The URL can be used to link to this page

Home My WebLink About181-135Originated: Delivered to:9-Oct-25HalliburtonAlaska Oil and Gas Conservation Comm.Wireline & Perforating Attn.: Natural Resource TechnicianAttn: Fanny Haroun333 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 TYPEDATA TYPE LOGGING DATE PRINTS # DIGITAL # E SET#1 2P-422A 50-103-20400-01 910312860 Kuparuk River Multi Finger Caliper Field & Processed 23-Sep-25 0 12 2P-422A 50-103-20400-01 910313140 Kuparuk River Multi Finger Caliper Field & Processed 28-Sep-25 0 13 2X-12A 50-029-21189-01 910262801 Kuparuk River Leak Detect Log Field- Final 26-Aug-25 0 14 3G-07A 50-103-20127-01 910313294 Kuparuk RiverLeak Detect LogField- Final 14-Sep-25 0 15 3K-20 50-029-23019-00 910312855 Kuparuk River Multi Finger Caliper Field & Processed 26-Sep-25 0 16 3K-32 50-029-22763-00 910292590 Kuparuk River Multi Finger Caliper Field & Processed 31-Aug-25 0 17 3Q-07 50-029-21682-00 910313132 Kuparuk River Tubing Cut Record Field- Final 28-Sep-25 0 18 3Q-09 50-029-21674-00 910313102 Kuparuk River Plug Setting Record Field- Final 13-Sep-25 0 19 3T-617 50-103-20918-00 910346072 Kuparuk River Radial Bond Record Field & Processed 25-Sep-25 0 110 1B-10 50-029-20656-00 910325714 Kuparuk RiverLeak Detect Log with IntelliScopeField & Processed 16-Sep-25 0 1PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF:Fanny Haroun, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518FRS_ANC@halliburton.comDate:Signed:Transmittal Date:T40970202-067195-176190-085201-088197-076186-194186-186225-053181-135T40974T40974T40975T40976T40977T40978T40979T40980T40981Leak Detect Log with1B-1050-029-20656-00910325714Kuparuk RiverIntelliScopeField & Processed16-Sep-2501Gavin GluyasDigitally signed by Gavin Gluyas Date: 2025.10.09 13:02:18 -08'00' Originated: Delivered to:8-Oct-25HalliburtonAlaska Oil and Gas Conservation Comm.Wireline & Perforating Attn.: Natural Resource TechnicianAttn: Fanny Haroun333 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 TYPEDATA TYPE LOGGING DATE PRINTS # DIGITAL # E SET#1 1B-06 50-029-20603-00 910356999 Kuparuk River Multi Finger Caliper Field & Processed 6-Oct-25 0 12 1B-06 50-029-20603-00 910356999 Kuparuk River Packer Setting Record Field- Final 7-Oct-25 0 13 1B-10 50-029-20656-00 910292758 Kuparuk River Leak Detect Log Field- Final 5-Sep-25 0 14 1B-10 50-029-20656-00 910292758 Kuparuk RiverMulti Finger CaliperField & Processed 1-Sep-25 0 15 1B-10 50-029-20656-00 910292758 Kuparuk River Plug Setting Record Field- Final 2-Sep-25 0 16 1E-36 50-029-22927-00 910357582 Kuparuk River Multi Finger Caliper Field & Processed 4-Oct-25 0 17 1E-36 50-029-22927-00 910293121 Kuparuk River Plug Setting Record Field- Final 8-Sep-25 0 18 1H-116 50-029-23594-00 910313707 Kuparuk River Multi Finger Caliper Field & Processed 22-Sep-25 0 19 1R-35 50-029-23050-00 910312848 Kuparuk River Leak Detect Log Field- Final 19-Sep-25 0 110 1R-35 50-029-23050-00 910312848 Kuparuk River Multi Finger Caliper Field & Processed 18-Sep-25 0 1PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF:Fanny Haroun, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518FRS_ANC@halliburton.comDate:Signed:Transmittal Date:181-075181-135198-213218-012201-210T40969T40969T40970T40970T40970T40971T40971T49072T40973T490731B-1050-029-20656-00910292758Kuparuk RiverLeak Detect LogField- Final5-Sep-250141B-1050-029-20656-00910292758Kuparuk RiverMulti Finger CaliperField & Processed1-Sep-250151B-1050-029-20656-00910292758Kuparuk RiverPlug Setting RecordField- Final2-Sep-2501Gavin GluyasDigitally signed by Gavin Gluyas Date: 2025.10.09 12:57:29 -08'00' WELL NAME API #SERVICE ORDER # FIELD NAMESERVICE DESCRIPTIONDELIVERABLE DESCRIPTION DATA TYPEDATE LOGGEDCOLOR PRINTS CDsCD5-1950103207600000 CRU WLSetting RecordFINAL FIELD3-Aug-21CD5-1950103207600000 CRU WLSetting RecordFINAL FIELD11-Aug-21CD5-9650103208110000 CRU WLPERFFINAL FIELD21-Jul-21CD2-31050103208260000 CRU WLDCSTFINAL FIELD16-Sep-21CD2-31050103208260000 CRU WLUSITFINAL FIELD24-Aug-21CD2-31050103208260000 CRU WLUSITFINAL FIELD25-Aug-21CD5-3150103208280000 CRU WLPERFFINAL FIELD27-May-21CD1-01A50103202990100 CRU WLRSTFINAL FIELD12-Sep-21MT7-0650103208310000 GMTU WLCORROSIONFINAL FIELD3-Oct-21MT6-0850103207720000 GMTU WLPSRFINAL FIELD14-Sep-21MT6-0850103207720000 GMTU WLPSRFINAL FIELD22-Oct-21MT7-0650103208310000 GMTU WLMECH CUTTERFINAL FIELD2-Sep-21MT7-0650103208310000 GMTU WLUSITFINAL FIELD12-Dec-21MT7-0650103208310000 GMTU WLUSITFINAL FIELD16-Dec-21MT7--0150103208320000 GMTU WLSCMTFINAL FIELD15-Nov-21MT7-0650103208310000 GMTU WLUSITFINAL FIELD19-Feb-21Lookout 150103203590000 GMTU WLRSTFINAL FIELD29-Mar-21Lookout 150103203590000 GMTU WLRSTFINAL FIELD2-Apr-21Delivery Receipt______ďďǇĞůů_____X_______________________________________Print Name Signature DatePlease return via courier or sign/scan and email a copy to Schlumberger.A Delivery Receipt signature confirms that a package (box, envelope, etc.) has been received. The package will be handled/delivered per standard company reception procedures. The package's contents have not been verified but should be assumed to contain the above noted SLB Auditor-Originated:PTS - PRINT CENTER600 E 57th Pl - Ste AAnchorage, AK 99518Delivered to:AOGCCATTN: Natural Resources Technician333 W. 7th Ave., Suite 100Anchorage, AK 99501-3539Transmittal Date:20-Dec-21Transmittal #:________________Signature12/21/2021Wd͗ϭϴϭϭϯϱϬͲ^Ğƚ͗ϯϲϭϲϱJRBy Abby Bell at 1:43 pm, Dec 21, 2021 1D-0350029204080000 KRU WLIPROFFINAL FIELD29-Aug-211F-0750029208300000 KRU WLGLSFINAL FIELD13-Oct-212W-0950029212350000 KRU WLSCMTFINAL FIELD18-Nov-212W-0950029212350000 KRU WLSCMTFINAL FIELD22-Sep-212U-1350029212610000 KRU WLPPROFFINAL FIELD16-Oct-213N-0650029215380000 KRU WLPPROFFINAL FIELD31-Oct-211Y-1750029223680000 KRU WLPPROFFINAL FIELD25-Jul-211Q-20A50029225890100 KRU WLSBHPSFINAL FIELD29-Jul-213S-24A50103204560100 KRU WLUSITFINAL FIELD25-Nov-212N-318A50103203430100 KRU WLSCMTFINAL FIELD12-Nov-211D-0350029204080000 KRU WLIPROFFINAL FIELD27-Mar-211D-0550029204170000 KRU WLSCMTFINAL FIELD8-Oct-211D-0250029204290000 KRU WLIPROFFINAL FIELD2-Apr-211A-0550029206270000 KRU WLLDLFINAL FIELD1-May-211B-1050029206560000 KRU WLWHIPSTOCKFINAL FIELD25-Sep-211F-0350029208530000 KRU WLPERFFINAL FIELD19-Oct-211Y-0650029209580000 KRU WLPPROFFINAL FIELD1-Nov-212D-0850029211580000 KRU WLGLSFINAL FIELD18-Jul-212D-0450029211760000 KRU WLBISNFINAL FIELD20-Nov-212D-0450029211760000 KRU WLSCMTFINAL FIELD10-Oct-212X-1550029211990000 KRU WLPPROFFINAL FIELD17-Oct-211Q-0950029212090000 KRU WLIPROFFINAL FIELD17-Nov-212E-1450029212140000 KRU WLSHBPFINAL FIELD30-Oct-212W-0950029212350000 KRU WLBISNFINAL FIELD19-Nov-211Q-0250029212480000 KRU WLIPROFFINAL FIELD29-Apr-212W-1450029212530000 KRU WLIPROFFINAL FIELD1-May-211Q-1550029213080000 KRU WLIPROFFINAL FIELD28-Apr-211R-0850029213330000 KRU WLIPROFFINAL FIELD3-May-211R-1350029213850000 KRU WLIPROFFINAL FIELD27-Jun-213F-0250029214470000 KRU WLWHIPSTOCKFINAL FIELD14-Nov-213F-1450029215000000 KRU WLLDLFINAL FIELD30-May-213M-0550029217060000 KRU WLCHEM CUTFINAL FIELD28-Oct-213M-0550029217060000 KRU WLSTRINGSHOTFINAL FIELD27-Oct-21 ! " # " " $ % &' ( )*! + (% ,- !. /"!! 0- ,- 12132+.2 4, . " ( % 05267 ! )/+/7 /+037 & % //637 /5167 )6))7 )2217 8 9 , :;; .<#33 /05378% )5)579% $ 9, (; . /51678% /01178% +0078% )22179% )55679% )0)79% 1 =: ( * , . !4 6 = 3" $ % ( " &' ( % - ( )" $ > "%- & % > >*!< ? -?> (!!4 &' ! & : /27 11+17 )/6+7063/70#34/@ * 12@ 6#64/@ - 06627 &-A -A*-!%>!& 9*!88**! 3 % !1 ! ! 5" B"$ ! "#$%#&'(% ()* "#$%#&'(% ) ++) $;* B'226)2 ;A0032 6 ", <$ ,#%- +))$( )632#)60+7;)5+3#)5057 $ . /27 135+7 /( & > & :! % % "*!<"> C " #B #B +*( ( ($ C 126 > D % ( *E % 162/B"% 2/6 ,02+.1)6#530+ %& ///#//+27;/030#/0+07 C 0 $B$-FG- $ $B$%$ 9 8GG#3&9 !4 32/8 #*C 5 ,= 12132+2;132+;H131/6. 01B% > #8 !4 (-1 507 13+7 2#525 24121 " 62( By Samantha Carlisle at 12:05 pm, Nov 10, 2021 Digitally signed by Shane Germann DN: O=ConocoPhillips Alaska, CN=Shane Germann, E=shane.germann@cop.com Reason: I have reviewed this document Location: your signing location here Date: 2021.11.10 12:06:13-08'00' Foxit PDF Editor Version: 11.0.0 SFD 11/15/2021VTL 01/24/2022 DSR-11/10/21 RBDMS HEW 11/12/2021 Last Tag Annotation Depth (ftKB) End Date Wellbore Last Mod By Last Tag: RKB 8,975.0 6/7/2018 1B-10 zembaej Last Rev Reason Annotation End Date Wellbore Last Mod By Rev Reason: Install Inner Wedge 9/25/2021 1B-10 famaj Casing Strings Casing Description CONDUCTOR OD (in) 20 ID (in) 18.94 Top (ftKB) 31.3 Set Depth (ftKB) 80.0 Set Depth (TVD) … 80.0 Wt/Len (l… 91.50 Grade H-40 Top Thread WELDED Casing Description SURFACE OD (in) 13 3/8 ID (in) 12.35 Top (ftKB) 30.3 Set Depth (ftKB) 2,547.0 Set Depth (TVD) … 2,271.9 Wt/Len (l… 72.00 Grade N-80 Top Thread BTC Casing Description PRODUCTION OD (in) 9 5/8 ID (in) 8.86 Top (ftKB) 28.3 Set Depth (ftKB) 9,358.4 Set Depth (TVD) … 6,837.2 Wt/Len (l… 47.00 Grade L-80 Top Thread BUTT Tubing Strings Tubing Description Tubing – Production String Ma… 3 1/2 ID (in) 2.99 Top (ftKB) 23.6 Set Depth (ft… 8,477.4 Set Depth (TVD) (… 6,049.5 Wt (lb/ft) 9.30 Grade L80 Top Connection EUE Completion Details Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des Nominal ID (in) OD Nominal (in)Make Model Com 23.6 23.6 0.08 HANGER 3.910 13.625 FMC tc1Aems FMC 13 5/8 x 4 1/2" New Standard Big Bore Tubing Hanger W/ 5" RH Acme top 1,799.4 1,695.5 42.94 SSSV 3.812 6.923 Camco TR- MAXX- 5E Camco 4 1/2" TRMAXX-5E 3.812" SSSV 1797' 1,809.4 1,702.7 43.04 XO REDUCING 3.833 4.500 XO Pup 4 1/2" IBTM Box x 3 1/2" EUE-Mod Pin 8,451.7 6,027.1 29.40 SBE 2.990 3.980 BAKER 80/40 PBR Seal assy Baker 3 1/2" EUE seal Assy 25.67' OAL buried below liner top New up Tubing Description Tubing – Production String Ma… 3 1/2 ID (in) 2.99 Top (ftKB) 8,423.2 Set Depth (ft… 8,902.5 Set Depth (TVD) (… 6,425.4 Wt (lb/ft) 9.30 Grade L80 Top Connection EUE Completion Details Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des Nominal ID (in) OD Nominal (in)Make Model Com 8,423.2 6,002.3 29.55 PACKER 6.120 8.440 Baker Baker 9 5/8" x 3-1/2" SLZXP Liner top packer - Left in hole down 8,451.1 6,026.6 29.40 PBR 4.000 6.500 Baker Seal Bore Extension (3' space out off tag) 8,835.4 6,365.8 27.32 TANDEM WEDGE 2.992 8.250 Northern Solutions Outer Wedge Northern Solutions 3 1/2" x 9 5/8" Tandem Wedge Assembly 8,850.0 6,378.7 27.27 NIPPLE 2.813 4.480 X Nipple HES 3 1/2" x 2.813" X nipple Profile (SN:) 8,860.4 6,388.0 27.23 TANDEM WEDGE 2.992 8.250 Northern Solutions Outer Wedge Northern Solutions 3 1/2" x 9 5/8" Tandem Wedge Assembly 8,875.0 6,400.9 27.18 NIPPLE 2.813 4.500 X Nipple HES 3 1/2" x 2.813" X nipple Profile (SN:) 8,894.5 6,418.3 27.10 NIPPLE 2.813 4.500 X Nipple HES 3 1/2" x 2.813" X nipple Profile W/ RHC Plug Installed (SN: 2727A-4-8) 8,895.4 6,419.1 27.10 MULE SHOES 3.640 8.500 Baker Poorboy Overshot Baker 3 1/2" x 9 5/8" Poorboy Overshot (6.77' Swallow) Tubing Description Tubing – Production String Ma… 8.66 ID (in) 3.25 Top (ftKB) 8,901.1 Set Depth (ft… 8,945.3 Set Depth (TVD) (… 6,463.5 Wt (lb/ft) Grade Top Connection Completion Details Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des Nominal ID (in) OD Nominal (in)Make Model Com 8,909.6 6,431.8 27.05 SLIDING SLEEVE 2.750 5.750 BAKER CMU SLIDING SLEEVE; SEIZED IN CLOSED POSITION 12/8/2007 8,919.6 6,440.6 27.01 XO REDUCING 2.875 3.500 CROSSOVER 3.5 x 2.875 8,921.4 6,442.3 27.00 SEAL ASSY 2.440 3.400 BAKER GBH 80-32 LOCATOR SEAL ASSEMBLY 8,922.3 6,443.1 27.00 PACKER 3.250 8.660 BAKER D PERMANENT PACKER 8,937.1 6,456.3 26.95 NIPPLE 2.250 3.668 OTIS XN NO GO NIPPLE 8,944.5 6,462.9 26.92 SOS 2.441 2.875 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 8,795.0 6,329.9 27.44 FISH EV Camera/Shroud/UQ and LQ/25' 2.0" CT 10/12/2021 0.000 8,863.0 6,390.3 27.22 WHIPSTOCK 3 1/2" NORTHERN SOLUTIONS INNER WEDGE. TOWS SET AT 8,848' TIED INTO K1 MARKER. (8858' TIED IN TO TUBING TALLY/8863' TIED IN TO SCHEMATIC). OAL 12.1'. 9/25/2021 0.000 8,875.0 6,401.0 27.17 X-LOCK W/ FLOW THRU SUB 2.81 X LOCK (W/ PACKING), & FLOW THROUGH SUB (OAL 18.5") 4/3/2020 1.750 8,891.0 6,415.2 27.12 CEMENT RETAINER (ME) WEATHERFORD FH1 RETAINER, 2.75" OD X ( OAL=1.46 ) 3/30/2020 0.000 1B-10, 11/8/2021 1:27:21 PM Vertical schematic (actual) PRODUCTION; 28.3-9,358.4 CMT SQZ; 9,158.0-9,178.0 CMT SQZ; 9,146.0 ftKB CMT SQZ; 9,146.0-9,158.0 CMT SQZ; 9,128.0 ftKB CMT SQZ; 9,128.0-9,138.0 Production Casing Cement; 8,870.0 ftKB APERF; 8,959.0-8,979.0 PACKER; 8,922.3 Production Casing Cement; 8,925.0 ftKB Cement Squeeze; 8,901.0 ftKB SLIDING SLEEVE; 8,909.6 Cement Squeeze; 8,894.0 ftKB Cement Retainer; 8,904.0 Cement Squeeze; 8,904.0 ftKB CHEM CUT; 8,901.0 NIPPLE; 8,894.5 X-LOCK; 8,894.0 CEMENT RETAINER (ME); 8,891.0 X-LOCK W/ FLOW THRU SUB; 8,875.0 NIPPLE; 8,875.0 WHIPSTOCK; 8,863.0 NIPPLE; 8,850.0 RPERF; 8,818.0-8,870.0 FRAC; 8,818.0 FISH; 8,795.0 PACKER; 8,423.2 GAS LIFT; 8,401.1 GAS LIFT; 7,645.5 GAS LIFT; 6,733.2 GAS LIFT; 5,127.3 GAS LIFT; 2,859.1 SURFACE; 30.3-2,547.0 SSSV ; 1,799.4 CONDUCTOR; 31.3-80.0 HANGER; 23.6 KUP PROD KB-Grd (ft) 31.99 Rig Release Date 12/13/1981 1B-10 ... TD Act Btm (ftKB) 9,403.0 Well Attributes Field Name KUPARUK RIVER UNIT Wellbore API/UWI 500292065600 Wellbore Status PROD Max Angle & MD Incl (°) 59.73 MD (ftKB) 6,300.00 WELLNAME WELLBORE1B-10 Annotation Last WO: End Date 6/28/2019 H2S (ppm) 40 Date 8/12/2016 Comment Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Des Com Run Date ID (in) SN 8,894.0 6,417.9 27.11 X-LOCK 2.81 X LOCK, NO PACKING, W/ FLOW THROUGH SUB (OAL 18") 3/26/2020 1.750 8,901.0 6,424.1 27.08 CHEM CUT 2 3/8" Chemical cut. 6/26/2019 0.000 8,904.0 6,426.8 27.07 Cement Retainer Set Weather Cement Retainer (OAL 1.46') 10/5/2019 0.000 Mandrels Station No/SPM Top (ftKB) Top Incl (°) Item Des OD Nominal (in) Nominal ID (in) Make Model Top (TVD) (ftKB) 1 2,859.1 47.15 GAS LIFT 5.968 2.915 Camco MMG 2,509.8 2 5,127.3 57.06 GAS LIFT 5.968 2.915 Camco MMG 3,810.4 3 6,733.2 53.33 GAS LIFT 5.968 2.915 Camco MMG 4,654.6 4 7,645.5 34.06 GAS LIFT 5.968 2.915 Camco MMG 5,342.0 5 8,401.1 29.66 GAS LIFT 5.968 2.915 Camco MMG 5,983.1 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 2,859.1 2,509.8 47.15 Schlum berger Camco MMG 1 1/2 GAS LIFT GLV RK 0.188 1,274.0 8/31/2021 2 5,127.3 3,810.4 57.06 Schlum berger Camco MMG 1 1/2 GAS LIFT OV RK 0.188 0.0 8/31/2021 3 6,733.2 4,654.6 53.33 Schlum berger Camco MMG 1 1/2 GAS LIFT DMY RK 7/18/2019 4 7,645.5 5,342.0 34.06 Schlum berger Camco MMG 1 1/2 GAS LIFT DMY RK 7/18/2019 5 8,401.1 5,983.1 29.66 Schlum berger Camco MMG 1 1/2 GAS LIFT DMY RK 7/18/2019 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft )Type Com 8,818.0 8,870.0 6,350.3 6,396.5 C-4, C-3, 1B-10 4/17/1994 4.0 RPERF 3 3/8" Hyperjet; 60° phasing 8,959.0 8,979.0 6,475.8 6,493.6 C-1, UNIT B, 1B -10 4/17/1994 6.0 APERF 3 3/8" Hyperjet; 60° phasing 9,128.0 9,138.0 6,627.5 6,636.6 A-5, 1B-10 2/4/1982 4.0 CMT SQZ 9,146.0 9,158.0 6,643.9 6,654.7 A-4, 1B-10 2/4/1982 4.0 CMT SQZ 9,158.0 9,178.0 6,654.7 6,672.9 A-4, 1B-10 2/4/1982 4.0 CMT SQZ Stimulation Intervals Interva l Numbe r Type Subtype Start Date Top (ftKB) Btm (ftKB) Proppant Designed (lb) Proppant Total (lb) Vol Clean Total (bbl) Vol Slurry Total (bbl) 1 FRAC 1/21/2008 8,818.0 8,870.0 0.0 0.00 0.00 Cement Squeezes Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Des Com Pump Start Date 8,870.0 9,100.0 6,396.5 6,602.2 Production Casing Cement 10/5/2019 8,925.0 8,975.0 6,445.5 6,490.1 Production Casing Cement 10/5/2019 8,904.0 8,944.0 6,426.8 6,462.4 Cement Squeeze 10/5/2019 8,894.0 8,922.3 6,417.9 6,443.1 Cement Squeeze PUMPED TWO COIL VOLUMES OF FRESH WATER FOLLOWED WITH 69 BBLS OF 15.8# PPG CEMENT 3/30/2020 8,901.0 8,922.3 6,424.1 6,443.1 Cement Squeeze 3/30/2020 Notes: General & Safety End Date Annotation 9/25/2021 NOTE: WELL SCHEMATICS LISTS ALL DEPTHS 5' DEEPER THAN TUBING TALLY IN WELL FOLDER. 1/29/1998 NOTE: WAIVERED WELL: IA x OA ANNULAR COMMUNICATION 1B-10, 11/8/2021 1:27:22 PM Vertical schematic (actual) PRODUCTION; 28.3-9,358.4 CMT SQZ; 9,158.0-9,178.0 CMT SQZ; 9,146.0 ftKB CMT SQZ; 9,146.0-9,158.0 CMT SQZ; 9,128.0 ftKB CMT SQZ; 9,128.0-9,138.0 Production Casing Cement; 8,870.0 ftKB APERF; 8,959.0-8,979.0 PACKER; 8,922.3 Production Casing Cement; 8,925.0 ftKB Cement Squeeze; 8,901.0 ftKB SLIDING SLEEVE; 8,909.6 Cement Squeeze; 8,894.0 ftKB Cement Retainer; 8,904.0 Cement Squeeze; 8,904.0 ftKB CHEM CUT; 8,901.0 NIPPLE; 8,894.5 X-LOCK; 8,894.0 CEMENT RETAINER (ME); 8,891.0 X-LOCK W/ FLOW THRU SUB; 8,875.0 NIPPLE; 8,875.0 WHIPSTOCK; 8,863.0 NIPPLE; 8,850.0 RPERF; 8,818.0-8,870.0 FRAC; 8,818.0 FISH; 8,795.0 PACKER; 8,423.2 GAS LIFT; 8,401.1 GAS LIFT; 7,645.5 GAS LIFT; 6,733.2 GAS LIFT; 5,127.3 GAS LIFT; 2,859.1 SURFACE; 30.3-2,547.0 SSSV ; 1,799.4 CONDUCTOR; 31.3-80.0 HANGER; 23.6 KUP PROD 1B-10 ... WELLNAME WELLBORE1B-10 Mandrels Station No/SPM Top (ftKB) Top Incl (°) Item Des OD Nominal (in) Nominal ID (in) Make Model Top (TVD) (ftKB) 1 2,859.1 47.15 GAS LIFT 5.968 2.915 Camco MMG 2,509.8 2 5,127.3 57.06 GAS LIFT 5.968 2.915 Camco MMG 3,810.4 3 6,733.2 53.33 GAS LIFT 5.968 2.915 Camco MMG 4,654.6 4 7,645.5 34.06 GAS LIFT 5.968 2.915 Camco MMG 5,342.0 5 8,401.1 29.66 GAS LIFT 5.968 2.915 Camco MMG 5,983.1 1B-10L1, 11/8/2021 1:27:23 PM Vertical schematic (actual) PRODUCTION; 28.3-9,358.4 RPERF; 8,818.0-8,870.0 FRAC; 8,818.0 FISH; 8,795.0 PACKER; 8,423.2 GAS LIFT; 8,401.1 GAS LIFT; 7,645.5 GAS LIFT; 6,733.2 GAS LIFT; 5,127.3 GAS LIFT; 2,859.1 SURFACE; 30.3-2,547.0 SSSV ; 1,799.4 CONDUCTOR; 31.3-80.0 HANGER; 23.6 KUP PROD KB-Grd (ft) 31.99 Rig Release Date 12/13/1981 1B-10L1 ... TD Act Btm (ftKB) 9,905.0 Well Attributes Field Name KUPARUK RIVER UNIT Wellbore API/UWI Wellbore Status PROD Max Angle & MD Incl (°) MD (ftKB) WELLNAME WELLBORE1B-10 Annotation End DateH2S (ppm) 40 Date 8/12/2016 Comment Mandrels Station No/SPM Top (ftKB) Top Incl (°) Item Des OD Nominal (in) Nominal ID (in) Make Model Top (TVD) (ftKB) 1 2,859.1 47.15 GAS LIFT 5.968 2.915 Camco MMG 2,509.8 2 5,127.3 57.06 GAS LIFT 5.968 2.915 Camco MMG 3,810.4 3 6,733.2 53.33 GAS LIFT 5.968 2.915 Camco MMG 4,654.6 4 7,645.5 34.06 GAS LIFT 5.968 2.915 Camco MMG 5,342.0 5 8,401.1 29.66 GAS LIFT 5.968 2.915 Camco MMG 5,983.1 1B-10L1PB1, 11/8/2021 1:27:23 PM Vertical schematic (actual) PRODUCTION; 28.3-9,358.4 CMT SQZ; 9,158.0-9,178.0 CMT SQZ; 9,146.0 ftKB CMT SQZ; 9,146.0-9,158.0 CMT SQZ; 9,128.0 ftKB CMT SQZ; 9,128.0-9,138.0 Production Casing Cement; 8,870.0 ftKB APERF; 8,959.0-8,979.0 PACKER; 8,922.3 Production Casing Cement; 8,925.0 ftKB Cement Squeeze; 8,901.0 ftKB SLIDING SLEEVE; 8,909.6 Cement Squeeze; 8,894.0 ftKB Cement Retainer; 8,904.0 Cement Squeeze; 8,904.0 ftKB CHEM CUT; 8,901.0 NIPPLE; 8,894.5 X-LOCK; 8,894.0 CEMENT RETAINER (ME); 8,891.0 X-LOCK W/ FLOW THRU SUB; 8,875.0 NIPPLE; 8,875.0 WHIPSTOCK; 8,863.0 NIPPLE; 8,850.0 RPERF; 8,818.0-8,870.0 FRAC; 8,818.0 FISH; 8,795.0 PACKER; 8,423.2 GAS LIFT; 8,401.1 GAS LIFT; 7,645.5 GAS LIFT; 6,733.2 GAS LIFT; 5,127.3 GAS LIFT; 2,859.1 SURFACE; 30.3-2,547.0 SSSV ; 1,799.4 CONDUCTOR; 31.3-80.0 HANGER; 23.6 KUP KB-Grd (ft) 31.99 Rig Release Date 12/13/1981 1B-10L1PB1 ... TD Act Btm (ftKB) Well Attributes Field Name KUPARUK RIVER UNIT Wellbore API/UWI Wellbore Status Max Angle & MD Incl (°) MD (ftKB) WELLNAME WELLBORE1B-10 Annotation End DateH2S (ppm) 40 Date 8/12/2016 Comment !!"!# $$!%&'# # !%!# $ ()*+,-./0123-24%5+6-,,-5467+6.1557.61261$7+6 **728(9./6-26 67+6*+9: -55(,-239657++74;< 29-5 9=;< $ 1)*,767 *+9:*+9-55(,-239657++ 29-5 9=;<9./(*.,7-51(6 % 413561!#%.92.37,,61396>?276(25+%7*,1<9,,95@ A413561!!""# " $ 92.(,-67>1,71B7261(1C9+%9,,395413-+*72*21@2-)%+6-,,)1612(*157=9610 -5 %0672+6-,,37,, 375615,1++7+D;*)%*()*95@! 0672.1)*,7691510395413)9,,74!!&#+6-267427-)95@*-++7+% *-++(*E0*)-+429,,74611,0-.761!!"15+6*-++4135E0*)-+429,,74611,0-.7;96;7.-)7+6(./E !!""%312/74*9*7021)"/61"/51)1B7)756%+764135/*()*;*)*9*7.-)70277%*()*74/ C*9,,%0122-<1,-)9,,-++7);,< 16-,0,(94,1++7+012">1(2+F !;;,+ $ A)9,,95@-++7);,< A".2-<1,-)9,,395413427++95@-++7);,<-54427++395413 396>D*-++7+-6,706%29@>6%-54!29@>610>9@>+947,7-5741(661;1661)102-6>1,7E!%!&# >9,7;7.-)7+6(./956>7(**72395413E!%!"#12/74*9*7021) 61/,;+%*(,,740277(,,74 69@>69561G59**,7E!%!#12/74*9*7-54*(,,74*-+659**,7.15695(741(610>1,7 A"2-<1,- )9,,>-4,-2@7.>(5/10)-629=;21/751(60)9,,;14<6>-63-+,70695>1,727*-274012+,9./,9572(5+,9./ ,957396>!" @-(@7295@ -;. :! GE!!#$ !" %! G$H$ IE!!#$ %$!!#$ H$I & $ ,9./,9573!"J@-(@7295@:42906.,7-561G59**,7E!%!#396>0,136>21(@>G,1./:+76E !%!#396>+,9./,957.>7./+76@114+,9./,957 A">9*+61./+76695@-++7);,<6-@ G59**,7E!!"#!!!!#76K8(77L74;;,+10$C*9,,%,-<95;;,+15 61*: A"1B9467+695@%-,,57@-69B7 A>9*+61./)9,,95@-++7);,<396> ,1++7+%49+*,-.7";;,/*9B9+*9,,%+8(77L7-3-<+6-;,9+>276(25+-6)9,,95@2-67%!;*)95% ;*)1(6 ' $ ,1+7%6/,;+%42<6-@E!%!#-54+76)9,,95@*-2-)7672+9,,631+6295@7=96 3954131006-547)374@7021)!%!#61)9459@>647*6>10!%!#16-,,1++7+,-+6">2";;,+ ! $ 9,,+6295@! 7=9639541361 ! 7=96-6!!M%276(25+07,,021)"61-54>7-,7461;*)9,,2-6 >1,761!!"'#72012)7427-)95@*-++7+-6-+)9,,74%-5410-54!2<4290674 395413N.,7-5()*74+377*+-54.>-+741(610>1,7 A-54 A&%;(9,46(25 3K$)1612-54 6-,15;96-54429,,;(9,46(2561)9459@>647*6>10!% '&M $ 29,,;(9,46(256110 %M-54 A&72012)377/,< 0(5.691567+6*-++-54 A'%,-672-,429,,95@-++7);,<%C-@96-612%K$)16121B72<.;96%69795%*-++ .,7-5,<6>21(@>!J395413-54429,,,-672-,021) 61 %&M(,,+>12639*7261 % -54429,, ->7-461 %&!M3>727 95.3-+/9./74021) K61! K /9./744135-@-95E %& M%021) K61 ! K74(.74*()*2-67-546-2@76 10/,;+ 3-+/9./74413561!KE %!!"M15+(,674396> 75@9577295@3>9,7429,,95@->7-461 % M012-,-2@72;754)161261)9459@>647*610%'M ">2,1++7+";;,+ $ 15695(7616+(20-.7-54 A'-54 A!%!$)1612%95O7.612 +61**74(57=*7.674,<E% M21(;,7+>1169++(7%+612-@7277,;27-/27,-<0-9,7495969-695@+-076<,1./1(610 95O7.6127*-9274-54.15695(7495>1,776413595395413E!%!M(,,74D/,;+1B7242-@@95@ +1)76>95@61!%!' M3>727)1612+6-,,74-54 *1**74027792.(,-674137221429,,95@0,(94616>7;96-54 A!27.1509@(274 %421**74 A %.,7-51(6-++7);,<396&$396> 294@7+76;96%+764135-54+6-,,74E!%!M-5427-667)*6396>+-)727+(,6+;(642-@@95@ +1)76>95@(*>1,761" 7.-)7+6(./-6!%"M+7-,;127-++7);,<12/74*9*7021)'/ 61 P/ %216-674396>%B-2<*()*2-674135.19,-54;-./+947%*1*027761)9459@>647*6>10 !% M $ 396>B756(29+764135E!!#)(,69*,769)7+%*11>012.-)72-2(5 A92.(,-67.19,1B7261 09,67274,-/73-672-54*()*!;;,+41356>7;-./+947610,(+>37,,;127 A%.-)72- -++7);,<61)9459@>647*6>10!"' -;. $'&" $ 6(./-2.1++395413%.15695(761312/*9*7(2537,,1B7261*1372*21-54312/*9*7()*';;,+C-21(54 -54,76+1-/12/*9*7()*;;,+10573)(4396>**;;7-4+-5449+*,-.71(66>775410.19,12/ *9*75+*7.695O7.612%(,,)-=*(,,51)1B7)75692.(,-67.,7-5)(4-,,6>73-<-21(54%475+96<951(6!! **@2-**27++(27-541;+72B7+6-2674-6"37,,>7-4;,77495@+,13,<61"*+9E&-4+775& 7-2,972956>74-<%12/*9*751)1B7)756 $ 12/*9*7351)1B7)756%49*,-.737,,61$**@%0,13.>7./37,,%+6-69.,1++2-67Q";*>%;(9,4-54 49+*,-.737,,61 !**@%0,13.>7./37,,%510,13%+7.(27.19,952-)+%+629*(*%>166-*.19,%.15092)51 *27++(27%)125961237,,%+6-54;<7,957-B-9,-;,96,< " $ 15695(761+6-54;<012,957-B-9,-;9,96<%(,,,9571(610-5.>12-54;295@61+(20-.7%,95742906% (5-;,761*-++%#%27427++7,957>7-4%-/7+7.154-667)*661%312/*-+6#%.15695(7%*72012)95@ 7B72<# $ 15695(7396>,9574290661%!"#%(5-;,761)-/70123-24*21@27++%%611,+.1B727495+,(4@7%1;6-95 +-)*,7-54+75461,-;%*27*.92.(,-67>16497+7,61;2-/74135+,74@7%+)116>,<396>7,95742906% 7,957! .(6672%%0927.(66721547*6>!%' #%>(5@(*012-;96-++()95@-5.>12+%312/0277% & $ 15695(74396>,957%-6+(20-.7.15092)74@114.(66721*72-6915%+6114;-./7,95778(9*)756%27.1B72< 78(9*)756%"6157,7B-612+%396>;,1./+:.15092)74@114.(6%+7.(274.19,-5437,,%,957% +6()*75410+*11,-;,7%+629*4135-54,(;29.-612%%;,734135277,396>%0277L7 *2167.67437,,%+6-2674312/95@.>7./,9+6 -;. ' $E!' #$ HIR E!' #$ Page 1/15 1B-10 Report Printed: 11/4/2021 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) 10/1/2021 00:00 10/1/2021 02:00 2.00 MIRU, MOVE MOB P Spot rig over well, set down and burrem around the rig and sub. Set down stair ways/hand rails. Unhook jeeps and sows. 0.0 0.0 10/1/2021 02:00 10/1/2021 04:00 2.00 MIRU, MOVE NUND P N/U BOP stack to wellhead 0.0 0.0 10/1/2021 04:00 10/1/2021 06:00 2.00 MIRU, MOVE CTOP P Prep rig and reel stand area for installation of reel. R/U tiger tank and hard line from Wellhead. Hook up hard line from innerconnect areas. 0.0 0.0 10/1/2021 06:00 10/1/2021 10:30 4.50 MIRU, MOVE CTOP P New reel arrived on location. PJSM - installing of new reel into Sub. Install reel Shims and torque bolts as per specs. Continue R/U hard line to TT. 0.0 0.0 10/1/2021 10:30 10/1/2021 19:30 9.00 SLOT, WELLPR CTOP P *** Rig on Hi-line power** Continue with reel installation and M/U iron inside the reel. and position for electrician to install bulkhead 0.0 0.0 10/1/2021 19:30 10/1/2021 22:30 3.00 SLOT, WELLPR CTOP P Prep for stabbing pipe, remove seam from pipe, install sheave on skate hook stabbing cable to tugger 0.0 0.0 10/1/2021 22:30 10/2/2021 00:00 1.50 SLOT, WELLPR CTOP P Electrician install 10k pressure bulkhead 0.0 0.0 10/2/2021 00:00 10/2/2021 03:00 3.00 SLOT, WELLPR CTOP P Electrician install 10k pressure bulkhead 0.0 0.0 10/2/2021 03:00 10/2/2021 05:00 2.00 SLOT, WELLPR CTOP P Make up stabbing cable and stab coil into injector 0.0 0.0 10/2/2021 05:00 10/2/2021 09:30 4.50 SLOT, WELLPR CTOP P Test Mig in cable - good test Install CT connector 0.0 0.0 10/2/2021 09:30 10/2/2021 15:00 5.50 MIRU, WHDBOP CTOP P Pull test - fill coil with 80 degree fresh water. Pressure test conector 5000 psi - pull test 40K Pump slack forward @ 2 bpm for 30 mins. 0.0 0.0 Rig: NABORS CDR3-AC RIG RELEASE DATE 10/17/2021 Page 2/15 1B-10 Report Printed: 11/4/2021 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) 10/2/2021 15:00 10/3/2021 00:00 9.00 MIRU, WHDBOP BOPE P BOP test wintessed by Brian Bixby 250/5000 psi Test 1. Swab 2 Test 2. Blind/Shear, BOP TV2, Charlie 4, 5, 8, &12 Test 3. BOP TV 1, Charlie 3, 7, & 11 Test 4. Manual choke D & Super choke C Test 5. Romeo 3, Bleeder 3, Tango 2, Charlie 2, & 10 Test 6. Charlie 1, 9, Bravo 5, and Tango 1 – install TIW test joint Test 7. Lower 2” pipe slip rams, TIW #1, Romeo 1, Bleeder 1 Test 8. Annular BOP Test 9. Upper 2” pipe slip rams, Bravo 6, & 8 Test 10. Bravo 7 – swap out 2” test joint for 2-3/8” Test 11. 2-3/8” pipe slip rams, TIW#2 – check N2 levels, swap to 2” test joint Test 12. Draw down accumulator Test 13. Stab injector and line up to reverse circulate coil, test inner reel valve and stripper. Tested all gas detectors, pits, cellar, Verified flow alarms - PVT Fail / Pass B6, B7, B8, Grease and re- test Fail / Pass 2-3/8" Pipe slip rams equalizer 0.0 0.0 10/3/2021 00:00 10/3/2021 01:00 1.00 MIRU, WHDBOP BOPE P BOP test wintessed by Brian Bixby 250/5000 psi Test 1. Swab 2 Test 2. Blind/Shear, BOP TV2, Charlie 4, 5, 8, &12 Test 3. BOP TV 1, Charlie 3, 7, & 11 Test 4. Manual choke D & Super choke C Test 5. Romeo 3, Bleeder 3, Tango 2, Charlie 2, & 10 Test 6. Charlie 1, 9, Bravo 5, and Tango 1 – install TIW test joint Test 7. Lower 2” pipe slip rams, TIW #1, Romeo 1, Bleeder 1 Test 8. Annular BOP Test 9. Upper 2” pipe slip rams, Bravo 6, & 8 Test 10. Bravo 7 – swap out 2” test joint for 2-3/8” Test 11. 2-3/8” pipe slip rams, TIW#2 – check N2 levels, swap to 2” test joint Test 12. Draw down accumulator Test 13. Stab injector and line up to reverse circulate coil, test inner reel valve and stripper. Tested all gas detectors, pits, cellar, Verified flow alarms - PVT Fail / Pass B6, B7, B8, Grease and re- test Fail / Pass 2-3/8" Pipe slip rams equalizer 0.0 0.0 Rig: NABORS CDR3-AC RIG RELEASE DATE 10/17/2021 Page 3/15 1B-10 Report Printed: 11/4/2021 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) 10/3/2021 01:00 10/3/2021 03:00 2.00 MIRU, WHDBOP BOPE T Fail / Pass B6, B7, B8, Grease and re- test Fail / Pass 2-3/8" Pipe slip rams equalizer 0.0 0.0 10/3/2021 03:00 10/3/2021 06:00 3.00 PROD1, WHPST PRTS P Pressure test both PDL's & Tiger tank line. 0.0 0.0 10/3/2021 06:00 10/3/2021 08:30 2.50 PROD1, WHPST PULD P Perform Valve checklist. Install injector and reel counters PJSM - P/U clean out BHA 0.0 0.0 10/3/2021 08:30 10/3/2021 09:00 0.50 PROD1, WHPST CTOP P Open Tree/ Pump open SSV - install fusable cap. WH = 125 psi IA = 63 psi OA = 201 psi 0.0 0.0 10/3/2021 09:00 10/3/2021 11:00 2.00 PROD1, WHPST TRIP P RIH while pumping min rate . 3 bpm. 0.0 8,000.0 10/3/2021 11:00 10/3/2021 11:30 0.50 PROD1, WHPST CTOP P Stop and adjust gooseneck 8,000.0 8,000.0 10/3/2021 11:30 10/3/2021 12:00 0.50 PROD1, WHPST TRIP P Continue TIH with 2" coil 8,000.0 8,000.0 10/3/2021 12:00 10/3/2021 13:00 1.00 PROD1, WHPST CIRC P Circulate 1.5 X B/U monitor well for losses 1:1 returns - hole stayed full/static 8,000.0 8,000.0 10/3/2021 13:00 10/3/2021 15:00 2.00 PROD1, WHPST TRIP P TOOH with Clean out BHA from 8,000 ft. Tag up gently at surface Counters less then 1 ft off at surface. 8,000.0 90.0 10/3/2021 15:00 10/3/2021 16:00 1.00 PROD1, WHPST PULD P PJSM - Break off injector & P/U Milling BHA and load into injector 90.0 0.0 10/3/2021 16:00 10/3/2021 19:30 3.50 PROD1, WHPST PULD P Pick up 2-3/8" Northern Solutions motor w/ 2.80 Northern Solutions DSM (SN 9b11195) and Northern Solutions 2.79"ng String Reamer (SN 9b11197) Pressure Deploy BHA, replace packoffs 0.0 90.0 10/3/2021 19:30 10/3/2021 20:30 1.00 PROD1, WHPST TRIP P RIH w/ window mill assembly 100 fpm @ 1 bpm pump pressure 1000 psi , hold 1 for 1 returns 90.0 8,736.0 10/3/2021 20:30 10/3/2021 21:30 1.00 PROD1, WHPST TRIP T Encoder for reel side motor became disconnected and had to be replaced by electrician 8,736.0 8,736.0 10/3/2021 21:30 10/3/2021 23:45 2.25 PROD1, WHPST TRIP P RIH w/ window mill assembly 100 fpm @ 1 bpm pump pressure 1000 psi , hold 1 for 1 returns, Start Duo Vis down coil to be @ bit at top of whip stock , Tie in K1 @ 8671, Log F/ 8660 @ 5 fpm -19.5' Correction, RIH T/ 8820 to circulate Duo Vis from bit to surface 8,736.0 8,822.0 10/3/2021 23:45 10/4/2021 00:00 0.25 PROD1, WHPST CIRC P Circulat Duo Vis F/ Bit @ 8820 to surface 8,822.0 8,822.0 10/4/2021 00:00 10/4/2021 00:15 0.25 PROD1, WHPST CIRC P Circulat Duo Vis F/ Bit @ 8820 to surface 8,822.0 8,845.0 10/4/2021 00:15 10/4/2021 06:00 5.75 PROD1, WHPST MILL P Close EDC, RIH and dry tag WS @ 8846', P/U wt 34k, Pump @ 1.8 bpm 3855psi 670 diff Free spin, Start Milling @ 8845 @ 1fph 8,845.0 8,851.0 10/4/2021 06:00 10/4/2021 06:30 0.50 PROD1, WHPST MILL P Motor stall, 100% losses when first exited casing. P/U 25 ft, circ @ 1.8 BPM, slowly getting some returns back. TIH slowly 8,851.0 8,851.0 10/4/2021 06:30 10/4/2021 19:30 13.00 PROD1, WHPST MILL P Start milling 1.8 BPM, returns .5 bpm, 4041 psi, 545 psi diff pressure, WOB 2.81, MW in 8.55#, CT weight 12.6K, milling 1fph. 8,851.0 8,865.0 Rig: NABORS CDR3-AC RIG RELEASE DATE 10/17/2021 Page 4/15 1B-10 Report Printed: 11/4/2021 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) 10/4/2021 19:30 10/4/2021 19:51 0.35 PROD1, WHPST REAM P Ream window F/8840 to various depths as to not create ledge, Down passes as milled ( 1deg LOHS ) up passes 30L, 30R, and 180 R of drilled @ 1 fpm. 1.8bpm , returns 1.03 bpm 3567psi 763 diff MW 8.59 in / 8.67 out PU wt 32k 8,865.0 8,865.0 10/4/2021 19:51 10/4/2021 21:03 1.20 PROD1, WHPST CTOP T 1 pass up at as drilled tool face, on first pass down @ as drilled bit became stuck, worked pipe -12 to 3 down hole weight on bit, pushed 12 k wob and pumped 2bpm came free 8,865.0 8,865.0 10/4/2021 21:03 10/4/2021 22:03 1.00 PROD1, WHPST CIRC T Pump 100 k lsrv pill to bit and squeeze 15 bbls into window track and OH 8,865.0 8,865.0 10/4/2021 22:03 10/4/2021 23:45 1.70 PROD1, WHPST TRIP T POOH laying in remaining 25bbls of 100K LSRV pill, PU WT 34K , open edc POOH @ 107 FPM Pump rate In 1.2 / Out .61 BPM ~ .2 bpm seepage , @ surface holding 100 psi whp 8,865.0 8,865.0 10/4/2021 23:45 10/5/2021 00:00 0.25 PROD1, WHPST PULD T PJSM for Pressure undeploy , tag up at surface space out 1.2 ft Pressure undeploy BHA #2 window mill assembly 8,865.0 8,865.0 10/5/2021 00:00 10/5/2021 01:10 1.17 PROD1, WHPST PULD T Pressure Undeploy BHA# 2 window mill assembly 8,865.0 8,865.0 10/5/2021 01:10 10/5/2021 01:30 0.33 PROD1, WHPST PULD T Lay down , 10' Pup Jt , DSM 2.80 ng, String Reamer 2.79 ng, check Northern Solutions motor, all checked good decision made to re-run motor 8,865.0 8,865.0 10/5/2021 01:30 10/5/2021 02:00 0.50 PROD1, WHPST PULD T Pick up 2.79 ng Crayola mill SN# 0A7812 , Northern Solutions .4 deg AKO motor 8,865.0 8,865.0 10/5/2021 02:00 10/5/2021 03:00 1.00 PROD1, WHPST PULD T Pressure Deploy BHA# 3 Crayola window dressing assembly 8,865.0 8,865.0 10/5/2021 03:00 10/5/2021 05:00 2.00 PROD1, WHPST TRIP T RIH with BHA#3 crayola mill assembly, rih @ 100fpm pump .5 bpm with .5 bpm returns ~ .3 bpm loss rate , Tie in @ 8660 @ 5fpm for -23' correction , close edc run in hole to 8840 8,865.0 8,865.0 10/5/2021 05:00 10/5/2021 10:30 5.50 PROD1, WHPST MILL T Start dressing window 1.80 bpm, returns 1.2 bpm, MW in 8.6, MW out 8.68, Circ pressure 3432psi, WOB .1, CT weight 32K, Made roughly 20 passes reaming crayola mill up/down rolling TF 30 L/30 R/180 HS seeing light motor work @ 8855-8856' until it cleaned up. Cleaned out rathole down to 8865' 8,865.0 8,865.0 10/5/2021 10:30 10/5/2021 11:30 1.00 PROD1, WHPST MILL T While rotating 180 LS saw overpull @ TOW 8845' - motor stall. Mill was stuck but motor could still orientate freely. Work string Max overpull up 9K, Max down 10K, worked free. P/U and circulate hole clean 8,865.0 8,865.0 10/5/2021 11:30 10/5/2021 12:00 0.50 PROD1, WHPST CIRC T While circulating B/U moving BHA above window Pull tight into landing nipple @ 8835' - Drop down, made multiple attempts dry/ pumping. no luck. While pumping in free spin area, the motor stalled indicating we have some junk beside or around the Bit. Rotated 180 LS and pulled through nipple @ 8835' - continue TOOH with 3K drag on BHA. 8,865.0 8,865.0 10/5/2021 12:00 10/5/2021 14:30 2.50 PROD1, WHPST TRIP T TOOH @ 50 fpm to surface to inspect BHA. 8,865.0 90.0 Rig: NABORS CDR3-AC RIG RELEASE DATE 10/17/2021 Page 5/15 1B-10 Report Printed: 11/4/2021 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) 10/5/2021 14:30 10/5/2021 17:00 2.50 PROD1, WHPST PULD T CT @ surface PJSM - Pressure Undeploy BHA #3 - window dressing assembly. Large chunk( 1.5" - 2") of crayola mill had broken off and remained in hole. 90.0 0.0 10/5/2021 17:00 10/5/2021 19:00 2.00 PROD1, WHPST WAIT T Wait on slickline unit. 90.0 0.0 10/5/2021 19:00 10/5/2021 19:30 0.50 PROD1, WHPST SLKL T Slick line crew on location, PJSM, spot truck and offload lubricator to pipe shed. 90.0 0.0 10/5/2021 19:30 10/6/2021 00:00 4.50 PROD1, WHPST SLKL T PJSM on RU, RU slick line PCE and tool string - 2.84" gauge ring. 0.0 0.0 10/6/2021 00:00 10/6/2021 02:00 2.00 PROD1, WHPST SLKL T RIH with slick line, 2.84" gauge ring. Crew change out @ 01:30. Drift to X nipple @ 8,832'. POOH 0.0 0.0 10/6/2021 02:00 10/6/2021 05:00 3.00 PROD1, WHPST SLKL T RD drift tool string, RU flow through X lock, RIH. Hang up temporarily at he SSSV hand spang through, continue in hole, Set X lock @ 8,832'. 0.0 0.0 10/6/2021 05:00 10/6/2021 07:00 2.00 PROD1, WHPST SLKL T RIH with slick line check set. Sheared indicator pin, Good run. 0.0 0.0 10/6/2021 07:00 10/6/2021 09:00 2.00 PROD1, WHPST SLKL T R/D slickliine 0.0 0.0 10/6/2021 09:00 10/6/2021 11:15 2.25 PROD1, WHPST PULD T PJSM - P/U and deploy Whipstock BHA 0.0 74.0 10/6/2021 11:15 10/6/2021 13:27 2.20 PROD1, WHPST TRIP T TIH with BHA #4, Whipstock assembly. Slowing speed through jewelry sections in the well. 74.0 8,660.0 10/6/2021 13:27 10/6/2021 13:45 0.30 PROD1, WHPST DLOG T Tie into K1 for -22.5' correction. P/U weight 35k. 8,660.0 8,735.8 10/6/2021 13:45 10/6/2021 14:03 0.30 PROD1, WHPST TRIP T Continue in hole, tag X nipple @ 8834' - TOWS - 8821.88' - Set 0 degree HS. Closed ECD slowly pressured up 1500, 2000, 3000 psi set WS @ 3000 psi, pressure drop occurred, pumped additional 3 bbls to ensure it was set. P/U weight 35K 8,735.8 8,810.0 10/6/2021 14:03 10/6/2021 14:45 0.70 PROD1, WHPST DISP T Squeezed 30 bbls of 100K LSRV pill, lay in 10 bbls on top. 8,810.0 8,810.0 10/6/2021 14:45 10/6/2021 16:21 1.60 PROD1, WHPST TRIP T POOH 8,810.0 47.0 10/6/2021 16:21 10/6/2021 18:21 2.00 PROD1, WHPST PULD T Tag up, Space out, PUD BHA #4, whipstock running BHA. 47.0 0.0 10/6/2021 18:21 10/6/2021 18:51 0.50 PROD1, WHPST CTOP T Covid testing of all - All negative. 0.0 0.0 10/6/2021 18:51 10/6/2021 20:21 1.50 PROD1, WHPST PULD T PU and PD BHA #5 - Whipstock milling assembly. IA 113 psi, OA 239 psi 0.0 75.0 10/6/2021 20:21 10/6/2021 22:15 1.90 PROD1, WHPST TRIP T Bump up, set counters, RIH with BHA #5- Window milling assembly. String reamer and diamond mill both 2.80 No Go. Start displacing ~40 bbl 100k Cp Hi vis pill. 75.0 8,660.0 10/6/2021 22:15 10/6/2021 22:51 0.60 PROD1, WHPST DLOG T Tie into the K1. Lost counter signal temporarily, Picked up, counters returned, RBIH to complete tie in for - 23' correction. 8,660.0 8,750.0 10/6/2021 22:51 10/6/2021 23:09 0.30 PROD1, WHPST SVRG T Inspect and tighten inner reel iron. 8,750.0 8,727.0 10/6/2021 23:09 10/7/2021 00:00 0.85 PROD1, WHPST DISP T Squeeze high vis pill away. 1.80 bpm in, 1.25 bpm out, CT 3135 psi, BHP 3335 psi, WH 0 psi. IA 170 psi, OA 545 psi 8,727.0 8,727.0 Rig: NABORS CDR3-AC RIG RELEASE DATE 10/17/2021 Page 6/15 1B-10 Report Printed: 11/4/2021 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) 10/7/2021 00:00 10/7/2021 00:36 0.60 PROD1, WHPST TRIP T Close EDC, PU Wt 32 k lbs, RIH Wt 17 k lbs, pumps off, dry tag TOWS @ 8822' 8,727.0 8,822.0 10/7/2021 00:36 10/7/2021 03:00 2.40 PROD1, WHPST WPST T PU and set rate @ 1.78 bpm in, 1.25 bpm out, CT 3500 psi, BHP 3368 psi. Free spin diff 500 psi. RIH and mill exit window. CT wt 11.38 k lbs, WOB 2 k lbs, one stall on first tag at rate, P clean and restart. mill exit window w ~ 125 psi motor work. ROP 0.8 ft/hr 8,822.0 8,823.8 10/7/2021 03:00 10/7/2021 15:00 12.00 PROD1, WHPST WPST T Milling 2.80" exit window. CT 3627 psi, BHP 3364 psi, @ 1.79 bpm in and 1.26 bpm out. Ct Wt 11.4 k lbs, WOB 2.17 k lbs, ROP 0.8 ft/hr. 8,823.8 8,827.9 10/7/2021 15:00 10/7/2021 18:00 3.00 PROD1, WHPST WPST T Milling, CT 4'129 psi, BHP 3,369 psi, @ 1.77 bpm in and 1.36 bpm out. Ct Wt 10.9 k lbs, WOB 3.26 k lbs 8,827.9 8,828.8 10/7/2021 18:00 10/7/2021 21:00 3.00 PROD1, WHPST WPST T Milling 2.80" exit window. CT 4,031 psi, BHP 3,398 psi, @ 1.78 bpm in and 1.35 bpm out. Ct Wt 10.3 k lbs, WOB 3.4 k lbs. **Bleed OA from 977 psi to 600 psi. Mostly gas. IA 414 psi 8,828.8 8,830.0 10/7/2021 21:00 10/8/2021 00:00 3.00 PROD1, WHPST WPST T Milling 2.80" exit window. CT 3,835 psi, BHP 3,387 psi, @ 1.79 bpm in and 1.39 bpm out. Ct Wt 10.64 k lbs, WOB 3.8 k lbs 8,830.0 8,831.0 10/8/2021 00:00 10/8/2021 03:00 3.00 PROD1, WHPST WPST T Milling 2.80" exit window. CT 3,835 psi, BHP 3,387 psi, @ 1.79 bpm in and 1.39 bpm out. Ct Wt 10.64 k lbs, WOB 3.8 k lbs 8,831.0 8,831.5 10/8/2021 03:00 10/8/2021 08:54 5.90 PROD1, WHPST WPST T Milling 2.80" exit window. CT 3,778 psi, BHP 3,401 psi, @ 1.79 bpm in and 1.39 bpm out. Ct Wt 10.57 k lbs, WOB 3.8 k lbs Penetrated 9-5/8" at 8832, returns fell from 1.4 to 1.1 and healed to 1.2 bpm. **suction pit foamed up @ 0410 Time mill @ 1'/hr to 8833.2 Mill rat hole to 8847' 8,831.5 8,847.0 10/8/2021 08:54 10/8/2021 10:30 1.60 PROD1, WHPST REAM P Ream window @ 1'/min , 3 passes @ HS, 1 pass ea. @ 30L , 30R, and 180, Pump rate 1.78 bpm 3748 psi 512 diff , pu wt 35 8,847.0 8,847.0 10/8/2021 10:30 10/8/2021 11:18 0.80 PROD1, WHPST CIRC P Circulate sweeps 5 bbl lowvis followed by 5 bbls high vis 8,847.0 8,847.0 10/8/2021 11:18 10/8/2021 13:30 2.20 PROD1, WHPST TRIP P Open EDC , POOH 100 fpm pumping 2 bpm with 1.33 bpm returns, ~.3 bpm seepage , pump pressure 3525 psi , perform jog @ 500' ran in hole @ 100 fpm T/1147, POOH tag up @ surface 8,847.0 8,847.0 10/8/2021 13:30 10/8/2021 15:00 1.50 PROD1, WHPST PULD P PJSM , space out tool, pressure undeploy BHA# 5 window mill assembly and lay down tools 8,847.0 8,847.0 10/8/2021 15:00 10/8/2021 15:18 0.30 PROD1, DRILL PULD P Pick up bha # 6- 2.5 deg AKO w/ BH Talon Bit 8,847.0 8,847.0 10/8/2021 15:18 10/8/2021 16:33 1.25 PROD1, DRILL PULD P Pressure Deploy BHA# 6 - Build drilling assembly, surface pressure 470psi 8,847.0 8,847.0 10/8/2021 16:33 10/8/2021 18:15 1.70 PROD1, DRILL TRIP P Tag up set depth 72.21 for bha#6 , RIH @ 100 fpm .35 bpm 8,847.0 8,847.0 10/8/2021 18:15 10/8/2021 18:33 0.30 PROD1, DRILL DLOG P Tie into the K1 for - 22.5' correctio 8,847.0 8,847.0 Rig: NABORS CDR3-AC RIG RELEASE DATE 10/17/2021 Page 7/15 1B-10 Report Printed: 11/4/2021 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) 10/8/2021 18:33 10/8/2021 18:57 0.40 PROD1, DRILL TRIP P Continue in hole, park and close EDC, PU Wt 32 k lbs, RIH though window clean. Slight WOB bobble and CT wt bobble at 3 foot below the window ( 8835') continue in hole 8,847.0 8,847.0 10/8/2021 18:57 10/8/2021 20:00 1.05 PROD1, DRILL DRLG P Drill L1 buid turn, CT 3,949 psi @ 1.80 bpm in and 1.40 bpm out. CT Wt 10.9 k lbs, 3 k WOB. 8,847.0 8,906.0 10/8/2021 20:00 10/9/2021 00:00 4.00 PROD1, DRILL DRLG P Drill L1 buid turn, CT 3,960 psi @ 1.80 bpm in and 1.46 bpm out. CT Wt 11.4 k lbs, 3 k WOB. 8,906.0 8,976.0 10/9/2021 00:00 10/9/2021 06:30 6.50 PROD1, DRILL DRLG P Drill L1 build turn, CT 4128 psi @ 1.80 bpm in and 1.51 bpm out. CT Wt 10.6 k lbs, 1.5 - 3 k WOB. Free spin diff 500 psi. 8,976.0 9,220.0 10/9/2021 06:30 10/9/2021 09:00 2.50 PROD1, DRILL TRIP P POOH @ 50'/min to window , Open EDC @ 8790' , POOH @ 100'/min 2.24 bpm 4120 psi 9,220.0 78.0 10/9/2021 09:00 10/9/2021 10:30 1.50 PROD1, DRILL PULD P PJSM, Tag up and space out 1.2' , Pressure Un-deploy BHA # 6 Build Assembly 550 psi surface pressure 78.0 0.0 10/9/2021 10:30 10/9/2021 11:00 0.50 PROD1, DRILL BOPE P Vacuume out stack and function test bop's 0.0 0.0 10/9/2021 11:00 10/9/2021 12:30 1.50 PROD1, DRILL PULD P Pick up xtreme .5 AKO motor with Hycalog SR3211-A3 SN# A257637 , Deploy BHA # 7 Lateral Drilling Assembly , change packoffs 0.0 78.0 10/9/2021 12:30 10/9/2021 15:00 2.50 PROD1, DRILL TRIP P Tag up set depth, RIH 100 fpm .4 bpm ,Close EDC @ 500' shallow agitator test 1.8 bpm 4520 psi 1045 diff , Tie in @ 8680 5 fpm for -24.5' Correction, 78.0 9,224.0 10/9/2021 15:00 10/9/2021 17:54 2.90 PROD1, DRILL DRLG P Tag bottom @ 9224' , begin drilling , 1.85 bpm in 1.36 bpm out 4760 psi , up wt 36 K coil wt while drilling 9.4 K 1.25 WOB ROP 200'/hr pulling bha wiper every 100' due to low out rate 9,224.0 9,620.0 10/9/2021 17:54 10/9/2021 18:06 0.20 PROD1, DRILL WPRT P PUH on wiper trip. PU Wt 37 k lbs. 9,620.0 9,248.0 10/9/2021 18:06 10/9/2021 18:18 0.20 PROD1, DRILL WPRT P RBIH 9,248.0 9,620.0 10/9/2021 18:18 10/9/2021 22:24 4.10 PROD1, DRILL DRLG P BOBD- CT 4560 psi, BH 3571 psi, @ 1.8 bpm in and 1.40 bpm out. Free spin diff 1120 psi. BHA kicked from 93° to 89.5° @ 9680' ROP fell from 200 ft/hr to sub 100 ft/h ~ 9678' PU Wt 42 k lbs @ 9691' PU Wt 55 k lbs @ 9693' - drilling something different, ratty, stacking weight. Kicked down again @ 9780' from 91.5° to 89° @ 9821' dropped pump rate to 1.6 bpm, targeted 3.5 k WOB, skidded along hard layer then kicked down to 83° @ 9884' Drilling low res rock at high ROP, unable to break through hard layer ~ C3 /C4 interface. Geo reports flakes of siderite in cuttings. 9,620.0 9,905.0 Rig: NABORS CDR3-AC RIG RELEASE DATE 10/17/2021 Page 8/15 1B-10 Report Printed: 11/4/2021 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) 10/9/2021 22:24 10/10/2021 00:00 1.60 PROD1, DRILL TRIP P POOH for larger bend motor. PU Wt 34 k lbs Open hole clean. Slight 0.8 k lbs WOB tug at 8824.5' Open EDC, Continue to POOH 2.12 bpm in and 1.45 bpm out. 9,905.0 3,713.0 10/10/2021 00:00 10/10/2021 01:00 1.00 PROD1, DRILL TRIP P Continue to POOH, CT Wt 14 k lbs 2.12 bpm in and 1.59 bpm out. 3,713.0 78.0 10/10/2021 01:00 10/10/2021 02:30 1.50 PROD1, DRILL PULD P Bump up & space out. PUD BHA #7, lat drilling assembly w 0.5° AKO moor and Hyc A3 bit. 78.0 0.0 10/10/2021 02:30 10/10/2021 04:06 1.60 PROD1, DRILL PULD P PU and PD BHA #8, L1 lateral drilling assembly - second try. 0.0 78.0 10/10/2021 04:06 10/10/2021 04:30 0.40 PROD1, DRILL TRIP P Bump up, set counters, RIH with BHA #8, NOV agitator, 0.8° AKO motor with BH Dynamus bit. 78.0 1,595.0 10/10/2021 04:30 10/10/2021 10:30 6.00 PROD1, DRILL SVRG T Injector stopped @ 1595' Troubleshoot issue. 1,595.0 1,595.0 10/10/2021 10:30 10/10/2021 12:00 1.50 PROD1, DRILL TRIP P Shallow agitator test 1.8 bpm , 915 dif 4275 pp , RIH @ 100 fpm , .25 bpm , tie in @ 8680' for -25' correction , started mud swap from duovis to power pro , PU wt 35 K SO wt 15 k RIH to 8820 1,595.0 8,820.0 10/10/2021 12:00 10/10/2021 12:30 0.50 PROD1, DRILL TRIP T Set down in window @ 8825' , pu wt 45 K to 8790' dragging junk pump 1 bpm motor stalled , broke free 8,820.0 8,790.0 10/10/2021 12:30 10/10/2021 13:15 0.75 PROD1, DRILL CIRC T Circulate Power Pro to bit for mud swap 9 bbls in pipe when hung up decision was made to finish with fluid swap prior to trip out 8,790.0 8,790.0 10/10/2021 13:15 10/10/2021 14:45 1.50 PROD1, DRILL TRIP T POOH EDC open pump 2.4 in pump pressure 3850 psi , trip out for D331 clean out bha 8,790.0 72.6 10/10/2021 14:45 10/10/2021 16:00 1.25 PROD1, DRILL PULD T PJSM , tag up space out 1.2' , Pressure undeploy BHA# 8 Lateral drilling assembly .7 AKO motor 545 psi surface pressure 72.6 0.0 10/10/2021 16:00 10/10/2021 16:12 0.20 PROD1, DRILL PULD T Reconfigure BHA, drop ultra slim resistivity for clean out run. 0.0 0.0 10/10/2021 16:12 10/10/2021 17:24 1.20 PROD1, DRILL PULD T PU/ PD BHA #9, clean out run with 0.6° AKO motor and D331 ridge set bit. ** 2.79" no Go 0.0 62.0 10/10/2021 17:24 10/10/2021 18:36 1.20 PROD1, DRILL TRIP T RIH W BHA #8, 62.0 8,660.0 10/10/2021 18:36 10/10/2021 19:00 0.40 PROD1, DRILL TRIP T Tie into the K1 for -26' correction. Close EDC, 8,660.0 8,717.0 10/10/2021 19:00 10/10/2021 20:00 1.00 PROD1, DRILL SVRG T Service rig, lock out reel and tighten leaking inner reel iron - took two attempts 8,717.0 8,717.0 10/10/2021 20:00 10/10/2021 21:54 1.90 PROD1, DRILL WASH T PU W 38 k lbs, RIH, 8801, stack weight and pressure up, stall. PU clean @ 35 k lbs. RBIH and stacked 2.3 k WOB, hard stall with heavy reactive torque. PU Wt 40 k lbs saw -4.5 k WOB then drug -2.6 k WOB till popped free. Chase 10 bbl High Vis surface to surface, pristine returns. RBIH, cut pump rate to min ~.4 bpm Clean to stack out with 4 k lbs WOB just above window at 8820'. PU Wt 45 k bs, -4 k WOB. Pressured up, stalled. PUH dragging junk. Work pipe up and down, rotate HOT left right, some amping up but mostly free, work pump to .7 bpm and 1000 psi diff. 8,717.0 8,455.0 Rig: NABORS CDR3-AC RIG RELEASE DATE 10/17/2021 Page 9/15 1B-10 Report Printed: 11/4/2021 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) 10/10/2021 21:54 10/10/2021 22:36 0.70 PROD1, DRILL TRIP T Pull heavy at Seal bore assembly, CT Wt 50 k lbs, -14.9 k WOB. Work pipe, down weight 10 k lbs up weight -17 k WOB. Pump down the back side, ( WH 1418, 1.69 bpm, BHP 3470 psi, ECD 11.2 ppg), rotate HOT, work pipe. Pop free. 8,455.0 8,455.0 10/10/2021 22:36 10/11/2021 00:00 1.40 PROD1, DRILL TRIP T PUH while pumping 5 bbls down back side. Consult with town engineering. Line up down the coil build 50 bbl Hi vis sweep while continuing to pull slowly up hole. IA = 184 psi and OA = 541 psi 8,455.0 8,190.0 10/11/2021 00:00 10/11/2021 02:12 2.20 PROD1, DRILL DISP T RIH to 8400' and lay in 46 bbls of high vis pill while pulling up hole. Park and line up down the back side. Bullhead hi vis sweep to the formation at 2.3 bpm, WH 1399, ECD 15 ppg. Slowly RIH while bullheading. 8,190.0 4,615.0 10/11/2021 02:12 10/11/2021 03:12 1.00 PROD1, DRILL WASH T Swap back to pumping down the coil. trip in hole. Set rate @ 8400', CT RIH Wt 13 k lbs, CT 3,442 psi At 1.88 bpm in and 1.56 bpm out. Free spin diff 431 psi. SBE area clean, 4,615.0 8,860.0 10/11/2021 03:12 10/11/2021 03:24 0.20 PROD1, DRILL DLOG T Tie into the K1 for +7' correction PU Wt 31 k lbs. 8,860.0 8,708.0 10/11/2021 03:24 10/11/2021 03:30 0.10 PROD1, DRILL WASH T Continue to RIH. CT Wt 14 k lbs, CT 3448 psi @ 1.88 bpm in and 1.61 bpm out. BHP 3408 psi, free spin diff 425 psi. 10.48 ECD at the window. 8,708.0 8,822.9 10/11/2021 03:30 10/11/2021 04:18 0.80 PROD1, DRILL WASH T Set down in the window @ 8822.87. WOB to 3.39 k lbs, stall. PU Wt 35 k lbs, clean. Restart, drop RIH speed through window from 5 ft/min to 1 ft/min stall. again at 0.3 ft/min stall 33 k PU Wt - clean Sneak up on it and set auto driller at 3' per hr, saw motor work 8822.39' burn off, stack and stall @ 8822.43', reset, same effect stall at 8822.4' PU 35 k lbs, clean, pumps to min rate, RIH, stack out 3.4 k WOB at 8822.3' PU 32 k lbs, clean. 8,822.9 8,822.9 10/11/2021 04:18 10/11/2021 06:18 2.00 PROD1, DRILL TRIP T POOH with BHA #9. Puming 1.88 bpm in and 1.54 bpm out, 8,822.9 62.0 10/11/2021 06:18 10/11/2021 07:48 1.50 PROD1, DRILL PULD T PUD BHA # 9 D331 clean out assembly 62.0 0.0 10/11/2021 07:48 10/11/2021 10:33 2.75 PROD1, DRILL WAIT T Waiting for Baker Oil Tools hand with venturi 0.0 0.0 10/11/2021 10:33 10/11/2021 12:33 2.00 PROD1, DRILL PULD T Pick up Baker Oil Tools Venturi and UP/ Down Jars , High side tool with scoup facing up, Pressure Deploy BHA# 10 venturi run 0.0 0.0 10/11/2021 12:33 10/11/2021 14:27 1.90 PROD1, DRILL TRIP T Tag up @ surface, set depths 66.41' , RIH with BHA# 10 venturi assembly , 100 fpm EDC open pump .34 bpm , Tie in @ 8680' for -25' correction RIH to 8800' Close EDC PU wt 34 k 0.0 8,800.0 Rig: NABORS CDR3-AC RIG RELEASE DATE 10/17/2021 Page 10/15 1B-10 Report Printed: 11/4/2021 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) 10/11/2021 14:27 10/11/2021 15:21 0.90 PROD1, DRILL FISH T Close EDC , pump 2 bpm , Wash down with venturi@ 2'/min F/8800 T/ 8821.95 tagged fish W/ 1.8 wob circulated on fish 1 min , picked up 34K to 8815, Wash down with Scoup down F/ 8815 T/88821.17 w/ .3 wob , PU T/8815 31 k - 1.2 WOB , Turn veturi scoup up, Wash down F/ 8815 T/8821.17 @ 1 fpm set down .46 wob , torque in with tool pu 31 k orient 90 R wash F/ 8815 T/ 8821.17 sat down .91 wob orient 180 R WOB fell to .4 , RIH T/8821.33 1.08 WOB Orient back to 90R tool torqued up, PU T/ 8813 Wash down F/8813 T/8821.17 set down .86 wob , P/U T 8812 RIH to 8821.53 set down 2.5 wob , P/U to 8812 RIH 90 L T/ 8821.29 Set Down 1.8 wob, torque L pick up T/8813 orient HS, RIH T/8821.35 set down, PU T/ 8813.57 orient low side RIH T/ 8821 WHP 175psi dump choke RIH T/8820.89 .51 wob 8,800.0 8,821.0 10/11/2021 15:21 10/11/2021 17:21 2.00 PROD1, DRILL TRIP T Paint yellow flag - POOH w/ BHA # 10 straight venturi assembly 8,821.0 0.0 10/11/2021 17:21 10/11/2021 19:21 2.00 PROD1, DRILL PULD T PJSM , PUD BHA# 10 service break venturi tool and install nozzle on end of coil 0.0 0.0 10/11/2021 19:21 10/11/2021 19:57 0.60 PROD1, DRILL CIRC T Circulate coil over to clean water 0.0 0.0 10/11/2021 19:57 10/11/2021 20:42 0.75 PROD1, DRILL CIRC T Pump 80 bbls clean water down well @ 2.5bpm clear well bore of power pro 0.0 0.0 10/11/2021 20:42 10/11/2021 21:30 0.80 PROD1, DRILL PULD T Pop injector off well and pick up camera bha , test cameral @ Surface max od on sleeve 2.375" 0.0 16.0 10/11/2021 21:30 10/12/2021 00:00 2.50 PROD1, DRILL TRIP T Tag up, set depth, RIH @ 80'/min pump min rate @ 7000' fill coil w/ methanol from little red , pump 1.5 bpm 16.0 8,473.0 10/12/2021 00:00 10/12/2021 03:00 3.00 PROD1, DRILL DLOG T Continue in hole with camera. Line up down the coil with neat MetOH. RIH to painted flag depth from previous BHA ~ 46' foot from TOWS. Pump MetOH to the bit while RIH slowly. Clean picture shortly after methanol lake water interface @ 00:04. Run in hole logging live video. 8,473.0 8,473.0 10/12/2021 03:00 10/12/2021 06:00 3.00 PROD1, DRILL TRIP T Pull heavy CT Wt to 42 k @ 8,868'. Unable to RBIH stacking neutral weight, unable to PUH pulling in steps to 40 k over, Clean pick up weight 35 k lbs. Line up down the back side and pump to 2 bpm, while working pipe. Turn coil and well over to PowerPro drilling mud. Work pipe from 80 k CT Wt to -9 k CT wt. - crew change 8,868.0 8,868.0 10/12/2021 06:00 10/12/2021 09:00 3.00 PROD1, DRILL TRIP T Work pipe from 80 k to -10 k lbs. Inspect injector, pump up tractions circuit. Displace well to power pro, release EVO camera. Release BOT. Work pipe from 80 k to -10 k lbs. load 7 bbls LVT into pill pit, pump around coil. 8,868.0 8,868.0 Rig: NABORS CDR3-AC RIG RELEASE DATE 10/17/2021 Page 11/15 1B-10 Report Printed: 11/4/2021 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) 10/12/2021 09:00 10/12/2021 12:00 3.00 PROD1, DRILL TRIP T Let LVT soak 30 minutes. work pipe from 80 k to -10 k lbs. Build 5 bbl beaded pill with active mud and 1 ppb alpine beads, pump down coil and up backside. Work coil from 80 k lbs to -10 k lbs. 8,868.0 8,868.0 10/12/2021 12:00 10/12/2021 15:00 3.00 PROD1, DRILL TRIP T Inspect injector and traction circuits. Work k coil from 100 k lbs max pull to - 10 k lbs. Circulate mud until MW in = MWO at 8.58 ppb. Trap pressure and observe wellhead to determine KW fluid. 8,868.0 8,868.0 10/12/2021 15:00 10/12/2021 16:18 1.30 PROD1, DRILL TRIP T WH fell from 504 to 321 at 16:30. Clean pit1 and pill pit 1 for KW fluid while observing WH. 8,868.0 8,868.0 10/12/2021 16:18 10/12/2021 19:18 3.00 PROD1, DRILL TRIP T WH down to 185 psi, 9.33 ppg static 8,868.0 8,868.0 10/12/2021 19:18 10/12/2021 21:18 2.00 PROD1, DRILL TRIP T PJSM w/ rig crew, work pipe a little, pump down coil keeping coil pressure under 3,000 psi, phone for approval to work pipe -22k continue working pipe w/no movement. 8,868.0 8,868.0 10/12/2021 21:18 10/12/2021 23:18 2.00 PROD1, DRILL TRIP T PJSM w/rig crew, line up to starve rig pump while working pipe between RIHW, PUW, Neutral. 8,868.0 8,868.0 10/12/2021 23:18 10/13/2021 00:00 0.70 PROD1, DRILL TRIP T Park at 25k, discuss plan forward with crew. 8,868.0 8,868.0 10/13/2021 00:00 10/13/2021 00:24 0.40 PROD1, DRILL TRIP T Park in netural weight 8,868.0 8,868.0 10/13/2021 00:24 10/13/2021 02:24 2.00 PROD1, DRILL TRIP T Continue working pipe up to 80k w/no movement. 8,868.0 8,868.0 10/13/2021 02:24 10/13/2021 02:54 0.50 PROD1, DRILL CTOP P WHP 319, 150 psi to 225 psi 80 psi to 215 psi 8,868.0 8,868.0 10/13/2021 02:54 10/13/2021 04:12 1.30 PROD1, DRILL CTOP P Discuss with town team Cut 10.7 ppg to 10.1 ppg 8,868.0 8,868.0 10/13/2021 04:12 10/13/2021 06:00 1.80 PROD1, DRILL DISP P Displace well to 10.1 ppg 8,868.0 8,868.0 10/13/2021 06:00 10/13/2021 07:00 1.00 PROD1, DRILL CIRC P Perform static loss test, 20 minute wait - 0.2 bpm losses Dynamic losses, when pumping over the top with charge pump 0.5 bpm 8,868.0 8,868.0 10/13/2021 07:00 10/13/2021 08:00 1.00 PROD1, DRILL CIRC P Discuss with town team, build 10.1 KW for coil with 776 lube. 8,868.0 8,868.0 10/13/2021 08:00 10/13/2021 08:18 0.30 PROD1, DRILL CIRC P Planns changed during morning meeting. Decision to load well with 9.8 NaCl. Call for brine and truck 8,868.0 8,868.0 10/13/2021 08:18 10/13/2021 14:48 6.50 PROD1, DRILL WAIT P Wait on 9.8 ppg brine 8,868.0 8,868.0 10/13/2021 14:48 10/13/2021 16:36 1.80 PROD1, DRILL DISP P Transfer NaCl brine to pits, verify weight. Bullhead 60 bbls 9.8 ppg NaCl down the annulus. 8,868.0 8,868.0 10/13/2021 16:36 10/13/2021 18:30 1.90 PROD1, DRILL DISP P Wait for slick 9.8 NaCl coil pill to be built. Pump 8,868.0 8,868.0 10/13/2021 18:30 10/13/2021 19:30 1.00 PROD1, DRILL DISP P Displace coil to 9.8 ppg 8,868.0 8,868.0 10/13/2021 19:30 10/13/2021 20:30 1.00 PROD1, DRILL CIRC P Shutdown, open lubricator at surface, shut valve on standing iron, open inner reel bleeder, montior well for flow 8,868.0 8,868.0 10/13/2021 20:30 10/13/2021 21:30 1.00 PROD1, DRILL CIRC P Rig floor on a vacuum, and inner reel slight 1/16" stream, continue to monitor well and coil for flow. 8,868.0 8,868.0 10/13/2021 21:30 10/13/2021 21:45 0.25 PROD1, DRILL CIRC P No flow, obtain static loss rate 4.0 bph 8,868.0 8,868.0 Rig: NABORS CDR3-AC RIG RELEASE DATE 10/17/2021 Page 12/15 1B-10 Report Printed: 11/4/2021 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) 10/13/2021 21:45 10/13/2021 22:15 0.50 PROD1, DRILL CTOP P PJSM, pull coil in tention 27k (20 %), function closed upper and lower pipe/slip rams, function to high side, manually lock in rams, 8,868.0 8,868.0 10/13/2021 22:15 10/13/2021 22:45 0.50 PROD1, DRILL CTOP P PJSM, strip up INJH, 86" from rig floor, mark pipe, install false bowl, slips, and dog collar, 8,868.0 8,868.0 10/13/2021 22:45 10/14/2021 00:00 1.25 PROD1, DRILL CTOP P PJSM, MU and install HOT TAP, drill hole into coiled tubing, confirm hole in tubing, Coil on Suck 8,868.0 8,868.0 10/14/2021 00:00 10/14/2021 07:00 7.00 PROD1, DRILL CTOP T Standby for Eline crew availablity, filling hole every hour 4 bbls 8,868.0 8,868.0 10/14/2021 07:00 10/14/2021 07:30 0.50 PROD1, DRILL CTOP P Stage scafold material to rig floor. 8,868.0 8,868.0 10/14/2021 07:30 10/14/2021 10:00 2.50 PROD1, DRILL CTOP P Remove hot tap equipment. Cut coil, excess wire pulled easily from upper end of coil. Clamp and cut wire. Skid injector 8,868.0 8,868.0 10/14/2021 10:00 10/14/2021 11:00 1.00 PROD1, DRILL CTOP P Rigged up Tugger and RON weight cell to wire line clamp. Pull~60' to 550 lbs - reset clamp Pull ~60' to 1,500' - reset clamp Pull ~60' to 2,800 lbs - reset clamp Pull ~10' to 2,680 lbs, weight broke back - anchor appeared to break free. 8,868.0 8,868.0 10/14/2021 11:00 10/14/2021 12:00 1.00 PROD1, DRILL CTOP P Pull excess slack to reach e-line ~ 400' total. Scaffold crew erected work platform on rig floor 8,868.0 8,868.0 10/14/2021 12:00 10/14/2021 13:30 1.50 PROD1, DRILL CTOP P RU e-line, Tie knot in wire. 8,868.0 8,868.0 10/14/2021 13:30 10/14/2021 18:00 4.50 PROD1, DRILL CTOP P Pull e-line from coiled tubing string. Atypical wire removal. Dragging something heavy - near surface ~ 2000' weight falling off to zero then dragging 2000 lbs. Stop at 500' use tugger to pull remaining wire Anchor retrieved e-line retrieved 8300' coil crew stripped 500' at surface 8,868.0 8,868.0 10/14/2021 18:00 10/14/2021 18:45 0.75 PROD1, DRILL CTOP P Dress coil stump install BOT External CTC, pull test traveling block hanging weight 14k, pull test to 42k, slack off, retighten, lock-tite set screws, 8,868.0 8,868.0 10/14/2021 18:45 10/14/2021 21:45 3.00 PROD1, DRILL CTOP P RU hose to pump in sub, complete building of 30 bbls lube pill, fill coil with 9.8 kwf (viscosified with 2% concentratrion of Lube 776), Sim-ops, eline mu cutter drift assembly on ground, and bring tools & equipment to RF. 8,868.0 8,868.0 10/14/2021 21:45 10/14/2021 22:15 0.50 PROD1, DRILL ELNE T Unable to RIH w/e-line past +/- 21', POOH, check tools, take picture of sticky tar on bottom of bullnose. 8,868.0 8,868.0 10/14/2021 22:15 10/14/2021 23:15 1.00 PROD1, DRILL ELNE T LD tools, take over to rig shop and dress eline head to 1.4" without burrs 8,868.0 8,868.0 10/14/2021 23:15 10/15/2021 00:00 0.75 PROD1, DRILL ELNE T Load E-line tools up to RF, MU eline rope socket 8,868.0 8,868.0 10/15/2021 00:00 10/15/2021 02:00 2.00 PROD1, DRILL ELNE T Set down w/ E-line drift 2,050' worked to get down to 2,184', over pulling 400lbs, We captured video of sample taken from tool string. E-line head rated for 900 lb. over pull. Decision was made to send E- liners to bed 8 hrs (10am), 8,868.0 8,868.0 Rig: NABORS CDR3-AC RIG RELEASE DATE 10/17/2021 Page 13/15 1B-10 Report Printed: 11/4/2021 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) 10/15/2021 02:00 10/15/2021 04:00 2.00 PROD1, DRILL ELNE T Send E-liners to bed for 8 hrs (10am), Rooms in Kuparuk KCC, call out additional 1502 parts for rigging up Little Red Services to RF for flushing coiled tubing, work sample in mud lab to determine best course of action with fluids. 8,868.0 8,868.0 10/15/2021 04:00 10/15/2021 07:00 3.00 PROD1, DRILL ELNE T Consult with town engineering, work plan forward. deliver sample of sludge from inside coil to kuparuk lab. 8,868.0 8,868.0 10/15/2021 07:00 10/15/2021 09:00 2.00 PROD1, DRILL WAIT T Wait on LRS 8,868.0 8,868.0 10/15/2021 09:00 10/15/2021 10:00 1.00 PROD1, DRILL ELNE T PJ discussion w LRS and crew. SPot up, rig up LRS build pump in 4 way above external coil connector. Verify CTC pressure limit of 5000 psi. PT both LRS and Nabors line to 3500 psi. 8,868.0 8,868.0 10/15/2021 10:00 10/15/2021 12:00 2.00 PROD1, DRILL ELNE T Wait on brine, Kuparuk lab relied to sample. They tried to dissolve / suspend with methanol, acid, and mutual solvent with no success. Sample simply balled up with none dissolving or going into suspension. Xylene and toluene both dissolved the sample. Stock field corrosion inhibiter partially dissolved the sample. 8,868.0 8,868.0 10/15/2021 12:00 10/15/2021 15:12 3.20 PROD1, DRILL DISP T Truck on location with 9.8 + KW. Verify density and RU to LRS. On line with LRS, Pump 100 bbls of diesel at 130 °F and 1.5 - 1.6 bpm and 2300 psi. Pump 100 bbls of 9.8 + nacl KW brine at 2350 psi and 1.7 to 1.9 bpm. SD, isolate, suck back LRS, release Hot oil. 8,868.0 8,868.0 10/15/2021 15:12 10/15/2021 16:00 0.80 PROD1, DRILL ELNE T Realign valves, verify no flow. Fill coil and backside (11 bbls - 1000' of 4.5" ) for 1 hr flow check. 8,868.0 8,868.0 10/15/2021 16:00 10/15/2021 16:30 0.50 PROD1, DRILL OWFF T Open bleed on coil and back side- observe for flow. 8,868.0 8,868.0 10/15/2021 16:30 10/15/2021 17:30 1.00 PROD1, DRILL OWFF T Attempt to load E line tool into coil. Unable to fall through coil, re position easy torques 8,868.0 8,868.0 10/15/2021 17:30 10/15/2021 20:30 3.00 PROD1, DRILL ELNE P Tools falling in hole freely, continue working to bottom. 8,868.0 8,868.0 10/15/2021 20:30 10/15/2021 20:42 0.20 PROD1, DRILL ELNE P At surface, LD E-line drift, tools very clean, PJSM for loading chemical into tools, discuss cutter hazards, working at heights, contingency plan in case of failure, test water hose on RF to be operating normally. discussed eye wash station and shower locations. Clear RF 8,868.0 8,868.0 10/15/2021 20:42 10/15/2021 22:36 1.90 PROD1, DRILL ELNE P Load Chemical, get a zero at RF, PU and load tools into coil, RIH to 200', 8,868.0 8,868.0 10/15/2021 22:36 10/15/2021 22:48 0.20 PROD1, DRILL ELNE P 8,795'. witness cutter fire, seen a little movement/weight bobble on E-line Unit, PUW 1,038 lbs 8,868.0 8,868.0 10/15/2021 22:48 10/16/2021 00:00 1.20 PROD1, DRILL ELNE P 8,795', Hung up with e-line, work to get free, continue OOH 8,868.0 8,868.0 10/16/2021 00:00 10/16/2021 00:15 0.25 PROD1, DRILL ELNE P Continue POOH with Eline 8,868.0 8,868.0 10/16/2021 00:15 10/16/2021 00:33 0.30 PROD1, DRILL ELNE P At surface, flow check well, PJSM for laying down cutterr 8,868.0 8,868.0 Rig: NABORS CDR3-AC RIG RELEASE DATE 10/17/2021 Page 14/15 1B-10 Report Printed: 11/4/2021 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) 10/16/2021 00:33 10/16/2021 01:03 0.50 PROD1, DRILL ELNE P LD/inspect/confirm cutter operation, cutter functioned properly. 8,868.0 8,868.0 10/16/2021 01:03 10/16/2021 02:15 1.20 PROD1, DRILL ELNE P Line up to circulate 9.8 ppg NaCI down the annulus (100 bbls) 8,868.0 8,868.0 10/16/2021 02:15 10/16/2021 03:15 1.00 PROD1, DRILL ELNE P Line up circulate 9.8 ppg NaCl down the coil (60 bbls) 8,868.0 8,868.0 10/16/2021 03:15 10/16/2021 04:15 1.00 PROD1, DRILL ELNE P Check well and coil for flow (no flow), pull to 27k 8,868.0 8,868.0 10/16/2021 04:15 10/16/2021 04:33 0.30 PROD1, DRILL ELNE P Back out Manual locks, and function open Upper and Lower pipe rams 8,868.0 8,868.0 10/16/2021 04:33 10/16/2021 04:51 0.30 PROD1, DRILL ELNE P Pull up 20' PUW 40k clean, indicating successful cut, RBIH, function closed Upper and Lower pipe/slip rams, manually lock in rams, set slips and dog collar, 8,868.0 8,868.0 10/16/2021 04:51 10/16/2021 06:51 2.00 PROD1, DRILL ELNE P RD/LD E-line - rig crews demo scaffold and stage bucket at foot of beaver slide. 8,868.0 8,868.0 10/16/2021 06:51 10/16/2021 09:21 2.50 PROD1, DRILL CTOP P PJSM, prep stump for cut. Scaffold crew on location, off load first bucket, remove rest of scaffold equip. Trim stump to 4' 8" height from rig floor. Ream tubing Skid cart with spoolable installed in storage reel side. Approx 24" clearance from bottom of quick union to top of coil. Stab CTC and dimple. Pull test to 30 k good. 8,868.0 8,868.0 10/16/2021 09:21 10/16/2021 11:33 2.20 PROD1, DRILL CTOP P Strip onto stump, make up quick union. PU wt 34 k lbs. Slowly pull spoolable connector to storage reel. Add 4 full wraps then ramp up POOH speed. Call out LRS mid trip 8,795.0 500.0 10/16/2021 11:33 10/16/2021 12:27 0.90 PROD1, DRILL CTOP P Near surface,fill hole the rig floor. Verify no flow. Follow slim BHA procedure to surface. Fill hole - flow check - well on a vac - LRS on location, spot up rig up in cellar tie onto test valves. 1.3 bbl fill up after 5 min - 15.6 bbl/hr 3.5 bbl fill up after 20 min - 10.5 bbl/hr Pop off well with whats left of BHA #10 500.0 0.0 10/16/2021 12:27 10/16/2021 13:57 1.50 DEMOB, WHDBOP CTOP P Bullhead 35 bbls diesel FP via the test valves on lower BOP rams. 750 psi @ 1.5 bpm 34 bbls pumped, shut down. ***Final WH -0, IA 73, and OA 93 psi 0.0 0.0 10/16/2021 13:57 10/16/2021 15:57 2.00 DEMOB, WHDBOP CTOP P N2 on location, RU, cool down, PT 4,000 psi, Come on line for 15 minutes at 1,500 SCF/min. Trap pressure in coil, blow down bleed off. Release Nitrogen. 0.0 0.0 10/16/2021 15:57 10/16/2021 17:27 1.50 DEMOB, WHDBOP CTOP P flush and blow down 0.0 0.0 10/16/2021 17:27 10/16/2021 18:03 0.60 DEMOB, WHDBOP SFTY P Pre-tour, crew change, PJSM for RD 0.0 0.0 Rig: NABORS CDR3-AC RIG RELEASE DATE 10/17/2021 Page 15/15 1B-10 Report Printed: 11/4/2021 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) 10/16/2021 18:03 10/17/2021 00:00 5.95 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 @ Midnight ***. Continue to work RD checklist, call for fuel for halfway house, load out KDTH trucks *** Rig Released @ Midnight ***. 0.0 0.0 Rig: NABORS CDR3-AC RIG RELEASE DATE 10/17/2021 1. Operations Abandon Plug Perforations Fracture Stimulate Pull Tubing Operations shutdown Performed: Suspend Perforate Other Stimulate Alter Casing Change Approved Program Plug for Redrill Perforate New Pool Repair Well Re-enter Susp Well Other: Whipstock CTD Prep Development Exploratory Stratigraphic Service 6. API Number: 7. Property Designation (Lease Number): 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pool(s): 11. Present Well Condition Summary: Total Depth measured 9,403 feet None feet true vertical 6,878 feet None feet Effective Depth measured 8,845 feet 8423, 8922 feet true vertical 6,276 feet 6002, 6443 feet Perforation depth:N/A feet N/A feet Tubing (size, grade, measured and true vertical depth)3.5 ''L-80 8,945' MD 6,464' TVD Packers and SSSV (type, measured and true vertical depth)PACKER - BAKER SLZXP LINER TOP PACKER 8,423' MD 6,002' TVD PACKER - BAKER D PERMANENT PACKER 8,922' MD 6,443' TVD 1,799' MD 1,696' TVD 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13. Prior to well operation: Subsequent to operation: 15. Well Class after work: Daily Report of Well Operations Exploratory Development Service Stratigraphic Copies of Logs and Surveys Run 16. Well Status after work: Oil Gas WDSPL GSTOR GINJ SUSP SPLUG Sundry Number or N/A if C.O. Exempt: Dusty Ward Contact Name:Dusty Ward Authorized Title:Senior Wells Engineer Contact Email:Dusty.Ward@cop.com Contact Phone:907 265-6531 3. Address:P. O. Box 100360, Anchorage, Alaska 99510 50-029-20656-00 8. Well Name and Number:KRU 1B-10ADL 25648 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 2. Operator Name:ConocoPhillips Alaska, Inc.4. Well Class Before Work: 5. Permit to Drill Number: 181-135 Packer measured true vertical Casing Length Size MD TVD N/A Kuparuk River Field / Kuparuk River Oil Pool Plugs measured Junk measured Burst Collapse CONDUCTOR 49 feet 20 '' 80' MD 80 PRODUCTION 9,330 feet 9 5/8 '' 9,358' MD 6837 SURFACE 2,517 feet 13 3/8 ''2,547' MD 2272 C4 sand perfs:8818'-8870' RKB" 69 BBLS OF 15.8 PPG CLASS G PUMPED. 190 PSIG FINAL PRESSURE - COULD NEVER GET GOOD HESITATION SQUEEZE Representative Daily Average Production or Injection Data Measured depth: True Vertical depth: SSSV -CAMCO TRMAXX-53 øø ø ø ø 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure 150 ø 5000 øø Authorized Name: Authorized Signature with date: Senior Engineer: Senior Res. Engineer: Printed and Electronic Fracture Stimulation Data WINJ WAG 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. 320-121 GINJ SUSP SPLUG Gas Service Form 10-404 Revised 3/2020 Submit Within 30 days of Operations By Samantha Carlisle at 11:13 am, Apr 22, 2020 DSR-4/22/2020VTL 4/28/20 SFD 4/23/2020 -00 RBDMS HEW 4/22/2020 DTTM START JOBTYP SUMMARYOPS 3/26/20 OPEN - CLOSE A/C SAND BRUSH n' FLUSH TBG TO CEMENT RETAINER, TAG W/ CCL @ 8904' RKB, SET 2.81 X LOCK, NO PKG, W/ 1.75" ID FLOW THROUGH SUB (OAL 18") W/ CCL @ 8894' RKB, CONFIRM LOCK SET W/ 2.81 CHECK SET & CCL @ 8894' RKB. COMPLETE. 3/27/20 OPEN - CLOSSET 3.5" SLIP STOP CATCHER @ 5308' RKB, PULLED OV @ 5127' RKB, PULLED GLV & SET DV @ 2859' RKB, LRS LOADED IA W/ 202 BBLS OF INHIBITED SEAWATER FOLLOWED BY 107 BBLS OF DIESEL, SET DV @ 5127' RKB, OBTAIN PASSING MIT-IA TO 2500 PSI. IN PROGRESS 3/28/20 OPEN - CLOSPULLED 3.5" SLIP STOP @ 5308' RKB, TAGGED 2.81" X-LOCK & FLOW THRU SUB W/ 2.74" IMPRESSION BLOCK (CLEAR PICTURE OF FISHNECK). JOB COMPLETE 3/30/20 OPEN - CLOSRAN IN HOLE WITH 2.75" X 1.46' FH-RETAINER TAGGED X-LOCK PUH GOT WT BACK CORRECTED TO 8894' PUH TO 8891' PUMPED 1/2" BALL SET RETAINER PRESSURED UP WELL 500 OVER BLEED WELL TO ZERO AND PUMPED DOWN COIL AND HAD NO PRESSURE BUILD UP PUMPED TWO COIL VOLUMES OF FRESH WATER FOLLOWED WITH 69 BBLS OF 15.8# PPG CEMENT. HESITATED SEVEN TIMES FOR 20 MINS EACH NEVER GOT A BUMP PUMP CEMENT AWAY POOH FREEZE PROTECT WELL WITH DIESEL WHEN WE WOULD HESITATE THE CIRC PRESSURE WOULD JUST DROP TO 190 PSI EVERY TIME 4/3/20 DRILLING SU DRIFT TBG W/15' 2 5/8" DUMMY WHIPSTOCK, TAG TOC @ 8897' SLM, SET 2.813" FLOW THRU X-LOCK @ 8875' RKB, RUN CHECK SET, COMPLETE 1B-10 WHIPSTOCK/CTD PREP Last Tag Annotation Depth (ftKB) End Date Wellbore Last Mod By Last Tag: RKB 8,975.0 6/7/2018 1B-10 zembaej Last Rev Reason Annotation End Date Wellbore Last Mod By Rev Reason: Update Schematic with cement squeeze 4/10/2020 1B-10 rogerba Casing Strings Casing Description CONDUCTOR OD (in) 20 ID (in) 18.94 Top (ftKB) 31.3 Set Depth (ftKB) 80.0 Set Depth (TVD) (… 80.0 Wt/Len (l… 91.50 Grade H-40 Top Thread WELDED Casing Description SURFACE OD (in) 13 3/8 ID (in) 12.35 Top (ftKB) 30.3 Set Depth (ftKB) 2,547.0 Set Depth (TVD) (… 2,271.9 Wt/Len (l… 72.00 Grade N-80 Top Thread BTC Casing Description PRODUCTION OD (in) 9 5/8 ID (in) 8.86 Top (ftKB) 28.3 Set Depth (ftKB) 9,358.4 Set Depth (TVD) (… 6,837.2 Wt/Len (l… 47.00 Grade L-80 Top Thread BUTT Tubing Strings Tubing Description TUBING 4.5 x3.5 x 2.875 WO 2019 String Max … 3 1/2 ID (in) 2.99 Top (ftKB) 23.6 Set Depth (ft… 8,477.4 Set Depth (TVD) (ft… 6,049.5 Wt (lb/ft) 9.30 Grade L80 Top Connection EUE Completion Details Top (ftKB) Top (TVD) (ftKB)Top Incl (°)Item Des Com Nominal ID (in) 23.6 23.6 0.08 HANGER FMC 13 5/8 x 4 1/2" New Standard Big Bore Tubing Hanger W/ 5" RH Acme top 3.910 1,799.4 1,695.5 42.94 SSSV Camco 4 1/2" TRMAXX-5E 3.812" SSSV 1797' 3.812 1,809.4 1,702.7 43.04 XO REDUCING XO Pup 4 1/2" IBTM Box x 3 1/2" EUE-Mod Pin 3.833 8,451.7 6,027.1 29.40 SBE Baker 3 1/2" EUE seal Assy 25.67' OAL buried below liner top New up 2.990 Tubing Description TUBING - 4.5 X 3.5 X 2.875 WO 2019 String Max … 3 1/2 ID (in) 2.99 Top (ftKB) 8,423.2 Set Depth (ft… 8,902.5 Set Depth (TVD) (ft… 6,425.4 Wt (lb/ft) 9.30 Grade L80 Top Connection EUE Completion Details Top (ftKB) Top (TVD) (ftKB)Top Incl (°)Item Des Com Nominal ID (in) 8,423.2 6,002.3 29.55 PACKER Baker 9 5/8" x 3-1/2" SLZXP Liner top packer Left in hole down 6.120 8,451.1 6,026.6 29.40 PBR Seal Bore Extension (3' space out off tag) 4.000 8,835.4 6,365.8 27.32 TANDEM WEDGE Northern Solutions 3 1/2" x 9 5/8" Tandem Wedge Assembly 2.992 8,850.0 6,378.7 27.27 NIPPLE HES 3 1/2" x 2.813" X nipple Profile (SN:) 2.813 8,860.4 6,388.0 27.23 TANDEM WEDGE Northern Solutions 3 1/2" x 9 5/8" Tandem Wedge Assembly 2.992 8,875.0 6,400.9 27.18 NIPPLE HES 3 1/2" x 2.813" X nipple Profile (SN:) 2.813 8,894.5 6,418.3 27.10 NIPPLE HES 3 1/2" x 2.813" X nipple Profile W/ RHC Plug Installed (SN: 2727A-4-8) 2.813 8,895.4 6,419.1 27.10 MULE SHOES Baker 3 1/2" x 9 5/8" Poorboy Overshot (6.77' Swallow) 3.640 Tubing Description TUBING WO 4.5x3.5x2.875" String Max … 8.66 ID (in) 3.25 Top (ftKB) 8,901.1 Set Depth (ft… 8,945.3 Set Depth (TVD) (ft… 6,463.5 Wt (lb/ft) Grade Top Connection Completion Details Top (ftKB) Top (TVD) (ftKB)Top Incl (°)Item Des Com Nominal ID (in) 8,909.6 6,431.8 27.05 SLIDING SLEEVE BAKER CMU SLIDING SLEEVE; SEIZED IN CLOSED POSITION 12/8/2007 2.750 8,919.6 6,440.6 27.01 XO REDUCING CROSSOVER 3.5 x 2.875 2.875 8,921.4 6,442.3 27.00 SEAL ASSY BAKER GBH 80-32 LOCATOR SEAL ASSEMBLY 2.440 8,922.3 6,443.1 27.00 PACKER BAKER D PERMANENT PACKER 3.250 8,937.1 6,456.3 26.95 NIPPLE OTIS XN NO GO NIPPLE 2.250 8,944.5 6,462.9 26.92 SOS BAKER SHEAR OUT SUB 2.441 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Des Com Run Date ID (in) 8,875.0 6,401.0 27.17 X-LOCK W/ FLOW THRU SUB 2.81 X LOCK (W/ PACKING), & FLOW THROUGH SUB (OAL 18.5") 4/3/2020 1.750 8,891.0 6,415.2 27.12 CEMENT RETAINER (ME) WEATHERFORD FH1 RETAINER, 2.75" OD X ( OAL=1.46 ) 3/30/2020 0.000 8,894.0 6,417.9 27.11 X-LOCK 2.81 X LOCK, NO PACKING, W/ FLOW THROUGH SUB (OAL 18") 3/26/2020 1.750 8,901.0 6,424.1 27.08 CHEM CUT 2 3/8" Chemical cut. 6/26/2019 0.000 8,904.0 6,426.8 27.07 Cement Retainer Set Weather Cement Retainer (OAL 1.46') 10/5/2019 0.000 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft)Type Com 8,818.0 8,870.0 6,350.3 6,396.5 C-4, C-3, 1B-10 4/17/1994 4.0 RPERF 3 3/8" Hyperjet; 60 deg phasing 8,959.0 8,979.0 6,475.8 6,493.6 C-1, UNIT B, 1B- 10 4/17/1994 6.0 APERF 3 3/8" Hyperjet; 60 deg phasing 9,128.0 9,138.0 6,627.5 6,636.6 A-5, 1B-10 2/4/1982 4.0 CMT SQZ 9,146.0 9,158.0 6,643.9 6,654.7 A-4, 1B-10 2/4/1982 4.0 CMT SQZ 9,158.0 9,178.0 6,654.7 6,672.9 A-4, 1B-10 2/4/1982 4.0 CMT SQZ Frac Summary Start Date 1/21/2008 Proppant Designed (lb) Proppant In Formation (lb) Stg # 1 Start Date 1/21/2008 Top Depth (ftKB) 8,818.0 Btm (ftKB) 8,870.0 Link to Fluid System Vol Clean (bbl) Vol Slurry (bbl) 1B-10, 4/20/2020 10:49:32 AM M D (ft K B) -322.8 -310.0 -24.9 -14.4 -6.6 23.6 28.2 31.2 32.8 70.2 80.1 1,799.5 1,809.4 2,000.0 2,476.4 2,546.9 2,859.3 2,878.3 4,644.4 5,117.1 5,122.4 5,136.2 6,310.0 6,733.3 6,752.3 7,645.3 7,664.7 8,400.9 8,420.3 8,451.1 8,477.4 8,550.9 8,782.5 8,817.6 8,821.2 8,827.1 8,835.3 8,850.1 8,855.0 8,870.1 8,875.0 8,877.0 8,892.1 8,894.0 8,895.3 8,901.2 8,902.6 8,905.8 8,913.4 8,921.3 8,924.9 8,937.0 8,943.9 8,945.2 8,959.0 8,978.3 8,979.7 9,019.4 9,060.4 9,100.1 9,127.0 9,138.1 9,144.0 9,150.6 9,161.7 9,178.1 9,204.1 9,233.9 9,273.0 9,358.6 9,799.9 Vertical schematic (actual) A OW… OIL/W… C OW… WEST … CAMP… BASE …KALU…UPPE…K-1 M…LOWE… KUPA…UNIT …UNIT …C-4 IN…C-4B … C-4A … C-3 IN… C-2 IN… C-1 IN…C-1B … C-1A … UNIT …B-8 IN…B-7 IN…B-6 IN…B-5 IN… B-4 IN… B-3 IN… B-2 IN…B-1 IN… UNIT …A-6 IN…A-5 IN…A5-2 S… A5-1 S…A-4 IN…A4-3 S… A4-2 S… A4-1 S…A-3 IN…A3-3 S…A3-2 S…A-2 IN…A-1 IN…MILUV… FLOAT SHOE; 9,357.3-9,358.4; 1.16; 3-9; 9.625; 8.861 CASING; 9,273.0-9,357.3; 84.25; 3-8; 9.625; 8.861 FLOAT COLLAR; 9,271.4-9,273.0; 1.62; 3-7; 9.625; 8.861 CMT SQZ; 9,158.0-9,178.0; 2/4/1982 CMT SQZ; 9,146.0-9,158.0; 2/4/1982 CMT SQZ; 9,128.0-9,138.0; 2/4/1982 CASING; 8,821.3-9,271.4; 450.07; 3-6; 9.625; 8.861 APERF; 8,959.0-8,979.0; 4/17/1994 SOS; 8,944.5-8,945.3; 0.78; 2-10; 2.875; 2.441 TUBING PUP; 8,938.2-8,944.5; 6.26; 2-9; 2.875; 2.441 NIPPLE; 8,937.1-8,938.2; 1.10; 2-8; 3.668; 2.250 TUBING PUP; 8,931.0-8,937.1; 6.11; 2-7; 2.875; 2.441 PACKER; 8,922.3-8,931.0; 8.70; 2-6; 8.660; 3.250 SEAL ASSY; 8,921.4-8,922.3; 0.93; 2-5; 3.400; 2.440 XO REDUCING; 8,919.6-8,921.4; 1.83; 2-4; 3.500; 2.875 TUBING PUP; 8,913.4-8,919.6; 6.12; 2-3; 3.500; 2.992 SLIDING SLEEVE; 8,909.6-8,913.4; 3.81; 2-2; 5.750; 2.750 TUBING PUP; 8,901.1-8,909.6; 8.50; 2-1; 3.500; 2.992 MULE SHOES; 8,895.4-8,902.5; 7.13; 3-14; 8.500; 3.640 NIPPLE; 8,894.5-8,895.4; 0.91; 3-13; 4.500; 2.813 Tubing - Pup; 8,875.9-8,894.5; 18.60; 3-12; 3.500; 2.992 NIPPLE; 8,875.0-8,875.9; 0.88; 3-11; 4.500; 2.813 Tubing - Pup; 8,873.1-8,875.0; 1.92; 3-10; 3.500; 2.992 TANDEM WEDGE; 8,860.4-8,873.1; 12.65; 3-9; 8.250; 2.992 Tubing - Pup; 8,850.9-8,860.4; 9.55; 3-8; 3.500; 2.992 NIPPLE; 8,850.0-8,850.9; 0.88; 3-7; 4.480; 2.813 Tubing - Pup; 8,848.1-8,850.0; 1.92; 3-6; 3.500; 2.992 RPERF; 8,818.0-8,870.0; 4/17/1994 TANDEM WEDGE; 8,835.4-8,848.1; 12.65; 3-5; 8.250; 2.992 Tubing - Pup; 8,825.9-8,835.4; 9.55; 3-4; 3.500; 2.992 MARKER JT; 8,782.5-8,821.3; 38.81; 3-5; 9.625; 8.861 Tubing; 8,481.0-8,825.9; 344.84; 3-3; 3.500; 2.992 PBR; 8,451.1-8,481.0; 29.91; 3-2; 6.500; 4.000SBE; 8,451.7-8,477.4; 25.67; 4-31; 3.980; 2.990 PACKER; 8,423.2-8,451.1; 27.93; 3-1; 8.440; 6.120 Tubing; 8,420.2-8,451.7; 31.58; 4-30; 3.500; 2.992 Tubing - Pup; 8,409.9-8,420.2; 10.21; 4-29; 3.500; 2.992 GAS LIFT; 8,401.1-8,409.9; 8.87; 4-28; 5.968; 2.915 Tubing - Pup; 8,390.9-8,401.1; 10.22; 4-27; 3.500; 2.992 Tubing; 7,664.6-8,390.9; 726.30; 4-26; 3.500; 2.992 Tubing - Pup; 7,654.3-7,664.6; 10.21; 4-25; 3.500; 2.992 GAS LIFT; 7,645.5-7,654.3; 8.87; 4-24; 5.968; 2.915 Tubing - Pup; 7,635.3-7,645.5; 10.18; 4-23; 3.500; 2.992 Tubing; 6,752.2-7,635.3; 883.10; 4-22; 3.500; 2.992 Tubing - Pup; 6,742.0-6,752.2; 10.15; 4-21; 3.500; 2.992 GAS LIFT; 6,733.2-6,742.0; 8.86; 4-20; 5.968; 2.915 Tubing - Pup; 6,723.0-6,733.2; 10.16; 4-19; 3.500; 2.992 CASING; 4,644.3-8,782.5; 4,138.27; 3-4; 9.625; 8.861 Tubing; 5,146.3-6,723.0; 1,576.69; 4-18; 3.500; 2.992 Tubing - Pup; 5,136.2-5,146.3; 10.16; 4-17; 3.500; 2.992 GAS LIFT; 5,127.3-5,136.2; 8.87; 4-16; 5.968; 2.915 Tubing - Pup; 5,117.1-5,127.3; 10.17; 4-15; 3.500; 2.992 MARKER JT; 4,603.6-4,644.3; 40.71; 3-3; 9.625; 8.861 Tubing; 2,878.2-5,117.1; 2,238.90; 4-14; 3.500; 2.992 Tubing - Pup; 2,868.0-2,878.2; 10.21; 4-13; 3.500; 2.992 GAS LIFT; 2,859.1-2,868.0; 8.91; 4-12; 5.968; 2.915 Tubing - Pup; 2,849.0-2,859.1; 10.15; 4-11; 3.500; 2.992 FLOAT SHOE; 2,545.1-2,547.0; 1.87; 2-5; 13.375; 12.347 CASING Baker Locked; 2,476.3-2,545.1; 68.84; 2-4; 13.375; 12.347 FLOAT COLLAR; 2,474.7-2,476.3; 1.58; 2-3; 13.375; 12.347 Tubing; 1,810.9-2,849.0; 1,038.03; 4-10; 3.500; 2.992 CASING; 32.7-4,603.6; 4,570.85; 3-2; 9.625; 8.861 XO REDUCING; 1,809.4-1,810.9; 1.55; 4-9; 4.500; 3.833 Tubing - Pup; 1,804.7-1,809.4; 4.71; 4-8; 4.500; 3.833 SSSV ; 1,799.4-1,804.7; 5.23; 4-7; 6.923; 3.812 Tubing - Pup; 1,794.9-1,799.4; 4.49; 4-6; 4.500; 3.833 CASING; 33.4-2,474.7; 2,441.30; 2-2; 13.375; 12.347 Tubing; 78.1-1,794.9; 1,716.82; 4-5; 4.500; 3.833 Tubing - Pup; 70.3-78.1; 7.81; 4-4; 4.500; 3.833 CONDUCTOR; 31.3-80.0; 48.70; 1-1; 20.000; 18.938Tubing; 31.7-70.3; 38.60; 4-3; 4.500; 3.833 HANGER; 30.3-33.4; 3.10; 2-1; 16.000; 12.347 HANGER; 28.3-32.7; 4.40; 3-1; 12.000; 8.861 Tubing - Pup; 24.4-31.7; 7.35; 4-2; 4.500; 3.833 HANGER; 23.6-24.4; 0.75; 4-1; 13.625; 3.910 KUP PROD KB-Grd (ft) 31.99 Rig Release Date 12/13/1981 1B-10 ... TD Act Btm (ftKB) 9,403.0 Well Attributes Field Name KUPARUK RIVER UNIT Wellbore API/UWI 500292065600 Wellbore Status PROD Max Angle & MD Incl (°) 59.73 MD (ftKB) 6,300.00 WELLNAME WELLBORE1B-10 H2S (ppm) 40 Date 8/12/2016 Comment Annotation Last WO: End Date 6/28/2019 Cement Squeezes Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Des Start Date Com 8,870.0 9,100.0 6,396.5 6,602.2 Production Casing Cement 10/5/2019 Cemented thru retainer @ 8904' RKB thru perfs and behind Production casing up to bottom of Surface casing @ 8870' RKB 8,925.0 8,975.0 6,445.5 6,490.1 Production Casing Cement 10/5/2019 8,904.0 8,944.0 6,426.8 6,462.4 Cement Squeeze 10/5/2019 8,894.0 8,922.3 6,417.9 6,443.1 Cement Squeeze 3/30/2020 SECOND ATTEMPT TO SHUT OFF C4 SANDS. CEMENT SQUEEZE 69 BBLS, 15.8 PPG CLASS G, THRU NONE SEALING OVERSHOT 8,901.0 8,922.3 6,424.1 6,443.1 Cement Squeeze 3/30/2020 Mandrel Inserts St ati on No /S Top (ftKB) Top (TVD) (ftKB) Make Model OD (in) Serv Valve Type Latch Type Port Size (in) TRO Run (psi) Run Date Com 1 2,859.1 2,509.8 Camco MMG 1 1/2 GAS LIFT DMY RK 0.000 0.0 3/27/2020 2 5,127.3 3,810.4 Camco MMG 1 1/2 GAS LIFT DMY RK 0.000 0.0 3/27/2020 3 6,733.2 4,654.6 Camco MMG 1 1/2 GAS LIFT DMY RK 7/18/2019 4 7,645.5 5,342.0 Camco MMG 1 1/2 GAS LIFT DMY RK 7/18/2019 5 8,401.1 5,983.1 Camco MMG 1 1/2 GAS LIFT DMY RK 7/18/2019 Notes: General & Safety End Date Annotation 1/29/1998 NOTE: WAIVERED WELL: IA x OA ANNULAR COMMUNICATION 1B-10, 4/20/2020 10:49:34 AM M D (ft K B) -322.8 -310.0 -24.9 -14.4 -6.6 23.6 28.2 31.2 32.8 70.2 80.1 1,799.5 1,809.4 2,000.0 2,476.4 2,546.9 2,859.3 2,878.3 4,644.4 5,117.1 5,122.4 5,136.2 6,310.0 6,733.3 6,752.3 7,645.3 7,664.7 8,400.9 8,420.3 8,451.1 8,477.4 8,550.9 8,782.5 8,817.6 8,821.2 8,827.1 8,835.3 8,850.1 8,855.0 8,870.1 8,875.0 8,877.0 8,892.1 8,894.0 8,895.3 8,901.2 8,902.6 8,905.8 8,913.4 8,921.3 8,924.9 8,937.0 8,943.9 8,945.2 8,959.0 8,978.3 8,979.7 9,019.4 9,060.4 9,100.1 9,127.0 9,138.1 9,144.0 9,150.6 9,161.7 9,178.1 9,204.1 9,233.9 9,273.0 9,358.6 9,799.9 Vertical schematic (actual) A OW… OIL/W… C OW… WEST … CAMP… BASE …KALU…UPPE…K-1 M…LOWE… KUPA…UNIT …UNIT …C-4 IN…C-4B … C-4A … C-3 IN… C-2 IN… C-1 IN…C-1B … C-1A … UNIT …B-8 IN…B-7 IN…B-6 IN…B-5 IN… B-4 IN… B-3 IN… B-2 IN…B-1 IN… UNIT …A-6 IN…A-5 IN…A5-2 S… A5-1 S…A-4 IN…A4-3 S… A4-2 S… A4-1 S…A-3 IN…A3-3 S…A3-2 S…A-2 IN…A-1 IN…MILUV… FLOAT SHOE; 9,357.3-9,358.4; 1.16; 3-9; 9.625; 8.861 CASING; 9,273.0-9,357.3; 84.25; 3-8; 9.625; 8.861 FLOAT COLLAR; 9,271.4-9,273.0; 1.62; 3-7; 9.625; 8.861 CMT SQZ; 9,158.0-9,178.0; 2/4/1982 CMT SQZ; 9,146.0-9,158.0; 2/4/1982 CMT SQZ; 9,128.0-9,138.0; 2/4/1982 CASING; 8,821.3-9,271.4; 450.07; 3-6; 9.625; 8.861 APERF; 8,959.0-8,979.0; 4/17/1994 SOS; 8,944.5-8,945.3; 0.78; 2-10; 2.875; 2.441 TUBING PUP; 8,938.2-8,944.5; 6.26; 2-9; 2.875; 2.441 NIPPLE; 8,937.1-8,938.2; 1.10; 2-8; 3.668; 2.250 TUBING PUP; 8,931.0-8,937.1; 6.11; 2-7; 2.875; 2.441 PACKER; 8,922.3-8,931.0; 8.70; 2-6; 8.660; 3.250 SEAL ASSY; 8,921.4-8,922.3; 0.93; 2-5; 3.400; 2.440 XO REDUCING; 8,919.6-8,921.4; 1.83; 2-4; 3.500; 2.875 TUBING PUP; 8,913.4-8,919.6; 6.12; 2-3; 3.500; 2.992 SLIDING SLEEVE; 8,909.6-8,913.4; 3.81; 2-2; 5.750; 2.750 TUBING PUP; 8,901.1-8,909.6; 8.50; 2-1; 3.500; 2.992 MULE SHOES; 8,895.4-8,902.5; 7.13; 3-14; 8.500; 3.640 NIPPLE; 8,894.5-8,895.4; 0.91; 3-13; 4.500; 2.813 Tubing - Pup; 8,875.9-8,894.5; 18.60; 3-12; 3.500; 2.992 NIPPLE; 8,875.0-8,875.9; 0.88; 3-11; 4.500; 2.813 Tubing - Pup; 8,873.1-8,875.0; 1.92; 3-10; 3.500; 2.992 TANDEM WEDGE; 8,860.4-8,873.1; 12.65; 3-9; 8.250; 2.992 Tubing - Pup; 8,850.9-8,860.4; 9.55; 3-8; 3.500; 2.992 NIPPLE; 8,850.0-8,850.9; 0.88; 3-7; 4.480; 2.813 Tubing - Pup; 8,848.1-8,850.0; 1.92; 3-6; 3.500; 2.992 RPERF; 8,818.0-8,870.0; 4/17/1994 TANDEM WEDGE; 8,835.4-8,848.1; 12.65; 3-5; 8.250; 2.992 Tubing - Pup; 8,825.9-8,835.4; 9.55; 3-4; 3.500; 2.992 MARKER JT; 8,782.5-8,821.3; 38.81; 3-5; 9.625; 8.861 Tubing; 8,481.0-8,825.9; 344.84; 3-3; 3.500; 2.992 PBR; 8,451.1-8,481.0; 29.91; 3-2; 6.500; 4.000SBE; 8,451.7-8,477.4; 25.67; 4-31; 3.980; 2.990 PACKER; 8,423.2-8,451.1; 27.93; 3-1; 8.440; 6.120 Tubing; 8,420.2-8,451.7; 31.58; 4-30; 3.500; 2.992 Tubing - Pup; 8,409.9-8,420.2; 10.21; 4-29; 3.500; 2.992 GAS LIFT; 8,401.1-8,409.9; 8.87; 4-28; 5.968; 2.915 Tubing - Pup; 8,390.9-8,401.1; 10.22; 4-27; 3.500; 2.992 Tubing; 7,664.6-8,390.9; 726.30; 4-26; 3.500; 2.992 Tubing - Pup; 7,654.3-7,664.6; 10.21; 4-25; 3.500; 2.992 GAS LIFT; 7,645.5-7,654.3; 8.87; 4-24; 5.968; 2.915 Tubing - Pup; 7,635.3-7,645.5; 10.18; 4-23; 3.500; 2.992 Tubing; 6,752.2-7,635.3; 883.10; 4-22; 3.500; 2.992 Tubing - Pup; 6,742.0-6,752.2; 10.15; 4-21; 3.500; 2.992 GAS LIFT; 6,733.2-6,742.0; 8.86; 4-20; 5.968; 2.915 Tubing - Pup; 6,723.0-6,733.2; 10.16; 4-19; 3.500; 2.992 CASING; 4,644.3-8,782.5; 4,138.27; 3-4; 9.625; 8.861 Tubing; 5,146.3-6,723.0; 1,576.69; 4-18; 3.500; 2.992 Tubing - Pup; 5,136.2-5,146.3; 10.16; 4-17; 3.500; 2.992 GAS LIFT; 5,127.3-5,136.2; 8.87; 4-16; 5.968; 2.915 Tubing - Pup; 5,117.1-5,127.3; 10.17; 4-15; 3.500; 2.992 MARKER JT; 4,603.6-4,644.3; 40.71; 3-3; 9.625; 8.861 Tubing; 2,878.2-5,117.1; 2,238.90; 4-14; 3.500; 2.992 Tubing - Pup; 2,868.0-2,878.2; 10.21; 4-13; 3.500; 2.992 GAS LIFT; 2,859.1-2,868.0; 8.91; 4-12; 5.968; 2.915 Tubing - Pup; 2,849.0-2,859.1; 10.15; 4-11; 3.500; 2.992 FLOAT SHOE; 2,545.1-2,547.0; 1.87; 2-5; 13.375; 12.347 CASING Baker Locked; 2,476.3-2,545.1; 68.84; 2-4; 13.375; 12.347 FLOAT COLLAR; 2,474.7-2,476.3; 1.58; 2-3; 13.375; 12.347 Tubing; 1,810.9-2,849.0; 1,038.03; 4-10; 3.500; 2.992 CASING; 32.7-4,603.6; 4,570.85; 3-2; 9.625; 8.861 XO REDUCING; 1,809.4-1,810.9; 1.55; 4-9; 4.500; 3.833 Tubing - Pup; 1,804.7-1,809.4; 4.71; 4-8; 4.500; 3.833 SSSV ; 1,799.4-1,804.7; 5.23; 4-7; 6.923; 3.812 Tubing - Pup; 1,794.9-1,799.4; 4.49; 4-6; 4.500; 3.833 CASING; 33.4-2,474.7; 2,441.30; 2-2; 13.375; 12.347 Tubing; 78.1-1,794.9; 1,716.82; 4-5; 4.500; 3.833 Tubing - Pup; 70.3-78.1; 7.81; 4-4; 4.500; 3.833 CONDUCTOR; 31.3-80.0; 48.70; 1-1; 20.000; 18.938Tubing; 31.7-70.3; 38.60; 4-3; 4.500; 3.833 HANGER; 30.3-33.4; 3.10; 2-1; 16.000; 12.347 HANGER; 28.3-32.7; 4.40; 3-1; 12.000; 8.861 Tubing - Pup; 24.4-31.7; 7.35; 4-2; 4.500; 3.833 HANGER; 23.6-24.4; 0.75; 4-1; 13.625; 3.910 KUP PROD 1B-10 ... WELLNAME WELLBORE1B-10 Frac Summary Start Date 1/21/2008 Proppant Designed (lb) Proppant In Formation (lb) Stg # 1 Start Date 1/21/2008 Top Depth (ftKB) 8,818.0 Btm (ftKB) 8,870.0 Link to Fluid System Vol Clean (bbl) Vol Slurry (bbl) 1B-10L1, 4/20/2020 10:49:35 AM M D (ft K B) -322.8 -310.0 -24.9 -14.4 -6.6 23.6 28.2 31.2 32.8 70.2 80.1 1,799.5 1,809.4 2,000.0 2,476.4 2,546.9 2,859.3 2,878.3 4,644.4 5,117.1 5,122.4 5,136.2 6,310.0 6,733.3 6,752.3 7,645.3 7,664.7 8,400.9 8,420.3 8,451.1 8,477.4 8,550.9 8,782.5 8,817.6 8,821.2 8,827.1 8,835.3 8,850.1 8,855.0 8,870.1 8,875.0 8,877.0 8,892.1 8,894.0 8,895.3 8,901.2 8,902.6 8,905.8 8,913.4 8,921.3 8,924.9 8,937.0 8,943.9 8,945.2 8,959.0 8,978.3 8,979.7 9,019.4 9,060.4 9,100.1 9,127.0 9,138.1 9,144.0 9,150.6 9,161.7 9,178.1 9,204.1 9,233.9 9,273.0 9,358.6 9,799.9 Vertical schematic (actual) A OW… OIL/W… C OW… WEST … CAMP… BASE …KALU…UPPE…K-1 M…LOWE… KUPA…UNIT …UNIT …C-4 IN…C-4B … C-4A … C-3 IN… C-2 IN… C-1 IN…C-1B … C-1A … UNIT …B-8 IN…B-7 IN…B-6 IN…B-5 IN… B-4 IN… B-3 IN… B-2 IN…B-1 IN… UNIT …A-6 IN…A-5 IN…A5-2 S… A5-1 S…A-4 IN…A4-3 S… A4-2 S… A4-1 S…A-3 IN…A3-3 S…A3-2 S…A-2 IN…A-1 IN…MILUV… FLOAT SHOE; 9,357.3-9,358.4; 1.16; 3-9; 9.625; 8.861 CASING; 9,273.0-9,357.3; 84.25; 3-8; 9.625; 8.861 FLOAT COLLAR; 9,271.4-9,273.0; 1.62; 3-7; 9.625; 8.861 CMT SQZ; 9,158.0-9,178.0; 2/4/1982 CMT SQZ; 9,146.0-9,158.0; 2/4/1982 CMT SQZ; 9,128.0-9,138.0; 2/4/1982 CASING; 8,821.3-9,271.4; 450.07; 3-6; 9.625; 8.861 APERF; 8,959.0-8,979.0; 4/17/1994 SOS; 8,944.5-8,945.3; 0.78; 2-10; 2.875; 2.441 TUBING PUP; 8,938.2-8,944.5; 6.26; 2-9; 2.875; 2.441 NIPPLE; 8,937.1-8,938.2; 1.10; 2-8; 3.668; 2.250 TUBING PUP; 8,931.0-8,937.1; 6.11; 2-7; 2.875; 2.441 PACKER; 8,922.3-8,931.0; 8.70; 2-6; 8.660; 3.250 SEAL ASSY; 8,921.4-8,922.3; 0.93; 2-5; 3.400; 2.440 XO REDUCING; 8,919.6-8,921.4; 1.83; 2-4; 3.500; 2.875 TUBING PUP; 8,913.4-8,919.6; 6.12; 2-3; 3.500; 2.992 SLIDING SLEEVE; 8,909.6-8,913.4; 3.81; 2-2; 5.750; 2.750 TUBING PUP; 8,901.1-8,909.6; 8.50; 2-1; 3.500; 2.992 MULE SHOES; 8,895.4-8,902.5; 7.13; 3-14; 8.500; 3.640 NIPPLE; 8,894.5-8,895.4; 0.91; 3-13; 4.500; 2.813 Tubing - Pup; 8,875.9-8,894.5; 18.60; 3-12; 3.500; 2.992 NIPPLE; 8,875.0-8,875.9; 0.88; 3-11; 4.500; 2.813 Tubing - Pup; 8,873.1-8,875.0; 1.92; 3-10; 3.500; 2.992 TANDEM WEDGE; 8,860.4-8,873.1; 12.65; 3-9; 8.250; 2.992 Tubing - Pup; 8,850.9-8,860.4; 9.55; 3-8; 3.500; 2.992 NIPPLE; 8,850.0-8,850.9; 0.88; 3-7; 4.480; 2.813 Tubing - Pup; 8,848.1-8,850.0; 1.92; 3-6; 3.500; 2.992 RPERF; 8,818.0-8,870.0; 4/17/1994 TANDEM WEDGE; 8,835.4-8,848.1; 12.65; 3-5; 8.250; 2.992 Tubing - Pup; 8,825.9-8,835.4; 9.55; 3-4; 3.500; 2.992 MARKER JT; 8,782.5-8,821.3; 38.81; 3-5; 9.625; 8.861 Tubing; 8,481.0-8,825.9; 344.84; 3-3; 3.500; 2.992 PBR; 8,451.1-8,481.0; 29.91; 3-2; 6.500; 4.000SBE; 8,451.7-8,477.4; 25.67; 4-31; 3.980; 2.990 PACKER; 8,423.2-8,451.1; 27.93; 3-1; 8.440; 6.120 Tubing; 8,420.2-8,451.7; 31.58; 4-30; 3.500; 2.992 Tubing - Pup; 8,409.9-8,420.2; 10.21; 4-29; 3.500; 2.992 GAS LIFT; 8,401.1-8,409.9; 8.87; 4-28; 5.968; 2.915 Tubing - Pup; 8,390.9-8,401.1; 10.22; 4-27; 3.500; 2.992 Tubing; 7,664.6-8,390.9; 726.30; 4-26; 3.500; 2.992 Tubing - Pup; 7,654.3-7,664.6; 10.21; 4-25; 3.500; 2.992 GAS LIFT; 7,645.5-7,654.3; 8.87; 4-24; 5.968; 2.915 Tubing - Pup; 7,635.3-7,645.5; 10.18; 4-23; 3.500; 2.992 Tubing; 6,752.2-7,635.3; 883.10; 4-22; 3.500; 2.992 Tubing - Pup; 6,742.0-6,752.2; 10.15; 4-21; 3.500; 2.992 GAS LIFT; 6,733.2-6,742.0; 8.86; 4-20; 5.968; 2.915 Tubing - Pup; 6,723.0-6,733.2; 10.16; 4-19; 3.500; 2.992 CASING; 4,644.3-8,782.5; 4,138.27; 3-4; 9.625; 8.861 Tubing; 5,146.3-6,723.0; 1,576.69; 4-18; 3.500; 2.992 Tubing - Pup; 5,136.2-5,146.3; 10.16; 4-17; 3.500; 2.992 GAS LIFT; 5,127.3-5,136.2; 8.87; 4-16; 5.968; 2.915 Tubing - Pup; 5,117.1-5,127.3; 10.17; 4-15; 3.500; 2.992 MARKER JT; 4,603.6-4,644.3; 40.71; 3-3; 9.625; 8.861 Tubing; 2,878.2-5,117.1; 2,238.90; 4-14; 3.500; 2.992 Tubing - Pup; 2,868.0-2,878.2; 10.21; 4-13; 3.500; 2.992 GAS LIFT; 2,859.1-2,868.0; 8.91; 4-12; 5.968; 2.915 Tubing - Pup; 2,849.0-2,859.1; 10.15; 4-11; 3.500; 2.992 FLOAT SHOE; 2,545.1-2,547.0; 1.87; 2-5; 13.375; 12.347 CASING Baker Locked; 2,476.3-2,545.1; 68.84; 2-4; 13.375; 12.347 FLOAT COLLAR; 2,474.7-2,476.3; 1.58; 2-3; 13.375; 12.347 Tubing; 1,810.9-2,849.0; 1,038.03; 4-10; 3.500; 2.992 CASING; 32.7-4,603.6; 4,570.85; 3-2; 9.625; 8.861 XO REDUCING; 1,809.4-1,810.9; 1.55; 4-9; 4.500; 3.833 Tubing - Pup; 1,804.7-1,809.4; 4.71; 4-8; 4.500; 3.833 SSSV ; 1,799.4-1,804.7; 5.23; 4-7; 6.923; 3.812 Tubing - Pup; 1,794.9-1,799.4; 4.49; 4-6; 4.500; 3.833 CASING; 33.4-2,474.7; 2,441.30; 2-2; 13.375; 12.347 Tubing; 78.1-1,794.9; 1,716.82; 4-5; 4.500; 3.833 Tubing - Pup; 70.3-78.1; 7.81; 4-4; 4.500; 3.833 CONDUCTOR; 31.3-80.0; 48.70; 1-1; 20.000; 18.938Tubing; 31.7-70.3; 38.60; 4-3; 4.500; 3.833 HANGER; 30.3-33.4; 3.10; 2-1; 16.000; 12.347 HANGER; 28.3-32.7; 4.40; 3-1; 12.000; 8.861 Tubing - Pup; 24.4-31.7; 7.35; 4-2; 4.500; 3.833 HANGER; 23.6-24.4; 0.75; 4-1; 13.625; 3.910 KUP PROD KB-Grd (ft) 31.99 Rig Release Date 12/13/1981 1B-10L1 ... TD Act Btm (ftKB) Well Attributes Field Name KUPARUK RIVER UNIT Wellbore API/UWI Wellbore Status PROD Max Angle & MD Incl (°) MD (ftKB) WELLNAME WELLBORE1B-10 H2S (ppm) 40 Date 8/12/2016 Comment Annotation End Date THE STATE °fALASKA GOVERNOR MIKE DUNLEAVY James Ohlinger Staff CTD Engineer ConocoPhillips Alaska, Inc. PO Box 100360 Anchorage, AK 99510 Re: Kuparuk River Field, Kuparuk River Oil Pool, KRU 113-10 Permit to Drill Number: 181-135 Sundry Number: 320-121 Dear Mr. Ohlinger: Alaska Oil and Gas Conservation Commission 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 v .aogcc.alaska.gov Enclosed is the approved application for the sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, ssi[,{ e�L.. Chmielowski Commissioner DATED this I q day of March, 2020. iBDMS—VWAPR 0 7 2020 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 2n AAr: 25 gan NUN MAR 16 2020 Oaf 7([c/2o A®GCC 1. Type of Request: Abandon ❑ Plug Perforations Q Fracture Stimulate ❑ Repair Well ❑ Operations shutdown ❑ Suspend ❑ Perforate ❑ Other Stimulate ❑ Pull Tubing ❑ Change Approved Program❑ Plugfor Redrill ❑ Perforate New Pool❑ Re-enter Susp Well ❑ Alter Casm g❑ Other: -Whipstock CTD PrepO 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: ConocoPhillips Alaska Inc Exploratory ❑ Development Q Stmtigraphic ❑ Service ❑ 181-135 3. Address: 6. API Number: PO Box 100360, Anchorage AK 99510 50-029-20656-OQoOa 7. If perforating: 8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? N/A KRU 1 B-10 Will planned perforations require a spacing exception? Yes ❑ No ❑✓ 9. Property Designation (Lease Number): 10. Field/Pool(s): fti— Atb 25648 Kuparuk River Field / Kuparuk River Oil Pool ' 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi): Plugs (MD): Junk (MD): 9,403' 6,878' 8,845' 6,276' 2,304 N/A N/A Casing Length Size MD TVD Burst Collapse Structural Conductor 49' 20" 80' 80' Surface 2,517' 13-3/8" 2,457' 2,272' Production 9,330' 9-5/8" 9,358' 6,837' Liner Perforation Depth MD (ft): Perforation Depth TVD (ft): I Tubing Size: Tubing Grade: Tubing MD (ft): N/A N/A 3-1/2" L-80 8,945' Packers and SSSV Type: Camco TRMAXX Packers and SSSV MD (ft) and TVD (ft): 1,799' MD / 1,696' TVD Baker SLZXP 8,423' MD / 6,002' TVD Baker D Permanent 8,922' MD /6,443' TVD 12. Attachments: Proposal Summary 0 Wellbore schematic LvJ 13. Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Stratigraphic ❑ Development 2 Service [J 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: 2020Z/r Zp OIL WINJ ❑ WDSPL E] Suspended ❑ GAS ❑ WAG ❑ GSTOR ❑ SPLUG ❑ 16. Verbal Approval: Date: yy'L Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned ❑ 17. 1 hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name: James Ohlinger Contact Name: Shane Germann Authorized Title: Staff CTD Engineer Contact Email: Shane.Germann CO .Com �S Contact Phone: 263-6927, 406-670-1939 :l 3/16/20 Authorized signature: Date: COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: Q Plug Integrity ❑ BOP Test u Mechanical Integrity Test ❑ Location Clearance ❑ Other: Burg iYS7" tD _75-0 7 1175, - ? . flnnv/ar prt✓lrv7-1-r2S�fl/��J #BDMbI 2� APk 0 7 2020 Post Initial Injection MIT Req'd? Yes F-1NoC� Spacing Exception Required? Yes ❑ No � Subsequent Form Required: 1 d — // b "L APPROVED BY Approved by: COMMISSIONER THE COMMISSION Date // Y71- 3//7/;0 Form 1O-003 Revised 4/2017 Approved application is valid for 12 months from the date of approval. Submit Form and Attachments in Duplicate s -I ConocoPhillips Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 March 16, 2020 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 cement squeeze perforations and set an Inner Wedge in KRU 1 B-10 (PTD #181-135) in order to drill one CTD lateral using the coiled tubing drilling rig, Nabors CDR3-AC. Attached to this application are the following documents: - 10-403 Sundry Application for KRU 1 B-10 - Operations Summary in support of the 10-403 sundry application - Current Wellbore Schematic - Proposed CTD schematic If you have any questions or require additional information, please contact me at 907-263-4597. Sincerely, Shane Germann ConocoPhillips Alaska Coiled Tubing Drilling Engineer KRU 1B-10 (PTD #181-135) CTD Summary for Sundry Summary of Operations: KRU well 1B-10 is a producer that was recently worked over to be set up for CTD operations. During the workover, 3'/" tubing was installed with tandem wedges to facilitate cutting a window with CTD. Prior to CTD operations CTU will cement squeeze the C4 perforations through a cement retainer and E -line will set an inner wedge within the tandem wedge. CDR3-AC will mill a window in the tubing and casing at 8,845' MD. After that the 113-101-1 lateral will be drilled to the southwest targeting the Kuparuk C -sand. The 1B -10L1 lateral will be completed with 2-3/8" slotted liner with a deployment sleeve on top. Pre -CTD Work 1. RU Slickline: Drift, set X -lock 2. RU CTU: Cement squeeze C4 perfs 3. RU E -Line: Set inner wedge at 8,845' MD 00 ROHS 4. Prep site for Nabors CDR3-AC rig. --aWork 1. M.IRU Nabors CDR3-AC rig using 2" coil tubing. NU 7-1/16" BOPE, test. 2. 1 B-101-1 Lateral (Kuparuk C -sand- Southwest) / a. Mill 2.80" window at 8,845' MD b. Drill 3" bi-center lateral to TO of 14,000' MD. c. Run 2-3/8" slotted liner with deployment sleeve from TO up to 8,840' MD. 3. Freeze protect, ND BOPE, and RDMO Nabors CDR3-AC rig. Post -Rig 4. Return well to production. Page 1 of 1 3/16/2020 KUP PROD WELLNAME 1B-10 WELLBORE 1B-10 "Well ConocoRPh iIIip 5 Attributes Ififigur Angie B MD 'f0 Alaska, Irc H.IaNama wxleoreavnuwl wellbomsmm: IMI°I mo(nKal actaun(rtkel K PAR VER UNIT 5002 2065600 P D 9]3 fi,300.00 9,4030 Comment H23IpPm1 Gale gnnolatlon Entl Cele KB.Grtl IN Rlg Release Dale 40 BI122016 Lea, fi1282018 31.99 1?71Y1981 1elo.lkUMol9l :3xagsl Last Tag vmlcaaonamnk tenwp annoiaam Depth MKO) Enam1. wellrore Last Moa By -.-_, ,.,_,,,,,,,._-, . _,,.. Lass Tag: 8,9JS.0 6(12018 18-10 related., ngAGEq', 231 Last Revv Reason AnnotationEntl 081e W¢IIWre Last Matl BY Rev Reason: Gas lift valves. Added cement retainer 1 W97. 1 15-10 leguns Casing Strings Cars mg... apnon oD("S ID IIn) Tap MKa) smpeirl Bel Depth Uodl . VJVLen p.-Graoe Top rnreaa CONDUCTOR 20 18.96 31.3 80.0 80.0 91.50 H-00 WELDED CONOlICT00.; 313ep0 a,,.,mr FMa. pi.ax,ns _-2,NO.O TI1&`'Vt9 anntiw Flud-d6sek za.a x000G:]/leets Cazing oecaracn Op(In) IO pn) Top MKa) Bet OepN (IIKOj let Depin jNp)... Wi/LM tI.. Gretle Top Threatl SURFACE 133/8 12.35 30.3 2,54)0 2,211.9 12.00 N-80 BTC casing PRODpeec0 rimrentID lin) Top InKB) set Depin SIKER ect..'r(IL)-jeff en ll... Gratle TopTnreatl PRODUCTION 9518 8.86 28.3 9,3584 6837.2 4].00 L-8p BUTT sssv;lnss.a Strings Strings owing Dg ' ". TUBING 4.Sx3.5x suing Ma...IOlinl 31/2 2.99 Top lone) 23.fi 8477.4tn M.. 84T1.4 6,049pM lTvol 8049.5 h.. 9,0Nrcl 9.30 Gretle LBOGra DUEa necgol DUE 2.875 WO 2019 UPPER COMPLETION CompielionDertift SURFACE; 3Ja2salo ToP(T Gn Toplim Nominal Top tnK3) Sonat (°) Item pe. coin to (in) 23.6 23.6 0.08 HANGER FMC 1398 x 4117 New Standard Big Some Tubing Hager Wl 5- 3.910 GAs L EF; 2.058.1 RH Acme top gnnxer FlJa. SalMnteaOrine: 2L.S.R.,taal"Grag 1,799mc 0- 1,695.5 42.94 SSSV Coo 41/2-TRMACK-SE3.812'SSSV 3812 gnmar Fqx-s mnlerl3nm', 1787' 3 W]0.5.1 a.3; ]/1eG018 1,809.4 1)027 43.04 XO REDUCING XO Plus 4112'IBTM Box 3112'EUE-Mori Pin 3.837 8,451,7 61 29.40 SBE Baker312"EUEseal ASsy 25STOALbo(edbe1owli1e1l0p 2.990 New up Gas uR:5,127.p Turing Description TUBING -45X 3.SX 2.875 WO 2019 string Ma... IS 312 2.99 Tap Mall 8,423.2 set Depm M_Get 8,902.5 D.PMl1VD)(...Wlllwrt) 64254 9.30 Gratle LBO Top connection EUE LOWER COMPLETION GAI LIR: 5.7]32 Complegon Details Amuhr R,H - ee Itrelerl0nne', 512pr $apLahleel PnnuWFLitl.,moeamakee; TOp1TV0) Topincl Nominal Top ONS) COKE) (°) Item Des Co. Iona) eta Baeoo.o'. TnaCOm 8,423.2 6.0023 29.55 PACKER Baker 998"X3-1R"TPLinel top packer Left in bole 6.120 GAS LIFn, ],8185 down 1 8.451.1 6,0266 29.40 PBR Seal Bore Extension (3' space out oft tag) 4.000 8,835.4 6365.8 27.32 TANDEM N.nhelnS011A1on93112x 998'Tanaem Wedge Assembly 2.992 Gas UR; Red 1 WEDGE 8850.0 6,3787 27.27 NIPPLE HES 31/2x2.813" X nipple Profile (Sal 2.813 PACKER: 0.432 8.860.4 6,3880 27.23 TANDEM Northern SOii.m.rs312- x 9 SATTandem Wedge Assembly 2.992 WEDGE SBE, 9, 451.7 PBR', 0, 0-511 9,9750 6,400.9 27.18 NIPPLE HES 3112' x 2.813' X nipple Profile 2.813 354.5 6,418.3 2710 NIPPLE HES311Z x 2.813'X Mpple role WIRHC Plug Insiste ((SN: 2.813 2727AJ B) 8895.4 6,419.1 27.10 MULE SHOES Baker3l@°x998'PGk1poy Overshol p6P Swallow) 3.640 T.,Ingo.... ippon TUBING wO stanB Me... I.pad 5.66 3.25 Top (M(6) Set Depin l4.set 8,901.1 8,945.3 DepM jNO)l... fip63.5 V+TpI'rt) Gratle Top Cannedlan 4.5x3.5x2.875" TANOEMWEOGE', 8. St Couple on Details FRAC e.e1e0 RPERF:0.0R.O.e. ](I.0 mpra-I I Topbcl Nominal Top MKO) (Mka) (•) arm Dee Com I. (In) 8.909.6 6,431.8 27.05 SLIDING BAKER CMU SLIDING SLEEVE; SEIZED IN CLOSED PUSITION 2.750 NIPPLE18.8W� SLEEVE 121B2007 8,919.6 8440.6 27.01 XO REDUCING CROSSOVER 3 5 a 2.875 2.875 TANDEMWEDGE8,980.4 8921.4 6,442.3 27.00 1 SEAL ASSY BAKER GBH 80-32 LOCATOR SEAL ASSEMBLY 2.440 6.443.1 2).00 PACKER BAKER D PERMANENT PACKER 3.250 -1 NIPPLE 0.8750 $937.1 6,456.3 7 NIPPLE OTIS XN NO GO NIPPLE 2.250 $944.5 6,452.9 I 'Rel BAKER SHETVOUTSUB 2441 NIPPLE, FIRMS Other In Hole repos retrtevabie plugs, valves, pumps, flaft, etc.) MALE SHOES; B,S5.4 Top ,`TVD) TOPlncl cnEM cur',aw10 Topf MKB) i') pes Co. Run Dale 10,11) 8,901.0 6,424.1 2208 CHEM CUT 2318"Cnemical cut. 9262019 0.000 8,904.0 6426.8 27.m Cement Retainer Set Weether Cement Retainer(OAL 1.46') 9152019 0.000 Cement RHairer;09]a0 perforations B Slots go, SLIDING SLEEVE; a con 6 sncv Do, -ASlm Ol bnat.M IESLASSI.e.glA KIS hospitals) 91m MK8) MKB) (nKe) unkM zone Dab 1 Type coin PaOKER;a,gaa 8,8180 8,8700 6,350.3 6,396.5 C-4, C-3.1&10 4/17/1994 40 DEERE 3317 Hypaet; 60 deg phasing NIPPLE,89at sos: acus 8,959.0 8,979.0 4475.8 6,493.fi 01,UNIT8,16411711994 -10 0 APERF 33/8' phasing Al SO Deg 9,128.0 9138.0 8627.5 6GSS 0-5, 1g-10 1/411982 4.0 Drai APERF', 9,146. 9,158.0 6,843.9 76547 A4---1 -BI -0 1/4/19824. CMT SOZ 9,158.0 9,17667219A, .,1 fi.fi54J Qfi.9 A 113-10 1/411982 4.0 CMT SOZ cMTso4a128.0e.13all Frac Summary clnrsoz a.tze.orae CMTSOZ8.18 da1eA0 Btart Date Proppenl Deslgnetl,1n) Pmppant In Icicle loo lin) 112112,108 CMTSG,EIP6.0ftag caT SO2; at59.Ga1790-, at, Sian ogle Tap DepM MKIO S. MKB) Llnkb Flula a'. Voleban Ma) Vol Blurty Song 1 1,`212008 88180 8,870.0 PgODIKPON: A.39,35B.4� KUP PROD WELLNAME 113-10 WELLBORE 1B-10 ConocoPhilla AlIQ aska I Valve I LakM1 GAS CXEM CUi', Cement P.M— 6LUNG SI ., APEflF8959.M$ 0— PPOOVCTIGN', Com 1B-10 Proposed CTD Schematic 13-3/8" 72# N-80 shoe @ 2547' MD C4 -sand perfs 8818'-8870' MD Proposed KOP @ 8845' MD C -sand perfs 18959'- 8979' MD A-saritl per's CMi SQZ 9128' - 9778' MD 4-1/2" 12.6# Tubing 4-1/2" Camco TRMAXX-5E SSSV @ 1799' RKB XO Pup 4-1/2" IBTM x 3-1/2" EUE @ 1809' RKB 3-1/2" Camoo MMG gas lift mandrels @ 2854', 5122', 6728', 7640', & 8396' RKB Baker Seal Assy. - 8447' (25.7' buried below LT) Baker SLZXP Liner Top Packer 8423' MD Baker SBE @ 8451' MD (4.0" ID) Northern Solutions WEDGE (see details) HES 3-1/2" X -Nipple @ 8889' RKB (2.813" ID) Baker Poorboy Overshot @ 8890' RKB Bottom of poorboy @ 8898' RKB Chem Cut - 8901' MD Left from original completion Baker CMU Sliding Sleeve @ 8910' RKB XO 2-7/8" x 3-1/2" Baker "D" Packer @ 8922' RKB Otis XN Nipple @ 8937' RKB Northern Solutions Wedge 9-5/8" 3-1/2" 9,30t L-80 Base Pipe " 8.25" OD (12.65' long) -25' Total Length " 0.625" Bore thru Upper Tray 1,125" Sore thru Lower Section " HES 2.81"X Nipple below 6-10L1 TO 14,000' MD Top of Liner @ 8845' MD Loepp, Victoria T (CED) From: Sent: To: Subject: Shane, What is the BOP test pressure? Victoria Loepp, Victoria T (CED) Thursday, March 19, 2020 9:32 AM 'Germann, Shane' KRU 1B-10(PTD 181-135, Sundry 320-121) Set Whipstock From: Germann, Shane <Shane.Germann@conocophillips.com> Sent: Tuesday, March 17, 2020 10:16 AM To: Loepp, Victoria T (CED) <victoria.loepp@alaska.gov> Subject: KRU 16-1010-403 Form Victoria, A 10-403 form was submitted yesterday afternoon for KRU 113-10 (PTD# 181-135) for whipstock setting and CTD prep work. The estimated date for commencing operations incorrectly states 1/20/2020 on the form. We estimate starting the operations described in the sundry around 3/26/2020. Sorry for the confusion. Thanks, Shane Germann Coiled Tubing Drilling Engineer Office: 907-263-4597 Cell: 406-670-1939 700 G St, ATO 664, Anchorage, AK 99501 DSR-4/9/2020 VTL 4/10/20 PTD IB/- J3 5-- Loepp, Victoria T (CED) From: Ward, Dusty K <Dusty.Ward@conocophillips.com> Sent: Friday, March 13, 2020 9:31 AM To: Loepp, Victoria T (CED) Subject: RE: [EXTERNAL]RE: 113-10 Sundry Path Forward Clarification Follow Up Flag: Follow up Flag Status: Flagged Victoria, Thank you for the quick reply! Have a good weekend. Dusty Ward Senior Wells Engineer Office: 907-265-6531 Cell: 503-476-2519 From: Loepp, Victoria T (CED) <victoria.loepp@alaska.gov> Sent: Friday, March 13, 2020 9:29 AM To: Ward, Dusty K <Dusty.Ward@conocophillips.com> Subject: [EXTERNAL]RE: 1B-10 Sundry Path Forward Clarification See comments in red below. Thanx, Victoria Victoria Loepp Senior Petroleum Engineer State of Alaska Oil & Gas Conservation Commission 333 W. 7th Ave Anchorage, AK 99501 Work: (907)793-1247 Victoria.Loepp cDalaska.aov CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Victoria Loepp at (907)793-1247 or ViCto6a.LoeoD@alaska aov From: Ward, Dusty K <Dustv.Ward@conocophillips.com> Sent: Friday, March 13, 2020 9:23 AM To: Loepp, Victoria T (CED) <victoria.loepp@alaska.gov> Subject: 1B-10 Sundry Path Forward Clarification Victoria, Hope this finds you well. We performed a workover on 1B-10 last year to set it up for CTD. Later in the fall, we tried to squeeze off the lower C1 area to see if we could isolate it from the C4, because we thought the C1 had a much higher water -cut. The results weren't conclusive, with similar water -cuts as before RWO. We contemplated various paths forward, including additional squeezes to control fluid movement, but since we can't get a good conclusion on where the water is coming from and if the C4 may just be as wet as the C1, we've decided to Squeeze off the entire near wellbore C -sands to give CTD the best chance at reaching lower water cut areas beyond the near wellbore. This is my first non -rig cement job running soup -to -nuts, and from my understanding of the sundry matrix, our path forward NOW is to squeeze off all the near wellbore, which kicks me out of the "squeezing off to control fluid movement within zone" category (10-404 only), and it kicks me into a "Plug for Re -drill" category (needing a 10-403 before we pump the next cement job), correct? Given this "change" of category due to our decision to "plug for redrill", then is the following path forward best? 1. Submit 10-404 to document squeeze attempt work to control fluid movement to date. Yes 2. Submit 10-403(plug for redrill) and get approval, before doing the full cement plug job (would probably include this in CTD's whipstock 10-403). Then CTD will follow up with 10-404(plug for redrill requires a 10-407) on the 10-403 when all the work is done like usual. Thanks for any clarification you can give. Please let me know if you have any questions. Appreciate your time. Good day. Dusty Ward Senior Wells Engineer Office: 907-265-6531 Cell: 503-476-2519 2 18g135 31125 WELL LOG TRANSMITTAL #905801940 To: Alaska Oil and Gas Conservation Comm. August 21, 2019 Attn.: Natural Resource Technician 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: Jet Cut and GR -CCL Records: 1B-10 Run Date: 06/27/2019 and 07/13/2019 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Fanny Sari, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 FRS—ANC@halliburton.com 1B-10 Digital Data in LAS format, Digital Log Image file 1 CD Rom 50-029-20656-00 RECEIVED AUG 2 7 2019 AOGCC PLEASE AU&NU WLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline & Perforating Attn: Fanny Sari 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907-275-2605 FRS—ANC@hallibufton.com Date: L/ Signed: STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑ Pull Tubing (] Operations shutdown ❑ Performed: Suspend ❑ Perforate ❑ Other Stimulate ❑ Alter Casing ❑ Change Approved Program ❑ Plug for Redrill ❑ erforate New Pool ❑ Repair Well D Re-enter Susp Well ❑ Other: CTD SETUP [21 2. Operator Name: ConocoPhillips Alaska, Inc. 4. Well Class Before Work: 5. Permit to Drill Number: Development p Exploratory ❑ Stratigraphic❑ Service ❑ 181-135 3. Address: P. O. Box 100360, Anchorage, Alaska 6. API Number: 99510 50-029-20656-00 7. Property Designation (Lease Number): 8. Well Name and Number: ADL 25648 KR <) IB -10 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pool(s): N/A Kuparuk River Field / Kuparuk River Oil Pool 11. Present Well Condition Summary: Total Depth measured 9,403 feet Plugs measured None feet true vertical 6,878 feet Junk measured None feet Effective Depth measured 8,871 feet Packer measured 8423, 8922 feet true vertical 6,397 feet true vertical 6002. 6443 feet Casing Length Size MD TVD Burst Collapse CONDUCTOR 49 feet 20 80' MD 80' TVD SURFACE 2,517 feet 13 3/8 " 2,547' MD 2272' TVD PRODUCTION 9,330 feet 9 5/8 " 9,358' MD 6837' TVD Perforation depth: Measured depth: 8818-8870. 8959-8979, 9128-9138.9146-9158 9158-9178 feet True Vertical depth: 6350-6396. 6476-6494.6627-6637 6644-6655 6655-6673 feet Tubing (size, grade, measured and true vertical depth) 4.5x3.5x2.875 L-80, L-80 J-55 8,945' MD 6,463' TVD Packers and SSSV (type, measured and true vertical depth) PACKER - BAKER LINER TOP PACKER 8,423' MD 6,002' TVD PACKER - BAKER D PERMNT PACKER 8,922' MD 6,443' TVD SAFETY VLV - CAMCO TRDP-4A SAFETY ` 1,799' MD 1,695' TVD 12. Stimulation or cement squeeze summary: Intervals treated (measured): N/A Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil -Bbl Gas-Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: Shut4N Subsequent to operation: Shut -IN 14. Attachments (required per20 AAC 25.070,25.071,&25.283) 15. Well Class after work: Daily Report of Well Operations III Exploratory ❑ Development Service ❑ Stratigraphic ❑ Copies of Logs and Surveys Run ❑ 16. Well Status after work: Oil El Gas ❑ WDSPL ❑ Printed and Electronic Fracture Stimulation Data ❑ GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP❑ SPLUG❑ 17. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or NIA if C.O. Exempt: 319-279 Contact Name: Dusty Ward Authorized Name: DustyWard Contact Email: Dusty.Ward@cop.com Authorized Title: Sr. Wells Engineer 1 9 Contact Phone: (907) 265-6531 Authorized Signature:ac, I I Date: W / Form 10-404 Revised 4/2017 q/¢//-7 3MMSAVAUG 2 12019 Submit Original Only r1 KUP PROD WELLNAME 1B-10 WELLBORE 1B-10 CowcoP1ill)p5 AQI�7117EIIK2.1 AHbutes 1IM,�ax Angle & MD TD Wellbore APUUW IWelllwn'solus Iknl'°I MG^NNR .A)8tlke.InGVFR II NIT PoOJ090ncann Donn Ik a �. 16-10, dIL'A181 peip PM Last Tag Varx>y riM'uk la`yHl Ann°I°Ibn DeWbM ER End Data Wellbx Lot Moa By _.............._......_ 9PJ N Y.iB .Last Tag: RKB 8,9]5.0 6/)12018 1B-10 m Uej ze HANGER, 318 Last Rev Reason AnmYaan End DaM WellDsre 1 Lazi Motl By Rev Reason: Multiple tubing cuts &DI2019 1B-10 famaj Casing Strings cosine--douon oD pry ID(in) Top MKel stl Depm MKB) set Depm lrvDL.. we" on!!...Grade Th'Im! CONDUCTOR 20 1894 31.3 80.0 80.0 9150 H>0 WELDED IT10 Casing Desadiation Dp lln) ID IMI TOp 11MB) Set DepIM1 MKB) Set Deem nYD1... WVLen p... Geode TopTbreae SURFACE 1338 12.15 30.3 2,54].0 2,2]19 ]200 N-80 BTC CONDUCTOR: 31aHG 0 'Imm, DeseriI OD (in) 1.0m, TOP ME) Set DegM1 lXxe1 Bet DepM (No)... WULen 11... Grone Tap TM1reatl PRODUCTION 9518 8.86 28.3 9,358.4 6.8322 4200 L-80 BUTT Tubing Strings 68aV:1,]SB.< TubmO DeKriPilOn TUBING 45 x3.5x 2.8]5 WO 2(19 SirmO Ma.,. 3112 Dn) �'20.99 TDP IXKBI 23.6 3el Depm (ry., 8,4]]4 Set Cepm TVDI1. 6,049.5 WIIIbMI 930 GraOe L80 COnnKtian CUE UPPER IT., COMPLETION Completion Details SURFACE.30M5470- roPm'D) iopmu Nominal TOP MR) japer 1.1 1. Cas Loin 81101 21.6 2. 0.08 HANGER FMC x412"New Standard Big Bore Tubing Merger 1 ' 3.910 G45 LIR; 3,�p.1 PHACme top 1 )99.4 116955 42.94 B SV Carew 4 WTRMA%X-%1 3.812 1797- 1,8094 1,]02.] 43.04 ING REDUCING XO Pup 4112' IBTM Sox x 3112' EUE-Mad Pin 3.833 8.4517 6,02]1 2940SBE Baker 'EUE seal ASSY 25ST 0L buried belowinettop 2.9 DA UFT, 51na New up TubinO"'alame TUBING -4Sx 35X 2.8]5 WO 2019 St ins Ma... 10 on) 312 2.99 Top MKB) 6N 8,423.2 8,902.5 Depm M.. sei Depm (IVIN 64264 Wt Both) 9.30 Grade 180 EUE wsuFTA..z LOWER COMPLETION ITopcomaction Completion Details QAEUFT;]W55 To (Tv I ToPlncl Nominal Top!lino) MKBI (°) IMMDea Cam ID lin) 8,423.2 6,002.3 29.55 PACKER Baker 9518" x }.1r " 1ZXP Liner top packer Le in here 6120 down wsuR:e.4av 8,451.1 6.0266 2940 PER Seal Bore Extension IT space out o8 lag) 4WO g,83S4 6365.8 2].32 ANDEM Nonllem Oluhons31/2"x9&'TantlemW WEDGE edge Assembly 2.992 PACRERIa.2 6850.0 6.3]8.] 27.27 NIPPLE HES 312"x2.813" X nipple Profile(SN) 2.813 $BE ill 1.t 8,860.4 6,388.0 2].23 AN EM NDnherO Snluaons 312" x 9 " Tandem Wedge Assembly 2.992 WEDGE 8,8750 6,400.9 2].18 NIPPLE HES3 'x2.813"% nipple P.F,1 (SN) 2813 8,894.5 6.418.3 7.10 NIPPLE HE 2'x "X nipple Profile Wl TI Plug INSlaled N: 2813 277A+8) 8,8954 6,419.1 7.10 MULE SHOES Baker 3112' x 9 &B' PGGrboy versMt (6 77' alk w) 3.640 rANpla NEDOa; 1. 4 RPERF, BFa11D8a10.0 xwneeleo TubinO Deedipinn SN. -Ma... Mlln) TUBING WO 5.86 3.25 4Sx3.5x2.875" TOp MKa) SN 8,9011 8,945.3 Depth M. Bel -0 PUD) I. 6463.5 WIBWM Oraae TOP LprnMbn Completion Details NIPPLE:84p0 Top(HDI roP mu Nominal Top MB) (pK ('1 11em Des Co. ID(inl 8, 09.6 61431.8 2].05 SLID BAKER SLIDINGEIZED IN CLOSED POSITION 2.]50 SLEEVE 12/6/2007 UNDEMWEDGE.emu 196 6440.6 2701 XO REDUCING CROSSOVER 35 x 2.875 2.875 ,921 4 6,442.3 2] W SEAL A BY BAKER GBH 80-32 LOCATOR SEAL ASSEMBLY 2,440 xIPPLEAMO 8, 22.3 6443.1 2] 00 PA NOR BAKER O PERMANENT PACKER 3.250 CATCHERSUB;e,8830 8,937.1 6456.3 26.95 NIPPLE OTIS XN NO GO NIPPLE 2,250 -FW5 BAILANO ROD, B.C885 6,462.9 2692 SOS BAKER SHEAR OUT SUB 2,M1 NIPPLE,e,m4s RHC em4,1 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) MNE SNDEs: e.e95.4 Top (HDI liP hno In (XKel Bins) I9 Das Com Run Dale Dem CHEM OUT, e,.O 236 23.6 008 BPVH 1CM HBPV 4191219 0.000 8,883.0 6,408.1 27.15 CATCHER SUB 219"Cakter any. 79 atmer "Bell guide 4192019 2.310 W2.31""G' FN GAL =B& suDlxo slEEVE; e,eres 8,888.5 6,413.0 21.13 BALL AND ROD Ball and and assy.699'oal 1. 8"FN )1182019 SEAL ABar:a@l4 ..,i 6894.5 6,418.3 2].10 RHC PLUG 281 X -RHC 7!1]2019 0.500 stxw BwO: s.e<oo PACI(ER:8933.J 8,901.0 6,424.1 7.08 CHEM CUT 23 R' Chemical cul 62&2019 0.000 PxNPLVG: a,mio 8,9 6,441.0]01 SILICA BAND Dump Bailed 11- of sand on PXN Plug 61812018 0.000 NmPLE;a.Wi1 8931.0 6450.8 2797 PXNPLUG 2.313 PXN Plug (Peg Mdy=40"B Prong=]8") 61812018 0.000 soslae«s Perforations B Slots APERF; 8 Real Mg]B 0� TOPMER Bbn MRO) Top (TVD) ("Eh BM TVD) Me) Let. Zone Date star Dana (stoyM 1 TYPE Com 8.8 18.0 8,8]0.0 5.3 6,396.5 C -0. C3, 18-10 411]/1994 CO TP -ERF 3 y1x:08b deg preaug CMT.C."a8081aaD cpTaDE; 519�.om�BL-. 69590 8.979.0 8,475.8 6,493.6 -q1rB894 -10 6.0 APERF pM1asirg ype0eb deg 9,126.0 9,1380 8,627.5 6,636.6 AS, 82 40 CMiSOZ CMT SDE 9148091580csnsoz. 9.i"GeRB� cMTaaz9lseoa,nlo_9,158.0 g, 1460 9.158.0 66439 6.654] A4. 82 40 CMT BOZ 9,1]8.06,654) 667.9 A4, 82 4.0 CMTS02 PRODUCTIox:..39.3 W.4 KUP PROD WELLNAME 113-10 WELLBORE 1B-10 Conoco illips'' Alaska.lnc. ,6,5 M1WA,a 1:o5zo PM Frac Summary Vw4L xeema&IvAuall BUSH Dab 1QM008 P,."., Gwyn. IBM ProppM In F—fion (1E1 _............__...__ __ BEV X: ]36 HAHGER,va SIV* SYtl Oate Top Dep1111RXE) Bo MKS) 1 12112008 8,8180 8,8]0.0 LInMb FIuiE 4yahm Vd Clean 0 VOI Blur 1 M rvlRall Mandrel Inserts SI aB N Ta RB on TPoI T MKS) IM1KBI MCRe MMeI -W. ODlld Sery Type Unnch Typ Po118W TRORun B., Ipai) pun Sale Com 1 2,859.1 2,509.8 Camco MMG 112 GAS LIFT DMY RK )/1812019 2 5,127,3 3,8104 Camco MM G 11Q GAS LIFT SOV DCR-i 711&2019 3 6733.2 4,654.6 Camm MMG 1112 GAS LIFT DMV RK )l1&2019 CCNDUCTOR,31a 0 4 ),645.5 5,3420 Camco MMG 112 GAS LIFT DMY RK )/182019 5 8401.1 5,983.1 Camco MMG 1 V2 GAS LIFT DMV RK )/182019 SSW I M..4 Notes: General & Safety Ene DaaAnnommn 1/29/1998 NOTE: WAIVEREDWELL'. IA x OA ANNULAR COMMUNICATION )/312019 NOTE: View SC5Bm60c W1 AI8ILk6 Scp.m68C1 . SURFACE', 30 i254T.0� GAIL UFT; x659., GAS LIFT; 5.1213 G LIFT. SM2 GAS UFT, PIKES OAS "FT. S..1 PACKER; 8,123.2 IGS, O.Wt 7 PBR, B,ZA T.DEMWEDGE', 5054 RFERF:0.815V50N.0 FRAC; 56180 4 HIPPIE;.BIGG TµDEM WEGGE: B.BJ4 NIPPLE; ILUIL CATCHER SUB; S®30 BALLPNDROD; 6,089.5 NIPPLE; 8®AS MG PLUG', 8.81.5 MULE SHOES; 885.a CHEM OUT. 8.9010 6UDBIGSLEEW;5Wa.0 SFPL ASSY. 5921.4 " sIUCASWD; 594.0 PACKER FUN PUN PLUG: B,Ai10 605. 59M.5 APEHESMM."LWB.Y— CMTSOZ;9.15.Da1mo, ' CMTSOL 51250Mte� 9.140,08, 1080 CMT 5p2', 9.1480 flNBt� :MT CMT 602 S.IYD8,1T8.0—� PRODUCTION: M"ISIB,4— Operations Summary (with Timelog Depths) 1B-10 Rig: NABORS 7ES Job: RECOMPLETION Time Log Stan Time End Time pur (hQ Phase Op Code Activity Coda Time P -T -X Operation Stan Depth (fiKB) End Depth (fIKB) 6128/2019 6/29/2019 24.00 MIRU MOVE MOB P Rig Down Derrickand pits Move Rig 00:00 0000 F/1 D T/ 113-10 and spot Sub base and pits Due to breaks on sub base failed Lost 5 firs on rig move due to repair R/U Derrick and spot pits (accept Rig @ 0001 6/29/19) 6/29/2019 6/29/2019 3.50 MIRU WELCTL OTHR P Take on 9.8 Brine and dilute back to 00:00 03:30 9.4 brine 7001bbls Continue R/U secondary annulus valves and R/U FMC lubricator Yest to 1000 psi All good Pull BPV and L/D same With 350 psi on Tubing 6/29/2019 6/29/2019 1.50 MIRU WELCTL KLWL P R/U flow back tank and R/U to pump 03:30 0500 down tubing and take Nunes through choke manifold Load pipe shed with 3 1/2" HT 38 drill pipe and strip same 6/29/2019 6/29/2019 2.50 MIRU WELCTL KLWL P Test line to 2000 psi and and hang rig 05:00 07:30 tongs and set sub racks on rig floor 6/29/2019 6/29/2019 12.50 MIRU WELCTL KLWL P Start pumping down Tubing @ 3 bbls 07:30 2000 minw/ 700psi take returns to flow back tank recover 65 bbls crude oil and lost returns continue pump 9.4 1 hole volume shut down pumping 9.4 brine cut back to 9.2 brine and pump 700 bbls of 9.2 brine with 280 psi open choke with no retunrs shut down purring and monitor well 30 mins with no pres on tubing and arm Both sides fill of 9.2 brine . 6/29/2019 6/30/2019 4.00 MIRU WHDBOP NUND P Set BPV and test same Pump down 20:00 00:00 back side @ 6 bbls w/ 350 psi Chock BPV all good Shut down N/D Tree and adapter Flange and FMC working on LDS 6/30/2019 6/30/2019 5.00 MIRU WHDBOP NUND P Continue N/D FMC tree and N/U 00:00 0500 BOP ,check both test joints N/U flow riser function test BOP System M/U 3 1/2" Test Joint 6/30/2019 6/30/2019 18.00 MIRU WHDBOP BOPE P Start testing BOP System W/ 3 1/2" 05:00 2300 Test joint (AOGCC Matt Herrera witness waived BOP test F/1 B-10 by E-mail) 250/2500 PSI C/O HCR kill line valve and test with both test joints All Valves tested to 250/2500 psi Well Head troubles due to FMC BPV and retest Choke valve # 14 All good 6/30/2019 7/1/2019 1.00 COMPZN RPCOMP CIRC P R/D Test equip and Fill Back side with 23:00 0000 9.0 Brine. 7/1/2019 7/1/2019 2.50 COMPZN RPCOMP OWFF P Continue Filling Back side with 9.0 00:00 02:30 Brine Tot 515 bbls and Pull FMC test dart and check BPV 40 psi on BPV and Circ 9.0 down Tubing @ 3 bbls w/ 250psi 120 bbls Shut down and check BPV no pres pull BPV and UD same 7/1/2019 7/1/2019 1.50 COMPZN RPCOMP OWFF P Continue Circ down Tubing @ 3 bbls 02:30 04:00 250 psi take returns through choke recover 80 bbls diesel from back side and lost retruns through open choke Shut down pumping and do static lost rate 120 bbl hr lost rate order and mix 8.8 brine 7/1/2019 7/1/2019 2.00 COMPZN RPCOMP OWFF P Monitor well, fill hole with 10 bbl's 04:00 06:00 every 30 minutes, w9ppg brine. rig up to UD tubing. Page 1110 Report Printed: 7/24/2079 NABORS 7ES Operations Summary (with Timelog Depths) 1B-10 Start Tme Start Depth 7/7/2079 ^13) End Depth (ftKB) loss rate ur. 18 bbl loss based off hole 50 psi. @ 3bbls tank lost 197 and Bull 0 bbls Shut W/ 40 psi on every 15 ugh choke well D.P pres End Tlme 7/1/2019 Dur(hn Phase 3.00 COMPZN Op Code Activity Code Time P -T -X n OPerin 06:00 09:00 RPCOMP OWFF P Cont to OWFF obtain static monitor well - No flow, Open up IA to fill with 9 ppg on the ho 7/1/2019 7/1/2019 4.50 COMPZN RPCOMP OWFF in 7 hour service rig si multaneously 09:00 1330 14:00 P P Cut 9.0 ppg back to 8.8 7/2/2019 7/2/2019 1.00 COMPZN RPCOMP SVRG crew on pulling hanger. fill static losses. 7/7/2079 7/1/2019 9.50 COMPZN RPCOMP OWFF CA =740 psi led off to bwiith 13:30 2300 spear. Damaged threads on saver Up brine F/ 7/2/2079 P Dspla eWel 8P PG 3 bbl s min @ sub. Remove saver sub. 15:00 hoke manifold take retrunrs to flow ba bac d 8.9+ @ 3 bblS w/ 90 psi bbl$ to well bore shut d own Pump total of 7/2/2019 3.00 COMPZN RPCOMP PULL ell bore 674 each. - Good test. head IA 8.8 Down IA 55 - No flow P Continue M/U baker spear and RIH down and Monitor well and latch up on Full joint of 3 1/2" DP casing and 30 psi on DP BOLDS. P/U to 175K and Slack off to mins bleed off 5 bbls tro 125K and P/U to 175K and Break over and Shut in and Monitor and scarred FMC hanger see picture 25 casing 35 psi and Mi Mil 71112019 7/2/2019 7.00 COMPZN RPCOMP OWFF 8.8 T/ 8.9 + 23:00 00:00 Hanger 20:00 00:00 P Displace Well w/8.9+@ Co Continue L/D 4 1/2", 12.75#, J-55, 165 psi Going through c 7/2/2079 7/2/2079 7.00 COMPZN RPCOMP KLWL Full open 00:00 07:00 Continue L/D 4 112" Tubing (Fluid Lost P Continue Displace Well 7/3/2019 11.50 COMPZN RPCOMP PULL Rate 10 Bbls Hr) 00:00 bbls min @ 165 psi @ 2 P Continue L/D 4 1/2" Tubing (Fluid Lost through full open choke. Rate 7 Bbls Hr) Jet cut joint flared 7/3/2019 7/3/20191.00 COMPZN RPCOMP RURD 1259 bbls. Total loss to w 1/2/2079 )7:00 13:3 079 13:30 6.50 COMPZN RPCOMP OWFF bbis P Shu Shut tlown antl monitor well on choke side. Tubing shut in w/ 0 pres open up tubing to flow line and monitor well - No flow, Open up IA to tiger tank - minimal flow decreasing to 7/2/2019 7/2/2019no 0.50 COMPZN RPCOMP SFTY flow over 2 hours. 13:30 14:00 P PJSM with Baker rep, FMC rep and ric 7/2/2019 7/2/2019 1.00 COMPZN RPCOMP SVRG crew on pulling hanger. 14:00 15:00 P Attempt to M/U top drive to single with spear. Damaged threads on saver Up brine F/ 7/2/2079 2.00 COMPZN RPCOMP RGRP 3 bbl s min @ sub. Remove saver sub. 15:00 hoke manifold T d 8.9+ @ 3 bblS w/ 90 psi saver sub 250/2500 PSI for 5 min Pump total of 7/2/2019 3.00 COMPZN RPCOMP PULL ell bore 674 each. - Good test. 17:00 - No flow on choke side. Tubing shut in w/ 0 pres open up tubing to flow line and monitor well - No flow, Open up IA to tiger tank - minimal flow decreasing to 7/2/2019 7/2/2019no 0.50 COMPZN RPCOMP SFTY flow over 2 hours. 13:30 14:00 P PJSM with Baker rep, FMC rep and ric 7/2/2019 7/2/2019 1.00 COMPZN RPCOMP SVRG crew on pulling hanger. 14:00 15:00 P Attempt to M/U top drive to single with spear. Damaged threads on saver 7/2/2079 7/2/2079 2.00 COMPZN RPCOMP RGRP sub. Remove saver sub. 15:00 17:00 T Replaced saver sub. Tested new saver sub 250/2500 PSI for 5 min 7/2/2019 7/2/2019 3.00 COMPZN RPCOMP PULL each. - Good test. 17:00 20:00 P Continue M/U baker spear and RIH and latch up on Full joint of 3 1/2" DP BOLDS. P/U to 175K and Slack off to 125K and P/U to 175K and Break over T/ 130K Pull hanger free Pull to Floor and scarred FMC hanger see picture in well file. Monitor well - All good. 7/2/2019 7/3/2019 4.00 COMPZN RPCOMP PULL P Hanger 20:00 00:00 Co Continue L/D 4 1/2", 12.75#, J-55, IJ4STubing Recover 58 -SS Bands (7 - SS Bands left in hole } L/D SSSV and Continue L/D 4 112" Tubing (Fluid Lost 7/3/2019 7/3/2019 11.50 COMPZN RPCOMP PULL Rate 10 Bbls Hr) 00:00 11:30 P Continue L/D 4 1/2" Tubing (Fluid Lost Rate 7 Bbls Hr) Jet cut joint flared 7/3/2019 7/3/20191.00 COMPZN RPCOMP RURD from 31/2"to 41/8" 11:30 12:30 P R/D tubing equipment. R/U drill pipe 7/3/2019 7/3/2019 0.50 COMPZN RPCOMP SVRG equipment. Clean and clear rig floor. 12:30 13:00 P Service rig. Grease top drive, blocks 7/3/2019 7/3/2018and 0.50 COMPZN RPCOMP SFTY crown. 13:00 13:30 P PJSM with Baker rep and rig crew on 7/3/2019 7/3/2019 2.00 COMPZN RPCOMP BHAH M/U BHA and PUDP. 13:30 15:30 P M/U BHA #2 Seal Overshot with CSG 7/3/2019 7/4/2019 8.50 COMPZN RPCOMP PULD scraper and boot baskets. 15:30 00:00 P Continue P/U 3 1/2" HT 38 D.P. F/ pipe shed and RIH T/7389' Operations Summary (with Timelog Depths) 1B-10 Rig: NABORS 7ES Job: RECOMPLETION Time Log Start Time EM Time Our (hr) Poe% Op Code Activity Cafe Time P -T -X Operatiari Start Depth (hKB) End Depth (RKB) 7/4/2019 7/4/2019 3.00 COMPZN RPCOMP PULD P Continue P/U 3 1/2" HT 38 D.P. F/ 00:00 03:00 pipe shed and RIH F/7389' T/8563' M/U Blower hose on top drive 7/4/2019 7/4/2019 2.00 COMPZN RPCOMP RGRP T Due to lube pump on top drive not 03:00 05:00 working troubleshoot w/ Nabors Mechanic. Replaced lube pump. 7/4/2019 7/4/2019 2.00 COMPZN RPCOMP FISH P Obtain parameters. UWT 165K, DWT 05:00 07:00 105K, ROT WT 130K. 3 BPM @ 340 PSI. 55 RPM TQ -Off 7.5K. SIO and dry tag at 8655'. P/U bum over stump 1 K WOB TQ -On 8.5K. Obtained full 6' swallow. Set down 30K string weight multiple times. No over pull on up stroke. 7/4/2019 714/2019 1.00 COMPZN RPCOMP CIRC P Circulate 3X STB strokes 165 Bbls @ 07:00 08:00 3 BPM 350 PSI. Loss to the well 91 Bbls. 7/4/2019 71412019 0.50 COMPZN RPCOMP OWFF P Observe well for flow for 30 Min. - No 08:00 08:30 flow - Fluid level falling in stack. UD single. RID blower hose. Filled after 30 Min hole took 3 Bbls. 7/4/2019 7/4/2019 5.00 COMPZN RPCOMP TRIP P POOH F/ 8620' T/ 1554' racking DP 08:30 13:30 back in derrick. Oil burping out of tubing when filling backside. 7/4/2019 7/4/2019 0.50 COMPZN RPCOMP CIRC P Circulate STB strokes to clear the drill 13:30 14:00 pipe. 15 Bbls @ 3 BPM 100 PSI. B/D top drive. 7/42019 7/412019 1.00 COMPZN RPCOMP TRIP P POOH F/ 1554'T/ 331' racking DP 14:00 15:00 back in derrick. Observe well for flow for 10 Min - No flow. 7/4/2019 7/4/2019 2.50 COMPZN RPCOMP BHAH P Stand back drill collars. UD fishing 15:00 17:30 BHA- NO FISH Clean out Boot baskets looks like we recover 7 SS Bands in pieces and Clean up Floor 7/4/2019 7/4/2019 1.50 COMPZN RPCOMP SHAH P M/U BHA # 3 W/ Baker 9 518" G -plug. 17:30 19: 00 7/42019 7/4/2019 4.00 COMPZN RPCOMP TRIP P RIH w/ Baker G -Plug on 3 1/2" HT 38 19:00 23:00 Work -String 1 min stand T/ 8624' and Fill hole and Set PKR @ 8624' PUW 148k SOW 105 7/4/2019 7/5/2019 1.00 COMPZN RPCOMP PRTS P Attempt to Test rasing @ 3 bbls No go 23:00 00:00 Injection rate @ 3 bbls min w/ 316 psi Shut Down 7/5/2019 7/5/2019 2.50 COMPZN TPCOMP P No test @ 8624' Release PKR and 00:00 02:30 POOH V 8162' Attempt to Reset PKR No Go Attempt several times Set on the way up but not on down stroke 7/5/2019 7/52019 5.00 COMPZN RPCOMP TRIP T POOH racking 3 1/2" DP back in the 02:30 07:30 derrick T/ 26'. Loss rate 8-10 BPH. 7/5/2019 7/5/2019 2.00 COMPZN RPCOMP BHAH T UD G Lock RBP #1. Clean and Gear 07:30 09:30 rig floor. P/U G Lock RBP #2 7/5/2019 7/5/2019 4.00 COMPZN RPCOMP TRIP T RIH T/8527' 09:30 13:30 7/5/2019 7/5/2019 0.50 COMPZN RPCOMP MPSP P Set RBP. Release from RBP. Center 13:30 14:00 of element at 8520'. Well will not hold hydrostatic fluid. 7/5/2019 7/5/2019 0.25 COMPZN RPCOMP OWFF P Observe well for flow for 10 min. - No 14:00 14:15 flow - Taking fluid 7/52019 7/5/2019 4.25 COMPZN RPCOMP TRIP P POOH F/ 8510' and Stand Back 3 14:15 18:30 1/2" HT work -String 7/5/2019 7152019 2.00 COMPZN RPCOMP BHAH P Clean up Floor and M/U BHA #5 18:30 20:30 Page 3/10 Report Printed: 7/24/2019 NABORS 7ES Operations Summary (with Timelog Depths) 1B-10 Job: RECOMPLETION Stan Time End Time Dur (hr) Phase Op Code Activity Code Time P -T -X Operation Stad Depth (eKa) End Depth @xe) 20:3019 20:30 2.50 COMPZN RPCOMP TRIP P RIH w/ 3 1/2" HT 38 Work -string T/ 23:0019 23:00 4267' 7/5/2019 7/6/2019 1.00 COMPZN RPCOMP PRTS P Set Baker 9 5/8" Test PKR @ 4267' 23:00 00:00 and Test Casing T/ 250/2500 PSI F/10 mins All Good pers up w/ 2.5 bbls Bleed off to 0 recover 2.3 bbls Release PKR and Monitor well 10 mins Allgood 7/6/2019 7/6/2019 1.00 COMPZN RPCOMP TRIP P Continue RIH F/ 4267 T/ 6445' 00:00 01:00 7/6/2019 7/6/2019 1.00 COMPZN RPCOMP PRTS P Set PKR @ 6445' and pressure up on 01:00 02:00 casing T/ 2500 PSI F/10 mins - good test. Release PKR and monitor well 10 mins - no flow 7/6/2019 7/6/2019 1.00 COMPZN RPCOMP TRIP P RIH F/ 6445' T/ 8473' 02:00 03:00 7/6/2019 7/6/2019 0.50 COMPZN RPCOMP PRTS P Set PKR @ 8473' center of element. 03:00 03:30 Test Casing T/ 2500 psi for 15 mins - good test. 4.6 Bbls T/ pressure up to 2500 psi. 4.4 Bbls bleed off. Release PKR. 7/6/2019 7/6/2019 1.00 COMPZN RPCOMP TRIP P RIH T/ 8515' engage RBP. Release 03:30 04:30 and allow element to relax. POOH T/ 8466'. Set RBP and release. 7/6/2019 7/6/2019 0.50 COMPZN RPCOMP PRTS TF_ Test RBP 8466' center of element T/ 04:30 05:00 2500 PSI for 15 Min. - Good test 7/6/2019 7/6/2019 5.00 COMPZN RPCOMP CIRC P Circulate STS at 4 BPM 530 PSI. 05:00 10:00 Halfway through circulation packer gas identified from when RBP was released. Shut annular and continued circulating through poor boy degasser 3 BPM 380 PSI. Checked for pressure - no pressure. Opened annular and observed well for flow for 10 Min. - No flow. Pump dryjob 25 Bbls 9.7 PPG brine. 7/6/2019 7/6/2019 4.00 COMPZN TPCOMP P POOH F/ 8460 T/ 34' racking back in 10:00 14:00 derrick. 7/6/2019 7/6/2019 0.25 COMPZN RPC 0 MMP _6WFF Observe well for flow - no flow. 14:00 14:15 7/6/2019 7/6/2019 0.75 COMPZN RPC 0 MMP SHAH P UD test packer and retrieval head. 14:15 15:00 Clean and clear rig floor. M/U retrieval head and RBP. 7/6/2019 7/6/2019 1.00 COMPZN RPCOMP MPSP T RIH 90'. Attempt to set G Lock RBP. 15:00 1600 Slips would not set in down stroke. They would set in up stroke. Attempt several times on at different depths with same result. Tool failure. 7/6/2019 16:00 7/6/2019 0.50 COMPZN RPCOMP BHAH T UD RBP and retrieval tool. Clean and 16:30 clear rig floor. 7/6/2019 7/6/2019 1.00 COMPZN RPCOMP BHAH T M/U retrieval tool and drill collars T/ 16:30 17:30 287' 7/6/2019 7/6/2019 0.50 COMPZN RPCOMP TRIP T RIH F/ 287'T/ 2171' for weight below 17:30 18:00 HES storm packer. 7/6/2019 7/6/2019 2.50 COMPZN RPCOMP SVRG T Cut and slip Drilling line 80' cut off slip 18:00 20:30 80' Service Rig 7/6/2019 7/6/2019 1.00 COMPZN RPCOMP BHAH T M/U Hallibuton RTTS strom PKR RIH 20:30 21:30 and Set @ 90' POOH LID 7/6/2019 7/6/2019 21:30 0.50 -CO MPZN RPCOMP PRTS T Test Halliburton 9 5/8" RTTS T 2500 22:00 psi 5 mins All good Bleed to 0 Blow Down line and Page 4110 ReportPrinted: 7/24/2019 Operations Summary (with Timelog Depths) IB -10 NABORS7ES Dur (hr)^ _ _ Phase Op Cotle ACGviry Cotle Tima P -T-% 17:00 7/8/2( 20:00 7/8/2( 21:00 7/8/20 22:00 7/9/20 00:00 7/9/20 01:30 7/9/20 02:30 7/9/20 03:00 17/9/201 09:30 r72 11 123:30 20:00 7/812[ 21:00 t 7/9/2( 09:30 7/9/20 10:30 7/9/20 15:30 16:30 7/9/2( 18:00 7/9/2( 20:00 250/2500 PSI M/U Haillibuton Running tool RIH 8' and latch up on RTTS releaseand monitor well 10 mins ok POOH and UD RTTS Continue RIH w/ 3 1/2" HT 38 Work string F/2179' t/5000' Continue RIH w/ 3 1/2" HT 38 Work stringF/5000' T/ 8460' on through poor boy. Heavy oil and slight gas returns. Losses to well 767 Bbls. Shut off pumps. Monitor for pressure for 15 Min - no pressure. Open annular observe well for flow - No flow, well taking fluid. POOH F/ 8466' T/ 760'. Gas fumes coming out of tubing. M/U top drive. Circulate BUS 50 Bbls @ 4 BPM 90 PSI, POOH F/ 760' T/ 287'. Monitor well for 10 Min - No flow Rack back drill collars. UD RBP and retrieval tool. M/U BHA # 9 W/ Baker over shot W/ mill cut Guide shoe RIH F/ Derrick W/ 3 1/2" HT 38 Work - Sting f/318'T/8643' PUW 152 SOW 105 Break Circ @ 2 bbls w/ 175 psi Job: Head Attempt to remove 9 5/8" Pack Off" Pulled 70K over on Pack off w/ no success. Notice one tubing head stud not moving freely. Cut one tubing stud 7/8/2019 7/8/2019 bolt off and relieved tension. 8.50 COMPZN RPCOMP WWSP 00:00 08:30 P Continue rock the bop stack to break the tubing spool free. of back bop and remove Genll packoff and spool and clean up 9 5/8" Mandrel hanger. 4 1/4" over all growth of 9 5/8" casing after tubing spool was removed. 7/8/2019 7/8/2019 8.50 COMPZN RPCOMP WWSPP Discuss Plan Forward with town. 08:30 17:00 M/U 9 5/8" spear. Engage 9 5/8" casing. P/U and verify adequate movement to land emergency slips. - Good travel. Set emergency slips with 120K over string weight to space out for wach's cutter. L/D spear. Cut off casing hanger total of 21". Install packoff. RILDS. Install new 13 5/8" 5K Thru-bore tubing head. Test intermediate packoff T/ 3000 PSI for 7/8/2019 7/anni o , ,.,. ,.,.,,.,�.. __ _ _ - _ 10 Min - Good test 17:00 7/8/2( 20:00 7/8/2( 21:00 7/8/20 22:00 7/9/20 00:00 7/9/20 01:30 7/9/20 02:30 7/9/20 03:00 17/9/201 09:30 r72 11 123:30 20:00 7/812[ 21:00 t 7/9/2( 09:30 7/9/20 10:30 7/9/20 15:30 16:30 7/9/2( 18:00 7/9/2( 20:00 250/2500 PSI M/U Haillibuton Running tool RIH 8' and latch up on RTTS releaseand monitor well 10 mins ok POOH and UD RTTS Continue RIH w/ 3 1/2" HT 38 Work string F/2179' t/5000' Continue RIH w/ 3 1/2" HT 38 Work stringF/5000' T/ 8460' on through poor boy. Heavy oil and slight gas returns. Losses to well 767 Bbls. Shut off pumps. Monitor for pressure for 15 Min - no pressure. Open annular observe well for flow - No flow, well taking fluid. POOH F/ 8466' T/ 760'. Gas fumes coming out of tubing. M/U top drive. Circulate BUS 50 Bbls @ 4 BPM 90 PSI, POOH F/ 760' T/ 287'. Monitor well for 10 Min - No flow Rack back drill collars. UD RBP and retrieval tool. M/U BHA # 9 W/ Baker over shot W/ mill cut Guide shoe RIH F/ Derrick W/ 3 1/2" HT 38 Work - Sting f/318'T/8643' PUW 152 SOW 105 Break Circ @ 2 bbls w/ 175 psi Job: Va.UU IU:UU Operations Summary (with Timelog Depths) F4 ...I. IB -10 7/10/2019 10:00 7/10/2019 13:30 3.50 Rig: NABORS 7ES TRIP Time Log RIH F/ 313' T/ 8670'. M/U top drive Job: RECOMPLETION Start Time 7/10/2019 End Time 7/10/2019 our dr) Phase 2.00 COMPZN COMPZN Op Cotla ggivily Code Time P -T -X start Depth Operation (flK8) End Depth (ttKB) 00:00 0200 and obtain parameters UWT 152K, RPCOMP FISH P PUW 152 SOW Break Circ 2 7/10/2019 7/10/2019 0.25 COMPZN ll a bbls w/ 175 psi Mill and wash over r FISH P DWT 112, 95 SPM, 1730 PSI. fish F/8655'8659' and latch up on fish 13:30 13:45 pull 45 K over, fired off Jars one time. at down 15K on fish top @ 8678', Fish seems to be free. Monitor well 30 mins Static loss rale around 40 fired jars once at 200K, once a 225K - bbls hr 7/10/2019 02:00 7/10/2019 0730 5.50 COMPZN COMPZN RPCOMP POOH F/ 8659' T/ 319'. Monitor well OWFF P fsh free. PIU 40' Observe well for flow No flow for 10 Min - No flow 7/10/2019 07:30 7/10/2019 0900 1.50 COMPZN FTP RPCOMP P Rack back collars. FISH ON34.88' - -Well CAL. UD seal assembly Clean and clear rig floor 7/10/2019 7/10/2019 1.00 COMPZN RPCOMP RHA. o Va.UU IU:UU ---.. ...I. _._ — .. ... ... ..r..... ..-.7.'i'nm. RIH T/ 313' on drillcollars. 7/10/2019 10:00 7/10/2019 13:30 3.50 COMPZN RPCOMP TRIP P RIH F/ 313' T/ 8670'. M/U top drive 7/11/2019 7/11/2019 5.00 COMPZN RPCOMP BHAH taking P and obtain parameters UWT 152K, 7/10/2019 7/10/2019 0.25 COMPZN RPCOMP FISH P DWT 112, 95 SPM, 1730 PSI. 13:30 13:45 at down 15K on fish top @ 8678', fired jars once at 200K, once a 225K - 7/10/2019 7/10/2019 0.50 COMPZN RPCOMP OWFF P fsh free. PIU 40' Observe well for flow No flow 13:45 14:15 - -Well Floor taking fluid. 7/10/2019 14:15 7/10/2019 8.75 COMPZN RPCOMP TRIP P POOH F/ 8636' BHA Depth. 22:30 23:00 BHA# Swabbing. Pump out of hole .5 - 1 BPM 50 -75 PSI. Over displacing pipe. T/ 7000'. No longer swabbing POOH F/ 7000' T/ 360' loss rate 60 bbls hr. Monitor well 10 Min - ok 7/10/2019 23:00 7/11/2019 1.00 COMPZN RPCOMP BHAH P Cont POOH and Stand Back4 3/4" 00:00 D.0 BHA#10 7/11/2019 00:00 7/11/2019 1.50 COMPZN RPCOMP BHAH P Continue UD Baker Retrievable PKR, 01:30 2 Full Joints , i Cut joint and # 1 GLM w/ pups 3 1/2" EUE BIRD. OAL UD 120.60' (very clean cut) See pics in well file. 7/11/2019 7/11/2019 1.00 COMPZN RPCOMP BHAH P Clean up Rig floor R/D power tong 7/111 02:30019 0/it/ 1.50 COMPZN RPCOMP BHAH P and Load BHA #11 M/U BHA# 11 T/ 340.41' and T/1 019 04:00019 04:00 7/11/2019 5.00 COMPZN RPCOMP TRIP P pump through rattler - all good 04:00 04:00 09:00 Continue RIH w/ 3 1/2" HT 38 work - String F/340.41 T/ 8750. Obtain parameters 158K UWT, 112K DWT, 15 7/11/2019 7/11/2019 0.50 COMPZN RPCOMP FISH RPM 6K Free Tq, 130 RWT 09:00 09:30 P Tagged top offish @ 8796' P/U Rot 15K RPM S/O saw tag and rolled over gaining 2' of swallow. P/U - no over pull. S/O tagged 4' higher than fully located depth. Re -confirmed tag 1415 ---.. ...I. ---r or aw omm aepm usou' 7/11/2019 14:15 7/11/2019 14:30 0.25 COMPZN RPCOMP OWFF P Observe well for flow - No flow - well 7/11/2019 7/11/2019 5.00 COMPZN RPCOMP BHAH taking P fluid Rack drill collars back. Fish R/U 14:30 19:30 tubing on. tongs. UD cut joint, pup joint blastjoints and pup joints. L/D fishing BHA. Recovered all blast rings OAL of fist 101.53' No lost junk in hole. Clean up Rig Floor 7/11/2019 7/1112019 19:30 3.00 COMPZN WELLPR BHAH P Load / BHA# 12And P/U pipe shed w/-70 22:30 BHA# 12 RIH T/ 367' Rig: NABORS 7ES Operations Summary (with Timelog Depths) IB -10 Job: RECOMPLETION Stan Time 72:30019 End Time 7/12(2019 Dur (hr) 1.50 Phase COMPZN Op Code Activity Code Time P -T -X Operation Start Depth ptK8) End Depth (WS) 22:30 0000 WELLPR TRIP P RIH w/ 3 1/2" HT 38 Work -String F/ 7/12/2019 00:00 7/1212019 3.00 COMPZN WELLPR TRIP P 367'T/2732' RIH W/3 1/2" HT 38 Work -String F/ 7/12/2019 03:00 0300 7/12/2019 3.50 COMPZN WELLPR WASH P 2732, T/8788, M/U top Drive and hook up blow hose 7/12/2019 D6:30 8.00 COMPZN WELLPR PULD P Start washing F/8788' T/ 8845' UWT 09:30 1730 160k DWT 115k RWT 60, Tq Off 6k@ 7/12/2019 17:30 7/12/2019 21:00 3.50 COMPZN WELLPR BHAH P 2 Bbls min w/200ps Ream F/ 8845' T/ 7/12/2019 21:00 7/12/2019 23:30 2.50 COMPZN WELLPR BHAH P 8904' TO On 6 -14K. POOH 150' and Monitor well 1 H. No Pump and RIH check tag up. No Fill T/ 8904' Top of II :,!:019 7/12/2 019 1.00 COMPZN WELLPR PULD P « uu L aaao LDDP F/ 8904'T/ 8310 06:30 0730 7/12/2019 07:30 7/12/2019 0930 2.00 COMPZN WELLPR SLPC P Cut and slip' drill line. Service draworks, top drive, blocks, and 7/12/2019 7/12/2019 8.00 COMPZN WELLPR PULD P crown. LDDP F/ 831 0' T/ 367' 09:30 1730 7/12/2019 17:30 7/12/2019 21:00 3.50 COMPZN WELLPR BHAH P Continue L/D Baker BHA #12 7/12/2019 21:00 7/12/2019 23:30 2.50 COMPZN WELLPR BHAH P R/U Pull wear Ring and Flush BOP stackout and clean up rig floor P/U Tubing Equipment F/ Completion 7/12/2019 23:30 7/13/2019 0.50 COMPZN RPCOMP RCST P String PJSM w crew M/U Baker poorboy 00:00 over shot and M/U Haliburton 9 5/8"X 3 1/2' PHIL Perme-tach Retrievalve 00:00 019 00:00 7/13/2019 02:00 2.00 COMPZN RPCOMP RCST P PKR Continue P/U Lower CTD Setup w/ 7/13/2019 7/13/2019 5.75 COMPZN RPCOMP RCST tandem Wedge Assembly Baker PKR 02:00 07:45 P Continue P/U 3 1/2" 9.3# L-80 EUE Mod Tubing M/U Tq 2240 ft/Ib. T/ 7/13/2019 7/13/2019 D.50 COMPZN RPCOMP S P 3556'. Found error in pipe tally. 0745 08:15 PJSM with rig crew and Baker rep. on POOH racking 3 1/2" tubing back in 7/13/2019 08:15 7/13/2019 08:45 0.50 COMPZN RPCOMP TRIP P derrick. POOH W/ completion string racking back in derrick UWT 59K DWT 50K F/ 3556'T/ 3052'. Pulled 20K over @ 3052' lost 1 OK string weight. Losses 7/13/2019 7/13/2019 1.25 COMPZN RPCOMP 0 T increased dramatically. 08:45 10:00 Establish static loss rate of 60 BPH. 7/13/2019 10:00 7/13/2019 14:00 4.00 COMPZN RPCOMP TRIP T Cont. POOH W/ completion string laying down jewelry and racking tubing back in derrick F/ 3052' T/ surface. 7/13/2019 7/13/2019 2.00 COMPZN RPCOMP SVRG pieceLast OOH was sea) assembly. 14:00 1600 T Clean and clear rig floor. Service 7/13/2019 7/14/2019 8.00 COMPZN EVALWB SLKL drawworks, top drive and blocks. 16:00 00:00 T R/U Halliburton slick line unit w/ relay line Make up 2.74 LIB RIH and tag up on the 3 1/2" stub 8895' / CCL F/ 7/14/2019 7/14/2019 4.00 COMPZN RPCOMP DSL 88957 8401' POOH W/ WLM 00:00 04:00 T Continue POOH and P/U Gamma ray tool RIH and Tag up @ 8895' WLM 7/14/2019 7/14/2019 2.00 COMPZN RPCOMP DSL T and Log F/ 8900' T/8350' POOH 04:00 06:00 R/D Halliburton slick line unit 7/14/2019 7/14/2019 06:00 06:30 0.50 COMPZN RPCOMP OWFFT Observe well for flow -Slight flow 019 019 0.50 COMPZN RPCOMP KLWL T observed at flow line 06:30 06:30 07:00 07:00 Bullhead 50 BbIS 8.9 PPG brine down well 3 BPM 150 PSI. Page 7110 Report Printed: 7124/2019 rcepon vrtmea: 7/24/2019 Operations Summary (with Timelog Depths) 18-10 F4 Rig: NABORS 7ES Time Log Job: RECOMPLETION Stag Time End Time 7/14/2019 7/14/2019 Our(hr) Phase Op Corte 0.50 COMPZN RPCOMP Agrvily Code OWFF Tme P -T -K Start Depth Operation (ftKB) End Depth(8KB) 07:00 0730 T Observe well for flow - No flow Well 7/14/2019 7/14/2019 07:30 10:00 2.50 COMPZN RPCOMP RURD taking fluid T R/U testing equipment - test joints, top drive chart recorder. Fill stack and choke with fresh water. Filling hole through IA with secondary kill from charge pump. 7/14/2019 7/14/2019 5.00 COMPZN RPCOMP BOPE Loss rate 100 BPH +/- 10:00 15:00 T Test BOP's w/ 3 1/2" & 4 1/2" test joints 250/2500 PSI for 5 Min each. Test gas alarms, PVT and accumulator. Test witnessed by 7/14/2019 7/14/2019 1.50 COMPZN RPCOMP RURD AOGCC rep Adam Earl. 15:00 16:30 T R/D testing equipment - test joint, top drive. B/D choke manifold, choke and 16:30 019 17:00 019 16:30 17:00 0.50 COMPZN RPCOMP RURD T Inilstlalll wear bushing 8.75" ID 7/14/2019 7/14/2019 17:00 22:00 5.00 COMPZN RPCOMP BHAH T Working on loadin 9 g pipe shed w/ 3 1/2"HT-38 work string and Baker BHA 22:00 019 00:00 019 22:00 00:00 2.00 COMPZN RPCOMP BHAH T PJSM/ M/U Baker BHA # 13 7/15/2019 7/15/2019 00:00 07:30 7.50 COMPZN RPCOMP PULD T Continue to P/U 3 1/2" HT 38 Work - string F/ pipe shed F/324.53 T 18400' 7/15/2019 7/15/2019 0.25 COMPZN RPCOMP FISH UWT 150K, DWT 105K 07:30 07:45 T M/U top drive. Engauge fish tag no-go at 8415'. Top offish at 8409'. Set down 10K. P/U to 165K. Set down 15K. P/U fish free at 170K. UWT 7/15/2019 7/15/2019 07:45 13:30 5.75 COMPZN RPCOMP TRIP 58K T POOH F/ 8415 BHA depth T/ 325' 7/15/2019 7/15/2019 13:30 15.30 2.00 COMPZN RPCOMP BHAH T UD BHA, drill collars and fishing tools 7/15/2019 7/16/2019 15:30 00:00 8.50 COMPZN RPCOMP BHAH T UD Baker PKR and L/D 11 Joint 3 1/2" EUE tubing T/ haliburton 9 5/8" L/D same , Baker Poorboy over shot pins are shear out on poorboy over shot. Clean up floor Load Pipe Shed with Baker New9 5/8:" PKR,Seal Bore Ext. 7/16/2019 7/16/2019 3.00 COMPZN RPCOMP PUTS Repin Poorboy over shot 00:00 03.00 T M/U Baker lower completion Assy1/2" 0.0 491.3 tandem wedge w/ 11 joints 3 1/2" EUE Poorboy over shot XO Baker SLZXP 9 5/8" PKR and XO t/ 3 1/2" HT 38 Work -String 7/16/2019 7/16/2019 03:00 04:30 1.50 COMPZN RPCOMP RURD T RD/RU Weatherford Power tongs RU 491.3 491.3 Nabors Tongs. Clean and organize 7 /16/2019 7/16/2019 704:301161 7.50 COMPZN RPCOMP PILL floor. establish 42 BBUHr. loss rate. 12:00 T RIH with 3-112" DP from 491.3' to 491.3 7/16/2019 7/16/2019 1.00 COMPZN RPCOMP RURD 8895.47 ELMD. 8905. les RKB. 12:00 13:00 T RU Slb E -Line sheaves, , CCL, GR 7/16/20197/16/2019 2.00 COMPZN RPCOMP ELOG T logging suite. 13:00 15:00 RIH with E -line to tag at 8421' ELM lag GR/CCL correlate 3' offset relative to original GR log. send data to Engineer for review. Dusty approved depth of Tandem wedges for the CTD side - 7/16/2019 7/16/2019 15:00 2.00 COMPZN RPCOMP RURD T rack. POOH RD SLB Eline. 1700 Paae 8/10 _ rcepon vrtmea: 7/24/2019 Operations Summary (with Timelog Depths) IB -10 Rig: NABORS 7ES Job: RECOMPLETION Time Log start Time 7/16/2019 End Time 7/16/2019 our inn 2.50 Phase COMPZN Op Code RPCOMP ANvity Code Time P -T -X O eration p Stan Depth (ftKB) End Depth (flK8) 17:00 19:30 HOSO T Drop 1.25" Phenolic ball allow to drop while RU pressure tesUsetting equipment to DP. Chase ball down to seat at 3BPM then reducing to 1.5 BPM to seat. pressure up DP to 4200 PSI see packer set. Bleed down to 0 Psi and Test casing U 2500 psi f/ 30 mins set top Pkr @ 8397' as / gamma ray Depth. 7/16/2019 7/17/2019 4.50 COMPZN RPCOMP TULD T Release PKR and Monitor Well 30 19:30 00:00 mins POOH and L/D 3 1/2" Work - string Lost rate 30 bbls hr 7/17/2019 7/17/2019 5.00 COMPZN RPCOMP PULD P Release PKR and Monitor Well 30 00.00 05:00 mins POOH and UD 3 1/2" Work - string Lost rate 30 bbls hr 7/77/2019 7/17/2019 0.50 COMPZN RPCOMP BHAH P UD Baker running Tool and Clean up 05:00 0530 Floor ,R/U to pull Wear Ring Bushing ,UD same and R/U to run 3 1/2" upper Completion String 079 7/17/2019 1.00 COMPZN RPCOMP OWFF P OWFF, well flowing, close BR bullhead 05:30 05:30 06:30 30bbl's @1 bpm 52 psi. 7/17/2019 7/17/2019 0.50 COMPZN RPCOMP TURD P RU to run completion 06:30 07:00 7/17/2019 7/17/2019 9.50 COMPZN RPCOMP PUTB P PU and RIH with 3-1/2" 9.3# EUE 8rd 07:00 16:30 217 joints total 7/17/2019 7/17/2019 2.00 COMPZN RPCOMP RURD P RU to run SSSV and 4-1/5" 12.6# 16:30 18:30 IBTM and Test Line U5000 psi ok 7/17/2019 7/17/2019 3.50 COMPZN RPCOMP RCST P Continue P/U 4 7/2" 12.6# IBT L-80 18:30 22:00 Tubing 7/17/2019 7/18/2019 2.00 COMPZN RPCOMP THGR P Tag up and space out w/7.81' pup 22:00 00:00 M/U FMC Tubing Hanger test SSSV lines U 5000 psi 7/18/2019 7/18/2019 1.50 COMPZN RPCOMP THGR P Continue testing SSSV lines t/ 5000 00:00 01:30 psi Tot joints run 4 1/2" 44 + 7.81 pup and 217 3 1/2" EUE Tuning PUW95K SOW75K 7/78/2019 7/18/2019 4.50 COMPZN RPCOMP CRIH P R/U U Displace well w/ 8.9 Brine w/ 01:30 06:00 1% Cl pumping down arm @ 4 bbls min w/ 285 psi 7/18/2019 7/18/2019 3.00 COMPZN RPCOMP PRTS T Drop ball and rod per BOT rep. 06:00 09:00 Landed TBG hanger (PU WT=93K, SOW=73K), RILDS and RU to test TBG/CSG. Emergency call from CPF-1 to get off high line power ASAP, Swapped from High line to genset power. Attempted to pressure test tubing to 3000 psi, at 2300 psi hook load decreased from 30K to 6K, Ldg. it showed some travel at the floor. Suspected the tbg hanger wasn't fully landed. BOLDS and pulled hanger to floor. Verified dimensions with FMC Anchorage. Hanger measurements and indications showed hanger was landed. 7/18/2019 7/18/2019 9.00 COMPZN RPCOMP THGR P Re -land TBG hanger, RILDS 09:00 18:00 Continue Test Casing and Tubing with no change Monitor well for 7 hr Shear out SOV @ 3000PSI Flow Back 30 bbl on the tubing side Build 450 bbls 9.2 Brine Page 9110 Report Printed: 7/24/2019 Operations Summary (with Timelog Depths) 1B-10 Rig: NABORS 7ES Job: RECOMPLETION Time Log Stan Time 7/18/2019 End Time 7/18/2019 Our (hr) Phase Op Code Activity Code Time P -T -X Operation Stan Depth (ftKB) End Depth (ii 3.00 COMPZN RPCOMP KLWL T Pump Down Back side @ 3bbls 18:00 21:00 280psi Take Turns through Choke- manfold F/ Tubing String @ 150 Back pres on Tubing pump 400 BBIs Shut down and monitor well l hr All good 7/18/2019 7/19/2019 3.00 COMPZN RPCOMP DSL T RID Hallibuton Stick line unit and RIH 21:00 00:00 w/ catcher for rod & ball drop of on rod POOH RIH Pull SOV 7/19/2019 7/19/2019 2.50 COMPZN RPCOMP DSL T Continue RIH and Pull SOV POOH 00:00 02:30 and LID same RID SOV RIH w/ new one set POOH and Sand By. 7/19/2019 7/19/2019 2.00 C OMPZN RPCOMP -R TS T Test Down Tubing U 3000 psi and 02:30 0430 open on the Back side Tested tubing 10 mins 3000 PSI no loss Bleed down to 1800 PSI and test Down IA to 2500 PSI f/ 30 mins no loss Bleed down Tubing and shear out SOV # 2 1800 psi Bleed off All pres and Ckeck flow Both IA and Tubing All good 7/19/2019 7/19/2019 0.50 COMPZN RPCOMP THGR P Set FMC BPV and test same U 1000 04:30 05:00 psi below All good 7/19/2019 7/19/2019 9.00 COMPZN RPCOMP NUND P NID BOP and Between well 05:00 14:00 maintenance on BOP stack N/U FMC Tree and 7/19/2019 7/19/2019 3.00 COMPZN RPCOMP THGR P Set Tell Plug and Tested tree 250/ 14:00 17:00 5000 PSI adapter flange test pack off 250/5000 PSI R/U Pull Test Plug . 7/19/2019 7/19/2019 4.50 COMPZN RPCOMP FRZP P R/U LRS and Teat lines to 2000 psi 17:00 21:30 and displace well w/ 140 bbls freeze protect diesel pump @ 2 bbls min w/ 750 psi and U -Tub 1 hr 7/19/2019 7/20/2019 2.50 COMPZN RPCOMP THGR P R/D LRS and RID FMC lubricator and 21:30 00:00 set BPV secure well and RID cellar Clean up and RID lubricator Release Rig F/ 1 B- 10 pad T/ 1 F-07 @ 0000 7 -19-19 Page 10110 Report Printed: 7/24/2019 Victoria T From: Sent: To: Ward, Dusty K <Dusty.Ward@conoco Phillips.com> Friday, July 19, 2019 Cc: 8:18 AM Loepp, Victoria T (CED); DOA AOGCC Prudhoe Senden, Subject: Attachments: Ba R. Tyler; NSK RWO CoMan; y Ward, Notification of BOP use on Nabors 7ESon 7/78/2019 1B-10 BOPE Letter 7_18 2019.doc Follow Up Flag: Flag Status: Follow up Flagged /'7-D /8 / - / 3 5 - Victoria Victoria and to whom it may concern, Please see attached document in response to Bulletin 10-003 in order to document the use of BOP equipment Please let me know if you have any questions. Dusty Ward on 18 10. Senior Wells Engineer Office: 907-265-6531 Cell: 503-476-2519 ConocoPhillips Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 July 18, 2019 AOGCC Industry Guidance Bulletin No. 10-003 Reporting BOPE Use to Prevent the Flow of Fluids from a Well Dear Commissioner: As per AOGCC Industry Guidance Bulletin No. 10-003, this letter is to follow up on BOPE usage on Nabors 7ES with a written report. Time of BOPE Use: 7/18/2019 at 10:30 hours Well Location: 1B-10 API Number: 50-029-20656-00-00 PTD Number: 181-135 Rig Name: Nabors 7ES Operator Contact: Dusty Ward. (o) 907-265-6531. (c) 503-476-2519. Dusty.Ward@conocophillips.com Operations Summary: On the morning of 7/18/2019, a ball and rod was dropped to pressure test (PT) tubing and casing. It was observed the Tubing and IA were in communication and the Shear Out Valve at —5118' RKB was suspected to have sheared early. Slickline was called to change out the SOV to finalize pressure test, when some flow was noticed on the well. At approximately 7/18/2019 at 10:30, the blinds were shut in. 8.9 ppg KWF was in the well. A 9.2 ppg KWF was circulated thru the SOV. A 30 minute no flow test will confirmed the well was static. Slickline operations were finished and RD. The tubing and casing were tested and the well was secured with a BPV in preparation to N/D BOPE for moving to 1 F-07. BOPE between well maintenance is currently being performed before the move to 1F-07. The blind ram will be retested at 1F-07 prior to starting any well -work at 1F-07. It will be tested to 250 psi and 2500 psi. BOPE Used: Blind Reason for BOPE Use: The blind ram was closed to prevent the well from flow. Actions To Be Taken: The blind ram will be retested once the rig is at I F-07 prior to starting well -work. If you have any questions or require any further information, please contact me at 265-6531. Sincerely, Dusty Ward Rig Workover Engineer CPAI Drilling and Wells Regg, James B (CED) From: Ward, Dusty K <Dusty.Ward@conocophillips.com> Sent: Friday, July 19, 2019 8:18 AM �D 171m l n To: Loepp, Victoria T (CED); DOA AOGCC Prudhoe Bay 6j Cc: Senden, R. Tyler; NSK RWO CoMan; Ward, Dusty K Subject: Notification of BOP use on Nabors 7ES on 7/18/2019 Attachments: 1 B-10 BOPE Letter 7 18 2019.doc Victoria and to whom it may concern, Please see attached document in response to Bulletin 10-003 in order to document the use of BOP equipment on 1B-10. Please let me know if you have any questions. Dusty Ward Senior Wells Engineer Office: 907-265-6531 Cell: 503-476-2519 ConocoPhillips Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 July 18, 2019 AOGCC Industry Guidance Bulletin No. 10-003 Reporting BOPE Use to Prevent the Flow of Fluids from a Well Dear Commissioner: As per AOGCC Industry Guidance Bulletin No. 10-003, this letter is to follow up on BOPE usage on Nabors 7ES with a written report. Time of BOPE Use: 7/18/2019 at 10:30 hours Well Location: I B-10 API Number: 50-029-20656-00-00 PTD Number: 181-135 1 Rie Name: Nabors 7ES ' Operator Contact: Dusty Ward. (o) 907-265-6531. (c) 503-476-2519. Dusty.Ward@conocophillips.com Operations Summary: On the morning of 7/18/2019, a ball and rod was dropped to pressure test (PT) tubing and casing. It was observed the Tubing and IA were in communication and the Shear Out Valve at —5118' RKB was suspected to have sheared early. Slickline was called to change out the SOV to finalize pressure test, when some flow was noticed on the well. At approximately 7/18/2019 at 10:30, the blinds were shut in. 8.9 ppg KWF was in the well. A 9.2 ppg KWF was circulated thru the SOV. A 30 minute no flow test will confirmed the well was static. Slickline operations were finished and RD. The tubing and casing were tested and the well was secured with a BPV in preparation to N/D BOPE for moving to IF -07. BOPE between well maintenance is currently being performed before the move to 1 F-07. The blind ram will be retested at I F-07 prior to starting any well -work at I F-07. It will be tested to 250 psi and 2500 ti psi. BOPE Used: Blind Reason for BOPE Use: The blind ram was closed to prevent the well from flow. Actions To Be Taken: The blind ram will be retested once the rig is at 1 F-07 prior to starting well -work. ' If you have any questions or require any further information, please contact me at 265-6531. Sincerely, Dusty Ward Rig Workover Engineer CPAI Drilling and Wells PTfj /B/—/ 3 S Loepp, Victoria T (CED) From: Ward, Dusty K <Dusty.Ward@conocophiIli ps.com> Sent: Wednesday, July 3, 2019 6:47 PM To: Loepp, Victoria T (CED) Subject. Re: [EXTERNAL]KRU 1 B-10(PTD 181-135, Sundry 319-279) RWO Change Approval Follow Up Flag: Follow up Flag Status: Flagged Thanks Victoria. I'll send to my Company Man. I might circle back to you later on this to make sure I understand expectations. 10-4 on including the regs and sundry info. Will try to include those in the future. Have a good 4th. Good day. Dusty Get Outlook for Android From: Loepp, Victoria T (CED) <victoria.loepp@alaska.gov> Sent: Wednesday, July 3, 2019 2:01:33 PM To: Ward, Dusty K Subject: [EXTERNAL]KRU 1B-10(PTD 181-135, Sundry 319-279) RWO Change Approval Dusty, I have reviewed the changes requested below and they are approved. Please include this approval with your copy of the approved sundry. While the changes are within regulations as they must be, they are changes to an approved sundry. When there is a change to an approved sundry, either a new Sundry for Change of Approved Program must be submitted for approval or many times, these changes are approved via email like this one. I appreciate the detail and regulation references that you provide as this will expedite these approvals. Naming the well, PTD #, Sundry number in the subject line as shown above is also helpful. Thanx, Victoria Victoria Loepp Senior Petroleum Engineer State of Alaska Oil & Gas Conservation Commission 333 W. 7th Ave Anchorage, AK 99501 Work: (907)793-1247 Victoria .Loeoo(a)alaska.00v CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Victoria Loepp at (907)793-1247 or Vic o iu Loe pp a dkuKngo� From: Ward, Dusty K <Dusty.Ward@conocophillips.com> Sent: Wednesday, July 3, 2019 7:06 AM To: Loepp, Victoria T (CED) <victoria.loepp@alaska.gov> Cc: Senden, R. Tyler <R.Tyler.Senden@conocophillips.com>; NSK RWO CoMan<NSKRWOCoMan@conocophillips.com>; Regg, James B (CED) <jim.regg@alaska.gov> Subject: FW: 18-10 Lower VBR Note Victoria, One additional change from information gained last night. - We didn't recover All of the SS bands holding the SSSV control line. - We therefore plan to add a Cleanout portion to the fishing BHA run to grab that -25' stub/seals above the upper packer. And we plan to do this fishing/cleanout run as the next step, because o The cleanout portion of the BHA should retrieve some of the bands or at least confirm the bands are pushed below where we'll set the deep 9-5/8" G -Plug previously mentioned. o The Fishing part of BHA keeps the scope moving forward. - Then we'll move forward with previously mentioned scope below. Let me know if you have questions/concerns. Again, FYI. Thanks for your time. Make it a great day. Dusty From: Ward, Dusty K Sent: Tuesday, July 2, 2019 3:56 PM To: Loepp, Victoria T (CED) <victoria.loeppCa@alaska.aov> Cc: Senden, R. Tyler <R.Tyler.Senden@conocophillips.com>; NSK RWO CoMan<NSKRWOCoMan@conocophillips.com>; 'James B Regg (DOA)' <jim.regg@alaska.eov> Subject: FW: 113-10 Lower VBR Note Victoria, Hope this finds you well. One additional change to the plan referenced below. It's become apparent that we should change the old PBU Gen 2 Tubing spool with a new one on 18-10. To swap this tubing spool we need to secure the well with downhole barriers. - We plan to secure the well by setting a G -Plug in the 9-5/8" casing down near -8640. o This will require running the 9-5/8" plug on 3.5" DP to that depth. o This step will also prove up casing integrity down to the G -plug, which is information we want to verify before we set the packer on the new completion. - We plan to set a 2nd barrier shallower and confirm it as well. - Then we'll make the tubing spool swap. Then we'll test the break and Lower VBR on 3.5" (referenced below). Pull the G -plugs. And then be back to our next fishing run. Again, from my understanding this is all FYI, as we're within regulations and sundries as referenced below and attached. Definitely holler if you have any questions or concerns. Thanks for your time. Good day. Dusty Ward Senior Wells Engineer Office: 907-265-6531 Cell: 503-476-2519 From: Ward, Dusty K Sent: Monday, July 1, 2019 3:44 PM To: Loepp, Victoria T (CED) <victoria.loepp@alaska.g > Cc: Senden, R. Tyler <R.Tyler.Senden@conocophillips.com>; NSK RWO CoMan <NSKRWOCoMan@conocophillips.com> Subject: 1B-10 Lower VBR Note Victoria, Hope this finds you well. FYI below on a small tweak to 16-10 RWO going forward. Summary: On 113-10 RWO, we couldn't get a 3.5" joint to test on the Lower VBR Pipe Rams. We believe this is due to the positioning of the test joint and the dart in the hanger profile. The 4.5" joints tested fine on the Lower VBR Pipe Rams. The rest of the BOPE (Blind, Upper VBRs, and Annular) all tested fine on 3.5" and 4.5" joints (or blank for blinds). So everything passed except Lower VBRs on 3.5". Our first tubing section to pull is practically all 4.5" as I note below. Requirements Understanding: Per regs 20 AAC 25.285.(c).(2).(A), we have a well with MPSP less than 3,000 psig and a rotary rig. From my understanding our tested Annular, Upper VBRs, and Blind rams satisfy all requirements AND fulfill the Sundry requirements; so the Lower VBRs (although shown in the sundry schematic) are above -and -beyond the requirements for this well, given its MPSP. Plan Forward: The current plan is to test the Lower VBRs on a 3.5" test joint once we're out of hole; so we plan to proceed with pulling our first section of tubing out of the hole. The first section of tubing consists of: - ^8430' of the 4.S" tubing; - Then a crossover and the last -226' is of the 3.5" tubing down to our pre -rig cut. Please let me know if you have any questions. Thanks for your time. Good day. Dusty Ward Senior Wells Engineer Office: 907-265-6531 Cell: 503-476-2519 THE STATE °fALASKA GOVERNOR MIKE DUNLEAVY Dusty Ward Sr. Wells Engineer ConocoPhillips Alaska, Inc PO Box 100360 Anchorage, AK 99510 Re: Kuparuk River Field, Kuparuk River Oil Pool, KRU 1B-10 Permit to Drill Number: 181-135 Sundry Number: 319-279 Dear Mr. Ward: Alaska Oil and Gas Conservation Commission 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 www, aogcc.alaska.gov Enclosed is the approved application for the sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, y Ze L. Chmielowski Commissioner DATED this �9 day of June, 2019. RBDMS-' JUN 101019 R E i V'i STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION JUN 0 3 2013 APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 r% 1. Type of Request: Abandon ❑ Plug Perforations ❑Fracture Stimulate ❑ Repair Well El Operations shutdown❑ Suspend ❑ Perforate ❑ Other Stimulate ❑ Pull Tubing ❑ Change Approved Program Plug for Rednll ❑ Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing ❑ Other: CTD SETUPI] 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: ConocoPhilli sAlaska Inc. Exploratory ❑ Development 121 Stratigrephic ❑ Service ❑ 181-135 r 3. Address: 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-029-20656-00-00 7. If perforating: 8. Well Name antl Number: What Regulation or Conservation Order governs well spacing in this pool? N/A ' Will planned perforations require a spacing exception? Yes ❑ No O • KRU 1B-10 9. Property Designation (Lease Number): 10. Field/Pool(s): ADL 25648 gc (5 1 Kuparuk River Field / Kuparuk River Oil Pool 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi): Plugs (MD): Junk (MD): 9,403' 6,878' 8871 1910pst Jun -24 Casing Length Size MD TVD Burst Collapse Conductor 49' 20" 80' 80' TVD Surface 2,517' 133/8 2,547' 2272' TVD Production 9,330' 95/8 9,358' 6837' TVD Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 8818-8870, 8959-8979, 9128- 6350-6396, 6475-6494, 6627- 4.5x3.5x2.875 J-55 8,945' 9138 9146-9158, 9158-9178 16637. 6644-6655 6655-6673 Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft): PACKER - BAKER FH RETRIVABLE PACKER MD= 8694 TVD= 6240 PACKER - BAKER D PERMANENT PACKER MD= 8922 TVD= 6443 SSSV - CAMCO TRDP-4A w/ NO GO MD= 1797 TVD= 1694 12. Attachments: Proposal Summary Wellbore schematic 0 13. Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Stratigraphic ❑ Development p Service ❑ 14. Estimated Date for 7/2212019 15. Well Status after proposed work: Commencing Operations: OIL El WINJ ❑ WDSPL ❑ Suspended ❑ GAS ❑ WAG ❑ GSTOR ❑ SPLUG ❑ 16. Verbal Approval: Date: Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned ❑ 17. 1 hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name: Dusty Ward Dusty Ward Contact Name: Authorized Title: Sr. Wells Engineer Contact Email: Dusty.Ward@cop.com Authorized Signature: 6-3 —aO � p1 Contact Phone: (907) 265-6531 Date: COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 31 - 2-7 1 Plug Integrity ❑ BOP Test 0?"" Mechanical Integrity Test ❑ Location Clearance ❑ Other: BOP 9-eStfa 2500 psI' 79nnvlar-/0 RBDMS" �uN 2019 Post Initial Injection MIT Req'd? Yes ❑ No Spacing Exception Required? Yes ❑ No Subsequent Form Required: 1,0-104 APPROVED BY Approved by: �Yl COMMISSIONER THE COMMISSION Date: iP k4rL 6�s�ly SATS �1(oll� fti Gin At J Submit Form and Form 10-003 Revised 4/2017 Appfoved appllCaflO 5 I 2 n r t date Of approval. Attachments in Duplicate AVVlt q0 sk-1 k9 ConocoPhillips Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 29 May, 2019 Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7" Avenue Suite 100 Anchorage, Alaska 99501 Dear Commissioner: ConocoPhillips Alaska, Inc. hereby submits an Application for Sundry Approval to work over Kuparuk Producer 1B-10 (PTD# 181-135). Well 1 B -I0 was drilled and completed in December of 1981 by Parker 141 as a Gas injector into the A -sands. The well was worked over in 1995, the A -sands were cemented off, and C -sands were opened to produce. In 2019 the well became a CTD candidate and the blast rings joints from 8829' RKB to 8893' RKB need to be removed for KOP. If you have any questions or require any further information, please contact me at 265-6531 Sincerely, Dusty Ward Senior Wells Engineer CPAI Drilling and Wells IB -10 RWO Procedure Kuparuk Producer CTD Setup PTD #181-135 Remainin¢ Pre -Rig Work 1. T-PPPOT and T -POT tests. 2. LockoutSSSV. 3. SBHP. 4. Open lowest GLM in upper completion. S. CMIT-IA to 2500 psig. 6. Chem cut the tubing nominally at "'8901' RKB in the middle of the 16' pup below the blast ring joints. 7. Chem cut the tubing nominally at ^8800 RKB in the middle of the first full joint above blast ring joints. 8. Install BPV and prepare well within 48 hrs of rig arrival. Rig Work MIRU 1. MIRU Nabors 7ES on 113-10. Pull BPV if need to circulate. 2. Record shut-in pressures on the T & IA. If there is pressure, bleed off IA and/or tubing pressure and complete 30 -minute NFT. Verify well is dead. Circulate KWF as needed. 3. Set BPV and confirm as barrier if needed, ND Tree, NU BOPE and test to 250/2,500 psi. Test annular 250/2,500 psi. Retrieve Tubing, Tubing, Packers, and Blast Ring Tubing Section 4. Pull BPV, MU landing joint and BOLDS. 5. Pull 4-1/2" tubing down to first packer (^'8694' RKB). 6. Pull first packer with 3-1/2" tubing down to pre -rig cut at -8800' RKB. 7. Washover tubing section blast rings to clean up. 8. Overshot tubing stub and pull blast ring section down to pre -rig cut at ^8901' RKB, then pull to surface. Cleanout Run 9. Perform a Cleanout run if necessary based on tubing condition and dress off 3.5" tubing stub if necessary. Install in 3-%" Tubing with tandem wedge for CTD Set Up 10. MU 3'/:" completion with overshot, tandem wedges, packer, GLMs, and SSSV. RIH and correlate completion so Kick Off Joints are at correct depth. 11. Once on depth, set packer and space out as needed. 12. Pressure test tubing to 3000 psi for 5 minutes. ✓ 13. Pressure test inner annulus to 2500 psi for 30 minutes on chart. ✓ ND BOP, NU Tree 14. Confirm pressure tests, then shear out SOV with pressure differential. 15. Install BPV. 16. NO BOPE. NU tree. 17. Pull BPV, freeze protect well, and set BPV if necessary. 18. RDMO. Page 1 of 1 20" 91.5# H-40 shoe @ 80' RKB 13-3/8" 72# N-80 shoe @ 2547' RKB KOP/TOWS @ 8828' RKB KOP/TOWS @ 8854' RKB C4 -sand perfs 8818'-8870' RKB C1 -sand perfs 8959'-8979' RKB A -sand perfs 9128'-9178' RKB (cmnt squeezed off) 113-10 Proposed RWO Completion PROPOSED COMPLETION 4-1/2" 9.3# L-80 EUE 8rd Tubing to surface 4-1/2" SSSV, then crossover from 4-1/2" to 3-1/2" 3-1/2" Camco MMG gas lift mandrels @ TBD Baker PBR xxxx' RKB Baker 4-1/2" x 9-5/8" Packer @ xxxx' RKB 3-'/z' X landing nipple at xxxx' RKB (2.813" min ID) V/2' x 9-5/8" Tandem Wedges (Integral X -Nipples 2.813") 3-1/2" Sealing Overshot REMAINING COMPLETION LEFT IN HOLE 9' cut stub top @ 8901' RKB 3.5" CMU Sliding Sleeve @ 8910' RKB Baker D Permanend Packer @ 8922' RKB (3.25" ID) OTIS XN nipple @ 8937' RKB (2.25" ID) Baker SOS @ 2.441' RKB 9-5/8" 47# L-80 shoe @ 9358' RKB 17' 13 5/8" 5000` WP HYDRL, TYPE "GK" 13 5/8" 5000" WP LATCHED TOP BY 13 5/8" FLANGED BOTTOM ANNULAR BOP 54 1/2" LENGTH 13-5/8" 50001 FLANGED HYDRIL DOUBLE CATE PREVENTOR 58 1/8" LENGTH 3" 50001 HCR VALVE 2" KILL LINE 9001 GATE VAI VE HYDRIL 13-5/8" 5k NSI HYDRAULIC RAhE SINGLE CATE FLANGED CONNECTION 36 IENGTH ,t KUP PROD WELLNAME 113-10 WELLBORE 1B-10 Conoc@Philfips I Well Attributes Max Ang1e8M0 TD TD AIeSNfi.In. FieM Name WeI1Mre APYW4 WMhore Shuts Irol r) MD ntl(B) 61K01 KUPARUK RIVER UNIT 500292069ROD PROD 59D 6,300.00 &403.0 comm. H205(ppm) ... AnmdEon EM DNe KBGrtl lnl Ry Retr e0atr SSSV:TRDP 40 &1212016 last VdO: 5/21/1995 31.99 12/1311981 1 aip, alvan9 e:aa AM Last Tag WNcaI a�MmaI."Knl) Annohton Deph TMO) I EnE Dau, WeIuou, LaatMM By Tait Tag: RKS 8,9]5.060/1018 ll&iu zembaej wHDER a.fi Last Rev Reason AnnoGnon Em Os. wellM,e Last MW ev Rey Ree6on: Tag & Set PXN PIug(Dump Omen pant on FIT, &&2018 1&10 zembaej Casing Strings casino DucNPNnn DD OnI mOn1 Top(mBl sel Depen lnxBl ser Depen RVDL_ WUIun 11 GIaEe rop TMeaa CONDUCTOR 20 18.94 31.3 800 80.0 91.50 H<0 WELDED CONDUCTOR; 31.3aD.0 CaSlq Ducrlpbn OD 6n1 10 (In) Top(M(B) Set tees XKB) sel DeptFRV01... WGIen 9... Grape Top TM1rctl SURFACE 13318 12.35 30.3 2,517.0 2.2)1.9 ]2.00 N-80 BTC OmDp Dexbptlan OD(N) 10 (In) TaP InKBI Set DeplM1 (XKB) Set DepM jN01... WIAen IL GMe Tep TM1wd aAFENRV I.>B6,e PRODUCTION 9518 8.86 28.3 9,3584 6.537.2 47.00 L-80 BUTT Tubing Strings T""w Daacnpmuo Sbing Ma...IDlml Top9"(8) Set DCPhDepih UVD)I... vn PNXI aMe Topcenmcuon TUBING WO 412 3.79 23.6 89463 6.463.5 12.J5 155 UNS 4.505x2.0]5" Completion Details Top IND) Top InclNominal 6URFACE: i23261].0� Topinnle (XKip rl no. Da. IDIim 23.6 236 ODS HANGER FMC GEN II HANGER 4.500 GASOFT,2656,7 1,'196.8 1,693.5 4282 SAFETY VLV CAMCO TRDP4A SAFETY VALVE wI NO DO 3.844 8.430.0 6,008.2 29.51 XO Retluceg CROSSOVER 4.5 X 3.5 3.500 8,6728 6221A 2],54 NIPPLE CAMCO DS NO GO LANDING NIPPLE 2.812 5,60.1 6227.9 2).4] PSR BAKER PER 3.090 ws UFp 3D'4.g 81893.8 5.240.1 27.35 PACKER BAKER FH RETRIVABLE PACKER 3.000 8,831.9 6,362.6 27.33 BLAST RINGS BLAST RINGS (2) 2.992 8,9096 6.431.8 2]05 BLEWEC BAKER CMU SLIDING SLEEVE: SEIZED IN CLOSED POSITION 2750 12/8200] GAe UFT:7 Use 8,919.6 6,4406 V. XO Redwing CROSSOVER 35 X 2.875 ZIPS 9.921A 6,4023 27.00 SEAL ABBY BAKER GBH 80.32 LOCATOR SEALASSEMBLY 2.440 8,922.3 6.43.1 27.00 PACKER BAKER D PERMANENT PACKER 3.250 Gets UFT,>.I 8.937.1 6,455.3 26.95 NIPPLE OTIS XN NO GO NIPPLE 2.25D 8,944.5 6,462.9 26.92 50S BAKER SHEAR OUT SUB 2441 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) mP(Omi Topma Top(Xn8) ('set r) Des cnm Run Do. Dunl BAS UFT;efi]).l 8.]39.66,T60.7 2].36 OBSTgUCTON ELirIa UNABLE TO PAS MANDREL 06 11/18/201 0.000 6880.0 6405.4 Zl. 6 TBG PUNCHES PRE -FRAC TUBING PUNCHES- 1.56- HSD. 4 SPF,5 1/1&2008 2.892 NIPPLE; B 6RB Deg phase @ all- 8890', 9 holes total - SLIDING SLEEVE WOULD NOT OPEN PeR:8em4 8,9200 6.411.0 -`u-Sano Dump Beiletl t l'ol 6antl on PXN Plug 6/812018 0.000 PACKER:eeve 8.931.0 8,450.8 PXN Plug 2.313 PXN Mug Runi, bo?)=40'&PLpq=15T fi182018 0.000 Perforations & Slots OBSTRLCTIDN;6,279.6 6aN PROOWTIDN:BT388 Tap(lip DuU1-) Dees hKohln Top Intel Bon (Test (XKB) III LusosE one Oale 1 cum 8,018.0 8,870.0 6,350.3 6.386[ G4. W.1B-ID 4/1])1994 4.0 ]318-Hypellel; Be tlag T Phmi, 8,959.0 8,9]9.0 6.4)5.8 6,093.6 Gt, UNIT B. 18 4Ill11994 6.0 3318'HyperjeL 60 tle0 .10 JRPEF. pbasllg 9,1280 9,136.0 fi.fi2].5 6,63fi.6 A-5, iB-10 27G1992 4.0 SO 9,1480 9,1580 6,6439 6,654.7 A4. 18.10 Z4/ 982 4.0 RPERF; a,B1Bpd9]D.0 4 _ FRAC: ee160 9,158.0 9,1780 66543 6,6729 IA4, 18- 2/4/1982 4.0 LMTSOZ TBG PUNL1E6; e.B�O Free Summary SWIDate Wopant pDmlpne49M limpmntln Formetian9M �S 1/2112008 ` g9� 6We 6hXDah TopDePMIXK01 am(XKB) Vq Cwon(bb9 Vg3(urry(bb9 1 11212000 8,818.0 8.8]00 SLEEVEC, S.�B.fi Mandrel Inserts st ail 6EALPa6Y:0.931< on Top(NO) VeNe UluhTs. Kansas TRO Run N Tap IXKB. (XKB) Make Motlel Sery Type Type It'll Run008 Com Mtieafienl: a9mp BA ,251) 1 2,856.7 2,5082 CAM00 -. "" 11IT GAS LIFT GLV RK 0.188 1,25).0 11242005 17172 PALKER:BYQ3 piwptoefi. v.0 2 5,314.2 3,912.1 CAMCO MMG 11/2 GAS LIFT OV RK 0.250 0.0 7/9/2009 37,113.8 4.9146 CAMCO MMG 112 GAS LIFT DMY RK 0.000 0.0 11/262000 uIPPLE; e.e3Ti 4 7,956.1 5,602.8 CAMCO MMG 1112 GAS LIFT DW TG 0.000 0.0 512V199S SOS', S.BNS 5 8.67.7.2 6.181.0 CAMCO MMG 1112 GAS LIFT Db1Y RK 0.000 0.0 1N9I2005 APERF:e,9SUHuppT0- 6 8,739.6 6280.] CAMCO MMG 1112 PROD OPHF RNP 0.000 0.0 113112008 CV Notes: General & Safety Enc mh AnnnGnnn N07E: WAIVERED WELL: IA x OA ANNUI kR COMMUNICATION eMf sOi', e,tgeA9,tY.o View Scmmatz wl Alaska Stsm matic9.0 I cMTSOL 9,11808, lsen: i LMTSOL8,146TA KB cMr SOL 9lpee-e Pfia' PRODUCTION. m3B,3R,4� I • Noel • ConocoPhiIIips Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510 -0360 June 27, 2011 AA:MU) ,IUL 0 8 2. Commissioner Dan Seamount Alaska Oil and Gas Commission 333 West 7 Avenue, Suite 100 Jr— — 3 '' Anchorage, AK 99501 , j $'„„ �SS�d� Commissioner Dan Seamount: Enclosed please find a spreadsheet with a list of wells from the Kuparuk field (KRU). Each of these wells was found to have a void in the conductor. These voids were filled with cement and corrosion inhibitor, engineered to prevent water from entering the annular space. As per previous agreement with the AOGCC, this letter and spreadsheet serves as notification that the treatments took place and meets the requirements of form 10 -404, Report of Sundry Operations. The cement was pumped on 3/21, 5/9, 5/23 and 5/24, 2011. The corrosion inhibitor /sealant was pumped 6/18, 6/19, 6/20 and 6/21, 2011. The attached spreadsheet presents the well name, top of cement depth prior to filling, and volumes used on each conductor. Please call MJ Loveland or Martin Walters at 907 - 659 -7043, if you have any questions. Sincerely, MJ L veland ConocoPhillips Well Integrity Projects Supervisor 1 • • ConocoPhillips Alaska Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top -off Report of Sundry Operations (10 -404) Kuparuk Field Date 06/27/2011 1A,1B,1E,1L,1Q,1Y PAD Corrosion Initial top of Vol. of cement Final top of Cement top off Corrosion inhibitor/ Well Name API # PTD # cement pumped cement date inhibitor sealant date ft L bbls 1 ft 1 gal 1A-03 50029206150000 1810880 I 16" I N/A I 23" I N/A 1.7 6/20/2011 1A-04A 50029206210100 2001940 18" N/A 23" N/A 2.5 6/20/2011 1A -16RD 50029207130100 1820310 SF N/A 22" N/A 5 6/18/2011 1B -03 50029205880000 1810560 _ SF _ N/A 23" N/A 5 6/21/2011 1B-04 50029205950000 1810650 18" N/A 18" N/A 2.5 6/21/2011 1B -05 50029202370000 1770010 31" 6.40 2'9" 5/24/2011 6 6121/2011 1B-07 50029206160000 1810890 _ 72" _ 1.00 22" 5/9/2011 2.5 6/21 /2011 1B -08A 50029206350100 1971120 _ 18'8" _ N/A 29" N/A 4.5 6/21/2011 1 B -09 50029206550000 1811340 _ SF N/A 23" N/A 5 6/20/2011 1 8-10 50029206560000 1 811350 SF N/A 23" _ N/A 6 6/21/2011 1B -12 50029223650000 1930610 _ 13'4" 2.00 24" 5/9/2011 6 6/21/2011 1B -101 50029231730000 2031330 _ 3" N/A 22" N/A _ 1.7 6/21/2011 1B -102 50029231670000 2031220 112" 0.60 36" 5/9/2011 1.7 6/21/2011 1E-05 50029204790000 1800580 r 19" N/A 19" N/A 1.7 6/19/2011 1E-22 50029208840000 1822140 _ 14" 1.75 17" 3/21 /2011 1.7 6/19/2011 1E-23 50029208580000 1821840 58' 10.75 2'5" 5/23/2011 3.4 6/19/2011 1E-30 50029208140000 1821390 _ 15'5" 1.75 16" 3/21/2011 2.5 6/19/2011 1E-105 50029232430000 2050060 _ 20" _ N/A 20" N/A 6 6/19/2011 1L-16 50029212020000 1841810 _ 14'9" _ 2.00 35" 5/23/2011 6 6/20/2011 1L-18 50029221450000 1910350 SF N/A 18" N/A 2.5 6/19/2011 1Q-24 50029225840000 1951210 _ 7'8" 1.00 12" 5/9/2011 , 5 6/18/2011 1Y-02 50029209410000 1830590 40'10" 5.00 41" 5/9/2011 8.5 6/18/2011 ___ _ 06/10/08 ~~~~~~ NO. 4741 Schlumberger -DCS 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Well Job # ~~At11N~~ JUN ~. ~ 200 Log Description Company: Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Kuparuk Date BL Color CD 2W-13 3J-17 2M-08 iB-10 1A-20 iG-13 11970689 11970690 11996642 11994672 11994673 11994674 GLS/PROD PROFILE - (0 GLS/PROD PROFILE /~ - v PROD PROFILE/DEFT / _ / / l( PROD PROFILE/DEFT ... G PROD PROFILE/DEFT - PROD PROFILE/DEFT 3 - J(o~!/~ 05/27/08 05/28/08 06/03/08 05/31/08 06/01/08 06/02/08 1 1 1 1 1 1 1 1 1 1 1 1 1A-03 11994673 PROD PROFILE/DEFT - / cpy~y 06/04/08 1 1 2W-17 11996644 PROD PROFILE/DEFT .-t ® ~( 06/05/08 1 1 iC-125 iC 127 11994677 ~ INJECTION PROFILE ~ - c.'~!~~0~~~0 06/05/08 1 1 - 1F 09 11994675 INJECTION PROFILE ~J _ L B~L~~~ 06/03/08 1 1 - 11994671 PROD PROFILE/DEFT -/ ®~<.(~ 05/30!08 1 1 iC-27 11994679 SBHP SURVEY -*(~ ®~G( 06/07/08 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. • • STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS ~,<c~ 1. Operations Performed: Abandon ^ Repair Well ^ Plug Perforations ^ Stimulate Q ~ 8~3ria. Ot~'If?3SSi0 Alter Casing ^ Pull Tubing ^ Perforate New Pool ^ Waiver ^ Time Extensi~~OL'J 8v Change Approved Program ^ Operat. Shutdown^ Perforate ^ Re-enter Suspended Well ^ 2. Operator Name: 4. Well Class Before Work: 5. Permit to Drill Number: ConoCOPhlllips Alaska, InC. Development ~ ~ Exploratory ^ 181-135 / ' 3. Address: Stratigraphic ^ Service ^ 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-029-20656-00 7. KB Elevation (ft): 9. Well Name and Number: RKB 98' ' 1 B-10 ° 8. Property Designation: 10. Field/Pool(s): ADL 25648,"ALK 466 Kuparuk River Field /Kuparuk Oil Pool ° 11. Present Well Condition Summary: Total Depth measured 9403' ' feet true vertical 6878' feet Plugs (measured) Effective Depth measured 8871' feet Junk (measured) true vertical feet Casing Length Size MD TVD Burst Collapse Structural CONDUCTOR 80' 20" 80' 80' .. _-.- -.. SURFACE 2507' 13-3/8" 2547' 2272' B-SAND LINER 3949' 9-5/8" 9358' 6837' Perforation depth: Measured depth: , 8818'-8870', 8959'-8979' ~;~.>~D~~~~~ ~~~~ ~ ~~~fi true vertical depth: 6350'-6397', 6476'-6494' Tubing (size, grade, and measured depth) 4.5"x 3.5"x 2-7/8", J-55/L-80, 8429'x8919'x8945' MD. Packers &SSSV (type & measured depth) pkr-- BAKER'FH' RETR. ; BAKER'D' PERM. pkr- 8694' ; 8922' Camco TRDP-4A SSSV= 1790' 12. Stimulation or cement squeeze summary: Intervals treated (measured) 8818'-8870' Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casin Pressure Tubin Pressure Prior to well operation SI -- Subsequent to operation 170 6147 5966 - 564 14. Attachments 15. Well Class after work: Copies of Logs and Surveys run _ Exploratory ^ Development ^' Service ^ Daily Report of Well Operations _X 16. Well Status after work: Oi10 ~ Gas^ WAG^ GINJ^ WINJ ^ WDSPL^ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.o. Exempt: none Contact Guy Schwartz @ 265-6958 Printed Name Guy Schwa `' Title Wells Group Engineer fi, Phone Date ~ -/Ca - O f~ Signature ~ ', C Pre ared b Sharon All u -Drake 263-4612 t Form 10-404 Revised 04/2006 ~'a ~~ 1 Submit final O y ~~~~ • ~ort4CC-Phillips Alaska, Inc. $-~ o _ _ API: 5002E TUBING SSSV T e: TRDF (0-8429, Annular Fluid: OD:4.500, ID:3.958) Reference Lo Last Ta :8871' • KRU 1 B-10 - - - -- - - Well T e: PROD An le a) TS: 27 de a7 8818 Ori Com letion: 12/13/1981 An le TD: 24 de 9403 Last W/O: 5/21/1995 Rev Reason: GLV C/O, CLOSE CMU, TBG Gas Lift - -m- ,. > Last Tag D2ta 1!2212008 ~ _.... PAax Hale An~l?~ ~ FO deg r¢~ 530p -..... _._ - - _ ~ .... _.... -- ~ ~ -....... ---....... MandrelNalve - r, " - '~ '" - Casing String - AL L STRINGS I 1 (285s-2a57, ~ _ _ Descri Ion Size To Bottom TVD Wt Grade Thread ~ CONDUCTOR 20.000 0 80 80 91.50 H-40 SURFACE 13.380 0 2547 2272 72.00 L-80 _ Gas lift PRODUCTION 9.625 ~ 0 4358 6837 47 n0 L-80 -1 MandrelNalve 2 Tubing. String -TUBING: _ ~, (5314-5315, Size To Bottom TVD WL Grade Thread 4.500 0 8429 6007 12.75 J-55 IJ4S 3.500 8429 8919 6440 9.30 L-80 EUE SRD 2.875 84fR RA45 646? 6.50 .1-55 Perforations Summary Interval TVD Zone Status Ft SPF Date Type Commen[ '31.3 ~iL7n r ,0- iy7 ~.4~;-3 2 4 41? 1~9T 395' 979 r 4i6 - 494 ~ 1 UNIT B 20 S 4'17 1914 __. H f~,rjFt b~ Jeg ~ha;ing Stimulations 8 Treatments Imerval Date r e t.;omment 9128 - 9138 5/18/1995 SOZ Cemented Perfs 9146 - 9178 5/18/1995 SOZ Cemented Perts 8818 - 8870 1/21/2008 FRAC C4 Sand FRACTURE TREATMENT . Pumped a total of 118400# of 16/20 Carbolite 300# left in WB with 12 PPA on formation 1672 BBL of SW, with an average pressure of 3245 psi. ISIP= 2325 psi, 5 min ~~o~~~ ~.a =1 aaa ~~~ ;teas ur< manare lswalve s - - _ _ _ St MD TVD Man Mfr Man Type V Mfr V Type V OD Latch Port TRO Date Run VW Cmnt 1 2856 2508 Camco MMG GLV 1.5 RK 0.188 1257 1/24/2008 2 5314 3912 Camco MMG OV 1.5 RK 0.250 0 1/24/2008 3 7113 4914 Camco MMG DMY 1.5 RK 0.000 0 11/26/2000 4 7956 5603 Camco MMG DMY 1.5 TG 0.000 0 5/21/1995 5 8627 6181 Camco MMG DMY 1 S RK __ O n00 0 12/9!2008 _ Rroduction MandrelsNalves St ~ MD ND Man Mfr Man Type V Mfr V Type V OD Latch Port TRO _ Date Run _ Vlv ~ Cmnt ~ - _ 3740 6~c1 C~1111UJ MG1G ---- -- - - OPEN 15 F:KP l)nflQ U 1~di~00Z 1 Other (plugs,_ equip., etc.) -SLEEVE Depth TVD Type Descriptio n ID 8909 b431 SLEEVE C Baker ~;l>lU Slidui~ sleeve -- - ~ LOSED 12 ~i2007 - `L iSn - Qther (plugs, equip., etc.) -JEWELRY _ __ De h ND T e _ Descri lion ID 1790 1688 SSSV Camco TRDP-4A w/ No Go 3.810 8673 6222 NIP Camco'DS' No Go Landin 2.812 8680 6228 PBR Baker 3.000 8694 6240 PKR Baker'FH' RETR. 3.000 8922 6443 PKR Baker'D' PERM. 3.250 8937 6456 NIP Otis'XN' NO GO 2.250 8944 6462 SOS Baker 2.441 RQdS fdR4 TTI ~ ddt General Notes - --- _ _ - Date Note 1/29/1998 NOTE: WAIVERED WELL: IA x OA ANNULAR COMMUNICATION 1/18/2008 NOTE: TUBING PUNCHES - 1.56" HSD. 4 SPF. 0 DEG PHASE SQZ (9128-9138) SQZ (9146-9178) 1 B-10 Well Events Summary DATE Summary 12/8/07 TAGGED @ 8924' SLM. BRUSHED XN NIPPLE @ 8937' RKB. SET 2.31" SV @ 8937. CLOSED CMU @ 8909' RKB. PULLED DV @ 8627' RKB, OV @ 5314' RKB. IN PROGRESS. 12/9/07 PULLED GLV @ 2856' RKB. SET DVs @ 2856', 5314' RKB. LOADED TBG & IA WITH 400 BBL SW & DSL FREEZE PROTECT. SET DV @ 8627' RKB. IN PROGRESS. 12/10/07 TESTED IA 3500 PSI, GOOD. PULLED CAT SV @ 8937' RKB. SET 2.31" PXN @ 8937' RKB. TESTED TBG 3500 PSI, GOOD. ATTEMPTED OPEN CMU SLIDING SLEEVE. IN PROGRESS. 12/11/07 MADE MULTIPLE ATTEMPTS TO ENGAGE AND OPEN CMU AT 8909' RKB WITH NO SUCCESS. READY FOR SCALE BLAST JOB. 12/12/07 SCALE BLASTED CMU WITH 40 BBLS GEUBEAD SLURRY MAKING 6 PASSES TOTAL ACROSS CMU AT 8909' CTMD, USED 3.5" x 2.875" XO AT 8919' FOR DEPTH CORRECTION, WELL LEFT SHUT IN AND FREEZE PROTECTED TO 2000' MD. RETURN IN THE AM (( IN PROGRESS )) 12/13/07 ATTEMPTED TO SHIFT CMU,MADE FIRST RUN WITH BAKKE HAMMER AND LOST TOOL ACTION, MADE FCO RUN WITH NOZZLE USING DIESEL GEL AND SLICK DIESEL, TRIED THIRD RUN WITH UP/DWN JAR AND SHEARED 42 BO, UNABLE TO PUMP IN WELL CMU APPEARS TO STILL BE CLOSED. 12/14/07 ATTEMPTED SHIFT CMU SLIDING SLEEVE AT 8909' RKB. IN PROGRESS. 12/15/07 BAILED SCALE BLASTING RESIDUE FROM 8799' TO 8848' SLM. IN PROGRESS. 12/16/07 BAILED FILL FROM 8846' TO 8890' SLM. IN PROGRESS. 12/17/07 BRUSHED TUBING ABOVE CMU AT 8909' RKB. BAILED TO 8898' SLM. ATTEMPTED OPEN CMU SLIDING SLEEVE AT 8909' RKB. IN PROGRESS. 12/18/07 PULL 1.5" DGLV/RK FROM 8407' RKB. PERFORM INJECTIVITY TEST; 2 BBUMIN AT 1400#, 14 BBLS USED. PUMP 15 BBL FREEZE PROTECT DOWN FLOWLINE. 12/28/07 SHOOT STRINGSHOT (3- 80 GRAIN/FT STRANDS) FROM 8805' - 8817' ACROSS CMU AT 8809'-8813'. DEPTHS REFERENCED TO TUBING TALLY. JOB IN PROGRESS. (ADDHOC CREW FROM PRUDHOE) 12/29/07 TAG TOP OF 2 7/8" TUBING Ca)_ 8922' RKB, W/ SAMPLE BAILER ,JOB IN PROGRESS 12/30/07 ATTEMPTING TO OPEN CMU, JOB IN PROGRESS 12/31/07 ATTEMPTING TO LATCH AND OPEN C- SAND CMU @ 8909' RKB, UNABLE TO LATCH OR OPEN ,SET 1 1/2" DMY @ 8740' RKB, PSI UP ON TUBING TO 2700# HOLDING BLEED BACK TO 2000# 1/6/08 MU AND RIH WITH 1.75" BHA & TAGGED GLM @ 7125' CTMD,POOH TO CHANGE BHA AND THE AMBIENT TEMPETURE FELL BELOW -40.LEFT WELL SHUT & FREEZE PROTECTED FOR THE NIGHT.WILL RETURN IN AM.JOB INCOMPLETE. 1/10/Q8 Weather hold -40 1/16/08 PERFORMED ACID WASH ACROSS CMU WITH 15 BBLS 15% HCL, MADE ATTEMPT TO SHIFT CMU OPEN AND WAS UNSUCCESSFUL. DISPLACE ACID FROM WELL TO CPF, RETURN IN THE AM TO ATTEMPT TO SHIFT CMU WITH HAMMER. WELL LEFT SHUT IN AND FREEZE PROTECTED WITH DIESEL, (15 BBLS DOWN FLOW LINE). 1/17/08 ATTEMPTED TO SHIFT CMU WITH BAKKE HAMMER, HAMMERED FOR 2 HRS BEFORE SHEARING 42 BO„CMU APPEARS TO STILL BE IN THE CLOSE POSITION AS WE COULD NOT INJECT INTO THE WELL, WELL LEFT SHUT IN AND FREEZE PROTECTED WITH DIESEL TO 4000' CTMD, READY FOR E-LINE 1 B-10 Well Events Summary 1/18/08 TUBING. PUNCHER USED TO ALLOW FRAC OF STRADDLED C-SANDS fCMU COULD NOT BE OPENED), INTERVAL 8888'-8890' WITH 1.56" HSD / 4SPF, ENTRANCE HOLE: 0.37" - 9 HOLES TOTAL. LRS INJECTIVI TEST POST PERF- 2 BPM AT 700 PSI. 26 BBLS DIESEL TOTAL PUMPED DOWN TUBING. 1/20/08 PULL 1.5" DGLV FROM "C" SAND PRODUCTION MANDERAL AT 8740' RKB. SET FRAC SLEEVE (68" OAL) AT 1790' RKB. JOB COMPLETE. 1/21/08 ,C4 Sand FRACTURE TREATMENT . Pumped a total of 118400# of 16/20 Carbolite 300# left in WB with 12 PPA on formation 1672 BBL of SW, with an average pressure of 3245 psi. ISIP= 2325 psi, 5 min pressure =1449 psi. FLUSH JOB TO COMPLETION, WITH 136 bbls INCLUDING 52 BBLS FREEZE PROTECTION. 1/22/08 TAGGED @ 8871' SLM, PULLED FRAC SLEEVE 1790' RKB, SET 3 1/2" SLIP STOP @ 8513' SLM, IN PROGRESS. 1124108 PULLED DV's @ 2856' RKB & 5314' RKB, SET OV @ 5314' RKB & SET GLV @ 2856' RKB. PULLED CATCHER. 1/28/08 MU AND RIH WITH SLIM BHA AND PERFORM POST FRAC FCO DOWN TO HARD L TAG @ 8948' CTMD, USING DUO-VIS GEL AND SLICK-DIESEL.HAD GOOD 1 FOR 1 RETURN WITH LIGHT TO MEDIUM AMOUNT OF SAND IN RETURN.LEFT WELL SHUT AND FREEZE PROTECTED WITH SLICK-DIESEL.JOB COMPLETE 1/31/08 TAGGED @ 8795' SLM. SET 1.5" DPHFCV @ 8740' RKB; VERIFIED SET WITH LIB. COMPLETE. 2/5/08 BAILED FRAC SAND FROM 8877' TO 8888' SLM. IN PROGRESS. 2/6/08 BAILED FRAC SAND FROM 8888' TO 8909' SLM. IN PROGRESS. IB-lO (PTD 1811350) failed TIFL . . Page 1 of 1 Regg, James B (DOA) From: NSK Problel'D Well Supv [n1617@conocophillips.com] Sent: Monday, August 20,200712:25 PM To: Maunder, Thomas E (DOA); Regg, James 8 (DOA) Cc: NSK Well Integrity Proj; NSK Problem Well Supv Subject: 18-10 (PTD 1811350) tailed TI FL Attachments: 18-10 schematic. pdt; 18-1090 day TIO plot.jpg ~"11 0IZ¡/01 Tom & Jim, /' Kuparuk gas lifted producer 18-10 (PTD 1811350) tailed a TIFL on 08/19/07 and has been added to the SCP report. The TIO immediately prior to SI tor the TIFL was 150/1150/660. A leaking GLV is suspected. Slickline will troubleshoot the tubing leak and repair it possible. ;,/ Attached is the schematic and the 90 day TIO plot. Please let me know it you have any questions. «18-10 schematic. pdt» «18-1090 day TIO plot.jpg» 8rent Rogers Problem Wells Supervisor 659-7224 6CANN~ AUG 2 3 2007 8/2112007 . . KRU 1 B-1 0 API: 500292065600 Well Tvoe: PROD Anole (cj) TS: 27 deg @ 8818 TUBING SSSV Type: TRDP Orig 12/13/1981 Angle @ TD: 24 deg @ 9403 (0-8429, Comoletion: OD:4.500, ID:3.958) Annular Fluid: Last W/O: 5/21/1995 Rev Reason: TAG BOTTOM Reference Loa: Ref Loa Date: Last Uodate: 8/14/2007 Last Taa: 8983' RKB TD: 9403 ftKB Gas Lift Last Taa Date: 8/11/2007 Max HOle-,6300 MandrelNalve 1 Descrintion Size Ton Bottom TVD Wt Grade Thread (2856-2857. CONDUCTOR 20.000 0 80 80 91.50 H-40 SURFACE 13.380 0 2547 2272 72.00 L-80 Gas Lift PRODUCTION 9.625 0 9358 6837 47.00 L-80 MandrelNalve 2 Size Too Bottom TVD Wt Grade Thread {5314-5315, 4.500 0 8429 6007 12.75 J-55 IJ4S 3.500 8429 8919 6440 9.30 L-80 EUE 8RD 2.875 8919 8945 6463 6.50 J-55 Interval TVD Zone Status Ft SPF Date TVoê Comment 8818 - 8870 6350 - 6397 C-4,C-3 52 4 4/17/1994 8959 - 8979 6476 - 6494 C-1,UNIT 20 6 4/17/1994 3 3/8" Hyperjet; 60 deg B nhasinn " Interval Date TVDe I Comment 1 9128 - 9138 I 5/18/1995 SQZ 1 Cemented Perfs I 1 9146 - 9178 I 5/18/1995 SQZ 1 Cemented Perfs , "'~ ,ii St MD TVD Man Mfr Man Type VMfr V Type VOD Latch Port TRO Date Run Vlv Cmnt 1 2856 2508 Cameo MMG GLV 1.5 RK 0.188 1281 4/25/2006 NIP 2 5314 3912 Cameo MMG OV 1.5 RK 0.250 0 4/25/2006 (8673-8674, 3 7113 4914 Cameo MMG DMY 1.5 RK 0.000 0 11/26/200 OD:3.500) 4 7956 5603 Cameo MMG DMY 1.5 TG 0.000 0 5/21/1995 5 8627 6181 Cameo MMG DMY 1.5 TG 0.000 0 5/26/1995 PBR (8680-8681, St MD TVD Man Mfr Man Type VMfr V Type VOD Latch Port TRO Date Run Vlv OD:3.500) Cmnt 1 6 87401 62811 Cameo MMG DMY 1.5 1 RKP I 0.000 0 15/25/20051 I .,. PKR I Deoth I TVD TVDe I Descrintion ID I (8694-8695, 1 8909 1 6431 SLEEVE-O I Baker CMU Slidina Sleeve; OPENED 8/9/2005 2.750 I OD:8.750) \ - , DeDth TVD TVDe Descrintion ID 1790 1688 SSSV Cameo TRDP-4A w/ No Go 3.844 8673 6222 NIP Cameo 'DS' No Go Landino 2.812 8680 6228 PBR Baker 3.000 8694 6240 PKR Baker 'FH' RETR. 3.000 ~ I--- 8922 6443 PKR Baker 'D' PERM. 3.250 ~ I--- 8937 6456 NIP Otis 'XN' NO GO 2.250 ~ I--- 8944 6462 SOS Baker 2.441 - I--- 8945 6463 TTL 2.441 SLEEVE-O (8909-8910, Date Note OD:3.500) 1/29/19981 NOTE: WAIVERED WELL: IA x OA ANNULAR COMMUNICATION PKR (8922-8923, OD:8.750) NIP (8937-8938, OD:2.875) TUBING (8919-8945, OD:2.875, ID:2.441) Perf .-.- I...... (8959-8979) ........ 1·000. ..... 1000000 SOZ I I (9128-9138) SOZ I I (9146-9178) Schlumberger NO. 3456 Schlumberger -DCS 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 A TTN: Beth 08/24/05 -1b l~f'l -& "-"'r'[o r, >~"g::. ·I-~.-· ê!:P f' ~l 20n¡:; ~Vif\~\!0~Þ.J ,JLJ t5 t - JUy Company: Alaska Oil & Gas Cons Comm Attn: Helen Warman 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Well Job# Log Description Date BL 1 E-18 l/i:J "ê ì l, 11015713 LEAK DETECTION LOG 08/06/05 1 1 F-01 J S)... -.1 j'l 11047354 PRODUCTION PROFILE WIDEFT 07/31/05 1 1Y-06A 19-/-i J '1 11015712 PRODUCTION PROFILE WIDEFT 08/05/05 1 3J-06 ¡ gS'- - ì.. 'i 11056679 PRODUCTION PROFILE W/DEFT 08/19/05 1 1Y-31 i '(3r 010 11015708 PRODUCTION PROFILE W/DEFT 08/03/05 1 1B-10 19ì -jJjÞ 11056671 PRODUCTION PROFILE W/DEFT - 08/12/05 1 3G-10 ¡c/t.- tiJ·( 11056670 INJECTION PROFILE 08/11/05 1 2Z-23 } qf;--QIÙ 11015717 INJECTION PROFILE 08/10/05 1 2X-06 8 ~ - if D 11015711 INJECTION PROFILE 08/04/05 1 2X-07 I In '.' /J.J 11015710 INJECTION PROFILE 08/04/05 1 1Y-04 /:13-· ,{, ~ 11047351 INJECTION PROFILE (REDO) 07/27/05 1 SIGNED: I 1/ r; D:.\/~ I !~- ~ DATE: Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. Kuparuk Color "- CD - ~~} 5))- ~~ s-· Schlumberger NO. 3213 Schlumberger -DCS 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 A TTN: Beth 9j¿7 09/24/04 Company: Alaska Oil & Gas Cons Comm AUn: Robin Deason 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Well Job# Log Description Date BL Color ~'f -OL( 2- 3C-06 10922465 PRODUCTION PROFILE W/DEFT 09/19/04 1 =tS-OS'1 2A-18 10802936 PRODUCTION PROFILE W/DEFT 09/12/04 1 1't- 0$8 2B-12 10802934 INJECTION PROFILE 09/10/04 1 ~ 1/- I'" I 2X-11 10802933 PRODUCTION PROFILE 09/09104 1 '~t- ~5 1B-10 10922467 PRODUCTION PROFILE 09/21/04 1 () ". ~5 3G-08 10802935 PRODUCTION PROFILE 09/11/04 1 r-í-oz ( 2F-08 10922466 PRODUCTION PROFILE 09/20/04 1 ~'Í - (( 7 2G-11 10884019 PRODUCTION PROFILE 09/08/04 1 - ~2. -,~ 1H-19 10802940 INJECTION PROFILE 09/14/04 1 í 2.- ~ 1H-07 10802939 INJECTION PROFILE 09/14/04 1 ~2 -()(O 1A-14 10802938 INJECTION PROFILE 09/13/04 1 t &1-0102H-03 10802945 INJECTION PROFILE 09/18/04 1 Iß?J-05tf 1Y-02 10802942 INJECTION PROFILE 09/16/04 1 ~- olflf 1 Q-13 10802941 INJECTION PROFILE 09/15/04 1 7 -H" 3H-09 10922468 INJECTION PROFILE 09/22/04 1 , ~6 -/'11 2T-02 10802944 TEMPERATURE SURVEY 09/18/04 1 ~9t)- /{,(P1A-26 10802943 LEAK DETECTION LOG 09/17/04 1 Kuparuk CD ~ ~~ r . s'€.ek I. kJa~ SCANNED NOli 0 82DD4 DATE: /f ~¿ Please sign and returLe copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. Schlumberger Schlumberger Technology Corporation, by and through is Geoquest Division 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 ATTN: Beth NO. 2926 Company: Alaska Oil & Gas Cons Comm Attn: Lisa Weepie 333 West 7th Ave, Suite 100 Anchorage, AK 99501 07/31/03 Field: Kuparuk Well Job # Log Description Date BL Color CD 1B-10 [ ~ V I?~~') SBHP 07/21103 1 lC-27 ) ~9'I~/~, TEMPIPRESS SURVEY 07122103 1 1 D-140 ~ [~ ~ SBHP 07/22103 1J-10 ~ ~ I SBHP 07/21103 1 2B-01 ~3 ~l ~,~ PRODUCTION PROFILE · 07119/03 1 2B-02 [~- ~ PRODUCTION PROFILE 07120103 2B'14 ~'~ _ PRODUCTION PROFILE 07/23/03 2E-11 ~ ~'~ ~ PRODUCTION PROFILE 07/~ 8103 3K-08~ ~=~ LDL 07125103 3M-03 ~ ~~ i~ LDL 07/24103 3S-19 ~~['~ PERFIJEWELRYI& INITIAL SBHPS 0711~103 1 , DATE: Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 June 20, 1995 Mr. David J. Johnston Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Subject: lB- 10GI(Permit No. 81-135) Well Completion Report Dear Mr. Commissioner: Enclosed is the well completion report for the recent 1B-10GI. Sincerely, operations on KRU W. S. Isaacson Kuparuk Petroleum Engineering WSI/skad STATE OF ALASKA AL ,,A OIL AND GAS CONSERVATION COM ION ., WELL COMPLETION OR RECOMPLETION REPORT AND LOG I Status of Well Classification of Service Well OIL [~] GAS r"-] SUSPENDED r'~ ABANDONED r~ SERVICE r--1 2 Name of Operator 7 Permit Number ARCO Alaska, Inc 81-135 3 Address 8 APl Number P.O. Box 100360, Anchorage, AK 99510-0360 50-029-20656 4 Location of well at surface i~L~'~&'~ii~Ji~- ~: ........ ' 9 Unit or Lease Name 494' FNI., 1302' FEI_, Sec. 9, T11N, R10E, UM ! ---""~ Kuparuk River Unit At Top Producing Interval~ ~ 10 Well Number 882' FNL, 1144' FWL, Sec. 3, T11N, R10E, UM 1B-10GI .... At Total Depth 11 Field and Pool 697' FNI_, 1338' FWL, Sec. 3, T11N, R10E, UM KUPARUK RIVER 5 Elevation in feet (indicate KB, DF, etc.) I 6 Lease Designation and Sedal No. 98' RKBI ADL 25648 ALK 466 12 Date SpuddedNov. 14, 1981 13 Date T.D. ReachedNov. 30, 1981 14 Date Comp. , Susp. or Aband.13_Dec.81 115 water Depth' If OffshOreNA feet MSL 116 NO' Of cOmpletiOns1. 17 Total Depth (MD+TVD) 18 Plug Back Depth (MD+TVD) 19 Directional Survey 120 Depth where SSSV set 21 Thickness of permafrost 9400' M D & 6872' TVD 9027' M D, 6537' TVD YES ~ NO L..JI 1797' feet MD 1650 APPROX 22 Type Electric or Other Logs Run DIL/SP/GR/BHCS FDC/CNL/GR/CAL CBL/VDL/CCL/CAL 23 CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE VV'I' GRADE TOP BTM HOLE SIZE CEMENT RECORD 20" 91.5" H-40 Surf. 80' 30" 280 sx AS II 13-3/8" 72" L-80 Surf. 2547' 17-1/2" 1600 sx Fondu & 400 sx AS II 9-5/8" 47" L-80 Surf. 9358' 12-1/4" 2115 sx Class "G" cement 24 Perforations open to Production (MD+TVD of Top and Bottom and .o 25 TUBING RECORD .u)l:= SIZE DEPTH SET (MD) PACKER SET (MD) interval, size and number) J~ ~-' 4-1/2" x 3-1/2" 8945' 8694' & 8922' 4spf: 8818'-8870'MD 6350'-6396'TVD ~ 0') 6 spf: 8959'- 8979' M D 6476' - 6494' TVD ~ '-- ~ ~_~ ACID, FRACTURE, CEMENT SQUEEZE, ETC ~===== r--- ~ _~P'I'H INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 4spf: 9128'-9138'MD 6628'-6637'TVD [,.1=,! c',J ~ ~ 9128'-9178' 25bbls15.6#/Gal. Class G latex cement 4spf: 9146'-9178'MD 6644'-6673'TVD U .~,. c.~ ,~, 27 PRODU(~i~ION TEST [Date First Production Method of Operation (Flowing, gas lift, etc.) Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE I GAS-OIL RATIO TEST PERIOD ~ Flow Tubing Casing Pressure CALCULATED OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Pr ss. 24-HOUR RATE I~ 28 CORE DATA iBrief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. Form 10-407 Submit in duplicate Rev. 7-1-80 C(3~INUED ON REVERSE SIDE C-~-(:X.OGIC MAR(ERS FORMATION TESTS NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS DEPTH TRUE VERT. DEl=TH GOR, and time of each phase. Top Kuparuk 8671' 6220' Base Kupamk 9234' 6724' RECEIVED JUN 2 1 1995 Alaska 0il & Gas Cons. Commission Anchoraa~e 31. LIST OF A'ri'ACHMENTS Drillin~l Activity Histor)/ 32. I hereby certify that the foregoing is true and correct to the best of my knowlege. 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 Date: 06/14/95 Page: 1 ARCO Alaska Inc. DAILY DRILLING REPORT REMEDIAL AND COMPLETION OPERATIONS RECEIVED JUN 2 1 1995 Alaska Oil & Gas Cons. Commission Anchora~-e WELL: lB-10 WELLID: 998376 AREA/CNTY: FIELD: SPUD: RIG:NORDIC WI: 0% SECURITY:0 AFE: *998376 TYPE:WOC AFE EST:$ 0M/ 0M STATE: API NUMBER: START COMP: FINAL: 05/08/95 ( 1) TD: 9400' PB: 9271' SUPV: DEB/DCM 05/09/95 ( 2) TD: 9400' PB: 9271' SUPV: DEB/DCM 05/10/95 (3) TD: 9400' PB: 9271' SUPV:DB 05/11/95 ( 4) TD: 9400' PB: 9271 ' SUPV: DB 05/12/95 ( 5) TD: 9400' PB: 9271' SUPV: DB 05/13/95 (6) TD: 9400' PB: 9271' SUPV:DB 05/14/95 (7) TD: 9400' PB: 9271' SUPV:DB 05/15/95 ( 8) TD: 9400' PB: 9271' SUPV:DB LOAD WELL WITH SEAWATER MW: 8.6 SEAWATER Move rig from 1B-09 to lB-10 and accept rig @ 2100 hrs 5/7/95. Prepare rig. Inject seawater into tubing to perforations to kill well. Shut down and monitored pressures. DAILY:S24,113 CUM:$24,113 ETD:SO EFC:$24,113 MIXING VISC BRINE LCM PIL MW:10.5 NACL/NABR Circulate 200 bbls seawater to kill well. Monitor well. Mix LCM pill. DAILY: $50,949 CUM: $75,062 ETD:SO EFC: $75,062 NU BOPE MW:10.3 NACL/NABR Displace LCM to perfs. Perform squeeze with LCM. Monitor well. ND tree. NU 13-5/8" BOP. DAILY: $36,152 CUM: $111,214 ETD:SO EFC: $111,214 PREP TO PULL TUBING MW:10.3 NACL/NABR NU BOPE. Test BOPE. RIH and spear tbg below hanger. Monitor well. Rig up to pull tubing. DAILY: $35,600 CUM: $146,814 ETD:SO EFC:$146,814 CBU @ 8605' MW:10.3 NACL/NABR POOH w/4-1/2" tbg. Recover 26 control line bands. M/U FTA #1: guide, overshot, jars and DC's. RIH w/3-1/2" DP. Test upper/lower kelly cock. DAILY:S117,593 CUM:$264,407 ETD:SO EFC:$264,407 TIH W/WASHOVER SHOE. MW:10.3 NACL/NABR Continue to fish. Fish tagged at 8664'. DAILY: $30,700 CUM: $295,107 ETD:SO EFC: $295,107 POH W/ PBR SPEAR MW:10.3 NACL/NABR RIH with 3-1/2" DP and tooth style shoe on wash pipe. Tag PBR at 8692', spear inside PBR, could not latch fish. POOH with 3-1/2" DP. DAILY:S7,755 CUM:$302,862 ETD:SO EFC:$302,862 MILL PACKER @ 8700' MW:10.3 NACL/NABR POOH with 3-1/2" DP and BHA. L/D spear, found in release position, not functioning. RIH w/ spear type B and DP t/8673'. POOH with DP, BHA. L/D fish and spear. Top of PBR Date: 06/14/95 Page: 2 ARCO Alaska Inc. DAILY DRILLING REPORT split, groove cut through 2+ ft, laid to low side. RIH with BHA. Tag pkr @ 8699', mill on packer. DAILY:SO CUM:$302,862 ETD:SO EFC:$302,862 05/16/95 (9) TD: 9400' PB: 9043' SUPV:DB BREAKOUT FTA#4 MW:10.3 NACL/NABR Mill on packer @ 8702'. POOH w/packer and tbg tail. Packer hung up at 6970'. Break out fishing tools, L/D fish, recovered all. DAILY:SO CUM:$302,862 ETD:SO EFC:$302,862 05/17/95 (10) TD: 9400' PB: 9043' SUPV:DRM RIG UP TO SQUEEZE "A" SAN MW:10.3 NACL/NABR Cleaned out fish and fishing tools. Run in hole with cleanout assy. Run in hole with Baker K-1 cement retainer to cement 'A' sand perfs. Squeeze. DAILY:SO CUM:$302,862 ETD:SO EFC:$302,862 05/18/95 (11) TD: 9400' PB: 9027' SUPV:DRM CIRCULATE AT 9027' 954:10.3 NACL/NABR Squeezed "A" sand perforations. Test BOPE. DAILY:S64,760 CUM:$367,622 ETD:SO EFC: $367,622 05/19/95 (12) TD: 9400' PB: 9027' SUPV:DRM POOH LAYING DOWN 3-1/2" D MW:10.3 NACL/NABR Circulate and condition mud at 9027'. Nipple down and Nipple down flow line and riser. Pressure test annular preventer. Clean out string and BHA %7. DAILY:S30,700 CUM:$398,322 ETD:SO EFC:$398,322 05/20/95 (13) TD: 9400' PB: 9027' SUPV:DRM 9-5/8" @ 9358' MW:10.3 NACL/NABR Run in hole with permanent packer and tail pipe assy. Run in hole with completion assy. DAILY: $82,966 CUM: $481,288 ETD:SO EFC:$481,288 05/21/95 (14) TD: 9400' PB: 9027' SUPV:DRM POOH WITH HALLIBURTON W/L MW:10.3 NACL/NABR Run in hole with completion assembly. Set Baker "FH" Ret. Packer. Pressure test tubing. Test SSSV. DAILY:S41,862 CUM:$523,150 ETD:SO EFC:$523,150 05/22/95 (15) SEAWATER/DIESEL TD: 9400' PB: 9027' SUPV:DRM RIG RELEASED MW: 8.5 Nipple up XMAS tree and test. Freeze protect well down 4-1/2" x 9-5/8" ann. Shut in well. Released rig at 2300 hfs 5/21/1995. DAILY:S206,177 CUM:$729,327 ETD:SO EFC:$729,327 End of WellSummary for We11:998376 RI CEIV£1) JUN 2 1 1995 Oil & Gas Cons. Commission Anchor~,;e ARCO (i=aska, Inc. Kuparuk Operations Post Office Box 196105 Anchorage, Alaska 99519-6105 Mark E. Eck Wells Superintendent Kuparuk Production NSK-69 Phone: 659-7226 Fax: 659-7314 March 5, 1995 Mr. David W. Johnston, Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Johnston: Attached in triplicate is an Application for Sundry Approvals (Form 10-403) and in duplicate are multiple Reports of Sundry Well Operations (Form 10- 404) on the following Kuparuk wells. Well Form Action, 1 B- 10 10-404 (Other) Communication 1 B-14 10-404 Stimulate 1 B- 15 10-404 Perforate 1 B- 18 10-404 Stimulate 1F-03 10-403 Variance 3F-02 10-404 Stimulate 3G- 13 10-404 (Other) Conversion If you have any questions, please call me at 659-7226. '¢~_., ~.~'. ~(.,V__. M. E. Eck Attachments Well Files (attach only) File: FTR112996 (w/o attach) RECEIV D ~,PR -6 '1995 ~.~.~a u~l & Gas Cons. Com~sslo~ Anchorage ARCO Alaska. Inc. is a Subsidiary of Atlantic Richfield Company STATE OF ALASKA (" ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Operation Shutdown__ Stimulate Plugging Pull tubing Alter casing Repair well Perforate Other X 2. Name of Operator ARCO Alaska, Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510 4. Location of well at surface 5. Type of Well: Development X Exploratory _ Stratigraphic _ Service 494' FNL, 1302' FEL, Sec. 9, T11N, R10E, UM At top of productive interval 882' FNL, 1144' FWL, Sec. 3, T11N, R10E, UM At effective depth 720' FNL, 1283' FWL, Sec. 3, T11N, R10E, UM At total depth 697' FNL, 1338' FWL, Sec. 3, T11N, R10E, UM 12. Present well condition summary Total Depth: measured 9 4 0 0 feet true vertical 6872 feet 6. Datum elevation (DF or KB) RKB 98 7. Unit or ProPerty name Kuparuk River Unit 8. Well number 1B-10 9. Permit number/approval number 81-135/94-:317 10. APl number 50-029-20656 11. Field/Pool Kuparuk River Field/Oil Pool feet Plugs (measured) None Effective depth: measured 9271 feet true vertical 6757 feet Junk (measured) None 13. Casing Length Size Structural Conductor 8 0' 1 6" Surface 2 5 0 8 9 5/8" Intermediate Production 9322' 7" Liner Perforation depth: measured 8818'-8870', true vertical 6350'-6396', Tubing (size, grade, and measured depth) 4.5", 12.6#/ft., J-55 @ 8627', 4.5", Packers and SSSV (type and measured depth) Cemented Measured depth True vertical depth 280 Sx PF 80' 80' 1600 Sx Fondu & 2547' 2272' 400 Sx AS II 750 Sx Prem. G 9358' 6837' 89591-8979', 6476'-6493', 9128'-9138', 9146'-9178' 6627'-6636', 6643'-6673' 12.6 #/ft., L-80 @ 8627'-9098' RECEIVED APR -6 1995 Alaska 0il & Gas Cons. Commis,, Anchorage PKR: Baker SAB @ 8697' & Baker FB-1 @ 9058'; SSSV: Camco TRDP-1A @ 1935' Stimulation or cement squeeze summary Communication will be repaired w/workover scheduled for 5/95. Form 407 will be subsequently submitted Intervals treated (measured) Treatment description including volumes used and final pressure 14. ReDresentative Daily Average Production or In!ection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 853 3613 1990 974 121 SubSequent to operation 2 6 3 3 1357 1478 15. Attachments 16. Status of well classification as: Copies of Logs and Surveys run __ Daily Report of Well Operations m Oil X Gas Suspended 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. 870 140' Service Form 10-404 Rev 06/15/88 Title Wells Superintendent Date ~::~/~"/~ ~ SUBMIT IN DUPLICATE STATE OF ALASKA SKA Oil AND GAS CONSERVATION COMI~~' ,ION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Operation Shutdown~ Stimulate~ Plugging ~ Perforate~ Pull tubing Alter casing Repair well Other X 2. Name of Operator ARCO Alaska, Inc. 3. Address P. O. Box 1 00360, Anchorage, AK 99510 4. Location of well at surface S. Type of Well: Development Stratigraphic __ Service 494' FNL, 1302' FEL, Sec. 9, T11 N, R10E, UM At top of productive interval 882' FNL, 1144' FWL, Sec. 3, T11 N, RI OE, UM At effective depth 720' FNL, 1283' FWL, Sec. 3, T11 N, R10E, UM At total depth 697' FNLr 1338' FWL~ Sec. 3~ T11 Ny R10Ep UM 12. Present well condition summary Total Depth: measured 9400 feet true vertical 6872 feet 6. Datum elevation (DF or KB) RKB 98 7. Unit or Property name Kuparuk River Unit 8. Well number 1B-10 9. Permit number/approval number 81-135/94-317 10. APl number 50-029-20656 11. Field/Pool Kuparuk River Field/Oil Pool feet Plugs (measured) None Effective depth: measured 9271 feet true vertical 6757 feet Junk (measured) None Casing Length Size Structural Conductor 80' 1 6" Surface 2508 9 5/8" Intermediate Production 9322' 7" Liner Perforation depth: measured 8818'-8870', true vertical Cemented 280 Sx PF 1600 Sx Fondu & 400 Sx AS II 750 Sx Prem. G 8959'-8979', 6476'-6493', 9128'-9138', 6627'-6636', Measured depth 80' 2547' 9358' 9146'-9178' 6643'-6673' True vertical depth 80' 2272' 6837' 6350'-6396', Tubing (size, grade, and measured depth) 4.5", 12.6#/ft., J-55 @ 8627', 4.5", 12.6 #/ft., L-80 @ 8627'-9098' Packers and SSSV (type and measured depth) PKR: Baker SAB @ 8697' & Baker FB-1 @ 9058'i SSSV: Camco TRDP-1A @ 1935' 13. Stimulation or cement squeeze summary Intervals treated (measured) Treatment description including volumes used and final pressure REC'EiV U JAN 30 1995 14. ,, t,._ ~t~l vv. .............. Representative Daily Average Production or Injection Dat~ Al~r~ '," ~-- ~'= ~'~"~ nnmmt~ln Prior to well operation OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure 2639 1334 4836 1000 At~{~ressure Subsequent to operation 1 256 1456 5704 15. Attachments 16. Status of well classification as: CoPies of Logs and Surveys run~ Daily Report of Well Operations X Oil X Ga_~ Suspended 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. 1000 Service 225 230 Signed ~/-/J~ Form 10-404 ~Re~P'06/~'5/88 Title Wells Superintendent Date 1/;)8/95 SUBMIT IN DUPLICATE ARCO Alaska, Inc. Kuparuk Operations Post Office Box 196105 Anchorage, Alaska 99519-6105 Telephone 907 859 2821 November 29, 1994 Mr. David W. Johnston, Chairman Alaska Oi! and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Johnston: Attached in triplicate are multiple Applicaton for.Sundry Approvals (Form 10-403) on the following KuparUk wells. Well Action 1B-10 1Q-14 2K-06 3G-13 Other (Communication) Other (Inj Valve) Other (Inj Valve) Other (Conversion) If you have any questions, please call me at 659-7226. Sincerely, M. E. Eck Wells Superintendent Kuparuk Production Engineering Attachments Well Files (attach only) File: FTR112996 (w/o attach) RECEIVED DEC - 1 1994 Alaska 0il & Gas Cons. Commission Anchorc..~s ARCO Alaska. Inc. is a Subsidiary of Atlantic Richfield Company STATE OF ALASKA ( ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon w Suspend __ Alter casing __ Repair well Change approved program __ Operation Shutdown m Re-enter suspended well __ _ Plugging m Time extension _ Stimulate_ Pull tubing __ Variance .X Perforate __ Other 2. Name of Operator !ARCO Alaska, Inc. 3. Address P. O. Box 100360, Anchorage, AK, 99510 4. Location of well at surface 5. Type of Well: Development X Exploratory _ Stratigraphic __ Service m 494' FNL, 1302' FEL, Sec. 9, T11N, R10E, UM At top of productive interval 882' FNL, 1144' FWL, Sec. 3, T11N, R10E, UM At effective depth 720' FNL, 1283' FWL, Sec. 3, T11N, R10E, UM At total depth 697' FNL, 1338' FWL, Sec. 3, T11N, R10E, UM 12. Present well condition summary Total Depth: measured 9400 feet true vertical 6872 feet Plugs (measured) Effective depth: measured true vertical 9271 feet Junk (measured) 6757 feet Casing Length Structural Conductor 8 0' Surface 2 5 0 8 Intermediate Production 93 2 2' Liner Perforation depth: measured 8818'-8870', true vertical 6350'-6396', Size Cemented 1 6" 280 Sx PF 9 5/8" 1600SxFondu& 400 Sx AS II 7" 750 Sx Prem. G 8959'-8979', 6476'-6493', 9128'-9138', 6627'-6636', L-80 @ 8627'-9098' 6. Datum elevation (DF or KB) RKB 98 feet 7. Unit or Property name Kuparuk River Unit 8. Well number 1B-10 9. Permit number 81-135 10. APl number 5_0 -029-20658 11. Field/Pool Kuparuk River F_ieJd/O~l, ~ool None RECt;~V ~1 DEC - 1 1994 None A ska Oik & Gas Cons. Commission Anchorc ~.:~ Measured depth True vertical depth 80' 80' 2547' 2272' 9358' 6837. 9146'-9178' . ',. 6643'-6673' Tubing (size, grade, and measured depth) 4.5", 12.6#/ft., J-55 @ 8627', 4.5", 12.6 #/ft., Packers and SSSV (type and measured depth) PKR: Baker SAB @ 8697' & Baker FB-1 @ 9058'; SSSV: Camco TRDP-1A @ 1935' Description summary of proposal ~X Detailed operation program _ 13. Attachments BOP sketch 14.' Estimated date ior commencing operation November 17, 1994 16. If proPosal was verbally approved Name of approver B. Wondzell Date approved 11/17/94 ,i 15. Status of well classification as: Oil X Gas Service Suspended ,, 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed~'~~ ~ ~' Title....Wells Superintendent FoR COMMISSION USE ONLY Date Conditions of approval: Notify Commission so representative may witness Plug integrity BOP Test Mechanical Integrity Test m Approved by ,order of the Commission Form 10-403 Rev 06/15/88 IApproval No.._ _ Location clearance __ I Subsequent form require lO- Approved Copy Original Signed By Returned David W. Johnston_ ~omm[ssioner uate SUBMIT IN TRIPLICATE Attachment 1 Application for Sundry Approval Kuparuk River Unit Well 1B-10 As a follOw-up to verbal approval granted by the AOGCC on 11/17/94, ARCO Alaska, Inc. requests a variance to the production equipment requirement of AOGCC 20AAC25.200(d) for production Well 1B-10. This well has a 3/4" diameter hole in the production tubing at 3700' WLM resulting from an unsuccessful attempt to set a Kinley insert orifice valve. This hole does not allow isolation of the tubing-casing annulus from produced fluids as required by 20AAC25.200(d), however, as long as Well lB- 10's production casing has integrity, reservoir fluids will be confined within the wellbore allowing the well to be safely produced. To prove Well 1B-10's production casing is competent, the tubing-production casing annulus will be pressure-tested at the earliest convenience. Additionally, Well 1B-10 is being evaluated for a potential workover in 1995 for reservoir management reasons unrelated to the leak. If a workover.is pursued, the leaking joint of tubing obviously will be replaced. : A Report of Sundry Well Operations will be submitted stating the results of the above mentioned pressure-test once it has been completed. !' . '). '; ~AI~ASKA STATE OF ALASKA · OILAND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1, Operations Performed: Operation Shutdown Pull tubing ~ Alter casing '5, 2, Name of Operator ARCO Alaska. Inc. 3, Address P. O. Box 100360, Anchorage, AK 99510 Stimulate Plugging~ Perforate X Repair well Other Type of Well: Development Exploratory Stratigraphic Service 6, Datum elevation (DF or KB) RKB 98 feet 7, Unit or Property name Kuparuk River Unit _ 4. Location of well at surface 8, 494' FNL, 1302' FEL, Sec. 9, T11N, R10E, UM o. : 882' FNL, 1144' FWL, Sec. 3, T11N, R10E, At effective depth 720' FNL, 1283' FWL, Sec. 3, T11N, R10E, At total depth 697' FNLr 133,8' FWL~ Sec. 3~ T11Nr R10E,~ UM 12, Present well condition summary Total Depth: measured 9 4 0 0 feet Plugs (measured) true vertical 6872 feet Well number 1B-10 9, Permit number/approval number 81-135 10. APl number 50-029-22656 11. Field/Pool Kuparuk River Field/Oil Po,,ol Effective depth: measured 9 2 71 feet Junk (measured) NOlle true vertical 6757 feet Casing Length Size Cemented Structural Conductor 8 0' 1 6" 280 SX PF Surface 2508 9 5/8" 1600 Sx Fondu & Intermediate 400 SX AS II Production 9322' 7" 750 Sx Prem. G Liner Perforation depth: measured 8818'-8870', 8959'-8979', 9128'-9138', true vertical 6350'-6396', 6476'-6493', 6627'-6636', Measureddepth Trueverticaldepth 80' 80' 2547' 2272' 9358' 6837' 9146'-9178' 6643'-6673' Tubing (size, grade, and measured depth) 4.5", 12.6#/ft., J-55 @ 8627', 4.5", 12.6 #/ft., L-80 @ 8627'-9098' Packers and SSSV (type and measured depth) PKR: Baker SAB @ 8697' & Baker FB-1 @ 9058'; SSSV: Camco TRDP-1A @ 1R,3~' ~, r- ! t t r' I~, 13.. Stimui'ation or cement squeeze summary '~,r' ~ ~ ~ v ~ ~/ Perforated 'C1' sand on 4/17/94 @ 6 spf & 60° phasing. Intervals treated(measured) MAY 2 ;5 1994 8959'-8979' Treatment description including volumes used and final pressure /.~I~SK~ U~i & Gas Cons. Commission N/A An~.hnr~n~ 14, Representative Daily Avera_ae Production or Iniection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure . Tubing Pressure Prior to well operation Subsequent to operation 1660 1111 3083 620 250 2 0 7 9 ~'/'~'''''' 1135 3696 620 200 15, Attachments Copies of Logs and Surveys run Daily Report of Well Operations X 16. Status of well classification as: Oil X Gas~ Suspended ~ Service 17. I hereby c/~rtify that the foregoing is true and correct to the best of my knowledge. ISi~lned ' Title Senior Engineer Form 10-404 Rev 06/15/88 SUBMIT IN DUPLICATE ARCO Alaska, Inc. KUPARUK RIVER UNIT ............ . .... ::: ..... ,.: ::g::WELL SERVICE REPORT WELL ..- lB-10 -' R~r:~,'~ 'C.I' CONTRACTOR/KEY PERSON DATE . _. DAY TIME "' OPERATION AT REPORT. TIME .......... E] COMPLETE LOG ENTRY ..~.. J FIELD EST: .......... $ 't ~/~, 54 .......... ,, PAGE 1 OF AFC/CC 25oDsloBb ACCUMULATED COST-- $ 2°, 330. I'-! CHECK THIS BLOCKIF SUMMARYCONTINUED ON BACK ........ We'"h°r ':-I'T°mP'-Report....... ;'~'1ch"' F==t°r' v'`'b'''."F%d-e;''' I W'ndV°~n';~"! AR3B-7031 . _ . ;.: 298-3486 :-U .. REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Operation Shutdown Stimulate m Plugging Perforate Pull tubing .......... Alter casing ,, , Repair well Other X 2. Name of Operator ARCO Alaska. Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510 5. Type of Well: Development ~ Exploratory _ Stratigraphic Service _.~ !4. Location of well at surface 494' FNL, 1302' FEL, Sec. 9, T11N, R10E, UM At top of productive interval 882' FNL, 1144' FWL, Sec. 3, T11N, R10E, UM At effective depth 720' FNL, 1283' FWL, Sec. 3, T11N, R10E, UM At total depth 697' FNL, 1338' FWL~ Sec. 3~ T11N, R10E, UM 12. Present well condition summary Total Depth: measured 9 4 0 0' feet true vertical 6872' feet Plugs (measured) 6. Datum elevation (DF or KB) RKB 9~' 7. Unit or Property name Kuparuk River Unit feet 8. Well number 1B-10 9. Permit number/approval number 81-135 10. APl number 50-029-20656 11. Field/Pool ,, Kuparuk River Oil Pool Effective depth: measured 9 2 71 ' feet true vertical 6757 feet Junk (measured) None Casing Length Size Structural Conductor 8 0' 2 0" Surface 2547' 13 3/8" Intermediate Production 935 8' 9 5/8" Liner Perforation depth: measured 8818'-8870', true vertical 6350'-6396', Cemented Measured depth True vertical depth 280 Sx Permafrost 80' 80' 1600 Sx Fondue & 2547' 2272' 400 Sc AS II 2115 Sx Class G 9358' 6837' 9128'-9138', 6627'-6636', 9146'-9178' 6643'-6673' Tubing. (size, grade, and measured depth) 4 1/2" N-80, TT @ 9098' Packers and SSSV (type and measured depth) Baker packers SAB @ 8697' and FB-1 @ 9058', Camco TRDP, lA,, @ 1935' Stimulation or cement squeeze summary REEEIVED DEC 11 1990 Alaska Oil & Gas Cons. Comm~ss~ Anchorage Intervals treated (measured) Treatment description including volumes used and final pressure 14. Prior to well operation Subsequent to operation Representative Daily Average Production or In!ection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure -0- -0- -0- 1900 -0- -0- -0- 1900 Tubing Pressure 2400 240O !15. Attachments Copies of Logs and Surveys run -- Daily Report of Well Operations m 16. Status of well classification as: Water Injector _ Oil X Gas Suspended ~ Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Form 10-404 Rev 09/12/90 SUBMIT IN DUPLICATE J .;~*,A STATE OF ALASKA MI~ " OILAND GAS C(~SERVATION COM ~ ION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon _ Suspend _ Alter casing _ Repair well Change approved program ._.X_ Operation Shutdown _ Re-enter suspended well _ _ Plugging _ Time extension _ Stimulate _ Pull tubing _ Variance _ Perforate _ Other 2. Name of Operator ARCO Alaska. Irl(~, !3. Address P. O. Box 100360, Anchorage, AK 99510 4. Location of well at surface 494' FNL, 1302' FEL, Sec. 9, T11N, R10E, UM At top of productive interval 882' FNL, 1144' FWL, Sec. 3, T11N, R10E, At effective depth 720' FNL, 1283' FWL, Sec. 3, T11N, R10E, At total depth 697' FNL, 1338' FWL, Sec. 3~ T11N, R10E, 12. Present well condition summary Total Depth: measured 94 0 true vertical 687 Effective depth: measured 9 2 7 true vertical 675 5. Type of Well: Development X Exploratory _ Stratigraphic _ Service UM UM UM 0' 2' 1' 7' feet Plugs (measured) feet feet Junk (measured) feet None 6. Datum elevation (DF or KB) RKB 9t~' feet 7. Unit or Property name Kuparuk River Unit 8. Well number 1B-10 9. Permit number 81-135 10. APl number 5o-029-20656 11. Field/Pool Kuparuk River Field Kuparuk River Oil Pool 14. 16. Casing Length Size Structural Conductor 8 0' 2 0" Surface 2 5 4 7' 13 3/8" Intermediate Production 935 8' 9 5/8" Liner Perforation depth: measured 8818'-8870', Cemented Measured depth True vertical depth 280 Sx Permafrost 80' 80' 1600 Sx Fondue & 2547' 2272' 400 Sx AS II 2115 Sx Class G 9358' 6837' 9128'-9138', 9146'-9178' true vertical 6350'-6396', 6627'-6636', 6643'-6673' Tubing (size, grade, and measured depth 4 1/2" N-80, TT @ 9098' Packers and SSSV (type and measured depth) Baker packers SAB @,,8697' and FB-1 ~ 9058'r Camco TRDP 1A~ 19,35' Attachments Description summary of proposal _ Detailed operation program _ ProPose converting well from gas injector to oil producer. Estimated date for commencing operation 15. September. 1990 If proposal was verbally approved Name of approver Date approved Service RECEIVED Alaska Oil & Gas Cons. 0mmiss[0n chora BOP sketch Status of well classification as: Oil X Gas _ Suspended _ 17. I here~,, certify that the foregoing is true and correct to the best of my knowledge. Signed · Title FOR COMMISSION USE'ONLY conditions of approval: Notify Commission so representative may witness Plug integrity __ BOP Test ~ Location clearance__ Mechanical Integrity Test u Subsequent form require APproved by the order Commission Form 10-403 Rev 5/03/89 ORIGINAL SIGNED BY LONNIE C. SMITH 10-'¢¢¢¢ OO~'~ IAppr°~J~~ ~ 9~o~e6 6 Commissioner Date ~'~ -e~ SUBMIT IN TRIPLICATE ARCO Alaska, Inc..~.. Post Office 360 Anchorage./~',~ska 99510 Telephone 907 277 5637 November 22, 1982 C. V. Chatterton Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Dear Mr. Chatterton: Please find attached the well completion reports for the following producing/injecting wells: 1B-9GI 1H-3 1B-10GI 1H-4 1B-11GI 1H-6 1E-11 1H-7 1E-14 1H-8 1E-15 Very truly yours, Area Operations Engineer slz Attachment cc: L. M. Sellers E. A. Simonsen R. L. Stramp H. C. Vickers AN0-332 w/attachments AFA-311 w/attachments AST-308 w/attachments AFA-326 w/o attachments REEEI ,ED DEC 0 J[982 . . STATE OF ALASKA ALASKA O(' %ND GAS CONSERVATION CO( IlSSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG - , . 1. Status of Well Classification of Service Well , OIL [] X GAS [] SUSPENDED [] ABANDONED [] SERVICE [] 2. Name of Operator 7. Permit Number ARCO Alaska, Inc. 81-135 ,, 3. Address 8. APl Number P.0.Box 360, Anchorage, AK 99510 so- 029-20656 . , 4. Location of well at surface 49/4' i. NL, 13UZ' ~ EL, 5cc 9, I 1 1N, l'(1 Ul- , UH 9. Unit or Lease Name Kuparuk River Unit At mop Producing lnterval 882I FNL, 1144' FWL, Sec 3, TllN, Rt0E, UM 10. WellNumber - 1B-10GI At motal Depth 697' FNL, 1338' FWL, Sec 3, T11N, R10E, UH 11.FieldandPool Kuparuk River Field 5. Elevation~indicate KB, DF, etc.) 6. Lease Designation and Serial No. ADL 25648 ALK 466 Kuparuk River Oil Pool 12. DateSp~;J~cr 13. DateT.D. Reached 14. Date Comp., Susp. orAband. 115. Water Depth, ifoffshore 116. No. of Completions I. 11/14/81 11/30/81 12/13/81 -- feet MSL 1 .17. Total Depth (MD+TVD) 18.Plug Back Depth (MD+TVD 19. Directional Survey I 20. Depth where SSSV set 21. Thickness of Permafrost 9400' 6872' 9271 ' 6757' YES f-IX NO[]I 1935' feet MD 1650' (approx) 22. Type Electric or Other Logs Run DIL/SP/GR/BHC.S, .FDC/CNL/GR/Cal, CBL./VDL/CCL/Cal 2~. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING ~ECORD AMOUNT PULLED 20" 91.5# H-40 .Sur. f 80' 3'0" 280 sx AS II 13 3/8"i 72# ...L-80 . Surf 2547' 17 1/2' 1600sx Fondu, & 400 sx AS II 9 5/8 47~t L-80 Surf .9358'~. 12 1/4 , 21.15 .sx Class .g Celnent _ ,. , 24. Perforations open to Production (MD+TVD of Top and, Bottom and 25. TUBIN~ RECORD '" interval, size and number) SiZE DEPTH SET (MD) PACKER SET (MD) 88i_i~-8830' ' 4 1/2" 9098' ' 9058' 8830-8850 ' 8850-8870' 26. ACID, FRACTURE, CEI~ENT SQUEEZE~ ETC'. 9128-9138' . "'DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERI/~L USED · , 9146-9158 ' , , · 9158-~' w/4 spf - : - ..-- , 27.' PRODUCl;IOI~ TEST .... Date First Production ~1 Method of Operation (F!owing, gas lift, etc.) . . . " I ., N/A Completed as gas .injector Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE I GAS-OIL'RATIO · 12/23/8~1 . 32,5 TEST PERIOD I1~ 3413 ~ ,. 1433. · 853.. 64/64I 420 ,... Flow T. ubing Casing Pressure CALCULATED I~ OIL'BBL '" GAS-MCF. WATER-BBL OIL GRAVITY-APl (corr) 'Press.' 225 --' 24'HouR RATE"~ I . 2520 1058 ~ ,630 , -- '28. CORE DATA ...... , ,, 'fBrief description of lithology, porosity, fractures, apparen't dips and presence of oil, gas or water. Submit core chips. N/A -. , .- · · .. · .~._'3. -{. .... Form 10-407 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE 29. 30. GEOLOGIC MARKERS FORMATION TESTS -. NAME ... Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. Top Kuparuk River Form. 8785' 6321 ' N/A Base Kuparuk River Form. 9234' 6724' 31; LIST OF ATTACHMENTS 32. I hereby certify that the foregoing is true and correct to the best of my knowledge r--'., c;i~inai Signed Area 0ps. Engr. t NOV 2.~ 1982 Signed. { ~y J. 5. DAYTON Title Dat~ 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 fromground 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". KUPARUK ENGINEERING TO: TRANSMITTAL # /~ / · Bose/Lorie L. Johnson Transmitted herewith are the following: PLEASE NOTE: BL - BLUELINE, S - SEPIA, F - FILM, T - TAPE RECEIPT ACKNOWLEDGED: .~~LEASE RETURN RECEIPT TO: DATE: ARCO ALASKA, INC. ~;'"' ''~''~' '"'~ ATTN: LORIE L. JOHNSON - AFA/311 P. O. BOX 360 ANCHORAGE, AK 99510 ARCO Alaska, Inc Post Office x 36() Anchorage. Alaska 99510 Telephone 907 277 5637 February 19, 1982 ~.~r. C. V. Q~atterton State of Alaska Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99510 Subject' State Reports Dear Sir' Enclosed please find the up-dated Completion Reports for drill sites- 11-3, 11-5, 13-8, 13-10, 14-12, 15-13, 15-14, IA-10, IA-ii, B-6, B-9GI,.B~10GI and West Sak #18. The gyro-multishot surveys enclosed are from drill sites 12-4A, 13-19, 14-12, 14-26, 15-14 and 15-15. The original gyro-multishot surveys for drill sites 11-1, 12-14, 13-6, 13-9, 14-13 and 16-1 were un- satisfactory and are scheduled to be re-~un. Information to be submitted on the corresponding completion, along with the accept- able survey, will be forwarded to your office when we receive them. Also included are subsequent sundries for drill sites 14-9A, 14~18, and 15-10, along with a Sundry of Intent to plug and abandon Kavik #1. Sincere ly, M. A, ~jor Area Drilling Engineer Enclosures ~/GLA' s s _. STATE OF ALASKA ALASKA('i~ AND GAS CONSERVATION C~ .,'MISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG r -1. Status o.f Well Classification of Service Well OIL [~ GAS [] SUSPENDED [] ABANDONED [] . SERVICE [] 2. Name of Operator 7. Permit Number ARCO Alaska, Inc. 81-135 3. Address 8. APl Number P. O. Box 360, Anchorage, Alaska 99510 50-029-20656 4. Location of well at surface 9. Unit or Lease Name 494' FNL 1302 FEL, Sec 9 TllN, R10E, k~c T~ONSi Kuparuk 25648 At Top Producing Interval VERIFIED 10. Well Number 923' FNL, 1111 FWL, Sec. 3, TllN, R10E, t~. E B-10GI At Total Depth I~. H.~ 11. Field and Pool 697' FNL, 1338 FWL, Sec. 3~ TllN, R10E, LM L Kuparuk River Field 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. Kupaz~k Oil Pool ~ J~' RKBI ADL 25648 ALL 466 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Suspl or Aband. 15. Water Depth, if offshore 116. No. of Completions 11/14/81 11/30/81 12/13/81 feet MSLI 1 17. Total Depth (MD+TVD) 18.Plug Back Depth(MD+TVD) 19. Directional Survey 20. Depth where SSSV set I 21. Thickness of PermafroSt )400'MD 6872'TVD 9271'MD, 6757'T~I YES [] NO [] 193~eetMDI 1650' (approx.) 9 · 22. Type E.'lectrjc or.Other Logs Run . . . DIL/SP/GR/BHCS FDC/CNL/GR/Cal CBL/VDL/CCL/Cal 23. CASING, LINER AND CEMENTING RECORD , SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLESIZE CEMENTING RECORD AMOUNT PULLED 20" 91 5# H-40 ' Surf. .8'0' ' 30" 280 sx A.S. II . 13-3/8" ~72# L-80 Surf. 25_.47 17~" 1600 sx Fondu & 400 sx A.S. II ' 9-5/8" 47# L.80" Surf.' 9_3~._5/87 127' 2115 sx Class "G" ~ement . , 24. Perforati..onsopentoPr°duction (MD+TVD of Top and Bottom and . . 25. TUBING RECORD in,terval., size and number) sIZE DEPTH SET (MD) PACKER SET (MD) 4½" 9098 ' 9'058 8818' - 8830' 8830' - 8850' 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. 8850' - 88~..0' DEPTH INTERVAL (MD) AMOUNT& KINDOF MATERIAL USED 9128' - 91'38' w/4 spf 9146' - 9158' 9158 ' 9178' . ; · . ~ .:'. . . ., :. ,.. ~ . 27. ' ~ ' ~)RODucTIoN TES~- ' ' Date ~i,rst .... Production,. ~ . .,.. . [Method. of Operation~ . (Flowing,,.., gas lift,., etc.) · N/A' Date of Test Hours Tested PRODUCTION FOR OI L-BBL GAS-MCF WATER-BBL CHOKE SIZE GAS-OIL RATIO ...... TEST PERIOD. I~ :. Flow Tubing "'CasingP, ressure'. CALCULATED OIE-BBL " GAS-MCF WATER-BBL , OIL GRAVITY-APl (corr) 'Press. i · 'l 24-HOUR RATE I1~ ' . . 28. CORE DATA '" Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips.' ECEIVED ~ , ' ' ' r " " ' " '_Naska Oil & Gas cons. Com.rn/ss/Oi~ ' ~chorags ,. Form 10-407 Rev. 7-1-80 CONTINUED ON REVERSE SIDE submit in duplicate ,, 29. 30.. GEOLOGIC MARKERS FORMATION TESTS NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. Top Kuparuk 8671 ' 6220 ' Base Kuparuk 9234 ' 6724 ' 31. LIST OF ATTACHMENTS 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Title 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 ARC° Alaska, Inc. Post Office B( ,30 Anchorage. Alaska 99510 Telephone C~07 277 5637 February 9, 1982 Mr. Lonnie Smith State of Alaska A1 aska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Subject' Gyroscopic Surveys Dear S'ir' Enclosed please find the completed Gyroscopid Surveys for Drill Sites 11-3, 11-5, 12-8B, 13-10, 15-12, 15-13, 1A-11, 1A-12, B-9GI and~B'lOGI. Also included are the completion reports for Drill Sites 1A-10, 1A-11, B-gGI and B-lOG1''' Sincerely, P. A. VanDusen District Drilling Engineer PAV'GA'ltc ARCO Alaska. If~c is ;~ S~jl:.~.~di;~V of Atl~nlicRichfieldCompa~'~y ALASKA ,:ANDGAS CONSERVATION C ~ ISSION ~ WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well ' Classification of Service Well OIL [] GAS [] SUSPENDED [] ABANDONED [] sERVICE [] 2. Name of Operator 7. Permit Number ARCO Alas:ka, Inc, 81-135 3. Address 8. APl Number P. O. Box 360, Anchorage, Alaska 99510 5o-029-20656 4. Location of well at surface 9. Unit or Lease Name 494' FNL 1302' FF.L Sec 9, TllN, R10E, UM Kuparuk 25648 At Top Producing Interval 10. Well Number T O B E S U B M I T T E D. ~'~' B-10GI /.in'fO r¢~¢t'v'~¢~ t/e¢~l/¥ .~,,~ ~,,1~1¢6 ',~1' Fieldand Pool At Total Depth T 0 B E S U B M I T T E D. ~(~97/F~,/L, /3~8/F~Z...~ec $ Kuparuk River Field 5. Elevation in feet (indicate KB, DF, etc.) ] 6. Lease Designation and Serial No. Kuparu:k 0il Pool 93' RKBI ADL 25648 ALL 466 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. 15. Water Depth, if offshore 116. No. of Completions 11/14/81 11/30/81 12/13/81 ...... feet MSLI 1 17. Total Depth (MD+TVD) 18.Plug Back Depth {MD+TVDI 19. Directional Survey 20. Depth where SSSV set 21. Thickness of Permafro.~t 9400 MD ¢¢7; 9271' MD YES~ NO[] 1935 feetMD 1650' (approx.) , 22. Type Electric or Other Logs Run DIL/SP/GR/BHCS FDC/CNL/GR/Cal CBL/VDL/CCL/Cal 23. CASING, LINER AND CEMENTING RECORD · SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED ,, 20" 91.5# H-40 Surf. 80' 3'0" 280sx A.S. II 13-3/8" 72# L-80 Surf. 2547 17~" 1600sx Fondu & 400s~: A.S. II" ' 9-5/8" 47# L-80 Surf 9358 1~,_',, 2115sx Class "G" ce~lent · ~' 4,. '. ., ., 24. Perforations open to Production (MD+TVD of Top and Bottom and 2.5. TUBING RECORD · interval, size.and number) SIZE DEPTH SET (MD) PACKER SET (MD) 8818' - 8830' 4~" 9098' 9058' 8830' - 8850' ,!. ' · 8850' - 8870' 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT& KIND OF MATERIAL usED 9128:! - , , 9146' _ 9158' , · 9158' - 9178' · · , 27. ' PRoDucTioN'-I:EST . Date First Production . ., Method of Operati.on (Flowing, gas .Hft, etc .) ,, .. N/A' '· Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE GAS-OIL RATIO · . TEST PERIOD ][~ ,, . ~ ,.., Flow Tubing Casing Pressure CA:LCULATEDr.~ OiLBBL' GAs.-McF WATER-BBL OIL GRAVITY-APl (corr) ;Press. . ,. 24.H:OuR RATE ~F" ' . 28. ' ', " ...... cORE DATA ,; '-Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. :-,- ;,,,~ . ; , . : : · · Form 10-407 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE 29. 30. I GEOLOGIC MARKERS FORMATION TESTS NAME Include interval tested, pressure data, all fluids recovered and graviz¥, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. T 0 B E S U B M I T T E ]1. N/A 31. LIST OF ATTACHMENTS ...... '32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed. ~/~! ~' ~--/~ Title Sr. Drlg. Eng:r.... Date ~---~-:-'5~'2---- 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- lng and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. item 28' If no cores taken, indicate "none". Form 10-407 B-iOGI Drilling History NU hydril and diverter. Spudded well @ 2330 hrs, 11/14/81. Drld 17-1/2" hole to 2562'. Ran 64 jts 13-3/8" 72#/ft N-80 casing w/shoe @ 2547'. Cemented 13-3/8" ca$~z~g w/1600sx Fondu and 400sx AS II. ND hydril and diverter system. Instld 13-3/8" packoff and tested to 2000 psi - ok. NU BOPE and tested to 3000 psi. Tested casing to 1500 psi - ok. Drld FC and cement. Tested casing to 1500 psi - ok. Drilled FS and 10' new form. Tested form to 12.5 ppg. EMW - ok. Drilled 12-1/4" hole to 9400'TD. Ran DIL/SP/GR/BHCS and FDC/CNL/GR/Cal. Ran 231 jts 9-5/8" 47#/ft L-80 BTC casing w/shoe @ 9358'. Cemented 9-5/8" casing w/2115sx Class "G" cement. Change out packing and tested to 3000 psi - ok Arctic Packed 9-5/8" x 13-3/8" annulus w/lO0 bbl H20' 300sx AS II and 12~ bbl Arctic Pack. Ran ~o from surf. to 9250'. Ran CBL/VDL/CCL/GR. Tested casing to 2000 psi - bled to 765 psi in 10 min. Set E-Z Drill @ 9075'. Stin§ into E-Z Drill - pressure annulus to 1500 psi and DP to 3000 psi - no leakoff. PU D.P. and st~_~§ back into E-Z Drill - pressure annulus to 1500 psi and D.P. to 3500 psi - no leakoff. PU 3-1/2" D.P., RIH and drill up E-Z Drill. Ran CBL/VDL/CCL/GR fr/9230'-7000'. Displaced well to NaC1/NaBr. RIH and perf 4 spf through the following intervals: 9158'-9178', 9146'-9158', 9128'-9138' 8850'-8870', 8830'-8850' and 8818'-8830'. RIH w/wireline and set packer ~ 9057'. RIH with 4-1/2" completion assembly w/tail @ 9098' and hydraulic set packer at 8696'. Stabbed into lower packer. Dropped ball and set packer @ 8696'. Tested tubing to 3000 psi w/no annulus pressure - ok. Attempt to shear soft-shock sub w/4500 psi - no success. Tag SSSV and found closed. Open SSSV and repressurized to 3300 - no indication of sub shearing. Test 4-1/2" x 9-5/8" annulus to 1500 psi - ok. Close SSSV and set BPV in tubing hanger. ND BOPE. NU tree and test to 5000 psi,' Pull BPV and test tree to 5000 psi. RIH and pull dummy through GLM. Displaced well to diesel. Replace dummy. Closed SSSV. Test 4-1/2" x 9-5/8" annulus to 1500 psi - ok. Set BPV. Secured well and released rig at 0600 hrs., 12/13/81. January 22, 1982 Mr. Bob Hines ARCO Alaska, Inc. P. O. Box 360 Anchorage, Alaska 99510 Re: 'Our Boss Gyroscopic Survey Job No. Boss-16933 Well No. B-10 (SEC9 TllN ~R10E) Kuparuk Field North Slope, Alaska Date of Survey: December 4, 1981 Operator: Everett Sellers Dear Mr. Hines: Please find enclosed the "Original.'., and one (1)' copy of our Boss Gyroscopic Multishot Directional Survey on the above well. Thank you for giving us this opportunity to be of service. KA/pr Sincerely, NL SPERRY-SUN, INC. Kirk Afflerbach District Supervisor Enclosures . BOSS 16933 ,: ~;. : ".'~::: ' ........ : ......... : ::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::: ':':':': '::~:::~";';~:":::?:~:~:~'~:':~:;~'::~'~':::~:::':':::?::: :¢¢~;::::~":::'::;:~:;~:::~:'? ~:~::~?f~'~:f~::~:f~:::~:~;~::~:~:~'~;~:~.~'~';:~ ~:~ ~'.: ~'~j F;.} ~.~. ~:': ;~": , ~,:::.'.::;.'-.'~.:.~-~,~};::~:~?.:.'~:~:r:~.~:~:~:.~:.:~::~:~:~::~ ~::'"~.':;'~':'::';'::~' ". t;~:~:;~.~:~;~.~:::~:?~{~.~:~::.~::.:~;~?~:~:.:~:.`.~:~:...~:{~:~.:~::~::~::~.~..:.%~:~::~;~;. ':''.. "':' , ::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::: ..... ::.'. .... ... .....:~:;~:~¢.-.~,,r~X,r,~]~?~ ~.~::.~;~::~,;~;~:~:~:~f~:~:~:?,. ........... ~.~,~,..,.,. ~:'~.':~'...~.::I:k...:;.~:~;~::~.:4~:~',:::~, :.::;4~x .:~:~'.::X.:~:'~.:.,~fi r~',~ x~`.~.)z~.~.:::~.~.:%~.~:x.z~¢.~.:.z~.~.:..*:~:?:~*.:.:4~:::::~..~.~s:.x ;~,,:.~,::.'~'-~,':': .:":~,::~:~.:q~ :~:.:~:.~::.X:.:,x.::.:..:.:..:.:::.:s?,:,.x~:.x.~.:?~:.x.?:.,~:...,.¢~ ~.~:~..x'.x~?~.-.:..:~, r~J.x.~.:-x~-~'.. :~..~. ~? ~...::,:,:.~-~:~'.X...~.:~..:~:: ...:,:.~]:..:.~'<,~.?,~x~.~. ..... -~.~,.~..~,.~:~..~.~x~ ~.-~-.~ .,..~ :,.: u .::.: ~ : R~¢ORO OF ~RVEY .... u..' ~ ., ' :, : .': ~. ~ ~ ' . ~.- ' ;. . - : i:: ~ ' : .:F~, ~, -~.~ .:: .' . -' ........... ~,.....,;...~ ........ ~.;-.~.-.--:-~-4.->-. L.~..:.~.:,-,.,J~.,.,~,.:..: ......... , ............ ~.,~....:.~... L ...... ..~.u:.~,~.~ ........... u..., .......... ~ ....................................... :...~ ................... ...~..u.,.-..~ ............................................ . ............ ~ .......... ~..,,.-~....' ........ ~...~...L-.~.~.~.:.....~.;.....~.~.u..-..~......uu.~.,~..:.........L-,...,'.~.......~;.~,~,..d.......:.:,~..L.,~...J.~.~,......J ........ ~.,.~., ~.,.,~ ......... :......-..-,~.~.~ ........ ~ ~ .... ,,.' -.-.- ~ ..... : :. ,, ..... .-.....--..- ....~.. ~e~?::~.~:?.:.:~:~:~)~:~q~:~`.~..:~:::~B:j~:~[:~:~.~:~.~.::~.~..:.X~.~:~`~4.:?~:~:..:~`~::~`:.~:.~.~.:.:~.~+~.::~.~{~:~`:~.:*:.::~.~:~:~.?.~:~::~.~?F~.~.)~$.~??::~.::~:~R:~.:x~.:%:~:~?~::~:~:.:.~::~g~`:R~ee~:~:~?X~:~:~?:.s:..:.4~¢..:.::~`::.~..:..:~a??:..:`:..:.~:~.~¢?s:.~:.s~x::~:~)~)~.:~)R~.~:?)~.k.~:~:~:::~g.:.::?.`::~.:;..~ :,~::~'.R~:.~:~:.::~:,:~:.)::~:~:? :.:'R.:~:~x-:,:'~R.:.:'.J:-~-~..~:':::~:~:' ~[~.~A~.:'~ ~::~.::~ef' "~:~:)?'~[~:~::'::':'.~'~.:{~::~:.~X':~::~-'~'~':'~R~'.?,~'.*~. ~ :: :'~ ~'~ .::~ ..).."'.:" x~, .~.:-.:'.~' :'..: ':::, ':. ~ '~ ",:.. ~" ..:"': ·" .'- ':'? .: .":'-. :¢-:' :',.:'.? ::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::: ~:~:~:~ ~xx~,~,~:~:.~:~:.~.~...~...r.~ ......... .......:~.: .:,.:. ....... .................. ~:~.,~-.~ ................. ~.~.,,~...,~,,.,~,,~,,~.~.~?,.~.~,.~.,,,.~ .................................. .?.~.,,,~,~,~,.~.~,,,.,.~:., ............ ~.~.,.~,.~,,,.~,~,,~:~.,.,.~,~.~.:,..~,.,~.~,~,.~,.~ ............ ~:~:.~,~.:~,~,.~,.,..~,.,....~..~.~ ........... .~, ................... ~ ...................... . .................................................................... ..,,~..,,,.,,.~,,~.~.,.,,..,,.~,,~. ............... ?-., .......... ,,~?,~,~ ............. ~.~.~:~.:.:`.~`.~..~.~.~..~:~.~.~:.~*~.~..[~j.`.~[.~:~.`.`~.`~.....~ ...................... ~,..., ..... · ...... ... ....... ... ......... · ....... .....,..,.......~... .. ~,.,......~..,,. ~s~.~s:~'~,a'~:.~'.~.'zig~.~:-R~w~9~.. ~%?~.:~,:~.Lt.~:w~'.~.~:.:~,-'..,~:~-. '"'"' w.:,.':.- .,.~L~.r. ws.?.:~t;,~:~,.,X~. ~.~...:~?.~.'~w~`.~..;:..:.~.~s~.~':~?~.:.~.~:.~.~.~'~.~.:~`~:;~.~:~.~'~.~:~ ~'~:.~)~,w~:~'&:.:.:~)X.:~.,~.:.:,~, ~:~{t~):~:.:.:~.~:~?~:.:.:.~.:~.~.~)~j.:~, ~.~.4`..`:.4~.:.~.~:.::.~.~.:;:x::r~:~;.~:~3~.~.~'~..;.~.~..'~:~:~.:~.~..~.~r:~.~.~.~:(.X~:r~.:~.X~`..;~.:~.::.~g~.:~`s:.~.~.L~.~&?.:~:'..~.:.~. :~:~w::~.~.~::~:~'.~.)..~:.)~'~[-~.:~.(:-~.:~?:~- ~'~.r..~:r~t.~.:.~:~::~.~.~.:.. " '. '.'~.'~: : '~ .. ,, '..: } ~.:'. .:..": .. :. '..'.'.:. ~.:.'.'.. .,. ' . ...-'.'..-~ ::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::: R~.~:::~:::~r4~.[~",:~'+'[E 0""~. ::~.~...~....~..~:~...~..:.~.:`:.:~:.~:~::~:~::.~..~.:`::~.~:~:x:.~..:.~.`:..R~e.:.~-:~.R.1.~-~:e~.~.~.~.~.:~..~....`~:.~.:.:..v~....e`~.~..~:~.~.:.~.~..~:~:.:.':~:~:.:B.:~..R~:~:.s:~:~.~::.~.:~.~.~.~:.:.~..:.~.~:~.~.:.:~.:~.~.::.::~.~.~.:.~.:.:.~.~.~.~`.~.:.~:..~.~..~.:~:~:~::~:~:~.:.~.:.~.`..:..~.~.:...~.:~.~:~`~...R:``... ~.?:.:-~:.~?:.:...`..:..~.4....~..~J~.....:..:~....`.~?...:~.~..~.:..?`..:.~.:...... ...... '-'"-~:?'~R?-:~',::"'~:~-.~'?~.:~..~:~-~:'~',:~ R~.:.d'.::'~':~:~,::('~'~""'~:~R.).:'-'":~:?~.':.:'~'~)~.~" '1):.:~?~"" .x~:',~:'~:"':'..?.:?~:~.~..~::-~.~:~:.::.)::~,).::~.' ~' ' "':' 1" . ' ', ":. :" "' ' 4.' ': '~,,~-~ . ~¥H" .' "~'~'~.' ..... :'D~'~E'~"~'-~ ..... ~"":: . ' .... ' ',.:'~' :'."~ ...... B'i'~A~c'E'~''': '~o'~'~,'.'t'~''''~'~',.'B'~o}~oo~ ' ~;-:~;:~:::;:~;~:~:~:~:~%:~. :~?;~:{:" ~;.:~4,;~¢~:::.:: '~'~::~:::f~t~:~:{~'~:~:-:~:~:f~:::~;:~:~ ~?;'.: ..... .:~,~/j~:J~:~;"~: :. x..x:~' ;..::.:~,~:.:::.;~;;:~ .t::;~::~::...:;,,:.:.i;~ ~ .:-'..?~:~:.:::~:~ ......... .~. . ~ .x::~-~:~..' ',:.:...,.s.,.,,. .... '.~ ,',' ~.' ....... · ~¢.~4:~;~{:;:( :.F~-'~:':::.~..:~:;~:~:~:~:~R~;?,.:~:~:~;~:. '-.% .~:.;~;~x~:~;~:~:~. E~:f~:.::.x:~:'-..: ~...~:~;:~;:.:.::-.,.,: ,;:, .-~.:::::~:::~:~:~:~:~: ~..': ~.:~'.' '~:, ...:.::Zx:;:::.':.~.-. :f.,',~$;~?B~:~:d~.,:.. c? ':~-. ;: ~::~:~j.".~:.~" ~: ~:~' ~:;~:~t~Z:: 3oo 'o ~o a99.99 2o6.99 5~e,oow .......... :'O-;'e9 ~ ............... 0"~~ ................ [~0¥--5""3'o"~5"'4'0".'w ..... :'~"OiOB7 400 0 4 .399,99 306,99 $71,10E 1,06 S 0,45 W' 1,15' S 23 4 11 W 0,100 . 500 0 41 499e99 '406,99' N1~,805 ~: - 0,78 S Oe05~ 5 - 0e78~'S -4~1~'40 5 ~ 0,~17 -0,67 ........ ~0 ~ ....... %~,..¥.F..S.9.~.~,, ~..~ ...... 8'0 5'~'~~ ........ ~ i 5. ~0'~'":~."~'"~'~? ~;'~ ~ ...... ~ '~ "~"~" '~;~~ ...... ~' ~'~''.''''zsv~-5'''"~'~''':'~'''~'s¥'~''':~?~''4'''~'~''''~''?~'''z''; ~' 5'o--- .... 2v~-~' ' 1000 11 15 ' 997,0~ 904,03 N14,205 ' 45,0~ N 8,85 5 '~ .45,89 N 11 7 18 ~' '~ 2,~34 44,14 1100 15 43 1094,24~ 1001,24 N14,305 67,64 N 14,59 5 69,20 N lZ 10 ~ ~' 4,48~ .... ~'3 ~ o -~ ~ - z-~' ~ -'~-~ 2 ~-.~.~ ?'-?-'-.] ~' ~"~'~ ,'-~'v .......... ~'~'~-'-;"~"0'~'"~ ............... ~"'~'~?' ~ S ...... ~ "~ ......... ~ ....... '-~ ;'o'z ...... ~ ................ ~ ~"," g' ~"~.""~'""~ ~ ..... ~"'~."'~'~"i"'"""""~'"'""/"~'"'{'~ ' ~',~'~'~-~ ' 1500 33~"~..76 ~ 1362.76 ~N.27.50E : 217,79~ N 87,24 E ": ~'23~.58 N 21~50'.~;:0 E' '~::: 3,776 ~800 42 57 ~ 1695.8~ 1602.81 N20.60E 386.09 N ~48.13 E 413'.53 N 20.59 24 E '~.. 4.690 1900'~3 ~3'" 1768,53' 1675,53 N19,0OE' 450'68 N 17i,38 E ' 482,16; N :20.~9'1~ E '"'. 1,083 ................................ ~::~; E~ :~: ~':~.~:x~::~..,1,. ME A $. 'DRIFT VERTICAL '-'-' ..................................................... S g B ~ :' DRIFT"''''''''' ''''''''::; '''': "--'""' """ 'TOTAL''"''' ''''"':'''''''"''':'"'''''''''~':'COORDINATES:'":~:'':" :'' :' ''~ ':: "" ~:''~'":'':''~'":?'? '"':" U::~':;': ~::~ "C"?:'''?? ~':":~;:':~ :~ 0'' $' U ~ R ~ E ~.~:::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::: DEPTH':'ANGL'E~. DEPTH SEA DIREC DISTANCE'':' ''ANGLE ; DEG/~OOFT DiSTANcE ?__. ....' D 'M. ,', '- ' · DEG. ' ' ,D M ~.'~;;;:.=2200~:'?:~r:.8:9.,'~'~;:~::~;~...'0,::?:~::~:,:'~:~:.~.9 ~ ;'i'.98: :~ ::..~:'?~1:900';~'. 98 :~%,.~NZ:O¥~O ~'?-~;'~.",;'.~"~9:7r~ ~O~:~SN-::~.'~;;~-~'~;~;:~'~=2~' 7',~'' 60 ~';~:'E'~ ~7%~:~=~%¥~ 7 ¢~;~ ~'"" ~:~:~':"~ ::~:~?'"~'~O~;;;:'~?'~"~f"~?~'¥'"' ":?~":,??~':~'~'~':~'~;~'~~ "~'"~" ~ ....... "~'' · .................................................................... ' .................. ~."--~'.~-~ ........ '?=' ............ ' .............. >....-~ ......... '...-,,~-:-~.-=.~-~.',-~.-'~...-: ..:~..~?.~...~-.~ .~...:~,~'......~-.-'~<-.~=.~?.: .. ~ ..-~;..~-~=-......,. ,;=-..'~:~.~:; ~ ;~<=~:~=?,~..--? ::'-.'..~..;..-~'..~-'~;~,~.~;=:~2...~=~2;~;; .~,~=~:~;~....,~..E..~;~.~:~.:<~;.? Z.,'~.e 7 '.,.'....~.,....' ;',:.~ ~" 67 S ,'~';. ..'~?' 2SO0 ST,S6 20~2~b~. ~979,b~ NZO.SOE 695.20 N Z59.06'E -- 7~-0 .... ~'"'~"0":'"2'~'"'~"i5 ........ 2500 ..... ~5~0 Z~SS.~8 2~fi0.~8 NZO.~OE 806'.~2 N ~00,20 E ; 860.~9 N - ~'~.sO'"'~6'~Y~~ ........ ~-~°~"'S'6~ ~~-~ ........ ~'~ ;'o~E ' 'fo'i~~-~ ......... ~';i'~ ~ '~'i"~~"'~'2'o"~'"'~2~7~'~'~2'7''''': 2900 49 45 2536.91 2443.91 N21,SOE 1048.42 N 391.65 E 1119,19 fl 20 29 2 ::~. '.~ ~ ~ ~. ~:::~ ~ ~..:-~: ~' ';' ~: ~. :~:~:.~: ~::'~~~:::~: ~::" '.~.'N'~: l~'-':~':0 E~: ~:.:~:::~"!- ~~ ~'~~ ~-,~--~:..-~ .-~'. ,.~. *..-~'~--,.,.,... ........ .. ~,~,-.,~ ~-~ .............. ,--~--,~-~-~-- ~:?:~':'~: :~'"~;~?;~:.:~::~::~?~J.~:~...~:~:~::~::~::~:~?~.'~'~:~t.:::.~.~:,: :~' :';;'~¥:~?~:~:~::~.:~Y:~::: .'~ :....:~.:c:~:~:~:~:;~..':'~..::..:Y :~:~t.~;~:~.~?~.:~.~::.~:6.~:~Y~:::.;.;,%,.,~:~:. Y~,.' .~ .::.. :.::.: ... :... ;~r:~.~::::......;.:?;~.~%::¥; ..... :::~.':;-:[ :~.~;:~:.~N;~.::...;:~.~::~.:::~;~:~.~:~:~::~:.~:::t~.~.~::~.:~:~:~.~ ~:U I' ~ M ~ · . , · & ~ ~ ~ e ~ ~ . -. ::.:.. 0.'.:':: 52;?:52f.~.~::::.:2~7~2~c:~:?~:6.~9.*~0:?:~.Nz2*:..~[~:~Ef./:~:::~.~:~.~.~*.~9~::::N..~..~:::?:~.5~9~ 1-T:-:~-E ::'?:~.:"~:1~3~'87':~'::N::'~.'2'0':'~?~'7:~:{?~.~:.:~': "E':::.?:?.f~ 0,3~. 1~Z6,39 ~~~~-~z'"'"" ~"~~~-~:~ ~,~--~-s:-~-;,~ 3500 53 ~8 ~ 2902,7~ 2809,7~ N22,50E 1~89,~ N 569,~0 E : ~59~,57 N ZO 5~ 17 E 0,5%3 1585,55 · 3600 5~ 8 296~,89 - 2868,89 N22,90E ~563,82 N 600,5~ E 1675,16 N 2% 0 ~5' E 0,87~ ~-~'0'0~'"' 56 '''~ i":': ...... 3 ~88';'~'2 ............ 3~0~9~'~"2 .......... N2"~";'"i"OE"'"'~'" "i"86'5-~-7~ .... N ............ ~.~.~7~~~~.~~-~j`.~:2...~.~.~.~:~:~:~:~.~'' ''':'''' "'"" 6100 56 ~2 ' 32~3~3~ 3~50.31 N2~.20E 19~2.02 N 766~95 E 208.7.98 N 2% 33::. ~ E . ' 0.072 2078e~8 ~200 57 51 'S297,3~ 320~,3~ N25,60E 20~8~3~ N 80Z,~ ............... ~71,98 N 2~ ~0'~8 E "1,527 Z%62,~7 ?.~-~oo?~'.:...~: ~:~ ~ ~::~::;:~ ~.' 0 s':'~ :n'~?;'~ ~ ;' o" ::X.~'~? N ;~: :e:.::~'~.~.:O ~%~:?:~:r~ :-~-:.~7 9: :: ~ :-:..:::~? ~e 7"8 .'::~ ~:?' E :??:'~ ~?-.::;~' z ~ ~::~?~,"-6'~?~ff?z~:::~::~.'~;?~: -" ~60'0 5'~' .... ~0 '~""3'5'~'~'~-'~f""'-'-'3'~2'~3'~''7' N'~-;-5'OE'",""~"~"-2'~ ~"~'9 N' '" '-~='9~'~-~' '~"::"~'~-0~'~"N~'22"~'8~:":~:3:3~ E: ~800~ 55 52 '. ~629~00 '3536~00' N28,80E 2~59,51 N ~037~17 E '2669~26 N 22 g~ ~ E ~ 0~8 : :., · . . - , ~:~ . 0 : 2662.25 ARCO,:,, · 82 E G HEAS, DRIFT: VERT'ICAL' SUB DRIFT TOTAL c°OR'DIflATES ........ - .... 'C"L"':O'""S"~'fR~';'ET"S ................. ~"~';'"~'~E~ ~ DEPTH ANGLE DEPTH SEA DZREC DZ STANCE ANOLE DEG/~OOFT 5200 56' 5~ ::f'.38~9.9.~- 3756.9~ N29.60E _~5300.57~ ....... 9 ' 390~,_~2..'.'38~1,32 N29.70E 5800 57 ~8 ~69.2~ ~076.2~ N30.90E 3~92.6~ N ~50.05 E 3506.50 N 2~ 25 36 E ~.~7 3D02.92 5900 59 ~3 ~221.~2 ~128.~2 N30,~OE 3266.12 N ~93.33 E 3591.32 N 2~ 3~ ~D E , ~.53D 3588.0~ ...... 4 2.'s'6 ......... .......... a':S' 2'i2' 6~00 59 ~7 ~76.29 ~383.29 N3~.20E 3635.87 N 1713.1~ E ~0~9.26 N 25 ................................... '" .............. .,'.'.' ...... -".- :.;----~-~-.~:~ .'. .... .-. · ,]'..~,~ ~ -:., -.,,~ . ._. -:...-.-.........~.~.s .. ,:. :-:, .,.-.-~,....s.,.,~,' :......: ....-:,.....-.:...,:.:,..,,.;.; '.,,..,g;;; 6900 ~6 55 4761.37 4668.37 N28.80E 3987.3~ N 1922.80 E 4426.74 N 25 4~ ~0 E ' ~.971 4~25.65 SECTION DISTANCE D M '$ %~.,:~-.:-!.:.:::...v~-..:..',, .:..':.: '. -'.-'....-1.:. c-.-:'- .'..:..-.:...':-.::.: ' :.', -:.',..-. ~...-:'c '..'.:~. ,,~..:.....:. ','-,-,:., :, :.'........ ':.!' -::: ':.'. ,..- ..: .- ~. -. :.',' ',:.' :.':'.:.: :. ~,~ ',......! ,..... '~-/. :-:w:.:..:..:..::.g:. ,~ · ~ ..~:~.:. ?: v ~?.-: ..' ~,:.. ,~.., ~f..... ..- ~..5~ ...~..-,. . -., -.. - .~ ~?~:-':?.'::'?':::~:~:?~:~"::'~:::~:.~?: :~.~;~::~?~%~::?:~)~;.'%~:~i~'(.:~;.~,;:; ':., ..~. :.:~."': . ,. ~..,~.:. ::::: ".". '" '.. "..~{"-:: ' '."".'.'-':.::. ::::.:.~::~'~.:::' ' .'""~. ':'.:"~' .~ :. ".. :-'.: t- ' )..::.~.~':~.:~.:~.~,:~:~:.:' '-' .:" ":':"..t,:t~:. ~:':":/~ '"'::~::~::?". "t~:~{' '"?' '?~)::.?' :.)~:.:'".:~;':?~.~:~'":::f~?: ':):'~'~:~C"?::~,~'.~:~:~.:. :' :' ' ' ' '. ~:', :' ' ' · '. 4~97.15 4565,34 4807.71 7600 34 26:~ 5304,'36': .5211,36 N28,00E 4~76.,88 N 2;I. 25,83 E 4865,83 N 2.5 54 20~ETM 0,911 7700 33 34" 5387,24 5294,24 N30,OOE 4425,81 N 2152,95 E . 4921,69 N 25..56 26 E'.:. 1,061 ., ~+864e 91 tMEAS' DRIFT':VERTICAL :. ~U8 ' DRIFT TOTAL COORDINATE5 C.L 0 ~ U R E ~ :, SEVERITY DEPTH ANGLE DEPTH SEA -,DIREC DISTANCE : 'ANGLE: DEG/iOOFT O . M ' ' . ' DEG, ' D :t~:/;,;~:: 8; O' 0~. ~i ~ ~ ~}: ~: :::;~ :: :' ::~ ~'~i.' ~:"~'~.:i '~:~ ~:~ ~:: :" :: ":; :~': :::: ~;;~ ~ 1~:~::'?i?~:~;~:}~((~:~:~:~ ]~ i~.O: ~ it 9: O~ ~:::}:t}; ~t ~' ~ :~; ~ ~ i::~i~;~: ~: ':' ' :":~i ?? :)~:~' ' Ii' '~i: :: ~i. ;+~ ~:';~ ?I ~: Ii' : '~:. ::~:::~;~;~:~ ~ ~'I'I~' ";;": '~Ii:''" ;,~': ": ;~:~ il' ~ff'i, I I "~ ~ ~. ~j~: t'~ i ~'~ ~;~:~ :I ~ ,:~i~: ~ ~ I ~ .~:~ ~:~: :~:~:~:t ~ ~ ~"' :~' ":~'; "ii:l~ :;:'? ';~ ;;::~ ':~: ~ ";i~:::: :~ "~'? '~' Il; ': ~:~i~:~::~:~::~::~ '--~ ::~::~:::::~,r e : ii "~ :~:~:,~i ~ ~, ~ ~,~l!]~ __; ]~ ~:~; ~ :~ .~ ~ '[~: ~' ~, :~' '"'I, ~ t~;r :;:~ : ::;~i: ~" : r~. ':~::: :': : ;:~: :~i: '' '," ~ ~. :: I' ';'" :' ,',I'' ,::: .:::i~ ~':'' :~' ~ ~ ~] ~ ~:~ ~ ~ ~:~ ~]~ i~'~ :i ' ;~ '~:' ~ ~i~:~ ~ :~ ~ ~ ~:~ ~ ~ ~: t~;~:~::' 8000 32 48 56D9~66 5546~66 N29'lOE 4567'20 N 2232'25 E 5083'53 N ~6 ~ 50 E' 0'76~ 8~00 32 ~ 5724~07. 56D~'07 N30~iOE ~6~'83 N 2258'73 E ' 5~7"05 N 26 ~5 '3 E 0'832 8200 30 55 5809,35 ' 5716_,~5 N31,OOE ~655.80 N 2285,28 E 5189,12 N 26. 7 '45"E ' 1,125 .7 05 8600 28 9 6156,91 6063.91 N35.30E ~824,53 N 2393,35 E 5385,56 N 26 23 6 E 0,990 8?00 27 17 62~5,~2 6152,~2 N~8,~OE ~861,76 N 2~21,25 E 8800 27 26 633~,23 62~.2~ N39.70E ~897.~? N 2~50,~2 E 5~76.2~ 9200 24 25 6692.83 6599,8~ N~i.20E 5031,67 N 2565.77 E 56~8.08 N 27 ' : SECTION DISTANCE 5082,80 5136,37 5239,24 5288,98 5337,74 5~8~.23 5431,08 5~+76,05 ,5.56~,57 5607.23 · 0 ,5.,3.6933 ......... - .... ............ ,, : ..... , ....... · ......... 2 · ...,,.,..~,., ,',..'~'.~. :..,.,' .... ..~,-..-:-:,:.~ .... ~..,,:.,u,'~::,.,'. - ,.?~: :.:..-~..~.. ,~ .. . · ...... ....- ..... -- ..., ~., .... -..,,:~, .,.,::. ,.,,~.. :., .3. :.JAN, 82 ', TRUE . · .-, CODE .: . . ,HE~RED ,,VE.RTZQAL TOTAL ' COORDZNATE5 : ''~ C-L' Q. ~ U R E~' ., .: SUB TOP KUP 8673. 62],9.69 4851.33 N 2/+'12.87 E TOP. UP ~ND_.. EIT~B~. ,,.'. 632~;)..~92 ' 4892.3.5__ N 2z~5.52 E · B S')!:':!i.:U'~?i?$:a [~i'~'~¢~i~:~'8 ~:-~'~:i~ii.-i-.!i;!!?~¢~ii~(~3 f~O"!~:-i:i.i¢~:i;~.~!~'~ ~.~::;~:~:!:~:i!:N i:~?:: i?ii:~:: ~ ~; ~ :.-:.,? :Y?:t-'::'-.::~:~%.::t~.t:~:~:.:::x~:~:~.~.s'.~.~¥,..?. "-:.:.... ;:~ "t'.~:',):-~.~'x?,~:~.:~::~:-:.:::::,:~.: ', - · , ~.-?,,,: ':.::~:'ttt?~'~:::~;.'.~,,,'.~ '.:':'t~.'.?~-...:t't ~, ~:';.~- .';' :~ :~'~:~,, . · .' : '. ~ ;~:~'~t PBTD 927~ -675~,Z6 5052e03 N 258~77 E' TD 9~00 6872,35 5076,98 N 2639,72 E 193 193, 100 0 0 _____~93 ...............~ .............. Z_9_3_L__._2..Q~O. ~ ................................ ._0_ 693 693, 600 0 0 794. 793, 700 0 0 ................. 894, ..... 8__.9_~,_ _800 _ 1 ........ ~ _ . 1313 1293. 1200 19 9 . 1426 1393. 1300 33 14 15.44 1493, 1400 51 18' 0.65 0.87 $ 0.52 W ' ':: :::.)~:t :,'.:.).:.t :.: ~..::..Li.: !:i~t-'~ .: :. ?; ;i;:.~ ~ c.-.- ,.'.~.``~`~.~.`~`..```.~-~-~--~.~-~?~.~.``.`~:~v~`~...~```.":``~`w.`~`~?:~.~-~;~::~-.~.`~ 6,61 N 0.06 W. ' 1893. 1800 175 34 557,44 N 208.58 E 1993. 1900 206 31 636,36 N 237,00 E ~" 2093, 2000 233 27 709,99 N .264.'4~+ E i.':'" 5 -':' '.':: .'~.:;i;¢.t.i;!ti':::' ". :: :'-' .::' i:.;::.i:~!-t!i:~Y!~;;'!'~': '' .;...u:.i!:~:~:ii:~:~i:~;i:yi;~t::::~!!!;i.~:.tiy:;..~.i!~i!~::~;.:i~:i~i!~::::!~.i~: ' .: .':<':..:.::: .::t:.Y ~;:¢:5<¢t .f::' :.-:..~;-::~%;';/;]; :?; :~'' ..~ ~.' ::,.' :' ' ;:~:.:~v ......y.~:..~.i..~..~.~i:::~:~:~::;~{:....':'..'.-t. ~:.:.:::.~....~ ".~;:;~::~..:~'.:. · ~L;;~:..:~;~',::7';~:;'~;:~;:':~,~.~.:. ;.~. ':,. 2~93. 2~00 341 36 1003,~6 N 37~,05 E 2593, 2500 395 54 1111,83 N ~16,56 E 2068 2199 ~ 2326 ~ ,, 2835 2988 __2600 459 3000 73z+ 3827 3093. ~008 3193, 3100 815 ~ 81 1871,86 N 735.~7 E 82 4914 3693, 3600 :122]. 79 2542,31 N 1082,88 E .i:'. ..5095~ ' ' ~3~i~_~, _ 3700" !~_02 ' 81 2674,56 N 1155,29 E 58~5 ~193. ~100 1652 90 3225.73 N 1~69,15 E 6040 4293, 4200 1747 95 3370.24 N ;1553e88 E ;~: ?~'~"3'~.~:~'~r~ ~.~;.~:~'~:~"? ~.~'~:':~ ~'3 e'~,~:~:~:?:~' ~4~ O0~ ::~:~?',:.~'. ~":~'~.~~:~?~,:~'~ ?/: ~.,.~:~:~:?~ ~:~:'~:/'~ 7,',~::~.:~'~?.'~.~:'~,~ ~,..:~;~;~?;;:~'~:~;:;;,~;3 ~ 5 ~', ;% ~:N ~,,~j;~, X~:~,:Z ~;'e ;:3~:~?;?'~?':~,~;~:;~'~ ~-; ~'-~, 6946 4793. 4700 2153 51 ~016.59 N 1938,36 E 7085 4893, 4800 2192 ....... . ............. ~ ...... ..7215., ............................ ~93_2.~ .......... ~,9.QO, 2222~ 7707 53e3~ 5300 23'Z4 7826 5~93e 5~00 2333 39 4101,49 N 1984,01 E 30 4176,01 N 20'21,96 E 21 4429,11 N 2154,86 E 19 4485,97 N 2186,44 E 7945 5593, 5500 2351 18 4541,24 N 2217,48 E 8413 5993, 5900 2420 - , 16 4749,71 N 2341,84 E ' ~ . 85~7 6093, 6000 Z~3~ 1~ 479~,10 N ' Z373,~' ~.L.;. 8 aa 1....~. ........... ,~ .__'~.6~._ ..... 6100 ..... .2448 .. ~4 ~, 4840,11 N ~ 2404,51 ' ~ 5oo - I ........... ....... ....... [ ................................. ' . . .... . ........ - . . , ~ - ~.~t~,:; '.::~:::?~ ?.~:~??~:: :~::~::.~-_ ':;.;:j:~':S~::.::~'.) ~:;.,,;:~f.;:-:. ~ ~ ;~:).f~, ~. t~, ~ .,,;: ;:- .;:?.~:',.:~ ~ ~'-;.~' '~' .,', ~:-~"?f ~'~' .' ' -:¥': - ~' t~.,r;'~q:::;:<.~....-~ .::;~.r'-..;~. :;~;,~:~; :..t-~¥:~YL~:~?,-:~::?;~;,. ::' :,.< :- :-.'~..: ..:,~';.4 .-; :-,:'.': '~:~ :-'::' '.-. :,.: ','. ',.;' :.... :" ~ k.. : %'~-'-': ~,' -? ;.~-: -, ...... .. - ......... ~ r.~,~ ...... .-.:..~-,-... ....... -,~. ,,.'- '.' ......... -' ~. .... · .,: ',..':.::: ~: :~,.:::?,¥:' ::~:,'.~?:;::: ::'t:.::'J,..~',:~,;.~':t :":::.".::C:. ,~,:~.?:,' ':":S.?~'.:;::'?,,f~:.: :' "::'.-.; ~ ,: ::"?.';~ :: ,,'::' :?[.. :: ~,):' ', :.. :.'" .:: ~:.:.::?,';:.?~' ?.:':,':-t,:~.~t~'?:i::::<~.?~::'~::~ ~:-::::'~,.:?'k:::':¥::: .-:?~.:,..-.,.' ,'.: .:¥:,::.t-:::,,::""~::? ,: :":,'.:.?..:,,.:~,.~,'~:~',: ',: ,?.-~ :~ :2,,:' :,: ' ~'.::: ~..: :.:<..'.:-,~' 'J:~' :: :':: .::: ..~4.:..f:',,:-:: :':, .':: :;:: t:: ~,'.??.::~:::.~ ::::~ ";~:-.:::.'~.,:~:~';.?t::Z::~:~:,:c~:~',,.' '::,,f~:,'.: ~,.(~::,':~?;:.{:~:,?:~' ~:: ~,... <,:.:¥~. "...:"":': :~:'. '.'Y:" <~:C"::<~Y :'t :':~, :. ~:;::t ?:',¥':'~?.¥~4~."~::~:c..'::: Y'r;' :¥~..-'::"? ~': -::'::. ?: ~ ~' ~'::: t.~:::~ ~4""F ' ..'."~' :.': ::'.'.:':t.~¥:':'.:~ ~:..~:':.~:.'~.:?~.,:~...~:::' ':~:.¥;:,,~'? ?::.":~ :~:::k~¥:'L:':¥%' .'::,'¥ ..":':~::~ ~..~' ~:.: .'.: ¥:~.:- ".Y..':'t,t '.:. ~"',' :' ,,':?::"..:-9.'.:':..:,,:::':'.: :"'":' Y ;.' '::': C".::.::' .: ' :: :' :'::-/~ .:..:'.?~,t :'~';' '~ '4¥ ::~ .:::.. ;:, ~; '?'t':~:?'~; ?).~',::.'~:?.:~,:,.~.~:::~y.¥?. ::.¥: ~f~?¥;:::',:~f? ~.:."~:)~,t::t.,~'~ .' :.., INTERPOLATED VALUES FOR EVEN 1000 FEET OF MEASURED DEPTH. 1000- 2000 ............ ~..3ooo.. :., 7000 8000 5639. TRUE . -', ............ : ER ~.'! CA,El: !: i:.i'ii';i!!i~!ii:.i:.i:i:i: S U B?~ii:!.::i:i~i:~ii:~iiiiii.~i!i:i..i~'~!~':!/ii:!iL:..:.:!i,;i:!...' !,~;:: ~.::: .-: .:..3: i.i:i.:: i?'i ~-i'~ .: ~. :~, ic,f;i:.?. !i'.i.i!.!i:'!il; :~.i...i.i?:!:i:i:'i~i::?ii!i~:il..'!:~!'!!i:i.!;.::.i:,ii i~:i:iiii:ii~ii:!i~i ~!~,i:ii'i:ii:i::~::~"!:;?i:i'i!::gi:':~"'~i~:.~::'ii !!:i' ~ :~:i:i~,~-.:t'~"',:i:~ ::~: ~; .:,: ..:ii 997. 904. ~5.04 N 8.76 E ' ....: 18~Z,- Z748, 515,00 N ' ~93,53 E ~ ".. .., D.:O.Z, ........ ~...:..~....: ............. ~ ~~~~o 7~ E ' · ........ '. ".. :_.. ~ -: &738. ~050.~8 N ~956.37 E ' 5546. ~567e3~ N 223Z,95 E .......... rll i~ ; .......... : ........ !~ .*~ ........................... i ........ VE RTJCAL .... SECTION: .......... ; ................... ; ...... :-*: .......... ~ ARCO ALASKA~ INC.-~ ..... : .... ' ...... ~' ~ .................... :~- ......... KUPARUK FIELD,WELL B, IO.: L::.~-::'._.--, _ ........ : :-:-. { ................. : ........ ~ - ' ~ ~ ,. ............ : ........{ RADIUS OF CURVATURE ....... . , - ~ GYROSCOPIC SURVEY ......... ~ ' ii ....................... ' . -,:':":--~ ...... ; ......... SCALE= I =' I000'-: -.: SURFACE 'LOCATI'O~_ IS:~ ...... ~ ....... ~ .... :""-':'~ ........ i--;-'~ - dAN. ZI ~ 1982: = ' - ~ : :':.. ~.. :.:: ....~ : · -- ..... ,'_v: ' I '" ~ I · ' ~ ; .... : .... . . : ~ '* . ' . . , · - 494: SNL--i~I30Z WEL ~ SEC. 9: ~ ;:.:T::--.--*:~. :- ....... ~*:--: ....; -'::~-~' '~ '":.:" ~ .'~': ~ L:?~ L:~-;T:.j~-4- :" ': :"::-::'~ ~: : : 'ARE TVD ~:.: :..:: ~:. :.: ._:_.:.::.: ...... :: ,::.~:.: ....:.: ~: :~'~' :. : :ALL DEPTHS- SHOWN . .. . ~ ~ ~:~-: , .,.~ . . ::..;~:~2_:h::::~': ~...~.;:: ~:::~L.?a~'. : - ::.b/:: :-; :.~ ~':=' , ~ :. -~ ....... :. ~-,,:-~--;-:-.4--:---;.-:~4-~--.-~-.:.,:--;- .... ::.. ;. · :F .:y.~.-:~7F[~"~:~..~::~q.~.~.~`~.t~:~-.~-~:.~:T~:.~:.~.:?.~:.: ...... ~ :~:'~ '-': ~ '": ~":" ~ - ........... F-:-:-:":-: .... :TVD = 6693 -.'T:~'::':: spe -sun December 7, 1981 Mr. Bob Hines ARCO Alaska, Inc. P. O. Box 360 Anchorage, Alaska 99510 Re: Our Boss Gyroscopic Survey Job No. Boss-16933 Well No. B-10 (SEC9 TllN R10E) Kuparuk Field North Slope, Alaska Date of Survey: December 4, 1981 Operator: Everett Sellers Dear Mr. Hines: Please find enclosed the "Original" and one (1) copy of our Boss Gyroscopic Multishot Directional Survey on the above well. Thank you for giving us this opportunity to be of service. Yours very truly, NL SPERRY-SUN, INC. Kirk Afflerbach District Supervisor KA/pr Enclosures DEC 1 5 ],98] Oil & Gas Cons. Com~iss,b;~ /~chorag~ MEASURED NORTH SLOPE~ ALASKA ~OSS GYRO SURVEY ............. NL SP RRY-~UN INC. · DEPTH DEPTH TVD DEG MIN DEG MIN DEG/iO0 NORTH/SOUTH EAST/WEST BOSS-16953 SECT]ON 0.00 100. · O0 00:/: O0 O0 0.00 -93.00 ORIGIN AT SURFACE 0.00 N 0.00 E 0.00 ~00.00 507.00 0 ~ S 71 6 E ,18 1.00 S .~6 ~ -~.10 500, 600. 700. 800. O0 O0 O0 O0 900.00 ~+g9.99 406.99 0 41 N 13 48 E .69 .~5 -'=?: .:,-.' .-""~'~"~'~"'"~':~'?~ ..-,.:' '.',-:.-',_ .""~'"~"3~'~~:~"~'~?~ ~~~``~:~`~{<~:~U:~:vU%~%:~::.~:~?~`~:.~.:~.:~:}:~..~C`:~::~):~:~? 898.56 805.56 8 S5 U 15 2~ E 2.96 28.35 N ~+.lq E 26.53 100 110 120 130 0.00 997.00 904.00 11 15 N 14 12 E 2.35 ~ ~'~ ...... ~ ~'"~' '.-:. ::..'. 4. :~.~'.F:. ~: ~""--'~'"~'~'~'~'~~:~'. :',::..::..:..::~c: :':,::- .:: '.'.': .::.'.::. :- ::..'.::. ~':- ~' ,:..:- :'. :- .::,. :. :' .'.~ --~: ~::-: ': '.-, :' :- .: -X' .':' ':-':':-::' ':' 0 · 0 0 0 , :..'"' ': '.:: .... '-" ,'~:"...:",;.:':.'::~::~:~:'-"q~':~'~'-'. - :>"" .:" :'~'::'::~':.:?C~'::'.?:.:~:",: :'::" '"::'~.':: '-~?.;'?.::.;..':'~' '~:~:~?': "..:~>~:?~:~:C~:~:~:~:~.~("::~'~C,.:~:..~:~?~:.:%~:.:?~?g~:-::~C%C?:C:C: 0'.00 [ 0.00 ~281,61 1188,61 25 9 N 27 0 E 6,19 Z~5.27 N 8,59 E 43.37 i~iii~6 !..~. ~ii811 . ~:~I.. ...... :... :.:.............:..: ..~. :....: :....::.......... ::...:..:..,.:?~F .:....:., :..:.:........:..:.:.~i~!'''':: .:.: .:: ~ .~.: ~ .::, ?.::.:,. :.:..: ... ..:. ~,::.:.., .L...: .: ......:c....-.~?ii.~!!!]61::5 ]~ 17 '7':' .:.:. ,t: Td'.:.J J-. ~~~ 132,23 N 39.49 E 133.99 135 · "0 155 160 0.00 1326.q¢ 0.00 0.00 0.00 0.00 1370.39 1~55,73 lq97.52 1539.12 1233.Aq 27 23 N 29 ¢8 E 5.10 151.68 N 50.02 E 156.09 '. . . :.: ..... j o N Z7 E S.SS s.77N ZO .SOE 2SS.SS 1700.00 I750.00 1800,00 1900.00 2000.00 619.90 1526.90 38 12 N 17 36 E 4.20 ~2~.90 N 126.21 E 344.02 ~ ,: ..:..::.:...:.::..., :.... ?~~~~~ :....- ..:.:~.;~.:.:~.~...;..~.: 65 fl. 53 1'565.5 ~:'~;:~;~?:?~:::2~:::~A: ~;~.;.~:~.~;~:~N~:~.~2~.~t~ ~ ~:5'~";:~.:".:~::~ '. :':;. :' i 8~1.77 17~8.77 ~2 2 N 19 ~2 E 1,76 51~.96 N 193.85 E 5~2.13 2100.00 2500.00 1917.00 182~+.00 z+O 22 N 19 24. E 1.69 577.03 N 215.89 E 606.80 ..... . · ..... . - , .,~ ..... .........,.. ~.~ ....... ,....]....~ . ..I.......,.,.............. · ~ ...J..... _..., ........l~.l,,..I ~..,......-.,,.-,. L.,.......-....-.. ,..-...-.....I.~1.~. ,I....1~..:..............-....-.._... ,...........-.~._-.,,-..&..,...... ,I...... ~{....., ,.' -........, .., ...,.-., .. :......._.- ..,,.:.%-..:....:...., .-...:..I.. :.._..........., :......,: .:..:....:.....:..:,,.:..,.....,:....,.'.:.,:.:..:.........:, ,,....-.: :.,: ....... :, · . ~ ' 22SS.~O 2100,0q .35 ll ' N 2",, '1.3 E 1,15 806.~8' N 300.11 E 8~7,25 .-~ ALASKA S[JRVEY B05S-169:33 NL SPERRY-SUN INC. DEPTH TVD DEG MIN DEG MIN ~EG/IO0 NORTH/SOUTH EAST/WEST SECTION ARCO ALASKA 1B-lO G1 KUPARUK NORTH SLOPE~ BOSS GYRO MEASURED DEPTH 2600.00 231q.95 2700.00 2,39q.17 2800. O0 2~68..q8 2. ],00 2503,53 -5~,~o. oo 25:36.88 2221.95 35 :38 N 20 6 E - .q6 860.85 N 320.11 E 90~.26 ,. ~ 75 ~a.,,:.?:,~.:?:::::.::,.~:,,..,:~ ..... ,:,: .:::,:.:~:,.:: ............ ~:80...,.5.0 ..::,N::?;~:~;:~:~:~:g:~;~'::~:/~~: ~::~:.~;.~-~.-.~.~'0.2~ 5000.00 3100.00 5200,00 3~00,00 3~00.00 2599."')7 2506,97 51 59 N 22 0 E 2.26 1120.~8'N ~20.3~ E 1178.85 ... . 2842.68 27~9.68 52 55 N 22 0 E .08 1~15.43 N 539.05 E 1493.25 .~,3_500.00 2902.70 2809.70 53 19- N 22 30 E .57 1489.45 N 569.3~ E 1572.~1 ...... ~ .... ~'~"~ ":.'.:':.::,:':--':.':' ':- ."-'-': "~ '-~?~'~ ..... ~ ........................ :~- :, .........· ........~.-r--,---,--~ ~,:..-....-.. c,,.......,.....:.~__ . ~.:~-_._.~...- .., ..:...'~.-::..~..::_~,~:::c-,',:._. '.,- '.:..-....-.....-.-.::..::....,.'....-, ....,,:,:.~.'c.:.'...,..-.:.::.../,;...?,..-.,.....:. .... ::'..,'.:':.....:"..v..,:.'..'."'. :, .~:~'. :. ,,.:.::oy?:'>.':>,::.:-':~ ,:72c%?.::?;..:::.:7,:-::c,i:3.:,?:c.v:..,, :c:*?~.~yy.2:{-::<=.r ;:':,.::.- .:;;, ':~ .... '..: .: . 3900.00 3133.~ 30~0.3~ 56 31 N 2~ 12 E 1.q7 1789,56 N 698.5~ E 18~6.58 ~000.00 '~'" 00.00 ~o.oo 4~00.00 ~00.00 3188,38 3095.58 56 ~2 N 24 6 E ,20 1865.74 N 732,70 E 1979,56 ~ ...... .: -- =?-:.._--~,-~T-..??~~?~.~.~i~~?~.:X~,:.~..~.,~. ............. ~ . · ~-;~- ~y~:~ ............... 5-~ ..... ~ ............... ~ ..... ~¥-:~'-~-:":-':6,.'-~::'::' ,.,5oo.oo 3,+59.16 --"q6---'¥0 .'00 3516.26 ~,700 ,~00- .';....-' ?.:. :.3572,75:., ~800.00.':"~;~ 3628.96 ~900.00 368~.81 5000.00 37qOoq6 3647.z~6 , 56 11 N 28 5z~ E .09 2604.81 N 1117.~+0 E 2811.63 ~c....._:...,.:. ,..... ~..~~~~-~=~... ~ ....... ... ,,...,... ~ ............. ~= ............... 5~ 00. Oo ..... ~57. ~ ~';97 r"""~¥'=5'~ ............... ' .............. ='"N''~ ............"~'~-~f:'~'~""""'~'"""'"'~"":'"'"'"'""'""i'"'~'~'F'i~ .......... ~"' ................ '"'"'"'"""'~'i'~'7"2'~ .... ':'"" ARCO ALASKA 1. B-10 G! KUPARUK INC. NORTH SLOPE9 ALASKA BOSS GYRO SURVEY TRUE MEASURED VERTICAL [DEPTH DEPTH BOSS-16935 NL SPERRY-SUN INC, · ' ~ ....... "'. .............. :~--~ ........................ ," .......... '-'. ..... ' ....... "'". -' ....... ...... ' "-'"-~'" '-". .... -"" i TVD DEG MIN DEG MIN DEG/IO0 NORTH/SOUTH EAST/W~gT S~$T[ON 3918.0q 57 59 N 29 30 E .12 2971,09 N 1323,79 E 3231,98 ~~'~"t~:?' .. ...... ,........: ..:-..:..~:.,-.'.:..:....::!~,:.~.:<.::-{~.::~.:-'.-:~g~:.:;=~~' :"..L:' J'-¥~ ~'.:.'.:':L~'~.:'.:~::-.:::..:?~-::~'-:'~:::~ ~'~' '~:-~ ~',',::.'~;~:~' :?':'":~: 4'.:."~'-:F.:f/?::.~ ':' .~'.. '?. ~'~' ' · ; 3 q 70 · 86 :'~':~:?~':.:~.?~'.58:(':~'~'-'I"~:':-:::~::~-~.:~;?~:'.?F-..'::~::N~:~:2 :~:~?:~:~:~.:.?3~:~.5:~:::~?:~N:~.~%~?~65~:~:~I~.:.:::~::~:~:?:~{::..`~ ~ ~ 6.87 ~ . : · · .:-:.:-:.:- -:-...-..:-. · ~:--.'.:...:..." · '-.:-:. -..T..? .'..'' .-..::-:'. :-.'...e · -'-'-~:-'...:'1'.. :':.,.'.:-. :::.y.-:-.::.%'":.' '.'-:~-:!-: '?q':' ':.e..::~:.::::.?:.?:.?:~::.....:. :.-:...-:... · ?:- '..:. -. L :.Y:.:'..~.:::.',..:~:.:~.~ig>~:F?~:.:..~?qL.~,: :{::.:{.2A~,: '{ :q {q-?F?c .- . '.. ::gS-J:.6%>?< ..- - ~ U I ~ · & ~ ~'::..:'::~:~::'.:~'~:..C~:C'~.,'~ ~-~ ~.~';'-_.:~ .?'.:. T'L~C. ':T'.?S:-::::'.'{~,{'.:'{:' {:':, ':? .:';:..,..,.-?~'~'.?~:"?:':':~'..'-~'::'..." ".'.. '~'.~ ,..~ -~ :-:~.~, .. :':'"::".':'.~':'"':~-:":'.':':-~:.'-'. ,:'.":'-, ':;, ,',./:', ':,".,' ", :,'"," '.' "'.'"":-':':"'-"'-'~ :- - ~' ...... ~,- ~[~:~Y ~9 ¥~ N ~0 6 E 1.58 ~266,09 N 1~9~,25 E ~572,17 6000,00 ~272.3~ 6100,00 6200,00 ~37~,77 _6~_0_0.00 4q25,~9 6~00.00 q~76.21 6500.00 ~527.10 6600,00 ~579,21 6700,00 4634,96 6800,00 4695.55 6900.00 ~761.29 7000.00 ~831.15 -'00.00 490~.27 ~.,,00.00 ~980.95 7300.00 7~00,00 51~1-.0~+ 7500,00 5222,25 __ 7600,00 5304,27 7700,00 5387.16 7800,..p0 5470.81 7900.00 5555.18 5129.25 35 20 N 27 18 E .79 ~326,11 N 2099,26 E /+793,09 ......... -- .... '.~--~.~"~t~ ~,' ~"~'~'~_.Tm'~~.i.~:-~..~:-~.<::..'.-.::.:-'.,'.:~.' '.: :..'-:~."~::.:-...-":~:. :.~~--~: ..'-.':.. :..:.??:7:1~":'..:"~..~'.': =.'?. v- --7 '-'?-':".. ~:~'. ' ~-...'.:.:..."':':-:::'..::.:~::. '.:',T - 0~ 5211 · 27 :..,.';:::~--??:~.::- :3 ~'.~¥:2-7:; .?%?:'-:: .-~.:,'.::N::~,.:... 2 8?:.:::~?.~:~?E~.~:?~.?:~:?~:.~9:.8~:~?::~:.~.~.::?~i~:.3:::~76 "::78:.:'~:~:~N:::~??:?~:~??2:!-25:':'~8:;O::;~?~:E~:~?~:~;~:~:6-85 · 22 5~62.18 32 ~ N 29 36 E .9~ ~520.3~ N 2205.9~ E 501~.57 8000,00 5639,57 :?:.;'8200,~00 i~.:ii.i',:. 5809,26 "e oo.oo 8/+00,00 5981.96 5546.57 32 /+9 N 29 6 E .80 ~567.09 N 2232.I9 E 5068.20 ~~.~..~-~,~.-.~:-,.~'~~:~..::~.-:.::.~.~....~-::.:=~.:_::.~...-.~'~ ...: ' ~ ~ :.L-. '.:~:.~-~C-.'.:.::..:-.:.~.':'?:::}.."~:::~:-% '.~L~ .'~::-~::.:2,. ~..:.:-':~-~:.:-:~'.::?:~.:"..:':~-~-.'::.:'-~'~:~'~ 5802 · 33 : ~--~.:: ~ 0 "~ 16.:' :~:::.::.:~ ':?~ ." · N?': 3i'~.. 5 ~ ;..:"~:::~?-'.:?~-~::' ?:::;.:.,'.' 8'~:0 ~?:.-:~.. ~:~:~ ~::.:: :~?~:.'.;::~.:7. 02:-- .'I'1::'.: :N::' :~.~:~`~:~:~:~:~.~:~:.:.~1:.~i.~`:?6...~::.~D~:~:~:~:~.:~::~;?:.:5.22 ~ 92 5888.96 29 ~0 N ~2 ~2 E .72 ~7~,~'N 2~38.~5 E 527~85 ARCO ALASKA lB-10 G1 KUPARUK INC. NORTH SLOPE9 ALASKA ~OSS GYRO SURVEY NL SP[RRY-SUN INC. TRUE MEASURED VERTICAL DEPTH DEPTH BOSS-16933 ~500.00 6069.07 8600.00 6156.82 700.00 ;00 , 23.02 5976.U7 29 9 N 3~ ~48 E 1.15 ~785.16 N 2365.73 E 5323.,87 . ~~-,~'~ 9 ~- '"~_ -~ ~ ~-- ~'- ~~~~~~~"'~.0~~ :;, ,:-,:; :: ?~;....~}.;., % :.} ~:'.~: ~:.~: :.,:~ .-~::.:[:.?~-:.::~.~ .-~ .:-::%~ .'..-,; ~.:. ~ ~ ~ ~ ............ 6330.02 27 5 N ~1 0 E .70 ~932.27 N 2~79.77 E ~508.50 9000.00 9100.00 9200.00 6512.19 6z~19o19 26 /43 N 40 30 E .43 4966.55 N 2509.31 £ 5553.02 *--~,,"~~:'~~~?':"'~'y_~?..~'~ .. · ........... . .-.'.~,~'-' .-'-u.:,..:-:.:u..-:-::.,.-~....'~'~" ':~"':-~."'..'--.~.;.~:,~-....:.:~'.~'~::.~'..~-;..,- ~-~;~S'-~'~'h-'~ ~.' '~:<-,-.<.: :.:-:-'-: :./ : .' ' . ** THE CALCULATIONS ARE BASED ON THE MINIMUM RADIUS OF CURVATURE METHOD ** HORIZONTAL DISPLACEMENT = 5647.95 FEET AT NORTH 27 OE'g. 1 MIN. EAST (TRUE) KUPARUK ii. .... NORTH SLOPE9 ALASKA DOSS -GYRO SURVEY MEASURED DEPTH .93, 193, 493, 593, 695, 794. 894, 996, 1099, 120/+, 1426, 1545, 1666. I~.~1796, 1934, 2068. 2199. i 2526. 2450. '2573, .......'~..~..-.?.',-.'~...~.~.-~.~., ~.--..~. ~.~:~;. ,~-~..~.....~?...-,~-~-~.~..-~.;?N L:.~.-.-.$..~...~ E ~iR~.'!¥1~.:S~N.~ :?IN~ .......................... · ...... .~...~::~: ;~:~.:~-!:!i~!:?~_;.i:i~i.~!i~}i VERTICAL SUB SEA BOSS-16933 TRUE RECTANGULAR COORDINATES 2698. 2855. ~ ........ · ......... .,-'' ...',,,,;.'.'.-." '.-~ ;.;. · -- ~..~.~_...--. :''~:':'-;-.'._:'~.:u'_:..'.:'..: .... ..: '-- -:'~'~':'"-'~'-"':':'::'~'"'"'-2 ..2.-':.,-;::;-.',.:,:';'.,",?~.._.~.1~..~_~ ........ ~ 1393. 1300. -1300. 18A. N 69. E lZ+93. 1400. -1AO0. 240. N 98. E 3653. 1893. 1800. -l~lO0. 558. N 209, E 1993, 1900. -1900. 636. N 237. E 2393. 2300. -2300. 917. N 3ql. E 2493. 2~00. -2400. 1003, N 37~. E ~S~3. 2800. -2800. · Z477. N 56~. E 2995. 2900. -2900. 160A. N 617. F ARCO ALASKA INC. 1B-10 G1 KUPARUK NO~TH SLOPE, ALASKA BOSS GYRO SURVEY BOSS-16933 MEASURED DEPTH T ~ UE .. "'" .':::,::;'~":~ ~i :':;5:1.;: ::: ::i:~;i::: DEPTH TVD ELEVATI ON NOR TH/SOUTH EAST/WEST 3828°. 4008..: .92. 4559. 4736° 4915.. 5096. 52 54 79. 66. 3893. 3800. 3993. 3900. .................: ...:.................:..........:............,:.....~.. .. ..... ..: ..... : . ..........,.....:..................,..... ~ :::.::.::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::: ........ -.- _ t ::i ::?: ::::::::::::::::::::::::::::::::::::::: ::::::::::::::::::::::::::::::::::::::::::60 ..0--~::-' '::::.?'::: ;- :: :::::::::::::::::::::::::::::::::::::::::::::::::::: / t -3800. 2809, N 1232. E -3900. 2946. N 1310. E 5655. 5845. 6041. 6236, 6433. 6625. 6946. 7085. 7215. 4 793..., ...,.. :.--....:-:.-:,'. .... .:.:, .. 47 O O..-,.::.::: ..: ..,...::<: ::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::: 7:: .......... 4893. 48oo. -48 o. ....... - 4993. 4900. -4900. 4176. N 2022. E 7340, .. 7464, 75~6, .... ". ............ 7707. 7826. 5393. 5300, -5300. 4429. N 5493. 5~00. -5400. 4486. N 2155, E 2187. E ),.:.::.:: ..,.:::.~:::::::::::::::::::::: o ~., .:.. :.:::',...'.-:: .....::::..... ':: ..:: i':'..:":" ============================================================================ ::::::::::::::::::::::: . ,.'- .......: ,.:.... ::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::: 8297, 5893 o 8413. 5993. KUpA. .~UK. _ ' ..... ' NORTH SLOPE,~ ALASKA BOSS GYRO SURVEY BOSS-16935 HEASURED VERTICAL SUB SEA TRUE RECTANGULAR COORDiNaTES DEPTH DEPTH TVD '- ELEVATION NORTH/SOUTH EAST/~EST 8527. 8979. 6393. 6.300. 6~93, 6400. 9090. : :..:;:::i~?'!:i!..;:~: 6 ~"~ ~'"':;.:~ii:i;'i~!: !.'~ii~!~i~'ii~!;~::: :?~:.'g-'o i:~i INTERPOLATED COORDINATES FOR EVERY 100,00 FEET OF SUB-SEA DEPTH FROM 0.00 FEET TO 6599.72 FEET -: Suggested form to be insertcd in each "Active" well folder to c~,cck for timoly c~liance w'J.t~ our rc<julations. · ' ' Operator, Wel 1 ~ame and Number Reports ,and Materials to be reCeived by: ! ~t/:- ~ ~% Required Date Received Remarks Ccmpletion Report Yes Wel 1.' History'.~, Yes. ,,-~'-/~'--o · .. ,,, Core Chips. , ./~/t~' ,~7. ~ 4 . Core ~pcription ff~d ~-C~ ~?Registered Su~ey Plat ~ ...... ......... ._. . , ...... . Inclination Su~ey . ~P ......... Dire~ional Su~ey ,. ', ~a~ --Pr .. .. Drill St~ Test Re~s ~n ~C , , , , Pr~u~ion T~t Retorts'~ ~ . ' . . . , .... , ~S R~, Yes ' .. . . , , TRAi!SMITTAL ~ //~,/ Transmitted herewith are the following- .... PLEASE - BLUEL.TilE, · J. J. Pawelek/Ann Simonsen //d RECEIPT ACt,, ....... · ARCO ALAS!iA, INC. ATTN: ANN SIMONSE~! P.O. BOX 36O A~C''=~ .... Ar, 9c~10 DATE' RECEIVED FEB 0 1 19~2 Alaska Oil & Gas Cons. CommiSsion - A FA/311 kachorage TS' NORTii SLOPE E~:GIREER[i:G (" J. J. Pawelek/Ann Simonsen DATE: ,' / - Z ?- g' ~ WELL :-'~':F. . . · Tran's.mitt~d herewith are the following' pLc'C- . ,,~ ..~: NOTE - BLUEL!~:, SEPIA, · F - FILM, T - TAPE RECEIPT ,.Cm,O,';LEDGE . . .~,. .-N....DATE' · ARCO ALAS}iA, INC. ATT~!: AHN SIMO~iSE~! - AFA/311 P.O. BOX' 360 A:ICUORAGE ~" cc510 RECEIVED r E B 0 21982 Alaska. Oil & Gas Cons. Commission Anchorage TO' NOP,.TIi SLOPE r., .... ,_~,G I,Ir_r_P, I i,G J. J. Pawelek/Ann Simonsen D:ATE.' · / -- /~-'S ~ WELL h,~..,E'~" · · Trans.m.,itted here:.:ith ate the following' PLEASr NOTE BL - BLUEL!~,E, S - SEPIA, F - FILH, T - TAPE _ AlasKa Oi~ &z,.H .Gas Cons. ARCO ALAS~CA, INC. '"'c"°rau~ ATTIC: AHN SIMO~SE~ - AFA/311 P.O. BOX ~ . o60 , NORTH %LOPE ~,GI~.IEERIi,G TRAi~£HITTAL ~ //6~ ~ ~' J. J. Pawelek/Ann Simonsen .. Transmitted here:.:i th ar'e the '"fol 1 owi A'g- PLEASE HOTE' BL - BLUEL!HE, S - SEPIA, · .. ... F- FILM, T - TAPE RECETPT AC .... n.:- .... r,, i,..,.', L E E . ,,.;,mED. · _ _' ,'.~,u..~i REC~.~?T TO' ARCO ALASKA, INC. ATT~',,. A,'~l Sl~.~u~2r'~, - AFA/311 P.O. BOX 360 ArlCHORAGE, AK 99510 ,o RECEIVED JAN- q 1982 Alaska Oil & Gas Cons. Commi~io~ Anchorage ARCO Alaska, Inc. P~)Sl Offi(~e B 0 Anchorage, AIP,,~Ka 99510 Telephone 907 277 5637 December 22, 1981 Mr. Hoyl e Hamil ton State of Alaska Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Subject: DS ll-3, DS 12-8B, DS 12-14, DS 13-9, DS 13-10, DS 14-12,~DS 15-13, DS 14-13, lA-9, lA-10, B-9GI, B-IOGI Dear sir. Enclosed please find the following' 1. Monthly Reports for drill site 13-10, 14-12, B-IOGI. e Well Completion Reports for drill sites ll-3, 12-14, 13-9, 14-13, 15-13. e Completion Gyroscopic Surveys for drill sites 1'2-8B, 15-13, lA-9, lA-10 and B-9GI. Sincerely, P. A. VanDusen District Drilling Engineer PAV'GA-ltc RE£EIVED DEC 19al Alaska 0il & Gas Cons. Commission Anchorage ARCO Alaska, Inc. is a subsidiary of AtlanticRichfieldCompany ,.~ '~" ~" STATE OF ALASKA A'LASK~, '~ND GAS CONSERVATION COlt( :SSION MONTHLY REPORT DRILLING AND WORKOVER · Drilling well~ Workover operation [] 2. Name of operator 7. Permit No. ARCO Alaska, Inc. 81-135 3. Address 8. APl Number P. O. Box 360, Anchorage, Alaska 99510 5o- 029-20656 4. Location of Well at surface 494' FNL, 1302 FF.L, Sec. 9, TllN, R10F., UM 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. 93' RKB] ADL 25648. ALE 466 For the Month of NoYembeT 9. unit or Lease Name Kuparuk 25648 10. Well No. B-10GI 11. Field and Pool Kuparuk River Field Kuparuk Oil Pool ,19 81 12. Depth at end of month, footage drilled, fishing jobs, directional drilling problems, spud date, remarks Spudded well @ 2330 hrs., 11/14/81. Ran and cemented 13-3/8" csg. hole to 9400'~ as of 11/31/81 Drilled 12z See Attached Drilling History 13. Casing or liner run and quantities of cement, results of pressur9 tests 20", 91.5#, H-40 conductor to 80' . Cemented w/400 sx A.S. II 13-3/8", 72#, N-80 casing to 2547'. Cemented w/1600 sx Fondu and 400 sx A.S. II. See Attached Drilling History 14. Coring resume and brief description N/A 15. Logs run and depth where run None to Date. ~16. DST data, perforating data, shows of H2S, miscellaneous data RECEIVED'. DEC2 1981 Alaska 0ii & Gas 00ns. Commission Anchorage 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. G ~' ~' ~r SNI NED ~ ~ TITLESelIior Drilling Engineer DATE J2"Z-Z--'~I OTE--Repor ,on t i each calendar month, regardless of the status of operations, and must be filed in duplicate with the Alaska 'Oil and Gas Conservation Commission by the 15th of the succeeding month, unless otherwise directed. Form 10-404 Submit in duplicate Rev. 7-1-80 B-10GI Drilling History NU hydril and diverter. Spudded well @ 2330 hrs., 11/14/81. Drilled 173" hole to 2562'. Ran 64 jts 13-3/8" 72#/ft N-80 BTC csg. w/shoe @ 2547. Cemented 13-3/8" csg. w/1600 sx Fondu and 400 sx ^.S. II. ND hydril and diverter. Install 13-3/8" pack-off and tested to 2000 psi - OK. NU BOPE and tested to 3000 psi - OK. Tested casing to 1500 psi - OK. Drilled FC and cement o Tested casing to 1500 psi - OK. Drilled FS and 10' new fora. Tested fora to 12.5 ppg EMW - OK. Drilled 122" hole to 9400', as of 11/31/81. RECElVE ) DEC2 198t. Alaska Oil & Gas Cons. Commission Anchorage Cxmmissic~= ~- ....... ' .... November 24, 1981 To witness BOPE Test ARCO, Kuparuk Ri~er Field Well No. 1B-10G1 Sec. 3, TllN, R10E, Permit No. 81-135 November 17, 1981: I left AnChorage ~t ll:$0 a.~u by Wien A~rlines ~o Field, Well No. 1B-10G1 at 3:30 ~,'m..~ ' i . When I arrived on the locatic~ ~ 13 3/8 casing was not run. ~ 18, 1981: While I was~~ for the BOPE test at Kuparuk, I ~~ 19, 1981: I witnessed~the BOPE ~t:on~Arco's, Kuparuk River Field, ~ NO.-iB-10G1. ~ ~' ~ I filled out an A.O.G.C.C. re~ (a~ ~..~)., .... In ~, I witnessed the B0~ test on Arco's K~ Ri~er Field, O&G # 4 4/80 STATE OF ALASKA ALASKA OIL & GAS CONSERVATION COMMISSION B.O.P.E. Inspection Report Inspector Date_ Well Operator ~. /~ Well .!-~? /~ ~t Location: Sec Dr il ling. Contracto Rig #If / Representative ~,~,~/q f/ .,-~ // ,,,, ,,,,/ Permit # ~ / / ~ ~' /3 +/Casing Set Representative Location, Genera! Well Sign .... General Housekeeping Reserve pit Rig BOPE Stack Annular Preventer Pipe Rams Blind Rams Choke Line Valves H.C.R. Valve Kill Line Valves Check Valve Test Pres sure ACCUMULATOR SYSTEM Full Charge Pressure _~(f~ ~ psig Pressure After Closure ~ ~. ~-~ psig 200 psig Above Precharge Attained: --min~-~-sec Full Charge Pressure Attained: ~ min --,.sec N2~ d/..,~ (93'-'~,~ ?~,~ ~9.~~; ~.sig Controls: Master ~/~ Remote ~/~'Blinds switch cover~/~,. Kelly and Floor Safety Valves Upper Kelly. Lower Kelly Bal 1 Type Ins ide BOP Choke Manifold No. Valves. ? No. flanges ' /~ Adjustable Chokes ~ Hydrauically operated choke Test Pressure Test Pressure ~ Test Pressure '~ Test Pressure /u//& Test Pressure Test Results: Failures .,, 7-~/~/~ Test Time j2~ hrs. RePair or Replacement of failed equipment to be made within days and Inspector/Commission office notified. Distribution orig: - AO&GCC cc - Operator cc - Supervisor September 17, 1981 Mr. R. R. Reiley District Drilling Engineer Sohio Alaska Petroleum Company Pouch 6- 612 Anchorage, Alaska 99502 Kuparuk 25648, 1 B-10 GI ARCO Alaska, Inc. Permit No. 81-135 Sur. LoC.~ 494tFNL, 13021FEL, Sec 9, T11N, R10E, OM. Bottomhole Loc.= 883~FNL, 1577'FWL, Sec 3, TllN, R10E, OM. Dear Mr. VanDusen ~ Enclosed is the approved application for permit to drill the a bore re fe rented we 11. We1! samples and a mud log are rapt required. A directional survey is required. If available, a tape containing the digitized log information shall be submitted on all logs for copying except experim~ntal logs, velocity surveys and dipmeter 'surveys. ~anyyrivers in Alas.ka. and' their drainage systems have been claSsi~ied as important for the spawning or migration of anadromous fish. Operations in these areas are subject to AS 16.50.870 and the regulations promulgated thereunder (Title 5, Alaska Administrative Code). Prior to commen~ing operations you may be 'conta.~.ted by the Habitat Coordinator's office, Department of Fish and C~ame. Pollution of any 'waters of the State is prohibited by AS 45, Chapter 3, Article ? and the regulations Promulgated thereunder (Title 18, Alaska Administrative Code, Chapter ?0) and by the Federal ~ater Pollution Control Act, as amended. Prior to I ,I ~1r. P. A. VanDusen Kuparuk 25648, 1 B-10 GI -2- September 17, 1981 commencing operations you may be contacted by a representative of the Department of Environmental Conservation. To aid us in scheduling field work, we would appreciate your notifying this office within 48 hours after the well is spudded. i'?e would also like to be notified so that a repre- sentative of the Commission may be present to witness testing of blowout preventer equipment before surf'a,ce caaingehoa is drilled. ' In the event of suspension or abandonment, please give this office adequataadvance ,not:i.fioation so' t~hat we may ha,ve a ~1j. tness presen,t. Very truly yours, ;1"""/ . ..,/ I' ,,' ,/ ".,p~/~ ,At, 1&"""", ""/1","" ~,,' " """"'~,' .., ,1" ",,""" ,.-' :;;.;>' ,t ~l """:",-:;.?","'-J'ft.:,~~p',,' /?? ,~~P?J-t. . ,~' "i" \I~.¿7J.."". ¡" 17' ¡7' V t." {/ Eoyle H. H:amilton , SIaN C11airman of ,BY'f)RDER Of JHJ; !COMMIS ' Alaska Oil &£ Gas Conservation ComIn1ssion Enclosure oc: Department of Fish &. Game, Habitat Section w/e encl. Department of Environmental Conservation 'iJl1olencl. tUH~: J)Q. .'-"'-'-"'-'- --,-,-,-"'_....- -.,--..- - -,--- --",,-,,-"- -,--,-,'- --"',-- ARCO Alaska, Inc. Post Office B~.. ,:t60 Anchorage, Alaska 99510 Telephone 907 277 5637 August lO, 1981 Mr. Hoyle Hamilton State of Alaska Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Hamilton: ARCO Alaska, Inc. proposes to drill a development well, Kuparuk 1 B-10 GI, commencing on approximately October 27, 1981. Attached please find: 1. A "Permit to Drill" application form. 2, A plat showing a) surface and target locations, b) ver- tical directional planning. e e A plat showing the proposed, wellbore in relation to other wells within 200' and other wells on B pad & B pad extension. A determination of maximum pressure to which BOPE could be subjected. Be Diagrams and operational procedures for the 20" 2000 psi diverter stack,and 13-5/8" 5000 psi RSRRA stack. Please feel free to contact us at 263-4270 if we can be of any assistance. Sincerely, P. A. VanDusen District Drilling Engineer PAV/ELP:sp Attachments ARCO Alaska, Inc. is a subsidiary of AtlanticRichfieldCompany C STATE OF ALASKA 0(.~ ALASKA ,L AND GAS CONSERVATION C ,MISSION PERMIT TO DRILL 20 AAC 25.005 la. Type of work. DRILL REDRILL DEEPEN lb. Type of well EXPLORATORY [] DEVELOPMENT OIL [] DEVELOPMENT GAS [] SERVICE DO STRATIGRAPHIC [] SINGLE ZONE MULTIPLE ZONE [] 2. Name of operator ARCO Alaska, Inc. 3. Address P.O. Box 360, Anchorage, Alaska 99510 R£ EIVEa 4. Location of well at surface -- 494'FNL, 1302'FEL, Sec 9, TllN, RIOE, UM SEP1 z~ 198I At top of proposed producing interval 1320'FNL, 1320'FWL, Sec 3, TllN, RlOE~Oii&GaSCons. Comm~a. __ At total depth '"'ChOr'~'"O'"u 883'FNL, 1577'FWL, Sec 3, TllN, RIOE, UM 5. ElevatiOn in feet (indicate KB, DF etc.) I 6. Lease designation and serial no. 62GL/ 66 Pad/ 93 RKB I ADL 25648, ^LK 466 9. Unit or lease name Kuparuk 25648 10. Well number 1 B-lO GI ~J-~Field and pool Kuparuk River Field Kuparuk River 0il Pool 12. Bond information (see 20 AAC 25.025) TypeStatewide 0il & Gas Surety and/or number Fed ]:ns Co. 8088-26-27 13. Distance and direction f~(~li~arest town 14. Distance to nearest property or lease line NW of Deadhorse, 30 miles 1320 at Target, 883 at TD feet 16, Proposed depth (MD & TVD) 17. Number of acres in lease 9225MD = 6949 TVD feet 2560 19. If deviated (see 20 AAC 25.050) 120. Anticipated pressures KICK OFF POINT 500 feet. MAXIMUM HOLE ANGLE 45 Ol(see2OAAC25.035(c) (2) Amount $500,000 15. Distance to nearest drilling or completed we, 1 60' to 1 B-11 GI feet 18. Approximate spud date at surface 11-1-81 2605 ,psig@ ~U-I' Surface __32,~6_0__ psig@ _64_4 3 _ft. (TVD) 21 Proposed Casing, Liner and Cementing Program SETTING DEPTH QUANTITY OF CEMENT SIZE Hole I72"Casing 30" ! 20" 17½" ~3-3/8" 72# 12¼" /9-5/8" 47# 22. Describe proposed program: Weight Corrug~ 9,1.5# Gradec~IC~ L-80 L-80. CASING AND LINER ,upling ~tedarlded Length 80' 3204' 9225' MD TOP TVD Surfac6 Surfac~ Surface Surfac~ M D BOTTOM TV D 5' ~5' 80' Ii80' · 3204' ~ 2700' 9225'1 6949' I I (include stage data) Backfilled 400ex AS II 2000ex Fondu + 300ex 500ex Ext G + 300ex G ARCO Alaska, Inc. proposes to drill a Kuparuk River Field Gas Injection Well to 9225' MD = 6949' TVD. A 20" 2000 psi annulur diverter will be install.ed on the 20" conductor while drilling the surface hole. A 13-5/8" 5000 psi RSRRA BOP stack will be installed on the 13-3/8" surface string & tested upon installation and weekly to 3000 psi. The well will be completed w/4½" tbg and pkr. Non-freezing fluids will be left 'in uncemented annul i thru the permafrost interval. Selected intervals will be perforated within the Kuparuk formation for injection and reported on subsequent report. A downhole safety valve will be installed with the completion string and shut and tested upon conclusion of job. 23. I hereby certify that the f_oregoing it, true and correct to the best of my knowledge SIGNED _~,~, '~i~~~~-~.. TITLEDist. Drilling Engineer DATE The space below for Commission use CONDITIONS OF APPROVAL ,, Samples required Mud log required I--lYES ~JO []YES '~O Permit number Approval date $ )- 13S~' 09/17/81 Directional Survey required ~-Y ES []NO IAPI number 50- Ol~?-~0 SEE COVER LETTER FOR OTHER REQUIREMENTS September 17, 1981 APPROVED BY ,COMM ISSl ON ER DATE by order of the Commission IS I Form 10-401 Rev. 7-1-80 Submit in triplicate F~ :""- ~l ' ': .... ' ...... ff ................. "--:'~ ...... ---~-: ............... '": I~ ..... ~ .................. : ..... : ....... : ......... i ............... I ~ ;.~= ~ ~ ,~ ~P~,B, ~L O. IB9 ~. 0 !B ~I ....... ~ ........... ~ ....................... ~.._~ ........... ~ ............. ~....~_. ........... ............... .............. ......................... ,._ .... .................. ........ ...... ._. , ~ ~ ' ~ -:1 ~0 ........ ~ .............. ~': .... ~ ....... ~ ....... , ...... ~ ........... ~ .............. ~ ~" ............. { ..... ~ ............... ~--"-':"~":': ........... {": "':-:"~'"~"-~. { :~ ., :-:.-.--~--~ .......... ,.-~--~~ ~IPST~,-;.i~ ...... -.~-~ ............... /--.F--.,-: ...... : ........ ~..~ ............... : ......... ,---:~ ................. ~ .......... ~---, ....... :~--~: .i.:L ~ ~: ; ~':: :::::: :'::~ ;'i~:: ~:~::.':::::-::: :::::~' ::::::::::::::::::::::::::::::::::::: :::::::::::::::::::::::::::::: ::::::::::::::::::::::::: :::- ::::::: ~::: ~-:: ::::':-:':: ' ~i[~ '~ ~.-~ ........ ~ ..... - .... ~-'-: .............. : .... :-'-~t ..... :--:-f'-: ....... :---tt~-.-:--m ...... :-:--""h: .......................... ~'-t .... : ................ f~--18~ .... :--?- -~-.:~-.-:~---:---~: ......... : .... ~:- :-:-: ...... :-:---: ........ : ......... i.-::- :--:~-{--.:-:-=--.-.{--~ ...... --~ .......... ~ ..... 7.-', ...... ~ ........ : .... :: ................. _~ ,.._:._~_:_~._:. :..../:..:...:__..;_z._~_~ :_~ ~:~- "~:?" :: ~ : ::L:::L: ['::-.T:~: L~'::'Z2::::L:.~':': L :J::- :LL~'.: ~:C'::~ ~ L. : :3 {:':..: ::L.I::/_:L::'.4 ::: : ~L :L.' :..': ::':....~ :L'L: ::::~.{.~ : [~ · :' :':: .~.::: ::: :: '::: :.LL::: },~ = ~ . ,, ~ : ~ .~ ,, . : . ~ ~ , ~:':.::, /: ,~:'~ ~ , ~ , ,~i~ ~ , ' , , ~ , ~ , ~ ~ , { ~ I . ~ , , , ~ ~ ~ ...... _ =~ . 21~ ............. ~-~' -= ................... = ........... t ............................ - ~ ~- - - '>_~ .-X:~ :Z 7'7 ~ LZ.~::::' :~ ~_:::~-2",.- '": ~.~ ~'2::2::' :~::::L~j.~:~ 7-: : : :::::~ ~-~-~: .'::~:~ -:~ ::::~: :~.~:~::.:: :-~: ' ..... ~- -~- ---~"~ - ' ~ , "* ~ ' , · ' - ,'~ ~ ~ - ~ ~'~ ~-:'~ .... ~- ~'~ ~,~-{.- , ~ ..-~ ......... ~:~ .... .~ ....... ~ , . , . , ,_~_._, ....... , ~ .~ .... ~.-~-;~-' ~ ~:' , ~. ,. .,~ ., ~_~_~.~ ....... L: .......... ~.: --:.=--~ :~.- -4 ..... ~_~.. : .... :-. -= .... L -~4 -~-:--, ........ ~--~ ......... · - - ~. ' ......... ~-~ ...... :-~ ~ -~ -~-.~ .... ~-~-.~-~-~ -.-~- ~- "~ i ~"F---~--m-~t .... '~ , ':": '~'~ ~ '~-f~nn~-~'- '~'"'~'-~ ..... ~--?-'-~ ~"-~-:'~'~'-f'-f--->'~- ~--~-- :-4-~-~ -~+~-~ ~"'+~'~"'-~'~-'~--'f'-?:f-'--~-~--'-f-~b ~z- '~:~~:~:' :,~- ~.,, ,,, ~ ,,,,- ,,~ ~,:,, .~ '-?~ ~ ~'~"~:~:"'~,-,,~: '.':? ~::, ~,,,. ':.. :~ .:, ~., :. ~ :". :" :' ~-t-'/: :':'f'. ': :' ~":" ;-'~'-~:-': .... f~",--: ~:-L:-"I_'. L:~'j-:"J-~:' %:'. }":'. ?"~-f':'-'~ ...... ?" '-~-~- ~--F -,4-,p~- ...... : - T . > h. ~ ~ .,,,.. . "i'll !~1' li~lOE.~ U.M. 43 ANTICIPATED PRESSURES Expected reservoir pressure in the Kuparuk interval has been determined to be 3275 psia = 3260 psig from RFT & pressure buildup date. This pressure @ 6350' SS = 6443' TVD will be balanced by 9.8 ppg mud wt. Normal drilling practice calls for a 10.4 ppg wt prior to penetration and during drilling of the Upper Kuparuk and remaining intervals. This will result in a 201 psi overbalance. It is anticipated the surface BOPE equipment could be subjected to a max- imum of 2605 psig during drilling operations. Derivation assumes a gas kick at reservoir temperature and pressure (165_°F, 3275 psia), gas migration to the surface w/o expansion, and cooling to '40°F summer cellar temperature. This is well below the 5000 psig BOPE working pressure and less than the 3000 psig weekly test pressure. Pi = pressure initial (reservoir) Ti = temperature initial (reservoir) Vi : volume initial (.reservoir) Pf = pressure final (surface) Tf : temperature final (surface) Vf : volume final (surface) PiVi = PfVf Since Vi = Vf ie no expansion. Pi = Pf Then Pf = PiTf = (3275 psia)(40°F + 460) T'i" ~ff Ti (165'0F + 460) Pf = 2620 psia = 2605 psig e Surface Diverter System 20" Bradenhead. 20" 2000 psi drilling spool w/10" side outlets. 10" ball valves, hydraulically actuated, w/lO" lines to reserve pit. Valves to open automati- cally upon closure of annular preventer. 20" 2000 psi annular preventer. 20" bell nipple. Maintenance & Operation 1. Upon initial installation close annular preventer and verify that ball valves have opened properly. 2. Close annular preventer and blow air through diverter lines every 12 hours. 3. Close annular preventer in the event that gas or fluid flow to surface is detected. If necessary, manually over- ride and close ball Valve to upwind diverter line. Do not shut in well under any circumstances. ( ~-5/8 " 5000 PSI RSRRA BOP STACK aNNULAR PREVENTOR g BLIND RaHS 8 ) PIPE RRMS I 2. 3. 4. ,,) 7 6----- ( ,,, TBG 20" slip on 2000# WP Bradenhead. 20¼" x 13-5/8" 5000# WP casing head. 13-5/8" x 13-5/8" 5000# WP tubing head. 13-5/8" x 13-5/8" 5000# flange by Graylok Hub adapter spoo 13-5/8" 5000 psi 13-5/8" 5000 psi and kill lines. 7. 13-5/8" 5000 psi pipe rams. 8. 13-5/8" 5000 psi blind .rams. 9. 13-5/8",, 5000 psi annular. · pi pe rams. drilling spool w/choke ACCUIULATOR CAPACITY TEST 1. CHECK AND FILL ACCUNULATOR RESERVOIR TO PROPER LEVEL WITH HYDRAULIC FLUID. 2. ASSURE THAT ACCUIULATOR PRESSURE IS 3000 PSI WITH 1500 PSI DOWNSTREAI.1 OF THE REGULATOR. 3. OBSERVE TIHE THEN CLOSE ALL UNITS SIHULTANE- OUSLY AriD RECORD THE TII,1E AND PRESSURE REHAIN- ING AFTER ALL UNITS ARE CLOSED WITH CHARGING PUHP OFF. 4. RECORD ON IADC REPORT, THE ACCEPTABLE LO'.~ER LIMIT IS 45 SECO;;DS CLOSIHG TIHE AND 1200 PSI RENAINING PRESSURE. 13-5/8" BOP STACK TEST l. FILL BOP STACK AHD MANIFOLD WITH ARCTIC DIESEL. 2. CHECK THAT ALL HOLD DO',,~N SCRE'~S ARE FULLY RE- TRACTED. PREDETERHINE DEPTH THAT TEST PLUG WILL SEAT A~;D SEAT IN WELLHEAD. RUN IN LOCK DO',,~N SCREWS IN HEAD. 3. CLOSE ANHULAR PREVENTER AND CHOKES AND BYPASS VALVES Oil I4ANIFOLD. 4. TEST ALL CCMPO~;E;;TS TO 250 PSI AND HOLD FOR lO MINUTES. 5. INCREASE PRESSURE TO 1800 PSI AND HOLD FOR l0 MINUTES. BLEED TO ZERO PSI. 6. OPEN ANNULAR PREVENTER AND CLOSE TOP SET OF PIPE RAHS. '. 7. INCREASE PRESSURE TO 3000 PSI AND HOLD FOR l0 IqINUTES. 8. CLOSE VALVES DIRECTLY UPSTREAI.I OF CHOKES. BLEED DOWNSTREAH PRESSURE TO ZERO PSI TO TEST VALVES. TEST RF_NAINING UNTESTED NANIFOLD VALVES, IF ANY, WITH 3000 PSI UPSTREAM OF VALVE AND ZERO PSI DOWNSTREAM. BLEED SYSTEM TO ZERO PSI. - 9. OPEN TOP SET OF PIPE RA~-IS AriD CLOSE BOTTC;,! SET OF PIPE ,RAMS. 10. INCREASE PRESSURE TO 3000 PSI AND HOLD FOR l0 HIHUTES. BLEED TO ZERO PSI, ll. OPEN BOTTOH SET OF PIPE RAHS. BACK OFF RUN- NING JOIHT AND PULL OUT OF HOLE. CLOSE ~LIND PillS AND TEST TO 3000 PSI FOR lO HINUTES. BLEED TO ZERO PSI. 12. OPE;I BLI~iD RA~,IS AND RECOVER TEST PLUG. MAKE SURE HANIFOLD A;;D LI,qES ARE FULL OF ARCTIC DIESEL AND ALL VALVES ARE SET IN DRILLI~;G POSITION. 13. TEST STANDPIPE VALVES TO 3000 PSI. 14. TEST KELLY COCKS A;(D INSIDE BOP TO 3000 PSI WITH KCO;:EY PUHP. 15. RECORD TEST I:lFO,~.IATIO,q ON BLO'JOUT PREVENTER TEST FORt.! SIGN AND SEHD TO GRILLI~;G SUPE.~- VISOR. 16. PERFORI! CC~':PLETE BOPE TEST ONCE A WEEK A:~D FUNCTIO~ALLY OPERATE BOPE DAILY. CHECK LIST FOR NEW WELL PERMITS Company Lease & Well No. ITEM APPROVE DATE (1) Fee ~-I~'~/ ,(~thru 8) . (3) Admi____~n (/ thru 11) (4) Casg ~ ~//~JS[ (12 thru 2~0)' ¸2. 4. 5. 6. 7. 8. o 10. 11. 12o 13. 14. 15. 16. 17. 18. 19. 20. YES NO Is the permit fee attached .......................................... ~ Is well to be located in a defined pool ............................. Is well located proper distance from property line .................. ~ .... Is well located proper distance from other wells .................... ~ Is sufffcient undedicated acreage available in this pool ............ Is well to be deviated and is well bore plat included ............... ~. Is operator the only affected party ................. ~i; ~.[.1...~.[. ~ · ......__ Can permit be approved before ten-day .... ''''..''~ Does operator have a bond in force .................................. Is a conservation order needed ...................................... Is administrative approval needed ................................... Is conductor string provided ........................................ Is enough~cement used to circulate on conductor and surface ......... Will cement tie in surface and intermediate or production strings Will cement cover all known productive horizons ..................... Will surface casing protect ~fresh water zones ....................... Will all casing give adequate safety in collapse, tension and burst..~ Is this well to be kicked off from an existing wellbore ............. Is old wellbore abandonment procedure included on 10-403 ............ Is adequate well bore separation proposed ........................... REMARKS (5) BOPE~ ~//~/~ (21 thru 24) d ~ (6) A d: ~ ~/Tg/~ 21. 22. 23. 24. 25. Is a diverter system required ....................................... Are necessary diagrams of diverter and BOP equipment attached ....... ~.~ Does BOPE h'ave sufficient pressure rating - Test to Does the choke manifold comply w/AP1 RP-53 (Feb.78) .................. Additional requirements ............................................. Additional Remarks: Geology: Engine~.ring: HWK ~ LCS.,~/~- BEW~~ WVAJAn JKT,,, ~ rev: 03/10/81 INITIAL I GEO- UNIT ION/OFF POOL CLASS STATUS AREA NO. . SHORE Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file, To improve the readability of the Well History file and to simplify finding information, information, of this nature is accumulated at the end of the file under APPENDIXi No 'special'effort has been made to chronologically organize this category of information. ~mm~mmmmmmmmmmmmmmmmm~ ~----BCHLUMBERGER----~ LIS TAPE VERIFICATION LISTING LVP 009.H05 VERIFICATION LISTING PAGE ** REE~ HEADER ** SERVICE NAME :SERVIC DATE :8i/i2/11 ORIGIN ~ REEL NAME :REEL ID CONTINUATION # PREVIOUS REEL COMMENTS :REEL COMMENTS ** TAPE HEADER ** SERVICE NAME :SER¥IC DATE :~i~0 ORIGIN : TAPE NAME :62346 CONTINOATION ~ :01 PREVIOUS TAPE COMMENTS ~TAPE COMMENTS EOF ** FI. hE HEADER FILE NAME :SERVIC.O01 SERVICE NaME VERSION # DATE : MAXIMUM LENGTH : 1024 FILE TYPE PREVIOUS FILE ** INFORMATION RECORDS MNE,~ CONTENTS CN : WN : FN : RANG: TOWN: SECT: COUN: STAT~ CTRY: ATLANTIC RICHFIELD COMPANY B-10 K[]PARUK lin NORTH SLOPE AbASKA USA CONTENTS PRES: NEDIT4F RECORD TYPE 047 ** UNIT TYPE CATE SIZE CODE 000 000 026 065 000 000 004 065 000 000 008 065 000 000 003 065 000 000 003 065 000 000 001 065 000 000 012 065 000 000 006 065 000 000 004 065 UNIT TYPE CATE SIZE CODE 000 000 O07 065 LVP 009.H05 VERIFICATION LISTING PAGE 2 RECORD TYPE 047 *~ RECORD TYPE 047 ~ JOB # 10707 62346 COMPANY NAM~ = ATLANTIC RICHFIELD COMPANY WELL NAME : B-lO FIELD = KUPARUK COUNTY = NORTH SLOPE SECTION : 09 TOWNSHIP = RANGE : 10E DIL RUN ~1~ LOGGED 29'NOV'S1 BOTTO~ LOG INTERVAL = 9392.0 FT. TOP LOG INTERVAL CASING'LOGGER BIT SIZE TYPE HOLE FLUID DENSITY VISCOSITY PH FLUID 50S$ RM 9 MEAS, TEMP. RMF 9 MEA$, TEMP, RMC @ ~EA$. TEMP. RM ~ OHT 13.3 IN. ~ 2539 FT. 12,25 IN. X C POLYMER 10.$ LB/G 63.0 S 9.0 5.0 C3 3.520 O~M $8 DF 2.150 OHMM 9 68 DF 1.652 OHM ~ I DF LVP 009.H05 VERIFICATION LISTING PAGE 3 ** DATA FORMAT RECORD *~ ENTRY BLOCKS TYPE SIZE REPR COiDE 4 I 6 6 8 4 73 9 4 65 0 ! 66 DATUM SPECIFICATION BLOCKS MNEM SERVICE SERVICE UNIT API APl API API FILE ID ORDER # LOG TYPE CLASS MOD NO. DEPT FT 0 0 0 0 0 SFLU I$ OHMM 0 0 0 0 0 IbM IS OHMM 0 0 0 0 0 ILD I$ OH~ 0 12 46 0 0 SP IS MV 0 I 0 0 0 GR IS GAPI 0 3! 32 0 0 DT IS U$/F 0 52 32 0 0 NPHI FDN PU 42 68 2 0 0 RHOB FDN G/C3 42 35 I 0 0 DRHO FDN G/C3 42 44 0 0 0 CALI FDN IN 42 28 3 0 0 GR FDN GAPI 42 31 32 0 0 NRAT FDN 42 42 1 0 0 NCNb FDN 42 34 92 0 0 FCNL FDN 42 34 93 0 0 DATA ** DEPT 9407 000 SFLU 2.396 IbM SP '13:477 GR -1025 000 DT RHOB -999.250 DRHO -999~250 CALI NRAT -999.250 NCNb -999.250 FCNL DEPT 9400.000 SFLU 2,4i0 ILM SP -87,688 GR -1025o000 DT RHOB -999'250 DRHO -999.250 CALf NRAT -999.250 NCNb -999.250 FCNb DEPT 9300.000 SFLU 2.506 IbM SP -8.266 GR 93.250 DT RHOB -999 250 DRHO -999 250 CALI NRAT '999:250 NCNL '999:250 FCNL ENTRY 6O ',lin 0 SIZE 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 LEVEL. 0 0 0 0 0 0 0 0 0 0 0 0 2 100 -999 -999 2 100 -999 -999 2 109 -999 -999 .162 .000 ,250 .250 .158 ,000 ,250 ,250 ,563 .250 .250 NPHI GR IbD NPHI GR GR SAMPLE ! REPR CODE 68 68 68 68 68 68 68 68 68 68 2,982 -999.250 -999.250 2.262 999.250 1,883 -999,250 -999'250 LVP OOg,H05 VERIFICATION LISTING PAGE 4 DEPT SP RHOB NEAT DEPT SP RHOB NEAT DEPT SP RHOB NEAT DEPT SP RHOB NEAT DEPT SP RHOB NEAT DEPT SP RHOB NEAT DEPT SP RHOB NRAT DEPT SP RHOB NEAT DEPT SP RHO8 NRAT DEPT SP RHOB NEAT 9200.000 SFLU 3 -10.008 GR 70 2.463 DRHO 0 3.137 NCNb 2013 9100.000 SFLU 3 -14.797 GR 73 2.459 DRHO 0 3.203 NCNL 2106 9000.000 SFLU 6 -17.938 GR 70 2,~I DRHO 0 3.0 3 NCNb 2146 8900.000 SFLU 3 750 GR 80 8800,000 SFLU 3 -18,922 GR 93 2.500 DRHO 0 3.225 NCNb 211B 8700.000 SFbU '7,438 GR 104 -999.250 DRHD -999 -999,250 NCNL -999 8eO0.O00 SFbU 2 9,484 GE 120 -9;9,250 DRHO -999 -999.250 NCNb '999 8500.000 SFLU 2 -6,969 GE 227 -999.250 DRHO -999 -999.250 NCNL -999 8400.000 SFLU 3 -19.125 GE 133 -999.250 DRHO -999 -999.250 NCNL -999 8300,000 SFbO 3 -9.344 GR 103 -999.250 DRHO -999 -999.250 NCN5 -999 DEPT 8200.000 SFbU 4 SP -i5.688 GR 103 RHOB -999,250 DRHO -999 .5 .7 .0 .0 .5 .1 .0 .0 .6 ,1 .0 ,0 .5 .0 .0 .0 .2 .I .1 .0 55 50 16 O0 20 26 O0 68 07 O0 51 63 08 O0 79 25 O0 O0 634 '625 . :2so 250 .289 312 '250 m .250 .391 .500 ,250 .250 025 000 250 250 760 125 250 250 355 500 250 DT FCNb IbM DT CALl FCN5 IbM CALI FCNb CALI FCNL CALI FCNL DT CALI FCNL IbM DT CAb[ FCNb DT CALl FCNL IbM CALI FCNL DT CALl FCNb DT CALI 3.164 94.375 13.148 691.000 687, 5.520 13 73 792 O0 ,564 8 ,~88 14, 13 t029,000 93, 5 14.961 646.500 1,~33 126, 88 -999.25O -999.250 I 776 i16i188 -999 250 -999 250 051 :ooo '999,~50 '999, 50 2,596 115,563 '999,250 '999,250 2.506 - '250 -999 250 10; '383 .188 -999.250 J NPHI GR ILD GR ILD NPHI GR NPHI GR NPHI GR NPHI GR NPHI GR ILO NPHI GR IbP NPHI GR IbP NPHI GR IbP NPHI GR 3,006 32,275 78.312 3 402 33i154 85 500 5,.262 30.469 71,250 3,438 23.779 74,688 3.320 32,9~0 110.0 0 1,497 -999.250 -999,250 I 653 -999:250 -999.250 1.943 -999 50 2.574 -999 250 -999:250 2.354 -999'25O -999'250 .336 -9 ,250 -9 ,250 bVP 009.H05 VERIF NRAT DEPT SP RHOB NRAT DEPT SP RHOB NRA~ DEPT RHOB NRAT DEPT SP RHOB NRAT DEPT SP RHOB NRAT DEPT SP RHOB NRAT DEPT SP RHOB NRAT DEPT SP RHOB NRAT DEPT SP RHOB NRAT DEPT SP RHOB NRAT DEPT SP ICATION LISTING -999.250 NCNb BIO0.O00 SFbU -8.063 GR -999,250 DRHO -999,250 NCNb 8O.0O 00 SFLU .-999 250 DRHO 999:250 NCNb 7900.000 SFLU -24 4220 GR -999: 25 DRHO -999,250 NCNb oo.ooo 9 250 DRHO 99 250 NCNb 7700.000 SFbU -10.023 GR -999,250 DRHO -999.250 NCNb 7600.000 SFLU -11,984 GR -999,250 DRHO -999,250 NCNb .. 7500.000 SFbU -14,992 GR -999*250 DRHO -999,250 NCNb 74~0 000 SFbU - 0:961 GR -999,250 DRHO -999'250 NCN[~ 7300,000 SFLU ":1.0,508 GR '999,250 DRHO -999,250 NCNb 7200.000 SFbU -7,438 GR -999.250 DRHO -999'250 NCNb 7100.000 SFLU '8,109 GR -999.250 FCNb 4 484 i08,'000 DT -999.25o CALl -999,250 FCNI~ 3 230 IbM 999 50 FCNL 13 875 DT -999.250 CALI -999.250 FCNb ! 65O InM 145:000 DX -99 250 CALI 2,865 IbM 170.625 DT -999.250 CALl -999.250 FCNb 7,535 IbM 83.500 DT -999.250 CALl -999,250 FCNL 3.418 IbM 141.750 DT -999 250 CAbI '999:250 FCNb 2,461 IbM 104,125 DT '999.250 CAbI '999.250 FCNb 2.391 IbM 100,625 DT -999'250 CALI -999,250 FCNb 2.553 IbM 66.688 DT -999 250 CALf '999:250 FCNb 2.109 IbM 90.500 DT '999,250 2.883 IbD 116 375 NPHI -999:250 GR -999'250 2,338 IbD 108'188 NPH[ -999:~50 GR -999. 50 2.756 II.D 12I 563 NPHI -999.'250 GR '999.250 I0~,678 IbD ,750 NPHI -999'250 GR '999,250 2,285 IbD 105,188 NPHI '999,250 GR '999,250 6,449 IbP 78'563 NPHI -999'250 GR -999.250 3,377 IbD 107,188 NPH[ -999.250 GR -999,250 2,461 IbD 107,000 NPHI -999,250 GR -999'250 2.256 IbD 109.563 NPHI -999,250 GR '999,250 2,613 IbD 101,563 NPHI -999.250 GR '999,250 2.074 IbP I06.000 NPHI PAGE 2.789 -999,250 -999.250 2.303 -999,250 -999.250 2,705 -999.250 -999,250 1.711 -999,250 -999.250 2.176 -999'250 -999:250 6.055 -999,250 -999.250 3,350 -999.250 -999.250 2,428 -999.250 -999,250 2,240 -999.250 -999.250 2,615 ~999,250 999,250 2,063 -999.250 bVP 009.H05 VERIFICATION bISTING PAGE 6 RHOB -999.250 DRHO NRAT -999,250 NCNb DEPT 7000.000 SFbU Sp -10.727 GR RHOB '999.250 DRHO NRAT '999,250 NCNb oo.ooo NRAT '999.250 NCNb DEPT 6800,000 SFLU Sp -8,953 GR RHOB -999.250 DRHO NRAT -999.250 NCNb DEPT 6700.000 SFLU SP -10.172 GR RHOB -999.250 DRHO NRAT -999.250 NCNb DEPT 6600.000 SFbU Sp -lO 227 GR RHOB -999i250 DRHU NRAT -999'250 NCNb DEPT 6500.000 SFhU SP -10.273 GR RHOB -999,250 DRHO NRAT -999.250 NCNb Sp '~ .164 GR RHOB 9 .250 DRHO NRAT -999.250 NCNb DEPT 6300,000 SFLU Sp -12,203 GR RHOB -999.250 DRHO NRAT -999.250 NCNb DEPT 6200.000 SFbU Sp -13.461 GR RHOB -999.250 DRHO NRAT -999.250 NCNb DEPT 6100.000 SFLU Sp -~9~.047 GR RHOB -9 .250 DRHO NRAT -999.250 NCNb DEPT 6000.000 SFLU '999,250 '999,250 2,090 88.938 -999,250 -999,250 2.947 80.813 -999.250 -999.250 2.889 83.000 -999.250 -999.250 2.684 96.688 -999.250 -999.250 2.320 88.625 -999.250 -999.250 2.547 76.250 .-999,250 999'250 4.250 84 875 -999!250 -999 250 2,727 117,938 '999,250 '999.250 2,777 98.000 -.999.250 999.250 3,123 84,000 -999,250 -999,250 4.148 CALI FCNL IbM DT CALI FCNL DT CALI FCN5 ILM DT CALI FCN~ DT CAhI FCNh DT CALI FCN5 DT CALI FCN~ IbM DT CALI FCNb IbM DT CALl FCN5 DT FCNb I~ DT CALI FCNL -999,250 -999,250 2.188 -9 50 -999.250 2.982 98.t88 -999.250 -999.250 3,057 101,563 -999'250 -999,250 2,836 107,000 -999,250 -999,250 2.594 107.750 -999.250 -999.250 2.865 107.375 -999 250 -999."250 4.473 ,75 -9 25O0 -999,250 3.098 1t2.563 -999'250 -999,250 3,031 113,188 -999,250 -999.250 3.439 ,250 999.250 4.320 GR NPHI GR NPHI GR NPHI NPHI GR NPHI GR NPHI GR NPHI GR NPHI GR NPHI GR NPHI GR -999,'250 2. 197 -999, 0 3.545 -999'250 -999.250 3,143 -999,250 -999,250 2,926 -999,250 -999,250 2 645 -999:250 -999.250 2,955 -.99 250 99~:250 4 434 '999:250 '999,250 3,279 -999'250 -999,250 3.174 -.999.250 999,250 3 619 -999.250 4.598 bVP 009.H05 VERIFICATION LISTING SP -14.742 RHOB -999 250 NRAT -999:250 DEPT 5900.000 NEAT 99 250 DEPT 5~00 O0 ' 52 RHOB -999,250 NEAT -999,250 DEPT 5~00 000 RHO9 2.283 NEAT 3.697 DEPT 5600.000 SP -14.602 RHOB ~,271 NRAT .'572 DEPT 5500,000 BP -20,4§2 RHDB 2,3 5 NEAT 3.449 DEPT 5400.000 SP -14.102 RHOB 2 295 NRAT 3:494 DEPT 5300.000 SP -15,758 RHOB 2,279 NEAT 3.484 DEPT 5200.000 SP -20.250 RHOB 2,191 NEAT 3.400 DEPT 5100,000 SP -32.406 RHOB 2.285 NEAT 3,695 DEPT 5000 000 SP "29i734 RHOB 2 199 NEAT 3,604 DRHO NCNb BFLU GR DRHO NCNb SFLU OR DRHO NCNb SFLU GR DRHO NCNb BFLU GR DRHO NCNb 8FbU GR DRHO NCNb BFLU GR DRHO NCNb SFLU DRHO NCNb SFbU GR DRHO NCNb SFLU DRHO NCNb SFLU DRHO NCNb 93,688 -999,250 -999.250 3.756 -99 50 -999,250 4.012 95.250 -999,250 -999.250 2,848 88.000 0,031 1943.000 4.258 76,625 7.535 83.500 0 021 1985: 00o 2122 O0 4 523 78~563 0.026 2246.000 5.293 81,375 o I7 2o :§oo 6.684 68.125 0 026 1 6 :ooo 5 625 0'005 2082.000 DT CALl FCNL IbM CALl FCNL IbM DT CALl FCNL CAbI ~CNb DT CALl FCNL DT CALI FCNL D~ CAbI FCNL CALl FCNb DT CALI FCNb DT CALI FCNb DT ChbI FCNb 109,~63 NPHI -999. 50 GR -999'250 4,~13 ILD 109. O0 NPHI 99'I 0 5O ~i~52 '~ 75 NPHI 50 GR '999'~50 3,100 IUD 113,375 NPHI 16.922 GR 528.000 4.473 114.000 NPHI .000 7,676 ILD 109.188 NPHI ~16'938 GR 3,236 ILD _13,~88 NPHI 116, 38 GR 606,500 4.879 ILD 108,000 NPHI -17.203 GR 628.000 6,617 120.750 NPHI '17.000 GR 599,000 4.832 ILD 120,750 NPHI 15.805 GR 491.500 6.520 119,750 NPHI 15.289 GR 580,500 PAGE -999 250 -999:250 4.301 : 9,.25o 999,250 4,273 999,250 :999,250 3.184 40,869 129,125 4 590 85.8i3 8 195 36!377 106 688 3.516 37,207 75.]12 5.121 36,914 86,125 6 855 a5:~98 81.312 5.203 41 357 80~000 6 39!941 65813 ~¥P 009,H05 VERIFICATION bfSTING PAGE 8 DEPT SP NRAT DEPT SP RHOB NRAT DEPT SP RHOB NRAT DEPT RHOB NRAT DEPT SP RHOB NRAT DEPT RHOB NRAT DEPT SP RHOB NRAT DEPT SP NRAT DEPT SP RHOB NRAT DEPT SP RHOB NRAT DEPT SP RHOB NRAT 4900.000 SFbU -20.047 GR 2,29I DRHO 3.545 NCNb 4800.000 SFLU '34,156 GR 2.19I DRHO 3.461 NCNb 4700.000 SFLU ~43,625 GR 2,168 DRHO 3,625 NCNb 4600,000 SFbU '22.047 GR 2,312 DRHO 3.561 NCNb 4500.000 SFLU '22.984 GR 2.262 DRHU 3,594 NCNb 4400.000 SFLU '24.078 GR 2.256 DRHO 3,688 NCNb 4300,000 SFLU -20.984 OR 2.283 DRHO 3.771 NCNb 4200.000 SFLU -51,250 GR 2,088 DRHO 3,479 NCNb 4100,000 SFLU -22.016 OR 2,150 DRHO 4,102 NCNL 4000.000 SFLU -20.984 GR 2,309 DRHO 3.783 NCNb 3900.000 SFLU -19.000 GR 2.270 DRHO 3.916 NCNb 4 76 0 1991 6 66 0 1963 9 64 0 2212 81 0 2238 5 6O 0 1995 63 0 1751 5 70 0 1759 5 22~08 6 67 -0 1745 6 77 0 1894 6 67 0 1898 .684 .250 .026 .000 .344 .500 .006 .000 .695 .938 .000 .266 .438 ,046 .000 77 012 ;000 .359 .656 .036 .000 .i29 ,625 O33 '000 . 758 '875 , .004 ,000 ,582 ,438 005 '000 . .805 .375 .027 .000 555 :250 ,025 ,000 IbM DT CALI FCNL DT CALI FCNb IbM DT CALI FCNL DT CALl FCNL DT CALl FCNU DT CALf FCNL DT CALI FCNL DT CALI FCNL DT CALl FCNL ILM DT CALf FCNb DT CALl FCNL 5.195 119'750 16.766 567.500 6,922 123.375 14,516 578.000 9.516 I24'188 14.234 621,000 6,754 118.000 19.828 629.500 6,234 125,563 17,656 543.500 6,160 129,500 17.828 510.000 5,816 132.125 15 703 , 7 :ooo 20.789 138 000 '14:063 620,000 8,477 110,375 16 72 7.234 120,563 16.641 501,500 7.215 123.000 14.844 474.500 IbP NPHI GR NPHI GR NPHI GR IUD NPHI GR NPHI GR II~D NPHI GR NPHI GR IUD NPHI GR NPHI GR NPMI GR NPHi GR 184 83 375 6,980 31.744 7 .500 9,~78 40, 20 64.563 3~ .293 .012 86.312 6.730 38.623 68,688 _. 7,148 40.234 75.375 6 461 42.'773 69,750 11.609 38,281 50'469 9 O86 48!486 73 125 7.105 42 529 88:563 .953 4 .752 74.500 bVP 009.H05 VERIFICATfON LfSTING DEPT 3800,000 SFbU SP i38,000 GR RHOB 2.199 DRHO NRAT 3"773 NCNb DEPT 3700.000 SFLU Sp ~28.000 GR' RHOB 2'232 DRHO NRAT 3.578 NCNb DEPT 3~00 000 SFLU SP 331156 GR RHOB 1,922 DRHO NRAT 4.285 NCNb DEPT 3500.000 SFLU SP -21.484 GR RHOB 2'i93 DRHO NRAT 3.918 NCNb -- DEPT 3400.000 SFLU Sp -20.578 GR RHOB 2.217 DRHO NRAT 3.355 NCNb DEPT 3300,000 SFLU Sp -36,531 GR RHOB 2,068 DRHO NRAT 3.615 NCNb DEPT 3200,000 SFLU SP -27'406 GR RHOB 2.152 DRHO NRAT 3,664 NCNb DEPT 3100,000 SF~U SP -38,594 GR RHOB 2.090 DRHO NRAT 3.693 NCNb DEPT 3000,000 SFLU SP -36.78i GR RHOB 2,i02 DRHO NRAT 3,602 NCNb DEPT 2900,000 SFLU Sp ~18,391 GR RHOB 2,107 DRHO NRAT 3.793 NCNb DEPT 2~00,000 BFbU SP -36.719 GR RHOB 2.033 DRHO 9,531 IbM 54.156 DT 0,009 CALI 2028,000 FCN5 9.023 ILM 72,312 DT 0,002 CALI 1993.000 FCNL 12,352 41.156 DT -0.002 CALl 2160.000 FCN5 5,6~4 60.8 3 DT 0.023 CALl i797.000 FCNL 6.492 IbM 49.438 DT 0,014 CALI 2468.000 FCNL 9.672 ILM 42.719 DT -0.00! CALI 2272.000 FCN5 9,359 IbM 56.53! DT -0,001 CALl 1711,000 FCNb 11.64t IbM 50,969 DT -0.003 CALI 2242.000 FCNL 13,203 49.344 DT 0.00! CALI 2426.000 FCNL 9.734 60.438 DT 0.000 CAbI 1649.000 FCNL 50,344 DT -0'018 CALl 9,i17 130,000 13,414 542,000 9.305 122.750 13'852 574.500 12,047 198,~00 14. 05 508,250 6,586 13I ,,75O .500 6.879 133'000 14.273 769.500 9,758 144,750 t5 86 9,461 136.750 13,742 471,500 13,094 i30,375 13,500 635'500 13 8I 13.602 710.500 7.332 132.375 15.906 427.250 li.484 133 000 - 4:4 o I~D NPHI GR IbD NPHI GR IbD NPMI GR NPMI GR NPHI GR NPHI GR. NPHI GR NPHI GR NPHI GR ILD NPHI GR PAGE 9.438 43.848 61.625 10 234 40!137 71 875 i I 953 41.281 7.016 45.703 72.750 .258 3 .986 51.719 10.125 39.990 43.688 10.602 41.797 62.938 13.070 42.432 56.000 13.172 40.674 49.219 8 727 431066 64,625 11.953 43.555 52.344 bVP 009,H05 VERIFICATION LISTING PAGE I0 NEAT 3,781 NCNb 2096,000 FCNL DEPT 2700,000 SFLU SP -4i.969 GR RHOB 2,051 DRHO NEAT 3,768 NCNb 14.289 IbM 46.438 DT -0.021 CALI 2284,000 FCN5 DEPT 2600,000 SFLU SP -35,312 GR RHOB 2,078 DRHO NEAT 3,645 NCNb 13.266 IbM 59,406 DT -0,006 CALI 2144.000 FCNL DEPT 2519,500 SFbU SP -999,250 GR RHOB 1,933 DRHO NEAT 4,391 NCNb -999.250 IbM -999.250 DT ~.680 CAbI 12 .000 FCNL $$ FILE TRAILER *~ FILE NAME :SERVIC,O0! SERVICE NAME : VERSION # : DATE : MAXIMU~ LENGTH : 1024 FILE TYPE : NEXT FILE NAME : $* TAPE TRAILER ** SERVICE NA~E :SERVIC DATE :81/12/11 ORIGIN :1070 TAPE NAME :62346 CONTINUATION # :01 NEXT TAPE NAME : COMMENTS :TAPE COMMENTS ** REEL TRAILER SERVICE NAME :SERVIC DATE :81/12/11 ORIGIN : REEL NAME :REEL ID CONTINUATION # NEXT REEL NAME : COMMENTS :REEL COMMENTS 576,000 14,844 146,125 ! '492 ,000 12,133 148,375 14,836 568,000 '999,250 -999,250 12.641 266,750 NPHI NPHI GR NPBf GR 15.156 43,262 50,438 i 289 59,844 -999 250 55i371 40 813