKB Gas Lift Mandrels: J Type MD TVD MMG 1 -1/2" XX XX F 3.5 ", 9.3 #, L -80, 8rd, EUE -Mod KB to 7,347' RKB MMG 1 -1/2" XX XX MMG 1 -1/2" XX XX - MMG 1 -1/2" XX XX 4 Baker PBR w/ 10' Stroke at 7,347' RKB , MMG 1 -1/2" XX XX X 4-- Baker'HB' Retrievable Packer at 7,361' RKB - Directional: XN . 2.81" Otis'XN' Nipple w/ 2.75" No -Go at 7,459° Max Incline: 47.2° @ 2500' RKB Max Dogleg: 5° @ 2100' SOS 1 3" ID Baker Shear Out Sub at 7,470' RKB ;;- Fill Tagged at 7,758' SLM 4/24/2012 Fill at: 7,758' SLM Last Updated: 25- Apr -13 TD: 8,120' RKB Updated by: JRC KUP • 1A -25 ConocoPhillips 01 Well Attributes Max Angle & MD TD Alaska, Inc. Welibore API /UWI Field Name Well Status Inc1 ( °) MD (ftKB) Act Btm (ftKB) , ,,,,,,, � 500292211600 KUPARUK RIVER UNIT PROD 47.19 2,500.00 8,120.0 Comment H2S (ppm) Date Annotation End Date KB-Grd (ft) Rig Release Date "' SSSV: Partial Lock Out 196 8/14/2012 Last WO: 35.01 1/1/1991 Well Conde: - 10 -25, 2/26/20137.1244 AM Schematic - Adual Annotation Depth (ftKB) End Date Annotation Last Mod ... End Date Last Tag. SLM 7,760.0 6/4/2012 Rev Reason: WELL REVIEW osborl 2/28/2013 I Casing Strings Casing Description String 0... String ID... Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd HANGER. 31 . CONDUCTOR 16 15.062 36.0 80.0 80.0 65.00 H -40 WELDED slk Casing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd _ SURFACE 95/8 8.921 35.0 4,641.1 3,838.6 36.00 J -55 BTC iimmemmlnit Casing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd PRODUCTI _ 7 6.276 30.0 8,128.3 26.00 J -55 BTC -ABMOD Tubing Strings Tubing Description String 0... String ID ... Top (5681) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd TUBING 4"x3 5" 3 1/2 2.992 31.0 7,471.0 5,999.3 9.30 J -55 EUE8rdABMOD Completion Details CONDUCTOR, Top Depth 36 -e0 (TVD) Top Inc! Nomi... - -__ .. Top (ftKB) (ftKB) (1 Item Description Comment ID (In) 31.0 31.0 0.18 HANGER MCEVOY GEN IV HANGER 4.000 I ` 1,783.4 1,737.9 31.88 SAFETY VLV CAMCO TRDP -4A SAFETY VALVE - LOWER PORTION LOCKED OUT 3.312 o. 4/25/2000 SAFETY VLV, 1.793 3,687.9 3,125.0 42.03 XO Reducing CROSSOVER 4 x 3.5, ID 2.992, #9.3, J -55, EUE8RDABMOD 3.500 2 7,347.2 5,898.2 34.47 PBR BAKER PBR w/ 10' STROKE 3.000 7,360.9 5,909.5 34.60 PACKER BAKER HB RETRIEVABLE PACKER 2.870 GAS LIFT, 7,458.6 5,989.2 36.10 NIPPLE OTIS XN NIPPLE NO GO 2.750 2,582 7,470.3 5,998.7 36.36 SOS BAKER SHEAR OUT SUB. ""ELMD TTL @ 7458' during PPROF on 3.000 U 4/18/2006"" O ther In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top Depth E " -y (TVD) Top lInd GAS LIFT, E j Top (ftKB) ("B) 1 Description Comment Run Date ID (in) 3,783 am 7,429.6 5,965.3 35.46 CATCHER 2.71 "x29" AVACatcher 2/13 /2013 0.000 7,458.6 5,989.2 36.10 PLUG 2.81" XXN Plug set in Nipple (OAL =53 ") 2/13/2013 0.000 Perforations & Slots Shot - Top (TVD) Btm (TVD) Dens ,. . Top (ftKB) Btm (ftKB) (ftKB) (0103) Zone Date (sh... Type Comment 7,576.0 7,584.0 6,082.6 6,088.9 C-4, C-3, C -2, 1/5/1992 8.0 APERF 180 deg Phase; HLS 2.5" SURFACE, ' � ■ UNIT B, 1A -25 35 4,647 7,584.0 7,596.0 6,088.9 6,098.2 C-4, C-3, C -2, 1/5/1992 8.0 APERF 180 deg Phase; HLS 2.5" ilk GAS LIFT, IF UNIT B, 1A -25 4 7,596.0 7,618.0 6,098.2 6,114.6 C-4, C -3, C -2, 1/5/1992 8.0 APERF 180 deg Phase; HLS 2.5" UNIT B, 1A -25 GAS LIFT. 7,622.0 7,643.0 6,117.7 6,134.1 UNIT B, 1A -25 1/5/1992 4.0 APERF 180 deg Phase; HLS 2.5" 5,278 ilik 7,776.0 7,783.0 6, 23 4 .4 6,239.6 A -5, 1A -25 6/11/1991 4.0 IPERF 180 deg Phase; HLS 2.5" TT GAS LIFT, 7,797.0 7,842.0 6,249.9 6,282.3 A -4, 1A -25 6/11/1991 4.0 IPERF 180 deg Phase; HLS 2.5" TT 5.587 Notes: General & End Date Annotation 5/15/1993 NOTE: Valve latch @ GLM 83 , 4683' is broken r above the No GO GAS LIFT, i. 7/15/2008 NOTE: POSSIBLE SCALE IN WELL PER LAST DRIFT 7 /15/08 7,291 c 8/4/2010 NOTE: View Schematic w/ Alaska Schematic9.0 MI PBR, 7,347 PACKER, 7,360 .. CATC 7,E . ` I= I/ !' PLUG, 7,459 - /�� NIPPLE, 7,459 1/" SOS, 7,470 E 1 APERF, 7,576-7,584 APERF, 7,5847,596 APERF, 7,596-7,618 PERF, _ Mi Ill 7,62 Mandrel Details Top Depth Top Port 5,.. (TVD) Inc! OD Valve Latch Size TRO Run _ N... Top(ftKB) (ftKB) ( °) Make Model (in) Sery Type Type (in) (pal) Run Date Corn... IPERF, 3 1 2,582.1 2,321.3 46.37 CAMCO KBMG 1 GAS LIFT GLV BK 0.156 1,260.0 2/12/2013 7,776 -7,78 2 3,783.1 3,195.8 42.00 MACCO SPM -1A 1 GAS LIFT GLV BTM 0.156 1,263.0 5/23/2009 3 4,683.4 3,871.1 39.98 MACCO SPM -1A 1 GAS LIFT DMY Broke 0.000 0.0 5/15/1993 4 5,278.0 4,320.8 41.36 MACCO SPM -1A 1 'GAS LIFT GLV BK 0.188 1,308.0 5/23/2009 PERF, T.797a,ea2 1� - 5 5,587.5 4,552.2 41.86 MACCO SPM -1A 1 GAS LIFT OV BK 0250 0.0 2/13/2013 6 7,291.1 5,852.0 33.90 CAMCO MMG-2 1 GAS LIFT DMY RK 0.000 0.0 10/3/1996 TD, 8,120 PRODUCTION, • • 309,128 • • l9 °7 2. WELL LOG TRANSMITTAL To: Alaska Oil and Gas Conservation Comm. June 6, 2012 Attn.: Howard Okland 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 SCANNED MAY 13 2,013 RE: Multifinger Imaging Tool (MIT) : 1A -25 Run Date: 6/4/2012 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Klinton Wood, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 1A -25 Digital Data (LAS), Digital Log file, Casing Inspection Report, 3D Viewer 1 CD Rom 50-029-22116-00 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline & Perforating Attn: Klinton Wood 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907 - 273 -3527 Fax: 907 - 273 -3535 klinton.wood@halliburton.com Date: - 1S01%/2-. Signed: 6 • , WELL LOG TRANSMITTAL To: Alaska Oil and Gas Conservation Comm. Attn.: Christine Mahnken 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 . - --~_ ---~-~ ~D~cember 8, 2009 RE: Production Profile: 1A-25 Run Date: 10/9/2009 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 1A-25 Digital Data in LAS format, Digital Log Image file, Interpretation Report 1 CD Rom 50-029-22116-00 Production Profile Log 1 Color Log 50-029-22 1 1 6-00 Production Array Log (CAT-RAT) 1 Color Log 50-029-22 1 1 6-00 PLEASE ACKNOWLEDGE RECEII'T BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline & Perforating Attn: Rafael Barreto 1~ ~ -- f (9 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907-273-3527 Fax: 907-273-35 5 ~,~ ~ _ , rafael.barreto~~31~,ton..com " -~, ? !lit Date: 1 g ~ a3 ~` I( ~~ i~ Signed: ~,~ t~----_°'-_ ConocoPhillips Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 Sept 6, 2008 Mr. Tom Maunder Alaska Oil & Gas Commission 333 West 7~' Avenue, Suite 100 Anchorage, AK 99501 °~N~ SEF' g. ~ 2QOF Dear Mr. Maunder: i Enclosed please find a spreadsheet with a list of wells from the Kuparuk field (KRU). Each of these wells was found to have a void in the conductor. These voids were filled with cement if needed and corrosion inhibitor, engineered to prevent water from entering the annular space. As per previous agreement with the AOGCC, this letter and spreadsheet serves as notification that the treatments took place and meets the requirements of form 10-404, Report of Sundry Operations. The cement was pumped August 28th, 2008. The corrosion inhibitor/sealant was pumped August 29th, Sept 5-6th,2008. The attached spreadsheet presents the well name, top of cement depth prior to filling, and volumes used on each conductor. Please call MJ Loveland or Perry Klein at 907-659-7043, if you have any questions. Sincerely, Perry Klei ConocoPhillips Well Integrity Projects Supervisor • • ConocoPhillips Alaska Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10-404) Kuparuk Field Date 9/6/2008 Well Name PTD # Initial top of cement Vol. of cement um ed Final top of cement Cement top off date Corrosion inhibitor Corrosion inhibitor/ sealant date ft bbls ft al 1A-17 190-151 SF NA SF NA 2.55 8/29/2008 1A-18 190-153 21' 2.80 27" 8/28/2008 1A-20 190-162 21' 2.80 25" 8/28/2008 7.65 8/29/2008 1A-25 190-167 14' 1.90 25" 8/28/2008 7.65 8/29/2008 1J-101 205-182 6" NA 6" NA 1.28 9/5/2008 1J-102 206-110 7" NA 7" NA 1.70 9/5/2008 1J-103 206-114 7" NA 7" NA 1.28 9/5/2008 1J-105 207-027 8" NA 8" NA 1.28 9!5/2008 1J-107 207-107 7" NA 7" NA 1.28 9/5/2008 1J-109 206-050 14" NA 14" NA 8.08 9/5/2008 1J-115 206-122 10" NA 10" NA 2.55 9/5/2008 1J-118 206-176 5" NA 5" NA 6.80 9/5/2008 1 J-120 207-045 4" NA 4" NA 2.55 9/5/2008 1J-127 206-047 6" NA 6" NA 1.70 9/5/2008 1J-135 207-038 8" NA 8" NA 1.70 9/6/2008 1J-136 206-154 9" NA 9" NA 1.70 9/6/2008 1J-137 206-108 12" NA 12" NA 5.10 9/6/2008 1J-154 205-035 4" NA 4" NA 4.67 9/6/2008 1J-156 206-067 8" NA 8" NA 5.95 9/6/2008 1J-159 206-005 20" NA 20" NA 14.87 9/6/2008 1 J-160 207-015 20" NA 20" NA 7.23 9/6/2008 1 J-164 205-144 20" NA 20" NA 11.90 9/6/2008 1 J-176 207-099 6" NA 6" NA 1.28 9/6/2008 1 J-184 206-044 8" NA 8" NA 1.28 9/6/2008 ~~~~~~~ Schlumberger -DCS 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Well Job # LW ~/ -- Wlr~~ H~i7 Cd .'. ~•D~t3 Log Description 08/06/08 N0.4803 Company: Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Kuparuk Date BL Color CD 1A-22 12097412 GLS ~ - (p 07/22/08 1 1 2G-04 12096519 PROD PROFILE - 07/23/08 1 1 1A-22 12097413 PROD PROFILE - '~- 07/23/08 1 1 1A-28 11996647 PROD PROFILE .- / 07/24/08 1 1 1A-25 11996648 PROD PROFILE .- i 07/25/08 1 1 2A-08 11996649 INJECTION PROFILE "' 07/26/08 1 1 1E-112 12080408 INJECTION PROFILE 07/27/08 1 1 2W-05 12080409 INJECTION PROFILE 07/28/08 1 1 3J-10 12097408 SBHP SURVEY 07/20/08 1 1 3M-28 12097411 SBHP SURVEY <. .- Q( 07/21/08 1 1 1 L-15 11982443 PROD PROFILE .- ~ 07/06/08 1 1 3Q-08A 12080407 SBHP SURVEY zC_ iq'}- l93 I ta'~ 07/26/08 1 1 30-09 12080406 SBHP SURVEY /(p °~-~~ 07/26/08 1 1 i L-24 11978468 PRODUCTION PROFILE j 07/26/08 1 1 1 F-17 12080410 PRODUCTION PROFILE ~ (p 07/29/08 1 1 30-11 12100430 SBHP SURVEY -D~/ a 07/31/08 1 1 2M-06 12100433 INJECTION PROFILE 08/02/08 1 1 iH-~, `1j 12100434 INJECTION PROFILE UZC- 6 '3 ~0 08/03/08 1 1 UGNU DS2-OBi 11996650 TEMPERATURE LOG , 07/27/08 1 1 2X-14 12100432 LDL t 08/01/08 1 1 i F-20 12100435 PRODUCTION P OFILE / 08/04/08 1 1 iH-09 12100436 INJECTION PROFILE U 08/05/08 1 1 Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. • ~~ Schlumberger NO. 3313 Schlumberger -DCS 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 A TTN: Beth Company: Field: Well Job# Log Description Date BL !9() ..1ft:, 7 1A-25 10942816 PRODUCTION PROFILE/DEFT 12/25/04 1 1~...~D-10 10942818 LDL & MUL TIFINGER CALIPER 12/27/04 1 2B if-Iff' 1 E-112 10715441 MPSP PRODUCTION PROFILE 11/12/04 1 JOI ~/:/f 1C-119 10942819 INJECTION PROFILE 12/28/04 1 :lD4...1-¿'71E-104 10942821 PERF RECORD W/SBHP 12/30/04 1 /8h-/Z i' 2T-12A 10922519 PRODUCTION PROFILE/DEFT 01/03105 1 ~()t.("l2.1 .1E-104 10942821 SCMT 12/29/04 2-() If·Z7 , 1 E-1 02 10942815 USIT 12/24104 SIGNED: 7 · I~l. I h ~ ~ ~l>M\\;:;!; L\P~ 1 R 2005 · fI, )¿1)VV"'-U/'-'~"'''''L'O<b'" · ,- .. - " DATE: Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. 1/19/05 JÇp"~~1 Alaska Oil & Gas Cons Comm Attn: Helen Warman 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Kuparuk -",~/ Color CD 1 1 .~ 1-('1- tJ5 THE MATERIAL UNDER THIS COVER HAS BEEN MICROFILMED ON OR BEFORE NOVEMBER 2, 200,.0,,,, P L M ATE R IA L THIS MA. I1 I1 C:LORILMFILM.DOC E E 'E W R K E R UNDER STATE OFALASKA ,, ~. ~ ~ ~ AL,~oKA OIL AND GAS CONSERVATION COlv..,v;ISSlON WELL COMPLETION OR RECOMPLETION REPORT AND LOG I Status of Well Classification of Service Well OIL ~ GAS ['--'] SUSPENDED r-~ ABANDONED 2 Name of Operator 7 Permit Number ARCO Alaska, Inc 90-167 3 Address i8 APl Number P.O. Box 100360, Anchorage, AK 99510-0360 50-029-22116 4 Location of well at surface ~._.._._, 9 Unit or Lease Name At Top Producing Interval il. _ i VE~IFi~g 10 Well Number 2637' FSL, 2650' FEL, SEC 8, T11 N, R10E, UMJ~ ~: '/~ [ 1A-25 At Total Depth So~ 11 Field and Pool 2304' FSL, 2486' FEL, SEC 8, T11 N, R10E,UM KUPARUK RIVER FIELD 5 Elevation in feet (indicate KB, DF, etc.) I 6 Lease Designation and Serial No. KUPARUK RIVER OIL POOL RKB 102', PAD 67'I ADL 25647 ALK 465 12 Date Spudded 13 Date T.D. Reached 14 Date Comp., Susp. or Aband. 15 Water Depth, if offshore 116 No. of Completions 12/21/90. 12/27/90. 6/5/91. N A feet M S LI 1 17 Total Depth (MD+TVD) 18 Plug Back Depth (MD+TVD) 19 Directional Survey 20 Depth where SSSV set 21 Thickness of permafrost 8115' MD, 6474' TVD 8009' MD, 6400' TVD YES X~ NO ~J 1783' feet MD 1500' APPROX 22 Type Electric or Other Logs Run DIL/SFL/ML/CET/CBL/GYRO 23 CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BO'FrOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 16" 62.5# H-40 SURF 115' 24" 224 SX AS I 9-5/8" 36# J-55 SURF 4682' 12-1/4" 1074 SX AS III, 453 SX CLASS G 7" 26# J-55 SURF 8093' 8-1/2" 300 SX CLASS G 24 Perforations open to Production (MD+TVD of Top and Bottom and 25 TUBING RECORD interval, size and number) SIZE DEPTH SET IMD) PACKER SET IMD) 4"? 3-1/2' 7471' 7360' 7776'-7783' W/2-1/" TT @ 8 SPF MD 6234'-6239' 'rVD 7797'-7802' W/2-1/2" TT @ 8 SPF MD 6250'-6252' 'FVD 26 ACID, FRACTURE, CEMENT SQUEEZE, ETC 7802'-7822' W/2-1/2" TT @ 8 SPF MD 6253'-6268' TVD DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 7822'-7842' W/2-1/2" 'Ir @ 8 SPF MD 6268'-6282' 'I'VD 27 PRODUCTION TEST Date First Production IMethod of Operation (Flowing, gas lift, etc.) I Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE I GAS-OIL RATIO I TEST PERIOD Flow Tubing Casing Pressure CALCULATED OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) ~ress. 24-HOUR RATE 28 CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. Form 10-407 ,: 'i~l~t[~?~.~bmit- ~' ""~ ~" in duplicate Rev. 7-1-80 C(~TINUED ON REVERSE SIDE GEOLOGIC MARKERS FORMATION TESTS NNVE Include interval tested, pressure data, all fluids recoverd and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. KUPARUK C TOP 7573' 6080' NA KUPARUK C BOTTOM 7617' 6114' KUPARUK A TOP 7762' $224' KUPARUK A BO'FI'OM 7910' 6331' 31. LIST OF ATTACHMENTS GYRO 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed. / ~,/J~f_J/~ ~"~~ Title AREA DRILLING ENGINEER Date INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1: Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21: Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". Form 10-407 ARCO ALASKA INC. DAILY OPERATIONS WELL: 1A-25 BOROUGH: NORTH SLOPE SPUD: 12/21/90 LEASE: ADL 25647 ALK 465 API: 50-029-22116 PERMIT 90-167 APPROVAL: WI: 55.252072 12/22/90 (1) DRILLING AT 1499' RELEASE: 01/01/91 OPERATION: DRILLING RIG: DOYON 14 MW: 9.3 VIS: 56 PAGE: 1 TD: 1499'(1499) SUPV:JMM 12/23/90 (2) TD: 3970' (2471) SUPV:JMM 12/24/90 (3) TD: 4700' ( .730) SUPV:JMM .12/25/90 (4) TD: 5692' ( 992) SUPV:JMM 12/26/90 (5) TD: 7363'(1671) SUPV:JMM 12/27/90 (6) TD: 7691'( 328) SUPV:PDW ACCEPT RIG ON 1A-25 AT 07:00 HRS 12/21/90. NU DIVERTER, TEST SAME, SPUD AT 14:00 HRS 12/21/90. KICK-OFF AT 600', UNABLE TO BUILD ANGLE WITH.l-i/4 DEGREE BENT HOUSING MOTOR, POOH AND CHANGE BHA TO 2-1/2 DEGREE BENT SUB, DRILL FROM 1413' TO 1499'. DAILY:S81,286 CUM:$81,286 ETD:S81,286 EFC:$1,770,000 REPAIRING DRAWWORKS MW: 9.8 VIS: 54 DRILL FROM 1499' TO 1961', POOH AND LD BENT SUB AND PU BENT HOUSING MOTOR. DRILL FROM 1961' TO 3970', POOH FOR WASHOUT, FOUND WASHOUT IN HWT DP. CO BIT REPAIR CHAIN ON DRAWORKS. DAILY:S51,893 CUM:$133,179 ETD:S133,179 EFC:$1,770,000 CIRC FOR CEMENT JOB 9-5/8"@ 4641' MW: 9.9 VIS: 50 REPAIR CHAIN IN DRAWORKS. RIH AND DRILL FROM 3970' TO 4700'. WIPER TRIP 20 STANDS, POOH AND RUN 109 JTS 9-5/8" 36#, J-55, BTC. FLOAT SHOE AT 4682'. CIRC AND REDUCE YP ON MUD. DAILY:S160,400 CUM:$293,579 ETD:S293,579 EFC:$1,770,000 DRILLING AT 5692' 9-5/8"@ 4641' MW: 9.6 VIS: 38 CIRCAND REDUCE YIELD POINT. CHANGEOUT DOWELL CEMENT HEAD, CEMENT 9-5/8" CSG WITH: 80 BBLS WATER SPACER, 371 BBL (1074 SX) ASIII LEAD CEMENT AT 12.1 PPG, 93 BBL (453 SX) CLASS G TAIL CMENT AT 15.8 PPG, DISPLACE WITH 355 BBL WATER. BUMP PLUG TO 2500 PSI, FLOATS OK. CEMENT RETURNS AT 11.3 PPG, PARTIAL RETURNS DURING JOB. RD DOWELL, ND DIVERTER, NU BOPE TEST SAME TO 3000 PSI. MU TURBINE BHA WITH PDC BIT. RIH, DRILL OUT FLOAT COLLAR AND TEST CASING TO 2000 PSI. DRILL OUT FLOAT SHOE AND 10' OF NEW FORMATION TO 4710' TEST FORMATION TO 12.5 PPG EMW, NO LEAK-OFF. DRILL FROM 4710' TO 5692' DAILY $148,848 CUM:$442,427 ETD:S442,427 EFC:$1,770,000 DROP SS SURVEY 9-5/8"@ 4641' MW:10.2 VIS: 40 DRILL FROM 5692' TO 7363'. CIRC AND DROP SS SURVEY IN PREP TO POOH FOR LOT ABOVE KUPARUK. DAILY:S57,402 CUM:$499,829 ETD:S499,829 EFC:$1,770,000 DRILLING AT 7691' 9-5/8"@ 4641' MW:10.8 VIS: 40 POOH, LD TURBINE, PU ROTARY BHA. RIH TO SHOE, TEST FORMATION INTEGRITY; LEAK OFF AT 11.3 PPG EMW. RIH, CIRC AND MIX LCM (KWIK SEAL MED) AND INCREASE MUD WEIGHT TO 10.8 PPG. POOH TO SHOE AND RETEST FORMATION, HELD GOOD AT 11.5 PPG EMW. RIH AND DRILL FROM 7363' TO 7691' DAILY:S69,885 CUM:$569,714 ETD:$569,71~ EFC:$1,770,00 WELL: 1A-25 OPERATION: .DRILLING RIG: DOYON 14 12/28/90 (7) TD: 8115' ( 424) SUPV:PDW 12/29/90 (8) TD: 8115'( SUPV:PDW o) 12/30/90 (9) TD: 8115'( SUPV:PDW o) 12/31/90 (10) TD: 8115'( SUPV:PDW o) 01/01/91 (11) TD: 8115'( SUPV:PDW o) 01/02/91 (12) TD: 8115' ( 0) SUPV:PDW CIRC, INCR MUD WT 9-5/8"@ 4641' MW:ll.3 VIS: 45 DRILL FROM 7691' TO 7834'. MUD BECAME GAS CUT (10.8 PPG IN AND 9.0 PPG OUT) INCREASE WT TO 11.0 PPG. DRILL TO 7848' AND INCREASE MUD WT TO 11.2 PPG. DRILL TO TD OF 88115' AND INCREASE MUD WT TO 11.4 PPG. INJECTOR lA-9 WAS ON INJECTION AND WAS SHUT-IN LAST NITE DUE TO THESE DRILLING PROBLEMS ON 1A-25. DAILY:S73,902 CUM:$643,616 ETD:S643,616 EFC:$1,770,000 CIRC OUT GAS CUT MUD 9-5/8"@ 4641' MW:ll.5 VIS: 41 INCREASE MUD WT TO 11.5 PPG, CIRC OUT GAS CUT MUD. SHUT-IN INJECTION ON OFFSET WELL lA-9. SHORT TRIP 15 STANDS, RETURNS CUT TO 9 PPG. RIH TO BOTTOM, SHORT TRIP 30 STANDS, RETURNS CUT TO 10 PPG, LOST TOTAL OF 50 BBL MUD WHILE CIRCULATING. DAILY:S135,015 CUM:$778,631 ETD:S778,631 EFC:$1,770,000 CBU AFTER TRIP TO SHOE 9-5/8"@ 4641' MW:ll.8 VIS: 43 CIRC 11.5 PPG MUD, CUT TO 11.0 PPG. INCREASE TO 11.6 PPG, CHECK FOR FLOW- 6 BBLGAIN, BOTTOMS UP GAS CUT TO 10.8 PPG. INCREASE MUD WEIGHT TO 11.7 PPG, BOTTOMS UP GAS CUT TO 10.8 PPG. INCREASE TO 11.8 PPG, CHECK FLOW, NO FLOW. LCM (QUICK SEAL AND COURSE MICA) MIXED WITH INCREASING MUD WEIGHT. POOH TO SHOE, RIH, CBU MUD CUT TO 11.1 PPG. INCREASING MUD WEIGHT TO 11.9 PPG TO PROVIDE TRIP MARGIN. NO LOSSES. DAILY:S66,621 CUM:$845,252 ETD:S845,252 EFC:$1,770,000 RIH TO COND FOR CASING 9-5/8"@ 4641' MW:ll.9 VIS: 42 WT UP TO 11.9 PPG, NO MUD LOSS. POOH TO SHOE, NO FLOW, RIH, CIRC SOME TRIP GAS OFF BOTTOM, MAX CUT TO 11.1 PPG. POOH FOR LOGS, RU HLS, RUN TRIPLE COMBO, RD HLS, RIH TO CONDITION FOR CASING. DAILY:S55,937 CUM:$901,189 ETD:S901,189 EFC:$1,770,000 RIH W/ 7" CASING 7"@ 8093' MW:ll.9 VIS: 42 RIH AFTER LOGGING. CIRC AND. CONDITION WITH MAX GAS CUTTING TO 11.3 PPG. NO MUD LOSS. POOH LDDP. RU AND RUN 7" CASING AT 1-1/2 MIN PER JOINT. UNABLE TO CIRCULATE. DAILY:S190,351 CUM:$1,091,540 ETD:S1,091,540 EFC:$1,770,000 RR AT 15:00 1/1/91 7"@ 8093' MW:ll.9 VIS: 0 FINISH RUNNING 189 JTS 7" 26# J-55 BTC CASING. ONLY PARTIAL RETURNS WHILE RUNNING CASING. UNABLE TO CIRC ON BOTTOM. RECIPROCATE 30', PUMP 10 BBL ARCO PREWASH, 35 BBL ARCO SPACER, 64 BBL DOWELL GAS BLOCK CLASS G CEMENT, DISPLACE WITH 306 BBL 11.9 BRINE. BUMP PLUG TO 2500 PSI AT 09:45. PU BOPE, SET SLIPS INJECT PACKING INTO PACKOFFS, TEST TREE TO 3000 PSI, FREEZE PROTECT 7" X 9-5/8 ANNULUS WITH 80 BBLS OF DIESEL. DAILY:S89,054 CUM:$1,180,594 ETD:S1,180,594 EFC:$1,770,00 PAGE: 2 ARCO ALASKA INC. DAILY OPERATIONS WELL: 1A-25 BOROUGH: NORTH SLOPE LEASE: ADL 25647 ALK'465 API: 50-029-22116 PERMIT 90-167 APPROVAL: WI: 55.252072 ACCEPT: 06/02/91 RELEASE: 06/05/91 OPERATION: COMPLEION RIG: NORDIC PAGE: 1 06/02/91 (13) TD: 8115 PB: 8008 SUPV:GB 06/03/91 (14) TD: 8115 PB: 8008 SUPV:GB 06/04/91 (15) TD: 8115 PB: 8008 SUPV:GB 06/05/91 (16) TD: 8115 PB: 8008 SUPV:GB LOADING PIPE SHED 7"@ 8093' MW:ll.9 NaCl/Br NU BOP'S AND TEST. LOAD PIPE SHED AND STRAP ACCES'S. DAILY:S21,037 CUM:$1,201,631 ETD:S1,201,631 EFC:$1,770,000 POH W/ COMP ASS'Y 7"@ 8093' MW:ll.9 NaCl/Br FINISHED LOADING PIPE SHED. RAN 4" X 3-1/2" COMPLETION ASS'Y. SET PKR @ 7351'. PKR WOULD NOT TEST. SHEAR PBR AND RETEST. RUN PLUG BELOW PKR AND TEST TBG. OK. PKR STILL WOULD NOT TEST. PULL PLUG. PULL AND STAND BACK COMPLETION ASS'Y. DAILY:S31,900 CUM:$1,233,531 ETD:S1,233,531 EFC:$1,770,000 POH 7"@ 8093' MW:ll.9 NaCl/Br POH W/ COMP ASS'Y. PU SPEAR AND GIH. LATCH TIW PACKER. JAR FREE AND POH. MADE BIT AND SCRAPER RUN. DAILY:S28,147 CUM:$1,261,678 ETD:S1,261,678 EFC:$1,770,000 RIG RELEASED 7"@ 8093' MW:ll.7 NaCl/Br FINISH BIT AND SCRAPER RUN. RE-RAN 4" X 3-1/2" SINGLE COMPLETION. SET PACKER @ 7361'. TEST PACKER. OK. TEST SSSV. OK. ND BOP STACK AND NU TREE. TEST TREE. OK. FREEZE PROTECT WELL. RELEASE RIG @ 0400 HRS 6-5-91. DAILY:S240,252 CUM:$1,501,930 ETD:S1,501,930 EFC:$1,770,000 SIGNATURE: DATE: o 1 17Lo o 2 i 6 o · 25C 7 ,o 26J /27~: /~° 18 / DS 1H 34 VICINITY MAP NOTES: 1. BASIS OF LOCATION AND ELEVATION IS D.S. MONUMENTATION PER LOUNSBURY & ASSOCIATES. 2. ELEVATIONS SHOWN ARE BRITISH PETROLEUM MEAN SEA LEVEL. ,.7.COORDINATES SHOWN ARE A.S.P. ZONE 4, N.A.D. 27. 4. LOCATED WITHIN PROTRACTED SECTION 5, T 11 N, R 10 E, UMIA T MERIDIAN, ALASKA. NO. Y X LAT. LONG. F.S.L. F.W.L. O.C. PAD 17L 5971570.96 540180.24 18A 5971251.02 540180.20 19H 5971203.06 540180.24 20M 5971179.05 540180.17 21G 5971155.00 540180.25 228 5971130.99 540180.19 231 5971011.10 540180.26 24F 5970915.06 540180.25 25C 5970819.08 540180.28 26J 597072,'7.13 540180.21 27E 5970699.09 540180.20 28D 5970675.10 540180.27 70'19'57.794" 149' 40'~6.654" 1283' 315' 59.6' 67.0' 70' 19'56.614" 149' 40'26.654" 1165' 514' 61.0' 66.5' 70'19'56.143" 149'40'26.660" 1115' ,:714' 61.7' 66.8' 70"19'55.906" 149' 40'26.666" 1091' 514' 62.0' 67.0' 70'19'55.670' 149" 40'26.667" 1067' ,.714' 62.4' 66.9' 70'19'55.4,:74" 149' 40'26.675" 104,.7' 315' 62.8' 67.0' 70' 19'54.255" 149" 40'26.689" 923.7' 512' 63.8' 66.,7,' 70' 19'53:7.310" 149' 40'26. 705" 827' 311' 64. 0' 66.7' 70'19'52.$66" 149'40'26.719" 731' ,:711' 65.3,' 67.0' 70' 19'51.422" 149' 40'26. 736" 635' 310' 62. 7' 67.2' 611' ,310' 62.5' 67.,:7' 587' 309' 62.4' 67.2' ~-~...-...._~ SUR~YOR'S CER~FICA ~' ~-,,*,,.,~ ..... 4e · e~e eeeee~eeeee ee ee~e · e~ REGI~RED AND LICENSED TO PRAC~CE LAND $UR~NG IN ~E STA~ OF ALASKA AND ~A T ~IS PLA T REPRESENTS A su~Y DoNE BY ~ OR UNDER ~Y DIRECT SUPERWSION, AND ~A T ALL DIMENSIONS ~'~ AND O~ER DETAILS ARE CORRECT AS OF OCTOBER 23, Iggo. 0/30/90 Change F.N.L. fo F.S.L. Date Description ARCO ALASKA, INC. D WG# NSDK- 1AOO-CEA-D1AX-6101D10 ARCO Alaska,Inc. DRILL SITE 1-A WEll CONDUCTOP.$ #17-#28 AS-BU/L. 7 LOUNSBURY & ASSOC. Dr. DC$ A,.~¥'.; REV. / Dote: 10/26/901Dwg: NSK 6.101d70 A Gy~:odata Di~'~ectionai._,CuPvey FC] I'"' Not-th Slo~e B_~.~eau, Alasi.:;a Submitted By: Gy~-odata Set-vices,, !nc. 3105 Lakesho~.-e DI.-,,. A-304. Anchor. a:'~e. Alaska 995J. 7 ....... ~-.. ,-, .= .............. / ~, .m L~ "'" 064....~ REAT LAND lient .... : ield ..... : ell · ection at: urveyors.: DIRECTIONAL DRILLING, INC. for Gyrodata Services, Inc. ARCO ALASKA, INC. KUPARUK RIVER UNIT KRU 1A-25 S,35.95,E T. STODDARD/J.C. STUART MEAS INCLN DEPTH ANGLE 0 0.00 100 0.14 200 0.08 300 0.13 400 0.04 500 0.09 600 0.52 700 3.03 800 7.12 900 9.25 1000 10.66 1100 11.43 .200 12.70 1300 13.89 1400 14.80 1500 19.03 1600 23.57 1700 28.30 1800 32.59 1900 36.89 2000 39.03 VERTICAL-DEPTHS BKB SUB-SEA 0.0. -102.0 100.0 -2.0 200.0 98.0 300.0 198.0 400.0 298.0 500.0 398.0 600.0 498.0 699.9 597.9 799.5 697.5 898.5 796.5 997.0 895.0 1095.1 993.1 1192.9 1090.9 1290.3 1188.3 1387.1 1285.1 1482.8 1380.8 1575.9 1473.9 1665.8 1563.8 1752.0 1650.0 1834.2 1732.2 1913.0 1811.0 7/GYRO ~urvey Codes: ~(RU1A25G) 01/24/91 Computation...: Survey Date...: RKB Elevation.: Job Number .... : API Number .... : RADIUS OF CURVATURE 01/04/91 102.00 ft AK0191G264 50-029-22116 RECORD OF SURVEY SECTION DIRECTION DISTNCE BEARING 0.0 N 0.00 E -0.1 N 32.19 W -0.3 N 17.40 W -0.5 N 15.75 W -0.'6 N 18.50 W RELATIVE-COORDINATES FROM-WELL-HEAD CLOSURE DL DISTNCE BEARING /100 0.0 N 0.0 E 0.0 N 90.00 E 0.00 0.1 N 0.0 W 0.1 N 16.10 W 0.14 0.3 N 0.1 W 0.3 N 21.43 W 0.06 0.5 N 0.2 W 0.5 N 19.63 W 0.05 0.6 N 0.2 W 0.6 N 19.05 W 0.09 -0.7 N 50.77 W 0.7 N 0.3 W 0.8 N 21.35 W 0.05 -0.7 S 29.55 E 0.5 N 0.6 W 0.7 N 50.96 W 0.43 2.4 S 43.95 E 2.0 S 1.3 E 2.4 S 32.50 E 2.51 11.2 S 38.84 E 8.7 S 7.1 E 11.2 S 39.50 E 4.09 25.4 S 36.91 E 19.9 S 15.9 E 25.4 S 38.59 E 2.13 42.7 S 36.05 E 33.8 S 26.2 E 42.7 S 37.74 E 1.41 61.9 S 34.62 E 49.4 S 37.2 E 61.9 S 36.99 E 0.77 82.8 S 34.32 E 66.6 S 49.1 E 82.8 S 36.36 E 1 27 ( 105.7 S 35.19 E 85.5 S 62.2 E 105.7 S 36.01 E 1~19 130.5 S 34.84 E 105.8 S 76.4 E 130.5 S 35.82 E 0.91 159.6 S 32.28 E 130.1 S 92.5 E 159.6 S 35.41 E 4.24 195.8 S 31.27 E 160.9 S 111.6 E 195.8 S 34.73 E 4.54 239.3 S 28.57 E 198.8 S 133.4 E 239.4 S 33.86 E 4.77 289.5 S 28.65 E 243.3 S 157.7 E 289.9 S 32.94 E 4.29 346.0 S 28.97 E 293.2 S 185.1 E 346.8 S 32.26 E 4.30 407.2 S 30.17 E 346.7 S 215.5 E 408.2 S 31.86 E 2.19 ',U 1A-25 RECORD OF SURVEY Page 2 01/24/91 MEAS INCLN DEPTH ANGLE 2100 43.29 2200 45.89 2300 46.70 2400 46.96 2500 47.19 2600 46.37 2700 46.37 2800 45.94 2900 44.56 3000 43.45 3100 42.91 3200 42.59 3300 42.11 3400 41.14 3500 41.31 VERTICAL-DEPTHS SECTION DIRECTION RELATIVE-COORDINATES BKB SUB-SEA DISTNCE BEARING FROM-WELL-HEAD 1988.3 1886.3 472.8 S 34.06 E 402.4 S 250.4 E 2059.5 1957.5 543.0 S 37.00 E 459.6 S 291.2 E 2128.6 2026.6 615.3 S 37.83 E 517.0 S 335.1 E 2197.0 2095.0 688.2 S 37.66 E 574.7 S 379.8 E 2265.1 2163.1 761.4 S 37.67 E 632.6 S 424.5 E 2333.6 2231.6 834.1 S 39.81 E 689.5 S 470.1 E 2402.6 2300.6 906.4 S 38.86 E 745.4 S 516.0 E 2471.9 2369.9 978.4 S 38.33 E 801.8 S 561.0 E 2542.3 2440.3 1049.4 S 38.30 E 857.5 S 605.0 E 2614.2 2512.2 1118.8 S 38.24 E 912.1 S 648.1 E 2687.1 2585.1 1187.2. S 37.76 E 966.0 S 690.2 E 2760.5 2658.5 1255.1 S 36.88 E 1020.0 S 731.3 E 2834.4 2732.4 1322,4 S 36.30 E 1074.1 S 771.5 E 2909.2 2807.2 1388,8 S 36.27 E 1127.6 S 810.8 E 2984.4 2882.4 1454.7 $ 35.63 E 1181.0 S 849.5 E 3600 41.52 3059.4 2957.4 3700 42.03 3134.0 3032.0 3800 41.99 3208.3 3106.3 900 42.20 3282.5 3180.5 4000 41.93 3356.7 3254.7 4100 41.71 4200 41.45 4300 41.32 4400 41.05 4500 40.80 4600 40.75 1520.9 S 36.05 E 1587.5 S 36.83 E 1654.4 S 36.76 E 1721.5 S 35.56 E 1788.5 S 34.97 E 1234.6 S 888.2 E 1288.2 S 927.8 E 1341.8 S 967.9 E 1395.9 S 1007.4 E 1450.6 S 1046.1 E 3431.2 3329.2 1855.1 S 34.46 E 1505.4 S 1084.1 E 3506.0 3404.0 1921.5 S 33.86 E 1560.3 S 1121.4 E 3581.1 3479.1 1987.5 S 32.42 E 1615.7 S 1157.5 E 3656.3 3554.3 2053.2 S 31.89 E 1671.4 S 1192.5 E 3731.9 3629.9 2118.5 S 32.25 E 1726.9 S 1227.3 E 3807.6 3705.6 2183.7 S 31.59 E 1782.4 S 1261.9 E CLOSURE DL DiSTNCE BEARING /100 474.0 S 31.89 E 4.64 544.1 S 32.36 E 3.01 616.1 S 32.95 E 0.92 688.8 S 33.46 E 0.28 761.9 S 33.86 E 0.23 834.5 S 34.29 E 1.39 906.6 S 34.69 E 0.50 978.6 S 34.98 E 0.51 1049.5 S 35.21 E 1.38 1118.9 S 35.40 E 1.11 1187.2 S 35.55 E 0.58 1255.1 S 35.64 E 0.51 1322.4 S 35.69 E 0.55 1388.8 S 35.72 E 0.97 1454.8 S 35.73 E 0.33 1520.9 S 35.73 E 0.28 1587.5 S 35.76 E 0.62 1654.4 S 35.80 E 0.05 1721.5 S 35.82 E 0.58 1788.5 S 35.80 E 0.38 1855.1 S 35.76 E 0.32 1921.5 S 35.70 E 0.37 1987.5 S 35.62 E 0.64 2053.2 S 35.51 E 0.35 2118.6 S 35.40 E 0.29 2183.8 S 35.30 E 0.29 lrvey Codes: 7/GYRO ~<RU 1A-25 MEAS DEPTH 4700 4800 4900 3000 5100 INCLN VERTICAL-DEPTHS ANGLE BKB SUB-SEA 40.06 3883.8 3781.8 40.53 3960.0 3858.0 40.96 4035.8 3933.8 40.89 4111.4 4009.4 40.96 4186.9 4084.9 5200 41.39 4262.2 4160.2 5300 41.38 4337.2 4235.2 5400 41.47 4412.2 4310.2 5500 41.76 4487.0 4385.0 5600 41.87 4561.5 4459.5 5700 42.06 4635.8 4533.8 5800 42.34 4709.9 4607.9 5900 42.46 4783.8 4681.8 6000 43.01 4857.2 4755.2 6100 43.45 4930.1 4828.1 6200 41.83 5003.6 4901.6 6300 41.57 5078.3 4976.3 6400 41.73 5153.0 5051.0 500 41.69 5227.7 5125.7 6600 41.71 5302.3 5200.3 6700 42.09 5376.8 5274.8 6800 38.43 5453.1 5351.1 6900 38.23 5531.5 5429.5 7000 35.28 5611.6 5509.6 o7100 34.13 5693.8 5591.8 7200 34.33 5776.5 · ~urvey Codes: 7/GYRO 5674.5 RECORD OF SURVEY SECTION DISTNCE 2248.3 2312.8 2377.9 2443.3 2508.8 2574.6 2640.6 2706.7 2773.1 2839.7 2906.4 2973.5 3040.9 3108.7 3177.1 3244.8 3311.3 3377.7 3444.2 3510.7 3577.5 3642.1 3704.1 3763.9 3820.8 3877.1 DIRECTION BEARING S 31.94 E S 31.41 E S 31.73 E S 33.63 E S 34.08 E S 33.47 E S 33.43 E S 33.87 E S 33.26 E S 32.80 E RELATIVE-COORDINATES FROM-WELL-HEAD 1837.5 S 1296.0 E 1892.5 S 1329.9 E 1948.1 S 1364.1 E 2003.3 S 1399.5 E 2057.7 S 1436.0 E 2112.4 S 1472.6 E 2167.5 S 1509.0 E 2222.6 S 1545.7 E 2278.0 S 1582.4 E 2333.9 S 1618.7 E S 32.52 E 2446.2 S 1691.8 E S 33.95 E 2502.6 S 1728.7 E S 33.30 E 2559.1 S 1766.3 E S 32.60 E 2616.6 S 1803.6 E S 34.67 E 2673.0 S 1841.1 E S 35.07 E 2727.6 S 1879.1 E S 34.90 E 2782.0 S 1917.2 E S 34.58 E 2836.7 S 1955.1 E S 34.02 E 2891.7 S 1992.6 E S 33.77 E 2947.1 S 2029.9 E S 36.88 E 2999.8 S 2067.2 E S 37.37 E 3049.3 S 2104.7 E S 36.10 E 3097.2 S 2140.4 E S 35.07 E 3143.5 S 2173.6 E S 34.09 E 3189.8 S 2205.5 E Page 3 01/24/91 CLOSURE DiSTNCE BEARING 2248.5 S 35.20 E 2313.1 S 35.10 E 2378.2 S 35.00 E 2443.7 S 34.94 E 2509.2 S 34.91 E /loo 0.71 0.52 0.45 0.82 0.21 2575.0 S 34.88 E 0.51 2641.1 S 34.85 E 0.02 2707.2 S 34.82 E 0.21 2773.6 S 34.79 E 0.40 2840.3 S 34.74 E 0.23 2907.1 S 34.71 E 2974.3 S 34.67 E 3041.7 S 34.64 E 3109.5 S 34.61 E 3178.0 S 34.58 E 0.33 0.48 0.66 0.63 O.55 3245.7 S 34.56 E 1.86 3312.2 S 34.56 E 0.31 3378.7 S 34.57 E 0.18 3445.2 S 34.58 E 0.15 3511.7 S 34.57 E 0.25 3578.5 S 34.56 E 3643.1 S 34.57 E 3705.1 S 34.61 E 3764.9 S 34.65 E 3821.8 S 34.66 E 3878.0 S 34.66 E 0.40 3.85 0.27 2.98 1.19 0.37 KRU 1A-25 Page 4 01/24/91 RECORD OF SURVEY MEAS INCLN DEPTH ANGLE 7300 33.99 7400 35.00 7500 37.02 7600 39.24 7700 41.08 VERTICAL-DEPTHS BKB SUB-SEA SECTION DISTNCE 5859.3 5757.3 3933.2 5941.7 5839.7 3989.7 6022.6 5920.6 4048.3 6101.2 5999.2 4109.4 6177.6 6075.6 4172.9 DIRECTION BEARING S 33.44 E S 33.14 E S 28.61 E S 26.39 E S 26.31 E RELATIVE-COORDINATES FROM-WELL-HEAD 3236.5 3283.8 3334.3 3389.1 3446.8 CLOSURE DiSTNCE BEARING 7 7800 42.83 6252.0 6150.0 4238.9 7 7900 44.58 6324.3 6222.3 4307.0 7 7979 46.05 6379.8 6277.8 4362.3 X 8115 46.05 6474.2 6372.2 4458.8 S 26.72 E S 25.72 E S 26.31 E S 26.31 E 3506.7 S 3568.6 S 3619.1 S 3706.9 S 2236.7 E 3934.2 S 34.65 E 2267.8 E 3990.8 S 34.63 E 2298.0 E 4049.5 S 34.57 E 2326.5 E 4110.7 S 34.47 E 2355.1 E 4174.6 S 34.34 E ^Survey Codes: 7/GYRO X/EXTRAPOLATED 2384.9 E 2415.5 E 2440.1 E 2483.5 E 4240.8 S 34.22 E 4309.3 S 34.09 E 4364.9 S 33.99 E 4461.9 S 33.82 E DL /lOO 0.40 1.01 2.60 2.39 1.84 1.76 1.82 1.90 0.00 KRU lA-25 Page DATA INTERPOLATED FOR 100 FT SUBSEA INTERVAL 5 01/24/91 SUBSEA DEPTH -100 0 100 30 ~00 400 500 600 700 80O 900 1000 1100 1200 1300 1400 1500 1600 i ~0 1900 2000 2100 2200 2.300 2400 MEAS DEPTH 2 102 202 302 402 502 602 702 802 904 1005 1107 1209 1312 1415 1520 1629 1741 1860 1986 2119 2261 2407 2554 2699 2843 INCLN TVD MD-TVD VERT DIRECTION ANGLE BKB DIFF CRRT BEARING 0.00 2 0 0 N 32.19 W 0.14 102 0 0 N 31.89 W 0.08 202 0 0 N 17.37 W 0.13 302 0 0 N 15.81 W 0.04 402 0 0 N 19.15 W 0.10 502 0 0 N 53.95 W 0.57 602 0 0 S 29.84 E 3.11 702 0 0 S 43.84 E 7.17 802 0 0 S 38.79 E 9.30 902 2 1 S 36.88 E 10.70 1002 3 2 S 35.98 E 11.52 1102 5 2 S 34.60 E 12.81 1202 7 2 S 34.40 E 14.00 1302 10 3 S 35.15 E 15.45 1402 13 3 S 34.45 E 19.96 1502 18 5 S 32.07 E 24.92 1602 27 8 S 30.50 E 30.08 1702 39 13 S 28.60 E 35.18 1802 58 19 S 28.84 E 38.73 1902 84 26 S 30.00 E 43.78 2002 117 33 S 34.62 E 46.39 2102 159 42 S 37.51 E 46.98 2202 205 46 S 37.66 E 46.75 2302 252 47 S 38.83 E 46.37 2402 297 45 S 38.87 E 45.35 2502 341 44 S 38.32 E RELATIVE COORDINATES FROM WELL HEAD 0.00 N 0.00 W 0.12 N 0.04 W 0.29 N 0.11 W 0.47 N 0.17 W 0.61 N 0.21 W 0.70 N 0.28 W 0.44 N 0.55 W 2.10 S 1.36 E 8.89 S 7.33 E 20.35 S 16.22 E 34.55 S 26.70 E 50.56 S 38.02 E 68.34 S 50.22 E 87.93 S 63.85 E 109.14 S 78.67 E 135.83 S 96.09 E 171.02 S 117.61 E 216.58 S 143.06 E 272.74 S 173.79 E 339.04 S 211.01 E 413.20 S 257.78 E 494.77 S 318.00 E 578.89 S 383.06 E 663.65 S 449.00 E 744.96 S 515.62 E 825.99 S 580.11 E KRU lA-25 Page 6 DATA INTERPOLATED FOR 100 FT SUBSEA INTERVAL 01/24/91 SUBSEA MEAS INCLN DEPTH DEPTH ANGLE TVD BKB 2500 2983 43.64 2602 2600 3120 42.84 2702 ~700 3256 42.32 2802 00 3390 41.23 2902 2900 3523 41.36 3002 3000 3657 41.81 3102 3100 3792 41.99 3202 3200 3926 42.13 3302 3300 4061 41.80 3402 3400 4195 41.46 3502 3500 4328 41.24 3602 3600 4460 40.90 3702 3700 4593 40.75 3802 3800 4724 40.17 3902 3900 4855 40.77 4002 4000 4988 40.90 4102 4100 5120 41.05 4202 4~00 5253 41.38 4302 ]0 5386 41.46 4402 4~00 5520 41.78 4502 4500 5654 41.97 4602 4600 5789 42.31 4702 4700 5925 42.60 4802 4800 6061 43.28 4902 ,4900 6198 41.87 5002 5000 6332 41.62 5102 MD-TVD VERT DIRECTION RELATIVE COORDINATES DIFF CRRT BEARING FROM WELL HEAD 381 40 S 38.25 E 902.97 S 640.89 E 418 37 S 37.58 E 976.94 S 698.64 E 454 36 S 36.55 E 1050.38 S 754.02 E 488 34 S 36.27 E 1122.53 S 807.08 E 521 33 S 35.73 E 1193.52 S 858.52 E 555 34 S 36.49 E 1265.14 S 910.66 E 590 35 $ 36.77 E 1337.24 S 964.50 E 624 35 S 35.40 E 1410.28 S 1017.70 E 659 34 S 34.66 E 1483.90 S 1069.28 E 693 34 S 33.89 E 1557.35 S 1119.36 E 726 33 S 32.27 E 1631.19 S 1167.33 E 758 33 S 32.11 E 1705.06 S 1213.56 E 791 32 $ 31.64 E 1778.24 S 1259.32 E 822 31 S 31.81 E 1850.52 S 1304.09 E 853 31 S 31.59 E 1923.23 S 1348.76 E 886 32 S 33.39 E 1996.50 S 1395.00 E 918 32 S 33.96 E 2068.53 S 1443.31 E 951 33 S 33.45 E 2141.65 S 1491.92 E 984 33 S 33.81 E 2215.14 S 1540.66 E 1018 34 S 33.17 E 2289.20 S 1589.75 E 1052 34 S 33.12 E 2364.38 S 1638.53 E 1087 35 S 32.61 E 2440.16 S 1687.90 E 1123 35 S 33.79 E 2516.52 S 1738.06 E 1159 37 S 32.87 E 2594.31 S 1789.23 E 1196 36 S 34.62 E 2671.80 S 1840.26 E 1230 34 S 35.02 E 2744.81 S 1891.20 E KRU 1A-25 Page 7 DATA INTERPOLATED FOR 100 FT SUBSEA INTERVAL 01/24/91 SUBSEA MEAS INCLN DEPTH DEPTH ANGLE TVD BKB 5100 6466 41.70 5202 5200 6600 41.71 5302 5300 6734 40.86 5402 00 6862 38.31 5502 ~00 6988 35.63 5602 5600 7110 34.15 5702 5700 7231 34.23 5802 5800 7352 34.51 5~02 5900 7474 36.50 6002 6000 7601 39.26 6102 6100 7732 41.65 6202 6200 7869 44.03 6302 6300 8011 46.05 6402 MD-TVD VERT DIRECTION RELATIVE COORDINATES DIFF CRRT BEARING FROM WELL HEAD 1264 34 S 34.69 E 2817.89 S 1942.14 E 1298 34 S 34.02 E 2891.42 S 1992.46 E 1332 34 S 34.82 E 2965.53 S 2042.44 E 1360 29 S 37.19 E 3030.74 S 2090.56 E 1386 26 S 36.25 E 3091.68 S 2136.40 E 1408 22 S 34.97 E 3148.05 S 2176.76 E 1429 21 S 33.89 E 3204.23 S 2215.22 E 1450 21 S 33.28 E 3260.81 S 2252.72 E 1472 23 S 29.77 E 3320.89 S 2290.46 E 1499 27 S 26.39 E 3389.62 S 2326.75 E 1530 31 S 26.44 E 3466.06 S 2364.62 E 1567 36 S 26.03 E 3549.06 S 2405.96 E 1609 42 S 26.31 E 3639.72 S 2450.28 E KRU 1A-25 Page 8 DATA INTERPOLATED FOR 1000 FT MEASURED DEPTH INTERVAL 01/24/91 MEAS INCLN VERT-DEPTHS SECT DIRECTION REL-COORDINATES DEPTH ANGLE BKB SUB-S DIST BEARING 0 0.00 0 -102 0 N 0.00 E 0 N 900 10.66 997 895 43 S 36.05 E 34 S z000 39.03 1913 1811 407 S 30.17 E 347 S 3000 43.45 2614 2512 1119 S 38.24 E 912 S 4000 41.93 3357 3255 1788 S 34.97 E 1451 S 5000 40.89 4111 4009 2443 S 33.63 E 2003 S 6000 43.01 4857 4755 3109 S 33.30 E 2559 S 7000 35.28 5612 5510 3764 S 36.10 E 3097 S 8000 46.05 6394 6292 4377 S 26.31 E 3633 S CLOSURE FROM-WELLHEAD DIST BEARING 100 0 E 0 N 90.00 E 0.0 26 E 43 S 37.74 E 1.4 215 E 408 S 31.86 E 2.2 648 E 1119 S 35.40 E 1.1 1046 E 1788 S 35.80 E 0.4 1399 E 2444 S 34.94 E 0.8 1766 E 3110 S 34.61 E 0.6 2140 E 3765 S 34.65 E 3.0 2447 E 4380 S 33.96 E 0.0 01/24/91 by GREAT LAND DIRECTIONAL DRILLING, INC. for Gyrodata Services, Inc. Client .... : ARCO ALASKA, INC. Field ..... : KUPARUK RIVER UNIT Well ...... : KRU 1A-25 Section at: S,35.95,E Surveyors.: T. STODDARD/J.C. STUART Computation...: RADIUS OF CURVATURE Survey Date...: 01/04/91 RKB Elevation.: 102.00 ft Job Number .... : AK0191G264 API Number .... : 50-029-22116 INTERPOLATED MARKERS REPORT Surface Location: 731 NSL 311 EWL S5 T11N R10E MARKER MEAS INCLN IDENTIFICATION DEPTH ANGLE KB 0 0.00 9-5/8" CASING 4682 40.18 TOP KUPARUK C 7573 38.64 BASE KUPARUK C 7617 39.55 TOP KUPARUK A 7762 42.17 BASE KUPARUK A 7" CASING PROJECTED TD 7910 44.77 8093 46.05 8115 46.05 VERT-DEPTHS SECT BKB SUB-S DIST DIRECTION REL-COORDINATES BEARING FROM-WELLHEAD 0 -102 3870 3768 6080 5978 6114 6012 6224 6122 0 N 0.00 E 2237 S 31.88 E 4093 S 26.99 E 4120 S 26.38 E 4214 S 26.56 E 0 N 0 E 1828 S 1290 E 3374 S 2319 E 3399 S 2331 E 3484 S 2373 E 6331 6229 6459 6357 6474 6372 4314 'S 25.79 E 4443 S 26.31 E 4459 S 26.31 E 3575 S 2419 E 3693 S 2476 E 3707 S 2483 E $reat Land DirectYonal Drilling, <KB>O 45O 9OO t350 t800 2250 '2700 3i50 3600 4050 4500 495O 5400 5850 6300 6750 7200 7650 8i00 450 VERTICAi SECTION __ ,~ ...... v~nlzu~ O~l ~IV ARCO ALASKA, INC. ...... KRU IA-25 Section at: S 35.95 E TVD Scale.' ! inch = 900 feet i ~ Dep Scale.' ! inch = 900 feet _ Drawn · 0t124/9t WarkeP Iden~ifica~ion MD TVD 9ECTN I A) KB 0 0 0 ~ B) PROJECTED TD 8ii5 6474 4459 4 \ ~ ' , X _ .,, \ . , ...... .... , i .............. INCLN 0.00 .05 0 450 900 t350 i800 2250 2700 3i50 q600 4050 4500 Section Departure Great Land Directional Drilling. Inc. Harker ~dentlflcatlon ~ HIS F../H A] KB 0 0 H 0 E BI PROJECTED 'ID 8i15 3707 S 2483 E PLAN VIEW ARCO ALASKA, INC. KRU tA-25 CLOSURE .....: 4462 ft S 33.82 E DECLINATION.: 0.00 E SCALE .......: ! inch = 600 feet DRAWN .......: 01/24/9! 300 0 300 600 900 t200 1500 1800 2i00 2400 2700 3000 3300 3600 3900 300 0 300 <- WEST · FAST -> 600 900 i200 i500 tSO0 2i00 2400 2700 3000 3300 , cored. L;inteffals core analysis ~p~ ~ dit~ intemls ff~¢di~itai~,data .., Ill I L I LOG '"'"'"=, RUN il' ,T]'E-RvALs ,"., sCALE ... NO. (to the nearest foot~. [inch,100 6) ~+P--I- bFc I- O- 3~"IA '..' ~.: . , i i -121 . 131 . , 14] :.,. .. - ... : .:,. · . . ~71 .. I II ~ I II I I ALASKA OIL AND GAS CONSERVATION COMMIboION REPORT OF SUNDRY WELL OPERATIONS Plugging 1. Operations Performed: Operation Shutdown __ Pull tubing Alter casing Stimulate X Repair well Perforate Other 2, Name of Operator ARCO Alaska. Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510 5. Type of Well: Development X Exploratory _ Stratigraphic _ Service 4. Location of well at surface 731' FSL, 311' FWL, Sec. 5, T11N, R10E, UM At top of productive interval 2637' FSL, 2650' FEL, Sec. 8, T11N, R10E, UM At effective depth 2372' FSL, 2519' FEL, Sec. 8, T11N, R10E, UM At total depth 2304' FSL~ 2486' FEL, Sec. 8, T11N, R10E, UM 12. Present well condition summary Total Depth: measured true vertical 811 5' feet 6474' feet Plugs (measured) 6. Datum elevation (DF or KB) 102' RKB 7. Unit or Property name Kuparuk River Unit 8. Well number 1A-25 9. Permit number/approval number 90-167 10. APl number 50-029-22116 11. Field/Pool Kuparuk River Oil Pool foot Effective depth: measured 8009' feet true vertical 6400' feet Junk (measured) Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: Length Size 115' 16" 4682' 9 5/8" 8093' 7" Cemented 224 Sx AS I 1074 Sx AS Iil & 453 Sx Class G 300 Sx Class G measured 7776'-7783',7797'-7842' true vertical 6234'-6239',6250'-6282' Tubing (size, grade, and measured depth) 4" 11#, J-55, 3688';3 1/2" 9.3#, J-55, Packers and SSSV (type and measured depth) SSSV: Camco TRDP-4A, 2582', Packer: 13. Stimulation or cement squeeze summary Fractured A Sand on 9/10/91 Intervals treated (measured) 7762'-7910' 14. Measured depth 115' 4682' 8093' True vertical depth 115' 3870' 6459' RECEIVED 7471' Baker HB, 7361' ,~iaska 0il & Gas Cons. 6ommissJ0a Treatment description including volumes used and final pressure 16 M# of 16/20, 119 M# of 12/18, and 15 M# of 10/14 Carbolite into A Sand, 6200 psi Representative Daily Average Production or Injection Dat~ OiI-Bbl Gas-Mcr Water-Bbl Casing Pressure Tubing Pressure Prior to well operation - 0- - 0- 0- - 0- 200 Subsequent to operation 4000 1600 450 -0- 250 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations X 16. Status of well classification as: Water Injector ~ Oil X Gas Suspended Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Si~ned Title Date Form 10-404 Rev 09/12/90 SUBMIT IN DUPLICATE _F_RA(~/ST.!tI~LAT ION S.U:~..,ARY_ ~L NO: . ¥ ~ - :a S AF'E: ~'? ~ / ~[ Procedure Date' _._ ~-~-~{ __ Begin Frac: Service Co' ~~~~ ___ Zone: Annulus Press' =-, ~~0 Tes~ Lines To: ~4 P01 STAGE VOL FLUID PROP RATE PRESSURE 7- '/.'50 __ _-q t, yo ,, !a. __ /Ho I¢ ,t ISlP' 15 Min: Fluid to Recover: Anchora¢ Avg Press: Sand Zn Zone: Sand In Csg: ~'.OZ,_.O~, .L Job Complete: / ~0__ m,~ll~,--- TA/mjk/3100/104 2/27187 Rig S'upervisOr - / 0 ' ARCO Alaska, Inc. Date: April 5, 1991 Transmittal #: 8058 RETURN TO: ARCO Alaska, Inc. ATTN: Maria Trevithick Kuparuk Operations File Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted here with are the following items. Please acknowledge receipt and return one signed copy of this transmittal. 1 A- 2 5 Acoustic Cement Bond Log 1 - 3 - 9 1 4 9 71 - 7 9 8 0 1 A - 2 5 Pulse Echo Cement Evaluation Log I - 3 - 9 1 4 9 8 2 - 7 9 8 2 Acknowledge' ~~~~~O a t e · Receipt Drilling State ~ Alaska' NSK RECEIVED APF~ 9 ~9~1 Anchorage ARCO Alaska, Inc. Date: January 18, 1991 Transmittal #: 7986 RETURN TO: ARCO Alaska, Inc. Attn: Maria Trevithick Kuparuk Operations File Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted here with are the following Open hole items. Please acknowledge receipt and return one signed copy of this transmittal. 1L-19 1L-19 1A-25 1A-25 1 -6-90 4767-8814 1 -6-90 4767-8786 12-31-90 0-8112 12-31-90 0-8112 1 L- 1 9 Dual Induction (2" Phasor) 1 - 6 - 91 4 76 7- 881 4 1 L-1 9 Cyberlook 1 -6-91 8050-8780 1 L-19 Compensated-Neutron- Litho- 1 - 6 - 9 0 4 767- 8786 Density (Raw Data) Compensated-Neutron- Litho- Density (Porosity) Dual Induction (5" Phasor) High Resolution Induction DFL 5"=100' High Resolution Induction DFL 2"=100' High Resolution Induction DFL Raw Data Log 1A-25 Microlog 1 2-31 -90 7350-8064 1 A- 25 Spectral Density Dual Spaced 1 2 - 31 - 9 0 4 650- 8045 Neutron Raw Log 1 A - 25 Spectral Density Dual Spaced 1 2 - 31 - 90 4 650 - 8045 Neutron Porosity Log 1 A-25 Spectral Density Dual Spaced 12-31-90 7350-8046 Neutron High Resolution Pass 1A-25 1 2-31 -90 0-81 1 2 RE£-EtVED DISTRIBUTION: D&M Drilling Franzen JAN 2 2 1991 Alaska 0il & Gas Cons. Commission] Anchor, age Vendor Package(Johnston~ NSK State of Alaska(+Sepia) RECEIVED JAN ~ ~ !991 Aia,~ka Oil & (~:~s Co~s. L;ommission Anchorage ARCO Alaska, Inc. Date: January 18, 1991 Transmittal #: 7987 RETURN TO: ARCO Alaska, Inc. Attn: Maria Trevithick Kuparuk Operations File Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted here with are the following items. one signed copy of this transmittal. 1A-25 1L-12 1L-12 Receipt Please acknowledge receipt and return LIS Tape and Listing 1 2 - 3 1 - 9 0 4 6.2 5 - 81 3 4 LIS Tape and Listing 1 2- 1 3-90 0-81 52.50 LIS Tape and Listing 1 2- 1 3- 9 0 7 4 7 3- 7 9 0 0 ~'1 Acknowledged' -'~-~ ........ Date' - ......... DISTRIBUTION: Lynn Goettinger State of Alaska RECEIVED jAN 2 2.. 1991 Alaska Oil & Gas Cons, Commission Anchorage December 14, 1990 Telecopy, (907)276-7542 A. Wayne McBride Area Drilling Engineer ARCO Alaska, Inc. P. O. Box 100360 Anchorage, Alaska 99510-0360 Re: Kupa~ River Unit IA-25 ARCO Alaska, Inc. Permit No. 90-167 Sur. Loc. 731'FSL, 311'FWL, Sec. 5, TllN, R10E, U~. Btmhole Loc. 2345'FSL, 2311'FEL, Sec. 8, TllN, R10E, UM. Dear Mr. McBride: Enclosed is the approved application for permit to drill the above referenced ~11. The pe~lt to drill does not exempt you from obtaining additional permits required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permitting determinations are made. The Commission will advise you of those BOPE tests that it wishes to witness. David W. Chairman Alaska Oil and Gas Conservation Commission BY O~ER OF THE COMMISSION dlf Enclosure Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. "--- STATE OF ALASKA ~'~ AL .~, OIL AND GAS C, ONS~VA~ COMk. SION PERMIT TO DRILL 20 AAC 25.005 · la. Type of Work Drill X Redrill ~ I lb. Type of Well Exploratory..__ Stratigraphic Test _ Development Oil Re-Entry _ Deepen --I Service _ Development Gas m Single Zone ~[ Multiple Zone 2.. Name of Operator 5.Datum Elevation (DF or KB) 10. Field and Pool ARCO Alaska. Inc. RKB 102'. Pad 67' GL feet Kuparuk River Field 3. Address 6. Property Designation Kuparuk River Oil Pool P. O. Box 100360~ Anchorage, AK 99510-0360 ADL 25647 ALK 465 4. Location of well at surface 7. Unit or property Name 11. Type Bond (see 20 AAC 25.025) 731' FSL,. 311' FWL, Sec. 5, T11N, R10E, UM KuDaruk River Unit Statewide At top of productive interval (TARGET) 8. Well number Number 2640' FNL, 2525' FEL, Sec. 8, T11N, R10E, UM 1A-25 #U630610 At total depth 9. Approximate spud date Amount 2345' FSL, 2311' FEL, Sec 8, T11N, R10E~ UM 17-DEC-90 $200,000 12. Distance to nearest 13. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and TVD) property line 1A-09 8132' MD 2311' ~ TD feet 37' at 1560' MD feet 2469 6494' TVD feet 16. To be completed for deviated wells 17. Anticipated pressure (see 20 AAC 25.035(e)(2)) kickoff depth 600' feet Maximum hofe ar~e 41 ° M,x~mum ~urface 2300 I~ At to~a~ depth (TVD) 3780psi9 @ 6494 18. Casing program Setting Depth size Specification Top Bottom Quantity of cement Hole Casing Weight Grade Coupling Length I~) TVD I~) TVD (include stage data! 24 16" 62.5# H-40 Weld 80' 35' 35' 115' 115' :~200 Cu. Ft. 12.25 9.625 36.0# J-55 BTC 4621 35' 35' 4656 3877' 2350 Cu. Ft. AS III & HF-ERW 520 Cu. Ft. Class G 8.5 7" 26.0# J-55 AB-MO[ 4621' 35' 35' 4656' 3877' 240 Cu. Ft. Class G 8.5 7" 26.0# J-55 BTC 3476' 4656' 3877' 8132' 6494' Top 500' above Kuparuk 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured feel Plugs (measured) true vertical feet Effective depth: measured feet Junk (measured) true verticaltrue vertical feel Casing Length Size Cemented Measured depth True Vertical depth Structural Conductor Surface CU. CU.,...RECEIVED Intermediate Production LinerDEC 1 1 1990 Perforation depth: measuredAlaska 0il& Gas Cons. Commission true verticalAnchorage i 20. Attachments Filing fee ,2[_ Property plat __ BOP Skelch X Diverter Sketch .2[. Drilling program ~ Drilling fluid program X Time va depth plot ~ Refraction analysis _ Seabed report _20 AAC 25.050 requirements X 21. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed ~/~J~~ Title Area Ddllin!~ Engineer Date / u.. , Permi, Number J AP, numb~ J Approval datel2/14/90 J See cover icl,er,or 74::~ '--' /~' 7 50- ~:~ .2. *~ -- ~ ~ //~ other re<:luirements Conditions of approval Samples required __Y e s X' N o Mud Icg required~ Y e s ~ N o Hydrogen sulfide measures~ Yes ..~ N o Directional survey required ~ Yes ~ N o Required working Pressure for BOPE ~ 2M; .~ 3 M; ~ 5 M; ~ 1 0 M; ~ I 5 M Other: / ~ ' ~- by order of A~_ppro . Commissioner the commission Date Form 10-401 Rev. 7-24-89 ~,,,~.~_~ in Iriplicate ARCO ALASKA, !no, Pad lA, Well No~ 25 Propoeed Kuparuk Field, North Slope, Alaeka 1 OOO. 2000 _ :3000 _ 4000 _ 5000 _ 6000 _ ?000 ,., . RKB ELEVATION, 102' RECEIVED KOP TVD-600 TMD-600 DEP'-O 3 9 BUILD 3 DEO 1 $ PER 1 O0 FT 21 DEC 1 1 1990 Alaska Oil & Gas Cons. uummission Anchorage 27 B/ PERMAFROST TVD-1502 TMD"1539 DEP-226 33 39 EOC TVD-1858 TMD-1973 DEP-472 T~ UONU SNDS TVD-2662 TMD,,3042 DEP-1176 T/ W SAK SNDS TVD-3252 TMD-3825 DEP-1692 B/ W SAK SNDS TVD-3677 TMD-4390 DEP-2064 9 5/8" CSO PT TVD,,3877 TMD-4656 DEP-2239 K-lO TVD-4072 TMD-4915 DEP-2410 AVERAGE ANGLE 41 DEC 11 HIN K-5 TVDmS092 TMD"6270 DEP-3302 TARGET - T/ ZONE C TVD=6077 TMD-7579 DEP=4164 T/ ZONE A TVD=6232 TMD=7785 DEP=4299 B/ KUP SNDS TVD=6343 TMD=7932 DEP-4396 TD / LOOOINO PT TVD-6494 TMD=8132 DEP-4528 i i 1000 2000 3000 VERTICAL SECT[ON I I 4000 5000 HOR~ONTAL ALE 1 ~N. PROJECTION = 1000 FEET ARCO ALASKA. Pad IA. Well No~ 25 Kuperuk Field. North Propoeed Slope, Alaska 1000 SURFACE LOGAT ! O# t 731' FSL. 311' FVL SEC. 5. T11#. RIOE z 1 000 I -,' 2000 30O0 4000 1000 0 I SURFACE WEST-E^ST 1000 I 2000 3000 I I RECEIVED DEC 11 1990 Alaska Oii& Gas Cons. Commission] Anchorage TARGET TVD=60?? THD=?$?9 DEP=4154 SOUTH 3371 EAST 2444 TARGET LOCAT[ON, 2640' FNL. 2525' FEL SEC. 8. TI1N. RIOE S 35 4164' DES 57 HI N E CTO TARGET) TD LOCATION, 2345' FSL, 2311' FEL SEC. 8, TIIN, RIOE 1100 \ I SO0~ / / / / / I~0 / / / ,50 t00 / / 00!_ ;50 200 250 lS~O 500 \ \ 3OO I 100i \ 300 350 400 4.50 L \ \ lO \ ',?OO \ \ \ \ \, ,% I?00 \ \ \ I 500 550 ZOO 650 550 500 450 400 350 30O R ¢EIVEP DEC 1 ] ]990 Oil & Gas Cons. Commission Anchorage DRILLING FLUID PROGRAM (1A-25) Spud to 9-5/8" Drill out to ~rface casing weight UD Density 8.6-10.0 8.6-9.6 PV 15-35 5-15 YP 15-35 5-8 Viscosity 50-100' 30-40 Initial Gel 5-15 2-4 10 Minute Gel 15-40 4- 8 APl Filtrate 10-1 2 8-10 pH 9-10 8.5-9 % Solids 10 +/- 4- 7 Weight up to TD 11.2 10-18 8-12 35-50 2-4 4-8 4-5 9.0-9.5 10-12 Drilling Fluid System: - Triple Tandem Shale Shaker - (2) Mud Cleaners - Centrifuge - Degasser - Pit Level Indicator (Visual and Audio Alarm) - Trip Tank - Fluid Flow Sensor - Fluid Agitators RECEIVED DE0 1 1 1990 Alaska Oil & Gas Cons. ¢omm~ss[O~ Anchorage Notes: - Drilling fluid practices will be in accordance with the appropriate regulations stated in 20 AAC 25.033. - Maximum anticipated surface pressure is calculated using a surface casing leak-off of 13.5 ppg EMW and a gas gradient of 0.11 psi/ft. This shows that formation breakdown would occur before a surface pressure of 2300 psi could be reached. Therefore, ARCO Alaska, Inc. will test the BOP equipment to 3000 psi. The nearest well to 1A-25 will be 1A-09. As designed, the minimum distance between the two wells would be 37' at 1560' MD. The wells would diverge from that point. Excess non-hazardous fluids developed from well operations and those fluids necessary to control the fluid level in reserve pits will be pumped down the surface/production casing annulus. The annulus will be left with a non-freezing fluid during any extended shut down in pumping operations. The annulus will be sealed with 175 sx of cement followed by arctic pack upon completion of fluid pumping. * Spud mud should be adjusted to a funnel viscosity between 100-120 to drill gravel beds. GENERAL DRILLING PROCEDURE KUPARUK RIVER FIELD lA PAD · 1 · 1 · Se · · 10. 11. 12. 13. 14. 15. 16. 17. 18. 19. 20. 21. Move in and rig up Doyon 14. Install diverter system. Drill 12-1/4" hole to 9-5/8" surface casing point according to directional plan. Run and cement 9-5/8" casing. Install and test BOPE. Test casing to 2000 psi. Drill out cement and 10' of new hole. Perform leak off test. Drill 8-1/2" hole to logging point according to directional plan. Run open hole evaluation logs or RLL as needed. Run and cement 7" casing. (Isolation of the Colville sands will be performed if there is hydrocarbon presence.) Pressure test to 3500 psi. ND BOPE and install temporary production tree. Secure well and release rig. Run cased hole cement evaluation and gyro logs Move in and rig up Nordic #1. Install and test BOPE. Perforate and run completion assembly, set and test packer. ND BOPE and install production tree. Change over to diesel Shut in and secure well. Clean location and release rig. Fracture stimulate well. Reperforate and add additional perfs. RECEIVED DEC 11 1990 Alaska 0il & Gas Cons, C0m~tssJon Anchorage f. 7 6 5 4 I I 13 5/8" 5000 F,.,t BOP STACK ACCUMULATOR CAPACITY TI~$T 1. CHECK AND FILL ACCUMULATOR RESERVOIR TO PROPER LEVEL WITH HYDRAULIC FLUID. 2, ASSURE THAT ACCUMULATOR PRESSURE IS 3000 PSI WITH 1500 PSI DOWNSTREAM OF THE REGULATOR. 3. OBSERVE TIME, THEN CLOSE ALL UNITS SIMULTANEOUSLY AND RECORD THE TIME AND PRESSURE REMAINING AFTER ALL UNITS ARE CLOSED WITH CHARGING PUMP OFF. 4. RECORD ON THE IADC REPORT. THE ACCEPTABLE LOWER LIMIT IS 45 SECONDS CLOSING TIME AND 1200 PSI REMAINING PRESSURE. BOP STACK TEST 1. FILL BOP STACK AND MANIFOLD WITH ARCTIC DIESEL. 2. CHECK THAT ALL HOLD-DOWN SCREWS ARE FULLY RETRACTED. PREDETERMINE DEPTH THAT TEST PLUG WILL SEAT AND SEAT IN WELLHEAD. RUN IN LOCK-DOWN SCREWS IN HEAD. 3.CLOSE ANNULAR PREVENTER AND CHOKES AND BYPASS VALVES ON THE MANIFOLD. ALL OTHERS OPEN. 4. TESTALL COMPONENTS TO 250 PSI AND HOLD FOR 10 MINUTES. INCREASE PRESSURE TO 3000 PSI AND HOLD FOR 10 MINUTES. BLEED TO ZERO PSI. 5. OPEN ANNULAR PREVENTOR AND MANUAL KILL AND CHOKE LINE VALVES. CLOSE TOP PIPE RAMS AND HCR VALVES ON KILL AND CHOKE LINES. 6. TEST TO 250 PSI AND 3000 PSI AS IN STEP 4. 7. CONTINUE TESTING AL VALVES, LINES, AND CHOKES WITH A 250 PSI LOW AND 3(X)O PSI HIGH. TEST AS IN STEP 4. DO NOT PRESSURE TEST ANY CHOKE THAT IS NOT A FULL CLOSING POSITIVE SEAL CHOKE. 8. OPEN TOP PIPE RAMS AND CLOSE BO'I-I'OM PIPE RAMS. TEST Bo'FrOM RAMS TO 250 PSI AND 3000 PSI. 9. OPEN PIPE RAMS. BACKOFF RUNNING JT AND PULL OUT OF HOLE. CLOSE BLIND RAMS AND TEST TO 3000 PSI FOR 10 MINUTES. BLEED TO ZERO PSI. 10 OPEN BLIND RAMSAND RECOVER TEST PLUG. MAKE SURE MANIFOLD AND MNES ARE FULL OF ARCTIC DIESEL AND ALL VALVES ARE SET IN THE DRILLING POSITION. 11. TEST STANDPIPE VALVES TO 3000 PSI. 12. TEST KELLY COCKS AND INSIDE BOP TO 3000 PSI WITH KOOMEY PUMP. 13. RECORD TEST INFORMATION ON BLOWOUT PREVENTER TEST FORM. SIGN AND SEND TO DRILLING SUPERVISOR. 14. PERFORM COMPLETE BOPE TEST ONCE A WEEK AND FUNCTIONALLY OPERATE BOPE DAILY. 1. 16" - 2000 PSI STARTING HEAD 2. 11" - 3000 PSI CASING HEAD 3. 11" - 3000 PSI X 13-5/8" - 5000 PSI SPACER SPOOL 4, 13-5/8" - 5000 PSI PIPE RAMS 5. 13-5/8" - 5000 PSI DRLG SPOOL W/ CHOKE AND KILL LINES 6. 13-5/8" - 5000 PSI DOUBLE RAM W/ PIPE RAMS ON TOP, BLIND RAMS ON BTM 7. 13-5/8" - 5000 PSI ANNULAR RECEIVED DEC 1 1 1990 0ii & Gas Cons. Commission Anchorage SRE 8/22/89 DOYON 14 ~,JPARUK RIVER UNI', 20" DIVERTER SCHEMATIC 5 6 4 I 5 DO NOT SHUT IN WELL UNDER ANY CIRCUMSTANCES MAINTENANCE & OPERATION , ,:, ( 3 2 . . . UPON INITIAL INSTALLATION, CLOSE PREVENTER AND VERIFY THAT VALVE OPENS PROPERLY. CLOSE ANNULAR PREVENTER AND BLOW AIR THROUGH DIVERTER LINES EVERY 12 HOURS. CLOSE ANNULAR PREVENTER IN THE EVENT THAT AN INFLUX OF WELLBORE FLUIDS OR GAS IS DETECTED. OPEN APPROPRIATE VALVE TO ACHIEVE DOWNWIND DIVERSION. ARCO ALASKA, INC., REQUEST S APPROVAL OF THIS DIVERTER SYSTEM AS A VARIANCE FROM 20AAC25.035(B) RECEIVED DEC 1 1 1990 Alaska 0il & Gas Cons. Commission Anchorage 1. 16" CONDUCTOR 2. SLIP-ON WELD STARTING HEAD 3. FMC DIVERTER ASSEMBLY WITH TWO 2-1/16"- 2000 PSI BALL VALVES 4. 20" - 2000 PSI DRILLING SPOOL WITH TWO 1(7' OUTLETS. 5. 10" HCR BALL VALVES WITH 10" DIVERTER LINES, A SINGLE VALVE OPENS AUTOMATICALLY UPON CLOSURE OF ANNULAR PREVENTER. VALVES CAN BE REMOTELY CONTROLLED TO ACHIEVE DOWNWIND DIVERSION 20" - 2000 PSI ANNULAR PREVENTER . SRE 2/6/90 CHECK LIST FOR NEW WELL PERMITS Company .~/'C-~ Lease & Well No. ITEM APPROVE DATE YES NO (1) Fee PP<,, 1. the Vermit fee attached .......................................... -- (2) Loc ,£Pc~ tz~z/~o (2 thru 8) (3) Admin ~?< ~ 9. (9 thru 13) 10. (10 and .13) 12. 13. (14 thru 22) 14. 15. (23 thru 28) 16. 17. 18. 19. 20. 21. 22. 2. Is well to' be located in a defined pool ............................. f~ 3. Is well located proper distance from property line .................. ~ 4. Is well located proper distance from other wells .................... ,~ 5. Is sufficient undedicated acreage available in this pool ............ ~ 6. Is well to be deviated and is wellbore plat included ................ 7. Is operator the only affected party ................................. 8. Can permit be approved before fifteen-day wait ...................... 23. 24. 25. 26. 27. 28. Does operator have a bond in force .................................. ~ Is a conservation order needed ...................................... ., Is administrative approval needed ................................... Is the lease number appropriate ..................................... _~ Does the well have a unique name and number . ' . . Is conductor string provided ........................................ Will surface casing protect all zones reasonably expected to serve as an underground source of drinking water ..................... Is enough cement used to circulate on conductor and surface ......... Will cement tie in surface and intermediate or production strings ... Will cement cover all known productive horizons ..................... Will all casing give adequate safety in collapse, tension and burst.. Is this well to be kicked off from am existing wellbore ............. Is old wellbore abandonment procedure included on 10-403 ............ Is adequate wellbore separation proposed ............................ Is a diverter system required ....................................... Is the drilling fluid program schematic and list of equipment adequate,FFw- Are necessary diagrams and descriptions of diverter and BOPE attached.~e Does BOPE have sufficient pressure",,rating - Test to ~OdDCb psig .. ~ Does the choke manifold comply w/API RP-53 (May 84) .................. Is the presence of H2S gas probable ................................. (6) OTHER _~f6 (29 thru 31) Geolo g7: Engineering: DWJ ~ LCS//~>~ BEW -~ rev: 01/30/89 6.011 For 29. 30. 31. 32. exploratory and Stratigraphic wells: Are data presented on potential overpressure zones?~. ................ Are seismic analysis data presented on shallow gas zones ............ If an offshore loc., are survey results of seabed conditions presented Additional requirements ............................................. ~ Additional Remarks: INITIAL GEO. UNIT ON/OFF POOL CLASS STATUS AREA NO. SHORE ~ ,' o o P~ /- ol/ ~; ? o /// ~ o 0,3 ~ O z 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. T° 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. LOGGING $K~VlC~ COMPUTER DIRECT DIGITAL LOGGING R£CEIVF. D JAN 2 2 1991 PROCESSED ANALYSIS .LLLLLLLLL .LLLLLLLLL IIIIIIIIII IIiIIIilII Ii II II II II II II II IiilIIiiiI IIIIIIiiII SSSSSSSS SSSSSSSSSS SS SS SS SS SSSSSSSSS SSSSSSSSS SS SS SS SS SSSSSSSSSS SSSSSSSS DDDDDDDDD UU UU NH NM ~uDDDDDDD UU UU HHN NHH DD DD UU UU HHHH HMHH DD DD UU UU MM MM NH NH DD DD UU UU HM HHHH HH DD DD UU UU MM MM MM DD DD UU UU MH MM DD DD UU UU HM MH DD DD UU UU HH HH DD DD UU UU MH HH DDDDDDDDDD UUUUUUUUUUUU MM NH DDDDDDDDD UUUUUUUUUU bin NH PPPPPPPPPPP PPF'PPPF'PPPF'~ PP P~ PP P~ PP PE PPPF'PPPPPPP~ PPPPPPPPPPPt PP PP PP PP PP 11 111 ill! ii I! ll II 11 il ii llli .1111 il iii 1ill II il lI il ii li ii liiI llil 1111 Illl illl Ili1 11 111 1111 I1 11 11 11 11 11 11 llllllllil 1111111111 00000000 0000000000 O0 O0 O0 O0 00 00 O0 O0 O0 O0 O0 O0 O0 O0 O0 O0 0000000000 000.00000 JJ JJ JJ J.J JJ JJ JJ JJ JJ JJ JJ JJJJJJJJJJJJ JJJJJJJJJJ 555555555555 555555555555 55 55 55 555555555 5555555555 55 55 55 555555555555 55555555555 AAAA AA AA AA AA AA AA AA AA AAAAAAAAAAAA AAAAAAAAAAAA AA AA AA AA AA AA AA AA 6666666666 666666666666 66 66 66 66 666666666666 66 66 66 66 66 66 666666666666 6666666666 NN NN NN bin HNN NNt,iN NN NN NN NN t,IN NN NN NN NN- NN NN NN NN NN NN NN NH NNNN NN NNN NN NN AA AAAA AA AA AA AA AR AA AA AA AAAAAAAAAAAA AAAAAAAAAAAA AA AA' AA AA AA AA AA AA 9999999999 999999999999 99 99 99 99 99 99 9~~ - 99.~99~99999 999999999999 99 99 '99 99 999999999999 9999999999 MM Mt H H M M M I H N M M M I"i M I MM MM MM MI H H H M M I"1M t H H M M M i' tin HI' H H M t MH f'lt Mt, l Mt HN Mt Ht'l t'it ii iii ilii ii ii ii ii li ii ii iiiiiiiiii iiliiiiiii REEL HEADER **** Service name: &G5FOI HEADER Date: 91701710 Origin: Comments: RECORDS Reel name: 492228 Pagm i Continuation ~: Ol TAPE HEADER Service name: &GSF01 Previous tape: Date: 91/01710 Origin Comments: Tapm name: 492228 Cantinuation ~: 01 ~** FILE HEADER **** File name: ,001 Maximum.length: 1024 Service name: Version Date: File type: LO Previous ¢ile: MNEM ON FN COUN 8TAT CTRY APIH LATI LONG SECT RANG EKB EDF EGL PD LHF DHF RUN TIHE DATE LCC LUN FL LUL ENGI WI TN DD DL CBLI TLI BLI TCS TLAB BHT HRT HT MSS DFD HVIS DFPH DFL EM RI, IF HFST MFSS RHC I NFORMAT I OH RECORDS Page ARCO ALASKA INC. KUPARUK NORTH SLOPE ALASKA USA 22116. 000 ..... 0 D~g. 0 Hin 0 Deg. 0 Min i IN .......... I OE .......... I 02. 000 ...... 101 .000 ...... &~, 000 ....... HS .......... KB. ......... KB .......... 2400. 000 .... 31 / 12/90 .... 30 .......... 492228 , . 7~3~ ,, NORTH SLOPE NORTH SLOPE YRRBEO RLIGEH 0115,000 .... ~120,000 .... 46~2,000 .... 46~2,00 O, ; 0,.000 ...... 8112,000, , , i900., 000, , , 2400,000. , . i55. 000 .... i 55. 000 .... QUICKOEL CIECULRTED 1 I, 900 ..... 42,000, .... 0~000 ...... 8,000 ..... 2,500 ..... , 1 ,830 ...... a4,000 ..... HEaS, , , API DATE LOGGED: 0 u uec. H HUH: 50-029-22116 12-31 -90 i Iiiiliiilii illiIilllll IililiiiiI i I i ilIiii · 0 0 40 65 0 0 40 65 0 0 40 65 0 0 20 65 0 0 20 65 0 0 20 65 0 0 4 68 0 0 34 65 0 0 34 65 0 0 2 65 0 0 3 65 0 0 3 65 FT 0 3 4 68 FT 0 3 4 FT 0 3 4 68 0 3 2 65 0 3 2 65 0 3 2 65 0 0 2 79 0 0 4 6:3 0 0 8 65 0 0 2 79 0 0 10 6,5 0 0 i0 65 0 0 20 65 0 0 20 65 0 0 20 65 0 0 20 65 FT 0 3 4 68 FT 0 3 4 FT 0 3 4 68 FT 0 ~ 4 68 FT 0 ~ 4 68 FT 0 3 4 68 HR 0 2 4 ~>o'"' HR 0 4 4 DEGF 0 1 4 68 [>EGF 0 I 4 68 0 2 ,-.") 0 65 0 2 20 65 L8,..'6 0 2 4 68 CP 0 2 4 68 O 2 4 68 0 2 4 68 014 H M 0 2 4 68 0 Ft H H 0 2 4 6 8 -:=: DEGF 0 2 4 0 2 i '-.-' 65 O. 14 t'l M 0 2 4 e,~" '- CONTENTS UNIT TYPE CATG SIZE CODE ERROR MCST MCSS CS BS I NFORMAT I ON RECORDS CONTENTS ~1000 .................................................. NEAS ............................................. 9~625 ................................................... 8.500 .................................................... UH I T DEGF TYPE CATG SIZE 4 i2 4 4 OODE 68 65 68 Pag~ ERROR COMMENT RECORDS Well Location Comment i: SURFACE: 731' FSL & 3ii' FWL Well Location Comment 2.: Well Location Commmnt 3: Well Location Comment 4: Well Film Commmnt l: HRI,ML,SDL?DSN RUN IN COMBINATION. Well File Comment 2.: DUE TO POOR HOLE cONDITIONS. HEAD Well File Comment 3: ARE RECORDED 46.2.5' DEEP TO SPLICE ON LOG AT 7730' IS TENSION AND & LINE TEHSION BOTTOM OF TOOL DUE TO SOFTWARE Well File Comment 4: ERROR, DXCO = +2.,0 & MXCO = -2.0 MMHOS. MUD CONTAINS L,CoM. *~ LIS tapm wpi~tmn b~: ANCHORAGE COMPUTIN6 CENTER *~ ~* All curve and tool mnemonics used are those which most closelp match *~ m~ Halliburton curve and tool mnemonics. ~ HALLIBURTON TO SCHLUMBERGER TOP BOTTOM MNEM SERVICE UNiT HNEM SERVICE UNIT DEPTH DEPTH DEPTH FT DEPT FT GR SDL GApI GR '-'-'~£L) GAPI FDSN DSN2 CPS FDSN DSN2 CPS NDSN DSN2, CPS NDSN DSN2 CPS NPHI DSN2 DECP .NPHI DSN2. DECP NRAT DSN2 C?C NRAT DSN2 C?C DPHI SDL DECP DPHI SDL. DECP DRHO SDL G,-"C3 DRHO SDL G?C3 FSDL SDL CPS FSDL SDL CPS NSDL SDL CPS NSDL SDL CPS 35 O0 4570 O0 4570 O0 4570 O0 4570 O0 4570 O0 4570 O0 4570 O0 4570 O0 4570 O0 8140.00 8130, O0 8130, O0 8130, O0 8130,00 8130,00 8i30, O0 8i 30. O0 8~t30, OO 8130,00 Page PE PELC QL QS RHO8 CALl HINV HNOR HDR HDX HHR HHX HDRS HMRS HDCN HMCN DFL SP TENS DLOD SDL SDL SDL $DL SDL SDL HL HL HRI HRI HRI HRI HRI HRI HRI HRI HRI HRI SDL SDL G?C3 IN OHMH OHMM OHMH OHMM MHHO MHHO OHMH MV LBS L85 PE PELC QL QS RHOB CALl MINV HHOR HDR HDX HHR HMX HDRS HMRS HDCH HMCN DFL SP TENS DLOD SDL SDL SDL SDL SDL SDL ML ML. HRI HRI HRI HRI HRI HRI HR I HRI HRI HRI SDL SDL G/C3 i N OHHM OHHM OHMM OHMM MMHO MMHO OHMM MV L85 LBS 4570,00 4570.00' 4570.00 4570,00 4570,00 4570,00 4570,00 4570.00 4570.00 4570 O0 4570 O0 4570 O0 4570 00 4570 O0 4570 OO 4570.00 4570.00 4570.00 4570.00 4570,00 130 OO 130 O0 8130 O0 8i 30 O0 8I 30 O0 8130 O0 8i 30 O0 8130 O0 8i30 O0 8130 O0 8130 O0 8130.00 8130.00 8i 30 O0 8130 O0 8i 30 O0 8i 30 O0 8130 O0 8130 O0 8130, O0 DATA ENTRY FORMA T SPEC I F I CA TYPE SIZE CODE 16 1 66 0 1 66 TIONS Page ENTRY BLOCK LEGEND TYPE DESCRIPTION Datum zpeciPication block zub-type Terminator ( no more ~ntpi~z ) DATA FORMAT DATUM SPECIFICATION BLOCKS **** SERVICE SERVICE API API API API FILE MNEM ID ORDER # UNIT LOG TYPE CLASS MOD # DEPT 492228 FT 0 0 O 0 1 GR SDL 492228 GAPI 94 0 0 1 0 FDSN DSN2 492228 CPS 94 0 0 1 O NDSN DSH2 492228 CPS 94 0 0 1 0 NPHi DSN2 492228 DECP 94 0 0 J O NRAT DSt42 492228 C/C 94 0 0 i 0 DPHI SDL 492228 DECP 94 0 O i O DRHO' SDL 492228 G?C3 94 0 0 1 0 FSDL SDL 492228 CPS 94 0 8 t 0 NSDL SDL 492228 CPS 94 0 0 i O PE SDI.. 492228 94 0 O 1 0 PELC SDL 492228 94 0 0 i O QL SDL 492228 94 0 0 1 0 QS SDL 492228 .94 0 0 1 0 RHOB SDL 492228 G/C3 94 0 O i 0 CALI SDL 492228 IN 94 .0' 0 I O MINV HL 492228 OHMH 94 0 0 1 0 HNOR HL 492228 OHMM 94 0 0 1 0 HDR HRI 492228 94 0 0 1 0 HDX HRI 492228 94 0 0 i 0 HMR HRI 492228 94 0 0 1 0 HHX HRI 492228 94 0 0 i 0 HDRS HRI 492228 OHMM 94 0 0 i 0 HMRS HRI. 492228 OHMM 94 0 0 1 0 HDCN HRI' 492228 HHHO 94 0 0 1 0 HMCN HRI: 492228 MMHO 94 0 0 t O DFL HRI 492228 OHMM 94 0 O 1 0 SP HRI 492228 MV 94 O 0 1 0 TENS SDL 492228 LBS 94 0 0 1 O DLOD SDL 492228 LBS 94 0 0 i 0 SPECIFICATIONS PRC # SIZE LVL SHPL RC 4 0 1 68 4 0 l 4 0 1 68 4 0 i 68 4 0 1 68 4 0 i 6.8 4 0 i 68 4 0 i 68 4 0 i 4 0 i 6,8 4 0 i 68 4 0 i 4 0 i 4 0 i 4 0 i 4 0 1 4 0 1 68 4 0 1 4 0 ~ 4 0 ] 4 0 1 68 4 0 1 4 0 i 4 0 1 68 4 0 1 68 4 0 I 68 4 0 1 68 4 0 1 68 4 0 t 68 4 0 1 68 PROCESS iNDiCATORS 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 OOO000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 O0000O 000000 000000 000000 000000 000000 000000 000000 000000 O0000O 000000 000000 OOO000 000000 000000 000000 000000 000000 000000 O00OO0 000000 000000 000000 000000 O00000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000.000000 000000 000000 000000 000000 000000 000000 Page DATA RECORDS DEPT GR FDSN NDSN NPHI NRAT DPHI DRHO FSDL NSDL PE PELC ~L ~S RHOB OALI HINV HNOR HDR HDX HHR HHX HDRS HhIRS HDCN HHCN DFL SP TENS DLOD Page 8i30,000 6?54,675 1,896 -999,250 8100,000 6754.675 -999,250 8000.000 7368.475 2,~69 401,046 7900,000 7569.675 9.275 165,271 ?~00,000 6777.273 ii,864 65.563 7700,000 7336,874 5,930 i76.529 7600,000 8011,675 11,023 104,516 7500,000 7728,874 2,156 584,248 81,526 16046,055 2,546 -999.250 1485.824 13821.094 .466 5,6i8 5,214 -.037 -999,250 -999.250 -999.250 -999,250 -999,250 6437.767 81,526 1485.8-24 13821.094 .466 16046,055 5,618 5,214 -,037 2,546 -999,258 -999,250 -999.250 -999,250 -999,250 -999,250 4692.4i6 i08,715 1391,230 13341.607 ,451 6654,484 4,624 5,555 .01 0 2,876 3.01 , 684 86,599 349,326 389,073 2,726 150.769 4463.519 78.645 2191 ,493 16023.834 .33i 16790,055 3,414 3,027 , 003 8,180 141,301 . 30.463 144.977 163,889 8,106 147. 304 4234,620 52,703 3155,604 1 7719,840 . 242 17155. 340 2. 635 3 , 062 , 032 I O, 069 75, 1 06 I2,428 73,291 61 , 088 15,850 i41 ,260 4263.232 78,323 1666i,625 5,050 173,679 2266,694 15731,521' ,313 2,978' 3,567 ,030 i48,524 27,498 159,488 5,899 141,869 4148,783 50,620 2995,333 17324.781 ,248 16854,770 2,406 2,738 .044 9.014 87,899 14,926 95,253 99,074 9,692 132,054 4091,558 9,832 -,099 -999,250 9.832 -.099 -999.250 1i40,080 10,136 .016 39,829 1096,788 7,729 ,OlO 9.334 968.008 5.935 .002 838.i32 7.336 .015 9,947 790,456' 6,114 ,027 3,856 890,i92 90,166 1422,535 13665,760 ,462 10,154 16418,910 3,768 2,153 -,078 ,007 2,184 408,835 133,101 483,943 58,760 564,669 1,688 144,518 4120,171 852,380 .i58 2,389 -999,250 ,158 2,389 -999,250 .171 2,368 2,493 ,172 2.366 6,051 ,236 2,260 i5.252 ,166 2,377 5,665 ,200 . ~ ,5~0 9;568 ,176 2,~9 1 ,712 .003 8.500 -999,250 .003 8.500 -999.250 ,035 11 ,114 2,570 .038 9.929 6.102 ,030 i.~j . 843 16.370 ,036 10.182 5.758 .028 10. 436 1 O, 093 -. 005 9,863 1,77 'i DEPT FSDL HINV HDCN GR NSDL HNOR HHCN FDSH PE HDR DFL DATA NDSN PELC HDX SP RECORDS NPHI QL HHR TENS NRAT QS H H X DI. OD DPHI RHO8 HDRS DRHO CALl HHRS Page 7400. 000 8 864,074 2.223 575,50i 7300.000 -999,250 -999.250 335,659 7200,000 -999,250 -999.250 329.191' ?100,000 -999,250 -999,250 414,706 7000,000 -999,250 -999,250 278,513 6900,oOo -999,250 -999,250 362.314 6800.000 -999,250 -999.250 751,667 6700,000 -999,250 -999,250 311,081 96.127 I6756,195 2.3i5 570.762 175.080 -999,250 -999.250 319,250 128.328 -999,250 -999,250 318.696 128.991 -999,250 -999,250 414,317 I04.369 -999,25.0 -999,250 279,523 134.766 -999,250 -999,250 352.060 109.324 -999,250 -999,250 771,115 126.599 -999,25.0 -999.25:0 309,481 1352,128 3.384 394,972 i,591 -999.250 -999.250 280.618 3.598 -999.250 -999,250 264.427 3.385 -999,250 -999.250 327,447 3,332 -999,250 -999,250 221.920 4.06@ -999,250 -999,250 271,770 3,540 -999,250 -999,250 461.110 1,502 -999.250 -999,250 245.310 3,121 13052'.346 3,923 ii1.79i 138.553 -999,250 -999,250 67,737 133,218 -999,250 -999.250 69,696 i2e.972 -999,250 -999,250 88.872 134,414 -999,250 -999.250 47,921 131,688 -999,250 -999,250 64,444 135,362 -999.250 -999,250 150,648 144,607 -999,250 -99.9,250 57,382 132,155 ,457 ,051 490,15i 3934,i90 -999,250 -999,250 315,134 4062.946 -999,250 -999.250 306,677 3991,4i5 -999,250 -999,250 374,875 3891,272 -999,250 -999,250 254,588 3891,272 -999,250 -999;250 330,725 3876,966 -999,250 -999.250 623,337 3562.230 -999,250 -999,250 286.502 3633.761 10,227 .005 48,074 843,064 -999.250 -999,250 24.08~ 822,788 -999,250 -999.250 30,777 810.184 -999,250 -999,250 35.006 794.840 -999.250 -999,250 17.562 852,928 -999.250 -999,250 25.577 842.516 -999,250 -999.250 79,i37 766,344 -999,250 -999,250 24,144 797,032 .209 2.305 1 , 738 -999,250 -999,250 2.979 -999,250 -999,250 3.038 -999,25.0 -999,250 2,4ii -999.250 -999.25.0 3,590 -999,250 -999,250 2,760 -999,250 -999.250 1 ,330 -999,250 -999,250 3,215 .018 1 O, 755 i ,752 -999,250 ii ,206 3,132 -999,250 i I. 08,6 3,i38 -999.250 i 0,869 2,4i4 -999,250 i2.994 3,578 -999,250 10,602 2,840 -999,250 I 0.2,96 1' ,297 -999,250 i 1 . 929 3,231 DEPT FSDL HDCN GR NSDL HNOR HHCN FDSN PE HDR DFL NDSN PELC HDX SP RECORDS NPHI QL HMR TEHS NRAT QS HHX DLOD DPHI RHOB HDRS DRHO CALi HHRS Page 6600,000 -999.250 -999.250 372..243 6500,000 -999.250 -999.250 382.962 6400.800 -999.250. -999.250 6300.088 -999.250 -999.250 45i.043 -999.250 -999.250 530.913 6100.000 -999.250 -999.250 425.648 6OO0,'OOO -999.250 -999.250 361.628 5900,.000 -999.,2S0 -999.250 355.678 -999,250 -999.250 386.629 i28,504 -999,250 -999,250 3el.546 160.504 -999.250 -999.250 7o2.352 166. 171 -999.250 -999.250 454.450 i32,922 -999,250 -999,250 557.467 111.752 -999,250 -999,250 430.535 141,0'02 -999,25.0 -999,250 381.446 69.954 -999,250 -999,250 350.849 -999,250 -999,250 266,147 2,559 -999,250 -999,250 335.465 4.296 -999.250 -999.250 393.157 1.750 -999.250 -999.250 346.388 2.803 -999.250 -999.250 355.979 1.820 -999,250 -999,250 323.303 2.16e -999.250 -999.250 275.1 03 2.240 -999.250 -99.9.250 285.'921 2.630 -999 -999 57 i44 -999 -999 I05 149 -999 -999 107 152 -999 -999 97 -999 -999 89 -999 -999 151 -999 -999 40 149 -999 -999 81 15! .250 .250 .137 .250 .250 .757 .749 .250 .250 .342 .711 .250 .250 .182 .923 .250 .258 .529 .352 .250 ,250 .541 ,580 .250 ,250 ,101 .764 ,250 .250 .319 .236 -999 -999 3i9 37i9 -99'9 -999 428 3576 -999 -999 525 3590 -999 -999 426 3605 -999 -999 459 3505 -999 -999 3404 -999 -999 349 3505 -999 -999 340 3361 .250 ,250 ,598 .250 ,250 ,489 ,537 .250 ,250 ,342 ,843 .250 .250 .554 .149 .250 .250 .549 ,006 .250 .250 · 072 · 863 ,250 ,250 .137 · 006 ,250 .250 .429 .944 -999. 250 -~'~, z5 0 22 692 824.432 -999.250 -999.250 51.816 844.708 -999,250 -999,250 51.029 814.020 -999.250 -999.250 34.777 806.896 -999.250 -999.250 38,716 818.952 -999,250 -999.250 41.625 785.524 -999.250 -999.250 -i8,893 824.980 -999.250 -999.250 37.605 791.552 -999,250 -999.250 2.686 -999.250 -999,250 2.6il -999.250 -999.250 i.501 -999.250 -999.250 2.217 -999,250 -999.250 1.884 -999,250 -999,250 2,349 -999.250 -999.250 2.765 -999.250 -999,250 2.812 -999.250 ii,iii 2.586 -999,250 9.838 2.621 -999,250 10.291 1.424 -999.250 i0.232 2.200 -999.250 10,719 1 .794 -999.250 1 0. 892 2.323 -999.250 i0.992 2,622 -999,250 i0.347 2,850 DEPT FSDL H I NV HDCN 5800.00.0 -999,250 -999.250 324.,375 5700,000 -999,250 -999,250 324,641' 5600,000 -999,250 -999,250 319,247 5500, O00 -999.250 -999,250 31'3.790 5400,000 -999,250 -999,250 410,026 5300,000 --999,250 -999,250 362,699 5200,000 8905,273 -999,25O 534,574 5l O0,000 9 046,074 -999,250 408,9i5 GR ,f,ISDL HNOR HHCH _ 77 -999 -999 329 50 -999 -999 356 -999 -999 336 89 -999 -999 331 -999 -999 433 107 -999 -999 9'5 17109 -999 614 95 170t7 -999 449 FDSN PE HDR DFL ,200 -999 .250 -999 · 250 259 ,797 2 DATA RECORDS HDSN NPHI NRAT DPHI DRHO PELC QL QS RNOB CALi HDX HHR HH× HDRS HHRS SP TENS DLOD · 250 -999,250 -999. 250 ,250 -999. 250 -999,250 , 587 64,472 307,5 i 8 ,726 150,849 3361 ,944 , 924 -999,250 -999 , 250 -999,250 , 250 -999,2'50 -999,250 -999. 250 · 250 260,471 74,852 332,880 , 242 2,272 150,947 3247,495 .968 -999,250 -999,250 -999,250 ,250 -999,250 -999,250 -999,250 ,250 237,316 54,781 291,349 · 834 2,753 146,374 3347,638 ,517 -999,250 -999,250 '999,250 ,250 -999,250 -999,250 -999.250 ,250 266,365 70,734 321,774 ,002 2,623 136.747 3218,883 ,371 -999,250 -999,250 -999,250 , 250 -999,250 -999,250 -999,250 · 250 305,048 81 ,406 389,402 · 814 2,049 147. 044 3i47,352 ,211 -999.250 -999,250 -999,250 , 250 -999,250 -999,250 -999,250 , 250 ,300 , 726 86 . 089 358 · 155 ,761 2,207 145,330 3061 .515 · 030 1603 ,340 3 ,250 325 ,620 ,330 ! 578 ,914 3 ,250 281 ,468 I -999,250 -999.250 28.312 809.088 -999,250 -999,250 38,264 77i,276 -999,250 -999,250 22.503 820,048 -999,250 -999,250 33,714 800.868 -999,250 -999,250 4i,417 781,i40 -999,250 -999,250 43,015 784,976 ,759 14350.871 ,421 .212 3.266 -,025 .753 77,177 441.929 ,726 143,564 3032,903 9,458 -,009 40,711 784,428 ,950 14301 ,980 ,426 ,072 3. 728 , Oi 3 ,815 60. 157 377,215 ,798 141 ,773. 3047,209 9,574 ,'024 26.393 772,920 Page -999,250 -999.250 3.083 -999,250 10.230 3 032 -999.250 -999,250 3,080 -999.250 10.485 2,807 -999,250 -999,250 3.132 -999,250 i0,446 2,969 -999.25 0 -999,250 3,127 -9'39,250 i 0,342 -g, 021 -999,250 -999,250 2,434 -999,250 10,464 2,305 -999,250 -999,250 2.757 -999,250 10,503 2,6i3 .244 2,248 1 ,871 ,021 i 0,579 1 ,627 ,257 2,226 2.445 ,009 i0.352 2.225 1 ti DEPT FSDL HINV HDCt,I GR NSDL HNOR HHCN FDSN PE HDk DFL DATA NDSN PELC HDX. SP RECORDS NPH I QL HHR TENS NRAT . -- H H X DLOD DPHI RHOB HDRS DRHO CALI HHRS Page li 8734 -999 205 4906 9000 '999 247 4800 8477 -999 4780 8835 -999 282 4600 -99'3 -999 -999 ,000 ,875 ,250 ,0i7 .000 ,674 ,250 ,924 ,000 · 6?4 ,250 ,409 .O00 .875 ,250 ,325 .OOO ,250 ,250 ,250 82,694 i6953,199 -999.250 213,369 114.837 17148,484 -999,250 263,437 82,991 17299,340 -999,250 279,304 90,908 16535,055 -999.250 359,522 51,343 -999,250 -99'9,250 -999,250 1749 3 175 3 1563 5 203 3 1648 3 214 3 1640 4 202 2 -999 -999 -999 -999 ,560 ,704 ,000 .798 ,245 ,856 ,860 ,251 ,447 ,219 .056 ,230 ,582 ,715 · 59'5 ,978 ,250 ,250 ,250 .250 1460.3,594 4.606 4i ,730 i39.792 i4087.980 5,496 · 47 ·391 136,890 14129 ·295 3,703 46,335 137.391 14326. 568 4,978 28,942 146.481 -999,25;0 -99'3,250 -999,250 127,832 -- -- -- -. U~ i86.34i 2947,066 .4t8 -,067 246,446 2789,698 .389 256,614 2932,760 ,400 239,658 2846,923 -999,250 -999,250 -9'99,250 2832,617 757 9 -- 1,8 752 9 20 7@2 9 -- 760 -999 -999 -999 736 .823 .02~ , ,028 ,526 ,042 ,320 ,096 ,060 .040 .510 ,236 ,230 ,003 .949 ,316 ,250 .250 ,250 ,752 ,244 2.-248 4,878 ,244 2,247 4,033 ,210 2,303 3',754 ,261 2.220 3,542 -999.250 -999.250 -999.250 .014 i 0,6,89 4,687 ,021 11,089 3,796 . 048 I 1, ,875 3,580 -.015 i 0.,850 2,781 -999.250 8.993 -999,2S0 ~.,m FILE TRAILER File name: ~GSFO!. Maximum length: !024 TRAILER RECORDS Service nammI Version #: File t~pe: LO Ne×t {ile: Date: Page 12 ~** FILE HEADER File name: °002 S~rvice name: Version #: Date: Maximum l'engt~: !024 File type: LO Previous ~ile: CN FN COUN STAT CTRY APIN LATI LOHG SECT TOWN RANG EKB EDF ECL PD LMF DMF ,RUN 'TIME DATE LOC L.UN FL LUL EHGI WITH DL CBD! CBL! TLI. TCS TLAB B.HT HAT MT MSS DFD HVIS DFPH DFL RMF HFST HFSS AMC CONTENTS ARCO ALASKA INC. IA-25 KUPARUK NORTH SLOPE ALASKA USA 22116.000.,' ........ .0 Deg. 0 Min, 0 Deg, 0 Mi n, lin ............ IOE ........... 102.000 ....... 1 01 . 000 ....... 67. 000 ........ MS ............ k'B ............ 2400. 000 ...... :31712?90 ...... 492228 .... 7636 . . . NORTH SLOP~ NORTH SLOPE YARBRO RUGEN 8115,000 ..... 8120,000 ..... 4682.000 ..... 4682.000 ..... O.O00 ........ 8112,000 ..... 1900.000 ..... 2400. 000 ...... 155,000 ....... 155,000 ....... QUICKGEL CIRCULATED 11 .90'0 ......... 42. 000 ......... O, O.O O .......... 8.000 .......... 2.. 500 .......... I , 830 .......... 84,000 ......... MEAS .... 3~690 .......... l NFORMAT I ON RECORDS UNIT AP1 HUM: 50-029-22116.. DATE LOGGED: 12-31-90.. 0 0 Illllll JJJlJil Jllllll IIIll 4.1Ill Illll Ill III JJJ 14.1 Ill ll4. III Ill 0 Smc m o · ii · · i · l 1 i, i ! · · i I l 1 · · · · i · · ! , I I!11.~ · iiIiii il Ii IIIIII Il Illlll II IIii11111 II IIIIIIIII IIIIIIIIIlll * · · · ! -. el ·, · Il I · · , i I i I i i · · · ! i · i i · , i i i i TYPE CATG SIZE CODE 0 0 40 65 0 0 40 65 O 0 40 65 0 0 20 65 0 0 20 65 0 0 20 65 0 0 4 68 0 0 34 65 0 0 34 65 0 0 2 65 0 0 3 65 0 0 3 65 FT 0 3 4 68 FT O ;3 4 68 FT 0 :3 4 68 0 3 2 65 0 3 '2 65 0 3 2 65 O 0 2 79 0 0 4 68 0 0 8 65 0 0 2 79 0 0 1 0 65 0 0 10 65 0 0 20 65 0 0 20 65 0 0 20 65 0 0 20 65 FT 0 3 4 68 FT 0 3 4 68 FT 0 3 4 6:3 Fl' 0 3 4 68 FT 0 3 4 68 FT 0 3 4 68 HR 0 2 4 68 HR 0 4 4 68 DEGF 0 1 4 68 DEGF 0 I 4 68 O 2 '20 65 0 2 20 65 LB,.'G 0 2 4 68 CP 0 2 4 68 O 2 4 68 O 2 4 68 OHMH 0 2 4 68 OHMH 0 2 4 68 DEGF 0 2 4 68 0 2 12 65 OHHM 0 2 4 68 Page ERROR 13 HNEH MCST HCSS BS INFORMATION RECORDS CONTENTS UNIT S3,000 .................................................. HEAS ............................................. 9.6.25. ..- ................................................ 8.500 ................................................... DEGF TYPE CATG SIZE 4 12 4 4 CODE 68 65 Page ERROR 14. COMMENT RECORDS Well Locat Wall Locat Well Locat Well Locat Well File W~ll Fila Wall File Wall File *~ LIS ~:* All ion Comment l: SURFACE: 731' FSL & 311~ FWL ion Comment 2: ion Comment 3: ion Comment 4: Comment l: HRI,ML,SDL?DSN RUN IN COMBINATION. SPLICE ON LOG AT 7730~ iS Comment 2: DUE TO POOR HOLE CONDITIONS. HEAD TENSION AND & LINE TENSION Comment 3: ARE RECORDED 46.25' DEEP TO BOTTOM OF TOOL DUE TO SOFTWARE Comment 4: ERROR. DXCO = +2.0 ~ MXCO = -2.0 MMHOS. MUD CONTAINS L.C.M. tape written bp: ANCHORAGE COMPUTING CENTER ** curve and tool mnemonics used are those which most closely match ~* Halliburton curve and tool mnemonics. ** HALLIDURTON TO SCHLUHBERGER TOP BOTTOM MNEM SERVICE UNIT MNEM SERVICE UNIT DEPTH DEPTH DEPTH FT DEPT FT 35.00 8i40.~0 GR.1 SDL GAPI GR SDL GAPI 7338.50 8134.00 FDSN! DSN2 CPS FDSN DSN~ CPS 7338,50 8134.00 HDSNI DSN2 CPS NDSN DSN2 CPS 7338.50 8134.00 NPHI1 DSN2 DECP N.PHI DSN2 DECP 7338.50 8134,00 NEAT1 DSN2 -C/C NRAT DSN2 C/C 7338,50 8134.00 DPHI! SDL DECP DPHI SDL DECP 7338.50 8~34.00 DRHO1 SDL G/C3 DRHO SDL G/C3 7338,50 8134.00 FSDL1 SDL CPS FSDL SDL CPS 7338,50 8134,00 NSDL1 SDL CPS NSDL SDL CPS 7338.50 8134,00 Pag~ 15 PE1 PELC1 QL1 Q$1 RHOB1 CALl1 HINV1 HHOR1 HDRI HD.',< 1 HHR1 HHXl HDRSl HHRSI HDCN i HNCN i DFLi TENSl DLOD 1 SDL SDL · SDL SDL SDL SDL HL ML HRI HRI HRI HRI HRI HRI HRI HRI HRI HRI SDL SDL IN OHMM OHMM OHMM OHMN MMHO MHHO OHMM LBS LBS PE PELC QL QS RHOB CRLI HINV MNOR HDR HDX HMR HHX HDRS HHRS HDCN HHCN DFL SP TENS DLOD -SDL SDL SDL SDL SDL SDL ML HL HRI HRI HRI .HRI HRI HRI HRI HRI HRI SDL SDL G?C3 IN OHMH OHMM OHHH OHHH HMHO HMHO OHHH LBS LBS 7338.5o 7338,5O 7338.50 7338,5O 7338,5O 7338,50 7338.50 7338 50. 7338 50 7338 50 7338 50 7338 50 7338 50 7338 5O 7338 50 7338 50 7338 50 7338,50 7338,50 7338,50 8134 8134 8134 8134 8134 8134 8134 8134 81 34 8134 8134 8134 8134 8134 8134 8134 8134 8134 81.34 81;34 .00 .OO ,00 .00 O0 O0 O0 O0 O0 O0 O0 O0 00 O0 DATA ENTRY . FORMAT TYPE SIZE SPECIFICA CODE 16 I 66 0 1 66 TIOHS Page 16 ENTRY BLOCK LEGEHD *~*~ TYPE DESCRIPTION 16 Datum speci¢ication block sub-type 0 Ter-mina~op ( no mope entries > DATA FORMAT SPEC I F I CA T IONS ************************************* *** DATUH SPECIFICATION BLOCKS -NNEH SERVICE SERVICE AP1 AP1 AP1 AP1 FILE ID ORDER # UNIT LOG TYPE CLASS MOD # DEPT 492228 ~T 0 0 O 0 2 GR SDL 492228 GAPI 94 0 0 3 FDSN DSN2 492228 CPS 94 0 0 3 flbSN DSN2 492228 CPS 94 O 0 3 i NPHi DSN2 492228 DECP 94 ~0 0 3 NEAT DSN2 492228 C/C 94 O bPHI SDL 492228 DECP 94 .O O 3 DRHO SDL 492228 G/C3 94 0 0 3 FSbL SDL 492228 CPS 94 O O 3 NSDL SDL 492228 CPS 94 O 0 3 1 PE SDL 492228 94 0 PELC SDL 492228 94 QL SDL 492228 94 0 0 3 QS SDL 492228 94 RHOB SDL 492228 G/C3 94 0 O 3 CALI SDL 492228 IN 94 0 0 3 NINV NL 492228 OHMN 94 0 0 3 1 HHOR NL 492228 OHNH 94 0 0 3 HDR HRi' 492228 94 O 0 3 HDX HRI 492228 94 0 O 3 HNR HRI '492228 94 0 O 3 1 HHX HRI 492228 94 '.0 0 3 HDRS HRI 492228 OHNN 94 '0 0 3 1 HMRS HRI' 492228 OH.NH 94 .O 0 3 1 HDCN HRI 492228 NNHO 94 ,0 0 3 1 HHCN HRI 492228 .MHHO 94 0 O 3 DFL HRI 492228 OHHH 94 0 O 3 SP HRI 492228 NV 94 0 0 3 TEN8 SDL 492228 LBS 94 O O 3 1- DLOD SDL 492228 LBS 94 0 0 3 1 PRC SIZE LVL SHPL RC 4 0 1 68 4 0 1 68 4 0 i 68 4 O. i 68 4 0 1 68 4 0 i 68 4 0 1 68 4 0 i 68 4 0 i 68 4 0 1 68 4 0 1 68 4 .0 1 68 4 0 1 68 4 0 1 68 4 0 1 68 4 0 1 68 4 0 1 6e 4 0 1 68 4 0 i 68 4 O i 68 4 0 1 68 4 0 i 68 4 0 I 68 4 0 1 68 4 0 1 68 4 0 1 68 4 0 1 68 4 0 I 68 4 O 1 68 4 0 1 68 PROCESS INDICATORS 000000 000000 000000 000000 000000 000000 000000 O0000O 000000 000000 OOO000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 O0000O 000000 OOOO00 000000 000000 000000 000000 000000 OOO000 O0000O 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 O0000O 000000 000000 000000 000000 OOOO00 000000 000000 000000 O00OO0 000000 O00000 000000 000000 000000 000000 000000 000000 000000 O00000 000000 000000 000000 000000 000000 000000 000000 000000 000000 Page 17 DEPT FSDL HINV HDCN GR NSDL HHOR . HHCH FDSN PE HDE DFL DATA NDSN PELC HDX SP RECORDS, NPHI Q-L HHR TEHS NRAT QS HHX DLOD DPHI RHOB HDRS DRHO CALl HHRS Page 18 8134.000 .6798.675 1.946 -12345,000 8100,000 6798,675 1.946 335.129 8000,.000 7250.675 3.190 399.307 7900.000 7072.074 5.72'0 166.602 7800.000 9101,875 14,923 78,060 7700..000 7345,675 7,670' 174,306 7'600,000 8042.475 10,847 101.914 ?500,000 3382.875 1.887 530,613 96, 16043, 2. -12345. 96, 16043', 2, 306, 99, 16606, 2, 386. 83. 16363. 5. 167, 47. 17338, 14, 75, 73, 16443, 5, 172, 56, 16857, 10, 96, 6l, 1346.0, 2. -498. 998 055 546 000 998 055 546 246 144 770 876 - 020 197 335 433 305 055 209 914 961 975 754 770 tOl 550 493 770 052 870 2074,211 6.235 0.000 3,368 2074,211 6,235 270.904 3,546 1486,856 4.511 301 .484 2,786 2188.354 3.433 141 , 43.4 7.433 3263,312 2.676 64.991 I 5,328 221 4. 942 3.018 148,054 5,580 2941 ,317 2,327 87,306 10, 659 1 65'I. 138 5,762 403,394 1,334 14667.818 i3.807 0,000 123450000. 14667.818 13.807 73.144 i51 .296 13367,355 5.361 85.925 153.263 1574'5. 816 3.852 3 1 . 665 147. 999 1.8029. 973 2 ,.939 15,173 141 ,4,91 15793.45.1 3,392 26.341 148,581 1 741 0,965 2.679 15. 032 136. 187 15142.113 5,810 i 17.662 15'1,466 0 4692 299 4577 348 4349 i46 4206 57 4177 158 4077 94 4248 -- 472 4034 .338 .015 . UOU .416 · 338 ,015 · 041 .967 ,417 · 094 ,078 .069 ,328 .011 · 044 · 008 .237 .025 ,184 .396 ,321 ,,-01 0 .659 ,252 ,255 ,Oil .289 .926 ,429 ,022 · 034 ,333 7.475 0.000 0,000 853.476 7,475 O, 000 32,690 856.216 9.503 -.017 38.318 789.908 7.605 .030 11 .791 757,576 5,840 .026 8,364 96 0,884 7. 537 .018 8.333 1412,984 6,257 -. 04 0 4,674 I 197.620 9. 693 ,015 41 . 34:-3 11 07,748 ,i6J 2.385 -i 2345.00'0 .161 2,385 2.984 .162 2.382 2.504 .165 2.377 6.002 .246 2,244 12.811 .178 2.357 5,737 ,204 2,314 9.812 -,127 2,859 1.885 .001 8.500 -12345.000 .00i 8,500 3.265. .040 I 1 , 073 2.585 ,019 9,968 5.973 .030 9.838 t3. 188 .013 10.110 5,781 · 026 1 0.370 1 0. 357 -.014 9. 792 2. 005 DATA RECORDS DEPT GR FDSN NDSH NPHI NRAT DPHI DRHO FSDL NSDL P£ PELC QL QS RHOB CALi MINV HNOR ' HDR HDX HHR HHX HDRS HHRS HDCN HHCN DFL SP TENS DLOD 7400.000 104.490 1343.283 13028.680 .459 10.~52 7929,074 16738,625 2,987 3,748 .027 .018 2,375 2,403 393,848 118,681 490,145 55,755 583,006 582,758 1,854 147,372 4062,946 '1182,824 Pag~ ,201 2,318 · 1 ,715 023 638 .716 i9 FILE TRAILER File name: &GSFOl,002 Maximum length: 1024 · TRAILER RE'CORDS Service name: Version #: File type: LO II Next f'ile: Date: Page 2O FILE. HEADER File name: .003 Service name: Version #: Date: Maximum length.: 1024 File t.vpe: LO Previous £ile: INFORMATION RECORDS Pagm 2i 'MNEM COHTEHTS ! UN I T TYPE CATG SIZE CODE ERROR CN WN FN COUN STAT CTRY APIN LATI LONG SECT TOWN RANG EK8 EDF EGL PD LHF 'DMF RUN TIME 'DATE LCC SON LUN FL LUL ENGI WITN DD CBDi CBL! TLI TCS TLAB BHT NRT NT NVIS DFPH DFL RH RHF HFST NFSS RHC ARCO ALASKA INC. KUPARUK NORTH SLOPE ALASKA ...... USA ...... 22Ii6,000 ................... O.Dmg, 0 Hin, 0 Deg, 0 Min, lin ............ IOE ............. 102,000 ........ I O1 . 000 ........ 67.000 ......... 240'0,000 ...... 3.1712790 .... ,, , 30 ............. 492-2-28 ..... 7636 .... uo' l SLOP NORTH SLOPE YARBRO RUGEN , , 8115,000 .............. @'12'0,000 .............. 6e2,ooo .............. 46~2,~00 ............. 0,000 ................ eli2-,O0.O ............. 1900,00'0 ............. .2400,00'0 .............. 155,'000 ............... 155,000 ............... Q~ICKGEL .~, CIRCULATED .,, 11.9.00 ................. ~2.000 ................... o,ooo .................... ~.000 ............ 2-,500 ............ 1,~O ............ 4,ooo,,. ......... HEAS., ..... 3,690 ............ i i O. 0 Sec O. 0 Sec IIIIIIII IIlIiIII IlIIIIlI illliIii i1111 iIliI i iii. II I IlIII i ItIi.· I IIIlI I IiiII · i · IIIllIIaI APl NUH: 50-029-221t6 ......... DATE LOGGED: 12-3i-90 ......... IlIIlIllIIIlllllIlIIIIIIlIIII IIIIlIIIII fIIllIIiI W II I I I · · · · I I I I IIliil IllItl I I l I i i ii ii i· iIiilliii iJliIliii iIIliiiiI iIilliliI · IIli i ilii · · iii i iiiI IlliIi ii iii ii Iii Ill/ill Iiii ·ill · i · I · ·ill IIIi III I Ill III · la · III I III IIIlII I I II I · II · I II i i ii .i · i i it ii · · i · · ! i i · i i i i i i i · · I · i I i FT FT FT FT FT FT FT FT FT HR HR DEGF DEGF LB/G CP OHHN OHHH DEGF OHHH 0 0 0 0 0 0 0 0 0 0 0 0 3 3 3 3 3 0 0 0 0 0 0 0 0 0 0 3 3 3 3 3 3 2 4 1 2 2 2 2 2 2 2 2 2 2 40 40 40 20 20 20 4 34 34 2 .5 3 4 4 4 2 2- 2 4 @ 2. 10 ~0 2.0 20 20 20 4 4 4 4 4 4 4 4 4 4 2.0 2.0 4 4 4 4 4 4 4 4 65 65 65 65 65 65 6.5 65 65 68 79 68 65 79 65 65 65 65 ~,5 68 68 68 68 68 68 68 68 68 65 65 68 68 68 68 68 68 65 IqNEN IqCST MCSS CS BS I NFORMAT I Ol, I RECORDS CONTENTS 83 000' I HE~S ........................................... g,~5 ......... : ............. : ................... 8 500 ' I IleliIelillemIiIleIIlelIemmmiIeIelIllIIllleellleleI UNIT 'DEGF TYPE CATG SIZE 4 i2 4. 4 CODE 68 Pag~ ERROR COMMENT RECORDS Well' LocatiOn Comment 1: SURFACE: 731' FSL & 3iI' FWL Well LoCation Comment 2: Wail Location Comment 3: Well Location Comment 4: well File Comment I: HRI,ML,SDLZDSN RUN IH COMBINATION. SPLICE ON LOG AT 7730' IS Well File Comment 2: DUE TO POOR HOLE CONDITIONS. HEAD TENS.ION AND & LINE TENSION Well File Comment 3: ARE RECORDED 4G.25' DEEP TO BOTTOM OF TOOL DUE TO SOFTWARE Wall Fil~ Comment 4: ERROR. DXCO = +2.0 & MXCO = -2.0 MMHOS. MUD CONTAINS ~ LIS tape ~pitt~n b~.: ANCHORAGE COMPUTING CENTER · ~ All curve and tool mnemonics u~ed ar~ those which most closel~ match · * Halliburton curve and tool mnemonics. HALLIBURTON TO SCHLUMBERGER TOP BOTTOM MNEM SERVICE UNIT MNEM SERVICE LINIT DEPTH FT DEPT FT GR2 SDL GAPI GR SDL GAPI FDSN2 DSN2 CPS FDSN DSN2 CPS NDSN2 DSH2 CPS HDSN DSH2 CPS NPHI2 DSN2 DECP NPHI DSN2 DECP t. IR~T2 DSN2 C/C NRAT DSN2 C/C DPHI2 SDL DECP DPHI SDL DECP DRH02 SDL G/C3 DRNO SDL G?C3 FSDL2 SDL CPS FSDL SDL CPS NSDL2 SDL CPS NSDL SDL CPS DEPTH DEPTH 35 O0 7327 75 7327 75 7327 75 7327 75 7327 75 7327 75 7327 75 7327 75 7327 75 8140 O0 8i 30 O0 8130 O0 8130 O0 8130 O0 8130 O0 8i 30 O0 81 30 O0 8130.00 8130.00 Pag~ 23 PE2 PELC2 QL2 Q$2 RHOB2 CALI2 TEHS2 DLOD2 SDL SDL SDL SDL SDL SDL SDL SDL G?C3 LBS LBS PE PELC QL Q$ RHOB CALI TENS DLOD S'DL SDL SDL SDL SDL SDL SDL G?C3 IN LBS LBS ?327.75 7327,75 7327.75 7327,75 7327.75 7327,75 7327,75 7327,75 8130.00 8130.00 8'13O. O0 8130.. O0 8130. O0 8130.00 8130.00 8130.00 ENTRY BLOCK~ ENTRY DATA FORMAT ' SPEC I F I CA T IONS TYPE SIZE CODE Pagm t6 1 66 0 1 66 ,** ENTRY BLOOK LEQEND TYPE DESCRIPTION 16 Datu~ zBeci?ication block sub-type 0 TerminaTor ( no more entries ) DATA F.ORMA T SPECIFICATIONS DATUM SPECIFICATION BLOCKS SERVICE SERVICE APl API AP1 AP1 FILE MNEM ID ORDER # UNIT LOG TYPE CLASS MOD # PRC # SIZE LVL SMPL RC PROCESS INDICATORS Page '25 DEPT 492228 FT 0 0 GR .SDL' 492228 GAPi 94 0 FDSN DSN2 492228 CPS 94 0 NDSH DSN2 492228 CPS' 94 0 NPHI DSH2 492228 DECP 94 0 HRAT DSH2 492228 C/C 94 O DPHI SDL 492228 DECP 94 0 DRHO SDL 492228 G/C3 94 0 FSDL 'SDL 492228 CPS 94 0 HSDL SDL 492228 CPS 94 0 PE' SDL 492228 94 0 PELC SDL .492228 94 O QL SDL 492228 ' 94 8 Q~ SDL 492228 94 0 RHOB SDL 492228 G/C3 94 0 CALl SDL 492228 IN 94 0 TENS SDL 492228 LBS 94 O DLOD SQL 492228 LBS 94 0 0 0 3 0 3 2 0 3 2 0 3 2 0 3 2 O 3 2 0 3 2 0 3 2 0 3 2 0 3 2 0 3 2 0 3 2 0 3 O 3 2 0 3 2 0 3 2 O 3 2 4 0 J 68 4 0 J 68 4 0 J 68 4 0 I 68 4 0 I 68 4 0 1 68 4 0 1 68 4 0 1 68 4 0 I 68 4 0 1 68 4 0 1 68 4 O. 1 68 4 0 t 68 4 0 1 68 4 0 1' 68 4 0 ~ 68 '4 O I 68 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 OOOO00 000000 000000 000000 000000 000000 OOOO00 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 DEPT FSDL TENS GR NSDL DL. OD FDSN PE DATA NDSN PELC RECORDS HPH I QL NRAT DPHI RNOB DRHO CALI Pag~ 26 6130 6754 6437 8100 6754 4692 $O0'O 7414 4463 7900 7667 4234 7800. 8853 4263 7700 752i '4148 7600 8121 4091 7500 87.05 4120 7400 7943 3934 .000 ,675 .767 .000 ,675 ,4. i6 · '000 ,675 .519 ,000 ,675 .620 . '000 .674 .232 , O00 .675 .783 .000 .675 .558 .000 .674 ,171 .000 .675 .190 81,526 16046,055 2162,648 81 .526 046. 055 1'40,080 108.715 16692,055 1096,788 78.645 16785.055 968,008 52,703 17380.387 838.132 78.323 16705.055 79.0,456 50,620 16885,055 89 O, 192 9'0.166 17434.055 852.380 96.127 16186.389 843.0'64 1485.824 5.618 1485.824 5,618 1402.349 4.835 2279,273 .3,740 31 03. 970 2.608 221 '2. 220 2.679 3046,427 2.395 1 46 O. 045 3.634 1371,469 3,394 13821.:094 5.214 13821,094 5,214 13287.793 5.280 16703.586 2.685 17861 . 6'09 3,122 15519.396 3.645 17367.400 2.690- 13144.150 1,079 13008.963 3.894 .466 -. 037 .466 -, 037 ,450 .I15 ,331 ,047 · 252 ,017 .320 ,014 ·245 ,025 ,433 .001 ,451 ,087 9.832 -.099 9,832 -,099 10.015 -. 0,10 7. 746 -. 002 6.0@2 .052 7.415 -. 027 6. 026 .065 9.516 .010 1 O, 026 -. 032 ,158 2,389 ,158 2.389 .172 2.365 ,178 2,357 ,230 2.270 .i71 2.368 ,207 2.308 .186 2.344 ,226 2,277 · 003 8.500 ,003 · 8,500 .035 11 .1i4 .033 9,929 .039 9.843 .036 i0.182 .024 10, 436 046 863 -,014 1 O, 755 DEPT FSDL TEllS NSDL DLOD DATA RECoRDs FDSN NDSN NPHI t. IRAT DPHI DRHO PE PELC QL QS RHO8 CALl Page FILE TRAILER File name: &GSF01,003 Maximum length: 1024 TRAILER RECORDS Service name: Version #: File type: LO Hext ~ile: Date: Page 28 :m~ FILE HEADER ~m~:~ File name: .004 Maximum length: 1024 Service name: File type: LO Version #: Previous ~ile: Date: MNEM CN WN FN COUN STAT CTRY APIH LATI LONG SECT TOWN RANG EKB E'DF EGL' PD LHF DH TIME DATE LCC LUN FL LUL ENGI WITH DD 'DL CBD1 CBL! TLI BLI TCS TLAB Bi-IT HAT HT NSS DFD MVIS DFPH DFL RM RHF MFST HFSS AMC INFORMATION CONTENTS ARCO ALASKA IflC. 1A-25 KUPARUK HORTH SLOPE .......... ALA.~KA ...... · .... USA ..... ' ..... 221 i6,000 ..................... 0 Deg. 0 Min. O. 0 Sec. o .o ,.,.,. .o. .o JOE ...................... I 02,000 .................. J(J! ,000 .................. 67,000, , ................. his ....................... 14,~ ....................... i<~ ....................... ~ l / l ~/90 ................ ~0 ...................... ~922~ .............. 7636 , NORTH SLOPE .... YREBEO .... EUGEN .... 8t ~5 00'0 ~120,00.0 ................ 4682,0 O0 ................ 4682 000 1900 000 1~. ~00,. ................. 1~, 0.00 .................. C~R~UL~TE~ ..... 11 .~00 ................... ~ 0 O0 0,000 .................... ~.000 ..................... ~.~00 ..................... ~ .~30 ..................... ~ 000 HE~S ............... 3, ~0 ..................... AP1 HUH: 50-029-221 DATE LOGGED i2-31-9 I i · J i i i'1 . i . . i i ,i I i i · I· , . ii I · ~I ·i , iIr iI Iril ,i ,.I id iIriIri (L ,, ,i i Ir !,IIIiIl ii ii I IIr · i i, [..l · ii iiiIr t · · i · I RECORDS UNIT · i · i I Ir I FT FI FT FT FT FT FT FT HR HR DEGF DEGF LB/G CP OHMH OHHH DEGF OHMH TYPE CATG SIZE CODE 0 O 40 65 0 0 40 65 0 0 40 65 0 0 20 65 0 0 20 65 0 0 20 65 0 O 4 68 0 0 34 65 0 0 34 65 0 0 2 65 0 0 3 65 0 0 3 65 0 3 4 68 0 3 4 68 0 3 4 68 0 3 2 65 0 3 2 65 0 3 2 6'5 0 0 2 79 0 0 4 68 0 0 8 65 0 O 2 79 0 0 10 65 0 0 10 65 0 .0 2 0 65 0 '0 20 65 0 0 20 65 0 0 20 65 0 3 4 68 0 3 4 68 0 3 4 68 0 3 4 68 .0 3 4 68 0 3 4 68 0 2 4 68 0 4 4 68 0 I 4 68 0 1 4 68 0 2 20 65 0 2 20 65 0 2 4 68 0 2 4 68 0 2 4 68 0 2 4 68 , .0 2 4 68 0 2 4 68 0 2 4 68 0 2 12 65 0 2 4 68 Page ERROR INFORMATION RECORDS ~0 CONTEHTS UNIT 'TYPE CAT~ SIZE CODE ERROR CS BS 83,000 .................................................. NE~S ............................................. 9.6~5 ................................................... 8,500 ............................. ~ ..................... DEGF 0 2 4 68 0 3 4 68 0 3 4 68 COMMENT RECORDS Well Location Comment l: SURFACE: 731' FSL & 311' FWL Well Location Commmnt 2: Wmll Location Commmnt 3: Well Location Commmnt 4: Well File Commmnt 1: HRI,ML,SDL/DSN RUN IN COMBINATION. SPLICE ON LOG AT 7730~ IS Wmll Film Commmnt 2: DUE TO POOR HOLE CONDITIONS. HEAD TENSION AND & LINE TENSION Wmll Film Commmnt 3: ARE RECORDED 46.25' DEEP TO BOTTOM OF TOOL DUE TO SOFTWARE Well Film Commmnt 4: ERROR. DXCO = +2.0 & MXCO = -2.0 MMHOS. MUD CONTAINS L.C.M. · m LIS tapm writtmn bp: ANCHORAGE COMPUTING CENTER ~m mm All curvm and tool mnmmonic~ u~md arm those which most closelp match mm · ~ HalliburtOn curve and tool mnemonics. ~ HALLIBURTON TO SCHLUMBERGER TOP BOTTOM MNEM SERVICE UNIT MNEM SERVICE UNIT DEPTH DEPTH DEPTH FT DEPT FT 35,00 8140.00 GR3 HRI GAPI GR HRI GAPI 46,25 4790,00 TENS3 HRI LBS TENS HRI LBS 46,25 4790,00 DLOD3 HRI LBS DLOD HRI LBS 46,25 4790,00 Pag~ 3i DATA F'ORMAT SPEC I F I CAT IONS ENTRY BLOCKS ENTRY · ~ ENTRY BLOCK LEGEND ~:~ TYPE DESCRIPTIOH Datum z~eci?ication block zub~type Terminator ( no more entries TYPE SIZE CODE 16 1 66 0 1 66 Page DA TA FORMAT DATUH SPECIFICATION BLOCKS SERVICE SERVICE AP1 APl APl APl MNEH ID ORDER # UNIT LOG TYPE CLASS MOD DEPT ~R HRI TENS HRI DLOD HRI 492228 FT 0 0 0 0 492228 GAPI 94 0 0 2 492228 LBS 94 0 0 2 492228 LBS 94 0 0 2 SPECIFICATIONS FILE PRC SIZE LVL SMPL RC 4 0 I 68 4 0 i 68 4 0 i 68 4 0 I 68 PROCESS INDICATORS OOOO00 000000 000000 000000 O00000 000000 000000 OOO000 000000 000000 OOOO00 000000 Page ~S DEPT 4?90.000 4700.000 4600.000 4500,000 .4400.000 4300.000 4200,000 4100,000 4000,000 390'0.000 3800,000 3700,000 3600,000 3500.000 3400,~000 3300,000 320'0.000 83.502 90.908 51 ,343 44,243 56.664 43.909 40,006 46,853 53,323 41,278 56,926 40,495 30,374 23,491 31,929 39,817 37,869 DATA RECORDS TENS 2804,004 2846.923 2832,617 2804.004 2632,331 2675,249 2660,943 2560,800 2560,800 2532,188 2489,269. 2474,963 2446,351 2417,738 2288,983 2303.289 2303,289 DLOD 756 760 736 731 72! 728 7'09 714 720 729 724 727 752 719 723 732 · 480 ,752 ,272 °40@ .668 .532 .352 ,284 ,3i2 ,080 , '148 ,436 . ,096 ,764 .60'0 .916 Pag~ DEPT GR TENS DATA DLOD RECORDS Page 35 3100. 3000, 2900. 2800, 2700, 2600, 2500, 2480, 2300, 2200. 2100 2.000 1900 i800 i700 1600 1500. 000 000 000 000 000 000 000 000 O00 000 ,000 000 000 000 000 000 000 42,040 36.466 38.145 39.257 40,380 36.453 33.465 4e.162 41.157 55.529 38,'000 44.606 33.44? 40.717 37,374 28.176 31.012 213'1.615 2131.615 2117,309 2103,003 1959.942 1988,554 1888,411 1888.411 1831.187 '1759.656 1802,574 1745.350 1788,268 1731,044 1659,513 16'02.288 16'02.288 724 697 695 680 692 718 685 697 702 6'30 710 732 75,3 754 761 ?@4 .696 .844 ,104 .308 .912 .12o .788 .296 .776 .172 ,448 .916 .740 ,412 .428 DEPT TENS DATA DLOD RECORDS Page 1400.000 1300.-000 1200,000 1100.-000 1000.000 900.000 800.000 700,~000 600..000 500,000 400,0.00 300.000 200,000 100,000 19.933 30,174 40.386 37.77'0 44,599 33.996 40.747 48.646 23.859 30,353 39.790 25.771 30.837 14.699 1545. 064 1516.451 1473. 533 1430,615 140;2,002 1344. 778 1287,553 i 216. 022 12'16. O22 1 ! 73.1 '04 ! 144,491 . 1115,879 1.072.961 'I 158,790 776,208' 775.1 12 782.236, 771 775. 112 763,604 753.192 743,876 754.036 749,904 763.6.04 758,672 765,796 807,444 FILE TRAILER m,~***~**~m.~.~.~**~ File name: &G5FO1.0'04 Maximum length: '!024 TRAIL'ER RECORDS Service name: Version #: File type: LO Next f'ile: Date: Page 37 *********************** REEL TRAILER **** Service name: &GSF01 Next reel: Date: 91,,"01/10 Origin: Comments: Reel name: 492228 Continuation #: 01 ,** TAPE TRAILER Service name: &GSF Next tape: Date: 91/0'1/10 Origin: Tape name: Comments: 492228 Continuation #: 01
