Similar Documents at Byron |
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Category:LICENSEE EVENT REPORT (SEE ALSO AO
MONTHYEARML20045A6941993-06-0404 June 1993 LER 93-003-00:on 930511,turbine Emergency Trip Oil Header Pressure Low Alert Received Followed by Reactor Trip & Turbine Trip Above P-8.Caused by Actuation of Overspeed Trip Relay.Faulty Power Supply Board replaced.W/930604 Ltr ML20024H2041991-05-22022 May 1991 LER 91-005-01:on 900817,preoutage Mod Work Initiated W/O Proper Operability Review Due to Programmatic Deficiencies. Daily Const Work Authorization Sheet formalized.W/910522 Ltr ML20029A6461991-02-20020 February 1991 LER 90-007-01:on 900612,main Steam Line Isolation Sys Declared Inoperable Due to Failure to Test Manual Initiation Handswitch.Caused by Deficiency in Procedure.Procedures reviewed.W/910219 Ltr ML18041A2251990-10-0303 October 1990 LER 90-006-00:on 900903,reactor Containment Fan Cooler 2C, Low Speed Fan Breaker Did Not Close,Resulting in Train a Safety Injection Signal.Caused by Miscommunication & Procedure Deficiency.Procedure revised.W/901003 Ltr ML20029A6901990-09-13013 September 1990 LER 90-011-01:on 900819,reactor Trip Occurred Due to Power Surge.Caused by Lightning Strike.Rod Drive Sys Will Be Modified W/New Model of Power Supply Less Likely to Cause Reactor trip.W/910221 Ltr ML20044B0991990-07-12012 July 1990 LER 90-007-00:on 900612,discovered That Steam Line Isolation Handswitch on Main Control Board Panel 1PM06J Not Tested During Past Refueling Outages.Caused by Deficient Procedure. All Similar Equipment Will Be reviewed.W/900712 Ltr ML20044A9871990-07-11011 July 1990 LER 89-005-01:on 890501,diesel Generator 1A Failed to Load to 5,500 Kw within 60 as Required.Caused by Max Fuel Setting on Fuel Control Sys Being Set Too Low.Vendor Instructions Added to Maint procedures.W/900629 Ltr ML20043D5841990-06-0101 June 1990 LER 90-006-00:on 900503,as Surveillance Underway All Indication on Digital electro-hydraulic Computer Panel Was Lost.Caused by Failure of Ampere Fuse Due to Short Circuit in Pushbutton.Lighting Circuit rewired.W/900530 Ltr ML20042G9121990-05-0808 May 1990 LER 87-012-01:on 870408,component Cooling Pump 1A Tripped When Surge Tank Level Dropped to Low Level Pump Trip Setpoint.Caused by Breakdown in Communication.Mod to Component Cooling Sys completed.W/900507 Ltr ML20042E1561990-04-0606 April 1990 LER 90-003-00:on 900307,individual Cell Voltage for Cell 53 Found to Be at 2.11 Volts,Contrary to Tech Spec Limit.Caused by Electrician Using Improper Acceptance Criteria Format & Inadequate Mgt Review of surveillance.W/900406 Ltr ML20006F7161990-02-16016 February 1990 LER 90-001-00:on 900118,determined That Containment Purge Isolation Sys Not Demonstrated Operable 100 H Prior to Start of Core Alterations.Caused by Cognitive Personnel Error. Task Force Formed to Review Tech Specs.W/900109 Ltr ML20006E1161990-02-0909 February 1990 LER 90-001-00:on 900118,during Functional Surveillance on Steam Generator Pressure Channel 526,channel 525 Spiked Low, Causing Reactor Trip & Safety Injection.Caused by Failure of Pressure Transmitter.Transmitter replaced.W/900126 Ltr ML20006D7401990-02-0505 February 1990 LER 87-004-01:on 870225,inadvertent Safety Injection Occurred During Maint Troubleshooting.Caused by Cognitive Personnel Error by Control Sys Technician Involved. Disciplinary Action Taken & Counseling done.W/900124 Ltr ML20005E2391989-12-26026 December 1989 LER 89-003-01:on 890227,area Radiation Monitor 2RT-AR012 Failed Automatic Checksource Test,Actuating Containment Ventilation Isolation Alarm.Caused by Faulty Detector. Detector Replaced & Monitor Returned to svc.W/891221 Ltr ML19327B9021989-11-0303 November 1989 LER 89-009-00:on 891005,conflicting Info Re Signals That Initiate Automatic Isolation of Steam Generator Blowdown Lines Found.Caused by Preservice Design Implementation Deficiency.Lines Isolated & Procedure changed.W/891103 Ltr ML19354D4681989-11-0101 November 1989 LER 89-008-01:on 890830,one Auxiliary Feedwater Suction Pressure Transmitter Calibr Not Head Corrected & Bases of Original Setpoints Not Questioned.Caused by Inadequate Procedures & Setpoint calculations.W/891101 Ltr 1993-06-04
[Table view] Category:RO)
MONTHYEARML20045A6941993-06-0404 June 1993 LER 93-003-00:on 930511,turbine Emergency Trip Oil Header Pressure Low Alert Received Followed by Reactor Trip & Turbine Trip Above P-8.Caused by Actuation of Overspeed Trip Relay.Faulty Power Supply Board replaced.W/930604 Ltr ML20024H2041991-05-22022 May 1991 LER 91-005-01:on 900817,preoutage Mod Work Initiated W/O Proper Operability Review Due to Programmatic Deficiencies. Daily Const Work Authorization Sheet formalized.W/910522 Ltr ML20029A6461991-02-20020 February 1991 LER 90-007-01:on 900612,main Steam Line Isolation Sys Declared Inoperable Due to Failure to Test Manual Initiation Handswitch.Caused by Deficiency in Procedure.Procedures reviewed.W/910219 Ltr ML18041A2251990-10-0303 October 1990 LER 90-006-00:on 900903,reactor Containment Fan Cooler 2C, Low Speed Fan Breaker Did Not Close,Resulting in Train a Safety Injection Signal.Caused by Miscommunication & Procedure Deficiency.Procedure revised.W/901003 Ltr ML20029A6901990-09-13013 September 1990 LER 90-011-01:on 900819,reactor Trip Occurred Due to Power Surge.Caused by Lightning Strike.Rod Drive Sys Will Be Modified W/New Model of Power Supply Less Likely to Cause Reactor trip.W/910221 Ltr ML20044B0991990-07-12012 July 1990 LER 90-007-00:on 900612,discovered That Steam Line Isolation Handswitch on Main Control Board Panel 1PM06J Not Tested During Past Refueling Outages.Caused by Deficient Procedure. All Similar Equipment Will Be reviewed.W/900712 Ltr ML20044A9871990-07-11011 July 1990 LER 89-005-01:on 890501,diesel Generator 1A Failed to Load to 5,500 Kw within 60 as Required.Caused by Max Fuel Setting on Fuel Control Sys Being Set Too Low.Vendor Instructions Added to Maint procedures.W/900629 Ltr ML20043D5841990-06-0101 June 1990 LER 90-006-00:on 900503,as Surveillance Underway All Indication on Digital electro-hydraulic Computer Panel Was Lost.Caused by Failure of Ampere Fuse Due to Short Circuit in Pushbutton.Lighting Circuit rewired.W/900530 Ltr ML20042G9121990-05-0808 May 1990 LER 87-012-01:on 870408,component Cooling Pump 1A Tripped When Surge Tank Level Dropped to Low Level Pump Trip Setpoint.Caused by Breakdown in Communication.Mod to Component Cooling Sys completed.W/900507 Ltr ML20042E1561990-04-0606 April 1990 LER 90-003-00:on 900307,individual Cell Voltage for Cell 53 Found to Be at 2.11 Volts,Contrary to Tech Spec Limit.Caused by Electrician Using Improper Acceptance Criteria Format & Inadequate Mgt Review of surveillance.W/900406 Ltr ML20006F7161990-02-16016 February 1990 LER 90-001-00:on 900118,determined That Containment Purge Isolation Sys Not Demonstrated Operable 100 H Prior to Start of Core Alterations.Caused by Cognitive Personnel Error. Task Force Formed to Review Tech Specs.W/900109 Ltr ML20006E1161990-02-0909 February 1990 LER 90-001-00:on 900118,during Functional Surveillance on Steam Generator Pressure Channel 526,channel 525 Spiked Low, Causing Reactor Trip & Safety Injection.Caused by Failure of Pressure Transmitter.Transmitter replaced.W/900126 Ltr ML20006D7401990-02-0505 February 1990 LER 87-004-01:on 870225,inadvertent Safety Injection Occurred During Maint Troubleshooting.Caused by Cognitive Personnel Error by Control Sys Technician Involved. Disciplinary Action Taken & Counseling done.W/900124 Ltr ML20005E2391989-12-26026 December 1989 LER 89-003-01:on 890227,area Radiation Monitor 2RT-AR012 Failed Automatic Checksource Test,Actuating Containment Ventilation Isolation Alarm.Caused by Faulty Detector. Detector Replaced & Monitor Returned to svc.W/891221 Ltr ML19327B9021989-11-0303 November 1989 LER 89-009-00:on 891005,conflicting Info Re Signals That Initiate Automatic Isolation of Steam Generator Blowdown Lines Found.Caused by Preservice Design Implementation Deficiency.Lines Isolated & Procedure changed.W/891103 Ltr ML19354D4681989-11-0101 November 1989 LER 89-008-01:on 890830,one Auxiliary Feedwater Suction Pressure Transmitter Calibr Not Head Corrected & Bases of Original Setpoints Not Questioned.Caused by Inadequate Procedures & Setpoint calculations.W/891101 Ltr 1993-06-04
[Table view] Category:TEXT-SAFETY REPORT
MONTHYEARML20217H5221999-09-30030 September 1999 Monthly Operating Repts for Sept 1999 for Byron Station, Units 1 & 2.With ML20217P6351999-09-29029 September 1999 Non-proprietary Rev 6 to HI-982083, Licensing Rept for Spent Fuel Rack Installation at Byron & Braidwood Nuclear Stations ML20217A1691999-09-22022 September 1999 Part 21 Rept Re Engine Sys,Inc Controllers,Manufactured Between Dec 1997 & May 1999,that May Have Questionable Soldering Workmanship.Caused by Inadequate Personnel Training.Sent Rept to All Nuclear Customers ML20212B9261999-08-31031 August 1999 Monthly Operating Repts for Aug 1999 for Byron Station,Units 1 & 2.With ML20210R3431999-07-31031 July 1999 Monthly Operating Repts for July 1999 for Byron Station, Units 1 & 2.With ML20210E2251999-07-21021 July 1999 B1R09 ISI Summary Rept Spring 1999 Outage, 980309-990424 ML20209G1751999-07-0808 July 1999 SG Eddy Current Insp Rept,Cycle 9 Refueling Outage (B1R09) ML20207H7941999-06-30030 June 1999 Rev 0 to WCAP-15180, Commonwealth Edison Co Byron,Unit 2 Surveillance Program Credibility Evaluation ML20207H8071999-06-30030 June 1999 Rev 0 to WCAP-15178, Byron Unit 2 Heatup & Cooldowm Limit Curves for Normal Operations ML20207H7851999-06-30030 June 1999 Rev 0 to WCAP-15183, Commonwealth Edison Co Byron,Unit 1 Surveillance Program Credibility Evaluation ML20207H7771999-06-30030 June 1999 Rev 0 to WCAP-15177, Evaluation of Pressurized Thermal Shock for Byron,Unit 2 ML20209H3711999-06-30030 June 1999 Monthly Operating Repts for June 1999 for Byron Station, Units 1 & 2.With ML20207H7561999-06-28028 June 1999 Pressure Temp Limits Rept (Ptlr) ML20207H7621999-06-28028 June 1999 Pressure Temp Limits Rept (Ptlr) ML20195J8001999-05-31031 May 1999 Monthly Operating Repts for May 1999 for Byron Station,Units 1 & 2.With ML20207B6481999-05-25025 May 1999 SER Accepting Revised SGTR Analysis for Byron & Braidwood Stations.Revised Analysis Was Submitted to Support SG Replacement at Unit 1 of Each Station ML20195B2591999-05-19019 May 1999 Rev 66a to CE-1-A,consisting of Proposed Changes to QAP for Dnps,Qcs,Znps,Lcs,Byron & Braidwood Stations ML20206R6991999-04-30030 April 1999 Monthly Operating Repts for Apr 1999 for Byron Station Units 1 & 2.With ML20195C7961999-04-28028 April 1999 Rev 2 to NFM9800233, Byron Station Unit 2 COLR for Cycle 8A (BY2C8A) M980023, Rev 2 to NFM9800233, Byron Station Unit 2 COLR for Cycle 8A (BY2C8A)1999-04-28028 April 1999 Rev 2 to NFM9800233, Byron Station Unit 2 COLR for Cycle 8A (BY2C8A) ML20205P7001999-03-31031 March 1999 Monthly Operating Repts for Mar 1999 for Byron Station,Units 1 & 2.With ML20205B5091999-03-26026 March 1999 SER Accepting Relief Requests 12R-24,Rev 0 & 12R-34,Rev 0, Related to Second 10-year Interval Inservice Insp for Byron Station,Units 1 & 2 ML20205C5101999-03-21021 March 1999 Revised Safety Evaluation Supporting Improved TS Amends Issued by NRC on 981222 to FOLs NPF-37,NPF-66,NPF-72 & NPF-77.Revised Pages Include Editorial Corrections ML20204G3831999-03-19019 March 1999 Safety Evaluation Accepting Second 10-yr Interval ISI Request for Relief 12R-11 M990004, Rev 0 to NFM9900043, Byron Unit 1,Cycle 10 COLR in ITS Format W(Z) Function1999-03-17017 March 1999 Rev 0 to NFM9900043, Byron Unit 1,Cycle 10 COLR in ITS Format W(Z) Function ML20206A8831999-03-17017 March 1999 Rev 0 to NFM9900043, Byron Unit 1,Cycle 10 COLR in ITS Format W(Z) Function ML20207M9231999-03-12012 March 1999 Amended Part 21 Rept Re Cooper-Bessemer Ksv EDG Power Piston Failure.Total of 198 or More Pistons Have Been Measured at Seven Different Sites.All Potentially Defective Pistons Have Been Removed from Svc Based on Encl Results ML20204H9941999-03-0303 March 1999 Non-proprietary Rev 4 to HI-982083, Licensing Rept for Spent Fuel Rack Installation at Byron & Braidwood Nuclear Stations ML20204C7671999-02-28028 February 1999 Monthly Operating Repts for Feb 1999 for Byron Station,Units 1 & 2.With ML20199G8271998-12-31031 December 1998 Rev 1 Comm Ed Byron Nuclear Power Station,Unit 1 Cycle 9 Startup Rept ML20205M7061998-12-31031 December 1998 Unicom Corp 1998 Summary Annual Rept. with ML20202F6181998-12-31031 December 1998 Cycle 8 COLR in ITS Format & W(Z) Function ML20206B4001998-12-31031 December 1998 Annual & 30-Day Rept of ECCS Evaluation Model Changes & Errors for Byron & Braidwood Stations ML20199E6371998-12-31031 December 1998 Monthly Operating Repts for Dec 1998 for Byron Station,Units 1 & 2.With ML20202F6021998-12-31031 December 1998 Cycle 9 COLR in ITS Format & W(Z) Function ML20196K6731998-12-31031 December 1998 10CFR50.59 Summary Rept for 1998 ML20207H7731998-11-30030 November 1998 Rev 0 to WCAP-15125, Evaluation of Pressurized Thermal Shock for Byron,Unit 1 ML20207H8011998-11-30030 November 1998 Rev 0 to WCAP-15124, Byron Unit 1 Heatup & Cooldown Limit Curves for Normal Operation ML20198D1501998-11-30030 November 1998 Monthly Operating Repts for Nov 1998 for Byron Nuclear Power Station,Units 1 & 2.With ML20196A4191998-11-19019 November 1998 Safety Evaluation Accepting QA TR CE-1-A,Rev 66 Re Changes in Independent & Onsite Review Organization by Creating NSRB ML20195F8321998-10-31031 October 1998 Monthly Operating Repts for Oct 1998 for Byron Nuclear Power Station,Units 1 & 2.With 05000454/LER-1998-018, Corrected LER 98-018-00:on 980912,inoperable Unit 1 DG Was Noted.Caused by Low Lube Oil Pressure Condition.Immediately Entered Into Lcoar for AC Sources TS 3.8.1.1,Action a1998-10-0909 October 1998 Corrected LER 98-018-00:on 980912,inoperable Unit 1 DG Was Noted.Caused by Low Lube Oil Pressure Condition.Immediately Entered Into Lcoar for AC Sources TS 3.8.1.1,Action a ML20207H7671998-10-0505 October 1998 Rv Weld Chemistry & Initial Rt Ndt ML20154L5501998-09-30030 September 1998 Monthly Operating Repts for Sept 1998 for Byron Nuclear Power Station,Units 1 & 2.With ML20197C9051998-08-31031 August 1998 Monthly Operating Repts for Aug 1998 for Byron Nuclear Power Station,Units 1 & 2.With ML20151Z9651998-08-31031 August 1998 Revised MOR for Aug 1998 for Byron Nuclear Power Station. Rept Now Includes Page 9 Which Was Omitted from Previously Issued Rept ML20238F6551998-08-28028 August 1998 SE Authorizing Licensee Request for Relief NR-20,Rev 1 & NR-25,Rev 0 Re Relief from Examination Requirement of Applicable ASME BPV Code,Section XI for First ISI Interval Exams ML20237E2331998-08-21021 August 1998 Revised Pages of Section 20 of Rev 66 to CE-1-A, QA Topical Rept ML20237B3361998-08-14014 August 1998 B2R07 ISI Summary Rept,Spring 1998 Outage, 961005-980518 ML20237B4841998-07-31031 July 1998 Monthly Operating Repts for July 1998 for Byron Nuclear Power Station Units 1 & 2 1999-09-30
[Table view] |
Text
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. , ,e^x Commonwealth Edison !
s Byron Nucirit St; tion -
j/ _
l 4450 North G:rman Church Rold ,
s Byron, Illinois C1010 i
-(
May 7,-1990-LTRt BYRON 90-0420 ;
Dear Sirs f
t l
The enclosed Licensee Event Report from Byron Generating Station is being .,
transmitted to you as a Supplemental Report to 87-12; Docket No. 50-454. -'
Since ely, s
l R.' Plenlewicz j! t l Stat.lon Manager ,<
l- Byron Nuclear Power Station ,
I RP/jr i
Enclosure Licensee Event Report No. 87-12 ,
i cci A. Bert Davis, NRC Region III Administrator .
W. Kropp, NRC Senior Resident Inspector INPO-Record Center CECO Distribution List ,
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r (0574R/0065R) '
~k 9005160274 900509 ,
PDR ALOCK 050004Q4- ,
s FDG , ,
LICEN$tE EVENT REPORT (LER)
Facility Name (1) Docket Number (2) Pace (3)
Bvron. Unit 1 01 51 01 01 01 41 51 4 01 l of! 0!4 ;
T5tle (4) - gggFgTY RELATED COMPONENT COOLING INOPERABLE DUE TO L0$$ OF WATER INVENTORY CAU$ED Event Date ($1 LER Number (6) Resort Date (7) Other Facilities involved (8)
Honth Day Year Year // $equential Revision Month Day Year Facility Names l Oceket Number (s) 77 ,/j/,/
I
// Number /// Number NONE 01 hi 01 01 of l l___
~ ~~~
.,j l 4 018 817 817 01 1 l 2 011 015 018 910 01$l010101 l l !
THl$ REPORT !$ $UBMITTED pVR$UANT TO THE REQUIPEMENTS OF 10CFR OPERATING d one y more M W _ M oW nd ( W, MODE (9) 6 20.402(b) 20.405(c) _ $0.73(a)(2)(iv) __ 73.71(b)
POWER _., 20.405(a)(1)(1) __ 50.36(ci(1) __ $0.73(a)(2)(v) .__ 73.7)(c)
LEVEL 20.40$(c)(1)(ii) 50.36(c)(2) .2_ 50.73(a)(2)(vil) Other ($pecify (101 0l0 g10 I_
20.405(a)(1)(iii)
_. 50.73(a)(2)(t) __ 50.73(a)(2)(viii)(A) in Abstract
/ / /,/,,/ / / / /,/,/,/,/,/ / //,/,/,/ /,/,/ /,/ / ,_ 20.405(a)(1)(iv) ,,._ 50.73(a)(2)(ii) _ 50.73(a)(2)(viii)(D)* below and in
/ /
//}/}/}////j/}/}/}/}////}/}/}/j/j/}/// _ 20.405(a)(1)(v) _ _ 50.73(a)(2)(ill) .__ 50.73(a)(2)(x) Text)
LICENSEE CONTACT FOR TH15 LER (12)
N;me TELEPHONE NUteER AREA CODE
.1. Schreck. Operatino Enoineer Ext. 2216 8l115 213141-l514141 l; E0MPLETE ONE LINE FOR EAEH COMPON N FAILURE DEStRIBED IN THIS REPCBT (13)
CAU$E $YSTEM COMPONENT MANUFAC- REPORTABLE CAU$C SYSTEM COMPONENT MANUFAC- REPORMBLE TURER TO NPRDS TURER TO NPRDS 1 I I I l l I I i l l l l 1 1 I I I I I i l i l l l l l SUPPLEMENTAL REPORT EXPECTED (14) Expected tlanth l Du l Year Submission
lyes (If v & iQmplete EXPECKD SUBMIS$10N DATE) X l NO l !l l AB$iRACT (Limit to 1400 spaces, i.e approximately fif teen single-space typewritten lines) (16)
On April 8,1987, at approximately 1725. a contracted maintenance crew began work on the Limitorque motor operator of the "1A" Residual Heat Removal (RH) Heat Exchanger Component Cooling Water Outlet Isolation Valve, ICC9412A. This valve was a point of isolation for work on the RH Heat Exchanger, which required it to be drained of Component Cooling Water (CC). shift Operating personnel granted permission, with the understanding that if it became necessary for the crew to stroke the valve, they would obtain authorization. The maintenance crew stroked the valve in order to release torque on the motor gear set.
it is unclear whether they actually received authorization or not. This allowed Component Cooling Water to back flow through ICC9412A to the Heat Exchanger and out the drain. This caused the (CC) surge tank to reach the low level CC Pump Trip. The "1A" CC Pump tripped at 1726 on April 8, 1987. The surge tank is common to both trains, consequently, both trains of Component Cooling were inoperable. The leak was discovered and isolated. The system was then re-filled, and the "1A" CC Pump re-started. The total time both trains were inoperable was 17 minutes. The cause of the event was a communication breakdown between the maintenance crew and Shift Operating personnel. Contracted maintenance personnel now work under the same procedures as station personnel which requires proper authorization prior to stroking any valves, in addition, a modification has been completed to provide automatic makeup water to the Component Cooling system in the event of a leak. The safety significance was minimal. RCS Temperature never exceeded 85'F.
There was one similar previous occurrence reported in LER 455/86-01.
I I 1
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,. _ _ LI([t(K[_ EVENT REPORT (LER) TEXT CONTINUATION FAttfITY NAME (1)' DOCKET NUPSER (2) LER NupeER (6) Pane (3) i d
Year //j // Revision j ff ' Sequential f
/
/// Number /j/j
// Number avren. Unit 1 0 1 5 1 0 1 0 1 0 l 41 51 4 817 - 01 1 12 - 011 012 0F 014 ll TEXT Energy Industry identification System (E!!$) codes are identified in the text as (xx)
A. PLANT CODEITIONS PRIOR TO EVENTt Byron Unit 1 Event Date/ Time. 04/08/87 / 1725
~
MODE 6 - Refueling Rx power 0%... RC$ (AB) Temperature / Pressure 85'r /de-eressurhRd
- 8. Q[1CRipT10N OF EVENT:
The "1A" Residual Heat Removal (RH)[SP) Heat Exchanger was Out of Service (00$) for gasket repleenment. -
The shell side, consisting of Component Cooling water (CC)[CC) was isolated and drained. . One of the points t of isolation of the 005 for CC was the RH Heat Exchanger CC Outlet Isolation Valve, ICC9412A.
The grease in Limitorque valve motor operators was scheduled to be changed out during the refueling outage. This activity was being handled by contracted maintenance personnel, supervised by utility management. Since this involved numerous Limitorques, the Work $vpervisor developed a plan with Operating j Management that each valve would be only taken Out of Service electrically for personnel protection. If it became necessary to mechanically stroke the valve the maintenance crew foreman would ask the $hift Engineer for specific autherlaation. This plan was consistent with $tation's work practices and programs.
At approximately 0842, on April 6,1987, the Work Supervisor (utility non-licensed) for the RH Heat Exchanger gasket replacement requested a temporary lif t of the mechanical portion of the Out of Service on ICC9412A in order to perform the grease change and gear box flush on the motor operator of ICC9412A. The Operating Shift Foreman (Itcensed) granted permission with the explicit' agreement that work was only to be performed on the motor and that the valve was not to be stroked open for any.reasor..
At approximately 1725, on April 8,1987, the contracted maintenance crew (non-licensed) began work on the valve. During the course of their work it bocas.e necessary to release the torque on the motor gear set which required stroking ICC9412A approximately half open. They stroked the valve. This allowed Component Cooling water to back flow to the RH Heat Exchanger, fill the empty Heat Exchanget, and pass through the open drain valve. The CC surge tank level dropped to the low level CC Pump Trip setpoint. The "1A" CC Pump, which was' running to support plant operations, tripped at 1726. The CC Surge Tank is common to both CC Trains, consequently both trains were inoperable at this time.
Shif t Operations, in response to the "1A" CC Pump Trip and Low Surge Tank level, dispatched an operator to
, investigate. He quickly determined that CC was draining into and out of the RH Heat Exchanger. He then closed "1A" RH Heat Exchanger Component Cooling Outlet throttle valve, ICC9507A, to isolate the leak, i
Water was.then restored to the surge tank and the "1A CC" Pump re-started. The total time both trains of CC were inoperable was 17 minutes. There were no safety system actuations.
l A Generating Station Emergency Plan Alert was declared and appropriate notifications made.
1 This report is required pursuant to 10CFR(a)(2)(vii). I I
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. . LIEENSEE EVENT REPORT (LER) TEXT EONTINLIATION
, FACILITY NAME (1) DOCKET NUPSER (2) LER NLNSER f 6) Pane (3) ;
Year /
fj/p/ $equential /p/p/ Revision [
/// Number p//
/ Number _
Byron. Unit 1 0 l B l 0 l 0 1 0 1 41 51 4 817 01 1 12 - 011 013 0F 014 l; TEXT Energy Industry Identification System (EIIS) codes are identified in the text as (xx)
C. (AUSE OF EVENT: l The root cause of this event was a communication breakdown between the contracted maintenance crew performing the work and Operating Shift personnel. l The contract maintenance personnel had been instructed to always receive permission from the $hif t Engineet-prior to manipulating the valve they are working on. The maintenance crew was interviewed and insist they did receive verbal permission to stroke ICC9412A. However, they do not remember who they talked to. shift operating personnel maintain that they never gave such permission. There was no requirement to document this permission in writing, Neither version could be corroborated.
i D. SAFETY ANALYSIS: '
Plant and Public safety were not affected. Loss of a heat sink for the Reactor Coolant System (RC$), ,
without loss of circulation, has a negligible effect for the short period of time the Ir/s occurred.
Reactor coolant temperature was maintained at approximately 85 degrees Fahrenheit through-out the event and RC$ forced re-circulation was maintained, via the operating RH train. The water level in the reactor cavity was greater than 23 feet, providing sufficient heat sink during the loss of Component Cooling. It would have provided suf ficient heat sink and cooling for an extended period of time if RH flow had been lost.
E. CQRRLCIIVE AET10NS:
Communications and proper work coordination between station maintenance personnel and Operating Shift personnel has been effective and does not warrant concern, consequently, corrective actions are focused on ,
contracted maintenance personnel.
As interim corrective action, contracted maintenance personnel have been re-informed of the requirement to obtain Shif t Engineer authorization prior to stroking any valve they are working on during the Limitorque motor operator grease enangeout.
The practice of requiring contracted maintenance personnel to get written authorization from the Shift Engineer was effective during startup operations. Contracted maintenance personnel now work under existing <
station procedures which require proper authorization prior to stroking any valves. The Out cf Service l program has been revised to give specific controls for work on a Limitorque valve. For contractor maintenance, an 00$ care will be placed on the valve so that specific authorization to operate the valve will be controlled by the Temporary Lif t Program or a second isolation point will be used so that the position of the valve being worked on does not affect the operation of the associated system.
A modification to the Component Cooling System has been completed to provide automatic makeup water to ,
maintain surge tank level. This would attempt to maintain water inventory in the event of a leak. I 1
This report &as placed in the Licensed Operator required reading program. In addition, this report was distributed to $tation Departments to be disseminated to respective department personnel.
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i0574R/0065R)
+ , , , ., , - - - ,
r-LICENSEE EVENT REPORT (LER) TEXT CDWTIMUATION FACILITY NAME (1) DOCKET NUMBER (2) LEn MunnEn (6) Pane (3)
' Year- /// Sequential /// Revision j fff fff
/// Number /// Number l svren. u' nit i o I s I o I o I o I al si 4 sir - of 1 12 - oli 014 .Or 014 ll TEXT Energy Industry Identification System (E!!$) codes are identified in the text as [xx] l 1'
- F. PREVIOU$ OCCURRENCES:
i LER NUMBER TITLE i
455-86-001 Both Trains of Component Cooling Inoperable Due to Personnel Error in a Relief Valve Setting.
G. COMPONENT FAILURE DATA: .
l a) $NUFACTURER NDPENCLATURE MDDEL Nut 91R MFG PART NUPBER ,
Not Applicable b) ELSULTS or NPRDS SEARCH!
Not Applicable i
-I i (0574R/0065R).