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Home My WebLink About184-151MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Monday, September 22, 2025 SUBJECT:Mechanical Integrity Tests TO: FROM:Bob Noble P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL ConocoPhillips Alaska, Inc. 2D-04 KUPARUK RIV UNIT 2D-04 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 09/22/2025 2D-04 50-029-21176-00-00 184-151-0 W SPT 5916 1841510 1500 2690 2690 2690 2690 300 320 320 320 4YRTST P Bob Noble 8/8/2025 30 MinPretestInitial15 Min Well Name Type Test Notes: Interval P/F Well Permit Number: Type Inj TVD PTD Test psi API Well Number Inspector Name:KUPARUK RIV UNIT 2D-04 Inspection Date: Tubing OA Packer Depth 1285 2000 1960 1960IA 45 Min 60 Min Rel Insp Num: Insp Num:mitRCN250810105509 BBL Pumped:0.8 BBL Returned:0.7 Monday, September 22, 2025 Page 1 of 1           2SHUDWLRQV $EDQGRQ 3OXJ3HUIRUDWLRQV )UDFWXUH6WLPXODWH 3XOO7XELQJ 2SHUDWLRQVVKXWGRZQ 3HUIRUPHG 6XVSHQG 3HUIRUDWH 2WKHU6WLPXODWH $OWHU&DVLQJ &KDQJH$SSURYHG3URJUDP 3OXJIRU5HGULOO 3HUIRUDWH1HZ3RRO 5HSDLU:HOO 5HHQWHU6XVS:HOO 2WKHU%L613DFNHUUHSDLU 'HYHORSPHQW ([SORUDWRU\ 6WUDWLJUDSKLF 6HUYLFH $3,1XPEHU 3URSHUW\'HVLJQDWLRQ/HDVH1XPEHU:HOO1DPHDQG1XPEHU /RJV/LVWORJVDQGVXEPLWHOHFWURQLFGDWDSHU$$&)LHOG3RROV 3UHVHQW:HOO&RQGLWLRQ6XPPDU\ 7RWDO'HSWK PHDVXUHG IHHW 1$IHHW 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3UHVVXUHV 3UHWHVW ,QLWLDO 0LQ 0LQ 0LQ 0LQ 37' 7\SH,QM : 7XELQJ 7\SH7HVW 3 3DFNHU79' %%/3XPS ,$ ,QWHUYDO 2 7HVWSVL %%/5HWXUQ 2$ 5HVXOW 3 :HOO 3UHVVXUHV 3UHWHVW ,QLWLDO 0LQ 0LQ 0LQ 0LQ 37' 7\SH,QM 7XELQJ 7\SH7HVW 3DFNHU79' %%/3XPS ,$,QWHUYDO 7HVWSVL %%/5HWXUQ 2$5HVXOW :HOO 3UHVVXUHV 3UHWHVW ,QLWLDO 0LQ 0LQ 0LQ 0LQ 37' 7\SH,QM 7XELQJ 7\SH7HVW 3DFNHU79' %%/3XPS ,$,QWHUYDO 7HVWSVL %%/5HWXUQ 2$5HVXOW :HOO 3UHVVXUHV 3UHWHVW ,QLWLDO 0LQ 0LQ 0LQ 0LQ 37' 7\SH,QM 7XELQJ 7\SH7HVW 3DFNHU79' %%/3XPS ,$,QWHUYDO 7HVWSVL %%/5HWXUQ 2$5HVXOW :HOO 3UHVVXUHV 3UHWHVW ,QLWLDO 0LQ 0LQ 0LQ 0LQ 37' 7\SH,QM 7XELQJ 7\SH7HVW 3DFNHU79' %%/3XPS ,$,QWHUYDO 7HVWSVL %%/5HWXUQ 2$5HVXOW 7<3(,1-&RGHV 7<3(7(67&RGHV ,17(59$/&RGHV 5HVXOW&RGHV : :DWHU 3 3UHVVXUH7HVW , ,QLWLDO7HVW 3 3DVV * *DV 2 2WKHUGHVFULEHLQ1RWHV )RXU<HDU&\FOH ) )DLO 6 6OXUU\9 5HTXLUHGE\9DULDQFH , ,QFRQFOXVLYH , ,QGXVWULDO:DVWHZDWHU 2 2WKHUGHVFULEHLQQRWHV 1 1RW,QMHFWLQJ &RQRFR3KLOOLSV$ODVND,QF .XSDUXN.58'3DG *X\&RRN 'XII\+LOOV 1RWHV0,7,$SHUVXQGU\SRVW%L61%LVPXWKUHSDLU 1RWHV ' 1RWHV 1RWHV 1RWHV 67$7(2)$/$6.$ $/$6.$2,/$1'*$6&216(59$7,21&200,66,21 MMec h an i c al Int egr i t y Tes t MLPUHJJ#DODVNDJRY$2*&&,QVSHFWRUV#DODVNDJRYSKRHEHEURRNV#DODVNDJRY FKULVZDOODFH#DODVNDJRY )RUP5HYLVHG0,7.58'[OV[ MEMORANDUM TO: Jim Regg P.I. Supervisor l FROM: Guy Cook Petroleum Inspector I Well Name KUPARUK RIV UNIT 213-04 Insp Num: mitGDC211229153015 Rel Insp Num: NON -CONFIDENTIAL State of Alaska Alaska Oil and Gas Conservation Commission DATE: Monday, January 3, 2022 SUBJECT: Mechanical Integrity Tests ConocoPhillips Alaska, Inc. 213-04 KUPARUK RIV UNIT 213-04 Src: Inspector Reviewed By: — P.I. Supry Comm API Well Number 50-029-21176-00-00 Inspector Name: Guy Cook Permit Number: 184-151-0 Inspection Date: 12/30/2021 Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min --- -- - YP ) TVD p 5916 Tubing2350 2350 2350 2350 Well 213-oa Type In' I spr 'Test std � I tato — . w - T e Test 1500 IA 760 1770 1750 PTD tsatslo BBL Pumped l _ 08 1BBL Returned 0.8 OA zlo 310 305 300 — -- -- - -- Interval 'I, OTHER P/F P y Notes: MITIA per Sundry 321-500. Bismuth bead repair. Testing completed with a Little Red Services pump truck and calibrated gauges. — avq `'/,kc3 *'�'t 7 Monday, January 3, 2022 Page 1 of 1 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 #:________________Signature12/21/2021Wd͗ϭϴϰϭϱϭϬͲ^Ğƚ͗ϯϲϭϳϮJRBy Abby Bell at 1:43 pm, Dec 21, 2021 1D-0350029204080000 KRU WLIPROFFINAL FIELD29-Aug-211F-0750029208300000 KRU WLGLSFINAL FIELD13-Oct-212W-0950029212350000 KRU WLSCMTFINAL FIELD18-Nov-212W-0950029212350000 KRU WLSCMTFINAL FIELD22-Sep-212U-1350029212610000 KRU WLPPROFFINAL FIELD16-Oct-213N-0650029215380000 KRU WLPPROFFINAL FIELD31-Oct-211Y-1750029223680000 KRU WLPPROFFINAL FIELD25-Jul-211Q-20A50029225890100 KRU WLSBHPSFINAL FIELD29-Jul-213S-24A50103204560100 KRU WLUSITFINAL FIELD25-Nov-212N-318A50103203430100 KRU WLSCMTFINAL FIELD12-Nov-211D-0350029204080000 KRU WLIPROFFINAL FIELD27-Mar-211D-0550029204170000 KRU WLSCMTFINAL FIELD8-Oct-211D-0250029204290000 KRU WLIPROFFINAL FIELD2-Apr-211A-0550029206270000 KRU WLLDLFINAL FIELD1-May-211B-1050029206560000 KRU WLWHIPSTOCKFINAL FIELD25-Sep-211F-0350029208530000 KRU WLPERFFINAL FIELD19-Oct-211Y-0650029209580000 KRU WLPPROFFINAL FIELD1-Nov-212D-0850029211580000 KRU WLGLSFINAL FIELD18-Jul-212D-0450029211760000 KRU WLBISNFINAL FIELD20-Nov-212D-0450029211760000 KRU WLSCMTFINAL FIELD10-Oct-212X-1550029211990000 KRU WLPPROFFINAL FIELD17-Oct-211Q-0950029212090000 KRU WLIPROFFINAL FIELD17-Nov-212E-1450029212140000 KRU WLSHBPFINAL FIELD30-Oct-212W-0950029212350000 KRU WLBISNFINAL FIELD19-Nov-211Q-0250029212480000 KRU WLIPROFFINAL FIELD29-Apr-212W-1450029212530000 KRU WLIPROFFINAL FIELD1-May-211Q-1550029213080000 KRU WLIPROFFINAL FIELD28-Apr-211R-0850029213330000 KRU WLIPROFFINAL FIELD3-May-211R-1350029213850000 KRU WLIPROFFINAL FIELD27-Jun-213F-0250029214470000 KRU WLWHIPSTOCKFINAL FIELD14-Nov-213F-1450029215000000 KRU WLLDLFINAL FIELD30-May-213M-0550029217060000 KRU WLCHEM CUTFINAL FIELD28-Oct-213M-0550029217060000 KRU WLSTRINGSHOTFINAL FIELD27-Oct-21 WELL NAME API #SERVICE ORDER # FIELD NAMESERVICE DESCRIPTIONDELIVERABLE DESCRIPTION DATA TYPEDATE LOGGEDCOLOR PRINTS CDsCD5-1950103207600000 CRU WLSetting RecordFINAL FIELD3-Aug-21CD5-1950103207600000 CRU WLSetting RecordFINAL FIELD11-Aug-21CD5-9650103208110000 CRU WLPERFFINAL FIELD21-Jul-21CD2-31050103208260000 CRU WLDCSTFINAL FIELD16-Sep-21CD2-31050103208260000 CRU WLUSITFINAL FIELD24-Aug-21CD2-31050103208260000 CRU WLUSITFINAL FIELD25-Aug-21CD5-3150103208280000 CRU WLPERFFINAL FIELD27-May-21CD1-01A50103202990100 CRU WLRSTFINAL FIELD12-Sep-21MT7-0650103208310000 GMTU WLCORROSIONFINAL FIELD3-Oct-21MT6-0850103207720000 GMTU WLPSRFINAL FIELD14-Sep-21MT6-0850103207720000 GMTU WLPSRFINAL FIELD22-Oct-21MT7-0650103208310000 GMTU WLMECH CUTTERFINAL FIELD2-Sep-21MT7-0650103208310000 GMTU WLUSITFINAL FIELD12-Dec-21MT7-0650103208310000 GMTU WLUSITFINAL FIELD16-Dec-21MT7--0150103208320000 GMTU WLSCMTFINAL FIELD15-Nov-21MT7-0650103208310000 GMTU WLUSITFINAL FIELD19-Feb-21Lookout 150103203590000 GMTU WLRSTFINAL FIELD29-Mar-21Lookout 150103203590000 GMTU WLRSTFINAL FIELD2-Apr-21Delivery Receipt______ďďǇĞůů_____X_______________________________________Print Name Signature DatePlease return via courier or sign/scan and email a copy to Schlumberger.A Delivery Receipt signature confirms that a package (box, envelope, etc.) has been received. The package will be handled/delivered per standard company reception procedures. The package's contents have not been verified but should be assumed to contain the above noted SLB Auditor-Originated:PTS - PRINT CENTER600 E 57th Pl - Ste AAnchorage, AK 99518Delivered to:AOGCCATTN: Natural Resources Technician333 W. 7th Ave., Suite 100Anchorage, AK 99501-3539Transmittal Date:20-Dec-21Transmittal #:________________Signature12/21/2021Wd͗ϭϴϰϭϱϭϬͲ^Ğƚ͗ϯϲϭϳϭJRBy 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 CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. From:Wallace, Chris D (OGC) To:AOGCC Records (CED sponsored) Subject:FW: Kuparuk Injector 2D-04 (184-151) Post BiSN repair testing. Date:Monday, December 13, 2021 1:36:10 PM Attachments:image001.png AnnComm Surveillance TIO for 2D-04.pdf From: Well Integrity Specialist CPF2 <n2549@conocophillips.com> Sent: Friday, December 10, 2021 2:24 PM To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov> Cc: Earhart, Will C <William.C.Earhart@conocophillips.com>; Well Integrity Specialist CPF2 <n2549@conocophillips.com> Subject: Kuparuk Injector 2D-04 (184-151) Post BiSN repair testing. Chris- Kuparuk injector 2D-04 (PTD 184-151) BiSN packer repair was recently completed and the well is currently passing an MIT-IA and IA DDT while offline. CPAI intends to bring the well on produced water injection and complete the 2 year testing as required per AIO 2B.037 (amended) and MIT required as per sundry 321-500. However, now that the packer/PBR repair has been completed, CPAI suspects the well is capable of passing an MIT-IA while on injection vs the currently required CMIT-TxIA. If the MIT-IA passes successfully AIO 2B.037 will be cancelled or amended to reflect the regained TxIA integrity on produced water. Due to the history of this well showing communication on cold sea water, CPAI at this time does not have intentions to put seawater injection to the pad and therefore does not currently have the ability to verify the repair to seawater injection. Therefore, 2D-04 will remain a produced water injector only. Please let me know if you have any questions or disagree with the plan. Attached is a copy of the 90 day TIO plot and current wellbore schematic. Dusty Freeborn Wells Integrity Specialist ConocoPhillips Alaska, Inc. Office phone: (907) 659-7224 Cell phone: (907) 830-9777 Last Tag Annotation Depth (ftKB) End Date Wellbore Last Mod By Last Tag: RKB (EST. 88' RAT HOLE) 8,473.0 4/12/2017 2D-04 pproven Last Rev Reason Annotation End Date Wellbore Last Mod By Rev Reason: Melt BiSN Beads 11/20/2021 2D-04 bworthi1 Casing Strings Casing Description CONDUCTOR OD (in) 16 ID (in) 15.06 Top (ftKB) 35.0 Set Depth (ftKB) 117.0 Set Depth (TVD) … 117.0 Wt/Len (l… 62.50 Grade H-40 Top Thread WELDED Casing Description SURFACE OD (in) 9 5/8 ID (in) 8.92 Top (ftKB) 34.9 Set Depth (ftKB) 3,949.1 Set Depth (TVD) … 3,115.0 Wt/Len (l… 36.00 Grade J-55 Top Thread BTC Casing Description PRODUCTION OD (in) 7 ID (in) 6.28 Top (ftKB) 32.0 Set Depth (ftKB) 8,603.0 Set Depth (TVD) … 6,212.1 Wt/Len (l… 26.00 Grade J-55 Top Thread BTC Tubing Strings Tubing Description TUBING String Ma… 3 1/2 ID (in) 2.99 Top (ftKB) 30.0 Set Depth (ft… 8,243.3 Set Depth (TVD) (… 5,941.4 Wt (lb/ft) 9.30 Grade J-55 Top Connection EUE8RD Completion Details Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des Nominal ID (in) OD Nominal (in)Make Model Com 30.0 30.0 0.09 HANGER 3.500 8.000 FMC GEN III TUBING HANGER 2,053.1 1,895.6 42.31 SAFETY VLV 2.810 5.937 BAKER FVI BAKER FVL SAFETY VALVE - LOCKED OUT 7/26/94 (FLAPPER PARTIALLY CLOSED) 2,104.3 1,933.1 43.48 GAS LIFT 2.937 5.563 MMH FMHO MMH/1/DMY/BK- 2/Comment: STA 1 4,386.6 3,402.1 49.09 GAS LIFT 2.937 5.563 MMH FMHO MMH/1/DMY/BK- 2/Comment: STA 2 5,968.0 4,418.7 49.41 GAS LIFT 2.937 5.563 MMH FMHO MMH/1/DMY/BK- 2/Comment: STA 3 6,876.3 5,007.0 49.95 GAS LIFT 2.937 5.563 MMH FMHO MMH/1/DMY/BK- 2/Comment: STA 4 7,592.1 5,484.3 46.40 GAS LIFT 2.937 5.563 MMH FMHO MMH/1/DMY/BK- 2/Comment: STA 5 8,150.8 5,874.5 44.03 GAS LIFT 2.937 5.563 MMH FMHO MMH/1/DMY/BK- 2/Comment: STA 6 8,194.0 5,905.7 43.64 PBR 2.810 4.000 BAKER BAKER PBR 8,207.7 5,915.6 43.51 PACKER 3.000 5.968 BAKER FHL BAKER FHL PACKER 8,230.8 5,932.4 43.32 NIPPLE 2.750 4.540 CAMCO D CAMCO D NIPPLE NO GO 8,242.5 5,940.8 43.21 SOS 3.000 4.570 BAKER BAKER SHEAR OUT SUB, ELMD TTL @ 8232' during DA COLLAR LOG on 02/02/85 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Des Com Run Date ID (in) SN 8,207.0 5,915.1 43.52 TUBING - LEAK CONFIRM LEAK W/ HOLEFINDER BETWEEN 8207'-8230' RKB (PACKER) 2/13/2017 8,231.0 5,932.5 43.31 CA-2 PLUG 2.75" CA-2 PLUG (2.79" NO-GO / 28" OAL) 10/1/2017 0.000 Mandrel Inserts St ati on N o/Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Make Model OD (in) Serv Valve Type Latch Type Port Size (in) TRO Run (psi) Run Date Com 1 2,104.3 1,933.1 43.48 1 GAS LIFT DMY BK2 0.000 0.0 11/18/1984 2:00 2 4,386.6 3,402.1 49.09 1 GAS LIFT DMY BK2 0.000 0.0 11/18/1984 3:00 3 5,968.0 4,418.7 49.41 1 GAS LIFT DMY BK2 0.000 0.0 11/18/1984 1:30 4 6,876.3 5,007.0 49.95 1 GAS LIFT DMY BK2 0.000 0.0 11/18/1984 6:30 5 7,592.1 5,484.3 46.40 1 GAS LIFT DMY BK2 0.000 0.0 11/18/1984 6:30 6 8,150.8 5,874.5 44.03 1 GAS LIFT OV BK 0.250 0.0 9/22/2021 1:00 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft )Type Com 8,288.0 8,290.0 5,974.1 5,975.6 UNIT B, 2D-04 11/12/1984 2.0 IPERF Squeezed, 4" Casing Gun 8,322.0 8,325.0 5,999.1 6,001.4 A-5, 2D-04 12/5/1984 2.0 IPERF 2 5/8" Slim Kone HC, 0° Ph 8,350.0 8,353.0 6,019.9 6,022.1 A-4, 2D-04 12/5/1984 2.0 IPERF 2 5/8" Slim Kone HC, 0° Ph 8,368.0 8,375.0 6,033.3 6,038.5 A-4, 2D-04 12/5/1984 2.0 IPERF 2 5/8" Slim Kone HC, 0° Ph 8,368.0 8,375.0 6,033.3 6,038.5 A-4, 2D-04 2/2/1985 2.0 IPERF Rigid Jet, 90° 'V' Phase 8,382.0 8,385.0 6,043.7 6,046.0 A-4, 2D-04 12/5/1984 2.0 IPERF 2 5/8" Slim Kone HC, 0° Ph Cement Squeezes Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Des Com Pump Start Date 8,288.0 8,290.0 5,974.1 5,975.6 Cement 8,163.0 8,171.0 5,883.3 5,889.0 Remedial BiSN Plug 11/20/2021 Notes: General & Safety End Date Annotation 12/25/2005 NOTE: WAIVERED WELL: T x IA COMMUNICATION **WATER INJECTION ONLY** 2D-04, 11/21/2021 8:30:33 AM Vertical schematic (actual) PRODUCTION; 32.0-8,603.0 IPERF; 8,382.0-8,385.0 IPERF; 8,368.0-8,375.0 IPERF; 8,368.0-8,375.0 IPERF; 8,350.0-8,353.0 IPERF; 8,322.0-8,325.0 IPERF; 8,288.0-8,290.0 Cement; 8,288.0 ftKB SOS; 8,242.5 CA-2 PLUG; 8,231.0 NIPPLE; 8,230.8 TUBING - LEAK; 8,207.0 PACKER; 8,207.7 PBR; 8,194.0 Remedial; 8,163.0 ftKB GAS LIFT; 8,150.8 GAS LIFT; 7,592.1 GAS LIFT; 6,876.3 GAS LIFT; 5,968.0 GAS LIFT; 4,386.6 SURFACE; 34.9-3,949.1 GAS LIFT; 2,104.3 SAFETY VLV; 2,053.1 CONDUCTOR; 35.0-117.0 HANGER; 30.0 KUP INJ KB-Grd (ft) 40.71 Rig Release Date 9/30/1984 2D-04 ... TD Act Btm (ftKB) 8,644.0 Well Attributes Field Name KUPARUK RIVER UNIT Wellbore API/UWI 500292117600 Wellbore Status INJ Max Angle & MD Incl (°) 51.25 MD (ftKB) 2,900.00 WELLNAME WELLBORE2D-04 Annotation Last WO: End DateH2S (ppm) DateComment SSSV: LOCKED OUT 1. Type of Request:Abandon Plug Perforations Fracture Stimulate Repair Well Operations shutdown Suspend Perforate Other Stimulate Pull Tubing Change Approved Program Plug for Redrill Perforate New Pool Re-enter Susp Well Alter Casing Other: BiSN Patch Repair 2.Operator Name:4. Current Well Class:5. Permit to Drill Number: Exploratory Development 3. Address:Stratigraphic Service 6.API Number: 7. If perforating:8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require a spacing exception?Yes No 9. Property Designation (Lease Number):10. Field/Pool(s): 11. Total Depth MD (ft):Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi):Plugs (MD):Junk (MD): 8644'None Casing Collapse Conductor Surface Intermediate Production Liner Packers and SSSV Type:Packers and SSSV MD (ft) and TVD (ft): 12. Attachments:Proposal Summary Wellbore schematic 13. Well Class after proposed work: Detailed Operations Program BOP Sketch Exploratory Stratigraphic Development Service 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations:OIL WINJ WDSPL Suspended 16. Verbal Approval:Date:GAS WAG GSTOR SPLUG Commission Representative: GINJ Op Shutdown Abandoned Contact Name: Contact Email: Contact Phone: Date: Conditions of approval: Notify Commission so that a representative may witness Sundry Number: Plug Integrity BOP Test Mechanical Integrity Test Location Clearance Other: Post Initial Injection MIT Req'd? Yes No Spacing Exception Required? Yes No Subsequent Form Required: APPROVED BY Approved by:COMMISSIONER THE COMMISSION Date: Comm.Comm.Sr Pet Eng Sr Pet Geo Sr Res Eng Tubing MD (ft): 5974-5976', 5999-6001', 6020- 6022',6033-6038', 6044-6046' Packer: 8208' MD and 5916' TVD SSSV: 2053' MD and 1896' TVD Length Size 117' 3115' TVD Burst COMMISSION USE ONLY Authorized Name: J-55 8243' 9/28/2021 3-1/2" STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL0025653 6242' 184-151 P.O. Box 100360, Anchorage, Alaska 99510 50-029-21176-00-00 ConocoPhillips Alaska, Inc. KRU 2D-04 N/A Kuparuk River Field/ Kuparuk River Oil Pool 8231'5932'8231' PRESENT WELL CONDITION SUMMARY MD 117' 3949' 6212'7" 16" 9-5/8" 82' 3914' dusty.freeborn@conocophillips.com 8603' Perforation Depth MD (ft):Perforation Depth TVD (ft):Tubing Size: 8288-8290', 8322-8325', 8350- 8353', 8368-8375', 8382-8385' 8571' (907) 659-7224 Authorized Title: 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Signature: Dusty Freeborn Packer: Baker FHL Packer SSSV: Baker FVL Safety Valve Tubing Grade: Senior Well Integrity Specialist Dusty Freeborn m n s 2 66 t c s Form 10-403 Revised 3/2020 Approved application is valid for 12 months from the date of approval. By Samantha Carlisle at 10:07 am, Sep 23, 2021 321-500 Digitally signed by Dusty Freeborn DN: OU=AK WELLS, O=ConocoPhillips, CN=Dusty Freeborn, E=dusty.freeborn@conocophillips.com Reason: I am the author of this document Location: your signing location here Date: 2021.09.22 18:14:19-08'00' Foxit PDF Editor Version: 11.0.0 Dusty Freeborn X DSR-9/23/21 X 10-404 DLB 09/23/2021 X VTL 9/28/21 9/28/2021 JLC 9/28/2021 Jeremy Price Digitally signed by Jeremy Price Date: 2021.09.28 13:42:15 -08'00' RBDMS HEW 9/28/2021 P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 22 September 2021 Commissioner Jessie Chmielowski Alaska Oil & Gas Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 Dear Commissioner Chmielowski, Enclosed please find the 10-403 Application for Sundry Approval for ConocoPhillips Alaska, Inc. well KRU 2D-04 (PTD 184-151) to place Bismuth beads on top of the packer and melt them into a solid plug to repair the failed packer/PBR. Please contact me at 659-7224 or 830-9777 if you have any questions. Sincerely, Dusty Freeborn Well Integrity & Compliance Specialist ConocoPhillips Alaska, Inc. Digitally signed by Dusty Freeborn DN: OU=AK WELLS, O=ConocoPhillips, CN=Dusty Freeborn, E=dusty.freeborn@conocophillips.com Reason: I am the author of this document Location: your signing location here Date: 2021.09.22 18:20:33-08'00' Foxit PDF Editor Version: 11.0.0 Dusty Freeborn KRU 2D-04 (PTD# 184-151) Description Summary of Proposal Well Work Justification & Objectives (and date required if appropriate): 2D-04 has a packer failure and TxIA leak in the PBR. To return the well to injection, the well needs a packer/PBR repair completed and integrity of the repair verified. Risk/Job Concerns: -SSSV at 2053' RKB locked out (flapper partially closed) -CA-2 plug is set in nipple at 8230'. Steps: 1.Run CBL as base line survey to attempt to identify bead location once deployed. 2.Pump 539 kg of Bismuth beads into IA above production packer. 3.Run CBL to survey Bismuth bead settling depth (at least 1983 in 2 at repair site). 4.Pump down IA to push beads to depth. 5.Run BiSN’s PRT tool to bead depth and deploy heating element to melt Bismuth beads into solid patch. 6.Run CBL to survey Bismuth patch top (estimated 1190 in2 after completion). 7.Perform IA DDT to verify integrity of Bismuth patch. 8.Normal well conditions for injection service and return well to injection. 9.Perform AOGCC witnessed MIT-IA once well has stabilized. 10.Perform 30-day injection period to verify Bismuth patch integrity. Perform AOGCC witnessed MIT-IA once well has stabilized. Last Tag Annotation Depth (ftKB) End Date Wellbore Last Mod By Last Tag: RKB (EST. 88' RAT HOLE) 8,473.0 4/12/2017 2D-04 pproven Last Rev Reason Annotation End Date Wellbore Last Mod By Rev Reason: ADDED LEAK and Removed NOTES 8/13/2020 2D-04 pproven Casing Strings Casing Description CONDUCTOR OD (in) 16 ID (in) 15.06 Top (ftKB) 35.0 Set Depth (ftKB) 117.0 Set Depth (TVD) … 117.0 Wt/Len (l… 62.50 Grade H-40 Top Thread WELDED Casing Description SURFACE OD (in) 9 5/8 ID (in) 8.92 Top (ftKB) 34.9 Set Depth (ftKB) 3,949.1 Set Depth (TVD) … 3,115.0 Wt/Len (l… 36.00 Grade J-55 Top Thread BTC Casing Description PRODUCTION OD (in) 7 ID (in) 6.28 Top (ftKB) 32.0 Set Depth (ftKB) 8,603.0 Set Depth (TVD) … 6,212.1 Wt/Len (l… 26.00 Grade J-55 Top Thread BTC Tubing Strings Tubing Description TUBING String Ma… 3 1/2 ID (in) 2.99 Top (ftKB) 30.0 Set Depth (ft… 8,243.3 Set Depth (TVD) (… 5,941.4 Wt (lb/ft) 9.30 Grade J-55 Top Connection EUE8RD Completion Details Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des Com Nominal ID (in) 30.0 30.0 0.09 HANGER FMC GEN III TUBING HANGER 3.500 2,053.1 1,895.6 42.31 SAFETY VLV BAKER FVL SAFETY VALVE - LOCKED OUT 7/26/94 (FLAPPER PARTIALLY CLOSED) 2.810 8,194.0 5,905.7 43.64 PBR BAKER PBR 2.810 8,207.7 5,915.6 43.51 PACKER BAKER FHL PACKER 3.000 8,230.8 5,932.4 43.32 NIPPLE CAMCO D NIPPLE NO GO 2.750 8,242.5 5,940.8 43.21 SOS BAKER SHEAR OUT SUB, ELMD TTL @ 8232' during DA COLLAR LOG on 02/02/85 3.000 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Des Com Run Date ID (in) SN 8,207.0 5,915.1 43.52 TUBING - LEAK CONFIRM LEAK W/ HOLEFINDER BETWEEN 8207'-8230' RKB (PACKER) 2/13/2017 8,231.0 5,932.5 43.31 CA-2 PLUG 2.75" CA-2 PLUG (2.79" NO-GO / 28" OAL) 10/1/2017 0.000 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft )Type Com 8,288.0 8,290.0 5,974.1 5,975.6 UNIT B, 2D-04 11/12/1984 2.0 IPERF Squeezed, 4" Casing Gun 8,322.0 8,325.0 5,999.1 6,001.4 A-5, 2D-04 12/5/1984 2.0 IPERF 2 5/8" Slim Kone HC, 0° Ph 8,350.0 8,353.0 6,019.9 6,022.1 A-4, 2D-04 12/5/1984 2.0 IPERF 2 5/8" Slim Kone HC, 0° Ph 8,368.0 8,375.0 6,033.3 6,038.5 A-4, 2D-04 12/5/1984 2.0 IPERF 2 5/8" Slim Kone HC, 0° Ph 8,368.0 8,375.0 6,033.3 6,038.5 A-4, 2D-04 2/2/1985 2.0 IPERF Rigid Jet, 90° 'V' Phase 8,382.0 8,385.0 6,043.7 6,046.0 A-4, 2D-04 12/5/1984 2.0 IPERF 2 5/8" Slim Kone HC, 0° Ph Cement Squeezes Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Des Com 8,288.0 8,290.0 5,974.1 5,975.6 Cement Mandrel Inserts St ati on N o/Top (ftKB) Top (TVD) (ftKB) Make Model OD (in) Serv Valve Type Latch Type Port Size (in) TRO Run (psi) Run Date Com 1 2,104.3 1,933.1 MMH FMHO 1 GAS LIFT DMY BK2 0.000 0.0 11/18/1984 2:00 2 4,386.6 3,402.1 MMH FMHO 1 GAS LIFT DMY BK2 0.000 0.0 11/18/1984 3:00 3 5,968.0 4,418.7 MMH FMHO 1 GAS LIFT DMY BK2 0.000 0.0 11/18/1984 1:30 4 6,876.3 5,007.0 MMH FMHO 1 GAS LIFT DMY BK2 0.000 0.0 11/18/1984 6:30 5 7,592.1 5,484.3 MMH FMHO 1 GAS LIFT DMY BK2 0.000 0.0 11/18/1984 6:30 6 8,150.8 5,874.5 MMH FMHO 1 GAS LIFT DMY BK 0.000 0.0 2/13/2017 Notes: General & Safety End Date Annotation 12/25/2005 NOTE: WAIVERED WELL: T x IA COMMUNICATION **WATER INJECTION ONLY** 2D-04, 8/13/2020 1:29:18 AM Vertical schematic (actual) PRODUCTION; 32.0-8,603.0 IPERF; 8,382.0-8,385.0 IPERF; 8,368.0-8,375.0 IPERF; 8,368.0-8,375.0 IPERF; 8,350.0-8,353.0 IPERF; 8,322.0-8,325.0 IPERF; 8,288.0-8,290.0 Cement; 8,288.0 ftKB CA-2 PLUG; 8,231.0 TUBING - LEAK; 8,207.0 PACKER; 8,207.7 GAS LIFT; 8,150.8 GAS LIFT; 7,592.1 GAS LIFT; 6,876.3 GAS LIFT; 5,968.0 GAS LIFT; 4,386.6 SURFACE; 34.9-3,949.1 GAS LIFT; 2,104.3 SAFETY VLV; 2,053.1 CONDUCTOR; 35.0-117.0 KUP INJ KB-Grd (ft) 40.71 Rig Release Date 9/30/1984 2D-04 ... TD Act Btm (ftKB) 8,644.0 Well Attributes Field Name KUPARUK RIVER UNIT Wellbore API/UWI 500292117600 Wellbore Status INJ Max Angle & MD Incl (°) 51.25 MD (ftKB) 2,900.00 WELLNAME WELLBORE2D-04 Annotation Last WO: End DateH2S (ppm) DateComment SSSV: LOCKED OUT Wallace, Chris D (CED) From: Well Integrity Specialist CPF2 <n2549@conocophillips.com> Sent: Tuesday, July 27, 2021 3:16 PM To: Wallace, Chris D (CED) Cc: Earhart, Will C; Well Integrity Specialist CPF2 Subject: KRU 2D-04 (PTD# 184-151) Report of failed diagnostic MIT -IA and MIT -T Attachments: 2D-04.pdf; 2D-04 90 day TIO plot 27 July 21.pdf Chris- KRU injector 2D-04 (PTD# 184-151) was originally reported to the AOGCC in September of 2017 for a recharging IA pressure. The initial diagnostics completed in 2017 yielded a passing MIT -IA but a failing IA DDT. The well was secured with a down hole plug and passed a CMIT-TxIA. The well remained shut in and secured since then with suspected TxIA communication. The well is being re-evaluated for repair options and diagnostics were conducted to verify the current condition of the well. The well now failed the diagnostic MIT -IA and MIT -T. Additional diagnostics will be conducted to identify the failure mechanism and the proper paperwork for repair will be submitted at that time. Attached is a current 90 day TIO plot and well bore schematic. Please let me know if you have any questions or disagree with the plan. Dusty Freeborn Wells Integrity Specialist ConocoPhillips Alaska, Inc. Office phone: (907) 659-7224 Cell phone: (907) 830-9777 J f WELD TEAM cCA1111l ps From. SK Well Integrity Supv CPF1 and 2 <n1617@conocophillips.com> Sent: Sun September 17, 2017 7:33 PM To: Wallace,�Ty (DOA) <chris.waIlace @alaska.gov> Cc: Senden, R<R.Tyler.Senden@conocophillips.com>; NSK Well Integrity Supv CPF1 and 2 <n1617@conocophilcom> Subject: KRU 2D-04 (PTD 4-151) Report of suspect IA pressure increase Chris, KRU water injector 2D-04 (PTD# 184-151) (AI 37) was reported today for an unexplained IA pressure increase. Operations attempted to bleed down thpressure, but it quickly re -pressurized. The well has been shut in since 9-7-17 and will remain shut in. DHD will performi tial diagnostics including an MIT -IA and pack off tests. If the initial diagnostic tests pass the well may be brought on Ovate * jection for a 30 day monitor. Any required paperwork for corrective action or continued injection will be submitted afte he monitor period or once an alternate plan has been determined. Attached is a wellbore schematic and 90 day TIO tr rd. Please let us know if you disagree or have any questions with this plan. Regards, Jan Byrne / Kelly Lyons Well Integrity Supervisor • Wallace, Chris D (DOA) From: NSK Well Integrity Supv CPF1 and 2 <n1617@conocophillips.com> Sent: Sunday, September 17, 2017 7:33 PM To: Wallace,Chris D (DOA) Cc: Senden, R.Tyler; NSK Well Integrity Supv CPF1 and 2 Subject: KRU 2D-04 (PTD# 184-151) Report of suspect IA pressure increase Attachments: 2D-04.pdf;2D-04 90 day TIO trend 9-17-17.JPG Chris, KRU water injector 2D-04(PTD#184-151) (AIO.037)was reported today for an unexplained IA pressure increase. Operations attempted to bleed down the IA pressure, but it quickly re-pressurized. The well has been shut in since 9-7-17 and will remain shut in. DHD will perform initial diagnostics including an MIT-IA and pack off tests. If the initial diagnostic tests pass the well may be brought on water injection for a 30 day monitor. Any required paperwork for corrective action or continued injection will be submitted after the monitor period or once an alternate plan has been determined. Attached is a wellbore schematic and 90 day TIO trend. Please let us know if you disagree or have any questions with this plan. Regards, Jan Byrne/Kelly Lyons Well Integrity Supervisor ConocoPhillips Alaska, Inc. Office phone: (907)659-7224 iliWELLS TEAMsatINED F~P 1 9 2.0 1.; ConocoPI ps 1 • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission 2 DATE: Thursday,August 10,2017 TO: Jim Regg y 2 � V I I( 1 SUBJECT: Mechanical Integrity Tests P.I.Supervisor CONOCOPHILLIPS ALASKA,INC. 2D-04 FROM: Chuck Scheve KUPARUK RIV UNIT 2D-04 Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry NON-CONFIDENTIAL Comm Well Name KUPARUK RIV UNIT 2D-04 API Well Number 50-029-21176-00-00 Inspector Name: Chuck Scheve Permit Number: 184-151-0 Inspection Date: 8/7/2017 Insp Num: mitCS170808075140 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min - Well I 2D-04 Type Inj W rTVD 5916 " Tubing 2510 - 2510 " 2510 2510 PTD ! 1841510 ;Type Test SPT Test psi 3000 IA 620 3300 ' 3240 3230 - BBL Pumped: 3 BBL Returned: 2.5 OA 240 510 510 510 Interval REQVAR P/F P ✓ Notes: MITIA Per AIO 2B.037. The requirement for CMIT-TxIA was waived by Chris Wallace via e-mail dated 7/28/2017. V,. • SCANNED re-:0 „ Thursday,August 10,2017 Page 1 of I i MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg vel/C e'Z( P.I.Supervisor ( L1 7 DATE: Thursday,August 10,2017 SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA,INC. 2D-04 FROM: Chuck Scheve KUPARUK RIV UNIT 2D-04 Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry J� NON-CONFIDENTIAL Comm Well Name KUPARUK RIV UNIT 2D-04 API Well Number 50-029-21176-00-00 Inspector Name: Chuck Scheve Permit Number: 184-151-0 Inspection Date: 8/7/2017 Insp Num: mitCS170808080205 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well 2D-04 'Type Inj w' TVD 5916 Tubing 2510 - 2510 2510 2510 ' PTD 1841510 - Type Test SPT Test psi I 1800 -I IA 680 770 790 - 798 BBL Pumped: 0.8 • BBL Returned: 0.8 OA 235 2000 ' 1930 1920 ' Interval REQVAR JP/F P A" Notes: MITOA Per A1O 2B.037 SCANNED rEB 2 34 r Thursday,August 10,2017 Page I of 1 • • Wallace, Chris D (DOA) From: Wallace, Chris D (DOA) Sent: Friday,July 28, 2017 6:01 PM To: NSK Well Integrity Supv CPF1 and 2 Subject: RE: KRU 2D-04 (PTD 1841510) Request for alternate test Attachments: image001.png Brent,Kelly, CMIT is not required on the few wells with produced water and no TxIA. Thanks Chris Ali tikw Original message From: NSK Well Integrity Supv CPF1 and 2<n1617@conocophillips.com> Date:07/28/2017 4:23 PM (GMT-09:00) To: "Wallace,Chris D(DOA)"<chris.wallace@alaska.gov> Cc: NSK Well Integrity Supv CPF1 and 2<n1617@conocophillips.com> Subject: KRU 2D-04(PTD 1841510) Request for alternate test Chris, With the completion of the injection test on produced water, 2D-04 is operating under AIO 26.037 (Amended)and an internal waiver to regulate produced water injection only. Condition 3 of AIO 26.037 requires a CMIT TxIA to the maximum anticipated injection pressure. While the well is on produced water injection,there is no TxIA communication and is operating under normal water injection criteria with the IA not to exceed 2000 psi. ConocoPhillips requests to perform an MITIA in place of the CMIT TxIA since the communication mechanism is not in place while on produced water. Please let me know if this would be acceptable. This well is to be tested with the rest of 2D during the month of August but if the CMIT is required, it will require some Slickline work to set the plug and prep the well for the test. Thank you in advance, Brent Rogers/Kelly Lyons NSK Well Integrity Supervisor CPF 1 &2 ConocoPhillips Alaska, Inc. Desk Phone(907)659-7224 Cell Phone(907)394-0402 1 • Wallace, Chris D (DOA) From: NSK Well Integrity Supv CPF1 and 2 <n1617@conocophillips.com> Sent: Saturday, June 3, 2017 6:46 PM To: Wallace, Chris D (DOA) Cc: Senden, R.Tyler; NSK Well Integrity Supv CPF1 and 2 Subject: RE: 2D-04 (AIO 2B.037, PTD 184-151) update 06-03-17 Attachments: 2D-04 90 day TIO plot.jpg Chris, The 30 day injection test has ended with produced water and has shown no signs of TxIA communication with the warmer injection water. 2D-04 will remain on PWI injection under the conditions of A10 26.037 and if further signs of communication appear the well will be reported at that time. Attached is a 90 day TIO plot for reference. Please let me know if you disagree with this plan. Brent Rogers I Kelly Lyons NSK Well Integrity Supervisor CPF 1 & 2 ConocoPhillips Alaska, Inc. Desk Phone (907)659-7224 Cell Phone (907) 394-0402 WELLS TEAM ConocoPhillips SCANNED JUN 1 2 2017 From: NSK Well Integrity Supv CPF1 and 2 Sen •Saturday, March 18, 2017 9:26 PM To: 'chn . allace@alaska.gov' <chris.wallace@alaska.gov> Cc:Senden,R.Tyler<R.Tyler.Senden@conocophillips.com> Subject: 2D-02 (A10 26.052, PTD 184-152), 2D-04(A10 26.037, PTD 184-151) and 2E-10 (PTD 184-230) update 3-18-17 Chris, 2D-02 (A10 26.052, PTD 184-152)1.O-04 (A10 26.037, PTD 184-151) and 2E-10(PTD 184-230) were all identified with TxIA communication earlier this wintei`a#.er their pads were swapped to colder seawater injection for the first time in years. (Please see the attached latest email coTmunication regarding each well.) We believe that the wells only display communication when on cold fluid injection due to shrinkage of the metal, causing the tubing to pull out of the PBR. Two of the wells (2D-04 and 2E-10) had this theoryrroborated when LDL's were run while on seawater and discovered that the PBR's were in fact the leak sources. 2D= 's acoustic LDL was run on 02/07/17 and 2E-10's acoustic LDL was run on 02/15/17. 2D and 2E pads will be swapped back to the warmer produced water injection (PWI) later this spring, currently anticipated to occur mid-April. To confirm that the leaks are indeed only prese when on cold water, when the pads resume PWI, CPAI intends to return the 3 wells to produced water injection and be ton a 30 day diagnostic monitor. 2D-02 and 2D-04 are already AA'ed for TxIA communication and they will resume management under their respective AA's. 2E-10 however is currently classified as a normal well and governed under Kuparuk's A10. Once we establish 2E-10's reaction on warm produced water injection, we will make a determination of whether or not we will be applying for an Administrative Approval. A follow-up email will be provided at the conclusion of the monitor period. Please let us know if you disagree with the plan forward. 1 . " • • d waliamot.10 6 c• i6 ...--) In 0 , 0 -1 1 • 14" • i• i .111, .. - --- - r-- _ 2 _ . T- CSJ - - I;..., - 03 •. \ r.... - LC) 0 C4 4) 1- to a. o ..„... t i — - -..., r"--- g - -•- (.4 76 2 _ - 6 r-- ..a' . r,..:. ,--- r-- • , Lll MP 41 4 `. 1 /4 14 i 'I i 1' 1 II V 4 'V i• 4'4 4 I' I 't r ' 'I ‘te ..› r.... 0 4.... 0- 0 Q Q C I 4-- C) 0 C.-J 0 0 Cr C) 0 0 0 L.L. 0 1!) 0 kr) C LO CNI (NI r r ISd • .%* '51 RECEIVED "2,6 V*6"1 MAY l 0 2017 WELL LOG TRANSMITTAL# ,C�GCC 0. Alaska Oil and Gas Conservation Comm. March 27, 2017 Attn.: Makana Bender 333 West 7th Avenue, Suite 100 DATA LOGGED Anchorage, Alaska 99501 .K.BENDER RE: Leak Detect Log with ACX: 2D-04 Run Date: 2/4/2017 and 2/7/2017 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 2D-04 Digital Data in LAS format, Digital Log file, Interpretation Report 1 CD Rom 50-029-21176-00 Leak Detect Log with ACX (Processed Log) 1 Color Log 50-029-21176-00 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline &Perforating Attn: Fanny Sari scANNED KA! 2 6i?fl i;_' 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907-275-2605 Fax: 907-273-3535 FRS_ANC@halliburton.com Date: Signed: , ✓teLa4z L, / ..e4tege ' • Wallace, Chris D (DOA) From: NSK Problem Well Supv <n1617@conocophillips.com> Sent: Sunday, November 27, 2016 1:29 PM To: Wallace, Chris D (DOA) Cc: Senden, R.Tyler Subject: RE: KRU 2D-04 (AIO 26.037, PTD 184-151) Report of high IA pressure 11-7-16 update 11-27-16 Chris, Based upon the small liquid leak rates obtained after the plug was set(<0.2 gpm), we have decided that the best opportunity to find the tubing leak(s) in 2D-04 is for the well to be online during logging when the cold water is being actively injected. Therefore we intend to pull the plug and return the well to injection long enough to complete the leak detect log with Eline. We don't anticipate the well needing to be online for more than 30 days. After the logging is complete,a tubing plug will be reset and the well will remain offline until a path forward can be established with proper paperwork filed before returning it to injection. The well is already AA'ed to allow TxIA communication and have the IA be equalized with injection pressure per AIO 26.037. Please let us know if you disagree. Kelly Lyons/Brent Rogers Problem Wells Supervisor ConocoPhillips Alaska, Inc. NHE® u � Desk Phone(907)659-7224 SCA Mobile Phone(907) 943-0170 From: NSK Problem Well Supv -nt: Monday, November 07,2016 10:57 AM To: - lace,Chris D (DOA)<chris.wallace@alaska.gov> Cc:Senden, '. ler<R.Tyler.Senden@conocophillips.com> Subject: KRU 2D-04 A 0 2B.037, PTD 184-151) Report of high IA pressure 11-7-16 Chris, KRU injector 2D-04(AIO 26.037, PTD -151) is currently waivered for TxIA communication. Per AIO 213.037,which was initially issued in 2008,the IA is allowed to e. .lize with the injection pressure up to 3000psi. It has been ConocoPhillips' internal policy for several years n. to not allow wells to operate with TxIA communication when on water injection. This well was allowed to remain onlin- .ecause it had not experienced communication in years. On 10- 29-16,the well was swapped from produced water to colde -awater injection after having been on produced water injection since 2010. The next day,on 10-30-16,the IA was iden 'ed with high IA pressure, maxing out just under 2300psi. After attempts to bleed the IA were unsuccessful,the well w. shut in and freeze protected. Currently it is suspected that the colder injection fluids caused the tubing to shrink and p• out of the seals at the PBR,allowing for communication to develop. The well has been secured with a tubing plug and a k detect log will be run to confirm or deny the theory. Prior to returning the well to injection, appropriate paperwork wil •- filed. Please let me know if you disagree. Attached is a 90 day TIO plot. Kelly Lyons/Brent Rogers Problem Wells Supervisor ConocoPhillips Alaska, Inc. Desk Phone(907)659-7224 1 i • Wallace, Chris D (DOA) From: NSK Problem Well Supv <n1617@conocophillips.com> Sent: Monday, November 07, 2016 10:57 AM To: Wallace, Chris D (DOA) Cc: Senden, R. Tyler Subject: KRU 2D-04 (AIO 2B.037, PTD 184-151) Report of high IA pressure 11-7-16 Attachments: 2D-04 90 day TIO 11-7-16.PNG Chris, KRU injector 2D-04 (AIO 26.037, PTD 184-151) is currently waivered for TxIA communication. Per A10 26.037, which was initially issued in 2008,the IA is allowed to equalize with the injection pressure up to 3000psi. It has been ConocoPhillips' internal policy for several years now to not allow wells to operate with TxIA communication when on water injection. This well was allowed to remain online because it had not experienced communication in years. On 10- 29-16,the well was swapped from produced water to colder seawater injection after having been on produced water injection since 2010. The next day, on 10-30-16,the IA was identified with high IA pressure, maxing out just under 2300psi. After attempts to bleed the IA were unsuccessful, the well was shut in and freeze protected. Currently it is suspected that the colder injection fluids caused the tubing to shrink and pull out of the seals at the PBR, allowing for communication to develop. The well has been secured with a tubing plug and a leak detect log will be run to confirm or deny the theory. Prior to returning the well to injection, appropriate paperwork will be filed. Please let me know if you disagree. Attached is a 90 day TIO plot. Kelly Lyons/Brent Rogers Problem Wells Supervisor ConocoPhillips Alaska, Inc. Desk Phone (907) 659-7224 Mobile Phone (907) 943-0170 SCANNED MAY 2 62017 _y !N N 1411 O. fi ✓1 < W W W ti z U - - O 4/1 W Cr O 0O (CA c o .n ',#e" o O O 0 001 O C a D °, N J Y y W m Lu W 'al 0 0 -J d 'al CJ CY 00 'is; nl (` 41 rO "' w to W O O O O O c�3 O O o O 5 0 o v v v v o 0 0 0 0 J81 N N GN Bap SCI " u, �., '� w v 0 up z ' 1 Z r 8 g • 8 S m ;13 88 5 o....• • ✓ D V N 03 � 7 _ _ Q (P 4.0 C N Oa. II ' IIIII CO n o 0 0 o S ;. (. w, r, c- c- U-I O - Vl � r i r'I r 1 (Y 0:11E'GsSii 6) !y )" - !Sd MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE: Tuesday,June 28,2016 TO: Jim Regg r7 P.I.Supervisorrei 7 J�jr 1(0 SUBJECT: Mechanical Integrity Tests ( ( ` CONOCOPHILLIPS ALASKA INC 2D-04 FROM: Johnnie Hill KUPARUK RIV UNIT 2D-04 Petroleum Inspector Src: Inspector Reviewed By: P.I.SuprvE NON-CONFIDENTIAL Comm Well Name KUPARUK RIV UNIT 2D-04 API Well Number 50-029-21176-00-00 Inspector Name: Johnnie Hill Permit Number: 184-151-0 Inspection Date: 6/21/2016 Insp Num: mitJWH160627110945 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well 2D-04 • Type Inj N`TVD 5916 Tubing 1390 3300 3330 - 3330 PTD 1841510 Type Test SPT Test psi 3000 '- IA 1240 3310 - 3230 - 3200 - Interval REQVAR P/F P OA 300 570 575 575 - Notes: CMIT TxIA Max anticipated� injection psi 3bbls diesel used o03 7 sumo NOV 2 22016 Tuesday,June 28,2016 Page 1 of 1 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg i r7 DATE: Tuesday,June 28,2016 P.I.Supervisor 1-.een (113 IRO SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 2D-04 FROM: Johnnie Hill KUPARUK RIV UNIT 2D-04 Petroleum Inspector Src: Inspector Reviewed B p� P.I.Supry'3 NON-CONFIDENTIAL Comm Well Name KUPARUK RIV UNIT 2D-04 API Well Number 50-029-21176-00-00 Inspector Name: Johnnie Hill Permit Number: 184-151-0 Inspection Date: 6/21/2016 Insp Num: mitJWH1606271I1252 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well 2D-04 Type Inj N• TVD 5916 - Tubing 850 1000 . 1050 - 1075 - PTD 1841510 - Type Test SPT Test psi 1800 IA 800 918 - 913 - 913 Interval REQVAR P/F P ' OA 250 2000 - 1920 - 1900 Notes: MITOA to 1800 psi A1O 2B.037 0.8bbls diesel used - SCANNED NOV 2 2 2016 Tuesday,June 28,2016 Page I of 1 WELL LOG TRANSMITTAL#902857312 To: Alaska Oil and Gas Conservation Comm. December 3, 2015 Attn.: Makana Bender 333 West 7th Avenue, Suite 100 DATA LOGGED Anchorage, Alaska 99501 `ZniVNI r :, M.K.B NDER RE: Multi Finger Caliper(MFC): 2D-04 Run Date: 10/24/2015 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 2D-04 Digital Data(LAS), Digital Log file, Casing Inspection Report, 3D Viewer 1 CD Rom 50-029-21176-00 PLEASE ACKNOWLEDGE 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 Fax: 907-273-3535 FRS_ANC@halliburton.com Date: Signed: ge Project Well History File' Page XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. RESCAN DIGITAL DATA OVERSIZED (Scannable) [3 Color items: [3 Diskettes, No. [] Maps: [] Grayscale items: [] Other, No/Type [] Other items scannable by large scanner r~ Poor Quality Originals: OVERSIZED (Non-Scannable) [] Other: NOTES: ;:D Logs of various kinds [] Other BY: BEVERLY BREN VINCENT SHERYL MARIA LOWELL DATE: /SI Project Proofing BY: BEVERLY BREN VINCENT SHERYL MAR A LOWELl. DATE: Is~ SCanning Preparation ~ x 30 = * b~ BY: BEVERLY BREN VINCENT SHERY~ LOWELL Production Scanning Stage l PAGE COUNT FROM SCANNED FILE: Stage 2 + /-~7- = TOTALPAGES (~ 7*v F PAGE COUNT MATCHES NUMBER IN SCANNING PREPARATION: X YES NO IF NO IN STAGE 1, PAGE(S) DISCREPANCIES WERE FOUND: YES NO (SCANNING IS COMPLETE AT THIS POINT UNLESS SPECIAL ATTENTION IS REQUIRED ON AN INDIViOUAL PAGE BASIS RESCANNEDBY~ BEVERLY BREN VINCENT SHERYL MARIA LOWELL DATE: ~si General Notes or Comments about this file: Quality Checked (done) 10125/02Rev3NOTScan ned.wlxt MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg �� z..-- DATE:Wednesday,June 06,2012 P.I.Supervisor SUBJECT:Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 2D-04 FROM: Matt Herrera KUPARUK RIV UNIT 2D-04 Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry NON-CONFIDENTIAL Comm Well Name KUPARUK RIV UNIT 2D-04 API Well Number 50-029-21176-00-00 Inspector Name: Matt Herrera Permit Number: 184-151-0 Inspection Date: 5/10/2012 Insp Num: mitMFH120601 1 1 5439 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well 2D-04 • Type Inj N 'TVD 5916 ' IA 995 1080 • 1090 - 1090 - PTD 1841510 - L_______.___Type Test L SPT,Test psi' 1800 - OA 0 1820 - 1740 1720 - — Interval REQVAR _ P/F i F Tubing 920 -930 - 940 940 - 1_ 1 Notes: MITOA per MO 2B.037 ,..-- -Faded, 4e -. .,2_c Ca - ,A9sc piss,vt (GA) drrypat h___lvw ref 10l 4 s s S- C I 6uCes-) SCANNED MAR 13 2014 Wednesday,June 06,2012 Page 1 of 1 • • '<Z it ZD -v Regg, James B (DOA) P� 1 645 From: NSK Problem Well Supv [n1617 @conocophillips.com] Sent: Monday, May 14, 2012 8:07 PM c ,� i� i To: Regg, James B (DOA) �� Cc: Brooks, Phoebe L (DOA); Dethlefs, Jerry C; NSK Problem Well Supv Subject: RE: Kuparuk witnessed MIT's Attachments: 2B -09 schematic.pdf; MIT KRU 2D -04 05- 10- 12.xls Jim, V2D-04 — Attached is a corrected MIT form with the MITOA added on it. I apologize for not having that on there. The initial pressure on the OA was 0 psi and remained 0 psi throughout the test so the OA shut in equipment would not have tripped during the CMIT TxIA. 2B -08 — The 6019' TVD is for the bottom packer for a tubing patch. The TVD for the Baker FHL production packer is 5831' TVD as noted on the schematic you are referencing. 2B -09 — The top production packer is at 5805' TVD and the lower packer is at the 5956' TVD. Attached is a wellbore schematic for reference. 2B -11 — I was unsure what to put in the result box so the test was designated inconclusive in the comment box. Thank you for clarifying for future reference. Please let me know if you have any further questions. Brent Rogers / Kelly Lyons Problem Wells Supervisor ConocoPhillips Alaska, Inc. Desk Phone (907) 659 -7224 ►� JUN .t all Pager (907) 659 -7000 pgr. 909 From: Regg, James B (DOA) [mailto:jim.regg@ alaska.gov] Sent: Monday, May 14, 2012 5:13 PM To: NSK Problem Well Supv Cc: Brooks, Phoebe L (DOA) Subject: [EXTERNAL]RE: Kuparuk witnessed MITs KRU 2D -04 (PTD 1841510) - Did not see results of MITOA? - Please explain the 1000psi pre -test pressure on IA. According to AIO2B.037, this well is required to have installed and operational an auto shut in tied to the OA, with a required trip pressure of 1000psi. I understand that this would have to be defeated for the CMIT, a pre -test pressure of 1000psi is confusing KRU 2B -08 (PTD 1840260) - Packer TVD should be 6019 ft based on the most recent well schematic in our well records (attached to 10 -404 for sundry 311 -147). - This raises a broader question relating to packer TVD. AOGCC and operators made a significant time commitment a few years back — including numerous reviews of well data — to resolve packer TVD differences; seems we are frequently discussing /debating packer TVD with CPAI. How does CPAI and AOGCC resolve this? KRU 2B -09 (PTD 1840270) - Packer TVD again; you show 5805 ft; we show 5956 ft; this time I do not have a well schematic to base this on, and no recent sundry notices /reports. At least the test pressure is unaffected KRU 2B -11 (PTD 1840350) 1 - Initial test shown inconclusive pressure loss did not stabilize); show this test result as "1" Jim Regg AOGCC 333 W. 7th Ave, Suite 100 Anchorage, AK 99501 907- 793 -1236 From: NSK Problem Well Supv [mailto:n1617t conocophillips.com] Sent: Saturday, May 12, 2012 8:38 PM To: Regg, James B (DOA); Schwartz, Guy L (DOA); Brooks, Phoebe L (DOA); DOA AOGCC Prudhoe Bay Subject: Kuparuk witnessed MIT's All, Attached are the test forms for the MIT's performed on 05/10/12. These included 2B pad (wells 06 & 10 were not tested as they were shut in at the time of testing), 2D -04 CMIT TxIA & MITOA as per AIO 2B.037 and the witnessed retest of 2H- 16. Please let me know if you have any questions. Brent Rogers / Kelly Lyons Problem Wells Supervisor ConocoPhillips Alaska, Inc. Desk Phone (907) 659 -7224 Pager (907) 659 -7000 pgr. 909 2 • . STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Submit to: jim.rega alaska.gov; doa. aoocc.prudhoe.bavCcaalaska.gov; phoebe.brooks@alaska.00v taphrmatieflerteralasicamov OPERATOR: ConocoPhillips Alaska, Inc. f FIELD 1 UNIT / PAD: Kuparuk / KRU / 2D pad eff �l/5lly DATE: 05/10/12 OPERATOR REP: Jensen / Phillips / Miller AOGCC REP: Matt Herrera Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. l Well 2D -04 Type Inj. N TVD - 5,916' Tubing 1040 3260 3210 3180 3170 Interval V P.T.D. 1841510 ' Type test P ' Test psi - 1500 Casing 1,000 3,270 ✓ 3,180 3,150 3,140 '''" P/F P '" Notes: CMIT -TxIA as per AIO 28.037. r OA 0 0 0 0 0 Well 2D -04 , Type Inj. N - TVD ' 5,916' Tubing 920 930 940 940 Interval V P.T.D. 1841510- Type test P - Test psi '1800 Casing 995 1,080 1,090 1,090 P/F ,'p Notes: MITOA as per AIO 2B.037 OA 0 • 1820 1740 1720 ' Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P /F_ Notes: OA Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA TYPE INJ Codes TYPE TEST Codes INTERVAL Codes D = Drilling Waste M = Annulus Monitonng I = Initial Test G = Gas P = Standard Pressure Test 4 = Four Year Cycle I = Industrial Wastewater R = Internal Radioactive Tracer Survey V = Required by Variance N = Not Injecting A = Temperature Anomaly Survey T = Test during Workover W = Water D = Differential Temperature Test 0 = Other (describe in notes) Form 10 -426 (Revised 06/2010) MIT KRU 2D - 04 05 - 10 - 12 • MEMORANDUM TO: gg ,g I PII Supervisor ~~r' ~(Z~~l~' FROM: Bob Noble Petroleum Inspector State of Alaska Alaska Oil and Gas Conservation Commission DATE: Wednesday, June 30, 2010 SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 2D-04 KUPARUK RIV UNIT 2D-04 Src: Inspector N(lN_(`(1NFTilF.NTi A i . Reviewed By: P.I. Suprv Comm Well Name: KUPARUK RIV UNIT 2D-04 API Well Number: 50-029-21176-00-00 Inspector Name: Bob Noble mitRCN100628081424 Insp Num: Permit Number: 184-151-0 Inspection Date: 6/25/2010 Rel Insp Num: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Wel~-2D-04 ' ~-ype Ip Tl ~I 'r`ID I 5916 IA 1000 1040 1060 ~ 1070 P.T.D~ l~ aalsl° T}~p Te eSt ; SPT Test psi 1800 ~ ~A 220 ~ 1800 ~ ~ 1740 1730 ,- IntervalREQvAR P/F l Tubin r g 1350 1350 _ ~ 1350 1350 I - Notes: MIT-OA ,1~1,IA~ ~~ `~ ~ ~ l ~~~, ~/ Z<~ ,L~ aJ7 ,- .~~ F ~~~1+ Wednesday, June 30, 2010 Page I of 1 • MEMORANDUM TO: Jim Regg ~ 7`2~ ~j ``~ Ic P.I. Supervisor FROM: BOb Noble Petroleum Inspector State of Alaska Alaska Oil and Gas Conservation Commission DATE: Wednesday, June 30, 2010 SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 2D-04 KUPARUK RIV lJNIT 2D-04 Src: Inspector NON-CONFIDENTIAL CJ Reviewed By: P.I. Suprv ~~ Comm Well Name: KUPARUK RIV UNIT 2D-04 API Well Number: 50-029-21176-00-00 Inspector Name: Bob Noble Insp Num: mitRCN100628080523 Permit Number: 184-151-0 Inspection Date: 6/25/2010 Rel Insp Num: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well ~~ 2D-04 Type Inj. ' N TVD s916 ~ jA P.T.D lsatsto'T eTest SPT ~ Test si ~ 3z6o ~ pA YP P 1640 iso 3260 3260 324 zso zso i zso i - __ Interval R>rQvAR p/F P 'Tubing ts3o ~ sz2o st6o 3t6o ~ I __ Notes: MIT-IA N~ ~ . reY ~ -~s~- t 5a~~; 1~~c: zP 03-7 n Wednesday, June 30, 2010 Page 1 of 1 ConocoPhillps P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 January 1St, 2010 Mr. Guy Schwartz Alaska Oil & Gas Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 Dear Mr. Guy Schwartz: U JA~~ ~ 1~3 ~~J~-off Enclosed please find a spreadsheet with a list of wells from the Kuparuk field (KRiJ). Each of these wells was found to have a void in the conductor. These voids were filled with cement if needed and corrosion inhibitor, engineered to prevent water from entering the annular space. As per previous agreement with the AOGCC, this letter and spreadsheet serves as notification that the treatments took place and meets the requirements of form 10-404, Report of Sundry Operations. The cement was pumped November 10th, 20th and 24th, 2009. The corrosion inhibitor/sealant was pumped December 29th and 30th, 2009. The attached spreadsheet presents the well name, top of cement depth prior to filling, and volumes used on each conductor. Please call MJ Loveland or Perry Klein at 907-659-7043, if you have any questions. Sincerely, Perry K1 ConocoPhillips Well Integrity Projects Supervisor • ConocoPhillips Alaska Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10-404) Kuparuk Field Date 01/01/10 - a~~ ~e ~r_ ~n a ~K Well Name API # PTD # Initial top of cement Vol. of cement um ed Final top of cement Cement top off date Corrosion inhibitor Corrosion inhibitor/ sealant date ff bbls ff al 2A-26 50103205750000 2080940 12" n/a 12" n/a 4.25 12/30/2009 2A-27 50103206040000 2091070 36" Na 36" n/a 12.75 12/30/2009 2C-14 50029212260000 1842100 18' 2.5 50" 11/20/2009 12.32 12/30/2009 2C-15 50029212190000 1842030 SF n/a 26" n/a 4.67 12/30/2009 2C-16 50029212180000 1842020 SF n/a 33" n/a 7.22 12/30/2009 2D-02 50029211770000 1841520 SF n/a 24" n/a 4.45 12/30/2009 2D-03 50029211780000 1841530 SF n/a 24" n/a 4.67 12/30/2009 2D-04 50029211760000 1841510 SF Na 24" n/a 4.45 12/30/2009 2p-05 50029211570000 1841260 SF Na 24" Na 4.45 12/30/2009 2D-08 50029211580000 1841270 SF n/a 28" n/a 4.67 12/30/2009 2D-13 50029210700000 1840120 21' 3.0 27" 11/10/2009' 5.1 12/30/2009 2D-14 50029211830000 1841590 SF n/a 24" n/a 6.37 12/30/2009 2D-16 50029211850000 1841610 28' 4.0 26" 11/10/2009 5.1 12/30/2009 3K-27 50029227510000 1970460 7' 1.0 12" 11/24/2009 2.97 12/29/2009 C Page 1 of 1 Regg, James B (DOA) /~ From: NSK Well Integrity Proj [N1878@conocophillips.com] Sent: Wednesday, October 08, 2008 4:48 PM To: Regg, James B (DOA); Fleckenstein, Robert J (DOA) Cc: NSK Problem Well Supv Subject: RE: KRU 2D-04 Attachments: MIT KRU 2D-04 05-28-08.x1s; MIT KRU 2D-04 06-19-08.x1s; MIT KRU 2D-04 06-21-08.x1s Jim, Enclosed are the three pressure tests you requested. Please let me knout if ou have an uestions. (~ r~~`~""~ ~~` h~~'~`` '~ ~~~~ Y Y q ~,: W _~~;: Sincerely, Perry From: Regg, James. B (DOA) [mailto:jim.regg@alaska.gov] Sent: Tuesday, September 30, 2008 12:25 PM To: NSK Problem Well Supv; NSK Well Integrity Proj Cc: Fleckenstein, Robert J (DOA) Subject: KRU 2D-04 We are missing MITs done 5/28/2008 (MITOA), 6/19/2008 (MITT), and 6/21/2008 (CMIT TxIA?). Please provide these so they can be part of record for admin approval application. Jim Regg AOGCC 333 W.7th Avenue, Suite 100 Anchorage, AK 99501 907-793-1236 10/8/2008 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Email to:jim.regg@alaska.gov; tom.maunder@alaska.gov;bob.fleckenstein@alaska.gov;doa.aogcc.prudhoe.bay@alaska.gov OPERATOR: FIELD /UNIT /PAD: DATE: OPERATOR REP: AOGCC REP: ConocoPhillips Alaska Inc. Kuparuk /KRU / 2D-04 06/21 /08 Phillips- AES Packer Depth Pretest Ini 'al 15 Min. 30 Min. Well 2D-04 Type Inj. W TVD 5,916' Tubing 1,600 550 2,550 2,550 Interval O P.T.D. 1841510 Type test P Test psi 1500 Casing 1,050 2,400 2,375 2,375 P/F P Notes: Diagnostic CMIT ~ OA 80 80 160 160 Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA TYPEINJ Codes D =Drilling Waste G =Gas I =Industrial Wastewater N =Not Injecting W =Water TYPE TEST Codes M =Annulus Monitoring P =Standard Pressure Test R =Internal Radioactive Tracer Survey A =Temperature Anomaly Survey D =Differential Temperature Test INTERVAL Codes I =Initial Test 4 =Four Year Cycle V =Required by Variance T =Test during Workover O =Other (describe in notes} MIT Report Form BFL 11/27/07 MIT KRU 2D-04 06-21-08.x1s STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Email to:jim.regg@alaska.gov; tom.maunder@alaska.gov;bob.fleckenstein@alaska.gov;doa.aogcc.prudhoe.bay@alaska.gov OPERATOR: FIELD /UNIT /PAD: DATE: OPERATOR REP: AOGCC REP: ConocoPhillips Alaska Inc. Kuparuk /KRU / 2D-04 06/19/08 Hanks- HES Packer Depth Pretest Initial 15 Min. 30 Min. Well 2D-04 Type Inj. W TVD 5,916' Tubing 1,625 2,400 2,400 2,390 Interval O P.T.D. 1841510 Type test P Test psi 1500 Casing 1,475 1,525 1,525 1,540 P/F P Notes: Diagnostic MITT OA 120 120 120 120 Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA TYPE INJ Codes D =Drilling Waste G =Gas I =Industrial Wastewater N =Not Injecting W =Water TYPE TEST Codes M =Annulus Monitoring P =Standard Pressure Test R =Internal Radioactive Tracer Survey A =Temperature Anomaly Survey D =Differential Temperature Test INTERVAL Codes I =Initial Test 4 =Four Year Cycle V =Required by Variance T =Test during Workover O =Other (describe in notes) MIT Report Form BFL 11/27/07 MIT KRU 2D-04 06-19-08.x1s STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Email to:jim.regg@alaska.gov; tom.maunder@alaska.gov;bob.fleckenstein@alaska.gov;doa.aogcc.prudhoe.bay@alaska.gov OPERATOR: FIELD /UNIT /PAD: DATE: OPERATOR REP: AOGCC REP: ConocoPhillips Alaska Inc. Kuparuk /KRU / 2D-04 05/28/08 Ives/Colee - AES Packer Depth Pretest Initial 15 Min. 30 Min. Well 2D-04 Type Inj. W TVD 5,916' Tubing 2,250 2,250 2,250 2,250 Interval O P.T.D. 1841510 Type test P Test psi 1500 Casing 2,300 3,00 2,925 2,875 P/F F Notes: Diagnostic MITIA OA 660 720 720 720 Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA TYPE INJ Codes D =Drilling Waste G =Gas I =Industrial Wastewater N =Not Injecting W =Water TYPE TEST Codes M =Annulus Monitoring P =Standard Pressure Test R = Intemal Radioactive Tracer Survey A =Temperature Anomaly Survey D =Differential Temperature Test INTERVAL Codes I =Initial Test 4 =Four Year Cycle V =Required by Variance T =Test during Workover O =Other (describe in notes) MIT Report Form BFL 11/27/07 MIT KRU 2D-04 05-28-08.x1s • ,,, ProActive Diagnostic Services, Inc. To: AOGCC Christine Mahnken 333 West 7th Avenue suite 100 Anchorage, Alaska 99501 (907) 659-51 Q2 ~~,~~~~ JUN ~ ~ Z00~ RE : Cased Hole/Open Hole/Mechanical Logs and/or Tubing Inspection(Caliper/ MTT) The technical data fisted below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the following ProActive Diagnostic Services, Inc. Attn: Robert A. Richey 130 West International Airport Road Suite C Anchorage, AK 99518 Fax. (9O7j 245-8952 1 J Caliper Report 19,Jun-08 2D-04 1 Report / EDE 50-029-21176-00 2J LeakDetection - WLD 15-Jun-08 2D~02 1 BL / EDE 50{729-21177-00 UT C t ~ ~-(- t S ~ J (o `-~4 ~ ~ ys e, iirs~-l- ~ 5 J !(v~195 ~( Signed : ~. Date Print Name: ~ ~nl l `i t~~ f~V l ,Cri- ~ /,~~ PROACTIVE DIAGNOSTIC SERVICES, INC., 130 W. INTERNATIONAL AIRPORT RD SUITE C, ANCHORAGE, AK 99518 PHONE: (907)245-8851 FAx: (907)245-88952 E-MAIL :?~ .,~:~ ~ :~:, A - WEBSITE:'r.~ C:\Documenls and Settings\OwnerlDesktop\Tiat~smit Conoco.doc Company: ConocoPhillips Alaska, Inc. Well: 2D-04 Log Date: June 19, 2008 Field: Kuparuk Log No.: 8689 State: Alaska Run No.: 1 API No.: 50-029-21176-00 Pipet Desc.: 3.5" 9.3 Ib. J-55 8RD EUE Top Log Intvl1.: Surface Pipet Use: Tubing Bot. Log tntvl1.: 8,214 Ft. (MDj • • Memory Multir-Finlger Caliper Log ~esult~s summary Inspection Type : Corrosive & Mechanical Damage Inspection COMMENTS: This caliper data is Beal into the Packer ~ 8,208' (Drillers Depth). This log was run to assess the condition of the tubing with respect to internal corrosive and mechanical damage. The caliper recordings indicate that the interval of 3.5" tubing logged is in goad to fair condoion, only two of the 266 joints logged have recorded wall penetrations in excess of 20% wall thickness. The damage recorded appears mostly in the form of Isolated Pitting, with same shallow corrosion beginning to form. An area of deposits is recorded from 2,520' to 2540' with a minimum ID of 2.56" In that interval. There are no areas of significant Cross Sectional Wall loss recorded throughout the tubing. Cross-sectional drawings of the most significant events recorded are included in #his report. The distribution of maximum recorded penetrations is illustrated in the Body Region Analysis Page of this report. A graph illustrating the correlation of recorded damage to borehole profile is included in this report. MAXIMUM RECORDED WALL PENETRATIONS Isolated Pitting Isolated Pitting ( 48%) Jt. 187 Nc other significant wall penetrations (>20%) are recorded. MAXIMUM RECORDED CROSS-SECTIONAL METAL LOSS No areas of significant cross-sectional wall loss (>13%) are recorded. MAXIMUM RECORDED ID RESTRICTIONS ~ 5,505 Ft. (MD) ~ 5,745 Ft. (MD) Deposits Deposits Deposits Min ID = 2.56" Jt. 82 Min ID = 2.74" Jt. 81 Min ID = 2.78" Jt. 12 No other significant I.D_ restrictions are recorded. 2,529 Ft. (MD) ~ 2,526 Ft. (MD} ~ 368 Ft. (MD} Field Engineer: K_ Miller Analyst: J. Thompson Witness: S. Ferguson ProActive Diagnostic Services, Inc. / P.O. Box 1369, Stafford, TX 77497 Phone: (281) 431-7100 or (888) 565-9085 Fax: {281) 431-7125 E-mail: PDS~~memorylog.com Prudhoe Bay Field Office Phone: {907) 659-2307 Fax: (907) 659-2314 V~ • Correlation of Recorded Damag ® Pipe 1 3.5 in (9.8' - 8208.4') Well: Field: Company: Country: Survey Date: ;e to Borehole Profile 2D-04 Kuparuk ConocoPhillips Alaska, Inc. USA June 19, 2008 ^ A pprox. Tool De viation ^ A pprox. Borehol e Profil e 14 758 1525 GLM 1 2317 3079 3851 c t GLM 2 ~, v 4 4637 5404 GLM 3 6191 GLM 4 6975 GLM 5 7753 GLM 6 263.2 8208 0 50 1 00 Da mage Pr ofile (% wall) /Tool D eviatio n (degr ees} Bottom of Survey = 263.2 1 25 50 75 100 v , ~ 125 ~ Z c 150 175 200 225 250 • • PDS Report Overview ~_ ~v Body Region Analysis Well: 2D-04 Survey Date: June 19, 2008 Field: Kuparuk Tool Type: UW MFC 24 No 211387 Company: ConocoF'hillips Alaska, Inc. Tool Size: 1.69 Country: USA No. of Fngers: 24 Anal st: .Thorn son Tubing: Nom.OD Weight Grade & Thread Nom.ID Nom. Upset Upper len. Lower len. 3.5 ins 9.3 f -55 8RD EUE 2.992 ins 3.5 ins 6.0 ins 0.0 ins Penetration and Metal Loss (°~ wall) ~ penetration body metal loss body 250 200 150 100 50 0 0 to 1 to 10 to 20 ro 40 to over 1% 10% 20% 40% 85% 85% Number of'oints anal sed rota) = 266 pene. 0 115 149 1 1 0 loss 50 210 6 0 0 0 Damage Configuration (body ) 60 40 ZO 0 isolated general line ring hole/poss pitting corrosion corrosion corrosion ible hole Number of ~oints dama ed total = 97 56 41 0 0 0 Damage Profile (% wall) ~ penetration body , _,.. metal loss body 0 50 100 n GLM 1 GLM 2 Gl_M 3 GLM 4 GLM 5 GLM 6 Bottom of Survey = 263.2 Analysis Overview page 2 • • PDS REPORT JOINT TABULATION SHEET 1 Pipe: 3.5 in 9.3 ppf J-55 8RD EUE Well: 2D-04 Body Wall: 0.254 in Field: Kuparuk Upset Wall: 0.254 in Company: ConocoPhillips Alaska, Inc. I' Nominal LD.: 2.992 in Country: USA Survey Date: June 19, 2008 Joint No. Jt. Depth (Ft.) I'~•n. Ul,.c~t (Irn.) Pen. Body (Ins.) Nen. % Metal I~~s, ",~~ Min. LD• (Ins.) Comments Damage Profile (%wall) 0 50 100 .1 10 t~ 00 1(1 ~ 2.91 PUP 1 1 n 0.03 1 ~~ ~ .91 46 U 0. 5 1 ~) t3 2.81 Shallo corrosio t. De osits. 3 78 t) 0.04 17 .' 2.88 Shall w corrosion. t De o i 4 108 t ? .03 I 1 ~ 2.91 t. De osi ts. 5 1 t) 0.03 1 1 (~ 2.86 Lt. De o its. 6 1 0 t) .05 I ~? ~) 2.90 Shall w corrosion. Lt. o f 7 201 I) 0.05 1 ~~ -1 2.87 hallow corrosion. Lt. sits. 8 233 t? 0.0 13 ~~ .86 Shall w ittin t De sits 9 61 i? 0.03 13 3 6 Shallow ittin . Lt De sits. 10 291 U 0.04 15 (, .9 Corrosion. t. osits. 11 321 t) 0.02 t3 0 2.89 12 351 U 0.05 19 t~ 2.78 Shallow orrosion. De sits. 13 383 l) 005 1'l -1 .89 Shallo corrosion. t. De sits. 14 414 (l 0.05 ~'tl I i) .86 Sallow corrosion. Lt. De si 15 444 a 0.03 11 1 2.91 16 476 t) 0.03 I ~ ~ i 2.88 Shallow it 'n Lt. De sits. 17 508 U 0.04 15 6 Shallow ittin L . e si 18 539 t) 0.03 1 U 2.89 Lt De osi ts. 19 568 U 0.03 12 2 93 20 6 0 U 0.03 12 4 2.89 Shallow ittin . Lt e sits. 1 632 U 0.03 U ~' .91 Lt. De osits. 22 664 11 0.04 14 1 2.88 Shall w ittin Lt. De si 23 695 tl 0.02 t3 ? 2.91 Lt. De osits. 24 7 ) 3 1 9 9 S Ilo i i e i 25 758 t) 0.04 1 5 I 2.91 Shallow corrosion. Lt. De osits. 26 790 U 0.03 11 2.88 Lt. a osits. 27 819 0 0.03 1:~ .? 2.92 Shallow ittin . 28 849 t) 003 11 ' 2.85 Lt. De osits. 29 878 t) 0.02 ~) 4 2.92 30 910 t) 0.03 1 Z 2.90 Lt D osi ts. 31 941 l).tl i 0.04 14 2.91 Shallow itti t. De site. 32 972 U .03 1 1 .90 lt. e os 33 1001 U 0.04 15 2.85 Shallow itti Lt. De sits. 34 1030 t) 0. 3 1 3 2.94 Shallow ittin . 35 1061 t) 0.03 It) 2.91 Lt. De osits. 36 1091 U 0.03 13 t 2.91 Shallow ittin . Lt a si 37 1122 U 0.03 1 i t, 2.87 Shallow corrosion. Lt. De osits. 38 1152 tt 0.03 11 1 2.91 Lt. De osits. 39 1183 t) 0.02 ? 2.90 Lt. De osi ts. 40 1215 U 0.03 11 1 2.91 t. De osits 41 1247 t) 0.04 18 s 2.90 Shallow ittin Lt. De sits. 4 1 79 t) 0.03 la t) 2.90 hallow ittin . 43 1310 t) 0.01 i ~ 2.89 Lt De osi ts. 44 1342 i) 0.03 1 1 2.88 Lt De osits. 45 1374 l) 0.03 12 (, 2.89 Shallow ittin . Lt. De sits. 1404 tt 0.03 13 !~ 2.89 Shallow ittin . 47 1432 ! ~ 0.04 1 ~ I 2.89 Shallow corrosion. 48 1461 0.05 '" 2.94 Corrosion. 4'~ 1493 0.05 2.91 Shallow corrosion. Lt. De osits. i Penetration Body Metal Loss Body Page 1 • • PDS REPORT JOINT TABULATION SHEET Pipe: 3.5 in 9.3 ppf J-55 8RD EUE Well: 2D-04 Body Wall: 0.254 in Field: Kuparuk Upset Wall: 0.254 in Company: ConocoPhillips Alaska, Inc. Nominal I.D.: 2.992 in Country: USA Survey Date: June 19, 2008 Joint No. Jt. Depth (Ft.) I'rvr. UI»~~t (Ins.) Pen. Body (Ins.) Pen. `% ;~1~~i.~l loss ",~~, Min. LD• (Ins.) Comments Damage Profile (%wall) 0 50 100 50 152 5 t ~ 0.02 7 _' 2.93 Lt. De sits. 51 1554 U 0.05 2U (, 2.90 Shallow corrosion. LL De osits. 52 1586 U 0.05 19 I 1 2.92 Shallow corrosion. Lt. De its. 53 1618 U 0.03 12 I 2.89 Shallow itti Lt. De sits. 54 1649 t) 0.03 13 E, 2.93 Sh Ilow itti 55 1679 t ~ 0.02 'i -1 2.89 56 1708 U 0.02 9 .' 2.91 Lt. De os ts. 57 1738 (~ 0.03 10 ~' 2.90 Lt. De osits. 58 1767 (~ 0.03 1 U 1 ~ 2.87 Lt. De osits. 59 1797 i ~ 0.03 1 1 2.85 Lt. De osits. 60 1 25 tt 0.03 1 I ~' 2.88 LL De osits. 61 1855 l) 0.03 13 U .88 Sh Ilow ittin Lt. De osits. 62 1884 l) 0.04 1 i 2.88 Shallow corrosion. Lt. osits. 6 1914 0 0.02 ~~ ~' 2.88 64 1944 E) 0. 4 14 I 2.88 Shallow ittin Lt. De osits. 65 1974 t) 0.04 15 I 2.90 Shallow ittin . 66 2005 t) 0.03 1;3 2.93 Shallow ittin . 66.1 203 (~ 0.03 L; t~ 2.94 PUP Shallow ittin . 66.2 2042 t ~ 0 t I ! ~ 2.81 SSSV 66.3 056 U 0.04 1 ~ I 2.91 PUP Shallow ittin . 67 062 U 0.03 11 2.9 Lt. De osits. 67.1 2093 Et 0 0 (i N A GLM 1 Latch ~ 2:30 68 2099 t) 0.04 14 2.91 Shallow ittin . 69 2131 (~ 0.03 12 ~ ~ 2.88 70 161 t~ 0. ~~ I .89 71 2193 U 0.03 13 I 2.92 Shallow ittin . 72 2225 (~ 0.02 9 2.91 73 2256 0 0.04 15 t~ 2.91 Shallow ittin . 74 2287 U 0.03 I .; (, 2.92 Shallow ~ttin . t. De sits. 75 2317 0 0.02 fs _' 2.93 76 2349 t) 0.03 12 I 2.88 Lt. a osits. 77 2378 (~ 0.02 7 2.94 78 2407 l) 0.0 I1 U 2.90 79 2436 U 0.04 15 _' 2.92 Shallow ittin Lt. De sits. 80 2467 U 0.04 1 7 ~' 2.91 Shallow corrosion. t. De osits. 81 2498 0 0.04 18 4 2.74 Shallow corrosion. Lt. De osits. 82 2527 U 0.03 13 2 2.60 Shallowc «osion. De its. 83 2556 U 0.03 11 4 2.92 84 2587 a 0.02 ~) I 2.91 85 2619 U 0.02 ~ E, 2.87 Lt. De osits. 86 2650 0 .02 ~) 2 2.91 87 2682 0 0.02 ~) 1 2.93 88 2714 0 0.02 ~ 1 2. 4 89 2 744 t ~ 0.01 6 I 2.89 90 2775 U 0.0 8 ~ 2.92 91 2805 t) 0.03 1Et 2.88 Lt. De osits. 92 2834 t i 0.03 1 1 I ~ 2.91 Lt. De osits. 93 2865 ~ ~ 0.02 ~~ r ~ 2.91 94 2897 0.02 2.92 9 ~ 2926 0.02 2.91 Penetration Body Metal Loss Body Page 2 • • PDS REPORT JOINT TABULATION SHEEP Pipe: 3.5 in 9.3 ppf J-55 8RD EUE Well: 2D-04 Body Wall: 0.254 in Field: Kuparuk Upset Wall: 0.254 in Company: ConocoPhillips Alaska, Inc. Nominal I.D.: 2.992 in Country: USA Survey Date: June 19, 2008 Joint No. Jt. Depth (Ft.) I'c~n. ~ it ~sc~t (Ins.) Pen. Body (Ins.) I'en. % Metal I osti ,~~ Min. LD• (Ins.) Comments Damage Profile (% wall) 0 50 100 96 958 a 0.02 9 i 2.92 97 2989 U 0.03 1 3 2.94 Shal ow ittin . 98 3020 U 0 01 4 ' 2.93 99 3049 U 0.03 I I 2.92 100 3079 n 0.02 ~) I .92 101 3111 O 0.02 ~) ~ 2.95 102 3141 U 0.0 9 a 2.93 103 3170 U 0.02 7 1 .91 104 3200 U 0.02 t3 I 2.91 105 3231 ~~ 0 03 1 1 is 2.92 106 3261 t) 0.02 ~' 2.95 107 3292 ~) 0.02 F) 1 .93 108 3323 a 0.02 ~ I 2.93 109 3354 U 0.01 -1 2.94 110 3384 t~ .04 16 I 2.91 Shallow co rosion. 111 3415 t~ 0.02 7 I 2.95 112 3445 tl 0.03 12 ) 2.93 113 3477 ~~ .03 13 ~ 2.92 Shallow ittin . 114 3507 ~~ 0.04 14 .' 2.94 Shallow ittin . 115 3539 ~) 0.03 11 2.94 116 3571 ~? 0. 4 15 2.93 Shallow ittin . 117 3602 U 0.04 17 2.93 Shallow ittin . 118 3634 t) 0.03 11 ~ .93 119 3665 ~~ 0.03 12 5 2.92 20 697 c~ 0.03 1"s Z .94 S Ilow it 'n . 121 3726 U 0.04 16 _' 2.90 Shallow ittin . 122 3758 ~ 0.02 ~) 2.94 123 3790 l) 0.01 5 a 2.92 124 3820 ~) 0.02 ~) ~ 2.91 125 3851 O 0.03 I ~ ? 2.91 126 3881 U .01 -1 I 2.95 127 3910 O 0.02 1 2.93 128 3940 U 0.02 ~) 2.92 129 3972 O 0.03 11 2.93 130 03 t) 0.01 U s 2.95 131 4036 ~) 0.02 ~) 1 2.89 132 4067 a 0.03 1 U 1 2.91 133 4098 l) 0.01 i 1 2.92 134 4130 O 0.04 1 i i ~ 2.90 Shallow corrosion. 135 4162 t1 0.02 t3 I 2.92 136 4193 t) 0.01 4 2 2.94 137 4225 U 0.03 i 4 2.92 Shallow ittin . 138 4257 ~) 0.05 its I _' 2.95 Shallow corm ion. 139 4288 ~) 0.02 is .' 2.94 140 4316 ~) 0.02 ~) ~ 2.93 141 4348 ~ i 0.01 5 _' 2.90 141.1 4377 O 0 l) U N A GLM 2 Latch ~ :00 142 4386 l) 0.01 Z 2.91 Lt. De osits. 143 4418 0.01 -t ~' 2.93 144 4449 0.01 ~ ' 2.94 Penetration Body Metal Loss Body Page 3 • • PDS REPORT JOINT TABULATION SHEEP Pipe: 3,5 in 9.3 ppf )-55 8RD EUE Well: 2D-04 Body Wall: 0.254 in Field: Kuparuk Upset Wall: 0.254 in Company: ConocoPhillips Alaska, Inc. Nominal I.D.: 2.992 in Country: USA Survey Date: June 19, 2008 Joint No. Jt. Depth (Ft.) I'c~n. t 11 ~.,~t (1rn.) Pen. Body (Ins.) Pen. % tilct.rl I u,. ';~~ Min. LD. (Ins.) Comments Damage Profile (% wall) 0 50 100 1 5 4481 U 0.03 13 4 2.94 Sh I i tin . 146 451 1 t J 0.0 9 5 2.93 147 4543 tJ 0.04 18 4 2 93 hallow ittin . 148 4574 tJ 0.05 ?(1 j 2.90 Shallow corrosion. 149 4605 t J 0.02 ~) .91 150 4 37 tJ 0.05 1 ~) - .90 Shallow orrosion. 151 4668 t J .02 ~~ _~ 2.92 152 4699 l1 0.0 I a 2.95 Shallow ittin . 153 4730 l) .03 1 ~ 5 2.93 Shallow ittin . 154 476 t J 0.03 12 b 2.95 15 4793 l) 0.0 14 _' 2.94 Shallow itti 156 4825 lJ 0.03 Imo' 1 2.9 157 4856 U 0.05 1 ~J I i J 2.92 1 8 4888 lJ 0.03 I s 2.91 Shallow ittin . 159 4919 U 0.03 IU 2.93 160 4951 t) 0.02 ~> 2.94 161 4979 t) 0.02 ~) t 2.94 16 5012 n.US 0.02 ~ _' 2.94 ittin 163 5041 t J 0.02 £~ I 2.93 164 5073 U 0.02 ~J 2.95 165 510 U 0.03 l > .95 Sallow itti 166 5132 U 0.02 9 _' 2.95 167 5162 U 0.05 18 _' .95 ha I w ittin . 168 5193 O 0.02 ~) _' 2.93 169 225 lJ 0. 3 12 I 2.91 170 5253 lJ 0.04 1 5 t, 2.94 Shallow corrosion. 171 283 lJ 0.0 1 ; I 2.9 Shallow ittin . 172 5312 ~ J 0.02 ' J 2.90 173 5342 U 0.02 ~J ~ .92 174 5372 11 0.03 11 _' 2.94 175 5404 tJ 0.05 1 ~) t, 2.92 Shallow corrosion. 176 5435 tJ 0.01 (, ' 2.95 177 466 a 0.04 14 t 2.92 Shallow ittin . 178 5495 U 0.05 1 ~J 3 2.93 Shallow corrosion. 179 55 7 (1 0.04 14 Z 2.93 Shallow ittin 180 5559 tJ 0.04 14 _' 2.92 Shallow corrosion. 1 1 5589 tJ 0.0 r3 _' 2.95 182 5618 U 0.02 '~ 2.93 183 5649 lJ 0.03 1 t ~ 2.93 Shallow cor osion. 184 5680 U 0.03 11 5 2.93 185 5712 tJ 0.02 ~' 2.93 186 5744 U 0.07 1£i 4 2.93 Isolated ittin . 187 5776 U 0.12 4£3 t .94 Isolat d i in . 188 5806 tJ 0.02 ~J I 2.89 189 5838 U 0.05 18 ~ 2.93 Sh II w ittin . 190 5869 a 0.03 11 Z 2.94 191 5901 U 0.04 1 5 (, 2.92 Shal w corrosion. 192 5933 (J 0.02 ~~ 2.89 192.1 964 !? D ~' N A GLM 3 Lat h~ 0 193 5971 0.03 ~ 2.93 Shallow ittin . Penetration Body Metal Loss Body Page 4 • • PDS REPORT JOINT TABULATION SHEET Pipe: 3.5 in 9.3 ppf J-55 8RD EUE Well: 2D-04 Body Wall: 0.254 in Field: Kuparuk Upset Wall: 0.254 in Company: ConocoPhillips Alaska, Inc. Nominal I.D.: 2.992 in Country: USA Survey Date: June 19, 2008 Joint No. Jt. Depth (Ft.) I'~~n. Ill„~~i (Ins.1 Pen. Body (Ins.) Pen. `~o ~1r~.~1 Ic~ss °r~, Min. LD• (Ins.) Comments Damage Profile (%wall) 0 50 100 194 6003 i ~ 0.03 1~ ~ 2.91 195 6034 U 0.01 5 _' 2.92 196 6066 t) 0.02 ~) .93 197 6096 U 0.02 '? 2.94 198 6128 t) 0.03 13 _' .9 Shallow ittin 199 6159 O 0.02 ~) .? 2.92 200 61 1 t) 0. 2 ~) _' 2.91 201 6223 t) 0.03 1Z 2.91 202 6254 O 0.02 ~> ~' 2.94 203 6285 l) 0.0 ti 1 2.93 204 6314 t) 0. ti ~' .94 205 6345 {~ 0.03 1 s 2.95 Shalow ittin . 206 6377 s ~ 0.02 -~ .91 207 409 t) 0.03 11 .92 08 441 (~ 0.03 12 2. 3 209 6472 !) 0. 1 ~ ~' .93 210 6503 a 0.02 2.93 11 653 a 0.0 ~ I 2.9 212 656 O 0.01 5 I .94 213 6596 (? 0 02 7 2.95 14 662 7 u 0.03 1 3 _' 2.9 215 6658 U 0.04 15 I .89 ha low co rosi n. 216 6687 t) .02 _' 2.92 217 6718 t) 0.04 I -1 ~ 2.96 Shallow corrosion. 1 6750 t) 0.0 I ~ 2.92 219 6781 U 0.02 i3 1 2.96 220 681 a 0.03 I u I 2.9 221 6844 i1 0.02 2.91 221.1 87 t) 0 s1 (~ N A GLM 4 Latch ~ 7:00 222 6880 t) 0.04 14 2.87 Shallow corrosion. Lt. De sits. 223 6912 t) 0.04 14 .92 ha low corrosion. 224 6943 t) 0.03 1 t 2.93 225 6975 U 0.02 7 .' 2.93 226 7006 a 0.02 2.94 2 7 7037 t) 0.02 7 s 2.93 228 7067 U 0.01 5 I 2.94 29 7098 U 0.01 6 ~ 2.94 230 71 0 O 0.02 ~) ' 2.95 231 7163 t) 0.02 ti ~ 2. 4 232 7194 ~? 0.04 1 ? 1 2.92 Shallow corrosion. 233 7226 t ~ 0.02 ~) _' .9 234 7257 O 0.03 1 U ~ 2.93 35 7287 l) 0.03 1 ~ 2.91 236 7319 U 0.03 13 -l .93 Shallow itti 37 7351 U 0.05 1(t 2.92 Shallow c r os'on. 238 7382 U 0.03 1 "? 4 2.91 239 7411 +) 0.03 11 `~ 2.93 240 7441 s ~ 0.02 ~) I 2.92 41 7471 O 03 I~ l 2. 1 242 7502 ~ s 0.03 I ; I '~ 2.90 Shallow ittin . Penetration Body Metal Loss Body Page 5 • PDS REPORT JOINT TABULATION SHEET Pipe: 3.5 in 9.3 ppf J-55 8RD EUE Well: 2D-04 Body Wall: 0.254 in Field: Kuparuk Upset Wall: 0.254 in Company: ConocoPhillips Alaska, Inc. Nominal I.D.: 2.992 in Country: USA Survey Date: June 19, 2008 Joint No. Jt. bepth (Ft.) I'c•n. Ut~sc•t (Ins.) Pen. Body (Ins.} I'c•n. % ~lt•t,cl I oss "4, Min. LD• (Ins.) Comments Damage Profile (%wall) 0 50 100 24 7534 t) 0.03 11 -1 2.92 44 7563 l) 0.05 2U _' .85 Corrosion Lt. De osi 44.1 7594 U 0 c1 U N G M 5 Latch ~ :00 245 7599 U .03 1 1 2.87 Lt. e o its. 246 76 9 t~.t)5 .03 11 I I 2.92 247 7659 U 0.03 11 - 2.95 248 7689 a 0.02 9 -1 2.94 249 7721 U 0.01 4 I 2.93 250 7753 l) 0.03 II 2.94 251 7782 U 0.05 I ~) ~ 2.93 Shallow corrosio . 252 7812 (? 0.03 11 b 2.93 253 7842 n 0.04 14 ; 2.93 Shallow corrosion. 254 7874 t~ 0.03 I , ~ 94 Shallow corrosion. 255 7903 t) 0.0 ct 2 2.93 56 7934 c ~ 0.01 5 _' 2.94 2 7 7965 t) 0.03 11 2.93 258 7997 0 0.03 12 2 2.92 259 80 9 t) 0.03 1~~ ? 2.93 Shallo ittin . 260 8059 t) 0.02 ~~ ~ 2.93 261 8091 ~~ 0.02 ~? _' 2.93 262 81 t~ 0.01 5 _' 2.94 262.1 8153 t) 0 U U N A GLM 6 Latch ®1:00 263 8159 c t 0.02 <1 1 2.93 263.1 8191 t~ 0 U t1 N A PBR 263.2 8208 U U U N A P cker Penetration Body f Metal Loss Body Page 6 ~,. PDS Report Cross Sections Well: 2D-04 Survey Date: June 19, 2008 Field: Kuparuk Tool Type: UW MFC 24 No 211387 Company: ConocoPhillips Alaska, Inc. Tool Size: 1.69 Country: USA No. of Fingers: 24 Cross Section for Joint 187 at depth 5805.133 ft Tool speed = 43 Nominal ID = 2.992 Nominal OD = 3.500 Remaining wall area = 97 Tool deviation = 50 ° Finger 24 Penetration = 0.123 ins Isolated Pitting 0.12 ins = 48% Wall Penetration HIGH 51DE = UP • • Cross Sections page 1 ~~ ~c~ PDS Report Cross Sections Well: 2D-04 Survey Date: June 19, 2008 field: Kuparuk Tool Type: UW MFC 24 No 211387 Company: ConocoPhillips Alaska„ Inc. Tool Size: 1.69 Country: USA No. of Fingers: 24 Tubing: 3.5 ins 9.3 ppf I-55 8RD EUE Analyst: I. Thomason Cross Section for Joint 186 at depth 5745.144 ft Tool speed = 43 Nominal ID = 2.992 Nominal OD = 3.500 Remaining wall area = 99 Tool deviation = 53 ° Finger 23 Penetration = 0.07 ins Isolated Pitting 0.07 ins = 28% Wall Penetration HIGH SIDE = UP • Cross Sections page 2 PDS Report Cross Sections .4 ~~ „ bNell: 2D-04 Survey Date: June 19, 2008 Field: Kuparuk Tool Type: UW MFC 24 No 211387 Company: ConocoPhillips Alaska, Inc. Tool Size: 1.69 Country: USA No. of Fingers: 24 Tubin 3.5 ins 9.3 f -55 8RD EUE _ Analyst: J. Thompson Cross Section for Joint 82 at depth 2528.823 ft Tool speed = 43 Nominal ID = 2.992 ~! Nominal OD = 3.500 Remaining wall area = 100 Tool deviation = 57 ° Finger 16 Projection =-0.254 ins Deposits ~~1in ID = 2.56 ins HIGN SIDE = UP L • Cross Sections page 3 PDS Report Cross Sections ~~ - ~~ „ Well: 2D-04 Survey Date: June 19, 2008 Field: Kuparuk Tool Type: UW MFC 24 No 211387 Company: ConocoPhillips Alaska, Inc. Tool Size: 1.69 Country: USA No. of Fingers: 24 Tubin 3.5 ins 9.3 f -55 8RD EUE Anal st: .Thom son Cross Section for Joint 81 at depth 2526.563 ft Tool speed = 43 Nominal ID = 2.992 Nominal OD = 3.500 Remaining wall area = 100 Tool deviation = 57 ° Finger 20 Projection = -0.187 ins Deposits Min ID = 2.74 ins. HIGH 51DE = UP • • Cross Sections page 4 CoinocoPhillips Alaska, Inc. KRU 2D-04 D-04 API: 500292117600 Well T INJ An b TS: 44 d 8202 SSSV Type: TRDP Orig Com lotion: 9/30/1984 Angle @ TD: 40 deg @ 8644 sssv (2053-2o5a Annular Fluid: Last W70: Rev Reason: Waivered Well ' OD:3.500) Reference L Ref L Date: Last U ate: 3(3!2006 Last T : 8511 CTMD TD: 8644 ftKB Last T Date: 2/9/2006 Max Hole An le: 51 d 2900 Casin S7in -CONDUCTOR Descri lion Size To Bottom TVD Wt Grade Thread Gas Lift CONDUCTOR 16.000 0 117 117 62.50 H~0 ~~/D~++~mY Casin Sin -SURFACE vane t 2t0azt0s Descr' lion Size To Bottom ND Wt Gr ® Thread ( , OD:5.313) SUR. CASING 9.625 0 3949 3115 36.00 J-55 C sin Strin - PR D C O Descri lion Size T Bottom ND Wt Grade Thread PROD. CASING 7.000 0 8603 6212 26.00 J-55 Gas LIft Tu Strin -TUBING "`~~D'"""'y Valve 2 ~ ize To Bottom ND Wt redo Thread (a3s7-a3aa, 3.500 0 8243 5941 9.30 J-55 8RD EUE OD:5.313) Perforetio s 3umm Interval ND Zone tua Ft SPF Date T Co m 8288 - 8290 5974 - 5976 UNIT B C 2 0 11/12/1984 S z cos Lin ,naeupummy 8322 - 8325 5999 - 6002 A-5 3 0 12/5/1984 IPERF 2 5/8" Slim Kone HC, Zero d .Phasin valve 3 (5968-5969, OD:5 313) ~- 8350 - 8353 6020 - 6022 A-4 3 0 12/5/1984 IPERF 2 5/8" Slim Kone HC, Zero d .Phasin . 8368 - 8375 6033 - 6039 A-4 7 2 22/1985 IPERF Rigid Jet, 90 deg. 'V' Phasin Gas Lift 8382 -8385 6044 - 6046 A-4 3 0 12/5/1984 IPERF 2 5/8" Siim Kone HC, Zero d .Phasin "~~""my 3timu & T en vanre 4 (ss7s-ss77 interval Date T Comment , ODS.3t3) 8288 -8290 11/12/1984 Cement Gaa Lift Ma ndrels Nalves St MD ND Men Mfr Man Type V Mfr V Type V OD Latch Port TRO Date R n Vlv C t Gas LiR r~m mm 1 2104 1933 MMH DMY 1.0 BK-2 0.000 0 1/15/19 ~ u y Valve 5 ~ l 2 4387 3402 MMH DMY 1.0 BK-2 0.000 0 1/15/19 (7592-7593, 3 5968 4419 MMH DMY 1.0 BK-2 0.000 0 1/15/19 oD:5.3t3) 4 6976 5071 MMH DMY 1.0 BK-2 0.000 0 1/15/1 5 7592 5484 MMH DMY 1.0 BK-2 0.000 0 1/i5/198 6 8151 5875 MMH DMY 1.0 BK-2 0.000 0 1/15/19 Gas Lirt Other lu s ui .etc. - J LRY indreUDtmmy De th ND T Descri lion ID valve 6 st5t atsz 2053 1895 SSSV Baker'FVL' "Locked Out 726/94"" Fla r rtiall cbsed . 2.810 ( - , OD:5.313) 8194 5906 PBR Baker 3.000 8208 5916 PKR Baker'FHL' 3.000 8231 5933 NIP Camco'D' Ni le NO GO 2.750 8242 5941 SOS Baker 2.992 PBR 8243 5941 TTL 2.992 (8794-8195, OD:3 500) Ge I t>~ . Date No 225/200 WAIVERED WELL: T x IA COMMUNICATION *"WATER INJECTION ONLY`* PKR (820&8209, OD:6.151) NIP (6231-8232, OD:3.500) TUBING (08243, OD:3.500, ID:2.867) SOS (8242-8243, OD:3.500) PeR (8288-8290) CemerR (8288-8290) 2D-04 (PTD# 184-151) Report of Failed MITIA Page 1 of 1 • Regg, James B (DOA) From: NSK Problem Well Supv [n1617@conocophillips.com] Sent: Thursday, May 29, 2008 9:33 AM ~ ~`5 To: Maunder, Thomas E (DOA); Regg, James B (DOA) ~~[ ~ l Cc: NSK Well Integrity Proj; NSK Problem Well Supv; CPF2 Prod Eingrs; CPF2 DS Lead Techs NSK Subject: 2D-04 (PTD# 184-151) Report of Failed MITIA Attachments: 2D-04 TIO Plot.ppt; 2D-04 Wellbore Schematic.pdf; MIT KRU 2D-04 05-28-08.x1s Jim/Tom, Kuparuk injector 2D-04 (PTD# 184-151) failed a diagnostic MITIA on 05/28/08. The T/I/O prior to the test was 2250/2300/660 and the T/I/O after the test was 2250/1120/380. CPAI previously received AOGCC approval for temporary water injection into this well which expires on 06/16/08. It is our intent during this time period to inject as necessary to diagnose the nature of the communication. Depending on the outcome of the diagnostics, CPAI will follow up with a 10-403 for repair or an AA request for continued injection. A 3 month TIO plot, Wellbore schematic, and MITIA report are attached. «2D-04 TIO Plot.ppt» «2D-04 Wellbore Schematic.pdf» «MIT KRU 2D-04 05-28-08.x1s» ..- Please contact me at your convenience if you have questions or comments. Martin Martin Walters / Brent Rogers Problem Wells Supervisor ConocoPhillips Alaska Inc. Office 907-659-7224 Cell 907-943-1720 / 1999 Pager 907-659-7000 #909 ~~1~N~ JUN ~. ~ 2008 6/5/2008 (~G-~51 IAP OAP T/IIO Plot - 2D-U4 2000 1500 a 1000 500 0 200 150 a E as 100 ~ Y O r t~ 50 0 29-Feb-08 13-Mar-08 26-Mar-O$ 08-Apr-O$ 21-Apr-08 04-May-08 17-May-08 Date • STATE OF ALASKA • ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Email to:jim.regg@alaska.gov; tom.maunder@alaska.gov;bob.fleckenstein@alaska.gov;doa.aogcc.prudhoe.bay@alaska.gov OPERATOR: FIELD !UNIT /PAD: DATE: OPERATOR REP: AOGCC REP: ConocoPhillips Alaska Inc. Kuparuk /KRU / 2D-04 05/28/04 Ives/Colee - AES Packer Depth Pretest Initial 15 Min. 30 Min. Well 2D-04 Type Inj. W TVD 5,916' Tubing 2,250 2,250 2,250 2,250 Interval O P.T.D. 1841510 Type test P Test psi 1500 Casing 2,300 3,000 2,925 2,875 P!F F Notes: Diagnostic MITIA OA 660 720 720 720 Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P!F Notes: OA Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA TYPEINJ Codes D =Drilling Waste G =Gas I =Industrial Wastewater N =Not Injecting W =Water TYPE TEST Codes M =Annulus Monitoring P =Standard Pressure Test R =Internal Radioactive Tracer Survey A =Temperature Anomaly Survey D =Differential Temperature Test INTERVAL Codes I =Initial Test 4 =Four Year Cycle V =Required by Variance T =Test during Workover O =Other (describe in notes) MIT Report Form BFL 11!27/07 2008-0528 MIT KRU 2D-04.x1s ~~* -~~~ ~ ~ KRU 2D-04 ~ ~ Ccar~ocaPhilli~a~ Alaska, Inc. Kuparuk 2D Water injection line Regg, James B (DOA) From: NSK Problem Well Supv [n1617@conocophillips.com] Sent: Tuesday, May 20, 2008 3:13 PM To: Regg, James B (DOA) Cc: Maunder, Thomas E (DOA); NSK Problem Well Supv; NSK Well Integrity Proj Subject: RE: Kuparuk 2D Water injection line Jim, The approved webs mentioned have been returned to water injection as follows: 2D-02 - BOl ~ - 17-z_ 2D-04 - BOI on 05/17108 at 08:30. i ~~ 1 ~1-15 2D-05 - BOi on 05119108 at 07:28. J ~~ _ I ~, Page 1 0~ ~~ Diagnostic testing and monitoring will be conducted during the 30 day test period. The results will be reparted to the AOGCC followed by any appropriate paperwork. Please let me know if you have any questions or need any more informa#ion. Brent RogerslMartin Walters Problem Wells Supervisar ConocoPhillips Alaska, Inc. Desk Phone {907} 659-7224 Pager {907} 659-7000 pgr. 909 From: Regg, James B (DOA) [mailto:jim.regg@alaska.gov] Sent: Wednesday, April 30, 2008 1:55 PM To: NSK Well Integrity Proj; NSK Problem Well Supv Cc: Maunder, Thomas E (DOA) Subject: RE: Kuparuk 2D Water injection line You are authorized to inject as outlined below to complete d Please provide copies of the diagnostic MITs mentioned in ~ Jim Regg AOGCC 333 W.7th Avenue, Suite 100 Anchorage, AK 99501 phone: 907-793-1236 fax: 907-276-7542 ostic testing and prepare your action plan. email. From: NSK Well Integrity Proj [ ailto:N1878@conocophillips.com] Sent: Tuesday, April 15, 200 :30 PM To: Regg, James B (DOA); aunder, Thomas E (DOA) Cc: NSK Problem Well S v; NSK Well Integrity Proj Subject: Kuparuk 2 ater injection line 6/5/2008 Kuparuk 2D Water injection line Page 1 of 2 Regg, James B (DOA) • • From: NSK Problem Well Supv [n1617@conocophillips.comJ ~Q-y'~ 5'I ~ ~ Sent: Thursday, May 01, 2008 2:32 PM l To: Regg, James B (DOA); Maunder, Thomas E (DOA) ~~ Cc: NSK Well Integrity Proj; NSK Problem Well Supv ~ ~~~ Subject: RE: Kuparuk 2D Water injection line Attachments: MIT KRU 2D-02 05-22-06.x1s; MIT KRU 2D-04 01-17-08.x1s; MIT KRU 2D-05 08-11-07.x1s Attached are the requested MIT reports. Contact me at your convenience if you have questions or comments. Martin Martin sitars 1 Brent Rogers Problem Wails Supervisor ConocoPhillips Alaska Inc. Office 907-659-7224 Cel I 907-943-'i 7201 1999 Pager 907-659-7000 #909 C~N~~ MAY ~ 2008 From: Regg, James B (DOA) [mailto:jim.regg@alaska.gov] Sent: Wednesday, April 30, 2008 1:55 PM To: NSK Well Integrity Proj; NSK Problem Well Supv Cc: Maunder, Thomas E (DOA) Subject: RE: Kuparuk 2D Water injection line You are authorized to inject as outlined below to complete diagnostic testing and prepare your action plan. Please provide copies of the diagnostic MITs mentioned in your email. Jim Regg AOGCC 333 W.7th Avenue, Suite 100 Anchorage, AK 99501 phone: 907-793-1236 fax: 907-276-7542 From: NSK Well Integrity Proj [mailto:N1878@conocophillips.com] Sent: Tuesday, April 15, 2008 2:30 PM To: Regg, James B (DOA); Maunder, Thomas E (DOA) Cc: NSK Problem Well Supv; NSK Well Integrity Proj Subject: Kuparuk 2D Water injection line Jim, The produced water injection line to 2D pad has been shut down for repairs since June 2006. Repairs are currently in progress with an expected completion date of 27APR08. At that time produced water injection capabilities will be restored to the pad. Just before and during the time of the water line shut down, three wells were reported with suspect TxIA communication. 5/1/2008 Kuparuk 2D Water injection line Page 2 of 2 2D-02 184- 2 • • _ 2D-04 184-151) 2D-05 (184-126) Due to the lack of injection water, build up rate (BUR) and trending diagnostics were not completed and the suspected leaks were not confirmed. Each well has however passed a diagnostic MITIA. At the completion of the water line repairs, ConocoPhillips requests approval to bring the above listed wells on produced water injection for 30 days for additional diagnostics and BUR TIO trending. Due to the lengthy shut in, a 30 day injection period is requested to adequately allow each well to come up to operating temperature throughout the well bore and become thermally stable before BUR TIO trending. If any of the wells indicate TxIA communication before the 30 days has passed it would be shut in and the AOGCC notified. At the end of the 30 days ConocoPhillips would present the AOGCC with the status and an action plan for each well. The action plans could included applying for an AA, 10-403 for repair, or returning the well to normal status depending on the test results. Please let me know if any additional information is required to gain approval for the 30 day injection period. MJ Loveland Well Integrity Project Supervisor ConocoPhillips Alaska, Inc. Office (907) 659-7043 Cell (907) 943-1687 5/1/2008 • STATE OF ALASKA r ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Email to:jim.regg@alaska.gov; tom.maunder@alaska.gov;bob.fleckenstein@alaska.gov;doa.aogcc.prudhoe.bay@alaska.gov OPERATOR: FIELD /UNIT /PAD DATE: OPERATOR REP: AOGCC REP: ConocoPhillips Alaska Inc. ~~~~~ ~f ~ 6 ~~~' Kuparuk /KRU / 2D-04 01 /17/08 Greenwood /Ives - AES Packer De th Pretest Initial 15 Min. 30 Min. We11 2D-04 T elnj. N TVD 5916' Tubing 1,000 1,000 1,000 1,000 Interval O P.T.D. 1841510 T petest P Test psi 1500 Casing 1,590 3,000 2,950 2,940 P/F P Notes: Diagnostic non-witnessed MITIA OA 160 170 170 170 Well 2D-04 T e In'. N TVD /5,916' Tubin 1,000 1,000 1,000 1,000 Interval O P.T.D. 1841510 T e test P Test si 1500 Casin 1,050 1,050 1,050 1,050 P/F P Notes: Diagnostic non-witnessed MITOA OA 150 1800 1740 1730 Well T e In'. TVD Tubin Interval P.T.D. T etest Test si Casing P/F Notes: OA Well T e In'. TVD Tubin Interval P.T.D. T e test Test si Casin P/F Notes: OA Well T e Inj. TVD Tubing Interval P.T.D. T e test Test si Casing P/F Notes: OA TYPE INJ Codes D =Drilling Waste G =Gas I =Industrial Wastewater N =Not Injecting W = Water TYPE TEST Codes M =Annulus Monftoring P =Standard Pressure Test R =Internal Radioactive Tracer Survey A =Temperature Anomaly Survey D =Differential Temperature Test INTERVAL Codes 1=Initial Test 4 =Four Year Cycle V =Required by Variance T =Test during Workover O =Other (describe in notes} MIT Report Form BFL 11/27/07 MIT KRU 2D-04 01-17-08.x1s 1~Ll1JCLL LII\ LL VY ULVl 111~\.V L1 V1111114 Regg, James B (DOA) • • From: Regg, James B (DOA) Sent: Wednesday, April 30, 2008 1:55 PM +~~~= To: 'NSK Well Integrity Proj'; NSK Problem Well Supv ~~~ Cc: Maunder, Thomas E (DOA) Subject: RE: Kuparuk 2D Water injection line You are authorized to inject as outlined below to complete diagnostic testing and prepare your action plan. Please provide copies of the diagnostic MITs mentioned in your email. Jim Regg AOGCC 333 W.7th Avenue, Suite 100 Anchorage, AK 99501 phone: 907-793-1236 fax: 907-276-7542 From: NSK Well Integrity Proj [mailto:N1878@conocophillips.com] Sent: Tuesday, April 15, 2008 2:30 PM To: Regg, James B (DOA); Maunder, Thomas E (DOA) Cc: NSK Problem Well Supv; NSK Well Integrity Proj Subject: Kuparuk 2D Water injection line ~~,{~~~ M~~ ~ ~ 20~ Jim, ra~C i ~rr~ The produced water injection line to 2D pad has been shut down for repairs since June 2006. Repairs are currently in progress with an expected completion date of 27APR08. At that time produced water injection capabilities will be restored to the pad. Just before and during the time of the water line shut down, three wells were reported with suspect TxIA communication. 2D-02 (184-152) 2D-04 (184-151 2D-05 (184-126) Due to the lack of injection water, build up rate (BUR) and trending diagnostics were not completed and the suspected leaks were not confirmed. Each well has however passed a diagnostic MITIA. At the completion of the water line repairs, ConocoPhillips requests approval to bring the above listed wells on produced water injection for 30 days for additional diagnostics and BUR TIO trending. Due to the lengthy shut in, a 30 day injection period is requested to adequately allow each well to come up to operating temperature throughout the well bore and become thermally stable before BUR TIO trending. If any of the wells indicate TxIA communication before the 30 days has passed it would be shut in and the AOGCC notified. At the end of the 30 days ConocoPhillips would present the AOGCC with the status and an action plan for each well. The action plans could included applying for an AA, 10-403 for repair, or returning the well to normal status depending on the test results. Please let me know if any additional information is required to gain approval for the 30 day injection period. MJ Loveland Well Integrity Project Supervisor ConocoPhillips Alaska, Inc. Office (907) 659-7043 4130/2008 01/20/06 Schlumberger NO. 3663 Schlumberger -DCS RECE\VED 2525 Gambell Street, Suite 400 Company: Alaska Oil & Gas Cons Comm Anchorage, AK 99503-2838 Attn: Helen Warman A TTN: Beth JAN 2 4 Z006 333 West 7th Ave, Suite 100 Anchorage, AK 99501 ~tt&Gascoos.~ Field: Kuparuk ~ Well Job # Log Description Date BL Color CD .~ 1 E-03 11144062 PROD PROFILE W/DEFT 01/14/06 1 1F-14 11144063 PRODUCTION PROFILE 01/15/06 1 28-14 11141241 PRODUCTION PROFILE 12/31/05 1 2G-14 11166751 SBHP SURVEY 01/12/06 1 1 E-06 11154118 PROD PROFILE WIDEFT 01/11/06 1 2X-05 11141246 INJECTION PROFILE 01/05/06 1 3A-04 11166752 INJ PROFILEIWFL 01/13/06 1 38-05 11154115 INJECTION PROFILE 01/09/06 1 2X-18 11154114 SBHP SURVEY 01/08/06 1 2X-18 11154117 PROD PROFILE W/DEFT 01/10/06 1 2H-09 11154103 PROD PROFILE W/DEFT 12/29/05 1 1 G-11 11154113 PROD PROFILE WIDEFT 01/07/06 1 2X-04 11141245 INJECTION PROFILE 01/04/06 1 2Z-13 11141242 PROD PROFILE WIDEFT 01/01/06 1 1 C-20 11133212 SCMT 12/25/05 1 2C-11 11144065 PROD PROFILE W/DEFT 01/17/06 1 ~~ 2N-339 N/A BHP SURVEY 12/01/05 1 2D-04 tM- J 5"1 N/A BHP SURVEY 12103/05 1 2U-13 11166753 PROD PROFILE W/DEFT 01/14/06 1 1 E-05 11166747 PROD PROFILE WIDEFT 12/25/05 1 2M-01 11154119 PROD PROFILE WIDEFT 01/19/06 1 SIGNED: -- F r,~ ~. 'F. 2.006 Ar . .~ $CANNED J¡:\t>l k ª . ,.. . DATE: '!f_tlM" ~ Y IN/] 7J ') Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. MIT KRU 2D-04 12-25-05.xIs --~) ----~} 8~~j.e~t:··..+VHt· KRU' 2I)-04..1¥~3P-Ø5·.xls..........'........."'..'......'..................................... ....:... .......'................,< ~~~~.~.·..~~~..Proþlem.. "#.711....~\l~y .·$Al()·.1..7@coJl()p()plji.~lip~·~S9rtt~ Ilte:Tuë 27 Dec; 2Ø0508:47::05~09ØO ...... . .'. ........ ... ..... .... ..,... .' ........,.... . . .,..... .... ... .'. ... . ........ ..' .. ...... ........ «MIT KRU 20-04 12-25-05.xls» Tom, Here are the MITIA results for 20-04 (PTO 184-151) following Jerry's 190EC05 report of possible TxlA communication. In addition to the MITIA passing it also passed a Orawdown/Build up rate test and tubing packoff tests. The pressure trend that Jerry sent last week definitely indicates possible communication, however at this time we can not locate the source, as all of our mechanical integrity tests have passed. The plan forward with this well is to internally waiver it for water only injection with the IA not to exceed 3000 psi. We will also pursue running the new Tecwell sonic leak detect tool. Please let me know if you have any questions about this well. MJ Loveland ConocoPhillips Problem Well Supervisor 659-7224 SCANNED FES 022006 :MIT KRU 2D-04 Content-Description: MIT KRU 2D-04 12-25-05.xls Content-Type: application/vnd.ms-excel Content-Encoding: base64 1 of 1 1/9/2006 9:20 AM -----~) ----) STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Email to:Bob_Fleckenstein@admin.state.ak.us;Jim_Regg@admin.state.ak.us;Tom_Maunder@admin.state.ak.us OPERATOR: ConocoPhillips FIELD 1 UNIT 1 PAD: Kuparuk/ KRU/2D DATE: 12125/05 OPERATOR REP: Rogers - AES AOGCC REP: Packer Depth Pretest Initial 15 Min. 30 Min. Well 2D-04 Type Inj. W TVD 5,106' Tubing 2700 2700 2700 2700 Interval 0 P.T.D. 1841510 Type test P T est psi 1500 Casing 3000 3400 3340 3330 P/F P Notes: Diagnostic MIT OA 520 520 520 520 Well Type Inj. TVD Tubing Interval P.T.D. Type test T est psi Casing P/F Notes: OA Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA TYPE INJ Codes o = Drilling Waste G = Gas I = Industrial Wastewater N = Not Injecting W = Water TYPE TEST Codes M = Annulus Monitoring P = Standard Pressure Test R = Internal Radioactive Tracer Survey A = Temperature Anomaly Survey 0= Differential Temperature Test INTERVAL Codes I = Initial Test 4 = Four Year Cycle V = Required by Variance T = Test during Workover o = Other (describe in notes) MIT Report Form BFL 9/1/05 MIT KRU 20-04 12-25-05.xls Kuparuk injection well 2D-04 (PTD 1841510) T x IA communication ---) ---~1 Tom: Kuparuk well 20-04 (PTO 1841510) injection well was reported today to have T x IA communication that exceeds our allowable bleed frequency. Attached is a 4 week trend plot that shows the recent problems with the lA, which has required bleeding 5 times in Oecember. Our plan is to perform an MITIA (last done 7/12/03), see if we can establish a leak rate, and propose logging the tubing with either a video or the Tec Well sonic tool to find the problem area. Previous packoff tests show they are not suspected of being the problem. The well will remain in water injection service until some point in the future it is repaired. Please let me know if you have any questions. «20-04 T-I-O Trend.gif» Jerry Oethlefs Problem Well Supervisor ConocoPhillips Alaska 907 -659-7224 Content-Description: 2D-04 T -1-0 Trend.gif T-I-O Trend.gif Content-Type: image/gif Content-Encoding: base64 1 of] 1/9/2006 9:21 AM 2D-04 T-I-O MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Randy Ruedrich Commissioner THRU: Jim Regg P.I. Supervisor DATE: July 12- 2003 t\~,~?~UBJECT: Mechanical Integrity Tests ~_Z~(.';i"~' ' , CPA 2D 4 FROM: John H. Spaulding KRU Petroleum Inspector Kuparuk River Field NON- CONFIDENTIAL Packer Depth Pretest Initial 15 Min. 30 Min. P.T.D.I 1841510 TypetestI P ITestpsil 1479 I Casingl 1950I 3250I 3125 I 3100 I P/F I P I Notes: P.T.D.I Notes: WellI P.T.D.I Notes: WellI P.T.D.I Notes: Notes: IType Inj. Type test IType Inj. Type test IType Inj. Type test Type Inj. Type test Type INJ. Fluid Codes F = FRESH WATER INJ. G = GAS I NJ. S = SALT WATER INJ. N '- NQT INJECTING Type Test M= Annulus Monitoring P= Standard Pressure Test R= Internal Radioactive Tracer Survey A= Temperature Anomaly Survey D= Differential Temperature Test Interval I= Initial Test 4- Four Year Cycle V= Required by Variance W= Test during Workover O= Other (describe in notes) Test's Details I traveled to Conoco/Phillips Alaska's KRU to witness the MIT on well 2D-04. Jared Brake was the CPA rep. today. The pretest pressures were monitored and found stable, the standard annulus pressure test was performed and appears to meet the AOGCC criteria for a successful MIT. M.I.T.'s performed: 1_ Number of Failures: 0 Total Time during tests: 1_ Attachments: cc: MIT report form 5/12/00 L.G. 2003-0712_M IT_KR U_2 D-04_js .xls 7/18/2003 OANNEL,,, i: UG 0 & 2003 STATE OF ALASKA:- ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS . . 2. Name of Operator Phillips Alaska, Inc. 3. ,Address P. O. Box 100360 Anchorage, AK 99510-0360 4. Location of well at surface 19' FNL, 756' FEL, Sec. 26, T11N, RgE, UM 5. Type of Well: Development __ F_xploratoq/__ S~r~tiDr-d~hic __ (asp's 529008, 5954178) 6. Datum elevation (DF or KB feet) RKB 127 feet 7. Unit or Property name Kuparuk Unit 8. Well number 2D-04 .At top of productive interval 1299'- FNL, 1169' FWL, Sec. 23, T11 N, RgE, UM ,At effective depth. ,At to~ depth 1081' FNL, 4304' FEI_, Sec. 23, T11N, R9E, UM (asp' s 525441, 5958381) 12_ Present well condition summary Total depth: measured true vertical 8644 feet 6244 feet Plugs (measured) 9. Permit number I approval number 10. APl number 50-029-21176 11. Field / Pool Kuparuk Oil Pool Effective depth: measured true vertical feet Junk (measured) feet Casing Length CONDUCTOR 117' SUR. CASING 3822' PROD. CASING 8476' Size Cemented Measured Depth True vertical Depth 16' 204 sx Celd Set Il 117' 117' 9°5/8' 950 sx AS m & 5O0 sx Class C 3949' 3115' 7' 460 sx Class C & 250 sa( AS I 8603' 6212' Perforation depth: (size, grade, and measured depth) RECEIVED Packers & SSSV (type & measured depth) 13. Stimulation or cement squeeze summary Intervals treated (measured) Treatment description including volumes used and final pressure 14. Prior to well operation Subsequent to operation OiFBbt Representative Daily Avera.qe Production or Injection Data Gas-Mci Water-Bbl Casing Pressure Tubinq..l~'ff...~._...u..m_- ~150~;:!':' :~ ~:i!i :.:' ~ .500!!i}!~: ......... 15. Attachments Copies of Logs and Surveys run m Daily Report of Well Operations __X 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signedjeff A. Spencer ~'~' ~~' -ritie Production Engineering Supervisor Questions? Call Jeff Spencer 659-7226 Date /~ /~( -- Prepared by Robert Chdstensen 659-7535 ORIGINALR"""s ,FL 2D.-04 DESCRIPTION OF WORK COMPLETED SUMMARY STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Operation Shutdown Pull tubing Alter casing Stimulate __ Plugging Repair well Perforate 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 X 4. Location of well at surface 21' FNL, 757'FEL, Sec. 26, T11N, R9E, UM At top of productive interval 1299' FNL, 1169' FWL, Sec. 23, T11N, R9E, UM At effective depth At total depth 1084' FNL, 972' FWL, Sec. 23, T11N, R9E, UM 6. Datum elevation (DF or KB) RKB 126 7. unit or Property name Kuparuk River Unit 8. Well number 2D-04 9. Permit number/approval number 84-1 51/94-1 81 10. APl number 50-029-211 76 11. Field/Pool Kuparuk River Oil Pool feet 12. Present well condition summary Total Depth: measured true vertical 8644 feet 6242 feet Effective depth: measured 8521 true vertical 61 47 feet feet Plugs (measured) None Junk (measured) None ORIGINAL Casing Length Size Structural 8 2' 1 6" Conductor Surface 3914' 9 5/8" Intermediate Production 8568' 7" Liner Perforation depth: measured 8322'-8324'; 8350'-8352' true vertical Cemented 204 SX COLD SET II 950 SX AS III & 500 SX CLASS C 460 SX CLASS C & 25O SX AS I ; 8368'-8374'; 8382'-8384' 5999'-6001', 6020'-6022', 6033'-6038', 6044'-6045' Tubing (size, grade, and measured depth) 3 1/2", 9.3 LB/FT, J-55 EUE 8243' Packers and SSSV (type and measured depth) BAKER FH PKR 8208', BAKER FVL 2053',OTIS MCX INJ VLV @ 2026' 13. Stimulation or cement squeeze summary Intervals treated (measured) N/A Treatment description including volumes used and final pressure Run MCX Injection Valve Measured depth 117' True vertical depth 117' 3949' 31 1 5' 8603' 6212' RECEIVED NOV '1 4 1994 0ii & Gas Cons. Commission 14. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcr Water-Bbl Casing Pressure Tubing Pressure Prior to well operation Subsequent to operation 1 300 1350 1050 ,~ 900 273O 2720 15. Attachments 116. Status of well classification as: Copies of Logs and Surveys run -- I' Water Injector X (WAG Injector) Daily Report of Well Operations X Oil _ Gas Suspended 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Service Title Wells Superintendent Date Form 10-404 Rev 06/15/88 SUBMIT IN DUPLICATE ARCO Alaska, Inc. WELL 2D-04 DATE 7/26/94 DAY TIME O7OO 0800 0920 1100 DESCRIPTION OF WORK Lockout SSSV/Tag/Run MCX Inj Valve CONTRACTOR I KEY PERSON HES-Kevin Corcoran Uni~70175 OPERATON AT REPORT TIME I-~ COMPLETE 'F'-I INCOMPLETE FIELD EST: $2,159 KUPARUK RIVER UNIT WELL SERVICE REPORT IAFC/CC# - SCA# 230DS28DL/40115 ACCUMULATED COST $2,159 LOG ENTRY SITP: 2650# 7"CP: 1150## 9-5/8"CP: 400# Page I of 2 MIRU HES & Lil Red-PT Lub to 3500g-OK! RIH w/RS, QC, 5' 1-7/8", ICI, 5' 1-7/8", KJ, SSS, QC, 3-1/2" BAKER LOT-Set LOT @ 2026' WLM- TP 2650g-Pump up to 3800g-CL press was 3500g& bled off to 2900g-Sleeve shifted-POOH RIH w/2.2 cent, TEL & 1.70 swage-Tools stopped @ 2220' WLM-Pumped diesel @ min ram-tools started falling-stopped again @ 4300' WLM-Pumped @ min rate and tools started falling again-Tag tobit tail @ 8213' WLM (8242' RKB)-Tag Eft] @ 8338' WLM (8367' RKB)-Bottom perfs @ 8384' RKB-17' of fill above bottom.perfs-POOH RDMO to 2D-05 NOV ! 4 1~94 'SUMMARY Gas Cons. Commission Locked out SSSV-Tagged fill @ 8367' RKB-17' of fffl above bottom perfs Left MCX Inj Valve out of well due to pending c'ru cleanout Final SITP: 2650g 7"CP:500g 9-5/8"CP: 400g :CHECK THIS BLOCK IF SUMMARY IS CONTINUED ON BACK Weather Temp. Chill Factor Visibility Wind Vel. Report °F °F miles knots AR3B-7031 298-3486 ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 June 29, 1994 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 Approval on the following Kuparuk well. Well 2D-04 Action Variance (Inj Valve) If you have any questions, please call me at 263-4241. Sincerely, P. S. White Senior Engineer Kuparuk Petroleum Engineering Attachments FTR062995 (w/o atch) RECEIVED JUL -5 1994 f~,isska 0g & Gas Cons. Commission ,, ~ch0rage AR3B-6003-93 242-2603 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Suspend Abandon Alter casing _ Repair well Change approved program _ 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 21' FNL, 757' FEL, SEC. 26, T11N, R9E, UM At top of productive interval 1299' FNL, 1169' FWL, SEC. 23, T11N, R9E, UM At effective depth Operation Shutdown_ Re-enter suspended well _ Plugging _ Time extension Stimulate_ Pull tubing_ Variance ~ Perforate Other 6. Datum elevation (DF or KB) At total depth 1084' FNL, 972' FWL, SEC. 23, T11N, R9E, UM 127' RKB 7. Unit or Property name Kuparuk River Unit 8. Well number 2D-04 9. Permit number 84-151 feet 10. APl number 50-029-21176 11. Field/Pool Kuparuk River Field Kuparuk River Oil Pool 12. Present well condition summary Total Depth: measured 8644 feet true vertical 6242 feet Effective depth: measured 8521 feet true vertical 6147 feet Casing Length Size Structural 1 1 7' 1 6" Conductor Sudace 3 91 4' Intermediate Production 8 5 6 8' Liner Perforation depth: measured 8322'-8324'; Plugs (measured) Junk (measured) ORIGINAL Cemented Measured depth True vertical depth 204SXCOLDSETII 117' 117' 9 5/8" ,i 950 SX AS III & 3949' 31 15' 500 SX CLASS C 460 SX CLASS C & 8603' 6212' 250 SX AS I 8350'-8352'; 6020'-6022', 8368'-8374'; 6033'-6038', 8382'-8384' 6044'-6045' RECEIVED JUL - 5 t994 true vertical 5999'-6001 ', Tubing (size, grade, and measured depth) 3 1/2", 9.3 LB/FT, J-55 EUE 8243' Packers and $SSV (type and measured depth) BAKER FH PKR 8208', BAKER FVL 2053' /~l~,sl<a 0il & Gas C0n~. Cernmis.~i0 13. Attachments Description summary of proposal ~ Detailed operation program _ BOPAi~e_ 14. Estimated date for commencing operation 15. Status of well classification as: Oil __ Gas __ Suspended 16. If proposal was verbally approved,~,. Name of approver RUSS DOUGLASS'~']' ~/Date approved 6/23/94 Service WATER/GAS INJECTION 17. I her;~y~ certi~ tllljat the f~)regoing is true and correct to the best of my knowledge. Si~ned "~~'~'~ P~'~- Date Title Senior Engineer FOR COMMISSION USE ONLY Conditions of approval: Notify Commission so representative may witness Plug integrity i BOP Test l Location clearance m Mechanical Integrity Test I Subsequent form require lO- IApproval No._ I ~-/- Approved by order of the Commission Form 10-403 Rev 06/15/88 Original Signee ~ David W. J0hn~t0n Commissioner Date ? f"~/,~' ? SUBMIT IN TRIPLICATE Approved Copy Returned Attachment 1 Request for Variance Kuparuk Well 2D-04 As per Conservation Order No. 173, Rule 5, paragraph (a) (2), ARCO Alaska requests Commission approval to replace the failed sudace controlled, subsurface safety valve in Injection Well 2D-04 with a downhole, spring controlled, injection valve. This injection valve will act as a one-way check valve allowing downward injection of water and gas while preventing upward flow of these fluids. The injection valve is capable of preventing uncontrolled flow by automatically closing if such a flow should occur. This request is necessary due to the failed control line and was verbally approved by Mr. Russ Douglass. RECEIVED JUL -$ t99z~ 0i~ & Gas Cor~s. Commission Anchorage ARCO Alaska, Inc. ,~ Post Office t~ t00360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 December 4, 1985 Mr. C. V. Chatterton, Chairman Alaska Oil and Cas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Dear Mr. Chatterton: Attached in duplicate are subsequent notices following wells at the Kuparuk River Field- on the Well Action Date Performed 1F-4 1F-5 1F-8 1G-3 1G-4 1L-3 1L-5 1Q-8 1Q-12 1Q-14 1R-3 1R-10 1Y-7 1Y-10 1Y-15 1Y-13 2B-6 2B-8 2B-11 2B-12 2C-2 2C-4 2C-5 2C-7 2D-4 2D-5 2F-3 2F-4 2F-15 2F-16 2D-1 0 2D-16 Conversion Conversion Conversion Conversion Conversion Conversion Conversion Conversion Conversion Conversion Conversion Conversion Conversion Conversion Conversion Conversion Conversion Conversion Conversion Conversion Conversion Conversion Conversion Conversion Conversion Conversion Conversion Conversion Conversion Conversion Conversion Conversion 10/24/85 10/24/85 10/24/85 10/25/85 10/25/85 10/24/85 10/24/85 10/25/85 10/25/85 10/25/85 10/26/85 10/26/85 10/26/85 10/26/85 10/26/85 10/26/85 11/5/85 11/5/85 11/5/85 11/5/85 11/6/85 11/6/85 11/6/85 11/6/85 1116/85 11/6/85 11/2/85 11/2/85 11/2/85 1112185 11/6/85 1116185 · ~. ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany _ .: . STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION CO~wMISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL OTHER [] 2. Name of Operator ARCO ALASKA, INC. 3. Address P. O. BOX 100360, ANCHORAGE, 4. Location of Well SURFACE LOCATION' T11N, RDE, UM 21' 5. Elevation in feet (indicate KB, DF, etc.) 127' 12. 7. Permit No. 84-151 8. APl Number ALASKA 99510 5o- 029-21176 9. Unit or Lease Name FSL, 757' FEL, SEC. 26, KUPARtJK RIVER UNIT 10, Well Number 2D-4 BOTTOMHOLE LOCATION: 1099' FNL, 1143' FWL, SEC. 11. Field and Pool 23, T11N, RDE, UM KUPARUK RIVER FIELD I 6. Lease Designation and Serial No. KUPARUK RI VER O ! L (RKB) ADL 25653 POOL Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate [] Alter Casing [] Perforations [] Altering Casing ~] Stimulate [] Abandon [] Stimulation [] Abandonment [] Repair Well [] Change Plans [] Repairs Made [] Other [] Pull Tubing [] Other [] Pulling Tubing [] (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). On November to a water conversion "C" sands. 6, 1985 Kuparuk well 2D-4 was converted from a producer injector well as part of the full field waterflood effort. Water is being injected into both the "A" and , r ECEiVED Alaska Oil & Gas C0nz. 14. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed The space below for Commission use Title KUPARUK Date OPERATJ ONS COORD i NATOR 11. I15/85 Conditions of Approval, if any: Approved by By Order of COMMISSIONER the Commission Date __ Submit "Intentions" in Triplicate Form 10-403 and "Subsequent Reports" in Duplicate R~v 7-1 A. ARCO Alaska, Inc..' Post Office ~. . 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 ., September 20, 1985 Mr. L..C. Smith Alaska Oil and Gas Conservation Commission 3001 ~Porcupine Street~ Anchorage, AK 99501 Dear L. C.-Smith: Per our conversation on September 4, 1985, ARCO Alaska, Inc. proposes to convert 110 production wells to water injection to implement fullfield waterflood of the Kuparuk River Unit. As discussed a single "blanket" sundry notice (form 10-403) has been completed for all well proposed to be converted to water injection. Individual subsequent sundry notices will be filed when the actual well conversions occur. As stated in form 10-403, well conversion to water injection will occur in two primary stages. The first stage will convert approximately four wells per drillsite to achieve a nine-spot pattern. First stage conversions are expected to be completed by approximately 10/15/85, prior to waterflood startup. The second stage of conversions will' convert approximately four additional wells per drillsite to achieve a line drive pattern. Second stage conversions are expected to be completed mid-December to January 1986. I would like to express my thanks and appreciation to the 'Commission in working with ARCO Alaska, Inc. in this area. If you have any questions please call me at' 263-4212. Sincerely, T. M. Drumm Kuparuk Operations Coordinator cc: J.F. Beall TMD:ps:013 RECEIVED S E P 2 0 O" & 6~s Co/is. Commission .¢ ARCO Alaska, Inc. is a Subsidiary of AtlanticRichlieldCompany - 6 - 7 - 8 2D- 2 - 4 -10 -11 -14 -16 2E-10 -12 -13 -14 2F- 1 - 2 - 3 - 4 -13 -14 -15 -16 2G- 1 - 3 - 5 - 7 -10 -12 -16 2U- 3 - 4 - 7 -11 -14 -16 2V- 2 - 4 - 5 - 6 - 7 - 8 2W- 2 - 4 - 5 - 8 - 9 MARK: 0092 100 96 95 84-152 151 126 143 101 99 159 161 84-230 211 196 197 83-183 188 187 190 156 159 172 177 84-118 139 80 85 106 128 132 85- 6 7 20 40 84-247 249 83-161 165 176 179 180 186 85- 16 12 84-191 212 219 20979 20970 20974 029-21177- 21176 21157 21169 21135 21134 21183 21185 029-21246 21227 21213 21214 029-21058 21063 21062 21065 21032 21035 21048 21052 029-21150 21165 21119 21124 21140 21159 21163 029-21269 21270 21283 21303 21262 21264 029-21037 21041 21051 21054 21055 21061 029-21279 21275 21208 21228 21235 25653 25658 25658 25657 25656 25644' I! 25643 25655 25644 !! 25655 25642 2580 12/15/85 " 10/15/85 " 12/15/85 2579 12/15/85 " 10/15/85 " 10/15/85 " 12/15/85 2584 10/15/85 " 12/15/85 " 12/15/85 " 10/15/85 2584 12/15/85 " 12/15/85 " 12/15/85 " 12/15/85 2583 12/15/85 " 12/15/85 " 10/15/85 " 10/15/85 " 12/15/85 " 12/15/85 " 10/15/85 " 10/15/85 2582 12/15/85 " 10/15/85 " 10/15/85 " 12/15/85 " 10/15/85 " 12/15/85 " 10/15/85 2575 10/15/85 " 12/15/85 " 10/15/85 2574 10/15/85 " 10/15/85 " 12/15/85 2581 10/15/85 2575 10/15/85 " 10/15/85 " 12/15/85 2581 10/15/85 " 12/15/85 2573 10/15/85 " 12/15/85 " 12/15/85 " , ECEIV ~lagk80i! & Ga~, Cor~s, Oorr~m!ss~or, STATE OF ALASKA ALASKA'"'"~". AND GAS CONSERVATION Cf"*'-'MISSION SUNDRY blOTICES AND REPORT ON WELLS DRILLING WELL [] COMPLETED WELL OTHER [] 2. Name of Operator ARCO Alaska, ]:nc. 3. Address P.O. BOx 100360, AnchOrage, Alaska 99510 4. Location of Well N/A 7. Permit No. see attached 8. APl Number 50- see attached 9. Unit or Lease Name Kuparuk River Unit 10. Well Number see attached 11. Field and Pool Kuparuk River Field 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. Kuparuk Ri vet 0i l Pool N/A I see attached 12. Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF' (Submit in Triplicate) ' (Submit in Duplicate) Perforate [] Alter Casing F-I Perforations [] Altering Casing [] Stimulate [] Abandon [] Stimulation [] Abandonment [] Repair Well [] Change Plans ~ Repairs Made [] Other [] Pull Tubing [] Other ~ Pulling Tubing [] (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). Pursuant to-form 10-403, it is proposed that the attached list of~^producing wells in the Kuparuk River Field be converted to water injection. The conversion will occur in two stages. The first conversion.~ to a nine-spot pattern will occur approximately 10/15/85. The second conversion to a line drive pattern will occur approximately :[2/:[5/85. ]:njection will be into the A and C sands. SE? 2 o 13B5 Gas Cons. commission Anchorage 14. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ;:~, ~'~ ~-~"~""~ Title Kuparuk Operations Coordinator Date The space below for Commission use 9/]8/85 Conditions of Approval, if any: Approved by Form 10-403 Rev. 7-1-80 Approved Copy By Order of COMMISSIONER the Commission Date Submit "intentions" in Triplicate and "Subsequent Reports" in Duplicate ARCO Alaska, I~ Post Offic,. ~ox 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 DATE: 06-18-85 TRANSMITTAL NO: 5219 RETURN TO: FINAL PRINTS/SCH CBL'S (ONE * OF ARCO ALASKA, INC. KUPARUK OPERATIONS ENGINEERING RECORDS CLERK ATO-1115B P,O. BOX 100360 ANCHORAGE, AK 99510 }IER~qI~H ARE. TItE FOLLOWING IT'I~qS. RETURN ONE SIGNED COPY OF L EACH ) PLEASE ACKNOWLEDGE THIS TRANSMITTAL. 1L-16--/' 11-05-84 -f 2D-4 J 11-04-84 2U-1j' 03-01-85 2U-2 -~ 03-01-85 2U-13 j 02-05-85 2U-14~" 02-09-85 2U-16 '" 02-10-85 2W-5 -- 11-25-84 2~'~-7 -'~ 11-27-84 2W-8 /' 11-27-84 2X-16 / 11-07-84 RUN #2 6994-7910 RUN ~1 5693-7620 RUN ~1 6760-7663 RUN #1 6987-8492 RUN ~1 4550-7316 RUN #1 5850-8446 RUN #1 4600-7786 RUN #1 4900-6991 RUN #1 4600-6070 RUN #1 5750-8059 RUN ~1 4530-6241 RUN #1 5140-7702 RUN ~1 7900-9568 RECEIPT ACKNOWLEDGED: B PAE B. CURRIER C HE VRON D & M DRILLING*BL L. JOHNSTON MOBIL NSK CLERK*BL DISTRIBUTION: W. PASHER EXXON PHILLIPS OIL J. RATHMELL DATE: AJa:~i,;-3 ,3;i S. 3~,~ S~,~, Commission STATE OF ALASKA*BL/ SOHIO SE UNION K.?ULIN/VAULT*FiLMS ARCO Alaska, InJ~ Post Offic~ _,ox 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 April 1, 1985 Mr. C. V. Chattert Alaska Oil and Gas 3001 Porcupine Dri Anchorage, AK 99 on, Chairman Conservation Commission ve 501 Oear Mr. Chatterton' Attached in duplicate are subsequent notices following wells at the Kuparuk River Field' on Well Action , Date Performed 1E-6 Fracture 1/26/85 1E-7 Reperf 1E-7 Fracture 3/1/85 1E-8 Reperf 1/28/85 1E-11 Reperf 2/1/85 1E-11 Fracture 2/7/85 1E-18 Fracture 3/13/85 1E-20 Stress Frac 3/19/85 1E-20 Fracture 3/23/85 1E-22 Fracture 3/22/85 1E-24 Fracture 3/22/85 1L-6 Fracture 2/2/85 1L-7 Fracture 1/30/85 1Q-9 Fracture 3/1 8/85 1Q-1 0 Fracture 3/5/85 1Q-1 2 Fracture 3/5/85 2A-3 Conversion 3/21/85 2A-4 Conversion 3/12/85 2A-5 Conversion 3/12/85 2A-6 Conversion 3/12/85 2A-7 Conversion 3/12/85 2C-4 Reperf 2/23/85 2D-4 Reperf 2/2/85 2V-8A Conversion 2X-8 Perforation 1/27/85 If you have any questions, please call Mike L. Laue Kuparuk Operations Coordinator MLL/kmc Attachment (Duplicate) me at 263-4253. the ARCO Alaska, Inc. is a Subsidiary of AtlanlicRichfieldCompany STATE OF ALASKA ALASKA ~IL AND GAS CONSERVATION CO~vIMISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL OTHER [] 2. Name of Operator 7. Permit No. ARCO ALASKA, INC. 84-151 3. Address 8. APl Number P. O. BOX 10,0360, ANCHORAGE, ALASKA 99510 5o- 029-21176 4. Location of Well SURFACE LOCATION' 21' FSL, 757' FEL, SEC, 26, T11N, R9E, UM BOTTOMHOLE LOCATION' 23, T11N, R9E, 5. Elevation in feet (indicate KB, DF, etc.) 127' (RKB) 12. 1099' FNL, 1143' FWL, SEC. UM I 6 . Lease Designation and Serial No. ADI 25653 9. Unit or Lease Name KUPARUK RIVER UNIT 10. Well Number 2D-4 11. Field and Pool KUPARUK RIVER KUPARUK RIVER POOl Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data FIELD OIL NOTICE OF iNTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate} Perforate [] Alter Casing [] Perforations [~ Altering Casing [] Stimulate [] Abandon [] Stimulation [] Abandonment [] Repair Well [] Change Plans [] Repairs Made [] Other [] Pull Tubing [] Other [] Pulling Tubing [] (Note: Report multiple completions on Form 10r407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). On February 2, 1985, the "A" sands of Kuparuk well 2D-4 were re-perforated. After testing the lubricator to 2500 psi, the was shot with a wireline conveyed gun. Interval (MD)- 8368-8375' (SPF) well 14, I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ~ Title OPERATIONS The space below for Commission use COORDINATOR 3/28/85 Date Conditions of Approval, if any: Approved by COMMISSIONER By Order of the Commission Date Form 10-403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate ARCO Alaskli, Inc. '"' ' ' Post Office buX 360 Anc.horage, Alaska 99510 Telephone 907 277 5637 ' A R E 'T'i"II!!: I::' 0 I... !.. C] W I i'-! (: N IF. 5' I,.6. N I"": D C [] I::'Y 0 I"- ., , 5' I:': (:.! L.I E: N C E: 2(.:-4 ' / O F I:i: V E N T,.? F'L. U 5" I... O (.';- .. , F'O,"; T F'I:.: R F: (::- A,? E: i',!. 'I-R Y O ''g ") "'"' ' '":' r.:- .-, .,.. ,. ....-,-..o-,:,..' I'.U~-!-,,-t R E Z I:' I:: R F:" C ,' ',7 A N g ..... O ''> "> ''> "--"'~ ~:~ · :. -' -' .... '::.--.. R 11 i'! '-Il: ''~ ... £.. g.A,.? ~ I1.': N :r I':.,_Y ..... 0'~ 'i '" ,",,:'r',r~.,~.,. . -',"- '"' ::" O ..) F\ ~,.; I".. 'Ir t I'"' 0 <''~' !:-" i-:.: A C ~, T I."-. i"! F:' C. A H C 0 <: :~ 86.5: ,.~ ,. 5' C !"1L U H B I.'T. I':.: r; E I'":': ( ~'~ (] ,? ]: N 6 I... I:: :1: i'-! T E: I'",' V L., ) C..' A F'i C CJ ..... C, A H C O '7,., '~ r-;... 0 ........ .... 7 SE; r) ...,,.- ........ . D I':: Ii:: ,?.-: 2 E I;.: ..... [--~' I ',.. I-I ,:'~ ,. . .... ,.. · O'[' :1: ,? ' ' 7-4 ~':' 0 .... -~ '? :-~ n .... · .." . I ! :,! ;,, '," .", '..-..r.:, .... '7'?':"'-I I "? .,.' ... .,.) C A H C 0 74.50 .... '?700 ~,. ,.-... {.J J..J ]: .I]:1 X- 'J UN :r. 0 U ','.' I · .. ARCO Alaska, Ino- Post. Office. .,x 360 Anchorage. Alaska 99510 Telephone 907 277 5637 ARCO Alaska, h' Post Office flox 360 Anchorage, Alaska 99510 Telephone 907 277 5637 9 "F ;I; S Fi) 'F 1; £ 0 "J" ;[ 5' 0 '? .I. S' 0 T .]; ,~:.." 0 '1" i[ 3 0 l' ]. ,:..:, 0 T I ,? L-I 'F .[ ,S C H [!: V F:' {-.:" i',! ':'" i I) ,?..-N .. ARCO AlasKa. Inc ~s a subs~chary ol AllantmR'cf3heldCompany ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 March 26, 1985 Mr. C. V. Chatterton Commi s s i one r State of Alaska Alaska Oil & Gas Conservation Commi ssi on 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT' Well Completion Reports Dear Mr. Chatterton- Enclosed are Well Completion Reports for the following wells' 2D-2 2D-3 2D-4 If you have any questions, please call me at 263-4944. Sincerely, . Gruber Associate Engineer JG/tw GRUS/L56 Enclosures RECEIVED MAR 2 7 1985 Alas~ oll & G~ co.s. g0mm.!.,~,~ion Armhorage ~t~... STATE OF ALASKA ~----_. ALASKA . __ AND GAS CONSERVATION CC ,ISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well OIL I~x GAS [] SUSPENDED [] ABANDONED [] SERVICE [] 2. Name of Operator 7. Permit Number ARCO Alaska, lnc. 84-151 3. Address 8. APl Number P. 0. Box 100360, Anchorage, AK 99510 50- 029-21176 4. Location of well at surface 9. Unit or Lease Name 21' FNL, 757' FEL, Sec.26, T11N, R9E, UN Kuparuk River Unit At Top Producing Interval 10. Well Number 1299' FNL, 1169' FWL, Sec.23, TllN, RgE, UM 2D-4 At Total Depth 11. Field and Pool 1084' FNL, 972' FWL, Sec.23, T11N, R9E, UM Kuparuk River Field 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. Kuparuk River 0i 1 Pool 127' RKBI ADL 25653 ALK 2579 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. 15. Water Depth, if offshore 16. No. of Completions 09/1 2/84 09/28/84 11/18/84 N/A feet MSL 1 17. Total Depth (MD+TVD) 18. Plug Back Depth (MD+TVD)19. Directional Survey I 20. Depth where SSSV set I 21. Thickness of Permafr°st 8644'MD,6242'TVD 8521 'MD,6147'TVD YES [] NO [] 2053 feet MD 1500' (Approx) 22. Type Electric or Other Logs Run DIL/SFL/GR/SP, FDC/CNL/GR, Cal, Gyro, CBL/VDL/GR/CCL, Temp. Log 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASINGSlZE WT. PER FT. GRADE TOP BOTTOM HOLESlZE CEMENTING RECORD AMOUNT PULLED 16" 62.5# H-40 Surf 117' 24" 204 sx Cold Set II 9-5/8" 36.0# J-55 Surf 3949' 12-1/4" 950 sx AS Ill & 500 sx Class G 7" 26.0# J-55 Surf 8603' 8-1/2" 460 sx Class G & 250 s~ AS I 24. Perforations open to Production (MD+TVD of Top and Bottom and 25. TUBING RECORD interval, size and number} SIZE DEPTH SET (MD) PACKER SET (MD) None 3-1/2" 8243' 8208' 26. ACID, FRACTURE, CEMENT SOUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT& KIND OF MATERIAL USED 8288' - 8290' 200 SX Class G See atta~.hed Addm~dum. 27. N/A PRODUCTION TEST Date First Production J Method of Operation (Flowing, gas lift, etc.) I Date of Test Hours Tested iPRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE I GAS-OIL RATIO TEST PE.,OD ~ I Flow Tubing Casing Pressure CALCULATED=1~ OIL-BBL GASWICF WATER-BBL OIL GRAVITY-APl (corr) Press. 24-HOUR RATE 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. NONE RECEIVED "Naska Oil & Gas Cons. Comrnissioa 'Anchora[Te Form 10-407 GRUS/WC29 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE 29. NAME GEOLOGIC'MARKERS~ 'i'~ ' : Top Upper Sand Base Upper Sand Top Lower Sand Base Lower Sand MEAS. DEPTH TRUE VERT. DEPTH 8201' 8208' 8305' 8464' 5909' 5914' 5985' 6104' 30. FOI~IMXTION TESTS '. Include interval tested, pressure data, all fluids recovered and gravity, GOR, and time of each phase. N/A 31. LIST OF ATTACHMENTS Add~_nrh~m 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed (--]0~ ~ Title Associate 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". Farm I ADDENDUM WELL: 10/09/84 11/05/84 2/o5/85 2/06/85 2/11/85 2D-4 Arctic Pak w/41 bbls AS I, followed by 60 bbls Arctic Pak. 8521' PBTD Rn CBL/VDL/GR/CCL/Gauge ring f/8492'-6987'. Rn gyro f/surf to 8490'. Frac well in seven stages w/total of 328 bbls of gelled diesel & 2016# of 100 mesh & 13,944# of 20/40 mesh. RU WL, RIH w/Temp tl, tag fill @ 8336'. Put well on flow to CO. Frac well in 7 stages w/total of 328 bbls of gelled diesel, 2,016# of 100 mesh & 13,944# of 20/40 mesh. Drilling ~uperintendent R£CEIVED 'Alaska Oil &. C~as Cons. Cornrnissio. ~c~rage ARCO Alaska, Inc. jr Post Office r=,..., 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 March 1, 1985 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT: 2D-4 Dear Mr. Chatterton' Enclosed is an addendum to the 2D-4 Well History to include with the Well Completion Report dated 01/30/85. If you have any questions, please call me at 263-4944. Sincerely, Gruber Associate Engineer JG/tw GRU4/L203 Enclosure RECEIVED MAR 0 8 1 85 AJaska 0il & Gas Cons. Commis$ioil Anchorage ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCornpany ARCO Alaska, Inc. Post Office Bo.. ~00360 Anchorage, Alaska 99510 Telephone 907 276 1215 February 5, 1985 Mr. C. V. Chatterton Commi s s i oner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT' 2D-4 Dear Mr. Chatterton' Enclosed is a Well Completion Report for the subject well. you have any questions, please call me at 263-4944. Sincerely, Gruber Associate Engineer JG/tw GRU4/L120 Enclosure If ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany ~'--' STATE OF ALASKA ALASKA ~__.AND GAS CONSERVATION CO. ,ISSION 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. 84-151 3. Address 8. APl Number P. 0. Box 100360, Anchorage, AK 99510 50- 029-21176 4. Location of well at surface 9. Unit or Lease Name 21' FNL, 757' FEL, Sec.26, TllN, R9E, UM Kuparuk River Unit At Top Producing Interval 10. Well Number 1299' FNL, 1169' FWL, Se¢.23, TllN, RgE, UM 2D-4 At Total Depth 11. Field and Pool 1084' FNL, 972' FWL, Sec.23, TllN, R9E, UN Kuparuk River Field 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. Kuparuk River Oi 1 Pool 127' RKBI ADL 25653 ALK 2579 17'. Total Depth (MD+TVD) 18. Plug Back Depth (MD+TVD) 19. Directional Survey 20. Depth where SSSV set I 21. Thickness of Permafrost 8644'MD,6242'TVD 8521 'MD,6147'TVD YES [] NO [] 2053 feet MDI 1500' (Approx) 22. Type Electric or Other Logs Run D IL/SFL/GR/SP, FDC/CNL/GR, Cal, Gyro, CBL/VDL/GR/CCL 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 16" 62.5# H-40 Surf 117' 24" 204 sx Cold Set II 9-5/8" 36.0# J-55 Surf 3949' 12-1/4" 950 sx AS Ill & 500 sx Class G 7" 26.0# J-55 Surf 8603' 8-1/2" 460 sx Class G & 250 s: AS I 24. Perforations open to Production (MD+TVD of Top and Bottom and 25. TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) None 3-1/2" 8243' 8208' 26. ACID, FRACTURE, CEMENT SOUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT& KIND OF MATERIAL USED 8288' - 8290' 200 SX Cia,ss G 27. N/A PRODUCTION TEST Date First Production J Method of Operation (Flowing, gas lift, etc.) I Date of Test Hours Tested iPRODUCTION FOR OIL~BBL GAS-MCF WATER-BBL CHOKE SIZE IGAS-OILRATIO TEST PERIOD I~ I Flow Tubing Casing Pressure CALCULATED=k OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press. 24-HOUR RATE .~i 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. NONERECEIVED Alaska 0il & Gas Cons. C0mmissi0r~ Anchorage Form 10-407 GRU3/WC57 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE 29. 30.' . ! - : ~ ,:: :. ,:-.- . ~f .::' . ~ i~~ .- -. :~ ',' _ : ..~ . . . ' :: ~ GEOLOGICMARK~RS ' . ......... i:- ~-t - ::FORMATi'ONTESTS . . NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. Top Upper Sand 8201' 5909' N/A Base Upper Sand 8208' 5914' Top Lower Sand 8305' 5985' Base Lower Sand 8464' 6104' 31. LIST OF ATTACHMENTS W~ll I-I~fnry (('nmnl~f{nn l'l~-~{l<;I mnH AdH~ndi,m ............ ~ ..... r .............. · ............ 32. I hereby certify that the foregoing is true and correct to the best of my knowledge '; 'LL' Associate Engineer Date Signed (~:f~'~;i/~ / L~]~ L, J~_-' Title i ~ " 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 ADDENDUM WELL: 10/09/84 2D-4 Arctic Pak w/41 bbls AS I, followed by 60 bbls Arctic Pak. MAR O 8 19-~5 A]a. ska Oil & Bas Cons. (:;ommissiorl Anchora~;e Drilling ~uPerintendent D&te ' ARCO 011 and Gas Company Well History- Initial Report- Daily Inetmctione: Prepare and submit the "Initial Report" on the first Wednesday after a well is spudded or work@var operations are started. Dally work prior to spudding should be summarized on the form giving inclusive dates only. District Alaska Field Kuparuk River Auth. or W.O. no. AFE 802956 ICounty, parish or borough North Slope Borough Lease or Unit ADL 25653 Title Completion State Alaska JWell no. 2D-4 Roll'n #4 AP1 50-029-21176 Operator ARCO Alaska, Inc. Spudded or W.O. begun 'jDate Complete I 11 / 11 / 84 Date and depth Complete record for each day reported as of 8:00 a.m. · 11/11/84 Hour 0030 Hrs. JARCO W.I. 56 24% IPrior status if a. W.O. 11/12/84 11/13/84 11/14/84 11/15/84 7" @ 8603' 8521' PBTD, 8644' TD, Tst'g lubr 10.2 ppg NaC1/NaBr Accept ri~ @ 0030 hrs, 11/11/84. RU DA, PU 4" csg gun, tst lubr. ND tree, NU & tst BOPE; OK. 7" @ 8603' 8521' PBTD, 8644' TD, RD BJ & sqz manifold RIH w/4" csg gun, perf 8288'-8290', POH. PU & RIH w/Bkr Model K-1 retnr, set @ 8138'. PU & RIH w/Bkr stinger on 3½" DP, tag retnr @ 8150' DPM. RU BJ pmp truck, est IR @ 2 BPM @ 2000 psi. M&P 200 sx C1 "G" w/.8% D-28, .3% D-31 & .1% D-6. Tail in w/5 bbls wtr, displ'd w/10.2 ppg brine. Pmp cmt to perf's @ 2 BPM/100 psi. Sqz 100 sx @ 1BPM/1400 psi. Sqz 40 sx .5 BPM/1550 psi. Shut pmp dn. SITP = 1450 psi. Wait 10 min. Sqz 15 sx. Shut pmp dn. SITP = 1450 psi. Wait 10 min, sqz 10 sx. Shut pmp dn. SITP = 1450 psi. Wait 10 min, sqz 15 sx. Shut pmp dn. Max & final press = 1450 psi. Sqz 180 sx, left 20 in csg. 7" @ 8603' 8521' PBTD, 8644' TD, POOH w/mill & retnr 10.2 ppg NaCl/NaBr POOH, LD Bkr stinger. PU Economill & DD, RIH to 8000', WOC. Fin RIH, tag retnr @ 8150' DPM, mill on retnr, POH. 7" @ 8603' 8521' PBTD, 8644' TD, RIH w/bit & scrpr 10.2 ppg NaC1/NaBr Fin POOH, LD mill & DD. PU bit, boot bskt, RIH, tag retnr @ 8150' DPM. Drl retnr, hart cmt f/8160' - 8519' DPM, circ hole cln. Tst perf's @ 8288'-90' to 1500 psi; OK. POOH, LD boot bskt. RIH w/bit & scrpr. 7" @ 8603' 8521' ?BTD, 8644' TD, Strap 3½" tbg 10.2 ppg NaC1/NaBr Fin RIH to 8519', circ brine untl cln, POOH, LD DP. tbg. RECEIVED Strap 3½" 1985 Alaska Oil & Gas Cons. Commission Anchorage The above is correct Signature ~1..~/~ ___,~...~_ ~ ~. For form preparation and dlatrill~tionT- see Procedurea Manual, Secflon~lO, Drilling, Pages 86 and 87. Date J Title I 11/20/84 Drilling Superintendent ARCO Oil and Gas Company Daily Well History-Final Report Instructions: Prepare and submit the "Final Report" on the first Wednesday after allowable has been assigned or well is Plugged. Abandoned, or Sold. "Final Report" should be submitted also when operations are suspended for an indefinite or appreciable length of time. On workovers when an official lest is not required upon completion, report completion and representative test data in blocks provided. The "Final Report" form may be used for reporting the entire operation if space is available. District ICounty or Parish Alaska I North Slope Borough Field ~Lease or Unit Kuparuk River I ADL #25653 Auth. or W.O. no. ~Title AFE 802956 I Completion Accounting State cost center code Alaska IWoII no. 2D-4 Roll'n #4 Operator ARCO Alaska, Inc. Spudded or W.O. begun Complete 11/16/84 11/17/84 11/18/84 11/19/84 2200 Oil Date and depth as of 8:00 a.m_ API 50-029-21176 A.R.Co. W.I. 56.24% Date 11/11/84 Complete record for each day reported irE,. I otal number of wells (active or inactive) on this cst center prior to plugging and I bandonment of this well I our I Prior status if a W,O, I ' 0030 Hrs. 7" @ 8603' 8521' PBTD, 8644' TD, Rig repair Start rn'g 3½" tbg. Shut dn f/rig repair. 7" @ 8603' 8521' PBTD, 8644' TD, Rig repair Shut dn f/rig repair.. 7" @ 8603' 8521' PBTD, 8644' TD, Bled dn press off contrl in 10.2 ppg NaC1/NaBr Repair rig. Rn 263 its, 3½", 9.3# J-55 IPC 8RD EUE compl string w/pkr @ 8208', "D" nipple @ 8231', TT @ 8243'. 7" @ 8603' 8521' PBTD, 8644' TD, RR ND BOPE, NU & tst tree to 5000 psi. Pmp 35 bbls diesel & 260 bbls of crude. Tst SSSV; OK. Drop ball & set Bkr FHL pkr. RR @ 2200 hrs, 11/18/84. 8644' 11/18/84 Single 8521' Rotary Old TD Released rig Flowing New TD Date IPB Depth Kuparuk S~nds I Kind of rig Type completion (single, dual, etc.) Official reservoir name(s) Classifications (oil, gas, etc.) Producing method Potential test data Alaska Oil & G~s Cons. OommissWn Well no. Date Reservoir Producing Interval Oil or gas Test time Production Oil on test Gas per day Gra ' 1 ii Pump size, SPM X length Choke size T.P. C.P. .~0'~/84 GOR corLr~c~e~- 1 ~lo,~j6~erinte..rfi~fe~[e date The above is correct Signature /~ For form preparat,o~ -andj~s~ribu--tion, see Procedures Manual, Section 10, Drilling, Pages 86 and 87. JDate JTitle ADDENDUM WELL: 10/09/84 11/05/84 2D-4 Arctic Pak w/41 bbls AS I, followed by 60 bbls Arctic Pak. 8521' PBTD Rn CBL/VDL/GR/CCL/Gauge ring f/8492'-6987' f/surf to 8490'. Rn gyro RECEIVED Alaska Oil & Gas Cons. Commission Anchorage Dril~intendent / D~te ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 February 4, 1985 Mr. C. V. Chatterton, Chairman Alaska Oil and Gas Conservation 3001 Porcupine Drive · Anchorage, AK 99501 Dear Mr. Chatterton' Attached is our notice of Field well 2D-4. If you have any questions, Commi ssi on intention to please call perforate Kuparuk me at 263-4253. Mike L. Laue Kuparuk Operations Coordinator MLL/kmc Attachment (In Triplicate) RECEIVED F E ~ 0 6 1985 Alaska 0il & Gas Cons. Commission Anchora.~e ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION CO,v~MISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL I-X] OTHER [] 2. Name of Operator 7. Permit No. ARCO ALASKA, INC. 84-151 3. Address P. O. BOX 100360, ANCHORAGE, ALASKA 99510 4. Location of Well SURFACE LOCATION' 21' FSL, 757' FEL, SEC. 26, T11N, R9E, UM BOTTOMHOLE LOCATION' 1099' FNL, 1143' FWL, SEC. 23, T11N, R9E, UM 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. 127' (RKB) I ADL 25653 12. 8. APl Number 50- 029-21176 9. Unit or Lease Name KUPARUK RIVER UNIT 10. Well Number 2D-4 11. Field and Pool KUPARUK RIVER FIELD KUPARUK RIVER OIL POOL Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate ~ Alter Casing [] Perforations [] Altering Casing Stimulate [] Abandon [] Stimulation [] Abandonment Repair Well [] Change Plans [] Repairs Made [] Other Pull Tubing [] Other [] Pulling Tubing [] (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). Per telephone conversation with Lonnie Smith (AOGCC) on 1/31/85, it is proposed that the "A" sand in Kuparuk well 2D-4 be re-perforated. Procedures call for the well to be perforated with a wi reline conveyed gun under a lubricator. Proposed Intervals (MD)' 8368-8375' (2 SPF) ANTICIPATED START DATE- February 1, 1985 Sub~ia~ W~k RECEIVED FE~ 0 6 ]985 Alaska 0il & Gas Cons. C0rrlrnJss/0n Anchorage 14. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed Title 0 P E R A T I 0 N S The space below for Commission use COORDINATOR Date 2/4/85 Conditions of Approval, if any: Approved by COMMISSIONER ~,pproved Cc~ P,.t~rn~l By Order of the Commission Form 10-403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate ARCO Alaska, Inc~'~ Post Office Box 360 Anchorage, Alaska 99510 Telephone 907 277 5637 RETURN TO: Date: 1/22/85 Transmittal No: PAGE 2 of 2 4988 ARCO ALASKA, INC. ATTN: Records Clerk ATO-1115B P.O. Box 100360 ~Anchorage, AK 99510 ~ransmitted herewith are the following items. Please acknowledge receipt and return one signed copy of this transmittal. 2D-4 CPL Cyberlook 2"/5" Density/Neutron "Raw" 2"/5" " " "Pot°'' . 2"/5" DIL-SFL/GR 8/29/84 Run 1 8000 - 8550 8/2?/84 Run t 8000 - 8592 8/29/84 Run 1 8000 ~ 8592 8/29/84 Run 1 3944 - 8618 2B-14 CPL Cyberlook 2"/5" Density/Neutron "Poro" 2"/5" " " "Raw" 2"/5" DIL-SFL 8/26/84 Run 1 7050 - 8550 8/26/84 " 7850 - 8558 8/26/84 " 7850 - 8558 8/26/84 " 3398 - 8584 /cat Receipt Acknowledged: B. Currier BPAE CheVron D&M Date :~.,-~ ': "' · -~ ,..~ . DISTRIBUTION . Drilling ' '~*~- Pssher State of AK .. Mobil Phillips Oil U~~ NSK Ops. J. Rat~ell Well Files ARCO Alaska, Im'~- ~ Post Office pox 360 Anchorage, Alaska 99510 Telephone 907 277 5637 RETURN TO: ARCO ALASKA, INC. ATTN: Records Clerk ATO-1115B P.O. Box 100360 horage, AK 99510 . f/~ransmitted herewith are the following items. and return one signed copy of this transmittal. Date: 1/22/85 Transmittal No: PAGE 1 of 2 4988 Please acknowledge receipt OH FINALS Schlumberger 2B-1 CPL Cybemlbok " 2"/5" Neutron/Density "Poro" " 2"/5'" " " "Raw" " 2"~5" DIL-SFL/GR 8/29/84 Run 1 5950 - 6595 8/29/84 Run 1 5950 - 6595 8/29/84 " 5950- 6595 8/29/84 " 2728 - 6621 2G-11 . CPL Cyberlook 2"/5" FDC-CNL/GR "Poro" 2"/5" " ""Raw" 2"/5" DIL-SFL/GR 9/16/84 Run 1 8000 - 8550 9/16/84 " 8000 - 8594 9/16/84' " 8000 - 8594 9/16/84 " 3316 - 8632 2D-7 CPL Cyberldok 8/27/84 Run i 6250 - 6756 " 2"/5" Density/Neutron "Raw" 8/28/84 " 6250 - 67'56 " 2"/5" " " "Poro" 8/28/84 " 6250 - 6756 " 2"/5" DIL-SFL/GR 8/28/84 " 3202 - 6786 " RFT "DIL-FDC-CNL-LSS-GR" " RFT Quicklook " 2"/5" LSS DT & Wavaforms Receipt Acknowledged: 8128184 " --- 8/28/84 " 6490.5-6619 8/28/84 " 6250- 6778 Date: B. Currier BPAE Chevron D&M . pISTRIBU~ Geology ~~ ' G.-~0'hio "~'"'""-"~ <~ :' Mobil Phillips.. Oil. ~..:_,,.. ~: ." "" ~ U -',,. NSK Ops. J. ~t~ell ~<.~: .:. ~ell Files . /cat ARCO Alaska, Inc. Post Office Box-~00360 Anchorage, Alaska 99510 Telephone 907 276 1215 January 10, 1985 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT' 2D-4 Dear Mr. Chatterton' Enclosed are the Well Completion Report and gyroscopic survey for the subject well. I have not received the portion of the 2D-4 Well History covering the completion details. When I do, I will forward a copy to you. If you have any questions, please call me at 263-4944. Sincerely, ~. Gruber Associate Engineer JG/tw GRU3/L48 Enclosures RECEIVED JAN ! 5 ].,°85 Alaska Oil & Gas Cons. Commission Anchorage ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany -~-" STATE OF ALASKA ~- ALASKA . AND GAS CONSERVATION CC ,ISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well OIL E~x GAS [] SUSPENDED [] ABANDONED [] SERVICE [] 2. Name of Operator 7. Permit Number ARCO Alaska, Inc. 84-151 3. Address 8. APl Number P. 0. Box 100360, Anchorage, AK 99510 50- 029-21176 4. Location of well at surface 9. Unit or Lease Name 21' FNL, 757' FEL, Sec.26, T11N, RgE, UM ~~'T.] Kuparuk River Unit At Top Producing Interval ~ VEriFiED t 10. Well Number 1299' FNL, 1169' FWL, Sec.23, TllN, RgE, UM !Surf ~ ! 2D-4 At Total Depth ia- P,.'~ 11. Field and Pool 108#' FNL, 972' FWL, Sec.23, T11N, RgE, UN Kuparuk River Field , t6. Lease Designation'andSerial No. Kuparuk River 0il Pool 5. Elevation127' RKBin feet (indicate KB, DF, etc.) ~'1 ADL 25653 ALK 2579 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. I 15. Water Depth, if offshore 116. No. of Completions 09/12/84 09/28/84 11/18/84I N/A 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 8644'MD,6242'TVD 8521 'MD,6147'TVD YES [~ NO [] 2053 feet MDI 1500' (Approx) , , 22. Type Electric or Other Logs Run DIL/SFL/GR/SP, FDC/CNL/GR, Cal, Gyro ,, 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE! WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 16" 62.5# H-40 Surf 117' 24" 204 sx Cold Set II 9-5/8" 36.0# J-55 Surf 3949' 12-1/4" 950 sx AS Ill & 500 sx Class G 7" 26.0# J-55 Surf 8603' 8-1/2" 460 sx Class G & 250 s~ AS I 24. Perforations open to Production (MD+TVD of Top and Bottom and 25. TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) None 3-1/2" 8243' 8208' 2~. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT& KIND OF MATERIAL USED , , N/A 27. N/A PRODUCTION TEST Date First Production I Method of Operation (Flowing, gas lift, etc.) I Date of Test Hours Tested PRODUCTION FOR OIL~BBL GAS-MCF WATER-BBL CHOKE SIZE' IGAs-OILRATIO TEST PERIOD II~ Flow Tubing Casing Pressure CALCULATED.I~ OIL-BBL GAS-MCF WATER~BBL OIL GRAVITY-APl (corr) Press. 24-HOUR RATE ~ 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. NONE RECEIVED 3AN 1 5 19 5 Alaska Oit & Gas Cons. commission Anchorage Form 10-407 GRU3/WC03 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE . ': . ('- ,:,.: 'i ~'.. :'-::: ~':' :.: .'i!i ':':"i'- ~'"'¥:' '~' : :' :.! : ~ ~' :7 '.,FORMA_i:i6N'TESTS-' '~ .... ':'","~:-- ~ : ,-:. GEOLOGIC MARKERS -, · NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. Top Upper Sand 8201' 5909' N/A Base Upper Sand 8208' 5914' Top Lower Sand 8305' 5985' ' ' Base Lower Sand 8464' 6104' 31. LIST OF ATTACHMENTS W~_ll Hi_~i:nrv_ Cvrn.~.onie .~l~rv~.v (? 32. I hereby certify that the foregoing is t~ue and correct to the best of my knowledge Signed ~)~d~_,) ~J~-)~'-" Title Associate Engineer Date 4 INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and Iog'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 (G L) 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". Fnrm lg~n7 ·~ ~ .~ ~ ~ North Slope 5o;ough Alas~ Fl~d ~: ?' e~ or Unit JWell no. Kupa~k River ; ~L 25653 ~l 2D-4 ~E ~ 802956 Drill Parker 19I AP1 50-029-21176 Operator ARCO Alaska, Inc. Spudded or W.O. begun [Date J,our Spudded 9/21/84 1800 hfs Date and deplh aa of 8:00 a.m; : 9/20/84 9/21/847 9/22/84 thru 9/24/84= 9/25/84 9/26/84 The above ia correot . For form preparation' ~d ~ri~ution, Complete recOrd for each day reported A.R.Co's W.I. 56.24% Prior status If a W.O. 16" @ 117' Moving rig. 16" @ 117' RU. 9-5/8" @ 3949' 3965', (3848'), Pmp top job Wt. 9.9, PV 17, YP 14, PH 10, WL 12, Sol 10 Accept rig @ 0600 hrs, 9/21/84. NU Hydrl & diverter lns. Spud well @ 1800 hrs, 9/21/84. Drl & surv 12¼" hole to 3965', 10 std short trip, C&C f/csg. RU & rn 99 its, 9-5/8", 36#, J-55 ERW BTC csg w/FS @ 3949', FC @ 3868'. Cmt w/950 sx AS III, followed by 500 sX C1 "G". Displ cmt w/291 bbls mud. CIP @ 0350 hrs, 9/24/84. ND diverter sys. RU to perform top job. 500', Assumed vertical 669', 4.1° N44.50W, 668.89 6 02 4.31N 4 24W · · · · · · 1002', 15.4°, N41.50W, 996.70, 62.12, 45.43N, 42.58W 1708', 35.7°, N34.50W, 1627.39, 370.74, 276.90N, 247.25W 2322', 48.9°, N34.50W, 2083.59, 779.58, 605.52N, 491.02W 2997', 51.0°, N38.SW, 2513, 1299, 1026N, 798W 3920'; 49.7°, N33.5W, 3101.51· 2009.12, 1606.52N, 1208..29W_ Wt. 9.1· P~::ll, YP 8, PH 11, WL 11, Sol 3 Fin top job. NU &tst BOPE; OK. TIE w/8½" BHA to 3856', tat csg to 1500 psi.- DO FC @ 3866', cat to FS @ 3949' + 10' new hole. Conduct formation tst to 12.0 ppg EMW. Drl 8½" hole to 4139', 48.6°, N31.5E, 3244.23 TVD, 2173.34 VS, 1745.89N, 1297.04 9-5/8" @ 3949' 6376', (2124'), POOH Wt. 9.3, PV 12, YP 9, PH 10.5, WL 11, Sol 4 Turbo drl & surv 8½" hole to 6376', lost 400 psi, POOH lk'g f/wshout. 4360', 48.5°, N33.50W, 3390.53 T~D., 2337.98 VS, 1885.60N, 1386.04W 5299', 48.7°, N42.50W, 3999.11TVD, 3052.48 VS, 2446.67N, 1828.49W 5920', 49.1°, N40.50W, 4407.58 TVD, 3519.74 VS, 2797.54N, 2137.79W 6301', 48.9°, N43.50W, 4657.54 TVD, 3806.84 VS, 3011.22N, 2330.20W tDate J ~tle ~'~/ 10110/84 Drillinm Suoerintendent ARCO Oil and Gas Company Daily Well History--Interim Instmctiena: This form is used during drilling or workover operations. If testing, coring, or perforating, show formation name in describing work performed. Number all drill stem tests sequentially. Attach description of all cores. Work performed by Producing Section will be reported on "Interim" sheets until final completion. Report official or representative test on "Final" form. 1) Submit "Interim" sheets when filled out but not less frequently than every 30 days, or (2} on Wednesday of the week in which oil string is set. Submit weekly for workovers and following setting of oil string until completion. District ICounty or Parish Istate Alaska North Slope Borough Field ILease or Unit Kuparuk River I ADL 25653 Date and depth Complete record for each day while drilling or workover in progress as of 8:00 a.m. Alaska IWell no. 2D-4 9/27/84 9~28~84 The above is correct 9-5/8" @ 3949' 7367', (991'), Turbo drlg Wt. 9.4, PV 16, YP 10, PH 10, WL 9.4, Sol 6 Fin TOH, found wshout @ ±5289'. PU 27 jts HWDP, TIH, drl 8½" hole f/6376'-7367' 6301', 48.9°, N43-[/2W, 4657.54 TVD, 3806.84 VS, 3011.22N, 2330.20W 6610', 49.7°, N42-1/2W, 4859.04 TVD, 4040.48 VS, 3182.55N, 2489.96W 7043', 48.6°, N42-1/2W, 5142.26 TVD, 4367.34 VS, 3424.03N, 2711.24W 9-5/8" @ 3949' 8346', (979'), Drlg Wt. 9.8, PV 19, YP 13, PH 10, WL 7, Sol 8 Drl & surv 8½" hole to 8346'. 7575', 46.4°, N43-1/2W, 5501.67 TVD, 4758.53 VS, 3710.89N, 2978.74W 7923', 46.8°,-N42-1/2W, 5741.64 TVD, 5009.36 VS, 3894.83N, 3150.28W RECEIVED N 5 ] 85 Alaska Oil & Gas Cons. Commission Anchorage IDate 10/10/841Tme Drilling Superintendent For form preparation and distribution see Procedures Manual Section 10, Drilling, Pages 86 and 87 " RCO Oil and Gas. Company Daily Well History-Final Report Instructions: Prepare and submit the "Final Report" on the first Wednesday after allowable has been assigned or well is Plugged, Abandoned, or Sold. "FlOral Report" should be submitted also when operations a~spended for an indefinite or appreciable length of time. On workovers when an official test is not required upon completion, report completion and represen~ data in blocks provided. The "Final Report" form may be used for reporting the entire if space is available. operation ~:~:~ ? ~ :: Accounting cost center code District Alaska Field Kuparuk Sands Auth. or W.O. no. AFE 802956 Parker 191 · Operator ARCO Alaska, Inc. Spudded or W.O. begun Drill ICounty or Parish Lease or Unit Title State North Slope Borough Alaska Well no. ADL 25653 2D-4 Drill Date and depth as of 8:00 a.m. Old TD 9/29/84 thru 10/01/84 Released rig API 50-029-21176 IA.R.Co. W.I. Fotal number of wells (active or inactive) on thisI ~ost center prior to plugging and 56.24% ~bandonment of this well 9/30/84 / 1558 hrs Complete record for each day reported 7" @ 8603' 8521' PBTD, (298'), RR 10.2 ppg NaCl/NaBr Drl & surv 8½" to 8640', C&C, CBU, 12 std short trip, C&C. RU Schl, rn DIL/SFL/GR/SP f/8618'-3944' & FDC/CNL/GR f/8592'-8000', CAL f/8592'-7200', FDC/CNL/GR f/8592'-8000'. RIH, precautionary rm f/8496'-8644', C&C f/csg. RU & rn 216 its, 7", 26#, J-55 w/FC @ 8522', FS @ 8603'. M&P 460 sx C1 "G" w/.8% D-60, .2% D-46 & 3% KCl. Displ w/317 bbls, 10.2 ppg NaC1/NaBr, bump plug. CIP @ 1558 hrs, 9/30/84. ND BOPE, NU & tst tree to 3000 psi. RR @ 2100 hrs, 9/30/84. New TD Date 2100 hfs - 9/30/84 Classifications (oil, gas, etc.) Oil PB Depth Kind of rig Type completion (single, dual, etc.) Single official reservoir name(s) Kuparuk Sands RECEIVED JAN 1 5' 1985 Alaska 0il &~Gas Cons. Commission 8521 ' Rotary Producing method Flowing Potential test data Well no. Date Reservoir Producing Interval Oil or gas Test time Production OII on test Gas per day Pump size, SPM X length Choke size T.P. C.P. Water % GOR Gravity Allowable Effective date corrected The above is correct For form preparation and distribution, ~ see Procedures Manual, Section 10, Drilling Superintendent S UB.$ URFA CE DIRECTIONAL SURVEY F~'~ UIDANCE [~'~ ONTINUOUS r-~OOL Company Well Name Field/Location ATLANTIC RICtt,FI,EL,D CO, MPANY , 2D-4 (21' FNL, 7,57' FEL, 526, ~(UPAR.UK. NORTH SLOPE. ALAS~,. ._ Job Reference No. 69805 Logged By: MCBRIDE RECEIVED JAN 1 5 1985 Alaska 0il & Gas Cons. Commission Date On DE~-O5-1 Computed By: STEV EHS GCT DIRECT]{]NA[, SURV.F.Y CUSTOMER [,,,liSTING FOR ARC() ALASKA, INC, 2D-4 KUPARUK NO~TH SLbPE, ALASKA SURVEY DATE: 4-hlTV-84 Ei,iG ], NE~;I~: ~{cBRIDE TUf)L [,OCATION: TANGKNTIAI'~- averaged (~eviation and azimuth INTF. PPOLATTON ~ VEIiTiCAI., S~CTION: H~3t(IZ, DIST, PRr~JE(.:TED O~TO a 'tARGET AZIMUTH OP' aaaTtt ~8 DiG 49 MIN 'WEST ARCO AI, ASKA, TNC, 2D'4 KUPARUK NORTti SI,OPE, AIuA,SKA COMPUTATIf]N [)Al ..~ ~"'[F..C'84 DATE L)F SURVEY: 4-NOV'84 KELLY BUSHING F. LEVATION: ENGINEERS McBRIDE INTERPOI,ATED VAI,UF.S FOR EVEN 100 FEET UF HISA~I.,IRED DEPTH TRUE SUB'SEA COURSF EAS[]RED VERTICAl, VERTICAL DEVIATION AZIMUTH DEPTH DEPTH DEPTH DEG i4IN DF, G PAGE 1 0,00 1DO,OD 200,00 300 o0 400~00 500 NO 600 oO 700 O0 800 O0 90O O0 0 O0 '127,00 100 O0 27,00 127,00 FT 200 O0 300 O0 400 O0 500 O0 599 97 699 76 799,09 897,60 VERTICAL DOGLEG. RECTANGULAR COORDINATES HORIZ, DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST, AZIMUTH FEET DEG/IO0 f'EE~ FEET FEET DEG SIN 73 o0 1.73 o0 ~73 O0 373 O0 472 97 572 76 672 O9 770 0,00 0,02 -0,06 zO.lO 0,17 -0.08 1,74 8,00 19,48 36,58 867,02 14 53 963,72 18 12 O0 11.84,9~ 1057,02 21 5 O0 1277 09 11.50,09 24 34 00 1366 89 1~39,89 27 35 O0 1454 09 1327,09 31 9 O0 1,538 20 1411,~0 33 52 O0 1620 42 1493,42 35 31, O0 1700 85 1573,85 37 23 00 1779 35 1652,35 ~9 11 1000 O0 904 92 11.0~ O0 10001~2 1~00 1300 1400 1500 1600 1700 1800 1900 2000.00 1855,81 1728,81 41 6 2100,00 1.929.83 1802.83 43 23 2200.00 2001 06 1.874,06 45 39 300,00 2069 5l 194~,51 48 2 ~400,00 2134 62 200t,62 50 39 2500.00 219'1 53 2070,53 50 57 2,600 O0 2260.41 2133,41 51 6 2700~00 2323,24 2196.2,t 50 58 2800~ oO 2386,20 2259,90 51 7 2900,00 244.8,82 2321,82 51 15 3000 oO 2511,44 2384,44 51 9 3100100 2574.22 2447,22 51 5 3200.00 2637'26 2510.2~ 50 43 3300,n0 2700,65 2573,65 50 31 3400,00 2764,27 2637,27 50 24 3500.o0 P827.8g 2700,89 50 33 3600,00 2891.51 27U4.51 50 29 3700 O0 2955.06 2828.06 50 31 3800~00 .]018.67 2891,67 5u 28 3900.~0 30fl2.02 2955,62 50 3 40 5R W 50.50 4.0 4 W 88 09 42 14 W 121~60 41 28 W 1.60,26 39 58 ~ 204,23 N'40 16 W 253,12 38 21 W 307.18 37 48 W 364.10 37 21 W .423,49 37 3 W 485'41 0,00 0,24 0,18 0 46 0 42 0 48 2 53 2 94 3 O2 3,48 3 67 3 03 3 34 3 52 3 O0 3 89 1'69 1,94 1.,84 1,81 2 26 2 52 2 09 '2 50 I 62 0 68 0 14 0 27 0 4.5 0 89 0,28 0.33 0 65 0157 0.16 0 39 0 49 0 45 0 44 0 31 0,00 N 0,15 N 0,27 N 0.40 N 0 45 N 0 56 N 2 12 N 28 60 N 0 O0 E 0 15 E 0 43 E 0 67 E 0 83 E 0 82 E 0,14 W 4,17 W 11,64 W 22'81W 0 O0 N 0 0 E 0 0 0 0 1 2 19 36 21 N 46 47 E 51 N 58 15 E 78 k 58 51 E 94 N 61 17 E O0 N 55 47 E 13 N 3 49 W 07 N 31 5 W 49 N 36 39 W 58 ~ 38 34 w 38 09 W 59 91 N 39 47 W 50 W 88 11 ~ 39 53 W 61 W 121 64 a 40 15 W 66 W 160 36 a 40 44 W 15 W 204 34 N 40 39 W 77 W 253 24 N 40 35 W 95 W 307 29 N 40 20 W 05 W 364 18 N 39 59 W 23 W 423 54 N 39 38 W 70 W 485 43 N 39 20 W 45,72 N 67,61N 56 92,8] N 78 121,49 N 104 155.00 N 133 192 31N 1.64 75 45 U 3 307 427 O0 N 346 38 W 481 02 N 386:39 W 537 81N 427'62 W 597 16 N 469 93 W 659 32 N 513 47 W 723 22 N 557 74 W 787 24 N 601 87 W 851 23 N 646 10 W 915 09 N 690,34 W 979,37 N 734,45 W 549,82 N 39 2 ~ 1 ~,99 N 38 46 W 87.09 N 38 29 W 759,89 a 38 12 W 835,68 N 37 54 W 913,30 N 37 38 W 990,95 N 37 23 W 1068,66 lq 37 Il W 1146~29 N 37 l'W 1224,17 N 36 52 ~ 1043,89 N 778 25 W 1302,07 N 36 42 W 1108,53 N 821~60 W 1379'81 N 36 32 W 1173.09 N 864 70 W 1457 34 N 36 23 W 1.237.08 N 908 15 W 1534 63 N 36 16 w 1300.74 N 951 73 W 1611 74 N 36 '11W 1364 37 N 995 37 W 1688 86 a 36 6 W 1428 03 N 1038 94 W 1765 98 N 36 2 W 1491 87 N 1082 38 W 1843 15 l~ 35 57 ~ 1555 84 N 1125 59 W 1920 27 N 35 52 W 1619 68 N 1168137 W 1997 11 N 35 48 ~ N 36 44 W 549,82 N 36 15 W 616 99 N 35 41 W 687 08 N 35 15 W 759 85 N 34 48 W 835 57 N 34 33 W 913 10 N 34 37 W 990 65 N 34 44 W 1068 23 N 34 34 w 1145 73 N 34 18 W 1223,46 N 3~ 5 W 1301 18 N 33 36 w 1378172 r{ 33 56 W 1456.04 N 34 20 W 1533.13 N 34 26 W 1610.05 N 34 25 W 1686,98 N 34 20 W 1763.90 N 34 6 w 1.840,87 N 33 55 W 1917.76 ~i 33 52 W 1094,35 ARCO AI, ASKA, 2D-4 KUP ;% RItK CObiPUTATIOI'~ [.)ATEi 4-DEC-84 PAGE 2 DA'rl,] OF SURVEY:. 4-NOV-84 KELbY BUSttlNG EbEVATION: 127.00 FT ENGINEERI McBRIDE INTERPOI~ATED VALUES FOR EVEN 100 FEET OF NEASURED DEPTH TRUE SUB-SEA COURSE EASURE[) VERTICAL VERTICAL DEVIATION AZIMUTH DEPTH £)~PTH DEPTH DEG .NIN DEG MIh VERTiCaL DOGDEG RECTANGUDAR COORDINATES HORIZ, DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/WEST DiST, AZIMUTH FEET DEG/IO0 FEET FEET FEET DEG ~IN 4000 O0 ]14.7 28 ]020 28 49 26 4~00 O0 3212 43 30~5:43 49 4 4~00 O0 3278 27 3151,~7 48 34 3217,37 430O O0 334.4 44.00 O0 3410 4500,00 3474 4600.00 3538 4700,00 3601 4800.00 3664 4900,00 3727 37 48 44 10 3283.10 49 9 '77 33q7.77 50 7 42 3411,42 50 43 41 ]474,41 51 11 07 3537.07 50 56 14 3600,14 50 50 N 34 28 W 2070.37 N 34 21 W 2146,01 N 34 22 W 2221'05 N 34 35.W 2295.87 N 34 59 W 2371 05 N 37 2 W 2447~20 N 37 58 W 2524,32 N 39 40 W 2601..97 N 40 32 W 2679,89 N 41 ! w 2757,45 0,91 0,41 0,31 1807 0,35 1869 1'15 1931 1 62 1993 1:88 2054 0,56 1,]6 2174 1,50 2233 1682,85 N 1211 13 W 2073 35 N 35 44 W 1745 40 N 1254 04 W 2149 20 N 35 41 ~ 55 N 1.296 40 N 1338 34 N 1381 17 N 1426 36 N 1473 69 N ]522 41N 1572 13 N 1623 5! w 2224 97 w 2299 93 W 2374 56 W 245 52 W 252~ 42 W 2605 50 W 2683 23 W 2760 45 k 35 39 W 46 N 35 30 w 82 U 35 35 W O8 N 35 35 W 17 N 35 39 W 70 N 35 45 W 43 N 35 52 w 75 N 36 0 W 5noo,no 3790 19 3663,79 50 2~ 5100.00 3854]43 3727,43 50 3q 5200.00 ]917'63 3790.63 50 57 5300.o0 3981.22 3854,22 49 7 5400 00 4047,17 3920 17 48 52 5500:00 41~2,79 3985 79 48 58 560o.00 4178.]5 405~ 35 49 7 5700 00 4243 54 4~16 54 49 28 5800:00 430B:26 4~8! 26 49 48 5900.00 4372.94 4245 94 49 24 N 42 8 W 2834,48 N 42 10 W 2911,48 N 42 14 W 2988,84 N 43 1~ W 3065,84 N 43 42 W 3140,75 N 43 27 W. 3215,94 N 43 25 W 3291.20 N 43 20 W 3366,79 N 43 8 W 3442,79 N 43 48 W 3518,83 0,37 3,~ 9 0 12 0'45 0~86 2290 70 N 1674 57 W 2837,51 N 36 10 W 347 89 N 1726 ]2 W 2914,24 N 36 19 W 405 31N 1778 37 W 2991.33 N 36 28 W 2462 13 N 1830 56 W 3068,07 N 36 37 W 516 48 N 1882 51 W ]142,70 N 36 47 'W 257! 16 N 1934 51 W 3217'93 N 36 57 ~ 2625 97 N 1986 44 ~ 3292,u7 N 37 6 W ~ 04 N 2038 57 W 3368,05 N 37 ~4 W 36 58 N 2090 79 W 3443,87 N 37 22 W 92 10 N 2143 08 W 3519,'75 ~ 37 30 w 6000,00 4437.99 4310,99 49 25 6100.00 4503.10 43'16,1,0 49 22 6200.00 4568,19 4441.19 49 24 6300 O0 4633,23 4506,23 49 28 6400:00 4698,16 4571.16 49 38 4762.9~ 4635,91 49 41 6500,00 6600,00 4827,55 4700.55 49 48 6700.00 4~92,~4 4765.14 49 44 6800 O0 4956,5l 4829.51 50 3 6900~00 5020.80 4893,80 49 55 43 59 W 3594,47 45 5 W 3669 97 44 57 W 3745145 44 50 W 3820,98 4.4 53 W 3896.61 44 47 W 3972 40 44 34 W 4048 30 44 24 W 4124 26 44 19 W 4200 43 44 13 W 4276 68 0,82 0,54 0'44 0,41 0'65 0.27 0 85 1~30 0.61 0,41 2846 80 N 2195 76 W 3595.23 a 37 38 ~ 2900 77 N ~249 12 W 3670 56 N 37 47 ~ 2954 3008 3062 3116 3170 3224 3279 3334 43 N 2302 84 W 3745 89 N 37 56 W 25 N 2356 44 W 3821 30 N 38 4 W 13 ~] 2410 11. W 3896 83 N 38 12 W 21N 2463.80 W 3972.54 N 38 19 ~ 46 N 2517,45 W 4048 38 h 38 27 W 89 N 2570,99 W 4124:30 N 38 33 W 58 N 2624,51 W 4200,45. N 38 40 W 4] N 2677,98 W 4276,68 N 38 46 W 7000.00 5084.78 4957 78 50 2 7100.00 5150,26 5023326 48 46 7200,0(.) 521.6,43 5089,43 48 lq 7300.o0 52~3 ]? 5156,32 47 26 7400 O0 5351~16 5224,16 47 11 7500'00 54~9 -t6 5~92 a6 46 45 7600.00 54~,2~ 5361,~8 46 22 770o.n0 5557.21 5430.21 46 lq 780n.00 56?6.50 5499.50 46 10 7900.0() 5695.81 5568.8% 45 45 N 44 15 W 4353 19 N 45 19 W 4428:36 N 45 5 w 4502.85 N 45 48 W 4576.72 N 45 bi W 4649,60 N 45 45 W 4722.~4 N 45 50 W ~794.14 N 45 45 W 4866 04 N 45 45 W 4937~62 U 45 4~ W 500q.18 3,18 0,22 0.69 1.06 1.84 0,61 0,32 1.tS 0,70 1,10 3389.53 N 2731,56 W 4353,20 N 38 51 W 3443 16 N 2784.80 W 4428.37 N 38 57 W 3495 89 N 2838,10 W 4502 90 N 39 4 w 3548 23 N 2890,89 W 457~80 N 39 10 W 3599 17 N 2943.83 W 4649'75 h 39 16 ~ 32 N 2995,98 W 4722.36 N 39 22 W 83 N 3048,06 W 4794,46 3650 3700 3751 3801 3851 N 39 28 W 34 N 3099,99 W 4866 46 N 39 34 W 67 N 3151,62 W 4938~16 N 39 39 W 95 N 3203,27 W 5009,84 N 39 44 ~ .) COaPIITAT'IF]N t)A't'EI 4-DFC-84 PAGE 3 ARC(') AbA,SKA, TNC, 2D-4 KI..JPA RIIK NORTH ~I.,OPE, AbASKA DATE OF $lJRVE¥: 4-NOV-84 KELbY B{,]SHING EhEVATION: ENGINEER: McBRIDE 127.00 FT INTERPOLATED VALUES FOR EVEN 100 FEE'r OF MEASURED DEPTH TR'UfC ~tJB-$EA COURSE EA~URFO V~RTICAIr,, VliRTYCAb DEVI[ATION AZIMUTH DEPTH DEPTH DEPTI,{ DEG MIN DEG VERTICAb DOGbEG SECTION SEVENITY FEET DEG/{O0 RECTANGULAR COORDINATES HOMIZ, DEPARTURE NORTH/SOUTH EAST/WEST DIST, AZIMUTH FEET FEET FEET DEG 8000 00 5765 66 5638,66 45 31 8100'00 58]6 45 5709,45 44 30 8200'00 5908 3] 5781,]3 43 35 8300'00 5981 1] 5854,13 42 43 8400'00 6055 42 592R,42 41 20 8500:00 6131 .j4 6004,34 ]9 57 8600,00 6207 99 6080,99 39 57 8644,00 6241 't2 6114,72 39 57 N 45 47 W 5080.20 N 44 44 W 5~50 36 N 43 9 W 5219 60 N 42 42 W 5288 O0 N 42 42 W 5354 79 N 42 2R W 5419 72 N 42 28 W 5483 N 42 28 W 5512 O1 1 09 1 52 4 70 1 09 2 07 0 O0 0 O0 0 O0 4001 45 N 335314, W 5220~65 N 39 57 W 4051 84 N 3399 62 W 5289,12 N 39 59 W 4101 08 N 3444 97 W 5356'99 N 40 I W 4148 99 N 3489 00 W 5421'00 N 40 3 W 4196 36 N ]532 36 W 5485,~6 h 40 5 ~ 4217,20 N 3551 44 W 551],40 N 40 6 W ARCO ALA,SKA~ !NC, 2D-4 K(~PARUK NOETH ,SLOPE, AbASKA TRU~ SUB'SEA COURSE; EASlJRED VF, RTICAL VERT,'[C~L DEV][ATION AZIMUTH DEPTH D~P.H DEPTH DEG ~IN DEG COMPUTATIOh DATF,,,',: ~-DE';C-U4 PAG~ 4 DATE OF SURVEY: 4-NOV-84 · KELLY BUSHING ENG~NEER~ McBRIDE iNTERPOLATED VAI,,UE6 D'OR EVEN lO00 f'E~T OF M~ASURED DEP'I' VERTICAL DOGLEG RECTANGULAR cnoNDINATE8 HORIZ, DEPARTURE $ECTION SEVERZTY NORTH/SOUTH ~AST/WEST D,iST, AZZ~[JTH FEET DEG/i O0 FEET FEET FEET DEG N 0 0 ~ 0,00 N 40 5~ W 5g,50 N 36 44 W 549,82 N 34 5 W 1301 18 N 34 28 W 2070~37 N 42 8 W 2834~48 N 43 59 W 3594,47 N 44 15 W 4353,19 N 45 47 W 5080,20 N 42 28 W 5512,01 0 O0 0,00 '127.00 0 0 1000 O0 994,92 867.92 14 53 2000 O0 1855.81 1728.8! 41 6 3000 O0 2511.44 2384,44 51 g 4000 O0 3147 28 3020.28 49 26 5000 O0 3790 79 3663.79 50 22 6000,00 4437 99 4310,99 49 25 7000,00 5084 78 4957,78 50 2 8000,00 5765 66 5638.66 45 31 8644,00 624! '12 6114,72 39 57 0 O0 3 67 2 26 0 28 0 91 0 3 18 1 O0 0 O0 0 O0 N 45 427 1.043 1,682 2290 2846 3389 3901 4217 0 O0 E 72 N 38 O0 N 346 89 N 778 85 N 1211 0 N 1674 ~0 N 2195 53 N 2731 81 N 3254 20 N 3551 127,00 FT 0 O0 N 0 0 E k 39 47 W ~ 39 2 W 07 N 36 42 W 35' N 35 44 W 51 N 36 10 ~ 23 a 37 38 ~ 20 a 38 51 W O0 N 39 49 ~ 40 N 40 b W 09 W 59 38 W 549 25 W 1302 13 W 2073 57 W 2837 76 W 3595 56 W 4353 61 W 5081 44 w 5513 ~RCO ALASKA, INC. 2D-4 KHPARUK SORTH SLOPE, AbAL~'A TRUE SUB-SEA COURSF EASt.IRED VERTI(..'.A[, VERTICAL DEVIATION AZIMUTH DEPTH DEPTH DEPI't DEG SIN PEG SIN COMPUTATION DATE: 4..DMC.,84 PAGE 5 · DATE OF SURVE¥I 4-NOV-84 · .... KELLY BUSHING ELEVATION: 127,00 FT ENGINE~RI McBRiDE INTERPO[.ATED VAI.UE$ FOR EVEN ~00 FEET OF sUB-SEA D~PTH VERTICAL DOGLEG RECTANGULAR COORDINATES HOR~Z. DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/WEST DfST, AZIMUTH FEET DEG/IO0 FEET FEET FEET DEG SIN 0.00 0.00 -127,00 0 0 N 0 0 E 27,00 27,00 -~00.00 0 7 N 21 16 E 127,00 127.00 0.00 0 12 N 57 55 E 227.00 227' O0 100.00 0 10 N 70 24 E 327,00 327'00 ~00'00 0 ] N 55 2] E 427,00 427~00 300,00 0 6 N 5 48 W 527.00 527,00 400,00 0 26 N 1.0 53 W 627,06 627,00 500,00 2 58 N 39 12 W 727,36 72'7'00 600.00 5 50 N 40 24 W 82~,22 827.00 700,00 9 3 N 40 35 W 800,00 12 40 900,00 16 30~ 1.127.!g 11000.00 19 15 3~ 1.227, 100,00 22 38 2 1127, 0 200,00 26 12 53 1427.00 1300,00 29 55 53 152'1 O0 1400.00 33 37 10 1.627 O0 1500,00 3540 03 1727 O0 ~600,00 37 57 01 1827 O0 1700,00 40 23 N 41 52 W N 40 12 W N 40 54 W U 42 27 W Ii 40 I1 w N 40 25 W N 38 30 w N 37 44, W N 37 17 W N 36 49 W 930.08 927,00 1033 30 1027.00 1355 1468 586 708 833 ~962 0 oo 0 O0 0 01 -O 10 -0 08 -0 13 0 O0 3,01 10,58 23,67 42,93 68.42 1.00 38 138 39 183 96 237 12 299 71 368 82 443 67 525 06 N 36 17 W 614,34 N 35 32 W 713,90 N 34 50 W 826 36 N 34 34 W 949:36 N 34 45 W 1072 86 N 34 26 W 11,96 36 N 34 o w 1320 44 N 33 51 w 1443 54 N 34 23 W 1565 Ob N 34 25 W 1685.90 2096 12 1.927,00 1800,00 43 17 2237 35 202'1,00 1000.00' 46 28 2388 03 2127,00 2000,00 50 24 2546 80 2227,00 2100,00 51 3 2705 97 2327,00 2~00,00 50 58 2~65 13 2427.00 2300,00 51 16 3024 fll 2527.00 2400.00 51 6 3183 79 2627,00 2500,00 50 46 3341.a8 2727,00 2600.00 50 34 3498,60 2827,u0 2700.00 50 33 N 34 13 W 1fl06.90 N 33 55 W 1927,83 N 34 12 W 2046,83 N 34 20 W 2162,75 N 34 31. W 2276,14 N 35 13 W 2390,65 N 37 40 W 2510 37 N 39 52 W 2633:88 N 41 I w 2757.28 N 42 7 W 2878.21 3655 86 2927.0o 2800.00 50 33 3813:10 3027.00 2900,00 50 25 3908.8~ 31~7.00 3000.00 49 29 4122 23 32~7.00 3100.00 49 0 4273:67 33~7 O0 3200.00 48 39 4425.q2 3t27:00 3300.00 49 27 4581.08 3627.00 3400.00 50 38 4740.ql 36~7.00 350¢).00 51 17 4899.78 372'1.00 3600.00 50 50 5056.84 38~7.()0 3700.00 5(! 27 0 O0 0 O0 0 51 0 13 0 74 0 34 2 15 1,95 3,08 3,55 3 32 :1 36 2 64 371. 3 21 3 95 I 83 I 95 I 7O I 85 2,49 2,34 2 17 '0 38 0 29 0 35 0 51 0 76 0 37 0 37 0,35 0 81 2112 047 0 4O 1,63 0.74 0,71 1.48 0,53 0,00 N 0,00 N 0,22 N 0.28 N 0,43 N 0,51 N 0,65 N 3,11N 8,87 N 18,82 N 33 35 N 52 50 N 76 97 N 000 E 0 O0 E 0 26 E '0 51 F; 0 67 E 0 85 E 0 81 E 0 9~ W 5 85 W 14 37 w 0 O0 N 0 0 E 0 0 0 0 0 1 3 10 23 O0 N 9O 0 E 34 N 48 48 E 58 N 60 43 E 80 N 57 17 E 99 N 58 4t E 05 a 51 1 g 25' N 16 38 W 63 iv 33 23 w 68 ~ 37 22 ~ 27 03 W 43 88 W 64 47 W 42 93 N 39 I W 68 43 N 39 53 W 40 N 39 56 N 105 139 180 342 407 25 N 89 46 N 120 4 N ~3 18 N 282 16 N 331 14 W 184 38 W 237 30 W 47 W 443 54 W 525 45 N 40 31W W 07 N,40 44 24 N 40 35 W 82 N 40 23 W 89 N 39 57 W 70 N 3932 W 07 N 39 9 W 478 88 N 384 82 W 614 34 h 38 47 W 559 65 N 443 27 ~ 713 93 N 38 22 W 651 74 N 508 753 17 N 578 85504 N 648 956 94 N 719 1059 9O N 789 1162 68 N 857 1263,52 M 926 1363,47 N 994 20 W 826 34 W 949 74 W 1073 10 W 1197 07 W 1321 70 W 1444 23 W 156~ 76 W 1687 1463 67 N 1063 25 W 1809.10 17 W 1930,38 79 W 2049,75 51 W 2165,98 75 W 2279,68 21 W 2394,47 99 W 2514,24 84 w 2637.54 1.564 1663 1759 1853 1947 2043 ~139 2233 2323 23 N 1131 37 N 1197 27 N 1263 11 a 1327 42 N 1393 33 N 1464 22 N 1.542 45 N 37 56 a 60 N 37 31 W 29 g 37 ll'W 01 N 36 55 w 37 N 36 40 W 81 a 36 24 ~ 64 ~ 36 14 ~ 78 N 36 6 w N 35 59 W ~ 35 52 w N 35 45 W N 35 41 ~ N 35 '37 W N 35 34 W N 35 38 w ~ 35 47 ~ O0 N 16~3.12 W 2760,58 N 36 0 W 17 N 1703,96 W 2881,08 h 36 15 W .RCO AI[.,A~SKA, TNC., .l. Ip ~I{IIK ;OR']'H SI,OPE, TRUF. SUB-SEA COU {:;'.5 F ;ASIIIiE[) VERTICAL VEPI']'CI~L DEVIATION AZIMUTH DEPTH DEPTH DEPTH DEG MIN OEG MIN CO~IPUTATIOh DA'I'E: 4-[)EC-84 PAGE 6 DATE OF SURVEY: 4,,,,NOV,,,,84 KELLY BUSHING ELEVATION: ENGINEER; McBRIDE INTERP()LATED VALUES FOR EVEN 100 FI~:ET C)F 'SUB','.SEh DEPTH VER'r.IcAb DOGLEG RECTANGULAR COORDINATES HORIZ, DEPARTURE SECTION' SEYERITY NORTH/8OUTH EAST/WEST DIST, AZIMUTH FEET DEG/1 O0 FEET FEET FEET DEG MIN .214.88 3927 O0 3800,00 51 0 i369.38 4027 O0 3900,00 48 46 i521'64 4127 O0 4000 00 48 58 i6'74,5~ 4227 i829.06 4327 i983.09 4427 i136,72 4527 49 23 i290 42 4627 ~444149 4727 i599.15 4827 e O0 4100,00 49 25 O0 4200,00 49 52 O0 4300,00 49 28 00 4400.00 O0 4500'00 49 28 00 4600.00 49 34 00 4700'00 49 48 i754 11 4927 O0 4RO0,O0 49 55 ~909 63 5027 00 4900,00 49 56 lob4 64 5127 00 5000,00 48 52 r215 89 52~7 O0 5100.00 48 17 1364 38 5327 O0 5200.00 47 14 1511 02 5427,00 5300,00 46 4~ 1656 18 5527,00 5400,00 46 ~800,73 5627.00 5500,00 46 10 t944,67 5727,00 5600.00 45 44 ~086.75 5827,00 5700,00 44 34 ~225 78 5927 O0 5RO0,O0 43 34 1362 O{ 6027 O0 5000,00 41 49 ~494 ]4 6127 O0 6000.00 39 57 ~624 79 6227 O0 6~00,00 39 57 ~644 O0 6241 72 6114,72 ]9 57 N 42 15 W 3000.37 " 43 45 W 3117'79 N 43 27 W 3232~21 N 43 24 W 3347 54 N 43 6 W 3464 94 N 43 55 W 3581 68 N 45 3 W 3697 69 N 44 50 W 3813 74 N 44 45 W 3930 29 N 44 34 W 4047,65 H 44 25 W 4165.45 ~ 44 13 W 4284.01 N 45 4 W 4401.89 N 45 3 W 4514,64 N 46 12 W 4623,63 N 45 49 W 4730.12 N 45 45 W 4834,53 N 45 45 W 4938'14 N 45 49 W 5040.91 N 44 59 W 5141,11 N 42 45 W 5237,33 N 42 36 W 5329,63 H 42 28 W 5416,09 N 42 28 W 5499,70 N 42 28 W 5512,01 0 56 0 59 0 29 0 17 0 47 0 54. 0 45 0 56 0 66 0 83 0 24 0 48 8 0 0 75 0 92 0 64 073 0 62 ! 45 1,49 1,33 0.00 '0,00 0,00 127,00 FT 249 258] 2667 2752 2837 2920 3003 3086 3170 00 N t945 01 N 2025 80 N 2105 54 N 2186 46 N 2268 08 N 235i 14 N 243 00 N 2516 74 W 3233 31 W 3348 96 W 3465 86 W 3582 86 W 3698 30 W 3814 W 4047 85 N 36 59 , 85 N 37 12 W' 98 N 37 25 W 46 ~ ~ 37 W 22 N 50 W 07 N 38 3 ~ 48 N 38 15 ~ 73 N 38 26 ~ 3254 47 N 2599 92 W 4165 47 N 38 37 3339 71 N 2683:12 W 4284 Ot N 38 46 W 3424 41 N 2765 88 W 4401 90 50 W 45 14 3504 3581 3655 3729 3802 3874 3944 27 N 2846 02 N 2924 92 N 3001 19 N 3077 03 N 3152 21 N 3226 77 N 3298 69 N 39 5 W 97 W 4623 76 N 39 14 ~ 74 W 4730 35 N &g 23 W 25 W 4834 91 N 39 31 W O0 W 4938 68 N 39 39 W 23 W 5041,63 N 39 47 , W 5142,03 ~ 39 54 W 4014 46 N 3365.25 ~ 5238,40 N 39 58 W 4082 52 N 3427,89 W 5330,80 N 40 1 W 4146 31N 3486,55 W 5417,37 N 40 3 W 4208 10 N 3543,11 W 5501.07 N 40 5 w 4217 20 N 3551,44 W 5513,40 N 40 6 W . 2413 86 N 178b 14 W 3002 83 N 36 29 W 84 N 1866 58 W 3119 82 N 36 44 W kRCO ALA.~KA, INC, LUPA RI~I{ ~ORTH .51.,(.'}P~, ALASKA MARKER TOP UPPFR SAND B~$E UPPER SAND TOP LOWRR BANI) BASF LOWER SAND PBTD TOTA6 O~PTH COMPUTATION [)ATE$ 4-DEC-84 1NTERPOI,ATED VAI~UES FOR CHOSEN H[}RIZON5 MEASURED DEPTH BICI,OW KB 8201 00 82O8 O0 8305 00 8464 00 8521 00 8644 00 PAGE 7 DATE OF SURVEY.~ 4-NOV-84 KEI..,bY BUSHING ELEVATION~ 127,00 ENGINE~]RJ MCBRIDE SURFACE LOCATION A~ ORIGIN: 21' FNL, 757' FEI., SEC 26. TIlN RgE, UM .! TVD RECTANG/LAR COORDI~A ES FRON KB SUB-SEA NORTH/SOUTH EAST/WEST 5909 05 5914 13 5984 80 6103 81 6147 44 624~,72 5782 05 5787 1] 5857 80 5976 81 6020 44 611,4 '12 4001 95 N 4005 47 N 4054 33 N 4131 87 N 4158 93 N 4217 20 N 3~5.3 61 ~ 3 56 90 W 3401 92 W 3473 34 W 3498 11 W 3551 44 W ~IRCO ~.LASKA~ TNC, ;UPAR[I~{ IO~TH SLOPE, ALASKA COMPUTATION DATEI 4-1)EC-84 PAGE 8 DATE OF 8URVE¥~ 4-NOV-84 KELLY BUSHING FbEVA~ION~ 127,00 FT ENGINEERI McBR1DE MARKER TOP UPPER SAND BASE UPPER SAND TOP DOWFR SAND BASE LOWER SAND PBTD TOTAL DEPTH MEASURED DEPTH BELOW KB 8201o00 8208,00 8305.00 8464.00 8521'00 8644,00 ORIGIN: 21' FNL~ 757' TVD FROM KB SUB-SEA 5909,05 5914 13 5984~80 6103,~1 6147, 4 6241.72 5782 05 5787 13 5857 80 5976 6020 44 6114 72 SURFACE LOCATION FEL. SEC 26. TllN, AgE, RECTANGULAR COORDINATES NORTH/SOUTH EAST/WEST 4001 95 N 4005 47 N 4054 33 N 4131 87 N 4158 93 N 4217 20 N 3353 61 ~ 3356 90 W 3401 92 ~ 3473 34 W 3498 ll W 3551 44 W FINAL WELD LOCATION AT MEASURED VERTICAL VERTICAL DEPTH DEPTH DEPTI4 8644.00 624~.72 6114.72 HORIZONTAL DEPARTURE DISTANCE AZIMUTH FEET DEG 5513,40 N 40 6 W SCHLUMBEROER RRCO ALASKA, INC. ~'O-4 KUPRRUK NORTH SLOPE, RLRSKR NOVEMBER 4, ]984 TVW PLOT FROM OCT DATA JOB REFERENCE 69805; WELL' 2D-4 SURFACE LOCATION' 21' FNL, 757' FEL, S26, T11N, R9E, UM VERT'ICAL PROJECTION ,-..'~. ,.t-l'-t-- .'~?.-t-?-, -e.~,~-..i- -,~-~., ..... i....4 ........ 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"F i l_.L_.i._.~_.~..L4...~-_.i...:......i...,..~-...i-4-_~ i I ] ,-..L.~ ~ ~ ~ .Z~_ : i ...... :---'~.-~-.-H..-~-~-!..-H.-~.-H..-H--H-~-~-r., ½-H-,-H-H-.+-.t-.'.:--H--.t4---H--i---..:?--b-.'--.H. .--?...:-.?-~---:'F------;-?--? ....... T'-?'T'-';"-i--?-'~--'?'"?'--;'-F"r-?"?-"?--"?-%'"?' -'"-"?'"'y'-'?"'1""~'-y-~' _.'T- "'"-?'"?-'~']'4~'~-.-'-"'":'" '"?'"Y? '?'"?-'?"%-'?"'?'"---?--m--?---?---~-?-y-:---..----~--.-?--.-~-?,--~---y-y- '?'t'*~':?"T-~"T-t'I"-FT-~-?-T... "F~i-'..TM -;~"~'-~'? :.--T-7' F'T'T'~-:'?"~-?"7-?F~-~'-'Y~-T'-"-T'-'FT-T"?'"?Y:-~'~-Y~T'TTT~T'T-:-"~- '"?'"?'T":"T"'.'"t"?"'.:"T'T"~"T"* .'T-i~'i-T'~''' '?"?-?'.:'"~ -?~-t..-y r--T-T...~ ..~T-~.-T.-71-T--.~.y.-.--FT--T--T-~-TT-T. -~?--!-T--~---?-7--~L TT'7"':'T'T"..'-"'.:-T" '"~'-Y?'":-'.t."'~T'T'T" "7'""7'~'"I-?'?T-:'"i":'":'"m."'~'":~'F,-' '~I~II~I'IT.:'; ~ : ~; : :~: ~;~/~ ii .... , i ',:' 1'~'"'"'~'"7'~'"!-'?'"'FF""?'Fi';'"--:'"~"I NW II PROJECTION ON VERTICAL PLANE OF AZIMUTH ~21 ~:~LEI~ IN YERTICI~. I~TI-I~ HORIZ SCALE = 1/I000 IN/FT WELL: 2D-4 SURFACE LOCATION: 21' FNL, 757' FEL, S26, T11N, R9E, 'UM HORIZONTAL PROJECTION NORTH ~ REF ~ SCF~.£ = I/l~O0 IN/FT 400O -lO00 -2000 ~TH -~000 -7000 Surges orm to be inserted in each" rive" well folder to d~.eck for timely ccmpliance with our regulations. · O~erator, ~Vel 1' Name Reports and Materials to be received by: Date Requir.,ed Date Received Remarks · Ccmpletion Report Yes I ° Core. Description ~/~~.' . Registered Survey Plat y~ ~ --'//~8~ ~'~ ,,, Prod~ctidn Test Reports ~/f/~_~,~./~ ./' ARCO Alaska, In_ Post Office Box 1479 Anchorage, Alaska 99510 Telephone 907 277 5637 December 18, 1984 Mr. C. V. Chatterton State of Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Dear Mr. Chatterton: Attached following in duplicate are subsequent notices on the wells at the Kuparuk River Field: Well Action ~ Date Performed 1E-5 Fracture 11/15/8 1E-8 Stressfrac 12/3/84 1G-2 Stressfrac 11/22/8 1G-4 Acidize 12/4/84 1L-3 Fracture 10/28/8 2A-4 Stressfrac 12/8/84 2C-3- Perforate 10/27/8 2D-4 Perforate 12/5/84 2V-1 Conversion 11/8/84 2V-2 Conversion 11/8/84 2V-3 Conversion 11/8/84 2V-4 Conversion 12/8/84 If you have any questions, please call me at 263-4253. Mike L. Laue Kuparuk 'Operations Coordinator MLL/kmc Attachment (Duplicate) R£Crr..IV rr.D DEC 2 Alasl(a Oil & Gas Cons. commission Anchorage ARCO Alaska. Inc. is a subsidiary o! AllanlicRichfieldCompany STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL IX1 OTHER [] 2. Name of Operator 7. Permit No. ARCO ALASKA, INC. 84-151 3. Address 8. APl Number P. O. BOX 100360, ANCHORAGE, ALASKA 99510 50-029-21176 9. Unit or Lease Name 21 ' 757 ' KUPARUK RIVER UNIT 4. Location of Well SURFACE LOCATION' FSL, FEL, SEC. 26, T11N, R9E, UM BOTTOMHOLE LOCATION' 1099' FNL, 1143' FWL, SEC. 23, T11N, R9E, UM 5. Elevation in feet (indicate KB, DF, etc.) 127' (RKB) 12. I6. Lease Designation and Serial No. ADL 25653 10. Well Number 2D-4 11. Field and Pool KUPARUK RIVER FIELD KUPARUK RIVER OIL POOL Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO' SUBSEQUENT REPORT OF' (Submit in Triplicate) Perforate [] Alter Casing [] Perforations Stimulate [] Abandon [] Stimulation Repair Well [] Change Plans [] Repairs Made Pull Tubing [] Other [] Pulling Tubing (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) (Submit in Duplicate) ~[~ Altering Casing [] [] Abandonment [] [] Other [] 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). On December 5, 1984, the "A" sands of Kuparuk well 2D-4 were perforated for production. After testing the lubricator to the well was shot with a wireline conveyed gun. Interval (MD)' 8322 8350 8382 8368 -8325' (1SPF) -8353' -8385' -8375' 2500 psi, 14. I hereby certify that the foregoing is true and correct to the best of my knowledqe. Signed ~ Title OPERAT I ON$ COORD ! NATOR The space below for Commission use Date 12/18/84 Conditions of Approval, if any: Approved by. By Order of COMMISSIONER the Commission Date Form 10-403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate :,.. ARCO Alaska, Post Office Box 100360 Anchorage, Alaska 99510 Telephone 907 276 1215 October 23, 1984 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT: Monthly Reports Dear Mr. Chatterton- Enclosed are the Monthly State Reports for the following wells' 2G-9 1L-8 2D-6 2B-16 2G-10 1L-4 2D-5 2B-15 2G-11 1L-3 2D-4 2B-14 2G-12 1L-2 2B-13 2G-13 Sincerely, Area Dril ling Engineer JBK/SH/tw. HILL/01 Enclosures RECEIVED NOV 0 Alas~.-,a 011 & Gas Cons. C0mmissl0;I Anchorage ARCO Alaska, Inc. is a Subsidiary of AllanlicRichlleldCompany ~ ~ STATE OF ALASKA ~ . '-~ ALASK.. ~)~ AND GAS CONSERVATION L ~N...,ISSION MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS 1. Drilling well~ Workover operation [] 2. Name of operator 7. Permit No. ARCO Alaska, Inc. 84-151 3. Address 8. APl Number P. O. Box 100360, Anchorage, AK 99510 50- 029-21176 9. Unit or Lease Name 21' FNL, 757' FEL, Se¢.26, TllN, RgE, UM Kuparuk River Unit i4. Location of Well at surface 5. Elevation in feet (indicate KB, DF, etc.) 127' RKB, Pad 90' 6. Lease Designation and Serial No. ADL 25653 ALK 2579 10. Well No. 2D-4 11. Field and Pool Kuparuk River Field Kuparuk River 0il Pool For the Month of September ,19 84 12. Depth at end of month, footage drilled, fishing jobs, directional drilling problems, spud date, remarks Spudded well ~ 1800 hfs, 9/12/84. Drld 12-1/4" hole to 3965', Ran, cmtd & tstd 9-5/8" csg, Performed top job, Drld 8-1/2" hole to 8640'TD as of 9/28/84, Ran logs, Ran, cmtd & tstd 7" csg, Secured well and RR ~ 2100 hrs, 9/30/84, 13. Casing or liner ru.n and quantities of cement, results of pressure tests 9-5/8" 36# J-55 HF-ERW BTC csg w/shoe ~ 3949' Cmtd w/950 sxs AS II I "G" cmt. 7" 26# J-55 HF-ERW BTC csg w/shoe @ 8603' Cmtd w/460 sxs Class "G" & 500 sxs Class 14. Coring resume and brief description N/A 15. Logs run and depth where run DIL/SFL/GR/SP f/8618' - 3944' FDC/CNL/GR f/8592' - 8000' Cal/ f/8592' - 7200' 16. DST data, perforating data, shows of H2S, miscellaneous data N/A RECEIVED NOV 0 5 Alaska 0ii & Gas Cons. Commission' I17. I hereby certify that the foregoing is true and correct to the best of my knowledge. /-~llt, tlUlCt~j5 NOTE--Re~r,,~n thfs f~or,~s required for each calendar month, regardless of the status of operations, and must be f¢led ~Zfn duplicate with the Alaska Oil and Gas~::onservatio~,~'ommission by the 15th of the succeeding month, unless otherwise directed. Submit in duplicate ARCO Alaska. In ,.c..~ ---.r:;.~, ..:: 9'.-s,~.i£ :, :~. ;.::on-.: .c.'[.7 2 , 37 Date: 10/19/84 Transmittal ~o: 4774 Return To: ARCO ALASKA, Inc. ATTN: Records Clerk ATO-1115B P.O. Box 100360 Anchorage, AK 99510 /T/rTransmitted herewith are the following items. Please acknowledge receipt and returm one signed copy of this transmittal. OH LIS Schlumbe~er Tape ~9576 2I)-4 9/29/84 Run 1 ~69551 2D-5 9/Z8/84 " ~69574 2B-14 9/26/84 " ~69579 2G-13 9/30/84 " #69555 1L-3 9/20/84 " 3935- 8641 3828- 7988 3388 - 8617 2830.5-7939 2027 - 8493.5 /cat Receipt Acknowledged: DISTRIBUTION B. Adams D & M F.G. Baker Drilling P. Baxter Geology BPAE Mobil Chevron NSK Operations W.V. Pasher G. Phillips Phillips Oil J.J. Rathmell R & D Alaska Oil & Gas Cons. commission Anchorage C. R. Smith State of Alaska Sohio Union Well Files TO: Receipt STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION 3001 Porcupine Drive Anchorage, Alaska 99501 (907) 279-1433 Stato o~' Al~.~,ka ~d Cas Conservation · 8001 Porcupine Drive Anchorage, Alaska ff)¢,501 of the following material which was transmitted via /~ / is hereby acknowledged: QUANTITY DESCRIPTION RECEIVED: DATED: Copy sent to sender YES _~ NO --__ MEMORAI',IOUM TO: THRU: FROM: Sta e of Alaska ALASKA OIL AND GAS CONSERVATION COMMISSION C. V. ~~er~on ., Lonnie C. Smith Commis s ioner Edgar W. Sipple, Jr~- Petroleum Inspector DATE: Sep~ 26, 1984 FILE NO: D. 5 I. 67 TELEPHONE NO: SUBJECT: Witness BOPE Test on ARCO's Kuparuk 2D-4, Sec. 26, TllN, R9E, LR,I, Permit No. 84-151, Parker Rig 191. Monday, S~tember 24, 1984: I traveled this date from ARCO' s. Kup~ruk:lL~2~ (Subje'c-t-'0f another report), to ARCO's Kuparuk 2D-4, Parker Rig 191, to witness a BOPE test. The drilling contractor was in the process of circulating to run casing. The BOPE test commenced at 12:00 pm and was concluded at 1:55 pm. There were no failures. I filled out the AOGCC BOPE inspection report which is attached to this report. In summary, i witnessed the BOPE test on ARCO's Kuparuk 2D-4, Parker Rig 191. At tacb~nent 02-00IA(Rev. 10/79) O&G t;4 t 5184 STATE OF ALASKA ALASKA OIL & GAS CONSERVATION COMMISSION B.O.P.E. Inspection Report Inspector Operator ~'~(~ k%e~%'/~ ~ · Location: Sec~T I1~ R ~f ~M · Drillin8 Contractor ~kf~F- Location, General ~.K Well Sign Reserve Pit Mud Systems Trip Tank Pit Gauge Flow Monitor Gas Detectors General Housekeeping ~ Rig 0 ~ BOPE Stack Preventer Pi.~Rams ,, Blind Rams Choke Line Valves H~. R~' Valve ~i£l L',in~_V~a ±v e s Visual Audio Test Pressure - Representative e mit Casing Set @ 3.¢~ Representative ACCUMULATOR SYSTEM Full Charge Pressure Pressure After Closure I~OO Pump incr. clos. pres. 200 psig 2. fOo psig. psig. ,~. min~ sec. Full Cha~e PK~ssur~Attained: _? min3 & sec. Controls: Master ~, Remote ~ Blinds switch cover /e~' Kel%y and F!oQr,,$,afe~t~ Upper Kelly&.-'~.Test Pressure Lower Kelly&W'~:~Test'Pres'sure: Ball Type~/~/~ Test Pressure Inside BOPs" 6)~Test P'reS"s'ur~ Choke Manifold l~.~.,?Te~res~sure No. flanges. Adjustable Chokes Hydrauically. operated chOke I Test Results: Failures '-'" ~ ....... - ....... Test Time / hrs. '~ · Repair or Replacement of failed equipment to be made within ,~//~' days and Inspector/ Commission office notified. Remarks :. /~-~,, ~,~J~£ ~ ~~~, · Distribution orig. - A0&GCC cc - Operator cc - Supervisor Inspecto August 24, 1984 M~. J. B. Kewin Area Drilling Engineer ARCO Alaska, !nc. P. O. Box 100360 Anchorage, Alaska 99510-0360 Re: Kuparuk River Unit 2D-4 ARCO Alaska, Inc. Permit No. 84-151 Sur. Loc~ 21'~, 757'FEL, Sec. 26, TllN, R9E, Btmhole Loc. 1099'FILL, I143'F%~, Sec. 23, TllN, R9E, t~. Dear Mr. Kewin: Enclosed is the approved application for permit to drill the above referenced well. ~ coring is conducted, a one cubic inch chip from each foot of recovered core is required. Samples of well cuttings and a mud log are not required. A continuous directional survey is required as per 20 AAC 25.050(b)(5). If available, a tape containing the digitized log info~ation shall be submitted on all logs for copying except experimental logs, velocity surveys and dipmeter surveys. Many rivers in Alaska and their drainage systems have been classified as important for the spawning or migration of anadromous fish. Operations in these areas are subject to AS 16.05.870 and the re~lations promulgated thereunder (Title 5, Alaska Administrative Code). Prior to commencing operations you may be contacted by the Habitat Coordinator's Office, Department of Fish and Game. Pollution of any waters of the State is prohibited by AS 46, Chapter 3, Article 7 and the regulations promulgated thereunder T~ (~tle 18, Alaska. Administrative Code, Chapter 70) and by the Federal Water Po!~utiOn Control Act, as amended. Prior to commencing operations you may be contacted by a representative of the Department of Environmental Conser~ation~. To aid us in scheduling field work, Please notify this office 24 hours prior to commencing installation of the blowout~prevention Mr. Jeffrey B. Kewin Kuparuk River Unit 2D-4 _August ~4, .~ 1984 equipment so that a representative of the Commission may be present to witness testing of the equipment before the surface casing shoe is drilled. !~ere a diverter system is required, please also notify this office 24 hours prior to commencing equipment installation so that the Commission may witness testing before drilling below the shoe of the conductor pipe. In the event of suspension or abandonment, please give this office adequate advance notification so that we may have a witness present. ruly yours, ~. V. ~nat tert6n Chairman of Alaska Oil and Gas Conservation Commission BY ORDER OF TH~'E COMLM!SS!ON be Enclosure cc: Department of Fish & Game, Habitat Section w/o enc!. Department of Environmental Conservation w/o encl. ARCO Alaska, Inc. ~ Post Office B~,~, 100360 Anchorage, Alaska 99510 Telephone 907 276 1215 August 15, 1984 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT: Kuparuk 2D-4 Dear Mr. Chatterton: Enclosed are: ° An application for Permit to Drill Kuparuk 2D-4, along with a $100 application fee o Diagrams showing the proPosed horizontal and vertical projections of the wellbore o A proximity plat o A diagram and description of the surface hole diverter system ° A diagram and description of the BOP equipment Since we estimate spudding this well on September 20, 1984, your earliest approval-will be appreciated. If you have any questions, please call me at 263-4970. Sincerely, ~ Area Drilling Engineer. JBK/JG/tw -~ GRU8/LI01 Attachments RECEIVED AUG2 2 ]~1t4 0il & Gas Cons. Commission Anchorage ARCO Alaska, Inc, is a Subsidiary of AtlanticRichfieldCompany -" STATE OF ALASKA ALASKA OiL AND GAS CONSERVATION COiv, MlSSlON ERMIT TO DRILL 20 AAC 25.OO5 la. Type of work. DRILL REDRILL DEEPEN lb. Type of well EXPLORATORY [] DEVELOPMENT OIL [~X DEVELOPMENT GAS [] SERVICE [] STRATIGRAPHIC ~ SINGLE ZONE J~ MULTIPLE ZONE~ % ' 2D-4 ~ 11. Field and pool ~ 2. Name of operator ARCO Alaska, Inc. 3. Address P. 0. Box 100360, Anchorage, Alaska 09510 4. Location of well at surface 21' FNL, 7571 FEL, Sec.26, T11N, RgE, UN At top of proposed producing interval 14221 FNL, 1402' FWL, Sec.23, T11N, RgE, UM At total depth 1099' FNL, 1143' FWL, Sec.23, TllN, RgE, UH 5. Elevation in feet (indicate KB, DF etc.) RKB 127', PAD 901 Lease designation and serial no. ADL 25653 ALK 2579 Kuparuk River Field Kuparuk River Oil Pool 12. Bond information (see 20 AAC 25.025) Federal Insurance Company Type Statewide Surety and/or number #8088-26-27 Amount $500,000 13. Distance and direction from nearest town 15. Distance to nearest drilling or completed 30 mi. NW of Deadhorse 2D-5 well280' @ surface feet 16. Proposed depth (MD & TVD) 8531' MD, 6242' TVD 19. If deviated (see 20 AAC 25.050) KICK OFF POINT 500 feet. 21 14. Distance to nearest property or lease line miles 21 feet 17. Number of acres in lease feet 2560 20. Anticipated pressures MAXIMUM HOLE ANGLE 48 o (see 20 AAC 25.035 (c) (2) Proposed Casing, Liner and Cementing Program 18. Approximate spud date 09/20/84 2739 psig@ 800F Surface 3144 _psig@ 6108 ft. TD (TVD) SIZE Hole Casing Weight 24" 16" 62.5# i 12~1/4" 9-5/8" 36.0# 8-1/2" 7,1 26. O# 22. Describe proposed program: CASING AND LINER Grade Coupling J-55 J-55 HF}ERW BTC Length SETTING DEPTH 3830' MD TOP TVD 80' 37' I 37' I 37' 37' I I 36' I 36' 8495' MD BOTTOM TVD 117' I 117' 3867' I 3107' I 8531' I 6242' I I QUANTITY OF CEMENT (include stage data) ± 200 cf 950 sx Arctic Set Iii & 500 sx Class G 300 sx Class G ARCO Alaska, Inc., proposes to drill a Kuparuk River Field development well to approximately 8531'MD (6242' TVD). Selected intervals will be logged. A 20", 2000 psi annular diverter will be installed on the 16" conductor while drilling the surface hole. The 13-5/8", 5000 psi, RSRRA BOPE stack will be installed on the 9-5/8" surface pipe. It will be tested upon installation and weekly thereafter. Test pressure will be 3000 psig (1800 psi for annular). Expected maximum surface pressure is 2739 psi. Pressure calculations are based on virgin reservoir pressure. Surface pressure is calculated with an unexpanded gas bubble at surface, including temperature effects. Casing will be tested to 2000 psi prior to releasing the drilling rig. Non-freezing fluids will be left in uncemented annuli through the permafrost interval. 2D-4 will be 280' away from 2D-5 at the surface. There are no closer wellbores anywhere downhole. Reserve pit fluids will be disposed of by pumping them down the 7" x 9-5/8" annulus of this well. The 7" x 9-5/8" annulus will be left with a non-freezing fluid during any (see attached sheet) 23. I hereby certify that the foregoing is true and correct to the best of my knowledge SIGN ED~'~ ~. ~ TITLE Area Drilling ThespacebelowdC(~m~ssi,~- f ~'~/' / CONDITIONS OF APPROVAL Samples required ~ Mud log required Directional Survey required e m,t m .O 'nu APPROVED BY Form 10-401 g~,, -71 on APl number 5o- O1.~- %4 ~7(~ Approval date E ~'l ~ ~ /.~)8/~,/~4 , SEECOVERL TTER FOR OTHER REQUIREMENTS mm~ss~on DATE GRU8/PD44 Submit in triplicate Permit to Drill 2D-4 interruptions in the disposal process. The well will be completed by the workover rig using 3-1/2", 9.2#/ft, J-55, 8rd tubing. Selected intervals will be perforated within the Kuparuk formation and reported on subsequent reports. A subsurface safety valve will be installed and tested upon conclusion of the job. After the workover rig has moved off location, this well will be fractured stimulated. RECEIVED Alaska Oil & Gas Cons. Commission Anchorage .-- ARCOiALASKA,---tNC. i --. PAD .2D i WELL :NO, : 41: RE~I SED ~ PROROSAL KUPARUK F'-]ELD.!~ NORTH~ ~ _ : /ASTM N WHIPSTOCI~,. INC,~ .... · ; ~ t ~ . i . --~ :'i ' ' ' ; ' ! ~ '~ ._ ~ , ' ' , ' I · : ! . SUREAClE ~ .... .... : ; - - - i ' i ' , T · i · -I , - · - i : ....... ..KOP_.._I_¥D 500_ HD=. 0 .... .'- : .... i I 9 ' i .... ---i ~ "- ' ~ ' ~...~' . - : . - ' - - 1 ::.. -"~? -.t :-: :_:_' j ' : ;iEOC; TVD~1914 TMD=2092 DEP=626 .... -~ i' TOP-UGNU SNDS TVD=212X TMDA2409 DEP-S61 ~ . . , "-.' .~ ...... -- ,f - ::-:-:-:---:J-::.-;:: ..... t---::-::-:-i ~ -.] ' ~ ~ -TOP W S^K SNDS- T,¥D=27~7- C: ? : - ; ! i : - ' ' ~ -m ' i ' i K-~ TVD=_3057~ TtID='3792 DEP=~885 < , , MD-_--3867--DEP=_-1-9-4:0 ..,~3- · ~ - ! - - i - ! - - ~ ....... ; _,...,~ I ~ ~'' '''. . ........ _ : .... ~ ~ : i I ' ' '' '- - AVERAGE ANGdE' ~ ~ - . : . . : . ~ .~ ~ : ~ . . : , . , ~ -' -' K i . i-- . DE~F:3867. ~ -5 TVD=4857 Tt'ID-6470 t -- i , { , -: - ~ ...... g ......... ;' ' 1 i i · ~ ..... ToP 'URPR SNDS' TIVD-5866 THD=7971 DEP'--4979' - - - ~ - - i - TOP. LOWR sNDS TVD=5993 .Tt'ID-~8160 DIEP=5.118 · - .- . . -, - -- !---B~SE-KUP-SNDS- TVD=B~Oe-TMD-=8331{ DEP=5245 _.~L; -__! '~E ;TD_ELDGG/NGjP_TJ___LT3/D=~4~__T/1D~SS31__DEP__.=_5393 ~ 'i; ;;' ' ' i' - ; ' : : .... , ....... i ........ ~ ....... ~... 3 .... ~ .... ooo.~ .._ ...... ' -- , --- T, ........ ~-' !-·--VER~- B'~LJ" '~ . ~ , , , . ~ ~ , , ,, , , z - ' i :' . l..- ; .... , ' nRCO-~LASr, A.-II~C. ~ ' PAD 2D, WELL'NO~'4'-REVISED PROPOSAE f KUPARUK:FIELD. NORTH iSLOPE. ALASKA- ~ ..... EASTMAN WHIPSTOCk. I~C ' - ' ': .... " ' ~ '-- ~ooo ~ ~ooo ~ .... : . . ) ~ I ~ .... : - ~ - - - ~ . . ~ ' ' f -- ~ _ .. , ,, ..... -- ~ ..... ~ ..... ' ~ ~ ; ' ' ' ~ ; ~ ] ' , . ; .... co. ., i ~.,iSURFACE. LOCAKI ON'K._{__ ;21' FICL. 7b"/'; FEL ! iSEC. ~6. 1') {N. i . I , : ? 6 Surface Diver:er System 1. 16"-2000 psi Tankco starting head. 2. Tankco quick connect assy. 16" X 20" 2000 psi double studded adapter. 20" 2000 psi drilling spool w/10" side outlets. 5. 10" ball valves, hydraulically actuated, w/lO" lines to reserve pit. Valves to open automatically upon closure of annular preventer. 6. 20" 2000 psi annular preventer. ?. 20" bell nipple. Haintenance & Operation Upon initial installation close annular preventer and verify ~hat bail valves have opened properly. Close annular preventer an¢ blow air through diverter lines every 12 hours. Close annular preventer i'n the event that gas or fluid flow to surface is cletected, if necessary, manually override and close ball valve to up, ind diverter line. Do not shut in well under any ¢ircumstance~, 16" Conductor RECEIVED AUG 2 Alaska Oil & Gas Cons. Commission Anchorage I'ANnUL.AR PREYE~I'~R · 9 DIAGRAM dl !3-5/8" SOOD PSi RSRRA BOP STACK 1. 16" - 2000 psi Tankco s;a~ing head 2. 11" -. 3000 psi 'casing hea¢ 3. Il" - 3000 psi x 13-S/B' - 5000 psi spacer spool 4. 13-5/B" - 5000 psi x 13-5/8' - SOO0 psi ~riliing spool 5. 13-5/8' - 5000 psi pipe rams 6. 13-5/B' - 5000 psi Urilling spool w/choke anO kill lines 7. !3-5/B" - 5000 psi' pipe rmms !3-S/8' - 5000 psi blinU rams g. 13-S/8" - 5000 psi annular L BLIND ) s ( ( i J~aska RECEIVED AUG 2 2 -!. FILL BOP STACK AND I~U~IFOLD WITH ARCTIC DIESEL. 2. CHECK THAT ALL HOLD DOWN SCREWS ARE FULLY RE'T~CT- ~-~ PREDE'FE~MINE DEPTH THAT TEST PLUG WILL SF. AT AND SEAT IN WELLHEJkD. RUN iN LOCK DOWN SC~S H~. 3. CLOSE ANNU~R PREVEN~R AND ~%~S ~S~~ OF ~~S. ~N~T ~ A~AIN~. ~S~ ~S ~. z~sz AUk CD~O.E~S ~D Z~O ~S] A~D ~0~'~0~ MINUT[$. 5. INCREASE PRESSURE TO 1800 PSI ~D HOLE FOR lO MINUTES. BLEED TO ZERO PSI. 6. OPEN ANNULAR PREVENTER AND CLOSE TOP SET OF PiPE 7. iNCEnSE PRESSURE TO 3000 PSi AND HOLD FOR ~. · P~SS~ ~~ OF ~ I~TION V~I~S. TO ZERO PSI TO TEST VALVES. TEST RE~!NING UNTESTED ~N!FOLD·VALVES, IF ANY, WITH 3~DO PSI UPST~E~, OF VALVE AND ZERO PSi DOWNSTRE~. BLEED SYST~ TO ZE~O PSI. 9. OPEN TOP S~ OF PiPE ~J AND CLOSE ~O~DM g~ OF PIPE R~. 10. INC~E PRESSURE T0 3DOD PSi AND HOLD FOR I0 MINUTES BLE~ T0 ZERO PSi. 1~. OPEN BO~DH S~ OF PIPE ~S. BACK OFF RUNNING JOINT A~D PULL OUT 0F HOLE. CLOSE BLIND R~S AND TEST TO 3DO0 PSI FOR 10 MINUTES. BLEED T0 PSI. 12. OPEN BLIND ~ ~D ~ECOVER TEST ' ' P.U~. ~KE SUAE ~NIFOLD AND LINES ARE FULL OF ARCTIC D:ESEL AND ALL VALVES ARE S~ iN D~ILLiNG POSiT:ON. 13. TEST STANDPIPE VALVES T0 3DOO PS~. 14. TEST KELLY CDC~ AND iNSIDE BOP 70 3000 PSi wiTH - KO~EY PUMP. ~5. RECORD T~ST INFORMATION ON BLOWO~ PAEYENTE~ FORM SIGN AND SEND TO DRILLING SUPERVISOR. 16. PERFO~ COMPL~E BO~E TEST ONCE A WEEK AND FUNC- TIONALLY OPE~TE BDPE DAILY. ACCUMULATOR CAPACITY TEST 1. CHECK AND FILL ACCUMULATOR RESERVOIR TO PROPER LEVEL WiTH HYDRAULIC F1. UID. 2. ASSURE THAT ACCUMULATOR PRESSURE IS 3000 PSi WiTH 1500 PSI DDWNSTREJU~ OF THE REGULATOR. 3. OBSERVE TIME, THEN CLOSE ALL UNITS SIMULTANEOUSLY AND RECORD THE TIME AND PRESSURE RE,*UklNING AFTER ;,l.L UNITS ARE CLOSED WiTH CHARGING PUMP OFF. 4. RECORD ON NADC REPORT. THE ACCEPTABLE LOWER LIMIT !S 45 SECONDS CLOSING TIME AND i200 PSI RE~LAiNING PRESSURE. 13-5/B" BOP ~ACK TEST Oil & Gas Cons. Commission Anchorage ARCO Alaska, Inc Post Office t~ox 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 July 5, 1984 Mrs. Elaine Johnson State of Alaska Alaska Oil & Gas Conservation Commi ssion 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT: Conductor As-Built Location Plat - 2D Pad Wells 1-4, 13-16 Dear Elaine: Enclosed is an as-built location plat for the subject wells. If you have any questions, please call me at 263-4944. Sincerely, Gruber Associate Engineer JG/tw GRU8/L25 Enclosure R CElVED i oUL 1 :I .4!aska Oil & Gas Cons. Commission Anchorage ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany DRILL ,51TE 2. D CONDUCTORS AS- BUILT LOCATIONS - ~' --'- - -T_- --_---.: , WELL ! Y -- 5,954,045.13 Lot. 70~17'07.8822. X = 529,129.90 Lon~, 149¢4§'$1.~88 153' FNL, 656'FEL EL. 89.7',0.G. 86.1' WELL Y · 5,954,089.31 Lot. 70°17'0B.:~185''' X -' 5E:9,089.~4 Long. 149°45'5Z.468'' 109' FNL, 677'FF..L EL. B9.6,0.G. 86.3' WELL WELL 4 WELL Y = 5,954,1~55.4Z Lat. 70°17~08.7=~;55'' X= 5~9~048.58 Long. t49045'53,645" 65' FNL, ?I?'FEI. EL. 89,7', O.G. 86.1' Y-' 5;954,177.42: Lot.?OOi7'og. iBBO" X= 57.9,008,09 Loeb. t49°~5'54.87.2'' ?-I° FNL~757'FEL . EL. Y= 15,955,508.~?. Lot. 70°17'O~.5842 X- 529,6~_4.74 Lon~.149°45~36.932'' I 6~?..' FNL, f44' FEL EL. 89.6 ~ WELL 14 WELL 15 -W-~LL- i6 Y ~ 5~953~552.61 Lut. 70~i7'05.0204'' X = 529~584.22 Lor,g. 149°45'$8. t08'' 647' FNL, 184'FEL EL. 89.8',0.$. 868' -, Y=5,953,596.7~ L;t. 70o17 ' 03 .4564'' X: 529~545.57_ Long. 149°45':~9.:287'' 603' FNL, 225' FEL EL. 89.6', O.G 87. I' Y = 5~953~640.$1 Lat. 70°17 '05.89[0" X = 5::'9,503.00 Long. 149°45'40.464" 559'FNL, 265'FEL EL. 89.§', 0.G.85.5~ CONDUCTORS 1-4lA t3-16 LOCATED IN PROTRACTED SECTION TOWNSHIP l! N RANGE 9E. UMIAT MERIDAN. - .,~ ~, BASIS OF ELEVATION tS TBM ~D-I~, BASIS OF IS ~NUMENTS ~D NORTH a ~DSOUTH PER LHD ' I / ~ j' ~' ~ -- ] ' i I 1~ M~~D ~ ~ACTICE LAND SUEVEYING 1N THE ~ATE OF ~K% ~ I~ , ~~ I~/ ~~' DRILL SITE 2-B ~~~ 1 ~e ~~'s'~L~ ~'~."~ ~NDUCTOR AS.~U,LT ~___ I ~--~, - .... O~t~an: J.B, ~ ~.n~:N~ 9.05~~ CHECK LIST FOR NEW WELL PERMITS Company Lease & Well No. ITEM APPROVE DATE YES NO REMARKS (1) Fee (2) Loc thru 8) (3) Admin .~ ~" ~ % "~ thru 11) '(10 and 11) (12 thru 20) 1 Is the permit fee attached .............................. 3. Is well located proper distance from property line ....... 4. Is well located proper distance from other wells .......... '' 5. Is sufficient undedicated acreage available in this pool . 6. Is well to be deviated and is well bore plat included ... "' 7. Is operator the only affected party .............................. (~--~,-- 8. Can permit be approved before ten-day wa~; .. ~ ' ....... ''..'' ...... './T~x_· e 10. 11. 12. 13. 14. 15. 16. 17. 18. 19. 20. 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 ~urface .... Will cement tie in surface and intermediate or production strings ... _~'~ Will cement cover all known productive horizons ................... Will surface casing protect fresh water zones ...i .......... '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 ........................... . ('21 thru 24) (6) Add: ff~.~ 21. 22. 23. 24. 25. Is a diverter system required ....................................... ~7'~ Arenecessary diagrams ofdiverterandBOP equipment attached ...... Does BOPE have sufficient pressure rating - Test to ~tZ~Z~ psig .. ~ff Does the choke manifold comply w/API RP-53 (Feb.78) ................... Additional requirements ............................................. Additional Remarks: 0 Geoiogy: Engi~ring: nw~g LCS~/-Y~nEW ~r~A ~ JKT ~JH ~ JA~/~_~ ~ _j rev: 12/08/83 6.CKLT INITIAL GEO. UNIT ON/OFF POOL CLASS STATUS AREA NO. SHORE Well History File APPENDIX Information of detailed nature that is not padiculady germane to the Well Permitting Process but is part of the history, file. To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically organize this category of information. ** DATE rAPE PREV ] ~'~:JS I i.)2 4 mmmm m mm ~m ~m~ m~ m ~ ! RA~G: 9E SECT: 26 STAT: ALASKA I .... C 'r A P E: l) E i'; "' :[ 't.' = " ... u;,~I'.T APl AP1 AP1 APl FIDE [;'17 OO OeO eo O t} :,.,,l ~,,, .... t') () 2 2 (: 0 I u 0 4 OliqM O0 126: ) 46 O 0 4 r,~V O0 010 Ol :::': :0' 0 GA, PI, O0 3~:(): ' 0:~ : 0:0 4. '~ : :: 0 4 GlO3 oo i~O:::: .02 (:; t ('13 ,:": 0 35 6 ()1 O' u ,:~ o CPs CPS 60:330 .,3,0 .... :: 0 ::':: 0 4 S P - 13 . 5469 (::4 R R Iri 0 ~!3 :1.. ;~ 574 [) '.~ F 0 NPFiI '~,9,5 ,'[ I )' ~',i C N L. SP ,,., 18.3,;[ 37 Gi,( N P a [ 31. 1383 r,., C .t,, h '.i' !¥! .... 1, ,I fi. ¢.;' 625 C t:~ l, i. 4 ~:: ,q,, 5. 00 4.8,1' 2,8770 0.G566 f,,F:AT 2 · 33 '? 9 7[: b ~ 1 ,t 8. '150 0 C ;~ .b I 5! 0. 2500 !5 . 'i f! 52 ]' [: I') 93. ? 500 (:;R 22 '24. C., 000 F C N L 5.531. t I [.,, ,x 93.75Or) CALI 2.93 '75 ii ~', ~ ,A '727. ~300 o 8. b 900 3.4512 3,3789 ! 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